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205-162
Image Project Well History File Gover 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~ ©J`~ - 1 r!Q o~ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II III II III ^ Rescan Needed III II~III II II III III RESCAN !~,~Color Items: ^ Greyscale Items: DIG TAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: BY: ~ Maria Date: ~o,L,`6 J [) ~ /s/ ~ 1 ,~ 1 Project Proofing III 11111111111 I I III BY: Maria Date: D ~ /s/ Scanning Preparation ~ x 30 = + ~ =TOTAL PAGES ~ `~ (Count does not include cover sheet) BY: Maria Date: ~' ~~ ~ ~ /s/ ~/ Production Scanning Stage 1 Page Count from Scanned File: ~~ 3 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~~ D ~ /s/ ' `~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III (I'I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III IIII II 10/6/2005 WeA History File Cover Page.doc 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION h ❑ OR RECO I REPORT AND LOG la. Well Status: cm ❑ 20AAC 25.105 74.-- 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. ofCompletion`sr Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 12, 2011 205 - 162 / 311 - 053, 311 - 090 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 November 30, 2005 50 103 - 20517 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2918' FNL, 206' FEL, Sec. 24, T11N, R4E, UM December 19, 2005 CD4 - 208 Top of Productive Horizon: 8. KB (ft above MSL): 36.5' RKB 15. Field /Pool(s): 1602' FSL, 710' FEL, Sec. 24, T11N, R4E, UM GL (ft above MSL): Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1300' FSL, 2143' FWL, Sec. 13, T11N, R4E, UM 2500' MD / 2357' TVD Nanuq Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 378039 y- 5957494 Zone 4 12792' MD / 6177' TVD ADL 380077, 380075 TPI: x - 377522 y - 5956741 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 375176 y 5961758 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) 1647' MD / 1600' 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 36.5' 114' 36.5' 114' 42" Portland Type III 9.625" 40# L -80 36.5' 2594' 36.5' 2440' 12.25" 380 sx AS Lite, 235 sx Class G 7" 26# L -80 36.5' 7314' 36.5' 6164' 8.75" 190 sx Class G 3.5" 9.3# L -80 7169' 12782' 6143' 6177' 6.125" slotted liner 24. Open to production or injection? Yes ❑ No Hi 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" 2007' ✓ kill string none 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED y� , 2500' 15 bbl of 17 ppg Class G cement ,r ¢ g � �jO t 6 LU I1 < Kitk off / p l+ (�J / 6.76 cm-r- RtIcia..4., 4- 30 0 9r- G!,-ss 4 (: to 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7` 431. 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 0 Sidewall Cores Acquired? Yes ❑ No 0 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. PN NONE ' t4,' RBDMS MAY 1.0 2011 t & G Cam mission OA Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE N3S113 u " bmit original only /~ t . /3 • ll .�AnGtte ' , 16 6 28. GEOLOGIC MARKERS (List all formations and markers e•tered): 29. FORMATION TESTS NAME MD TVD Well tested? El Yes 0 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 1647' 1600' 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 Summary of Daily Operations, schematic (VJ 2, j 1 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265 - 6820 Printed Name G. L. Alvord Title: Alaska Drilling Manager Signature - (.. Phone 265 - 6120 Date 5(' kaa ti 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 Iv _< • WNS • CD4-208 C�oPhi . Well A riltytes Max Angle & MD TD At I ;is _ Wellbore APW WI Feld Name Well Status Inc! MD (kKB) Act Bien (BKB) [r,,,,,„f. 1 , {p ,. # 501032051700 [ NANUO I C) INJ 95 74 9,106.17 - __ 12,792.0 Comment 1925 (ppm) Date lAnnotation l End Date KB (ft) Rig Release Date SSSV WRDP Last WO l 44.03 12/24/2005 '° - - _' � [ .P• 2 T' T 9.2 ,AM '- ST31€ni4 ueL Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Ad _ .. Last Tag SLM 4.949 0 4/3/2011 Rev Reason: PUMP CEMENT, TAG Imosbor j 4/3/2011 Casing Strings_ HANGER, 23 - , Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H WELDED ?, Casing Description String 0... String ID ... Top (ROB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd ' SURFACE 9 5/8 8.835 37.1 2,594 3 2,440.2 40.00 L -80 BTC ._._.- Casing Description String 0... String ID .. Top (ROB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.151 34.9 7,314 2 6,166 9 26.00 L 80 BTCM __. .._ . _ . „ � . ;� � �; Casing Description S String 0... String ID .. Top (ttK6) Set Depth (i... Set Depth (T1/D) ... String WI... String .. String Top Thrd _ LINER 3 1/2 2 992 7,169.1 12,782 0 6,177.1 9.30 L-80 SLHT N / CONDUCTOR, Liner Details � v ( `� 37 -114 Top Depth j, (ND) Top Ind Nomi... Top MOB) (kKB) (e) Item Description Comment 10(in) �O 7,169.1 6,143.6 80.01 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 e. S NIPPLE, 2,102 IV , 7,182.1 6,146.0 81.35 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 T r I '' 7,185.2 6,146.5 81.38 HANGER BAKER 'DG' FLEX LOCK HANGER 4.400 w tiA 7,240.0 6,154.7 82.02 XO 4.5x3.5" 4.5" OD, 3.958" ID, 72.6#, L -80 x 3.5" 3.500 Di-ti 12 747.0 6,176 3 E8 75 BUSHING BAKER PACK OFF BUSHING 2.380 • suRFACE. Tubing Strings --ry i TUBING k- 3] 2 594 Tubing Description String O . String ID Top (ftKB) Set Depth (1.. Set Depth (ND) .. Str g Wt... String ... String Top Thrd P a 5x3 5" 3 12 2 992 I 2 2 5 7,191 0 I _ 6 147 4 J_ 9 30 L 80 EUEMOD 4:, Completion Details G '13.1) Top MOB) Top Depth (NTVDD) Top loci Komi... GAS LIFT 4,416 . _.. (kKB) C) Item Description Comment ID(in) Lir 22.5 22.5 -0.09 HANGER FMC TUBING HANGER 4.500 131.3 131 3 0.25 XO 4 5x3 5" 3.500 ` 26.51 NIPPLE CAMCO 'DS' NIPPLE 2,102.0 2,004.5 2.812 yr 6,684.6 5,985.1 61.24 PACKER BAKER PREMIER PACKER 2.875 GAS LIFT, 6,725.0 6,003.7 63.02 NIPPLE 3.5" HES'XN' NIPPLE w/2.75" NO GO 2.750 6,590 7,165.5 6,143.0 79.84 WLEG BAKER FLUTED WIRELINE ENTRY GUIDE w /SHEAR 2.970 TBG - Other In Hole !reline retrievable plugs, valves, pumps, fish, etc.) PUNCHES, Top Depth 6,661 ITVDI Top net Top (BOB) (BKB) (°) Description Comment Run Date ID (in) 6,660.5 5,972.9 60.18 TBG 2.0: TUBING PUNCH GUN, 6.5 GRAM CIRCULATION 3/24/2011 2.992 PACKER, 6,685 ___ - PUNCHES CHARGES, 4SPF, 0 DEG. PHASE. : ,.' 6,700.0 5,992.5 61.92 CMT Retainer PUMPED 15 BBLS OF 15.8 CLASS G CEMENT THROUGH 4/2/2011 CMT Retainer. 77 RETAINER SET AT 6700 CTMD, PULLED OUT OF 6,788 J ; RETAINER, PUSHED 50 BBLS CEMENT IN IA, PUMPED It (ADDITIONAL 15 BBLS IN 3.5 TUBING TO TOC TO 4935 NIPPLE, 6,725 _..___ _ _ ________ .. '.... CUT PLUG, Perforations & Slots 4,935 Shot Btm(TVD) Dens lit Top (ROB) glen (ftKB) MB) (Mat) Zone Date (eh- -- Type Comment 7,336 -0 12,747 G 6,167.6 6,176.3 12/23/2005 40.0 SLOTS SLOTTED LINER, alternating i c Notes: General sold /slotted pipe WLEG, 7.166 r, 8 Safety End Date Annotation __- 12/23/2005 NOTE TREE: FMC 4- 1 /76 ", 5,000 PSI - TREE CAP CONNECTION 7" OTIS 12/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NTERMEDIATE, 35 -7,314 5 g I Mandrel Details.. SLOTS, F. Top Depth Top Port 7336 -12747 `- `" A ' (fVD) Intl OD Valve Latch Sine TRO Run Stn To ROB {MB) C) Mak Model (in) Type Type (in) (psi) Run Date Can... 1 4,415.8 4,056.9 25.84 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/5/2006 2 6.58 ] 5.t36.9 57.63 CAMCO KBMG t GAS LIFT DMY BK 0.000 0.0 4/5/2006 LINER, 7,169 - 12,782 TD (CD4 -208). 12,792 CD4 -208 Well Work Summary DATE SUMMARY 3/22/11 TBG OPEN TO 2.80" TO 6725' RKB. EASURED BHP @ 6701' SLM: 2708 / TEIO29. READY FOR E -LINE. 3/24/11 SHOOT 2.0" TUBING PUNCH GUN USING 6.5 gram CIRCULATION CHARGES 4SPF 0 DEG PHASING. TOP SHOT DEPTH = 6660.5" BOTTOM SHOT = 6665.5' CCL TO TOP SHOT =8.5' CCL STOP DEPTH = 6652.0'. AFTER SHOT WAS FIRED OBSERVED IA DROP FROM 800 PSI TO 100 PSI, TUBING WENT UP FROM 400 PSI TO 475 PSI. 3/26/11 PERFORM INJECTIVITY TEST POST TBG HOLE PUNCH, ESTABLISHED 2.0 BPM DOWN IA @ 425 PSI. WELL READY FOR CTU CEMENT JOB. 3/30/11 RIG UP COIL, PERFORM WEEKLY BOP TEST. 3/31/11 P . PED 15 BBLS OF 15.8 CLASS G CEMENT THROUGH RETAINER SET AT 6700 CTMD, PULLED OUT OF RETAINER, PUSHED 50 BBL V 1 1 • • I ' • • • • • BBLS IN 3.5 TUBING TO TOC TO 4935 FT. WELL IS FREEZE PROTECTED TO 3000 FT. 4/2/11 TAGGED @ 4949' SLM. MIT IA @ 2500 PSI. PASSED. MIT TBG @ 2500 PSI. PASSED. • PULLED DV @ 4416' RKB. JOB SUSPENDED AWAITING SEAWATER. 4/3/11 SET DV @ 4416' RKB. VERIFY SET. READY FOR E -LINE. 4/5/11 PERFORMED TUBING CUT WITH 2.70" JRC JET CUTTER AT 3100' RKB. TUBING AND I/A PRESSURE EQUALIZED TO 550 PSI AFTER CUT. TIED -IN TO GLM AT 4416' RKB • • ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: CD4 - 208 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 4/8/2011 8:00:00 AM Rig Release: 4/12/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/06/2011 24 hr Summa W.O. trucks for rig move 08:00 00:00 16.00 0 0 MIRU MOVE OTHR T W.O. Trucks from Deadhorse. Preparing rig for move and performing rig maintenance. 04/07/2011 W.O. trucks until released from BP. Started moving rig to CD4 -08 00:00 12:00 12.00 0 0 MIRU MOVE OTHR T Waited on trucks from Deadhorse. Prepare rig for moving and perform general rig maintenance. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move rig from CD3 to CD4 -08. 04/08/2011 Complete rig move to CD4 -08. Accepted rig 0800, 4/08/2011. Displace well to mud, ND tree, NU BOPE and begin test. 00:00 08:00 8.00 0 0 MIRU MOVE MOB P Continue moving rig from CD3 to CD4. PJSM to RU elec., steam, air, glycol and steam service lines. Work on all acceptance items. 08:00 10:30 2.50 0 0 SLOT DRILL PRTS P Rig accepted at 0800 4/8/2011. PJSM for PT IA. Tested IA to 2000 PSI with 1.8 BBL. Tested tree adapter to 5000 PSI for 10 min. RU FMC lubricatior and test to 250/2000 PSI for 5 min each. Pull BPV and R/D lubricator. 10:30 12:45 2.25 0 0 SLOT DRILL CIRC P RU circ lines to choke skid & tiger tank. PT lines to 2000 PSI. Held spill drill. Response time of 2 minutes. Rig put on High Line power @ 1130 am. 12:45 14:30 1.75 0 0 SLOT DRILL CIRC P Displace well with 50 BBL fresh H20, 35 BBL Flozan pill and 120 BBL of 9.6 PPG LSND mud @ 3 BPM holding 500 PSI with choke. ICP = 200 PSI. After displacement, SI well and pressure was zero. Open and V monitor for 10 minutes, no flow. 14:30 18 :45 4.25 0 0 SLOT WHDBO NUND P Set BPV and test to 1500 PSI. Bleed to zero, ND tree, install blanking plug and NU BOPE. 18:45 19:30 0.75 0 0 SLOT WHDBO OTHR T Incident occured when a roustabout on the rig floor rolled his ankle. Due to his inability to walk down the stairs, Alpine security was called and the ambulance responded to take him off the rig and to the medic. Page 1 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:45 1.25 0 0 SLOT WHDBO SFTY T Held Safety Stand Down. Investigated the accident scene, discussed the responsibility of all personnel to stop the job if it is unsafe. Reiterated that we are not in a hurry to get the job done and all jobs must have a PJSM. 20:45 22:00 1.25 0 0 SLOT WHDBO BOPE P Returned to work. PJSM on testing the BOPE. RU to test. 22:00 00:00 2.00 0 0 SLOT WHDBO BOPE P Test BOPE, upper VBR, choke manifold, upper & lower IBOP to 250 / 3500 fro 5 min with 3.5" and 4.5: test joint. 34/09/2011 Test BOPE. POOH w/ 96 Jts plus cut jt.of 3 -1/2" tubing. Run and set CIBP @ 2710' MD. Cut 7" casing @ 2700' MD. 00:00 03:30 3.50 0 0 SLOT WHDBO BOPE P PJSM. Cont. Testing BOPE. Tested upper 3.5" X 6" VBRs w/ 3.5" and 4.5" test joints. Also choke valve #2, HCR Choke, 4" Demco, dart valve, F.O. safety valve, blinds to 250 / 3500 PSI. Tested annular w/ 3.5" and 4.5" test joints to 250 / 2500 PSI. Accumulator test - system pressure start - 3000 PSI; after close pres = 1850 psi. Increased 200 PSI in 35 sec, full pres in 3 min. 28 sec. N2 bottle AVE = 2050 PSI. 03:30 04:30 1.00 0 0 SLOT WHDBO BOPE P Pull blanking plug. RD all test equip. 04:30 05:30 1.00 0 0 SLOT DRILL PULL P Mob casing equip and RU to pull 3 -1/2" tubing 05:30 10:00 4.50 0 0 SLOT DRILL PULL P Unseat hanger and POOH wit 2 jts 4.5" tubing and 96 joints + one 12' cut jnt. 3 -1/2" tubing. 10:00 11:00 1.00 0 0 SLOT DRILL PULL P RD casing equip 11:00 11:30 0.50 0 0 SLOT DRILL MPSP P Mob CIBP to rig floor. 11:30 14:00 2.50 0 0 SLOT WHDBO MPSP P RU and test lower 2 -7/8" X 5" VBRs G1� to 250/3500 PSI f/ 5 min. 14:00 18:30 4.50 0 0 SLOT DRILL TRIP P PJSM. MU CIBP, RIH on 4" drillpipe. Set at 2710' MD. POOH. 18:30 19:00 0.50 0 0 SLOT DRILL TRIP P POOH 9 stabds standing back 4" DP. Snagged man rider line with rotary hose and damaged rotary hose. 19:00 19:30 0.50 0 0 SLOT RIGMNISFTY T Inspected hose and determined it needed to be replaced. Held safety stand down with crew. 19:30 20:15 0.75 0 0 SLOT DRILL TRIP P Cont. POOH and LD BHA 20:15 21:45 1.50 0 0 SLOT RIGMNI RGRP T PJSM. Remove rotary hose and send to shop to swap out connections. 21:45 00:00 2.25 0 2,547 SLOT DRILL TRIP P PJSM. MU Baker casing cutter. RIH to 2547'. Page 2 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/10/2011 24 hr Summary Cut 7" casing in two spots. Circ'd out freeze protect. Pulled 1st 2530' of casing. RIH and speared 2nd 180' of casing. 00:00 03:00 3.00 2,547 2,547 SLOT RIGMNT RGRP T Install new rotary hose and test to 3000 PSI 03:00 04:00 1.00 2,547 2,700 SLOT DRILL TRIP P Continue RIH with Baker Casing cutter from 2547' to 2710' MD and tag CIBP. PU and locate collar @ 2682' MD. Locate cutter 2700' MD and make first cut @ 70 RPM, Torque = 1K, .5 BPM and 950 PSI. PU = 65K, SO = 65K. Observe 150 PSI increase on OA after cut. 04:00 05:00 1.00 2,700 2,530 SLOT DRILL CPBO P PU and locate cutter @ 2530' MD (ck for collars in area) and make second cut @ 70 RPM, Torque = 1K, .5 BPM and 950 PSI. PU = 65K, SO = 65K. Observe 500 PSI increase on OA after cut. 05:00 05:30 0.50 2,530 2,530 SLOT DRILL CIRC P Displace OA with 9.6 PPG mud @ 4 BPM, ICP = 600 PSI, FCP = 900 PSI. Pumped 100 BBLS total. Monitor well, static. 05:30 07:30 2.00 2,530 0 SLOT DRILL TRIP P POOH w /Baker mechanical cutter and LD BHA. 07:30 08:30 1.00 0 0 SLOT WHDBO BOPE P Clear floor. Pull Wear bushing 08:30 11:30 3.00 0 0 SLOT WHDBO BOPE P PJSM. C/O top rams to 7 ". Set test plug and RU test equip. 11:30 12:00 0.50 0 0 SLOT WHDBO BOPE P Test annular with 7" test joint to 250/2500 psi, upper pipe rams 250/3500 PSI, each for 5 min, charted. 12:00 13:30 1.50 0 0 SLOT WHDBO BOPE P RD test equip, pull test plug, pull 7" pack -off and set casing wear ring. 13:30 15:15 1.75 0 0 SLOT DRILL FISH P MU spear assembly. RIH, engage hanger and pull free @ 88k. PU 3' and circ two BU @ 5 BPM and 150 PSI. Pull hanger to rig floor, LD spear assembly and monitor well for 30 minutes, static. 15:15 17:45 2.50 0 0 SLOT DRILL FISH P PJSM. RU casing equipment and POOH w/ 7" casing. 17:45 19:15 1.50 0 0 SLOT DRILL FISH P RD casing equipment. Pull wear ring, set test plug. 19:15 20:15 1.00 0 0 SLOT WHDBO BOPE P PJSM. C/O upper rams to 3.5 X 6" VBR's. 20:15 21:15 1.00 0 0 SLOT WHDBO BOPE P Test 3.5 X 6" VBR's to 250 / 3500 PSI. 21:15 22:00 0.75 0 0 SLOT WHDBO BOPE P RD test equipment, install wear ring, mobilize fishing tools to floor. 22:00 00:00 2.00 0 750 SLOT DRILL FISH P MU spear assembly and begin RIH to 750'. 04/11/2011 POOH w/ 7" casing stub. RIH w/ cement/kill string. Pump cement plug. CIP @ 1845. Land tubing. WOC 15 hrs. Page 3 of 5 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 750 2,486 SLOT DRILL FISH P Continue in hole with Baker spear assembly to 2486'. PU = 82K, SO = 75K. Engage fish and set grapple. Make straight pull to 200K, then apply 850 psi with no circulation. Hit jars 5 times w/ 225K. Pull 275 K and apply 500 PSI. Fish started to move and circ started gradually up to 1.7 BPM. Pulled 90° and established circ at 3 BPM @ 500 PSI. Held Kick while tripping drill. 02:00 03:30 1.50 2,486 2,486 SLOT DRILL FISH P Circulate 2 BU, 320 BBL total. 4.5 BPM, ICP = 700 PSI, FCP = 250 PSI. SD and monitor well for 30 minutes. 03:30 11:00 7.50 2,486 0 SLOT DRILL FISH P Attempt to POOH on elevators, well swabbing. Pumped out of hole @ 2 BPM @ 150 PSI to 2298' MD. Attempt to POOH on elevators and got good hole fill. POOH and LD BHA w/ fish. 11:00 11:30 0.50 0 0 SLOT RIGMNT SVRG P Lubricate rig 11:30 13:15 1.75 0 0 SLOT DRILL RURD P RU 3 -1/2" casing equipment 13:15 16:15 3.00 0 2,685 SLOT DRILL TRIP P PJSM. RIH w/ 3 -1/2" tubing and tag CIBP P, 2710' MD. PU to 2685' for cement job. 16:15 18:15 2.00 2,685 2,685 SLOT CEMEN "CMNT P RU cementers. Batch up cement. PT lines to 2500 PSI. k 18 18:45 0.50 2,685 2,685 SLOT CEMEN" CMNT P Pump 10 BBL of MudPush II, 19.5 BBL of 17.0 PPG cement followed by It 2 BBL of MudPush II. Swapped to rig pumps and pumped 16 BBL of mud displacement. CIP at 1845, 4/11/2011. 18:45 19:30 0.75 2,685 2,288 SLOT DRILL TRIP P POOH from 2685 to 2288' MD. 19:30 21:00 1.50 2,288 2,288 SLOT DRILL CIRC P Drop tubing wiper ball and pumped 40 BBL of 10 PPB nut plug sweep at 7 BPM followed by 2 BU, 300 BBL of 9.6 Mud. 21:00 23:00 2.00 2,288 2,004 SLOT DRILL TRIP P POOH from 2288 to 2004. MU tubing hanger and land in wellhead. 23:00 00:00 1.00 2,004 2,004 SLOT DRILL PRTS P Run in LDS and RU to test hanger seals to 5000 PSI. 04/12/2011 Landed tubing hanger and tested. WOC for 15 hrs. Tested cement to 2000 psi for 30 min. Good test. ND BOP and NU tree and test. Displace mud, freeze protect well w/ diesel. Clean pits and prepare to move to CD4 -210. 00:00 01:30 1.50 0 0 SLOT DRILL PRTS P PJSM. Test hanger seals to 250/5000 PSI for 5 min. RD test equip and landing jt. LD casing tools from floor. 01:30 02:30 1.00 0 0 SLOT RIGMNT SLPC P PJSM. Cut drilling line Page 4 of 5 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 10:00 7.50 0 0 SLOT CEMEN" WOC P WOC for 15 hrs from CIP time. Routine maintenance, cleaning, move prep in progress. 10:00 11:30 1.50 0 0 SLOT CEMEN" PRTS P PT cement through IA to 2000 PSI for 30 min on chart. Good test. 11:30 14:30 3.00 0 0 SLOT DRILL NUND P PJSM. ND ROPE. NU tree and test. 14:30 15:00 0.50 0 0 SLOT DRILL NUND P Pull two way check and RU to circulate. 15:00 16:15 1.25 0 0 SLOT DRILL CIRC P PJSM. Displace mud from wellbore with water @ 8 BPM and 650 PSI initial and 800 PSI final PSI. 16:15 21:00 4.75 0 0 SLOT DRILL FRZP P }21 I I ittle Red and freeze protect well bore with diesel. Pumped 130 BBL. U -tube well and set BPV. OFF HIGH LINE @ 1800. 21:00 00:00 3.00 0 0 SLOT DRILL DMOB P Remove secondary annulus valve, install tapped flanges, secure wellhead, clean pits & rock washer. Release Rig @ 2400 4/12/2011. Page 5of5 • • 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 -208 4 .o APR 1 S ZOf1 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 -208 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20517 -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 Klinton Woo halliburton.com j06 /( cP0 Date: A:N ?� Signed:_ .9 C•aus. Amilmge • • S TRITE a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONS II CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 G. L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99501 Re: Colville River Field, Nanuq Oil Pool, CD4 -208 Sundry Number: 311 -090 Dear Mr. Alvord: ''+ :t APR 4 2 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, D aniel T. Seamount, Jr. 5 '7 4- Chair DATED this. 1 day of March, 2011. Encl. II • ConocoPhillips Alaska, Inc. Post Office Box 100360 INV Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 March 18 2011 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 MAR 2 3 ,1 Re: Sundry Permit -- Request to Re -Enter CD4 -208 and Plug for Re -drill �f8� Cons, o Connis urplrnt Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re -enter the CD4 -208 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 4/6/2011. Doyon Rig 141 will perform the work. This operation is planned following the pre -rig abandonment work approved in Sundry number 311 -053. The sidetracking procedures will be covered in a separate Application for a Permit to Drill CD4 -08. 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 -208 Current Schematic 4. CD4 -208 Pre -Rig Abandonment Schematic 5. CD4 -208 Set up for Sidetrack Schematic 6. Pre -Rig abandonment procedures approved in Sundry #311 -053 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 Mike Winfree at 265 -6820 or Chip Alvord at 265 -6120. Sincere y, Mike A. Wi free Drilling Engineer Attachments: cc: CD4 -08 Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Mark Chambers ATO 1566 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation %/ 4 ECEIVEC STATE OF ALASKA ` f f ► ALASKA OIL AND GAS CONSERVATION COMMISSION r 4 vl /, = ;I l' APPLICATION FOR SUNDRY APPROVALS S 20 AAC 25.280 Alstita Ti! X31 Gas Cans. Canvass") il 1. Type of Request: Abandon ❑ Plug for Redrill ig - Perforate New Pool ❑ Repair Well ❑ Ghana;, 1., Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑�ii11��1111 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well 0 - Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development is Exploratory ❑ 205 -162 - 3. Address: 6. API Number: Stratigraphic ❑ Service ❑ P.O. Box 100360, Anchorage, Alaska 50- 103 - 20517 -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 -208 - 9. Property Designation (Lease Number): 10. Field / Pool(s): 380077,`380075 - Colville River Field / Nanuq 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): 12,792 - 7,170 12,792 7,170 Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16' 114' 114' Surface 2,557' 9-5/8" 2,594' 2,440' 5,750 psi 3,090 psi Intermediate 7,277' 7" 7,314' 6,166' 5,410 psi 7,240 psi Production Liner 12,745' 3 -1/2" 12,782' 6,177' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n/a n/a 3 -1/2" L-80 7,191' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer and WRDP SSSV Packer set at 6,684' MD (5,985 TVD) -- SSSV set at 2,102' MD (2,004' TVD) 12. Attachments: Description Summary of Proposal IS 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development in - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 4/6/2011 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended - IS 16. Verbal Approval: Date: n/a WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike A. Winfree 265 -6820 A� Printed Name G.L Alvord Title Drilling Manager V• Signature 416- Phone 907 - 265 -6120 Date 3//2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 11 - 0 Plug Integrity ❑ BOP Test X Mechanical Integrity Test ❑ Location Clearance ❑ Other: J 2 Sd0 ,O S.. 4&) I --; //4 / -0 2 coo / t o s& Am "Lt" !GS - £ "--) - R B I ,1 -h.s i - , . t o c L. ‹ . <«pAQ b t z) AA-c. ZS: 2_8S (k) Subsequent Form Required: / 6 _ L / / • - / APPROVED BY Approved by d / COMMISSIONER THE COMMISSION Date: 3 / ,; (! 1 1 Br APR 042011410RI(1NA L 7 3 Form 10 -403 Revised 1/2010 Submit in Duplicate • • Down 141 CD4 -208 Abandonment Procedures The proposed scope of work for this sundry application includes: 1. MIRUDoyon141 2. Circulate out diesel freeze protect to 9.0 ppg KWF through the tree to tiger tank a. Nanuq reservoir pressure is Tess than 7.0 ppg 3. Set BPV and test from below 4. With tested BPV, KWF, Casing - Packoff Test, and competent cement as barriers, ND tree and NU BOPE and test 3S0 rs. 7;54— 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. 5. Pull 3 -1/2" tubing a. Test lower rams 6. RIH and set CIBP in 7" casing at 2,710' MD 74:3 �- e e 2 ' Ls as 7. Make up mechanical casing cutter and RIH to cut 7" casing —100' below surface shoe 8. Pull 7" casing to surface with spear and lay down 9. RIH with cement stinger and set cement kick off plug from the top of bridge plug into the surface shoe 10. Run 3 -1/2" tubing kill string Li PT 11. Install TWC and test from below 12. ND BOPE and NU tree pt" Zooptt 13. Pull TWC and displace well to inhibited brine and diesel freeze protect 14. Set BPV, Secure Well, RDMO. -P /96 it 1/4 CD-,Xvcteol drf Arr." 6'4 l-1° 7//OS:1 Ma 941/c /) crcg7; p rvt le ",'ey. ,lee'49 - a j 2q • • CD4 -208 Current Schematic WNS CD4 -208 ConocoPhillips 'Well Attributes Max Angle & MD TD rJii ^.;k 1, r, Wellbore APIAIWI Field Name Well Status Ind t MD (IMB1 Act Btm (RKBi 501032051700 NANUG IN, 95.74 9.106.17 12.792 0 Comment IH25 1ppm) Date Annotation End Date K8 -Grd (R) Rig Release Date "' SSSV WHOP L End Date Ann Lact " 0 44.03 1212412005 - - g o, Actu€1 r. 'Annotation Depth 4N(0) Last Mod ._ End Date Last Tag: Rev Rea000: GC TALLIES 'most; 12.'612009 Casing Strings Casing Description String 0... String ID ... Top (00(01 Set Depth If... Set Depth (NDI . S[nng Wt... String String Top Thrd NAN3ER. CONDUCTOR 16 15.25x0 37.0 1140 1140 6500 H-40 9, jc, I Caning Description String 0... Sirup ID ... Top (110(61 Set Depth If_. San Depth (ND) ... String Wt... String ... String Top TAN SURFACE 95/8 8.835 37.1 2.594.3 2.440.2 40.00 L - BTC Casing Description String 0... Sting ID ... Top (N(BI Set Depth Ii_. Set Depth (TYDI String Wt.. String ... String Top TMd INTERMEDIATE 6.151 34.9 7,314.2 6.166.9 2600 L - 80 ETCM A - Casing Description String 0 .. String 10... Top (11KBl Set Depth It... Set Depth (TVD) .. String Wt.. String String Top Thrd LINER 31.2 2.992 7.1691 127822 6.1777.1 9.30 BC SLH" _ finer Details COAR,tiTOR. Top Depth 3. -1'd ITVD) Top tool Norm.. T (1108) IKKB) (1 Rem Desorption Comment 10 (in) IP .169.1 6.143.6 80.01 SLEEVE BAKER 'FIR` LINER SETTING SLEEVE 4420 h1Pot.e.2 r,2 11 7.185 ,2 8146.5 81.38 HANGER BAKER' DG FLEX LOCK HANGER 4 400 ?.195.0 6.146.0 81 50 X0 5x4 5" 4 RUC I 7.240.0 9.1541 8201 X04.bx3.5" 330(5 12.74.0 0.1 :63 88 70 HUSHING BSKo- POCK OFF ELOPING 2.380 Tubing Strings 'SURFACE, * A Tubing Desorption String O Stoop ID ... Top 10001 ISM Depth II Set Depth (TVOI.. Stnng Wt... String Thal Top Th 72.eva TCEN 4.5x35 3112 2.932 7.191.0 6147.4 9310 1 L-8,0 1 EUEMOD Completion Details tom. Top Depth ITVDI Top tool Nom T op (11002 ( 6 ) (') Item Description Comment ID (in) GAS I. F :G+6 22.5 22.5 -0.09 HANGER FMC I UBING HANGER 4.500 T. 131.3 131.3 0.25X04.5x3.5" 3.500 II 2.102.0 1.004.5 26.51 NIPPLE CAMCO 'DS NIPPLE 2.812 1. 6.684.6 5.985.1 61.24 PACKER BAKER PREMIER PACKER 2.875 GASL:F '. 6.7150 6.003.7 6302 NIPPLE 3.5 HES 'XN NIPPLE wr7. 75 NO GO 2.750 6.3 II 7.165.5 6 143 0 79.84 'i LEG BAKER. FLUTED WIRELINE ENTRY GUIDEw/SHEAR 2.970 It Perforations & Slots III Shot PACKER. 6.6Qa Top (ND) Btm (ND) Dens Top 110(6) 500 (SOB) (0081 (Ma6) Zone Date (st. Type Comment ill 7.336 11./47 6.16/.6 6.1/6.3 1212112005 40.0 SLOTS SLOT I EU LINER, alterratmg NIPPLE °.6.12' sod /Olotiod pipe Notes: General & Safety 111 End Date Annotation 1 2:2312005 NO tt: I PEE: FMC 4- 1;16'. 5.0.}O PSI- I HEE CAPCONNECfION OI IS 111612009 NOl E' VIEW SCHEMAI IC w7Ataska Schemattc9.0 wte0.7 lee ETERNEC A 15.7 3x 1 -- S -OTS. ..:: - : Mandrel Details 5.3SE.12747 Top Depth Top Port ITVD) loci OD Valve Latch Size TRO Run Stn Top lEKB) ( 8 ) TI Mahe Model lint Scot Type Type (n) (psi} Run Date Com... 1 4.415.8 4.056.9 25.84 CAMCO KBMG 1 GAS LIFT DMY BK 0 000 0 0 452 2 6.589.6 5936. 157.63 CAMLO K8M6 1 ESP DMY 8K 0000 0.0 052006 LN_R. T.1E9-'21E2 TO :C0l.2Cd 1. .............. 2152 • r • CD4 -208 Pre -Rig Abandonment Schematic (Reference Sundry # 311 -053) CD4 - 208 Nanuq Injector Abandonment February 17, 2011 X Diesel (to be removed by rig) I 16" Insulated Conductor to —114' PIER 3 -'/2' x 4 -' /z' cross -over, 2 jts below 4 -'/2" hanger 3 -' /2' 9.3 ppf L -80 EUE 8rd Mod Tubing 2.813" DB Landing Nipple 9 -5/8" 40 ppf L -80 BTCM Surface Casing is►J 244 ' TVD 2594' MD / 0 Corrosion inhibited em Top MD TVD Angle seawater 1) Tubing Hanger 32' 32' 0 deg 2) 4 -'/2' 12.6 #/ft IBT -Mod Tubing (2) 3) Crossover Cut Tubing @ 3100' 4) 3'/2 ", 9.3#/ft, EUE 8rd Mod Tubing 5) Camco DB nipple 2102' 2005' 26.9 6) 3-%", 9.3 # /ft, EUE 8rd Mod Tubing 7) Camco KBMG- GLM w/ 1" Orifice Valve 4416' 4057' 25.8 8) 3'/2', 9.3#/ft, EUE 8rd Mod Tubing 9) Camco KBMG- GLM w/ Spartec 6590' 5937' 57.8 10) 3 -' /z', 9.3#/ft, EUE 8rd Mod Tubing (2) 7 GL J KBMG GLM w/ 1" DV 11) Baker Premier Packer 6678' 5982' 61 12) 3 -'/2 ", 9.3#/ft, EUE 8rd Mod Tubing (1) 13) HES "XN" (2.750 ") - 63.0° inc 6725' 6003' 63 14) 3- 9.3#/ft, EUE 8rd Mod Tubing +/- 8 jts 15) BOT Stinger with Fluted WLEG/ stinger 7191' 6147' 80.7 Stung into tieback extension 10', bottom at 7060' 16) Baker 5" x 7" Flexlock Liner Hanger 7169' 6143' 80 17) 3-W, 9.3 # /ft, SLHT Tubing +/- 4 jts 18) 3-W 9.3 #/ft L -80 SLHT liner w/ blank across shale and slots across sand 19) Baker Shoe w/ packoff bushing 12747' 6176' 15.8 ppg Class G cement KBMG GLM w/ 1" DV 3 -Y2' 9.3 #/ft SLHT liner: Top of cement I ® ® �` 8 slots / ft, 2 -'/4' x 1/8" slots © —6368' MD / 5871' TVD ® ® _ 17 18 19 — "V Top Reservoir at 16 Nanuq 7235' MD / 6154' TVD TD 6 -1/8" hole 7" 26 ppf L -80 BTC Mod 14184' MD / 6159' TVD Production Casing @ +/-84.1° 7314' MD, 6163' TVD S i CD4 - 208 Nanuq Injector Rig Abandonment March 18, 2011 *�® t.,- A::::::: 44"a .!, Diesel Freeze Protect ; : 16" Insulated Conductor to —114' J s 3 -' /2' x 4 -' /z" cross -over, 2 its below 4-W hanger 3 -' /2" 9.3 ppf L -80 EUE 8rd Mod Tubing Kill String 4 8.6 ppg Inhibited Brine Top of plug @ 2,400' MD 9 -5/8" 40 ppf L -80 BTCM Surface Casing A oh. 2,594' MD / 2,440' ND 17.O ppg KO Plug Casing Cut @ 2,700' MD CIBP CIBP @ 2,710' MD 9.0 ppg LSND Mud Cut Tubing @ 3,100' MD 8.6 ppg Inhibited Seawater r KBMG GLM w/ 1" DV 4,416' MD 15.8 ppg Class G cement KBMG GLM w/ 1" DV 3 -' /z' 9.3 #/ft SLHT liner: Top of cement �� 8 slots / ft, 2-W x 1/8" slots 6,368' MD / 5,871' TVD , i :i I - F Top Reservoir at ., Nanuq 7,235' MD / 6,154' ND TD 6 -1/8" hole 7" 26 ppf L -80 BTC Mod 14,184' M D / 6,159' ND Production Casing @ +/ -84.1° 7,314' MD, 6,163' ND • • • • Work Approved in Sundry # 311 -053 Objectives 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 —500' below the surface casing shoe. 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 packer (-6700'). Retainer should have internal check valve to prevent backflow of fluid from below 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 50 bbls of cement taking all returns from the IA. After 50 bbls have been pumped, close IA at surface and begin laying in 15 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 4416' RKB. 5. If successful pulling DV leave pocket open and circulate in 110 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 @ 4416' RKB. Confirm set by creating differential pressure. 8. RDMO E -Line: 1. RIH with Jet Cutter and cut 3.5" tubing at 3100' RKB ( -500' below surface casing). 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. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: CD4 -208 Run Date: 3/24/2011 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 -208 t Digital Log Image file 1 CD Rom Digital Data in LAS format, g g e g 50 -103- 20517 -00 p1.! V APf7 'r 8 0 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 g°5----1°Q a OAS Klinton Wood @halliburton.com 1 Date: Signed: • . AsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI3IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 T. Senden Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4 -208 Sundry Number: 311 -053 Dear Mr. Senden: Application for Sundry Approval relating Enclosed is the approved g to the above PP PP ry PP 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. 01 4 ti o • . • r an o m sione DATED this day of March, 2011. Encl. 1"RCC.;Gi V elf STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISS• FEB 2 8 2011 . APPLICATION FOR SUNDRY APPROVALS IL 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon f Rug for Redrill 7 • Perforate New Pool r Repair w ell r Change Appe(gp16#krggwam r Suspend ?: Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r r Ot her: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory fl 205 -162 , 3. Address: 6. API Number: Stratigraphic r Service r • P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20517 -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 i✓ CD4 -208 , 9. Property Designation (Lease Number): • 10. Field /Pool(s): ADL 380075, 380077 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): 12792 • 6177 '. 12244' 6181' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2557 9.625 2594' 2440' INTERMEDIATE 7279 7 7314' 6164' LINER 5613 3.5" 12782' 6177' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 7336'- 12496' 6168' -6182' 3.5 L - 7191 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD= 6685 TVD= 5985 NIPPLE - CAMCO 'DS' NIPPLE MD= 2102 TVD= 2005 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/7/2011 Oil r Gas r WDSPL r Suspended rip ,\ 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 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: Wells Engineer Signature ■4\ Phone: 265 -1544 Date 2 /is/ ti Commission Use Only Sundry Number: fJt /)1 i!�/ • 0 r Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: 0 I APPROVED BY 3 , / r Approved by: p. COMMISSIONER THE COMMISSION Date3 ` MAR n ,� 2. .A6../ R Form 1u-406 'Revi � 11 w �,{ \ \\ 0R1G1NAL 7 4 3./.11 Submit in D plicate s\ /i • _ WNS • CD4 -208 P ConocoPhillips Well A 1Lwtes Max Angle & MD TD • ' $,, l Wallbore APpUWI [Field Name Well Status Inc) ('I I MD (R103) Act Dim (ftKB) us+acrzYlnhR.