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Home My WebLink About200-110 Im;.._? Project Well History File Coy.. °age 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. ~00-- / 1_O Well History File Identifier Organizing ~,~.:. [] RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVER, SIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other BEVERLY ROBIN VINCENT SHERY~WINDY Project Proofing BEVERLY ROBIN VINCENT SHERYL ~)/VINDY Scanning Preparation / x 30 = 30 + I~g~ TOTAL PAGES BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO IF NO ~N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES ~ NO III II!11111111 II III RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION a ❑ ❑ OR ❑ RECO e P Well REPORT AND LOG la. Well Status: oil ❑ 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: July 27, 2012 • • 200 - 110 / 312 - 141, 312 - 175 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 27, 1998 50 - 103 - 20250 - 01 - 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 373' FNL, 2425' FWL, Sec. 5, T11N, R5E, UM August 10, 2000 CD1 - 22A • Top of Productive Horizon: 8. KB (ft above MSL): 55.5' RKB 15. Field /Pool(s): 3324' FNL, 1319' FEL, Sec. 32, T12N, R5E, UM GL (ft above MSL): 45' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 212' FNL, 2319' FWL, Sec. 32, T12N, R5E, UM 2910' MD / 2910' TVD Alpine Oil Pool • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 385851 y 5975756 Zone 4 • 11500' MD / 6924' TVD ADL 25558, 25559 • TPI: x - 387414 y - 5978061 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 385808 y - 5981198 Zone 4 2308' MD / 2308' TVD 4716 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) 835' MD / 835' TVD - 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 30' 110' 30' 110' 24" 9 cu yds High Early Cold Set 9.625" 40# L -80 35' 3110' 35' 3110' 12.25" 542 sx Class G, 450 sx AS III, 60 sx ASI 1 7" 26# L -80 24' 8430' 24' 6931' 8.5" 477 sx Class G 24. Open to production or injection? Yes ❑ No El If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" 2994' none none E 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ NOV 0 1201Z DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6537' -8430' 25 bbls of 15.8 ppg Class G Neat pO G C 2910' -3360' 394 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No gi u Sidewall Cores Acquired? Yes ❑ No Q 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. SCANNED APR 1 9 2013 NONE Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE Submit original only l 7 3 Yea �\ -'v) �,�' , ##$79 ,h \ � . t a e 29. GEOLOGIC MARKERS (List all formations and rips encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 835' 835' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. (/t/ Contact: Weifeng Dai @ 263 -4324 Email: Weifena.Dai(conocoohillips.com Printed Name G. L. Alvord Title: Alaska Drilling Manager Signature Kok Phone 265 -6120 Date (-4 7l 3 l1Lpf t -- 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 10/2012 CD1 -22A Pre Rig Well Work Summary ' DATE' SUMMARYOPS 4/13/12 DRIFTED TBG WITH 1.75" S. ER & FB -BLB TO 8072' RKB. UNABLE ET DEEPER DUE TO 81 DEG DEVIATION. BRUSH XN -NIP @ 7654' RKB. IN PROGRESS. 4/14/12 MEASURED BHP @ 7845' RKB (MAX PSI= 4774.45/ TEMP= 158.35 F). SET 3.81" CAT SV @ 7654' RKB. PULLED GLV'S @ 3426 & 5528' RKB. IN PROGRESS. 