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205-068
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~~ Well History File Identifier Organizing (done> ^ Two-sided lil Il~litlltfl I~III ^ Rescan Needed ~II (I~IIIII~I IIIIlI RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria - ,_ Project Proofing BY: Maria i, Scanning Preparation BY: Maria Production Scanning Stage 7 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: ~' / ~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /S, ~, P NO "iuiuiiumiim ReScanned BY: Maria Date: /s/ Comments about this file: DIGITAL DATA iskettes, No. f~.. ^ Other, No/Type: Date: ~ I OVERSIZED (Non-Scannable) ^ Logs of various kinds: Date: ' ~ ~ a OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Other:: w~P iuiuiiiuuiiiu rt, W~ p • ~ x 30 = j ~o + ~ ~f T__ =TOTAL PAGES I ~ ^- I ~ ~ (Count does not include cover sheet) Date: Ci~ /s/ a~, ~~~.e«~ uiimiimoiim 10/6/2005 Well History File Gover Page.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: CD2-60 Run Date: 9/25/2009 January 5, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-60 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20511-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto ~0~~ 6 6900 Arctic Blvd. ~ ~~ ~ Anchorage, Alaska 99~ 18 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto(~.halliburton;com ; - ~~ _ /I ~~ Date: - Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil Gas SPLUG Plugged Abandoned Q Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WAG WDSPL Other No. of Completions: Service El Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number. ConocoPhillips Alaska, Inc. or Aband.: September 30, 2009 205 068 309 343 309 282 309 292 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 0360 June 8, 2005 50 103 20511 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2162' FNL, 1491' FEL, Sec. 2, T11 N, R4E, UM July 6, 2005 CD2 60 0 Top of Productive Horizon: 8. KB (ft above MSL): 52.4' RKB 15. Field /Pool(s): 2419' FSL, 1589' FWL, Sec. 14, T11 N, R4E, UM GL (ft above MSL): 15.9' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD TVD): 1472' FNL, 1447' FEL, Sec. 23, T11 N, R4E, UM 14275' MD 7374' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 1 Total Depth (MD TVD): 16. Property Designation: Surface: x 371743 y 5974194 Zone 4 18695' MD 7375' TVD ADL 380075, 380077 TPI: x 369362 y 5962976 Zone 4 1,1. SSSV Depth (MD TVD): 17. Land Use Permit: Total Depth: x 371542 y 5959047 Zone 4 nipple 2317' MD 1909' TVD 380075 18. Directional Survey: Yes No El 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) 1847' MD 1647' 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 not applicable 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" 62.5# H-40 36.7' 114' 36.7' 114' 42" pre installed 9.625" 36# J -55 36.7' 3276' 36.7' 2373' 12.25" 550 sx AS Lite, 241 sx Class G 7" 26# L -80 36.7' 14331' 36.7' 7379' 8.5" 315 sx Class G 24. Open to production or injection? Yes No gi 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) NOV 2 6r wp 4.5" 13104' 13033' MD 7035' TVD 5LA N N O Y 7 2009 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 14275' 30 bbls 15.8 ppg Class G RECEIVED 27. PRODUCTION TEST NOV 1 3 2UU9 Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Alaska Oil Gas Cons. Commission Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE *t1 orage GAS RATIO Test Period Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY API (corr) Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? Yes No i0 Sidewall Cores Acquired? Yes No iig If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 7/2009 CONTINUED Oly, Q 2009 Submi iginal only z5 7‘ Il,, 6 1!s/ 28. GEOLOGIC MARKERS (List all formations and markers 'countered): 29. FORMATION TESTS NAME MD TVD Well tested? 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 1847' 1647' needed, and submit detailed test information per 20 AAC 25.071. Top Alpine D 13992' 7310' Top Alpine C 14197' 7365' Base Alpine C 18592' 7384' N/A Formation at total depth: Alpine A 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Robertson 265 Printed Name A G. L. Alvord Title: Alaska Drilling Manager )l Signature Phone 7i (t Date ,f "off f2-0d C• prepared by: 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 7/2009 1 ConocoPhillips Alaska, Inc. ALPINE CD2 -60 CD2 -60 11 (0-13104, 0 a 10 SSSV Type: API Well�pe:' INJ Angle 0 TS: deq (a9 TUBING WRDP Ong Completion: 7/10/2005 Angle TD: 95 deg 18695 ID:3.958) Annular Fluid: Last WiO Rev Reason: Set INJ VLV Reference Lo.: Ref Log Date Last Update: 2/24/2008 Last Tag: TD 18695 ftKB °RODUCTION (0 14331, Last Tag Date: Max Hole Angle: 95 deg :a: 18268 00:7.000, 0 Casing Stdee ALL STRINGS Wt:26.00) Description Size Top Bottom TVD Wt Grade Thread SURFACE CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED (0-3276, S URFACE 9.625 0 3276 I 237 36.00 J -55 BTC OD:9.625, I Wt:36.00) P RODUCTION 7.000 0 14331 7378 26.00 L BTCM OPEN HOLE 6.125 14331 18695 18695 0.00 Tubing String TUBING Size Top Bottom TVD Wt Grade Thread 4. 500 0 13104 7064 12.60 L 80 IBTM Gas Lift Mandrels /Valves St I MD I TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt Gas Lift 1 8641 4963 CAMCO KBG -2 DMY 1.0 BK -5 0.000 I �08 /27/2006, andrel/Dummy Valve/ Other (plugs, equip., etc.) COMPLETION (8641-8642, Depth TVD Type Description ID 00:5.984) 0 0 PUP 33' PUP 3.958 2317 1909 NIP CAMCO 'DB' NIPPLE 3.812 2317 1909 VALVE 4.5" A -1 INJECTION VALVE (HWS -0443) ON DB LOCK set 8/16/2007 1 -250 13033 7035 PACKER r BAKER PREMIER PACKER 3.875 13092 7059 NIP HALLIBURTON'XN' NIPPLE 3.725 1.3103 7063 WLEG WIRELINE GUIDE 3.875 PACKER 1 ;13033- 13034, OD:5.970) NIP ;13092- 13093, I OD:5.000) WLEG ;13103- 13104, OD:5.000) I I 1 OPEN HOLE 1 ;14331- 18695, OD:6.125) I1 1 l CD2 -60 Plug Operations DATE SUMMARY 8/14/09 GAUGED TBG TO 3.885" TO A -1 INJ VALVE 2317' RKB; PULLED INJ VAL. GAUGED TBG TO 3.78" TO XN NIPPLE 13092' RKB. READY FOR E /L. 8/19/09 STAND -BY ELINE CREW FOR CHEMICAL CUTTERS TO BE TRANSPORTED FROM DEADHORSE TO ALPINE. 8/29/09 MEASURED BHP 13,092' RKB: 3793 PSI. DRIFTED TUBING TO 13,092' RKB W/ 23' x 2.81" BARBELL ASSY. IN PROGRESS. 8/29/09 STAND -BY AND FREIGHT CHARGES FOR HES CHEM CUTTER SPECIALIST AND MATERIALS BROUGHT TO DEADHORSE FOR CHEMICAL CUT 8/31/09 SET BOTTOM BAKER SPACER ASSY. (26' 2" OAL) IN XN NIPPLE 13,092' RKB. SET TOP BAKER SPACER ASSY. (26' 2" OAL, PHOTOS ATTACHED TO WSR) ON BOTTOM SPACER 13,053' SLM. WELL IS READY FOR CTU. 9/5/09 RUN BAKER DB CUTTER STACK OUT ON SPACER ASSEMBLY Y 13069' CTMD. GOOD MOTOR WORK, RAN CUTTER FOR ONE HOUR WHILE TAKING RETURNS TO CD2 -42. COIL HUNG UP 1331' CTMD WHILE POOH. UNABLE TO GO UP OR DOWN. LOST CIRCULATION DOWN COIL AND UNABLE TO PUMP DOWN WELL. SHEARED SHEAR OUT DISC, HAD CIRCULATION FOR APPDX 5 BBLS AT A RATE OF .5 BPM 4500 PSI BUT LOST CIRCULATION. BLED DOWN GAS CAP ON IA PUMPED 45 BBLS OF HOT DIESEL. COIL STILL STUCK W/ NO CIRCULATION. IN PROGRESS. 9/6/09 WSR CONTINUED FROM 9/05/09. ATTEMPT TO FREE UP COIL FROM 1330' CTMD, NO SUCCESS. UNIT ON DRY WATCH FOR THE NIGHT. IN PROGRESS. 9/7/09 CUT COIL AT SURFACE AND DROP BALL TO DISCONNECT. PRESSURE UP WHILE PULLING TENSION ON COIL AND UNABLE TO CIRCULATE OR DISCONNECT OUT OF BHA AT 1330'. RU HES ELINE TO CUT COIL. IN PROGRESS. f i 9/7/09 PREP CREW AND EQUIPMENT FOR RCT AT ALPINE. MOBILIZE PERSONNEL TO ALPINE AND CHECK EQUIPMENT. 9/8/09 RIH W /HES E -LINE AND MADE FOUR CUTS. CUT 1 (1272') CUT 2 (1226') CUT 3 (1178') AND CUT 4 (1000') WAS ABLE TO CIRCULATE AFTER CUT #4. GET COIL ROLLED BACK TOGETHER TO PULL 1000' OF COIL OUT, BUT PIPE DID NOT COME FREE. APPARENTLY CUT 4 MADE A HOLE IN THE PIPE BUT DID NOT CUT IT. IN PROGRESS. 9/8/09 PERFORMED RCT SERVICE TO CUT STUCK COIL TUBING AT 1268', 1226', 1178' AND 1000'. 9/9/09 CIRCULATE METHANOL FROM CIR POINT (1000') TO SURFACE. LET METHANOL SOAK APPLY PRESSURE AGAINST IT. CYCLE PIPE WITH NO MOVEMENT. START CIRCULATING HOT SEAWATER, IN PROGRESS. 9/10/09 CIRCULATED 1000 BBLS OF HOT SEAWATER DOWN COIL TAKING RETURNS TO OPEN TOP TANKS. FLUSH COIL WELL W/ DIESEL METHANOL. CUT COLD ROLL INSTALLED TIW VALVE XO's FOR E -LINE TO STAB ON. READY TO RUN CUTTER DOWN COIL BUT CUTTERS DID NOT MAKE IT TO ALPINE DUE TO HEAVY FOG. DRY WATCHING UNIT, IN PROGRESS. 9/10/09 STAND BY ON EQUIPMENT RCT) TO ARRIVE TO ALPINE FOR CD2 -60 9/I1/09,E -LINE CUT COIL. RECOVERED 1042' OF COIL. RIH W/ WASH TOOL ASSEMBLY TO TOP OF BHA 1302' CTMD. PUMPING HOT (155 DEG) SEAWATER JETTING ON BHA FISH. IN PROGRESS. 9/11/09 RIG UP WIRELINE EQUIPMENT. PU AND RIH WITH 1" RADIAL CUTTING TORCH AND CUT COIL TUBING 999.5 FEET /.5' HIGHER THAN HOLES MADE PREVIOUSLY BY RCT 1000' 9/12/09 JETTING ON FISH W/ HOT SEAWATER A TOTAL OF 6 HOURS. CIRCULATED 75 BBLS OF METHANOL. USED SLICKLINE TO BAIT COIL STUB. RECOVERED AN ESTIMATED 270' OF COIL. ESTIMATE 4' OF COIL ON TOP OF BHA STILL IN THE HOLE. STRIPPING OFF RECOVERED PIPE OFF OF SPOOL, IN PROGRESS. 9/12/09 RAN 3.65" LIB TAGGED COIL STUB 1019' SLM, COIL TUBING ON HIGH SIDE OF TBG, SET 3.625" BAKER OVERSHOT ON COIL STUB 1019' SLM. READY FOR COIL. CD2 -60 Plug Operations 9/13/09 RECOVERED 4' COIL STUB BAKER DB UNDER REAMING FISH FROM 1•CTMD. NOTE: ONLY 1 OF 2 (5/8 BALL RECOVERED IN THE FISH. REMOVE ICE PLUG FROM 1825' CTMD TO 3816' CTMD. LEFT WELL SHUT IN AND FREEZE PROTECTED WITH METHANOL AND SLICK DIESEL DOWN TO 4362' CTMD /3500 TVD.WELL READY FOR SLICK -LINE. 9/14/09 PULLED TWO 26' BAKER SPACER ASS'Y 13092' RKB. DID NOT RECOVER 5/8" BALL. READY FOR E -LINE. 9/14/09 PU AND RUN IN HOLE WITH TUBING PUNCH 2' CARRIER, 2' LOAD 4 SHOT PER FOOT(8 HOLES BY .52 ENTRY) AND CORRELATE. PERFORATE THEI-IRSTFULL JOINT OF TUBING ABOVE THE PACKER. SHOT DEPTH OF 13016 13018'. 9/18/09 LOGGED CALIPER SURVEY FROM 13139' TO 12850' RKB. GOOD DATA. IN PROGRESS. 9/19/09 MEASURED BHP 13092' RKB: 3657 PSI. COMPLETE. 9/23/09 RIH WITH 2- 15/16" RADIAL CUTTING TORCH, CORRELATED TO TUBING DETAIL, CUT TUBING AT 13000'. (3 ALPINE CREW DAYS 9/23 9/25) S ConocoPhillips Time Log Summary Wellview Web Reporting Report Well Name: CD2 60 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 9/10/2009 12:00:00 PM Rig Release: 9/13/2009 3:00:00 PM Time Logs. Date From To Dur S. Depth E. Depth Phase Code Subcode .T Comment 09/10/2009 24 hr Summary Rig Maintenance while next well being prepared 12:00 00:00 12.00 SITEP RIGMNT RGRP P Rig Maintenance Inspect check #1 Mud pump bearings, Clean Paint Top drive, Clean Prep Iron Roughneck f/ repairs, Rig Test all 2" hoses to 5000 psi f/ 10 min 09/11/2009 Rig Maintenance 00:00 12:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance inspect MP #1 check bearing clearence Cont. clean paint TD Cont. clean paint iron ruffneck Cont. pressure test 2" high pressure hoses 12:00 00:00 12.00 SITEP RIGMNT RGRP P Continue rig maintenance, Change out Iron roughneck jaw, Work on Boiler, Paint top drive, Work on replacing old section of chain on skate, Adjust service loop, Remove rotary table cover to repair lock pins, Mud pump mainteance, Inspect drag chain 09/12/2009 00:00 12:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance Paint TD work on tbg PM on mud pumps(chnage out valves seats) Work on iron ruffneck finish replacing chain on pipe skate 12:00 00:00 12.00 SITEP RIGMNT RGRP P Cont. rig maintenance, Flush Change oil in rotary table Gear box, Install lock pins f/ rotary table, Continue welding projects, Install covers on rotary table, remove drawworks gaurds and change out grease line fittings, Continue mud pump work, Install Iron roughneck on tracks 09/13/2009 Rig maintenance Released rig f/ maintenance 1500 hrs. 9/13/09 Prep for move to CD2-48 WO 00:00 15:00 15.00 SITEP RIGMNT SVRG P Finish up rig maintenance P/M on mud pumps Scrub paint pit room Paint mud manifold finish service on rotary table Prep rig for move to CD2 -48 WO 09/22/2009 Begin rig move f/ CD2 -56 Page 1 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 MIRU MOVE MOB P Blow down water steam lines Cut high line power Prep to move pit/motor complex 09/23/2009 Move in rig up Clean pits take on 10.6 ppg CaCl2 brine RU to kill well PJSM on killing well Kill well pumping 35 bbls hi -vis CaCl2 10.6 ppg followed by 200 bbls CaCl2 to fill tbg Shut in monitor pressure Cont. with well kill pumping 240 bbls 10.6 ppg CaCl2 obtain sample btms up 8.0 ppg Cont. pumping 150 bbls obseverd 10.5 ppg sample 90 bbls pumped of the additional 150 bbls.- Shut in monitor pressure SIDPP 180 SICp 180 psi (lost appriox 132 bbls fluid during well kill) performed s series of bleed monitor pressure until well was dead (Modified exhale test) 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Move out Pit Motor complexes skid rig on subbase back sub off of well 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Swap well gaurds from CD2 -57 to CD2- 59 Install Drillers side wind wall back onto sub 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Move rig to CD2 -60L1 center rig over well Skid rig to drill position spot up Pit Motor Complexes Move in pipe shed 05:00 06:00 1.00 0 0 MIRU MOVE RURD P Connect Steam, air and water service lines Highline power on 0600 hrs. Accepted rig 0600 hours. 06:00 10:30 4.50 0 0 MIRU MOVE RURD P Clean Pits 3,5, &6 Load CACL Brine in pits Install temperary windwall in cellar Tested rig gas detectors Electrician Drill site Operator confirmed rig ESD working. 10:30 11:30 1.00 0 0 MIRU WELLPFOTHR P RU and test FMC Lubricator 250/2000 psi Pull BPV RD Lubricator SITP =1150 psi IA pressure 650 psi 11:30 13:00 1.50 0 0 MIRU WELLPF RURD P RU hardlines, hoses and manifold for well kill operations Condition CACL brine in pits to 10.6 ppg Mixed 35 bbl high vis spacer w/ 10.6 ppg brine 13:00 13:15 0.25 0 0 SLOT WELLPF SFTY P Held PreJob safety and Opts meeting on planned well kill procedures Drill Site Operator advised of up coming operations 13:15 13:30 0.25 0 0 SLOT WELLPF PRTS P Fill lines pressure test to 2500 psi Good test 1 Page 2 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 00:00 10.50 0 0 SLOT WELLPF KLWL P Pumped kill weight fluid (10.6 ppg CaCl2) ICP 1100 psi 35 bbls hi -vis pill followed by 200 bbls 10.6 ppg 3 bbls /min to fill tbg to shot holes 13,017' Shut in well monitor pressure SIDPP 0 SICP 940 psi all returns outside to tiger tank Cont. circ btms up f/ 13,017' (240 bbls) Shut down shut in well monitor pressure SIDPP 180 psi SICP 400 psi Sample of return fliud wt. 8.0 ppg Lost approx. 100 bbls fluid to well while circulating Open well circ 150 bbls 2 bbls /min observed 10.5 ppg in sample taken 90 bbls pumped Shut down shut in well monitor pressure SIDPP 180 psi SICP 180 psi Lost approx. 32 bbls lost total of approx. 132 bbls during kill) Preformed a series of bleed monitor pressure Bleed #1 bled annulus pressure down to 40 psi Shut in well SIDPP 80 psi SICP 40 psi after 20 mins. SIDPP 140 psi SICP 120 psi Bleed 2 Bled 2 bbls from annulus took 6 mins to bleed Shut in well SIDPP 40 psi SICP 30 psi after 20 mins. SIDPP 100 psi SICP 80 psi Bleed #3 bled 2 bbls from annulus took 8 mins to bleed Shut in well SIDPP 20 psi SICP 20 psi after 25 mins. SIDPP 40 psi SICP 60 psi Bleed #4 bled 2 bbls form annulus took 12 1/2 mins to bleed shut in SIDPP 20 psi SICP 0 after 2 hrs. SIDPP 0 SICP 0 09/24/2009 Finish BOPE test RD Pull BVP MU landing jt. into hanger Back out lock down pulled to 125K 1/2" movement worked tubing hanger to 125k pumped oil into void between tubing hanger seals wrapped and steamed wellhead pulled on string hanger began moving out of wellhead with 180K on wt. indicator Work pipe attempting to pull packer free working up to 260 k monitoring well on trip tank while working pipe static losses 6 bbls /hr. shut off hole fill pump Observed gas breaking out of brine well began to flow began to circ btms up gas break out increasing shut in well Circ btms up through choke 2 bbls /min 400 is (added lubes to brine) shut down pump open well observed flow 12 momitor well flow P P p P dropped off to 2% worked pipe pulling up to 260 k still unable to pull packer free Observed well well still flowing 2 Shut in well performed exhale test 00:00 01:00 1.00 0 0 SLOT WHDBO OWFF P Monitor well SITP =0 SICP =O Open return line to pits check for flow Well dead Blow down and rig down Lines and manifold 01:00 01:30 0.50 0 0 SLOT WHDBO RURD P RU FMC lubricator and Pull BPV Rig Down lubricator 01:30 03:00 1.50 0 0 SLOT WHDBO NUND P PJSM Remove tree inspect ACME threads Install Blanking plug in hanger 03:00 04:30 1.50 0 0 SLOT WHDBO NUND P NU BOP Stack flow nipple and flowline Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment n 04:30 12:00 7.50 0 0 SLOT WHDBO BOPE P RU and test BOPE Annular tip? Preventor 250/2500 Rams, choke, L� kill, manifold TD, and floor safety valves 2 psi Perform a es 50 3500 ps Accumulator test Chuck Scheve AOGCC waived witnessing tests. Choke manifold valves 8 3 failed low pressure tests. Changed out gates and seats retested valves, good tests. 12:00 13:00 1.00 0 0 SLOT WHDBO BOPE P LD landing joint and blanking plug blow down choke and kill lines Pull BPV 13:00 16:15 3.25 0 0 SLOT WELLPF PULL P Engage tubing hanger with landing joint(a) xo to top drive Back Out Lock Down Studs pulled to 125K 1/2" movement worked tubing hanger to 125k rechecked lock down studs, ok pumped oil into void between tubing hanger seals wrapped and steamed wellhead pulled on string hanger began moving out of wellhead with 180K on wt. indicator Page 4 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 00:00 7.75 0 0 SLOT WELLPF PULL P ork i e attempting to pull packer pp P 9 P P free working up to 260 k monitoring well on trip tank while working pipe static losses 6 bbls /hr. shut off hole fill pump Observed gas breaking out of brine well began to flow began to circ btms up gas break out increasing shut in well Circ btms up through choke 2 bbls /min 400 pis (added lubes to brine) shut down pump open well observed flow 12 momitor well flow dropped off to 2% worked pipe pulling up to 260 k still unable to pull packer free Observed well well still flowing 2 Shut in well performed exhale test ISIDDP 80 psi ISICP 85 psi monitor pressure for 1 hr. DPP 60 psi CP 55 psi Open choke bled off 3 bbls Shut in well ISIDPP 20 psi ISICP 0 psi monitor pressure for 30 mins.- DP 30 psi CP 25 psi Open choke bled off 3 bbls. ISIDPP 20 psi ISICP 0 psi Monitor pressure for 30 mins. DP 20 psi CP 0 psi Open well observed slight flow fluid level began to drop slowly Prep to monitor on TT work pipe Note- Hole took 55 bbls static losses while working pipe 55 bbls while circ btms up Gained 12 bbls while working pipe after cicr btms up Got 9 bbls back during exhale test total losses to well 89 bbls 09/25/2009 Conduct exhale test. Bled pressure to 0 psi. Open well, observe gas breaking out w /slight flow. Flow quit observed well on TT and worked pipe to 260 K RU Halliburton E -line RIH cut tbg 13,000' POOH RD wireline MU landing joint into tbg hanger Pull LD tbg hanger 249 jts 4 1/2" tbg Gas lift mandrel assembly DB nipple 00:00 03:00 3.00 0 0 SLOT WELLPF OWFF P Conduct exhale test. Bled pressure to 0 psi. Open well, observe gas breaking out of slight flow. Flow quit static loss, observed well on TT and worked pipe to 160K no movement packer 03:00 11:15 8.25 0 0 SLOT WELLPF CPBO P Held PJSM, RU Halliburton E -line pressure test lubricator to 500 psi RIH w/ Radial torch Cutter made corrilation passes put cutter on depth Cut tubing A13,000' MD. Monitor well on trip tank throughout static losses 3-4 BPH. POOH w/ E -line RD wireline equipment LD lubricator clear tools from rig floor Page 5 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:00 0.75 0 0 SLOT WELLPF PULL P PU landing joint A and engaged hanger Back Out Lock Down Studs Pulled hanger and confirmed tubing cut 200 K PUW. Monitor well and observed static loss of 3 BPH. Landed hanger Break out top drive and laid down xo, floor safety valve pup joint SOW =125k. Pull hanger to floor and Laid down tubing hanger and landing joint Monitor well static losses of —4 bph observed 12:00 12:15 0.25 13,000 13,000 SLOT WELLPF SFTY P PJSM on laying down tubing 12:15 00:00 11.75 13,000 2,157 SLOT WELLPF PULL P Pull out of hole w/ 4 1/2" tbg laid down 249 jts plus GLM assembly DB nipple (10,843') Note Hole still taking fluid lost 95 bbls last 24 hrs.( 26 bbls static 69 bbls on trip out w/ tbg) Total losses to date 290 bbls 09/26/2009 Finish pulling laying 4 1/2" tbg 299 jts plus cut off jt.- RU test Hydrill to 250 2500 psi VBR's to 250 3500 psi w/ 4" test jt.- MU fishing assembly 1 RIH Tag top of fish 12,998' work over fish to 13,006' Jar on packer (no movement on packer) Attempt to release grapple f/ fish unable to release work pipe appears that packer is moving up hole 00:00 02:30 2.50 2,157 0 SLOT WELLPF PULL P Continue to POOH laying down tubing All fish accounted for Cutoff joint 19.35' ETOF 12,998' Rig down tubing equipment clean rig floor 02:30 03:30 1.00 0 0 SLOT WHDBO BOPE P Install test plug and 4" test joint Tested Annular Preventor 250/2500 psi Upper and Lower VBR's 250/3500 Pull test plug Set wear ring 03:30 05:30 2.00 0 282 SLOT FISH PULD P MU Fishing BHA #1 Dressoff shoe, bushing, 5 3/4" overshot ext., 5 3/4" C cs\f■ Overshot dressed w/ 4.5" spiral grapple, 4 3/4" Bumper sub, m4 3/4" jar, (8) 4 3/4" DC's, Accelerator, XO W 05:30 14:15 8.75 282 12,900 SLOT FISH TRIP P Pick up 21 joints of 4" drill pipe from shed RIH to 12,900' slow last 30' of each stand due to fluid running over drill pipe 14:15 15:15 1.00 12,900 13,006 SLOT FISH FISH P Lay down 2 joints of drill pipe Establish ccirculation 1.5 bpm 140 psi PUW 255K SOW 137K ROT wt. 185K RIH tagged TOF 12,997 Work over fish to 13,006' 15:15 18:15 3.00 13,006 13,006 SLOT FISH FISH P Jar on fish staged up from jarring .275K and pulling to 330K to jarring 350K and pulling to 390K no movement of packer 18:15 00:00 5.75 13,006 12,991 SLOT FISH FISH P Attempt to release grapple f/ fish Unable to release working pipe appears fish is moving up hole continue to work jar pipe Page 6 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/27/2009 24 hr Summary Worked fish free POOH laid down fish recovered remainder of completion string (Note left slips, slip housings and all seal elements on packer in hole) MU clean out assembly Cut slip drill line RIH w/ clean out assembly to 6792' 00:00 02:15 2.25 12,991 12,991 SLOT FISH TRIP P Continue to work pipe fish moving up hole PUW 268K SOW 135K flow check well, slight static loss 2 bph 02:15 10:45 8.50 12,991 282 SLOT FISH TRIP P POOH on elevators from 12,991' to 282' Worked through tight spot 5848' Flow check well 8292' 282' observed slight static losses 10:45 15:00 4.25 282 0 SLOT FISH PULD P Layed down XO accelerator Stood back 1 stand of DC's Lay down 5 DC's (boxes flared) Layed down Jars and Bumper Sub Pulled fish to rig floor recovered remainder of completion equipment Cutoff joint, pup jt, Packer, pup jt., full joint, XN nipple, pup jt., WLEG. Closed blind rams welder made two cuts to lay down Baker Loc'd tools Clear tools from rig floor *slips, slip housings and all seal elements on packer left in hole 15:00 17:00 2.00 0 595 SLOT FISH PULD P Move tools to rig floor MU Fishing BHA #2 6 1/8" bit, (2) 4 3/4" boot baskets, csg scraper, bit sub, (2) string magnets, 4 3/4" Bumper sub, jars, XO, 18 jts of 4" HWDP 17:00 17:15 0.25 595 595 SLOT RIGMNT SFTY P PJSM on cut slip drill line 17:15 18:30 1.25 595 595 SLOT RIGMNT SLPC P Cut slip 50' drill line service TD 18:30 19:30 1.00 595 2,022 SLOT FISH TRIP P RIH w/ clean out assembly f/ 595' to 2022' picking up 45 jts. 4" Dp f/ pipe shed) 19:30 19:45 0.25 2,022 2,404 SLOT FISH TRIP P RIH w/ clean out assembly f/ 2202' to 2404' w/ DP f/ derrick 19:45 20:15 0.50 2,404 2,404 SLOT RIGMNT RGRP T Electrician chnage out switch on Iron Ruffneck 20:15 00:00 3.75 2,404 6,792 SLOT FISH TRIP P Cont. RIH w/ CO assembly f/ 2404' to 6792' (filling pipe every 20 stds) PU wt. 155 SO wt. 120 09/28/2009 Cont. RIH w/ clean out assembly to 14,316' Circ btms up work junk bskts Obseverd heavy gas break out btms up Shut in well w/ annuluar finish circ out gas Monitor well Circ btms up 2 Observed gas break out btms up shut in monitor well perform exhale test pressures coming down Circ btms #3 observed gas break out btms up (less than 2 previous btms up) perform exhale test 2 pressures coming down as before Open well monitor on TT- gained 24 bbls well dead in 4 hrs.- no gas break out fluid level 3 -4" below flow line Begin trip out w/ clean out assembly 00:00 04:15 4.25 6,792 14,316 SLOT FISH TRIP P RIH with BHA #2 from 6,792' to 14,316' worked through tight spots at 13,140' and 13,390' Page 7 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:45 1.50 14,316 14,316 SLOT FISH CIRC P Establish circulation staged pumps up to 4.5 bbls /min 1080 psi btms up had gas boiling and breaking out at surface lost 55 bbls of mud to hole while circulating 05:45 07:30 1.75 14,316 14,316 SLOT FISH OWFF P Shut down pump observed fluid in annulus dropping slightly Shut in well circulate 50 bbls through full open choke 3 bpm 530 psi returns dirty with solids 11.3 ppg when fluid cleaned up shut down pumps closed choke monitor pressures for 20 minutes SICP =61 psi SIDP =27 psi bled 5 bbls to trip tank (10 min.) and shut in choke monitored well for 15 minutes SICP =28 psi SIDP =25 psi Open choke bleed down annulus open annular preventor monitor well 07:30 11:15 3.75 14,316 14,316 SLOT FISH CIRC T Circulate and condition brine 4 bpm 920 psi had gas breaking out of brine throughout second bottoms up increased gas observed at bottoms up continued to circulate until returns clear of gas Lost 52 bbls of brine to hole 11:15 12:30 1.25 14,316 14,316 SLOT FISH OWFF T Shut down pumps shut in well and perform Exhale test Bled 5 bbls of brine to trip tank (7:50 min.) shut in well observe pressures for 20 minutes SICP =100 psi SIDPP =100 psi Bled 4 bbls to trip tank (8:35 min.) shut in choke Observed pressures for 20 minutes SICP =56 psi SIDPP =56 psi 12:30 14:30 2.00 14,316 14,316 SLOT FISH CIRC T Circulate hole 4 bpm returns stayed clean until) bottoms up circulate out gas less volume than previous 2 BU) returns cleaned up in 40 bbls past bottoms up 14:30 19:30 5.00 14,316 14,316 SLOT FISH OWFF T Monitor well on TT gained 24 bbls Well dead in 4 hrs.- observed fluid level drop 3 to 4 below flow line for last hour No gas break out 19:30 00:00 4.50 14,316 9,463 SLOT FISH FISH P Blow down top drive, kill choke lines, choke manifold POOH on TT f/ 14316' to 9463' Hole taking good fill monitor well 20 stds out well dead fulid level 2 -3" below flow line Lost 122 bbls while circulationg gained 24 bbls while monitoring well total losses for day 98 bbls total losses to well 461 bbls of 10.5 ppg CaCl2 Page 8 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/29/2009 24 hr Summary POOH LD clean out assembly Flush stack Test Hydril to 250 2500 psi MU Baker cmt. retainer RIH Set 14,275' Test to 1000 psi Estabish injection rate 2 bbls /min 1830 psi Circ btms up Observed some cas break out RU cement equipment 00:00 04:00 4.00 9,463 595 SLOT FISH TRIP P Cont. POOH w/ clean out assembly f/ 9463' to 595' Flow ck HWDP well static 04:00 05:30 1.50 595 0 SLOT FISH PULD P POOH w/ clean out assembly stand back HWDP Break bit LD XO, jars, bumper sub, string magnets, csg scraper, junk baskets recovered 3 large pieces of packer slips several smaller pieces of meatl f/ packer 05:30 07:00 1.50 0 0 SLOT WHDBO BOPE P PU test jt. pull wear bushing Set stack washing wear bushing PU stack wash flush stack function rams Hrydril LD stack washer pull wear bushing no recovery of any metal 07:00 08:00 1.00 0 0 SLOT WHDBO BOPE P Set test plug test Hydril to 250 2500 psi as per regulation after use for well control. Pull test plug set drilling wear bushing 08:00 08:15 0.25 0 0 SLOT CEMEN" SFTY P PJSM on MU cement retainer 08:15 18:00 9.75 0 14,218 SLOT CEMEN" TRIP P MU Baker cement retainer RIH to 14,218' (149 stds) PU wt. 280 SO wt 140 18:00 19:15 1.25 14,218 14,275 SLOT CEMEN PRTS P LD single on std 150 Get on depth w/ retainer 14,275' Set retainer Pressure test to 1000 psi Good test 19:15 20:00 0.75 14,275 14,275 SLOT CEMEN" CIRC P Sting into retainer establish injection rate 2 bbls /min 1830 psi w/ 10.5 ppg CaCl2 brine 20:00 22:30 2.50 14,275 14,275 SLOT CEMEN" CIRC P LD single Circ DP annulus volume 4 bbls /min 840 psi Observed some gas break out btms up shut down monitor well Well static fluid level just below flow line Blow down top drive 22:30 00:00 1.50 14,275 14,275 SLOT CEMEN" RURD P RU head pin, valves, hoses for cement job 09/30/2009 Performed squeeze cement job through cement retainer A 14,275' w /30 bbls 15.8 ppq- Pu reverse circ 1.5 DP volume then circ long way adding lubes to brine POOH w/ retainer running tool RU attempt to test 7" casing unable to get high pressure test bleed off 625 psi in 4 mins.- RU test BOPE Slip cut drill Iline MU test packer Page 9 of 26 T ime Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 14,275 14,275 SLOT CEMEN P Held pre -job safety meeting and cemented per schedule. Pumped 5 bbls water Tested lines to 3500 psi. Pumped 15 bbls Biozan water Mixed and pumped 20 bbl Mud push 11.5 ppg followed by 30 bbls Class G tail cmrt 15.8 ppg Pumped 5 bbls water behind owed by 15 bbls Biozan water_ displaced with 55.6 bbl Of 10.5 ppg CaCl2 brine Stung back into retainer and displaced continued to displace w/ 125.6 bbls 10.5 ppg CaCl2 brine Placing 30 bbls cmt through retainer intinal rate 2 bbls /min 870 psi final rate 1 bbl /min 3050 psi Unstung f/ retainer monitor well static CIP 0130 hrs. 01:30 03:00 1.50 14,275 14,275 SLOT CEMEN" CIRC P Rig up and reverse at 4 bpm and 880 psi. Blow down kill line 03:00 05:15 2.25 14,275 14,275 SLOT CEMEN "CIRC P Circulate at 4 bpm and 1020 psi. Monitor well static. Rig down and blow down lines 05:15 10:00 4.75 14,275 7,158 SLOT CEMEN "TRIP P Pull out of the hole on elevators from 14,275' to 7,158' Fluids out of balance. Pump slug at 8110' and pull 10 stands to 7158'. Drill pipe still) pulling wet. Attempt to circulate and drill pipe plug at 1300 psi. 10:00 12:00 2.00 7,158 7,158 SLOT CEMEN" CIRC P Pre -job safety meeting and rig up to reverse circulate. Reverse and clear drill pipe. Reverse at 4 bpm and 640 psi. Rig up to circulate the long way and circulate bottoms up at 6 bpm and 940 psi. Pump pill and blow down top drive 12:00 14:30 2.50 7,158 0 SLOT CEMEN" TRIP P Finiish POOH f/ 7158' w/ cement retainer running tool 14:30 15:30 1.00 0 0 SLOT DRILL PRTS P Close bind rams pressure test 7" casing to 250 psi (good) 3500 psi (No good lost 625 psi in 4 mins. Checked surface equipment retest to 3500 psi No Good lost 600 psi in 5 mins. 15:30 16:00 0.50 0 0 SLOT WHDBO BOPE P Pull wear bushing set test plug Page 10 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 22:00 6.00 0 0 SLOT WHDBO BOPE P RU test BOPE Hydril to 250 2500 psi VBpipe rams, choke kill line valves, choke manifold valves, to drive IBOP's dart, floor safety valve, with 4" test jt to 250 3500 psi performed accumulator recovery test pulled test jt tested blind rams to 250 3500 psi Pulled test plug changed to 4 1/2" test jt. Tested Hydril to 250 2500 psi tested VB rams to 250 3500 psi Pull test jt. installed wear bushing 22:00 22:15 0.25 0 0 SLOT RIGMNT SFTY P PJSM on cut slip of drill line 22:15 23:30 1.25 0 0 SLOT RIGMNT SLPC P Cut slip 60' drill line service TD, drawworks, iron ruffneck 23:30 00:00 0.50 0 13 SLOT DRILL PULD P PJSM MU Baker retrieveamatic packer XO 10/01/2009 RIH w/ Baker retrievamatic packer test casing 5052', 9995' to 3500 psi Good tests test 13,109' Leaked off -Pull up to 12,950' test to 3500 psi Good test RIH to13,109' pump down DP to test down to cmt retainer to 3500 psi lost 400 psi in 20 mins.- released packer POOH Observed DP connection on 2nd std out was backed off 3 threads possible cause of slow leak on test) Retorque pipe POOH check make up on next 20 stds.- Finish POOH LD packer 00:00 06:45 6.75 13 5,032 SLOT DRILL TRIP P RIH w/ Baker retrieve -a -matic packer to 5032' Note: Observed chucks of cement falling out of std 10 Pulled back to packer Rabbited DP to remove cement from DP 06:45 08:00 1.25 5,032 5,032 SLOT DRILL PRTS P Set packer 5032' RU test casing f/ 5032' to surface to 3500 psi for 30 mins.(Good test) 08:00 10:45 2.75 5,032 9,995 SLOT DRILL TRIP P Cont. RIH w/ packer f/ 5032' to 9995' 10:45 12:00 1.25 9,995 9,995 SLOT DRILL PRTS P Set packer 9995' Ru test casing f/ 9995' to surface to 3500 psi for 30 mins. Good test) 12:00 13:00 1.00 9,995 13,142 SLOT DRILL TRIP P RIH w/ packer f/ 9995' to 13.142' string took wt. 13,142' 13:00 13:30 0.50 13,142 13,109 SLOT DRILL PRTS P PU to 13,109' set packer RU Attempt to test casing f/ 13.109' to sufrace to 3500 psi wouldn't hold pressure Note- Baker Premier Packer setting depth was 13,032' 13:30 14:00 0.50 13,109 12,950 SLOT DRILL TRIP P Pulled back f/ 13,109' to 12,950' 14:00 15:00 1.00 12,950 12,950 SLOT DRILL PRTS P RU test casing f/ 12,950' to surface to 3500 psi for 30 mins. (Good Test) 15:00 16:00 1.00 12,950 13,109 SLOT DRILL TRIP P Release packer RIH to 13,109' checking torque on DP connections Page 11 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 13,109 10,109 SLOT DRILL PRTS P MU top drive Set packer 13,100' Test 7" casing f/ 13,100 to cement retainer 14,275' pumping down DP pressure bled down 400 psi in 20 mins. 16:30 00:00 7.50 10,109 0 SLOT DRILL TRIP P Release packer- Blow down TD, kill choke lines POOH w/ packer f/ 13,109' Found DP connection backed out 3 threads (possible source of slow leak during test) retorqued DP checked connections coming out of hole for 1st. 20 stds. continued to POOH w/ packer LD packer XO 10/02/2009 Cont.RIH W/ clean out assembly to 13,096' Wash ream to 14,282' top of retainer (tagged soft cmt 14,275' Circ 2 X btms up 9 bbl /min Rotate recpicate pipe Perform FITto 12.6 ppg EMW POOH LD clean out assembly 00:00 01:30 1.50 0 595 SLOT DRILL PULD P PJSM MU clean out assembly (bit, scraper, 2 junk bskts. bit sub, 2 string magnets, bumper sub, jars, XO, 18 HWDP) RIH to 595' 01:30 07:15 5.75 595 7,172 SLOT DRILL TRIP P PJSM RIH w/ clean out assembly picking up 207 jts 4" DP f/ pipe shed to 7172' fill pipe every 20 stds) 07:15 09:45 2.50 7,172 13,096 SLOT DRILL TRIP P Cont. RIH w/ CO assembly f/ 7172' to 13,096' w/ DP f/ derrick(fill pipe every 20 stds) 09:45 13:30 3.75 13,096 14,282 SLOT DRILL WASH P Wash ream f/ w/ bit scraper f/ 13,096' to 14,282' (tagged soft cmt 14,275' tagged up on retainer 14,282') 5 bbls /min 1350 psi w/ 50 rpm's PU wt. 255 k SO wt 135 k Rot wt. 170 k torque 13,000 ft/lbs 13:30 14:45 1.25 14,282 14,282 SLOT DRILL CIRC P Circ 2 X btms up 9 bbls /min 2800 psi w/ 50 rpm's shut down TD 7& circ 9 bbls /min 2600 psi 14:45 15:45 1.00 14,282 14,043 SLOT DRILL TRIP P Flow ck static POOH f/ 14,282' to 14,043' PU wt. 250 k Blow down TD Pull air slips 15:45 16:45 1.00 14,043 14,043 SLOT DRILL FIT P RU perform FIT 14,264' MD 7373' TVD 800 psi w/ 10.5 ppg brine 12.6 ppg EMW lost 15 psi in 30 mins. RD blow down kill line 16:45 23:00 6.25 14,043 46 SLOT DRILL TRIP P Cont. POOH w/ clean out assembly f/ 14,043' to 595' (top of HWDP flow ck(static) Std back HWDP 23:00 00:00 1.00 46 0 SLOT DRILL PULD P Change to 3 1/2" elevators LD C/O BHA recovered 2 large pieces of metal f/ packer on string magnets several small pieces of metal in junk bskts. 10/03/2009 Cut slip DL MU whip stock assembly RIH to 13,168' Orient WS Circ Attempt to go in hole unable to pass below 13,168' Circ POOH w/ WS assembl 00:00 00:30 0.50 0 0 SLOT DRILL PULD P Clera rig floor of bit, scraper,junk bskts, string magnes Page 12 of 26 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD2-60 Run Date: 9/14/2009 ~ ~~ ~ ~ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-60 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20511-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. barreto@halliburton'. com Date: • November 10, 2009 f~ // ;i ~ i Signed: ~ t' ,''~'~ ..y_ Page 1 of 1 zo s---064) L t Schwartz, Guy DOA From: Anderson, Nina M Nina .Anderson @conocophillips.com] Sent: Monday, October 05, 2009 1:04 PM To: Schwartz, Guy L (DOA) Subject: CD2 -60A Injector AOR Guy, As a follow up to the recently submitted CD2 -60A permit to drill application, a list of wells that fall under the AOR Injection guidelines have been listed. There are three wells within a 1/4 mile radius of the planned CD2 -60A Alpine injector. These wells include CD4- 16, CD3 -319, and Nanuq 3. CD4 -16 is an Alpine A producer well that has a cemented intermediate casing shoe. CD3 -319 is a Kuparuk well that also has a cemented intermediate casing shoe, and is geologically isolated from the Alpine reservoir. Nanuq 3 is an exploration well that was plugged and abandoned in 2007. This well was never completed although it does have intermediate casing and all hydrocarbon zones cemented. Please let me know if you have any questions. Nina Anderson A we NO 2 7 2009 Drilling Engineer Alpine Drilling Team Office: (907) 265 -6403 Cell: (907) 575 -3256 11/23/2009 CD2 -60A Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G Ryan .G.Robertson @conocophillips.com] Sent: Friday, October 02, 2009 9:36 AM To: Schwartz, Guy L (DOA) Cc: Galiunas, Elizabeth C; Chambers, Mark A; Anderson, Nina M Subject: RE: CD2 -60A Guy, Thank you for your response. Unfortunately we were unable to test the integrity of the casing and cement retainer below 13,109' MD yesterday night as planned. After the crews had established that there was a hole in the 7" casing between 12,950' MD and 13,109' MD using a Baker Retrieve -o -matic test packer, they attempted to run back to 13,109' MD to test the integrity of the casing and retainer below that depth. To do this, the test packer had to be unseated at 12,950' MD, which required the driller to apply left hand torque to it. It is felt that at this point a drill pipe connection loosened. This caused the pressure test below 13,109' MD to fail once the crews got the test packer reset at that depth. At this point it was a priority to trip the packer and drill string from the hole and re- torque the drillpipe connections to avoid worsening the problem and prevent a possible fishing job. Two loose connections were found during the trip out, one at 60' below the table, and one roughly 5 stands below that. It should be noted that the pressure decline profile of the failed test below 13,109' MD did not match the previous failed tests performed when the suspected hole area was responsible for the loss in pressure. The pressure decline on this last test was more pronounced and linear. It is strongly felt that the test failed due to the backed off drillpipe, and the integrity of the casing and retainer below 13,109' MD has not been compromised. It is also understood that it is not a State requirement to have a full integrity test on the cement retainer. Please do not hesitate to call if you have any questions or concerns, Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, October 02, 2009 8:31 AM To: Robertson, Ryan G Cc: Galiunas, Elizabeth C; Anderson, Nina M; Chambers, Mark A Subject: RE: CD2 -60A Ryan, Thank you for the update. Your plan forward is reasonable and you have verbal approval to move ahead as outlined below. Nina, Still need the AOR review statement. I can't tell if there are any Alpine penetrations with mile of the new well with the data supplied. Thanks, Guy Schwartz Senior Petroleum Engineer 11/23/2009 CD2 -60A Page 2 of 2 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto: Ryan. G.Robertson ©conocophillips.com] Sent: Thursday, October 01, 2009 4:36 PM To: Schwartz, Guy L (DOA) Cc: Galiunas, Elizabeth C; Anderson, Nina M; Chambers, Mark A Subject: CD2 -60A Guy, It has been determined on that there is a hole in the 7" casing on the CD2 -60A wellbore. The hole, located between a depth of 13,109' MD and 12,950' MD, was found today through a series of pressure tests using a 7" test packer. Due to hole problems that included wellbore breathing and gas to on the originally planned open hole sidetrack, it was decided to isolate the CD2-60 lateral wellbore. This was done by setting a cement retainer at 14,275' MD. Once this retainer was set in place, 30 bbl of cement was pumped below it, and then the running assembly was pulled from the hole. At that point, an attempt was made to pressure test the 7" casing to 3,500 psi. Unfortunately the casing would not hold the test. It was initially speculated that the cement retainer that was ran in the hole and set at a depth of 14,275' MD was responsible for the failed pressure tests. To prove this, a test packer was ran in the hole, as there was also concern that the casing may have been compromised while pulling the packer. The drill crews tested the casing above the testing tool without issue from 5,000', and then from 10,000' MD. After that, it was determined through a pair of tests that the 7" casing was good above 12,950' MD, however at 13,109' MD, the casing leaked in a similar fashion to that of the initial failed tests. The packer was set at 13,033' MD, which falls into this depth window, further supporting the case that removing the packer from the hole is what compromised the integrity of the casing. The plan forward is to test the casing and retainer below 13,109' MD. From that point the test packer will be pulled from the hole, and a clean out assembly will then be ran to ensure the casing is free of any cement prior to running the whipstock. Once the hole is drilled, the window from 12,950' MD to 13,109' MD will be isolated by means of straddle packers. Please let me know if you have any questions or concerns, Ryan Robertson Drilling Engineer 1 ConocoPhillips Alaska 1 Direct: (907) 263 -6318 1 Mobile: (907) 980 -5107 11/23/2009 CD2-60L1 Shut In Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 29, 2009 8:00 AM To: Maunder, Thomas E (DOA) Subject: FW: CD2 -60L1 Shut In Thanks for your response this morning... I need to remember to tell them about the slope inspector notification!! Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Monday, September 28, 2009 4:58 PM To: 'Robertson, Ryan G' Subject: RE: CD2 -60L1 Shut In Ryan, Thank you for the update. I discussed your plan forward concerning setting a CIBP and sidetracking from the 7" casing with the commissioners. You have verbal approval to execute the steps as outlined below. Please contact me Tuesday morning and we can discuss the permitting requirements needed to reflect the changes planned. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto: Ryan. G.Robertson @conocophillips.com] Sent: Monday, September 28, 2009 4:51 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Cc: Anderson, Nina M; Galiunas, Elizabeth C Subject: CD2 -60L1 Shut In Doyon 19 functioned the annular preventer this morning to perform a series of exhale tests on the CD2 -60L1 sidetrack well. Over the weekend, the Baker Premier Packer was retrieved from a depth of 13,033' MD 7,035' TVD. Unfortunately several of the slips on the packer were seen to be missing once it was brought to surface. The decision was made to run a cleanout assembly to the 7" casing shoe in order to remove any debris remaining in the well. The assembly had reached a depth of 14,316' MD this morning at which point the well was circulated. As bottoms up was nearing surface, gas was seen to be breaking out of the 10.6 ppg brine in the hole. This prompted the rig crew to shut in the annular preventer and perform an exhale test. 11/23/2009 CD2-60L1 Shut In Page 2 of 2 The well was bled down and then shut in to monitor. The flow rate began to decrease and the pressure was taking longer to build up once shut in thus indicating wellbore breathing. It should be mentioned that breathing had been an issue on this well since kill weight fluid was initially pumped. After performing the exhale test, the well was opened and a bottoms up was circulated. As bottoms up was approaching, gas was once again noted at surface. Circulation was maintained on the well this time, and the gas seen at surface decreased to the point where the return flow was clean. It should be noted that none of the gas detection monitors were alarmed. The well was further circulated for over two bottoms up to ensure there was no gas entering the wellbore. Circulation was then stopped, and the well shut in with the annular preventer. This was done to conduct another exhale test to further prove that no gas was present in the hole. Once completed, bottoms up was circulated again. The plan forward is to POOH with the clean out assembly once the well is determined to be dead and free of gas. At this point the annular preventer and BOPE will be tested. We are currently working towards putting together a plan to sidetrack the existing wellbore in the upper Alpine C sand which is approximately +1- 100' MD up from the intermediate casing shoe. A cement retainer will be set to isolate the original wellbore CD2 -60. A whipstock will be placed above the cement plug to sidetrack the well at approximately +1- 14,257' MD. The sidetracked wellbore will be called CD2 -60A. ConocoPhillips will submit a 10-401 change of approved program and a sundry to isolate the original perforations in CD2 -60. Please let me know if you have any questions, Ryan Robertson Alpine Drilling Engineer ConocoPhillips Alaska Office: 265.6318 Cell: 980.5107 11/23/2009 CD2-60L1 Shut In Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, September 25, 2009 11:33 AM To: Regg, James B (DOA) (jim.regg @alaska.gov) Cc: Foerster, Catherine P (DOA) Subject: FW: CD2 -60L1 Shut In FYI Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson @conocophillips.com] Sent: Friday, September 25, 2009 11:08 AM To: Maunder, Thomas E (DOA) Cc: Doyon 19 Company Man; Schwartz, Guy L (DOA); Galiunas, Elizabeth C; Anderson, Nina M; Chambers, Mark A; Noel, Brian Subject: CD2 -60L1 Shut In Tom, Yesterday the annular preventer on Doyon 19 was used for well control purposes on the CD2 -60L1 sidetrack well. The BOPE had been successfully tested earlier on in the day prior to beginning rig operations. Once tested, the back pressure valve was pulled, and the tubing hanger engaged with the landing joint. After determining that the tubing hanger was free of the wellhead, the rig pulled on the 4.5" tubing string in an attempt to release the Premier packer set at 13,033' MD 7,035' TVD. The packer unfortunately would not release. Several hours after the rig initially pulled on the packer, gas was observed at surface and the well began to flow. At that point, the annular preventer was used to shut in the well, and bottoms up was circulated at 2 bpm. Once bottoms up had reached surface, the pumps were shut down, and the well was opened up. It was observed that the well was still flowing slightly, however the large break out of gas seen when the annular preventer was initially closed was no longer present. The flow from the well continued to drop, however a series of exhale tests were performed using the annular preventer again to shut in the well. This was done in order to determine that wellbore breathing was responsible for the flow, and not another gas bubble. It should be noted that wellbore breathing had been an issue when the well was initially killed with 10.6 ppg brine. Performing the exhale tests ruled out another bubble in wellbore, and once flow had completely stopped, the well began taking losses at roughly 2 bbl /hr. It is felt that the gas seen at surface was a result of the packer shifting while attempting to release it, allowing a gas bubble trapped below it to escape. If the packer had released as planned, the drilling program called for the well to be circulated and monitored as it was known a gas bubble was likely present below the packer. Currently the plan forward is to cut the 4.5" tubing above the packer and pull 300 joints from the hole. At that point, the annular preventer and pipe rams will be tested before running back in the hole with drillpipe and an overshot fishing assembly. 11/23/2009 CD2 -60L1 Shut In Page 2 of 2 Let me know if you have any questions or concerns, Thanks, Ryan Robertson Drilling Engineer ConocoPhillips Alaska Office: 265 -6318 CeII: 230 -9027 11/23/2009 • ! ~ ~~ ~ ~ ~ ~ ~~~ ~ F. ~ `°TE ~'u~' ~ ~~ h ~5~:._. I - F ~ ~ .~ / y v" ~ ~~ k ~Y~ ~ k~- ~ "~~6i €~~~~ ~ ~~~ ~ ~ y ~. . ~ { `~'; ~ ~ ~ ~ kG~ ~ :§ ~ ~ ~ ~ ~ . ~ s h 4 k 4 h ~`"" ~ ~ ~w ~ ~ ~ ~ ~~~` ~ ~ °~~~' '~ ~ ~ ~y SEAN PARNELL, GOVERNOR , ~~~~ ~N i".. c~ ~~ ~_.~ G ~ ~ ~w. `<.~ ... Y.~'~. ~ ~ 4 ~.~~~ V,~ ti_.k l~L ~.~-~ ~~ ;~ # ~ ~ S~~ ~I~ Atsy ~i0-7 ~a~tc ~ 333 W. 7th AVENUE, SUITE 100 r ~ CO~S"~i R~AiiO~ C~r~'IIS'S'I0~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 +' FAX (907) 276-7542 Mr. C. Alvord Alpine Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~ ~~ ~~ ~ ~ Re: Colville River Field, Alpine Oil Pool, CD2-60 Sundry Number: 309-343 ~~~~at~N~~ ~~`~~ ~ ~~ 20~9 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 'znspector 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 sh~wn, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this ~ day of October, 2009 Encl. ~~~ .~1 ~~E~V'~~,,~o~ • ~, I • 9.3 STATE OF ALASKA sEp 2~ ZaQ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~as~~ ~1~ & Gas ~ans. Commission 2o aac ~s 2so Anchora~e 1. Type of Request: Abandon Sus end ^ O erational shutdown ^ p p Perforate r, Waiver Other Altercasing ^ Repairwell ^ Plug Perforations ^~ Stimulate ~ Time Extension ^ Change approved program ^~ Pull Tubing ^ Pertorate New Pool ^ p 'O • Re-enter Sus ended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill N b r: O~~b~' ~ ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ `z~$ 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20511~ 7. KB Elevation (ft): 9. Well Name and Number. ~ 52' RKB above GL / 36.3' MSL CD2-60 ~ 8. Property Designation: , , 10. Field/Pools(s): ADL 380075, 380077 Colville R iver Field/AI ine Oil Pool PRESENT WELL CONDIT ION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective ~epth nn~ (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 18695 7376~ -18695 7376- Casing Length Size MD ND Burst Collapse Structural Conductor 77 16" 114 114 Surface 3239 9.625" 3276 2373 3520 2020 Intermediate 14294 7" 14331 7379 4599 5410 Production 13071 4.5" 13103 7064 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O en Hole 14331'-18695 O en Hole 7379-7376 Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: ~ Detailed Operations Program ^~ BOP Sketch ^ Exploratory ^ Development ^ Service ~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/29/2009 Oil ^ Gas ^ Plugged ~- Abandoned ^ 16. Verbal ApprovaL Date: 9/28/09 WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: Guy Schwartz 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Liz Galiunas - 265.6247 Printed Name C. AIVOPd Alpine Drilling Manager Signature ~.,~~~ ~,..,~,t ~ L'~ .~ o~e 265-6120 Date: 09/30/2009 ~ ~ ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integ~ity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Requi~ed: / ~ - YQ ~ APPROVED BY / ! Approved by: COMMISSIONER THE COMMISSION ~ ~ Date: ~ ~ ~ Z v Form 10-403 Revised 7/2005 i S~ ~, F.. ~ ~~~. v ~~ i ~ ~. 2~0~3 +~'''~ j~ 9'-3°' °`~ ~ ~-( ~ ~ °1 ~ ~ ~ ~ SUBMIT IN DUPLICATE ~ ~ ~/ ~ ~ 1 l.~~ . • Proposed Plan 1. Runninq Cement Retainer a. RIH with cement retainer on 4" drillpipe. i. Set the top of retainer at 14,277' MD. ii. Un-sting from retainer and pressure test to 1,000 psi. iii. Sfing back into retainer and circulate to establish injection parameters. b. Un-sting from retainer. c. Circulate bottoms up to free annulus of any potential gas. i. SIMOPS: Build and condition viscosified brine for setting whipstock. 2. Remember to notify the State of upcoming BOP test 3. Cementinq a. Pump 20 bbl of fresh water. b. Pump 20 bbl of 11.5 ppg Mud Push spacer. c. Pump 30 bbl of 15.8 ppg, Class `G' cement. i. Pump 70 bbl of fresh water pill out of the drillstring ii. Stab into retainer and spot Mud Push and cement. iii. Chase cement with 3 bbl of fresh water. d. Un-sting from retainer and reverse circulate remaining cement from drillpipe. e. Perform full circulation of lubricated brine. f. POOH. 4. Pressure Testina a. Once out of hole, test 7" casing to 3,500 psi for 30 minutes b. Perform full BOPE test. 5. Runnina Whipstock and Millina Out a. Make up whipstock assembly and run in hole. b. Setting whipstock i. Orient whipstock to 45° right. ii. Set top of whipstock at 14,257' MD iii. Mill the window out of the 7" intermediate casing starting at 14,257' MD. 1. Flow at 300 gpm with 10.5 ppg viscosified brine 2. Drill 20 ft of gauge rat hole 3. Circulate bottoms up and POOH 6. Make up 6.125" GeoPilot Assemblv a. Run in hole to whipstock b. Displace to 10.3 ppg Flo Pro c. Drill out as per directional program ~~~~.~~~~~~~ • • CD2-60 Plugging Productive Zone Plan & sidetrack for CD2-60A CD2-60A Sidetrack Schematic / CD2-60 VI D Bottom of Whipstock Anchor: 14271' Cement Retainer: 14 (1.5' Length) Spa 1 St Full joint: ~-~~~~~.~~~. MD / 7376' TVD ConocoPhillips Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 29, 2009 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit: Plug Perforations in CD2-60 Dear Sir or Madam: • ~or~t~~~oP~ i I ~ 1 ~ ~ ~EC~I~'ED ~~~ ~ ~ ~~~~ ~I~ske Oil & Gss Gans~ ~~r~nniss~ion Anchore~e ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to plug the perforations on CD2-60. A new Permit to Drill will be submitted to sidetrack out of the 7" casing and re-drill the lateral section as CD2-60A. Doyon 19 moved onto CD2-60 on September 23~d, 2009 with the goal of pulling the completion and drilling a sidetrack below the intermediate casing. The completion was pulled out of the well successfully, but encountered wellbore breathing and gas at surface. Due to unstable conditions of the wellbore, the decision was made to plug the lateral. A cement retainer will be set at 14277' and 30 bbls of 15.8 ppg class G cement will be pumped below the retainer. After this point, the well CD2-60 will be isolated from future injection. A 10-407 will be submitted, indicating the productive zone has been plugged. The new plan is to exit out of the 7" casing (in the Alpine C sand). CD2-60A will be kicked off with a whipstock and drilled to a TD of 21,053 ft MD. Upon isolation the original lateral, CD2-60 will maintain API: 50-103-20511-00. The new horizontal well will become CD2-60A (API: 50-103-20511-01). Please find attached: ^ Form 10-403 Application ^ Plan forward to plug perforations. ^ Proposed Kick off Schematic diagram. If you have any questions or require further information, please contact Liz Galiunas 265-6247 or Chip Alvord at 265-6120. Sincerely, A Liz Galiunas Drilling Engineer ~ ~ Attachments: cc: CD2-60 Well File / Sharon Allsup Drake Chip Alvord Ryan Roberston Nina Anderson Tim Schneider ATO 1530 ATO 1577 ATO 1702 ATO 1706 ATO 1768 u C~ ~~ `~~ ~,~ ~ p, ~ ~`~ ~-~~ ~ ~ ~= ~f ~~ ~ ,~~~~ ~ ~ [ ~~' ~~~ ~,~ ~ ~, , ~ ~ ~ ~ ~ ~ g ~ ~ ~~ $ ~ ~ 6 ~ ~~ ~~ `~ ~ ~ ~ SEAN PARNELL, GOVERNOR .~~~ ~ ~~~~~ ~ ~ ~~ ~ ~ ~~ ~ ~_~ ~~`~ ~,, ~ ~ ~ ~.. ~ ~ , -.~ ~~ ~ ~ ~_ ,~ ~ ALASSA OIL Ai~D G~5 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI011T COM~IISSIOl~ ~+~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ;- FAX (907)276-7542 Mr. C. Alvord Alpine Drilling Manager ConocoPhillips Alaska, Inc. , ~ ~~~~ ~ ~ ; : ~: ~ , . ~ ~~ ~° ~ `~ ~~ l~ ~ ~: P.O. Box 100360 Anchorage, AK 99510 ~~ ~~--~- fl ~ Re: Colville River Field, Alpine Oil Pool, CD2-60 Sundry Number: 309-292 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 consider~d timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of September, 2009 Encl. • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 18th, 2009 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, 5uite 100 Anchorage, Alaska 99501 Re: Sundry Permit: Pull tubing in CD2-60 Dear Sir or Madam: ~ • • ~ono~oF~hill~p~ .~ .. ~ . . 1.. . . .. ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to return to CD2-60 to puil the existing tubing and completion. A new Permit to Drill wiil be submitted to open-hole sidetrack and ~ re-drill the lateral section as CD2-60L1. It is intended that Doyon 19 wil! return to CD2-60 and pertorm the work described in this sundry application. Date for proposed work is September 18~', 2009. ConocoPhiliips Alaska drilled CD2-60 (PTD#: 205-068) in June, 2005. The well was originally completed as an Alpine 'A' injector, however poor rock qualiry has kept injectivity rates too low to ~ provide sufficient pressure support for nearby producing wells. The proposed well plan is to de-complete the CD2-60 well and drill a new 6.125" horizontal section. This new CD2-60L1 well will be sidetracked at approximately 14,480 ft MD from the low side of the original wellbore, and is planned to parallel the original wellbore roughly 300 ft to the west, reaching a planned TD of 21,055 ft MD. ~~D~ Upon completion of work on CD2-60/CD2-60L1, the original~wellbore will remain as CD2- 60 (API: 50-103-20511-00), and the new horizontal we(I will become CD2-60L1 (API: 50-103- 20511-60) Please find attached: 1. Form 10-403 2. A proposed re-entry program 3. Current completion schematic for CD2-60 4. Actual surveys from CD2-60. If you have any questions or require further information, please contact Ryan Robertson 265-6318 or Chip Alvord at 265-6120. Sincerely, Ryan Robertson Drilling Engineer ,.~~ , -~, ; > .... ~ . :/ _ry `J f ~ .i /._~n•~,~K ....... ...~,....... r / . f .___.. , r. ~. G, , i, ~_. , _ .,- ~...._ _..._.... .._..__~.__._....._--.~ ~-. - ~ . Attachments: cc: CD2-60 Well File / Sharon Allsup Drake Chip Alvord Liz Galiunas Nina Anderson Tim Schneider ATO 1530 ATO 1577 ATO 1704 ATO 1706 ATO 1768 b~ ~~ ~~ ~~~ Q' ~ .. . . ~ ~ ~ ~.,s r ~: -~ ~ ,~,~ ~; i ~ ~, ~ ~ ,, :, STA7E OF ALASKA ALASKA OIL Ah1D GA5 CONSERVATI~N COMMISSION . ~ -' APPLtCATIfJN FQR SUNDRY APPROVAL ~o aac ~s.2ao 1. Type of Request Abandon, ^ 5uspend ^ Qperational shutdown ^ Perforate ^ Waiver ^ Ofher L~ Atter casing ^ Repairwell ^ Plug Perforations ^ Stimulate ~ Time Exiension ^` Change approved program ~ Pull Tutiing ~~ Perforate New Pool ~ Re-enter Suspended Well ^, ~ 2. Qperator Name; 4. Current Well Class; 5:'P~rmit tobrill Numberi GorrocoPhillips Alaska, Inc: Develapment ^' Explaratary ^ 205-068' • 3. Address; Stratigraphic ^ Service 0, 6. API Number. P. O, Box 1 D0360, Anchorage, Alaska 99510 50-1 Q3-20511-OQ , 7. KB Elevation (ft): ~ ~ ~1~L i t 1~ .~' ~~7 = l 9. Weii Nar~e and Number. = 52' RKB a . ~Z ~ ~ . ,-~ L ~ S ~D2-6t} ' $. Property ~esignation: ~.~y.E' 10, FieldiPools{s): ADL 380075, 3800T7 • Coiville RiVer'FieldtAlpine Oil Pool • PRESENT WELI. CONDIT ION SUMMARY Total Depth MD (ft); Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft); Plugs (measured} Junk (measured): 18695 • 7376 . . 18695 7376 . Casing E.ength Size MD TVD Burst Collapse Structural Gonductor 77 16'~ 114 114 Surfiace 3239 9.625° 3276 2373 ,352b 2D20 lntermediate 14294 7~~ 14331 7379 4599 5410 Productian 13071 4.5'~ 131Q3 7064 Liner Rerforation Depth M~ (ft): Perforation Depth TVD (ft): Tubi~g Size; Tubing Gradei Tubing MD (ft): t+~/A N/A 4.5 L-$0 13103 Packers and'SSSV 7ype: ° Packers and SSSV MD (ft): Baker Premier Packer and Gamco DB Nipple PaGke-': 13,0~3' MD, DB 1al IE. 2,317' MD 12. Aftachments: Description Summary of Proposal ~ 13. Well Ctass after praposed work: v ~ b~ Qetalled Operatians Program 0 BOP 5ketch ^ Exploratory ^ D~velopment ~ Senr~ce L`°_I~y ~ '~ ~~'o` ~' ~ 14: Estimated Date for 15. We8 Status after proposed wark: Commencing Operations: 9l18/2~Q9" pil ^ Cas ^' Plugged ^ Abandoned ^ 16. Verbal Approval; Date: WAG ~ GINJ ^ WINJ ~ WDSR~ ^ Commission ReRresentativet 17. J h~retiy certify that the foregoing is true ar~d correct to the best of my knowledge: Contact Rvan Robertson - 265:531$ Pnnted Name C. A~VOCd Atpine Orilling Manager- 5ignature ~Y ~ Phone 265-6'12~ Date: 08l17/2009 COMMISSION USE ~NLY Cpndi6ons of approval; Natify-Gommission so that a representaUve may witness Sundry Num6er: ~ ~ ~~~ ~ ~~ P1~g Int2gtify^ BOP Test Mechanical Integrity Test Loeation Ciearance ^ + " -f~.r 3 50o p s~ ~d P - y ~ / QlP~er:' ~/"w ~~'S ~~ rh.e.. ti) ~ S c s ~ ~ ~ n , . (~D ~ L S Subsequent Form Required? ~~ ~ OL) _~ ,~~~ ~ - APPRQVED BY ~ Approved by; COMMISSIONER THE GOMMISSION ~ ~ ~~ Date: P~~ l0 ~ /~~ ~ ~~`~ Farm 10-4D3 Revised 7/2005 SUBMIT IN ~UPLICATB 0 R I G I~I A L ~~~:~~ ~~~. ~~~, ~~~~~4 ~~ ~,~~~ - ~~ ~a~~ ~ ~ Pre-Riq Work 1. Slickline will pull A-1 injection valve. 2. Slickiine will drift tubing to 3.725" with gauge ring to `XN' nipple at 13,092 ' RKB. 3. E-Line wili run chemical cutter and CCL. 4. Chemical cut the inner mandrel sleeve of Baker Premier packer set at 13,033' RKB. 5. Make a pass with CCL across packer cut. 6. RIH with E-line PDS caliper. Caliper from 13,103' RKB to M12,900' RKB to verify good packer cut. Ria Procedure 1. Move rig onto CD2-60. ~~~`~~ 3~ 2. Nipple down tree. Nipple up BOPE and test to 3,500 psi. 3. Pull 4-1/2" tubing and packer. ~ 4. Drill 6-3/4" horizontal section to well TD of 21,055' MD / 7,467' TVD. ~ 5. Circulate hole clean and pull out of hole. '~'~(~ 6. Run 4-1/2", 12.6 ppf, L-80 tubing with 4-1/2" Camco DB Nipple (to land Camco A1 injection valve), 4-1/2" KBG-2 gas lift mandrel, 4-1/2" x 7" Baker Premier packer, XN nipple and 4-1/2" tubing tail extension (± 1,500' MD) . 7. Land Hanger. 8. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 9. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. 10. Remove 2 way check. 11. Displace well to corrosion inhibitor and freeze protect. 12. Record tubing pressure. 13. Rig up lubricator. Drop RHC ball and rod. 14. Set Premier packer with 4,000 psi plus recorded tubing pressure (Approx. 4,800 psi). 15. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 16. Bleed off tubing pressure. 17. Install BPV and secure well. 18. Move rig off. ~ ~ Current Completion Schematic Alpine CD2-60 Injection Well Completion 16" Conductor to 114' 4-1/2" Camco DB Nipple (5.62" OD x 3.812" ID) at 2,317' MD = 1,909' ND 9-5/8" 36 ppf J-55 BTC Surface Casing at 3,276' MD / 2,373' ND Cemented to surface 4-1/2" 12.6 ppf L-80 IBT-M Updated 08/12/2009 Comoletion MD ND Tubing Hanger 32' 32' 4-1/2", 12,6#/ft, IBT-Mod Tubing 4-1/2", Camco DB Nipple 2317' 1909' 4-1/2", 12,6#/ft, IBT-Mod Tubing 4-1/2" Camco KBG2-GLM 8641' 4963' 4-1/2", 12.6#/ft, IBT-Mod Tubing Baker Premier Packer 13033' 7035' 4-1/2", 12.6#/ft, IBT-Mod Tubing 4-1/2", "XN" at 66.5° inc 13092' 7059' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 13103' 7064' Camco KBG-2 GLM w/ dummy (5.984" OD x 3.938" ID) at 8,641' MD / 4,963' ND ~' ' 7" 26 ppf L-80 BTC-M Production Casing _ at 14,331' = 7,379' TVD @+/- 85.4° . :.:..:<.:.:.:.:.:.>. - - ------ --- - ~ TOC @+/- 12,422' MD / 6,762' ND Well TD at 18,695' MD / 7,376' ND i Top of Atpine C at 14,4B0' MD / 7,387' TVD ~~~ " ..,:.:::::::.. ~ Top of Alpine A at 15 033' MD /7,412' ND ~' `<~ '~ ~ Baker Premier Packer (5.97" OD x 3.875" ID) at 13,033' MD / 7,035' ND ~ ~ ConocoPhillips(Alaska) Inc. CD2 Alpine Pa C D2-60 501032051100 ~~~~~~- ~~~Ili ~~i ~~ Definitive Survey Report 20 August, 2009 ~~~ ~~ LILM tJf~T IV` Sperry ~rilling Services ~ ~ Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NADI~S2Z,;,(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD2-6Q ~ U~~~h~ Well Position +N/S O.OOft Northing: 5,974,194.47ft Latitude: 70° 20' 15.835 N +EI-W 0.00 ft Easting: 371,743.77ft Longitude: 151° 2' 26.471 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.90ft vesign ~uc-ou , M~x. ;, Audit Notes: Version: 9 Phase: ACTUAL Tie On Depth: 11,756.04 Vertteal Se~Ylon: Depth From (NDj +N t~S +E/ V11 ~ 4 Di~ection~~ , , . . . ~~~ . f , "~~ ,. ~~~ ~~' . . . ~p~ ~~. ~~t ~~.. . . 36.47 0.00 0.00 180.00 84.00 617.10 CD2-60 gyro (CD2-60PB1) 744.18 11,756.04 CD2-60PB1 (CD2-60PB1) 11,756.04 18,646.54 CD2-60 (CD2-60) CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+~FRAKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 6/17/2005 1: 6/17/2005 1; 7/6/2005 12: Survey ~.~ ~„~,~..., ~ ' Map Illlap 'Verticaf ' MD ? Inc Azi -' 'Nf? t: . NQ8S +Nl~S '+E/ 1N ' Northing Easting ', DLS Sec#ian (~~ (°) (°? (ftl , ~ : (ft? , lft? ' ift) . (ft) (ft) ' (°/10Q'~ (~l , Surv$y Tool Name , ~ 36.47~~ 0.00 ~ r. 0.00 , 36.47 .. -15.90 ~~ 0.00 ~~ 0.00 5,974,194.47 ~371,743.77 0.00 . 0.00 UNDEFINED 84.00 0.00 0.00 84.00 31.63 0.00 0.00 5,974,194.47 371,743.77 0.00 0.00 CB-GYRO-SS (1) 168.00 0.80 184.00 168.00 175.63 -0.58 -0.04 5,974,193.89 371,743.72 0.95 0.58 CB-GYRO-SS (1) 258.00 3.30 185.00 257.93 205.56 -3.79 -0.31 5,974,190.68 371,743.39 2.78 3.79 CB-GYRO-SS (1) 347.00 6.00 193.00 346.63 294.26 -10.8B -1.58 5,974,183.62 371,742.00 3.11 10.88 CB-GYRO-SS (1) 438.00 9.00 193.00 436.84 384.47 -22.45 -4.25 5,974,172.10 371,739.13 3.30 22.45 CB-GYRO-SS (1) 528.00 11.50 182.00 525.41 473.04 -38.28 -6.15 5,974,156.30 371,736.97 3.52 38.28 CB-GYRO-SS (1) 617.00 14.50 182.00 612.12 559.75 -58.29 -6.85 5,974,136.31 371,735.93 3.37 58.29 CB-GYRO-SS (1) 744.18 16.88 188.22 734.56 682.19 -92.48 -10.04 5,974,102.18 371,732.15 2.29 92.48 MWD+IFR-AK-CAZ-SC (2) 834.02 17.19 196.26 820.47 768.10 -118.14 -15.63 5,974,076.63 371,726.13 2.64 118.14 MWD+IFR-AK-CAZ-SC (2) 929.07 20.23 195.79 910.49 858.12 -147.44 -24.03 5,974,047.47 371,717.22 3.20 147.44 MWD+IFR-AK-CAZ-SC (2) 1,024.09 23.34 196.52 998.71 946.34 -181.30 -33.86 5,974,013.79 371,706.82 3.29 181.30 MWD+~FR-AK-CAZ-SC (2) Ri20/2009 9:46:O6AM Page 2 COMPASS 2003.16 Build 69 H,p-LL.~ URT ConocoPhillips ' / Definitive Survey Report ConocoPhillips sE~~~~y csr~€i~i~,~ Alaska HALLIBURTON 9p~rry Clrilling ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2-60 CD2-60 CD2-60 ~ ~ ConocoPhillips ~-' . . ~OCIOCOP~"'11~~I S Definitive Survey Report p Alaska ' ~ ~~ y~ ~~ ~ Lo~al~Co,ordinate~~R~fers~ce , w . ~~. WeII CD2-60 ~~ ~ NQ Reference:, ~ x: CD2-60 ( @ 52.37ft (CD2-60 O MD Referencec~ ~: 'CD2-60 ( @ 52.37ft (CD2-60 O ~ I~orth Reference:~ .. ' True ~_~3urveyCatCUlatiQn`Method~~ ~ MinimumCurvature ~ Database. ~A{ EDM v16 Prod 1,119.22 28.42 193.77 1,084.27 1,031.90 -221.39 -44.61 5,973,973.90 371,695.38 5.49 221.39 MWD+IFR-AK-CAZ-SC (2) 1,213.17 32.65 194.09 1,165.18 1,112.81 -267.70 -56.11 5,973,927.79 371,683.09 4.51 267.70 MWD+IFR-AK-CAZ-SC (2) 1,309.15 34.10 184.48 1,245.33 1,192.86 -318.87 -69.14 5,973,876.86 371,669.19 1.53 315.87 MWD+IFR-AK-CAZ-SC (2) 1,404.64 35.80 195.38 1,323.59 1,271.22 -371.72 -83.24 5,973,824.26 371,654.19 1.86 371.72 MWD+IFR-AK-CAZ-SC (2) 1,500.46 38.34 195.36 1,400.04 1,347.67 -427.41 -98.55 5,973,768.85 371,637.93 2.65 427.41 MWD+IFR-AK-CAZ-SC (2) 1,595.90 41.37 19522 1,473.30 1,420.93 -486.40 -114.67 5,973,710.14 371,620.80 3.18 486.40 MWD+IFR-AK-CAZ-SC (2) 1,690.58 44.57 193.39 1,542.57 1,490.20 -548.93 -130.59 5,973,647.90 371,603.83 3.63 548.93 MWD+IFR-AK-CAZ-SC (2) 1,785.91 49.02 193.45 1,607.82 1,555.45 -616.50 -146.71 5,973,580.62 371,586.55 4.67 616.50 MWD+IFR-AK-CAZ-SC (2) 1,861.20 51.93 192.89 1,666.46 1,616.09 -688.06 -163.45 5,973,509.36 371,568.59 3.09 688.06 MWD+IFR-AK-CAZ-SC (2) 1,976.63 53.12 192.87 1,726.52 1,674.15 -761.69 -180.33 5,973,435.84 371,550.45 1.25 761.89 MWD+tFR-AK-CAZ-SC (2j 2,071.88 55.82 192.29 1,781.86 1,729.49 -837.54 -197.20 5,973,360.50 371,532.29 2.88 837.54 MWD+IFR-AK-CAZ-SC (2) 2,166.16 58,31 192.91 1,833.12 1,780.75 -914.75 -214.47 5,973,283.59 371,513.70 2.70 914.75 MWD+IFR-AK-CAZ-SC (2) 2,261.78 60,53 193.49 1,881.76 1,829.39 -994.69 -233.27 5,973,203.79 371,493.54 2.38 994.89 MWD+IFR-AK-CAZ-SC (2) 2,357.22 60.01 192.35 1,929.09 1,876.72 -1,075.67 -251.80 5,973,123.35 371,473.63 1.17 1,075.67 MWD+IFR-AK-CAZ-SC (2) 2,452.61 59.31 192.59 1,977.28 1,924.91 -1,156.05 -269.58 5,973,043.29 371,454.48 0.77 1,156.05 MWD+IFR-AK-CAZ-SC (2) 2,544.07 60.49 193.57 2,023.14 1,970.77 -1,233.12 -287.49 5,972,966.55 371,435.26 1.59 1,233.12 MWD+~FR-AK-CAZ-SC (2) 2,642.40 62.13 194.08 2,070.35 2,017.98 -1,316.88 -308.10 5,972,883.16 371,413.21 1.73 1,316.88 MWD+IFR-AK-CAZ-SC (2) 2,737.54 62.12 193.93 2,114.83 2,062.46 -1,398.48 -328.46 5,972,801.93 371,391.47 0.14 1,398.48 MWD+IFR-AK-CAZ-SC (2) 2,833.27 61.21 193.57 2,160.27 2,107.90 -1,480.32 -348.49 5,972,720.44 371,370.05 1.01 1,480.32 MWD+IFR-AK-CAZ-SC (2) 2,928.00 60.04 194.01 2,206.73 2,154.36 -1,560.49 -368.18 5,972,640.63 371,349.00 1.30 1,560.49 MWD+IFR-AK-CAZ-SC (2) 3,023.06 60.61 194.07 2,253.80 2,201.43 -1,640.62 -388.20 5,972,560.87 371,327.60 0.60 1,640.62 MWD+IFR-AK-CAZ-SC (2) 3,118.24 62.14 193.67 2,299.39 2,247.02 -1,721.72 -408.22 5,972,480.12 371,306.19 1.65 1,721.72 MWD+IFR-AK-CAZ-SC (2) 3,213.21 62.17 193.22 2,343.75 2,291.38 -1,603.40 -427.75 5,972,398.80 371,285.28 0.42 1,803.40 MWD+IFR-AK-CAZ-SC (2) 3,276.00 62.31 193.32 2,373.00 2,320.63 -1,857.48 ~40.50 5,972,344.95 371,271.60 0.27 1,857.48 MWD+IFR-AK-CAZ-SC (2) ~-5/~~~ x 12 ~~f4" ~ ~ . 3~~~~ ':. ~~ ,, .. 3,268.84 62.34 193.34 2,378.96 2,326$59 -1,668.54 -443.12 5,972,333.93 371,268.79 0.27 1,868.54 MWD+IFR-AK-CAZ-SC (2) 3,383.57 61.69 193.88 2,423.41 2,371.04 -1,949.84 -462.81 5,972,252.98 371,247.72 0.65 1,949.84 MWD+~FR-AK-CAZ-SC (2) 3,479.18 61.27 194.32 2,469.06 2,416.69 -2,031.32 -083.27 5,972,171.88 371,225.87 0.60 2,031.32 MWD+~FR-AK-CAZ-SC (2) 3,573.95 60.70 194.58 2,515.03 2,462.66 -2,111.57 -503.95 5,972,091.99 371,203.82 0.65 2,111.57 MWD+IFR-AK-CAZ-SC (2) 3,669.20 60.40 194.02 2,561.86 2,509.49 -2,191.95 -524.44 5,972,011.99 371,181.96 0.60 2,191.95 MWD+IFR-AK-CAZ-SC (2) 3,764.51 59.64 194.54 2,609.49 2,557.12 -2,271.95 -544.80 5,97t,932.35 371,160.24 0.93 2,271.95 MWD+~FR-AK-CAZ-SC (2) 3,859.72 59.10 195.25 2,657.99 2,605.62 -2,351.12 -565.86 5,971,653.56 371,137.63 0.86 2,351.12 MWD+IFR-AK-CAZ-SC (2) 3,954.74 58.46 194.94 2,707.25 2,654.88 -2,429.58 -587.02 5,971,775.48 371,115.33 0.73 2,429.58 MWD+IFR-AK-CAZ-SC (2) 4,050.12 57.59 195.67 2,757.75 2,705.38 -2,507.62 ~08.37 5,971,697.83 371,092.65 1.12 2,507.62 MWD+IFR-AK-CAZ-SC (2) 4,145.48 56.61 196.45 2,809.55 2,757.18 -2,584.56 -630.52 5,971,621.28 371,069.19 1.24 2,584.56 MWD+IFR-AK-CAZ-SC (2) 4,239.22 57.48 196.34 2,860.54 2,808.17 -2,660.02 -652.72 5,971,546.22 371,045.70 0.93 2,660.02 MWD+IFR-AK-CAZ-SC (2) 4,333.88 58.25 196.82 2,910.89 2,658.52 -2,736.84 -675.59 5,971,469.81 371,021.52 0.92 2,736.84 MWD+IFR-AK-CAZ-SC (2) 4,429.53 58.12 197.20 2,961.32 2,908.95 -2,614.56 ~99.37 5,971,392.51 370,996.42 0.36 2,814.56 MWD+IFR-AK-CAZ-SC (2) 4,524.47 57.69 196.90 3,011.76 2,959.39 -2,691.46 -722.95 5,971,316.03 370,971.53 0.53 2,891.46 MWD+IFR-AK-CAZ-SC (2) 4,621.06 58.40 198.15 3,062.88 3,010.51 -2,969.60 -747.63 5,971,238.33 370,945.52 1.32 2,969.60 MWD+IFR-AK-CAZ-SC (2) 8/20/2009 9:46:06AM Page 3 COMPASS 2003.16 Build 69 -772.80 5,971,159.27 370,919.00 2.32 3,049.11 MWD+IFR-AK-CAZ-$C (2) -796.40 5,971,081.29 370,B94.06 0.80 3,127.51 MWD+IFR-AK-CAZ-SC (2) -820.72 5,971,001.82 370,868.38 0.79 3,207.42 MWD+IFR-AK-CAZ-SC (2) -845.13 5,970,922.38 370,642.61 0.64 3,287.29 MWD+IFR-AK-CAZ-SC (2) -869.07 5,970,843.08 370,817.31 0.58 3,367.01 MWD+IFR-AK-CAZ-SC (2) -893.13 5,970,763.11 370,791.89 0.43 3,447.42 MWD+IFR-AK-CAZ-SC (2) -917.45 5,970,682.61 370,766.18 0.70 3,528.35 MWD+IFR-AK-CAZ-SC (2) -941.64 5,970,601.80 370,740.61 0.73 3,609.59 MWD+IFR-AK-CAZ-SC (2) -965.11 5,970,520.44 370,715.75 0.73 3,691.37 MWD+IFR-AK-CAZ-SC (2) -987.96 5,970,436.94 370,691.50 0.40 3,773.29 MWD+IFR-AK-CAZ-SC (2) -1,010.37 5,970,356.42 370,667.68 0.63 3,856.20 MWD+IFR-AK-CAZ-SC (2) -1,031.76 5,970,274.08 370,644.88 0.72 3,938.93 MWD+IFR-AK-CAZ-SC (2) -1,052.86 5,970,191.35 370,622.34 1.22 4,022.04 MWD+IFR-AK-CAZ-SC (2) -1,073.46 5,970,108.28 370,600.34 1.42 4,105.48 MWD+IFR-AK-CAZ-SC (2) -1,092.20 5,970,027.13 370,580.21 0.73 4,186.97 MWD+IFR-AK-CAZ-SC (2) -1,110.60 5,969,942.12 370,560.35 1.08 4,272.31 MWD+IFR-AK-CAZ-SC (2) -1,126.82 5,969,858.66 370,542.71 2.23 4,356.08 MWD+IFR-AK-CAZ-SC (2) -1,140.62 5,969,777.13 370,527.51 1.61 4,437.86 MWD+IFR-AK-CAZ-SC (2) -1,154.59 5,969,694.59 370,512.13 1.07 4,520.66 MWD+IFR-AK-CAZ-SC (2) -1,169.32 5,969,613.16 370,496.00 0.34 4,602.36 MWD+IFR-AK-CAZ-SC (2) -1,184.66 5,969,531.79 370,479.27 0.69 4,684.01 MWD+IFR-AK-CAZ-SC (2) -1,200.89 5,969,450.45 370,461.64 0.56 4,765.64 MWD+IFR-AK-CAZ-SC (2) -1,218.51 5,969,369.16 370,442.64 1.21 4,647.25 MWD+IFR-AK-CAZ-SC (2) -1,236.20 5,969,290.74 370,423.61 0.36 4,925.99 MWD+~FR-AK-CAZ-SC (2) -1,255.78 5,969,207.36 370,402.59 1.24 5,009.73 MWD+IFR-AK-CAZ-SC (2) -1,276.50 5,969,126.27 370,380.48 0.82 5,091.19 MWD+IFR-AK-CAZ-SC (2) -1,297.68 5,969,045.51 370,357.93 0.39 5,172.33 MWD+IFR-AK-CAZ-SC (2) -1,318.45 5,968,964.72 370,335.77 0.86 5,253.50 MWD+IFR-AK-CAZ-SC (2) -1,339.30 5,968,882.75 370,313.52 0.28 5,335.84 MWD+IFR-AK-CAZ-SC (2) -1,359.11 5,968,800.73 370,292.31 1.39 5,418.21 MWD+IFR-AK-CAZ-SC (2) -1,376.88 5,968,718.19 370,273.12 1.28 5,501.08 MWD+IFR-AK-CAZ-SC (2) -1,393.15 5,968,635.55 370,255.44 0.79 5,584.01 MWD+IFR-AK-CAZ-SC (2) -1,409.35 5,968,551.66 370,237.80 0.30 5,668.20 MWD+~FR-AK-CAZ-SC (2) -1,424.29 5,968,46929 370,221.45 2.14 5,750.85 MWD+~FR-AK-CAZ-SC (2) -1,437.91 5,968,389.15 370,206.46 1.01 5,831.24 MWD+~FR-AK-CAZ-SC (2) -1,451.92 5,968,306.10 370,191.03 1.44 5,914.55 MWD+IFR-AK-CAZ-SC (2) -1,464.91 5,968,225.71 370,176.66 1.18 5,995.18 MWD+IFR-AK-CAZ-SC (2) -1,477.82 5,968,145.94 370,162.38 0.39 6,075.18 MWD+IFR-AK-CAZ-SC (2) -1,491.08 5,968,067.81 370,147.79 0.48 6,153.56 MWD+IFR-AK-CAZ-SC (2) -1,505.44 5,967,986.55 370,132.04 0.71 6,235.08 MWD+IFR-AK-CAZ-SC (2) ~ ~ HALLiBIJRTON ConocoPhillips ' `-' . . Definitive Survey Report ConocoPhillips ~perry Clrilling Alaska : 8/20/2009 9:46:O6AM Page 4 COMPASS 2003.16 Build 69 HALLIB~.lRTON sp~~~-y ca~~i~~n~ • ConocoPhillips • ~' . . < Definitive Survey Report Cono~oPh~ll~ps Alaska : 8,522.28 59.78 189.71 4,903.59 4,851.22 $,315.67 -1,519.53 5,967,906.22 370,116.57 0.79 6,315.67 MWD+IFR-AK-CAZ-SC (2) 8,616.29 59.84 1B8.80 4,950.67 4,898.50 -6,395.87 -1,532.60 5,967,826.26 370,102.13 0.84 6,395.87 MWD+IFR-AK-CAZ-SC (2) 8,712.56 60.14 189.41 4,999.02 4,946.65 -6,478.19 -1,545.79 5,967,744.20 370,087.53 0.63 6,478.19 MWD+IFR-AK-CAZ-SC (2) 8,805.97 60.56 188.99 5,04523 4,882.66 -6,558.32 -1,558.77 5,967,664.30 370,073.19 0.60 6,558.32 MWD+IFR-AK-CAZ-SC (2) 8,902.82 60.99 189.16 5,092.51 5,040.14 -6,641.78 -1,572.10 5,967,581.08 370,058.43 0.47 6,641.78 MWD+IFR-AK-CAZ-SC (2) 8,998.14 61.47 188.88 5,138.39 5,086.02 -6,724.30 -1,585.20 5,967,498.81 370,043.92 0.57 6,724.30 MWD+IFR-AK-CAZ-SC (2) 9,092.80 61.97 188.64 5,183.24 5,130.87 ~,606.69 -1,597.90 5,967,416.65 370,029.82 0.57 6,806.69 MWD+~FR-AK-CAZ-SC (2) 9,187.84 61.60 189.39 5,228.17 5,175.80 ~,889.40 -1,611.02 5,967,334.19 370,015.29 0.80 6,889.40 MWD+IFR-AK-CAZ-SC (2) 9,283.26 61.19 189.96 5,273.85 5,221.48 -6,971.99 -1,625.10 5,967,251.86 369,999.80 0.68 6,971.99 MWD+~FR-AK-CAZ-SC (2) 9,378.60 61.47 192.05 5,319.60 5,267.23 -7,054.09 -1,641.07 5,967,170.05 369,982.43 1.95 7,054.09 MWD+IFR-AK-CAZ-SC (2) 9,474.07 62.10 192.86 5,364.74 5,312.37 -7,136.24 -1,659.21 5,967,088.23 369,962.69 1.00 7,13624 MWD+IFR-AK-CAZ-SC (2) 9,568.31 62.10 193.10 5,408.83 5,356.46 -7,217.39 -1,677.92 5,967,007.41 369,942.60 0.23 7,217.39 MWD+IFR-AK-CAZ-SC (2) 9,671.97 61.25 193.83 5,458.02 5,405.65 -7,306.13 -1,699.16 5,966,919.06 369,920.04 1.03 7,306.13 MWD+IFR-AK-CAZ-SC (2) 9,759.37 60.98 193.98 5,500.24 5,447.87 -7,380.42 -1,717.55 5,966,845.11 369,900.38 0.34 7,380.42 MWD+IFR-AK-CAZ-SC (2) 9,854.75 61.26 19425 5,546.30 5,493.93 -7,461.41 -1,737.92 5,966,764.48 369,876.63 0.38 7,461.41 MWD+IFR-AK-CAZ-SC (2) 9,949.47 61.67 194.58 5,591.55 5,539.18 -7,542.01 -1,758.64 5,966,684.26 369,856.55 0.53 7,542.01 MWD+IFR-AK-CAZ-SC (2) 10,045.09 60.57 194.12 5,637.73 5,585.36 -7,623.12 -1,779.39 5,966,603.52 369,834.41 1.23 7,623.12 MWD+IFR-AK-CAZ-SC (2) 10,139.72 60.48 191.52 5,684.30 5,631.93 -7,703.44 -1,797.67 5,966,523.53 369,814.76 2.39 7,703.44 MWD+IFR-AK-CAZ-SC (2) 10,234.56 60.76 191.18 5,730.83 5,678.46 -7,784.47 -1,613.93 5,966,442.80 369,797.12 0.43 7,784.47 MWD+~FR-AK-CAZ-SC (2) 10,329.64 61.09 190.89 5,777.03 5,724.66 -7,866.03 -1,829.84 5,966,361.53 369,779.82 0.44 7,866.03 MWD+IFR-AK-CAZ-SC (2) 10,425.25 61.43 191.65 5,823.01 5,770.64 -7,948.24 -1,846.22 5,966,279.61 369,762.03 0.78 7,948.24 MWD+~FR-AK-CAZ-SC (2) 10,520.33 61.93 191.82 5,868.11 5,8t5.74 -8,030.19 -1,863.24 5,966,197.97 369,743.61 0.55 8,030.19 MWD+~FR-AK-CAZ-SC (2) 10,615.81 61.96 192.53 5,913.02 5,660.65 -8,112.56 -1,881.02 5,966,115.93 369,724.44 0.66 8,112.56 MWD+~FR-AK-CAZ-SC (2) 10,711.00 62.05 192.87 5,957.70 5,905.33 -8,194.55 -1,899.49 5,966,034.27 369,704.56 0.33 8,194.55 MWD+IFR-AK-CAZ-SC (2) 10,806.33 62.37 193.98 6,002.15 5,949.78 -8,276.58 -1,919.07 5,965,952.59 369,683.58 1.08 8,276.58 MWD+IFR-AK-CAZ-SC (2) 10,901.41 62.65 194.31 6,046.03 5,993.66 -8,358.37 -1,939.69 5,965,871.18 369,661.57 0.43 8,358.37 MWD+IFR AK-CAZ-SC (2) 10,996.35 63.15 194.20 6,089.28 6,036.91 -8,440.28 -1,960.50 5,965,789.64 369,639.37 0.54 8,44028 MWD+IFR-AK-CAZ-SC (2) 11,092.11 63.43 194.20 6,132.33 6,079.96 -8,523.21 -1,981.48 5,965,707.09 369,616.97 029 8,52321 MWD+IFR-AK-CAZ-SC (2) 11,184.83 63.06 194.34 6,174.07 6,121.70 -8,603.45 -2,001.89 5,965,627.22 369,595.19 0.42 8,603.45 MWD+IFR AK-CAZ-SC (2) 11,260.17 62.37 194.30 6,217.77 6,165.40 -8,685.55 -2,022.85 5,965,545.50 369,572.84 0.72 8,685.55 MWD+~FR-AK-CAZ-SC (2) 11,375.42 61.62 192.82 6,262.50 6,210.13 -8,767.29 -2,042.57 5,965,464.10 369,551.72 1.58 8,767.29 MWD+IFR-AK-CAZ-SC (2) 11,470.52 61.21 192.48 6,308.00 6,255.63 -8,848.77 -2,060.86 5,965,382.95 369,532.05 0.53 8,848.77 MWD+IFR-AK-CAZ-SC (2) 11,565.32 60.80 192.07 6,353.95 6,301.58 -8,929.80 -2,078.46 5,965,302.25 369,513.04 0.57 8,929.80 MWD+IFR-AK-CAZ-SC (2) 11,660.75 60.39 792.53 6,400.61 6,348.44 -9,011.02 -2,096.19 5,965,221.35 369,493.94 0.60 9,D11.02 MWD+IFR-AK-CAZ-SC (2) 11,756.04 59.73 193.55 6,448.37 6,396.00 -9,091.47 -2,114.82 5,965,141.24 369,473.94 1.16 9,091.47 MWD+IFR-AK-CAZ-SC (2) 11,760.00 59.72 193.53 6,450.36 6,397.99 -9,094.79 -2,115.62 5,965,137.93 369,473.08 0.50 9,094.79 MWD+IFR-AK-CAZ-SC (3) 11,784.81 59.43 195.34 6,462.93 6,410.56 -9,115.51 -2,120.96 5,965,117.31 369,467.40 6.40 9,115.51 MWD+IFR-AK-CAZ-SC (3) 11,816.65 59.89 196.85 6,479.01 6,426.64 -9,141.91 -2,128.57 5,965,091.05 369,459.33 4.34 9,141.91 MWD+IFR-AK-CAZ-SC (3) 11,860.14 60.32 197.58 6,500.69 6,448.32 -9,177.92 -2,139.73 5,965,055.23 368,447.56 1.76 9,177.92 MWD+IFR-AK-CAZ-SC (3) 11,912.35 60.60 197.43 6,526.43 6,474.06 -9,221.24 -2,153.40 5,965,012.15 369,433.16 0.59 9,22124 MWD+IFR-AK-CAZ-SC (3) 8/20/2009 9:46:06AM Page 5 COMPASS 2003.16 Build 69 I Survev ~ I . ~ HALLIBURTON "r~perry CJrilline~ ConocoPhillips ~ ~-' . . ,' Definitive Survey Report COIlG1COP~'11~~Ip5 Alaska '' 11,957.12 61.08 197.26 6,548.24 6,495.87 -9,258.56 -2,165.06 5,964,975A5 369,420.86 1.11 9,258.56 MWD+~FR-AK-CAZ-SC (3) 12,006.74 62.72 198.81 6,571.61 6,519.24 -9,300.17 -2,178.62 5,964,933.67 369,406.59 4.28 9,300.17 MWD+IFR-AK-CAZ-SC (3) 12,101.96 62.44 198.97 6,615.46 6,563.09 -9,380.14 -2,205.98 5,964,854.19 369,377.86 0.33 9,380.14 MWD+IFR-AK-CAZ-SC (3) 12,197.22 63.21 199.73 6,658.97 6,606.60 -9,460.10 -2,234.06 5,964,774.73 369,348.42 1.06 9,460.10 MWD+IFR-AK-CAZ-SC (3) 12,292.14 62.75 199.26 6,702.09 6,649.72 -9,539.81 -2,262.26 5,964,695.52 369,318.84 0.66 9,539.81 MWD+IFR-AK-CAZ-SC (3) 12,386.75 61.79 200.03 6,746.11 6,693.74 -9,618.68 -2,290.43 5,964,617.15 369,289.35 1.24 9,618.68 MWD+IFR-AK-CAZ-SC (3) 12,481.91 62.75 197.55 6,790.40 6,738.03 -9,698.41 -2,317.55 5,964,537.90 369,260.87 2.52 9,698.41 MWD+IFR-AK-CAZ-SC (3) 12,577.23 62.29 195.87 6,634.38 6,782.01 -9,779.40 -2,341.87 5,964,457.35 369,235.18 1.64 9,779.40 MWD+IFR-AK-CAZ-SC (3) 12,672.55 63.42 193.14 6,877.88 6,825.51 -9,661.51 -2,363.10 5,964,375.62 369,212.55 2.81 9,861.51 MWD+IFR-AK-CAZ-SC (3) 12,767.62 63.10 188.16 6,920.68 6,868.31 -9,944.91 -2,378.79 5,964,292.51 369,195.44 4.69 9,944.91 MWD+IFR-AK-CAZ-SC (3) 12,862.29 64.34 183.72 6,962.61 6,910.24 -10,029.31 -2,387.56 5,964,208.27 369,185,23 4.40 10,029.31 MWD+IFR-AK-CAZ-SC (3) 12,957.63 64.53 180.83 7,003.76 6,951.39 -10,115.24 -2,390.97 5,964,122.43 369,180.35 2.74 10,115.24 MWD+IFR-AK-CAZ-SC (3) 13,053.01 66.13 182.25 7,043.57 6,991.20 -10,201.87 -2,393.30 5,964,035.85 369,176.53 2.16 10,201.87 MWD+~FR-AK-CAZ-SC (3) 13,148.30 67.05 182.53 7,081.43 7,029.06 -10,289.24 -2,396.95 5,963,946.56 369,171.39 1.00 10,289.24 MWD+IFR-AK-CAZ-SC (3) 13,243.79 66.54 181.86 7,119.05 7,066.68 -10,376.94 -2,400.31 5,963,860.94 369,166.53 0.84 10,376.94 MWD+IFR-AK-CAZ-SC (3) 13,288.80 66.74 181.40 7,136.90 7,084.53 -10,418.25 -2,401.49 5,963,819.67 369,164.65 1.04 10,418.25 MWD+IFR-AK-CAZ-SC (3) 13,339.33 66.93 178.89 7,156.78 7,104.41 -10,464.70 -2,401.60 5,963,77323 369,163.74 4.58 10,464.70 MWD+IFR-AK-CAZ-SC (3) 13,385.03 67.46 177,92 7,174.50 7,122.13 -10,506.81 -2,400.43 5,963,731.11 369,164.19 2.27 10,506.81 MWD+~FR-AK-CAZ-SC (3) 13,434.52 68.24 175.83 7,193.16 7,140.79 -10,552.57 -2,397.93 5,963,685.31 369,165.91 4.22 10,552.57 MWD+IFR-AK-CAZ-SC (3) 13,479.56 69.55 173.71 7,209.38 7,157.01 -10,594.41 -2,394.10 5,963,643.41 369,169.02 5.27 10,594.41 MWD+IFR-AK-CAZ-SC (3) 13,529.67 71.05 171.98 7,226.27 7,173.90 -10,641.22 -2,388.22 5,963,596.52 369,174.10 4.42 10,641.22 MWD+IFR-AK-CAZ-SC (3) 13,575.15 72.19 171.09 7,240.61 7,188.24 -10,683.91 -2,381.86 5,963,553.73 369,179.72 3.12 10,683.91 MWD+IFR-AK-CAZ-SC (3) 13,624.99 73.52 168.48 7,255.30 7,202.93 -10,730.77 -2,373.42 5,963,506.73 369,187.37 5.67 10,730.77 MWD+IFR-AK-CAZ-SC (3) 13,670.44 74.73 167.38 7,267.74 7,215.37 -10,773.52 -2,364.27 5,963,463.84 369,195.78 3.54 10,773.52 MWD+IFR-AK-CAZ-SC (3) 13,720.18 75.32 166.34 7,280.59 7,228.22 -10,820.31 -2,353.35 5,963,416.87 369,205.90 2.34 10,820.31 MWD+IFR-AK-CAZ-SC (3) 13,765.66 76.16 165.17 7,291.79 7,239.42 -10,863.03 -2,342.50 5,963,373.97 369,216.01 3.10 10,863.03 MWD+IFR-AK-CAZ-SC (3) 13,815.23 77.42 163.86 7,303.12 7,250.75 -10,909.54 -2,329.62 5,963,327.26 369,228.10 3.62 10,909.54 MWD+IFR-AK-CAZ-SC (3) 13,859.97 77.97 162.30 7,312.65 7,260.28 -10,957.35 -2,316.90 5,963,285.23 369,240.10 3.62 10,951.35 MWD+IFR-AK-CAZ-SC (3) 13,910.74 78.83 160.66 7,322.86 7,270.49 -10,998.51 -2,301.10 5,963,237.82 369,255.09 3.59 10,998.51 MWD+~FR-AK-CAZ-SC (3) 13,958.14 79.45 159.34 7,331.79 7,279.42 -11,042.25 -2,285.18 5,963,193.81 369,270.26 3.03 11,042.25 MWD+IFR-AK-CAZ-SC (3) 14,005.92 80.69 158.42 7,340.03 7,287.66 -11,086.15 -2,268.22 5,963,149.63 369,286.47 3.21 11,086.15 MWD+IFR-AK-CAZ-SC (3) 14,051.33 82.15 157.03 7,346.81 7,294.44 -11,127.70 -2,251.20 5,963,107.80 369,302.77 4.42 11,127.70 MWD+IFR-AK-CAZ-SC (3) 14,101.21 82.45 155.21 7,353.49 7,301.12 -11,172.90 -2,231.19 5,963,062.27 369,322.00 3.67 11,172.90 MWD+IFR-AK-CAZ-SC (3) 14,148.67 82.57 153.80 7,359.68 7,307.31 -11,215.37 -2,210.93 5,963,019.46 369,341.53 2.96 11,215.37 MWD+IFR-AK-CAZ-SC (3) 14,196.11 83.38 152.19 7,365.48 7,313.11 -11,257.32 -2,189.56 5,962,977.16 369,362.18 3.78 11,257.32 MWD+IFR-AK-CAZ-SC (3) 14,255.03 83.97 150.35 7,371.97 7,319.60 -11,306.67 -2,161.41 5,962,925.34 369,389.45 3.26 11,308.67 MWD+IFR-AK-CAZ-SC (3) 14,300.06 85.37 149.17 7,376.16 7,323.79 -11,347.40 -2,138.83 5,962,886.23 369,411.36 4.06 11,347.40 MWD+IFR-AK-CAZ-SC (3) 14,331.00 85.81 148.75 7,378.54 7,326.17 -11,373.83 -2,122.92 5,962,859.54 369,426.81 1.96 11,373.83 MWD+IFR-AK-CAZ-SC (3) 7" x 8~1/2"' ~ ~ ~ ~ _ 14,354.80 86.14 148.42 7,380.21 7,327.84 -11,394.09 -2,110.54 5,962,839.07 369,438.84 1.96 11,394.09 MWD+IFR-AK-CAZ-SC (3) 8/20/2009 9:46:O6AM Page 6 COMPASS 2003.16 Build 69 . .~ ~ HALLIBURTON ~~aerry CJrt~lir,g ConocoPhillips ~ ti-' . . , Definitive Survey Report C0118COP~'ll~~l~?S' Alaska'' 14,449.31 67.19 148.66 7,385.71 7,333.34 -11,474.58 -2,061.32 5,962,757.76 369,486.68 1.14 11,474.58 MWD+IFR-AK-CAZ-SC (3) 14,546.08 68.39 147.27 7,389.44 7,337.07 -11,556.56 -2,010.04 5,962,674.92 369,536.54 1.91 11,556.56 MWD+IFR-AK-CAZ-SC (3) 14,569.72 90.18 147.96 7,389.98 7,337.61 -11,593.41 -1,986.67 5,962,637.68 369,558.27 4.40 11,593.41 MWD+~FR-AK-CAZ-SC (3) 14,641.43 90.86 149.14 7,389.51 7,337.14 -11,637.52 -1,959.69 5,962,593.12 369,565.49 2.63 11,637.52 MWD+IFR-AK-CAZ-SC (3) 14,686.50 90.43 150.04 7,389.01 7,336.64 -11,676.38 -1,936.88 5,962,553.87 369,607.63 2.21 11,676.38 MWD+IFR-AK-CAZ-SC (3) 14,736.79 89.07 150.71 7,389.23 7,336.86 -11,720.10 -1,912.02 5,962,509.74 369,631.74 3.01 11,720.10 MWD+IFR-AK-CAZ-SC (3) 14,780.36 87.90 149.82 7,390.38 7,338.01 -11,757.92 -1,890.42 5,962,471.56 369,652.69 3.37 11,757.92 MWD+IFR-AK-CAZ-SC (3) 14,832.12 67.59 15029 7,392.41 7,340.04 -11,802.73 -1,864.60 5,962,426.31 369,677.73 1.09 11,802.73 MWD+IFR-AK-CAZ-SC (3) 14,883.51 67.90 150.84 7,394.44 7,342.07 -11,847.45 -1,839.37 5,962,381.17 369,702.20 1.23 11,647.45 MWD+IFR-AK-CAZ-SC (3) 14,927.34 88.54 150.90 7,395.60 7,343.43 -11,885.72 -1,818.04 5,962,342.55 369,722.86 1.47 11,885.72 MWD+IFR-AK-CAZ-SC (3) 15,023.42 88.60 151.27 7,398.20 7,345.83 -11,969.80 -1,771.60 5,962,257.70 369,767.66 0.39 11,969.80 MWD+~FR-AK-CAZ-SC (3) 15,118.97 89.46 150.77 7,399.81 7,347.44 -12,053.37 -1,725.31 5,962,173.35 369,812.70 1.04 12,053.37 MWD+~FR-AK-CAZ-SC (3) 15,214.30 89.87 150.92 7,400.37 7,348.00 -12,136.62 -1,678.87 5,962,089.32 369,857.71 0.46 12,136.62 MWD+~FR-AK-CAZ-SC (3) 15,309.92 89.03 150.89 7,401.29 7,348.92 -12,220.17 -1,632.36 5,962,005.00 369,902.76 0.88 12,220.17 MWD+IFR-AK-CAZ-SC (3) 15,405.71 68.82 152.05 7,403.09 7,350.72 -12,304.31 -1,586.64 5,961,920.09 369,947.06 1.23 12,304.31 MWD+IFR-AK-CAZ-SC (3) 15,501.24 88.30 150.31 7,405.49 7,353.12 -12,387.98 -1,540.60 5,961,835.66 369,991.65 1.90 12,387.98 MWD+IFR-AK-CAZ-SC (3) 15,596.62 89.56 150.52 7,407.27 7,354.90 -12,470.91 -1,493.52 5,961,751.94 370,037.30 1.34 12,470.91 MWD+IFR-AK-CAZ-SC (3) 15,691.84 68.88 150.87 7,408.56 7,356.19 -12,553.93 -1,446.92 5,961,668.14 370,082.47 0.80 12,553.93 MWD+~FR-AK-CAZ-SC (3) 15,787.04 88.33 750.58 7,410.88 7,358.51 -12,636.95 -1,400.38 5,961,584.35 370,127.58 0.65 12,636.95 MWD+IFR-AK-CAZ-SC (3) 15,882.59 88.54 150.07 7,413.49 7,361.12 -12,719.94 -1,353.09 5,961,500.57 370,173.44 0.58 12,719.94 MWD+IFR-AK-CAZ-SC (3) 15,978.01 89.81 147.00 7,414.87 7,362.50 -12,801.31 -1,303.30 5,961,418.37 370,221.83 3.48 12,801.31 MWD+IFR-AK-CAZ-SC (3) 16,073.24 69.44 146.70 7,415.49 7,363.12 -12,881.04 -1,251.22 5,961,337.77 370,272.53 0.50 12,881.04 MWD+IFR-AK-CAZ-SC (3) 16,168.71 89.27 146.14 7,416.56 7,364.19 -12,960.57 -1,198.42 5,961,257.35 370,323.96 0.67 12,960.57 MWD+IFR-AK-CAZ-SC (3) 16,264.54 88.97 146.66 7,418.03 7,365.67 -13,040.38 -1,145.40 5,961,176.65 370,375.61 0.63 13,040.38 MWD+IFR-AK-CAZ-SC (3) 16,359.79 68.30 147.89 7,420.30 7,367.93 -13,120.48 -1,093.92 5,961,095.68 370,425.70 1.47 13,120.48 MWD+IFR-AK-CAZ-SC (3) 16,455.44 87.43 147.55 7,423.87 7,371.50 -13,201.29 -1,042.86 5,961,014.02 370,475.36 0.98 13,201.29 MWD+IFR-AK-CAZ-SC (3) 16,550.91 86.88 149.11 7,428.61 7,376.24 -13,282.44 -992.81 5,960,932.03 370,524.02 1.73 13,282.44 MWD+IFR-AK-CAZ-SC (3) 16,646.16 8829 149.32 7,432.62 7,380.25 -13,364.20 -944.11 5,960,649.46 370,571.31 1.50 13,364.20 MWD+IFR-AK-CAZ-SC (3) 16,741.73 89.07 151.38 7,434.82 7,382.45 -13,447.23 -896.85 5,960,765.64 370,617.15 2.30 13,447.23 MWD+~FR-AK-CAZ-SC (3) 16,636.92 89.09 150.07 7,436.35 7,383.98 -13,530.25 -850.30 5,960,681.84 370,662.26 1.38 13,530.25 MWD+~FR-AK-CAZ-SC (3) 16,932.28 88.85 150.87 7,438.06 7,385.69 -13,613.20 -803.31 5,960,598.10 370,707.82 0.88 13,613.20 MWD+IFR-AK-CAZ-SC (3) 17,026.68 87.87 150.90 7,440.77 7,388.40 -13,695.64 -757.40 5,960,514.90 370,752.31 1.04 13,695.64 MWD+IFR-AK-CAZ-SC (3) 17,123.05 87.50 150.59 7,444.66 7,392.29 -13,779.65 -710.34 5,960,430.10 370,797.92 0.50 13,779.65 MWD+IFR-AK-CAZ-SC (3) 17,218.65 89.16 151.28 7,447.44 7,395.07 -13,863.17 -663.92 5,960,345.81 370,842.90 1.88 13,863.17 MWD+IFR-AK-CAZ-SC (3) 17,313.89 91.20 151.48 7,447.15 7,394.78 -13,946.77 -618.30 5,960,261.45 370,887.08 2.15 13,946.77 MWD+IFR-AK-CAZ-SC (3) 17,409.38 90.82 151.84 7,445.46 7,393.09 -14,030.80 -572.96 5,960,176.66 370,930.95 0.55 14,030.80 MWD+IFR-AK-CAZ-SC (3) 17,504.07 91.60 151.98 7,443.46 7,391.09 -14,114.32 -528.41 5,960,092.40 370,974.09 0.84 14,114.32 MWD+IFR-AK-CAZ-SC (3) 17,600.16 92.09 151.40 7,440.37 7,388.00 -14,198.87 ~82.86 5,960,007.09 371,018.18 0.79 14,198.87 MWD+~FR-AK-CAZ-SC (3) 17,695.28 91.50 150.81 7,437.39 7,385.02 -14,282.11 -436.92 5,959,923.08 371,062.69 0.88 14,252.11 MWD+IFR-AK-CAZ-SC (3) 17,790.88 92.24 149.76 7,434.27 7,381.90 -14,365.09 -389.56 5,959,839.31 371,108.62 1.34 14,365.09 MWD+IFR-AK-CAZ-SC (3) 8/20/2009 9:46:06AM Page 7 COMPASS 2003.16 Build 69 ~ surve~r ~ ~ 17,886.50 91.62 17,981.89 91.07 18,077.64 91.75 18,172.97 93.30 18,268.37 95.89 18,363.68 95.58 18,459.53 95.33 18,554.79 94.90 18,646.54 94.71 18,695.00 94.71 149.96 150.61 150.43 150.66 150.71 150.18 149.81 150.54 149.94 149.94 7,431.05 7,428.81 7,426.45 7,422.25 7,414.61 7,405.09 7,395.98 7,387.48 7,379.80 7,375.82 7,378.68 -14,447.75 7,376.44 -14,530.58 7,374.08 -14,613.90 7,369.88 -14,696.83 7,362.24 -14,779.74 7,352.72 -14,862.23 7,343.61 -14,944.66 7,335.11 -15,027.17 7,327.43 -15,106.54 7,323.45 -15,148.34 -294.33 5,959,672.23 371,200.99 -247.23 5,959,588.12 371,246.66 -200.40 5,959,504.41 371,292.06 -153.84 5,959,420.73 371,337.18 -107.07 5,959,337.45 371,382.55 -59.35 5,959,254.03 371,428.64 -12.16 5,959,170.93 371,474.61 33.22 5,959,090.80 371,516.62 57.41 5,959,048.59 371,542.09 0.69 14,447.75 MWD+IFR-AK-CAZ-SC (3) 0.88 14,530.58 MWD+IFR-AK-CAZ-SC (3) 0.73 14,613.90 MWD+IFR-AK-CAZ-SC (3) 1.64 14,696.83 MWD+IFR-AK-CAZ-SC (3) 2.72 14,779.74 MWD+IFR-AK-CAZ-SC (3) 0.64 14,862.23 MWD+~FR-AK-CAZ-SC (3) 0.46 14,944.86 MWD+IFR-AK-CAZ-SC (3) 0.89 15,027.17 MWD+IFR-AK-CAZ-SC (3) 0.68 15,106.54 MWD+IFR-AK-CAZ-SC (3) 0.00 15,148.34 PROJECTED to TD 8/20/2009 9:46:O6AM Page 8 COMPASS 2003.16 Build 69 HALLIBURT ~ ConocoPhillips ~ ti--' . . Definitive Survey Report Cono~oPhillips Sperry E.