+"' 501032051700 _ INANUQ INJ 95 /4 i 9,106.17 12 . /92.0 • - Comment 1-125(ppm) Date An tation End Date KB-Grtl (11) Rig Release Date "' SSSV: WRDP , Last WO* 4404 I 12/24/2005 W ou cx4IS PIEE_AIL 12/1{7009 029;44 AM ' _ _ SdT Le Eckel Annotation I Depth (ftKB) End Date Annotation ( os Last Mod ... End Date Last Tag- I Rev Reason- QC TALLIES Imbor 12/6/2009 Casing Strings a r Casing Description String 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 23 tl CONDUCTOR 16 15.250 37.0 114 - 0 114.0 65.00 H WELDED Casing Description String 0... Suing ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 8.835 371 2,594 -3 2440.2 40.00 L-80 BTC - -- — .. -- — ,. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WI... String ... String Top Thrd „ .'! INTERMEDIATE 7 6.151 349 7,314.2 _ - _ 6,166.9 26.00 L BTCM _ ' w � Casing Description String 0... String ID ._ Top (NKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd LINER 31/2 2 -992 7,169 -1 12,782.0 6,177.1 9.30 L-80 I SLHT Liner Details CONDUCT37 -OR, r Top Depth I I (TVD) Top Inc! N i... 114 Top MKS)(RI(B) (°) Item Description Comment ID (in) Ilri 7,169.1 6,143.6 80.01 SLEEVE BAKER 'HIT LINER SETT ING SLEEVE 4.420 l ar 7,182.1 6,146.0 81.35 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 NIPPLE, 2,102 '; 7,185.2 6,146.5 81.38 HANGER BAKER 'DG' FLEX LOCK HANGER 4.400 7,195.0 6,148.0 81.50 XO 5x4.5" 4.500 7,240.0 6,154.7 82.02 XO 4.5x3.5" 3.500 12,747.0 6,176.3 88.75 BUSHING BAKER PACK OFF BUSHING 2.380 SURFACE, . Tubing g Descript on String 0... ( String ID ... 'Top (ftKB) Set Depth (f..- Set Depth (TVD) ..String Wt... Str g ,String Top Thrd 37.2,594 TUBING 4.5x3.5" 31/2 2.992 22.5 7,191.0 6 ' 1474 9.30 L-80 EUEMOD Completion Details �(h 1. R Top Inc e 1 N i_. To Depth (Tab Item D seri b ID (in) on Comment GAS LIFT,— - 7 KB (ftKB) _ p 4,415 131.3 131.3 0.25HANGER FMC TUBING HANGER 4.500 XO 4.5x3.5" 3.500 2,102.0 2,004.5 26 51 NIPPLE CAMCO 'DS' NIPPLE 2.812 6,684.6 5,985 1 61 24 PACKER BAKER PREMIER PACKER 2.875 GAS LIFT, -- 6,590 6,725.0 6,003.7 63.02 NIPPLE 3.5" HES 'XN' NIPPLE w/2.75' NO GO 2.750 7,165.5 6,143.0 79 -84 WLEG BAKER FLUTED WIRE LINE ENTRY GUIDE w /SHEAR 2.970 Perforations & Slots A � Shot -,-1 "+- Top (TVD) Btm (TVD) Dens PACKER, 6,665 _ TopjitKB) J Btm (RKB) (905/ (1108) Zone Date (str.. Type Comment at 7,3361 12.747 6,167.6 6,176.3 12/23/2005 40.0 SLOTS SLOTTED LINER, altemating NIPPLE, 6,725 - solid/slotted pipe 1111 ' Notes: General & Safety End Date Annotation 12!23/2005 NOTE: TREE: FMC 4- 1/16", 5,000 PSI - TREE CAP CONNECTION 7" OTIS 12/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 WLEG, 7,166- - -- ( q 4 NTERMEDNTE, 35 -7,314 ta 1 N h SLOTS, e s..: 9° . s Depth ..o 3 < 5.. Z. ,i r,4,0," ,•°`ed'.a°a;417. I # d 0 � ew h 7,336 - 12,747 �.� Top Depth Top " Port (TVD) Inc/ Latch Sire TRO Run # Stn TQp,(/5B) MKS) ( ° 1 Make NodN r r Sery Trp• Valve TYM (inl (pai) Run Date cam... 1 4,415.8 4,056.9 25.84 CAMCO KBMG GAS UFT DMY BK 0.000 0.0 4/5/2006 g 2 6,589 6 5,936 9 57.63 CAMCO KBMG 11111 ESP DMY BK 0.000 0.0 4/5/2006 LINER, 7,169- 12,782 TO (CD4 -208), 12,792 • • CD4 -208 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 6685' RKB. ' 2. Run in hole and set inflatable retainer below packer. 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 50 bbls of the same ' 15.8 ppg Class G cement into the IA above the packer. 5. Lay in 15 bbls of cement on top of the retainer. 1700' t «."- '' T c _D 6. Tag cement top. 7. PT tubing and IA to 2000 #. 8. Pull gas lift valve from mandrel at 4416' 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 3100'. 12. Set back pressure valve in preparation for the rig. S „ t*e c 208' war/ was /A o J ve'n't y 1f / /e'1 F ee a /Ave/'�i1 fr/ ri e // 0 s C 4/ � f r4e , "`"'�G�c 0. / / w 4t f w. vj d to it 4 wel �`/� the i Oy / Cv "lee W Q1�6 kal1 be 404 effect`/' iv C aide iverr 14J ec�`i / N►G << ccu be �f'4CV4' *14 4 letter loC qt; 4 , Ti�re for 2' yo ov` e e ver z/e,,,x4 • • CD4 - 208 Nanuq Injector Abandonment February 17, 2011 Diesel (to be removed by rig) © 16" Insulated Conductor to -114' tie:! 3 -' /" x 4 -Y2" cross -over, 2 jts below 4 -'/2" hanger 3 -W 9.3 ppf L -80 EUE 8rd Mod Tubing 2.813" DB Landing Nipple 9 -5/8" 40 ppf L -80 BTCM Surface Casing 2594' MD / 2440' TVD Corrosion inhibited • m Top MD, Dm Anale seawater 1) Tubing Hanger 32' 32' 0 deg 2) 4- 12.6 #/ft IBT -Mod Tubing (2) 3) Crossover Cut Tubing @ 3100' 4) 3'/2 ", 9.3 # /ft, EUE 8rd Mod Tubing 5) Camco DB nipple 2102' 2005' 26.9 6) 3 -'h ", 9.3 # /ft, EUE 8rd Mod Tubing 7) Camco KBMG- GLM w/ 1" Orifice Valve 4416' 4057' 25.8 8) 3-V, 9.3 # /ft, EUE 8rd Mod Tubing 9) Camco KBMG- GLM w/ Spartec 6590' 5937' 57.8 10) 3- 9.3 # /ft, EUE 8rd Mod Tubing (2) G KBMG GLM w/ 1" DV 11) Baker Premier Packer 6678' 5982' 61 12) 3 -W, 9.3#/ft, EUE 8rd Mod Tubing (1) 50 wD 13) HES "XN" (2.750 ") - 63.0° inc 6725' 6003' 63 C— 14) 3 -'/2 ", 9.3 # /ft, EUE 8rd Mod Tubing +/- 8 jts 15) BOT Stinger with Fluted WLEG/ stinger 7191' 6147' 80.7 Stung into tieback extension 10', bottom at 7060' 16) Baker 5" x 7" Flexiock Liner Hanger 7169' 6143' 80 17) 3- 9.3 # /ft, SLHT Tubing +/- 4 jts 18) 3 -'/2' 9.3 #/ft L -80 SLHT liner w/ blank across shale and slots across sand 19) Baker Shoe w/ packoff bushing 12747' 6176' 15.8 ppg Class G cement KBMGGLMw /1 "DV 3 -'W' 9.3 #/ft SLHT liner: • 8 slots / ft, 2-%" x 1/8" slots Top of cement � ®� _ ' % —6368' MD / 5871' TVD ® s 18 Top Reservoir at 41(_16) Nanuq 7235' MD / 6154' TVD TD 6-1/8" hole 14184' MD / 6159' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ +/ -84.1° 7314' MD, 6163' TVD 0 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 ~ MEMORANDUM To: Jim Regg i P.I. Supervisor t P.~~ ~ (~ +U~`~( [ FROM: Bob Noble Petroleum Inspector . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-208 COLVILLE RIV NAN-N CD4-208 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: COLVILLE RN NAN-N CD4-208 API Well Number: 50-103-20517-00-00 Inspector Name: Bob Noble Insp Num: micRCN090729085730 Permit Number: 205-162-0 / Inspection Date: ~~23/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ CD4-208 Type Inj. N 1'~ 5982 IA 963 1735 1706 1699 P.T.D 2051620 TypeTest SPT Test psi 1735 ~f~ 596 643 628 624 Interval 4YRTST P~ P '~ Tubing 2301 2301 2301 2301 Notes: ~~ ~ ~~~--- P~~~~ ~ ~,: . ~ ~ ^1 `, , , ~ - ' : ;1~~~ ~ ,,.: . ._ k.~ ... \. ~~" t ~ww.r a. Wednesday, July 29, 2009 Page 1 of 1 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 r ,w~~~~ ~ ~~~ ~; ~ ~~~ w~~;y Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~. ~ ~~s-I ~a- 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 iuCin 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 1 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 CD4-16 206-131 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 • Page 1 of 1 Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Friday, February 29, 2008 2:27 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: CD4-208 (205-162) Tom, Jim, We started injection in CD4-208 on March 6, 2007. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 29, 2008 2:23 PM To: Walker, Jack A Cc: Jim Regg Subject: CD4-208 (205-162) Jack, You sent in a 404 regarding converting this well to injector on November 12. When did injection first occur in the well? There is no date given on the document. Thanks in advance. Please send your response to Jim as well since 1 will be gone. Tom Maunder, PE AOGCC ~~NE~ MAR ~- 9 2068 ai29iZOOs r~ ConocoPhillips November 12, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for CD4-208 Dear Commissioner: ~~~ ~,b5 ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the Nanuq well CD4-208. This report will cover the conversion from apre- producer to an injector. If you have any questions regarding this matter, please contact me at 265-6268. G'~ ~ incerely, J. Walker Staff Production Engineer CPAI Alpine Engineering JW/skad • Jack Walker Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6268 ~~~~~~~~ NOV ~. ~ ~~tc? Alaska Oil & Gay C~~. ~~t~zr;;;~:.,~ Actela4rage ~~~ MAR ~ 20~ -a/-off STATE OF ALASKA R~~I~D Nov l ~ ~aaT ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~aska Q~1 ~ has Ciyns. C~Imr~y~~+~n Anchnrage t. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ Convert to Inj. Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-162 / 3. Address: Stratigraphic ^ Service Q 6. API Number: _ P. O. Box 100360, Anchorage, Alaska 99510 50-103-20517-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.5' - CD4-208 - 8. Property Designation: 10. Field/Pool(s): ADL 380077, 380075 Colville River Field, Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured 12792' ~ feet true vertical 6177' ' feet Plugs (measured) Effective Depth measured 12244'' feet Junk (measured) true vertical 6181' ~ feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2539' 9-5/8" 2594' 2440' PRODUCTION 7259' 7" 7314' 6164' SLOTTED LINER 5613' 5" x 4.5" x 3.5" 12782' 6177' Perforation depth: Measured depth: slotted liner 7336'-12496' true vertical depth: 6165'-6176' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7191' MD. Packers & SSSV (type & measured depth) Baker Premier pkr @ ss76' Camco'DS' nipple ~ 2102' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na na SI -- Subsequent to operation na na SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: ~./~'~`/ a1 /~' °7 Oil^ Gas^ WAG GINJ^ WINJ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/,4 if C.O. Exempt: none contact Jack Walker @ 265-6268 Printed Name Jack Walker Title Production Engineer Signature ~, ~ ®. ~ ` Phone: 265-6268 Date ! ~ /~'Z~6''~ G I C~- Pre Sharon Allsu Drake 263-4612 v Form 10-404 Revised 04/2006 ORIGINAL ~ ~~,~ ~ e~ ~ooo Submit Original Onfy ~3 ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051620 Well Name/No. COLVILLE RIV NAN-N CD4-208 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20517-00-00 MD 12792 TVD 6177 Completion Date 12!23/2005 Completion Status 1-OIL Current Status 1-OIL UIC ~ ~/ REQUIRED INFORMATION Mud Log No Samples No Directional Surv Yes ~~ DATA INFORMATION Types Electric or Other Log s Run: GR/Res/Dens/Neutron (data taken from Logs Portio n 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 ~~ED D Asc Directional Survey 0 12792 Open ~og Cement Evaluation 5 Col 1 5990 7172 1/9/2006 ULTRASONIC IMAGER CEMENT/CORROSION LOG USIT/GR/CCL ~~/ !'ED D Asc Directional Survey 0 12244 Open PB 1 ~,,~D D Lis 13763 Induction/Resistivity 10545 12735 Open 4/6/2006 GR EWR4 ROP PWD ~ GeoPilot ~t 13763 LIS Verification 10545 12735 Open 4/6/2006 GR EWR4 ROP PWD D Lis 13764 Induction/Resistivity 2559 12186 Open 4/6/2006 GeoPilot PB 1 GR EWR4 ROP PWD GeoPilot ~t 13764 LIS Verification 2559 12186 Open 4/6/2006 PB 1 GR EWR4 ROP PWD GeoPilot ~og Production 5 Blu 1 6900 11620 Open 3/24/2006 Production Profile w/Ghost with WeIITec Tractor 18- Mar-2006 *',~ED C Lis 15137 Induction/Resistivity 2559 12244 Open 5!16/2007 P61 LIS Veri, GR, FET, ROP w/Graphics PDS i D C Lis 15137 Induction/Resistivity 2559 12792 Open 5/16/2007 LIS Veri, GR, FET, ROP w/Graphics PDS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051620 Well Name/No. COLVILLE RIV NAN-N CD4-208 Operator CONOCOPHILLIPS ALASKA INC MD 12792 TVD 6177 ADDITIONAL INFORMATION Well Cored? Y / N~ Chips Received? 'Y`t-Rt~ Analysis c1`7-A~ Received? Comments: Compliance Reviewed ay: Completion Date 12/23/2005 Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~-~N Formation Tops ~ N API No. 50-103-20517-00-00 UIC Y Date: Summary by Month: Individual Well Production Well Name: COLVILLE RN NAN-N CD4-208 API: 50-103-20517-00-00 Permit to Drill: 2051620 Operator: CONOCOPHILLIPS ALASKA INC Field/Pool: COLVILLE RIVER, NANUQ OIL Sales Cd: 12 Acct Grp: 4 Final Status: 1-OIL Current Status: I-OIL 2006 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-In Shut-[n Shut-In Days 2 0 0 0 0 0 0 0 0 0 pii 672 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 0 0 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 0 2006 Totals: Oil 672 Water 0 Gas 0 Cum Oil 672 Cum Wtr 0 Cum Gas 0 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut-In Shut-In Days 0 0 Oil 0 0 Wtr 0 0 Gas 0 0 2007 Totals: Oil 0 Water 0 Gas 0 Cum Oil 672 Cum Wtr 0 Cum Gas 0 • Monday, February 04, 2008 Page 1 Summary by Month: Individual Well Injection /Disposal Well Name: COLVILLE RIV NAN-N CD4-208 API: 50-103-20517-00-00 Permit to Drill: 2051620 Operator: CONOCOPHILLIPS ALASKA INC Field/Pool: COLVILLE RIVER, NANUQ OIL Sales Cd: 12 Acct Grp: 4 Final Status: 1-OIL Current Status: 1-OIL 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth WAG WAG WAG Shut-In Shut-In Shut-In Shutdn Shut-In Shut-In _ Shut-In Days 26 30 23 0 0 0 0 0 0 0 Wtr 24,458 32,917 28,209 0 0 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 0 2007 Totals: Water 85,584 Gas 0 Cum Wtr 85,584 Cum Gas 0 u Monday, February 04, 2008 Page 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, November 29, 2007 9:48 AM To: 'Sharon Altsup-Drake ; 'Walker, Jack A' Subject: CD4-208 (205-162) Sharon and Jack, We have received a 404 documenting the conversion of this well from pre-produced to injector. When was injection begun? Thanks, Tom Maunder, PE AOGCC 11/29/2007 Page 1 of 1 Maunder, Thomas E (QOA) From: Maunder, Thomas E {DOA) Sent: Tuesday, October 09, 2007 1:19 PM To: Jim Regg Subject: CD4-208 {205-162) Jim, CPAI may have injected in this weft withou# proper authorization. 1 was clearing some emaiis out and had one regarding a sidetrack for this well. When l checked, it turned out the email was in the file. 1 ran across a report of a MIT conducted May 3, 2007 and #hen checked for MIT li. 1 don't find that ! did a MIT ii. The print out shows this well to be 1-oil completed 12/23/05. The wel! was permitted as an injector, but was completed as a development well. It is sta#ed in the application letter that CPAI intended to flow the welt back for 5 -15 days to mitigate damage and then the well would be SI. There is little information in RDBMS regarding production. 2 production days are reported in March 2006, but then April and May are blank. Zero production is reported for June 2006 - February 2007. 26, 30 and 23 water injection days are reported far March -June 2007. There is a message in the file from MJ in mid-March 2006 informing us that the well was showing some signs of T x IA communication and tha# CPAI planned to complete the cleanup flow, effect wireirne repairs and St the well. I have checked the 403 log and do not find any sundry in 2005 - 2007 relating to converting this well from producer #o injector. This is another case where I thought injecting into a producer would have RDBMS identify the well #o McMains. I will bring you the file. Tom 10/9/2007 r ~ I~C:iANICAL INTEGRITY R :PORT ~ ,~ ~ '~~~ P ~ ~ F~ BUD ~ ~_ _ _ : 1~ ~~~.-~C~' OPER ~ FZEI.D ~'~ As~ ~1~1 ~ ~`e. ~1~~ ~. :? G r y ~ S ~ ~ : ~ ~a~-~ S i;:_LL NUME ER ~,~_- ~ ~ ~,~,~~~. ~ 1 .N h LL ~7AT_ ~_ TD : ~l`l~~ ?~.. _ fs~ 111 TVD ; =ETD : ~ ~~~1'-1 ~ ~ ~ ~ TvD Casing ~ Shoe_ ~. \ MD ~,~ l TVD; i~~l. ~~ ?'~ 1 ~I~ -~-7i _:~ e .. ~~~ Shoe . '~} T~,IT, ; ~ i; P . ~•~ .'•r J =ubi~S ~_ 1~._Pacice= ~(o~ ~'_~ T_'J7i Set Gt ~ i`1,~ f\ ole See ~ '~~1 and Perks 5 ~ ~cJ to ~~ v~..,~-~.... ^~'= Cc.A?~=C~_~ tNTEGR?TY - PART #? xnrulus Press Test: I?~~ ; ?5 rain ~'~; ~0 min (f~3~~. C ac.~en t s : ~~--a'~l '~'GHI~NIC?~.. ±NTEGRl-T~ -- PAR.?' # 2 ~---~ ~~,~v~'~ Cement Volumes :~_ Amt. Liner ~ 4~- ; Csa ~~~~ S5~ ; DV ~~--- - C,~t JoI to covet pet=s ~ `~e2c`dS 1~ ~,h~.5 ~~~~t`~~~1~ ~e=• eore tiCal TOC C ~~~ ~,~ '`-' ~ S ~ - Cement Bond Log (Yes or No)~; Ind AOG C File ~~(L~, c3,p~c~~cr-~ ~~. ~.a~.:c~t~ `-~ ~,c: ~ ~",~~ b ~~v~~~„~~~\ Cc~ c•° „"~} '~1rvc~~ ~i~` .`~ e~`ti~i~5cc,~ 1G C3L ~vzluation, ~on~ above perfs `~ c ~~ ~ `~S ~~ ,h ~ ~ t~ t ~~` ~ ~~~rJvJ r:C~ 'J~~ r ~ Production Z.ag: '?'ype_~t;~~~ Evaluation ~L~ ~^~ -5-- 9 ~ - CONCLJSIOtdS : ~ - . ~" '" ( ?art :1 : ~~„~,,,, ~tJ~,z,`~ ~ r ~--J~~~~S:~~ ?art #Z ~~ .~~x~~,~ `~ I~~C': ~~~~,~~l~~~~ ~~•h STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 205-1~2 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final Q 306-266 8/22/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbls): 2006 / 3rd 28553 100 0 28653 39 7/3/2006 9/20/2006 CD4-320, CD4-318A, CD4-17 CD4-321 CD4-214, CD4-211 2006 / 4th 32707 100 0 32807 33 10/4/2006 12/8/2006 , , CD4-215 2007 / 1st 0 0 10* 10 0 2007 / 2nd 0 0 0 0 0 2007 ! 3rd 0 0 0 0 0 Total Ending Report is due on the 20th 61260 200 379 61839 72 Volume of the month following the final month of the quarter. Ex: (bbls>: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in~ectivit test I hereby certify that the foregoin is true and correct to the best of my knowledge. //~~ Signature: ~ Date: ~'`~ i~5 ~O ~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INS I KUG I IONS UN KtVtKSt SIUt suomit rn uupncate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class:. Stratigraphic ^ Service ^ 6. Permit to Drill Number. 205-162 ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-266 8/22/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbis): Zoos / 3rd 28553 100 0 28653 39 7/3/2006 9/20/2006 CD4-320, CD4-318A, CD4-17 CD4-321, CD4-214, CD4-211, Zoos / ath 32707 100 0 32807 33 10/4/2006 12/8/2006 CD4-215 2007 / 1st 0 0 10* 10 0 2007 / 2nd 0 0 0 0 0 Total Ending Report is due on the 20th volume 61260 200 379 61839 72 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivit test s true a nd correct to the best of my knowledge. I hereby certify that the foregoing i d me Si t ~ '~~~-'~- ~ D t ~ ~S ~a7 gna ure: ~ a e: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ ~ WELL LOG TIZANS~V[ITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 May 9, 2007 RE: MWD Formation Evaluation Logs: CD4-208 & PB 1 AK-MW-4084842 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 fo tted CD Rom it erification listing. API : 50-103-20517-01, 70 00 a i5 i C~ ~ ~ ~-~ ~ ~ ~~~ ~~~ o~~~-~ cs lJ f .C; ~uJ !(o px ~ t v ! ~~ ~~ ~ . b ~~ ,~ ~.. ~- ~ ~d~~ 1v1~1v1VKAlV ll U 1~1 ~ State of Alaska Alaska Oil and Gas Conservation CommiJ,f_.i TO: aim Regg ';'1 DATE: Thursday, May 03, 2007 P.[. Supervisor ~^s~'i =i 'J! ~ ~ _,~ +' SUBJECT: biechanicat Integrity Tests i ~ CONOCOPHILLIPS 9i.aSK.A [VC CD4-208 FROM: JOZITl CTISp COLV[LLE RI V' SAV-N CDd-2o8 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -` Comm Well Name: COLVILLE RN NAN-N CD4-208 API Well Number: so-1o3-2os1~-oo-oo Inspector Name: John Crisp Insp Num: mitJCro7oso2t22o25 Permit Number: 205-162-0 Inspection Date: 4'2812007 Rel Insp Num: Packer Depth Pretest Initial ~ 15 Min. 30 Min. 45 Min. 60 Min. Well cDa-2os ',Type Inj. w ! T`D ~ ' sas IA Boa t6so ~ ~63a t6i9 ~ 2osiezo iTypeTest sPr', Test psi ; P.T.D Isoo ~ pA ', stz sao i s~9 sv _-. Interval r~.2Tar, P/F P Tubing' 9'6 ~ 9~a 9~s _ 9~s NOteS' .6 bbl pumped for test. Thursday, May 03, 2007 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. We11 Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 20~-1r32` ; ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-266 8/22/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbls): 2006 ! 3rd 28553 100 0 28653 39 713!2006 9/20/2006 CD4-320, CD4-318A, CD4-17 CD4-321, CD4-214, CD4-211, 2006 / 4th 32707 100 0 32807 33 10/4/2006 12/8/2006 CD4-215 2007 / 1st 0 0 10* 10 2007 ! 2nd Total Ending Report is due on the 20th volume 61260 200 379 61839 72 (bbls): of the month following the final month of the quarter. Ex: July 20 for the second quarter April 20 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in~ectivit test I hereby certify that the foregoing ist nd correct tot h b of my knowledge. ru e e s t a e ~ ` ' ~~ - ~ -- ~ ._ ., ~ / Si t \ ~ : ` \ ~ ''~: ~f r3 f0' gna ure: . = ~---~ - Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 205-162 ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD4-208 2. Address: WAG 4b. Well Status: Oil ~ Gas 8. API Number: P. O. Box 100360, Anchorage, Alaska G1NJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation 0 or Final ^ 306-266 8/22!2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): .Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal ~ ~ drilling mud, completion occurred 1...~:l e ~ ~:! fluids, formation fluids and ~~ 1 any necessary water ~ ~ ~ ~~i~~ added Previous 369* 369 ~~ ~ORSa C;itrtt~€~;~EOtt totals (bbls}: -.~, r, etst <~ ~ 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28553 100 0 28653 39 7/3/2006 9/20/2006 CD4-320, CD4-318A, CD4-17 CD4-321 CD4-214 CD4-211 2006 / ath 32707 100 0 32807 33 10/4/2006 12/8/2006 , , , CD4-215 007 / 1st Totai Ending Report is due on the 20th volume 61260 200 369 61829 72 (bbls}: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. --__W t l ~~3lJ(~ Si t t ~'-~ D gna ure: ` a e: Printed Name: Randy'Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 20~-1~ ConocoPhillips Alaska, lnc. Development 0 Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-183 5/30/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbls): 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28553 100 0 28653 39 7/3/2006 9/20/2006 CD4-320, CD4-318A, CD4-17 CD4-214, CD4-211, CD4-321 2006 / 4th 32707 100 0 32807 33 10/4/2006 12/8/2006 , CD4-215 2007 ! 1st Total Ending Report is due on the 20th volume 61260 200 369 61829 72 (bbls): of the month following the final month of the quarter. Ex: July 20 for the second quarter April 20 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivit test st of my knowledge. f hereby certify that the foregoing is tr ue a nd correct to t h e be ~~ ' ° - - ~ ~ Signature: ~ ~`-°`~ ~ ~~~`--- Date: ~ ~ 'Z fa Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 205-152 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil ^~ Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-183 5/30/2006 Co{ville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369* 369 totals (bbls): 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28553 100 0 28653 39 7/3/2006 9/20/2006 CD4-320, CD4-318A, CD4-17 Zoos / 4th 2007 / 1st Total Ending Report is due on the 20th volume 28553 100 369 29022 39 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Pertormance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in'ectivi test I hereby certify that the foregoing is tr d correct to the best of my knowledge. Signature: Date: ~~ ~~, ~pE; Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate >+~ _ ~ ~ ~ ~~ s ~ - 3 I AI.ASSI, OIL A1~TD GAS C011TSER~ATI011T CO1rIlrIISSIOI~T Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKi, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX {907) 276-7542 Re: Colville River Field, Nanuq-Nanuq Oil Pool, CD4-208 Sundry Number: 306-266 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to your request to increase the allowable volume .that may be disposed into the surface casing annulus of the above-referenced well. Your request to increase the allowable disposal volume to 70,000 barrels is GRANTED. 20 AAC 25.080(d)(1) restricts the maximum disposal volume to 35,000 barrels unless "...the operator demonstrates that compliance with [the] limitation is imprudent." CD4-208 is one of two wells available at this drill site authorized for annular disposal. The determined down-hole injection pressures of other potential wells at the drill site are relatively high and could result in exceeding the leak-off pressure of the surface casing shoe. Also, since the only physical solids processing equipment available at Alpine is part of the rig equipment, there is no practicable grinding alternative in the area. The Commission is satisfied that CPAI has demonstrated that meeting the regulatory volume requirement is, in this case, imprudent. Please note that disposal into the surface/production casing annulus of CD4-208 must comply with the remaining requirements and limitations of 20 AAC 25.080. 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 ~f15_°I(o a ConocoPhillips Alaska Colville River, CD4-208 > Sundry Number: 306-266 • application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~~ day of August, 2006 Encl. ~•~ ~ ~~~ Al~G 0 9 2006 STATE OF ALASKA da. ALASKA OIL AND GAS CONSERVATION COMMISSIC~~ska f3i1 & Gas Cons. Commission ANNULAR DISPOSAL APPLICATION Anchorage 20 AAC 25.080 1. Operator 3. Permit to DriN Name: Number: 205-162 ConocoPhillips Alaska 4. API Number: 50-103-20517-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-208 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: Nanuq 5, CD4-320, CD4-209, CD4-210 Torok and Seabee formation, shale, siltstone and sandstone ' b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation - None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1 600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 73. Maximum anticipated pressure at shoe: 15,840 bbls 8/6/2006 densities range from diesel to 12#/gal 2067 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, domestic waste water, any added water 17-Aug-06 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data 0 Other 0 previous authorization for new oroduct cleanuo fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ '^ (~ ~ Signature: - ----~ --- Title: Printed ~ Phone ZG f "~ ~I 7 ~1 f / ~ Name: Chip Alvord Number: 265-6120 Date: ` ~/ ~~O Commission Use Only diti f C l ~ ~~~ ~`US~a l LOT i d on ons o approva : : rev ew an approva Subsequent form required: ~ d " Approval number: ~f~~.1c I oC l!L ~X _ /_ /1 APPROVED BY Approved by: ~ STONER THE COMMISSION Date: G`r~/~J 'f'/~ r v g~d1s `'~~ /o • c~ Form 10-403RD Rev. 6/2004 O ~ f V `~ TRUCTIONS ON REVERSE ~ ~ ~~~ ~ ~ ~QOSubmit in Duplicate I • Annulus Disposal Transmittal Form -Well CD4-208 AOGCC Reeulations. 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD4-208 2 The depth to the base of freshwater aquifers and permafrost, if 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. (R'ef. 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 may be 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 70,000 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 CD1&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 2067 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 I 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 de 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 CD4-318A, CD4-16, CD4-17, CD4-321 will be enerated. 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 NlA containment of drillin waste. • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) v~~°a ~.o-~~,~os AssumAtions Well CD4 -2 08 500 psi f 1 , Maximum injection pressure o Date 8/7/ 20 06 0 ppg 12 id i fl i . s u on Maximum density of the inject si/ft 434 0 i h " p . s oe casing s Pore pressure at the 9 5/8 Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi Maximum Fluid Density to avoid Burst of Surface CaSing R drostatic +pApplied - Formation 85% - pH U p y burst _ 4,888 = ( 2,439 * 0.052 * MW,,,~ ) + 1500 - ( 0.4337 * 2,439 ) N = 35 PPg MWmax 2,439 TVD ~ Surface Casing String Size 9.625 in Weight 40 PPf Grade L 80 d ~o' v Yburst100% 5,750 psi b° .N ~ 4,888 Psi pburst85% U Depth of Shoe 2,439 ft FIT/LOT @ Shoe 16.3 ppg or 2,067 psi FIT/LOT for Annulus 14.4 ppg c Max Surf. Pressure 1,500 psi 0 0 t; TOC Est. @ 6,368' MD 5,824' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String pcollapse85% - pHydrostatic +pApplied - pGasGradient - pHeader 4,599 =( 5,824 * 0.052 ~` MWn,~ )+ 1,500 - ( 0.0700 * 5,824) - 1,000 MWmax = 14.9 PPg 4.5 "Tubing 2nd Casing String Size 7 in 6,164 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 pst pcollapse85°/ 4,599 psi Top of Cement 5,824 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Amax allowable =Shoe TVD Depth * .052 * Shoe FIT/I,OT Amax allowable - ( 2,439 * .052 * 16.3 ) Pmax allowable - 2,067 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD4-208 CD4-208 x Y elts etails @ AOGCC Ann. Disp. Permit # Surface Ca ermit Date sing Shoe ASP 4 Coordinates ource well NAD 27; Ann. Vol. "*** 3/e134.1o tart Date aaonia~.i4 nd Date ~ nc from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. urf LOT (ppg) Surface casing TVD (ft) nnular LOT (ppg) omments xp ora ion Nanuk 1 Nanuk 2 Nanu 3 n n 1737 584 376499.69 378326.61 5957361.96 5956241.68 11.8 14.9 1781 2393 5.1 Exploration P&A'd Ex toration Nanu 5 Started again 5/24106 with CD4-319 CD4-208 CD4-318 CD4-209 305-373 306-183 306-181 12/9/2005 5/30/2006 5/26/2006 CD4-208, CD4-318, CD4-209 CD4-320. CD4-316A CD4-210, CD4-209, CD4-320 30,023 15840 547 12/14/2005 7/3/2006 5/30/2006 1/19/2006 7/2/20D6 1366 0 2054 621 377174.72 378134.16 376138.41 377929.60 47 999 5955790.42 5956792.74 5956308.25 5957379.44 77 5957483 18.4 16.3 18.2 14.7 18 4 2400 2439 2375 2377 2386 16.1 14.4 17.1 17.50 17 30 25,525 bbis to 5130106 Ann Dis SD date: 7/3/2006 Not for annular dis osal CD4-210 CD4-320 704 1280 . 377 377898.52 . 5958051.35 . 17.1 2378 . 17.80 Not for annular dis osal * Lateral distance in feet, between surface casing shoes, in the X-Y plane *" As of May 5, 2006 Note that this sheet is not the definitive record for annular disposal volumes • • Note to File CD4-208 (205-162...306-266) Colville River Unit (Nanuk-Nanuq) ConocoPhillips Alaska, Inc Re uest Increase allowed annular disposal volume from 35,000 barrels to 70,000 barrels. Recommendation Approve annular disposal of up to 70,000 barrels of fluid in CRU CD4-208. Discussion ConocoPhillips Alaska Inc. ("CPAI"} has made application to increase the allowed disposal volume in the 9-5/8" x 7" annulus of the subject well from 35,000 barrels to 70,000 barrels of fluid. Annular disposa{ had been previously approved for this well through sundry 306-183, approved May 30, 2006. This document presents pertinent information supporting this request and recommends approval of ConocoPhillips' request. --As authorized by sundry 306-183, CPAI has disposed of a total of 15,840 bbls (as of 8/6/06} into the 9-5!$" x 7" annulus of this well. They have not observed any problems. --CPA! is making this request due the availability of only 2 surface casing annuli on CD4 pad. There are 5 other annuli on CD4, however 1 has experienced plugging problems, the pump in pressure on another was only slightly lower than the determined surface leak-off pressure and for the remaining 3 the initial pump in breakdown pressure exceeded the surface leak- off. --AD is the standard method CPAI uses to dispose of drilling waste. The grinding equipment is part of the rig equipment and solids are processed for disposal on-site. --In support of this application, CPAI provided surface-cementing information on the 3 additional wells drilled since 306-183 was approved. 2 of the wells are between 600' - 700' distant while the 3`d is nearly 1300' distant. Examination of the provided records did not reveal information that would preclude approval of CAPI's request. --A log analysis performed by Steve Davies is attached. As noted in his analysis, there are no USDWs in the area. He recommended granting CPAI's request. Based on examination of the submitted information and analysis, I concur and recommend approval of ConocoPhillips' request to increase the allowable disposal volume in CD4-208 to 70,000 bbls. Tom Maunder, PE Sr. Petroleum Engineer August 21, 2006 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\060821--CD4-208_increase.doc s ~ Note to File CRU CD4-208 (PTD 2051620) Re: ConocoPhillips' Application for Sundry Approval for Increase of the Annular Disposal Limit for Well CD4-208 Request ConacoPhillips requests approval to continue to dispose of waste drilling fluids by pumping them into the annulus of CD4-208. Due to a low number of usable annuli at the CD4 drilling site for disposal, they seek to increase the current injection limit from 35,000 barrels to 70,000 bbls. Recommendation Approve increasing the annular injection limit in CD4-208 to 70,000 bbls. Discussion CPAI's application was reviewed along with records from CD4-208, Nanuq 3, and Nanuq 5. Various reports from the operator place permafrost thickness between 800' and 1600' in this area. My estimate is 1350'. According to the findings and conclusions of Area Injection Orders 18, 18A, and 18B, there are no underground sources of drinking water beneath the permafrost in the Colville River Unit area. Examination of well log data from exploratory wells in and near the CD4 drill site conducted for the Nanuq Area Injection Order (AIO 28) confirms that there aze no aquifers within the affected area that could serve as underground sources of drinking water. The surface casing shoe of CD4-208 lies at the base of a thick claystone and siltstone interval at about 2403' TVDss. This interval contains about 140 true vertical feet of claystone and siltstone, and it functions as the upper confining layer. The annulus used for disposal of drilling wastes extends from the surface casing shoe to the top of cement for the 7-inch casing string, which is estimated to be at about 5788' TVDss. Beneath the CD4-208 surface casing shoe is a sequence of siltstone, claystone and shale with scattered, thin layers of sandy siltstone and silty sandstone that are the receptors for the injected waste fluids. Lower confinement is provided by several intervals of claystone, shale and siltstone that have an aggregate thickness of about 400 true vertical feet. Conclusions The 9-518-inch surface casing shoe is set neaz the base of a thick claystone and siltstone interval. There appears to be a sufficient volume of sandy siltstone and silty sandstone open to the annulus to accept the proposed additional injected fluids. Upper and lower confining layers aze sufficiently thick to ensure injected materials stay within the target interval. There are no USDWs in this area. I recommend approval of increasing the injection limit from 35,000 to 70,000 bbls for CD4-208. Steve Davies Senior Petroleum Geologist August 10, 2006 West Manua 3 CRU CD4-208 Annular Injection Zone CD4-208 Nanuq 5 East Vertical axis presented in true vertical depth subsea; no horizontal scale. ~f~ R-~ n_~nn~ i F ConocoPhillips Alaska, Inc. .