4/15/12 PULLED ORIFICE © 7456' RKB (VLV PACKED WITH SCALE). SET 1" DV's @ 3426',5553' & 7456' RKB's. ATTEMPT TO PULL CAT SV © 7654' RKB. UNABLE TO GET PAST 7519' SLM DUE TO SCALE. BLED IA TO 1550 psi. IN PROGRESS. 4/16/12 BAIL FINE SANDS f/ 7513' - 7524' SLM. ATTEMPT TO PULL CAT SV. UNABLE TO LATCH DUE TO FILL. IN PROGRESS. 4/19/12 RU CTU, RUN #1 PERFORMED A FCO TO 7642' CTMD, 1:1 RETURNS, RUN #2 PULLED CAT SV @ 7642' CTMD, RUN #3 RIH, F/P TUBING TO 2500' WITH GOOD CLEAN DIESEL, READY FOR E- LINE 4/20/12 UNABLE TO RIH HOLE DUE TO ICE PLUG. LRS ABLE TO SQUEEZE 2 BBLS OF METHANOL DOWN HOLE BUT LOCKED UP TIGHT. 4/22/12 RU CTU, FOUND A BAD SPOT ON THE REEL, CUT 1085' OF COIL, RIH, ENCOUNTERED MULTIPLE ICE PLUGS 804', 903', 1282' CTMD, MADE IT THROUGH ICE, RIH TO 5000' CTMD, F/P TUBING, READY FOR E -LINE 4/23/12 RIH WITH A BAKER 3.70" O.D. CAST IRON CEMENT RETAINER AND SET @ DEPTH OF 7640' / MAKE UP A 2" O.D. CIRCULATION GUN LOADED 4' / 4 SPF / 0° PHASE / BH CHARGE AND PERF THE FIRST PUP JOINT ABOVE THE PACKER @ DEPTH OF 7571' -7575' / TUBING PSI DECREASED BY 250PSI AFTER SHOOTING HOLES. LRS PUMPED @ 1.5 BPM 2900 PSI DOWN TBG TAKING RETURNS UP IA. DECIDE TO SHOOT MORE HOLES, IN PROGRESS. 4/24/12 RIH AND SHOOT SECOND SET OF CIRCULATION HOLES FROM 7571' -7575' WITH 2" O.D. PERF GUN LOADED 4 SPF / 0° PHASE 4/25/12 ATTEMPTED TO SQUEEZE CEMENT THROUGH RETAINER AT 7640' MD. UNABLE TO STING INTO RETAINER AFTER SEVERAL ATTEMPTS. POOH TO INSPECT SINGER TOOL. FOUND A LARGE QUANTITY OF SCALE AND SOME FRAC SAND ON THE TOOL ASSY. FREEZE PROTECTED WELL. WILL RETURN IN AM FOR CLEAN OUT. JOB IN PROGRESS. 4/26/12 PERFORMED CLEANOUT TO TOP OF RETAINER USING GEL AND DIESEL. ATTEMPTED TO STING INTO RETAINER MULTIPLE TIMES. POOH INSPECTED STINGER. FOUND SCALE AND INDICATION OF SITTING INTO TRASH. WELL FREEZE PROTECTED. JOB IN PROGRESS. 4/27/12 MILLED RETAINER OUT IN 4 MINUTES AND PUSHEDTO 7936' CTMD. MILLED FROM 7500' TO 7640'. FREEZE PROTECTED WELL. HAD A HARDLINE SEAL FAILURE AT THE REEL 2 GALLONS WERE CAUGHT IN CONTAINMENT. JOB IN PROGRESS. 4/28/12 SET INFLATABLE RETAINER AT 7604' MD. PUMPED 25 BBLS OF 15.8 POUND CLASS G NEAT CEMENT BELOW RETAINER. PUMPED AN ADITIONAL 20 BBLS INTO IA. SPOTTED 20 BBLS OF CEMENT IN TBG WHILE PUH MAINTAINING 1:1 RETURNS. FREEZE PROTECTED WELL TO 2000' TVD. JOB COMPLETE. 5/3/12 TAGGED © 6291' SLM. PT IA @ 2000 PSI. PT TBG @ 2000 PSI. BOTH PASSED. TBG AND IA TESTS WAIVED BY JOHN CRISP @ 06:30 ON 5/3/2012 PULLED DV @ 5553' RKB. LRS TO CIRC MUD / DIESEL OVERNIGHT. IN PROGRESS. 5/4/12 SET DV @ 5553' RKB. VERIFY TBG x IA DIFFERENTIAL. READY FOR E -LINE. 5/13/12 CUT TUBING MID -JOINT AT 4192' USING RCT- 2937 -200 WITH EMA ANCHOR. T /IA/OA BEFORE CUT 650/450/50, AFTER CUT 500/500/50. IA TRACKED TUBING WHILE PRESSURING UP TO 1500 PSI TO VERIFY TxIA COMMUNICATION. 5/14/12 DEMOBILIZED FROM CD1 -22A. STAGED TRUCK FOR LONG TERM STORAGE IN CONTAINMENT AT CD2. • • ConocoPhiIIips Time Log & Summary WeiMew Web Reporting Report Well Name: CD1 - 22 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 7/7/2012 10:05:00 PM Rig Release: 7/16/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/02/2012 24 hr Summary Move MI Swaco Bali mill to CD1 -22B area, move motor complex to CD1 -22 area, move pits to CD1 -22 area, moved sub '228' onto CD4 road and the road failed. Crib hole in the road w/ 3" x 12" boards, lay 20 mats ahead of sub, drive rig up onto mats, move ahead '160'. start trucking /laying mats on roadway. 