~r~ll~nc~ Alaska ~~ ~~ ~ 4 4~ ~ ~' ~ ~" ` ~ ~°~~~ i E`~ r ~ ~ 3 ~ s ~ ~~ ~ ~, ~ ~~,u' ~ ~ '~ ~" ~ ~ " ~ ~~ ~ ~ ~~., ~ ~~ ~ t ~ ~.w ~ ~ ~ ~ ~~ ~ " ~ ~ ~ ~ ~ ~ ~ r ~~ ~ ~ ~`'y~ ~ €~ ~ 4 ~ SEAN PARNELL, GOVERNOR ~~ ~~ ~ ~~ ~ ~ ~ ~ ~ g « ~~ ~ ~ ~ ~-7~ ~~ t~isi/ Vr~-7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T CODII~IISSIOrIT ~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 a FAX (907) 276-7542 Mr. John Peirce Wells Engineer ConocoPhillips Alaska Inc. P.O. Box 100360 ~ a ~ Anchorage, Alaska 99510 ~ ~ ~ -- ~0 Re: Colville River Field, Alpine Oil Pool, CD2-60 ~ Sundry Number: 309-282 Dear Mr. Peirce: ~ :~'-~ ~'., ~.~~~ ,,,,~: ~p~tt~~I~ 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 Cornmission 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 uniess rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this C~~of Au st 2009 - y $~ ~ Encl. ~ ~~,a~ ~~~~~~~~~ ~p STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ;~~~; ~~~ ~~~~ ~'~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~~~~ ~i~ ~~ ~9`=~~ 4 G~r~, S;~~y~ rE~r~~ ;T.i 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ -~-» -~ .:f~ Waiver Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time E~ension ~ cutdnbing Pack,er Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploretory ^ 205-068 • 3. Address: Stratigraphic ~ Service Q, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20511-00 • 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 Requires? Yes ^ NO ~ CD2-60 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075, 380077 ' RKB 37' , Colville River Field / Alpine Oil Pool ~ 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective oepth nn~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18695' , 7376' ' 18695' ' 7376' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 3224' 9-5/8" 3276' 2377' PRODUCTION 14279' 7" 14331' 73~8~ OPEN HOLE 4364' 5-1/2" 18695' 7375 PerForation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 4.5" L-80 13104' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier pkr @ 13033' Camco'DB' nipple @ 231T 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 17, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q' GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name JOhn PeirCe Title: Wells Engineer Signature ~ ` Phone 265-6471 Date 8~+ Z~~~ Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness ~- Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: / n T~Q Y [J f y ~ ,h~ ; ~ ~'' APPROVED BY ~ Approved by: ,~ OMMISSIONER THE COMMISSlON Date: ~ Form 10-4~'Revised 06/2(~6 ~ Sub it in Duplicate ~ ; ~ .~,~ ~~: r~~_i~; .~. ~s, ~~Q~ y~.- ~%y~ /S~ G'~~ ``";~i e/ ~-/~/-ot °~ CD2-60 Proposed Procedure for Pre-Rig S/T Premier Packer Cut ~ CD2-60 is an Alpine injector that will not take injection, thus it has been scheduled for a Rig Sidetrack to begin in mid-September 2009. A Baker Premier Packer in the exiting completion at 13033' RKB is to be cut by E-line using a chemical cutter before the rig moves on location. A successful cut of the inner mandrel sleeve located in the base of the packer will enable the rig to pickup the tubing string and release the packer. A cut inner mandrel sleeve enables the Premier Packer to release so that the entire tubing string can be pulled in one trip by the rig. Procedure: Slickline: 1) Pull the A-1 injection valve (1.25" min ID) from the Camco DB Nipple at 2317' RKB. 2) Drift the tubing with a 3.7" gauge ring to ~13092' RKB (to the 3.75" ID XN Nipple). E-line: 3) Fire a string shot across the Premier Packer located at 13033' RKB. 4) Run Caliper log from the tubing tail at 13103' RKB to surface, focusing on getting good data across the Premier Packer at 13033' RKB before making a Packer cut. 5) RIH with Chem Cutter. Make passes to position to make a cut within a 2' window at the base of the Premier Packer at 13033' RKB. Cut the inner mandrel sleeve located at the base of the packer. 6) Run a post-cut Caliper from the tubing tail at 13103' RKB to ~13000' RKB to verify a good cut and proper cut placement location before the rig arrives. 7) Make another Chem cut to cut the packer inner mandrel sleeve (repeat step 6), if cut quality or the placement appear inadequate to enable successful release of the packer. JWP 8/12/2009 ~y' I ` . Cc~nt~~~-~hilli~~ Af~~k~, 1n~c: iUBING (0-13104, OD:4500, ID:3.958) 'RODUCTION (0-14331, OD:7.000, W ~26.00) SURFACE (0-3276, OD 9.625, W~~.36.00) Gas Lifl - andrel/Dummy Valve 1 (8641-8642, OD:5.984) PACKER ;13033-13034, OD:5.970) NIP ;13092-13093, OD:5.000) W LEG ;13'103-13104, OD:5.000) OPEN HOLE ;14331-18695, OD:6.125) ' ' 1 ~ ALPINE CD2-60 RECEIVED STATE OF ALASKA APR 2 4 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA1IS Gas Cons. Commission 1. Operations Performed: Abandon Repair Well Plug Perforations Stimulate E efi€h0ragc Alter Casing Pull Tubing Perforate New Pool Waiver Time Extension Change Approved Program Operat. Shutdown❑ Perforate Re -enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 205 -068 3. Address: Stratigraphic Service 0 6. API Number P. O. Box 100360, Anchorage, Alaska 99510 50 103 20511 7. KB Elevation (ft): 9. Well Name and Number: RKB 37' CD2 -60 8. Property Designation: 10. Field /Pool(s): ADL 380075', 380077 Colville River Field Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 18695' feet true vertical 7376' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 3224' 9 -5/8" 3276' PRODUCTION 14279' 7" 14331' OPEN HOLE 4364' 6 -1/4" 18695' Perforation depth: Measured depth: ��y true vertical depth: SCANNED MAY 0 6 2008 Tubing (size, grade, and measured depth) 4 -1/2" L -80, 13104' MD. Packers SSSV (type measured depth) Baker Premier Packer set at 13033' Camco 41/2" DB nipple at 2317' 12. Stimulation or cement squeeze summary: Intervals treated (measured) S SR MAY 0 5 2008 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil Bbl Gas Mcf Water Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation 600 1600 2200 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory Development Service El Daily Report of Well Operations _X 16. Well Status after proposed work: Oil❑ Gas WAGS GINJ❑ WINJ WDSPL❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Tim Schneider Printed Name Ti S neider Title Production Engineer Signature L,..e Phone T Date Z 7-O, l ��N�� �,p Prepared by Jeanne Haas 263 -4470 f Form 10-404 Revised 04/2006 l A L f�' jt. Submit Origi nl zs;o3 Well Name Date Int Monthly Water Ini Vol Cum Wtr In( CD2 -60 01/31/06 9,152 9,152 CD2 -60 02/28/06 53,464 62,616 CD2 -60 03/31/06 6,362 68,978 CD2 -60 04/30/06 0 68,978 CD2 -60 05/31/06 3,158 72,136 CD2 -60 06/30/06 0 72,136 CD2 -60 07/31/06 0 72,136 CD2 -60 08/31/06 0 72,136 CD2 -60 09/30/06 0 72,136 CD2 -60 10/31/06 0 72,136 CD2 -60 11/30/06 0 72,136 CD2 -60 12/31/06 0 72,136 CD2 -60 01/31/07 0 72,136 CD2 -60 02/28/07 0 72,136 CD2 -60 03/31/07 0 72,136 CD2 -60 04/30/07 0 72,136 CD2 -60 05/31/07 0 72,136 CD2 -60 06/30/07 0 72,136 CD2 -60 07/31/07 0 72,136 CD2 -60 08/31/07 0 72,136 CD2 -60 09/30/07 0 72,136 CD2 -60 10/31/07 2,624 74,760 CD2 -60 11/30/07 0 74,760 CD2 -60 12/31 /07 0 74,760 CD2 -60 01/31/08 0 74,760 CD2 -60 02/29/08 0 74,760 CD2 -60 03/31/08 2,916 77,676 CD2 -60 04/30/08 7,885 80,592 *The well is currently injecting an average 600 BWPD @2200 psi rate pressure as of 4- 24 -08. WSR Well Service Report Page 1 of 1 Well Service Report I Well I Job Scope II CPAI Rep CD2 -60 1 HPBD Brake, Jared I Date IlDaily Work II Unit Number I 3/9/2008 68 Network Daily Cost Cum Cost I Company Unit Supervisor 10210709 $13,320 I $13,320 LRS LUNDSTROM Initial Initial T/I /O 1350/1500/300 Final Final T/I/O 1700/750/400 Field: ALPINE Pressures: Attempt HPBD by pumping 4 stages (200 bbls each), of 62 deg seawater at 8 bbls 24 hr. a minute with 3200 psi of WHP during pump operation. Well did not show Summary increased signs of injectivity during pumping operation. Handed well over to DSO once complete to bring back on injection. STARTTIME OPERATION 01:00 PM RU Pressure test 04:00 PM Pump 5 bbl diesel spear 3 bpm. 04:06 PM Pump 120 bbls of 62 deg seawater 8 bpm with 3250 WHP. 04:36 PM SD pump and monitor pressure for 15 minutes. Initial SD pressure 2350 psi on well head, after 15 minutes pressure fell off to 1700 psi 04:51 PM Pumped second stage of SW (200 bbls) at 8 bpm, whp while pumping was 3125 psi. 05:21 PM Pump 2 bbls of diesel through surface lines 05:33 PM Monitor pressures for 15 minutes, initial SI pressure 2100 psi, after 15 minutes WHP fell to 1850 psi. 06:03 PM Pumped third stage of 200 bbls seawater at 7 bpm (loosing prime from tank), injection pressure of 2950 psi. J P p 06:48 PM Pump 2 bbls of diesel 07:00 PM Monitor pressure for 15 minutes, initial SI was 2100 psi, after 15 minutes WHP was 1800. Pumped fourth stage of seawater at 7 bpm, (120 bbls lost prime). WHP while 07:30 PM pumping was 2950 psi. Follow with 15 bbls of diesel. Hand well over to production for injection. To From Non Fluid Type Note Well Well recoverable http: /anc402 /weq /worklog. aspx ?ID= AA56881 B6CDA429D942FCDF3096A2449 &Date 4/18/2008 WSR Well Service Report Page 1 of 1 11111 Well Service Report I Well Job Scope II CPAI Rep CD2 -60 HPBD Brake, Jared I Date IlDaily Work II Unit Number 1 1 4/12/2008 44 Network Daily Cost Cum Cost I Company I Unit Supervisor 10210709 $11,860 $11,860 LRS I MURPHY Initial Initial T/I /O 1450/1500/100 Final Final T/I/O 1850/1750/680 Field: ALPINE Pressures: Performed 4 stage HPBD by pumping 709 bbls of 44 deg F seawater 9 bpm 24 hr. (3600 psi injection pressure). Well did not indicate any signs of breaking down or Summary increased injection during job. STARTTIME OPERATION 09:00 AM MIRU dual LRS pumps. 11:00 AM Pump first 200 bbl SW stage 9 bpm, with 3600 psi. 12:00 PM SD pumps and monitor pressures. Tubing pressure 5 mins= 1720, 10 mins 1625, 15 mins= 1580. 12:30 PM Pump 2nd stage with 200 bbls of SW 9 bpm with 3450 psi. 01:30 PM SD pumps and monitor pressures. Tubing pressure 5 mins= 1800, 10 mins 1710, 15 mins= 1550. 02:00 PM Pump 3rd stage with 200 bbls of SW 8.4 bpm with 3200 psi. 03:00 PM SD pumps and monitor pressures. Tubing pressure 5 mins= 1875, 10 mins 1820, 15 mins= 1650. 03:30 PM Pump 4th stage with 106 bbls of SW 8.4 bpm with 3200 psi. 04:30 PM SD pumps and monitor pressures. Tubing pressure 5 mins= 2075, 10 mins 2000, 15 mins= 1900, 20 mins= 1875, 25 mins= 1875. 05:00 PM RDMO To From Non- Note Fluid Type Well Well recoverable http:// anc402 /weq /worklog.aspx ?ID= 71453499B 1 E84EDE9F0A21 C449C4E 163 &Date =4/... 4/18/2008 )U DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050680 Well Name/No. COLVILLE RIV UNIT CD2-60 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20511-00-00 MD 18695 TVD 7375 Completion Date 7/10/2005 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D Asc Directional Survey 11756 18695 Open 9/7/2005 IIFR tt 'ED D Asc Directional Survey 11756 18695 Open 9/7/2005 MWD QED D Asc Directional Survey 0 13543 Open 9/7/2005 IIFR PB1 D Asc Directional Survey 0 13543 Open 9/7/2005 MWD PB1 r~ D Lis 13280 Induction/Resistivity 3249 18630 Open 9/26/2005 GR EWR4 ABI CNP SLD ~ ROP ACAL PWD .Kpt 13280 LIS Verification 3249 18630 Open 9/26/2005 GR EWR4 ABI CNP SLD ROP ACAL PWD D Lis 13281 Induction/Resistivity 3249 13501 Open 9/26/2005 PB 1 GR EWR4 CNP SLD ROP ACAL PWD ~ 13281 LIS Verification 3249 13501 Open 9/26/2005 PB 1 GR EWR4 CNP SLD ROP ACAL PWD D C Lis 13648 Induction/Resistivity 114 18695 Open 2/22/2006 ROP DGR EWR plus Graphics / PB 1 114-13543 ROP DGR EWR SLD CTN i plus Graphics og Pressure 5 Blu 1 53 6000 Case Pressure & Temp log / Note Logging interval is - 53 to 6000 ft Log Cement Evaluation 5 Blu 1 12900 13230 Case Memory Cement Bond Log GR/CCL/CBLlVDL 15 Jan 2006 ~ D C L,erSG(~ 14379 Induction/Resistivity 3249 18695 Open 1/29/2007 LIS Veri, GR, FET, ROP w/Graphics / .KD C L8S ~t5 14379 Induction/Resistivity 3249 13543 Open 1/29/2007 PB1 LIS Veri, GR, NCNT, FET, NPHI, RHOB, ROP w/Graphics 0 0 DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050680 Well Name/No. COLVILLE RIV UNIT CD2-60 Operator CONOCOPHILLIPS ALASKA INC MD 18695 TVD 7375 Completion Date 7/10/2005 Completion Status WAGIN Current Status WAGIN Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~\J Chips Received? Analysis ~`TiV" Received? Comments: Compliance Reviewed By: Daily History Received? ~ N Formation Tops ~jN Date: API No. 50-103-20511-00-00 UIC Y a ,~ U 1'~1 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ate.. ot~' Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~; o ~~ M.. Loveland ConocoPhillips Well Integrity Project Supervisor r-- f ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31.2007 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 CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2!17/2007 CDZ-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17!2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1,0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11:9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-6{J 205-068 6" na 6" na 1 3/8/2007 1,~ 1- ~~nocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 0~~ ~,b ~,, n Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment bra r ., C ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31.2007 Weli Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 _ 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16!2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 318!2007. CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 T 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2!18/2007 CD2-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18!2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16!2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068. 6" na 6" na 1 3/8/2007 ' ~~ WELL LOG TRANSMITTAL To: State of Alaska November 29, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs CD2-56_L 1, CD2-57, CD2-59_PB 1, CD2-60_PB 1. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~~ v=c CD2-56_L1: SOLI - 15b '~ ~~(3~s' s abu -~s+ ~ 1 L~3`~~ Digital Log Images: 1 CD Rom SO-103-20498-00, 60 Digital Log Images: 1 CD Rom 50-103-20492-00 ~ CD2-59_PB 1: Sri ~ 2-q`( ..~~`6 ~ I~13~ $ Digital Log Images: 1 CD Rom 50-103-20505-00,70 CD2-60 PB 1: V ~~ ~,ps-U b 25 # (~~3~-`~ Digital Log Images: 1 CD Rom 50-103-20511-00, 70 Re: Question about removal of SSSVs for Alpine wells Subject: Re: Question about removal of SSSVs for Alpine wells From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 17 Oct 2006 14:24:04 -0800 'I`o: NSFt F'roblciz~ ~~'cll Suln~ '=n16 i 7;u conocohhillihs.com CC: jim re<~~`~(u'<rdn~in.statc.~ik.us Marie, With the wells SI and secured with the wellhead valves, it is not necessary to install the SSSVs at this time. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10!17!2006 12:05 PM: Tom & Jim, ~ fps-~ ~ A question has come up regarding removal of SSSVs at Alpine. CD2-60 and CD4-17 had downhole gauges installed in the past few days to record shut-in bottom hole pressure for the next 4 to 6 weeks. The wells will remain SI at the wellhead during this entire time. CD4-17 doesn't have a flowline and has not been on production since the rig completed drilling operations. With the wells staying SI with wellhead valves closed while the SBHP data is gathered, it seems that it would be permissible to leave the SSSVs out until the gauges are removed. The SSSVs will be installed when slickline pulls the gauges prior to bringing the wells back on line. Please advise if we've interpreted the conservation order and regulations correctly. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617~conacophillips.com 1 of 1 10/17/2006 2:24 PM .MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~b _ DATE: Tuesday, September 26, 2006 Jim Rea ~,lN P.LSupervisor ~~N'~;G~ If % ~lII,- r, SUBJECT: Mechanical Inte~rityTests ~ CONOCOPHTLLIPS .ALASK,1 INC CD2-60 FROM: JOhn Spaulding COLVILLE RIV liMIT CD2-60 ~ J Petroleum Inspector l/'J1 •-' Src: Inspector Reviewed By: P.I. Suprv ;`.i NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD2-60 API Well Number 50-103-20511-00-00 Inspector Name: John Spaulding Insp Num: mitJS060925132408 Permit Number: 205-068-0 Inspection Date: 9!12/2006 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _ T_ _ __~_ Well ~ cDZ-6o IType Inj. f N 'I TVD joss '~ IA i i3so I 2zoo zl9o ztao '~ 2lso ~, YP ~ - _ ----- _ - -- ~+ -- P.T ~ 2oso6so lT1T eTest ' sPT'I Test psi I~~87~ '~ OA o i o '~ 0 I o ~ j -- _ _- ___ _ _.__ _ __ __ i___ Interval aYxrsT p~F a Tubing ~, I~oo Iaoo Iaoo Iaoo ~ Iaoo Notes Tuesday, September 26, 2006 Pale t of 1 MIT CRU CD2-60 08-3I-06.x1s ~ ~ Subject: MIT CRU CD2-60 0$-31-06.x1s From: NSK Well Integt-ity Pr~~j <N1878 cr,conocophillips.com-> Date: Fri, Ol Scp 2006 14:0~:?9 -0800 To: Tom Maunder -=tom_maunder(u'.admii~.staie.ak.u~ ~, .Ia~7~es Rtg~ ~jim_reb~~«`adn~iil.siaie.ak.us> CC: bobfleckensteir~(u?admin.state.ak.us, NSE; Problem Well S~ipv <n1617(rr;~coriocophillips.com=~ «MIT CRU CD2-60 08-31-06.x1s» Tom, Here is a repeat MITIA for CD2-60 (PTD 205-068}. This is a passing test that follows up the 4 year MITIA that failed on 8/27/06. The well just needed IA fill up to pass the MITIA. Since this was a diagnostic test the Inspectors were not given 24 hour notice, therefore the 4 year MITIA will be repeated on this well when an Inspector can be present. We will coordinate this repeat MIT with the Inspectors this month while they are at Alpine for SVS testing. Please let me know if you have any questions about the data. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 Content-Description: MIT CRU CD2-60 08-31-06.x1s ''MIT CRU CD2-60 08-31-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 __ 1 of 1 9/5/2006 9:37 AM HH l..V '+4.~H.VV 1 CU11UW U(7 Subject: A.A C0 443A.001 Follow up From: NSI~ Well Integrity Proj <N1878@conocophillips.corn> Date:. Fri, Ol Sep 2006 I0:56:44 -0800 To: 7arnes Reg ~<jim_re`g~admin.state.ak.us>. Thomas'~Iai~nder Morn_maunder(a:>a~min.state.ak.us> ~C: NSK Problem Well Supv <n1617(~z;conocopkillips.com>, NSK Well. Intc~;r7ty Proj~ <NI8ai!st%~EC~~oca~i~illips.eom> y~3 ~ Tom, Jim, ~t~r-i-~t~t~ apS--C}~~ As a foflow~up to AA CO 43A.001 allowing the temporary removal of injection valves from CRU ~-~_,~c~-iCD2-55, CD2-56, CD2-6 which expired 8/31/06, this email is to notify the commission that the injection valves have been reinstalled and function tested as of 8/31/06 on all three wells. The wells are still Si but can be available for State Inspector Witnessed SSSV testing if requested. Please let me know if you need any additional details or a more formal notification that the injection valves have been installed. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 1 oft 9/5/2006 9:39 AM ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg~admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips amine/ CRU /CD2 08/31 /06 Jared Brake Packer Depth Pretest Initial 15 Min. 30 Min. WeII CD2-60 Type Inj. N TVD 7,035' Tubing 1,600 1,600 1,600 1,600 Interval o P.T.D. 2050680 Type test P Test psi 1758.75 Casing 1,400 2,550 2,550 2,550 P/F P Notes: diagnostic MITIA following failed MIT 8/27/06 OA 0 0 0 0 Inspector was not given 24 hour notice -test will be repeated with Inspector present Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G=Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1!05 MIT CRU CD2-60 0831-06.x1s STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION '~' '"~ Mechanical Integrity Test ~ ~"'~ ~'~ ~~~a Email to: Winton_Aubert~admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder(d~admin.state.ak.us OPERATOR: FIELD /UNIT !PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alpine/ CRU /CD2 08/31/06 Jared Brake Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-60 Type Inj. N TVD 7,035' Tubing 1,600 1,600 1,600 1,600 Interval o P.T.D. 2050680 Type test P Test si 1758.75 Casing 1,400 2,550 2,550 2,550 P!F P Notes: diagnostic MITIA following failed MIT 8/27/06 OA 0 0 0 0 Inspector was not iven 24 hour notice -test will be repeated with Inspector present Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPE INJ Codes D =Drilling Waist G =Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test aos-o(~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CRU CD2-60 08-31-O6.xls MEMORAPTDUM TO: Jim Regg ~~t- `2ii~ ~~ ~ ~v~~~~. P.I. Supervisor / FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commissi DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHII.LIPS ALASKA INC CD2-60 COLVILLE RIV iJNIT CD2-60 Src: Inspector NON-CONFIDENTIAL ©~ ~t~/ Reviewed By: P.I. Suprv~l5~-' Comm Well Name• COLVILLE RIV UNIT CD2-60 API Well Number s0-103-20511-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS060828150838 Permit Number: 205-068-0 Inspection Date: 8/27/2006 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-60 TYPe Inj. N TVD 7035 Is, 1280 2470 2270 2070 p.T. zoso6so TypeTest SPT Test psi I~sa.~s OA o 0 0 0 Interval axxTST p~ P Tubing »oo o.iz izoo voo Notes Casing failed to pressure test losing 200 psi per 15minutes for lhour+. j ' J Wednesday, August 30, 2006 Page I of i JUi. Y 7 2006 ~ ,, ~ 't • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS101~~8S~(a OII St CaS CUn$. CotnmlS~lon REPOF7T OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 Alter Casing ^ Pu11 Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~e~-elopn,ent ~ Exploratory ^ 205-068 / 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20511-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' CD2-60 8. Property Designation: 10. Field/Pool(s): ADL 380075, 380077 Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 18695' ~ feet true vertical 7376' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet -Casing Length Size. MD TVD - Burst Collapse - Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3224' 9-5(8" 3276' 2373' PRODUCTION 14279' 7" 14331' 7378' OPEN HOLE 4364' 6-1/8" 18695' 7376' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 13104' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 2317' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ee I~a~ ~1=~• ,1U~ ~ "~ ~do~ Treatment descriptions including volume s 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 Subsequent to operation 124 21 S 449 720 271 14. Attachments 15. Well Class after proposed work: ~ Copies of Logs and Surveys run _ Ex lorato p ry ^ D Development Service ~-~~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ ~ GINJ^ WINJ ^ WDSPL^ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C O Exempt: 306-182 contact Tim Schneider Printed Name Tim chneider Title Staff Production Engineer Signature ` ' Phone 265-6859 Date 7 / j -C / Pre aced b Jeanne Haas 263-4470 Form 10-404 Revised 04/2004 (~j ~ \ Submit Original Only 13-JUL-06 15:24 Well EVENT SUMMARY Report DS RES WL ---DATE---TIME- ------------- EVENT REASON ---------------- CD2 ALP 60 30-JUN-06 13:55 P&A-ed or Suspended - Long Term SI CD2 ALP 60 29-JUN-06 22:15 Convert to Seawater Injection - CD2 ALP 60 22-JUN-06 07:43 P&A-ed or Suspended - Long Term SI ^ CD2 ALP 60 09-JUN-06 01:53 Open Well- Return to Service CD2 ALP 60 01-JUN-06 00:01 Convert to Gas Lift Well i A/M ALLOC SAND OIL WATER GAS MATERIAL M NO --C--- SWI M NO --C--- SWI M NO --C--- 258 959 221 OIL M NO --C--- 0 0 0 OIL M NO --C--- OIL • alpa.ak.ppco.co Pg 1 Thursday, Jul 13 2006 15:24 ~~ • ! Welt Name Date Prod Oil Vol Gas Form Vol Water Vol Tubing Bbls. Bbls. Pressure 270 302 278 509 426 267 473 289 295 97 461 273 38 318 259 18 358 259 2 249. 264 64 325 260 158 427 269 258 554 261 360 672 262 442 809 275 293 827 291 76 263 276 3058 6280 218 449 271 CD2-60 6/9/06 6/10/06 6/11 /06 6/12/06 6/13/06 6/14/06 6/15/06 6/16/06 6/17/06 6/18/06 6/19/06 6/20/06 6/21 /06 6/22/06 Total Volumes Daily Averages 6/9/06 1:53 Open well 6/22/06 7:43 Shut in 6/29/06 22:15 Convert to SWI _.:6/30/06.13:55 Shut in Bbls. 81 118 72 8 0 0 0 55 135 219 304 375 287 81 1735 124 r1 LJ d s~ j ~'a° "a ~' 1 i ~ ~ ~ I ,l x.i ~ ~ ~ ~ ~.. ~ .~ ..m ..~. .~~ .,o _s.. .mil ~ . ..s, ~_3 ~.~ ALASSA OIL A1QD GA5 CO1~t5ER~PATIOI~T COl-IIrII55IO1~T Tim Schneider Staff Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • 7~ FRANK H. MURKOWSK/, GOVERNOR d 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD2-60 Sundry Number: 306-182 Dear Mr. Schneider: 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. ~D~ _ p (o g Qin~arPly :~ ConocoPhillips May 11, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for CD2-60 Dear Commissioner: Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD2-60. We are planning to convert this well from a MWAG injector to a producer for approximately three months. The reason for the conversion is to reduce the area reservoir pressure for the planned drilling of an Alpine `A' horizontal producer west of CD2-60. The reservoir pressure is currently ±4000 psi or ±11.0 ppg. Once the area pressure is reduced, a request to convert back to an injector will be submitted. If you have any questions regarding this matter, please contact me at 265-6859. Sincere) T. S. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad ' STATE OF ALASKA $~;p ALASKA OIL AND GAS CONSERVATION COMMISSION -- APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ convert well from Chan e a roved ro ram 9 PP P 9 ^ Pull Tubing ^ Perforate New Pool ^ injector to Re-enter Suspended Well ^ producer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 205-068 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20511-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.7' / 52' AMSL CD2-60 - 8. Property Designation: 10. Field/Pool(s): ADL 380075,- 380077 Colville River Field /Alpine Oil Pool ' 11. PRESENT WELL CONDI710N SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18695' 7376' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 114' 114' SURFACE 3239' 9-5/8" 3276' 2373' PRODUCTION 14294' 7" 14331' 7378' OPEN HOLE 4364' 5-1/2" 18695' 7376' Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 4-1 /2" L-80 13104' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier pkr @ 13033' Camco 'DB' nipple @ 2317' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 23, 2006 Oil 0' Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name im Schneider Title: Staff Production Engineer Signature Phone 265-6859 Date •~~('Y~( , Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S F~: <<~~~ ~~ 2000 Subsequent Form Required: ~~ APPROVED BY ~,,,~ D~ Approved by: COMMISSIONER THE COMMISSION ~ Date: V "~ ~ -~.~ S•z3 •a~ Form 10-403 Revised 7/2005 /~ `~ ~~ . ~, ~ Submit " Duplicat~ ._.a, ~~6 -~. C`~~o~t~p~tilli~s AI~, I~~. _ _ CD2-60 BING API: 5010320511 (0-13104, SSSV T e WRDP 00:4.500, ~ YP 103.958) Annular Fluid: "i Reference Loa: 'RODUCTION (0-14331, 00:7.000, wt:zs.oo> SURFACE (0-3276, 00:9.625, Wt:36.00) Gas Lift i ndrel/Dummy valve 1 I (8641642, 00:5.984) PACKER ;13033-13034, 00:5.970) NIP :13092-13093, 00:5.000) WLEG~~ - '13103-13104, 00:5.000) i r~ OPEN HOLE ' ,14331-18695, 00:6.125) t .ALPINE Orig Completion: ~ 7/10/2005 CD2~60 Angle @ TD: 95 deg @ 18E Rev Reason: Set DMY, Set -Last Ta~Date: ~ ~ M_ ax Hole Angle: i 96 deg. at7 18268 i ~ __ _ Casing Strin~_ALL_STRINGS _ _ __ _ _ _ __ _ __ _ _ Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED SURFACE 9.625 0 3276 2373 36.00 J-55 BTC PRODUCTION 7.000 0 14331 7378 26.00 L-80 BTCM OPEN HOLE 6.125 14331 18695 18695 0.00 ___ Tubi~_String -TUBING - _ _ - _ _ Slze _ L_ Top B ottom • - TVD Wt ~ Grade- i Thread _ _ 4.500 ~ _0- ~_ 13104 ~ 7064 ~ i2.60 ~_ L-80_ r _ {BTM _ Gas Lift MandrelsNalves - - - __ _ - St MD ~ND Man Mfr Man Type V Mfr V Type V ODT Latch Port f TR O~Date ~Vlv Run Cmnt 1 8641 4963 CAMCO KBG-2 DMY 1.0 0.000 0 BK-5 _ 1/16/200 ~i _ Other lu s, ec~u~ip., etc. - JEWELRY _ _ _ Deoth TVD Tvoe - Description ~ ID RE: Ques~ions on Sundry Application for well CD2-60 Subject:. IZE: Questions on Sundry Application for well GD2-60 From: "Schneider, Tim S." <Tim.S.Schneider@conocophillips.com =~~ Date: Tue, 30 May 2006 14:12:11 =0800 'To: [)arc Rohe <_da~~c roh~,u~adiliin.stalc.al:.us~~ C'C': Stephen F ~a~l~ti ~ ste~e dati~ies(r~admin.statc.akus=~, Thomas Maunder ~~-t~~m_nlatindc.rrri'adn~iil.statc.ak.us%, ~~Piers~~1~, Chris 1Z" ~'-C'kris.R.Piersonr"u'~conocophillips.com=°> ",~~lonr.o, Chas" <Chris.:~loi~zo(uconoeo}~hillips.com% Dave, Chris Pierson and I have provided the information you've requested below: If further clarification is needed, please don't hesitate to call Chris (265-6112) or me. Thanks Tim Schneider ConocoPhillips Alpine Subsurface Engineering Staff Engineer 907-265-6859 907-632-8136 {Mobile) tim. s . schneider~.~c..,nacophillips . com -----Original Message----- From: Dave Roby [mailto_:dave roby@admin.state.ak.us] Sent: Tuesday, May 30, 2006 9:02 AM To: Schneider, Tim S. Cc: Stephen F Davies; Thomas Maunder Subject: Questions on Sundry Application for well CD2-60 Tim, I have a few questions for you related to your application dated 5/11/06, received in our offices 5/22/06, to temporarily convert well CD2-60 (PTD 205-068) from an MWAG injector to a producer in order to lower the reservoir pressure in that area for future drilling operations. My questions are: 1) The current pressure is estimated at 4000+ psi, what was the initial reservoir pressure at the time the well was originally completed? -Original measured pressure: 7/19j05: 4067 psi @ 7000' SSTVD datum -Current pressure: 5/20/06: 4379 psi @.7000' SSTVD datum (Post injecting 69Mbbls) 2) What is the estimated production volume required to achieve the desired reduction in reservoir pressure? -We would like to produce 155,000 STB from the pattern if the. well will do it. This equates to 1700 bopd over the next 3 months. 3) Do you anticipate that this operation will result in a decrease in the production rates of the producers in this area of the field, and if so how much of a decrease? -We don't expect any drop in offset rates, since the Alpine "A" is the majority of CD2-60's OH completion interval(see attached). The offset well to the East; CD2-37 is 1 of 2 5/30/2006 2:27 PM RE: Questions on Sundry Application for well CD2-60 • • an Alpine "C" producer. The nearest Alpine "A" production is in the CD2-43 well, 2500' to the NW of CD2-60's Alpine "A" penetration (See attached word document). 4) Do you anticipate that this operation may cause any permanent loss of reserves and if so how much? -I see no risk to reserves. We operate under the same Reservoir Management practices as we've done in the other part of the field (CDl-14 is a good analog). 5) Do you plan to "make up" the reservoir voidage caused by this operation after the two additional wells are drilled and CD2-60 is returned to injection? -Right now we have injected more fluid than we have taken out. Our goal is to get the pattern to a voidage neutral status. If we end up creating voidage, we will make it up. Thank you for your help. Dave Roby Reservoir Engineer Alaska Oil & Gas Conservation Commission (907)793-1232 d.ave robv~~~a.dmin.state.ak.us Content-Description: CD2-60_log_08-OS.ppt CD2-60_log_OS-OS.ppt Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 Content-Description: CD2-60 map.doc CD2-60 map.doc Content-Type: application/msword Content-Encoding: base64 2 of 2 5!30/2006 2:27 PM CD2-60: Sundry request-Inj. To Producer • •Subject: CD2-60: Sundry request-Inj. To Producer From: "Schneider, Tim S." <Tin1.S..Schneider@conocophillips.com> Date: Mon, 22 ?~'iay 2C~t:)6 1 x:34:2I -0800 To: Thomas f~~laundcz~ ~~tom maunder(rladmin.state.ak.us=~ Tom, 4~-~~~~c-~.~~~ ~~ ~.~'~~ To expand on my phone message from earlier today. ~' CPAI is planning to drill two wells West of the CD2-60 injector into the Alpine "A" sand in Aug/Sep 2006. The CD2-60's reservoir pressure is estimated at 4000+ psi. In order to provide a more acceptable drilling environment, we are wanting to produce CD2-60 to get the area reservoir pressure down to 3500 psi or lower. The duration of producing CD2-60 is expected to be +/- 4-8 weeks. ~ We were proposing a 24 hour "man-watch" during this operation since we'll be flowing back the CD2-404 Kanik well at the same time. A remote ESD to the SSV would be installed at the flowback unit vs. the SSSV (subsurface controlled safety valve; ie. K-valve). If the flowback operation ends prior to completing the "area pressure reduction", the 24 hour man-watch would continue. The sundry that Sharon had sent to your office today did not provide this detail within the Sundry. ~ If you need further information from me, please let me know. Thanks, Tim Schneider ConocoPhillips Alpine Subsurface Engineering Staff Engineer 907-265-6859 907-632-8136 (Mobile) tim.s.schneider@conocophillips.com 1 of 1 Sl23/2006 8:01 AM ~ CO 4~t3A.001, AI04E.00 t, AI04E.002, A[0~4C 005 ~~ C] Subject: CO 443A.001, AI04E.001, AI04E.002, AI04C.005 From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Fri, 19 May 2006 09:26:09 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Robert E Nlintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, trmjrl <trmjrl@aol.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <Shannon.donnelly@conocophillips.com>, "Mark P. Worcester" <mark.p.worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <Mikel.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <P1attJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>, jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, Loren Leman <loren Leman@gov.state.ak.us>, Juiie Houle <julie_houie@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, ,tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm7200 <mkm7200@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bi11 Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>, jack newell <jack.newell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, n1617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, Crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Todd Kratz <ToddKratz@chevron.com>, Gary Rogers <gary_rgers@revenue.state.ak.us>, Arthur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks mews@radiokenai.com>, ~f 2 5/ 19x2006 9:26 ANI CO 44~A.001, A(0~4E.001, AI046.002, AI04~~ • 3erry' McCutcheon <susitnahydronow@yahoo.com>, Paul Todd <paulto@acsalaska.net>, Bill Walker ' <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Rob Dragnich <rob.g.dragnich@exxonmobil.com>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <marguerite_kremer@dnr.state.ak.us>, , Alicia Konsor <alicia_konsor@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Winton G Aubert <Winton_aubert@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com> Content-Type: application/pdf CO4~13A-OOl.pdf Content-Encoding: base64 Content-Type: application/pdf AIO4E-002.pdf Content-Encoding: base64 Content-Type: applicatiorv'pdf AIO4E-OOl.pdf Content-Encoding: base64 Content-Type: application/pdf AIO4C-005 Cancellation.pdf Content-Encoding: base64 ~f 2 5;19/2006 9:26 AM • FRANK H. MURKOWSKl, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL CO 4-I3AAOI Ms. MJ Loveland Problem Well Supervisor - NSK 69 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 Re: Temporary Removal of Injection Valves Colville River Unit Dear Ms. Loveland: Pursuant to Rule 11 of Conservation Order ("CO") 443A, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission'') hereby grants ConocoPhillips Alaska, Inc. ("CPAI")'s request for administrative approval to temporarily remove the required subsurface safety valve from injection wells CD2-5~, CD2-~6, and CD2-60. AOGCC finds that CPAI will remove the A-1 injection valve from each well to allow for monitoring of the surface pressures. The injection valves will be out of the wells through early August 2006. The Commission further finds that CPAI will leave these wells shut in except fora 1-hour period every two weeks when each well's master valve will be opened to monitor tubing pressure. Recent inspections of CD2 location indicates the safety valve systems for all wells are suitable for the intended service, with only a few deficiencies identified that were immediately corrected. No state witnessed safety valve system tests of the 3 wells have been performed since they have only injected water. The Commission has no record of well integrity concerns for the 3 mentioned injection wells and believes that removal of the injection valves from CD2-5~, CD2-56, and CD2- 60 will not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to allow the temporary removal of injection valves from CRU CD2-~~, CD2-56, and CD2-60 is conditioned upon the following: 1. Wells shall be tagged showing the date and reason for removal of the injection valve; Ms. MJ Loveland May 18, 2006 Page 2 of 2 2. Wells shall be attended while the master valve is open for monitoring tubing pressure; 3. Wells shall remain shut-in except during the monitoring of tubing pressure; 4. The injection valve must be reinstalled within 15 days of commencing injection in a well; ~. This approval expires on August 31, 2006 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. DOtiE at Anc~ae, Alaska and dated May 18, 2006. Cathy P. oerster Commissioner Mary Jones David McCaleb Mona Dickens 'XTO Energy, Inc. fHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden OiI Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 John Levorsen Kay Munger Samuel Van Vactor 200 North 3rd Street, #1202 Munger Oil Information Service, Inc Economic insight lnc. Boise, ID 83702 PO Box 45738 3004 SW First Ave. Los Angeles, CA 90045-0738 Portland, OR 97201 Michael Parks Mark Wedman Schiumberger Marple's Business Newsletter Halliburton Drilling and Measurements 117 West Mercer St, Ste 200 6900 Arctic Blvd. 2525 Gambell Street #400 Seattle, WA 98119-3960 Anchorage, AK 99502 Anchorage, AK 99503 Ciri Baker Oil Tools Ivan Gillian Land Department 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99507 Anchorage, AK 99503 Jilf Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadfa Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling lnc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 lei p~ .~....___1...,... _... .~,...., _„~., . .....,......~ • Subject: RE: Request for Alpine SSSV variance Frorn: NSK Problem We1i S~zpv <n1617(~~conocophillips.com> Date: Wed, 17 May 2006 08:09:7 -0800 ~~ ,~ ~ f~ ~ .~~(~ ~'a: NSI~ Prot~Iem We1i Supv <n1617@conocaphillips.com>, Tames Regg i 1 ~~~~~~~ ` <}irn_regg~ad~nin.state.ak.us> CC: Tam N~aunder <tom maunder@adminatate.ak.~xs> Jim, I'rn fallowing up on this request, it appears that our new guy sent it to the wrong place. I wanted to make sure you got it since Alpine would like to pull the SSSV's this week and begin monitoring the 3 SI wells. Please advise if this is acceptable. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 -----Original Message----- From: NSK Problem Well Supv Sent: Tuesday, May 16, 2006 9:19 AM To: bob_fleckenstein@admin.state.ak.us Subject: Request for Alpine SSSV variance Bob, In order to monitor offset wells to the planned CD4-16 D&C; ConocoPhillips would tike to monitor the surface pressure's of injection wells CD2-55,56,60 (All SI). In order to do this, we would like to leave the A-1 inj. valve out of the hole until early August. ConocoPhillips requests a variance from the state rule that all Alpine wells require an operational SSSV. The wells will remain shut in during the monitoring period with the exception of a 1 hour period every two weeks where the master wil) be opened to monitor tubing pressure. To bring the well back online ConocoPhillips would have 15 days to install a functioning SSSV per state rule. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 I of 1 5!18/2006 2:1J PM Conservation Order 443 ~ ~ ~:`->~: ~, October 7, 2004 • Page 7 Rule 4 Drilling and Completion Practices (Restated from CO 443) a. After drilling no more than 50 feet below a casing shoe set in the AOP, a formation integrity test must be conducted. The test pressure need not exceed a predetermined pressure. b. Casing and completion designs may be approved by the Commission upon applica- tion and presentation of data that demonstrate the designs are appropriate and based upon sound engineering principles. c. Permit(s) to Drill deviated wells within the AOP shall include a plat with a plan view, vertical section, close approach data and a directional program description in lieu of the requirements of 20 AAC 2~.050(b). d. A complete petrophysical log suite acceptable to the Commission is required from below the conductor to TD for at least one well on each drilling pad in lieu of the re- quirements of 20 AAC 25.071(a). The Commission may, in its discretion, require additional wells on a pad to be logged using a complete petrophysical log suite. Rule 5 Automatic Shut-in Equipment (Restated from CO 443) a. All production and gas injection wells must be equipped with afail-safe automatic surface safety valve ("SSV") and a surface controlled subsurface safety valve ("SSSV"). b. Water injection wells must be equipped with either a double check valve arrangement or a single check valve and "SSV. c. Safety Valve Systems ("SVS") must be tested on a six-month frequency. Sufficient notice must be given so that a representative of the Commission can witness the tests. d. Subsurface safety valves may only be removed after demonstrating to the Commis- sion that the well is not capable of unassisted flow of hydrocarbons. Sufficient no- tice must be given so that a representative of the Commission can witness the tests. Rule 6 Reservoir Pressure IVlonitorin~ (Restated from CO 443) a. Prior to regular injection, an initial pressure survey shall be taken in each injection well. b. A minimum of six bottom-hole pressure surveys shall be measured annually. Bot- tom-hole surveys in paragraph (a) may fulfill the minimum requirement. The reservoir pressure datum shall be 7000 feet TVD subsea. d. Pressure surveys may consist of stabilized static pressure measurements at bottom- hole or extrapolated from surface, pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open-hole formation tests. e. Data and results from pressure surveys shall be reported annually on Form 10-412, Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412 but shall be made available to the Commission upon request. f. Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with part (e) of this rule. Conservation Order 443 October 7, 2004 • Page 10 Rule 11 Administrative Action (Restated from CO 443) Upon proper application or its own motion, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardize correlative rights, or compromise ultimate recovery and is based on sound engineering principles. DONE at Anchorage, Alaska and dated October 7, 2004. John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearine. A request for rehearing must be received by a:30 PM on the 23`' day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes} an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Cout. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on whtich the request is deemed de- nied (i.e., 10~' day after the application for rehearing was filed}. Safety Valve ~ Well Pressures Test Report Pad: Cxu_CD Z In sp Dt 3!19/2 006 Inspec ted by John Crisp Interval Insp No SVSO P000002627 Kelated Insp: svsJCr0604 1 9 12 2 3 t t Field Name C OLVILLE RI VER. Operator C ONUCO PHILLIPS ALASKA INC Operator Rep Ga ry Seltentei ch Reason 180-Day ~ - Sre: Operator {Fell Datrr __-, ~ Pilots ~ ~~~SV ~ b~S'SV ~ S"hutltt Dt~ Well Type ~ Well Pressu _ - res ~ Gas Liff ~ lYawei~ ~ Comntettts e Permit Separ Set L/P 'Cest lest "Cesl Date S1 O iI,WAUUINJ, Inner Outer Tubing -- _ Number Number PSf PSl Trip Code Code Code U AS,CYLLt;, Sl PSI PSI YSI Ycs(No YeslNo -01 2051180 l51 100 96 P P P OlL f ~ - 2-02 2051090 WAG -- _ __ - __ CD2-03 2050920 151 l00 98 P P P -- _ _ _OIL _ - __ _ _ _ -. i - - __ ---- CD2-OS _ __ --- _ __ 2040970 _-- - 151 - - _ - - l0U 94 I' P P OIL _ -_ __ __ _ _. _ I- - _ _ D2 U6 031590 _ _ -_ __ - _ GINJ - -___ _ __ _._ _ __ D2-07 2031870 - - _ WAG _ _ , _ _ -_ _ I - <_ _-_ . _-- CD2-08 _ _ -_ -- 2022500 _ __ - _ _ __ - _ _ _ _ _ _ GINJ -- - _ _ _ _ _ ~ _ - _ - 2041290 151 100 99 P P P - _ _ _ OIL _- - -__ _-- -- - CD2-10 - - -- 2031950 _ ___ 151 - - __ 100 99 - P 6 - _P- I_ O1L I ___-_. __________.___ ___ _ Retest Date. 3li9/2006 ll2-11 2051320 WAG -_ __ _ _. _ - _ _ - -- _ ._ - D2- l2 2030730 GINJ _ _ _ _ __ -- - - _. ___ __ __ _ _ _ CD2-l3 2022030 15l 100 97 P P P OIL __ _ - _ _ - - __ -_ -- CD2-14 2011770 151 100 99 P P 9 _ - -_ Oll _ _ - __ _ __ _ _ _ _. _ _ __ ___- _.