~:. ~~,. Post Office Box 100360 ~, ~, Anchorage, Alaska 99510-0360 ~~n~~~~~'' Telephone 907-276-1215 August 8, 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 CD4-208 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4-208 (Sundry permit #306- 183) be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the limited available annuli on CD4, it is requested that the volume limit described in 20-ACC 25.080 d. 1. be raised from 35,000 bbls to 70,000 bbls. Currently there are seven penetrations drilled from the CD4 pad. Only 3 wells (CD4-208, CD4-318, CD4-319} were strong candidates for annular disposal. The other 4 wells (CD4-209, CD4-320, Nanuq 5, &CD4-210) had either surface casing leak off tests that were relatively close to the annular leak off test or the annular leak off test was greater than the surface casing leak off test. The latter cannot be an annular disposal candidate due to the low surface leak off tests. The other wells are marginal candidates for annular disposal, because the injecting pressure will likely be close to the casing shoe test pressure and small fluctuations in the injection pressure may cause the well to be shut down prematurely. The three permitted annuli are now limited to two useable annuli, since annular disposal was shut down on CD4- 318 due to the pressures exceeding limits after only 547 bbls of fluid. As of 8/6/06 we have disposed of 15,840 bbls of fluid into CD4-208. Also as of 8/6/06 we have disposed of 30,023 bbls into CD4-319. Increasing the allowable disposal volume for CD4-208 will allow for time to drill more wells and potentially other candidates for annular disposal. For further details please reference the original annular disposal permit for CD4-208, approved 5/30/2006. Annular disposal in CD4-208 started on 7/3/2006. In review, the initial annular LOT (14.4 ppg) occurred at a lower equivalent mud weight than the casing shoe test (16.3 ppg LOT). If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, L°"~r~* r a~ Liz Galiunas Drilling Engineer cc: CD4-208 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 WGS`cv~c\~C~ `~ r~S~~~,pC--~ `t S `t r` ~-~ ~S~Crc_~ v ~ ~ ~l ~- ~~c5 ~°~~,y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 205-162 ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 7. Well Name: CD4-208 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20517-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal 0 or Continuation ^ or Final ^ 306-183 5/30/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 369" 369 totals (bbls): 2005 / 4th 2006 i 1st 2006 / 2nd 2006 7 3rd Total Ending Report is due on the 20th volume 369 369 0 (bb~s): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. c---~---.. ____•-a.. Signature: ~ ~ ~ Date: 7 ~~ alO~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate CD4 -208 (PTD 205-162) .~ Subject: CD4-208 (PTD 205-T62) From: NSK Problem Well Supv <n1617~conocophillips.conl> Date: Thu, 16 Mar 2006 09:21:06 -0900 ~To: Thomas 1~~launder ~-. on~maunder(ii=admin.siate.ak.us->, .lames Red ~~~;jimre<<<~~~!~~dnlin.st~~tc.ak.us~=~ CC: ~~SK Ni~oblem bVell Supv <nl(i17~~~:conocophillips.com=~- Tom, New well CD4 -208 (PTD 205-162) is showing signs of TxIA communication by an elevated IA pressure tracking tubing pressure. The current plans are to flow test the well into a tank for a few days to clean up the well bore then diagnosing and repairing the TxIA AnnCom with slickline. The communication is The well will be SI after flow testing. Let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 ~~ ~~i~~ F:,~~- 1 of 1 5/31/2006 1:10 PM ~~ LJ Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 r'' ~~ FRANK H. MURKOWSK/, GOVERNOR >~ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Nanuq Oil Pool, CD4-208 Sundry Number: 306-183 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this (day of June, 2006 Encl. ao~ /6a ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~n~~~~' ~'' ~~ Telephone 907-276-1215 May 19, 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 CD4-208 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-208 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 CD4-208 approximately June 3, 2006 or as soon as a permit is available. 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 CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: no new wells 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 (14.4 ppg) occurred at a lower equivalent mud weight than the casing shoe test (16.3 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. Sin ,F,.ely, ~". -.. ~~J/ d ~. ~'°~~ John n Drilling Engineer cc: CD4-208 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSfON ANNULAR DISPOSAL APPLICATIOIrJ, 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 205-162 - ConocoPhillips Alaska 4. API Number: 50-103-20517-00 - 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-208 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: Nanuq 5 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1 600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2067 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- formation fluids associated with the diesel contaminated drilling mud completion fluids 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 3-Jun-O6 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. ' 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foreg o ing is true and correct to the best of my knowledge. ,~ ° Signature: ~~ ~~~ / ~ Title: ~ t~~ ~C~-~~-a-~+-r Printed Phone Name: Chip Alvord Number: 265-6120 Date: '~2-AtZo~L Commission Use Only sf'~~`{~~s Conditions of approval: LOT review and approval: f b i S d ~'-`~~ ' l ' l ~' ~ sequent orm requ re u : Approval number: ~ J~./ .f (~ APPROVED BY THE COMMISSION '"' Approved by: COMMISSIONER Date: ~7 ,,~v v S: Zs.ob Form 10-403RD Rev. 6/20040 I RUCTIONS ON REVERSE Su mit m Dup irate Annulus Disposal Transmittal Form -Well AOGCC Reeulations, 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD4-208 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 CD1 &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 2067 psi. See attached calculation calculations showin how this value was determined. a e. $ 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 oral 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 NIA de 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 CD4-318, CD4-209, CD4-320, CD4-210, CD4-211, CD4-16, will be enerated. CD4-17 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com Hance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ~ • Well CD4-208 Date 5/ 19/2006 u v zs 00 H U 0 0 0 TOC Est. @ 6,368' MD - ~ 5,824' TVD Surface Casing Strin Size 9.625 in Weight 40 PPf Grade L 80 Yburst100% 5,750 psi Pburst85% 4,888 psi Depth of Shoe 2,439 ft FIT/LOT @ Shoe 16.3 ppg or 2,067 psi FIT/LOT for Annulus 14.4 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 5,824 * 0.052 ~ MWm~ ) + 1,500 - ( 0.0700 * 5,824) - 1,000 MWmax = 14.9 PPg 2nd Casing Strin Size 7 in Weight 26 ppf Grade L 80 Ycollapset00% 5,410 Pst Pcollapse85°/ 4,599 Pst Top of Cement 5,824 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>439 * .052 * 16.3 ) Pmax allowable - 2,067 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Pressure Calculations for Annular Disposal ot+'`:` ~:: .y .: U -: N I ~~ (for submital with Annular Disposal Application) Assumptions 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 2,439 TVD ,/ Version 1.0 - Jan'OS Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,439 * 0.052 * MWmax ) + 1500 - (0.4337 * 2,439 ) MWmax = 35 PPg • • ~onocoPhillips Casing Detail 9 5/8" Surface Casing Well: CD4-208 Date: 12/1/2005 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 2.24 37.10 Jts 3 to 67 65 Jts 9-5/8" 40# L-80 BTC Csg 2465.90 39.34 Weatherford Float Collar 1.47 2505.24 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 85.03 2506.71 Ray Oil Tools "Silver Bullet" Float Shoe 2.59 2591.74 2594.33 TD 12 114" Surface Hole 2604.33 TOTAL BOWSPRING CENTRALIZERS -39 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66. 74 joints in the pipe shed. Run 67 joints - 7 joints stay out Casing shoe @ 2594.3' MD/ 2439.7' TVD Use Best-o-Life 2000 pipe dope MU torgue ~ 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt- 130k Block Wt - 75k Supervisor. Hill/Kuenzeler • • ConocoPhillips Alaska Page 1 of 3 Cementing Report Legal Well Name: CD4-208PB1 Spud Date: 11/29/2005 Common Well Name: CD4-208PB1 Report #: 1 Report Date: 12/2/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Cement Job Type: Primary Primary ~ Squeeze Open Hole Squeeze Casin _ _Plug Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,594 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 12/2/2005 SQ Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SQ Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Steve Doughten Pipe Movement: Reciprocating Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibfl Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:19:45 Time End: 21:22 SPM: 1 Stroke Length: 20.0 (ft) Drag Up: 165 ( Ibs) Drag Down: 145 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 20:18 Disp Avg Rate: 6.40 (bbl/min) Returns: 100 Volume Excess %: 400.00 Start Slurry Displ : 19:45 Disp Max Rate: 7.50 (bbl/min) Total Mud Lost: (bbl) Meas. From: 145 Start Displ: 21:17 Bump Plug: Y Cmt Vol to Sarf: 145.00 (bbl) Time Circ Prior End Pumping: 21:45 Press Prior: 750 (psi) To Cementing: 2.00 End Pump Date: 12/2/2005 Press Bumped: 1,200 (psi) Ann Flow After: N Mud Circ Rate: 294 (gpm) Top Plug: Y Press Held: 2 (min) Mixing Method: Tub Mud Circ Press: 300 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Densometer Mud Data Type: Spud Mud Density: 9.8 (ppg) Visc: 66 (s/qt) PV/YP: 22 (cp)/19 (Ib/100ftz) Gels 10 sec: 8 (Ib/100ftz) Gels 10 min: 21 (Ib/100ftz) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: (°F) Displacement Fluid Type:Mud Density: 9.8 (ppg) Volume: 172.10 (bbl) Stage No: 1 Slurry No: 1 of 4 Slurry Data Fluid Type: FLUSH Description: Biozan water w/nut plug Class: Purpose: Wash & MAR Slurry Interval: (ft) To: (ft) Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Printed: 5/19/2006 1:50:40 PM • • ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: CD4-208PB1 Spud D ate: 11/29/2005 Common Well Name: CD4-208PB1 Report #: 1 Report Date: 12/2/2005 Event Name: ROT -DRILLING Start: 1 1/28/2005 End: 12/24/2005 Stage No: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: LEAD Description: ASLite Class: Purpose: PRIMARY Slurry Interval: 2,095.00 (ftJro: (ft) Cmt Vol: 301.0 (bbl) Density: 10.70 (ppg) Yield: .4.45 (ft /sk) Mix Water: 20.72 (gal) Water Source: LAKE Slurry Vo1380 (sk) Water Vo1:259.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: Spacer Description: MUDPUSH XL Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: PRIMARY Slurry Interval: 2,594.30 (ftJro: 2,095.00 (ft) Cmt Vol: 49.0 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft'/sk) Mix Water: 5.10 (gal) Water Source: LAKE Slurry Vo1235 (sk) Water Vo1:28.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Pfintetl: 5/1920001 tib0:4U YM • • ConocoPhillips Alaska Cementing Report Page 3 of 3 ~ Legal Well Name: CD4-208PB1 Spud Date: 11/29/2005 Common Well Name: CD4-208PB1 Report #: 1 Report Date: 12/2/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Casing Test ,Test Press: 2,500 (psi) ~~ For: 30 (min) Cement Found between Shoe and Collar: N Log/Survey Evaluation Shoe Test Liner Top Test Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Interpretation Summary i Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Tool: N Tool: N Held PJSM, Cemented 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/nut plug as marker -Switched over to Dowell - Pumped 3 bbls water -Tested lines to 2500 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPush spacer @ 5.4 bbls/min @ 195 psi -Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min @140 psi to 350 psi -Observed nut plug marker @ shakers w/ 283 bbls lead slurry pumped -Pumped down surge can -pumped total of 301 bbls lead slurry -Switched to tail slurry mixed & pumped 49 bbls -15.8 ppg (Class G w/ .2% D0146, .3% D065, 2% S001) @ 5.7 bbls/min - 340 psi -Dropped top plug w/ 20 bbls water. Switched back to rig pumps & displaced cement w/ 172 bbls 9.8 ppg mud @ 6.4 bbls /min ICP 300 psi -Reciprocated pipe while pumping until 22 bbls displacement away -hole becoming sticky -set down onto landing ring for remainder of job. pre bump pressure 760 psi -Slow rate to 4 bbls / mins for last 10 bbls of displacement -bumped plug w/ 1200 psi - Checked floats OK - CIP @ 2145 hrs. -Full returns through out job w/ 145 bbls cement to surface. Printed: 5/19/2006 1:50:40 PM ~ • Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD DFS REPT NO. DATE CD4-208 ODR 2,605.0 2,449.0 2.20 3 12/2/2005 SUPERVISOR RIG NAME 8 NO. FIELD NAME / OCS NO. AUTH MD DAILY TANG CUM. TANG Lar Hill/Zane Kuenzler Do on Drillin Inc 19 AI ine 14,184.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/MUD Ni lin u Flow line. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W/MUD BOP test, P/U DP, M/U BHA, drill out, FIT. Dis lace to LSND. 12/1/2005 146,957 450,496 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 10093007 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 12/1/2005 2,548.71 28.920 174.560 9.625 in 2,594.0 ft 7.000 in 7,200.0 ft 11/27/2005 DENSITY(ppg) 10.00 ~ PP ECD ~ ~ 0 ' CUM COST 0 MUD DATA DAILY COST __ _ - -- -- - - --r -- FV PV/YP I GELS WL/HTHP FC/T.SOL ~ OIL/WAT ~ %SandIMBT PhlpM ', PfIMf CI Ca i H2S i LIME ; ES 300 34/71 42/85 6.6/ 3/ / 1.3/30.0 8.8/ 0.05/ _ _ - _- _ - -- -_ _ _ BIT NO. 1 BHA No.~ 1 BHA /HOLE CONDITIONS BHA WT. BELOW JARS STRING WT. UP STRING VVT. DN STRING WT ROT TORQUE I UNITS ~ BHA LENGTH - _ __- - i 885.89 _- ITEM DESCRIPTION NO JTS LENGTH O.D. LD. CONN SIZE CONN TYPE Bit 3 1.50 12.250 4.500 Mud Motor 29.23 8.000 5.000 Sub -Float 2.11 7.790 2.810 Stabilizer -NonMag 6.00 8.020 2.875 Crossover -NonMag 1.69 8.000 2.750 MWD 8.97 8.000 2.000 MWD 8.84 8.000 2.000 MWD 9.82 8.000 2.000 UBHO 2.92 8.000 2.750 Flex Joint -NonMag 30.96 7.500 2.813 Flex Joint -NonMag 30.72 7.750 2.813 Jars 34.28 7.625 2.875 Drill Pipe -Heavy Wgt 718.85 5.000 3.000 BITS _ _ -- _. ----- BIT I RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN 1-O-D-L B G-O-R 1 / 1 12.250 HUGHES-CHR MX-C1 6039440 2/16/1/18/1/12 114.0 11/30/200 3-3-CT-H-1 I WT-TD BIT OPERATIONS __ j 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP BIT I RUN WOB RPM GPM PRESS i P BIT HRS -- ` --- -- OPERATIONS SUMMARY FROM I TO HOURS CODETROUBLE SUB PHASE I DESCRIPTION 00:00 02:45 2.75 DRILL P WIPR SURFAC Pumped out from 2115' to 885' w/ 550 gpm, 40 rpm, 1660 psi to top of permafrost @ 1,700' and 400 gpm, 40 rpm, 1000psi from 1,700 to 885'. 02:45 03:45 1.00 DRILL P WIPR SURFAC Checked flow, static. RIH from 885' to 2,605'. String wt. PUW=160K SOW=140K ROT=150K TQoff=5K all @ 2, 583'. 03:45 05:30 1.75 DRILL P CIRC SURFAC Circ'd 3X BU w/ 650 gpm, 50 rpm, 2400 psi. 05:30 08:00 2.50 DRILL P TRIP SURFAC POOH on TT to BHA @ 885'. 08:00 10:00 2.00 DRILL P PULD SURFAC Downloaded MWD, UD BHA. Cleared rig floor. 10:00 12:00 2.00 CASE P RURD SURFAC R/U to run 9.625" casing. Held PJSM. 12:00 15:15 3.25 CASE P RUNC SURFAC RIH w/ 40 #, 9.625" casing as per detail to 1,679'. 15:15 15:45 0.50 CASE P CIRC SURFAC Circ'd BU staged pumps to 5 BPM, 320 psi. Printed: 5/19/2006 1:50:11 PM • ~ Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD ~~ TVD DFS REPT NO. DATE CD4-208 ODR 2,605.0 2,449.0 2.20_ 3 12/2/2005 -- - -__ - OPERATIONS SUMMARY - --- - FROM TO r HOURSI CODE TROUBLE SUB - --- - PHASE DESCRIPTION 15:15 15:45 0.50 CASE P CIRC SURFAC String wt. PUW=140K SOW=125K 15:45 17:30 1.75 CASE P RUNC SURFAC Cont'd to RIH w/ 9.625" casing to 2,557'. P/U landing jt. and hanger. Landed @ 2,594. 17:30 17:45 0.25 CASE P OTHR SURFAC UD Franks tool and blew down TD. 17:45 19:45 2.00 CEMENT RURD SURFAC M/U cement head and line. Circa hole for cement job w/ 6.56PM, 350 psi. String wt. PUW=165K SOW=145K w/ pump. 19:45 22:00 2.25 CEMENT PUMP SURFAC Held PJSM, Cemented 9 5/8" casing as follows: Pumped 40 bbls Biozan Ovate w/ nut plug as marker -Switched over to Dowell -Pumped 3 bbls water - Tested lines to 2500 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPush spacer @ 5.4 bbls/min @ 195 psi -Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min @140 psi to 350 psi -Observed nu plug marker @ shakers w! 283 bbls lead slurry pumped -Pumped down surge can -pumped total of 301 bbls lead slurry -Switched to tail slurry mixed & pumped 49 bbls -15.8 ppg (Class G w/ .2% DO-46, .3% D065, 2% S001) @ 5.7 bbls/min - 340 psi -Dropped top plug w/ 20 bbls water. Switched back to rig pumps & displaced cement w/ 172 bbls 9.8 ppg mud @ 6.4 bbls /min ICP 300 psi -Reciprocated pipe while pumping until 22 bbls displacement away - hole becoming sticky -set down onto landing ring for remainder of job. pre bump pressure 760 psi -Slow rate to 4 bbls /mins for last 10 bbls of displacement -bumped plug w/ 1200 psi - Checked floats OK - CIP @ 2145 hrs. -Full returns through out job w/ 145 bbls cement to surface. 22:00 23:00 1.00 CASE P MIT SURFAC Tested casing to 2,500 psi for 30 mins. Good test, R/D. 23:00 00:00 1.00 CASE P RURD SURFAC R/D casing equipment. 24 HR SUMMARY: Completed wiper trip, circa hole clean. POOH on TT, UD BHA. Ran casing to 2,594' and cemented. R/D casing and cementing equipment. PERSON NEL DATA --- -- ---- COMPANY SERVIC E NO. HOURST r_ -- - - -- COMPANY ~ SERVICE NO. HOURS ConocoPhillips Company M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 PRA -Petroleum Resour 1 Dowell 2 Doyon Drilling Inc 26 FMC Corporation Wellhe 1 ACI -Arctic Catering 5 Peak Oilfield Services Halliburton -Sperry-Sun 2 Baker Oil Tools Halliburton -Sperry-Sun 2 AOGCC -Alaska Oil & G 1 Halliburton -Sperry-Sun MATERIALS /CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel (Rig) 3,264 6,988 Water (Drilling) 600 -3,825 Fuel (Camp) 480 -1,520 Water (Potable) RESERVOIR AND INTERVAL DATA ___ RESERVOIR NAME ZONE TOP BASE COMMENTS CD1-19A CD4-208 1550 0 0.0 Printed: 5/19/2006 1:50:11 PM PRESSURE IN GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-208 Rig: Doyon 19 Date: Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Hill/Kuenzler Pump used: #z Mud Pump ~ strokes ~ 0.1005 Bbls/Strk ~ 8.00' Strk/min ~ T f T ~ i P d ~ ype o est: openholeTest LOT/Frr ng own ump drillpipe. Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 37.1 Ft 2594.0 Ft-MD 2439.0 Ft-TVD 2625.0 Ft-MD 2467.0 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: usE Prcl< LIST ~ 0 0 0 2550 0 0 0.00 575 Casin Test Pressure Int e rit Test 2 150 1 2550 2 40 0.25 500 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 200 2 2550 4 100 0.50 490 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 6 450 3 2550 6 275 1.00 4 Test Pressure: 2500.0 psi Rotating Weight: 130.0 Lbs $ 700 4 2550 8 350 1.50 Rotating Weight: 130.0 Lbs Blocks/Top Drive Weight: 74.0 Lbs 10 950 5 2525 10 500 2.00 4 Blocks/Top Drive Weight 74.0 Lbs Desired PIT EMW: 18.0 ppg 12 1150 6 2525 12 725 2.50 470 Estimates for Test: 0 bbls Estimates for Test: 1065 si 0 bbls 14 1350 7 2525 14 850 3.00 470 ~ ~ 16 1550 8 2525 16 725 3.50 470 EMW =Leak-off Pressure + Mud Weight = 850 + 9 6 PIT 15 Second 18 1800 9 2525 18 650 4.00 470 . 0.052 x TVD 0.052 x 2439 Shut-in Pressure, si 20 2000 10 2525 4.50 460 EMW at 2594 Ft-MD (2439 Ft-TVD) = 16.3 500 22 2200 15 2500 5.00 460 sooo L t 50 i d i t t h ld 24 2500 20 2500 5 50 460 os ps ur n g es , e . 98% of te st pres sure. 25 2550 25 2500 6 00 460 . 28 2500 30 2500 6 50 460 2500 ~ ~~~~' ""~'~ i ~ 1 ~ . :-, , 7.00 450 7.50 450 4 8.00 50 zooo 8 50 450 w . ~ 9 00 450 . 1500 9.50 4 y w 10.00 4 4 1000 -~ 500 0 0 1 z s o 5 , o , a 2 0 z e so ~~CASING TEST Barrels -~-L EAK-OFF 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 omments: LOT Equivalent Mud Weight 16.3 ppg. Good Casing test held 98% pressure. w i ~.v~+-cuo Dui lace Summary • • ~~~~~~~~'~ ~ Casing Detail 7" Casing Well: CD4-208 Date: 12/5/20 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.90 FMC Gen V Hanger 1.68 34.90 Jts 3 to 170 168 Jts 7" 26# L-80 BTCM Csg 7187.93 36.58 Weatherford Float Collar 1.25 7224.51 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.95 7225.76 Ray Oil Tools "Silver Bullet" Float Shoe 1.47 7312.71 7314.18 TD 8-3/4" Hole 7324.00 8-314" Hole TD @ 7324 MD 16166' TVD 7" Shoe @ 7314.18' MD 16164' TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-15 Straight blade centralizer one per jt on jts. # 109,110,111 Straight blade cent. one every other joint #'s 113 to 167 Straight blade cent.on jt. # 168 Top Nanuq Sand -7240' MD - 6155 TVD 175 joints in shed - 170 total jts. to run Last 5 jts. Out RA tag top of jt. # 10 @ 6884' Use Run & Seal i e do e Average make up torque 8000 ft/Ibs Remarks: Up Wt - 250 k Dn Wt - 175 k Block Wt - 75k Supervisor. Mickey/Kuenzuler • ConocoPhillips Alaska Page 1 of 3 Cementing Report Legal Well Name: CD4-208PB1 Spud Date: 11/29/2005 Common Well Name: CD4-208P61 Report #: 2 Report Date: 12/8/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Cement Job Type: Primary Primary _ _ S ueeze Open Hole Squeeze Casing ~ Plug _ _ _ _ Hole Size: 8.750 (in) Hole Size: Hole Size: Hole Size: TMD Set: 7,314 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 12/8/2005 SO Date: Date Set: BTM set: (ft) Csg Type: Production Casing SQ Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Production Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movem~ttt: Reaprocat+ng Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:06:30 Time End: 08:45 SPM: Stroke Length: 25.0 (ft) Drag Up: 250,000 (Ibs) Drag Down: 175,000 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 07:56 Disp Avg Rate: 7.00 (bbl/min) Returns: 100 Volume Excess %: 40.00 Start Slurry Displ : 08:07 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: N/A Start Displ: 08:07 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 08:52 Press Prior: 690 (psi) To Cementing: 1.00 End Pump Date: 12/8/2005 Press Bumped: 1,337 (psi) Ann Flow After: N Mud Circ Rate: 273 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 490 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Mud Data Type: Non-Disp. LS Density: 9.8 (ppg) Visc: 40 (s/qt) PV/YP: 7 (cp)/14 (Ib/100ft2) Gels 10 sec: 9 (Ib/100ft2) Gels 10 min: 10 (Ib/100ftz) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: (°F) Displacement Fluid Type:Mud Density: 9.8 (ppg) Volume: 255.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: FLUSH Descripti on: CW100 Class: Purpose: PRIMARY Slurry Interval: 5,249.00 (ft)To: 4,130.00 (ft) Cmt Vol: 30.0 (bbl) Density: 8.30 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Printed: 5/19/2006 1:50:47 PM • • ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: CD4-208PB1 Spud Date: 11/29/2005 Common Well Name: CD4-208PB1 Report #: 2 Report Date: 12/8/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Purpose: SPACER Slurry Interval: 6,368.00 (ft~o: 5,249.00 (ft) Cmt Vol: 30.0 (bbl) Density: 12.00 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: TAIL Slurry Interval: 7,314.00 (ftJro: 6,368.00 (ft) Cmt Vol: 40.0 (bbl) Density: 15.80 (ppg) Yield: 1.16 (ft'/sk) Mix Water: 5.01 (gal) Water Source: lake water Slurry Vo1:190 (sk) Water Vo1:23.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) Pressure: 12.50 (ppge) Liner Lap: For: 30 (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: 30 (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N Log/Survey Ev aluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N Cet Run: N Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Remarks PJSM -Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 3700 psi -Pumped 25 bbls CW-100 @ 4.3 bbls/min @ 338 psi -Mixed & pumped 30 bb ls MudPush XL @ 12.0 ppg @ 4.5 bbl/min @ 395 psi -Dropped btm plug -Mixed & pumped 40 bbls tail slurry Class G w/ additives @ 15.8 ppg @ 362 psi -Dropped top plug w/ 20 bbls water f/ Dowell Printed: 5/19/2006 1:50:47 PM • • ConocoPhillips Alaska Page 3 of 3 Cementing Report Legal Well Name: CD4-208PB1 Spud Date: 11/29/2005 Common Well Name: CD4-208P61 Report #: 2 Report Date: 12/8/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Remarks Switched to rig pumps & displaced w/ 255 bbls 9.8 ppg LSND mud @ 7 bbls/min @ 320 to 630 psi -slowed rate to 3.5 bbls/min @ 320 to 690 psi for last 10 bbls of displacement -bumped plug w/ 1337 psi -held for 5 mins. -bleed off & check floats - CIP @ 0852 hrs. -Full returns throught the job -reciprocated pipe until last 10 bbls of displacement Printed: 5/19/2006 1:50:47 PM • • Page 1 of 3 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME CD4-208 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 7,324.0 TVD 6,166.0 DFS 8.20 REPT NO. 9 DATE 12/8/2005 SUPERVISOR Don Micke /Zane Kuenzl RIG NAME & NO. Do on Drillin Inc 19 FIELD NAME / OCS NO. AI ine AUTH MD 14,184.0 DAILY TANG 0 CUM. TANG 0 CURRENT STATUS RIH to clean out shoe, ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD 0 CUM INTANG W/ MUD 0 24 HR FORECAST Drill out shoe +20', FIT, C/O to OBM, drill ahead horiz. DATE OF LAST SAFETY MEETING 12/8/2005 DAILY TOTAL 386,382 CUM COST W/MUD 1,841,046 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF 16.23 AFE 10093007 AUTH. LAST SURVEY: DATE TMD INC AZIM 12/7/2005 7,268.34 82.350 331.990 LAST CASING 7.000 in 7,314.0 ft NEXT CASING 3.500 in 14,184.0 ft LAST BOP PRES TEST 12/8/2005 -- -- - - DENSITY(ppg) g,$0 PP '', ECD 9.80 MUD DATA' DAILY COST Q CUM COST Q FV PV/YP ] GELS WUHTHP ; FC/T.SOL OIUWAT %Sand/MBT~ PhIpM ~ Pf/Mf CI ~ Ca i H2S LIME ~ ES ~_ _'_ 40 7/14 8/9 3.6/8.8 1/ / 0.3/17.5 9.0/ 0.05/ __ __ i eHA No. ', 3 BHA /HOLE CONDITIONS BIT No. 3 BHA WT. BELOW JARS STRING VJT. UP -- STRING WT. DN STRING WT. ROT; TORQUE I UNITS ~ BHA LENGTH - -- _~_ - _ - -- _ _ ft-Ibf 374.02 --- - ITEM DESCRIPTION NO JTS LENGTH O.D. ~ LD. CONN SIZE CONN TYPE Bit 1 1.20 6.125 4.000 5200 Series Geo Pilot 1 16.18 5.000 2.820 5200 Geo Flex 1 11.54 4.750 1.250 I-L-S Stab 1 3.60 4.750 1.250 DM HOC 1 8.56 4.670 1.920 SP4 1 24.53 4.740 1.250 PWD 1 10.78 4.740 1.250 TM HOC 1 10.94 4.600 1.920 Sub -Float 1 0.97 4.640 2.250 Stabilizer -NonMag 1 5.45 4.750 2.250 Flex Joint -NonMag 1 30.93 4.750 2.250 Flex Joint -NonMag 1 31.00 4.750 2.250 Flex Joint -NonMag 1 31.01 4.750 2.250 Crossover 1 1.68 4.870 2.500 Drill Pipe -Heavy Wgt 3 91.89 4.000 2.563 Jars - Up/Down Jars 1 32.42 5.125 2.000 Drill Pipe -Heavy Wgt 2 61.34 4.000 2.563 -- _ -- - _ __ - _ BITS BIT 1 RUN SIZE MANUF. 1 TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R ~~ _ _ _ - 3 / 3 i 6.125 DBS FSF2553 10748311 15/15/15/// i 7,324.0 12/8/2005 0-0-NO-A-D-I-NO-BHA BI T OPERATIONS __ _ _-- _ BIT I RUN j WOB ~ RPM i GPM PRESS ~ P BIT HRS 24Hr DIST 24Hr ROP -CUM HRS ~ CUM DEPTH CUM ROP OPERATIONS SUMMARY_ __-__ - FROM ~ TO HOURS CODE ~ITROUBLE~ SUB PHASE , DESCRIPTION 00:00 01:30 1.50 CASE P RUNC INTRM1 Continue running 7" 26# L-80 BTCM csg f/ 2999' to 4923' (115 jts total) 01:30 02:30 1.00 CASE P CIRC INTRM1 Est. circulation @ 3.5 BPM -stage pump to 5 BPM & circulate btms.up + ICP 530 psi FCP 400 psi 02:30 05:30 3.00 CASE P RUNC INTRM1 Continue running 7" 26# L-80 csg f/ 4923' to 7277' (170 jts total) PU hanger & landing jt. -Land casing w/ FS @ 7314' FC @ 7224' No problems running casing 05:30 06:00 0.50 CEMENT PULD INTRM1 RD fill up tool -blow down TD - RU cmt. head & lines Printed: 5/19/2006 1:50:25 PM • • Page 2 of 3 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME JOB NUMBER 'EVENT CODE 24 HRS PROG TMD TVD DFS ~ REPT NO. DATE CD4-208 ', ODR 7,324.0 6,166.0 8.20 9 12/8/2005 - - -- - - OPERATIONS SUMMARY FROM T TO ~ OURS T _ CODE TROUBLE'. SUB ! PHASE _ -- - DESCRIPTION --- ----- 06:00 07:30 ' 1.50 CEMENT - CIRC _ _ _ INTRMI __ _ _ ----- - Est. circulation @ 2 BPM -stage pumps up to 6.5 BPM - ICP 660 psi FCP 490 psi -Reciprocate pipe 250 K PU 175 k SO -condition mud for cmt job 07:30 08:00 0.50 CEMENT PUMP INTRM1 PJSM -Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 3700 psi -Pumped 25 bbls CW-100 @ 4.3 bbls/min @ 338 psi -Mixed & pumped 30 bbls MudPush XL @ 12.0 ppg @ 4.5 bbl/min @ 395 psi -Dropped btm plug -Mixed & pumped 40 bbls tail slurry Class G w/ additives @ 15.8 pp @ 362 psi -Dropped top plug w/ 20 bbls water f/ Dowell 08:00 09:00 1.00 CEMENT DISP INTRMI Switched to rig pumps & displaced w/ 255 bbls 9.8 ppg LSND mud @ 7 bbls/min @ 320 to 630 psi -slowed rate to 3.5 bbls/min @ 320 to 690 psi for last 10 bbls of displacement -bumped plug w/ 1337 psi -held for 5 mins. - bleed off & check floats - CIP @ 0852 hrs. -Full returns throught the job - recipracated pipe until last 10 bbls of displacement 09:00 10:00 1.00 CEMENT OTHR INTRM1 RU & test casing to 3500 psi for 30 mins. -bleed off pressure - 10:00 10:30 0.50 CEMENT PULD INTRM1 RD cmt. lines & cmt head - LD landing jt. 10:30 11:30 1.00 DRILL P OTHR INTRM1 Pull wear bushing -Install pack off & test to 5000 psi for 10 mins 11:30 12:00 0.50 DRILL P OTHR INTRM1 LD csg elevators & long bails 12:00 13:00 1.00 WELCTL EORP INTRM1 Held PJSM. C/O top rams to 3.5"X6" variable. 13:00 17:30 4.50 WELCTL BOPE INTRM1 Tested BOPS. Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke & kill line valves, choke manifold valves, floor safety & dart valves, TD IBOP valves to 250 & 5000 psi -Performed accumulator closure test -Witnessing of test waived by J. Crisp of AOGCC. Blow down kill & choke lines - RD test equipment. 17:30 18:00 0.50 DRILL P OTHR INTRMI Installed wear bushing. 18:00 18:15 0.25 DRILL P RIRD INTRMI P/U short bails and elevators. 18:15 18:30 0.25 DRILL P PULD INTRM1 P/U Geo-Span unit to ri floor. 18:30 18:45 0.25 DRILL P PULD INTRM1 P/U 6 jts. 4" DP from shed and S/B in derrick. 18:45 22:45 4.00 DRILL P PULD INTRM1 P/U BHA #3 including: bit, Geo-pilot, 6X MWD, flt sub, stab, upload MWD, 3X flex DCs, XO, 3X 4" HWDP, C/O jars to new, 2X 4" HWDP. Total length 374'. 22:45 00:00 1.25 DRILL P TRIP INTRMI P/U 4" DP from shed and singled in hole to 1,228'. 24 HR SUMMARY: Landed 7" casing @ 7,314' and cemented per program. Pressure tested casing to 3500 psi for 30 mins. R/D, C/O rams, test BOPE. P/U BHA #3 including Geo-pilot and singled in hole to 1,228'. PERSON NEL DATA COMPANY SERVICE NO. i HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 PRA -Petroleum Resour 1 Dowell 2 Doyon Drilling Inc 25 FMC Corporation Wellhe ACI -Arctic Catering 5 Baker Oil Tools Halliburton -Sperry-Sun 2 Quadco / Totco 1 Halliburton -Sperry-Sun 2 ASRC Energy Services ( 1 Halliburton -Sperry-Sun MATERIALS /CONSUMPTION ITEM UNITS USAGE ON HAND ~ ITEM UNITS USAGE ON HAND Fuel (Rig) 2,650 12,103 Water (Drilling) 550 -8,465 Fuel (Camp) 400 -1,120 Water (Potable) Printed: 5/19/2006 1:50:25 PM • ~J ConocoPhillips Alaska, Inc. Daily Drilling Report Page 3 of 3 WELL NAME JOB NUMBER EVENT CODE ~ 24 HRS PROG TMD CD4-208 ODR '. 7,324.0 RESERVOIR AND INTERVAL DATA ND DFS REPT NO. DATE 6.166.0 I _8.20_ ~ 9 12/8/2005 RESERVOIR NAME ZONE TOP BASE COMMENTS CD1-19A - _ - CD4-208 - - 1120 0 0.0 - Printed: 5/19/2006 1:50:25 PM ~ ~ ~ PRESSURE IN GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-208 Rig: Doyon 19 Date: 12/8/2005 Volume In ut Pum Rate: Drilling Supervisor: Kuenzler/Mickey Pump used: Cement unit ~ Barrels ~ ' Bbis/strk ~ 0.8 Bbl/min i d Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ ng own Pump annulus. ~ Casin Test Pressure In te rit Test Hoie Size: 8-3/Y' ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 34.9 Ft 2,594 Ft-MD 2,440 Ft-TVD 6,368 Ft-MD 5,824 Ft-TVD Bbls si Min si Bbls si Min si Casino Size and Description: 9-5/8" 4o#/Ft L-ao BTC ~ 0 0 0 0 430 Chan es for Annula r Ade ua c Test Pressure Int e rit Tes t 1 0.5 61 0.25 420 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 240 0.5 410 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 364 1 405 ize is that drilled below outer casing. 