00:00 00:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving rig f/ CD4 to CD1. Rig released f/ CD4 -213B @ 2359 hrs 7/1/2012 for move to CD1 -22B (5.2 mile move). Peak move MI Swaco ball mill, maneuver to pad entrance, left pad @ 2300 7/1/2012 hrs, set down @ CD1 @ 0130 hrs 7/2/2012. 00:15 01:30 1.25 MIRU MOVE MOB P Moving pits and motors away from rig. Maneuver motor complex to in front of camp, attach tow bar. Sow went to CD2 to have weights installed. 01:30 01:45 0.25 MIRU MOVE SFTY P Pre job safety meeting. 01:45 03:30 1.75 MIRU MOVE MOB P Skid rig floor and pin. Raise windwalls and secure, Raise stomper feet. Peak hook up to motor complex w/ weighted SOW and Petunia @ 0300 hrs. Left CD4 pad @ 0330 hrs. 03:30 03:45 0.25 MIRU MOVE SFTY P Pre job safety meeting. Moving motor complex. 03:45 04:00 0.25 MIRU MOVE MOB P Move sub off of well CD4 -213B. Moving motor complex. 04:00 04:15 0.25 MIRU MOVE SFTY P Pre job safety meeting. Moving motor complex. 04:15 05:15 1.00 MIRU MOVE MOB P Remove lower wind walls on sub base. Moving motor complex. 05:15 05:30 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving complex's to CD1. Moving motor complex. 05:30 08:45 3.25 MIRU MOVE MOB P Motor complex arrived @ CD1 @ 0845 hrs, remove Tow bar. 08:45 09:00 0.25 MIRU MOVE MOB P Trucks and cat on trailer travel back to CD4. 09:00 09:15 0.25 MIRU MOVE RURD P Peak hook up to pit complex tow bar w/ weighted SOW and Petunia @ 0900 hrs. Left CD4 pad @ 0915 hrs. Page 1 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 12:45 3.50 MIRU MOVE MOB P Left CD4 pad @ 0915 hrs with pit complex. Travel 3.7 mile to intersection /stop sign @ CD4 /CD1 & CD2 intersection. Continue to prepare rig sub for move to CD1. PJSM @ noon crew change. 12:45 13:30 0.75 MIRU MOVE OTHR P Wait on air travel on runway. Check tires, and moving system of pits. Given clearance @ 1330 hrs to access runway with pit module. Need matting boards for road at the end of runway. Continue to prepare/wait to move rig sub to CD1. 13:30 15:30 2.00 MIRU MOVE MOB P Move pits from intersection /stop sign @ CD4 /CD1 & CD2 towards the runway. Need matting boards for road at the end of runway. Pits on CD1 pad @ 1530 hrs, Unhook trucks by 1600 hrs. Continue to prepare/wait to move rig sub to CD1. 15:30 16:00 0.50 MIRU MOVE MOB P Sub moving from the end of CD4 pad onto road @ 1530 hrs, travel 228' when the right front outside tire broke through the road - shifted to the right '10" (Road failed). 16:00 18:30 2.50 MIRU MOVE MOB P Evaluate situation (Rig supervisor, toolpusher, drilling supt), cut 3" x 12" cribbing, fill hole with cribbing, bring truckload of mats (20) to in front of sub. Loader operator start laying mats in front of rig. 18:30 18:45 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving from failed gravel road to matting boards. 18:45 19:30 0.75 MIRU MOVE MOB P Travel ahead onto the mats and move 160' to near the end of mats. Note: Road failed on left rear side while getting to the mats. 19:30 00:00 4.50 MIRU MOVE RURD P Trucking mats, laying mats on the road ahead of the rig sub in preparation of using the Hop /Scotch method of moving Rig on mats. Hop /Scotch Method: Lay out single layer, travel to end, double up mats behind- leaving a single row to rest on at the end, back up to end, lay the double mats which are now in front as a single row. Continue ahead and repeat. 