____ - _-_ _ . Retest Date: 3/2712006 CD2-15 2011590 __ -_- - _- - _ _ __ _ GINJ -. _ ~ _._ _ _ _ - _ _ - __ -16 2021440 WAG _ ___._ _ _ _ ___ __ __ _ __ _ _ -_ CD2-i7A 2050170 -WAG _ -__ _- _-_ __. - _ _ _ _ - 2031510 _ _ _ _ _ _ _- WAG _ _ __ _ _ C 2-19 2021120 151 100 99 P P P _ _ --_ - - OIL - _ _._ __ _ "thursday; May 18, 2006 Pad: CRU_CD 2 ln sp Dt 3/19!2 006 Inspec ted by John Crisp Interval Insp No SVSO P000002627 Related Insp: svsJCr0604 1 9 1 223 1 1 Field Name C OLVILLE RI VER Operator C ONOCO PHILLIPS ALASKA lNC Operator Rep Ga ry Seltentei ch Reason 180-Day " Src: Operator I _ Well Data _ ~ -Priors ~ S,SV ~ S~`SV ~S/tutln Dr~ !Yell 11'Pe ~ We!! Pressu res ~ Gas 1 ift ) Waiver ~ Comments Well Permrt p Se ar Set L/P Cest Pest rest llate SI Or1,WACr,C,1N I, Inner Chder Cubing Number Number PSI PSI Trip Code Code Code G AS,CYCLI:, Sl PSI P.SI PSI Yes/Nu Yes/No CD2 20 2031050 151 100 97 P P P O11 _" _ -- ~ _- _ _- ~ __ ___ _ _ _ __ D2 21 042450 51 00 97 P - - P ___ -_ ~~ ~ _ - - - OlL -_ - _ -- _ I C 2-22 2020920 _. _ _ __ __ WAG _ _ - _ _ _ __ CD2-23 2021340 151 100 96 P P P O1L ~ CD2-24 2010950 151 100 97 P P P 011, CD2-25 2020740 151 100 95 P P P OIL -_ - -- CD2-26 2012320 G1NJ -_ -._ __ __-_ _ ___ ___ ____ _ _ CD2-27 -.- --- 2031770 - __ _ _ _ _ WAG 1{ _ - -_ _ CU2-28 _____ 2022 ! 70 -- - 15 l 100. 93 P I P _ P _ __ _ _ _ OIL - _ _ _. __ I CD2-29 2021480 WAG I _ _ _ _ D2-30 2031350 WAG _ _ _ _ - _ _ _ _ CD2-31 2040820 151 100 96 P P P - OIL _ _ - _ - - - _ _ _ _ CD2-32 2020290 - - -- WAG - __ _ _ _ _ _ _ ~ -_ _ __ _ CD2-33B 2011250 15( 100 98 P P P 011, _ __ - _ _ _ CD2-34 2011910 151 100 98 _ P P P O[L + __ _ - _ - _ __ _ __ ___ . _ _ _ _ _ _ _ 2-35A __ ___ __ - 2022440 _ _ ___. __ INJ _ __. - I _ -_ __ _ _ (.D2-36 2030140 _ _ _ - -- -- GINJ _ _ _ _ _ - - __ _ CU2-37 2022110 --_ 151 - _ 100 96 _ _ P P - P ___ _ IL _ _ - _ - - - . _ -_ __ _ -_ - -38 2021710 - __ - J _ - _ - - CD2-39 2011600 151 100 97 P P 9 __ _ _~ _ _ . L __. __ _ _ _ - - -- - - - - __ _ ___ __ ~ _ _-_ _ - __ _ __ __ _ _ _ __ _-- - _ --I- -1_ _ _ _ --_- - _I Retest Date: 3/30/2006 __ __ _. Thursday, May l8, 2006 Pad: Cttu_coz Insp Dt 3 /1 912 006 Inspected by John Crisp Interval 1nspNo svsopooooo2627 Rclatcd lnsp: svsJCr06041912r31 I Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA 1NC Operator Rep Gary Seltenteich Reason 180-Day '" _. Src: Operator Well Dala _ _ _ - _ ~ _ Palots ._ - _ ~ S,S I ~ SSS~ Shuffn Pt ~ _ J ~ ~ ~ _ _ ( iYell Type , _ _ ~ _ Wcll Pressures i Gus Li t ~ iti giver ~ Comments ~ f - _ _ _ ~ ~ I Well Permit Separ Set L/P 'l'est 'l'est Pest Date SI OiI,WAG,GTNJ, loner _ Outer 'T'ubing ' Number ___._ _.. __ __. Number ~__ -_ ._. PSI PSl Trip __ Code Code Code GAS,CYCL,E, S( PSI PSI PSI Yes/No YeslNo CD2-4U 2031260 _ __ _ _ -- -- -- -r-- ---- WAG _ _ - __ _ -_ _ __- _ _.__ ---- -_ CD2-41 2021260 151 100 99 P P P OlL _ _ _ _- - - - - CD2-42 2010670 151 100 97 P P P OIL -- - -- - - -.__ .__ D2-43 03 (970 51 00 97 P P P - IL _ _ __ _ _ __ - _ _ _ i i__ _ _ _ _.. _ _ __ _ CD2-44 2021650 WAG CD2-45 2012120 151 l0U 97 P P P - OIL _ _ - __-- -_ _ ._ __ - 6 2020820 - WAG _ _ _ _ .-- -_ ._ D2-47 2012050 L51 100 98 P P P OIL __ _ _ CD2-48 2021080 G1NJ _ _ __ ~ ; _ _. _ - -- - 2012490 GINJ - _ -_ ___ _ D2-50 2020490 151 100 97 - P P P - __ __ - OIL __ __ _ _ _- _ _ _ _ _ _ _ _ (.D2-51 2022490 --- -- GINJ _ - - CD2-52 2030930 151 100 96 P P P O(1, _ _ __ __ _- __ __ - _ __ -53 2040890 3/12/2006 SI _ _ _ _ __- -__- CD2-54 2041780 _.. __ _ _ - _- _ __ _ - _GINJ __ _- i _. _. _ __ __ _ _ _ _ ~ __ - __ - _ ~ '' CD2-56 2041500 __ W AG - _ -__ __ _ , _ __ . ___ _ __ __-_ __ 2040720 WAG _ _-._ - - _ _- -_ __ __ - - - - - CD2-58 2030850 _ __ _. _ WAG _ _ _ _~ _~_ _ - _ _ -_ __ __ - - CD2-60 _- 2050680 __ - _. _ _ _ __ _- _.__ __ 3/7/2006 _ ___ _ _. __ _. SI ~ _ __ _ -. _ -_ _ _ _ - - `Thursday, May 18, 200 Pad: cltu_t:D2 Insp Dt 3/19/2006 Inspected by John Crisp interval lnsplVo svsoPOOOOO2627 Related Insp: svsJCr060419I223-11 Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Gary Seltenteich Reason 180-Day ' - _ Src: Operator Well DAta Pilars S.SV S<~SV I Shuiln Dr yYett Type {{ Well Pressures I Gas Li t ~ Waiver __ _ - _ _ _ _ _ _ - - _ ~ - - 1 -- ~ _ _ I _ t _ _ '~ ~------ i Conl~nerats WeII Permit Separ Set LIP `leaf Test Test DaleSl Oi1,WAG,GIN,I, Inner Outer tubing Number Number PSI PSl 'T'rip Code Code Code GAS,CYCLI~, SI PSl PSI PSI Yes/No Yes/No Comments Performance L -41, CD2-42, CD2-43, CD2-45, CD2-47, CD2-SQ CD2-52 were tested 3120!06 CD-10 had a -- - - - trozen SSV & would not close. T'he valve was thawed Xc retested OK. CD2-l4 SSSV was serviced and Wells Components Failures FallUre Rate retested good 3/27/06 CD2-39 SSSV was serviced and retested good 3/30/06 26 78 3 3.85% - _ - __ I ~~ • I~hursday, May I S, 2006 ~y r • Review of Sundry Application 306-182 ConocoPhillips Alaska, Inc. Well CD2-60 AOGCC Permit 205-068 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to convert this MWAG injector to a temporary producer in order to reduce the reservoir pressure in this area of the field in preparation of future drilling operations. Recommendation: I recommend approval of Sundry Application 306-182 to allow CPAI to perform this operation. Discussion: CPAI proposes to temporarily convert, for approximately three months, the subject well to a producer in order to lower the pressure in this region of the Alpine Pool, to approximately 3,500 psi, prior to the planned drilling operations later this summer. Changing the status of a well, even temporarily has the potential to adversely impact reserves, as such I asked Mr. Tim Schneider with clarification on the proposed activity. Per Mr. Schneider's email, attached to this review, the pressure in the subject well was 4,067 psi when completed on July 19, 2005, and has risen to 4,379 psi as of May 20, 2006, as a result of ongoing injection activity. Therefore, the proposed activities would seek to reduce the reservoir pressure by approximately 900 psi from its current level and over 500 psi from the initial pressure. The estimated production volume required to achieve this level of pressure reduction is 155,000 bbls, which is more than twice the volume, 69,000 bbls, that has been injected in this well. The proposed pressure drop and production volume represent a substantial, localized reduction in reservoir energy and give rise to concerns about performance of the other wells in this area of the injection pattern. I asked Mr. Schneider about the potential effects on the injectors in the area and he stated that the CD2-60 well is completed primarily in the Alpine "A" sand and the nearest producer is completed in the Alpine "C" sand, therefore he does not anticipate any reduction in production rates from the offset wells. Attached are a map of this portion of the field and across-section of the subject well that Mr. Schneider provided to illustrate his point about the zone of injection and the productive intervals of the nearby wells. I also asked Mr. Schneider if they anticipated this operation causing any loss in reserves and their voidage replacement plans. He informed me that they anticipate no risk of loss of reserves and that they have currently injected more than they have produced and plan ~ ~~ ~ ~ to achieve a neutral voidage replacement for the injection pattern and will adjust future injection activities as necessary to achieve this goal. Conclusion: CPAI's proposed activities would create a substantial, localized, and temporary change in the reservoir energy, however their overall operational strategy for the pool will be to maintain complete voidage replacement. I believe that the steps that CPAI would take are prudent and that any possible negative effects on overall reserves would be negligible. Therefore, I recommend that CPAI's proposed activities for the subject well be approved. D.S. Robydz°` Reservoir Engineer May 30, 2006 CD2-60 (07/06/05) TD ~~ i CD2 6 0 PR ELIM ~ •~ 5 ` IYIE~ 1/Q ~ 1 NfitE RVO_NV.O_P, L-_ J ~s Rsw tw ~m i ~ '. S w ., RPD 1 ~ "- GR 1 ~, RPS_t _ _. _. _. _ _. __ _.. _ __ H60'ssNd _. _ ,f1 ~ ( __ _- - ~ ~m s ~ ~ - - -~ ~ ALP D j Y ~ __ - e ~ F ee~w i ~ ~ _ ~ - ' 4 26 sstW ~ ~ y 3 - a ? .~ .~ _ . s e., _ ... _._, _._ ss a _ ~brbs. _ t ALP B _.. __ -..._.. _ . _ s ALP_ASand -''e_~_..._ ; i .. :_. _ __ r g ~1 ~1 s ___ ... ~ -T990'sstvd CD2.60P81 i i 1100'scNa ' took a kick 7100 iN0 ,~ M ~ ~ weight up to 12 PP9 Prsu ssbwy ~ sIW 1H2]' a Possiblefrec'SinKingak CrtEOruYCwnsnt-180JOmE) ~yTO row.gm misppp 111 pressured up from CD2•ti5lnj I -ArwolFrxtura ~ as s~~3 ~ x iMeraected by C02-60P81 wel o ` ... h ~: 3 S 5 ~ 17800-18200 and ~ncrsaryyriertx Resistivit dro s _ aK as !;R cleans u „aMO,a, -Suppressed due to water 0 '" ~P ~ ~ ~ $ ' ~ ~ ~ ~ eE ~ ~ ~ ~ ~ ~ ~ ~ - ALP C ALP BTT ALP A ALP B ALP C roRwsr~ + _ 7 i ~ ~' e ~ ~~~~~. )I ~5 ~i. ~~ I j . .~ 1 s °o t 7 i I t YL Ts 41 iy ~"` ~ ~~ ~ OR N ~ ~ ~~~ i i ~P o j 1 ~' i I .1 ' I I` ~ '~ I lil I i ~~,_ it 1 ,i ~~~ ~~ r. b w i . I' ~-~~ 1 pp ~ I _ -_ _ ~i ~ .. ~ t . • Alpine A Sand --- Alpine C Sand Frac'd 111fells MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, March 02, 2006 Jim Regg ~~~~- .~~I~-~~~ P.I. Supervisor ~ ~ StiBJECT: Mechanical Integrity Tests CONOCOPHII.LIPS ALASKA INC CD2-60 FROM: John Crisp COLVILLE RIV UNIT CD2-60 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ."17~ Comm Well Name: COLVILLE RIV UNIT CD2-60 Insp Num: miUCr060209090544 Rel Insp Num API Well Number 50-103-20511-00-00 Permit Number: 205-068-o Inspector Name: John Crisp Inspection Date: 2/4/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ICD2-6o Type Inj. ~ ~'~' ~ TVD ~ ~o3s ~ ~ 2so ~ zoao 2020 2oto p T ~ zoso6ao TypeTest I sPT ~ Test psi V I~sB.~s ~ pA a o bzo ~ 620 ~ 620 ~ Interval INITAL p~ P Tubing j 1967 ~ I967 ~ I96~ i I967 Notes IA pressures monitored & stable prior to test. No tubing to IA problems reported by Operator. 1.9 bbls pumped for test. Thursday, March 02, 2006 Page 1 of I Schfumber~er B ,~ q_.. ~ ~ L~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth '~3~ii~:, r.. .a VL:d11Jl~~ta. ~-/~a~.~~~i ~~~bft.~7~ Field: Alpine • • Well Job # Log Description NO. 3695 Company: Alaska Oil 8~ Gas Cons Comm Attn; Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 color Date BL Prints CD CD2-11 REDO 11133210 SCMT ~- 3 12/14!05 1 CD3-110 11133217 SCMT o2p - ( 01/19/06 1 CD2-60 11133216 MEMORY CBL j - 01/15/06 1 CD2-60 11133216 PRESSURE & TEMPERATURE LOG 01/15/06 1 SIGNED: DATE: ~~ '~'~ ~~ Please sign and return one copy of this transmittal to Seth at the above address or fax to (907) 561-8367. Thank you. 02/21 /06 i WELL LOG TRANSMITTAL ~~~ -l~~% ~~ To: State of Alaska February 16, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian /,~(~ ~- 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs CD2-60 + PB 1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-60 + PBl LAS Data & Digital Log Images: 50-103-20511-00, 70 1 CD Rom 1 ~~ ,~~~~~~~ ! ,r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Alpine CRU CD2 02/04!06 Dusty Beller -AE5 John Crisp Packer De th Pretest Initial 15 Min. 30 Min. Well CD2-17A T e In'. W TVD 7,496' Tubing 1521 1521 1521 1521 Interval I P.T.D. 2050170 T e test P Test si 1874 Casing 400 2005 1940 1950 P/F P Notes: Initial MIT OA 400 600 550 550 Well CD2-59 T e In'. W TVD 6,899' Tubing 1826 1826 1826 1826 Intenaa{ I P.T.D. 2042480 T pe test P Test si 1725 Casing 550 2012 2000 2000 P/F P Notes: Initial MIT OA 700 800 800 810 Weli CD2-D2 Ty e In~. W TVD 7,105' Tubing 1637 1637 1637 1637 Interval I P.T.D. 2051090 T e test P Test si 1776 Casing 550 2420 2400 2390 P/F P Notes: Initial MIT OA 500 650 650 650 Well CD2-60 T e In'. W TVD 7,035' Tubing 1967 1967 1967 1967 {nterval P.T.D. 2050680 T e test P Test si 1759 Casing 250 2040 2020 2010 P/F P Notes: Initial MIT OA 420 620 620 620 Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CRU CD2 02-04-06-1.xls MEC:iANICAL INTEGRITY REPORT ~ ~~'~ ~~'`-' UD U '.. ~ : OPER ~ FIELD C~~'~ ~ `~j~~rl~~- :..G r S~S~ S~ : i.~LL NITMBER ~~a-~~ .~ ~ LL DAT ~_ TD : t~6~`~ .?~?.. ~~~~ S" V~D ; ?BTD : ?vID ?'VD ~« C ~ s i ~, g : Shoe : ~ i-11~3 ` MD TVD ; D ~l : ~~ ?~ ~~ ~ T~r`Di _:, e .. `---~'-l---- Shoe : '~ '?'`JT ; : CP . ?•~ 'i J -c~'-- ~~~_Packer \~,03~j?~ T'~i Set at ~~\~~"'~ _o1e i ~ S=~e ~ C~ and (~ ~~_; ~0~~ ~. Perks ~ to 133 \ r~~ ;S ~C"r'.P?3?C~_T, wNTEGR?TY - ~ Q~.T # 1 r_nnulus Press Test: I~ 15 min ~0 min ~ C oc~en t s : _ i'J~'JZ+r.c. ~.4,~,~`y S m~SS;JKc ~5~ . vJv~E tom. C~J c`1 ~ ~S ~~ ~ '-, w,`} ~ ~ ~ ~ ~ ~LC~ '-~' CH1~?~ 1 C~_.I., INTEGRITY - PAF? T # 2 ' --~ ~ ~~~ 1~j~j\, S ~ ` \ r Cement Volumes :~ A.mt. Liner NPo Cs~ 3~~y~; DV ~1~- . C,~t Jol to cover aer_s ~~ _ v ~:~ ,~~ ~c ~, ~ ~S~P ;~ s s f _ :~eoretical TOC C~ `Zo ~ ~ ~ \a\~~W ~,,` y t' ' u ~ Cement Bond Log (Yes or No) ~ In AOGCC File c~~c~ror.~r` ~ . 'u' ~ CBL Evaluation, gone above p erfs o~~ ~'~'lC~~ :clo~~ct,` `, ~ Production I.og: Type Evaluation CONCLUS ~ ON5 Part #1: ?art T2 ~d .. ~~ --o~ `,a5 Re: CD2-60:Approval request to commence WA•G injection Subject: Re: CD2-60:Approval request to commence WAG injection From: Thomas lti~la~znder <tom_maunder~a,admin,state.ak.us> Date: ti~t~"cal, ~~ tan X0(16 14:45:25 -0900 To: "Schneider, Tim S." -~Tin~.S.Sc}meidcrr~c?conocophillips.com~.~ ('C: "Pierson, Chris R" <C'tlris.R.Pierson%<<'~conocophillips.com.> Tim, I have examined the information you have submitted and confirm your assessment. It is preferable if it would have been possible to obtain more "log", however the angles are not in your favor. What log was obtained does should very good bond and it is not unreasonable to presume that cement deeper in the well is of similar quality. By copy of this email, you have approval to place the well in service. Please have the field people make arrangements for one of the Inspectors to witness a MIT once the well is thermally stabilized. Call or message with any questions. Tom Maunder, PE AOGCC Schneider, Tim S. wrote, On 1/25/2006 10:21 AM: Mr. Maunder, CPAI requests approval to commence WAG injection into CD2-60. The first cycle will be seawater. The SCMT log is attached. The log was run on January 15, 2006 and indicates good bond across the logged interval from 13;094' MD (7,008' SSTVD) to 13,189' MD {7,045' SSTVD). ®escription of 7" Casing Cement Job Purrtped on 6180f05: R)H with casing. Nole was packing off from 13,190 to 13,227. Worked pipe down from 13,227-13,245 without pumps. Hale conditions improved. Campleted RIH to 14,331' with circulation. Made up the cement head. Established circulation at 1 BPM 430 psi -final 3.5 BPM 730 psi, No pipe movement. Held PJSM for cement job. Cemented 7" casing as follows: Pumped 5 bbls CW 100. Tested lines to 3700 psi, Pumped 15 bbls CW-100 at 4.1 BPM @ 690 psi, Mixed & pumped 30 bbls of 11.5 ppg MudPush II ~ 4.1 BPM 680 psi. Dropped btm plug. Mixed & pumped 64.9 bbls of 15.8 ppg Class G w/ 0.2°lo DO46; 0.3% DO65, 0.4% ®167, 0.1 % B155 tai! slurry @ 4 BPM @ 400 psi. Dropped top plug wf 20 bbls water. Switched to rig pumps. Displaced cement with 480 Bbls of 9.6 ppg lSND mud from rig pump 5 BPM. Observed pressure increasing as Mudpush & Cmt turned the corner. Slowed pumps to 3.3 bblslmin w/480 bbls of displacement pumped wlpressure fram 440 psi to 580 psi. At 500 bbls. of displacement gone, pressure began rising from 580 to 1790 psi. Slowed pump to 1.6 bblsfmin {hole packing off -lost returns with 510 bbls of displacement gone}. Reduced to 1.6 BPM and bumped plug. CiP 1940 Hrs. Floats held, lost 10 bls mud during displacement - no flow from annulus after shutting down pump. 1 of 2 1/25/2006 2:46 PM Re: CD2-60:Approval request to commence W~ injection RU & pressure test 7'" casing to 3500 psi for 30 mins. C~K - RD The tubing and casing were successfully MIT'd an 7!9/05 as documented belaw; RU FMC lubricator. Test tree and FMC lubricator to 5000 psi 10 minutes -okay. RD lubricator. Test lines to 5000 psi. Pressure up on tbg to 4800 psi to set packer. Test tbg fior 30 mins. at 4800 psi. Bleed off annulus to 0 psi. Left well pressure of 1500 psi on tubing. 1TVe would like to place this well on seawater injection. All tie-in work and E&I is completed. The limited 95' MD intental we were able to fog indicates very good bond. Based on this information 1'd conclude the Alpine interval is adequately isolated in CD2-60. Please let me know if you have any questions. I`ll forward the MIT form to Bob and Jim. «CD2-60 Tbg detail.xls» «CD2-60 1320 View.pdf» «MIT CD2-60 7-9-05.x1s» «CD2-60 SCMT 15-Jan-2006 Print Rev #1.PDS» «CD2-60_log_08-05.ppt» Tim Schneider ConocoPhillips Alpine Subsurface Engineering Staff Engineer 907-265-6859 907-632-8136 (Mobile) tim.s.schneider(a3canocophillips.ca 2 of 2 1/25/2006 2:46 PM Tubing Detail ConocoPhillips Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM Company Well: ~;:€;;~~r:; Date: ?i ~•M: ~; 5 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS E~;ny,^~,:: 3~KIi t~. .:: G 32.54 PPe'•'.' G 1; '" TS;a hrngF: 3.83 32.54 ,f~., ;_49 `n 3:~t ;,~ ,ts 4 1 r^'" 2 :i~ L .?C; it=;TPw1 T:: 2280.90 36.37 ~a?~~a: 4 " , ~~ ?:;~p~: 5.fi?.." i~C x'~.£s1 ~ 1.46 2317.27 .(" <.~::? :~ ::~f~ `•~.lY.s. 41it"'i:5~ L•:?i; i~;TPN1 T': 6311.99 2318.73 P::p - 4 1;'" 12 :i~ t.-8~ iE~'-Pu1 ~1~;. 9.81 8630.72 Ga;`:trc 4 !2." +;F~i-2 t-..Pa`: t~';':;n::rn, .:~?~` 0:.; :~: ;?:i;3" ;f1 7.33 8640.53 P.::; - G 1;'" '.2 ti?? t. •8r €f-:T. Put ~l~-; 9.81 8647.86 ,JY.~. ~ YO 1:12 ' ~ 1 .Jf.=. 4 1 r`.<" 2 :7?f l_-?C; ?t;TPK1 T'~: 4365.20 8657.67 P.: - 4 1 ~ :" 12 i~ t-• 3r 1 tr'-Px1 "1~;, 9.86 13022.87 ~.:" ` ~: ~ .aie~;?' Prn:~-~:e~r ?%a;: ~::>r 5: l" . X :.?75" i~ 7.80 13032.73 P:::; - G 1I." ' 2 :~ t.-~T 3 f:'-P~~ Utz , 9.51 13040.53 Jts 1 ~n : 1 ,1?s G 1 i2" ~ r :~~ tr?C:f;TPu1 T: ~ 42.00 13050.04 u ~"':;1~" t~fi?PLF " C;:~ ;<:~ 72 :,IC 1.22 13092.04 F':,;: -~ ~ 1/2" "...,~ (-:-~;% I~~~~ '-ter 9.76 13093.26 ~`. 1;l` ~5't-PCz " C;:~ 5" t7D;; ~,+% " € 1.36 13103.02 ~4'€,~'" t1at9 t~k9 €~~; 13104.38 320 ~t:s. E~~ztt in p3Pe s~e~ 3i11 j'ts, try ru¢~ -19 1a~#: its. t~E~t >:a€..~e1 i+~ ~SCz41' '+:1C3 ~ 4~S~r:~' T~~ ~s`E?,',+~£?r v 13,iF33` 1~~ - ~0~5' ~~+: Tod t~f fitlg~ks~n „~"` -1~E,197' ?i~€D ~ T38~i ' T~FD viii )~S. ;~?'i'ft~+~ _-, ~•.843~: UEZ `1S`t - 1 _I ~E: SupervisorD. Burley / L. Hill STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS{ON Mechanical Integrity Test Email to: Ji3~, ;.;>g, ~.x??~#r:~i:~.;;ta~:.ak.~ bab "'es;: cr3ste~~ % ~ ,..:;, .z k ..~~ cfr3., ,,.A:...sk._is OPERATOR: ConocoPhillips Alaska Inc FIELD 1 UNIT /PAD: Alpine CD-2 DATE: 7/9/2005 OPERATOR REP: Larry Hill AOGCC REP: Packer De th Pretest initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-60 Inj. T pe N TVD 7,035' Tubing 1,600 1,750 1,750 1,750 Interval I P.T.D. 205-068 Test T e P Test psi 3500 IA 3,710 3,700 3,700 P/F P Notes: OA 700 700 700 700 MIT Report Form Revised: 03/18/04 MIT CD2-60 7-9-05.x1s • u CD2-60 (07/06/05) TD -- g CD 2-6 0 PR ELIM I ~ - I IMEW fIO A 1 ~ xSI iE RVD WAR t ~~. _ 3i ~ a 0 OIR 1b bYN 1D0 ~~ .) RP~_1 -_ GR 1 - RPS_t ___ _ __._ _- __ _ _. __ - __ - 7360' Nd _ _ __- _. _ unv: iso ss 1 1 _ a •e ~ i ALP D r e s¢ - •7 ~ QE r -'~ 3 . L c ` I f - S _ li _ _ ss 1 _ ..~._ _._._ _ s, ALP A Sand ,..,_.,. ALP B 1 ' _~ ~~~' 1 7776 saNa - _. _ ss 1 ~ ~7390'sstvd CD2~60P81 took a kick , 7100' uNd 7100' s h a weigh up to 12 ppg i rr ••lowr. •s7r+e+tr u a Possible fret's in Kingak m csr0ansr c«n•m-+8090 m0 bN•yh7 7• pp0 pressured up from CD2351nj -AraafrMUra i ~' - - ' intersected by CD2-60P81 well o ~ __. P "'4. ~ , - - _._. -__ < L- ~ Imruxpyrir-0% 17800.18200md aK R i iv' r " N°~ , as GR cleans u -Suppressed due to wafer ~ F ~ ~ ~, ~, ~ ~ ~ ~ i ~k ~ a ALP C ALP B4? ALP A ALP B ALP C roAm7rox_t 3 e ~ I ~~ u ~ '- ~~ ~ i ~~ ~I ~ . ~ I I / y 1 ~ ~ i ~ ~ _ L ~" ~ ~N jj ~ ~ ~ ~ . `~ IR~ I_ ~ ~ '.T i I ~r ~ ~~~ t~. ~~~ i ~l~ '~`'E~ IY b NOI ~ OP r _~ I I ,VI*T I I 1 _ ' ~., is h i I ~ '. ~ f - ~ll~. il.. ^ i • • • Edit Display annotate View Help • ConocoPhillips December 15, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-61.20 Alaska QI ~ ;,~~ Cons. C+~mmission Anchorage i Subject: Corrected Well Completion Report for CD2-60 /CD2-60PB1 (APD 205-068) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached corrected Well Completion Report for the recent drilling operations on the Alpine wells CD2-60 I CD2-60PB1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~- ~ ~t G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad • STATE OF ALASKA • ~~~~~~/~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ ~~a5 WELL COMPLETION OR RECOMPLETION REP RT. ND LOG 1a. Welt Status: Oil ^ Gas Plugged Abandoned Suspended ^ WAG ~/ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions~ Other_ 1b. ell ass: "`~.~;t Developm~~~~8~@ Exploratory ^ Service ~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: July 10, 2005 12. Permit to Drill Number: 205-068 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 8, 2005 13. API Number: 50-103-20511-00 & -70 4a. Location of Well (Governmental Section): Surface: 2162' FNL, 1491' FEL, Sec. 2, T11 N, R4E, UM 7. Date TD Reached: July 6, 2005 14. Well Name and Number: CD2-60 / CD2-60PB1 At Top Productive Horizon: 2419' FSL, 1589' FWL, Sec. 14, T11 N, R4E, UM 8. KB Elevation (ft): 36.7' RKB 1 52' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 1472' FNL, 1447' FEL, Sec. 23, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 18695' MD / 7375' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371744 y- 5974194 Zone- 4 10. Total Depth (MD + ND): 18695' MD / 7375' TVD 16. Property Designation: ADL 380075, 380077 TPI: x-369362 y- 5962976 Zone- 4 Total Depth: x- 371542 - 5959047 Zone- 4 11. Depth where SSSV set: Landing nipple @ 2317' 17. Land Use Permit: ALK ASRCNPRA 18. Directional Survey: Yes 0 No 19. Water Depth, if Offshore: NIA feet MSL 20. Thickness of Permafrost: 1847' 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" 62.5# H-40 36.7' 114' 36.7' 114' 42" Pre-installed 9.625" 36# J-55 36.7' 3276' 36.7' 2373' 12.25" 55o sx AS Lite, 241 sx Class G 7" 26# L-80 36.7' 14331' 36.7' 7378' 8.5" 315 sx Ctass G cement plug @ 11751'-12291' and 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 13104' 13033' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETG. open hole completion from 14331'-18695' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection not available Method of Operation (Flowing, gas lift, etc.) Injector -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure 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". NONE S Df-t<, [~~C 2 0 200 Form 10-407 Revised 12/2 ^ ~ ~ ~ ~ ~' ° CONTINUED ON REVERSE r~ 2a. 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". CD2-60 Seabee Form. 3359.5' 2412' Nanushak 6335' 3847' Gamma Ray Shale 12325.5' 6718' Kalubik 13096.5' 7061' Kuparuk Formation 13204' 7103' Miluveach 13843' 7309' Top Alpine D 13992' 7310' Top Alpine C 14197' 7365' Base Alpine C 18592' 7384' NiA TD 18695' 7375' CD2-60PB1 TD 13542' 7443' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name /~ 7C. Al~vord Title: Alpine Drillino Team Leader ( / Signature .F,L ~ /~lC.- Phone Date ' Lt t ~ ~~ ~ 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 December 7, 2005 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~EC~~vEa Commissioner SEC Q ~ ~pp5 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7 Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-60 /CD2-60PB1 (APD 205-068) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Alpine welts CD2-60 /CD2-60PB1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~~ ~ , (~'~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad - - ~~ • STATE OF ALASKA i ~E~ 4 ~ 2~~ ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil g CO~g, CummiBs WELL COMPLETION OR RECOMPLETION REPORT AND L~~rhn.«..~. 1a. WeII Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., s or Aband.: July 10, 2005 12. Permit to Drill Number: - 205-0681 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 8, 2005 13. API Number: 50-103-20511-00 ~ 4a. Location of Well (Governmental Section): Surtace: 2162' FNL, 1491' FEL, Sec. 2, T11 N, R4E, UM ~ 7. Date TD Reached: July 6, 2005 ~ 14. Well Name and Number: CD2-60 /CD2-60P61 At Top Productive Horizon: 2419' FSL, 1589' FWL, Sec. 14, T11 N, R4E, UM 8. KB Elevation (ft): 36.7' RKB / 52' AMSL ~ 15. Field/Pool(s): Colville River Field Total Depth: 1472' FNL, 1447' FEL, Sec. 23, T11N, R4E, UM 9, Plug Back Depth (MD + ND): 18695' MD 17375' ND Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 371744 " y- 5974194 J Zone- 4 10. Total Depth (MD + ND): - 18695' MD / 7375' ND ~ 16. Property Designation: ADL 380075380077 TPI: x-369362 Y- 5962976 Zone- 4 Total Depth: x- 371542 ' - 5959047 Zone- 4 11. Depth where SSSV set: Landing nipple @ 2317' 17. Land Use Permit: ALK ASRCNPRA 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: xx MD 21. Logs Run: GRiRes/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" 62.5# H-40 36.7' 114' 36.7' 114' 42" Pre-installed 9.625" 36# J-55 36.7' 3276' 36.7' 2377' 12.25" 550 sx AS lice, 241 sx Class G 7" 26# L-80 36.7' 14331' 36.7' 7378' 8.5" 315 sx Class G cement plug @ 11751'-12291' and 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 13104' 13033' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. open hole completion from 14331'-18695' MD '' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection not available Method of Operation (Flowing, gas lift, etc.) Injector -waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure 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". _ h0~~1' s i,i . I R~~a? ~I:~- I~E.f; C) 2005 NONE l ~ 7'!D - b .~": :_ . Form 10-407 Revised 12/2003 f 1 ~ ~ ~ ~ ~ ~ ~ CONTINUED ON REVERSE za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-60 Seabee Form. 3359.5' 2412' Nanushak 6335' 3847' Gamma Ray Shale 12325.5' 6718' Kalubik 13096.5' 7061' Kuparuk Formation 13204' 7103' Miluveach 13843' 7309' Top Alpine D 13992' 7310' Top Alpine C 14197' 7365' Base Alpine C 18592' 7384' N/A TD 18695' 7375' CD2-60P61 TD 13542' 7443' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name . Alvord Title: Alpine Drillino Team Leader Signature Phone Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared by Sharon Allsup-Drake Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion, Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 • ConocoPhillips Alaska ` Page ~ of ~ 3 Operations. Summary Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 'Date From - To Hours Code C©de' Phase Description of Operations 6/7/2005 18:00 - 23:00 5.00 MOVE ~ MOVE MOVE ~ Moved rig from CD2-59 to CD2-60 and rigged up. 23:00 - 00:00 1.001 WELCTL~ NUND MOVE ~ Nippled up riser and flowline. Taking on spud mud. 6/8/2005 00:00 - 01:30 ' 1.50 I DRILL 01:30 - 03:00 ~ 1.50 DRILL 03:00 - 04:00 1.00 DRILL 04:00 - 07:00 ~ 3.00 I DRILL 07:00 - 08:00 I 1.001 DRILL 08:00 - 13:45 I 5.75 f DRILL 13:45 - 00:00 I 10.25 I DRILL 6/9/2005 ; 00:00 - 12:00 ! 12.00 DRILL 12:00 - 20:00 I 8.00 I DRILL 20:00 - 21:00 i 1.001 DRILL 21:00 - 00:00 ; 3.00 ~ DRILL 6!10/2005 100:00 - 01:30 I 1.501 DRILL 01:30 - 02:45 1.25; DRILL 02:45 - 04:00 I 1.25 ~ DRILL 04:00 - 06:45 I 2.75 i DRILL 06:45 - 08:30 I 1.751 DRILL 08:30 - 10:30 i 2.001 DRILL 10:30 - 12:30 I 2.001 CASE 12:30 - 15:45 I 3.25 i CASE 15:45 - 16:15 ! 0.501 CASE Rig accepted @ 2300 Hrs. OTHR . SURFAC NU riser -Take on spud mud PULD SURFAC PU 8" MN flexDC's & HWDP & std back in derrick OTHR SURFAC Fill hole & check for laeks -Held pre-spud meeting with crews PULD I SURFAC MU BHA -bit, motor, MWD -Upload MWD -orient tools -Pressure test mud lines to 3500 psi DRLG SURFAC Spud in @ 0700 hrs. -Drill 12 1/4" hole f/ 114' to 16T J WOB 5 k RPM 40 GPM 450 @ 700 psi String wt. PU 90 SO 90 Torque on/off btm.- 3500!3500 ft. lbs. MWD not pulsing OTHR SURFAC Trouble shoot MWD -pull & change out pulser -check connection @ Hcim -Upload MWD -RIH to 167' -MWD failed -Pull out & change out ( -Upload MWD -RIH to 167' ' " ' DRLG SURFAC MD 1,125 TVD Drill 12 1/4 hole f/ 16T to 1,165 WOB 25/35 k RPM 40 GPM 530 @ 1450 psi i String wt. PU 115 SO 110 i ~ Torque on/off btm.- 800016000 ft. lbs. ADT- 5.25 hrs =ART - 2.05 hrs. AST - 3.20 hrs. i DRLG SURFAC Ran 6 gyro surveys. Drill 12 1/4" hole f/ 1,165' to 2688' MD - 2117 TVD ADT - 12.71 hrs. =ART - 7.62 hrs. AST - 5.09 hrs. i WOB 30 k RPM 60 GPM 650 @ 2880 psi String wt. PU 126 SO 115 Rot 121 ~ Torque on/off btm. - 9,500/7,500 ft. lbs. ! ' ' DRLG SURFAC Drill 12 1/4 from/ 2688 MD - 2377 TVD to 3286 ADT - 4.9 hrs. =ART - 4.79 hrs. AST - .11 hrs. WOB 25/35 k RPM 60 GPM 650 @ 2300 psi String wt. PU 130 SO 115 Rot 120 Torque on/off btm. - 9,000/7,500 ft. lbs. CIRC SURFAC Circulated sweep out of hole. WIPR SURFAC POOH backreaming with 40 RPM 500 GPM. Hole packed off if pulling ~ too fast. Over pull 10/20 K. ' ' WIPR SURFAC ~ Continue POOH w/ pump f/ 2021 to 884 - 500 gpm @ 1300 psi w/ 50 rpm TRIP SURFAC Flow check (static) RIH f/ 884' to 3286' -Hole in good condition CIRC SURFAC Break circulation -Pump nut plug sweep & circulate hole clean 600 gpm @ 2200 psi w/ 60 rpm TRIP SURFAC Fiwo check (static) POOH on TT f/ 3,286' to 1,926' (hole took good fill) POOH f/ 1926' to 1640' -improper fill - Monitor well (static) TRIP ~ SURFAC RIH f! 1640' to 1926' -Monitor well (static) POOH f! 1926' to 167' -hole took proper fill PULD i SURFAC Handle BHA -Std back NM flex DC"s -Down load MWD - LD MWD - OTHR i SURFAC motor & bit LD Iron roughneck spinners - RU to run 9 5/8" casing -Pre job safety meeting RUNC ~ SURFAC Run 9 5/8" 36# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats -first 4 connections made up w/ BakerLoc) 41 jts. csg. for 45 total to 1885' CIRC SURFAC 'I Break circulation -circulate btms up + Printed: 7/14/2005 2:50:13 PM • ConocoPhillips Alaska Page 2 of ~ 3 Operations Summary Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Sub !phase Code ! Description of Operations 6/10/2005 ~ 16:15 - 18:00 1.75 ~ CASE i RUNC SURFAC Continue running 9 5/8" 36# BTC csg. f! 1885' to 3,276'. Total jts. run 78 -Landed casing @ 1800 Hrs w/ shoe @ 3276' & FC @ 3188' 18:00 - 18:30 0.501 CASE RURD SURFAC Made up cement head and laid down Franks fillup tool. 18:30 - 22:15 3.75 CASE CIRC SURFAC Circulated working rate up to 7 BPM. Checked out stroke counter for count total. PJSM for Cementing. 22:15 - 00:00 1.75 CEMEN PUMP SURFAC Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/nut plug - 6 bpm @ 240 psi w/ rig pump -Switch to Dowell -Pumped 3 bbls water -test cement lines to 2500 psi -Dropped btm plug -Mixed & ~ pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.0 bpm @ 175 psi - " " Mixed & pumped 435 bbls of lead slurry (ASL w/ 30% D-53, 0.6% G D046, 1.5% D079, 1.5% S001, 43.1% D124, 9°lo BWOW D44, 0.5% ~ ~ D-65) @ 10.7 ppg - 6.5 bpm @ 50 - 350 psi -switched to tail slurry 50 Bbls ("G" w/ 0.2% D46, 0.3°!o D65, 2% S001) @ 15.8 ppg - 5.2 bpm i @ 325 - 400 psi 6/11 /2005 00:00 - 00:45 0.75 CEMEN DISP SURFAC ~ Dropped top plug 8~ pumped 20 bbls water w/ Dowell -Switch to rig ~ ~ ~ pumps -Displaced w/ 9.6 ppg mud @ 7 bpm 370 to 600 psi for first 220 i bbls -slowed to 4 bpm @ 660 psi for last 6 bbls. -Bumped plug t! 1050 i psi - CIP @ 0040 hrs, floats helds. ~~ Full returns during job w/ 200 bbls cement returns to surface - i f recripcated pipe until 360 Bbls of lead slurry away, landed hanger on 00;45 - 01:30 ~ 0.75 CEMEN OTHR SURFAC i 01:30 - 03:45 ~ 2 25 CEMENT{ OTHR SURFAC landing ring. Test casing to 2600 psi for 30 mins. RD cmt lines & head -flush riser & landing jt . ~ . 03:45 - 07:00 3.25 WELCTL~ NUND SURFAC ND riser -Install wellhead & test to 5000 psi - NU BOPE 107:00 - 08:00 1.00 WELCT OTHR ~ SURFAC Set test plug & rig up to test BOPE ~ 08:00 - 13:00 5.00 WELCTL BOPE ~ SURFAC Test BOPE to 250 psi ii 5000 psi - Annular to 3500 psi -perform i accumulator closure test -Witnessing of test waived by Chuck Scheve ~ AOGCC 13:00 - 13:30 ~ 0.50 WELCT OTHR SURFAC RD test equipment -pull test plug -Set wear bushing 13:30 - 14:00 ~ 0.50 DRILL OTHR SURFAC RU to pick up 5" drill pipe 14:00 - 00:00 ~ 10.00 DRILL PULD SURFAC PU 5" drill pipe f/ pipe shed ~ stand back in derrick 6/12/2005 00:00 - 02:00 i 2.00 DRILL ~ PULD SURFAC Finish picking up & standing back 5" drill pipe (291 jts - 97 stds.) 02:00 - 05:00 3.00. DRILL PULD SURFAC MU 8 1/2" BHA -Geopilot, MWD w/ RA sources -Unload MWD -Load RA sources -RIH w/ NM flex DC's to 198' 05:00 - 06:45 ~ 1.75 DRILL TRIP SURFAC RHI w/ BHA & HWDP to 740' -Shallow test MWD &Geopilot 06:45 - 09:15 ~ 2.50 DRILL ~ TRIP SURFAC ~ RIH f/198' to 3037 -picking up 5" drill pipe (72 jts.) & Ghost reamers 09:15 - 10:15 i 1.00 DRILL CIRC SURFAC ~ Break circ -Circulate string vol. & btms up -breaking in seals on ~ ~ ~ Geopilot -Wash down f/ 3037 -tag top of cmt @ 3169' -Clean out cmt ~ ~ ~ to top of FC @ 3188' 10:15 - 12:30 i 2.25 CEMENT(DSHO SURFAC Clean out shoe track -Drill FC @ 3188' - cmt to top of FS @ 3274' - i ~ Drill out shoe - Cleanout out rat hole to 3286' -Drill 20' new hole to 1 1 3306' 12:30 - 13:00 0.50 CEMENI CIRC i SURFAC CBU. 13:00 - 14:00 1.00 CEMEN FIT i SURFAC 14:00 - 21:00 ~ 7.00 DRILL DRLG INTRM1 ~ RU perform LOT to 16.3 PPG EMW.- RD ~ Drill f! 3,306' to 4,175' MD / 2,825' TVD, ADT= 4.63 hrs, WOB 10/15K, RPM 170, 665 gpm @ 2200 psi, UP 160 K, DN 112 K, ROT 135 K, Torque on 11,000 ft/Ib -off 10,500 ft/Ib, ECD's ranging f/ 11.0 to 11.4 i ~ ppg, Mud wt. 9.6 ppg, Pumping Hi-vis weighted sweeps every +/- 10 21:00 - 22:30 1.50 RIGMNT RGRP ~ INTRM1 stands. j Working on SCR. Unable to drill with one pump due to no MWD data or ability to send commands to Geo pilot. 122:30 - 00:00 ~ 1.50 DRILL DRLG INTRM1 Drill f/ 4,175' to 4,270' MD / 2,879' TVD, ADT= .85 hrs, WOB 10/15K, ~ ~ ~ RPM 170, 665 gpm @ 2210 psi, UP 160 K, DN 112 K, ROT 135 K, Printed: 7114!2005 2:50:13 PM r1 ~J ConocoPhillips Alaska Operations. Summary "Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From..- T 6112/2005 22:30 - 00:( CD2-60 CD2-60 ROT -DRILLING doyon1 @ppco.com Doyon 19 Hours ~; Code 'Code Ij Phase 1.50 ~ DRILL ~ DRLG ~ INTRM1 6/13/2005 100:00 - 04:30 4.501 DRILL DRLG ~ INTRM1 04:30 - 05:45 I 1.251 RIGMNTI RGRP ~ INTRM1 05:45 - 09:15 ~ 3.50 ~ DRILL f DRLG ~ 1NTRM1 09:15 - 09:45 0.50 RIGMNT RGRP INTRMI 09:45 - 12:00 2.25 DRILL .DRLG i INTRM1 12:00 - 00:00 I 12.00 I DRILL ;DRLG I INTRM1 6/14/2005 100:00 - 12:00 I 12.00 I DRILL I DRLG I INTRM1 12:00 - 00:00 1 12.001 DRILL I DRLG ! INTRM1 6/15!2005 ! 00:00 - 07:30 7.50; DRILL I, DRLG 1 INTRMI 07:30 - 08:00 0.50' DRILL DRLG INTRMI 08:00 - 12:00 ! 4.00 ~ DRILL DRLG INTRM1 12:00 - 14:00 I 2.00 i DRILL 1 DRLG !INTRMI 14:00 - 15:15 1.25 DRILL CIRC INTRM1 Start: 6/7/2005 Rig Release: 7/10/2005 Rig Number: 19 Page 3 of 13 Spud Date: 6/8/2005 End: 7/10/2005 Group: Description of Operations Torque on 11,000 ft/Ib -off 10,500 ft/Ib, ECD's ranging f/ 10.9 to 11.4 ppg, Note: Drilling with jumper on SCR while looking for part. Drill 8 1/2" hole w/ GeoPilot f/ 4270' to 4651' MD 3078' TVD WOB 15 k RPM 100/130 GPM 670 @ 2300 psi Saver sub back out of TD -Change out saver sub Drill 8 1/2" hole w/GeoPilot f/ 4651' to 5127' MD 3308' TVD WOB 15k RPM 100!130 GPM 670 @ 2300 psi Lost high line power - e{eetrican working on SRC to restore power Drill 8 1/2" hole w/ GeoPilot f/ 5127' to 5222' MD 335$' TVD ADT past 12 hrs. - 5.41 hrs. WOB 15 k RPM 100/130 GPM 670 @ 2300 psi String wt. PU 155 SO 125 Rot 140 Torque on/off btm - 12,000/10,000 ft. lbs. ECD - 10.8 to 11.6 ppg Drill 8 1/2" hole w! GeoPilot f! 5222' to 6363' MD 3861' TVD ADT past 12 hrs. - 6.85 hrs. WOB 10/15 k RPM 100/140 GPM 670 @ 2600 psi String wt. PU 162 SO 135 Rot 148 Torque on/off btm - 10,000/8,000 ft. lbs. ECD - 11.1 to 11.8 ppg Drill 8 1/2" hole w/ GeoPilot f/ 6363' to 7982' MD 4626' TVD ADT past 12 hrs. - 7.97 hrs. WOB 15/20 k RPM 130 GPM 670 @ 2710 psi String wt. PU 180 SO 145 Rot 162 Torque on/off btm - 12,000/10,000 ft. lbs. ECD - 11.1 to 11.7 ppg Drill 8 1 i2" hole w1 GeoPilot fl 7982' to 9409' MD 5334' TVD ADT past 12 hrs. - 7.06 hrs. WOB 15/20 k RPM 145 GPM 670 @ 2620 psi String wt. PU 200 SO 160 Rot 175 Torque on/off btm - 14,000/12,000 ft. lbs. ECD - 11.1 to 11.7 ppg Drill 8 1/2" hole w/ GeoPilot f/ 9409' to 10,359' MD 5791' TVD WOB 15/20 k RPM 155 GPM 675 @ 3000 psi String wt. PU 215 SO 155 Rot 185 Torque on/off btm - 15,500/12,000 ft. lbs. ECD - 11.1 to 11.7 ppg GeoPilot stuck in the home position. Troubleshoot tool. Drill 8 1/2" hole w/ GeoPilot f/ 10,359' to 10,825' MD 6016' TVD ADT past 12 hrs. - 7.32 hrs. WOB 15120 k RPM 155 GPM 640 @ 2270 psi String wt. PU 220 SO 160 Rot 185 Torque on/off btm - 13,000111,500 ft. lbs. ECD - 11.1 to 11.3 ppg Drill 8 1/2" hole w/ GeoPilot f/ 10,825' to 11,121' MD 6146' TVD ADT 1.73 hrs. WOB 20 k RPM 165 GPM 670 @ 2450 psi String wt. PU 225 SO 165 Rot 190 Torque onloff btm - 15,000/11,000 ft. lbs. ECD - 11.1 to 11.3 ppg Geopilot failed. Circulated hole clean. Printed: 7/14!2005 2:50:'13 PM C: ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT -DRILLING Start: 6R/2005 Contractor Name: doyon1 @ppco.com Rig Release: 7/10/2005 Rig Name: Doyon 19 Rig Number: 19 Date From = To Hours .:.Code Sub Phase Code r 6!15/2005 15:15 - 00:00 8.75 ~ DRILL TRIP INTRMI 6/16!2005 00:00 -04:30 4.50 DRILL PULD I INTRMI 04:30 - 05:00 0.50 DRILL TRIP INTRM1 05:00 - 05:30 0.50 DRILL OTHR INTRM1 05:30 - 06:30 1.00 DRILL TRIP INTRM1 06:30 - 08:00 1.50 RIGMNT RSRV INTRM1 08:00 - 08:30 0.50 WELCT OTHR INTRM1 08:30 - 13:15 4.75 DRILL ~ TRIP INTRM1 13:15 - 14:00 0.75 DRILL REAM INTRMI 14:00 - 00:00 10.00 DRILL DRLG ~ INTRM1 6/17/2005 6/18/2005 00:00 - 12:00 ; 12.00 i DRILL I DRLG I INTRM1 12:00 - 23:15 11.25 DRILL DRLG INTRM1 23:15 - 00:00 i 0.75 WELCT OBSV I INTRM1 00:00 - 01:00 I 1.001 WELCTLI COND I INTRM1 01:00 - 02:30 i 1.501 WELCTL KILL ! INTRM1 02:30 - 03:30 I 1.00 i WELCTIj OBSV I INTRM1 03:30 - 09:30 ':, 6.001 WELCTI~ KILL INTRM1 09:30 - 10:00 I 0.501 WELCTu OBSV INTRM1 10:00 - 12:45 ~ 2.751 WELCTL ~ KILL ' INTRM1 12:45 - 13:00 ~ 0.25 ~ WELCT OBSV INTRMI 13:00 - 19:15 6.25 WELCT KILL INTRM1 19:15 - 22:00 i 2.75 WELCT OBSV ~ INTRM1 Page 4 of 13 Spud Date: 6/8/2005 End: 7/10/2005 Group: Description of Operations POOH to BHA. Std back HWDP. PJSM. Remove sources. Download MWD. LD GeoPilot. MU motor and bit. Change out pulser. Upload MWD. RIH to 739'. Shallow test MWD. Blow down top drive. RIH w/ 5" DP f/ 739' to 3224'. Cut and slip drilling line. Service top drive and drawworks. Fill pipe. Function test all BOP components. RIH to 11,027'. Washed and reamed from 11,027' to 11,121'. Drill 8 1/2" hole w/Mud motor f/ 11,121' to 11,867' MD 6505' TVD ADT 6.9 hrs. AST 1.03 hrs ART 5.87 hrs WOB 12/17 k RPM 120 GPM 651 @ 2950 psi String wt. PU 235 SO 170 Rot 198 Torque on/off btm - 19,000!18,000 ft. lbs. ECD - 10.8 to 11 ppg Drill 8 1/2" hole w/Mud motor f/ 11,867' to 12,646' MD 6921' TVD ADT 7.7 hrs. AST 1.6 hrs ART 6.1 hrs WOB 12/17 k RPM 120 GPM 651 @ 3300 psi String wt. PU 260 SO 170 Rot 205 Torque on/off btm - 20,000/19,500 ft. lbs. ECD - 10.8 to 11 ppg DriN 8 1!2" hole wlMud motor f/ 12,646' to 13,542' MD 7443' TVD ADT 6.59 hrs. AST .7 hrs ART 5.89 hrs WOB 12/17 k RPM 120 GPM 630 @ 3220 psi String wt. PU 290 SO 175 Rot 215 Torque on/off btm - 22,500/21,500 ft. lbs. ECD - 10.8 to 11 ppg Checked well due to flow increase. Well flowing. Shut in and observed pressure. Worked kill sheet and begin mixing 11 PPG kill mud. Pressures: 2335 hrs DP 560 Casing 429 Est gain Driller 8 Bbls. 2340 hrs 560 420 2345 hrs 540 410 2350 hrs 520 400 2355 hrs 500 390 0000 hrs 480 390 Observe well while weighting mud system to 11.0 ppg. SIDPP - 480 psi to 370 psi. SICP - 390 psi to 380 psi. PJSM. Pump kill wt mud to bit at 3 bpm at 980 psi. Losing mud to formation. Drill pipe pressure increased to 1460 psi with no increase in casing pressure. S1 and observe welt. SIDPP 90 psi. SICP - 380 psi. Mix 20 ppb Mix II for loss circulation. Circ kill wt mud to surface. Unable to weight up returns to 11.0 ppg at 3 bpm. Reduced rate to 2 bpm. Kill wt mud cut from 11.0 ppg to 10.2 ppg. Small amount of gas. Had 5000 ppm chloride increase. Influx is seawater. SI and obseve well. SIDPP - 130 psi. SICP - 280 psi. Increas mud wt to 11.4 ppg. Pump kill wt mud @ 2 BPM SIDPP 90 psi SICP 290 psi. Shut in SIDPP 90 psi SICP 290 psi. Pumping kill mud 11.4 PPG. 3BPM @ FCP 490 psi. Shut in and monitor weN SIDDP 40psi SICP 160psi weight up system to Printed: 7/14/2005 2:50:13 PM ConocoPhillips Alaska Page 5 of 13 Opera#ions`Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To 6/18/2005 19:15 - 22:00 22:00 - 00:00 6!19!2005 00:00 - 01:30 101:30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:30 07:30 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 14:30 14:30 - 22:30 22:30 - 00:00 6/20/2005 100:00 - 02:30 02:30 - 04:30 04:30 - 12:00 12:00 - 16:15 ~ 16:15 - 17:00 17:00 - 20:00 20:00 - 21:30 21:30 - 22:15 22:15 - 00:00 I 6121 /2005 00:00 - 02:00 02:00 - 02:30 02:30 - 04:30 j 04:30 - 10:00 I 10:00 - 10:30 10:30 - 17:45 I 17:45 - 19:45 19:45 - 20:45 CD2-60 CD2-60 Spud Date: 6/8/2005 ROT -DRILLING Start: 6!7/2005 End: 7/10/2005 doyon1@ppco.com Rig Release: 7!10/2005 Group: Doyon 19 Rig Number; 19 Hours Code !Code ! Phase Description of Operations 2.75 WELCTy OBSV INTRMI 11.4ppg Bleed offAnnular 2.00 WELCTy OTHR INTRM1 Opened well and established circulation @ 2 BPM 1050 psi. Packed off. ~ ~ Working pipe with intermintent circulation and rotation. ' ' 1.501 WELCTL~ OTHR INTRMI Work pipe from 13,542 to 13,520 . Hole pkg off and sticky. 1.00 ~ WELCTL CIRC INTRM1 Est' circ at 3 bpm. Increase flow rate to 11 bpm at 2700 psi. Attempt to III std back one std. Top drive would not function in the reverse mode. ~ Resume circ at 10 bpm at 1100 psi w! no MWD signal. 0.50 WELCTL OTHR ~ INTRM1 Had small flow out annulus. Pressure test surface equipment to 2000 I psi. OK. 1.00 WELCT CIRC j INTRMI CBU at 8 bpm at 650 psi. 1.00 WELCT OTHR INTRM1 Perform exhale test. Test indicated breathing. Std back 1 std. 2.50 WELCT TRIP INTRM1 Had small flow out annulus. POH w/ pump from 13,502' to 12,169' at 3 3.00 i WELCT COND ~ INTRM1 bpm - 250 psi. Monitor well. Initially static. Well started flowing out annulus after 5 min. i ~ Circ and increase mud wt to 11.7 ppg. 1.00 WELCTL OBSV INTRM1 Observe well. Std back 1 std. Well is static. 0.50 ~ WELCTI~ TRIP j INTRM1 POH on trip tank from 12,065' to 11,694'. Hole not taking proper fill. ~ I I I Had small flow out annulus. RIH to 12 074'. 2.50 WELCTL~ KILL I INTRMI , I Circulated @ 7.5 BPM 590 psi and raised MW to 12 PPG. Well static. 8.00 WELCTLTRIP INTRMI POOH on trip tank. Drill pipe parted. Top of Fish 12,329'. Fish consist of i ~ 1 17 Jts of drill pipe + BHA. Total length of fish 1,213.22'. Fishing neck I i 21.13' of 5" DP. 1.50 FISH PULD ~ INTRM1 Picked up and made up fishing string. 2.50 FISH PULD I INTRM1 IConf PU and RIH w/ fishing assembly. RIH with 3 stds 5" HWDP. 2.00 (FISH TRIP 1 INTRMI ~ RIH to 3250'. 7.50 RIGMNT RGRP i INTRM1 Shut well in. Switch rig power from highline to cold start generator. Change out components in #3 SCR. RD Geospan. Change out washer ~ 'springs on top drive dollies. 4.25 FISH TRIP INTRM1 RIH from 3,250' to 8,292'. 0.75 ~ FISH ~ CIRC INTRM1 Circulated and pumped slug to prevent pipe from over flowing. ' ' 3.001 FISH TRIP INTRM1 RIH from 8,292 to 11,761 . Taking weight. 1.501 FISH ~ CIRC INTRM1 ~ Washing down taking weight. Circulating @ 4 BPM 610 psi. Slowly ~ 0.75 FISH I CIRC I INTRMI increased rate to 10 BPM @ 1520 psi. Started Posing @ 85 BPH. I Mixed and pumped 40 Bbls LCM 25 PPB. washed down to 12,173' with 1 1.751- FISH (TRIP I INTRM1 I partial returns taking weight. Washing down and RIH to 12,282' with partial returns. Rotating and i I i I working in overshot was swabing on the up stroke and pushing mud in Mud lost 430 Bbls ~ on the down stroke Est 2.00 j FISH ~ FISH i INTRMI . . . 1 Wash to top of fish at 12,313'. Pump at 2.3 bpm at 430 psi w/ no ~ I 0 50 ~ 1 FISH TRIP ~ INTRMI returns. Tq - 18k-20k. Unable to engage fish. f! 12 313' 11 878' / t POOH ! . 1 1 ( I , w no re urns. w pump , to 2.00 FISH OTHR INTRM1 I Mix and spot 25 bbls LCM pill. (7 ppb each - G-Seal, Nut Plug ,Mix II). ~ 5.50 ~ FISH TRIP I INTRMI No returns. POOH w/ pump f/ 11,878' to 7406' w/ no returns. Hole became wall ' ' I i . 75k above wt to free drill string after each sticky from 9500 to 7500 i connection. Mud started u-tubing out drill pipe at 8000'. 0.501 FISH ~ OTHR I INTRM1 Pump 40 bbl dry job. Well is static. Hole will not take fill. 7.25 i FISH I TRIP ~ INTRM1 POOH on trip tank from 7406' to 2106'. Fill hole through drill pipe. ~ i Monitor well @ 3249' & 2106' (static) POOH f! 2106' to 686' -hole I taking proper fill -Stand back HWDP ' 2.001 FISH f PULD INTRM1 s - LD circ sub, xo, oil jars & bumper sub. i;< I LD Acc. jars, Std, back DC j I ~ overshot (overshot was packed solid w! shale) j 1.001 FISH OTHR INTRM1 Clean up rig floor -measure fishing tools for run #2 -Overshot for 2nd Printed: 7/14/2005 2:50:13 PM ConacoPhillips Alaska Page 6 of 13 Operations Summary"Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7!10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date 'From.