4 2 495 1.5 timated TOC for Hole Depth. 5 2.5 586 2 3 Enter inner casing OD at right Desired PIT EMW: 16.5 ppg 6 3 550 2.5 390 Estimates for Test: 850 si 0.6 bbls 7 3.5 525 3 385 ~ ~ 8 4 515 3.5 385 EMW =Leak-off Pressure + Mud Weight = 586 PIT 15 Second 9 4.5 510 4 380 + 9 8 0.052 x TVD 0.052 x 2440 Shut-in Pressure, si 10 5 505 4.5 380 EMW at 2594 Ft-MD (2440 Ft-TVD) = 14.4 420 15 5.5 500 5 375 o0 ~ 20 5 5 370 o . 25 6 370 30 6.5 370 7 365 7.5 360 8 360 w ~z 8.5 355 j 9 355 soo 9.5 35 ~ w ,~ 10 3 a 0 o , 2 3 4 e s o e t o 1 5 2 0 z s so "'~~CA SING TEST Barrels -~-L EAK-OFF TE ST 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 5/8" Surface casing shoe LOT = 14.4 ppg SURFACE CASING SHOE SEPARATION FROM CD4-208 CD4-208 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 378134.16 5956792.74 ells Nanuk 1 Nanuk 2 Details @ AOGCC n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. **** tart Date nd Date is anc from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments xp ora ion Exploration P&A'd Nanu 3 1737 376499.69 5957381.96 11.8 1781 Ex !oration f~nu 5 584 378326.61 5956241.68 14.9 2393 15.1 CD2-319 305-373 12/9!2005 CD4-208, CD4-318 25525 12/14/2005 1/19/2006 1388 377174.72 5955790.42 18.4 2400 16.1 CD4-208 0 378134.16 5956792.74 16.3 2439 14.4 CD4-318 2054 376138.41 5956308.25 18.2 2375 17.1 * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of May 5, 2006 Note that this sheet is not the definitive record for annular disposal volumes caslN° t>t rays Calculation Methad: Minenum Cumture Scan Mefhod: Trav. Cylinder North Project: Colville River Unit ~ , zaa.m zsea.33 sae' asl ConocoPhillips ~`"~~''~" "° "° MU ~. si Z 81x3.93 73U.18 7' W„° Bn'~ieinodElapia:e~e Site: Alpine CD4 3 xm.to 1z7ez.oo 3vz- }1 ~aS1C8 GeodeticMagraticModelnBGGM2W5CONU5) Well: CD4208 ~i Wellbore: CD4208 HALLIBURTON Ground Level: 19.00 Survey: CD4-208 , ~ • RKB: Doyon /9L 55-10ft (Doyon 19138-1 t19)~ Non hing/ASP V: 5957492.96 ~ Sp~r-y Drilling Ssrvic~s EnstinylASPX 3780382fl 1200 - ~ - $Q~k - - - ~Z~ O 600 - - - - - - -,y - ---- d' \ 4,F \~ ~i ~ ~ -- - 0 - - - ~ 9 5/8" z - c ~ I o ~ y t -600 - - ~1 - - 7 ' d 9 5/8" 'I o ~~ z ~ I r .. 'o rn 5/8" -1200 -- -- - - - ~ ~, - 9 5/8" ~ • GD~31a ~~ ~ ~ 9 5/8" -1800- - - - ~ ~~ -' ,~16Q~1, CD431 G~A~ 2 d~~~ Nan~4 5 -2400 -- ~,, - - --~ --- ~ -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 West(-)/East(+) (600 ft/in) ~ • X'7'C ~ir.iC~ ~'11r=, r1t'c:>t1, °( 71.i )-r %1', r i"+~__rjt»t..-tr-_C;. t!:7 r].1 `~: _a iJ l; c:. 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This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 145 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 42% XS of the calculated hole volume. --On the initial leak off test, the pressure slope rises with some inflections to the determined LOT point at 16.3 EMW. Approximately .4 bbl was pumped in with the pressure declining to 14.7 EMW. During the observation period, the pressure declined to about 13.0 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the .break at 14.4 EMW. The pressure declined with additional pumping to 13.7 EMW. During the observation period, the pressure declined to 12.6 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/ mile radius of CD4-208. Nanuq 5 is about 600' distant at 5 o'clock from the surface shoe. An examination of the cementing information for this well did not reveal any problem that would preclude granting CPA's request for CD4-208. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. it. Tom Maunder, PE Sr. Petroleum Engineer May 30, 2006 G:\common\tommaunder\Well Information\By Subject\Amiular Disposal\060530--CD4-208.doc • Note to File CRU CD4-208 (PTD 2051620) Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Waste on Well CD4-208 Request ConocoPhillips requests approval to dispose of waste drilling fluids by pumping them into the annulus of CD4-208. This annulus extends from the base of 9-5/8" casing at 2600' MD (2384' true vertical feet subsea, or TVDss) to the top of 7" casing cement at about 6368' NID (5770' TVDss). Recommendation Approve annular injection operations in CD4-208 as proposed. Discussion CPAI's application to inject wastes generated by drilling operations into the annulus of CD4-208 was reviewed along with records from offset wells Nanuq 3 (1600' to the west) and Nanuq 5 (600' to the south). The diagram below presents a schematic view of CD4-208 with respect to Nanuq 3 and Nanuq 5. Depths are presented as TVDss. Northwest Nanuq 3 CD4-208 Nanuq 5 Southeast 1 . 11 1 - oka, U~I:ih ;rt~.l, 1 Ionrrr. I Garmro Qty Dtyth Rarfi.ily Rarosrfy ;;!:.i ..'.'1 :.. .!_ lvl, .T 1 I 1 1 (Jr'fA rn ~~G. ~- . ~.. tNDSS __ RaD -0 DTjNis - G:rI 3, 0: ON.MN ZO - ;0 VSf ; 1 1 G.n ls ,,,,,,,,,,,,, D : oNM/e zD : ') Ru0(R-S~ R NOB MWDi I I 1 .... '::: '::: Son~torx': ::. Ra5(RrS; RNOB~RNOB MWBr - - .~.;._ aldtfonc': ::. '~ ~ ~ ~ ••• ... ... ... .. .... ONMM 200 ` - [; G.'C7 2 [ 'wrl 1 1 .~:........ ": ~• 0 : ONMM ^.00 [; G~CJ 2 [ III I (A'Br: RNOB~6 U1 GR(BV/ ;D G.:rI 30 RNOB{BUt. _ ~ [; G"C7 3[ CI ~ ~I I 1 ;0 G:r] 30 ~ v: C3 3 [ ~ [; ~ ~I 1 - ~ ~ ~~ ~ I~ ~ 1 I as~ -iDDar I ~ ~ - -iDOa ~,~; ;il , ~ ; , T; , : iii 1 1 1 I I 1 I 1 -zooa - ~ ~ zoDO?~~oo I 1 ~ . 1 1 1 I I I -3000, ~ i i -3DOIF~!,.,. I 1 OI I ~1 1 `~I 1 1 1 1 1 -400G O j j -400G '~ I I U 1 - NI • I 1 ' 1--1 -5006 •..'.. i i -500G : ' _ . a I I -- a 1 I ~ . 1 I i 5 ~ I 1 1 I -600L , , -6000=:~!~G '- - . -7000 . -- ~. . .. -7006'C".;. - ~ Annulus Confining Intervals '"•""' CRU CD4-208 ~ ~ May 25, 2006 Note to File Page 2 of 2 Various reports from the operator place permafrost thickness between 800' and 1600' in this area. My estimate is 1350'. According to the findings and conclusions of Area Injection Orders 18, 18A, and 18B, there are no underground sources of drinking water beneath the permafrost in the Colville River Unit area. Examination of well log data from exploratory wells in and near the CD4 drill site conducted for the Nanuq Area Injection Order (AIO 28) confirms that there are no aquifers within the affected area that could serve as underground sources of drinking water. Surface casing shoes in offset wells Nanuq 3 and Nanuq 5 were set near the base of a sequence of interbedded siltstone and claystone at 1740' and 2261' TVDss, respectively. The surface casing shoe of CD4-208 lies within a thick claystone interval at about 2384' TVDss. The annulus that will be used for disposal of drilling wastes extends from the surface casing shoe to the top of cement for the 7-inch casing string, which is estimated to be at about 5770' TVDss. Immediately beneath the CD4-208 surface casing shoe is a thick sequence of siltstone, claystone and shale with scattered, thin layers of sandy siltstone and silty sandstone that will be receptors for the injected waste fluids. Upper confinement will be provided by about 140 true vertical feet of claystone and siltstone. Lower confinement will be provided by four intervals of claystone, shale and siltstone that have an aggregate thickness of about 400 true vertical feet. Conclusions The 9-5/8-inch casing shoe is set near the base of a thick claystone interval. Upper and lower confining layers are sufficiently thick to ensure injected materials stay within the target interval. There are no USDWs in this area. Based on examination of the submitted information and well records for Nanuq 3 and Nanuq 5, I recommend approval of pumping of drilling waste fluids into the annulus of CD4-208. Steve Davies Senior Petroleum Geologist May 25, 2006 • ConocoPhillips May 2, 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 ~;, Subject: Well Completion Report for CD4-208 (APD 205-162) Dear I~ommissioner: Conoc;oPhillips Alaska, Inc. submits the attached Well Completion Report for the recent: drilling operations on the Alpine well CD4-208. 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/:>kad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND. LOG 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ ~ .s 1b. Well Class: Development ^ Exploratoiy"R Service ^ StratigraphlG~'est^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., 2'jj S' orAband.: December , 2005 12. Permit to Drill Number: 205-1621 • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 30, 2005 " 13. API Number: 50-103-20517-00 4a. Location of Well (Governmental Section): Surface: 2918' FNL, 206' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: December 19, 2005 14. Well Name and Number: CD4-208 At Top Productive Horizon: 1602' FSL, 710' FEL, Sec. 24, T11 N, R4E, UM 8. KB Elevation (ft): 36.5' RKB 15. Field/Pool(s): Colville River Field Total Depth: 1300' FSL, 2143' FWL, Sec. 13, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 12244' MD / 6181' TVD Nanuq Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378039 y- 5957494 Zone- 4 10. Total Depth (MD + ND): 12792' MD / 6177' ND 16. Property Designation: ADL 380077, 380075 • TPI: x- 377522 y- 5956741 Zone- 4 Total Depth: x- 375176 - 5961758 ' Zone- 4 11. Depth where SSSV set: Landing Nipple @ 2102' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1647' 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 36.5' 114' 36.5' 114' 42" Portland Type III 9.625" 40# L-80 36.5' 2594' 36.5' 2440' 12.25" 380 sx AS Lite, 235 sx Class G 7" 26# L-80 36.5' 7314' 36.5' 6164' 8.75" 190 sx Class G 3.5" 9.3# L-80 7169' 12782' 6143' 6177' 6.125" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 7191' 6678' slotted liner from 7336'-12496' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production March 19, 2006 Method of Operation (Flowing, gas lift, etc.) pre-produced injector Date of Test Hours Tested not available Production for Test Period --> OIL-BBL 480 GAS-MCF 6700 WATER-BBL not available CHOKE SIZE not available GAS-OIL RATIO not available Flow Tubing Casing Pressure press. 1720 psi 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". '° " ~ , ~4"t"~ p ~S~II{S BFI. CLAY 2 5 200fi ~ • z3 • o NONE ~ ~'~~1CD e7„W ,~..~..„„,~.,,.,...- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~~~~~~~ ~s ~s.ns 51.E-`'~ S?'lc%~' „' ~~ r dt`jl,~ ze. s zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-208 Nanuq sand 7235' 6154' N/A CD4-208PB1 TD 12244' 6181' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C. Alvord Title: Alpine Drillino Team Leader Signature ~ `~ Phone 1 (~_ (°p ~ ~ Date ~ 2`' 2 ~ ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Event Name: ROT -DRILLING Start: 11/28/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Rig Name: Doyon 19 Rig Number: 19 Date .From - To ' - - - -_ Hours ' Code 'Sub 'Code - --- - 11/30/2005 00:00 - 10:15 MOVE MOVE 10.25, 10:15 - 12:00 I 1.75 ~ WELCT~ NUND 12:00 - 13:15 ', 1.25 WELCTL~ NUND ',13:15-13:45' ~ 13:45 - 14:45 14:45 - 15:30 ~ 15:30 - 18:45 ,18:45-19:30 ' 19:30 - 00:00 I 12/1/2005 00:00 - 12:00 ii II 12:00 - 22:30 I' I 22:30 - 23:15 23:15 - 00:00 12/2/2005 ',.00:00 - 02:45 ~I 02:45 - 03:45 0.501, DRILL 'PULD 1.00!, WELCT OTHR 0.7511 DRILL SFTY 3.251 DRILL PULD 0.751 DRILL 4.50' DRILL Page 1 of 11 Spud Date: 11/29/2005 End: 12/24/2005 Group: Phase ' Description of Operations MOVE ~'I Prep'd for rig move.. Moved shed, pit and motor complex, jacked rig floor. Moved to CD4-208. RIGUP Rig accepted @ 1015 hrs. N/U diverter. ~ RIGUP ,Finished N/U diverter and installed turn buckles, koomey lines, mud ~ bucket line, vac line, cellar pump service line, built dike around diverter. ', Took on spud mud. 'SURFAC ~ P/U BHA components for spud. SURFAC ', P/U std DP and perform function test of diverter system and koomey recovery. I' SURFAC I Held pre-spud meeting w/ all personnel. Performed table top diverter drill. SURFAC P/U BHA #1 including: bit, motor, flt sub, stab, MWD (installed pulser), UBHO. Loaded MWD, P/U std DCs and jar from derrick. OTHR 'SURFAC Filled stack w/ mud and tested surface equip. to 3500 psi. DRLG 'SURFAC ~~ Drilled from 114' to 432' MD/ 431' TVD. Took gyros @ 80', 169', 259', 12.00 ~, DRILL DRLG 10.50 DRILL ~ DRLG 0.75,I~ DRILL I ~1CIRC 0.75 DRILL WIPR 2.751, DRILL ~I WIPR 1.00' DRILL 'WIPR 03:45 - 05:30 05:30 - 08:00 108:00 - 10:00 1,10:00-12:00 12:00 - 15:15 15:15 - 15:45 15:45 - 17:30 17:30 - 17:45 ,17:45 - 19:45 1.75' DRILL CIRC 2.50 DRILL TRIP 2.00 DRILL PULD 2.00 CASE RURD 3.25 CASE RUNC 0.50 CASE ~ CiRC 1.75!: CASE !RUNG 0.25 2.00 19:45 - 22:00 2.25 349'. I ADT=1.72 ART=1.52 AST=0.17 String wt. PUW,SOW, ROT all =100K TOon/off=5K/4K @ 432' SURFAC 'i Drilled from 432' to 1,738' MD/ 1682' TVD. ADT=7.42 AST=3.29 ART=4.13 ICI String wt. PUW=128K SOW=126K ROT=125K TOon/off=7.5K/5.5K all @ 1,738'. II SURFAC I Drilled from 1,738' to 2.605' MD/ 2,449 TVD. !,ADT=8.13 AST=1.00 ART=7.13 ', String wt. PUW=147K SOW=139K ROT=145K TOonloff=8.5K/6K all @ 2,605'. SURFAC 'Circa hole clean w/ 2X BU prior to short trip w/ 655 gpm, 60 rpm, and i 2,240 psi. Checked flow, static. SURFAC I, POOH w/pump from 2.605' to 2,155' w/ 550 gpm, 40 rpm, and 1660 psi. SURFAC ~ Pumped out from 2115' to 885' w/ 550 gpm, 40 rpm, 1660 psi to top of permafrost @ 1,700' and 400 gpm, 40 rpm, 1000psi from 1,700 to '' 885'. 'SURFAC 'Checked flow, static. RIH from 885' to 2,605'. String wt. PUW=160K SOW=140K ROT=150K TQoff=SK all @ 2,583'. ;SURFAC ' Circ'd 3X BU w/ 650 gpm, 50 rpm, 2400 psi. ~ SURFAC '. POOH on TT to BHA @ 885'. 'SURFAC ~ Downloaded MWD, UD BHA. Cleared rig floor. SURFAC ~ R/U to run 9.625" casing. Held PJSM. SURFAC RIH w/ 40 #, 9.625" casing as per detail to 1,679'. SURFAC ~ Circa BU staged pumps to 5 BPM, 320 psi. ', String wt. PUW=140K SOW=125K II SURFAC ' Cont'd to RIH w/ 9.625" casing to 2,557. P/U landing jt. and hanger. ~, 'Landed @ 2,594. CASE OTHR 'SURFAC , UD Franks tool and blew down TD. CEMENl~ RURD 'SURFAC '~ M/U cement head and line. Circa hole for cement job w/ 6.5BPM, 350 ~ psi. String wt. PUW=165K SOW=145K w/pump. CEMEN 1 PUMP I SURFAC Held PJSM, Cemented 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker -Switched over to Dowell -Pumped i 3 bbls water -Tested lines to 2500 psi -Dropped btm plug -Mixed & Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD4-208 CD4-208 ROT -DRILLING Doyon Drilling Inc Doyon 19 Date From - To '! Hours Code 'Code' Phase 12!2/2005 19:45 - 22:00 12/3/2005 22:00 - 23:00 23:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 12:00 ',12:00 - 13:15 13:15 - 13:45 13:45 - 14:15 14:15 - 14:45 ,14:45 - 18:15 ,18:15 - 19:30 ' 'i19:30-19:45' X19:45-20:15 j 20:15 - 22:00 I I 22:00 - 22:15 I ~ 22:15 - 22:30 ~', 122:30 - 23:30 i 23:30 - 00:00 12/4/2005 ' 00:00 - 00:30 'i 00:30 - 12:00 ~I 2.25 ~I CEMENl~ PUMP SURFAC I 1.001 CASE 'MIT 1.00 !CASE ' RURD 2.50 WELCTL EQRP 1.00! WELLSRDEOT 1.00 ~I, WELCTL,' EQRP 2.OO RIGMNTRGRP 1.00 WELCT EQRP 4.501 WELCT BOPE 1.251 WELCTL BOPE 0.50', WELLSR EQRP 0.501 DRILL ' RIRD 0.501 DRILL PULD 3.50 DRILL ~', PULD I 1.25 ~ DRILL TRIP 0.25', DRILL TRIP 0.50''., DRILL REAM 1.75' CEMEN ~, DSHO 0.25 ~,! CEMENT DSHO 0.251 CEMEN7CIRC 1.OO CEMEN~FIT 0.501 RIGMNT RGRP 0.50, DRILL CIRC 11.50' DRILL DRLG I SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC i SURFAC 'SURFAC ',SURFAC ~~ SURFAC SURFAC ',SURFAC (SURFAC SURFAC INTRMI INTRM1 Page 2 of 11 Spud Date: 11/29/2005 Start: 11/28/2005 End: 12/24/2005 Rig Release: 12/24/2005 Group: Rig Number: 19 Description of Operations pumped 50 bbls 10.5 ppg MudPush spacer @ 5.4 bbls/min @ 195 psi - !Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min '~ @140 psi to 350 psi -Observed nut plug marker @ shakers w/ 283 bbls lead slurry pumped -Pumped down surge can -pumped total of 301 ~I bbls lead slurry -Switched to tail slurry mixed & pumped 49 bbls -15.8 ppg (Class G w/ .2% DO-46, .3% D065, 2% S001) @ 5.7 bbls/min - ~, 340 psi -Dropped top plug w/ 20 bbls water. Switched back to rig ',pumps & displaced cement w/ 172 bbls 9.8 ppg mud @ 6.4 bbls /min ICP 300 psi -Reciprocated pipe while pumping until 22 bbls 'displacement away -hole becoming sticky -set down onto landing ring for remainder of job. pre bump pressure 760 psi -Slow rate to 4 bbls / 'mins for last 10 bbls of displacement -bumped plug w/ 1200 psi - Checked floats OK - CIP @ 2145 hrs. -Full returns through out job w/ 145 bbls cement to surface. Tested casing to 2,500 psi for 30 mins. Good test, R/D. ~I R/D casing equipment. ICI Cleaned and N/D diverter system, C/O junk sub. N/U casing head and tested to 1000 psi for 30 mins. N/U BOPE. ~! Broke annular and changed out seals. M/U choke and con't N/U BOP. Tested BOPs. Hydril to 250 ik 3500 psi -Top pipe rams ,HCR choke & ~! HCR kill line valves, choke manifold valves 1-16, floor safety & dart ',valves, TD (BOP valves to 250 & 5000 psi - Finished testing BOPS including: choke and kill, lower pipe rams and blinds. Performed accumulator closure test -Test wltness~! b}~ John i Crisp of AOGCC. Installed long wear bushing. 'i P/U short bails and elevators. P/U BHA components. P/U BHA #2 including: bit, motor, float sub, stab, 3X MWD and upload, 3X flex DCs, HW jars, 14X HWDP from derrick to 716'. Pulse tested ~ MWD. Blew down TD. RIH w/ 5" DP to 1,871'. C/O to 4" handling equipment. Cont'd to RIH w/ 4" DP to 2,440'. ,Broke circ. and washed to 2,505' with no cement encountered. Drilled out FC @ 2,505', shoe track, FS @ 2,592', and rathole to 2605' w/ 300 gpm, 40 rpm, 1740 psi. Drilled from 2,605' to 2,625' MD/ 2,467 TVD. ADT=0.19 ART=0.19 String wt. PUW=144K SOW=125K ROT=135K TQon/off=8K/7.5K SPR#1=30stk/190psi, 40stk/280psi SPR#2=30stk/190psi, 40stk/280psi all @ 2,625' Circa BU for FIT w/ 500 gpm, 1480 psi, 40 rpm. R/U and perform FIT to 16.3 EMW. R/D FIT equip. Work on TD, no rotary due to kink in air hose. Held PJSM. Displaced to 9.6 ppg LSND w/ 530 gpm, 50 rpm, 1000 psi. Checked flow, static. ',Drilled from 2,625' to 3,966' MD/ 3,655' TVD. ADT=7.04 AST=0.39 ART=6.65 GPM 650 PP 2600 psi ' String wt. PUW=160K SOW=135K ROT=145K TQon/off=9K/7.5K all @ ;.3,871'. ECD 10.5 Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Event Name: ROT -DRILLING Start: 11/28/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Rig Name: Doyon 19 Rig Number: 19 Date 12/4/2005 Page 3 of 11 Spud Date: 11/29/2005 End: 12/24/2005 Group: From - To 'Hours Code ', Sub ', Phase Description of Operations 00:30 - 12:00 ~~, 12:00 - 00:00 12/5/2005 II 00:00 - 12:10 12:00 - 00:00 i it ill 12/6/2005 ~ 00:00 - 12:00 1,12:00 - 00:00 ~i 12/7/2005 ' 00:00 - 02:00 '~, 02:00 - 03:30 03:30 - 05:00 05:00 - 05:30 I 05:30 - 07:00 i ~I j 07:00 - 08:30 ' I~! 08:30 - 12:00 ' ';12:00-13:00 Code 11.50:! DRILL I~ DRLG ' INTRM1 I SPR #1=30stk/150psi, 40stk/220psi SPR #2=30stk/150psi, 40stk/210psi @ 3,584' and 0830hrs. 12.001 DRILL I DRLG INTRM1 Drilled from 3,966' MD to 5,208' MD/ 4,769' TVD. ADT=6.74 AST=2.60 ART=4.14 GPM 650 PP 2950 psi ' ~, !String wt. PUW=185K SOW=150K ROT=170K TQon/off=10.5K/9K all ~ I @ 5,208'. ECD 10.5 ' SPR #1=30stk/200psi, 40stk/260psi I I 'SPR #2=30stk/200psi, 40stk/270psi @ 5,208' and 2300hrs. 12.00 ~ DRILL DR G L INTRM1 ' Dri I 5 208' to 5 726' MD/ ' TVD. I ed from 5,309 ADT=8.36 AST=7.44 ART=0.92 GPM 600 PP 2550 psi String wt. PUW=200K SOW=155K ROT=175K TQon/off=11 K/9.5K all i @ 5,726'. ECD 10.3 ' ', 'I SPR #1=30stk/270psi, 40stk/320psi '~ SPR #2=30stk/250psi, 40stk/320psi @ 5,590' and 0730hrs. 12.00 DRILL 'DRLG ',INTRMI ,Drilled from 5,726' to 5,939' MD/ 5,497 TVD. i ADT=8.92 AST=8.77 ART=0.15 GPM 650 PP 2850 psi ' String wt. PUW=185K SOW=170K ROT=180K TQon/off=11 K/8.5K all ' @ 5,876'. ECD 10.2 ' ~~ SPR #1=30stk/240psi, 40stk/290psi ~ SPR #2=30stk/230psi, 40stk/290psi @ 5,876' and 2000hrs. 12.00 j DRILL I DRLG INTRM1 Drilled 8 3/4" hole w/ motor f! 5939' to 6639' MD 5916' TVD ADT - 9.08 hrs. =ART 1.47 hrs. AST 7.61 hrs WOB 15/18 k RPM 0/70 GPM 650 @ 3350 psi l ~, String wt. PU 185 SO 165 Rot 177 i ~ Torque on/off btm - 10,000/8,500 ft. lbs. ' 'ECD - 10.23 to 10.65 ppg 12.00', DRILL DRLG INTRM1 Drilled 8 3/4" hole w/ motor f/ 6639' to 7,221 MD/ 6,152' TVD. ADT-8.20 ART-2.06 AST-6.14 I WOB 15/22K RPM 0/70 GPM 650 @ 3460 psi i I I String wt. PU 185 SO 160 Rot 174 ' '~~ Torque on/off btm - 11,500/9,000 ft. lbs. ~ ! ECD to 10.65 ppg 2.00 DRILL II DRLG INTRM1 !Drilled 8 3/4" hole w/ motor f/ 7221' to 7324' MD 6166' TVD ~ ~ 'ADT - 1.22 hrs. =ART .22 hrs. AST 1.00 hrs. '; WOB 15/18 k RPM 0/70 GPM 650 @ 3480 psi String wt. PU 190 SO 160 Rot 173 ' Torque on/off btm. - 10,000/8,500 ft lbs. ECD - 10. 6 ppg 1.50 DRILL ~~ CIRC INTRM1 'i Pump sweep & circulate btms up - 650 gpm @ 3250 psi w/ 70 RPM 1.501 DRILL ~! WIPR I INTRMI I Flow check (static) Wiper trip f/ 7324' to 6385' -Back reamed & ' ',pumped 550 gpm @ 2350 psi w/ 70 RPM - No problems - flow check ,(static) 0.50 DRILL ~ TRIP INTRM1 RIH f/ 6385' to 7244' - no problems 1.50 ~ DRILL CIRC ', INTRM1 'Wash down f/ 7244' to 7324' -Circulate 2X btms up @ 460 gpm @ j ~ ', ' 1800 psi w/ 70 RPM -shakers clean ', I, * Note - # 2 mud pump down 1.50'' DRILL CIRC '~~ INTRMI I Flow check (static) POOH spotting tube pill f/ 7324' to 6385' -hole took ' correct fill 3.50', DRILL INTRM1 TRIP POOH on TT f/ 6385' to 5430' Hole taking proper fill -Pumped dry job ' @ 5430' -Continue POOH on TT f/ 5430' to 1871' (Flow checked @ 9 5/8" shoe -static) 1.00 DRILL !TRIP INTRM1 ~ C/O to 5" handling equip. and cont. to UD 5" DP to 715'. Checked flow, 'static. Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/7/2005 CD4-208 CD4-208 ROT -DRILLING Doyon Drilling Inc Doyon 19 From - To .Hours'! Code ' Code I Phase -- __ 13:00 - 13:45 I _ _ 0.75' DRILL _ ~ PULD 13:45 - 15:30 I 1.751 DRILL PULD ',15:30 - 16:00 0.501 DRILL I DEOT ii 16:00 - 18:30 2.50 CASE 'RURD '18:30-19:30 i, i 19:30 - 22:45 122:45 - 23:15 23:15 - 00:00 I, 12/8/2005 ~I 00:00 - 01:30 'I 01:30 - 02:30 02:30 - 05:30 I' 05:30 - 06:00 106:00 - 07:30 07:30 - 08:00 I I 08:00 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 11:30 11:30 - 12:00 ~~ 12:00 - 13:00 1,13:00-17:30 17:30 - 18:00 16:00 - 18:15 18:15 - 18:30 '18:30-18:45 18:45 - 22:45 1.00'' CASE RURD 3.25 CASE RUNC 0.501 CASE 'CIRC 0.75' CASE I RUNC 1.50' CASE 'RUNC 1.00, CASE (CIRC 3.001 CASE !RUNC 0.50 ~! CEMEN PULD 1.50', CEMEN CIRC 0.50 II CEMENT PUMP ! 1.00 CEMEN DISP i 1.001 CEMEN OTHR 0.5011 CEMEN PULD 1.00 DRILL OTHR 0.50 DRILL ' OTHR 1.00 ~ WELCTL! EORP 4.50'', WELCTLI BOPE 0.50 ~I DRILL ~ OTHR 0.25'''., DRILL '; RIRD 0.251 DRILL j PULD 0.25 DRILL PULD 4.00'.: DRILL PULD 1 ' 22:45 - 00:00 '1 1.25 DRILL 12/9/2005 00:00 - 00:30 0.50!, DRILL 00:30 - 04:00 I 3.50 I DRILL ~ INTRMI INTRM1 NTRM 1 ', INTRM1 I NTRM 1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 ~I I NTRM 1 INTRM1 I NTRM 1 INTRMI ' INTRM1 INTRMI 'INTRMI INTRM1 j INTRM1 I INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI INTRMI TRIP i INTRMI DEOT INTRM1 TRIP (INTRMI Page 4 of 11 Spud Date: 11/29/2005 Start: 11/28/2005 End: 12/24/2005 Rig Release: 12/24/2005 Group: Rig Number: 19 Description of Operations - - S/B HW and UD jars. S/B 6.75" DCs and UD BHA. ', Pull wear bushing and install test plug. Held PJSM, changed rams to 7", tested doors to 5000 psi. R/U casing equip, installed 7" wear bushing, and UD test joint. Finished R/U of 7" caskng equip. Held PJSM. ~! Ran 7" 26# L-80 MBTC casing as follows: FS (Ray Oil Tools silver bullet) 2 jts.- FC (Weatherford) 2 jts.(First 4 connections made up w/ ', Baker Loc -fill pipe & check floats) 56 jts. to 2569' (60 jts. total) Circa 1 casing volume w/ pump staged to 5 BPM, 300 psi. String wt.- PUW=130K SOW=125K !~ Confd to RIH w/ 7" casing f/ 2569' to 2,999' (70 jts total). ',Continue running 7" 26# L-80 BTCM csg f/ 2999' to 4923' (115 jts total) Est. circulation @ 3.5 BPM -stage pump to 5 BPM 8~ circulate btms.up + ICP 530 psi FCP 400 psi Continue running 7" 26# L-80 csg f/ 4923' to 7277 (170 jts total) PU hanger & landing jt. -Land casing w/ FS @ 7314' FC @ 7224' I No problems running casing RD fill up tool -blow down TD - RU cmt. head & lines Est. circulation @ 2 BPM -stage pumps up to 6.5 BPM -ICP 660 psi ' FCP 490 psi -Reciprocate pipe 250 K PU 175 k SO -condition mud for cmt job ~ PJSM -Cement 7" casing as follows: Pumped 5 bbls CW-100 -Test lines to 3700 psi -Pumped 25 bbls CW-100 @ 4.3 bbls/min @ 338 psi - iMixed & pumped 30 bbls MudPush XL @ 12.0 ppg @ 4.5 bbl/min @ 395 psi -Dropped btm plug -Mixed & pumped 40 bbls tail slurry Class G w/ additives @ 15.8 ppg @ 362 psi -Dropped top plug w/ 20 bbls i water f/ Dowell Switched to rig pumps & displaced w/ 255 bbls 9.8 ppg LSND mud @ 7 bblslmin @ 320 to 630 psi -slowed rate to 3.5 bbls/min @ 320 to 690 psi for last 10 bbls of displacement -bumped plug w/ 1337 psi -held for ~I 5 mins. -bleed off & check floats - CIP @ 0852 hrs. -Full returns throught the job - recipracated pipe until last 10 bbls of displacement RU & test casing to 3500 psi for 30 mins. -bleed off pressure - RD cmt. lines & cmt head - LD landing jt. 'li Pull wear bushing -Install pack off & test to 5000 psi for 10 mins LD csg elevators & long bails ~! Held PJSM. C/O top rams to 3.5"X6" variable. ', Tested BOPS. Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke 8~ kill line valves, choke manifold valves, floor safety & dart valves, TD ', IBOP valves to 250 & 5000 psi -Performed accumulator closure test - IWitnessing of test waived by J. Crisp of AOGCC. 111 BLow down kill & choke lines - RD test equipment. Installed wear bushing. P/U short bails and elevators. ~! P/U Geo-Span unit to ri floor. P/U 6 jts. 4" DP from shed and S/B in derrick. P/U BHA #3 including: bit, Geo-pilot, 6X MWD, flt sub, stab, upload MWD, 3X flex DCs, XO, 3X 4" HWDP, C/O jars to new, 2X 4" HWDP. 'Total length 374'. P/U 4" DP from shed and singled in hole to 1,228'. Test Geo Span to 3500 psi -shallow test MWD @ 1228' Continue RIH -picking up 4" DP f/ pipe shed f/ 1228' to 5902' Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Page 5 of ~ 1 Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Spud Date: 11/29/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To '! Hours Code 'Code Phase Description of Operations 12/9/2005 ii 04:00 - 05:30 1.501 RIGMNT' RSRV ~~, INTRM1 ~ PJSM -Cut & slip drill line 60' -Service TD 05:30 - 06:30 ~i 1.00' DRILL TRIP I INTRM1 ~ Continue RIH -picking up remaining DP f/ pipe shed f/ 5902' to 6952' - i ~I run 1 std DP f/ derrick to 7047 06:30 - 08:00 1.50 DRILL REAM I INTRM1 MU TD & wash down f/ 6947 to 7185' (top of cmt) Break in GeoPilot 08:00 - 12:30 ~I 4.50 CEMENT DSHO INTRM1 i Drill out cement in shoe track f/ 7185' to to 7224' (top of FC) drill FC @ 7224' -drill cmt to 7313' -drill out FS @ 7313' -clean out rat hole to ', 7324' -Drill 20' new hole to 7344' '~ I ,String wt.- PUW=190K SOW=135K ROT=160K TOon/off=11 K/10K 12:30 - 13:00 ~ 0.50 DRILL CIRC ~' ', INTRMI ' Ciculate hole clean for FIT ' ~; 13:00 - 13:45 0.75 DRILL ~, FIT INTRM1 RU & perform FIT to 12.5 ppg EMW - 900 psi w/ 9.7ppg mud @6164 TVD - RD 13:45 - 15:15 j 1.50 !. DRILL ;CIRC ''~ PROD PJSM -Change well over to 9.2 ppg OBM -Shut down monitor well ,15:15 - 00:00 ~ 8.75' DRILL ' DRLH ,PROD Static ~ Drill 6 1/8" horz. section f/ 7,344' to 8,097. ~ ~ 'ADT=6 hrs TDT=6 hrs ART=6hrs ~; String wt.-PUW=195K SOW=135K ROT=160K TOon/off=10K/9.5K 12/10/2005 00:00 - 12:00 ~ 12.00 I! DRILL `DRLH PROD I 12:00 - 00:00 I ~ ~ 12.00' DRILL ..DRLH ,PROD 12/11/2005 100:00 - 01:00 'I 1.00 DRILL 'DRLH 'I PROD 01:00 - 02:00 1.00' DRILL ;CIRC '~ PROD j, 02:00 - 03:30 '~, 1.50 I DRILL II W IPR I PROD 03:30 - 04:00. 0.50 i DRILL I CIRC 'i PROD 04:00 - 04:30 ' 0.50 I DRILL ',TRIP PROD I! 04:30 - 05:30 1.00' DRILL ,REAM I, PROD !, 05:30 - 12:00 6.501 DRILL DRLH PROD ~I ~ 12:00 - 00:00 ! 12.00 ~ DRILL ~~ DRLH ', PROD li Drilled 6 1/8" horz. section w/ GP f/ 8097' to 8861' MD 6193' TVD ADT - 9.38 hrs. i WOB 10/13 k RPM 90 GPM 230 @ 2250 psi ', String wt. PU 200 SO 125 Rot 157 Torque on/off btm - 11,000/10,000 ft. lbs. ECD - 10.59 to 10.9 ppg i Drilled 6 1/8" horz. section w/ GP f/ 8861' to 9,439' MD 6178' TVD ~I ADT - 10.0 hrs. WOB 10/12 k RPM 80 GPM 230 @ 2410 psi String wt. PU 210 SO 110 Rot 155 Torque on/off btm - 11,500/10,500 ft. lbs. ~IECD-10.8 to 11.6 ppg ~ Drilled 6 1/8" hoz. section w/ GP f/ 9439' to 9529' MD 6180' TVD ~I ADT - .49 hrs. ~' WOB 9/11 k RPM 90 GPM 230 @ 2450 psi String wt. PU 205 SO 115 Rot 155 ',Torque on/off btm. - 11,500/10,000 ft. Ibs ECD - 11.2 ppg ~ Circulate for wiper trip 230 gpm @ 2350 psi w/ 90 rpm -Flow check - Istatic '',Wiper trip f/ 9529' to 8765' w/ pump @ 200 gpm @ 1880 psi w/ 80 rpm No packing off or tight hole through shale section - iCirculate btms. up 230 gpm @ 2240 psi W/ 90 rpm ~ RIH f/ 8765' to 9434' -hole in good condition - no problem going through shale section Wash down f/ 9434' to 9529' -Circulate btms up 230 gpm @ 2280 psi ~I w/ 90 rpm 'Drilled 6 1/8" horz. section f/ 9529' to 9912' MD 6206' TVD ADT - 4.6 hrs. WOB 8/10 k RPM 90 GPM 230 @ 2330 psi String wt. PU 210 SO 110 Rot 155 Torque on/off btm. - 11,500/10,500 ft. Ibs all @ 9,817' ECD - 10.8 to 11.3 ppg Drilled 6 1/8" horz. section f/ 9912' to 10,871' MD - 6,230' TVD. ADT - 10.06 hrs. Printed: 4/26/2006 3:22:tOPM ConocoPhillips Alaska Page 6 of 11 Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Spud Date: 11/29/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To 'Hours ' Code ' Code ~I Phase Description of Operations 12/11 /2005 112:00 - 00:00. I _ _ -_ - _ _- - __ _ ---- 12.00, DRILL I DRLH PROD WOB 10/12K RPM 120 GPM 230 @ 2560 psi String wt. PU 215 SO 115 Rot 155 ~I ~~ I Torque on/off btm. - 12,000/10,000 ft. Ibs alf @ 10,871' ' ~I ECD - 11.0 to 11.3 ppg 12/12/2005 00:00 - 12:00 12.00' DRILL DRLH ;PROD ', Drilled 6 1/8" horz. section w/ GP f/ 10,871' to 11,500' MD 6201' TVD ii ' ~ 'ADT - 8.42 hrs. WOB 9/12 k RPM 120 GPM 207@ 2160 psi i, ,String wt. PU 215 SO 100 Rot 158 ' ~! it ' ,Torque on/off btm. - 11,500/10,500 ft. Ibs ', i 'i ECD - 11.05-11.38 Hole started taking fluid @ 11,050' - Inital lose rate 40 bbls/hr -losses i 'have stopped @ +/- 11,350' ;12:00 - 00:00 I 12.001 DRILL ,DRLH PROD Drilled 6 1/8" horz. section w/ GP f/ 11,500' to 12,244' MD 6181' TVD 12/13/2005 100:00 - 01:00 I 1.001 DRILL I CIRC 01:00 - 12:00 ' 11.001 DRILL TRIP 12:00 - 19:00 I~ 7.00' DRILL 'i TRIP ' 'ADT - 10.9hrs. I WOB 10/14 k RPM 120 GPM 230@ 2540 psi ii String wt. PU 220 SO 70 Rot 160 'Torque on/off btm. - 11,500/10,500 ft. Ibs 'ECD - 11.10-11.25 PROD I Circulate 2X btms up while trouble shooting GeoPilot -stood back 2 ~ stds to 12,108' - 211 gpm @ 2280 psi w! 70 rpm -unsuccessful in I linking up with GP PROD 'Flow check (slight flow) POOH w/ pump f/ 12,108' to 7,238' - 182 gpm / 1300 psi / 80 rpm -flow check well, static. ',PROD I POOH w/ pump from 7,238' to 6,379' - 126 gpm / 700 psi -flow check well, static. Continue to POOH on trip tank from 6,379' to 374' -Flow ~ check 10 mins. static 19:00 - 19:30 ' 0.50' DRILL I TRIP PROD 'POOH w/ BHA f/374' to 90' 19:30 - 00:00 4.50 DRILL 1 PULD PROD ,Flow check (static) Down load MWD -Change out GeoPilot & GP pony 01:00 it 12/14!2005 00:00 DRILL 1 00 ~ TRIP ' PROD ''sub -Check bit (bit good to rerun) Up load MWD -shallow test tools Ii MU bha -RIH with flex collars and hwd - . . . 1 p 01:00 - 05:00 ~ 4.001, DRILL 'TRIP ,PROD ,RIH with 4" DP to 4185' -changed out sixteen joints of drill pipe due ' ' ' I ' minimun tool joint OD. 'i 05:00 - 06:00 1.00 DRILL it DEOT ~~, PROD Break in GeoPilot bearings -troubleshoot link to tools -function test ' ~ I j GeoPilot, OK. - 5 bpm / 1680 psi 06:00 - 07:30 i 1.50; DRILL TRIP PROD ~, RIH with 4" DP to 7183' 07:30 - 07:45 ' 0.25 ~ DRILL ' SFTY ', PROD !Held safety meeting with crew prior to installing nonrotating Drill pipe ' I Casing protectors 07:45 - 09:30 ~i 1.75 I DRILL ',TRIP I~ PROD 'RIH from 7,143' to 8,002' -installing WWT NRDPCP's (one per joint on 4" DP) 09:30 - 13:00 I 3.50' DRILL TRIP ;PROD RIH -picked up 33 jts of 4" hwdp -installed NRDPCP's -one per joint 13:00 - 14:45 ', 1.75 ! DRILL I TRIP ', PROD I Continue to RIH with 4" DP from 9020' to 10,000' -installed NRDPCP's ~ ' I one pre joint -Totals of 91 in string 14:45 - 15:30 0.75 , DRILL TRIP PROD ~' RIH from 10,000' to 10,450' -wiped through tight spot from 10,370' to ' ~ 1 10,380' -unable to rass 10,450' after several attempts. ~~ 15:30 - 17:00 DRILL 1.50 li REAM I PROD ;staged pumps up to 3.9 bpm / 1730 psi -wash and ream tight spots ' i~ ~ ~ from 10,450' to 10,704' (slight effort) -shut down pumps -observed 5 i M d i M d 9 2 t t 9 ppg n u w . ou well, flow ng. u wt. . ppg - . 