37/03/2012 Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). Skid rig towards catilever 15', continue moving away f/ CD4. At midnight, have moved sub approx 1.04 miles from CD4. Page 2 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 MIRU MOVE MOB T Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). Skid rig towards catilever 15', continue moving sub away f/ CD4. Approx 1.04 miles total moved away f/ CD4 @ midnight. MI Swaco power washing ball mill @ CD1. Doyon work on mud pumps, and working on steam lines in pits @ CD1. 37/04/2012 Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). At midnight, have moved sub approx 1.7 miles from CD4. At the road 1.4 miles f/ CD4, 4 hrs shuffling : Had (2) waste water trucks, and (1) water truck service camp. Received (2) dumpsters f/ trash, transfered some materials /supplies to CD1 pad to work with. 00:00 00:00 24.00 MIRU MOVE MOB T Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). Approx 1.7 miles total moved away f/ CD4 @ midnight. From 1300 hrs to 1700 hrs, shuffled equipment to keep camp operational : At the road 1.4 miles from CD4 pad (Shooting range), 2 waste water trucks, and one water truck serviced camp. Two dumpsters were delivered to the camp, some parts and materials were brought to camp and some materials were taken f/ CD4 to CD1 for welders to work with at CD1. A extra loader was also brought to be behind the rig, on the CD4 side of rig. Work being done @ CD1: MI Swaco power washing ball mill - prepare f/ painting. CH2MHill cleaning tanks @ injection skid, 2 cleaned, one of which was inspected. Will clean another tank tommorrow. Doyon work on mud pumps, checking chains, electrician performing work orders on traction motors. Working on steam lines in pits, working to prep boilers f/ inspection - boiler #2 feed pump valves and lines. 07/05/2012 Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). At midnight, have moved sub approx 3.1 miles from CD4. Page 3 of 90 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 MIRU MOVE MOB T Laying mats on roadway CD4, move using hop /scotch method (leap frog) using 126 mats (459' move ahead each time). Approx 3.1 miles total moved away f/ CD4 @ midnight. Work being done @ CD1: MI Swaco power washing ball mill - ready to paint- prepare f/ painting. CH2MHill cleaned all three tanks at injection skid, 2 tanks have been inspected. Doyon work on mud pumps, electrician installing emergency lights in pits, re -lamp lights in pits. Working on steam lines in pits, replacing camlocks w/ hammer unions, working to prep boilers f/ inspection - boiler #2 feed pump valves and lines, replace gasket on isolation valve on top of boiler # 1, rattle boiler tubes on #2 boiler. Welder welding toe plates on roof of motor module. 37/06/2012 Laying mats, moving to Runway stop lights. Wait on air transportation flights until 1830 hrs. Resume moving, shuffling mats. At midnight, have moved sub approx 3.6 miles from CD4 (almost to intersection). 