- To Hours Code ~ Sub ', phase ~' Description'of Operations Code.; 6/21 /2005 j 19:45 - 20:45 ` 1.00 FISH , OTHR INTRMI I run wrong OD -Sent to Baker shop - (well static) 20:45 - 22:15 22:15 - 00:00 1.50' RIGMNT RSRV 1.75 WELCT OTHR 6/22/2005 00:00 - 02:00 2.001 FISH 02:00 - 10:00 i 8.00 FISH 10:00 - 10:30 I 0.50 FISH 10:30 - 13:30 ~ 3.00, FISH 13:30 - 19:30 ~ 6.00 FISH 19:30 - 20:00 0.50 FISH 20:00 - 00:00 4.00 I FISH i 6/23!2005 ~ 00:00 - 00:30 00:30 - 02:00 02:00 - 05:30 05:30 - 09:00 09:00 - 09:30 09:30 - 09:45 09:45 - 12:30 12:30 - 13:00 ~ 13:00 - 20:15 i 20:15 - 21:30 21:30 - 23:00 23:00 - 00:00 PULD TRIP OTHR FISH TRIP CIRC TRIP INTRM1 PJSM -Slip i3< cut 60' drill line -service TD (monitor well on TT -static) INTRM1 Drained stack -pull wear bushing -Set test plug -Prep to test BOPE - Observed flow f/annulus from below test plug -Pulled test plug -filled stack -monitor well (static) set wear bushing * Overshot back f/ Baker shop * Note: Lost 697 bbls mud to hole last 24 hrs. INTRM1 MU 8 1/8" crippled mill shoe, overshot with 5"grapple, extension, bumper sub, jars, 12 - 6 114" collars and accelerator. INTRM1 RIH f/ 686' to 12,074. Pump 8 bbls mud every 10 stds to clear tools. Pump 3 bbm at 40 - 90 psi w! no returns. Lost 109 bbls on trip in hole. INTRMI Wash f/ 12,704' to 12,313' at 3 bpm at 500 psi. Tagged up at 12,313'. INTRMI Work pipe from 12,313' to 12,325' at 2.5 bpm - 400 psi. Top drive torque - 20k-24k at 30 rpms. Torque dropped to 18k at 12,325'. Unable Ito make any progress below 12,325'. INTRM1 I POOH w/ pump f/ 12,325' to 7979' - 2.4 to 1 BPM @ 200 psi -mud u tubing out of drill pipe INTRM1 Observed well -static -pumped dry job - no returns -monitor well static INTRMI POOH on TT -monitoring hole flow checked @ 7028', 6551' & 6075' well static 0.50 { FISH TRIP I PROD 1.50 I FISH TRIP ~ PROD 3.50 FISH TRIP I PROD 3.50 FISH PULD j PROD 0.50 CEMENTI PULD 0.25 CEMENT{{ SFTY 2.751 CEMENI(TRIP 0.50 CEMENl~TRIP 7.251 CEMENIjTRIP 1.25 CEMENl~CIRC ~ I~ 1.50 CEMENlIPLUG PROD PROD PROD PROD PROD PROD PROD 1.001 CEMEN~?TRIP PROD 6/24/2005 j 00:00 - 01:00 1.00 01:00 - 05:30 4.50 05:30 - 07:00 1.50 TRIP (INTRMI CMT ~ INTRMI TRIP ,INTRMI Lost 832 bbls to hole over last 24 hrs. POH on trip tank f! 5980' to 5504'. Hole not taking proper fill. POH w/ pump f/ 5504' to 3887'. 1.2 bpm at 90 psi. Pump dry job. POH on trip tank f/ 3887' to 686'. Monitor well. Static. Std back HWDP. LD fishing BHA. Overshot was plugged with clay/shale. Circulating sub above jars was sheared. RU 3 112" tbg equipment. PJSM on running tbg. PU and RIH w! 3 1/2" muleshoe and 32 jts 3 1!2" tbg. MU XO's and Halliburton plug catcher. RIH w/ 1 std 5" DP. Break circ. Circ well at 4 bpm with full returns. RIH w/ cementing assembly f1 1099' to 12,229' Wash down f/ 12,229' to 12,325' - 3 bbls/min @ 400 to 550 psi -hole getting stickle f! 12,295 to 12,325' -pulled up & LD 1 single of DP - RU cement head & lines -resumed pumping & working pipe Held PJSM -With tbg stinger @ 12,291' Set P&A / KO plug as follows Pumped 5 bbls water -tested lines to 3000 psi -pumped 15 bbls water - Mixed & pumped 57 bbls. 17.0 ppg Class G cmt @ 4.5 bbls/min @ 772 to 257 psi -pumped 9 bbls water behind -shut down & dropped drill pipe dart -Displaced w/ 186 bbls 12.0 ppg mud -latched dart into plug catcher sub w/ 510 psi -bleed off pressure -dart held - CIP @ 1053 hrs. -rig down cement head & lines POOH f/ 12,291' to 10,897' - on TT -hole was swabbing -flow check - well static Shear plug catcher at 2880 psi. POH w/pump f/ 10,897' to 10,385' at 1.3 bpm at 190 psi. Check flow. Static. WOC RIH f/ 10,325' to 11,087'. Wash down at 2 bpm at 350 psi w/slight returns and tag cement at 11,751'. Printed: 7/14/2005 2:50:13 PM • ConocoPhiUips Alaska Operations Summary Report Legal Well Name: CD2-60 Page 7 of 13 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code bode Phase 6!24!2005 07:00 - 13:30 i 6.50 ~ DRILL TRIP ~ INTRM1 13:30 - 14:30 14;30 - 15:00 15:00 - 19:30 1.00 DRILL ~ OTHR INTRM1 0.50 WELCT~OTHR INTRM1 4.50 WELCT BOPE INTRM1 19:30 - 20:00 20:00 - 22:00 22:00 - 00:00 6/25/2005 00:00 - 00:30 00:30 - 01; 00 01:00 - 03:30 03:30 - 07:30 ~ 07:30 -09:00 109:00 - 09:30 09:30 - 10:00 10:00 - 11:00 0.50 WELCTI~ OTHR `INTRM1 2.00 DRILL OTHR INTRMI 2.00 DRILL TRIP IINTRMI 0.50 DRILL STRIP INTRMI 0.50 DRILL RIRD INTRM1 2.50 DRILL PULD INTRM1 4.00 DRILL PULD INTRM1 1.501 RIGMNT RSRV INTRM1 0.500 DRILL CIRC INTRM1 0.50 DRILL 'TRIP INTRM1 1.00 DRILL CIRC INTRM1 11:00 - 11:30 ~ 0.50 DRILL TRIP ~ INTRM1 11:30 - 12:30 1.00 DRILL CIRC INTRM1 12:30 - 12:45 0.25 DRILL OTHR INTRMI 12:45 - 13:45 1.00 DRILL TRIP I INTRM1 13:45 - 14:45 1.00 DRILL CIRC IINTRMI 14:45 - 15:00 0.25 DRILL OTHR INTRM1 15:00-16:00 ~ 1.00 DRILL (TRIP INTRMI 16:00 - 17:30 ~ 1.50 DRILL I CIRC INTRM1 17:30 - 17:45 0.25 DRILL OTHR INTRMI 17:45 - 18:45 ~ 1.00 DRILL TRIP INTRMI 18:45 - 20:15 i 1.50 ~ DRILL i CIRC IINTRMI 20:15 - 20:30 0.25 DRILL OTHR INTRM1 20:30 - 23:15 ; 2.75 DRILL ,REAM , INTRM1 I, 23:15 - 00:00 ~ 0.75 DRILL ~ OTHR j INTRMI 6126!2005 100:00 - 01:30 ~ 1.50 DRILL OTHR INTRMI 01:30 - 05:30 4.00 DRILL DRLG INTRM1 05:30 - 12:00 i 6.501 DRILL , DRLG , INTRM1 12:00 - 21:30 i' 9.501 DRILL DRLG I INTRM1 Description of Operations POH w/ 2 stds DP. Pump dry job. POH on trip tank to 10,135'. Well is breathing. Pump dry job. POH on trip tank to 3094'. Monitor well. Static. PJSM. MU and set Baker storm pkr at 124'. Pull wear bushing set test plug RU i~ test ROPE - Hydril to 250 & 3500 psi -Pipe rams, blind rams, choke ii kill line valves, choke manifold valves,TD IBOP valves, dart & floor safety valves -performed accumulator closure test -Test witnessed & approved by Jeff Jones AOGCC Pull test plug -set wear bushing MU packer retrieving tool -RIH & retrieve storm packer - LD tools Flow check well (static) POOH w/ DP f/ 2998' to 2502' -flow check - slight flow -POOH f/ 2502' to 2046' -flow check -slight flow -POOH f/ 2046' to 1571' Cont' POH on trip tank f! 1571' to 1004'. Monitor well. Slight flow. LD plug catcher and xo's. RU to LD 3 112" tbg. POH LD 32 jts 3 1/2" and mule shoe. Monitor welt. Slight flow. PU and MU BHA to 1006'. Slip and cut drilling line. Service top drive. Displaced to 9.6 ppg at 476 gpm at 900 psi. Monitor welt. Well is breathing. RIH to 3290'. Displace to 9.6 ppg mud at 400 gpm at 680 psi. Monitor well. WeII is breathing. RIH to 5194'. Displace well to 9.6 ppg mud at 400 gpm at 970 psi. Well is breathing. Check shot surveys for Cazandra calibration f! 5099' to 5194' RIH to 7097'. Displace well to 9.6 ppg mud at 400 gpm at 970 psi. Welt is breathing. Check shot surveys for Cazandra calibration f/ 7002' to 7097' RIH to 9000' Displace well to 9.6 ppg mud @ 400 gpm @ 980 psi w/ 40 rpm -torque 11,500 ft/Ibs. -flow check -well breathing -slight flow Check shot surveys for Cazandra calibration f/ 8940' to 9000' RIH to 10,903' Displace well to 9.6 ppg mud @ 400 gpm @ 1040 psi w/ 40 rpm - torque 13,000 ft/Ibs. -flow check well breathing -slight flow Check shot surveys for Cazandra calibration f! 10,808' to 10,903' Wash & ream f! 10,903' to 11,759' 400 gpm @ 1140 to 1200 psi w/ 40 rpm Begin trenching f/ 11,729' to 11,759' -prep to time drill off cmt plug Continue trenching f/ 11,729'to 11,759'. Time drill f/ 11,759' to 11,805' to sidetrack well. ~ Drill 8 1/2" hole w/ motor f/ 11,805' to 12,141' MD 6628' TVD Past 12 hrs ADT - 6.86 hrs ART - 2.04 hrs AST - 4.82 hrs WOB 12l15k RPM 80 GPM 588 @ 2370 psi String wt. PU 285 SO 150 Rot 200 Torque on/off btm - 21,000 / 20,000 ft. lbs. ECD - 10.2 to 10.5 ppg Drill 8 1!2" hole w/ motor f/ 12,141' to 12,813' MD 6937' TVD WOB 10/14 k RPM 80 GPM 590 @ 2750 psi String wt. PU 250 SO 165 Rot 200 Torque on/off btm. - 16,500/15,500 ft/Ibs. ECD - 10.5 to 10.7 ppg Printed: 7/14!2005 2:50:13 PM • ConocoPhillips Alaska Page 8 of 13 Operations Summary ...Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6!8!2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7!10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From- To Hours ~ Code ' 'Sub i phase __ _ _ _ ;Code 6/26/2005 21:30 - 22:30 1.00 RIGMNT RGRP INTRMI 22:30 - 23:00 0.50 DRILL DRLG I INTRM1 23:00 - 23:30 I 0.50 RIGMNT RGRP INTRMI 23:30 - 00:00 ~ 0.50 DRILL DRLG INTRMI 6!27/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I INTRMI 12:00 - 23:15 I 11.251 DRILL I DRLG I INTRM1 23:15 - 00:00 6/28/2005 i 00:00 - 01:00 0.751 DRILL I CIRC I INTRMI 1.001 DRILL I CIRC I INTRM1 Description of Operations Change out swivel packing Drill 8 1/2" hole w/ motor f/ 12,813' to 12,857' Same parameters as above Tighten swivel packing Drill 8 1/2" hole w/ motor f/ 12,857' to 12,901' MD 6891' TVD Past 12 hrs. ADT - 7.36 hrs. =ART - 4.98 hrs. AST - 2.38 hrs WOB 12!18 k RPM 80 GPM 590 @ 2700 psi String wt. PU 250 SO 165 Rot 200 Torque on/off btm. - 16,500/15,500 ftl.Ibs ECD - 10.5 to 10.7 Note: Flow checking on connections -observed slight flow - no gas or chloride increase observed on btms ups Drill 8 1/2" hole w/ motor f/ 12,901' to 13,664' MD 7266' TVD ADT - 6.88 hrs. =ART - 4.18 hrs. AST - 2.7 hrs. WOB 14118 k RPM 80 GPM 622 @ 3040 psi String wt. PU 270 SO 160 Rot 205 Torque on/off btm. - 18,000/16,500 ft/Ibs. ECD - 10.6 to 10.8 ppg Drill 8 1/2" hole w/ motor f/ 13,664' to 14,341' MD 7379' TVD ADT - 5.64 hrs. =ART - 2.77 hrs. AST - 2.87 hrs. WOB 14118 k RPM 80 GPM 622 @ 3000 psi String wt. PU 275 SO 150 Rot 205 Torque on/off btm. - 21,0001 19,500 ftllbs. ECD - 10.6 to 10.7 ppg Begin circulating hole clean for wiper trip 600 gpm @ 2650 psi w/ 80 rpm Circulate btms up - 600 gpm @ 2620 psi w/ 60 rpm -standing back 3 stds to 14,045' -flow check (slight trickle) 01:00 - 03:30 I ~ 2.50 DRILL WIPR INTRMI I Wiper trip f/ 14,045' to 12,236' - 400 gpm @ 1370 psi w/ 60 rpm ~ ' ' ' 03:30 - 04:30 1.00 DRILL TRIP INTRMI -Wash down to 14,341 Flow check (well static) RIH f/12,236 to 14,236 04:30 - 06:30 ~ 2.00 DRILL CIRC INTRMI Pump hi vis sweep & circulate 600 gpm f 2660 psi 160 rpm i ~ Stood back three stands to 14,045' while circulating ( Flow check well, static. 06:30 - 08:30 08:30 - 09:30 ~ 2.00 DRILL 1.001 DRILL ~ WIPR ~ WIPR ~ INTRMI INTRM1 Wiper trip f/ 14,045' to 12,236' - 400 gpm @ 1350 psi w/ 60 rpm j Flow check (well static) RIH (/12,236' to 14,236' -Wash down to 14,341' 09:30-11:00 ~ 1.50!DRILL (CIRC INTRM1 11:00 - 13:15 ~ 2.25 i DRILL ~ TRIP INTRMI 13:15 - 14:30 I 1.251 DRILL i TRIP ~ INTRM1 14:30 - 14:45 j 0.251 DRILL 'TRIP INTRM1 14:45 - 20:30 I 5.75 i DRILL TRIP INTRM1 20:30 - 22:00 1.50 DRILL I OTHR INTRM1 22:00 - 23:15 , 1.25 DRILL ~~ TRIP INTRM1 23:15 - 23:30 ~ 0.25 DRILL ~ OTHR I INTRM1 23:30 - 00:00 I 0.50 DRILL I TRIP ~ INTRM1 Circulate and condition mud 600 gpm / 2700 psi / 60 rpm Increase mud wt. to 9.8 ppg Pump out from 14,331' to 12,236' spotting tube pill 3.0 bpm 360 psi Flow check well, static. POOH on trip tank from 12,236' to 10,808', hole taking proper fill Flow check well, static. Pump dry job /blow down top drive POOH on trip tank f/ 10,808' to 3580' -worked through minor tight spots @ 6705' 8~ 6606' -stuck pipe @ 3580' Work stuck pipe- torque and slump -hitting down jars - fared pipe free Wash down to 3706' - 400 gpm @ 1010 psi - 60 rpm -Back ream f/ 3706' to 3195' -worked through spot @ 3580' & 3528' -free going up & down Monitor well @ 3195' -well static Continue to POOH on TT f! 3195' to 2719' - proper fill Printed: 7/14/2005 2:50:13 PM • ConocoPhillips'Alaska Operations Summary Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT -DRILLING Start: 6/7/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10!2005 Rig Name: Doyon 19 Rig Number: 19 Date From - To 'Hours '! Code '' Code ' Phase 6!29/2005 00:00 - 01:30 ~ 1.50 DRILL TRIP INTRM1 01:30 - 04:00 2.50 DRILL PULD INTRMI 04:00 - 06:00 2.00 CASE OTHR INTRM1 06:00 - 08:00 2.00 CASE RURD INTRM1 08:00 - 08:15 0.25 CASE SFTY ~ INTRMI 08:15 - 12:00 3.75 CASE RUNC INTRM1 12:00 - 12:30 0.50 CASE CIRC ~ INTRM1 12:30 - 15:45 3.25 CASE RUNC INTRMI 15:45 - 17:00 i 1.25 CASE CIRC INTRMI 17:00 - 19:45 2.75 CASE RUNC INTRMI 19:45 - 21:00 1.25 ~ CASE CIRC INTRM1 21:00 - 00:00 3.00 ~ CASE RUNC INTRM1 6/30/2005 00:00 - 01:00 ~ 1.00 ~ CASE CIRC INTRM1 01:00 - 02:00 ~ 1.00 CASE RUNC ~ INTRM1 02:00 - 10:45 i 8.75 CASE CIRC INTRM1 ~ ~ ~ 10:45 - 13:00 2.25 ~ CASE RUNC INTRM1 13:00 - 13:30 ~ 0.50 ~ CEMEN RURD ~ INTRM1 13:30 - 17:00 ~ 3.50 CEMEN ~ CIRC INTRM1 II 17:00 - 17:45 I, 0.75 ~ CEMENl~PUMP INTRM1 17:45 - 20:00 I 2.25! CEMENTDISP .INTRM1 Page 9 of 13 Spud Date: 6/8/2005 End: 7/10/2005 Group: Description of'Operatons POOH f/ 2719' to 199' -stood back hwdp Set back nmfc's -down load LWD -lay down bha -clean up rig floor. Pull wear bushing -set test plug -change top pipe rams f/ 3 1/2"x6" VBR to 7" pipe ram -test to 250 psi 8 5000 psi -pull test plug -set thin wall wear bushing -changed drive sub on Top Drive to 4" XT. RU to run casing Held safety and Opts meeting with crew Run 7" 26# L-80 BTCM as follows: FS - 2 jts. - FC - 74 jts. to 3236' - (Baker Loc 1st four connections -pump through string on jt. #4 to check floats) install straight blade centralizers on first 14 jts. Staged pumps up to 6.0 bpm / 410 psi -reciprocated pipe -circulated one pipe volume (124 bbls) Pumps off -PUW 138K SOW 119K Run casing from 3236' to 6803' - 160 jts total Stage pumps up 3.5 bpm @ 420 psi initial / 4.6 bpm @ 380 psi final Total of 296 blls pumped -reciprocated pipe throughout. Pumps off -PUW 205K SOW 135K Run 7" casing from 6803' to 9784' - 230 jts. total Stage pumps up to 3.8 bpm @ 450 psi initial / 4.5 bpm @ 490 psi final Pumped 350 bbls total -reciprocated pipe throught Pumps off - PU 260 K SO 140 Run 7" casing f/ 9784' to 12,208' - 287 jts total Stage pumps up to 4.0 bpm @ 660 psi initial / 4.0 bpm @ 540 psi final -reciprocated pipe throught Run 7" casing f/ 12,208' to 13,185' - 310 jts. total Run casing :Lost SOW @ 13,190', attempted to circ, hole packing off - regained circ -worked pipe from 13,185' to 13,210' -hole packing off.Laid down one joint -regain circ and wash from 13,185' to 13,140'. Continue to work pipe pumping 4 bpm ! 570 psi fighting tight hole and packing off to 13,227'. Worked pipe down from 13,227' to 13,245' with out pump hole conditions improved. Continue to run casing from 13,245' to 14,298' SOW from 140K to 75K (block wt.) MU FMC fluted hanger and landed in wellhead with FS @ 14,330.78' and FC @ 14,242.06' Lay down fill-up, blow down Top Drive - MU Dowell 2 plug cement head Stage pumps up slowly initial rate 1 bbls /min @ 430 psi - fina13.5 bbl / min @ 730 psi - No pipe movement - PJSM on cmt job Cement 7" 26# L-80 csg as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 15 bbs CW-100 @ 4.1 bblslmin @ 690 psi - Pumped 30 bbls 11.5 ppg Mudpush II @ 4.1 bbls/min @ 680 psi - Dropped btm plug -Pumped 64.9 bbls 15.8 ppg tail slurry Class G w/ 0.2% D046, 0.3% D065, 0.4% D167, 0.1% 6155 @ 4 bbls/min @ 400 psi -Dropped top plug w/ 20 bbls water -switched to rig pumps Displaced cmt w/ 9.6 ppg LSND mud as follows: 150 bbls @ 4.4 bbls/min @ 480 psi - 30 bbl @ 4.6 bbls/min @ 300 psi (* observed 200 psi drop in pressure @ 179 bbls - no losses & pumps OK) 30 bbls @ 4.8 bbls/min @ 310 psi - 270 bbls @ 5 bbls/min @ 330 psi to 750 psi (* Observed pressure increasing as Mudpush & cmt turned the corner) slowed pumps to 3.3 bbls/min w/ 480 bbls of displacment pumped w/ pressure f/ 440 psi to 580 psi - @ 500 bbls of displacement gone pressure began rising f! 580 to 1790 psi -slowed pump to 1.6 bblslmin (hole packing off -lost reutrns with 510 bbls of displacment gone) Printed: 7/14/2005 2:50:13 PM ConocoPhiflips Alaska Operations Summary,'Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT -DRILLING Start: 6/7/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Rig Name: Doyon 19 Rig Number: 19 Page 1 D of 13 Spud Date: 6/8/2005 End: 7/10/2005 Group: 'Date 'From - To Hours Code Sub ' Phase ~, Description of Operations Code 6!3012005 17:45 - 20:00 2.25 CEMEN If DISP INTRM1 finished displacing @ 1.6 bbls/min final pressure before bumping plug 1060 psi -bumped plug w/ 523 bbl @ 1550 psi - CIP @ 1940 hrs. - ~ Checked floats OK -Lost 10 bbls mud during displacement - no flow f/ ~ ~ annulus after shutting down pump 20:00 - 20:30 0.50 DRILL DEOT INTRMI Tested 7" casing to 3500 psi for 30 mins. 20:30 - 21:15 0.75 CEMENT PULD INTRM1 RD cmt lines & cmt head - csg elevators & landing jt. 21:15 - 00:00 2.75 ~ DRILL OTHR INTRM1 ~ Pull wear bushing -set & test pack to 5000 psi for 10 mins. -Pull I I ~ pack-off running tool -set upper test plug -Change top pipe rams f/7" to 3 1/2" X 6' VBR -test rams & body to 5000 psi. 7/1/2005 00:00 - 00:30 0.50 CASE OTHR INTRM1 ~ Pull test plug and set wear bushing in wellhead 1 100:30 - 05:00 4.50 DRILL ~ PULD INTRMI Lay down 5" drill pipe from derrick ~ 05:00 - 05:30 05 30 18 00 0.50 RIGMNT ~ RSRV INTRM1 12 50 DRILL ~ PULD INTRM1 Service rig Fi i ill i f i k 435 t t t h l i d 5" d d : - : ~ . p pe rom err c ( s. n s ay ng own r j o ap j 18:00 - 23:15 5.25 WELC BOPE INTRM1 Pull wear bushing -Set test plug - RU & test BOPE - Hydril to 250 ~ i T 3500 psi -Pipe rams,blind rams, choke & kill line valves, choke manifold valves, TD IBOP'S, Dart & TIW valves to 250 & 5000 psi - i ~ Performed accumulator closure test -Witnessing of test was by Chuck ~ ~ ~ Scheve AOGCC ~ RD -Pull test plug -set wear bushing 123:15 - 00:00 0.75 DRILL PULD ~ INTRM1 Begin PU & MU 6 1/8" BHA -Motor, float sub, stab, 7/2/2005 i 00:00 - 03:15 3.25 DRILL ~ PULD I INTRM1 j Continue to MU BHA - PU DM, Res, PWD and TM HOC collars MU bit ~& scribe tools and upload LWD. PU 3 NM flex DC's, 5 jts HWDP and I jars -shallow test tools 03:15 - 04:15 ~ 1.00 RIGMNT RSRV ~ INTRM1 Slip and cut drilling line -service Drawworks ~ 04:15 - 10:00 ~ 5.75 DRILL ' TRIP INTRM1 RIH picking up 4" drill pipe to 6893' " " 10:00 - 11:30 1.50 WELCT SFTY i INTRMI I Held PJSM and performed stripping drill with B crew 11:30 - 13:00 1.50 WELCT SFTY ~ INTRMI Held PJSM and performed stripping drill with "A" crew -Blow down j lines. ~ 13:00 - 19:00 6.00 DRILL TRIP ~ INTRMI Continue to RIH picking up 4" drill pipe to 13,255' (405 jts. total) 19:00 - 20:00 1.00 DRILL TRIP INTRMI Continue to RIH w/ pipe f/ derrick f/ 13,255' to 14,018' 20:00 - 20:30 I 0.50 DRILL REAM INTRM1 ~ Wash down f/ 14,018' to 14,202' -tagged top of cmt. ~ 20:30 - 00:00 3.50 CEMENl ~ DSHO I INTRM1 Clean out shoe track - cmt, wiper plugs, FC @ 14,242' - cmt to FS @ 14, 329' ~ ~ W06 4/6 k RPM 40 GPM 210 @ 2100 psi String wt. PU 270 SO 115 Rot 175 I i Torque 17,000 ft/Ibs. 7!3/2005 00:00 - 00:45 0.75 i CEMEN DSHO i INTRM1 Drill out FS @ 14,330' to 14,331' -clean out rat hole to 14,341' -drill 20' I I new hole to 14,361' 00:45 - 01:30 01:30 - 02:15 i , 0.75 CEMENlf OTHR I INTRM1 0.75 CEMEN'Tf FIT ~ INTRM1 I CBU - 210 gpm ! 2120 psi ! 40 rpm RU and pertorm PIT to 12.5 ppg EMW -Blow down lines 02:15 - 04:00 1 1.75 DRILL i CIRC PROD Flow check well, static. Pumped 40 bbls of SafeClean spacer and 1 ~ ~ ~ ! changed well over to 9.6 ppg Flo-Pro mud ~ 104:00 - 04:30 0.50 DRILL OTHR i PROD 218 gpm / 2070 psi 155 rpm i Flow check well, static -clean surface equipment -obtain SPR's 04:30 - 12:00 ~ 7.501 DRILL DRLH i PROD Drill 6 1/8" horz. hole w/ motor f/ 14,361' to 14,470' MD - 7386' TVD ~ I ~ ADT - 4.83 hrs. =ART - 3.51 hrs. AST - 1.32 hrs. ~ I WOB - 10/18 k RPM 80 GPM 220 @ 2520 psi String wt. PU 245 SO 130 ROT 175 ~ I Torque on/off btm. - 16,000/15,000 ft. lbs. j 12:00 - 00:00 12 00 DRILL DRLH I PROD ECD - 10.81 to 10.9 ppg Drill 6 1/8" hor hole w/ motor f! 14 440' to 14 882' MD 7392' TVD i . , , z. AST - 1 96 hrs. I ADT - 4 09 hrs =ART - 2.13 hrs . . . . WOB - 20!25 k RPM 80 GPM 220 @ 2650 psi Printed. 7/14/2005 2:50:13 PM ConocoPhillips Alaska Page ~ ~ of ~3 Operations Summary Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From'-To Hours 'Code Sub ~ Code Phase ! Description of Operations 7/3/2005 12:00 - 00:00 12.00 ~ DRILL DRLH PROD String wt. PU 220 SO 135 Rot 170 Torque onfoff btm. - 12,500!12,000 ft/Ibs. ECD - 10.9 to 11.1 ppg 7/4/2005 ~ 00:00 - 12:00 12.00 DRILL ~ DRLH PROD ~ Drill 6 1 /8" horz. hole w! motor f/ 14,882' to 15,451' MD 7405' TVD ~ ADT - 8.52 hrs. =ART - 6.83 hrs. AST - 1.69 hrs. ~ WOB - 10/20 k RPM 80 GPM 220 @ 2650 psi String wt. PU 215 SO 140 Rot 175 i ~ ~ Torque on/off btm. - 12,500/11,000 ft/Ibs. ECD - 11.0 to 11.3 ppg 12:00 - 00:00 i 12.00 ~ DRILL DRLH PROD ~ Drill 6 1/8" horz. hole w/ motor f/ 15,451' to 16,213' MD 7417' TVD ADT - 8.15 hrs. =ART - 6.89 hrs. AST - 1.26 hrs. ~ WOB - 6/12 k RPM - 80 GPM 222 @ 2750 psi String wt. PU 220 SO 130 Rot 175 Torque on/off btm. - 13,500/12,500 ft/Ibs. i ~ ~ , ECD - 11.0 to 11.1 ppg 7/5/2005 i 00:00 - 12:00 12:00 - 00:00 7/6/2005 100:00 - 12:00 12:00 - 18:00 18:00 - 21:00 21:00 - 00:00 7!7!2005 00:00 - 04:15 04:15 - 06:30 06:30 - 09:00 09:00 - 12:00 ~ ~ Observed very slight flow on connections f/ 15,164' 12.00 ~ DRILL DRLH PROD Drill 6 1/8" horz. hole w/ motor f/ 16,213' to 16,977 MD 7441' TVD ~ .ADT - 7.2 hrs. =ART - 5.23 hrs. AST - 1.97 hrs. WOB - 6/15 k RPM - 80 GPM 220 @ 2950 psi String wt. PU 230 SO 128 Rot 173 ~ Torque on/off btm. - 14,500/12,500 fUlbs. ~ ECD - 11.2 to 11.3 ppg 12.00 DRILL DRLH ~ PROD ~ Drill 6 1/8" horz, hole w/ motor f/ 16,997 to 17,650' MD 7436' TVD ADT - 7.31 hrs. =ART - 6.57 hrs. AST - .74 hrs. ~ WOB - 10115 k RPM - 80 GPM 220 @ 3050 psi String wt. PU 235 SO 130 Rot 175 I Torque on/off btm. - 14,000112,500 ftflbs. EGD - 11.1 to 11.3 ppg 12.00 DRILL DRLH PROD Drill 6 1!8" horz. hole w! motor f! 17,650' to 18,504' MD 7392' TVD ADT - 7.571 hrs. =ART - 6.46 hrs. AST - 1.11 hrs. WOB - 10!15 k RPM - 80 GPM 220 @ 3150 psi String wt. PU 235 SO 125 Rot 175 i ~ i Torque on/off btm. - 14,500/14,000 ft/Ibs. ~ ECD - 11.2 to 11.35 ppg ~ ~ ~ Slight flow observed at connections from 18, 123' ' " ' ' 6.00 DRILL DRLH PROD ~ Drill 6 1/8 horz. hole w/ motor f/ 18,504 to 18,695 MD 7375 TVD ADT - 5.98 hrs. =ART - 5.98 hrs. AST - 0.00 hrs. WOB - 20 k RPM - 80 GPM 220 @ 3160 psi ~ i ~ String wt. PU 235 SO 117 Rot 170 ~ Torque on/off btm. - 14,500/14,000 ft/Ibs. ~ ECD - 11.2 to 11.35 ppg ~ i Slight flow observed at connections. 3.00 ~ DRILL CIRC PROD Circulated and raised MW to 10.3 PPG. 3.00 DRILL TRIP PROD 4 25 DRILL TRIP PROD POOH to 17,363' Backreaming W 220 GPM and 75 RPM. B f 1 3 40 2 0 / 27 0 i / 7 ' ' . I i ~ ackream rom 7, to 14, 2 gpm ps 0 rpm 63 0 - 6 Monitor well, slight flow 2.25 WELCTI~ COND i PROD ~ Circ and cond mud -increase mud wt. from 10.3 ppg to 10.6 ppg 2.50 WELCTL COND PROD 1215 gpm / 2550 psi 170 rpm ECD - 12.2 ppg ~ Monitor well, observed slight flow -Circ and increase mud wt. from 10.6 1 ppg to 10.9 ppg 189 gpm / 2270 psi / 65 rpm i ~ ECD - 12.3 ppg 3.00 ~ WELCTL, COND ,PROD ~ Monitor well, observed slight flow -Circ and increase mud wt. from 10.9 Printed: 7/14/2005 2:50:13 PM • " ConocoPhillips Alaska Page 12 of ~ 3 Operations Summary Report' Legal Well Name: CD2-60 Common Well Name: CD2-60 Spud Date: 6/8/2005 Event Name: ROT -DRILLING Start: 6/7/2005 End: 7/10/2005 Contractor Name: doyon1@ppco.com Rig Release: 7/10/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To 7/7/2005 i 09:00 - 12:00 12:00 - 15:15 15:15 - 19:00 119:00 - 20:30 20:30 - 00:00 7/8/2005 00:00 - 02:30 02:30 - 03:30 03:30 - 06:15 06:15 - 07:15 7/9/2005 Hours Code ~ Code 3.00 WELCTL~ COND 325 WELCT COND I 3.75 WELCTyCOND 1.50 WELCTL OBSV 3.50 ~ WELCTL TRIP 2.501 DRILL TRIP 1.00 WELCT OTHR 2.751 DRILL CIRC 1.00 ~ DRILL TRIP 07:15 - 08:15 1.00 DRILL TRIP 08:15 - 12:15 i 4.00 DRILL TRIP 12:15 - 12:45 0.501 DRILL (TRIP 12:45 - 16:45 I 4.OOi DRILL (TRIP 16:45 - 20:15 3.50 DRILL TRIP 20:15 - 21:45 1.50 DRILL 21:45 - 22:15 ~ 0.50 ~ DRILL j TRIP PULD 22:15 - 22:45 ~ 0.501 CMPLTN RURD 22:45 - 00:00 1.25 ~ CMPLTN RUNT 00:00 - 10:15 10.25' CMPLTNi RUNT Phase Description of Operations PROD ppg to 11.5 ppg 168 gpm / 1990 psi / 30 rpm ECD - 12.82 ppg PROD Monitor well -very slight flow -Circ and increase mud wt. to 11.8 ppg 168 gpm 1970 psi / 30 rpm ECD - 13.1 ppg PROD Monitor well -very slight flow -Circ and increase mud wt. to 12.0 ppg 126 gpm 1 1970 psi 130 rpm ECD - ??? ppg PROD I Circulated 12 PPG mud. 100 Bbls from surtace lost 22 Bbls. Monitored well flowed back 4.5 Bbls and fluid dropped 3" below flowline and was static. PROD POOH with pump @ 2 BPM to 11,829'. Observed well every 5 stands. PROD POOH with pump at 2.0 bpm i 1160 psi -hole taking correct fill. PROD Observed slight flow from pipe and flowline. Performed exhale test. Well had barite sag in the annulus. Weight out was 11.3 to 11.7 PPG coming out. PROD CBU @ 2.0 bpm / 1120 psi -even out mud wt. to 12.0 ppg in and out. 'Flow check well, observed slight flow, decreased untill static in 40 min. PROD POOH with pump at 2.0 bpm ! 1080 psi -hole taking correct fill. Mud wt. out 11.5 - 12.4 ppg PROD ~ POOH -slowed pulling speed to 250 fph from 9152' to 8866' increased mud viscosity from 46 to 52 increased rate to 3.0 bpm / 1490 psi untill higher vis mud @ bit ECD - 13.6 ppg PROD POOH with pump from 8866' to 6004' - 2.0 bpm i 940 psi -hole taking correct fill. PROD Flow check well, static in 10 min, monitor well additional 10 min, static. (Attempted to POOH without pump, swabbing. PROD ~ POOH with pump from 6004' to 3140' - 2.0 bpm / psi -hole taking correct fill. PROD Monitor well static for 15 min. POOH on trip tank to 376'. PROD POOH and laid down BHA. PROD Pulled wear bushing. PROD Rigged up to run tubing. PJSM. PROD Made up Completion and RIH to 473' on 4 1/2" tubing. CMPLTN Continue running 4 1!2" completion -Ran 291 jts. 4 1/2" 12.6# L-80 IBTM tbg (301 jts. total) MU FMC tbg hanger & landing jt B. -Land tbg in wellhead w/ tail @ 13,104.38' - XN nipple @ 13,092.04' -Packer @ 13,032.73' - GLM @ 8,640.53' & DB nipple @ 2,317.27' 10:15 - 11:15 ~ 1.001 CMPLTN( SEOT CMPLTN 11:15 - 14:30 i 3.251 CMPLTN( NUND I CMPLTN 14:30 - 15:30 I 1.00 CMPLTN RURD I CMPLTN 15:30 - 21:15 I 5.75 I CMPLTN( FRZP ~ CMPLTN 21:15 - 00:00 I 2.75 I CMPLTN( PCKR f CMPLTN 7/10/2005 100:00 - 02:00 j 2.00 ; CMPLTN OTHR ~ CMPLTN RILDS - LD LJa install TWC - MU LJb - test hanger seals to 5000 psi - LD landing jt. B N/D BOPE, Change out junk sub on top drive. N/U tree and test tubing hanger adapter to 5000 psi for 10 min. Test tree and FMC lubricator to 5000 psi 10 min.-OK. Pull TWC - RD lubricator - RU circ manifold and hard lines Pumped 150 Bbls brine into tubing taking returns from annulus. Returns were 1.5 to 2 Bbls for every 10 Bbls pumped. Tubing pressure was too high. Bullheaded 125 Bbls water down the annulus. Resumed pumping treated brine followed by 241 Bbls diesel with good returns. "' Lost 265 bbls of 10.3 - 12.0 ppg FloPro mud to open hole" Dropped ball/bar. Setpacker with 4800 psi. held pressure 30 min to test tubing. Pressured up Annulus to 3700 psi MIT for 30 min. Bled annulus to 0 and left well pressure of 1500 psi on tubing. Flush and blow down circ manifold and lines - RD hard lines and Printed: 7/14/2005 2:50:13 PM Printed: 7/14/2005 2:50:13 PM ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Jim Repg(c~admin.state.ak.us: Bob Fleckenstein(cDadmin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc FIELD /UNIT /PAD: Alpine CD-2 DATE: 7/9/2005 OPERATOR REP: Larry Hill AOGCC REP: Packer De th Pretest initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-60 In'. T e N TVD 7,035' Tubin 1,600 1,750 1,750 1,750 Interval I P.T.D. 205-068 Test T e P Test si 3500 IA 3,710 3,700 3,700 P/F P Notes: OA 700 700 700 700 MIT Report Form Revised: 03/18!04 CD2-60 MIT Form .xls ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska CD2-60 Job No. AK ZZ-0003753059, Surveyed: 6 July, 2005 Survey Report 2 August, 2005 Your Ref.• API 501032051100 Surface Coordinates: 5974194.47 N, ~ 371743.77 E ~(70° 20' 15.8352" N, 151 ° 02' 26.4713" VUJ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 52.37ft above Mean Sea Level ~- ~- ~ ~'~ ~ ~ ~ ~ ~ Survey Ref.• svy496 A tlattibuttcn CsmtiW~Y ConocoPhillips Alaska, Inc. Survey Report for CD2-60 Your Ref: API 501032051100 Job No. AK ZZ-0003 753059, Surveyed: 6 July, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11756.04 59.730 193.550 6396.00 6448.37 9091.47 S 2114.82 W 5965140.51 N 369473.76 E 11760.00 59.720 193.530 6397.99 6450.36 9094.79 S 2115.62 W 5965137.19 N 369472.90 E 11784.81 59.430 195.340 6410.56 6462.93 9115.51 S 2120.96 W 5965116.57 N 369467.22 E 11816.65 59.890 196.850 6426.64 6479.01 9141.91 S 2128.57 W 5965090.31 N 369459.15 E 11860.14 60.320 197.580 6448.32 6500.69 9177.92 S 2139.73 W 5965054.49 N 369447.37 E 11912.35 60.600 197.430 6474.06 6526.43 9221.24 S 2153.40 W 5965011.41 N 369432.97 E 11957.12 61.080 197.280 6495.87 6548.24 9258.56 S 2165.06 W 5964974.30 N 369420.67 E 12006.74 62.720 198.810 6519.24 6571.61 9300.17 S 2178.62 W 5964932.92 N 369406.40 E 12101.96 62.440 198.970 6563.09 6615.46 9380.14 S 2205.98 W 5964853.43 N 369377.67 E 12197.22 63.210 199.730 6606.60 6658.97 9460.10 S 2234.06 W 5964773.97 N 369348.23 E 12292.14 62.750 199.260 6649.72 6702.09 9539.81 S 2262.28 W 5964694.75 N 369318.65 E 12386.75 61.790 200.030 6693.74 6746.11 9618.68 S 2290.44 W 5964616.37 N 369289.15 E 12481.91 62.750 197.550 6738.03 6790.40 9698.41 S 2317.56 W 5964537.12 N 369260.68 E 12577.23 62.290 195.870 6782.01 6834.38 9779.40 S 2341.87 W 5964456.55 N 369234.98 E 12672.55 63.420 193.140 6825.51 6877.88 9861.51 S 2363.10 W 5964374.82 N 369212.34 E 12767.62 63.100 188.160 6868.31 6920.68 9944.91 S 2378.79 W 5964291.70 N 369195.23 E 12862.29 64.340 183.720 6910.24 6962.61 10029.31 S 2387.56 W 5964207.46 N 369185.03 E 12957.63 64.530 180.830 6951.39 7003.76 10115.24 S 2390.97 W 5964121.61 N 369180.14 E 13053.01 66.130 182.250 6991.20 7043.57 10201.87 S 2393.30 W 5964035.02 N 369176.33 E 13148.30 67.050 182.530 7029.06 7081.43 10289.24 S 2396.95 W 5963947.73 N 369171.19 E 13243.79 66.540 181.860 7066.68 7119.05 10376.94 S 2400.31 W 5963860.10 N 369166.32 E 13288.80 66.740 181.400 7084.53 7136.90 10418.25 S 2401.49 W 5963818.82 N 369164.44 E 13339.33 66.930 178.890 7104.41 7156.78 10464.70 S 2401.61 W 5963772.38 N 369163.53 E 13385.03 67.460 177.920 7122.13 7174.50 10506.81 S 2400.43 W 5963730.26 N 369163.98 E 13434.52 68.240 175.830 7140.79 7193.16 10552.57 S 2397.93 W 5963684.45 N 369165.70 E 13479.56 69.550 173.710 7157.01 7209.38 10594.41 S 2394.10 W 5963642.56 N 369168.82 E 13529.67 71.050 171.980 7173.90 7226.27 10641.22 S 2388.22 W 5963595.66 N 369173.90 E 13575.15 72.190 171.090 7188.24 7240.61 10683.91 S 2381.86 W 5963552.86 N 369179.52 E 13624.99 73.520 168.480 7202.93 7255.30 10730.77 S 2373.42 W 5963505.86 N 369187.17 E 13670.44 74.730 167.380 7215.37 7267.74 10773.52 S 2364.27 W 5963462.96 N 369195.58 E 13720.18 75.320 166.340 7228.22 7280.59 10820.31 S 2353.35 W 5963415.99 N 369205.70 E 13765.66 76.160 165.170 7239.42 7291.79 10863.03 S 2342.50 W 5963373.09 N 369215.81 E 13815.23 77.420 163.860 7250.75 7303.12 10909.54 S 2329.62 W 5963326.37 N 369227.90 E 13859.97 77.970 162.300 7260.28 7312.65 10951.35 S 2316.90 W 5963284.34 N 369239.90 E 13910.74 78.830 160.660 7270.49 7322.86 10998.51 S 2301.10 W 5963236.93 N 369254.89 E Dogleg Vertical Rate Section (°/100ft) North Slope, Alaska Comment 9091.47 Tie-On Point 0.504 9094.79 Window Point 6.398 9115.51 4.340 9141.91 1.759 9177.92 0.592 9221.24 1.111 9258.56 4.280 9300.17 0.330 9380.14 1.076 9460.10 0.655 9539.81 1.244 9618.68 2.518 9698.41 1.636 9779.40 2.811 9861.51 4.690 9944.91 4.404 10029.31 2.742 10115.24 2.155 10201.87 1.002 10289.24 0.837 10376.94 1.038 10418.25 4.582 10464.70 2.274 10506.81 4.217 10552.57 5.267 10594.41 4.419 10641.22 3.120 10683.91 5.671 10730.77 3.536 10773.52 2.342 10820.31 3.103 10863.03 3.617 10909.54 3.622 10951.35 3.589 10998.51 • • 2 August, 2005 - 15:20 Page 2 of 5 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60 Your Ref.• API 501032051100 Job No. AK-ZZ-0003753059, Surveyed: 6 July, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13958.14 79.450 159.340 7279.42 7331.79 11042.25 S 2285.18 W 5963192.92 N 369270.06E 3.032 11042.25 14005.92 80.690 158.420 7287.66 7340.03 11086.15 S 2268.22 W 5963148.73 N 369286.27E 3.214 11086.15 14051.33 82.150 157.030 7294.44 7346.81 11127.70 S 2251.20 W 5963106.90 N 369302.58E 4.416 11127.70 14101.21 82.450 155.210 7301.12 7353.49 11172.90 S 2231.19 W 5963061.37 N 369321.81E 3.666 11172.90 14148.67 82.570 153.800 7307.31 7359.68 11215.37 S 2210.93 W 5963018.56 N 369341.33E 2.956 11215.37 14196.11 83.380 152.190 7313.11 7365.48 11257.32 S 2189.56 W 5962976.25 N 369361.99E 3.776 11257.32 14255.03 83.970 150.350 7319.60 7371.97 11308.67 S 2161.41 W 5962924.42 N 369389.26E 3.261 11308.67 14300.06 85.370 149.170 7323.79 7376.16 11347.40 S 2138.83 W 5962885.31 N 369411.17E 4.059 11347.40 14354.80 86.140 148.420 7327.84 7380.21 11394.09 S 2110.54 W 5962838.14 N 369438.65E 1.961 11394.09 14449.31 87.190 148.680 7333.34 7385.71 11474.58 S 2061.32 W 5962756.83 N 369486.50E 1.144 11474.58 14546.08 88.390 147.270 7337.07 7389.44 11556.56 S 2010.04 W 5962673.98 N 369536.36E 1.912 11556.56 14589.72 90.180 147.960 7337.61 7389.98 11593.41 S 1986.67 W 5962636.74 N 369559.10E 4.396 11593.41 14641.43 90.860 149.140 7337.14 7389.51 11637.52 S 1959.69 W 5962592.17 N 369585.32E 2.634 11637.52 14686.50 90.430 150.040 7336.64 7389.01 11676.38 S 1936.88 W 5962552.92 N 369607.46E 2.213 11676.38 14736.79 89.070 150.710 7336.86 7389.23 11720.10 S 1912.02 W 5962508.79 N 369631.57E 3.015 11720.10 14780.36 87.900 149.820 7338.01 7390.38 11757.92 S 1890.42 W 5962470.61 N 369652.52E 3.374 11757.92 14832.12 87.590 150.290 7340.04 7392.41 11802.73 S 1864.60 W 5962425.36 N 369677.57E 1.087 11802.73 14883.51 87.900 150.840 7342.07 7394.44 11847.45 S 1839.37 W 5962380.21 N 369702.03E 1.228 11847.45 14927.34 88.540 150.900 7343.43 7395.80 11885.72 S 1818.04 W 5962341.58 N 369722.70E 1.467 11885.72 15023.42 88.600 151.270 7345.83 7398.20 11969.80 S 1771.60 W 5962256.73 N 369767.70E 0.390 11969.80 15118.97 89.460 150.770 7347.44 7399.81 12053.37 S 1725.31 W 5962172.37 N 369812.55E 1.041 12053.37 15214.30 89.870 150.920 7348.00 7400.37 12136.62 S 1678.87 W 5962088.34 N 369857.56E 0.458 12136.62 15309.92 89.030 150.890 7348.92 7401.29 12220.17 S 1632.38 W 5962004.01 N 369902.62E 0.879 12220.17 15405.71 88.820 152.050 7350.72 7403.09 12304.31 S 1586.64 W 5961919.10 N 369946.92E 1.230 12304.31 15501.24 88.300 150.310 7353.12 7405.49 12387.98 S 1540.60 W 5961834.65 N 369991.51E 1.900 12387.98 15596.62 89.560 150.520 7354.90 7407.27 12470.91 S 1493.52 W 5961750.93 N 370037.17E 1.339 12470.91 15691.84 88.880 150.870 7356.19 7408.56 12553.93 S 1446.92 W 5961667.12 N 370082.34E 0.803 12553.93 15787.04 88.330 150.580 7358.51 7410.88 12636.95 S 1400.38 W 5961583.32 N 370127.46E 0.653 12636.95 15882.59 88.540 150.070 7361.12 7413.49 12719.94 S 1353.09 W 5961499.54 N 370173.32E 0.577 12719.94 15978.01 89.810 147.000 7362.50 7414.87 12801.31 S 1303.30 W 5961417.33 N 370221.71E 3.481 12801.31 16073.24 89.440 146.700 7363.12 7415.49 12881.04 S 1251.23 W 5961336.72 N 370272.41E 0.500 12881.04 16168.71 89.270 146.140 7364.19 7416.56 12960.57 S 1198.42 W 5961256.30 N 370323.85E 0.613 12960.57 16264.54 88.970 146.660 7365.66 7418.03 13040.38 S 1145.40 W 5961175.59 N 370375.50E 0.626 13040.38 16359.79 88.300 147.890 7367.93 7420.30 13120.48 S 1093.92 W 5961094.62 N 370425.60E 1.470 13120.48 16455.44 87.430 147.550 7371.50 7423.87 13201.29 S 1042.88 W 5961012.95 N 370475.26E 0.976 13201.29 North Slope, Alaska Comment • 2 August, 2005 - 15:20 Page 3 of 5 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60 Your Ref.• API 501032051100 Job No. AK ZZ-0003753059, Surveyed: 6 July, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 16550.91 86.880 149.110 7376.24 7428.61 13282.44 S 992.81 W 5960930.95 N 370523.92E 1.731 13282.44 16646.16 88.290 149.320 7380.25 7432.62 13364.20 S 944.11 W 5960848.38 N 370571.22E 1.497 13364.20 16741.73 89.070 151.380 7382.45 7434.82 13447.23 S 896.85 W 5960764.55 N 370617.06E 2.304 13447.23 16836.92 89.090 150.070 7383.98 7436.35 13530.25 S 850.30 W 5960680.75 N 370662.17E 1.376 13530.25 16932.28 88.850 150.870 7385.69 7438.06 13613.20 S 803.31 W 5960597.00 N 370707.74E 0.876 13613.20 17026.68 87.870 150.900 7388.40 7440.77 13695.64 S 757.40 W 5960513.79 N 370752.24E 1.039 13695.64 17123.05 87.500 150.590 .7392.29 7444.66 13779.65 S 710.34 W 5960428.98 N 370797.85E 0.501 • 13779.65 17218.65 89.160 151.280 7395.07 7447.44 13863.17 S 663.92 W 5960344.68 N 370842.83E 1.880 13863.17 17313.89 91.200 151.480 7394.78 7447.15 13946.77 S 618.30 W 5960260.31 N 370887.01E 2.152 13946.77 17409.38 90.820 151.840 7393.09 7445.46 14030.80 S 572.98 W 5960175.52 N 370930.89E 0.548 14030.80 17504.07 91.600 151.980 7391.09 7443.46 14114.32 S 528.41 W 5960091.25 N 370974.03E 0.837 14114.32 17600.16 92.090 151.400 7388.00 7440.37 14198.87 S 482.86 W 5960005.93 N 371018.13E 0.790 14198.87 17695.28 91.500 150.810 7385.02 7437.39 14282.11 S 436.92 W 5959921.92 N 371062.64E 0.877 14282.11 17790.88 92.240 149.760 7381.90 7434.27 14365.09 S 389.56 W 5959838.14 N 371108.57E 1.343 14365.09 17886.50 91.620 149.980 7378.68 7431.05 14447.75 S 341.59 W 5959754.68 N 371155.12E 0.688 14447.75 17981.89 91.070 150.610 7376.44 7428.81 14530.58 S 294.33 W 5959671.05 N 371200.95E 0.877 14530.58 18077.64 91.750 150.430 7374.08 7426.45 14613.90 S 247.23 W 5959586.93 N 371246.63E 0.735 14613.90 18172.97 93.300 150.660 7369.88 7422.25 14696.83 S 200.40 W 5959503.22 N 371292.03E 1.644 14696.83 18268.37 95.890 150.710 7362.24 7414.61 14779.74 S 153.84 W 5959419.53 N 371337.16E 2.715 14779.74 18363.68 95.580 150.180 7352.72 7405.09 14862.23 S 107.07 W 5959336.24 N 371382.52E 0.642 14862.23 18459.53 95.330 149.810 7343.61 7395.98 14944.86 S 59.35 W 5959252.81 N 371428.82E 0.464 14944.86 18554.79 94.900 150.540 7335.11 7387.48 15027.17 S 12.16 W 5959169.70 N 371474.59E 0.887 15027.17 18646.54 94.710 149.940 7327.43 7379.80 15106.54 S 33.22E 5959089.57 N 371518.61E 0.684 15106.54 18695.00 94.710 149.940 7323.45 7375.82 - 15148.34 S 57.41 E - 5959047.36 N 371542.08 E - 0.000 15148.34 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. - Vertical depths are relative to Doyon 19 (52.37'). Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. - The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18695.OOft., The Bottom Hole Displacement is 15148.45ft., in the Direction of 179.783° (True). 2 August, 2005 - 15:20 Page 4 of 5 DrlllQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60 Your Ref.• API 501032051100 Job No. AK ZZ-0003753059, Surveyed: 6 July, 2005 Alaska North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11756.04 6448.37 9091.47 S 2114.82 W 11760.00 6450.36 9094.79 S 2115.62 W 18695.00 7375.82 15148.34 S 57.41 E Survey tool program for CD2-60 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 617.00 612.12 To Measured Vertical Depth Depth (ft) (ft) 617.00 612.12 18695.00 7375.82 Comment Tie-On Point Window Point Projected Survey Survey Tool Description CB-SS-Gyro (CD2-60P61) MWD+IIFR+MS+SAG (CD2-60P61) North Slope, Alaska • 2 August, 2005 - 15:20 Page 5 of 5 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Alaska North Slope North Slope, Alaska CD2-60PB 1 Job No. AK ZZ-0003753059, Surveyed: 17 June, 2005 S u r v e y R e p o r t 2 August, 2005 Your Ref.• API 501032051170 Surtace Coordinates: 5974194.47 N, 371743.77E (70° 20' 15.8352" N, 151 ° 02' 26.4713" VI/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 52.37ft above Mean Sea Level ~ - ~- L ~ ~ ~ ~'~ ~ ~ ~ Survey Ref.• svy495 A ttaitiburton Company ConocoPhillips Alaska, Inc. Survey Report for CD2-60PB1 Your Ref.• API 501032051170 Job No. AK-ZZ 0003753059, Surveyed: 17 June, 2005 Alaska North Slope North Slope, Alaska Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -52.37 0.00 0.00 N 0.00E 5974194.47 N 371743.77E 0.00 CB-SS-Gyro 84.00 0.000 0.000 31.63 84.00 0.00 N 0.00E 5974194.47 N 371743.77E 0.000 0.00 168.00 0.800 184.000 115.63 168.00 0.58 S 0.04 W 5974193.89 N 371743.72E 0.952 0.58 258.00 3.300 185.000 205.56 257.93 3.79 S 0.31 W 5974190.68 N 371743.39E 2.778 3.79 347.00 6.000 193.000 294.26 346.63 10.88 S 1.58 W 5974183.62 N 371742.00E 3.113 10.88 438.00 9.000 193.000 384.47 436.84 22.45 S 4.25 W 5974172.10 N 371739.13E 3.297 22.45 528.00 11.500 182.000 473.04 525.41 38.28 S 6.15 W 5974156.30 N 371736.97E 3.516 38.28 617.00 14.500 182.000 559.75 612.12 58.29 S 6.85 W 5974136.31 N 371735.93E 3.371 58.29 MWD+IIFR+MS+SAG 744.18 16.880 188.220 682.19 734.56 92.48 S 10.04 W 5974102.18 N 371732.15E 2.289 92.48 834.02 17.190 196.260 768.10 820.47 118.14 S 15.63 W 5974076.62 N 371726.12E 2.642 118.14 929.07 20.230 195.790 858.12 910.49 147.44 S 24.03 W 5974047.46 N 371717.22E 3.202 147.44 1024.09 23.340 196.520 946.34 998.71 181.30 S 33.86 W 5974013.77 N 371706.82E 3.285 181.30 1119.22 28.420 193.770 1031.90 1084.27 221.39 S 44.61 W 5973973.88 N 371695.38E 5.486 221.39 1213.17 32.650 194.090 1112.81 1165.18 267.70 S 56.11 W 5973927.77 N 371683.09E 4.506 267,70 1309.15 34.100 194.480 1192.96 1245.33 318.87 S 69.14 W 5973876.83 N 371669.19E 1.527 318.87 1404.64 35.800 195.380 1271.22 1323.59 371.72 S 83.24 W 5973824.23 N 371654.18E 1.860 371.72 1500.46 38.340 195.360 1347.67 1400.04 427.41 S 98.55 W 5973768.81 N 371637.92E 2.651 427.41 1595.90 41.370 195.220 1420.93 1473.30 486.40 S 114.67 W 5973710.10 N 371620.79E 3.176 486.40 1690.58 44.570 193.390 1490.20 1542.57 548.93 S 130.59 W 5973647.86 N 371603.81E 3.627 548.93 1785.91 49.020 193.450 1555.45 1607.82 616.50 S 146.71 W 5973580.57 N 371586.54E 4.668 616.50 1881.20 51.930 192.890 1616.09 1668.46 688.06 S 163.45 W 5973509.31 N 371568.58E 3.087 688.06 1976.63 53.120 192.870 1674.15 1726.52 761.89 S 180.33 W 5973435.78 N 371550.44E 1.247 761.89 2071.88 55.820 192.290 1729.49 1781.86 837.54 S 197.20 W 5973360.43 N 371532.27E 2.878 837.54 2166.16 58.310 192.910 1780.75 1833.12 914.75 S 214.47 W 5973283.52 N 371513.69E 2.698 914.75 2261.78 60.530 193.490 1829.39 1881.76 994.89 S 233.27 W 5973203.71 N 371493.52E 2.380 994.89 2357.22 60.010 192.350 1876.72 1929.09 1075.67 S 251.80 W 5973123.27 N 371473.61E 1.172 1075.67 2452.61 59.310 192.590 1924.91 1977.28 1156.05 S 269.58 W 5973043.20 N 371454.46E 0.765 1156.05 2544.07 60.490 193.570 1970.77 2023.14 1233.12 S 287.49 W 5972966.45 N 371435.23E 1.589 1233.12 2642.40 62.130 194.080 2017.98 2070.35 1316.88 S 308.10 W 5972883.06 N 371413.19E 1.729 1316.88 2737.54 62.120 193.930 2062.46 2114.83 1398.48 S 328.46 W 5972801.82 N 371391.44E 0.140 1398.48 2833.27 61.210 193.570 2107.90 2160.27 1480.32 S 348.49 W 5972720.33 N 371370.02E 1.007 1480.32 2928.00 60.040 194.010 2154.36 2206.73 1560.49 S 368.16 W 5972640.50 N 371348.97E 1.300 1560.49 3023.06 60.610 194.070 2201.43 2253.80 1640.62 S 388.20 W 5972560.73 N 371327.57E 0.602 1640.62 3118.24 62.140 193.670 2247.02 2299.39 1721.72 S 408.22 W 5972479.98 N 371306.16E 1.649 1721.72 3213.21 62.170 193.220 2291.38 2343.75 1803.40 S 427.75 W 5972398.65 N 371285.24E 0.420 1803.40 2 August, 2005 - 15:23 Page 2 of 6 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60PB1 Your Ref.• API 501032051170 Job No. AK-ZZ-0003753059, Surveyed: 17 June, 2005 Alaska North Slope Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 3288.84 62.340 193.340 2326.59 2378.96 1868.54 S 443.12 W 5972333.78 N 371268.75E 0.265 1868.54 3383.57 61.690 193.880 2371.04 2423.41 1949.84 S 462.81 W 5972252.83 N 371247.68E 0.851 1949.84 3479.18 61.270 194.320 2416.69 2469.06 2031.32 S 483.27 W 5972171.71 N 371225.83E 0.597 2031.32 3573.95 60.700 194.580 2462.66 2515.03 2111.57 S 503.95 W 5972091.82 N 371203.78E 0.648 2111.57 3669.20 60.400 194.020 2509.49 2561.86 2191.95 S 524.44 W 5972011.81 N 371181.92E 0.601 2191.95 3764.51 59.640 194.540 2557.12 2609.49 2271.95 S 544.80 W 5971932.17 N 371160.19E 0.927 2271.95 3859.72 59.100 195.250 2605.62 2657.99 2351.12 S 565.86 W 5971853.37 N 371137.78E 0.856 2351.12 3954.74 58.460 194.940 2654.88 2707.25 2429.58 S 587.02 W 5971775.29 N 371115.28E 0.729 2429.58 4050.12 57.590 195.670 2705.38 2757.75 2507.62 S 608.37 W 5971697.62 N 371092.60E 1.120 2507.62 4145.48 56.610 196.450 2757.18 2809.55 2584.56 S 630.52 W 5971621.07 N 371069.14E 1.236 2584.56 4239.22 57.480 196.340 2808.17 2860.54 2660.02 S 652.72 W 5971546.01 N 371045.65E 0.933 2660.02 4333.88 58.250 196.820 2858.52 2910.89 2736.84 S 675.59 W 5971469.59 N 371021.46E 0.920 2736.84 4429.53 58.120 197.200 2908.95 2961.32 2814.56 S 699.37 W 5971392.28 N 370996.36E 0.364 2814.56 4524.47 57.690 196.900 2959.39 3011.76 2891.46 S 722.95 W 5971315.80 N 370971.47E 0.526 2891.46 4621.06 58.400 198.150 3010.51 3062.88 2969.60 S 747.63 W 5971238.09 N 370945.45E 1.321 2969.60 4717.95 60.410 196.990 3059.83 3112.20 3049.11 S 772.80 W 5971159.02 N 370918.93E 2.316 3049.11 4811.81 61.040 196.520 3105.73 3158.10 3127.51 S 796.40 W 5971081.04 N 370893.99E 0.801 3127.51 4907.17 61.280 197.330 3151.72 3204.09 3207.42 S 820.72 W 5971001.56 N 370868.31E 0.785 3207.42 5002.34 61.420 196.660 3197.35 3249.72 3287.29 S 845.13 W 5970922.12 N 370842.54E 0.635 3287.29 5096.89 61.960 196.770 3242.19 3294.56 3367.01 S 869.07 W 5970842.81 N 370817.24E 0.580 3367.01 5191.82 62.310 196.540 3286.56 3338.93 3447.42 S 893.13 W 5970762.83 N 370791.81E 0.426 3447.42 5287.02 62.880 196.920 3330.38 3382.75 3528.35 S 917.45 W 5970682.32 N 370766.10E 0.696 3528.35 5382.11 63.220 196.240 3373.48 3425.85 3609.59 S 941.64 W 5970601.51 N 370740.53E 0.731 3609.59 5477.18 63.780 195.780 3415.90 3468.27 3691.37 S 965.11 W 5970520.14 N 370715.67E 0.731 3691.37 5571.91 63.950 195.400 3457.63 3510.00 3773.29 S 987.96 W 5970438.63 N 370691.42E 0.402 3773.29 5667.37 64.300 194.850 3499.29 3551.66 3856.20 S 1010.37 W 5970356.11 N 370667.59E 0.635 3856.20 5762.29 64.060 194.140 3540.63 3593.00 3938.93 S 1031.76 W 5970273.77 N 370644.79E 0.719 3938.93 5857.20 65.200 194.380 3581.29 3633.66 4022.04 S 1052.88 W 5970191.03 N 370622.25E 1.223 4022.04 5952.24 64.250 193.320 3621.87 3674.24 4105.48 S 1073.46 W 5970107.95 N 370600.25E 1.420 4105.48 6045.03 64.380 192.580 3662.09 3714.46 4186.97 S 1092.20 W 5970026.79 N 370580.12E 0.732 4186.97 6142.16 63.630 191.760 3704.66 3757.03 4272.31 S 1110.60 W 5969941.78 N 370560.26E 1.083 4272.31 6238.06 62.050 190.140 3748.44 3800.81 4356.08 S 1126.82 W 5969858.30 N 370542.61E 2.230 4356.08 6332.46 60.900 189.010 3793.52 3845.89 4437.86 S 1140.62 W 5969776.77 N 370527.41E 1.609 4437.86 6428.43 61.180 190.140 3839.99 3892.36 4520.66 S 1154.59 W 5969694.22 N 370512.03E 1.071 4520.66 6523.32 60.890 190.310 3885.94 3938.31 4602.36 S 1169.32 W 5969612.78 N 370495.90E 0.343 4602.36 North Slope, Alaska Comment • 2 August, 2005 - 15:23 Page 3 of 6 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60P61 Your Ref.