17:00 - 18:00 1.00 ~~ WELCTIi CIRC PROD Shut in well @ 1702 hours - ISIDPP= 340 psi, ISICP= 160 psi, monitor ~, li ~ I ,pressures 15 minutes DP-380, csg-180 ~ ~ ~ Circ well on choke - @ 2.5 bpm until! bottoms up from start of reaming 11 ';around (pumped 125 bbls, lost 40 bbls) no gas cut mud observed. Shut i I ' j in well. I Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Page 7 of 11 Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Spud Date: 11/29/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To ,Hours Code Code Phase Description of Operations 12/14/2005 ' 18:00 - 19:30 1.50 WELCTL~I OTHR PROD 'Performed Exhale test -Pressures prior to bleed - DP 420 CSG 350 - 19:30 - 20:45 20:45 - 23:00 I i 23:00 - 00:00 12/15/2005 ~j 00:00 - 08:00 I ~, 08:00 - 10:00 10:00 - 12:45 I ~I 12:45 - 16:30 Open well & bleed off annulus through gas buster to TT -bleed 9 bbls in 5 mins -Csg pressure 0 DP pressure 100 -shut in well & monitor ', ~ IDP 90 Csg 0 - 5 mins. DP 190 Csg 180 -Open well & pumped 8 bbls :through choke -Shut in & monitor - IDPP 340 CP 310 -after 8 mins DP i '~, 340 CSG 300 -Open well & bleed off annulus through gas buster to TT !, ~, ~ -Bleed 2.5 bbls in 11 mins. @ end of bleed DPP 40 psi Csg 0 -Open I~ Hydril -observed slight flow -Blow down ckoke line -Flow check (static) 1.25 DRILL CIRC PROD Circulate btms up @ 4 bbls/min @ 1560 psi w/ 10 rpm 12K torque - 'hole stable on losses -shut down pump -flow check (static) 2.25 DRILL TRIP I, PROD ~ RIH f/ 10,704' to 11,178' -had to rotate string in several spots f/ 10,704' ', 'to 11,178' to pass -Unable to pass @ 11,178' -Attempt wash wash & ream down f/ 11,178' -hole packing off & losing fluid - unable to work ', ' I !, pass 11,178' -Stood back 1 std. DP -Work pipe through tight hole f/ ~~ ,11,080' to 11,020' pulling 85 k over (well is breathing agian) 1.00 DRILL REAM ~~ PROD !Est. circulation -Wash & ream f/ 11020' to 11,178' -Hole packing off & pulling tight up & taking wt. down 8.00 DRILL REAM ', PROD I Work tight hole from 11,020' to 11,190, unable to pass 11,190'. Hole packing off and pulling tight (75K over) from 11,050' to 11,190'. Varied ~~ pump rates, rpm, worked pipe with pump only and no pump with no ,progress. 2.00'' DRILL I REAM PROD Work pipe up from 11,190' to 11,020' -hole packing off and pulling tight i i from 11,190' to 11,120'. When able pumped at 3 bpm / 1280 psi / 40 2.75', DRILL ~! REAM ;PROD rpm ~i POOH with pump from 11,020' to 10,545' - 4 bpm / 1820 psi / 60 rpm, no problems. Well breathing on connections -lost 85 bbls of mud ' (0000-1200 hrs) Pulled last stand @ 100 fph to map ABI surveys for side track. 3.751 DRILL 'i DRLH !PROD I! 16:30 - 00:00 7.501 DRILL Ali DRLG I',I PROD 12/16/2005 ! 00:00 - 12:00 12.00 DRILL ~, DRLH I PROD 12:00 - 17:00 I 5.00' DRILL I DRLH I PROD it Side track well: Time drill from 10545' to 10,565' WOB 0/5 k RPtM~~ GPM 168 @~ 1~70~0/19t1~0 psi ~ r„~~~~ 'Drill 6 1/8" horz. section w GP f/ 10, 565' to 10,745' MD 6242' TVD '~ ADT 9.9 hrs. WOB 10/12 k RPM 130 GPM 180 @ 1920 psi String wt. PU 225 SO 115 Rot 165 Torque on/off btm. - 12,000/11,000 ft. Ibs ECD - 11.1 ppg Lost - 136 bbls OBM ', Hole taking fluid 8~ breathing on connections I~ Drill 6 1/8" horz. section w GP f/ 10,745' to 11,222' MD 6226' TVD ADT 9.53 hrs. '~ WOB 10/18 k RPM 100/120 GPM 197 @ 2280 psi String wt. PU 225 SO 110 Rot 160 Torque on/off btm. - 13,000/10,500 ft. Ibs ', ECD - 11.4 ppg Lost - 132 bbls OBM Well breathing on connections Drilled 6 1/8" horz. section w/ GP f/ 11,222' to 11,554' MD 6226' TVD ADT - 3.08 hrs. ' WOB 15/20 k RPM 80/ 110 GPM 193 @ 2250 psi ', String wt. PU 225 SO 115 Rot 160 Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 S b Date From - To 'Hours Code Code' Phase - __ ~ --- - 12/16/2005 12:00 - 17:00 5 00 DRILL DRLH 'PROD 17:00 - 18:30 '18:30-19:30' 19:30-21:15 1,21:15-00:00', ~' 12/17/2005 i 00:00 - 05:00 i ~~ i 05:00 - 11:00 '~ 11:00 - 12:00 i ,12:00 - 16:30 ~I 12/18/2005 16:30 - 17:00 ', i 17:00 - 17:15 ~ 17:15 - 18:00 118:00 - 19:15 i 19:15 - 21:00 ~ 21:00 - 00:00 00:00 - 05:00 I 05:00 - 07:45 07:45 - 09:15 09:15 - 11:00 11:00 - 13:00 113:00 - 13:45 1.501 DRILL I TRIP I PROD 1.00 !DRILL I TRIP ;PROD 1.751 DRILL I TRIP I PROD 2.751 DRILL I TRIP !:PROD 5.00. DRILL 'TRIP (PROD 6.00' DRILL I TRIP ;PROD 1.001 DRILL !..TRIP I PROD 4.501 DRILL PULD PROD 0.50 ~I RIGMNT', RGRP PROD 0.25', DRILL ''TRIP 'PROD 0.75 DRILL I OTHR PROD 1.251 DRILL TRIP I PROD 1.75 RIGMNT RSRV 'PROD 3.00 DRILL TRIP ,PROD 5.00 ~' DRILL 'TRIP ii PROD 2.75' DRILL ~ TRIP I~, PROD ~I 1.50 i DRILL ' CIRC PROD 1.751 DRILL I REAM I PROD 2.00 DRILL i REAM PROD I 0.75' DRILL TRIP ~ PROD Start: 11/28/2005 Rig Release: 12/24/2005 Rig Number: 19 Page 8 of 11 Spud Date: 11/29/2005 End: 12/24/2005 Group: Description of Operations ', Torque on/off btm - 12,000/10,000 ft. lbs. ECD - 11.3 ppg Well still breathing slightly -Lost 61 bbls OBM Trouble shoot GP -Circulate btms up @ 193 gpm @ 2050 psi _ standing back pipe f/ 11,554' to 11,307' -Flow check observed very I slight flow POOH w/ pump f/ 11,307 to 10,700' 185 gpm @ 1580 psi w/ 80 rpm - Found wash out in DP on 7th std out on btm jt of std. - 2.47 f/ top of 'box 3/4" long x 1 /8" wide Change out jt. -Check Sperry tools - GP still not functioning -flow ~I check (very slight flow) Continue to POOH w/ pump f/ 10,700' to 9211' W/ 185 gpm @ 1780 psi ~I w/ 80 rpm -Well static on connections -hole taking proper fill - no hole problems ;Continue to POOH w/ pump f/ 9211' to 7238' - 185 gpm / 1780 psi ! 80 rpm - Pump out from 7238' to 6284' 185 gpm / 1400 psi -Well static on connections -hole taking proper fill -flow check @ 7400' and 6284', static. POOH on trip tank from 6284' to 374' -hole taking proper fill -flow check well @ 750', static. Stand back hwdp and nmfc's -plug into tool and download -pull up inspect rotary steerable -observed non rotating housing cracked 70% of OD. - 8 inches below rollers -break out bit. ~, MU BHA # 5 -Changed out rotary steerable, nmflex collar, smart stab and TM HOC -installed new pulser -initiate tools '.Work on Top Drive torque make -up RIH w/ BHA f/ 94' to 374' Break in bearing on GP -Shallow test tools ~ RIH f/ 374' to 2277 -fill pipe -blow down TD -flow check well -static i PJSM -Cut & slip drill line 60' -service TD,DW, & crown '~ Continue RIH f/ 2277 to 7051' RIH from 7051' to 10,000' -serviced NRDPCP's -check torque on bolts, reset top clamp to spec -changed out 6 clamps. ',RIH from 10,000' to 10,447 -rotate down 2 stands to 10,638' -stage pumps up to 4.1 bpm / 1770 psi / 30 rpm @ 10.5K ft/Ibs 147K rot do wt. -pumped up survey @ 10,733' to confirm bha in new hole -ECD= 11.4 '~ ppg. Continue to RIH - 2.5 bpm / 1130 psi / 40 rpm from 10,733' to '.10,946' -hole began packing off -lost returns -work pipe up to 10,893'. ,Stage pumps up to 4.0 bpm / 1810 psi ! 40 rpm @ 11 K ft/Ibs conditon 'mud -final ECD=11.06 ppg. Wash and ream tight hole from 10, 893' to 10,954' - 4 bpm / 1830 psi / 50 rpm -hole packing off -worked pipe back up to 10,920' -made numerous attempts -packoff occuring different spots from 10,932' to 10,954' -pulled through tight spot from 10,934' to 10,928' (sand/shale ;interface) returns across shakers nearly all sand. - 50 k over after each 'i attempt. ~ Reduce pump rate to 2.2 bpm / 830 psi / 75 rpm @ 11/11.5K ft/Ibs - work down from 10,920' to 10,990' -had several slight packoff events from 10,950' to 10,965' -picked up 5 to 10' to clear packoff and L continued slow reaming through shale. No problems from 10,970' to 10,990'. Lost 50 bbls of MOBM due to packing off. Wash and ream from 10,990' to 11,115' - 2.0 bpm / 710 psi / 50 rpm ',RIH from 11,115' to 11,402' -SOW 120-115K. Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Page 9 of 11 Opera#ions Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Spud Date: 11/29/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To ', Hours !Code 'Code Phase Description of Operations - - i __ 12/18/2005 ,,13:45 - 15:00 1.251~I DRILL ~ REAM ~ PROD _. _ ____ - _ - _- - ~ Stage pumps up to 4 bpm / 1740 psi 100 rpm - precationary ream from ' ' ~ to 11,554 , no problems. 11,402 j 15:00 - 00:00 ', 9.00 DRILL ',DRLH I PROD Drill 6 1/8" horizontal hole from 11,554' to 12,045' MD 6216' TVD ', ' ' ! ADT - 6.6 hrs. I ' ' WOB 14/18 k RPM 100 GPM 176 @ 1970 psi - 168 @ 1870 psi ', ~I ~ String wt. PU 250 SO (rot. down 120) Rot 165 '~ ', I Torque on/off btm - 12,000!11,000 ft. lbs. I 'ECD - 11.3 PP9 ~, Hole breathing on connections -Observed no gas on btms up after connections -losing approx. 20 bbls/hr average losses '~ - DRILL ~ DRLH 'PROD 12/19/2005 1100:00 - 04:45 4.75, !~ Lost 168 bbls OBM ',Drill 6 1/8" horizontal hole from 12,045' to 12,244' MD to complete , , ~ 04:45 - 12:00 7.2511 DRILL I DRLH PROD 'sidetrack Drill 6 1/8" horizontal hole from 12,045' to 12,547 MD 6176' TVD ADT - 8.37 hrs. '~i WOB 10!14 k RPM 100 GPM 170 @ 2100 psi i ~' !,String wt. PU 240 SO (rot. down 130) Rot 162 Torque on/off btm - 13,000/11,000 ft. lbs. 'ECD - 11.5 PP9 i ', ' ~ Hole breathing on connections -Observed no gas on btms up after ', ~ ~, ~ !~ connections -losing approx. 26 bbls/hr average losses 1 Lost 311 bbls OBM ~ ;12:00 - 14:30 l DRILL DRLH ,PROD 2.50 I Drilled 6 1/8" horizontal hole f/ 12,547 to 12,783' MD 6174' TVD i 'i ~ I ADT - 2.09 hrs. I !, ' ! WOB 14/17 k RPM 100 GPM 170 @ 2140 psi I Hole still taking fluid & breathing on connections I 14:30 - 15:45 ~ 1.25'1 DRILL I CIRC ~ PROD ;Circulate 9.3 ppg MW @ 170 gpm @ 2100 psi 100 rpm @ 11 k torque 15:45 - 16:45 1.00 DRILL DRLH PROD i Drilled 6 1/8" horizontal hole f/ 12,738' to 12,792' MD 6180' TVD I ' ADT - .47 hrs. ~, WOB 14/17 k RPM 100 GPM 170 @ 2170 psi ~ ~~ I I ,String wt. - PU 225 SO 120(rot. down) Rot 150 I ', I ~ Torque on/off btm. - 13,000/11,000 ft lbs. ~ I ~I ~ ECD - 11.5 PP9 ~ i ', ~ ~ ~~ Hole taking fluid & breathing on connections -Took big drink @ 12792' , ~ Lose rate 80+ bbls/hr.- TD called @ 12,792' i 16:45 - 18:00 ; 1.25 I DRILL .TRIP ~ PROD Backream f/ 12,792' to 12,643' - 105 gpm @ 1280 psi / 60 rpm t 18:00 - 19:30 1.50'. DRILL 'CIRC 'PROD 1 ' ,Spot 40 bbls LCM pill (15# dyna red / 2 # nut plug / 15# 250# cal carb) ' ' ,,19:30 - 00:00 I 4.50 DRILL TRIP ,PROD - 2.5 to 3 bbls/min @ Continue POOH w/ pump f/ 12,643 to 10,642 I~ ~I ',1285 psi w/ 50 rpm ', Lost 239 bbls OBM last 12 hrs. 12/20/2005 00:00 - 05:15 I 5.25 ~,I DRILL .!TRIP PROD ~! Pump out from 10,542' to 7,237 3 bpm / 1250 psi / 50 rpm i 05:15 - 06:30 1.25' DRILL 'i CIRC ~!, PROD ',Flow check well, static in 5 minutes ' Circ and condition mud - 4.5 bpm / 1530 psi / 70 rpm i Reduced vis for trip out. Flow check well, static. 06:30 - 08:30 i, 2.00', DRILL ~, TRIP '.PROD ,Pump out from 7,237 to 5,615' - 3 bpm / 730 psi -hole taking proper fill 08:30 - 16:30 I 8.00 ~, RIGMNT RGRP ,PROD ~ ~ I Troubleshoot Top Drive -grabber would not release -unable to ', , ' ', succesfully repair grabber ,;16:30 - 17:30 ~, 1.00' DRILL ,CIRC II PROD i RU circ hose on drill pipe -circ hole 3 bpm / 780 psi to break gels and 'i I thin mud -flow check well static. 17:30 - 00:00 6.50' DRILL !TRIP I PROD I POOH on trip tank from 5616' to BHA. Stood back HWDP. Hole fill ', ~', j good Flow Check @HWDP well static. Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Event Name: ROT -DRILLING Start: 11/28/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours ' Code ,Sub 12121!2005 12/22/2005 12/23/2005 Code 00:00 - 02:45 ' 2.75 DRILL `PULD 02:45 - 03:00 li 0.251 WELCTL' OTHR 03:00 - 03:30 0.501 CMPLTN RURD 03:30 - 03:45 ~ 0.25' CMPLTN SFTY ~~ 03:45 - 09:15 ~ 5.50 ~~ CMPLTN RUNT Page 10 of 11 Spud Date: 11/29/2005 End: 12/24/2005 Group: Phase ', Description of Operations PROD ', Flush BHA -plug in and down load tools -Lay down BHA -clear tools j from rig floor and clean up trip mess. CMPLTN I Function test BOPE -remove GeoSpan skid from rig floor. CMPLTN I~ Rig up to run 3 1/2" liner CMPLTN 'I Held Prejob Safety and Opts meeting with crew CMPLTN ' PU and RIH with 176 jts of 3 1/2", 9.3# L-80 SLHT slotted and blank I I 09:15 - 16:45 ' 7.50 CMPLTN TRIP ~i, CMPL 16:45 - 18:00 1.25 CMPLTN OTHR ',CMPL ;18:00 - 20:00 ', 2.00 CMPLTNi CIRC CMPL 20:00 - 00:00 !~ 4.00 CMPLTNi TRIP I CMPL 00:00 - 05:30 ' 5.50 CMPLTN'' TRIP I CMPL 05:30 - 05:45 ' 0.25 ,CMPLTN SFTY 'CMPL 05:45 - 10:30 4.75' CMPLTN OTHR 'CMPL ;10:30 - 18:00 ', I 7.50'x, WELCTL BOPE CMPL ~I II 18:00 - 18:30 '1 ' I 0.50', DRILL ~I PULD ,CMPL ';18:30 - 19:30 ~ CMPLTN'' RURD 'CMPL 1.00 i I 19:30 - 00:00 ' t 4.50 CMPLTN; RUNT I CMPL 00:00 - 06:45 ~ ~ ~, ~~ ' 6.75 ~ CMPLTN RUNT ~ CMPL ' ~i '~ '' I I I 06:45 - 08:15 I 1.50'..: CMPLTN SEOT ',CMPL 08:15 - 08:45 ' 0.50 CMPLTN', OTHR CMPL 08:45 - 12:00 3.25 CMPLTN' NUND ',CMPL ,12:00 - 13:30 ~' ~, 1.50 CMPLTNi OTHR CMPL ',13:30 - 14:00 0.50, CMPLTN SFTY 1'~ CMPL ~ 14:00 - 15:30 ! 1.501 CMPLTN,I FRZP '.CMPL 15:30 - 16:15 '. 0.75 ~1 CMPLTN' OTHR 'CMPL ,16:15 - 16:30 ~I 0.25 I CMPLTNi PCKR ~ CMPL liner with 1 jt - 4 1/2", 12.6#, L-80 SLHT blank on top -change running 'tools and MU Baker Flex Lock hanger assembly TN RIH with liner below 4" drill pipe from 5616', tagged bottom @ 12792' PUW 230K SOW 135K TN ' RU and establish circulation 3.5 bpm / 900 psi -dropped and pumped ,down setting ball pressured up to 4000 psi- set and anchor tested hanger with 40K SOW picked up and released from hanger with shoe @ 12,782', Top of Liner @ 7169'. PUW 205K TN Circulated surface to surface prior to trip. TN 'Observed well dead. POOH on trip tank from 7,169' to 4,843'. TN POOH from 4843' -Lay down Baker liner running tools TN Held Prejob Safety and Opts meeting with rig crew /Schlumberger TN RU Schlumberger -ran USi'T log for cement evaluation from 7D75' to TOC @ 610D'-good bond -POOH w/elute tools -rig down 'Schlumberger TN !Set test plug -test rams, choke, kill, manifold and surface safety valves 'to 200/5000 psi -tested annular preventor 200/3500 psi. John Crisp (AOGCC) waived witnessing test. Pull test plug Had one failure on step #2 -trouble shoot slight leak -located and ~I repaired drip from flange on choke manifold 1.5 hrs. TN '' Laid down Flex collars from derrick. TN 'Rigged up to run tubing. PJSM. TN Ran 3.5" upper completion string. 70 Jts. + jewelery. TN ', Run 3 1/2" completion from 2176' - (all jts. 3 1/2" 9.2# L-80 eue) as follows: WLEG - pup jt -locator sub - pup jt - 14 jts - XN nipple w! RHC plug installed - 1 jt. tbg - pup jt -Baker Premier packer - pup jt. - 2 jts. tbg - pup jt. -Camco GLM w/dummy valve installed - pup jt. - 70 jts. tbg ', - pup jt. -Camco GLM w/ dummy valve installed - pup jt -Camco DS nipple - 64 jts. tbg - XO - 4 pups 4 1/2" 12.6# L 80 IBTM - 2 jts 4 1/2" 12.6# L 80 IBTM - (tagged liner top with 3 1/2" tubing and spaced out '~, as required) - MU hanger & landing jt. -land tbg in wellhaed on FMC tbg hanger w/ wleg @ 7191' - XN nipple @ 6751' -packer @ 6678' - GLM 1 @ 6590' -GLM 2 @ 4419' - DS nipple @ 2102' TN I RILDS - LD LJa -install TWC - MU landing jtb - RU and test M/M hanger seals to 5000 psi - LD LJb TN ', PU stack washer tool and flush stack - LD wash tools TN ND BOPE - NU adaptor flange and tree on wellhead -test each to 5000 psi for 10 min. TN RU FMC lubricator and pull TWC - RU hard line and circulating 1 manifold for change over TN ~~ Held Prejob Safety and Opts meeting with Rig Team TN ' Establish circulation with Dowell -test lines to 2500 psi -pumped 20 bbls of mineral oil -displace well with diesel @ 3 bpm 780 psi - 410 psi TN ~!, RU Doyon lubricator -drop packer setting bal /rod - RD lubricator TN '',,Pressure test lines to 5000 psi -set packer with 4600 psi -bled 650 psi 'off annulus 16:30 - 18:00 1.50 ! CMPLTNI DEOT I, CMPLTN Test tubing to 4350 psi -bled to 4125 psi in 30 min. -Test 3 1/2" x 7" Printed: 4/26/2006 3:22:10 PM ConocoPhillips Alaska Page 11 of 11 Operations Summary Report Legal Well Name: CD4-208 Common Well Name: CD4-208 Spud Date: 11/29/2005 Event Name: ROT -DRILLING Start: 11/28/2005 End: 12/24/2005 Contractor Name: Doyon Drilling Inc Rig Release: 12/24/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To 'Hours Code '' Code' Phase Description of Operations 16:30 - 18:00 1.50 12/23/2005 CMPLTN CMPLTN ~ annulus to 3620 psi -bled to 3460 psi in 30 min. -bleed down lines , ' 18:00 - 18:45 l 0.75 . CMPLTN RURD CMPLTN '.Rigged down test manifold. ', i 18:45 - 20:30 ~ 1.75 CMPLTN! RURD I CMPLTN ,Rigged up lubracator and set Back Pressure Valve. Secured well and dressed tree. 20:30 - 00:00 3.50 DRILL ': PULD 'CMPLTN i Set mouse hole and laid down 4"drill pipe. ' " I 12/24/2005 00:00 - 09:00 9.00 I CMPLTN OTHR ',.CMPLTN Continue to lay down 4"drill pipe -removed 91 NRDPCP s (331 jts of 4 I ~ I I DP and 32 jts of 4" hwdp total) ', 09:00 - 14:30 ~, 5.50' CMPLTN CMPLTN OTHR I ',Clean rig of miner oil base mud residue -Pipe rack drip pans, floor I ',mats and walk ways, drip pans under rotary table, waste fluid tote in ', ~~ cellar -change drive sub on top drive to 4 1/2" IF and clean cellar. ,Released rig to CD4-318 @ 1430 hours. I! ! III LI I!I j it I ', ' I~ i i 'I ~, I ', III li I' I!~ I !I 'I I ', ** Total MOBM losses to 6 1/8" horizontal hole = 1273 bbls. i II ~!II li I Printed: 4/26/2006 3:22:10 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Jim Regq(a~admin.state.ak.us: Bob Fleckensteint~admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc FIELD 1 UNIT I PAD: Alpine /CD4 DATE: 11 /23/2005 OPERATOR REP: David Burley AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4-208 In~. T e N TVD 5,982' Tubin 900 1,340 1,470 1,460 Interval I P.T.D. 205-162 Test T e P Test si 3500 IA 800 3,620 3,490 3,460 P/F P Notes: OA 550 0 550 550 550 MIT Report Form Revised: 03/18/04 CD4-208 MIT Form .xls TUBING (x131, OD:4.500, ID:3.958) PUP (26-131, OD:4.500) XO (131-132, OD:4.500) TUBING (131-7191, OD:3.500, ID:2.992) PRODUCTION (0-7314, OD:7.000, Wt:26.00) PACKER (ss78~67s, OD:5.980) NIP (6725726, OD:3.960) SLEEVE (7169-7170, OD:5.790) NIP (7182-7183, OD:5.600) xo (7195-7196, OD:5.570) LINER plssalss, OD:5.000, Wt:15.00) PUP (7196-7240, OD:4.500) LINER (7196-7240, OD:4.500, Wt:12.60) C~~~~~R~illips Ala, It~C. •LPINE C D4208 CD4-208 API: 501032051700 Well T e: INJ An le TS: de SSSV Type: NONE Orig Com letion: 12/24/2005 Angle @ TD: 89 deg @ Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo 32' RKB Ref Log Date: Last Update: 1/15/2006 Last Ta TD: 12792 ftKB Last Tag Date; _ _ Max Hole Angle: 96 deg @ 9106 _ _ _ _ _ __ Casing String -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 114 114 65.00 H-40 WELDED SURFACE 9.625 0 2594 2440 40.00 L-80 BTC PRODUCTION 7.000 0 7314 6163 26.00 L-80 BTCM LINER 5.000 7169 7196 6148 15.00 L-80 SLHT LINER 4.500 7196 7240 6155 12.60 L-80 SLHT LINER 3.500 7240 12782 6177 9.30 Tubing String -TUBING Size To Bottom TVD Wt Grade L-80 SLHT Thread 4.500 0 131 131 9.30 L-80 EUM 3.500 131 7191 -_ 6147 9.30 L-80 EUM Perforations Summary _ __ Interval TVD Zone Status Ft SPF Date T e Comment 7336 - 6165 - 6176 411 40 2/23/200 SLOTS SLOTTED LINER, 12747 alternating solid/slotted pipe Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 4416 4057 AMC KBMG DMY 1.0 BK-2 0.000 0 2/23/200 2 6590 5937 AMCO KBMG DMY 1.0 BK-2 0.000 0 2/23/200 Other lu s, a uip., etc . - JEWELRY _ _ _____ De th TVD T e Descri lion ID 23 23 HANGER FMC 4.5" TBG HANGER wlPUP 2.992 26 26 PUP 3.958 131 131 XO 3.500 2102 2005 NIP CAMCO 'DS' NIPPLE 2.812 ~~ 6678 5982 PACKER BAKER PREMIER PACKER 2.875 6725 6003 NIP 3.5" HES'XN' NIPPLE w/2.75" NO GO w/RHC PROFILE PLUS RHC PLUG 2.813 7166 6143 WLEG BAKER FLUTED WLEG 2.970 7191 6147 TTL - 2.920 -- Other __ - - - lu s,_equi~„ etc. -LINER JEWELRY _ __ -- _ __ De th TVD T e Descri lion ID 7169 6143 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 7182 6146 NIP BAKER 'RS' PACKER SEAL NIPPLE 4.250 7185 6146 HANGER BAKER 'DG' 5x7" FLEX LOCK LINER HANGER 4.400 7195 6148 XO 4.000 7196 6148 PUP 3.958 7240 6155 XO 3.500 12747 6176 BUSHING BAKER PACK-OFF BUSHING 2.380 12780 6177 SHOE BAKER V-SET FLOAT SHOE - . - - _ -- General Notes 0.000 Date Note 2/23!200 TREE: FMC 4-1/16", 5,000 PSI TREE CAP CONNECTION 7" OTIS LINER (7240-12782, OD:3.500, Wt:9.30) Halliburton Company Global Report ('~mpau~: Conoco Phillips Alaska Inc. Ilatc: 1;27/2000 7imc 10:47.44 I'a~c: I Field: Colville River Unit C„-iinlin:ucj ~ l j IZc icrcncc: Well: CD4-202. T rue North Site: Alpine CD4 ~'crtic:~l ("f~~11) Itcfe rcuce: CD4-208- 55.1 ~~cll: CD4-208 ticcliun (~ Sj Refere nce: Well (0.OON.QOOE_0-OOAzi) 11'rlli~aW: CD4-208 tiurce~ (~alculaGou ~Ictho~l: Minimum Curvatu re Db: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD4 Site Position: Northing: 5957526 .10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174 .70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.00 deg Well: CD4-208 Slot Name: Alpine CD4 Well Position: +N/-S -35.35 ft Northing: 5957492 .96 ft Latitude: 70 17 32.618 N +E/-W -135.88 ft Easfing : 378038 .28 ft Longitude: 150 59 14.723 W Position Uncertainty: 0.00 ft Wellpath: CD4-208 Drilled From: CD4-208PB1 501032051700 Tie-on Depth: 10540.04 ft Current Datum: CD4-208: H eight 55 .15 ft Above System Datum: Mean Sea Level Magnetic Data: 11/30/2005 Declination: 23.50 deg Field Strength: 57498 nT Mag Dip Angle: 80.62 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.15 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 1/18/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 80.00 438.00 CD4-208P B1 Gyro (80.00-438.00) CB-GYRO-SS Camera based gyro single shot 476.13 10540.04 CD4-208P 61 IIFR (476.13-12203. MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10545.00 12700.43 CD4-208 IFR (10545.00-1 2700.43 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 1111 Intl ~iim 7~1) ti p, l~1 I) \;%ti t;;l~ flap.A' ~lnpl: luol ft deg deg ft ft ft ft ft ft 36.15 0.00 0.00 36.15 -19.00 0.00 0.00 5957492.96 378038.28 TIE LINE 80.00 0.30 323.00 80.00 24.85 0.09 -0.07 5957493.05 378038.21 CB-GYRO-SS 169.00 0.40 334.00 169.00 113.85 0.56 -0.35 5957493.52 378037.94 CB-GYRO-SS 259.00 0.75 331.00 258.99 203.84 1.35 -0.77 5957494.33 378037.53 CB-GYRO-SS 349.00 0.30 325.00 348.99 293.84 2.06 -1.19 5957495.04 .378037.12 CB-GYRO-SS 438.00 0.15 252.00 437.99 382.84 2.22 -1.43 5957495.20 378036.88 CB-GYRO-SS 476.13 0.25 256.78 476.12 420.97 2.18 -1.56 5957495.17 378036.75 MWD+IFR-AK-CAZ-SC 566.78 1.47 155.15 566.76 511.61 1.08 -1.27 5957494.06 378037.03 MWD+IFR-AK-CAZ-SC 656.28 2.54 151.45 656.20 601.05 -1.70 0.16 5957491.26 378038.42 MWD+IFR-AK-CAZ-SC 744.90 4.26 149.40 744.66 689.51 -6.26 2.78 5957486.66 378040.96 MWD+IFR-AK-CAZ-SC 835.36 5.81 151.84 834.77 779.62 -13.19 6.65 5957479.67 378044.71 MWD+IFR-AK-CAZ-SC 931.25 9.59 154.91 929.78 874.63 -24.71 .12.33 5957468.06 378050.21 MWD+IFR-AK-CAZ-SC 1026.45 13.41 162.98 1023.06 967.91 -42.45 18.93 5957450.21 378056.51 MWD+IFR-AK-CAZ-SC 1121.76 17.10 170.42 1115.00 1059.85 -66.85 24.50 5957425.73 378061.69. MWD+IFR-AK-CAZ-SC 1217.19 20.64 173.35 1205.29 1150.14 -97.40 28.78 5957395.12 378065.47 MWD+IFR-AK-CAZ-SC 1312.20 21.20 173.36 1294.04 1238.89 -131.09 32.71 5957361.36 378068.85 MWD+IFR-AK-CAZ-SC 1407.83 23.61 170.23 1382.45 1327.30 -167.15 37.96 5957325.23 378073.52 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('omp.~nv: ConocoPhillipsAlaskalnc. 11stc : 1/2/2006 lilac: 10:47'44 Pn,c: 2 Field: Colville River Unit Cu-u nlin~~ic(~I~_) Itc Fcrencc: Well: CD4-203. T rue North ~tiitc: Alpine CD4 ~"crti c:~l fl ~l)~ 12cfc rcncc: CD4-208. 55.1 \~cll: CD 4-202 ticeti un (~5~ Nefcrc nce: Well (O.OON,O.OOEO-OOAziI ~1'ell~iath: CD4-20S Surc e~ (~aladalluu ~lcthud: Mi nimum Curvatu re Ilh: Oracle tiur~ c~ X11) lncl ~zim lll) Sys 111) 1S 6:;1~" 11a~iA ~I»pF foul ft deg deg ft ft ft ft ft ft 1502.00 24.68 170.86 1468.38 1413.23 -205.14 44.28 5957287.14 378079.22 MWD+IFR-AK-CAZ-SC 1597.23 24.85 170.91 1554.85 1499.70 -244.53 50.60 5957247.66 378084.90 MWD+IFR-AK-CAZ-SC 1692.74 26.28 167.13 1641.01 1585.86 -284.97 58.48 5957207.11 378092.12 MWD+IFR-AK-CAZ-SC 1787.88 27.42 168.61 1725.89 1670.74 -326.98 67.50 5957164.96 378100.46 MWD+IFR-AK-CAZ-SC 1883.12 27.50 171.89 1810.41 1755.26 -370.25 74.93 5957121.58 378107.19 MWD+IFR-AK-CAZ-SC 1978.37 27.85 171.71 1894.76 1839.61 -414.03 81.24 5957077.70 378112.79 MWD+IFR-AK-CAZ-SC 2073.58 27.04 172.59 1979.25 1924.10 -457.50 . 87.24 5957034.14 378118.08 MWD+IFR-AK-CAZ-SC 2168.65 26.64 .173.82 2064.08 2008.93 -500.12 92.32 5956991.45 378122.47 MWD+IFR-AK-CAZ-SC 2264.15 26.83 176.57 2149.38 2094.23 -542.92 95.91 5956948.60 378125.37 MWD+IFR-AK-CAZ-SC 2359.30 28.34 175.78 2233.71 2178.56 -586.88 98.86 5956904.60 378127.60 MWD+IFR-AK-CAZ-SC 2453.76 28.25 177.06 2316.88 2261.73 -631.57 101.66 5956859.88 378129.67 MWD+IFR-AK-CAZ-SC 2548.71 28.92 174.56 2400.26 2345.11 -676.87 104.99 5956814.54 378132.26 MWD+IFR-AK-CAZ-SC 2617.63 28.83 173.55 2460.61 2405.46 -709.97 108.43 5956781:39 378135.17 MWD+IFR-AK-CAZ-SC 2686.63 28.75 172.53 2521.09 2465.94 -742.95 112.46 5956748.34 378138.66 MWD+IFR-AK-CAZ-SC 2781.96 28.77 171.90 2604.66 2549.51 -788.40 118.67 5956702.81 378144.14 MWD+IFR-AK-CAZ-SC 2877.42 28.79 171.79 2688.32 2633.17 -833.89 125.19 5956657.22 378149.92 MWD+IFR-AK-CAZ-SC 2973.16 28.47 171.27 2772.36 2717.21 -879.26 131.95 5956611.75 378155.94 MWD+IFR-AK-CAZ-SC 3068.32 27.46 170.08 2856.41 2801.26 -923.30 139:17 5956567.61 378162.44 MWD+IFR-AK-CAZ-SC 3163.75 27.13 169.47 2941.21 2886.06 -966.36 146.94 5956524.42 378169.51 MWD+IFR-AK-CAZ-SC 3259.14 26.63 172.23 3026.30 2971.15 -1008.93 153.80 5956481.75 378175.68 MWD+IFR-AK-CAZ-SC 3354.50 25.96 171.51 3111.79 3056.64 -1050.75 159.77 5956439.85 378180.97 MWD+IFR-AK-CAZ-SC 3449.77 27.24 172.36 3196.98 3141.83 -1092.98 165.75 5956397.52 378186.26 MWD+IFR-AK-CAZ-SC 3545.33 26.86 172.06 3282.08 3226.93 -1136.04 171.64 5956354.38 378191.45 MWD+IFR-AK-CAZ-SC 3640.53 28.07 172.96 3366.55 3311.40 -1179.57 177.36 5956310.77 378196.46 MWD+IFR-AK-CAZ-SC 3736.03 27.93 172.13 3450.87 3395.72 -1224.02 183.17 5956266.23 378201.56 MWD+IFR-AK-CAZ-SC 3831.47 27.50 171.15 3535.36 3480.21 -1267.94 189.62 5956222.22 378207.29 MWD+IFR-AK-CAZ-SC 3926.96 26.99 171.09 3620.26 3565.11 -1311.13 196.37 5956178.93 378213.34 MWD+IFR-AK-CAZ-SC 4022.26 26.39 171.06 3705.40 3650.25 -1353.42 203.01 5956136.54 378219.29 MWD+IFR-AK-CAZ-SC 4118.38 26.82 171.76 3791.35 3736.20 -1395.98 209.44 5956093.88 378225.03 MWD+IFR-AK-CAZ-SC 4213.79 27.36 173.04 3876.29 3821.14 -1439.04 215.18 5956050.73 378230.07 MWD+IFR-AK-CAZ-SC 4308.98 26.67 172.53 3961.09. 3905.94 -1481.94 220.61 5956007.76 378234.80 MWD+IFR-AK-CAZ-SC 4404.41 25.92 170.92 4046.65 3991.50 -1523.77 226.68 5955965.84 378240.20 MWD+IFR-AK-CAZ-SC 4499.92 25.25 169.84 4132.79 4077.64 -1564.44 233.57 5955925.07 378246.42 MWD+IFR-AK-CAZ-SC 4595.59 21.95 174.33 4220.46 4165.31 -1602.33 238.94 5955887.10 378251.18 MWD+IFR-AK-CAZ-SC 4691.24 19.87 175.86 4309.80 4254.65 -1636.33 241.88 5955853.05 378253.56 MWD+IFR-AK-CAZ-SC 4786.64 19.39 186.09 4399.69 4344.54 -1668.26 241.37 5955821.14 378252.54 MWD+IFR-AK-CAZ-SC 4882.24 16.59 193.87 4490.62 4435.47 -1697.30 236.41 5955792.19 378247.11 MWD+IFR-AK-CAZ-SC 4977.66 14.37 198.13 4582.57 4527.42 -1721.78 229.46 5955767.83 378239.76 MWD+IFR-AK-CAZ-SC 5073.45 13.60 208.03 4675.54 4620.39 -1743.02 220.47 5955746.73 378230:43 MWD+IFR-AK-CAZ-SC 5169.34 13.20 219.72 4768.83 4713.68 -1761.40 208.17 5955728.56 378217.83 MWD+IFR-AK-CAZ-SC 5264.54 13.01 229.82 4861.57 4806.42 -1776.68 193.04 5955713.53 378202.45 MWD+IFR-AK-CAZ-SC 5359.78 12.64 245.82 4954.46 4899.31 -1787.86 175.34 5955702.64 378184.57 MWD+IFR-AK-CAZ-SC 5455.17 12.81 268.01 5047.56 4992.41 -1792.51 155.23 5955698.32 378164.40 MWD+IFR-AK-CAZ-SC 5550.40 12.65 283.64 5140.48 5085.33 -1790.42 134.54 5955700.75 378143.75 MWD+IFR-AK-CAZ-SC 5645.90 15.77 301.28 5233.09 5177.94 -1781.21 113.28 5955710.30 378122.64 MWD+IFR-AK-CAZ-SC 5741.53 19.79 315.59 5324.18 5269.03 -1762.88 90.82 5955728.99 378100.48 MWD+IFR-AK-CAZ-SC 5836.62 27.87 321.19 5411.10 5355.95 -1734.01 65.58 5955758.26 378075.72 MWD+IFR-AK-CAZ-SC 5932.17 33.49 324.52 5493.25 5438.10 -1695.10 36.26 5955797.63 378047.03 MWD+IFR-AK-CAZ-SC 6027.71 36.56 325.62 5571.48 5516.33 -1650.14 4.88 5955843.09. 378016.39 MWD+IFR-AK-CAZ-SC 6123.08 41.98 326.40 5645.28 5590.13 -1600.10 -28.83 5955893.67 377983.50 MWD+IFR-AK-CAZ-SC 6218.41 47.85 328.63 5712.76 5657.61 -1543.32 -64.91 5955951.03 377948.35 MWD+IFR-AK-CAZ-SC 6314.04 51.45 328.84 5774.67 5719.52 -1481.03 -102.72 5956013.92 377911.56 MWD+IFR-AK-CAZ-SC 6409.34 51.99 328.93 5833.71 5778.56 -1416.98 -141.38 5956078.58 377873.94 MWD+IFR-AK-CAZ-SC • Halliburton Compan~ Global Report ('ntup:+u~: ConocoPhillips Alnska Inc. i)ati~: 1;2712006 I lwc: 10.4744 Pale: 3 Field: Co lville River Unif Cu-u rdinau~(\I.) Re ference: Well_ CD4-200. Tr ue North tine: Alp ine CD4 ~'crti cal (Il I)) Refe rence: CD4-202 55.1 ~~cll: CD4-202 ticcli un (~'ti) licferc ncc: Well i0.OON O OOEO.OOAzi) ~1'cllpaU~: CD4-208 Sur~ c~ C'alculatinn ~IcUurd: Mi nimum Curvatu re Uh: Oracle Sung ~~il) lucl Mini l ~ D Sps l ~~ I) V'ti L%«' ~Tap\ ~lapl: lonl ft dey deg ft ft ft ft ft ft 6504.74 55.41 330.86 5890.18 5835.03 -1350.47 -179.91 5956145.70 377836.50• MWD+IFR-AK-CAZ-SC 6600.37 58.05 .330.43 5942.64 5887.49 -1280.79 -219.11 .5956216.00 377798.44 MWD+IFR-AK-CAZ-SC 6695.86 61.74 330.32 5990.53 5935.38 -1208.99 -259.94 5956288.45 377758.79 MWD+IFR-AK-CAZ-SC 6791.56 65.96 330.21 6032.69 5977.54 -1134.42 -302.54 5956363.70 377717.41 MWD+IFR-AK-CAZ-SC 6886.85 70.21 331.22 6068.25 6013.10 -1057.32 -345.76 5956441.47 377675.44 MWD+IFR-AK-CAZ-SC 6982.25 72.74 331.70 6098.56 6043.41 -977.86 -388.97 5956521.62 377633.53 MWD+IFR-AK-CAZ-SC 7077.42 75.76 331.69 6124.39 6069.24 -897.23 -432.40 5956602.94 377591.42 MWD+IFR-AK-CAZ-SC 7172.72 80.18 332.76 6144.25 6089.10 -814.78 -475.81 5956686.08 377549.35 MWD+IFR-AK-CAZ-SC 7239.32 82.01 331.92 6154.56 6099.41 -756.50 -506.36 5956744.83 377519.76 MWD+IFR-AK-CAZ-SC 7268.34 82.35 331.99 6158.51 6103.36 -731.13 -519.87 5956770.42 377506.66 MWD+IFR-AK-CAZ-SC 7392.43 87.08 333.53 6169.93 6114.78 -621.30 -576.41 5956881.14 377451.92 MWD+IFR-AK-CAZ-SC 7487.31 86.22 332.87 61.75.48 6120.33 -536.76 -619.11 5956966.36 377410.59 MWD+IFR-AK-CAZ-SC 7582.43 81.13 327.45 6185.96 6130.81 -454.80 -666.10 5957049.06 377364.94 MWD+IFR-AK-CAZ-SC 7678.05 82.06 329.01 6199.94 6144.79 -374.38 -715.90 5957130.27 377316.46 MWD+IFR-AK-CAZ-SC 7773.55 82.37 333.16 6212.88 6157.73 -291.58 -761.64 5957213.80 377272.07 MWD+IFR-AK-CAZ-SC 7868.97 82.43 335.15 6225.50 6170.35 -206.46 -802.87 5957299.57 377232.23 MWD+IFR-AK-CAZ-SC 7963.97 85.47 337.60 6235.52 6180.37 -119.92 -840.72 5957386.70 377195.80 MWD+IFR-AK-CAZ-SC 8059.60 90.60 339.15 6238.79 6183.64 -31.11 -875.92 5957476.07 377162.04 MWD+IFR-AK-CAZ-SC 8156.32 92.27 336.61 6236.37 6181.22 58.46 -912.33 5957566.20 377127.10 MWD+IFR-AK-CAZ-SC 8251.94 93.88 337.32 6231.24 6176.09 146.32 -949.69 5957654.66 377091.17 MWD+IFR-AK-CAZ-SC 8347.30 93.26 336.47 6225.30 6170.15 233.86 -987.04 5957742.78 377055.25 MWD+IFR-AK-CAZ-SC 8442.70 93.57 336.74 6219.62 6164.47 321.26 -1024.85 5957830.78 377018.86 MWD+IFR-AK-CAZ-SC 8505.63 94.56 337.38 6215.16 6160.01 379.07 -1049.32 5957888.97 376995.34 MWD+IFR-AK-CAZ-SC 8538.57 94.06 335.46 6212.68 6157.53 409.17 -1062.45 5957919.28 376982.69 MWD+IFR-AK-CAZ-SC 8583.41 93.94 333.60 6209.56 6154.41 449.55 -1081.69 5957959.97 376964.12 MWD+IFR-AK-CAZ-SC 8633.70 94.12 333.11 6206.02 6150.87 494.39 -1104.19 5958005.16 376942.35 MWD+IFR-AK-CAZ-SC 8678.48 94.12 331.78 6202.80 6147.65 533.99 -1124.85 5958045.08 376922.34 MWD+IFR-AK-CAZ-SC 8729.22 92.95 331.74 6199.68 6144.53 578.60 -1148.81 5958090.08 376899.10 MWD+IFR-AK-CAZ-SC 8772.81 92.76 332.16 6197.50 6142.35 617.03 -1169.28 5958128.82 376879.26 MWD+IFR-AK-CAZ-SC 8823.85 93.69 331:58 6194.63 6139.48 661.96 -1193.31 5958174.14. 376855.97 MWD+IFR-AK-CAZ-SC 8870.51 95.37 332.48 6190.95 6135.80. 703.04 -1215.12 5958215.57 376834.82 MWD+IFR-AK-CAZ-SC 8915.56 95.36 332.28 6186.74 6131.59 742.78 -1235.92 5958255.64 .376814.68 MWD+IFR-AK-CAZ-SC 8964.00 94.55 331.59 6182.55 6127.40 785.37 -1258.62 5958298.58 376792.67 MWD+IFR-AK-CAZ-SC 9012.67 93.69 331.86 6179.06 6123.91 828.12 -1281.62 5958341.69 376770.37 MWD+IFR-AK-CAZ-SC 9060.87 93.88 331.11 6175.87 6120.72 870.38 -1304.58 5958384.32 376748.10 MWD+IFR-AK-CAZ-SC 9106.18 95.74 331.71 6172.07 6116.92 910.02 -1326.18 5958424.30 376727.15 MWD+IFR-AK-CAZ-SC 9155.36 94.87 330.81 6167.53 6112.38 952.96 -1349.73 5958467.61 376704.30 MWD+IFR-AK-CAZ-SC 9202.29. 93.75 331.37 6164.00 6108.85 993.92 -1372.35 5958508.93 376682.35 MWD+IFR-AK-CAZ-SC 9249.32 90.97 330.87 6162.06 6106.91 1035.07 -1395.04 5958550.44 376660.33 MWD+IFR-AK-CAZ-SC 9295.87 87.94 330.37 6162.51 6107.36 1075.62 -1417.88 5958591.35 376638.16 MWD+IFR-AK-CAZ-SC 9346.66 86.40 330.82 6165.01 6109.86 1119.81 -1442.78 5958635.94 376613.97 MWD+IFR-AK-CAZ-SC 9394.64 85.72 332.00 6168.31 6113.16 1161.84 -1465.69 5958678.33 376591.75 MWD+IFR-AK-CAZ-SC 9442.75 85.16 332.54 6172.14 6116.99 1204.29 -1488.00 5958721.13 376570.13 MWD+IFR-AK-CAZ-SC 9487.10 85.97 331.56 6175.57 6120.42 1243.35 -1508.73 5958760.52 376550.05 MWD+IFR-AK-CAZ-SC 9588.35 85.60 334.37 6183.01 6127.86 1333.28 -1554.62 5958851.18 376505.62 . .MWD+IFR-AK-CAZ-SC 9683.77 85.29 336.50 6190.59 6135.44 1419.79 -1594.16 5958938.30 .376467.49 MWD+IFR-AK-CAZ-SC 9778.34 85.97 336.54 6197.79 6142.64 1506.27 -1631.73 5959025.38 376431.33 MWD+IFR-AK-CAZ-SC 9873.78 85.66 336.44 6204.76 6149.61 1593.56 -1669.70 5959113.26 376394.79 MWD+IFR-AK-CAZ-SC 9968.48 85.60 334.87 6211.97 6156.82 1679.58 -1708.63 5959199.90 376357.27 MWD+IFR-AK-CAZ-SC 10064.80 85.66 333.86 6219.31 6164.16 1766.17 -1750.18 5959287.14 376317.13 MWD+IFR-AK-CAZ-SC 10155.71 85.66 336.18 6226.19 6171.04 1848.33 -1788.45 5959369.91. 