00:00 05:45 5.75 MIRU MOVE MOB T Continue moving sub base on CD4 road toward Alpine. Run way warning sign (3.4 miles f/ CD4 pad) Leap frogging rig mats 05:45 08:00 2.25 MIRU MOVE SVRG T Service rig - On hold for flights in & out of Alpine 08:00 08:30 0.50 MIRU MOVE SFTY T PJSM on changing out shackles in derrick 08:30 12:00 3.50 MIRU MOVE SVRG T Change out shackles in derrick f/ 3 part to 4 part (while on hold for flights in & out of Alpine) 12:00 12:15 0.25 MIRU MOVE SFTY T PJSM on changing out shackles in derrick 12:15 16:00 3.75 MIRU MOVE SVRG T Continue to change out shackles f/ 3 part to 4 part in derrick 16:00 16:15 0.25 MIRU MOVE SFTY T Safety meeting on changing out tugger sheave in derrick 16:15 18:00 1.75 MIRU MOVE SVRG T Change out tugger line sheave in derrick (while on hold for flights in & out of Alpine) 18:00 18:15 0.25 MIRU MOVE SFTY T PJSM on continuing to move sub base - leap frogging rig mats 18:15 00:00 5.75 MIRU MOVE MOB T Continue moving sub base on CD4 road toward intersection of CD4 Road & CD1 /CD2 (3.6 miles f/ CD4 pad @ midnight) Leap frogging rig mats. 37/07/2012 Move to CD1 -22, Spot rig & level, spot pits and motors. Rigging up. Move pipe shed f/ CD4 to CD1. Checked emergency shut downs f/ Engines /Generators, SCR's. Check ESD's f/ Well # 21 and #23. All worked good. Page 4 of 90 1 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 MIRU MOVE MOB T Continue moving sub base on CD4 road toward intersection of CD4 Road & CD1 /CD2. Leap frogging rig mats, once the turn towards CD1 was made at the intersection, backed up towards CD2, cleared intersection, re -set mats ahead (enough mats to get 100' onto runway). Move rig to the runway, then a total of 300' of the runway was matted. 06:00 06:45 0.75 MIRU MOVE MOB P Move rig (without mats on the runway) to the stagging area by the ATAC shack (Off the runway). 06:45 12:00 5.25 MIRU MOVE MOB P Sorting mats, moving mats to CD1 -22 to set rig mats for the well. Set herculite and mats for rig at the well. 12:00 12:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving rig from in front of ATAC shack to CD1 -22B. 12:15 17:00 4.75 MIRU MOVE MOB P Move rig from ATAC shack to well row on CD1. 17:00 18:00 1.00 MIRU MOVE MOB P Move rig over Well CD1 -22A. Shim support feet f/ cantilever. Lower wind walls. 18:00 18:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on skidding rig floor and spotting pits and motors. 18:15 19:30 1.25 MIRU MOVE SKID P Skid rig floor. Peak moving pipe shed f/ CD4 to CD1. 19:30 20:30 1.00 MIRU MOVE MOB P Move and spot pits and motors to rig. Shim modules. 20:30 20:45 0.25 MIRU MOVE SFTY P Pre job safety meeting on rigging up service lines. 20:45 23:00 2.25 MIRU MOVE RURD P Rig up/ Hook up service lines. Connect Hi -Line to the rig. Put pumps together. Accept rig @ 22:00 hrs 7 -7 -2012 23:00 00:00 1.00 MIRU MOVE RURD P Double check all charge pumps. Obtain RKB measurements. Peak maneuver pipe shed onto pad. Note: Electricians, Driller and Toolpusher tested Emergency Shut Downs for Generators /Engines, SCR's. Checked emergency shut down f/ Well # 23 and Well # 21. All working good. 07/08/2012 PJSM, move pipe shed & ball mill, spot both. PJSM, Displace tbg & tbg ann to 9.8 brine to '4200', monitor - static, Set BPV, test -ok, rig down lines, PJSM, Nipple down tree, Nipple up BOPE. RU /start BOPE test. Witness of test waived by AOGCC inspector Jeff Jones. Page 5 of 90 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 MIRU MOVE OTHR P PJSM on spotting pipe shed - Spot pipe shed & spot ball mill. MI Swaco Ball mill spotted @ 0130 hrs. Peak left to put trucks away. Arrange to fly back to deadhorse 7/8/2012. Truck pusher and (2) drivers. 