• API 501032051170 Job No. AK 2Z-0003753059, Surveyed: 17 June, 2005 Alaska North Slope North Slope, Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 6618.27 61.190 190.970 3931.92 3984.29 4684.01 S 1184.66 W 5969531.41 N 370479.17E 0.685 4684.01 6713.36 60.970 191.520 3977.90 4030.27 4765.64 S 1200.89 W 5969450.07 N 370461.54E 0.557 4765.64 6808.84 61.000 192.840 4024.21 4076.58 4847.25 S 1218.51 W 5969368.77 N 370442.53E 1.209 4847.25 6901.07 61.090 192.480 4068.86 4121.23 4925.99 S 1236.20 W 5969290.34 N 370423.50E 0.355 4925.99 6999.23 61.270 193.850 4116.18 4168.55 5009.73 S 1255.78 W 5969206.95 N 370402.48E 1.236 5009.73 7094.97 61.530 194.690 4162.02 4214.39 5091.19 S 1276.50 W 5969125.85 N 370380.37E 0.817 5091.19 • 7190.20 61.880 194.560 4207.16 4259.53 5172.33 S 1297.68 W 5969045.09 N 370357.82E 0.387 5172.33 7284.88 62.610 194.160 4251.25 4303.62 5253.50 S 1318.45 W 5968964.29 N 370335.65E 0.857 5253.50 7380.43 62.870 194.250 4295.01 4347.38 5335.84 S 1339.30 W 5968882.32 N 370313.41E 0.285 5335.84 7475.74 62.610 192.790 4338.67 4391.04 5418.21 S 1359.11 W 5968800.30 N 370292.19E 1.389 5418.21 7571.17 62.660 191.420 4382.53 4434.90 5501.08 S 1376.88 W 5968717.75 N 370273.01E 1.276 5501.08 7666.11 63.150 190.780 4425.78 4478.15 5584.01 S 1393.15 W 5968635.10 N 370255.32E 0.792 5584.01 7762.12 63.350 191.010 4468.99 4521.36 5668.20 S 1409.35 W 5968551.20 N 370237.68E 0.299 5668.20 7856.72 61.860 189.470 4512.52 4564.89 5750.85 S 1424.29 W 5968468.82 N 370221.33E 2.138 5750.85 7949.58 60.960 189.760 4556.96 4609.33 5831.24 S 1437.91 W 5968388.68 N 370206.34E 1.007 5831.24 8046.85 59.610 189.330 4605.17 4657.54 5914.55 S 1451.92 W 5968305.62 N 370190.90E 1.440 5914.55 8142.06 58.530 188.980 4654.11 4706.48 5995.18 S 1464.91 W 5968225.23 N 370176.53E 1.177 5995.18 8237.18 58.330 189.350 4703.91 4756.28 6075.18 S 1477.82 W 5968145.45 N 370162.26E 0.392 6075.18 8330.50 58.480 189.850 4752.80 4805.17 6153.56 S 1491.08 W 5968067.32 N 370147.66E 0.484 6153.56 8427.28 59.120 190.130 4802.93 4855.30 6235.08 S 1505.44 W 5967986.05 N 370131.91E 0.706 6235.08 8522.28 59.780 189.710 4851.22 4903.59 6315.67 S 1519.53 W 5967905.71 N 370116.44E 0.792 6315.67 8616.29 59.840 188.800 4898.50 4950.87 6395.87 S 1532.60 W 5967825.75 N 370102.00E 0.839 6395.87 8712.56 60.140 189.410 4946.65 4999.02 6478.19 S 1545.79 W 5967743.67 N 370087.40E 0.631 6478.19 8805.97 60.560 188.990 4992.86 5045.23 6558.32 S 1558.77 W 5967663.77 N 370073.05E 0.596 6558.32 8902.82 60.990 189.160 5040.14 5092.51 6641.78 S 1572.10 W 5967580.55 N 370058.30E 0.470 6641.78 8998.14 61.470 188.880 5086.02 5138.39 6724.30 S 1585.20 W 5967498.26 N 370043.79E 0.566 6724.30 9092.80 61.970 188.640 5130.87 5183.24 6806.69 S 1597.90 W 5967416.10 N 370029.69E 0.573 6806.69 9187.84 61.600 189.390 5175.80 5228.17 6889.40 S 1611.02 W 5967333.63 N 370015.15E 0.797 6889.40 9283.26 61.190 189.960 5221.48 5273.85 6971.99 S 1625.10 W 5967251.30 N 369999.66E 0.678 6971.99 9378.60 61.470 192.050 5267.23 5319.60 7054.09 S 1641.07 W 5967169.48 N 369982.29E 1.946 7054.09 9474.07 62.100 192.860 5312.37 5364.74 7136.24 S 1659.21 W 5967087.66 N 369962.74E 0.997 7136.24 9568.31 62.100 193.100 5356.46 5408.83 7217.39 S 1677.92 W 5967006.83 N 369942.65E 0.225 7217.39 9671.97 61.250 193.830 5405.65 5458.02 7306.13 S 1699.16 W 5966918.47 N 369919.89E 1.028 7306.13 9759.37 60.980 193.980 5447.87 5500.24 7380.42 S 1717.55 W 5966844.51 N 369900.24E 0.344 7380.42 9854.75 61.260 194.250 5493.93 5546.30 7461.41 S 1737.92 W 5966763.87 N 369878.49E 0.384 7461.41 2 August, 2005 - 15:23 Page 4 of 6 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60PB1 Your Ref.' API 501032051170 Job No. AK ZZ-0003753059, Surveyed: 17 June, 2005 A-aska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9949.47 61.670 194.580 5539.18 5591.55 7542.01 S 1758.64 W 5966683.64 N 369856.39E 0.530 7542.01 10045.09 60.570 194.120 5585.36 5637.73 7623.12 S 1779.39 W 5966602.90 N 369834.26E 1.225 7623.12 10139.72 60.480 191.520 5631.93 5684.30 7703.44 S 1797.67 W 5966522.90 N 369814.61E 2.394 7703.44 10234.56 60.760 191.180 5678.46 5730.83 7784.47 S 1813.93 W 5966442.17 N 369796.96E 0.430 7784.47 10329.64 61.090 190.890 5724.66 5777.03 7866.03 S 1829.84 W 5966360.89 N 369779.66E 0.438 7866.03 10425.25 61.430 191.650 5770.64 5823.01 7948.24 S 1846.22 W 5966278.97 N 369761.87E 0.782 7948.24 10520.33 61.930 191.820 5815.74 5868.11 8030.19 S 1863.24 W 5966197.32 N 369743.45E 0.549 8030.19 10615.81 61.960 192.530 5860.65 5913.02 8112.56 S 1881.02 W 5966115.27 N 369724.27E 0.657 8112.56 10711.00 62.050 192.870 5905.33 5957.70 8194.55 S 1899.49 W 5966033.61 N 369704.40E 0.329 8194.55 10806.33 62.370 193.980 5949.78 6002.15 8276.58 S 1919.07 W 5965951.92 N 369683.42E 1.083 8276.58 10901.41 62.650 194.310 5993.66 6046.03 8358.37 S 1939.69 W 5965870.50 N 369661.41E 0.426 8358.37 10996.35 63.150 194.200 6036.91 6089.28 8440.28 S 1960.50 W 5965788.96 N 369639.20E 0.537 8440.28 11092.11 63.430 194.200 6079.96 6132.33 8523.21 S 1981.48 W 5965706.40 N 369616.80E 0.292 8523.21 11184.83 63.060 194.340 6121.70 6174.07 8603.45 S 2001.89 W 5965626.52 N 369595.02E 0.421 8603.45 11280.17 62.370 194.300 6165.40 6217.77 8685.55 S 2022.85 W 5965544.79 N 369572.66E 0.725 8685.55 11375.42 61.620 192.820 6210.13 6262.50 8767.29 S 2042.57 W 5965463.39 N 369551.55E 1.582 8767.29 11470.52 61210 192.480 6255.63 6308.00 8848.77 S 2060.86 W 5965382.24 N 369531.87E 0.533 8848.77 11565.32 60.800 192.070 6301.58 6353.95 8929.80 S 2078.48 W 5965301.53 N 369512.86E 0.575 8929.80 11660.75 60.390 192.530 6348.44 6400.81 9011.02 S 2096.19 W 5965220.62 N 369493.76E 0.601 9011.02 11756.04 59.730 193.550 6396.00 6448.37 9091.47 S 2114.82 W 5965140.51 N 369473.76E 1.158 9091.47 11851.41 59.440 193.140 6444.28 6496.65 9171.49 S 2133.81 W 5965060.82 N 369453.41E 0.479 9171.49 11945.92 59.010 192.920 6492.64 6545.01 9250.60 S 2152.11 W 5964982.03 N 369433.75E 0.497 9250.60 12041.43 59.200 193.300 6541.68 6594.05 9330.42 S 2170.70 W 5964902.54 N 369413.80E 0.395 9330.42 12136.80 58.250 192.810 6591.19 6643.56 9409.83 S 2189.12 W 5964823.46 N 369394.03E 1.089 9409.83 12232.23 58.010 192.200 6641.57 6693.94 9488.95 S 2206.67 W 5964744.65 N 369375.13E 0.598 9488.95 12327.68 57.510 192.290 6692.49 6744.86 9567.84 S 2223.79 W 5964666.06 N 369356.66E 0.530 9567.84 12422.66 56.830 191.790 6743.99 6796.36 9645.90 S 2240.44 W 5964588.31 N 369338.68E 0.842 9645.90 12518.15 56.350 192.860 6796.57 6848.94 9723.77 S 2257.45 W 5964510.74 N 369320.34E 1.062 9723.77 12613.34 55.950 193.810 6849.59 6901.96 9800.69 S 2275.68 W 5964434.14 N 369300.79E 0.929 9800.69 12708.07 54.980 192.970 6903.29 6955.66 9876.60 S 2293.76 W 5964358.54 N 369281.42E 1.258 9876.60 12802.77 54.600 192.700 6957.89 7010.26 9952.04 S 2310.95 W 5964283.41 N 369262.95E 0.464 9952.04 12897.84 54.360 195.200 7013.14 7065.51 10027.13 S 2329.59 W 5964208.65 N 369243.02E 2.155 10027.13 12992.98 53.400 195.020 7069.22 7121.59 10101.32 S 2349.63 W 5964134.81 N 369221.72E 1.021 10101.32 13088.31 52.540 194.720 7126.63 7179.00 10174.88 S 2369.16 W 5964061.60 N 369200.93E 0.936 10174.88 13183.39 53.780 195.070 7183.64 7236.01 10248.41 S 2388.72 W 5963988.41 N 369180.11E 1.337 10248.41 North Slope, Alaska Comment • 2 August, 2005 -15:23 Page 5 of 6 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD2-60P61 Your Ref.• API 501032051170 Job No. AK ZZ-0003753059, Surveyed: 17 June, 2005 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13278.68 53.250 194.520 7240.30 7292.67 10322.49 S 2408.29 W 5963914.68 N 369159.28E 0.724 10322.49 13374.02 55.080 194.280 7296.11 7348.48 10397.35 S 2427.51 W 5963840.16 N 369138.79E 1.930 10397.35 13469.28 55.770 194.120 7350.17 7402.54 10473.39 S 2446.75 W 5963764.46 N 369118.25E 0.737 10473.39 13543.00 55.770 194.120 7391.64 7444.01 10532.50 S 2461.61 W 5963705.62 N 369102.37E 0.000 10532.50 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Doyon 19 (52.37'). Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13543.OOft., The Bottom Hole Displacement is 10816.33ft., in the Direction of 193.155° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 13543.00 7444.01 10532.50 S 2461.61 W Projected Survey Survey tool program for CD2-60PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 617.00 612.12 To Measured Vertical Depth Depth (ft) (ft) 617.00 612.12 13543.00 7444.01 Survey Tool Description CB-SS-Gyro MWD+I IFR+MS+SAG North Slope, Alaska Comment Projected Survey • 2 August, 2005 - 15:23 Page 6 of 6 DrillQuest 3.03.06.008 L_J • 20-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-60 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,756.04' MD Window /Kickoff Survey: 11,760.00' MD (if applicable) Projected Survey: 18,695.00' 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 ~ ~'~ ~ Signed ~~ `~J Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 20-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-60 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,756.04' MD Window /Kickoff Survey: 11,760.00' MD (if applicable) Projected Survey: 18,695.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALL{BURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriNing Services Attn: Carl Ulrich 6900 Arctic Blvd. AK 99518 ~ Anchorage, ,./ / r~ ~ ~ ~~ ~~ r`~ ~~ pp Date / ~. i ~ Signed '`~ t~nV Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 20-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-60 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 13,543.00' 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 .~.... `r I ~d Date ~~t ~ Signed ~ "W Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 20-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ~~EFlNI~I~E~ Re: Distribution of Survey Data for Well CD2-60 PB1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 13,543.00' 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 ~} ( , , . e' J f ra r, 1J {{ ~j Date ~ ~ ~ `' Signed 1~. , 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 August 15, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CDZ-60, AK-MW-3753059 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~13~ 1 LDWG formatted Disc with verification listing. API#: 50-103-20511-00. a, a~~, 4~~ • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 August 15, 2005 RE: MWD Formation Evaluation Logs: CD2-60 PB1, AK-MW-3753059 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#: 50-103-20511-70. ~ ~~ ~ 3 aSi ~ 65 - o~ ~ RE: CD2-60 permitted depth Subject: RE: CD2-60 permitted depth From: "Johnson, Vern" <Vern.Johnson@conocophillips.com> ~ ~ ~ ~~ ~j Date: Thu, 07 Ju12005 11:06:12 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: "Alvord, Chip" <Chip.Alvord@conocophillips.com> Tom, We called TD not long after I sent the email to you yesterday afternoon. TD was called at 18695', which is within 500' of the originally permitted wellbore, so I don't plan on sending over a 10-401. Let me know if you need any further information. Vern Johnson -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin.state.ak.usj Sent: Thursday, July 07, 2005 7:48 AM To: Johnson, Vern Subject: Re: CD2-60 permitted depth Vern,. Going past 500' does require a new permit. See 20 AAC 25.015. (b) (2) of the regulation allows continued drilling to be verbally approved. This well is within the CRU and there are no issues with other wells or the boundary. You have approval to go beyond 500' and from the permitted depth. Please submit the new permit as you plan. Tom Maunder, PE AOGCC Johnson, Vern wrote: Tom, As discussed, we are past our originally planned total depth for CD2-60. Depending on what we observe on logs, we may want to drill more than 500' past the originally permitted depth. If we do, we will submit a new 10-401 tomorrow. It is important that we get a better understanding of the geology in the area, so the additional footage is more for evaluation purposes than infectivity purposes. We are currently at 18648 MD 16:54, at ± 18749 we will be at the originally permitted X-Y TD location. Let me know if you have any questions or require further information. Vern Johnson 907-265-6081 1 of 1 7/7/2005 11:43 AM STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re~~~y~adrr:i:~.state.a>i.~~~~ aa~cc pr~_Ed~~ae bt:r~L~~nn.s~tate.al<.us b~:i~ teckenstein~~asrrr:i:~.stlite.a>~.u~~ Contractor: Doyon Rig No.: 19 DATE: 7/1/2005 Rig Rep.: Welsh/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey/Burley Field/Unit & Well No.: Colville Rv CD2-60 PTD #: 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 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 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 Results CHOKE MANIFOLD: Quantity Test Resu 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 1350 P 200 psi Attained 46 P Full Pressure Attained 3 min 56 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2400 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 r~:~~~;~3adrr:in.state.ak.us Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Date 07/01/05 Time 8:00 Test start 6:OOPM Finish BOP Test (for rigs) BFL 11/09/04 Waived By Chuck Shelve Witness Lu Doyon19 07-1-05 CD2-60.x1s RE: CD2-60 P & A Procedures • ~ Subject: RE: CD2-60 P & A Procedures From: "Noel, Brian" <Brian.Noel@conocophillips.com> Date: Mon, 27 Jun 2005 11:38:32 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: "Johnson, Vern" <Vern.Johnson@conocophillips.com>, "Alvord, Chip" <Chip.Alvord@conocophillips. com> Tom - Weekend operations have gone well according to plans described in Vern's note. Cement plug in place, BOP tested, staged in hole (displacing 12 ppg mud w/ 9.6 ppg), sidetracked off plug and drilling ahead with full returns to new 7" casing point at 14,255'. Have 800'left to drill to reach casing point. Details of the plugback operation from the morning reports: RIH w/ cementing assembly f/ 1099' to 12,229'. Wash down f/ 12,229' to 12,325' - 3 bbls/min @ 400 to 550 psi - hole getting sticky f/ 12,295 to 12,325' - pulled up & LD 1 single of DP - RU cement head & lines - resumed pumping & working pipe. Held PJSM -With tbg stinger ® 12,291'. Set P&A/KO plug as follows: Pumped 5 bbls water - tested lines to 3000 psi - pumped 15 bbls water - Mixed & pumped 57 bbls. 17.0 ppg Class G cmt @ 4.5 bbls/min ~ 772 to 257 psi - pumped 9 bbls water behind - shut down & dropped drill pipe dart - Displaced w/ 186 bbls 12.0 ppg mud - latched dart into plug catcher sub wf 510 psi - bleed off pressure - dart held - CIP @ 1053 hrs. - rig down cement head & lines. Shear plug catcher at 2880 psi. POH w/ pump f/ 10,897' to 10,385' at 1.3 bpm at 190 psi. Check flow. Static. WOC - 4.5 hours. RIH f/ 10,325' to 11,087'. Wash down at 2 bpm at 350 psi w/ slight returns and tag cement at 11,751'. Let me know if you need more info. Thanks - Brian 265-6979 ` { ~~.1~ v0`J`t`"~~ ~ `~~c ~Q~.1S(c ~.1 0 -----Original Message----- b~~~ ~~,.~.. C~„~~('~.1~~ From: Thomas Maunder [mailto:tom maunder`'admin.state.a'~.usJ ~~ Sent: Monday, June 27, 2005 9:45 AM l (` To: Noel, Brian ~ \~O'T ~` CC ~ ~ZSh S~OV, Cc: Johnson, Vern; Alvord, Chip Subject: Re: CD2-60 P & A Procedures Brian, ~~ Qy~ ,/~ Here is the note Vern copied us on regarding plugging back CD2-60. I `~V// was wondering if you could provide some of the actual information ~/a~-p~' regarding setting the plug, tagging, etc. From our discussion Saturday, o I understand that operations went fairly well. Thanks in advance for the information. Tom Maunder, PE AOGCC Johnson, Vern wrote: Tom, As discussed yesterday, we were unsuccessful fishing our drilling BHA (see attached file showing the assembly). The logging tools in the BHA include two radioactive sources. The top of the fish is at ± 12329' MD, the bottom of the fish is at ± 13542' MD and total depth of the hole section is 13542' MD. Two fishing attempts were made. We were unable to engage the fish on either attempt. It was decided to quit fishing due to inability to engage the fish, deteriorating hole conditions, and limited ability to circulate. Higher than expected reservoir pressure (+/- 11.7 ppg equivalent vs. expected 1 of 2 6/27/2005 3:56 PM RE: CD2-60 P & A Procedures • 9.3 ppg) required 12 ppg mud for tripping, which we suspect caused lost circulation above the BHA. ', The plan forward is to run in the hole with a tubing stinger, and pump a i single 17 ppg abandonment/kick off plug from ± 12307 to ± 11700' MD, ', with 30 % excess. We plan to wait above the plug for ± 6 hr, then attempt to tag the plug. Provided the plug is found as expected, we will pull out of hole and perform a BOP test. After testing BOPS a drilling assembly will be picked up and run in the hole. We will stop several times to establish circulation and drop the mud weight from 12 ppg to ± 9.6 ppg, it is hoped that by decreasing the mud weight we will reduce or eliminate the lost circulation problems. We plan to kick off the cement plug and land the intermediate hole section near the originally permitted location, but slight higher TVD. By landing at a higher TVD we expect to avoid the reservoir pressure issues we encountered while drilling the pilot hole. We will penetrate the Alpine C ± 860' MD from the pilot hole. If you need further information please call or email. I may be out of the office for several days, Chip Alvord 265-6120 or Brian Noel 265-6979 can answer any questions in my absence. Vern Johnson «BHA%201ost%20in%20CD2-60PBl.pdf » 2 of 2 6/27/2005 3:56 PM • . ~~ ~ f~ Operator : Conoco Phillips Alaska Inc. Well :CD2-60 ®I~O~~~~~ ~~~dl~~~ Field: Alpine Location : CD2 Rig : #19 BHA# 3 Date In E~~16/200~ MD In (ft) : 11 i21 TVD In(ft} :6145 Dafe Cur 6117'2005 MD Cur(ft}: 1?189 TVD Cur(ft}: 6671 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32's) TFA (in2) Dull Condition 3 8.500 Hu hes HCM605 7011483 5x15 0.863 MOTOR DATA Run# OD in) MFR Model Serial# Bend Nzl l32's) Av Dif si) Cum Circ HrS S 7.000 SSDS SperryDrill 700056 1.22' 165 15.76 COMPONENT DATA Item Description Serial OD ID Gauge Weight Top Con Length Bit -Center # # (in) (in) (in) (Ibs/ft) (ft) Blade (ft) 1 HMC605 "RR PDC Type" Bit 7011483 8.500 3.500 8.500 . 160.60 P 4-1/2" Req 1.00 2 7" SperryDrill Lobe 7/8 - 6.0 stq 700056 7.000 4.753 8.250 70.69 B 4-112" {F 25.27 3.16 3 Float Sub 647 6.688 2.500 103.00 B 4-1/2" IF 1.45 4 DM HOC 46899 6.660 2.250 105.17 B 4-1/2" IF 8.96 5 I-L-S Stabilizer 82081 6.760 1.920 8.313 112.45 B 4-1/2" IF 2.20 37.66 6 63/4" RLL w//DGR+EWR-PWp 78462 6.700 1.920 110.29 B 4-1/2" IF 20.87 7 I-L-S Stabilizer 4157 6.760 1.920 8.313 112.45 B 4-1 /2" IF 2.17 60.76 8 6-3/4" HCIM 134508 6.750 1.920 112.09 B 4-1 /2" IF 6.98 9 6-3/4" RLL SLD-CTN-ACAL 77516 6.750 8.190 106.76 B 4-1/2" IF 28.29 10 TM HOC 727423 6.630 3.250 89.38 B 4-1/2" IF 9.97 11 Non-Mag Flex Drill Collar 10574615 6.438 2.813 89.76 B 4-1/2" tF 31.05 12 Non-Mag Flex Drill Collar C997 6.438 2.813 89.76 B 4-1/2" IF 30.84 13 Non-Mag Flex Drill Collar 884 6.250 2.813 83.38 B 4-1/2" IF 30.57 14 3x HWDP 5.000 3.000 49.30 B 4-1l2" IF 89.46 15 DNT Drilling Jar (194.54 hrs) 16210044 6.125 2.375 85.32 B 4-1/2" IF 32.80 16 14x HWDP 5.000 3.000 49.30 B 4-1/2" IF 419.44 17 2x DP (S) - NC50(XH) -19.50# 5.000 4.276 22.60 B 4-112" IF 63.62 18 Weatherford Ghost Reamer 266638 6.500 2.500 8.500 96.36 B 4-1/2" IF 6.00 808.94 19 32x DP (S) - NC50(XH) - 19.50# 5.000 4.276 22.60 B 4-1/2" IF 1016.20 20 Weatherford Ghost Reamer 263127 6.500 2.500 8.500 96.36 B 4-1/2" IF 6.41 1831.19 21 2x DP (S) - NC50(XH) -19.50# 5.000 4.276 22.60 B 4-1/2" IF 63.36 1896.91 ~~~~~~ Operator : Conoco Phillips Alaska Inc. Well :CD2-60 ®~0 X61 ~ ~ ~~~b) ~ ~ ~ Field : Alpine Location : CD2 Rig : #19 Activity Hrs BHA Weight (Ib) Drilling : 10.32 in Air (Total) 73548 Reaming : 0.00 in Mud (Total) 62787 :irc-Other : 5.44 in Air (Bel Jar:: 23040 _ _~ PERFORMANCE In Out Inclination (deg) 63.31 57.73 Azimuth (deg) 194.24 192.54 Drill String OD(in) Len(ft) DP(G)-NC50(XH)-19.50# 5.000 10292 Distance ft ROP ft/hr Build °/100' Turn °/100' DLS °/100' Oriented : 94.00 44 Rotated : 974.00 109 -0.50 -0.30 n ~~ Planned Flow Rate= 540~40gpm /Planned Rotary= 60-120rpmMotor Factor= .33Rev/Gal / CasingShoe (c~3276 'Bit-Dm=32.53'/Bit-Dgr- 40.6' /Bit-Res=48.16'/ Bit/Pwd=56.44' /Bit-SId=79.13' /Bit-Acal=89.73' /Bit-Ctn=93.22' /Rig Floor Ofset=69.33°'s Jar has 194.54hrs ~ start of run ~~I~.L111D1=a ~1=~V11=E~ Operator : Conoco Phillips Alaska Inc. Well : CD2-60 Field : Alpine Location : CD2 Rig : #19 OBJECTIVES: BHA #3 -This assembly will be used to complete the 8-1/2" Plug Back section, 11121-13605' +/-., drilling the tangent, holding 61.155° Inc and 193.121 ° Azimuth to 12200'. The assemby will then begin a 4°/100' drop, to 12353', hold 55° Inc, and maintaining 193.121 °, to 13605' TD for plug back section. RESULTS: BHA #3 - STATE OF ALASKA ~vosio4 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim regg~~adrr:in.state.a>~.us aac~. ~r~Ed~,ae ht:~~ad:nin.stafe.ak.us brt f€eckensten :~3adrr:i:~.state.a>~.u• Contractor: Doyon Rig No.: 19 DATE: 6!24/2005 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.: Mickey/Lutrick Field/Unit & Well No.: Colville Rv CD2-60 PTD # 205-068 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 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 CHOKE MANIFOLD: Quantity Test Res No. Valves 16 FP Manual Chokes 1 P Hydraulic Chokes 1 P Test Result P 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 ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1450 P 200 psi Attained 49 P Full Pressure Attained 3 min 54 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2300 Test Results Number of Failures: 2 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: ~m reg~~;~~adr~:in.stUte.a>~.us~ Remarks: #5 valve on choke manifold leaked. Greased it and it tested. Also changed out a grease zert on C.M. Valve #11. Good test. 24 HOUR NO YES X Date 06/21 /05 Test start .G NO Time 4:00 Finish Waived By Witness Jeff Jones BOP Test (for rigs) BFL 11/09/04 Doyon19 06-24-05 CD2-60-3.xls STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~~m rGgq ;ti~adn:in.state.ak.us~ acgcc pr~¢d~~oe o~:~ad:n~n.stae.ak.us brl ~ eckenatein„~adr~:i:~.state.ak.us Contractor: Doyon Rig No.: 19 DATE: 6/11/2005 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.: Mickey/Hill FieldlUnit & Well No.: Colville Rv CD2-60 PTD # 205-068 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 Resu 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 CHOKE MANIFO LD: Annular Preventer 1 13-5/8 P Quantity Test Resu Pipe Rams 1 3-1/2x 6 P No. Valves 16 P Lower Pipe Rams 1 3-1/2x 6 P Manual Chokes 1 P Blind Rams 1 blinds P Hydraulic Chokes 1 P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8 P Time/Pressure Test Resu Check Valve 0 NA System Pressure 2950 P Pressure After Closure 1450 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 45 P Trip Tank P P Full Pressure Attained 3 min 45 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 @2400 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 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 reg~q~:~3adn:in.state.a>c.~tr ,Remarks: Base flange on FMC Alpine uni-head adapter began leaking on the last test. Retightened and j retested OK. 24 HOUR NOTICE GIVEN YES X NO Date 06/09/05 Time 6:50 Test start 8:OOam 6/11 Finish Waived By Chuck Scheve Witness Tim Krupa/Don Mic BOP Test (for rigs) BFL 11/09/04 Doyon19 06-11-OS CD2-60.x1s ~ ' a~ a~ ~~ 1 ~ 1 3 i j ~' # h ~ ' ~~ i " ;~~ ~ ~ ~ ~ } ~ ~ ~ ' ~~ ?, Y FRANK H. MURKOWSKI, GOVERNOR o' 9 ~~~~ ~~~~++t¢~ ~~a~ ~r~~+ AL~-7R~ OIL A11TD t7r0a7 ~ 333 W. 7"' AVENUE, SUITE 100 CO~SERQAiiOl` CO~TISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Colville River CD2-60 &CD2-60 PB1 ConocoPhillips Alaska, Inc. Permit No: 205-068 Surface Location: 2162' FNL, 1491' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 1095' FNL, 1684' FEL, SEC. 23, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals 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 Commission's petroleum field inspector at (907) 659-3607 (pager). ~,., Si erel >'~~' ~/ ~~ '`` aniel T. Seamount, Jr. Commissioner DATED this, day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 28, 2005 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-60 &CD2-60PB1 Dear Sir or Madam: Conoc Philli s ~~~~ APR ~ ~ 2005 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Alpine CD2 drilling pad. The intended spud date for this well is 5/14/2005. It is intended that Doyon Rig 19 be used to drill the well. The pilot hole well, CD2-60PB1 will be drilled through the Alpine C sand at +/-61 ° inclination for logging and evaluation purposes. The well will be plugged back above the HRZ with cement. ~ The well CD2-60 will then be drilled off the cement plug and landed in the Alpine C sand horizontally. 7" casing will then be run and cemented in place. The horizontal section will be drilled and completed as an open hole injector. At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. There have been 41 wells ~ drilled on CD1 pad and 53 wells drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. It is also requested that the packer placement requirement be relaxed to place the completion packer 300 ft TVD above the Alpine formation. 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 i 0-401 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. Proposed pilot hole plug back diagram. 6. Proposed completion diagram. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. 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 is: 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. . 1 l ~' l If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Si rely, Vern John on Drilling Engineer Attachments APR %'005 Alaska Oit c~ ~~s ~~s~:i. (;~'~~a~aissia~s Anchara~a cc: CD2-60 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Chris Alonzo Steve Moothart Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1770 ATO-1756 Kuukpik Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 APR ~ zaa~ 1 a. Type of Work: Drill / Redrill 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service^/ Devel ~~ ('y~~ jjgfq~, ;,i'~16`H$6 2. Operator Name: 5. Bond: / Blanket Single Well 11. Wj~llNe~~ Number: 1i 1 ~ c ConocoPhillips Alaska, Inc. Bond No. 59-52-180 &~ CD2- CD2-60 PB1 6 0 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18279' ~ TVD: 7433' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Alpine Oil Pool Surface: 2162' FNL, 1491' FEL, Sec. 2, T11 N, R4E, UM ~ ALK 380075, 380077 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2795' E=NL, 3727' FEL, Sec. 14, T11 N, R4E, UM ASRC NPRA N!A 5(14f2005 Total Depth: 9. Acres in Property: 14. Distance to ~,£~~° ~~~, ~dc. ~ 1095' FNL, 1684' FEL, Sec. 23, T11 N, R4E, UM 2560 Nearest Property: Ems. ,~~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest 5'' ' / Surface: x- 371744 y- 5974194 Zone- 4 (Height above GL): 36.7 feet r well within Pool: CD2-55 , j036 16. Deviated wells: 17. Anticipated Pressure (see zo AAC 25.035) Kickoff depth 200 ~ ft. Maximum Hole Angle: 91 ° Max. Downhole Pressure: 3363 psig /Max. Surface Pressure: 2620 psig ~ 18. Casing Program Setting Depth Quantity of Cement Size S ecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Portland cement 12.25" 9.625" 36# J-55 BTC 3273 37' 37' 3310' 2390' 618 sx AS Lite & 230 sx LiteCrete 8.5" 7" 26# L-80 BTC-M 14118 37' 37' 14155' 7394' 264 sx 15.8 ppg G 6.125" 4.5" 12.6# L-80 EUE-M 13060' 32' 32' 13092' 7121' Tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD {ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft}: Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Linear Perforation Depth MD (ft): Perforation Depth TVD (ft): None None 20. Attachments: Filing Fee ~ BOP Sketch Drilling ProgramQ Time v. Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson Q 265-6081 Printed Name C. Alvord Title Alpine Drilling Team Leader Signature / ~ Phone ZG 5".- (o /2 o Date 4- f 2'(~ m ~' L ~ Pre ared b Vern Johnson Commission Use Only Permit to Drill API Number: Permit Approval See cover letter C°_~~ C) Number: ,..7 , L,7 ~ - j ~ ~ - ~~ 50- /~a ~~, Q Date: for other requirements Conditions of approval : Samples required ^ Yes ~ No Mud log required ^ Yes ~ No vey required ~ Yes ^ No r Hydrogen sulfide measures ^ Yes ~No Directional su c ~ 'aSiaO P`~~` c~`~.~Zu-.~~~~~ce's~t- biu~~~t-v`~caa~l~~"`4 ~-z.~Xc3 c~3t`~A4~,~S.iO~iSCh~~~ Other: ~ ~ ~ 3~~~~s4t"f~O~) ~"~,~~' ~~crCCSc~ ~c5.t.~ttci' ~c~"~c.~~~~~~~a~ `~~. 'O p><c-c~ :o sue=, ~ n e.ctoc-~1 "'' l A l0 ~Fs~3 , BY ORDER OF Approved by: ii~ ~ COMMISSIONER THE COMMISSION Date: ~ ~~ (J Form 10-401 Revised 3/2003 ORIGINAL Submit in duplicate zj ~~~ • CD2-60 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discuss Islas 12-1/4" Hole / 9-5/8" Casing Interval APR ~ ~~~~ Event Risk Level Miti ation Stia~ ~ ~~ `~~°~~ " Conductor Broach Low Monitor cellar continuous) Burin interva . ~ a Well Collision Low G ro sin le shots travelin c tinder dia rams Gas Hydrates Low / Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surtace Formations ~ >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-1/2" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface. Formations i 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 i 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 ~1;€iSSii3t ORIGINAL • Alpine: CD2-60 &CD2-69PB1 Procedure ~ !,~ 1. Move on Doyon 19, dewater cellar as needed. ~ ~ ~ ~ ~ ~ 2. Nipple up riser. Alaska ~ ~ ~~::; C . s. i~a;~s t8ssi0rt 3. Drill 12 ~/<" hole to the surface casing point as per the directional plan. ~ 4. Run and cement 9 5/8" surface casing. 5. Pressure test casing to 2500 psi. 6. Install and test BOPE to minimum 5000 psi. / 7. Drill out 20' of new hole. Perform leak off test. 8. Drill 8-1/2" hole through the Alpine interval (LWD: GR/RES/DENSITY/POROSITYPWD) '~ 9. Plug back the pilot hole with two cement plugs ' 10. Kick off the cement plug with 8-1/2" drilling assembly. 11. Drill 8'/z" hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD) ~ 12. 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. 13. ROPE test to 5000 psi. 14. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and pertorm formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 15. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). ~~ 16. Circulate the hole clean and pull out of hole. 17. Run 4-~/2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. OR161NAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 2 ,(~ ' r ed in following attachments. CD2-58 is the closest well. Well separation is 9.9' C~ 470' l!:~.;, - ~~qq~ ..-.~ :~J Drilling Area Risks: '~~~ Luis There are no hi h-risk events e. over- ressures zones antici ated. ' ~41aSk~ ~ ~ ~, -~~ ~:~.::,, ~ ;;;t,tta~~f~t 9 ( 9• p ) p r p~~ Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely c~'ause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed ' kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2-60 will be injected into the class 2 disposal well on CD1 pad, or a permitted annulus on CD2. The CD2-60 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1700' TVD. The only significant hydrocarbon zone is the Alpine reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk as per regulations. Upon completion of CD2-60 form 10-403, Application for Sundry Operations -Annular Disposal,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. 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" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi U~:161NAL CD2-60 DRILLING FLUID PROGRAM • • ~~~ moo. r..Ui ~. SPUD to 9-518"surface casing oint -12 '/4" Intermediate hole to casing point - 8'/i" i o "' Seolir6~RJ8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 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) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH $.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 KCL 6 Surtace Hole: i~t;: i A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flew line viscosity at t 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 includins~ CD2-ti0 P61: 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 Alpine 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 M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL • CD2-60 P61 Plup Back Schematic• Alaska 0;1 ~~a~fated 04/28/05 RKB - GL = 37' Sp Sun'D11`~~1@R ~ryF.., Plan INP04 ~ Wellhead 16" Conductor to 114' 9.8 ppg drilling mud in hole 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3310' MD / 2390' ND (planned) cemented to surface rnucf plus #2:700' Kick off olua Ton at +/- 12105' MD / 6634 ND 17 ooa tg #2 700 ftTon HRZ ~ 12402' MD / 6788' ND Top Alpine Reservoir at ~ piua #1 : +/_ 800' IToo CtD +1-12805 MD +/-13440' MD / 7382' TVD Plug #1 800 ft / 6971' ND 1. 15.8 ooa Pilot Hole TD at +/- 13605' MD / 7478' TVD ~ OR161NAL • C Alpine CD2-60 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 1902' ND = 2300' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3310' MD / 2390' ND cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT ID) w/dummy Updated 04/28/05 Sperry Sun Directional Plan WP04 RECEIVE[ APR 2 9 2005 Alaska Oil & Gas Cons, t,u,,,fniss Anchorage Com letion mQ T~ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 2300' 1902' 4-1/2", 12.6#!ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 12920' 7042' 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 13020' 7089' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-63.7° inc 13080' 7115' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 13092' 7121' Baker Premier Packer +/- 13020' MD/ 7089' ND < 300' ND from top of Alpine C TOC @ +/- 12532' MD / 6843' ND (1464' MD above top Alpine C) Top Alpine C at 13996' MD / 7379' ND 7" 26 ppf L-80 BTC Mod Production Casing @ 14155' / 7394' TVD @+/- 87.5° Well TD at 18279' MD / 7433' TVD OR161NAL i • cue-so ~ ,~ ~ ~~ PRESSURE INFORMATION AND CASING DESIGN ~ ~ ~ m ~;, ~` ~F (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 pressured 81i-~n§~'ifo'~ eNt~; .rf, -•~ 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 3310 / 2390 14.5 1081 1640 7" 14155 / 7394 16.0 3346 2620 N/A 18279 / 7433 16.0 3363 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surtace, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 842 psi 2. Drilling below surtace casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - O.i] x 2390 =1563 psi OR ASP =FPP - (0.1 x D) = 3346 - (0.1 x 7394') = 2607 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3363 - (0.1 x 7433') = 2620 psi ~-~~ OR161NAL ~ ~ Cementing Program: ~~' .~. ~~~ 9 5/8" Surface Casing run to 3310' MD / 2390' TVD. lss~~~. ~ ~~ ~' ~ ~ ` " °.,°~~~~n-`°ss6~"' Cement from 3310' MD to 2810' (500' of fill) with Class G + Adds @ 15 ~ ~~P~`and from 2$10' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (+/-1847' MD). Lead slurry: (2810'-1847') X 0.3132 ft3/ft X 1.5 (50% excess) = 452.4 ft3 below permafrost 1847' X 0.3132 ft3/ft X 4 (300% excess) = 2313.9 ft3 above permafrost Total volume = 452.4 + 2313.9 = 2766.3 ft3 => 618 Sx @ 4.48 ft3/sk System: 618 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% BWOW1 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 ft3lsk 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 Pilot Hole Cementing Requirements Cement Plug #1:13605' MD to 12805' MD = 800'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 800' X 0.3941 ft3lft X 1.15 (15% excess) = 315.3 ft3 => 272 Sx @ 1.16 ft3Jsk Cement Plug #2:12805' MD to 12105' MD = 700'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 700' X 0.3941 ft3/ft X 1.15 (15% excess) = 317.2 ft3 => 318 Sx @ 1.00 ft3/sk 7" Intermediate Casing run to 14155' MD / 7433' TVD Cement from 14155' MD to +l-12532' MD (50% more cement above the packer as there is between the packer and the Alpine C) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (14155' -12532') X 0.1268 ft3/ft X 1.4 (40% excess) = 288.1 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 288.1 + 17.2 = 305.3 ft3 => 264 Sx @ 1.16 ft3/sk System: 264 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 u~41GINAL • ~ ConocoPhillips ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-60 Plan: CD2-60PB1 ^ ~ Proposal Report 26 April, 2005 ., 4% b ~pelrlry L1lrfliln~ a-elrvi+ ORIGINAL " '-~ Sperry Drilling Services HAl L1Bl JR~TG"~ " . . ~~ ~~~ ~~ ~ '~ Planning Report -Geographic P' Sperry Drilling Services - ; $ ~ Database: EDM 2003.11 Single User D6 Local Co-ordinate Reference: Well Plan: D -~ ~`°~` ` °^ Company: ConocoPhillips Alaska Inc. ND Reference: CD2-60 @ 52.9~O~ ~D~,6q~tig~(~,~,~-+37)) Project: Colville River Unit MD Reference: CD2-60 @ 52. D2w60 i~(~}'S~9~37)) Site: Alpine CD2 North Reference: True , Well: Plan: CD2-60 Survey Calculation Method: Min~i~~~gr~~~r~ ' 1 , is~\=t Wellbore: Plan: CD2-60PB1 ~??'l ':~~" " ' Design: CD2-60PB1wp04 . i ~ Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: CD2-60 - - - Well Position +N/-S 0.000 ft Northing: 5,974,194.4700ft Latitude: 70° 20' 15.835" N +E/-W 0.000 ft Easting: 371,743.7700ft °" Longitude: 151° 02' 26.471" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 15.900 ft Wellbore Plan: CD2-60PB 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength j BGGM2004 4/26/2005 23.5902 80.6070 57,530 Design CD2-60PB1wp04 Audit Notes: Version: I Phase: PLAN Tie On Depth: 37.000 Vertical Section: Depth From (ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 37.000 0.000 0.000 180.000G ; Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft)- (°I100ft) (~) 37.000 0.000 0.0000 37.000 0.000 0.000 0.00 0.00 0.00 0.0000 200.000 0.000 0.0000 200.000 0.000 0.000 0.00 0.00 0.00 0.0000 2,238.497 61.155 193.1214 1,872.897 -962.654 -224.396 3.00 3.00 0.00 193.1214 12,200.000 61.155 193.1214 6,678.742 -9,460.401 -2,205.229 0.00 0.00 0.00 0.0000 12,353.875 55.000 193.1214 6,760.068 -9,587.533 -2,234.864 4.00 -4.00 0.00 180.0000 13,605.377 55.000 193.1214 7,477.900 -10,585.938 -2,467.593 0.00 0.00 0.00 0.0000 4/26/2005 4:16:36PM Page 2 of 7 COMPASS 2003.11 Build 50 ~~ ,~ Sperry Drilling Services HALL1Bt ! TON , ~ ~~~~~~ Planning Report -Geographic Sperry Drilling Services Database: EpM 2003.11 SingVe Userbb Local Co-ordinate Reference: Well Plan; CD2-60 Company: ConocoPhillips Alaska Inc. ND Reference: CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37}) Project: Colville River;,Unit MD Reference: CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) Site: Alpine CD2 North Reference: True Well: Plar.. CD2-60 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-60P61 Design: CD2-60PB1wp04 ~~K F' ~ r 4 Prognosed Ca sing Points I-~ ~~~'~;4 ~~`~ c J~:~J Measured Vertical Casing Hole Depth Depth Diameter Di ameter .-> r _ 3,310.343 2,390.000 9-5/8 1 2-1/4 '-'I~~'"'"'"~' 12,300.000 6,730.003 7 8-112 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) {% S°1 (ftl (ftl (ft1 ?dame 2,928.742 61.16 193.12 2,205.900 -1,551.47 -361.65 C-40 3,353.664 61.16 193.12 2,410.900 -1,913.96 -446.15 C~0 4,124.741 61.16 193.12 2,782.900 -2,571.73 -599.47 C-20 6,313.607 61.16 193.12 3,838.900 -4,438.96 -1,034.73 K3 Marker i 6,732.310 61.16 193.12 4,040.900 -4,796.14 -1,117.99 Basal K-3 Sand 6,796.566 61.16 193.12 4,071.900 -4,850.96 -1,130.76 K-2 Marker ..6,991.409 61.16 193.12 4,165.900 -5,017.17 -1,169.51 Base K-2 Cycle 9,918.187 61.16 193.12 5,577.900 -7,513.88 -1,751.49 Aibian 97 10,944.217 61.16 193.12 6,072.900 -8,389.14 -1,955.52 Albian 96 12,402.399 55.00 193.12 6,787.900 -9,626.24 -2,243.89 HRZ 12,780.727 55.00 193.12 7,004.900 -9,928.06 -2,314.24 Base HRZ i 12,867.899 55.00 193.12 7,054.900 -9,997.60 -2,330.45 K-1 Marker 12,948.098 55.00 193.12 7,100.900 -10,061.58 -2,345.37 Kuparuk Fm 13,028.297 55.00 193.12 7,146.900 -10,125.56 -2,360.28 LCt)-Miluveach 13,321.196 55.00 193.12 7,314.900 -10,359.23 -2,414.75 Mituveach A 13,370.012 55.00 193.12 7,342.900 -10,398.17 -2,423.82 Alpine D 13,439.750 55.00 193.12 7,382.900 -10,453.81 -2,436.79 Alpine C i 13,492.053 55.00 193.12 7,412.900 -10,495.53 -2,446.52 Alpine A 13,544.357 55.00 193.12 7,442.900 -10,537.26 -2,456.25 Base Alpine 4/26/2005 4:16:36PM Page 7 of 7 COMPASS 2003.11 Build 50 ~~'~ ~' ~~' ` 9i1~ ~~ ~ ~~ ConocoPhillips Alaska Inc~,~h: ~ ~.. ry :; ~~~~ .., Colville River Unit ~ - ~- -t~ Alpine CD2 Plan: CD2-60 Plan: CD2-60PB1 CD2-60PB1wp04 Anticollision Report 26 April, 2005 Spelrlr~ drilling ~~r~rices ~.$ ~, =.vnc[31usIC1N seTTiwcs ~y~~~~~~~~~ Mterpofati Method-. MD IMerva1:255tations G 1 1 t MeN a M m mC rva[ure.. (may 0 { d :;^ Ftom: 37.000 To 13605.371 Error Model fSCWSA M RanOe~ .5000 502 Methoo +'~tnd Norm Ertnr Surtace. EII pt wl Con¢ ' - R^(ws~_e Wvll: PI+rt: C^2-°_ORC;'xp0$ Werri~~~g ~1a;}oL: Rules liasod ~AL.L'BUp~ON C[RVEY pKIH:R.n\I Spspry Drilllog Ssrvicss I,b ~: zoos-a-z6TOe:ee:oo YmW, i YM cv~t,~s. Nl.on,l DrPln rr„o, Dehm r„ ~r,ermlan Tvm 37.IMMI 91111.IIIH1 ('D?-MIPBIwpO1C[f-[;5R(?-SS "`""" 900.OIIU 1]605377 fDtfioPBlwp04MWD}IFR-AK-CAZ3C Critical Issues: =i- 1 Trsv~e€ting Cylinder ArSnmtk (CF{)+A7.,t1 I'i v,l Cend'e io Centre Se~paratlon ($ ftfiu~ w-. ca ca c:-~ a, ..+v 8EC210N DETA115 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFett ~bc 'E`+Y~1 1 37.000 0.000 0.0000 37.000 0.000 0.000 0.00 0A000 O:M01 z zao.ooe o.ooo o.ooo0 2ao.ooo o.aoe e.ooe o.oo e.oooo Bteue 3 2238.197 61.155 193.1214 1672.897 -962.854 -224.396 3.00 193.1211 9~V~.y 0. ~ ~ 4 12200.000 61.155 193.1214 6678.742 -9460.401 -2205.229 0.00 0.0000 946P401 5 12353.875 55.000 193.]214 6760.068 -9587.533 -223d.864 4.00 ]88.00110 9561.533 6 13605J77 55.000 193.1214 7477.900 -10585.938 -2467.593 0.00 0.0000 10585.938 { C: :~ air ~~ '~, . @ »rc .ysra4 q~~ ~5 'PM `~ ~ Sperry Drilling Services C31""tC3+~!C~~'1~ ~ r-r~-Lrrrl~uRT® Anticollision Report Sperry Drilling Services Company: ConocoPhillips Alaska Inc. Local Co-ordinate Reference: Well Plan: CD2-60 Project: Colville River Unit ND Reference; CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) Refareroce Site: Alpine CD2 MD Reference: CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) Site Error: O.000ft North Reference: True Reference Well: Plan: CD2=60 Survey Calculation Method: Minimum Curvature Well Error: O.000ft Output errors are at 1.00 sigma Reference Wellbore Plan: CD2-60P81 Database: EDM 2003.11 Single User Db nn,a, u,it.c uaaiyr~ ....~ .. ~+..