376280.19 MWD+IFR-AK-CAZ-SC 10253.66 85.91 334.86 6233.39 6178.24 1937.24 -1828.93 5959459.45 376241.17 MWD+IFR-AK-CAZ-SC . Halliburton Company Global Report ('ompan~: ConocoPhilllpsAlas~a Inc. Ilalc: 1%?71200o Iimc: 10:47:44 Pu~c: ! Ficl~l: Co lville River Unit Co-u nlinatc(\I:) Re ference: W ell: CD4-208, Tr ue North Sic: Alp ine CD4 Verti cal 11 VI)~ Rcli~ rcncc CD4-208: 55.1 ~Vcll: CD4-208 Secti on (~ S) Referen ce: W 211 (O.OON.O-OUE O OOAziI ~~'cllpath: CD4-208 Sur~ c~ ('alculation ~Icthod: Mi nimum Curvatur e Ub: Oracle tiunc~ ~~ill lucl lzini ll'll tictil~'U \:S I~.~IV ~la~i1 ~lapl~; fool ft deg deg ft ft ft ft ft ft 10346.81 84.30 334.02 6241.34 6186.19 2020.96 -1868.97 5959543.81 376202.49 MWD+IFR-AK-CAZ-SC 10444.15 87.46 335.32 6248.34 6193.19 2108.70 -1910.50 5959632.20 376162.40 MWD+IFR-AK-CAZ-SC 10540.04 92.08 335.37 6248.72 6193.57 2195.83 -1950.49 5959719.96 376123.83 MWD+IFR-AK-CAZ-SC 10545.00 92.15 335.45 6248.54 6193.39 2200.33 -1952.55 5959724.50 376121.84 MWD+IFR-AK-CAZ-SC 10601.74 90.62 336.31 6247.17 6192.02 2252.10 -1975.73 5959776,63 376099.51 MWD+IFR-AK-CAZ-SC 10697.08 90.97 336.04 6245.84 6190.69 2339.31 -2014.24 5959864.44 376062.42 MWD+IFR-AK-CAZ-SC 10792.60 91.40 337.12 6243.87 6188.72 2426.94 -2052.20 .5959952.67 376025.89 MWD+IFR-AK-CAZ-SC 10888.24 92.02 337.46 6241.01 6185.86 2515.12 -2089.11 5960041.43 375990.42 MWD+IFR-AK-CAZ-SC 10983.91 93.13 336.73 6236.72 6181.57 2603.16 -2126.30 5960130.06 375954.66 MWD+IFR-AK-CAZ-SC 11079.35 92.89 332.63 6231.70 6176.55 2689.29 -2167.06 5960216.83 375915.32 MWD+IFR-AK-CAZ-SC 11174.83 92.08 330.68 6227.56 6172.41 2773.24 -2212.34 5960301.50 375871.40 MWD+IFR-AK-CAZ-SC 11270.34 91.16 329.31 6224.86 6169.71 2855.92 -2260.08 5960384.93 375825.01 MWD+IFR-AK-CAZ-SC 11366.00 89.61 329.02 6224.22 6169.07 2938.05 -2309.11 5960467.84 375777.33 MWD+IFR-AK-CAZ-SC 11461.52 89.61 331.42 6224.87 6169.72 3020.95 -2356.55 5960551.49 375731.24 MWD+IFR-AK-CAZ-SC 11515.58 88.63 333.63 6225.70 6170.55 3068.90 -2381.49 5960599.84 375707.09 MWD+IFR-AK-CAZ-SC 11556.16 89.00 333.93 6226.54 6171.39 3105.30 -2399.41 5960636.52 375689.76 MWD+IFR-AK-CAZ-SC 11651.26 94.13 335.78 6223.94 6168.79 3191.32 -2439.79 5960723.17 375650.78. MWD+IFR-AK-CAZ-SC 11745.88 94.06 334.62. 6217.18 6162.03 3276.99 -2479.38 5960809.47 375612.59 MWD+IFR-AK-CAZ-SC 11842.71 91.84 335.59 6212.20 6157.05 3364.70 -2520.08 5960897.82 375573.32 MWD+IFR-AK-CAZ-SC 11937.50 88.87 335.59 6211.61 6156.46 3451.01 -2559.25 5960984.75 375535.56 MWD+IFR-AK-CAZ-SC 12032.87 91.03 336.09 6211.70 6156.55 3538.02 -2598.28 5961072.37 375497.95 MWD+IFR-AK-CAZ-SC 12128.18 93.07 336.65 6208.29 6153.14 3625.28 -2636.46 5961160.23 375461.20 MWD+IFR-AK-CAZ-SC 12222.67 92.08 335.82 6204.04 6148.89 3711.66 -2674.50 5961247.22 375424.57 MWD+IFR-AK-CAZ-SC 12319.18 94.43 334.79 6198.56 6143.41 3799.20 -2714.75 5961335.39 375385.75 MWD+IFR-AK-CAZ-SC 12414.26 95.36 335.03 6190.45 6135.30 3884.99 -2754.92 5961421.81 375346.98 MWD+IFR-AK-CAZ-SC 12510.35 94.80 333.88 6181.94 6126.79 3971.35 -2796.19 5961508.82. 375307.11 MWD+IFR-AK-CAZ-SC 12604.42 92.27 331.90 6176.14 6120.99 4054:91 -2838.98 5961593.06 375265.70 MWD+IFR-AK-CAZ-SC 12700.43 88.75 330.29 6175.29 6120.14 4138.94 -2885.37 5961677.82 375220.67 MWD+IFR-AK-CAZ-SC 12792.00 88.75 330.29 6177.28 ~ 6122.13 4218.46 -2930.74 . 5961758.05 375176.60 MWD Halliburton Company. Global Report Comp:ui~: Conoco Phillips Alaska Inc. Dare: Ir27/2006 "time: 10:49:3' I'a,c: I I~icl~l: Colville River Unit Cu-urilinstclAH:) Ref erence: Well: CD4-208, Tr ue North tine: Alpine CD4 Ccrticail (1 ~ D~ Kcfer cncc: CD4-2G8~ 55.1 ~~c1i: CD4-20Z ticrtiun I~~ti~ Kcfercn cc: Well (O.OON,O-OOE O OOAzi) ~~ cllpath: C~4-203P61 tiun e~~ l'alculatiun '. lcthud: Minimum Curvatur e Db: Oraeie Survey: Start Date: Company: Engineer: Tool Tied-to: Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD4 Site Position: Northing: 5957526 .10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174 .70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.00 deg Well: CD4-208 Slot Name: Alpine CD4 Well Position: +N/-S -35.35 ft Northing: 5957492 .96 ft Latitude: 70 17 32.618 N +E/-W -135.88 ft Easting : 378038 .28 ft Longitude: 150 59 _ 14.723 W Position Uncertainty: .0.00 ft Wellpath: CD4-208PB1 Drilled From: Well Ref. Point 501032051770 Tie-on Depth: 36.15 ft Current Datum: CD4-208: H eight 55. 15 ft Above System Datum: Mean Sea Level Magnetic Data: 11/30/2005 Declination: 23.50 deg Field Strength: 57498 nT Mag Dip Angle: 80.62 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.15 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 1!18/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 80.00 438.00 CD4-208P61 Gyro (80.00-438.00) CB-GYRO-SS Camera based gyro single shot 476.13 12203.20 CD4-208P61 IIFR (476.13-12203. MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey SID Inc! \tim 7~U ti ~ti 111 \-ti I~:a~ ~lai~A 11ap[; l~nnl ft deg deg ft ft ft ft ft ft 36.15 0.00 0.00 36.15 -19.00 0.00 0.00 5957492.96 378038.28 TIE LINE 80.00 0.30 323.00 80.00 24.85 0.09 -0.07 5957493.05 378038.21. CB-GYRO-SS 169.00 0.40 334.00 169.00 113.85 0.56 -0.35 5957493.52 378037.94 CB-GYRO-SS 259.00 0.75 331.00 258.99 203.84 1.35 -0.77 5957494.33 378037.53 CB-GYRO-SS 349.00 0.30 325.00 348.99 293.84 2.06 -1.19 5957495.04 378037.12 CB-GYRO-SS 438.00 0.15 252.00 437.99 382.84 2.22 -1.43 5957495.20 378036.88 CB-GYRO-SS 476.13 0.25 256.78 476.12 420.97 2.18 -1.56 5957495.17 378036.75 MWD+IFR-AK-CAZ-SC 566.78 1.47 155.15 566.76 511.61 1.08 -1.27 5957494.06 378037.03. MWD+IFR-AK-CAZ-SC 656.28 2.54 151.45 656.20 601.05 -1.70 0.16 5957491.26 378038.42 MWD+IFR-AK-CAZ-SC 744.90 4.26 149.40 744.66 689.51 -6.26 2.78 5957486.66 378040.96. MWD+IFR-AK-CAZ-SC 835.36 5.81 151.84 834.77 779.62 -13.19 6.65 5957479.67 378044.71 MWD+IFR-AK-CAZ-SC 931.25 9.59 154.91 929.78 .874.63 -24.71 12.33 5957468.06 378050.21 MWD+IFR-AK-CAZ-SC 1026.45 13.41 162.98 1023.06 967.91 -42.45 18.93 5957450.21 378056.51 MWD+IFR-AK-CAZ-SC 1121.76 17.10 170.42 1115.00 1059.85 -66.85 24.50 5957425.73 378061.69 MWD+IFR-AK-CAZ-SC 1217.19 20.64 173.35 1205.29 1150.14 -97.40 28.78 5957395.12 378065.47. MWD+IFR-AK-CAZ-SC 1312.20 21.20 173.36 1294.04 1238.89 -131.09 32.71 5957361.36 378068.85 MWD+IFR-AK-CAZ-SC 1407.83 23.61 170.23 1382.45 1327.30 -167.15 37.96 5957325.23 378073.52 MWD+IFR-AK-CAZ-SC 1502.00 24.68 170.86 1468.38 1413.23 -205.14 44.28 5957287.14 .378079.22 MWD+IFR-AK-CAZ-SC . ~ Halliburton Company! Global Report (bmpan~: ConocoPhillips Alaska Inc. Ficlil: Colville River Unit tiitc: Alpine CD4 ~~cll: CD4-202 Nellpauh: CD4-20SPB1 `;u rcc~ III) locl ~zim ft deg deg 1597.23 24.85 170.91 1692.74 26.28 167.13 1787.88 27.42 168.61 1883.12 27.50 171.89 1978.37 27.85 171.71 2073.58 27.04 172.59 2168.65 26.64 173.82 2264.15 26.83 176.57 2359.30 28.34 175.78 2453.76 28.25 177.06 2548.71 28.92 174.56 2617.63 28.83 173.55 2686.63 28.75 172.53 2781.96 28.77 171.90 2877.42 28.79 171.79 2973.16 28.47 171.27 3068.32 27.46 170.08 3163.75 27.13 169.47 3259.14 26.63 172.23 3354.50 25.96 171.51 3449.77 27.24 172.36 3545.33 26.86 172.06 3640.53 28.07 172.96 3736.03 27.93 172.13 3831.47 27.50 171.15 3926.96 26.99 171.09 4022.26 26.39 171.06 4118.38 26.82 171.76 4213.79 27.36 173.04 4308.98 26.67 172.53 4404.41 25.92 170.92 4499.92 25.25 169.84 4595.59 21.95 174.33 4691.24 19.87 175.86 4786.64 19.39 186.09 4882.24 16.59 193.87 4977.66 14.37 198.13 I)atc 1/27/2006 lime: 10.49:33 l';r,c: , (~u-urelinatc(SFJ ReCcrencr. Well; CD4-20S, True North ~~crlical (~I~~ 1)) Kclcrcncc: CD4-208. 55.1 Sectiuu (~S) Reference: Well (O.OGN,O-OOEO-OOAti) tiur~~c~ ('alculntiun )Icthud: Minimum Curvature Db: Oracle nl~ s~,r~l) ~:~ I~nt ft ft ft ft 1554.85 1499.70 -244.53 50.60 1641.01 1585.86 -284.97 58.48 1725.89 1670.74 -326.98 67.50 1810.41 1755.26 -370.25 74.93 1894.76 1839.61 -414.03 81.24 1979.25 1924.10 -457.50 87.24 2064.08 2008.93 -500.12 92.32 2149.38 2094.23 -542.92. 95.91 2233.71 2178.56 -586.88 98.86 2316.88 2261.73 -631:57 101.66 2400.26 2345.11 -676.87 104.99 2460.61 2405.46 -709.97 108.43 2521.09 2465.94 -742.95 112.46 2604.66 2549.51 -788.40 118.67 2688.32 2633.17 -833.89 125.19 2772.36 2717.21 -879.26 131.95 2856.41 2801.26 -923.30 139.17 2941.21 2886.06 -966.36 146.94 3026.30 2971.15 -1008.93 153.80 3111.79 3056.64 -1050.75 159.77 3196.98 3141.83 -1092.98 165.75 3282.08 3226.93 -1136.04 171.64 3366.55 3311.40 -1179.57 177.36 3450.87 3395.72 -1224.02 183.17 3535.36 3480.21 -1267.94 189.62 3620.26 3565.11 -1311.13 196.37 3705.40 3650.25 -1353.42 203.01 3791.35 3736.20 -1395.98 209.44 3876.29 3821.14 -1439.04 215.18 3961.09 3905.94 -1481.94 220.61 4046.65 3991.50 -1523.77 226.68 4132.79 4077.64 -1564.44 233.57 4220.46 4165.31 -1602.33 238.94 4309.80 4254.65 -1636.33 241.88 4399.69 4344.54 -1668.26 241.37 4490.62 4435.47 -1697.30 236.41 4582.57 4527.42 -1721.78 229.46 ~l~liA 11~p1~: In~l ft ft 5957247.66 378084.90 MWD+IFR-AK-CAZ-SC 5957207.11 378092.12 MWD+IFR-AK-CAZ-SC 5957164.96 378100.46 MWD+IFR-AK-CAZ-SC 5957121.58 378107.19 MWD+IFR-AK-CAZ-SC 5957077.70 378112.79 MWD+IFR-AK-CAZ-SC 5957034.14 378118.08 MWD+IFR-AK-CAZ-SC 5956991.45 378122.47 MWD+IFR-AK-CAZ-SC 5956948.60 378125.37 MWD+IFR-AK-CAZ-SC 5956904.60 378127.60 MWD+IFR-AK-CAZ-SC 5956859.88 378129.67 MWD+IFR-AK-CAZ-SC 5956814.54 378132.26 MWD+IFR-AK-CAZ-SC 5956781.39 378135.17 MWD+IFR-AK-CAZ-SC 5956748.34 378138.66 MWD+IFR-AK-CAZ-SC 5956702.81 378144.14 MWD+IFR-AK-CAZ-SC 5956657.22 378149.92 MWD+IFR-AK-CAZ-SC 5956611.75 378155.94 MWD+IFR-AK-CAZ-SC 5956567.61 ..378162.44 MWD+IFR-AK-CAZ-SC 5956524.42 378169.51 MWD+IFR-AK-CAZ-SC 5956481.75 378175.68 MWD+IFR-AK-CAZ-SC 5956439.85 378180.97 MWD+IFR-AK-CAZ-SC 5956397.52 378186.26 MWD+IFR-AK-CAZ-SC 5956354.38 378191.45 MWD+IFR-AK-CAZ-SC 5956310.77 378196.46 MWD+IFR-AK-CAZ-SC 5956266.23 378201.56 MWD+IFR-AK-CAZ-SC 5956222.22 378207.29 MWD+IFR-AK-CAZ-SC 5956178.93 378213.34 MWD+IFR-AK-CAZ-SC 5956136.54 378219.29 MWD+IFR-AK-CAZ-SC 5956093.88 378225.03 MWD+IFR-AK-CAZ-SC 5956050.73 378230.07 MWD+IFR-AK-CAZ-SC 5956007.76 378234.80 MWD+IFR-AK-CAZ-SC 5955965.84 378240.20 MWD+IFR-AK-CAZ-SC 5955925.07 378246.42 MWD+IFR-AK-CAZ-SC 5955887.10 378251.18 MWD+IFR-AK-CAZ-SC 5955853.05 378253.56 MWD+IFR-AK-CAZ-SC 5955821.14 378252.54 MWD+IFR-AK-CAZ-SC 5955792.19 378247.11 MWD+IFR-AK-CAZ-SC 5955767.83 378239.76 MWD+IFR-AK-CAZ-SC 5955746.73 378230.43 MWD+IFR-AK-CAZ-SC 5955728.56 378217.83 MWD+IFR-AK-CAZ-SC 5955713.53 378202.45 MWD+IFR-AK-CAZ-SC ' 5955702.64 378184.57 MWD+IFR-AK-CAZ-SC 5955698.32 378164.40 MWD+IFR-AK-CAZ-SC 5955700.75 378143.75 MWD+IFR-AK-CAZ-SC 5955710.30 378122.64 MWD+IFR-AK-CAZ-SC 5955728.99` 378100.48 MWD+IFR-AK-CAZ-SC 5955758.26 378075.72 MWD+IFR-AK-CAZ-SC 5955797.63 378047.03 MWD+IFR-AK-CAZ-SC 5955843.09 378016.39 MWD+IFR-AK-CAZ-SC 5955893.67 377983.50 MWD+IFR-AK-CAZ-SC 5955951.03 377948.35 MWD+IFR-AK-CAZ-SC 5956013.92 377911.56 MWD+IFR-AK-CAZ-SC 5956078.58 377873.94 MWD+IFR-AK-CAZ-SC 5073.45 13.60 208.03 4675.54 4620.39 -1743.02 220.47 5169.34 13.20 219.72 4768.83 4713.68 -1761.40 208. 17 5264.54 13.01 229.82 4861.57 4806.42 -1776.68 193. 04 5359.78 12.64 245.82 4954.46 4899.31 -1787.86 175. 34 5455.17 12.81 268.01 5047.56 4992.41 -1792.51 155. 23 5550.40 12.65 283.64 5140.48 5085.33 -1790.42 134. 54 5645.90 15.77 301.28 5233.09 5177.94 -1781.21 113. 28 5741.53 19.79 315.59 5324.18 5269.03 -1762.88 90. 82 5836.62 27.87 321.19 5411.10 5355.95 -1734.01 65. 58 5932.17 33.49 324.52 5493.25 5438.10 -1695.10 36. 26 6027.71 36.56 325.62 5571.48 5516.33 -1650.14 4. 88 6123.08 41.98 326.40 5645.28 5590.13 -1600.10 -28. 83 6218.41 47.85 328.63 5712.76 5657.61 -1543.32 -64. 91 6314.04 51.45 328.84 5774.67 5719.52 -1481.03 -102. 72 6409.34 51.99 328.93 5833.71 5778.56 -1416.98 -141. 38 Halliburton Company Global Report ('nmp:~nc. ConocoPhillips Alaska Inc. ll>ite. 1i27i2006 live 10:49'33 Pa,e: 3 Field: Colville River Unit (~~~-urdinatc~A1:1 Reference: Well: CD4-208. True North ~tiiie: Alpine CD4 1crtical (l~~l)t Rrfercnce CD4-208- 55.1 «~ell: CD4-203 ~ectiun (~~,~~ Reference 4'Vell (O OON.O-OQEO-OOAziI ~1~cllpath: CD4-208PB1 Suncv(~alcul»lion ~lcthud: Minimum Curvature Ilb: Oracle Surccc III) loci ~zim llD ~~_ s 1~1) \iti I~:11 \1.~8A Slapl~: I'rml ft deg deg ft ft ft ft ft ft 6504.74 55.41 330.86 5890.18 5835.03 -1350.47 -179.91 5956145.70 377836.50 MWD+IFR-AK-CAZ-SC 6600.37 58.05 330.43 5942.64 5887.49 -1280.79 -219.11 5956216.00 377798.44 MWD+IFR-AK-CAZ-SC 6695.86 61.74 330.32 5990.53 5935.38 -1208.99 -259.94 5956288.45 377758.79 MWD+IFR-AK-CAZ-SC 6791.56 65.96 330.21 6032.69 5977.54 -1134.42 -302.54 5956363.70 377717.41 MWD+IFR-AK-CAZ-SC 6886.85 70.21 331.22 6068.25 6013.10 -1057.32 -345.76 5956441.47 377675.44 MWD+IFR-AK-CAZ-SC 6982.25 72.74 331.70 6098.56 6043.41 -977.86 -388.97 5956521.62 377633.53 MWD+IFR-AK-CAZ-SC 7077.42 75.76 331.69 6124.39 6069.24 -897.23 -432.40 5956602.94 377591.42 MWD+IFR-AK-CAZ-SC 7172.72 80.18 332.76 6144.25 6089.10 -814.78 -475.81 5956686.08 377549.35 MWD+IFR-AK-CAZ-SC 7239.32 82.01 331.92 6154.56 6099.41 -756.50 -506.36 5956744.83 377519.76 MWD+IFR-AK-CAZ-SC 7268.34 82.35 331.99 6158.51 6103.36 -731.13 -519.87 5956770.42 377506.66 MWD+IFR-AK-CAZ-SC 7392.43 87.08 333.53 6169.93 6114.78 -621.30 -576.41 5956881.14 377451.92 MWD+{FR-AK-CAZ-SC 7487.31 86.22 332.87 6175.48 6120.33 -536.76 -619.11 5956966.36 377410.59 MWD+IFR-AK-CAZ-SC 7582.43 81.13 327.45 6185.96 6130.81 -454.80 -666.10 5957049.06 377364.94 MWD+IFR-AK-CAZ-SC 7678.05 82.06 329.01 6199.94 6144.79 -374.38 -715.90 5957130.27 377316.46 MWD+IFR-AK-CAZ-SC 7773.55 82.37 333.16 6212.88 6157.73 -291.58 -761.64 5957213.80 377272.07 MWD+IFR-AK-CAZ-SC 7868.97 82.43 335.15 6225.50 6170.35 -206.46 -802.87 5957299.57 377232.23 MWD+IFR-AK-CAZ-SC 7963.97 85.47 337.60 6235.52 6180.37 -119.92 -840.72 5957386.70 377195.80. MWD+IFR-AK-CAZ-SC 8059.60 90.60 339.15 6238.79 6183.64 -31.11 -875.92 5957476.07 377162.04 MWD+IFR-AK-CAZ-SC 8156.32 92.27 336.61 6236.37 6181.22 58.46 -912.33 5957566.20- 377127.10 MWD+IFR-AK-CAZ-SC 8251.94 93.88 337.32 6231.24 6176.09 146.32 -949.69 5957654.66 377091.17 MWD+IFR-AK-CAZ-SC 8347.30 93.26 336.47 6225.30 6170.15 233.86 -987.04 5957742.78 377055.25 MWD+IFR-AK-CAZ-SC 8442.70 93.57 336.74 6219.62 6164.47 321.26 -1024.85 5957830.78 377018.86 MWD+IFR-AK-CAZ-SC 8505.63 94.56 337.38 6215.16 6160.01 379.07 -1049.32 5957888.97 376995.34 MWD+IFR-AK-CAZ-SC 8538.57 94.06 335.46 6212.68 6157.53 409.17 -1062.45 5957919.28 376982.69 MWD+IFR-AK-CAZ-SC 8583.41 93.94 333.60 6209.56 6154.41 449.55 -1081.69 5957959.97 376964.12 MWD+IFR-AK-GAZ-SC 8633.70 94.12 333.11 6206..02 6150.87 494.39 -1104.19 5958005.16 376942.35 MWD+IFR-AK-CAZ-SC 8678.48 94.12 331.78 6202.80 6147.65 533.99 -1124.85 5958045.08 376922.34 MWD+IFR-AK-CAZ-SC 8729.22 92.95 331.74 6199.68 6144.53 578.60 -1148.81 5958090.08 376899.10 MWD+IFR-AK-CAZ-SC 8772.81 92.76 332.16 6197.50 6142.35 617.03 -1169.28 5958128.82 376879.26 MWD+IFR-AK-CAZ-SC 8823.85 93.69 331.58 6194.63 6139.48 661.96 -1193.31 5958174.14 376855.97 MWD+IFR-AK-CAZ-SC 8870.51 95.37 332.48 6190.95 6135.80 703.04 -1215.12 5958215.57 376834.82 MWD+IFR-AK-CAZ-SC 8915.56 95.36 332.28 6186.74 6131.59 742.78 -1235.92 5958255.64 376814.68 MWD+IFR-AK-CAZ-SC 8964.00 94.55 331.59 6182.55 6127.40 785.37 -1258.62 5958298.58 376792.67 MWD+IFR-AK-CAZ-SC 9012.67 93.69 331.86 6179.06 6123.91 828.12 -1281.62 5958341.69 376770.37 MWD+IFR-AK-CAZ-SC 9060.87 93.88 331..11 6175.87 6120.72 870.38 -1304.58 5958384.32 376748.10 MWD+IFR-AK-CAZ-SC 9106.18 95.74 331.71 6172.07 6116.92 910.02 -1326.18 5958424.30 376727.15 MWD+IFR-AK-CAZ-SC 9155.36 94.87 330.81 6167.53 6112.38 952.96 -1349.73 5958467.61 376704.30 MWD+IFR-AK-CAZ-SC 9202.29 93.75 331.37 6164.00 6108.85 993.92 -1372.35. 5958508.93 376682.35 MWD+IFR-AK-CAZ-SC 9249.32 90.97 330.87 6162.06 6106.91 1035.07 -1395.04 5958550.44 376660.33 MWD+IFR-AK-CAZ-SC 9295.87 87.94 330.37 6162.51 6107.36 1075.62 -1417.88 5958591.35 376638.16. MWD+IFR-AK-CAZ-SC 9346.66 86.40 330.82 6165.01 6109.86 1119.81 -1442.78 5958635.94 376613.97 MWD+IFR-AK-CAZ-SC 9394.64 85.72 332.00 6168.31 6113.16 1161.84 -1465.69 5958678.33 376591.75 MWD+IFR-AK-CAZ-SC 9442.75 85.16 332.54 6172.14 6116.99 1204.29 -1488.00 5958721.13 376570.13 MWD+IFR-AK-CAZ-SC 9487.10 85.97 331.56 6175.57 6120.42 1243.35 -1508.73 5958760.52 376550.05 MWD+IFR-AK-CAZ-SC 9588.35 85.60 334.37 6183.01 6127.86 1333.28 -1554.62 5958851.18. 376505.62 MWD+IFR-AK-CAZ-SC 9683.77 85.29 336.50 6190.59 6135.44 1419.79 -1594.16 5958938.30 376467.49 MWD+IFR-AK-CAZ-SC 9778.34 85.97 336.54. 6197.79 6142.64 1506.27 -1631.73 5959025.38 376431.33 MWD+IFR-AK-CAZ-SC 9873.78 85.66 336.44 6204.76 6149.61 1593.56 -1669.70 5959113.26 376394.79 MWD+IFR-AK-CAZ-SC 9968.48 85.60 334.87 6211.97 6156.82 1679.58 -1708.63 5959199.90 376357.27 MWD+IFR-AK-CAZ-SC 10064.80 85.66 333.86 6219.31 6164.16 1766.17 -1750.18 5959287.14 376317.13 MWD+IFR-AK-CAZ-SC 10155.71 85.66 336.18 6226.19 6171.04 1848.33 -1788.45 5959369.91 376280.19 MWD+IFR-AK-CAZ-SC 10253.66 85.91 334.86 6233.39 6178.24 1937.24 -1828.93 5959459.45 376241.17 MWD+IFR-AK-CAZ-SC 10346.81 84.30 334.02 6241.34 6186.19 2020.96 -1868.97 5959543.81 376202.49 MWD+IFR-AK-CAZ-SC . ~ Halliburton Compan~ Global Report l~nwp:~u~: Conoco Phillips Alaska Inc. I).,tc U27!2006 liwc•: 10:49'33 Pa,c: 4 Ficl~l: Co lville River U nit ('u-urd inatcl~A1~:) Rr fcrrncc: Well: CD4-202. Tru e North dire: Alp ine CD4 ~ crtia il (I~~~I1) Ilc(c rcncc: CD4-202- .55.1 ~~eJl: CD4-202 ~ectiu n ~~~ti) Rcleren rc: Well (0.OON.G.OOEO OOAziI ~1'cllpnth: CD4-208PB1 tiurvc~ ('alaila[ion ~tetlu>d: Mi nii~~um Curvature Uh: Oracle ~ur~c~ ~lll Inci ~iiin l~'D Sy,111) S/ti I~:-1~' )1:~~~A' ~I>~pl~; l~nol ft deg deg ft ft ft ft f[ ft 10444.15 87.46 335.32 6248.34 6193.19 2108.70 -1910.50 5959632.20 376162.40 MWD+IFR-AK-CAZ-SC 10540.04 92.08 335.37 6248.72 6193.57 2195.83 -1950:49 5959719.96 376123.83 MWD+IFR-AK-CAZ-SC 10639.01 93.44 336.93 6243.95 6188.80 2286.23 -1990.46 5959810.99 376085.33. MWD+IFR-AK-CAZ-SC 10728.11 93.38 336.80 6238.65 6183.50 2368.02 -2025.41 5959893.33 376051.72 MWD+IFR-AK-CAZ-SC 10830.24 93.01 333.55 6232.96 6177.81 2460.56 -2068.21 5959986.54 376010.43 MWD+IFR-AK-CAZ-SC 10925.80 93.69 334.58 6227.38 6172.23 2546.35 -2109.94 5960072.99 375970.11 MWD+IFR-AK-CAZ-SC 11021.08 93.69 331.14 6221.24 6166.09 2630.95 -2153.30 5960158.27 375928.12 MWD+IFR-AK-CAZ-SC 11116.49 92.58 328.30 6216.02 6160.87 2713.21 -2201.33 5960241.30 375881.43 MWD+IFR-AK-CAZ-SC 11212.07 91.09 328.32 6212.96 6157..81 2794.49 -2251.52 5960323.38 375832.58 MWD+IFR-AK-CAZ-SC 11306.58 91.65 329.84 6210.70 6155.55 2875.55 -2300.07 5960405.20 375785.36 MWD+IFR-AK-CAZ-SC 11401.67 92.89 333.12 6206.94 6151.79 2959.02 -2345.43 5960489.39 375741.36 MWD+IFR-AK-CAZ-SC 11495.26 91.65 334.04 6203.23 6148.08 3042.76 -2387.03 5960573.79 375701.12 MWD+IFR-AK-CAZ-SC 11591.84 90.29 332.34 6201.59 6146.44 3128.94 -2430.59 5960660.66 375658.98 MWD+IFR-AK-CAZ-SC 11682.47 91.59 334.39 6200.11 6144.96 3209.94 -2471.21 5960742.30 375619.68 MWD+IFR-AK-CAZ-SC 11782.49 93.88 336.33 6195.33 6140.18 3300.74 -2512.86 5960833.75 375579.51 MWD+IFR-AK-CAZ-SC 11876.52 92.89 336.42 6189.78 6134.63 3386.74 -2550.47 5960920.34 375543.30 MWD+IFR-AK-CAZ-SC 11973.79 91.40 334.17 6186.14 6130.99- 3475.03 -2591.10 5961009.28 375504.12 . MWD+IFR-AK-CAZ-SC 12067.14 88.87 331.60 6185.92 6130.77 3558.11 -2633.64 5961093.03 375462.93 MWD+IFR-AK-CAZ-SC 12160.22 91.59 330.55 6185.55 6130.40 3639.57 -2678.65 5961175.20 375419.25 MWD+IFR-AK-CAZ-SC 12203.20 93.20 331.74 6183.75 6128.60 3677.18 -2699.37 5961213.14 375399:14 MWD+IFR-AK-CAZ-SC . 12244.00 93.20 331.74 6181.47 6126.32 3713.06 -2718.66 5961249.32 375380.44 MWD • • 02-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD4-208 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,540.04' MD Window /Kickoff Survey: 12,700.43' MD (if applicable) Projected Survey: 12,792.00' 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 ~'~~ ~~ rG~'~ Signed } Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 02-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD4-208 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.15' MD Window /Kickoff Survey: 12,203.20' MD (if applicable) Projected Survey: 12,244.00' 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 ~:%~-~ t'1 ~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ WELL LOG TRANSMITTAL To: State of Alaska March 17, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 ,~ ~~ 3 RE: MWD Formation Evaluation Logs: CD4-208, I AK-MW-4084842 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 Disc with verification listing. API#: 50-103-20517-00. ~~lr_ Obi :] WELL LOG TRANSMITTAL J To: State of Alaska March 17, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 ~ ~~ Anchorage, Alaska 99501-3539 ~ 3 RE: MWD Formation Evaluation Logs: CD4-208 PB1, AK-MW-4084842 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 Disc with verification listing. API#: 50-103-20517-70. ~-- app -~~ z Schlumberger ~~ NO. 3648 Schlumberger-DCS 2525 Gambell Street, Suite 400 ~}~~ ~ ~ Z~D~ Com an p y' Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman Attn: Beth ~~ ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~6 Field: Alpine Color Well Job # Log Description Date BL Prints CD CD4-319 i 1'940 USIT 11/27/05 1 CD4-208 Q - (~ 11166740 USIT 12122105 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. 01 /05/06 • • ' STATE OF ALASKA w 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~ir:~ re~~~;~~adrr:i~.state.ak.us ac~cc pr~.4d~oe b~:voiad:~=n.state.ak.us bcl :€eckenste;n~;~aon:~n.state.ak.u~~ Contractor: Doyon Rig No.: 19 DATE: 12/22/2005 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD4-208 PTD # 205-162 Operation: Drlg: x Test: Initial: 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 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 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly x Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test R P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 2950 P Pressure After Closure 1550 P 200 psi Attained 38 P Full Pressure Attained 3 min 02 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2200 psi Test Results Number of Failures: 1 Test Time: 5.5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: 'l~~ :~e~~;~~adrr:i:~.stUte.ak.~ty~ Remarks: Flange on choke manifold leaked, repaired and retested OK. 24 HOUR NOTICE GIVEN YES X NO Date 12/21/05 Time 4 Test start 11:30pm Finish BOP Test (for rigs) 8FL 11/09/04 Waived By John Cris Witness Tim Krupa/Dave B Doyon19 12-22-05 CD4-208.x1s Re: CD4-208 (250-162) sidetrack operations. ~~ • Subject: Re: CUB-?(18 (2,~U-1 f~~~) sidetrack operations. From: Thoma ~~l~~un~l~r ~~~ torn_maunder@admin.state.ak.us>' Date: Fri, 1(, [)ec ~OO~ 1 x:01:01 -0900 LJ '['o: "Johnson, Vern" "~`crn..lohrlson~u::conocophillips.<<~m?~ t'C: "Craliunas. F~'lizai~eth ("' ~ Elirah~th.C.C;aliuna~ rrconocophillips.com=-. "Noel, l3riau" °~:F3rian.vocl<<rconocophillips.coir~-~, "f~l~~ord, Chip" ~_:Chip.~l~or~lr"<<:a~nocophillips.con~-~~~ Vern, et al, Thanks for the updates. I agree that the lost hole section is best called PB 1. Glad the SI event was determined to be breathing. It is important to communicate such events to us. I think the regulation requires notice when the BOP is used to prevent flow from the well. Call or message with any questions. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 12/16/2005 11:43 AM: Tom, As discussed this morning, we have had problems drilling CD4-208 with Doyon 19, and have sidetracked the well. We were able to drill 6-1/8" undulating horizontal to 12244' MD in the Nanuq reservoir, when we had a rotary steerable tool failure. After tripping for the BHA we were unable to work past 11190' MD. We backed up and sidetracked at 10545' MD and plan to drill along the originally planned trajectory, with a modified TVD profile. We expect the hole that we have abandoned to collapse, and not contribute to the usable length of the well, so we consider the well a plug back (PB1), rather than a lateral (L1). Let me know if you think it should go the other way and we can discuss. Also note that we experienced wellbore breathing when running back in hole. The well was shut in to assess the situation until it was confirmed that the well was breathing. The mud weight was not increased. It has been clarified that we need to contact the AOGCC within 24 hrs of shutting in the well. Let me know if you need any further information. Vern Johnson 907-265-6081 1 of 1 12/16/2005 12:01 PM STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re~~;~3adrr:i:~.state.a>i.u~~ Uo~cc ;~_~d~oe bt:v;~ari:~n.state.Uk.us bol eckenst°in :ti~adr~:i:~.stute.ak.u ~~ Contractor: Doyon Rig No.: 19 DATE: 12/8/2005 Rig Rep.: Welsh/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey/Keunzler Field/Unit & Well No.: Colville Rv CD4-208 PTD # 205-162 Operation: Drlg: x Workover: Explor.: Test: Initial: Weekly: Bi-Weekly x Test Pressure; Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 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 Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 27 P Full Pressure Attained 2 min 44 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2150 psi 'i Number of Failures: 0 Test Time: 4_5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope ', Inspector 659-3607, follow with written confirmation to Superviser at: ,€im_re~ ~q ti~d,_r~:in-stute.a>~.~~s~ .Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Waived By John Crisp Date 12/06/05 Time 6:40pm Witness Don Mickey/John Welsh est start Finish 5: BOP Test (for rigs) BFL 11/09/04 Doyon19 12-08-05 CD4-208.x1s STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim req,~~adr~:i:~.state.a>i.us~ Uo~.~`}.~d~oe_bt:~~ad:nn.state.ak. us hrl eckenstpn:;~~adrnin.state.a>~.u ~~ Contractor: Doyon Rig No.: 19 DATE: 12/3/2005 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.: Hill/Keunzler Field/Unit & Well No.: Colville Rv CD4-208 PTD # 2EIrS-162 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 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 Re No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1500 P 200 psi Attained 35 P Full Pressure Attained 2 min 57 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 3 @2150, 1 @2000 Number of Failures: 0 Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re~~yadr~:i~.st~t~.~?t,tts Remarks: Changed out cap seal on annular Preventer prior to test. Test OK 24 HOUR NOTICE GIVEN YES X NO Date 12/02/05 Time 7:OOam Test start Finish Waived By Witness Not Waived John C BOP Test (for rigs) BFL 11/09/04 Doyon19 12-03-05 CD4-208.x1s • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: tarn_m-::nd~;:~~:?adrf~iri.st. ^.a~.:~s BCi~;cc___;.,r:;dl"Er7o ~3;~;%i`t~a+~nli':.::t?;°.:~it.::S i7C;i7__fiGi7li£?n:>iC-:itlL!,u£:Ci173ii >i;~tta ~91~..:: Date: 30-Nov-05 Operation: Drlg Contractor: Doyon Rig No. Operator: Conoco Phillips Alaska Inc. Oper. Rep. Field/Unit & Well No.: CD4-208 Rig Rep.: Location: Sec. 24 T. T11 N R. R4E Development x Exploratory: 19 PTD # 205-162 Rig Ph. # 670-4300 Hill Krupa/Lupton Merdian UM A ...T..C~~ ........................................................... ........ ......... ................... MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign : P Systems Pressure: 2950 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1750 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: min 30 sec. Systems Pressure Attained: 2 mim 6 sec. DNERTER SYSTEM INSPECTION: Nitrogen Bottles: 4 2150 si avers e Diverter Size: 20 in. psig Divert VaNe(s) Fuli Opening: YES VaNe(s) Auto & Simultaneous: YES MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 16 in. Trip Tank: P P Vent Line(s) Length: 85 ft. Mud Pits: P P Line(s) Bifurcated: N/A Flow Monitor: P P Line(s) Down Wind: YES Line(s) Anchored: YES GAS DETECTORS: Light Alarm Turns Targeted /Long Radius: N/A Methane P P Hydrogen Sulfide: P P :::::::::::: .:..... I _ o V~~r~l~.~c ~M~~~::.:.:::: ..... . .::::::.::~::.: RIG 19 SUB Div. Vent line Non Compliance Items 0 Repair Items Wlthir N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Test went ood AoGCC REP.: Witnessing waived by Chuck Scheve OPERATOR REP.: Larry Hill Diverter Test (for rigs) BFL 11/20!00 Diverter Test CD4-208 Doyon 19, 11-30-05.x1s Re: CD4-208 Subject: Re: CD4-208 From: "I~homas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, Ol Nov 2005 14:22.21 -0900 "To: ".fohnson, Vc;rn" ~~-~~crn.JohnSC~~~«i~coilocOphillips.com> CC: "Galiunas. L~:liiabcth ("' <~~'~izaheth.~'.Galiunas"u conc~cophif!ips.c~~n1==. "ti~~cl. Brian" ~_Brian.vocl(~i'conocophlli~~s.con~=> Vern, Not a problem on your XS. Main issue is to calculate with the basis 300' above the proposed packer depth. Tom Johnson, Vern wrote, On 11/1/2005 2:09 PM: ', Tom, ', we will amend the plan to include 300' above the packer. Unless we ', suspect a significant washout, we will continue to use 40 percent excess on the cement calculations. Let me know if you need any further information. Vern Johnson -----Original Message----- From: Thomas Maunder [z~ai.l.to:tom maund.erc~?admi.n.state.ak.us] Sent: Tuesday, November O1, 2005 9:45 AM To: Galiunas, Elizabeth C Cc: Johnson, Vern; Noel, Brian Subject: CD4-208 Hi Liz, As you might guess, I am looking at the application for CD4-208. Looks good. One point, you have asked to place the packer -250 tvd above the Nanuq reservoir. Such placement was also requested at CD1/CD-2. Based on the drawing, your plan is to have the TOC 200' and above the proposed packer depth. In a "normal" situation there should be a minimum of 300' of cement above the "highest" packer depth. I know that you have XS in your planned volume, however I'd appreciate if you'd add 100' and to your planned column length. Message back with any questions and the new volume. Thanks for your attention to this matter. Tom Maunder, PE AOGCC 1 of 1 11/1/2005 2:22 PM ~~ ~'°' ~~ ~ ~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~+ ~~~~r ~+ ° -~~t~~ ~~ ~ v~-7 jy~ 333 W. T" AVENUE, SUITE 100 COI~SERQA'1'IO1~T CUIrII~'IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 Chip Alvord Fax (so7~ 27s-7542 Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD4-208 ConocoPhillips Alaska, Inc. Permit No: 205-162 Surface Location: 2918' FNL, 206' FEL, SEC. 24, T11N, R4E, UM Bottomhole Location: 2683' FNL, 3768' FEL, SEC. 13, T 11 N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Injection operations are not authorized until the Commission approves the Nanuq Oil Pool Area Injection Order. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Cc actor at (907) 659- 3607 (pager) . Si DATED this day of November, 2005 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALP..._,A OIL AND GAS CONSERVATION COM LION PERMIT TO DRILL 20 AAC 25.005 ;t (. bs 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory ±y Development Oil Multiple Zone Re-entry ~ Stratigraphic Test ~ Service Q ~ Development Gas ~ Single Zone `? Q 2. Operator Name: 5. Bond: Blanket ~ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD4-208 3. Address: 6. Proposed Depth: ; 12. Field/Pool(s): PO Sox 100360, Anchorage AK 99510-0360 MD: 14184 ~ T/D~ 6159 Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Nanuq Nanuq Oil Pool Surface: 2918' FNL, '206 FEL, Sec. 24, T11 N, R4E, UM ~ saoo77, saooi5 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3668' FNL, 726' FEL, Sec. 24, T11 N, R4E, UM ADL 38077 14-Nov-05 Total Depth: 9. Acres in Property: 14. Distance to Nearest 2683' FNL, 3768' FEL, Sec. 13, T11 N, R4E, UM ~ 2560 Property: 1286T FNL ADLSSOS75 ' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 378039 ~ y- 5957493.5 Zone- ~ 4 (Height above GL): 36.7 feet Within Pool: Nanuq 3 1929' ~ 16. Deviated wells: Kickoff depth: 600 feet a 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.78 degrees Downhole: 2787. Surface: 2169 ' 18. Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 40# L-80 BTC-M 2563 37 37 2600 2443 534 Sx AS Lite & 230 sx Litecrete 8.75" 7" 26# L80 BTC-M 7163 37 37 7200 6468 Sx 15.8 ppg class G 6.125" 3.5" 9.3# L80 EUE 8rd M 7047 32 32 7047 6123 Tubing (o Sk ~~ 6.125" 3.5" 9.3# L80 SLHT 6964 7050 6123 14174 6159 Slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor 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 Anal Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirem~ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature ~ ~ Phone 907-265-6120 Date 20-Oct-05 Commission Use Only Permit to Drill ~. ~~ ~~~ ~ API Number: --~~ //~~ ~ ~` ~~ 7 "- Permit A proval `~ ~ See cover letter for other uirements re Number: , G.c~ 50- / ~iJ Date: ~ ~ q . Conditions of approval : M ~ ~ ,~,.c~n} e~a~~,}.