04:30 06:30 2.00 SLOT CSGRC' RURD P PJSM - on rigging up to displace - RU lines for displacement 06:30 08:00 1.50 SLOT CSGRC' OTHR P PU FMC lubricator - Test to 2000 psi - Pull BPV - RD lubricator. Note: Outer annulus (9 -5/8" x 7 ") 120 psi. Note: Rig floor to ground level 36.61', Lower lock down screws 34.48', upper Lock down screws 32.25'. 08:00 09:00 1.00 SLOT CSGRC' RURD P Cont. rigging up line to displace well to 9.8 ppg brine 09:00 09:15 0.25 SLOT CSGRC' SFTY P Pre job ops & safety meeting on displacement 09:15 11:00 1.75 SLOT CSGRC' DISP P Tested line to Tiger tank to 2000 psi - Displaced well f/ freeze protect crude & 12.6 ppg mud w/ 9.8 ppg brine (120° temp) - staged pump f/ 2 bbls /min @ 350 psi to 5 bbls /min @ 1220 psi - Pumped 200 bbls.9.8 ppg brine - FCR 5 bbls /min @ 1180 psi - Initial pressure tbg 850 psi & IA 850 psi - Pressure bled to 0 when annulus was opened to tank Observed 12.6 ppg mud @ 64 bbls pumped - Observed 9.8 ppg brine to surface @ 150 bbls pumped - pumped an additional 50 bbls brine to clean up well - Last sample @ 195 bbls pumped good 9.8 ppg brine 11:00 11:30 0.50 SLOT CSGRC' OWFF P Shut down & monitor well for 30 mins. Well dead. Rig electrician tested gas alarms. 11:30 12:30 1.00 SLOT CSGRC' RURD P Blow down line to Tiger tank - RD line f/ tubing side - RU line f /cement line in cellar to annulus (for testing BPV in direction of flow) 12:30 13:00 0.50 SLOT CSGRC' PRTS P Set BVP & test in direction of flow to 1500 psi for 10 mins. 13:00 13:30 0.50 SLOT CSGRC' OTHR P Blow down & RD lines 13:30 13:45 0.25 SLOT WHDBO SFTY P Pre job safety meeting on nippling down tree and nippling up BOPE. 13:45 16:00 2.25 SLOT WHDBO NUND P Nipple down FMC tree. Install blanking plug. Terminate control line. Page 6 of 90 • • Time Logs g Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 20:30 4.50 SLOT WHDBO NUND P Nipple up 13 -5/8" 5m BOPE: remove Alpine quick connect on bottom of stack- leave on stump. Install 4' length spool 11" 5M x 11" spacer p 5M- Weatherford ser # 48302) under the BOP's, pick up and set down on wellhead. Tighten bolts to 7800 ft Ibs, using Hy -Torq wrench. Install riser to flow line. Connect fill up line. 20:30 20:45 0.25 SLOT WHDBO SFTY P Pre job safety meeting on rigging up to test BOPE. 20:45 22:30 1.75 SLOT WHDBO RURD P Rig up to test BOPE with 4 -1/2" test jt. Testing w/ blanking plug. Screw onto blanking plug with 7 -1/2 rounds, left hand. 22:30 00:00 1.50 SLOT WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. Tested the annular to 250 psi low and 2500 psi high. Tested choke manifold valves 1,2,5,7,10,11,12,13,14,15,16 to 250 psi low and 4000 psi high against top pipe rams (3 -1/2" x 6 ". Tested against kill line HCR, tested upper and lower IBOP on the top drive to 250 psi low and 4000 psi high. Rig electrician tested gas alarms @ 1100 hrs 7/8/2012. 37/09/2012 Finish test of BOPE, pull BPV, RU to pull tubing, back out LDS, pull tubing (129+ 16.26 "cut jt,) Set test plug & test Annular & upper & lower pipe rams w/ 4" test jt.) set wear bushing - MU /RIH w/ 7" scraper to 3464', circulate, POOH to 1555'. 