~ v„x~ , vu no,si ae, ~.c. _. •....,. ._......... --~ ~ v..w A p d Reference CD2-60PB1wp04 ~"-~ ~~~g ~ ~ ~• ° ' `' ~ u Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria ~ p g~ ~ ~ ~ Error Model: ISCWSA Interpolation Method MD Interval 25.OOOft "" ~ L~¢ Depth Range: Unlimited Scan Method: Trav. Cylin r North ~~ _~^~" Results limited by: Maximum center-center distance of 5,OOO.OOOft Error Surtace: Elliptical C ~~t"u ~ - -- Warning Levels evaluated at: 0.00 Sigma y?',:;._;, Survey Tool Program Date 4,26/2005 From To (ftl (ft) Survey (Wellbore) Tool Name Description 37.000 900.000 CD2-60P61wp04 (Plan: CD2-60P61) CB-GYRO-SS Camera based gyro single shot , 900.000 13,605.377 CD2-60PB1wp04 (Plan: CD2-60PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measure _ Centre Distance Deviation Warning Site Name Depth d Distance (ft} from Plan Offset Well -Wellbore -Design Iftl (ft) Iftl Alpine :;D2 CD2-36 - CD 2-36 - CD 2-36 267.621 275.000 241.656 5.65 236.010 Pass -Major Risk CD2-36 -CD2-36 P81 -CD2-36 P61 267.621 275.000 241.656 5.65 236.010 Pass -Major Risk CD2-37 -CD2-37 -CD2-37 245.277 250.000 230.010 4.52 225.489 Pass -Major Risk CD2-38 -CD2-38 -CD2-38 245.477 250.000 220.285 4.93 215.356 Pass -Major Risk CD2-38 -CD2-38 (Sag) -CD2-38 (Sag) 245.477 250.000 220.285 4.46 215.828 Pass -Major Risk CD2-39 -CD2-39 -CD2-39 291.398 300.000 210.112 5.29 204.835 Pass -Major Risk CD2-39 -CD2-39P61 -CD2-39PB1 290.584 300.000 210.096 5.39 204.725 Pass -Major Risk CD2-40 -CD2-40 - CD2-40 245.984 250.000 199.996 5.18 194.819 Pass -Major Risk CD2-40 -CD2-40P81 -CD2-40PB1 245.984 250.000 199.996 5.18 194.819 Pass -Major Risk CD2-41 - CD2-41 - CD2-41 246.348 250.000 188.576 5.15 183.425 Pass -Major Risk CD2-42 -CD2-42 -CD2-42 246.709 250.000 180.570 4.42 176.146 Pass -Major Risk CD2-42 -CD2-42PB1 -CD2-42PB1 246.709 250.000 180.570 4.53 176.037 Pass -Major Risk CD2-43 -CD2-43 -CD2-43 223.114 225.000 170.520 4.66 165.862 Pass -Major Risk CD2-43 -CD2-43PB1 -CD2-43PB1 223.114 225.000 170.520 4.66 165.862 Pass -Major Risk CD2-44 -CD2-44 - CD2-44 246.714 250.000 160.505 5.20 155.305 Pass -Major Risk CD2-45 -CD2-45 -CD2-45 223.457 225.000 151.053 4.11 146.938 Pass -Major Risk CD2-46 -CD2-46 -CD2-46 247.052 250.000 140.238 4.54 135.695 Pass -Major Risk CD2-47 - CD2-47 -CD2-47 247.275 250.000 130.424 4.56 125.867 Pass -Major Risk CD2-48 -CD2-48 - CD2-48 247.816 250.000 120.573 5.09 115.481 Pass -Major Risk CD2-49 -CD2-49 -CD2-49 271.354 275.000 110.014 5.16 104.859 Pass -Major Risk CD2-50 -CD2-50 -CD2-50 224.274 225.000 100.373 4.46 95.910 Pass -Major Risk CD`?-50 -CD2-50PB1 -CD2-50PB1 224.274 225.000 100.373 4.57 95.800 Pass -Major Risk CD2-51 -CD2-51 -CD2-51 224.877 225.000 90.860 4.71 86.153 Pass -Major Risk CD2-52 -CD2-52 -CD2-52 320.654 325.000 80.426 6.71 73.720 Pass -Major Risk CD2-53 -CD2-53 -CD2-53 248.852 250.000 70.961 5.17 65.794 Pass -Major Risk CD2-54 -CD2-54 -CD2-54 273.468 275.000 58.358 5.75 52.605 Pass -Major Risk CD2-54 -CD2-54L1 -CD2-54L1 273.468 275.000 58.358 5.75 52.605 Pass -Major Risk CD2-55 -CD2-55 -CD2-55 273.713 275.000 49.509 2.95 46.560 Pass -Minor 1/200 CD2-56 -CD2-56 -CD2-56 397.236 400.000 32.466 8.52 23.978 Pass -Major Risk CD2-56 -CD2-56L1 -CD2-56L1 397.236 400.000 32.466 8.52 23.978 Pass -Major Risk CD2-57 - C02-57 -CD2-57 470.990 475.000 27.323 10.14 17.289 Pass -Major Risk CD2-58 -CD2-58 -CD2-58 472.698 475.000 18.704 8.94 9.890 Pass -Major Risk CD2-58 -CD2-58L1 -CD2-58L1 472.698 475.000 18.704 8.94 9.890 Pass -Major Risk Plan: CD2-59 -Plan: CD2-59 -CD2-59 Rig Surveys 274.740 275.000 8.880 5.52 3.362 Pass -Major Risk Plan: CD2-59 -Plan: CD2-59 -CD2-59wp03 274.736 275.000 8.456 5.77 2.690 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/26/2005 3:45:05PM Page 2 of 3 COMPASS 2003.11 Build 50 ~~~ ~-, ConocoPhillips ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-60 Plan: CD2-60 .. Proposal Report 27 April, 2005 w~~~ ~, ~~,P~ 2005 ~~~rlr~r [~rilling Selr~rice ORIGINAL aNt4o7anoNs r..~~~~~~~~ ~~ .. calcuwum Mee,°d: 94unm°m curvaNre Ertorsrsmm Iscwsn scan Medroe' irav. Cylinder Norm Ert°r Surface' EIIiPtipl Conc wam~n9 Me9ad: Rules awed Geodetk DaWm: NAO 7927 ((NADCON cONU5) MaPrieBC Model: 8GGM2o04 Pro ect: Colville River Unit ~ Site: Alpine CD2 Well: Plan: CD2~0 Wellbore: Plan: CD2~0 ND MD Mnotation 6730A03 12300.000 Tien Poinf43egin Dir-4A0°DLS, 12300.000 ft MD, 6730.003 ft ND 6819.918 12480254 Cordinue Dir, 3.65°DLS, 37.1386°TFO, 12480254'MD, 6819.918'7VD 7383.956 14155.000 T' Csg Pt • 14155.OOOft MD, 7393.956 RND; 2795 FNL & 372T FEL; Sec14T11N4204E 7397900 14275.323 Target (fieef); 14275,323' MD, 7397900' ND 740423515000A00 Potential (<157 fault, lsooo'MD 7407 731 15400.000 Potential 1c15 faun 15400' MD ~~~~~~~~~0~ Sperry Drilling Services Gmamld lsvs3; a5.9tk1 RKH: G372~&0 sn 52.9008 (~D2•fi(7 P?ig (75.9+3-;? fdortltirxr}'ASP Y: 93T4194.4iT%# ~~~~'''~~ 37a743.7740 Plan: CD2$Ovop04 , . 7412347 16500.000 PolenRal (r15'J fault, lrSUO'MD 7426066 17500.000 Potential (<15~ fault, 17500' MD 7432900 18279261 Target (Tce)-18279.263 ft MD, 7432900 R TVD; 1095ft FNL 8 76848 FEL, Sec23-T11N~t04E sEC7foN oerats Sec MD krc Azi ND +NIS +EI-W DLeg TFace VSec Target -2000 t 12100.000 57.157 193.1214 6730A03 41543998 ,22714.716 0.00 0.0000 9543998 2 1298tA~r4 63.000 198.OOOD 6819918 43894.9'13 .2266.776 400 37.1386 9894313 3 12866117 57.300 2(R~'15 6613919 &B47941 ,2374244 365 14674411 9647941 4 14275321 89.489 1502096 7397900.11298A51 ,2189962 365 57.7789 11296.451 l'D~+°p04 Heel 5 18279.264 89A9B 1501098 743290D -14773141 "179B80 0.0D 0.0000 147731M (X12EOwP04Tce cnslNC oETats No TVO 9D Name 91ze 1 2390.000 3310.343 9 5/8" 95/8 2 8730.003 12300.000 7" ] 3 7393.956 14155.000 7" l 4 ]432.900 f8099I2pM Hob 4-tYl 2600 - I ,,~~. = ..,,.__, . . .. ~.... ~ ._ ..,,_. _ _~, ...~._. =o ~ e o `l, t a `" ~"~y. 4000 m ' Tie-in PointBegin Dir - 4.00°DLS,12300.000 ft MD, 6730.003 ft TVD - u ~ Continue Dir; 3.65° DLS, 37.1386° TF0,12480.254' MD, 6819.918' ND 7 ` Potential (<15') fault, 15000' MD €i~ 1 - __ _ ...... __....__. _ _ . __.._ _ _ _ _ r.~ Po fault, 5400 MD tential (<15~ 1 ' Base HRZ ~ ~ ~ Potential (<15') t u 1650 uMD .. soon HRZ . _ K-1 Marker - , r a ( _ 7 ' MD_'~' Potent I <15 f I~ SQQ Kupan~c Fm O ~ E`,'3 ~ " _ ~ ~. " ~ ____ ~„"___ . LCUa4lilweach .__ .,~"_W _ _ __ _. _.... ..m_..... ' ~ m - ~ Milweach A ',. s `~~ 1 ine D Al i'1a13: Ci~2-GOi~B1wp04 ' -' s ~ c' _ p ~ o i P aooo ~ ' - Alpine C FEL; Sec14-711 N-R 7" Csg Pt -14155.000k MD, 7393.956 ft ND; 2795' F L & 3727 Plan. CD2 wp04 61/8" Op~l'Hole Target (Hee(l); 14275.323' MD, 7397.900' ND ~` ( ~ ~ Target (Tce)-18279.263 ft MD, 7432.900 ft ND;1095ft FNL & 1684ft FEL, Sec23-711 N-R04E ~ 0 2000 4000 soon 6000 taooo 12000 14000 t6ooo Vertical Section at 180.00° (2000 ftlin) ~, Sperry Drilling Services HAL LIBt1FITt~f " ' . ~ ~~ ~ ~ ~~ ~ Pla nning Report -Geograp hic n~~ervFces . ,q ~; Database: EDM 2003.11 Sing le User Db Lo cal Co-ordinate Reference: Well Plan; CD2-60 ~ Company: ConocoPhillips Ala ska Inc. N D Reference: CD2-60 @ 52. fQig ( 900ft (CD2'-Bt ~b.3~~ U ~? Project: Colvi lle River Unit. MD Reference: CD2-60 @ 52.900ft (CD2-60 Rig ( 15.9+37)) Site: Alpin e CD2 No rth Reference: True ~~c~a~~r ~;~ e~ ~ ~ ~'~ f t. ~ rr Well: Plan: CD2-60 Su rvey Calculation Method: Minimum Curvature ~ i "` "' Wellbore: Plan: CD2-60PB1 f ~ " r° u~' Design: CD2- 60PB1wp04 Planned Survey CD2-60PB1 wp04 Map Map MU Inclination Azimuth ND SSND +N/-S +EI-W °Northing Fasting DLSEV Vert Section (ftl {°) (°) (ft) (ft) (ft) (ft) Ift) (ft) (°/100ft) (ft) 37.000 0.000 0.0000 37.000 -15.90 0.000 0.000 5,974,194.4700 ` 371,743.7700 ' 0.00 0.00 SHL -- 2162ft FNL & 1491ftFEL; Sec02-T11N-R04E 100.000 0.000 0.0000 100.000 47.10 0.000 0.000 5,974,194.4700 371,743.7700 0.00 0.00 200.000 0.000 0.0000 200.000 147.10 0.000 0.000 5,974,194.4700 371,743.7700 0.00 0.00 ' Begin Dir -- 3. 00°DLS, 200 .000 ft MD, 200.000 ft ND 300.000 3.000 193.1214 299.954 247.05 -2.549 -0.594 5,974,191.9317 371,743.1324 3.00 2.55 i 400.000 6.000 193.1214 399.635 346.73 -10.189 -2.375 5,974,184.3237 371,741.2211 3.00 10.19 ~ 500.000 9.000 193.1214 498.768 445.87 -22.900 -5.338 5,974,171.6668 371,738.0416 3.00 22.0 600.000 12.000 193.1214 597.082 544.18 -40.645 -9.474 5,974,153.9959 371,733.6025 3.00 40.65 700.000 15.000 193.1214 694.308 641.41 -63.378 -14.773 5,974,131.3592 371,727.9160 3.00 63.38 800.000 18.000 193.1214 790.179 737.28 -91.035 -21.220 5,974,103.8189 371,720.9976 3.00 91.03 i i 900.000 21.000 193.1214 884.432 831.53 -123.540 -28.797 5,974,071.4504 371,712.8663 3.00 123.54 i 1,000.000 24.000 193.1214 976.810 923.91 -160.805 -37.484 5,974,034.3424 371,703.5445 3.00 160.81 1,100.000 27.000 193.1214 1,067.058 1,014.16 -202.728 -47.256 5,973,992.5967 371,693.0576 3.00 202.73 ~, 1,200.000 30.000 193.1214 1,154.930 1,102.03 -249.192 -58.087 5,973,946.3277 371,681.4343 3.00 249.19 ~ 1,31)0.000 33.000 193.1214 1,240.184 1,187.28 -300.072 -69.947 5,973,895.6622 371,668.7067 3.00 3D0.07 i j 1,400.000 36.000 193.1214 1,322.587 1,269.69 -355.228 -82.804 5,973,840.7390 371,654.9095 3.00 355.23 ~ 1,500.000 39.000 193.1214 1,401.913 1,349.01 -414.508 -96.622 5,973,781.7088 371,640.0806 3.00 414.51 1,600.000 42.000 193.1214 1,477.945 1,425.04 -477.750 -111.364 5,973,718.7333 371,624.2605 3.00 477.75 1,700.000 45.000 193.1214 1,550.474 1,497.57 -544.781 -126.989 5,973,651.9851 371,607.4928 3.00 544.78 i 1,600.000 48.000 193.1214 1,619.302 1,566.40 -615.416 -143.454 5,973,581.6472 371,589.8232 3.00 615.42 1,900.000 51.000 193.1214 1,684.239 1,631.34 -689.463 -160.715 5,973,507.9124 371,571.3003 3.00 689.46 2,000.000 54.000 193.1214 1,745.108 1,692.21 -766.718 -178.723 5,973,430.9827 371,551.9749 3.00 766.72 2,100.000 57,000 193.1214 1,801.742 1,748.84 -846.970 -197.430 5,973,351.0691 371,531.8999 3.00 846.97 i 2,200.000 60.000 193.1214 1,853.986 1,801.09 -929.999 -216.784 5,973,268.3905 371,511.1302 3.00 930.00 i 2,238.497 61.155 193.1214 1,872.897 1,820.00 -962.654 -224.396 5,973,235.8724 371,502.9614 3.00 962.65 Start Sail--61.155° , 2238.497 ft MD, 187 2.897 ft ND ; 2,300.000 61.155 193.1214 1,902.568 1,849.67 -1,015.120 -236.626 5,973,183.6279 371,489.8371 0.00 1,015.12 2,400.000 61.155 193.1214 1,950.813 1,897.91 -1,100.426 -256.510 5,973,098.6815 371,468.4978 0.00 1,100.43 2,500.000 61.155 193.1214 1,999.057 1,946.16 -1,185.732 -276.395 5,973,013.7351 371,447.1584 0.00 1,185.73 ~l li 2,600.000 61.155 193.1214 2,047.301 1,994.40 -1,271.038 -296.280 5,972,928.7888 371,425.8191 0.00 1,271.04 i 2,700.000 61.155 193.1214 2,095.545 2,042.65 -1,356.344 -316.165 5,972,843.8424 371,404.4798 0.00 1,356.34 i 2,800.000 61.155 193.1214 2,143.789 2,090.89 -1,441.649 -336.050 5,972,758.8960 371,383.1405 0.00 1,441.65 2,900.000 1 61.155 193.1214 2,192.034 2,139.13 -1,526.955 -355.935 5,972,673.9497 371,361.8012 0.00 1,526.96 ~ 2,928.742 61.155 193.1214 2,205.900 2,153.00 -1,551.474 -361.650 5,972,649.5342 371,355.6678 0.00 1,551.47 C-40 I 3,000.000 61.155 193.1214 2,240.278 2,187.38 -1,612.261 -375.820 5,972,589.0033 371,340.4619 0.00 1,612.26 ~ 3,100.000 61.155 193.1214 2,288.522 2,235.62 -1,697.567 -395.705 5,972,504.0569 371,319.1225 0.00 1,697.57 3,X0.000 61.155 193.1214 2,336.766 2,283.87 -1,782.873 -415.590 5,972,419.1106 371,297.7832 0.00 1,782.87 3,300.000 61.155 193.1214 2,385.010 2,332.11 -1,868.179 -435.474 5,972,334.1642 371,276.4439 0.00 1,868.18 ~ ~~ 3,310.343 61.155 193.1214 2,390.000 2,337.10 -1,877.002 -437.531 5,972,325.3785 371,274.2369 0.00 1,877.00 it 9-5/8" Csg Pt: 3310.343 ft MD, 2390.000 ft ND - 9 5/8" 3,353.664 61.155 193.1214 2,410.900 2,358.00 -1,913.957 -446.145 5,972,288.5786 371,264.9924 0.00 1,913.96 C-30 i 3,400.000 61.155 193.1214 2,433.254 2,380.35 -1,953.485 -455.359 5,972,249.2178 371,255.1046 0.00 1,953.48 i 3,500.000 61.155 193.1214 2,481.499 2,428.60 -2,038.790 -475.244 5,972,164.2715 371,233.7653 0.00 2,038.79 3,600.000 61.155 193.1214 2,529.743 2,476.84 -2,124.096 -495.129 5,972,079.3251 371,212.4260 0.00 2,124.10 4/26/2005 4:16:36PM .Page 3 of 7 COMPASS 2003.11 Build 50 "" Sperry Drilling Services ALL11~tt ~1RTCt ~ ~ . ~~ ~~~~~~~ Planning Report -Geographic Sperry Drilling Services $ ~ ~ ~ ~~ + n Yom" Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: . C -60 We ia ~-- Company: ConocoPhillips Alaska Inc. ND References C~ ~.gep~Oft~ 60 Rig (15.9+37)) ~ ~~ Project: Colville River Unit MD Reference: CD2- ~2.~900ff- 60 Rig (15.9+37)) E Site: Alpine CD2 North Reference: True Well: Plan: CD2-60 Survey Calculation Method: ~~~~s~ i~{~ir~urh~yr~~tnu~ t~;r $:!ivi, Wellbore: Plan: CD2-60P61 ~,~„r,~,..r. `~ " "" '~ Design: CD2-60PB1wp04 ' " "a Planned Survey CD2-60P81wp04 MD Inclination Azimuth tft: l°) l°) 3,700.000 61.155 193.1214 3,800.000 61.155 193.1214 3,900.000 61.155 193.1214 4,000.000 61.155 193.1214 4,100.000 61.155 193.1214 4,124.741 61.155 193.1214 C-20 4,200.000 61.155 4,300.000 61.155 4,400.000 61.155 4,500.000 61.155 4,600.000 61.155 4,700.000 61.155 4,81)0.000 61.155 4,900.000 61.155 5,000.000 61.155 5,100.000 61.155 5,200.000 61.155 5,300.000 61.155 5,4C0.000 61.155 5,500.000 61.155 5,60D.000 61.155 5,700.000 61.155 5,800.000 61.155 5,900.000 61.155 6,000.000 61.155 6,100.000 61.155 6,200.000 61.155 6,300.000 61.155 6,313.607 61.155 K-3 Marker 6,400.000 61.155 6,500.000 61.155 6,600.000 61.155 6,700.000 61.155 6,732.310 61.155 Basal K-3 Sand 6,796.566 61.155 K-2 Marker 6,8G!0.000 61.155 6,940.000 61.155 6,991.409 61.155 Base K-2 Cycfe 7,000.000 61.155 7,100.000 61.155 7,200.000 61.155 7,300.000 61.155 7,400.000 61.155 Map Map ND SSTVD +N/-S +F/-W Northing Fasting DLSEV Vert Section Ift) (ft) 1ftl (ft) tft) lft) (°/100ft) (ft) 2,577.987 2,525.09 -2,209.402 -515.014 5,971,994.3787 371,191.0866 0.00 2,209.40 2,626.231 2,573.33 -2,294.708 -534.899 5,971,909.4324 371,169.7473 0.00 2,294.71 2,674.475 2,621.58 -2,380.014 -554.784 5,971,824.4860 371,148.4080 0.00 2,380.01 2,722.720 2,669.82 -2,465.320 -574.669 5,971,739.5396 371,127.0687 0.00 2,465.32 2,770.964 2,718.06 -2,550.626 -594.554 5,971,654.5933 371,105.7294 0.00 2,550.63 2,782.900 2,730.00 -2,571.732 -599.473 5,971,633.5763 371,100.4497 0.00 2,571.73 193.1214 2,819.208 2,766.31 -2,635.932 -614.438 5,971,569.6469 371,084.3901 0.00 2,635.93 193.1214 2,867.452 2,814.55 -2,721.237 -634.323 5,971,484.7005 371,063.0507 0.00 2,721.24 193.1214 2,915.696 2,862.80 -2,806.543 -654.208 5,971,399.7542 371,041.7114 0.00 2,806.54 193.1214 2,963.940 2,911.04 -2,891.849 -674.093 5,971,314.8078 371,020.3721 0.00 2,891.85 193.1214 3,012.185 2,959.28 -2,977.155 -693.978 5,971,229.8614 370,999.0328 0.00 2,977.15 193.1214 3,060.429 3,007.53 -3,062.461 -713.863 5,971,144.9151 370,977.6935 0.00 3,062.46 193.1214 3,108.673 3,055.77 -3,147.767 -733.748 5,971,059.9687 370,956.3542 0.00 3,147.77 193.1214 3,156.917 3,104.02 -3,233.073 -753.633 5,970,975.0223 370,935.0149 0.00 3,233.07 193.1214 3,205.161 3,152.26 -3,318.378 -773.518 5,970,890.0760 370,913.6755 0.00 3,318.38 193.1214 3,253.405 3,200.51 -3,403.684 -793.402 5,970,805.1296 370,892.3362 0.00 3,403.68 193.1214 3,301.650 3,248.75 -3,488.990 -813.287 5,970,720.1833 370,870.9969 0.00 3,488.99 193.1214 3,349.894 3,296.99 -3,574.296 -833.172 5,970,635.2369 370,849.6576 0.00 3,574.30 193.1214 3,398.138 3,345.24 -3,659.602 -853.057 5,970,550.2905 370,828.3183 0.00 3,659.60 193.1214 3,446.382 3,393.48 -3,744.908 -872.942 5,970,465.3442 370,806.9790 0.00 3,744.91 193.1214 3,494.626 3,441.73 -3,830.214 -892.827 5,970,380.3978 370,785.6396 0.00 3,830.21 193.1214 3,542.871 3,489.97 -3,915.520 -912.712 5,970,295.4514 370,764.3003 0.00 3,915.52 193.1214 3,591.115 3,538.21 -4,000.825 -932.597 5,970,210.5051 370,742.9610 0.00 4,000.83 193.1214 3,639.359 3,586.46 -4,086.131 -952.481 5,970,125.5587 370,721.6217 0.00 4,086.13 193.1214 3,687.603 3,634.70 -4,171.437 -972.366 5,970,040.6123 370,700.2824 0.00 4,171.44 193.1214 3,735.847 3,682.95 -4,256.743 -992.251 5,969,955.6660 370,678.9431 0.00 4,256.74 193.1214 3,784.091 3,731.19 -4,342.049 -1,012.136 5,969,870.7196 370,657.6037 0.00 4,342.05 193.1214 3,832.336 3,779.44 -4,427.355 -1,032.021 5,969,785.7732 370,636.2644 0.00 4,427.35 193.1214 3,838.900 3,786.00 -4,438.962 -1,034.727 5,969,774.2149 370,633.3609 0.00 4,438.96 193.1214 3,880.580 3,827.68 -4,512.661 -1,051.906 5,969,700.8269 370,614.9251 0.00 4,512.66 193.1214 3,928.824 3,875.92 -4,597.966 -1,071.791 5,969,615.8805 370,593.5858 0.00 4,597.97 193.1214 3,977.068 3,924.17 -4,683.272 -1,091.676 5,969,530.9341 370,572.2465 0.00 4,683.27 193.1214 4,025.312 3,972.41 -4,768.578 -1,111.561 5,969,445.9878 370,550.9072 0.00 4,768.58 193.1214 4,040.900 3,988.00 -4,796.141 -1,117.985 5,969,418.5416 370,544.0124 0.00 4,796.14 193.1214 4,071.900 4,019.00 -4,850.955 -1,130.763 5,969,363.9580 370,530.3005 0.00 4,850.96 193.1214 4,073.556 4,020.66 -4,853.884 -1,131.445 5,969,361.0414 370,529.5678 0.00 4,853.88 193.1214 4,121.801 4,068.90 -4,939.190 -1,151.330 5,969,276.0950 370,508.2285 0.00 4,939.19 193.1214 4,165.900 4,113.00 -5,017.167 -1,169.507 5,969,198.4467 370,488.7226 0.00 5,017.17 193.1214 4,170.045 4,117.14 -5,024.496 -1,171.215 5,969,191.1487 370,466.8892 0.00 5,024.50 193.1214 4,218.289 4,165.39 -5,109.802 -1,191.100 5,969,106.2023 370,465.5499 0.00 5,109.80 193.1214 4,266.533 4,213.63 -5,195.107 -1,210.985 5,969,021.2559 370,444.2106 0.00 5,195.11 193.1214 4,314.777 4,261.88 -5,280.413 -1,230.870 5,968,936.3096 370,422.8713 0.00 5,280.41 193.1214 4,363.022 4,310.12 -5,365.719 -1,250.755 5,968,851.3632 370,401.5320 0.00 5,365.72 4/26/2005 4:16:36PM Page 4 of 7 COMPASS 2003.11 Build 50 ORIGINAL Sperry Drilling Services 1RT09N IE3t .. ~~ Q ~~ ~ Planning Report -Geographic ~~+ (~ ~ r~ Drillin Services ~ r ry 9 Database: EDM 2003.11 SingleUser Db .- Lo ..- cal Co-ordinate Reference: ~~~5 ~i_.,~ I ~arY'G~PI~~$6' aii~. -~-0 •.~ :~;.~tiUJ; Company: ConocoPhillips Ala ska lnc. N D Reference: CD2-60 @~~®-60 Rig (15.9+37)) Project: Colvi lle River Unit MD Reference: CD2-60 @ 52.900ft (C'~2-60 Rig (15.9+37)) Site: Alpin e CD2 No rth Reference; True Well: Plan : CD2-60 Su rvey Calculatio n Method: Minimum C urvature Wellbore: Plan : CD2-60PB1 Design: CD2 -60PB1wp04 Planned Survey CD2-60P81wp04 Map Map MD Inclination Azimuth TVD SSND +N/-S +E/-W Northing Easting DLSEV Vert Section Ift) (`) (~) (ft) (ft) (ft) (ft) (~) (ft) (°/100ft) (ft) ' 7,500.000 61.155 193.1214 4,411.266 4,358.37 -5,451.025 -1,270.640 5,968,766.4168 370,380.1926 0.00 5,451.03 I 7,600.000 61.155 193.1214 4,459.510 4,406.61 -5,536.331 -1,290.525 5,968,681.4705 370,358.8533 0.00 5,536.33 7,70(1.000 61.155 193.1214 4,507.754 4,454.85 -5,621.637 -1,310.409 5,968,596.5241 370,337.5140 0.00 5,621.64 7,800.000 61.155 193.1214 4,555.998 4,503.10 -5,706.943 -1,330.294 5,968,511.5777 370,316.1747 0.00 5,706.94 7,900.000 61.155 193.1214 4,604.242 4,551.34 -5,792.249 -1,350.179 5,968,426.6314 370,294.8354 0.00 5,792.25 8,000.000 61.155 193.1214 4,652.487 4,599.59 -5,877.554 -1,370.064 5,968,341.6850 370,273.4961 0.00 5,877.55 8,100.000 61.155 193.1214 4,700.731 4,647.83 -5,962.860 -1,389.949 5,968,256.7386 370,252.1567 0.00 5,962.86 8,200.000 61.155 193.1214 4,748.975 4,696.07 -6,048.166 -1,409.834 5,968,171.7923 370,230.8174 0.00 6,045.17 8,300.000 61.155 193.1214 4,797.219 4,744.32 -6,133.472 -1,429.719 5,968,086.8459 370,209.4781 0.00 6,133.47 8,400.000 61.155 193.1214 4,845.463 4,792.56 -6,218.778 -1,449.604 5,968,001.8995 370,188.1388 0.00 6,218.78 8,500.000 61.155 193.1214 4,893.707 4,840.81 -6,304.084 -1,469.489 5,967,916.9532 370,166.7995 0.00 6,304.08 8,600.000 61.155 193.1214 4,941.952 4,889.05 -6,389.390 -1,489.373 5,967,832.0068 370,145.4602 0.00 6,389.39 8,700.000 61.155 193.1214 4,990.196 4,937.30 -6,474.695 -1,509.258 5,967,747.0604 370,124.1208 0.00 6,474.70 8,800.000 61.155 193.1214 5,038.440 4,985.54 -6,560.001 -1,529.143 5,967,662.1141 370,102.7815 0.00 6,560.00 8,900.000 61.155 193.1214 5,086.684 5,033.78 -6,645.307 -1,549.028 5,967,577.1677 370,081.4422 0.00 6,645.31 9,000.000 61.155 193.1214 5,134.928 5,082.03 -6,730.613 -1,568.913 5,967,492.2213 370,060.1029 0.00 6,730.61 9,100.000 61.155 193.1214 5,183.173 5,130.27 -6,815.919 -1,588.798 5,967,407.2750 370,038.7636 0.00 6,815.92 9,200.000 61.155 193.1214 5,231.417 5,178.52 -6,901.225 -1,608.683 5,967,322.3286 370,017.4243 0.00 6,901.22 9,300.000 61.155 193.1214 5,279.661 5,226.76 -6,986.531 -1,628.568 5,967,237.3823 369,996.0850 0.00 6,986.53 9,400.000 61.155 193.1214 5,327.905 5,275.01 -7,071.837 -1,648.453 5,967,152.4359 369,974.7456 0.00 7,071.84 9,500.000 61.155 193.1214 5,376.149 5,323.25 -7,157.142 -1,668.337 5,967,067.4895 369,953.4063 0.00 7,157.14 9,600.000 61.155 193.1214 5,424.393 5,371.49 -7,242.448 -1,688.222 5,966,982.5432 369,932.0670 0.00 7,242.45 9,700.000 61.155 193.1214 5,472.638 5,419.74 -7,327.754 -1,708.107 5,966,897.5968 369,910.7277 0.00 7,327.75 9,80(1.000 61.155 193.1214 5,520.882 5,467.98 -7,413.060 -1,727.992 5,966,812.6504 369,889.3884 0.00 7,413.06 9,900.000 61.155 193.1214 5,569.126 5,516.23 -7,498.366 -1,747.877 5,966,727.7041 369,868.0491 0.00 7,498.37 j 9,918.187 61.155 193.1214 5,577.900 5,525.00 -7,513.880 -1,751.493 5,966,712.2551 369,864.1681 0.00 7,513.88 Albian 97 10,000.000 61.155 193.1214 5,617.370 5,564.47 -7,583.672 -1,767.762 5,966,642.7577 369,846.7097 0.00 7,583.67 10,100.000 61.155 193.1214 5,665.614 5,612.71 -7,668.978 -1,787.647 5,966,557.8113 369,825.3704 0.00 7,668.98 i 10,200.000 61.155 193.1214 5,713.859 5,660.96 -7,754.283 -1,807.532 5,966,472.8650 369,804.0311 0.00 7,754.28 10,300.000 61.155 193.1214 5,762.103 5,709.20 -7,839.589 -1,827.417 5,966,387.9186 369,782.6918 0.00 7,839.59 10,400.000 61.155 193.1214 5,810.347 5,757.45 -7,924.895 -1,847.301 5,966,302.9722 369,761.3525 0.00 7,924.90 10,500.000 61.155 193.1214 8,858.591 5,805.69 -8,010.201 -1,867.186 5,966,218.0259 369,740.0132 0.00 8,010.20 10,600.000 61.155 193.1214 5,906.835 5,853.94 -8,095.507 -1,887.071 5,966,133.0795 369,718.6738 0.00 8,095.51 10,700.000 61.155 193.1214 5,955.079 5,902.18 -8,180.813 -1,906.956 5,966,048.1331 369,697.3345 0.00 8,180.81 10,800.000 61.155 193.1214 6,003.324 5,950.42 -8,266.119 -1,926.841 5,965,963.1868 369,675.9952 0.00 8,266.12 i 10,900.000 61.155 193.1214 6,051.568 5,998.67 -8,351.424 -1,946.726 5,965,878.2404 369,654.6559 0.00 8,351.42 10,944.217 61.155 193.1214 6,072.900 6,020.00 -8,389.144 -1,955.518 5,965,840.6795 369,645.2202 0.00. 8,389.14 Albian 96 11,000.000. 61.155 193.1214 6,099.812 6,046.91 -8,436.730 -1,966.611 5,965,793.2940 369,633.3166 0.00 8,436.73 i 11,100.000 61.155 193.1214 6,148.056 6,095.16 -8,522.036 -1,986.496 5,965,708.3477 369,611.9773 0.00 8,522.04 11,200.000 61.155 193.1214 6,196.300 6,143.40 -8,607.342 -2,006.380 5,965,623.4013 369,590.6379 0.00 8,607.34 11,300.000 61.155 193.1214 6,244.544 6,191.64 -8,692.648 -2,026.265 5,965,538.4549 369,569.2986 0.00 8,692.65 11,400.000 61.155 193.1214 6,292.789 6,239.89 -8,777.954 -2,046.150 5,965,453.5086 369,547.9593 0.00 8,777.95 11,500.000 61.155 193.1214 6,341.033 6,288.13 -8,863.260 -2,066.035 5,965,368.5622 369,526.6200 0.00 8,863.26 11,600.000 61.155 193.1214 6,389.277 6,336.38 -8,948.566 -2,085.920 5,965,283.6158 369,505.2807 0.00 8,948.57 i 11,700.000 61.155 193.1214 6,437.521 6,384.62 -9,033.871 -2,105.805 5,965,198.6695 369,483.9414 0.00 9,033.87 11,800.000 61.155 193.1214 6,485.765 6,432.87 -9,119.177 -2,125.690 5,965,113.7231 369,462.6021 0.00 9,119.18 11,900.000 61.155 193.1214 6,534.010 6,481.11 -9,204.483 -2,145.575 5,965,028.7767 369,441.2627 0.00 9,204.48 j 4/26!2005 4:16:36PM Page 5 of 7 COMPASS 2003.11 Build 50 ORIGINAL ~ ~ q . Sperry Drilling Service '` ,~~.r. '~t`AL.L1E3l.tIr=1TClN ~~ ~~~~~~ Planning Report-Geographic ~~3 .;~. ~~ ~jr~ ,~~ ,, l.U;s Sperry Drilling Services ~~~ Database: EDM 2003.1 1 Single User Db F'181r G42~60 - _„ Local Co-ordinate Referer" Company: ConocoPhillips Alaska Inc. ND Reference: CD2~i6~ 52`90Aft (CD2-60 Rig (15.9+37)) Project: Colville River Unit MD Reference: CD2-60 @ 52.9bOft (CD2-60 Rig (15.9+37)) Site: Alpine CD2 North Reference: True Well: Plan: CD2-60 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2-60P61 Design: CD2-60PB1wp04 Planned Survey CD2-60PB1wp04 Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ftl (ftl (ft) (ft) (ft) (ft) (°/100ft) (ftl 12,000.000 61.155 193.1214 6,582.254 6,529.35 -9,289.789 -2,165.460 5,964,943.8304 369,419.9234 0.00 9,289.79 12,100.000 61.155 193.1214 6,630.498 6,577,60 -9,375.095 -2,185.344 5,964,858.8840 369,398.5841 0.00 9,375.09 12,200.000 61.155 193.1214 6,678.742 6,625.84 -9,460.401 -2,205.229 5,964,773.9376 369,377.2448 0.00 9,460.40 Begin Drop; 4.00° DLS, 180° TFO, 12200.000' MD, 6678 .742' ND 12,300.000 57.157 193.1214 6,730.003 6,677.10 -9,543.998 -2,224.716 5,964,690.6928 369,356.3329 4.00 9,544.00 7.. 12,353.875 55.000 193.1214 6,760.068 6,707.17 -9,587.533 -2,234.864 5,964,647.3409 369,345.4425 4.00 9,587.53 ~. Start Sail; 55.000° INC, 12 353.875' MD, 6760.068' ND i 12,400.000 55.000 193.1214 6,786.524 6,733.62 -9,624.330 -2,243.441 5,964,610.6990 369,336.2377 0.00 9,624.33 12,402.399 55.000 193.1214 6,787.900 6,735.00 -9,626.244 -2,243.888 5,964,608.7931 369,335.7590 0.00 9,626.24 i HRZ 12,507.000 55.000 193.1214 6,843.882 6,790.98 -9,704.107 -2,262.037 5,964,531.2587 369,316.2816 0.00 9,704.11 12,600.000 55.000 193.1214 6,901.239 6,848.34 -9,783.883 -2,280.633 5,964,451.8184 369,296.3255 0.00 9,783.88 12,700.000 55.000 193.1214 6,958.597 6,905.70 -9,863.660 -2,299.229 5,964,372.3781 369,276.3693 0.00 9,863.66 ~ 12,780.727 55.000 193.1214 7,004.900 6,952.00 -9,928.061 -2,314.241 5,964,308.2483 369,260.2593 0.00 9,928.06 i Base HRZ 11 12,800.000 55.000 193.1214 7,015.954 6,963.05 -9,943.436 -2,317.825 5,964,292.9378 369,256.4132 0.00 9,943.44 i 12,8ti7.899 55.000 193.1214 7,054.900 7,002.00 -9,997.604 -2,330.452 5,964,238.9983 369,242.8631 0.00 9,997.60 i K-1 Marker 12,900.000 55.000 193.1214 7,073.312 7,020.41 -10,023.213 -2,336.421 5,964,213.4975 369,236.4570 0.00 10,023.21 12,948.098 55.000 193.1214 7,100.900 7,048.00 -10,061.584 -2,345.366 5,964,175.2883 369,226.8585 0.00 10,061.58 Kuparuk Fm 13,000.000 55.000 193.1214 7,130.670 7,077.77 -10,102.989 -2,355.017 5,964,134.0572 369,216.5009 0.00 10,102.99 13,028.297 55.000 193.1214 7,146.900 7,094.00 -10,125.563 -2,360.279 5,964,111.5783 369,210.8540 0.00 10,125.56 LCU=Miluveach 13,100.000 55.000 193.1214 7,188.027 7,135.13 -10,182.766 -2,373.613 5,964,054.6169 369,196.5447 0.00 10,182.77 13,200.000 55.000 193.1214 7,245.385 7,192.49 -10,262.542 -2,392.209 5,963,975.1766 369,176.5886 0.00 10,262.54 13;300.000 55.000 193.1214 7,302.743 7,249.84 -10,342.319 -2,410.805 5,963,895.7363 369,156.6325 0.00 10,342.32 ~ 13,321.196 55.000 193.1214 7,314.900 7,262.00 -10,359.228 -2,414.747 5,963,878.8984 369,152.4026 0.00 10,359.23 Miluveach A 13,370.012 55.000 793.1214 7,342.900 7,290.00 -10,398.172 -2,423.825 5,963,840.1185 369,142.6607 0.00 10,398.17 Alpine D 13,400.000 55.000 193.1214 7,360.100 7,307.20 -10,422.095 -2,429.401 5,963,816.2960 369,136.6763 0.00 10,422.10 i 13,439.750 55.000 193.1214 7,382.900 7,330.00 -10,453.806 -2,436.793 5,963,784.7185 369,128.7437 0.00 10,453.81 Alpine C 13,492.053 55.000 193.1214 7,412.900 7,360.00 -10,495.532 -2,446.520 5,963,743.1685 369,118.3060 0.00 10,495.53 Alpine A f 13,500.000 55.000 193.1214 7,417.458 7,364.56 -10,501.872 -2,447.997 5,963,736.8557 369,116.7202 0.00 10,501.87 I 13,544.357 55.000 193.1214 7,442.900 7,390.00 -10,537.258 -2,456.246 5,963,701.6185 369,107.8683 0.00 10,537.26 Base Alpine 13,600.000 55.000 193.1214 7,474.816 7,421.92 -10,581.648 -2,466.593 5,963,657.4154 369,096.7640 0.00 10,581.65 13,6J5.377 55.000 193.1214 7,477.900 7,425.00 -10,585.938 -2,467.593 5,963,653.1435 369,095.6909 0.00 10,585.94 Target (Toe); 13605.377' MD, 7477.900' ND, 2189' FNL & 3968' FEL; Sec14-T11 N-R04E ~ 4/26/2005 4:16:36PM Page 6 of 7 COMPASS 2003.11 Bui{d 50 3'A~~~, li-1Al.LI B V RTC7 t1i Sperry Drilling Services calrA,L tiv~ MNlwd: Mintmun GwvaLre ANNOTATIONS smnM~ r~.aw`cy,na~l u, Project: Colville River Unit ND MD Annaation ° Ena Sufi: Elr IL°nk i ei°d W1e4e a W M Site: Alpine CD2 DLS, 12300.000 k MD, 6730.003 R ND 6730.00312300.000 Tietin PoinfBegin Dir -4.00 Mi Dir 37 1386°TFO 12480 254'MD 918'NO 6819 97812480 254 C 3 65°DLS fi819 : ~ am g e ~eaoetie ~nm; N~tsn lRnocon COnus) retic M°tlel: Occ~ooa Ma Well: Plan: CD2.60 ; , . ° nue . , . , . . . 7393.95614155.000 T' Csg Pt -14155.0008 MD, 7393.956 R TVD; 2795' FNL 8 372T FEL; Sec14T11N~204E ' g 7397.90014275.323 Target (Heel); 14275.323' MD, 7397.900 TVD -- ~ Wellbore: ;'gy'm is l.~G-b~ 7404.23515000.000 Potential (<15') 5autt, 15000"A1D 7407.73115400.000 Potential (<15) fault, 15400' MD Ground t,ev¢1 159Chi 7417.34716500.000 Potential (<75 fa0tt, 16500' MD RK`u'~ L`{32~Ei: ~a>. 52:~::.'T, (C6i~@0 Rig t'r5.s*a7p ~n- ~rD~~c~~~nA '`+`~•'N'+'~' 7426.08817500.000 Poten0al (<15 fault, 17500' MD 7432 90018279 263 Tar et (Tce)-18279 263 ft MD 7432 900 R ND; 1095ft FNL 816848 FEL Sec23-T11N~204E Nonhing%ASt' Y`. 5974 f~ d70E ..: . . , . , . g f,a:;tirx.#tASP 7:' 371?~13 TZf#i J sECTaN DETAr.s Sec MD Inc Axi ND +NIS +E/-W DLeg 7Face VSec Target 1 12300.000 57.157193.7214 6730.003 A543.998.2224.716 0.00 0.0000 9543.996 2 12480.254 63.000198.0000 6619.916 A694.313.2266.776 4.00 37.1386 9694.313 3 12669.117 57.300202.4915 6913.919 A847.941.2323.244 3.65146.7446 9847.941 4 14275.323 89.499150.2098 7397.90011248.451-2169.062 3.65.67.778911298.451 C0264~Np0411ce1 5 18279264 89.499150.2098 7432.90014773.141 -179.680 0.00 0.000014773.147 CD260/.P04 Tce 9 5/8" _C 8000 O O O M L O Z Tie-in Point/Begin Dir - 4.00°DLS,12300.000 ft MD, 6730.003 ft ND ~ -yoa ..___._______._~ ~ __._.~......._..__.._.._____........._... in Continue Dir; 3.65° DLS, 37.1386° TF0,12480.254' MD, 6819.918' ND T' Gsg Pt -14155.000ft MD, 7393.956 ft ND; 2795' FNL & 3727' FEL; Sec14T11N-R04E Target (Heel);14275.323' MD, 7397.900' ND Potential (<15') fault, 15000' MD Potential (<15~ fault, 15400' MD Potential (<15') fault, 16500' MD _ Potential (<15~ fauk,17500' MD -Target (Toe)-18279.263 ft MD, 7432.900 ft ND;1095ft FNL & 1684ft FEL, Sec23-711 N-R04E 61/8" Open Hole -3000 0 3000 6000 9000 12000 West{-)/East(+) (3000 ft!'in) cnswc ot:rnas no feu Mo rare sar zmooo 391nua ase- sea x srwnm ammo r 7 3 7.'Bi956 t4tssmo r r a ra;zroo ee~ialentwle aia 3s s~ ~;- "~7 ~ 1 r li '~ r;'~ c:: ~. „ ~~ ' , ,- e ~ '° S: t.+~ ~_ 15000 18000 21000 ~-r~~cvP'~~~~1'~S • Database: EDM 2003.11 Single User Db Compacy: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-60 Wellbore: Plan: CD2-60 Design: CD2-60wp04 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Project Colville River Unit. North Slope Alaska, United States ~ ~ ~ f~. ~ '? ~~ ~ ~ {, Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) b Using WeS~'tylf ~~ . ;; '~ , , Map Zone: Alaska Zone 04 Using geodetic scale factor. Well Plan: CD2-60 Well Position +N/-S 0.000 ft Northing: 5,974,194.4700 ft Latitude: 70° 20' 15.835" N +E/-W 0.000 ft Easting: 371,743.7700 ft Longitude: 151 ° 02' 26.471" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 15.900 ft i J Wellbore Plan: CD'2-60 Magnetics Model Name Sample Date Declination Dip Angle .Field Strength I BGGM2004 4/26/2005 23.5902 80.6070 57,530 Design CD2-60wp04 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 12,300.000 Vertical Section: Depth From (ND) +N/-S +FJ-W Direction (ft) (ft) (ft) (°) 37.000 0.000 0.000 180.0000 P{an Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NJ-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 12,300.000 57.157 193.1214 6,730.003 -9,543.998 -2,224.716 0.00 0.00 0.00 0.0000 12,480.254 63.000 198.0000 6,819.918 -9,694.313 -2,266.776 4.00 3.24 2.71 37.1386 12,669.117 57.300 202.4915 6,913.919 -9,847.941 -2,323.244 3.65 -3.02 2.38 146.7446 14,275.323 89.499 150.2098 7,397.900 -11,298.451 -2,169.062 3.65 2.00 -3.25 -67.7789 18,279.264 89.499 150.2098 7,432.900 -14,773.141 -179.880 0.00 0.00 0.00 0.0000 4/27/2005 9:00:20AM Page 2 of 5 ~!~~~.~, Sperry Drilling Services HAL.LI~ JIF;eTC~ Well Plan: CD2-60 CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) True Minimum Curvature COMPASS 2003.11 Build 50 ~ ! Sperry Drilling Services Planning Report -Geographic Database: EDDY 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska lnc. TVD Reference: Project: Colville River Unit MD Reference: Site: Alpine CD2 North Reference: Well: Plan: CD2-60 Survey Calculation Method: Wellbore: Plan: CD2-60 Design: CD2-60wp04 Planned Survey CD2-60wp04 MD Inclination Azimuth TVD SSTVD +N/-S +E/-W (ni 1°) (°) In) (ni In) (ft) 12,300.000 57.157 193.1214 6,730.003 6,677.10 -9,543.998 -2,224.716 Tie-ih PoinUBegin Dir -- 4. 00°DLS, 12300.000 ft MD, 6730.003 ft TVD 12,400.000 60.375 195.8970 6,781.856 6,728.96 -9,626.745 -2,246.167 12,412.302 60.777 196.2274 6,787.900 6,735.00 -9,637.042 -2,249.132 HRZ 12,480.254 63.000 198.0000 6,819.918 6,767.02 -9,694.313 -2,266.776 Continue Dir ; 3.65° DLS, 37.1386° TFO, 12480.254` MD, 6819.918' TVD 12,500.000 62.399 198.4454 6,828.975 6,776.08 -9,710.980 -2,272.263 12,600.000 59.370 200.7861 6,877.635 6,824.73 -9,793.263 -2,301.562 12,669.117 57.300 202.4915 6,913.919 6,861.02 -9,847.941 -2,323.244 12,700.000 57.732 201.2579 6,930.505 6,877.61 -9,872.117 -2,332.949 12,800.000 59.214 197.3383 6,982.807 6,929.91 -9,952.549 -2,361.086 12,843.599 59.897 195.6662 7,004.900 6,952.00 -9,988.588 -2,371.759 Base HRZ 12,900.000 60.810 193.5421 7,032.800 6,979.90 -10,036.018 -2,384.113 12,945.863 61.578 191.8395 7,054.900 7,002.00 -10,075.223 -2,392.938 K-1 Marker 13,000.000 62.510 189.8659 7,080.280 7,027.38 -10,122.184 -2,401.937 13,045.279 63.312 188.2376 7,100.900 7,048.00 -10,161.992 -2,408.276 Kuparuk Fm 13,100.000 64.303 186.3045 7,125.055 7,072.15 -10,210.696 -2,414.486 13,151.266 65.256 184.5192 7,146.900 7,094.00 -10,256.866 -2,418.856 LCU-Mifuveach 13,200.000 66.180 182.8511 7,166.941 7,114.04 -10,301.195 -2,421.708 13,300.000 68.132 179.4982 7,205.769 7,152.87 -10,393.311 -2,423.575 13,400.000 70.150 176.2372 7,241.381 7,188.48 -10,486.672 -2,420.078 13,500.000 72.225 173.0592 7,273.632 7,220.73 -10,580.896 -2,411.232 13,600.000 74.351 169.9550 7,302.391 7,249.49 -10,675.601 -2,397.073 13,636.131 75.131 168.8482 7,311.900 7,259.00 -10,709.863 -2,390.661 Miluveach A 13,700.000 76.519 166.9154 7,327.541 7,274.64 -10,770.402 -2,377.658 13,755.484 77.740 165.2516 7,339.900 7,287.00 -10,822.901 -2,364.647 Alpine D 13,800.000 78.724 163.9308 7,348.979 7,296.08 -10,864.913 -2,353.067 13,900.000 80.957 160.9920 7,366.619 7,313.72 -10,958.749 -2,323.398 13,995.897 83.122 158.2065 7,379.900 7,327.00 -11,047.748 -2,290.291 Alpine C 14,000.000 83.214 158.0896 7,380.388 7,327.49 -11,051.529 -2,288.774 14,100.000 85.488 155.2144 7,390.231 7,337.33 -11,142.876 -2,249.335 14,155.000 86.745 153.6397 7,393.956 7,341.06 -11,192.371 -2,225.648 7" Csg Pt -14155.000ft MD, 7393.956 ft TVD; 2795' FNL 8 3727' FEL; Sec14-T11 N-R04E - 7" 14,200.000 87.773 152.3572 7,396.108 7,343.21 -11,232.418 -2,205.241 14,275.323 89.499 150.2098 7,397.900 7,345.00 -11,298.451 -2,169.062 Target (Heel) ; 14275.323' MD, 7397.90 0' TVD -CD2-60wp04 Heel HALLI V Y Sperry Drilling Services Well Plan: CD2-60 CD2-60 C 52.9GGft (CD2-60 Riy (15.9+37)) CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) True ~ ~^, ~^ Minimum Curvature ~ ~ ~ ~ ' ~ ~,~ ~` ~~P~ ~ ~ ~~J.I`a ,A1~S~ez ~ii 4~; ~r~5 ~t7+t~- uwlC _:iuf; Map Map ~P1R~~Cit f+kT .Northing Easting DLSEV Vert Section (ft) {n) (°noon) (nl 5,964,690.6928 369,356.3329 0.00 9,544.00 I 5,964,608.3316 369,333.4711 4.00 9,626.74 5,964,598.0875 369,330.3308 4.02 9,637.04 5,964,541.1307 369,311.7112 4.00 9,694.31 5,964,524.5618 369,305.9404 3.65 9,710.98 5,964,442.7990 369,275.2408 3.65 9,793.26 5,964,388.5037 369,252.6287 3.66 9,847.94 5,964,364.4999 369,242.5127 3.65 9,872.12 5,964,284.5667 369,213.0070 3.65 9,952.55 5,964,248.7191 369,201.7192 3.66 9,988.59 5,964,201.5105 369,188.5576 3.65 10,036.02 5,964,162.4657 369,179.0635 3.66 10,075.22 5,964,115.6692 369,169.2637 3.65 10,122.18 5,964,075.9787 369,162.2452 3.66 10,161.99 5,964,027.3918 369,155.2039 3.65 10,210.70 5,963,981.3071 369,150.0448 3.66 10,256.87 5,963,937.0375 369,146.4353 3.65 10,301.19 5,963,844.9736 369,142.9937 3.65 10,393.31 5,963,751.5746 369,144.8930 3.65 10,486.67 5,963,657.2204 369,152.1255 3.65 10,580.90 5,963,562.2947 369,164.6618 3.65 10,675.60 5,963,527.9315 369,170.4864 3.66 10,709.86 5,963,467.1836 369,182.4509 3.65 10,770.40 5,963,414.4739 369,194.5611 3.66 10,822.90 5,963,372.2738 369,205.4204 3.65 10,864.91 5,963,277.9515 369,233.4770 3.65 10,958.75 5,963,188.4067 369,265.0549 3.66 11,047.75 5,963,184.6001 369,266.5064 3.60 11,051.53 5,963,092.5994 369,304.3745 3.65 11,142.88 5,963,042.7106 369,327.2094 3.66 11,192.37 5,963,002.3236 369,346.9272 3.65 11,232.42 5,962,935.6870 369,381.9680 3.66 11,298.45 4/27/2005 9.~00:20AM Page 3 of 5 COMPASS 2003.11 Buiid 50 ~~~~ ~ ` =` Sp erry Drilling Services HAI 1 U~-~-~ ~t _ ~~~ ~~~ ~~~~~~ Pla nning Report -Geographic Sperry Drilling Services Database: EDM 2003:11. Single User Dt? Local Co-ordinate Reference: Well Plan: CD2-60 Company: ConocoPhillips Alaska Inc.. TVD Reference: CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) Project: Site: Colville River Unit Alpine CD2 MD Reference: North Reference: CD2-60 @ 52 True . 0 i (15.9+37)) ~~ ~~,~~ ~~"'`~ ~~ ~ Well: Plan : CD2-60 Survey Calculatio n Method: Minimum Cur vature ~" ' ~.,«sf Wellbore: Plan : CD2-60 ~ ~Q ,~, 9i n(~ ,- Design: CD2 -60wp04 ~.+ :3~ =U~~~ Planned Survey CD2-60wp04 " -R t'w^' I ~~ +i3. ~.c.,,,~~:SSl~;;', Map ~'}~~~'tiiF'~s,~ ~.ap..et- - ~.a~ MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV .Vert Section (ftl (`) (`) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) fft) 14,300.000 89.499 150.2098 7,398.116 7,345.22 -11,319.866 -2,156.803 5,962,914.0669 369,393.8587 0.00 11,319.87 i 14,400.000 89.499 150.2098 7,398.990 7,346.09 -11,406.648 -2,107.122 5,962,826.4552 369,442.0438 0.00 11,406.65 14,500.000 89.499 150.2098 7,399.864 7,346.96 -11,493.430 -2,057.441 5,962,738.8435 369,490.2290 0.00 11,493.43 14,600.000 89.499 150.2098 7,400.738 7,347.84 -11,580.212 -2,007.761 5,962,651.2319 369,538.4141 0.00 11,580.21 ~ 14,700.000 89.499 150.2098 7,401.612 7,348.71 -11,666.993 -1,958.080 5,962,563.6202 369,586.5992 0.00 11,666.99 14,800.000 89.499 150.2098 7,402.486 7,349.59 -11,753.775 -1,908.400 5,962,476.0085 369,634.7843 0.00 11,753.78 ' 14,900.000 89.499 150.2098 7,403.361 7,350.46 -11,840.557 -1,858.719 5,962,388.3969 369,682.9694 0.00 11,840.56 15,000.000 89.499 150.2098 7,404.235 7,351.33 -11,927.339 -1,809.038 5,962,300.7852 369,731.1545 0.00 11,927.34 Potential (<15') fault, 15000' MD i 15,100.000 89.499 150.2098 7,405.109 7,352.21 -12,014.121 -1,759.358 5,962,213.1735 369,779.3396 0.00 12,014.12 15,200.000 89.499 150.2098 7,405.983 7,353.08 -12,100.902 -1,709.677 5,962,125.5618 369,827.5247 0.00 12,100.90 15,300.000 89.499 150.2098 7,406.857 7,353.96 -12,187.684 -1,659.997 5,962,037.9502 369,675.7098 0.00 12,187.68 15,400.000 89.499 150.2098 7,407.731 7,354.83 -12,274.466 -1,610.316 5,961,950.3385 369,923.8949 0.00 12,274.47 i Potential (<15') fault, 15400' MD 15,500.000 89.499 150.2098 7,408.605 7,355.71 -12,361.248 -1,560.635 5,961,862.7268 369,972.0800 0.00 12,361.25 i 15,600.000 89.499 150.2098 7,409.480 7,356.58 -12,448.029 -1,510.955 5,961,775.1152 370,020.2651 0.00 12,448.03 15,700.000 89.499 150.2098 7,410.354 7,357.45 -12,534.811 -1,461.274 5,961,687.5035 370,068.4502 0.00 12,534.81 15,800.000 89.499 150.2098 7,411.228 7,358.33 -12,621.593 -1,411.593 5,961,599.8918 370,116.6354 0.00 12,621.59 15,900.000 89.499 150.2098 7,412.102 7,359.20 -12,708.375 -1,361.913 5,961,512.2801 370,164.8205 .0.00 12,708.37 16,000.000 89.499 150.2098 7,412.976 7,360.08 -12,795.156 -1,312.232 5,961,424.6685 370,213.0056 0.00 12,795.16 16,100.000 89.499 150.2098 7,413.850 7,360.95 -12,881.938 -1,262.552 5,961,337.0568 370,261.1907 0.00 12,881.94 16,200.000 89.499 150.2098 7,414.724 7,361.82 -12,968.720 -1,212.871 5,961,249.4451 370,309.3758 0.00 12,968.72 16,30.000 89.499 150.2098 7,415.598 7,362.70 -13,055.502 -1,163.190 5,961,161.8334 370,357.5609 0.00 13,055.50 i 16,400.000 89.499 150.2098 7,416.473 7,363.57 -13,142.283 -1,113.510 5,961,074.2218 370,405.7460 0.00 13,142.28 ~ 16,5(10.000 89.499 150.2098 7,417.347 7,364.45 -13,229.065 -1,063.829 5,960,986.6101 370,453.9311 0.00 13,229.07 Potential (<15') fault, 16500' MD 16,600.000 89.499 150.2098 7,418.221 7,365.32 -13,315.847 -1,014.149 5,960,898.9984 370,502.1162 0.00 13,315.85 16,700.000 89.499 150.2098 7,419.095 7,366.20 -13,402.629 -964.468 5,960,811.3868 370,550.3013 0.00 13,402.63 16,800.000 89.499 150.2098 7,419.969 7,367.07 -13,489.410 -914.787 5,960,723.7751 370,598.4864 0.00 13,489.41 i 16,900.000 89.499 150.2098 7,420.843 7,367.94 -13,576.192 -865.107 5,960,636.1634 370,646.6715 0.00 13,576.19 17,000.000 89.499 150.2098 7,421.717 7,368.82 -13,662.974 -815.426 5,960,548.5517 370,694.8566 0.00 13,662.97 17,100.000 89.499 150.2098 7,422.592 7,369.69 -13,749.756 -765.746 5,960,460.9401 370,743.0417 0.00 13,749.76 17 20 000 0. 9.49 8 9 150.2098 7 423.466 7 370.57 -13 836.537 -716.065 5 960 373.3284 370,791.2269 0.00 13,836.54 i 17,300.000 89.499 150.2098 7,424.340 7,371.44 -13,923.319 -666.384 5,960,285.7167 370,839.4120 0.00 13,923.32 17,400.000 89.499 150.2098 7,425.214 7,372.31 -14,010.101 -616.704 5,960,198.1051 370,887.5971 0.00 14,010.10 17,500.000 89.499 150.2098 7,426.088 7,373.19 -14,096.883 -567.023 5,960,110.4934 370,935.7822 0.00 14,096.88 Potential (<15') fault, 17500' MD 17,600.000 89.499 150.2098 7,426.962 7,374.06 -14,183.664 -517.342 5,960,022.8817 370,983.9673 0.00 14,183.66 17,7b0.000 89.499 150.2098 7,427,836 7,374.94 -14,270.446 -467.662 5,959,935.2700 371,032.1524 0.00 14,270.45 I 17,800.000 89.499 150.2098 7,428.711 7,375.81 -14,357.228 -417.981 5,959,847.6584 371,080.3375 0.00 14,357.23 17,900.000 89.499 150.2098 7,429.585 7,376.68 -14,444.010 -368.301 5,959,760.0467 371,128.5226 0.00 14,444.01 18,000.000 89.499 150.2098 7,430.459 7,377.56 -14,530.791 -318.620 5,959,672.4350 371,176.7077 0.00 14,530.79 i 18,100.000 89.499 150.2098 7,431.333 7,378.43 -14,617.573 -268.939 5,959,584.8234 371,224.8928 0.00 14,617.57 i 18,20.000 89.499 150.2098 7,432.207 7,379.31 -14,704.355 -219.259 5,959,497.2117 371,273.0779 0.00 t 14,704.35 18,279.264 89.499 150.2098 7,432.900 7,380.00 -14,773.141 -179.880 5,959,427.7673 371,311.2713 0.00 14,773.14 Targ%t (Toe)--18279.263 ft MD, 7432.900 ft TVD; 1095ft FNL R 1684ft FEL, Sec23-T11 N-R04E - 6 1/8" Open Hole -CD2-60wp04 Toe J 4/27/2005 9:00:20AM Page 4 of 5 COMPASS 2003.11 Build 50 ~~~~~~~~ c~nc~cc~Ph~'r~li s Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-60 Welibore: Plan: CD2-60 Design: CD2-60wp04 Geologic Targets Plan: CD2-60 Sperry Drilling Services • Planning Report -Geographic H LLa1~luA°rc~ Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD2-60 TVD Reference: 'CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) MD' Reference: CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) North Reference: True a - 3^°' ~ ~ Survey Calculation Method: Minimum Curvatu~~ ~ ~ ~.,,,d TVD Target Name (ft) - `ti h~rr;e 7,397.900 CD2-80wp04 Heel - Rectangle (sides W4,004.000 H200.000 D0.000) ~,~R ~ ~ LOO~~ ~y t,. ~~qq c G` ' „ e+ ~t~r~i~~ ~"~ ~= 5 +WS +E/-W Northing Fasting ft ft (ft) (ft) -11,298.451 -2,169.062 5,962,935.6870 369,381.9680 7,432.900 CD2-Stlwp04 Tae -14,773.141 -179.880 5,959,427.7673 371,311.2713 - Po'mt Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft> (rt) (") (••) 3,310.343 2,390.000 9-5/8 12-1/4 14,155.000 7,393.956 7 8-1/2 III L 18,279.263 7,432.900 4-112 6-1I8 Prognosed Formation Intersection Points fdleasured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) i~darn~ 2,928.742 61.16 193.12 2,205.900 -1,551.47 -361.65 C-40 3,353.664 61.16 193.12 2,410.900 -1,913.96 -446.15 C-30 ~ 4,124.741 61.16 193.12 2,782.900 -2,571.73 -599.47 G20 6,313.607 61.16 193.12 3,838.900 -4,438.96 -1,034.73 £C-3 Marker 6,732.310 61.16 193.12 4,040.900 -4,796.14 -1,117.99 6asa1 K-3 Sand 6,796.566 61.16 193.12 4,071.900 -4,850.96 -1,130.76 K-2 Marker 6,991.409 61.16 193.12 4,165.900 -5,017.17 -1,169.51 Base K-2 Cycle 9,918.187 61.16 193.12 5,577.900 -7,513.88 -1,751.49 Albian 97 i 10,944.217 61.16 193.12 6,072.900 -8,389.14 -1,955.52 Albian 96 12,412.302 60.78 196.23 6,787.900 -9,637.04 -2,249.13 HRZ 12,843.599 59.90 195.67 7,004.900 -9,988.59 -2,371.76 Base HR2 12,945.863 61.58 191.84 7,054.900 -10,075.22 -2,392.94 K-1 Marker 13,045.279 63.31 188.24 7,100.900 -10,161.99 -2,408.28 KuparukFm 13,151.266 65.26 184.52 7,146.900 -10,256.87 -2,418.86 t_CU-Miiuveach 13,636.131 75.13 168.85 7,311.900 -10,709.86 -2,390.66 Miluveach A ~ 13,755.484 77.74 165.25 7,339.900 -10,822.90 -2,364.65 Alpine D 13,995.897 83.12 158.21 7,379.900 -11,047.75 -2,290.29 Alpine C 4/27/2005 9:00:20AM Page 5 of 5 ~~~.~~ COMPASS 2003.11 Build 50 9 • ConocoPhillips Alaska Inc. `~~~ ~ ~~~~~ Colville River Unit ~~~°```~ ~'"~ ~` ~~'" "~ ''' ' `~ -~ Alpine CD2 Plan: CD2-60 Plan: CD2-60 CD2-60wp04 Anticollision Report 26 April, 2005 ~p~erll~ Dri~~~nc~ ~ell~v~ces ~~~ ANTI COt I IS1C3N SfTT1N 4 ~~~~~~~~~~~ Interp I t M th d'. MD Inlarval 255talions C I I t Meth tl M C fure it I R - ~: 12300 To 18279264 E Mod I ISC WSA Maximum Range 5000 MO!t il ~..yiuid0 ~< th Error Surface. EII pt cal Con e v~~+.ye Reference Well: Plan. CD?-60w~~04 Warning McO~od: Rifles Based HA~w L1P~~T~~ -~ til-k\'F. }' I'RrH::It1\I - Spe11y Dril00g Serviea5 ~ _.. - ~- De w--r4-zn111.1n. : c.llda 1 } c ~~,n, : In.rwnl II:~.pIhl 11 ~.pIhT -.'ey/Plvn T I N Wlll.l fMl (B (1'ItU-SS WN .61N) Iii 10.01X1 MWU Ifk-,\li-(,12-SC c fl~°~,ua ~~ K Ixr-°,w cD2~owao4 n1Wn+IeR-}~_ P uu1 Cu R ~m'Jnn Sie N re ,Dc I r f'a~i CO:fin F K.i n e M Di _. y...-. a~ve:em -.~~ aw~zmew -..-- ._ 8,400 334 ~ .-- :300 ...~30 i~ .~ ~.. :320 ..,......... .'~ /- ,. X30 COld5 / /. ~ ~\ ~ \ 2sa ~ ~ i r , \ ~. ~ a ~ \~ ~ v, 300,- : _. - ~~ s0 -•~"~ } ,/ Aso ,., 1 \~ f i ~ A / i' /~~ J \~\ t i~ ' ~xn«wwa' 1 r/' ~ 4ib i 1. / / ~\ ` ` : , .. ~ 1 t I 1 `~ I I ~ I I i ~ ~~ I I 2701.. .... -.. ~ -..: '.. .., :. ..3 .. 7- It \ \ l ~r ,' fi I 00 .- f ;\ :.,, ~ 1' \ \ '12,0_,..... i/i ,1... \~ -:167 ~ ! /,: . r -: ~. i `. -.. :..