~ `d (~oc~erc`~ P~h e,.c~~~7~kc~rp`fc c~ C7~Q«S . y,~~ 4> Samp req fired ~ Yes ~ No ~ Mud log required Yes ~ No ~ No y gen s fide measures Yes ~ No Directio I survey required Yes , Other: ~~ +~~ ~~ ~~~ ~n~~c~~~pr~DC'f. C' t~~~~ APPROVED BY Appro THE COMMISSION Date: ~ '~ D V~ ~ Form 10-401 Revised O6/2004~ ~.,~~~ 1;/ ~ `( i.:~ , ~ 2005 Submit inDuplicate .~ ConocoPhilli s Alaska, Inc• P Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 27, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-208 Dear Sir or Madam: ~OI'lOC0~11~1 S ~ ~ ~ h ~~ . ~ n .~~ ,r `+~ + ;' t~ L~i~~ ~~ ~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 11/14/2005. It is intended that Doyon Rig 19 be used to drill the well ~ cxt~o ~ ~~ ~~( ~ CD4-208 will be drilled to penetrate the reservoir horizontally and undulate throughout the horizontal. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner injector. 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 injection fourth quarter 2006. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- +/- 250 ft TVD above the Nanuq reservoir. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. 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 diverter set up. If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, Vern Johnson at 265-6081, or Chip Alvord at 265-6120. Sincerely, .. ~~ Liz Galiunas Drilling Engineer • Attachments cc: CD4-208 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Liz Galiunas Jack Walker Lanston Chin • ATO 1530 ATO 1700 ATO 1702 ATO 1704 ATO 1740 Kuukpik Corporation :7 CD4-208 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" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin 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' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casin Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD 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 ~ HZS 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 HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers n~''r~~~~~. • • Nanup : CD4-208 Procedure 1) Move on Doyon 19. 2) Rig up and test diverter. `"" 3) Drill 12-%4" 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. 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. r 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, 17) Rig up a-line and run a cement eval ~ n log. ,.,.na.v. o _ .r..,..a,~e,~--- 18) Run 3-%2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel, packer and stinger assembly. Sting in, space out and land hanger. 19) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 20) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 21) Circulate tubing to diesel and install freeze protection in the annulus. 22) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 23) Set BPV and secure well. Move rig off. CJ 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 84~@ 1696' 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 Pumpina Operations: Incidental fluids developed from drilling operations on well CD4-208 will be injected into a permitted annulus ° on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-208 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 CD4-208 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 wi11 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)'` (2600') + 1,500 psi = 3122 psi Pore Pressure = 1,105 psi Therefore Differential = 3122 -1105 = 2017 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 n"~~~~~L ~ • 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 PP9 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. 64/36 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 64/36 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. ~!~~~!~L • • CD4 - 208 Nanuq Nanuq Injector Completion 16" Insulated Conductor to 114' 3-'/" x 4-'/" cross-over, 2 jts below 4-''/2" hanger 3-'/" 9.3 ppf L-80 EUE 8rd Mod Tubing 2.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2600' MD / 2443' TVD Sperry Sun Directional Plan WPOS ~ ar2soas Circulate diesel and/or corrosion inhibitor before setting packer after tubing is spaced out and landed. Uooe r Com leo tion: T op MD ~ Item 1) Tubing Hanger 32' 32' 2) 4-''/i' 12.6 #/ft IBT-Mod Tubing (2) 3) Crossover 4) 3'/2', 9.3#/ft, EUE 8rd Mod Tubing 5) Camco DB nipple 2100' 2000' 6) 3-''/z', 9.3#fft, EUE 8rd Mod Tubing 7) Camco KBMG- GLM (2.867" ID) 6568' 5929' 8) 3-'/i', 9.3#/ft, EUE 8rd Mod Tubing (2) 9) Baker Premier Packer 6668' ''s~$1' 10) 3 Yi', 9.3#/ft, EUE 8rd Mod Tubing (1) 11) HES "XN" (2.750")- 63.0° inc 6728' 6010' 12) 3-'/z', 9.3#/ft, EUE 8rd Mod Tubing +/- 8 jts 13) BOT Stinger with Fluted WLEG/ stinger 7047' 6123' Stung into tieback extension 10', bottom at 7060' Lower Completion: Too MD TVD 1[g1I1 14) Baker 5" x 7" Flexlock Liner Hanger 7050' 6123' 15) 3 Yz "', 9.3#/ft, SLHT Tubing +/- 4 jts 16) 3-'/~' 9.3#/ft L-80 SLHT liner w/blank across shale and slots across sand 17) Baker Shce w/ packoff bushing 14174' 6159' Top of cement Wei `~``"''""'`'~ ~ ~ 6468' MD / 5871' TVD ~~~~ 4 ~~~ Top Reservoir at +/- Nanuq 7248' MD / 6159' T1 ll~ 7" 26 ppf L-80 BTC Mod Production Casing @ +/-81.6° 7200' MD, 6153' TVD ~" ~'~~L 3-'/~' 9.3#/ft SLHT liner: 8 slots / ft, 2 '/:' x 1 /8" slots TD 6-1/8" hole 14184' MD / 6159' TVD ' • • CD4-208 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 2600 / 2443 14.5 1105 1598 7" 7200 / 6153 16.0 2784 ~ 2168 N/A 14184 / 6159 16.0 2787 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASPI 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 Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1105 - (0.1 x 2443') = 860.7 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 2443 = 1598 psi OR ASP =FPP - (0.1 x D) = 2784 - (0.1 x 6153') = 2169 psi Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2787 - (0.1 x 6159') = 2168 psi ORDINAL • • Cementing Program: 9 5/8" Surface Casing run to 2600' MD / 2443' TVD. Cement from 2600' MD to 2100' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2100' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (2100'-1795') X 0.3132 ft3/ft X 1.5 (50% excess) = 143.3 ft3 below permafrost 1795' X 0.3132 ft3/ft X 4 (300% excess) = 2248.8ft3 above permafrost Total volume = 424.7 + 2248.8 = 2391.1 ft3 => 534 Sx @ 4.48 ft3/sk System: 534 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 7200' MD /6153' TVD Cement from 7200' MD to,~y46~/-' MD (minimum 500' MD above top of Nanuq reservoir) - with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (7200' -6~8') X 0.1503 ft3/ft X 1.4 (40% excess) = 154.0 ft3 annular ,v~ol~. ~}y ® ( / 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint v lame G~ Y " ~"t ~ 1 Total volume =~,54-~'+ 17.2 = ft3 =>~Sx @ 1.16 ft3/sk t~ ~ 16S System: 148 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 BWOCement • ~ ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-208 Plan: CD4-208 Plan: CD4-208wp06 Proposal Report 26 October, 2005 HAl.L.IE3l.~RTQN Sperry Drifting Service ~~ p~ ~4nOC4~''II~ • GIp4°on M~tlal: MkYn~n CLrvrdrr ~rsr.an. ~5~ sear M.°nt Tr.v. grwr Nor+h Error S°Aacrr: E~tkd Conk Project: Colville River Unit j Alaska W-nYq MMME: iWba BnW ~ ~++n Site: Alpine CD4 Well: Plan: CD4-208 HALLIBURTON £ GramdLevel: 19.00 RKEi: D°yar 19 C 55.10fl (DOya~ i 5 ~ ~ 1 ~ i 7, %51492% N Rl i A$PV Plan: CD4-208wp06 Sperry Drilling Services i ng ' o E~i~,gasP x a9a3s2e - - _ - - -~ - - - _ _ ~ SHL; 2918' FNL 8206' FEL; Sec24-T11 Na204E Begin Dir; 3° DLS,150° TFO, 600' MD, 600' ND ) Continue Dir; 3° DLS, 32° TFO, 900' MD, 898' TVD 1500 -- _ _ _ Start Sail; 27.8° INC,1560' MD,1523' ND Base Permafrost i 9~i/8" Csg Pt; 2600' MD, 2443' ND e,~ 95/8" Csg -121/4" Hole ~ C30 ---_ . c 3000 -- coo - 0 ~ ~ ~ .~ ~. _. - Q K3 -- _ Begin Dir, 4° DLS,160° TFO, 4503' MD, 4126' TVD --- d --- -- (' ~ 4500 _ Ic-2 Base _.-. ------ --- to i v ~ CD4-208wp06 7" Csg Pt; 7200' MD, 6153' TVD; 3668' FNL 8726' FEL; Sec24T11 N~R04E d ~ 7" Csg - 83/4" H 41/2 Csg - 6118" Hole 7 I _ _ - i H 6000 - Albian 97 :. - --- _ - -- - - - ~ _ _ ~ - - __ - --_ Tap Narwq (ARMan 96) Target (T1); 7276' MD, 6162' Target (T3); 9300' MD, 6160' N Target (T5);12000' MD, 6160' Target (T2); 8100' MD, 6250' ND Target (T4);10500 ' MD, 6246' ND Target (T6);13200' MD, 6214' TVD .__.. -- - __ _ _ -- --- -- 7500 - --- -- ~ , j ~ Target (Tce);14184' MD, 6159' ND, 2683' FNL 8 3768' FEL; Sec13-T11 N~R04E -3000 -1500 0 1500 3000 4500 6000 7500 9000 ~, ,.~.,.~a.ro... C Philli onoco ps ~ ~~ :,r~:x~.t ~~ WiD,~,~N~, ~~ MALLIBURTON c`°`~°~ Rice '~„;a„e a ss,on ioov«, iviwi.iv7~ NorMing~A$P Y: 5957d92.% Sperry Drilling Services F~e„ynsax: ~~~~ 6000 j _- - -CDd-208wp~6 412" Csg -61/8" Hole Target (Tce);14184' MD, 6159' TVD, 2683' FNL 8 3768' FEL; Sec13 T11 N~204E 4500 ----- Target (1'6);13200' MD, 6214' TVD C Target (f5);12000' MD, 6160' TVD ~00 _ - ~ i i r .... I ~ Target (T4);10500' MD, 6246' TVD ~00 _ - ---__ --' - -- - _ _ _ --- z ~ i ~ ! Target (1'3); 9300' MD, 6160' TVD ' ~ I ~ I ~ O ': (n ~ _ - - _ , Target (T2); 8100' MD, 6250' TVD Target (T1); 7276' MD, 6162' TVD i 7" Csg ~.3 ole ~ -1500 FEL; Sec24-T11 Nat04E _ i--II- 7" Csg Pt; 7200' MD, 6153' TVD; 3668' FNL 8 726 -7500 -6000 -4500 -3000 -1500 SHL; 2918' FNL 8206' FEL; Sec24T11N-R04E Begin Dir; 3° DLS,150° TFO, 600' MD, 600' TVD Continue Dm 3° DLS, 32° TFO, 900' MD, 898' TVD Start Sail; 27.8° INC,1560' MD,1523' TVD ~~ 95/8" Csg -121!4" Hole 918" Csg Pt; 2600' MD, 2443' TVD Begin Dir; 4° DLS,160° TFO, 4503' MD, 4126' TVD 0 1500 3000 4500 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db .Company: ConocoPhilGps Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-208 WeQbore: Plan: CD4-208 Design: CD4208wp06 Sperry Drilling Services MALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: WeN Plan: CD4-208 -Slot 8 TVD Referonce: Doyon 19 ~ 55.10ft (Doyon 19 (36.1+19)) MD Reference: Doyon 19 (~ 55.10ft (Doyon 19 (38.1+19)) North Reference: True Survey Calculation Method: Minimum Cwvature 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 Zona 04 Using geodetic scale factor Wsl( Plan: CD4-208 -Slot 8, Alpine CD4 Well Position +NI-S 0.00 ft Northing: 5,957,492.98 ft ~ Latitude: 70° 17' 32.818" N +E/-W 0.00 ft Easting: 378,038.28 ft ~ Longitude: 150° 59' 14.723" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.00 ft Wegbore Plan: CD4-208 Magnetics Modal Narne Sampla Date Declhwtlon Dip Angle Flald Strength BGGM2005 11/11/2005 23.52 80.82 57,497 Design CD4208wp08 Audit Notes: Version: Phase: PLAN Tie On Dapth: 38.10 Vertical Sectlaan Depth From (1'VD) +N/-8 +EFW Direction (ft) (fU ifU ('1 38.10 0.00 0.00 326.00 10/26/2005 2:12:47PM Page 2 of 9 COMPASS 2003.11 Build 50 1 ~ ! , / • ConocoPhillips Alaska .Database: EDM 2003.11 Sin®le User Db Company:..: ConocoPhillips Alaska Inc. Project Colville River Unit Slte: Alpine CD4 Well: Plan: CD4-208 Wellboro: Plan: CD4208 Design: CD4208wp06 Sperry Drilling Services • NALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD4-208 - Sbt 8 TW Reference: Doyon 19 ~ 55.1011 (Doyon 19 (38.1+18)) MD Reference: Doyon 19 ~ 55.108 (Doyon 19 (38.1+19)) North Reference: True Survey Calculation Method: Minimum Curvature Plea Summary Measured Vertical Dogleg Build Turn ~Pth Inellnatian Azimuth Depth +N/-g +El.W Rate Rata RaW TFO (~ , 1') ~°) IfU (ft) IfU l°M00~ (°NOOft) ('I100ft) C) 36.10 0.00 0.00 36.10 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 0.00 900.00 9.00 150.00 898.77 -20.36 11.76 3.00 3.00 0.00 150.00 1,560.23 27.82 172.76 1,523.00 -219.92 57.44 3.00 2.85 3.45 32.21 4,503.57 27.82 172.76 4,126.11 -1,582.70 230.45 0.00 0.00 0.00 0.00 7,276.67 84.61 334.08 6,182.11 -682.78 -553.02 4.00 2.05 5.82 160.03 7,314.30 83.11 334.08 6,166.13 -649.13 -569.38 4.00 -4.00 0.00 180.00 7,927.75 83.11 334.08 6,239.75 -101.39 -835.61 0.00 0.00 0.00 0.00 8,100.06 90.00 334.01 6,250.10 53.16 -910.85 4.00 4.00 -0.04 -0.54 8,219.50 94.78 334.05 6,245.12 160.42 -983.09 4.00 4.00 0.03 0.40 9,180.60 94.78 334.05 6,185.08 1,021.59 -1,382.25 0.00 0.00 0.00 0.00 9,300.07 90.00 334.16 6,160.10 1,128.93 -1,434.37 4.00 -4.00 0.09 178.66 9,413.59 85.46 334.16 6,164.60 1,231.00 -1,483.80 4.00 -4.00 0.00 179.97 10,386.28 85.46 334.16 6,241.60 2,103.68 -1,906.43 0.00 0.00 0.00 0.00 10,489.81 80.00 334.12 6,246.10 2,205.73 -1,955.90 4.00 4.00 -0.04 -0.54 10,587.02 93.49 334.12 6,243.45 2,284.15 -1,993.95 4.00 4.00 0.00 0.00 11,813.15 93.49 334.12 6,162.75 3,475.04 -2,571.78 0.00 0.00 0.00 0.00 12,000.36 90.00 334.11 6,160.10 3,553.45 -2,609.84 4.00 -4.00 -0.01 -179.91 12,068.72 87.27 334.11 6,161.73 3,614.92 -2,639.87 4.00 -4.00 0.00 -179.98 13,132.39 87.27 334.11 6,212.47 4,570.76 -3,103.57 0.00 0.00 0.00 0.00 13,200.74 90.00 334.13 6,214.10 4,632.23 -3,133.40 4.00 4.00 0.02 0.33 13,284.48 93.35 334.13 6,211.65 4,707.53 -3,169.92 4.00 4.00 0.00 0.00 14,183.99 93.35 334.13 6,159.10 5,515.49 -3,561.78 0.00 0.00 0.00 0.00 10/26/2005 2:12:47PM Page 3 of 9 COMPASS 2003.11 Build 50 ~~~~~#. e ~ • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company::.. ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-208 Wellbore: Plan: CD4-208 Design: CD4208wp06 Sperry Drilling Services NALLIBURTON Planning Report -Geographic Sperry Drilling Services Locaf Co~ordinats Reference: WeU Plan: CD4-208 - S~ 8 TVD Reference: Doyon 19 ~ 55.10ft (Doyon 19 (38.1+19)) MD Reference: Doyon 19 ~ 55.10(1 (Doyon 19 (36.1+19)) North Reference: True Survey Calculat7on Method; Minimum Curvattxe Ptantwd 8urvay CD4208wp06 Map. Map MD Inc{tnation Azimuth TVD 88TVD +Nl-S +Ef YY Northing- Eastiny DLSEV Vert Section Iftl r) c•- 1ft) rftt! c~c) ~~) « ~~) r/,00fU Ifl- 36.10 0.00 0.00 36.10 -19.00 0.00 0.00 5,957,482.96 378,038.28 0.00 0.00 $HL; 2918' FNL & 206' FE L; Sec24-T11 N-R04E 100.00 0.00 0.00 100.00 44.90 0.00 0.00 5,957,492.96 378,038.28 0.00 0.00 200.00 0.00 0.00 200.00 144.90 0.00 0.00 5,957,492.E 378,038.28 0.00 0.00 600.00 0.00 0.00 600.00 544.90 0.00 0.00 5,957,492.96 378,038.28 0.00 0.00 / Begin Dir; 3° DLS, 150° TFO, 600' MD, 600' TVD 700.00 3.00 150.00 689.95 644.85 -2.27 1.31 5,957,490.67 378,039.55 3.00 -2.61 800.00 6.00 150.00 799.63 744.53 -9.06 5.23 5,957,483.82 378,043.38 3.00 -10.44 900.00 9.00 150.00 898.77 843.67 -20.36 11.76 5,957,472.41 378,049.70 3.00 -23.46 Continue Dir; 3° DLS, 32° TFO, 900' MD, 898' TYD 1,000.00 11.65 157.94 997.15 942.05 -36.50 19.46 5,957,456.16 378,057.14 3.00 -41.74 1,100.00 14.43 162.92 1,094.56 1,039.46 -57.77 26.91 5,957,434.77 378,064.25 3.00 -62.94 1,200.00 17.29 166.29 1,190.74 1,135.64 -84.12 34.10 5,957,408.30 378,071.00 3.00 -88.81 1,300.00 20.18 168.73 1,285.44 1,230.34 -115.49 40.99 5,957,376.83 378,077.39 3.00 -118.66 1,400.00 23.11 170.58 1,378.38 1,323.28 -151.77 47.58 5,857,340.45 378,083.38 3.00 -152.43 1,500.00 26.05 172.03 1,469.31 1,414.21 -192.88 53.83 5,957,299.25 378,088.97 3.00 -190.01 1,560.23 27.82 172.76 1,523.00 1,467.90 -219.92 57.44 5,957,272.15 378,092.14 3.00 -214.44 Start Sail; 27.8 ° INC, 1560' MD, 1523' TVD 1,800.00 27.82 172.76 1,558.18 1,503.08 -238.34 59.78 5,957,253.71 378,094.17 0.00 -231.02 1,647.29 27.82 172.76 1,600.00 1,544.90 -260.23 62.56 5,957,231.77 378,096.60 0.00 -250.72 Base Permafrost 1,700.00 27.82 172.76 1,646.62 1,591.52 -284.64 65.65 5,957,207.32 378,099.30 0.00 -272.89 1,800.00 27.82 172.76 1,735.06 1,679.96 -330.94 71.53 5,957,160.93 378,104.43 0.00 -314.36 1,900.00 27.82 172.76 1,823.50 1,768.40 -377.24 77.41 5,957,114.55 378,109.55 0.00 -356.03 2,000.00 27.82 172.76 1,811.94 1,856.84 -423.54 83.29 5,957,068.16 378,114.68 0.00 -387.70 2,100.00 27.82 172.76 2,000.38 1,945.28 -469.84 89.17 5,957,021.78 378,119.80 0.00 -439.37 2,200.00 27.82 172.76 2,088.82 2,033.72 -516.14 95.04 5,956,975.39 378,124.93 0.00 -481.05 2,300.00 27.82 172.76 2,177.26 2,122.16 -562.44 100.92 5,958,929.01 378,130.05 0.00 -522.72 2,323.56 27.82 172.76 2,198.10 2,743.00 -573.35 102.31 5,956,918.07 378,131.26 0.00 -532.54 C-40 2,400.00 27.82 172.76 2,265.70 2,210.60 -608.74 106.80 5,956,882.62 378,135.18 0.00 -564.39 2,500.00 27.82 172.76 2,354.14 2,289.04 -655.04 112.68 5,956,836.23 378,140.30 0.00 -606.06 2,557.62 27.82 172.76 2,405.10 2,350.00 -681.72 116.06 5,956,808.51 378,143.28 0.00 -630.07 C-30 2,600.00 27.82 172.76 2,442.58 2,387.48 -701.34 118.56 5,956,789.85 378,145.43 0.00 -847.73 2,600.47 27.82 172.76 2,443.00 2,387.80 -701.56 118.58 5,956,789.63 378,145.45 0.00 -647.83 9-5/8" Csg Pt; 2600' MD, 2443' TVD - 9 5/8" Csg - 12 114" Hole 2,700.00 27.82 172.76 2,531.02 2,475.92 -747.64 124.43 5,956,743.46 378,150.56 0.00 -889.40 2,800.00 27.82 172.76 2,619.46 2,564.36 -793.94 130.31 5,956,697.08 378,155.68 0.00 -731.08 2,900.00 27.82 172.76 2,707.90 2,652.80 -840.24 136.19 5,956,650.69 378,160.81 0.00 -772.75 2,964.67 27.82 172.76 2,765.10 2,710.00 -870.18 139.99 5,956,620.69 378,164.12 0.00 -799.70 C-20 3,000.00 27.82 172.76 2,786.34 2,741.24 -886.54 142.07 5,956,604.30 378,165.93 0.00 -814.42 3,100.00 27.82 172.76 2,884.78 2,829.68 -932.84 147.95 5,956,557.82 378,171.08 0.00 -856.09 3,200.00 27.82 172.76 2,973.22 2,918.12 -979.14 153.82 5,856,511.53 378,178.18 0.00 -897.76 3,300.00 27.82 172.78 3,061.66 3,006.56 -1,025.44 159.70 5,956,465.15 378,181.31 0.00 -939.43 10/26/2005 2:12:47PM ~ ~P~geof~ ~ ~ ~ COMPASS 2003.11 Build 50 • • ° Ph C ll Sperry Drilling Services NALILIBURTON onoco i ~ S p Planning Report -Geographic Alaska Sperry Drilling Services Datagase: EDM 2003.11 Single User Db Local Go-grdirtaM RefR~ance: VVefl Plan: CD4-208 - Sbt 8 Company: ConocoPhillips Alaska Inc. TYD Rafenoca: Doyon 19 ®55.10ft (Doyon 19 (38.1+t9}) Protect: Colville River Unit MD Reference: Doyon 19 ~ 55.10ft (Doyon 19 (36.1+t9}) SiW: Alpine CD4 North Reference: True Well: Plan: CD4-208 Survey Cakulatbn Method: Minimum Curvature Weilbore: Plan: CD4-208 Design: CD4208wp08 Planned Survey CD4208wp06 Map Map MD Inclination Azimuth TVD SSTVD _ +fV/.S +E/-W Northing EastMp pL3EV Vort Saatlon (fu r} r} ift- 1111 (flU (~ ~~~ (~} i°/toofu ift- 3,400.00 27.82 172.76 3,150.10 3,095.00 -1,071.74 165.58 5,956,418.76 378,186.44 0.00 -981.11 3,500.00 27.82 172.76 3,238.55 3,183.45 -1,118.04 171.46 5,956,372.38 378,191.56 0.00 -1,022.78 3,600.00 27.82 172.76 3,326.99 3,271.89 -1,164.34 177.34 5,958,325.99 378,196.69 0.00 -1,064.45 3,700.00 27.82 172.76 3,415.43 3,380.33 -1,210.64 183.21 5,956,279.60 378,201.81 0.00 -1,106.12 3,800.00 27.82 172.76 3,503.87 3,448.77 -1,256.94 189.09 5,956,233.22 378,206.94 0.00 -1,147.79 3,900.00 27.82 172.76 3,592.31 3,537.21 -1,303.24 194.97 5,958,186.83 378,212.06 0.00 -1,189.46 4,000.00 27.82 172.76 3,680.75 3,625.65 -1,349.54 200.85 5,956,140.45 378,217.19 0.00 -1,231.14 4,100.00 27.82 172.76 3,769.19 3,714.09 -1,395.85 206.73 5,856,094.08 378,222.32 0.00 -1,272.81 4,150.78 27.82 172.76 3,814.10 3,759.00 -1,419.36 209.71 5,956,070.51 378,224.92 0.00 -1,293.97 K-3 4,200.00 27.82 172.78 3,857.63 3,802.53 -1,442.15 212.60 5,956,047.68 378,227.44 0.00 -1,314.48 4,300.00 27.82 172.76 3,946.07 3,890.97 -1,488.45 218.48 5,956,001.29 378,232.57 0.00 -1,356.15 4,400.00 27.82 172.76 4,034.51 3,978.41 -1,534.75 224.36 5,955,954.90 378,237.69 0.00 -1,397.82 4,442.50 27.82 172.78 4,072.10 4,017.00 -1,554.43 226.86 5,955,935.19 378,239.87 0.00 -1,415.53 K-2 4,500.00 27.82 172.76 4,122.95 4,067.85 -1,581.05 230.24 5,955,908.52 378,242.82 0.00 -1,439.49 4,503.57 27.82 172.76 4,126.11 4,071.01 -1,582.70 230.45 5,955,906.86 378,243.00 0.00 -1,440.98 Begin Dir; 4° D LS, 160° TFO, 4503' MD, 4126' ND 4,560.68 25.69 174.56 4,177.10 4,122.00 -1,608.24 233.30 5,955,881.28 378,245.44 4.00 -1,463.75 K-2 Base 4,600.00 24.23 175.97 4,212.75 4,157.65 -1,624.78 234.67 5,955,864.72 378,246.54 4.00 -1,47$.23 4,700.00 20.60 180.39 4,305.19 4,250.09 -1,862.85 235.99 5,955,828.64 378,247.25 4.00 -1,510.53 4,800.00 17.13 186.55 4,399.81 4,344.71 -1,695.08 234.19 5,955,794.44 378,244.92 4.00 -1,536.25 4,900.00 13.93 195.58 4,496.16 4,441.06 -1,721.31 229.28 5,955,768.30 378,239.58 4.00 -1,555.24 5,000.00 11.24 209.29 4,593.78 4,538.68 -1,741.41 221.28 5,955,748.34 378,231.26 4.00 -1,567.43 5,100.00 9.51 229.49 4,692.17 4,637.07 -1,755.28 210.22 5,955,734.85 378,219.98 4.00 -1,572.75 5,200.00 9.29 254.13 4,790.87 4,735.77 -1,762.85 196.17 5,955,727.30 378,205.81 4.00 -1,571.17 5,300.00 10.87 275.97 4,889.39 4,834.29 -1,764.10 179.20 5,955,726.33 378,188.82 4.00 -1,582.71 5,400.00 13.18 291.27 4,987.25 4,932.15 -1,759.00 159.37 5,955,731.75 378,169.08 4.00 -1,547.40 5,500.00 16.25 301.32 5,083.98 5,028.88 -1,747.59 136.80 5,955,743.52 378,146.70 4.00 -1,525.32 5,600.00 19.67 308.10 5,179.10 5,124.00 -1,729.93 111.59 5,955,761.59 378,121.78 4.00 -1,496.58 5,700.00 23.27 312.89 5,272.15 5,217.05 -1,706.09 83.87 5,955,785.88 378,094.45 4.00 -1,461.31 5,800.00 26.97 316.45 5,362.69 5,307.59 -1,676.20 53.76 5,955,816.25 378,064.84 4.00 -1,419.69 5,900.00 30.75 319.20 5,450.25 5,395.15 -1,640.39 21.42 5,955,852.57 378,033.08 4.00 -1,371.93 6,000.00 34.57 321.40 5,534.43 5,479.33 -1,588.86 -12.99 5,955,894.86 377,999.35 4.00 -1,318.25 6,100.00 38.42 323.20 5,614.81 5,558.71 -1,551.78 -49.32 5,955,942.31 377,863.79 4.00 -1,258.91 6,200.00 42.30 324.73 5,691.00 5,635.90 -1,499.41 -87.38 5,955,995.29 377,926.59 4.00 -1,194.21 6,300.00 46.19 326.04 5,762.62 5,707.52 -1,441.99 -128.88 5,958,053.34 377,887.93 4.00 -1,124.45 6,400.00 50.10 327.19 5,829.33 5,774.23 -1,379.79 -167.94 5,956,116.19 377,847.99 4.00 -1,049.99 6,440.86 51.70 327.62 5,855.10 5,800.00 -1,353.08 -185.02 5,956,143.17 377,831.35 4.00 -1,018.29 Albian 97 6,500.00 54.02 328.22 5,890.81 5,835.71 -1,313.13 -210.05 5,958,183.52 377,806.97 4.00 -971.18 6,600.00 57.94 329.15 5,946.75 5,891.85 -1,242.33 -253.11 5,956,255.00 377,785.07 4.00 -886.40 6,700.00 61.87 330.00 5,996.88 5,941.78 -1,167.74 -296.91 5,958,330.29 377,722.49 4.00 -802.07 6,800.00 65.81 330.79 8,040.95 5,985.85 -1,089.71 -341.23 5,956,409.02 377,678.44 4.00 -712.59 8,900.00 69.75 331.53 6,078.76 6,023.86 -1,008.63 -385.87 5,956,480.81 377,638.13 4.00 -620.42 7,000.00 73.69 332.24 6,110.12 6,055.02 -924.89 -430.60 5,956,575.25 377,592.77 4.00 -525.98 7,100.00 77.64 332.92 8,134.87 6,079.77 -838.90 -475.20 5,956,1.95 377,549.57 4.00 -429.75 10/26/2005 2:12:47PM r Page 5 of 9 COMPASS 2003.11 Build 50 t d~ ~ `e L • ~ ConocoPhillips Alaska Databases EDM 2003.11 Single User Db Company: ConocoPhilFps Alaska Inc. Project: Colville River Unit Slte: Alpine CD4 Well: Plan: CD4-208 We11Wre: Plan: CD4208 Design:. CD4-208wp06 Sperry Drilling Services Planning Report -Geographic local Go-ortlinafie Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBURTON Sperry Drillin8 Services VYeU Plan: CD4-208 - SIB 8 Doyori 19 ~ 55.10ft (Doyon 19 (38:1+19)) Doyon 19 ~ 55.tOft (Doyon 19 (36.1+19}) True Minimum Curvature Planned Survey .. CD4-208wp06 Map Map MI) Inelinatiort /ltlmuth TVD 8SND +N/3 +l'el-W Northtnq Eaetiny DI.SEV Vert Seatlon ttt) (') (`l Ift) tftl (~) (~ t~ti hU (•hoo~ tftt 7,200.00 81.58 333.58 6,152.90 6,097.80 -751.08 -519.45 5,956,750.47 377,506.75 4.00 -332.20 7,200.68 81.61 333.59 6,153.00 6,097.90 -750.48 -519.75 5,956,751.07 377,508.46 4.17 -331.53 7" Csg Pt; 7200' MD, 6153 ' ND; 3668' FNL & 726' FEL; Sec24-T11 N -R04E - 7" Csg - 8 3/4" Hole 7,247.87 83.47 333.89 6,159.10 6,104.00 -708.70 -540.37 5,956,793.18 377,486.53 4.00 -285.37 Top Nanuq (Albian 96) 7,276.67 84.61 334.08 6,162.11 8,107.01 -682.78 -553.02 5,956,819.30 377,474.30 4.~ -256.80 Target (T1); 7276' MD, 616 2' ND -CD4-208wp05 T1 7,300.00 83.68 334.08 6,164.49 6,109.39 -661.91 -563.17 5,956,840.33 377,484.50 3.99 -233.83 7,314.30 83.11 334.08 6,168.13 6,111.03 -649.13 -569.38 5,956,853.21 377,458.49 4.01 -219.78 7,400.00 83.11 334.08 6,176.42 6,121.32 -572.61 -606.57 5,956,930.31 377,422.55 0.00 -135.53 7,500.00 83.11 334.08 8,188.42 6,133.32 -483.32 -649.97 5,957,020.28 377,380.61 0.00 -37.23 7,600.00 83.11 334.08 6,200.42 6,145.32 -394.03 -693.37 5,957,110.26 377,338.66 0.~ 61.08 7,700.00 83.11 334.08 6,212.42 6,157.32 -304.74 -736.77 5,957,200.23 377,296.72 0.00 159.35 7,800.00 83.11 334.08 6,224.42 6,169.32 -215.46 -780.17 5,957,290.21 377,254.78 0.00 257.64 7,900.00 83.11 334.08 6,236.42 6,181.32 -126.17 -823.57 5,957,380.18 377,212.84 0.00 355.94 7,927.75 83.11 334.08 6,239.75 6,184.65 -101.39 -835.61 5,957,405.14 377,201.20 0.00 383.21 8,000.00 86.00 334.05 6,246.61 6,191.51 -36.72 -867.07 5,957,470.32 377,170.80 4.00 454.42 8,100.06 90.00 334.01 6,250.10 6,195.00 53.16 -910.85 5,957,560.89 377,128.49 4.00 553.41 Target (T2); 8100' MD, 6250' ND -CD4-208wp05 T2 8,200.00 94.00 334.04 6,246.61 6,191.51 142.94 -954.58 5,957,651.36 377,086.22 4.00 652.30 8,219.50 94.78 334.05 6,245.12 6,190.02 160.42 -963.08 5,957,668.97 377,078.00 4.01 671.55 8,300.00 84.78 334.05 6,238.42 6,183.32 232.55 -998.20 5,957,741.85 377,044.07 0.00 750.98 8,400.00 84.78 334.05 6,230.09 6,174.99 322.15 -1,041.81 5,957,831.95 377,001.92 0.00 849.65 8,500.00 94.78 334.05 6,221.76 6,166.66 411.76 -1,085.42 5,957,922.24 376,959.77 0.00 948.32 8,600.00 94.78 334.05 6,213.43 6,158.33 501.36 -1,129.04 5,958,012.53 376,917.82 0.00 1,046.99 8,700.00 94.78 334.05 6,205.10 6,150.00 590.98 -1,172.65 5,958,102.82 376,875.47 0.00 1,145.87 8,800.00 94.78 334.05 8,196.78 6,141.68 680.56 -1,216.26 5,958,193.11 376,833.32 0.00 1,244.34 8,900.00 94.78 334.05 6,188.45 6,133.35 770.17 -1,259.87 5,958,283.40 376,791.17 0.00 1,343.01 9,000.00 94.78 334.05 6,180.12 6,125.02 859.77 -1,303.49 5,958,373.89 376,749.02 0.00 1,441.68 9,100.00 94.78 334.05 6,171.79 6,116.69 949.37 -1,347.10 5,958,463.98 376,706.87 0.00 1,540.35 9,180.60 94.78 334.05 6,165.08 6,109.98 1,021.59 -1,382.25 5,958,536.75 376,672.90 0.00 1,619.88 9,200.00 94.00 334.06 6,163.59 6,108.49 1,038.98 -1,390.71 5,958,554.28 378,864.72 3.99 1,639.03 8,300.07 90.00 334.16 6,160.10 6,105.00 1,128.93 -1,434.37 5,958,844.92 378,622.53 4.00 1,738.02 Target (T3); 9300' MD, 6160' ND -CD4-208wp05 T3 9,400.00 86.00 334.18 6,163.58 6,108.48 1,218.80 -1,477.89 5,958,735.47 376,580.47 4.00 1,836.86 9,413.59 85.46 334.16 6,164.60 6,109.50 1,231.00 -1,483.80 5,958,747.76 376,574.77 4.01 1,850.27 9,500.00 85.46 334.16 6,171.44 8,116.34 1,308.52 -1,521.35 5,958,825.88 378,538.49 0.00 1,935.54 9,600.00 85.46 334.16 6,179.35 6,124.25 1,388.24 -1,584.80 5,858,916.29 376,498.50 0.00 2,034.22 9,700.00 85.46 334.16 6,187.27 6,132.17 1,487.96 -1,608.25 5,959,006.69 376,454.52 0.00 2,132.90 9,800.00 85.46 334.16 6,195.19 6,140.09 1,577.68 -1,851.70 5,959,097.10 376,412.53 0.00 2,231.57 9,900.00 85.46 334.16 6,203.11 6,148.01 1,667.40 -1,695.15 5,959,187.50 378,370.55 0.00 2,330.25 10,000.00 85.46 334.18 6,211.02 6,155.92 1,757.12 -1,738.59 5,959,277.91 376,328.58 0.00 2,428.93 10,100.00 85.46 334.16 6,218.94 6,163.84 1,848.84 -1,782.04 5,959,368.31 376,286.58 0.00 2,527.60 10,200.00 85.46 334.16 6,226.86 6,171.76 1,936.56 -1,825.49 5,959,458.71 376,244.59 0.00 2,826.28 10,300.00 85.46 334.16 6,234.77 6,179.87 2,026.27 -1,868.94 5,959,549.12 376,202.61 0.00 2,724.86 10,386.28 85.46 334.16 6,241.60 6,186.50 2,103.68 -1,906.43 5,959,827.12 376,166.38 0.00 2,810.10 10,400.00 86.01 334.15 6,242.62 6,187.52 2,116.00 -1,912.40 5,959,639.53 378,160.62 3.98 2,823.64 10/26/2005 2:12:47PM Page i6 of 9 COMPASS 2003.11 Build 50 d a .. . ConocoPhittips Alaska .Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Stte: Alpine CD4 Well: Plan: CD4-208 Wellbore: Plan: CD4-208 Design: CD4208wp06 Planned Survey... CD4208wp06 Sperry Drilling Services • PI R rt G h~ NALLIBURTON anning epo - eograp Ic Sperry Drilling Services LocalCo-ordinate Reference: Well Plan: CD4-208 -Slot 8 TVD Reference: Doyon 19 ~ 55.tOft (Doyon 19 (36.1+19)) NID Reference: ~ Doyon 19 ~ 55.10ft (Doyon 19 (36.1+19)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +NkS +E/-W Northing Fasting DLSEV YertSectioQ (Ri (•~ (•~ (~ ttiitt (tt) (ft) (~ (~) t°/loofu tftl 10,499.81 90.00 334.12 6,246.10 6,191.00 2,205.73 -1,955.90 5,959,728.95 378,118.58 4.00 2,922.36 Target (T4); 10500' MD, 6246' TVD -CD4-208wp05 T4 10,500.00 90.00 334.12 6,246.10 6,191.00 2,205.91 -1,855.98 5,958,730.12 376,118.50 0.00 2,922.55 10,587.02 93.49 334.12 8,243.45 6,188.35 2,284.15 -1,993.95 5,959,808.96 376,081.81 4.01 3,008.65 10,600.00 93.49 334.12 6,242.66 6,187.56 2,285.81 -1,999.61 5,959,820.71 376,076.35 0.00 3,021.47 10,700.00 93.49 334.12 6,236.57 6,181.47 2,385.61 -2,043.18 5,959,911.20 376,034.24 0.00 3,120.29 10,800.00 93.49 334.12 6,230.49 6,175.39 2,475.41 -2,086.75 5,960,001.69 375,992.13 0.00 3,219.10 10,900.00 93.48 334.12 6,224.40 6,189.30 2,565.21 -2,130.32 5,960,092.18 375,950.03 0.00 3,317.82 11,000.00 93.49 334.12 8,218.32 6,163.22 2,655.01 -2,173.90 5,960,182.67 375,907.82 0.00 3,416.73 11,100.00 93.48 334.12 6,212.23 6,157.13 2,744.81 -2,217.47 5,980,273.18 375,865.81 0.00 3,515..55 11,200.00 93.49 334.12 6,206.15 6,151.05 2,834.62 -2,261.04 5,960,363.85 375,823.71 0.00 3,614.36 11,300.00 93.49 334.12 6,200.06 6,144.96 2,924.42 -2,304.62 5,960,454.14 375,781.60 0.00 3,713.18 11,400.00 93.49 334.12 6,193.98 6,138.88 3,014.22 -2,348.19 5,960,544.63 375,739.49 0.00 3,811.99 11,500.00 93.49 334.12 6,187.89 6,132.79 3,104.02 -2,391.76 5,960,635.12 375,697.39 0.00 3,910.81 11,600.00 93.49 334.12 6,181.81 6,126.71 3,193.82 -2,435.33 5,960,725.61 375,855.28 0.00 4,009.62 11,700.00 93.49 334.12 6,175.72 6,120.62 3,283.63 -2,478.81 5,960,816.10 375,613.17 0.00 4,108.44 11,800.00 93.49 334.12 6,169.64 6,114.54 3,373.43 -2,522.48 5,960,906.59 375,571.07 0.00 4,207.25 11,900.00 83.49 334.12 8,163.55 6,108.45 3,463.23 -2,566.05 5,960,997.07 375,528.96 0.00 4,306.07 11,913.15 93.49 334.12 6,162.75 6,107.65 3,475.04 -2,571.78 5,981,008.88 375,523.42 0.00 4,319.06 12,000.00 90.01 334.11 6,160.10 6,105.00 3,553.13 -2,609.68 5,961,087.66 375,486.80 4.00 4,404.99 12,000.36 90.00 334.11 6,160.10 6,105.00 3,553.45 -2,609.84 5,961,087.89 375,488.85 4.00 4,405.35 Target (T6); 12000' MD, 6160' TVD -CD4-208wp05 T5 12,068.72 87.27 334.11 6,161.73 6,106.63 3,614.92 -2,839.67 5,961,149.93 375,457.82 4.00 4,472.99 12,100.00 87.27 334.11 6,163.22 6,108.12 3,643.04 -2,653.31 5,961,178.26 375,444.84 0.00 4,503.93 12,200.00 87.27 334.11 6,167.99 6,112.89 3,732.80 -2,696.93 5,961,268.81 375,402.49 0.00 4,802.81 12,300.00 87.27 334.11 6,172.76 6,117.66 3,822.76 -2,740.54 5,981,358.38 375,360.34 0.00 4,701.70 12,400.00 87.27 334.11 6,177.53 6,122.43 3,912.62 -2,784.15 5,961,449.91 375,318.20 0.00 4,800.59 12,500.00 87.27 334.11 6,182.30 8,127.20 4,002.48 -2,827.77 5,961,540.46 375,276.05 0.00 4,899.47 12,800.00 87.27 334.11 6,187.07 6,131.97 4,092.34 -2,871.38 5,961,631.01 375,233.90 0.00 4,998.36 12,700.00 87.27 334.11 6,191.84 6,136.74 4,182.21 -2,914.99 5,981,721.56 375,191.76 0.00 5,097.25 12,800.00 87.27 334.11 6,196.61 6,141.51 4,272.07 -2,958.61 5,961,812.11 375,149.61 0.00 5,196.14 12,900.00 87.27 334.11 6,201.38 6,146.28 4,361.93 -3,002.22 5,961,902.66 375,107.47 0.00 5,295.02 13,000.00 87.27 334.11 6,206.15 6,151.05 4,451.79 -3,045.83 5,961,993.21 375,065.32 0.00 5,393.91 13,100.00 87.27 334.11 6,210.92 6,155.82 4,541.65 -3,089.45 5,962,083.76 375,023.17 0.00 5,492.80 13,132.39 87.27 334.11 6,212.47 6,157.37 4,570.76 -3,103.57 5,962,113.08 375,009.52 0.00 5,524.82 13,200.00 89.87 334.13 6,214.10 6,159.00 4,631.56 -3,133.07 5,962,174.36 374,981.01 4.00 5,591.73 13,200.74 90.00 334.13 6,214.10 6,159.00 4,632.23 -3,133.40 5,962,175.03 374,980.70 4.00 5,592.47 Target (T6); 13200' MD, 6214' TVD -CD4-208wp05 T6 13,284.48 93.35 334.13 6,211.65 6,156.55 4,707.53 -3,169.92 5,862,250.90 374,945.41 4.00 5,675.31 13,300.00 93.35 334.13 6,210.75 6,155.65 4,721.47 -3,176.68 5,962,264.95 374,938.88 0.00 5,890.65 13,400.00 93.35 334.13 8,204.90 6,149.80 4,811.29 -3,220.24 5,962,355.48 374,896.78 0.00 5,789.48 13,500.00 93.35 334.13 6,199.06 6,143.96 4,901.12 -3,263.81 5,962,445.97 374,854.68 0.00 5,888.31 13,600.00 93.35 334.13 6,183.22 6,138.12 4,990.94 -3,307.37 5,962,536.48 374,812.58 0.00 5,987.13 13,700.00 93.35 334.13 6,187.38 6,132.28 5,080.76 -3,350.94 5,862,626.99 374,770.49 0.00 8,085.98 13,800.00 93.35 334.13 6,181.53 6,126.43 5,170.58 -3,394.50 5,962,717.50 374,728.39 0.00 6,184.79 13,900.00 83.35 334.13 6,175.69 6,120.59 5,260.41 -3,438.06 5,962,808.01 374,686.29 0.00 8,283.62 14,000.00 93.35 334.13 6,169.85 6,114.75 5,350.23 -3,481.63 5,982,898.52 374,644.19 0.00 8,382.44 14,100.00 93.35 334.13 6,164.01 6,108.91 5,440.05 -3,525.18 5,962,988.03 374,602.10 0.00 6,481.27 10/26/2005 2:12:47PM Page 7 of 9 COMPASS 2003.11 Build 50 ~'~~~F~ ° ~ Sperry Drilling Services ConocoPhtllt S i-IALI~IBURTON p Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Locat Co~c-rdlnate Referanw: `Web Plan: CD4-208 - Sbt 8 Company: ConocoPhilNps Alaska Ina TVD Reference: Doyon 19 ~ 55.10ft (Doyon 19 {36.1+19j) Project: Colville River Unft MD Referonce: Doyon 19 ~ 55.10ft (Doyon 19 (36.1+19)) Site: Alpine CD4 North Referonce: True Well: Plan: CD4-208 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-208 Design? CD4-208wp06 Planned$urvey CD4208wp06 Map Map MD Inclinatbn Azimuth.. TVD SSTVD +Nt-S +E(-W Northtng EasUng DLSEV tft1 (°? C) tit) iftl {tt) 1~ lfU (ft) t•n0ofti / 14,183.99 93,35 334.13 6,159.10 6,104.00 5,515.49 -3,581.78 5,963,065.05 374,568.74 0.00 Target (Toe); 14184' MD, 6159' TVD, 2683' FNL & 3768' FEL; Sec13-T11 N-R04E - 4 1l2" Csg • 6 1/8" Hole -CD4-208wp05 T7 Vart 3actbn fftj 8,564.27 Geologic Taryeb Plan: CD4-208 TVD Target Name +NlS +EI-W Northing EasUng (~' -Shape /1: ft (tt) l~) 6,180.10 CD4-208wp05 TS 3,553.45 -2,809.84 5,981,087.99 375,486.65 - Point 6,159.10 CD4-208wp05 T7 5,515.49 -3,561.78 5,963,085.05 374,566.74 - Point 6,162.11 CD4-208wp05 T1 -682.78 -553.02 5,956,819.30 377,474.30 - Point 6,160.10 CD4-208wp05 T3 1,128.93 -1,434.37 5,858,644.92 376,622.53 - Point 6,250.10 CD4-208wp05 T2 53.16 -910.85 5,957,580.89 377,128.49 - Point 6,214.10 CD4-208wp05 T6 4,632.23 -3,133.40 5,962,175.03 374,980.70 - Point 6,246.10 CD4-208wp05 T4 2,205.73 -1,955.90 5,959,729.95 376,118.58 - Point Prognosed Geeing Pointe Measured Vertical Casing Hole Depth Depth Diameter Diameter {ft) lit) (") {") 2,600.47 2,443.00 9-5/8 12-1/4 7,200.88 6,153.00 7 8-3/4 14,183.98 8,159.10 4-1 /2 6-1/8 10/26/2005 2:12:47PM Page 8 of 9 ~; ~ ~ ~`~ 1 ~ ~ ~ ~ COMPASS 2003.11 Build 50 ~ • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4208 Wellbore: Plan: CD4-208 Design: CD4208wp06 Sperry Drilling Services HALLIBURTQN Planning Report -Geographic Sperry Drilling Services Local Go-ordinate Reference: Well Plan: CD4-208 - Sbt 8 TW Reference: Doyon 19 ~ 55.10ft (Doyon 19 (38.1+19?) MD'Reference: Doyon 19 ~ 55.10ft (Doyon 19 (38.1+19)) North Reference: True Survey Calculation Method: M~imum Curvature Prognosed Forrrration tntereection Polrrts Measured Depth Inclination Azimuth 1,647.29 27.82 172.76 2,323.56 27.82 172.76 2,557.62 27.82 172.76 2,964.67 27.82 172.76 4,150.78 27.82 172.76 4,442.50 27.82 172.76 4,560.68 25.69 174.56 6,440.86 51.70 327.62 7,247.67 83.47 333.89 Vertical Depth +NI-E +ET-W (R) (ft) (ft) Nam. 1,600.00 -260.23 62.56 Base Permafrost 2,188.10 -573.35 102.31 C-40 2,405.10 -681.72 116.06 C-30 2,765.10 -870.18 139.99 C-20 3,814.10 -1,419.36 209.71 K-3 4,072.10 -1,554.43 226.86 K-2 4,177.10 -1,608.24 233.30 K-2_Base 5,855.10 -1,353.08 -185.02 Albian 97 6,159.10 -708.70 -540.37 Top Nanuq (Albian 96) 10/26/2005 2:12:47PM Page 9 of 9 COMPASS 2003.11 Build 50 ~~ ( t ~..~ • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-208 Plan: CD4-208 CD4-208wp06 Anticollision Report 26 October, 2005 FfALL~BURTQN Sperry Drilling Services ~~~~{~l ~~. ~~.J ~. T`~ J y ~-` .~ HALLIBURTON Sperry Drllling Servless ;!~ , CW21J MVf27 \, 1 210 1 <D72of (wpM) COa1w 1<.v0e1 r.°m caow ro ^o ,a, - - ms _ _. Tr67elling C7linder Agimulh (TFO+AZII I°~ ss Centre to Cenlrc $epars6ion ~lO fUin~ Caution: 3.5' to tolerance line of CD4-207wp04 at 800' M~ 17.5' to tolerance line of CD4-210wp04 at 1280' 56.4' to tolerance line of CD4-209wp05 at 6445' Trn'ellulg s)'IinOer.uinwlh ITFO<AZII ~° s 1 (~19nn• m Crnlrc ti<par61i0n ~5 R(1~ SECTION DE7AII5 5« MD Ix Ari TVD +N/S +U-W DLeg TFu< VSc< Target 1 76.10 0.00 0.00 X.IO 0.00 0.00 0.00 0.00 0.011 2 700.00 0.00 0.00 [00.00 0.00 0.00 0.00 0.00 0.00 3 700.00 ).00 IS0.00 878.77 -20.36 11.76 3.00 1.70.00 47.K 1 1360.27 27.72 172.77 1323.00 -217.72 57.14 3.00 1121 -214.44 5 1503.57 27.62 172.7{ 1126.11 •1.78270 SNI.IS 0.00 0.00 -IIW.98 f 7277.77 86.61 3W.06 LIE211 -fei7t -511.02 1.00 160.03 -i16.p CD4208wp05 T1 7 731140 U.11 7N.p 71x.11 -Nf.ll -569.70 1.00 Ip.00 -217.76 t 7727.75 13.11 334.08 [239.73 -101.39 -&15.71 0.00 0.00 38.7.21 f t100.Of 70.00 334.01 [250.10 33.1E -)1045 1.00 -0.5i 537.11 CD4208wp05 T2 10 1217.50 74.78 331.05 6215.12 160.12 -76!.09 1.00 0.10 611.55 11 fIp.LO )1.78 331.05 fILS.Ot 1021 ~9 -1382.25 0.00 0.00 161f.p IS 7700.07 70.00 3N.16 [1{0.10 1128.73 -11;.1.17 1.00 178.K 1738.02 CD4-208wp05 Tl U (117.19 85.16 334.16 [1[4.60 1231.00 -1183.p 1.00 179.7] 1650.27 11 10386.St e3.K 331.16 Q11.60 2103.x -IfU6.J3 0.00 0.011 2810.10 IS 10177.81 70.00 )31.12 6246.10 2205.73 -1155.90 4.00 -0.4 2922.3E CDI-20Bwp05 T1 IL 10561.02 flA9 334.12 62J3A5 2284.15 -1991.75 I.W 0.00 7006.[5 17 IIf Il.15 77.19 ]34.12 {162.75 31]5.01 -2511.7tl 0.00 0.00 171 f.OL IB 1200046 N1.00 7N.11 7160.10 3553.45 -2609.64 1.00 -17).71 K05J5 CD4-208wp03 T5 If 12061.72 87.27 7N.I1 6161.73 KN.f3 -3637.E7 1.00 -177.77 /112.77 30 13132.39 f1.S] 331.11 6212A7 1570.7[ 4701.5] 0.00 0.00 552181 21 U300.11 70.00 337.13 [211.10 K322i 4131.10 4.00 0.33 5392.17 CD4208wpOS T6 22 Il2t1At 73.35 331.13 6211.65 6707.17 4169.72 1.00 0.00 5{75.71 B UW.ff 7345 331.13 [159.10 5515.N -)x1.76 0.00 0.00 [SN.27 CD4208w'p03n 10/26/2005 2:08 PM ConocoPhillips Alaska Company; ConocoPhiAips Alaska Inc. Protect: CdvAle River Unit Reference Si~• Alpine CD4 Site Error. O.OOft Reference Well: Plan: CD4-208 well Error: O.oOR Reference Wellbore' Plan: CD4208 Reference Design: CD4-208wp06 • Sperry Drilling Services Anticollision Repoli Locaft:ostt'dinate Ratirence; TVD Reference: MDReference: North Refsrerue: Survey Cakulatiort tiAethod: Output errors are at Database: Offset TitD RefKeru:e: ~ALLIBURTON Sperry Drilling Services Well Plan: CD4-208 -Slot 8 Doyon 19 ~ 55.10ft (Doyon 19 (36.1+19)) Doyon t9 ~ 55.10ft (Ooyon 19 (36.1+79)) True Minimum CtavaWre 1.00 sigma EDM 2003.11 Sktple User Db Offset Datum Reference CD4-208wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00(7 Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Umited by: Ma>amum center-center distance of 1,614.79(7 Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 10/28/2005 from Ta (tt) (ft) Survey (Wellbare) Tool Name Deaartpgan 38.10 800.00 CD4-208wp06 (Plan: CD4208) CB-GYRO-SS Camera based gyro single shot 800.00 14,183.99 CD4-206wp06 (Plan: CD4-208) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Surturtsry ReferalCe flfiset Corttro to Nodso Allowable Measured Measured ferrtre Distance Deviation Watzting $its tJams Drp>tti 'Depdt Distance - (ft).: Nom Plan Offset Web- Wetlb©-s. Destyn lff) (ff) (ff1 (ff) Alpine CD2 CD2-36 - CD 2-38 - CD 2-38 13,200.74 18,200.00 1,576.09 286.36 1,349.87 Pass -Major Risk CD2-36 -CD2-38 PB1 -CD2-36 PBt 14,162.41 14,725.00 1,330.87 302.58 1,083.86 Pass -Major Risk CD2-58 -CD2-58 -CD2-56 13,248.24 15,300.00 1,169.00 305.59 993.03 Pass -Major Risk Alpine CD4 Nanuq 5 -Nanuq 5 -Nanuq 5 1,695.84 1,675.00 83.40 38.89 50.40 Pass -Major Risk Nanuq 5 /Plan: CD4212 -Nanuq 5 -Nanuq 5 1,695.84 1,675.00 83.40 38.89 50.39 Pass -Major Risk Nanuq 5 /Plan: CD4212 -Plan: CD4212 - CD4-212 1,695.84 1,675.00 83.40 38.88 50.39 Pass -Major Risk Plant: CD4-203 -Plan: CD4-203 - CD4-203 (wp04) 449.99 450.00 100.87 9.38 91.50 Pass -Major Risk Plan: CD4-204 -Plan: CD4204 - C04-204 (wp04) 349.89 350.00 80.93 7.21 73.73 Pass -Major Risk Plan: CD4205 -Plan: CD4.205 - CD4-205 (wp04) 801.12 800.00 60.07 18.99 43.08 Pass -Major Risk Plan: CD4208 -Plan: C04-206 - CD4-206 (wp04) 124.97 125.00 41.31 2.32 38.99 Pass -Major Risk Plan: CD4-207 -Plan: CD4207 - CD4207 (wp04) 799.80 600.00 20.48 16.98 3.51 Pass - Maja Risk Plan: CD4209 -Plan: CD4209 - CD4209 (wp05) 699.61 700.00 21.00 14.93 8.07 Pass -Major Risk Plan: CD4-210 -Plan: CD4210 - CD4210 (wp04) 1,279.99 1,275.00 41.82 24.16 17.46 Pass -Major Risk Plan: CD4-211 -Plan: CD4211 - CD4-211 (wp04) 624.78 625.00 59.82 13.17 48.65 Pass -Major Risk Plan: CD4-213 -Plan: CD4213 - CD4-213 (wp03) 349.99 350.00 100.04 7.21 92.84 Pass -Major Risk Plan: CD4-214 -Plan: CD4-214 - CD4214 (wp03) 549.99 550.00 120.19 11.55 106.85 Pass -Major Risk Plan: CD4-215 -Plan: CD4215 - CD4-215 (wp03) 348.99 350.E 140.21 7.21 133.01 Pass -Major Risk Plant: CD4-218 -Plan: CD4216 - CD4216 (wp03) 669.82 675.00 155.36 14.28 141.08 Pass -Major Risk Plant: CD4-217 -Plan: CD4-217 - CD4.217 (wp02) 249.99 250.00 180.24 5.04 175.21 Pass -Major Risk Plan: CD4318 (Horizontal) -Plan: CD4-318 - CD4- 424.88 425.00 201.28 9.11 192.17 Pass -Major Risk Plan: CD4-318 (Horizontal) -Plan: CD4-318P61 - CD 424.88 425.00 201.28 9.11 192.17 Pass -Major Risk Plan: CD4319 -Plan: CD4-319 - CD4-319wp06 324.98 325.00 220.63 6.81 213.82 Pass -Major Risk Plan: CD4-320 (Horizontal) -Plan: CD4-320 - CD4- 474.76 475.00 241.47 10.07 231.40 Pass -Major Risk Alpine SatelYtes Nanuq 5 -Nanuq 5 -Nanuq 5 1,895.84 1,675.00 83.40 38.63 50.73 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/26/2005 1:33:OBPM Page 2 0/ 2 COMPASS 2003.11 Build 50 r Plan: CD4-208wp06 (Plan: CD4-208/Plan: CD4-208) 0 a ~`~ P ;~ ~ -~ 0 ,~ C y a .:_ U ~~-~ Measured Depth [ft] CD4-208wp06 CD2-36, CD 2-36, CD 2-36 V2 CD2-36, CD2-36 PBI, CD2-36 PBl Wt1- CD2-58, CD2-58, CD2-58 V 12 CD2-58, CD2-SSLI, CD2-58L1 V7 - Nang 5 / Plat CD4-212, Nang S, 1fm1R~5 VBlanp 5 / Plat CD4-212, Plat - Naup 5, Nauq 5, Nang 5 VO Nang 5, Naap 5, Nang 5 VO ~ Plat CD4-203. Plat CD4203, CD4-204. P9~: CD4-204. CD4•2E~R{avp041uVCD4-205. PIS: CD4.205. ~('D4-206. Plmc CD4-206, CD9siE~vp~QiNCD4-2(Y7. Ply: CD4-207, Plat CDZ•209, Plan: CD4209, CD42s?(wp~uVCD4-210, PFan: CD4-210, CD4~2tCtevpOq~nYCD4-21 I, Plat CD4-21 I, CD4-213, Plat CD4213, CD42tStavpO'~uHCD4214, Plat CD4-214, CD4+2f4tevp®pV~D4-215, Plat CD4-215, CD427S(t~~i1iCD4~216, Plaac CD4-216, Plat CD4-217, Plat CD4-217, CD4~}.77'[evp0'd~iCD4-318 (Haimntal~ PFac CDG~9'1'b, C0~+3t;~~¢QIB~IFiaiwMal), Plat Cb~1~lt6P~4E1H~3i8@Q~1-319, CD4779aep0&108: CD4.320 (Haiaonlal~ PFD: CD4-320, CD4-320wp04 VO 358000 360000 362000 364000 366000 368000 370000 Date Printed: October 18, 2005 Existing Wells Planned Wells _o 0 0 _~ L O 2 C CD4-3 374000 376000 378000 380000 CD4-31 ConocoPhillips Alaska Inc. Alpine Colville River Unit Alpine CD4 ConocoPhillips alaeka ""`'-"' ~`"N"~~ CD4-216 (wp0~D4-214 (wp043~ 366000 368000 370000 372000 374000 376000 378000 380000 382000 Fasting (4000 ft/in) I-204 (wp04) 4-320wp04 4-205 (wp04) wp04) ) (wp05) ~ ~ ~wp04) LPINE u • Oee oror E%AIxJm Yic. refs CaNNa WaYnll w.E cw-wa.yoa Ny IN/A wxxee lacvxon x vw]aa u r ]fnn]ea n C CM Ceneclion -p.f] ' lox xe RM/A Mepnefc DeAiwxon ]].S] • AEE xe /N/A ply; RD.f] ell xe. ~M/A peyxq yw IDD it fyxem (N D)Relersn<e. Original VS Plane: 326.00 rer.xlww: nxe:cw-]a View VS Plane: 326.00 Ea. x«ynE u.lo ] I -~-~CD4-208wp06 Pbn -+-~ Nanuq 3 -+-~ Nanuq 5 r---------` I ) Uni Y m erl bveG/ir5 sed~on rvsf Refe~<~~.. s~+ ~----- (Plan View ! < < . < .f . . < < < . e e e .. < < < < ...... ~ « . ~ . < mm mPmmN ~a~ w ~mmmmmmao ae m~mm mmaom~pmY NmmmmmDmmmmcom O ~ h W P O~ n n ~ '~ ~~ NI M~ t~•I ~~~ iy P P S A M P ~ ("pI M ~ 5976000 r - 5975000 5974000 . 5973000 -_L i 1 1__i__i i . ~ _ -~_ 1 i i._I_ J _r .l.J__ L i_1J__ L - s972oo0 - ~ I I I I I I I I I L I I I I I I I I I I I I I i--I- i 17--r r- r _I r- r t -1 -r t r-r -r-r r -t -r-r- 5971000 1__L.l_ _t _I-_l_ l- _l ._I L L 1-J__I_- l__l_ 1_a_L1--1 -J_l--. s97ooo0 ~{ I l l l l l l l i I I I I I I I I I I I I I I l- r l i 1---1- - - - - - 5969000 ~ T T ~ T i 1 f T T J r I T T T 1 T J_I_I-l _I__I_.I _J__, _ -I--.1 1 J--I-1 J- r-I__L L r-I__I-' 5968000 + I _I-_ I I I _I I I I I I_ I -_ I I I_ I__ I I I I_-1 - - 5967000 ~ , r~rrl rrr))rr))r IIrT I- +- I--r-1--t t-+ i--r- - - - - s966oo0 Z I I I I i r r I I 1_L1.1_1__L_L1_I I 11.J__L1.1.J_L I- s96sooo I I I I I I I I I I I I I 1 1 1 1 --r-I-rrt~--r-rrt-I coz-sue:, r-r-I--rtrt.~_r_ 5964000 L1.J_LL1J__L_L1J Da-zoawpoe 1J J__L11J_L- s963oo0 I I I I I I I r l l l I I I I I I I I 9 2000 T-i-1~1"-rT~~-"T"71 cDZ-se T-f ~-CT-f-1_r__ 5 6 1--1-I--~-~1~-1--1-1~.a__. L-1~-~-1-1-a-!•-- l 38 I I l l l I ' s961000 _ _ I 11 1 1 1 1 1 1 1 l i - _ 5960000 Section View i -+- NanE]q l -+- Nanuq 2 -+- CD2-36_Sag ~ ~ r"""E'"~"~ ~ CD2-58_Sag -+--CD2-SBLI Sag ~ T-1 I T-T~~rT~~ L 7-1 rT7-l i" ~-1-+-•-- ~-I--4-+-~ -I_~__F- - -+ ~-~++ ~-4-+ j ~:-1J_LL11_LL1JJ_L.. NanEp 3 • Nanlp t I. 1J_L11J_L1-. I I I I I I I I I I I 1 1 1 1 1 1 1 1 r-t-i--r t+~--t-t-t-1-1--r - t 1--r+-t-1-I-- 5959000 5958000 s9s7ooo '56000 '55000 '54000 '53000 '52000 '51000 '50000 '49000 '48000 '47000 L Q O 2 E a~ T 3642 4642 5642 6642 7642 8642 V 8 P ~ 8 1~ ~ ~ '~ 8 l? 8 8 (V 8 (off O (V [[~} ((~~ R [[-~~ f'l Q f~ ~O Q 1C S p0 ~ 8 V f~ ~ EV ~ ~ ~ ~ u F Page 1 d 1 (toolbox Pool.xls) 10281005 2:34 PM 0 • • -- ~_ ~ , . SHARON K. ALLSUP-DRAKE 11'16 CONOCOPHILLIPS ATO 1530 700 G ST. 1 ANCHORAGE AK 99501 oarE ~~~ w"~s2-1aj311 _ PAY TO THE ,~/ 1 ~~ ©r !~ ~ Jl~fi 1 / l K-[ ~ /~ V l.° ORDER OF ~~ ~~~'~ ~ iYC.~ DOLLARS L1 e.~ ~ ~ CHASE chase MaDhattaD Bank USA, N.A. V811d Up TO SOOO DOIIafS e ' 200 White Clay Center Dr, Newark. DE 19)11 MEMO --- ~ ~ ~:031L00144~:2L84 7 190 79 2 761I'iL16 a • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGRA.PHS TO BE INCLUDED IN TRANSMITTAL LETTER 1~IE ~' ~~-~ C-~ ~ G'-~~ WELL NAl PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as ' last two (2) digits a function of .the original API number stated are between 60-69) ~ above. PILOT HOLE In accordance with 20 AAC 25.005(f), all ~ (p)er records, data and logs acquired for the pilot i hole must be clearly differentiated in both ~ name (name on permit plus PH) and API number (50 - 70/80) from records, data and togs acquired for well (name on permit). i SPACIl~TG The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and Qroduce/infect is contingent ~ upon issuance of a conservation order ~ I approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. the d t itt b DRY DITCH o e m All dry ditch sample sets su SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost ~ or from where samples are first caught and 10' sample intervals through target zones. w ~/ Rev: 04/01/05 C\jody\transmittal_checklist ~~-~~zs ~ a~1`~~s ~j'h L~~{X 6-x-7 ~~Y •~ y(~ d~ v ~ ~?-~ ~~ ~ yl~. ~~ ~~~~ ~~~~~ s ;~~r~ `i !.~° ~~, ~~ // WELL PERMIT CHECKLIST Field & Pool Well Name: COLVILLE RIV UNIT CD4-208 Program SER Well bore seg ^ PTD1Z:2051620 Company ~ONOCOPHILLIPS ALASKA INC Initial ClasslType SER I PEND GeoArea _ Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattache_d_______________________ _________ _________Yes _--_-.-__ 2 Lease number appropriate_ - - _ - - - _ _ _ - Yes Surface Location and top. prod_ interval in ADL 380077; TD-in ADL 380075. - - - _ - _ _ 3 Uniquewell_nameandnumber_-__--___________________ __-__.--___Yes __-_--__-__-___-______--_- ~ 4 Well located in_a.defned_pool- - - - _ - - No- Located within _ro osed- Nanug Oil Pool; conservation order in ro ress. P -P p g 5 Well located p[operdiskanee-from drilling unit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - - - Conforms to_statewide_spacing_rules _ _ _ - _ . - - - - - - - - _ - - _ _ - _ _ - ..... _ - _ _ - _ _ - - - - _ - 6 Well located properdistance_fromotherwells__________________ ___________ Yes_ _____Conformsto-statewide_spacing-rules-______-____----_.______________-- ----------- 7 Sufficientacreageayailableindtillinqunrt____________________ _______--. Yes_ ____-__---_____--__-_--- --------------- 8 If deviated,is_wellboreplat-included_______________________ ____________ Yes- _____-._---_____ - 9 Operatoronly affected party - - - - - Yes 10 Operatorhas_appropriate_bondinfgrce_____________________ ______.__-Yes. _____--______..__-_ 11 Permit can be issued without conservation order Yes Appr Date 12 Pe[mitcanbeissuedwithoutadministrative_approval_____________ ________ ___Yes- -_---_________---______--_----__-_- ------------- SFD 11!1/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by-Injection Order # (put_1O# in_comments)-(For_ No_ - - - - - - -Area Injection Order currently in progress. -Injection operationsscheduled to begin 4th-Qtr_of 2006. - - _ - 15 All wells.within 114_mile area_of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - . - No other wells open to-proposed-pool within 114 mile.- _ _ _ _ _ - - - - _ . _ _ _ _ _ - - _ ----------- 16 Pre-produced injector duration of pre production less than 3 m4nths_(For service well only) No_ - _ - - . -Well will be flowed back for 5 -15 days for clean-up. _ _ - - - 17 ACMP_Finding of Consistency-has been issued fo[this project_ - - - _ _ - - _ - - NA- - ACMP consist_ency_determination no longer a factor in issuing permits_to drill, _ - - _ - -- - Engineering 18 Condu_ctorstringprovided__ _____________________ ____ ____--__---Yes_ -__ - - - 19 Surface casing_protectsall-knownUSDWs______----------- ------------ NA_- -_____Noaquifes,perA1O18ACOnclusion_3.____-----__-_______-.---.---_-______-_-__ 20 _C_MT_u_otadequate-tocirculate.oncond_uctor&surf_csg------------ ---------- -Yes_ ____._----_ __--__-----__--__--__-_-- __---_-__--_-_-__--_-_-_-__-.-- 21 _C_MT_u_ol_ adegu_ate_to tie-in long string to surf csg_ No_ Annular disposal maybe proposed. _All_hydrocarbon zones to be_covered. _ - .. - . - . - - 22 CMT_will coverall kno_wnpro_ductive horizons- - - - _ _ - - - - No_ - - - - - Slotted liner completion pl_anned._ - . - _ _ 1 23 Casing designsadeguateforC,T,B&-permafrost---- ----------- -___--_- .Yes_ _____-_--_______--.--_ 24 Adequate tankage-or reserve pit - _ _ _ - Yes - - ... -Rig is_equipped with st_eel_pits. -NO reserve-pitplanne_d, All waste to approved annulus or disposal well.- 25 If_a_re-drill,has_a_10-4.03 for abandonment been approved___________ ____________N_A__ ___-_-_----_____-__--_--__---_--_-----.__--__-_-__----__--____- ----_ ~i 26 Adequate wellboreseporation-proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ - _ . -Proximity analysis performed, Traveling cylinder path calculated, Gyros likely, - - _ _ - - _ _ _ _ _ .. _ _ - _ _ - - _ 27 Ifdiverterrequired,doesitmeetregulations ___________________ ___________Yes- _____-__---_______-----, - - Appr Date 28 Drilling fluid_program schematic & equip list adequate_ - - - - . - . - - - - Yes Maximum expected formation pressure 8.7-EMW.. MW up to 9,8_ppg in 8-314" hole and 8,8_ppg in_zone. - _ - - TM 111112005 29 BOPEs,-do they meetregu_lation________________________ ____-____Yes- _.._________-- __-________________---_____--_ - }~~ 30 BOPE_press rating appropriate; Pest to_(put psig in comments)- - - - _ - - Yes MASP calculated at 2169 psi._ 3500_psi_app[opriate. CPAI usually_tests to 5000-psi. - - 31 Choke manifold compliesw/API-RP-53 (_May 84) - Yes - - - - - - - 32 Work willoccurwithoutoperationshutdo_wn_______________ ____ _______-_ Yes- ---__-____ -- 33 Is presence_of H2Sgas-probable- No_ H2S was_not reported in_exploration wells. _Rig is equipped with sensors and_alarms._ _ - _ - 34 Mechanical_condition of wells within AOR verified (For service well only) _ - - Yes - There are no reservoir_penetrationstyithin 1!4 mile.. - - - - Geology 35 Permit_can be issued wlo- hydrogen_sulfide measures - - - - --- - - - - - - Yes - Initial seryice well in new reservoir. No H2S likely, but Drilling Hazards Summary indicates detection-system_ 36 _D_ata_presented onpate-ntial overpressure zones ...... . . . . . . . . . . .. . . Yes - - - - - Expected reservoirpressure is 8,7-ppg EMW; will be drilled with mud weight of 8.8 ppy, - _ _ _ _ - - - Appr Date 37 Seismic analysis of shallow qas-zones- - - - - _ _ - NA_ Multiple exploratory wells in area, Hydrates possible at base permaf[ost; mitigation measures discussed. SFD 111112005 138 Seabed condition survey (if off-shore) _ - _ _ _ _ - NA- _ - - - - - _ _ _ _ - - _ _ - _ _ , - - - - - - - - - - - - - - 39 Contact name/phone.for weekly progress_reports [exploratory only]_ NA_ _ - Geologic Commissioner: Engineering Date: Commissioner: Date o issi Date Initial service well for ro osed Nanu Oil Pool. Conservation Order and Area In ection Order are endin In ection P P q 1 P 9• 1 r operations may not begin until Area Injection Order has been approved. l v • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. A ~; Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 08 09:55:31 2006 Reel Header Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library ~'~~b~ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Field MWD/MAD LOGS WELL :[NAME: CD4-208 API NUMBER: 501032051700 OPERATOR: ConocoPhillips Alaska, Inc. LOGGI:[~G COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-MAR-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: W-0004084842 W-0004084842 W-0004084842 LOGGING ENGINEER: M. HANIK M. HANIK R. KRELL OPERATOR WITNESS: D. MICKEY D. MICKEY D. BURLEY MWD RUN 6 JOB NUMBER: W-0004084842 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: 2918 FSL: FEL: 206 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 55.15 GROUND LEVEL: 19.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS v~fjJ '1~ ~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2594.0 2ND STRING 6.125 7.000 7314.0 3RD STRING PRODUCTION STRING REMARKS: 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. THIS WELLBORE IS AN OPEN HOLE SIDETRACK, EXITING CD4-208 PB1 AT 10545'MD/ 6248'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,5,6 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 3,5,6. NO PROGRESS WAS MADE ON MWD RUN 4 6. 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. 7. MWD RUNS 1-3,5,6 REPRESENT WELL CD4-208 WITH API#: 50-103-20517-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12792'MD/6177'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.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2559.0 RPD 2580.0 RPS 2580.0 RPM 2580.0 FET 2580.0 RPX 2580.0 ROP 2605.5 all bit runs merged. STOP DEPTH 12735.0 12742.0 12742.0 12742.0 12742.0 12742.0 12792.5 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 2559.0 3 7324.0 5 10545.5 6 11554.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7324.0 10545.0 11554.0 12792.5 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 2559 12792.5 7675.75 20468 2559 12792.5 RPD MWD OHMM 0.37 2000 23.9395 20325 2580 12742 RPM MWD OHMM 0.08 2000 17.7819 20325 2580 12742 RPS MWD OHMM 0,48 2000 13.2558 20325 2580 12742 RPX MWD OHMM 0.48 2000 13.9581 20325 2580 12742 FET MWD HOUR 0.19 93.54 1.61518 20325 2580 12742 GR MWD API 31.91 175.03 90.408 20353 2559 12735 ROP MWD FT/H 2.15 433.48 127.09 20375 2605.5 12792.5 • • First Reading For Entire File..........2559 Last Reading For Entire File...........12792.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2559.0 7277.5 RPD 2580.0 7270.0 RPM 2580.0 7270.0 RPX 2580.0 7270.0 RPS 2580.0 7270.0 FET 2580.0 7270.0 ROP 2605.5 7324.0 LOG HEADER DATA DATE LOGGED: 07-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7324.0 TOP LOG INTERVAL (FT) 2605.0 BOTTOM LOG INTERVAL (FT) 7324.0 BIT ROTATING SPEED {RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 12.7 MAXIMUM ANGLE: 82.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESTS. 4 134758 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORREC'PION ( IN) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direct.ion .................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 2594.0 Fresh Water Gel 9.60 36.0 9.5 450 .0 2.500 72.0 1.390 134.6 4.500 72.0 4.000 72.0 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 2559 7324 4941.5 9531 2559 7324 RPD MWD020 OHMM 0.37 2000 13.2272 9381 2580 7270 RPM MWD020 OHMM 0.42 2000 8.04892 9381 2580 7270 RPS MWD020 OHMM 0.48 1757.65 5.96447 9381 2580 7270 RPX MWD020 OHMM 0.48 2000 6.18834 9381 2580 7270 FET MWD020 HOUR 0.19 51.14 1.1339 9381 2580 7270 GR MWD020 API 52.61 175.03 104.591 9438 2559 7277.5 ROP MWD020 FT/H 6.82 433.48 170.118 9438 2605.5 7324 First Reading For Entire File..........2559 Last Reading For :Entire File...........7324 File Trailer Service name .............STSLIB.002 • • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7270.5 10545.0 FET 7270.5 10545.0 RPM 7270.5 10545.0 RPD 7270.5 10545.0 RPS 7270.5 10545.0 GR 7278.0 10545.0 ROP 7324.5 10545.0 LOG HEADER DATA DATE LOGGED: 12-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MENfORY OR REAL-TIME): Memory TD DRILLER (F'I') 10545.0 TOP LOG INTERVAL (FT): 7324.0 BOTTOM LOG IN'T'ERVAL (FT) 10545.0 BIT ROTATING ~~PEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 81.1 MAXIMUM ANCrLE: 95.3 TOOL STRING ('T'OP TO BOTTOM) VENDOR TOOL, CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7314.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 102000 FLUID LOSS (C3) 1.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 149.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 ,0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam 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 7270.5 10545 8907.75 6550 7270.5 10545 RPD MWD030 OHMM 9.16 2000 42.1026 6550 7270.5 10545 RPM MWD030 OHMM 0.08 2000 31.2852 6550 7270.5 10545 RPS MWD030 OHMM 3.33 2000 20.1983 6550 7270.5 10545 RPX MWD030 OHMM 2.21 2000 21.1863 6550 7270.5 10545 FET MWD030 HOUR 0.33 62.21 1.86735 6550 7270.5 10545 GR MWD030 API 31.91 144.24 79.5381 6535 7278 10545 ROP MWD030 FT/H 14.82 199.97 103.03 6442 7324.5 10545 First Reading For Entire File..........7270.5 Last Reading For Entire File...........10545 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 • • Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10545.5 11503.5 FET 10545.5 11503.5 RPM 10545.5 11503.5 RPX 10545.5 11503.5 GR 10545.5 11496.5 RPD 10545.5 11503.5 ROP 10545.5 11554.0 LOG HEADER DATA DATE LOGGED: 16-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11554.0 TOP LOG INTERVAL (FT) 10545.0 BOTTOM LOG INTERVAL (FT) 11554.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7314.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 71.0 MUD PH: .0 MUD CHLORIDES (PPM): 102000 FLUID LOSS (C3) 1.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 142.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ........................ Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel L~ 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 10545.5 11554 11049.8 2018 10545.5 11554 RPD MWD050 OHMM 12.17 39.3 17.8575 1917 10545.5 11503.5 RPM MWD050 OHMM 11.11 40.37 17.1637 1917 10545.5 11503.5 RPS MWD050 OHMM 10.9 46.48 17.6585 1917 10545.5 11503.5 RPX MWD050 OHMM 10.26 58.9 19.2584 1917 10545.5 11503.5 FET MWD050 HOUR 0.34 93.54 1.32201 1917 10545.5 11503.5 GR MWD050 API 43.44 132.21 68.9463 1903 10545.5 11496.5 ROP MWD050 FT/H 2.15 314.08 68.9787 2018 10545.5 11554 First Reading For Entire File..........10545.5 Last Reading For Entire File...........11554 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... ~ i Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT; .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11497.0 12735.0 RPM 11504.0 12742.0 RPX 11504.0 12742.0 RPS 11504.0 12742.0 RPD 11504.0 12742.0 FET 11504.0 12742.0 ROP 11554.5 12792.5 LOG HEADER DATA DATE LOGGED: 19-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12792.0 TOP LOG INTERVAL (FT) 11554.0 BOTTOM LOG INTERVAL (FT) 12792.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7314.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S) 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 103500 FLUID LOSS (C3): 1.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 136.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11497 12792.5 12144.8 2592 11497 12792.5 RPD MWD060 OHMM 7.56 28.54 21.1877 2477 11504 12742 RPM MWD060 OHMM 6.57 27.51 19.4141 2477 11504 12742 RPS MWD060 OHMM 6.43 28.45 19.104 2477 11504 12742 RPX MWD060 OHMM 6.51 32.03 20.1686 2477 11504 12742 FET MWD060 HOUR 0.41 46.84 2.998 2477 11504 12742 GR MWD060 API 52.46 141.42 81.5337 2477 11497 12735 ROP MWD060 FT/H 10.19 138.79 73.0572 2477 11554.5 12792.5 First Reading For Entire File..........11497 Last Reading For Entire File...........12792.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Reel Trailer r~ ~~ Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File s L • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar OS 10:09:39 2006 Reel Header Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/03/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • ~ i~~ ~~i Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Colville River Field MWD/MAD LOGS WELL NAME: CD4-208 PB1 API NUMBER: 501032051770 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-MAR-06 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000408484 MW-000408484 LOGGING ENGINEER: M. HANIK M. HANIK OPERATOR WITNESS: D. MICKEY D. MICKEY SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: 2918 FSL: FEL: 206 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 55.15 GROUND LEVEL: 19.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2594.0 2ND STRING 6.125 7.000 7314.0 3RD STRING PRODUCTION STRING • ~ REMARKS: 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. THE MAIN CD4-208 WELLBORE EXITS FROM THIS WELLBORE AT 10545'MD/6248'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2 & 3 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 RUN 3. NO PROGRESS WAS MADE ON MWD RUN 4. 6. 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. 7. MWD RUNS 1-3 REPRESENT WELL CD4-208 PBl WITH API#: 50-103-20517-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12244'MD/6181'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.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH • GR 2559.0 12186.5 RPD 2580.0 12193.5 FET 2580.0 12193.5 RPS 2580.0 12193.5 RPM 2580.0 12193.5 RPX 2580.0 12193.5 ROP 2605.5 12244.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2559.0 7324.0 MWD 3 7324.0 12244.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2559 12244 7401.5 19371 2559 12244 RPD MWD OHMM 0.37 2000 24.4032 19228 2580 12193.5 RPM MWD OHMM 0.08 2000 17.8901 19228 2580 12193.5 RPS MWD OHMM 0.48 2000 12.9874 19228 2580 12193.5 RPX MWD OHMM 0.48 2000 13.5711 19228 2580 12193.5 FET MWD HOUR 0.19 62.21 1.3309 19228 2580 12193.5 GR MWD API 31.91 1 75.03 92.3602 19256 2559 12186.5 ROP MWD FT/H 6.82 4 33.48 133.891 19278 2605.5 12244 First Reading For Entire File..........2559 Last Reading For Entire File...........12244 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 • • Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03j08 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 2559.0 7277.5 FET 2580.0 7270.0 RPX 2580.0 7270.0 RPS 2580.0 7270.0 RPM 2580.0 7270.0 RPD 2580.0 7270.0 ROP 2605.5 7324.0 LOG HEADER DATA DATE LOGGED: 07-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7324.0 TOP LOG INTERVAL (FT) 2605.0 BOTTOM LOG INTERVAL (FT) 7324.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 12.7 MAXIMUM ANGLE: 82.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 134758 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2594,0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 36.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) .0 • RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.500 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.390 134.6 MUD FILTRATE AT MT: 4.500 72.0 MUD CAKE AT MT: 4.000 72.0 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 N sam 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 2559 7324 4941.5 9531 2559 7324 RPD MWD020 OHMM 0.37 2000 13.2272 9381 2580 7270 RPM MWD020 OHMM 0.42 2000 8.04892 9381 2580 7270 RPS MWD020 OHMM 0.48 1757.65 5.96447 9381 2580 7270 RPX MWD020 OHMM 0.48 2000 6.18834 9381 2580 7270 FET MWD020 HOUR 0.19 51.14 1.1339 9381 2580 7270 GR MWD020 API 52.61 175.03 104.591 9438 2559 7277.5 ROP MWD020 FT/H 6.82 433.48 170.118 9438 2605.5 7324 First Reading For Entire File..........2559 Last Reading For Entire File...........7324 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 • • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7270.5 12193.5 RPD 7270.5 12193.5 RPM 7270.5 12193.5 FET 7270.5 12193.5 RPS 7270.5 12193.5 GR 7278.0 12186.5 ROP 7324.5 12244.0 LOG HEADER DATA DATE LOGGED: 12-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12244.0 TOP LOG INTERVAL (FT) 7324.0 BOTTOM LOG INTERVAL (FT) 12244.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.1 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7314.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 102000 FLUID LOSS (C3) 1.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 149.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL • MATRIX: MATRIX DENSITY: HOLE CORRECTION (TN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7270.5 12244 9757.25 9948 7270.5 12244 RPD MWD030 OHMM 7.17 2000 35.0503 9847 7270.5 12193.5 RPM MWD030 OHMM 0.08 2000 27.2656 9847 7270.5 12193.5 RPS MWD030 OHMM 3.33 2000 19.6779 9847 7270.5 12193.5 RPX MWD030 OHMM 2.21 2000 20.6046 9847 7270.5 12193.5 FET MWD030 HOUR 0.33 62.21 1.51858 9847 7270.5 12193.5 GR MWD030 API 31.91 1 44.24 80.6029 9818 7278 12186.5 ROP MWD030 FT/H 14.82 1 99.97 99.1449 9840 7324.5 12244 First Reading For Entire File..........7270.5 Last Reading For Entire File...........12244 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06j03/08 Origin ...................STS Tape Name ................UNKNOWN J ~ ~' Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/03/08 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