00:00 02:15 2.25 SLOT WHDBO BOPE P Continue BOPE test. Witness of test waived by AOGCC rep Jeff Jones. All of these tests were 250 psi low and 4000 psi high, held f/ 5 minutes each and charted. Tested choke manifold �� valves 3,4,6,8, and 9. Tested Demco 4" valve on mud line. Tested, HCR on choke line and manual valve, tested manual valve on the kill line. Tested Floor safety valve and dart valve. Tested lower pipe rams (3 -1/2" x 6 ") and blind rams. Pumped through both the manual choke and super choke to confirm functioning, choked flow to 1500 psi. Tested accumulator: Full charge 3050 psi, after closure 1600 psi, 200 psi build up in 35 seconds, full charge in 176 seconds. 02:15 02:45 0.50 SLOT WHDBO RURD P Blow down choke manifold, rig down testing equipment, lay down blanking plug. 02:45 03:15 0.50 SLOT CSGRC' OTHR P Pull back pressure valve with "T" bar. 03:15 04:15 1.00 SLOT CSGRC' RURD P Rig up to pull 4 -1/2" 12.6 ppf L -80 IBT -m tubing. Page 7 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 SLOT CSGRC'SFTY P Pre job safety meeting on pulling 4 -1/2" tubing. 04:30 05:00 0.50 SLOT CSGRC' PULD P Pick up 4 -1/2" thread protectors to the floor. Make up 4 -1/2" NSCT landing joint. 05:00 05:45 0.75 0 4,204 SLOT CSGRC' OTHR P Screw into tubing hanger (8 -1/4 rounds -2000 ft Ibs of torque) w/ 4 -1/2" NSCT landing joint. Back out lock down screws on the tubing hanger, re- tighten gland nuts. 05:45 06:00 0.25 4,204. 4,169 SLOT CSGRC' PULL P Pull hanger free w/ 115k on weight indicator. Pull to floor and remove landing joint and FMC hanger w/ pup. Prepare (2) control lines to be rolled up on spool. 06:00 12:30 6.50 4,169 0 SLOT CSGRC' PULL P Pull and lay down 129 jts of 4 -1/2" 12.6 ppf L -80 IBT -m tubing, one Camco KBG -2 GLM w/ pups, one Bal -O SSSV with pups, and a cut joint ( 16.26') f/ 4204'. Note: Pumped a 25 bbl dry job (10.5 ( , ppg) @ 1330', pumping 5 bpm w/ 220 'f( psi. Note: Recovered all (57) 5/8" stainless Steel Bands. Total length recovered = 4193.59' RKB. 12:30 13:15 0.75 0 0 SLOT CSGRC' RURD P Clean off rig floor, rig down tubing equipment. 13:15 13:30 0.25 0 0 SLOT WHDBO SFTY P Pre job safety meeting on rigging up to test BOPE with 4" test joint. 13:30 14:00 0.50 0 0 SLOT WHDBO RURD P Rig up to test the annular, top and bottom pipe rams (3 -1/2" x 6 ") with 4" test joint. 14:00 15:00 1.00 0 32 SLOT WHDBO BOPE P Test top and bottom pipe rams w/ 4" test joint and test plug. Test to 250 psi low and 4000 psi high, hold each test 5 minutes. Test annular to 250 psi low and 2500 psi high, 5 minutes each. Chart test. 15:00 15:30 0.50 32 0 SLOT WHDBO RURD P Pull test plug, install FMC wear bushing with 6.875" ID. Blow down choke manifold. 15:30 16:00 0.50 0 0 SLOT CSGRC' SFTY P Pre job safety meeting on making up BHA w/ 6 -1/8" bit & 7" casing scraper. 16:00 17:15 1.25 0 223 SLOT CSGRC' PULD P Make up 6 -1/8" bit, 7" casing scraper, bit sub, x -o, weatherford drilling jar, x -o, (6) 4 -3/4" drill collars, x -o to 223.25'. 17:15 17:30 0.25 223 223 SLOT CSGRC' RURD P Change elevators from 3 -1/2" to 4 ". 17:30 19:15 1.75 223 2,050 SLOT CSGRC'TRIP P Trip in the hole picking up 4" drill pipe from the shed, RIH to 3464'. 