~ ; zoo- A~ 20° '~ +z0 `~ ~ ---~. / -, \ ....240 /, ~ - \ ~ ~ ~ J \ 280.. _.-. -, / ! \ ' ~ _. _ ~ , 216 .~ ~-....-.. --~ , _)GO ._ ^150 From Cabur Ta MD _ ' 1400 100 n°o- rma-:moo ~°- ~o~'-+mm 'I'rav tiilegC Ilndel':1it~uCh '1'FC}+AfI o-zoow ( ) ]°l 's t"enn~ee z0 C ~ zri Selrsraf na 4 t f in Critical Issues: from sidetrack point to TD t / 200 \_ '120 29 s. 21 50 ~a~ "~43 1;'A ~` Trsce€ting Cy'lindex Aaimuz0 (TF{1+AZp ~° s Cenza~e ra Ce Drx Sepal.lnan ~S fi!Lfj SECTION DETAILS Sa MD Inc Av T{D +N/-S +E/-W OLeg TFare VSec Targe[ 1 12300.000 17.157 193.1214 6730.003 -9543.998 -2224.716 0.011 0.0000 9443.998 ,, 2 12400.254 63.000 198.0000 6819.916 -9694.313 •2266.776 4.00 37.138fi 9694.]13 _ 7 12669.117 57.700 202.4915 6913.919 -9847.941 -2327.244 3.65 146.74x6 9647.941 ~~ 4 14275.323 89.499 150.2098 7397.900 -11298.451 -2169.062 3.65 -67.7789 11298.45! CD2.60ry~49ec1 5 18279.264 89.499 150.2098 7432.900 14773.141 -179.880 0.00 0.0000 14777.141 CD2-6~n'pu4 Tne 1: _. ~~ c, ~~" ~„~ ~~ a,,y _ ~r~ t ~~~ PM • '` ~ ~ Sperry Drilling Services 1C~~C~-~~~~1~~ Anticollision Report Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD2 Site Error: O.000ft Reference Well: Plan: CD2-60 Well Error: O.000ft Reference Wellbore Plan: CD2-60 Reference Design: CD2-60wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALi,.1 TO Sperry Drilling Services Well Plan: CD2-60 CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) CD2-60 @ 52.900ft (CD2-60 Rig (15.9+37)) True Minimum Curvature ~ ,~°"~ ~^°' ~ ~ pvt.~ 1.00 sigma ~.~.'~„1 tf sf ~~ EDM 2003.11 Single User Db Offset Datum t~1O'~ ~ ~ ~GJ1 Reference CD2-60wp04 i~~l rt ~ I~rrvo~ tt Fitter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria f Interpolation Method MD Interval 25.000ft Error Model: ISCWSA ` °°8"'r"t3~ Depth Range: 12,300.000 to 18,279.264ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 5,000.OOOft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program f=rom To Ift1 (ft) Survey (Wellbore) 37.000 900.000 CD2-60PB1wp04 (Plan: CD2-60PB1) 900.000 12,300.000 CD2-60PB1wp04 (Plan: CD2-60PB1) 12,300.000 18,279.264 CD2-60wp04 (Plan: CD2-60) Tool Name CB-GYRO-SS M W D+I FR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC Summary Site Name Offset Well -Wellbore -Design Alpine CD2 CD2-36 - CD 2-36 - CD 2-36 CD'1.-36 -CD2-36 P61 -CD2-36 P61 CD2-37 -CD2-37 -CD2-37 CD2-43 -CD2-43 -CD2-43 CD2-47 - CD2-47 -CD2-47 CD2-51 -CD2-51 -CD2-51 CD2-52 -CD2-52 -CD2-52 CD2-53 -CD2-53 -CD2-53 CD2-55 -CD2-55 -CD2-55 CD2-56 -CD2-56 -CD2-56 CD2-56 -CD2-56L1 -CD2-56L1 CD2-57 -CD2-57 -CD2-57 CD2-58 -CD2-58 -CD2-58 CD2-58 -CD2-58L1 -CD2-58L1 Alpine CD4 Plan: CD4-213 -Plan: CD4-213 -CD4-213 (wp03) Plan: CD4-215 -Plan: CD4-215 -CD4-215 (wp03) Plan: CD4-320_Horiz -Plan: CD4-320 -CD4-320 (wp Reference Offset Centre ko No-Go Allowable Measured Measure Centre Distance Deviation Warning Depth d Distance (ft) from Plan (ftl Ift) (ftl 18,265.325 16,900.000 17, 310.662 15, 558.000 18,177.572 17 ,085.000 13, 732.010 19, 040.000 12, 300.000 13, 850.000 13, 321.075 15, 238.000 13, 299.947 18, 027.000 13, 699.94 5 19, 554.000 18, 258.438 15, 975.000 18, 268.355 13, 850.00 0 18,266.091 13,175.000 18 , 274.212 10, 499.958 3,386.808 336.52 3,053.882 Pass -Major Risk 3,474.895 331.02 3,147.559 Pass -Major Risk 2,028.752 348.20 1,682.870 Pass -Major Risk 2,043.273 302.02 1,742.741 Pass -Major Risk 1,669.609 292.13 1,393.207 Pass -Major Risk Out of range Out of range Out of range 242.358 26.97 241.810 Pass -Minor 1/200 4,587.012 301.73 4,290.013 Pass -Major Risk 4,043.871 294.85 3,752.607 Pass -Major Risk Out of range 4,961.069 358.78 4,607.576 Pass -Major Risk Out of range 1,906.992 305.81 1,656.333 Pass -Major Risk 1,211.132 280.96 1,069.523 Pass -Major Risk 2,816.455 282.25 2,577.998 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4!26/2005 5:07:56PM Page 2 of 2 COMPASS 2003.11 Build 50 ~r:. Date 4126(2005 ~~ ~'"~~ `W .~lullixlnnll I IINIIIIIII (IIII IIII III MIIIx1111111NIIIN111111111111111IIII IIIIIIIIII I € WELl6GRE TARGET DE1'AIL3 (ftRAF CO)~ORDINATES) + + Project: Colville Rivet Unit Name TVD +N?-S +Ef-W Northing Fasting Shape AM'lA~/ VR ~\J "~AYM~~~~~C L/ € # 7 ,~: c;U2 .. CD2.60wp0:: Fleei , . 7337.°00 -91248.459 -2469.062 5962935.f~R7464301.4680 Recta:^.gle(40t?n.000x200.000) € r Well: P4'Ul: CD2~0 CD2-60wp02 Neel Circle 7397.90p -11298.451 -2164.062 5962335.6870369381.9680 Ciro€e {Radius: 1320.000) CD2-60wp04 Heel 7397.990 -11298.451 -2169.062 5462935.6870369381.9680 Rectangle (4004.OOOr.24S0.000) WeMbore: Pk'9n: CD2$0 CD2.60wp02 Tae; 7432.400 -14773.141 -974.860 5459427.7673 3 71 311,2713 __ CD2.60wp02 Toe Ciro3e 7432.400 •14773.141 -179.880 5959427.7673371391.2713 GircEe (Radius: 1320.000) _ ~-~-IBl JF3TON Plan: CD2-trA~vl~t'.; CD2.60wp04 Tce 7432.900 -14773.141 -179.880 5959427.7873371311.2713 Sperry Drilli ng Services ~ - cxoUr : =~uee ~a.sEra ' € ! S RK6: CD2~SQ ~i~ 52.Bn(}~ ECCF2-56 Rg (95.9>3*,I s ~ 1 Y ~ € .......-. ..._ ... .........._...._...._,_,._' . : fi97d 4Tf}4 RE,xthiYtgiASP 9 .........,,,..._.__......_.. . ' ._ ................ .,,. _.,..... ..._.... _ { ExsfirlgiggF X; 379 rS3.77W E -_ €_ 3 ( €_ __ __ t € _ C € ~ ~- Pry 9jJ Y € 333 IIJJ c ° mow, _ q ~~ -S - ~~ -11000 .-.__ .~..._,. ....,, ..~.._....,,__...,..__-.....~....,.__ ._.._.. W~ ~-_ ~ C 0 CD2~i0w~02 Heel Circle = € o _= N 777 i E ~ v 1 L € it Z s o ~ ~ __ I _ ~ CD2~Owp02 Ice Circle a ~a ~ ~ ~ 1~~ ~ ~ ~~ ... _ ~ ~ !°'.:: s -17E170 ~ ~ - 4:. C.,S: ~i i ~ _ _ 4V' d, € -11000 X800 ~0 -0400 2270 0 2ZOD -0400 6500 West(-)IEast(+) (2200 Win) i n n n n n u n n n n n m m u u n n m m ~ n u m m ~ n n n n n n n n n w n u m w n u u u u l u u u l u u u u l u u n m l w l u u l u u l u u u u l m n u n u l u u x m u u l u u m u u n w u l u u l w l u x l x x m x x l u x x x l x x l x x l x u x l x x x x m x n n n n n x l m l w l n m u m m m ~ m l l m w l m i n m m m 9 n l x m l m n m m n n n n n m u m p l m l m l l n n m m ~ u m m m n n x n m m ~ m n n n n n n u m n n n m m ~ m m ~ n n n n n u n n n n u n u n n n n m m ~ n n n n u n u n n n m m ~ u u m n n n u n m m ~ n u n u m n n n m u m m ~ u u m m ~ n m m ~ m m ~ n n u ff r~ {P '.' ~ ^ * ar ConocoPl~lllipsAlaskaMa~Alpine) ~ Project: Colville RiverUnR ^~aa ~~,,rr~~.y~ ~/~ , { y ~w ~ig¢ ap ~ ~ ~ _..:-.-• S14c. i-UPII-ic i..i11 MV^ .V ~'V fR M * Alpine ca,~°,ari,nw»:,noa: Mk~knumcnnawre Well: Plan: CD2.60 Scan NletlwdnT~rn.Cylin4er NOM Wellbore: Plan: CD2~0 Error S°r/ace: Elliptical Conic Warning Nlebwd: Rules Basatl {.t A E 1 ~~! ~CI~/^liie C+ectlefie ~9~NA X127 fNAU~~CIXJUS) BG Pin: Plan: CDZ~O (wp04) Spent' DriII1Dg Services RfCf3: CC32~6R r~ 52.9(#4Y lQD2kdl t~ f1a.9+37}) HartPsltxyASP Y; 5974199.9769 Eas1s~~,y'ABf' k: 37174'.i.77U9 .y:'.~..v~ayy ~_ a....'.= o ~a,~~, _ r a D a ~ r d H ~ C~fCUi~a ~~ T,-~}"`- re,~rtr' ~ ,<;: _ rrx~;, z,,~,. ~.. _. _ -__._ ~ L I ll" I I f >€ u r ~. In r 1..-1sv e ,.. ., _.. , . ..d~ ., ~.~ a.,, ._...;xc :. _r .,, ;. ,. i. .,:.. ,_ .. ., _ .. ~ lk'~-.Jlu rmr at ttll M i~4L_tb . tS' -911 !P~ 16.;4t~ ~ :. i7 clas.u-i :.~k ~'1rg £Ytn i cw .'wtchl -.'f1S` 38=.~° ~ 'D7~~rLriscu~,~~Liizknvrn¢ilQlute} t'il?t~Ci ~' C~ -,:a *; CD2-55 Pl~n: CD2-60 (wp04) o tsao 300o asoo soon ~soo soon tosoo tzooo Vertical Section at 150.20° (1500 ft/in) CD2-54 ~ CRU CD2-60 &CD2-60PB1 Proposed Injector Alpine Oil Pool 2050680 ~ D~- C02-1 ~a ~~ Confidential wells are red \ SFD 5/4/2005 D1-as 01-4 i 01-39PH1 CD2-44 , C02-4s I GD1 t OQ~ o ~4 co: CD2- 0 P 1 t'~o ~~~~ OZ-47 ~~. 1 X00 ~\ GDi -13 Area of Review-` 16°°O Openhole~ ,~~oo° . 1~°023 CD2-6 T17N, R4E, UM ~ r .c . ~~~~ -®s CD1-39 ~\ -229F -. 1.~~ coz+=,, cD1- i coz-sz GD2-58 L CO1-229 coz-se 24 coz-s3 ¢NNJUK 1 ~ Feei 2,000 4,000 6,409 $,000 ANNOTATIONS ~~ ~r /~''~f'~f`' • + Q„1/~s/'~ ~ ~(~"~~f."' YWV! ~V'~,,/j !/.7 l CaIwlaOm Me9ad: Mm~mum Curvatwe ErrorSyslem: ISCWSA Scan Memod~ 7rav. cylinder N°M Error Surface: Ellptieal tonic Warning Metlwd: Rules Based Geodetic Dalum. NAD 1927 MA0GON CONUS) MagneOO Modal: GC:CZt104 Project: Colville River Unit $Ite; apin@C.~ Vlicii: ."la-1. 1.0~fil~ Welll3ore: Plan: CD2~OP61 7vo MD Annotati°D 37.0110 37900 SNL-2162RFNL 81497ftFEL; Sec02-T11Ni204E ZOg,ggp 200,000 In Dir-3.00°DLS, 200.000RMD, 200.000 RTVO ~g 1872$97 2238.407 Start SaiF-61 !55°.2238A97R MD, 1872.897RTVD T,s90900 3370.343 9d'6"CpplsIg~~P,,t 3310.343ft MD.2390A00ft TVD ~g,068 12353.875 Start Sad'; 55.000°NC, 12353875'M~60.068'11/D &747TVD 11~11eL.~ ~ ~ R"'~""~" N GrnaarxS larval: 35.E RKB: C02E0 ;a%52.9t~R (CD2{i5.9+37)j Pi3n: C~4-~0P~1VJ~} 7477900 73605377 Target (TDe); 13605.377' MD, 7477.900 TVD, 2189' Fl4L &3968' FEL; Srx14T11N1204E Sperry Drilling Services NwtldlI~ASP 1': 597A194A7W F~1;.~tA~x: 3T7743,TIIX1 -_-_-- sECT1orI DeraLs Sec MD klc Azi TVD +NIS +F/-W Dleg TFate VSec Tatget 1 37.000 OAW OAOOD 37.000 OA00 0.000 080 0.0000 0.000 2 210.000 0.000 OBOOD 200000 O.OOD 0.000 0811 OA000 0.000 3 2238A97 61.155193.1214 1872897 962654 ,22A.396 380193.1214 962.6'54 a tn6ooog 61.tss 19ama ss7a~4z 94soam ,2ao52a9 0.00 o,6ogo 94euam SHL -2162ft FNL & 1491ftFEL; Se c02-T11N-R04E s 123s1s7s SSaoo 193ma 6760.068 9597s13 9234964 am 160.9060 95675q 0 6 73605377 55000 1931214 7477900.10585936 ?A6'7593 0.00 08000 105&5.938 Begin Dir - 3.00°DLS, 200.000 ft MD, 200.000 ft TVD CASING DEfAiL9 No 1VD MD Name Slxe 1 2390.000 3370.3439518" 95/8 2 6]30.003 72300.000 7" ] 4 Start Sail-~'i1.155° , 2238.497 ft MD,1872.897 ft TVD C-40 - - - 9-518" Csg Pt: 3310.343 ft MD, 2390.000 ft TVD ^"r _ " ~..._ C30 € _ _... _ .._..._..l . _ _..._ ...... ___ .. _....._.. _ _ ..... _ _i_.. - C-20 K3 Marker ~ Basal K3 Sand Base K-2 Cyde K-2 Marker 1 Albian 97 ~?" i Albian 96 j ( ~? -~--------- _ ........................ ~-o HRZ f _ (_..-- Base HRZ K-1 Marker Begin Drop; 4.00° DLS 180° TF0,12200.000 MD, 6678.742' TVD ~" ' ~ ~ ~ Kuparuk Fm ~+ ~ ~ T _~._ __,_.__._ _ _ ......,,, _.,_._ . Start Sail; 55.000° INC,12353.875' MD, 6760.068' TVD Ys LCU-Milweach "r~ ^~ - - ~ ° - -__ Milweach A ~ ~ ~~.; ~_~_ ~ 3 , ~.n sl -_ _, ." --~ Alpine D ~ ~ 7 t..., Alpine A Alpine C ~ Target (Tce);13605.377' MD, 7477.900' TVD, 2189' FNL & 3968' FEL; Sec14-711 N-R04E Base Alpine ' l( -1500 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 180.00° (1500 ft/in) , ,,, tlntl: Mi c i mti M i G W ANNOTA710NS ~'~ a c., m e n nun wa re s~M~r~"`cjn~ «n Pro ect: Colville River Unit ~ No MD Annotation ~~~~~~~~~ warrgM°eptl:I51a9~a ~ DL ~ ~ : p~N Site: AlpineCD2 37.000 37.000 S(IL-2162ft FNL81491ftFEL; Sec02•T11N4204E 200.000 200.000 BeginDir-3.00°DLS,200.000ftMD,200.000kND Geodehc . N 92 P QJ WNl15) AU Magr~h: M~Mal: 8GC3.®BA Weli: Plan: CD2-60 1872.8972238.497 Start Sail-61.155°, 2238.497k MD, 1872.897k7VD " Wellbore: Plan: CD250PB1 Csg Pt: 3310.343 k MD, 2390.000 ft ND 2390.000 3310.343.9518 6676.7aazzo9.9oo Begin Drop; 4.00° DLS, 160° TF0, 12200.000' MD, 6678.742' ND 6760.06812353.875 Start 3ai1; 55.000° INC, 12353.875' MD, 6760.068' TVD CF°~ne L 7477.90013605.377 Target (foej; 13605.377 MD, 7477.900' ND, 2189' FNL 83968' FF1.; Sec14T11N-aoaE iHQ~Li BUFtTO1V RKB: C[?2mi3 ra ;23~Ert2 (CULdiE: 3v[y?15.9°: Plan: CD2.60P817nIp04 " N°nhincy'ASP Y: 5976104 ~t74C, .. Sperry Drilling Services ~n„~'AS7=x: >rt>a~a7n; sECrlor4 DETaas SHL - 2162ft FNL & 1491ftFEL; Sec02-T'I Begin Dir - 3.00°DLS, 200.000 ft MD, 200.000 ft ND Start Sail-X1.155° , 2238.497 ft MD,1872.897 ft ND 95/8" Csg Pt: 3310.343 ft MD, 2390.000 tt ND c 0 0 0 N t L ~' O Z L 3 O N Begin Drop; 4.00° DLS,180° TF0,12200.000' MD, 6678.742' TVD Sail; 55.000°INC, 12353.875' MD, 6760.068' ND Sec MD Inc A~ TND +WS •FJ-V11 DLeg TFace 7,/Sec Target 1 37.000 0.000 0.0000 37.000 0.000 0.000 0.00 0.0000 0.000 2 200.000 0.000 0.0000 200.000 0.000 0.000 0.00 0.0000 0.000 3 2238.497 61.155193.1214 1872.897 4!62654 -224.396 3.00193.1214 962.654 4 12200.000 61.159193.1214 6678.742.9460.401.2205.229 0.00 0.0000 9460.401 5 12353.875 55.000193.7214 6760.06841587.533-2234.864 4.00180.0000 9587.533 6 13605.377 55.000793.1214 7477.90010585.938-2467.593 0.00 0.000010585.938 Target (Tce);13605.377' MD, 7477.900' ND, 2189' FNL & 3968' FEL; Sec14-711 N-R04E casnc een>ws ao nu Mo ~ sw 1 ZRD.000 33'103A3 958' 9N8 z a~3oam tznoam r ~ L3 ~~* f'L ' ~ ~-", ~~, fT_~ .w .. ~ c_r: -0000 -2000 0 2000 4000 6000 8000 10000 12000 West(-)/East(+) (2000 ft/in) • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 99501 • 11 q1 DATE ~~ Y~` ~ 61 PAY TO THE ~~ ~~ Ll L~~S K~ / ~C J~ ~`~~/, OO , t ORDER OF ~/l - / `---C "' `~ ~ d~ C /5 ~ Ooh ~~,.: ~s + G~~ ~ CHASE Chase Manhattan sank usn, N.n. V211d Up TO 5000 DOIIdfS ' I00 Whlto Clary Center Dr., NcwnrF. DC 19111 MEMO C ~~ -(oO ~ ""`._. ~~~~~'..._ i~.".'" ~:03LLOOL44~:2L847L9079276ii'L~OL • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO SE INCLUDED IN TR~A^N,,S~MITTAL LETTER WELL NAME (---~ ~ ~~~'~ PTD# ~~~~~~~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing welt , 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 (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH)_ ' G~~ ~' (.~f ~~ and API number (50'/~'~ ~ 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the 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. 7l -'7© Rev: 04!01/OS C\j ody\transm ittal_checklist L. PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLVILLE RN UNIT CD2-60 Program SER Well bore seg ^ PTD#:2050680 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached_______________________________ Yes- .___ -- - - -- 2 Lease number appropriate_ _ _ - - - - . - . - , _ - - _ . Yes _ - - _ _ - -Surface location and top-prod interval in ADL 380075, TD in_ADL_380077, - _ _ _ _ 3 Un[quewellnameandnumber- ----- ---------------------- - -- Yes- ---- -- -- -- ----- -- -------- -- --- --- ------ - ~ - --------- --- 4 Well located in a_defnedpool__-__--_-_______________--____,______ Yes_ ___--Colville_Riverlln~Alpine Oil Pool governed_byCO443A.__._______---._____________-.___ 5 Well located proper distance-f[om drilling unit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ - .More than 500 feet f[omthe exterior_boundary of the affected area. _ - _ _ - - _ _ _ _ _ - _ _ - _ _ , _ _ _ _ _ _ . _ _ _ 6 Well located proper distance from otherwells- - - - - - - - - - - - - - - Yes More than 500 lineal feet of_anotherA_Ip_ine Oil Pool development well._ , . 7 Sufficient acreage available in drilling unit - - - - Yes - - - - - - - - - 8 If_deyiated,is_wellboreplat_included__--_____________________________ Yes. __----.__-__._ - - --- 9 Operator only affected party- - - - - - - Yes - - - - - - - - -- -- 10 Ope[atorhas_appropriate-bond inforCe_- -- -- -- ~-- ------ ---- - - Yes- ------ --- -- ------ -- -------------- ----------- -------------- -- 11 Permit_canbeissuedwithoutconseryationorder______ _______________ ____ Yes- __----._________-__--_--_.____. ------------------------------------------- Appr Date 12 Permikcan be issued without administrativ_e_appr_oval _ _ - - _ - _ _ _ , Yes - --------------------- SFD 51412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-sfrataauthorizedby_InjectionOrde[#(puk1O#in-comments)_(F4r- NA__ ________________-_-._______________________-______--_--__________-___-- 15 All wells-wikhin1l4.milearea.ofreyiewidentified(Fo[serv_icewellgnly)_______________ NA_ _______-_____.__.____________________--____._-___-__--_.-_--_--_-._.---_-_ 16 Pre-produced injector; duration of pre production Less than_ 3 months_(For service well only) _ - NA_ - - - , . _ _ _ - - _ _ . _ - _ _ . ------------------------------------ 17 ACMP-Finding of Consistency_hasbee_nissuedforthisp[oject-------------------- NA__ ____-___-___________--__--__-________-__-________-______------_ -__---_ Engineering 18 Conductor string.provided - - - - - - Yes - - - - - - - - - - - - - - 19 Surface casing_protectsallknownUSDWS_---.-.-.___--_--_.____ NA__ -___--NOaquifers,_perA1O 1$Aconclusion$______________________________________--.._, 20 CMT.vol_adequ_ate_to circulate_on conductor& surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ .. _ _ - - _ _ _ _ _ _ _ _ - - _ - -------------------------------------------------------- 21 CMT.vol-adequa#e,to tie-in long string tosurf csg- - - - _ _ - - - . No- _ _ _ _ _ - -All hydrocarbon zones will be_covered. Annular disposal may_be_proposed, _ _ - _ _ _ - . 22 CMT,willcoverallknown-productiyehorizoris____________________________ No__ ______Open-hole completionpl_anned,-__-_.___-__----.--.-__--_-.--._____._________ 23 Casing designs adequate for C,T,B&_permafrost__---_--____----.-- -- Yes- ------------------------------------------------------------------ ----- 24 Adequate tankage_or reserve pit - _ - _ _ - - _ _ . - _ _ _ Yes _ _ . Rig is_equipped with steel_pits. No reserve_pitplanned, All waste to approved annulus or disposal wells.. _ - - - 25 If_a_re-drill, has-a 10-403 for abandonment been approved . - - _ - _ - - NA- _ _ - - - _ - - _ -- -- - -- 26 Adequate!+vellbore separationproposed _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ . - - _ -Proximity analysis performed. Traveling cylindet path calculated: Gyros possible, - . _ _ _ _ _ _ _ _ _ - _ _ - - _ 27 If_dive~terrequired,doesitmeekregulations_____________________-______._ NA__ _--_--piyerterwaiverhas_beengiyenforCl)2_pad.____----,_______-___._____ ---------------- Appr Date 28 Drilling fluid_ program schematic-& equip listadequate- - - - - - , _ - - - _ .. _ - - Yes _ _ _ _ _ _ -Maximum expected formation pressure 8,7_EMW._ MW planned 9.0 - 9.3 ppg.. _ _ _ _ _ - - . TEM 514!2005 29 BOPEs, do they meet_regulation - - - Yes - - - - - - - - - - - - q `!~/~ ~r t 30 BOPE_press rating appropriate; test ko_(put prig in cgmments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ _ - - _ _ MASP calculated at 2620psi, 3500-psi_appropriate. CP_AI usually_tests to 5900_psi. _ - _ _ _ _ _ _ _ _ - _ - - _ _ _ _ / 31 Choke_manifgldcomplieswlAPl_RP-53(May84)___________________________ Yes_ --.__._____ -------------------------------------------------------------- 32 Workwiiloccurwi#houtoperationshutdown_______________________________ Yes- _____.___ -- -- - -- - 33 Is pre&ence-of H2S gasprobable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ .. _ _ _ _ _ _ _ _ - - No. _ _ _ _ _ - H2S has n9tbeen repgrted at Alpine. _ Rig is equipped with sensors and_alarms._ _ . _ _ . _ _ _ _ _ _ _ _ , . _ _ _ _ - 34 Mechanical_condition of wells within AOR verified (Forservice well only) _ . - _ _ _ _ - Yes _ _ - - - - - There_ are no reservoir-penetrakioos within 114 mile of-CD2-60. _ _ _ - - _ _ , _ _ _ _ Geology 35 Perrnit_canbeissuedwlohydrogen_sulfidemeasu[es_---„___________________ Yes_ __-__--____________----._---_______- - -- ---- - 36 Data_presented on potential overpressure zones _ - _ - - _ _ _ . - Yes Expected reservoirpressure is 8,7-ppg EMW; will be drilled with 8.8 - 9.3 ppg mud.. _ - - - . - _ . - - Appr Date 37 Seismic analysis of shallow gas-zones.. _ - - --- NA - - - - - SFD 514/2005 38 Seabed condition suryey_(rf_ offsho[e) - - _ _ - _ _ _ _ - - _ _ _ - NA - - ----- -- -- - ---- 39 .Contact name/phoneforweekly progress_reports[exploratoryonlyj ________________ NA-_ ______-__--_-___-__.____-______-_________---____-__--_--_ Geologic Engineering Public Commissioner: Date: Commi ssioner: Date Commissioner Date / ~ ~~~'~~~~~~I41Ge~li,/ ~ ~f~'®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 fife. To improve the readability of the Well Nistory file and 10 simplify finding information, information of this nature is accumulated at the end of the fife under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 10 13:54:32 2005 Reel Header Service name .............LISTPE Date .....................05/08/10 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/08/10 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • boa-o~~ 13zg~ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: CD2-60 API NUMBER: 501032051100 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 10-AUG-05 JOB DATA MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0003753059 MW0003753059 MW0003753059 LOGGING ENGINEER: M. HANIK R. KRELL R. KRLLL OPERATOR WITNESS: D. MICKEY D. LUTRICK D. MICKEY MWD RUN 7 JOB NUMBER: MW0003753059 LOGGING ENGINEER: R. KRELL OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 2162 FSL: FEL: 1491 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.37 GROUND LEVEL: 15.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~ i ' BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3276.0 2ND STRING 6.125 7.000 14331.0 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 EXITS THE CD2-60 PB1 WELLBORE AT 11760'MD/6450'TVD. 4. MWD RUNS 1-3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LTTHO- DENSITY (SLD), PRESSURE WHILE DRILLING (PWD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 4 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA. MWD RUNS 6 & 7 COMPRISED DIRECTIONAL, DGR, EWR4, AND PWD. RUN 7 ALSO INCLUDED AT-BIT INCLINATION (ABI) POROSITY DATA ARE NOT INCLUDED FOR THIS WELL SECTION. THOSE DATA MAY BE FOUND IN THE CD2-60 PB1 PRESENTATION. 6. THE MWD TOOL STRING WAS LOST IN HOLE DURING RUN 5. ALL RUN 5 DATA ARE REAL-TIME. THERE ARE 3 UNEXPLAINED DATA GAPS FOR SEDP/SFXE AND 1 FOR SGRC WITHIN THE RUN 5 INTERVAL. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 8. MWD RUNS 1-7 REPRESENT WELL CD2-60 WITH API#: 50-103-20511-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18695'MD/7376'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.......05/08/10 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 3249.0 FET 3260.0 RPD 3260.0 RPM 3260.0 RPS 3260.0 RPX 3260.0 ROP 3286.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD all bit runs merged. STOP DEPTH 18630.0 18637.0 18637.0 18637.0 18637.0 18637.0 18695.0 BIT RUN NO MERGE TOP 4 3249.0 5 11121.5 6 11760.0 7 14341.0 REMARKS: MERGED MAIN PASS. MERGE BASE 11121.5 11760.0 14341.0 18695.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3249 18695 10972 30893 3249 18695 ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR 1 J 0.06 2181.45 40.36 445.07 0.05 1795.27 0.06 1808.81 0.1 2000 0.1 2000 0.15 214.84 First Reading For Entire File..........3249 Last Reading For Entire File...........18695 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/10 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.......05/08/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER J 162.628 30818 3286.5 18695 107.447 30702 3249 18630 6.30186 29387 3260 18637 6.54247 29387 3260 18637 11.6036 29387 3260 18637 10.9563 30674 3260 18637 1.38624 30674 3260 18637 FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3249.0 11083.5 RPX 3260.0 11076.0 RPS 3260.0 11076.0 RPM 3260.0 11076.0 RPD 3260.0 11076.0 FET 3260.0 11076.0 ROP 3286.5 11121.5 LOG HEADER DATA DATE LOGGED: 15-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11121.0 TOP LOG INTERVAL (FT) 3286.0 BOTTOM LOG INTERVAL (FT) 11121.0 BIT ROTATING SPEED (RPM}; HOLE INCLINATION (DEG MINIMUM ANGLE: 56.6 MAXIMUM ANGLE: 65.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMB ER DGR DUAL GAMMA RAY 61497 EWR4 ELECTROMAG. RESIS. 4 10469972 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3276.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 36..0 MUD PH: 9.0 MUD CHLORIDES (PPM): 200 FLUID LOSS {C3) 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.030 124.0 MUD FILTRATE AT MT: 2.600 68.0 MUD CAKE AT MT: 3.300 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3249 11121.5 7185.25 15746 3249 11121.5 ROP MWD040 FT/H 13.43 404.01 216.306 15671 3286.5 11121.5 GR MWD040 API 46.26 207.47 109.931 15670 3249 11083.5 RPX MWD040 OHMM 0.54 1795.27 6.51369 15633 3260 11076 RPS MWD040 OHMM 0.1 1808.81 6.41555 15633 3260 11076 RPM MWD040 OHMM 0.1 1809.23 6.6162 15633 3260 11076 RPD MWD040 OHMM 0.1 1869.71 7.10763 15633 3260 11076 FET MWD040 HOUR 0.15 66.16 0.656495 15633 3260 11076 • • First Reading For Entire File..........3249 Last Reading For Entire File...........11121.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/10 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.......05/08/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 11076.5 11760.0 RPD 11076.5 11760.0 GR 11084.0 11760.0 ROP 11122.0 11759.5 LOG HEADER DATA DATE LOGGED: 18-JUN-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME}; Memory TD DRILLER (FT} 11760.0 TOP LOG INTERVAL (FT) 11121.0 BOTTOM LOG INTERVAL (FT) 11760.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.5 MAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 61497 EWR4 ELECTROMAG. RESIS. 4 10469972 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT); 3276.0 • • BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 38.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.700 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.060 140.0 MUD FILTRATE AT MT: 1.900 85.0 MUD CAKE AT MT: 2.400 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPD MWD050 OHMM 4 1 68 12 4 , FET MWDO50 HOUR 4 1 68 16 5 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11076.5 11760 11418.3 1368 11076.5 11760 ROP MWD050 FTjH 7.63 280.26 124.944 1276 11122 11759.5 GR MWD050 API 53.43 174.53 106.327 1292 11084 11760 RPD MWD050 OHMM 6.81 11.26 8.10136 1287 11076.5 11760 FET MWD050 HOUR 0.27 25.3 2.54912 1287 11076.5 11760 First Reading For Entire File..........11076.5 Last Reading For Entire File...........11760 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08j10 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.......05/OS/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 11705.5 14286.0 RPS 11705.5 14286.0 RPM 11705.5 14286.0 ROP 11760.0 14341.0 GR 11760.5 14294.0 FET 11760.5 14286.0 RPD 11760.5 14286.0 LOG HEADER DATA DATE LOGGED: 27-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14341.0 TOP LOG INTERVAL (FT) 11760.0 BOTTOM LOG INTERVAL (FT) 14341.0 BIT ROTATING SPEED {RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.4 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3276.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 38.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .830 132.8 MUD FILTRATE AT MT: 1.420 70.0 MUD CATtE AT MT : 1. 8 0 0 7 0. 0 i NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11705.5 14341 13023.3 5272 11705.5 14341 ROP MWD060 FT/H 0.06 378.71 118.946 5163 11760 14341 GR MWD060 API 52.52 445.07 149.804 5068 11760.5 14294 RPX MWD060 OHMM 1.68 12.78 4.89076 5160 11705.5 14286 RPS MWD060 OHMM 1.66 13.14 5.26159 5160 11705.5 14286 RPM MWD060 OHMM 1.66 20.43 6.18532 5160 11705.5 14286 RPD MWD060 OHMM 1.82 21.79 6.12809 5052 11760.5 14286 FET MWD060 HOUR 0.42 214.84 0.976677 5052 11760.5 14286 First Reading For Entire File..........11705.5 Last Reading For Entire File...........14341 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 • . Date of Generation.......05j08/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 14286.5 18637.0 RPM 14286.5 18637.0 RPS 14286.5 18637.0 RPX 14286.5 18637.0 FET 14286.5 18637.0 GR 14294.5 18630.0 ROP 14341.5 18695.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 18695.0 TOP LOG INTERVAL (FT) 14341.0 BOTTOM LOG INTERVAL (FT) 18695.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.7 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178513 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 14331.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 42.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 82000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .060 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .030 158.0 MUD FILTRATE AT MT: .090 69.0 MUD CAKE AT MT: .070 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): $# TOOL STANDOFF (IN): EWR FREQUENCY {HZ): • #~ REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14286.5 18695 16490.8 8818 14286.5 18695 ROP MWD070 FT/H 0.61 2181.45 97.4517 8708 14341.5 18695 GR MWD070 API 40.36 132.48 78.3728 8672 14294.5 18630 RPX MWD070 OHMM 0.05 26.24 6.75561 8702 14286.5 18637 RPS MWD070 OHMM 0.06 271.53 7.53176 8702 14286.5 18637 RPM MWD070 OHMM 1.89 2000 23.7218 8702 14286.5 18637 RPD MWD070 OHMM 2.47 2000 21.0958 8702 14286.5 18637 FET MWD070 HOUR 0.43 128.05 2.763 8702 14286.5 18637 First Reading For Entire File..........14286.5 Last Reading For Entire File...........18695 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/08/10 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................05/08/10 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 r a Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug 09 15:11:13 2005 Reel Header Service name .............LISTPE Date .....................05/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................05/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA #13~8f Scientific Technical Services Scientific Technical Services CD2-60 PB1 501032-051170 ConocoPhillips Alaska, Inc. Sperry Drilling Services 09-AUG-05 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0003753059 MW0003753059 LOGGING ENGINEER: M. HANIK R. KRELL OPERATOR WITNESS: D. MICKEY D. LUTRICK SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 2162 FSL: FEL: 1491 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.37 GROUND LEVEL: 15.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3276.0 2ND STRING 3RD STRING PRODUCTION STRING ~ mss- a~~ 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 WA5 A PLANNED PILOT HOLE. 4. THE MAIN CD2-60 WELLBORE EXITS FROM THIS WELLBORE AT 11760'MD/6450'TVD. 5. MWD RUNS 1-3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 6. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO- DENSITY (SLD), PRESSURE WHILE DRILLING (PWD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 4 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA. 7. THE MWD TOOL STRING WAS LOST IN HOLE DURING RUN 5. ALL RUN 5 DATA ARE REAL- TIME. 8. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPSjVENDOR MEETING HELD ON 26 SEPTEMBER 2001. 9. MWD RUNS 1-5 REPRESENT WELL CD2-60 PB1 WITH API#:50-103-20511-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13543'MD/7444'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 SPACTNG). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.6 - 11.0 PPG MUD SALINITY: 200-400 PPM CHLORIDES L FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD • 25,000 PPM CHLORIDES Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3249.0 13501.5 NCNT 3260.0 11031.0 RPX 3260.0 11076.0 RPS 3260.0 11076.0 RPM 3260.0 11076.0 RPD 3260.0 13493.5 FET 3260.0 13493.5 FCNT 3260.0 11031.0 PEF 3260.0 11045.0 NPHI 3260.0 13447.5 RHOB 3278.5 13461.0 DRHO 3278.5 11045.0 ROP 3286.5 13543.0 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 4 3249.0 11121.5 MWD 5 11121.5 13543.0 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 ROP MWD FT/H 4 1 68 4 2 • GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD GjCM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3249 13543 8396 20589 3249 13543 ROP MWD FT/H 6.6 404.01 194.367 20514 3286.5 13543 GR MWD API 46.26 437.78 116.111 20347 3249 13501.5 RPX MWD OHMM 0.54 1795.27 6.51369 15633 3260 11076 RPS MWD OHMM 0.1 1808.81 6.41555 15633 3260 11076 RPM MWD OHMM 0.1 1809.23 6.6162 15633 3260 11076 RPD MWD OHMM 0.1 1869.71 6.93844 20277 3260 13493.5 FET MWD HOUR 0.15 66.16 0.781267 20277 3260 13493.5 NPHI MWD PU-S 14.72 56.27 30.7963 20277 3260 13447.5 FCNT MWD CNTS 495.01 2258.25 990.482 15543 3260 11031 NCNT MWD CNTS 99614.3 168111 128839 15543 3260 11031 RHOB MWD G/CM 1.905 2.892 2.40189 20241 3278.5 13461 DRHO MWD G/CM -0.058 0.246 0.0451823 15534 3278.5 11045 PEF MWD BARN 1.26 11.42 2.85366 15571 3260 11045 First Reading For Entire File..........3249 Last Reading For Entire File...........13543 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/09 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.......05/08/09 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY • • VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3249.0 11083.5 PEF 3260.0 11045.0 RPM 3260.0 11076.0 RPD 3260.0 11076.0 FET 3260.0 11076.0 NPHI 3260.0 11031.5 FCNT 3260.0 11031.5 NCNT 3260.0 11031.5 RPX 3260.0 11076.0 RPS 3260.0 11076.0 DRHO 3278.5 11045.0 RHOB 3278.5 11045.0 ROP 3286.5 11121.5 LO G HEADER DATA DATE LOGGED: 15-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11121.0 TOP LOG INTERVAL (FT) 3286.0 BOTTOM LOG INTERVAL (FT) 11121.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.6 MAXIMUM ANGLE: 65.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 61497 EWR4 ELECTROMAG. RESIS. 4 10469972 SLD STABILIZED LITHO DEN 161646 CTN COMP THERMAL NEUTRON 10603702 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3276.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 36.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 6.4 RESISTIVITY {OHMM) AT TEMPERATURE (DEGF} MUD AT MEASURED TEMPERATURE (MT) 1.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.030 124.0 MUD FILTRATE AT MT: 2.600 68.0 MUD CAKE AT MT: 3.300 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 • Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 GjCM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3249 11121.5 7185.25 15746 3249 11121.5 ROP MWD040 FT/H 13.43 404.01 216.306 15671 3286.5 11121.5 GR MWD040 API 46.26 207.47 109.931 15670 3249 11083.5 RPX MWD040 OHMM 0.54 1795.27 6.51369 15633 3260 11076 RPS MWD040 OHMM 0.1 1808.81 6.41555 15633 3260 11076 RPM MWD040 OHMM 0.1 1809.23 6.6162 15633 3260 11076 RPD MWD040 OHMM 0.1 1569.71 7.10763 15633 3260 11076 FET MWD040 HOUR 0.15 66.16 0.656495 15633 3260 11076 NPHI MWD040 PU-S 14.72 56.27 31.8022 15544 3260 11031.5 FCNT MWD040 CNTS 495.01 2258.25 990.488 15544 3260 11031.5 NCNT MWD040 CNTS 99614.3 168111 128839 15544 3260 11031.5 RHOB MWD040 G/CM 2.115 2.634 2.38677 15534 3278.5 11045 DRHO MWD040 G/CM -0.058 0.246 0.0451823 15534 3278.5 11045 PEF MWD040 BARN 1.26 11.42 2.85366 15571 3260 11045 First Reading For Entire File..........3249 Last Reading For Entire File...........11121.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/09 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.......05/08/09 • • Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 11032.0 13447.5 RHOB 11045.5 13461.0 FET 11076.5 13493.5 RPD 11076.5 13493.5 GR 11084.0 13501.5 ROP 11122.0 13543.0 LOG HEADER DATA DATE LOGGED: 17-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13543.0 TOP LOG INTERVAL (FT) 11121.0 BOTTOM LOG INTERVAL (FT) 13543.0 BTT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.5 MAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 61497 EWR4 ELECTROMAG. RESIS. 4 10469972 SLD STABILIZED LITHO DEN 161646 CTN COMP THERMAL NEUTRON 10603702 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3276.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 38.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.700 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.060 140.0 MUD FILTRATE AT MT: 1.900 85.0 MUD CAKE AT MT: 2.400 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): #• REMARKS: C Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPD MWD050 OHMM 4 1 68 12 4 FET MWD050 HOUR 4 1 68 16 5 NPHI MWD050 PU-S 4 1 68 20 6 RHOB MWD050 G/CM 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11032 13543 12287.5 5023 11032 13543 ROP MWD050 FT/H 6.6 280.26 123.38 4843 11122 13543 GR MWD050 API 48.09 437.78 136.817 4677 11084 13501.5 RPD MWD050 OHMM 2.24 13.95 6.36891 4644 11076.5 13493.5 FET MWD050 HOUR 0.27 25.3 1.20129 4644 11076.5 13493.5 NPHI MWD050 PU-S 15.43 45.66 27.4928 4733 11032 13447.5 RHOB MWD050 G/CM 1.905 2.892 2.45181 4707 11045.5 13461 First Reading For Entire File..........11032 Last Reading For Entire File...........13543 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/08j09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................05/08/09 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 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 2 11/7/05 AG DB C.A. PER K05146ACS 3 11/08/06 CZ GD PER K06058ACS 34 J Z 35 36 P r, 32 3 DR L SIV - 6 G) T12 T11 N Y J W_ 2 O ELI 6 5 0 V Lj VICINITY MAP (NTS) PLANT N O CD2 -01 CD2 -02 ASPC 0 CO2-03*CD2-04 N O CD2-05,CD2-06 r� CD2 -0700O2-08 6°03'35" D2-09 .CD2 -10 • CD2 -11 . CO2 -12 CD2 -13 0CD2-14 CD2 -15 *.CD2 -16 CD2 -17 00O2-18 CD2 -19 0CD2-20 CD2 -21 0 CD2 -22 LCM F CD2 -230 cD2-2a CD2 -250 C12-26 a CD -2 02-27: CD2 -28 PAD CD2 -29 . CD2 -30 CD2 -31 .CD2 -32 CD2 -33 00O2-34 D2-310 CD2 -36 CD2-37:CD2-38 LEGEND: DD2-39• 10' O PROPOSED CONDUCTOR CD2 -41 O.CD2-42 1 CD2 -430 • CD2 -44 • EXISTING CONDUCTOR CD2-45:CO2-46 CD2 -47: CD2 -48 NOTE: coz-a1 CD2 -50 02-51 • NO CHANGE TO CONDUCOTR LAYOUT CD2 -530 SINCE 4/9/2004. S CD2 -54 1)2-550 CD2 -56 CD2 -57 . CD2 -58 CD2 -59 0 CD2 -60 T E]KUUKPIK IMMFul. 139 E.51d Aw. - Andmm%Ala" 99503 - (907)2731590 Alpine Office (90]) 6]04739 Alpine Survey Office �.� ALPINE MODULE:CD20 UNIT: CD Cin®c®Phiips ALPINE PROJECT CD -2 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 01-02-05-1 05-27-1 CD—CD20-121 1 OF 3 3 REV I DATE I BY CK APP DESCRIPTION IREVI DATE IBYI CKIAPPI DESCRIPTION 0 5/29/01 G. D. J. Z. C. A. PER A01004ACS 6 4/13/06 CZ BD I C.A. PER K06058ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U. M. SEC.LINE 0/S PLAN WELL Y' X' LAT.(N) LONG.(W) FNL FEL GND PAD i* i* I* CD2 -1 5, 974,781 .09 371 681.81 70° 20' 21.594" 151 ° 02' 28.574" 1577' 1562' 8.7 15.9 CD2 -2 5,974,770.84 371 682.85 70° 20' 21.493" 151' 02' 28.539" 1587' 1561' 8.7 15.9 CD2 -3 5,974,761.44 371 683.77 70° 20' 21.401" 151° 02 28.507 1597' 1560' 8.7 15.9 CD2 -4 5,974,751.48 371,684.73 70° 20' 21.303" 151° 02 28.474 1606 1559 8.7 15.9 CD2 -5 5,974,741.17 371 685.60 70° 20' 21.202" 151 ° 02' 28.443" 1617' 1558' 8.7 15.9 CD2 -6 5,974,731.13 371 686.73 70° 20' 21.103" 151 ° 02' 28.406' 1627' 1556' 8.7 15.9 CD2 -7 5,974.721.46 371 688.17 70° 20' 21.008" 151' 02' 28.359" 1636' 1555' 1 8.7 15.9 CD2 -8 5, 974 711.45 371 688.72 70° 20' 20.910" 151' 02' 28.337" 1646' 1554' 8.7 15.9 CD2 -9 5,974,701.48 371 690.14 70° 20' 20.812" 151 ° 02 28.291 1656' 1552' 8.7 15.9 CD2 -10 5,974,691.64 371 691.07 70° 20' 20.716" 151 ° 02' 28.259" 1666' 1551' 8.7 15.9 CD2 -11 5,974,681.62 371 692.02 70° 20' 20.617" 151 ° 02' 28.226" 1676' 1550' 8.7 15.9 CD2 -12 5,974,671.61 371 692.98 70° 20' 20.519" 151 ° 02' 28.193" 1686' 1549' 8.7 15.9 CD2 -13 5,974,661.90 371,694.26 70° 20' 20.424" 151° 02' 28.151" 1696' 1548' 8.7 15.9 CD2 -14 5,974,652.12 371,695.50 70° 20' 20.328" 151° 02' 28.110" 1706' 1546' 8.7 15.9 CD2 -15 5,974,641.66 371,696.24 70° 20' 20.225" 151° 02' 28.083" 1716' 1545' 8.7 15.9 CD2 -16 5,974,631.95 371,697.39 70° 20' 20.130" 151° 02' 28.044" 1726' 1544' 8.7 15.9 CD2 -17 5,974,622.10 371,698.48 70° 20' 20.033" 151° 02' 28.008" 1736' 1543' 8.7 15.9 CD2 -18 5,974,612.15 371 699.38 70° 20' 19.935" 151 ° 02' 27.976" 1746' 1542' 8.7 15.9 CD2 -19 5,974,602.64 371 700.50 70° 20' 19.842" 151 ° 02' 27.939" 1755' 1541' 8.7 15.9 CD2 -20 5,974,592.18 371 701.77 70° 20' 19.739" 151 02' 27.897" 1765' 1539' 8.7 15.9 CD2 -21 5,974,582.28 371 702.51 70° 20' 19.642" 151' 02' 27.870" 1775' 1 1538' 8.7 1 15.9 CD2 -22 5,974572.39 371,704.15 70° 20' 19.545" 151° 02 27.817 1785 1536' 8.7 1 15.9 CD2 -23 5,974,562.21 371,704.52 70° 20' 19.445" 151° 02 27.801 1795 1536' 8.7 15.9 CD2 -24 5,974,552.30 371 705.92 70° 20' 19.348" 151 ° 02 27.756 1805' 1534' 8.7 15.9 CD2 -25 5,974,542.33 371 706.81 70° 20' 19.250" 151 ° 02 27.725 1815' 1533 8.7 15.9 CD2 -26 5,974,532.34 371 707.80 70° 20' 19.152" 151° 02 27.691 1825' 1532' 8.7 15.9 CD2 -27 5,974,522.31 371,709.10 70° 20' 19.053" 151° 02 27.648 1835 1531 8.7 15.9 CD2 -28 5,974,512.60 371 709.87 70' 20' 18.958" 151 ° 02 27.620 1844' 1530' 8.8 15.9 CD2 -29 5, 974 502.63 371 711.26 70° 20' 18.860" 151' 02' 27.575" 1855' 1528' 8.8 15.9 CD2 -30 5,974,492.75 371 712.00 70' 20' 18.763" 151' 02' 27.548" 1865' 1527' 8.8 15.9 CD2 -31 5,974,482.74 371,713.04 70° 20' 18.665" 151° 02 27.513 1875 1526' 8.8 15.9 CD2 -32 5,974,472.57 371 714.18 70° 20' 18.565" 151 ° 02 27.474 1885' 1525 8.8 15.9 CD2 -33 5,974,463.34 371,715.28 70° 20' 18.475" 151' 02 27.438 1894 1523 8.8 15.9 CD2 -34 5,974,452.65 371 716.13 70° 20' 18.370" 151 ° 02' 27.407" 1905' 1522' 8.8 15.9 CD2 -35 5,974,442.90 371 717.49 70° 20' 18.274" 151 ° 02' 27.363" 1915' 1521' 8.8 15.9 CD2 -36 5,974,433.20 371 718.42 70° 20' 18.179" 151 ° 02 27.331 1924 1520 8.7 15.9 CD2 -37 5,974,423.05 371,719.40 70° 20' 18.079" 151' 02 27.297 1934 1519' 8.7 15.9 CD2 -38 5,974,413.52 371 720.66 70° 20' 17.986" 151' 02 27.256 1944' 1517' 8.7 15.9 CD2 -39 5,974,403.28 371 721.83 70° 20' 17.885" 151° 02' 27.216' 1954' 1516' 8.7 15.9 CD2 -40 5,974,393.27 371,722.68 70° 20' 17.787" 151° 02' 27.187" 1964' 1515' 8.7 15.9 CD2 -41 5,974,383.33 371 723.84 70° 20' 17.689" 151 ° 02' 27.148" 1974' 1514' 8.7 15.9 CD2 -42 5,974,373.69 371 724.77 70° 20' 17.595" 151° 02 27.116' 1984' 1513' 8.7 15.9 CD2 -43 5 974 363.45 371 725.60 70° 20' 17.494" 151' 02 27.087 1994 1512 8.7 15.9 CD2 -44 5,974,353.42 371 726.94 70° 20' 17.396" 151 ° 02' 27.042" 2004' 1510' 8.6 15.9 CD2 -45 5,974,344.11 371 728.07 70° 20' 17.304" 151 ° 02 27.005 2013' 1509' 8.6 15.9 CD2 -46 5,974,333.52 371 729.06 70° 20' 17.200" 151 ° 02' 26.971 2024' 1508' 8.6 15.9 CD2 -47 5,974,323.53 371 730.13 70° 20' 17.102" 151 ° 02 26.934 2034 1506 8.6 15.9 CD2 -48 5,974,313.77 371,731.19 70° 20' 17.006" 151° 02 26.898 2043 1505' 8.6 15.9 CD2 -49 5,974,303.80 371 732.05 70° 20' 16.908" 151' 02 26.868 2053' 1504' 8.5 15.9 CD2 -50 5,974,293.84 371,733.00 70° 20' 16.811" 151° 02 26.836 2063' 1503 8.5 1 15.9 CD2 -51 5,974,283.88 371,734.28 70° 20' 16.713" 151° 02 26.793 2073 1502 8.5 15.9 CD2 -52 5,974,274.18 371 735.18 70' 20' 16.618" 151 ° 02 26.762' 2083' 1501' 8.5 15.9 CD2 -53 5,974,264.07 371,736.31 70° 20' 16.518" 151° 02 26.724 2093 1499 8.5 15.9 CD2 -54 5,974,254.19 371 737.50 70° 20' 16.421" 151° 02 26.684 2103 1498 8.5 15.9 CD2 -55 5,974,244.05 371,738.44 70° 20' 16.322" 151° 02 26.652 2113' 1497' 8.5 15.9 CD2 -56 5,974,234.27 371 739.42 70° 20' 16.226" 151 ° 02 26.618 2123' 1496' 8.5 15.9 CD2 -57 5,974,224.26 371 740.55 1 70° 20' 16.128" 1 151 ° 02' 26.580" 2133' 1494' 8.5 15.9 CD2 -58 5,974,214.18 371 741.60 1 70° 20' 16.029" 1 151 ° 02 26.544 2143 1493 8.5 15.9 CD2 -59 5,974,204.48 371 742.95 1 70° 20' 15.934" 1 151' 02' 26.544" 2152' 1492' 8.5 15.9 CD2 -60 5,974,194.47 371,743.77 1 70° 20' 15.835" 1 151° 02 26.471' 2162' 1491' 8.5 15.9 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) 3. * INDICATES DATA PER LOUNSBURY AS -BUILT. 1r/ ALPINE MODULE:CD20 UNIT: CD ConocoPhillips ALPINE PROJECT CD -2 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 01-02-05-1 05-27-01 CE-CD20-121 2 of 3 6 REV I DATE I BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 4/13/0 AG I BD C.A. PER K03074ACS 1 6 11/08/0 CZ GD C. A. PER K06058ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER JR. DWG. CE-CD20-102, SHEET 1, REV 0. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, JUNE 2001. 4. CONDUCTOR CD2-35 WAS AS-BUILT 3/12/98 BY LOUNSBURY AND ASSOC., CONDUCTORS CD2-23 AND CD2-39 WERE AS-BUILT 3/22/00 BY LOUNSBURY. AS-BUILT COORDINATES ARE FROM DWG. NO. CE-CD20-664D2, SHEET 2, REV. 1. 5. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD2-37, CD2-32 & CD2-24, 05/06/01, FB 2001-14 PGS 76-78; CONDUCTOR CD2-49, 5/07/01, FB2001-15 PG 2; CONDUCTOR CD2-33, 5/08/01, FB 2001-15 PGS 11-13; CONDUCTORS CD2-05, CD2-15 & CD2-50, 5/09/01, FB 2001-15 PGS 21-22; CONDUCTORS CD2-13, CD2-14, CD2-16, CD2-17 & CD2-19, 9/09/01, FB 2001-25 PGS 12-13; CONDUCTORS CD2-25, CD2-26, CD2-28, CD2-36, CD2-45, CD2-47 & CD2-48, 10/04/01, FB 2001-26 PGS 36-38; CD2-34, 10/12/01, FB 2001-27 PGS 12-13; CONDUCTORS CD2-22 & CD2-38, 4/01/02, FB 2002-13 PG 44; CONDUCTOR CD2-29, 4/02/02, FB 2002-13 PG 51; CONDUCTORS CD2-30, CD2-40, CD2-44, CD2-51, CD2-53, CD2-55 & CD2-57, 4/09/02, FB 2002-15 PGS 2-5; CONDUCTORS CD2-41 & CD2-46, 4/19/02, FB 2002-16 PG 73; CONDUCTOR CD2-08, 4/27/02, FB 2002-17 PG 47; CONDUCTORS CD2-07, CD2-10, CD2-11, CD2-12, CD2-18 & CD2-20, 9/10/02, FB 2002-24 PGS 3-9; CONDUCTORS CD2-06, CD2-09, CD2-43, CD2-54, CD2-56 & CD2-58, 4/10/03, FB 2003-08 PGS 43-46; CONDUCTORS CD2-21 & CD2-27, 4/25/03, FB 2003-09 PGS 47-50; CONDUCTORS CD2-31 & CD2-521 5/14/03, FB 2003-09 PGS 73-74, CONDUCTORS CD 2-1 THRU CD2-4 & CD2-59, CD2-60, 4/9/04 LCMF FB 2004-06 PG. 29 & PGS. 33-38. SURVEYOR'S CERTIFICATE ���•�'���\�� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ♦♦♦ �� OF ALj ��� TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS ♦ " S/F- ♦ AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT �P•..•••••••••.. G;.• •••'09 �1� :♦ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. i 49th , ■= / """""""""/ .....:.. • .............. DATE: REGISTRATION N0. LS-8629 �.......�...............................::.�o. 19 / Janice M. Zilko Aff AlF •�. sT'•� No. LS-8629 .���`AV ♦♦♦4I1 pROFESS I ONA� \' •��♦♦♦• K U U K P I K P ,,.........- LCMFuc 119 E.61MAw. • Anchouga, Mata DOM • (W7)Z73-18M Alpine Office 6704739 (907) Alpine Survey Office �.� ALPINE MODULE:CD20 UNIT: CD C®n cePhillips ALPINE PROJECT CD-2 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. 01-02-05-1 05-27-01 I DRAWING NO: CE-CD20-121 PART: 3 OF 3 REV: 6