19:15 19:30 0.25 2,050 2,050 SLOT RIGMNT SVRG P Service rig 19:30 21:00 1.50 2,050 3,464 SLOT CSGRC'TRIP P Trip in the hole picking up 4" drill pipe from the shed, RIH to 3464'. Page 8 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:45 0.75 3,464 3,464 SLOT CSGRC' CIRC P Circulate & rotate 7" scraper. Stage up to 420 gpm w/ 1370 psi, then go to 600 gpm w/ 2650 psi. Rotate 20 rpm w/ 3.5k ft lbs of torque. PU wt 130k, SO wt 125k, Rot wt 126k. 21:45 22:00 0.25 3,464 3,464 SLOT CSGRC' RURD P Blow down the top drive, turn elevators around for trip out. Line up on trip tank. Flow check well- static. 22:00 22:15 0.25 3,464 3,464 SLOT CSGRC' SFTY P Pre job safety meeting on pulling out of hole (tripping). 22:15 00:00 1.75 3,464 1,555 SLOT CSGRC' TRIP P Trip out of the hole w/ the 7" casing scraper f/ 3464' to 1555'. X7/10/2012 Con't POOH w/ 7" scraper, MU Baker 7" CIBP, RIH, set @ 3405' - Test to 2500 psi for 10 mins. - POOH - LD setting tool - MU 7" casing cutter assembly RIH - locate casing collars @ 3384' & 3344' - Cut 7" csg @ 3362' - Unable to circ up OA- Circ btms up - well static - POOH to 2952' - Locate Csg collars - Cut 7" csg @ 2994' - Circ thru cut, 9.8 ppg brine to surface - flow check, slight flow - CBU - flow check static - POOH LD cutter - Change out upper rams to 7" - pull wear bushing and test 00:00 00:45 0.75 1,555 58 SLOT CSGRC' TRIP P Trip out of the hole w/ the 7" casing scraper f/ 1555' to 58'. 00:45 01:30 0.75 58 0 SLOT CSGRC' PULD P Lay down jars, scraper x -o's and bit. 01:30 02:00 0.50 0 9 SLOT CSGRC' PULD P Make up Baker K -1 7" cement retainer /Bridge Plug. 02:00 05:00 3.00 9 3,405 SLOT CSGRC'TRIP P Trip in the hole w/ Baker K -1 Cement retainer /bridge plug f/ 9' to 3405' - PU wt 125 SO wt. 120 ( pump on every 10 stds) 05:00 05:30 0.50 3,405 3,405 SLOT CSGRC' MPSP P Drop ball - Pressure up to 800 psi to set bridge plug @ 3405' - Bleed off pressure - Pull 10 k over to set slips - Pulled 20 k over to shear off f/ setting tool 05:30 06:15 0.75 3,405 3,405 SLOT CSGRC' PRTS P RU & pressure test bridge plug to 2500 psi for 10 mins.(Good test) Bleed off pressure - Blow down lines & RD 06:15 08:00 1.75 3,405 0 SLOT CSGRC'TRIP P POOH on TT f/ 3405' 08:00 08:30 0.50 0 0 SLOT CSGRC' PULD P LD bridge setting tool - Clear rig floor of excess tools 08:30 08:45 0.25 0 189 SLOT CSGRC' PULD P MU Baker Multi- string cutter - stab - 6-43/4"DC-XO- 08:45 10:45 2.00 189 3,405 SLOT CSGRC' TRIP P RIH w/ Cutting assembly on 4" Dp - - Tagged top of CIBP @ 3405' - 10:45 11:30 0.75 3,405 3,362 SLOT CSGRC' CPBO P Pull up & locate 7" casing collars @ 3384' & 3344' - Get cutter on depth @ 3362' - Cut 7" casing - 5 bbls /min @ 600 to 1000 psi w/ 80 rpms' W 5.5 k torque 11:30 12:15 0.75 3,334 3,334 SLOT CSGRC' CIRC P PJSM on circulating to Tiger tank - Attempt to circ thru casing cut @ 3334' to Tiger tank - Pumped 5 bbls @ 1.5 bbls /min @ 1500 psi - No returns to tank - Shut down - Open pipe rams & monitor well - slight flow 12:15 12:45 0.50 3,334 3,334 SLOT CSGRC' CIRC P Circ btms up @ 3334' @ 4 bbls /min @ 720 psi - Flow ck well static - slight drop Page 9 of 90 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:00 0.25 3,334 2,952 SLOT CSGRC` TRIP P POOH on TT f/ 3334' to 2952' 13:00 13:45 0.75 2,952 2,994 SLOT CSGRC` CPBO P Locate 7" casing collars @ 2978' & 3018' - Get cutter on depth @ 2994' - Cut casing @ 2994' @ 5 bbls /min @ 920 psi w/ 90 rpm's w/ 5.5 k torque - Observed pressure drop to 400 psi when cut out 13:45 14:00 0.25 2,984 2,984 SLOT CSGRC` CIRC P Pull up to 2984 - Close top rams - Attempt to circ thru cut @ 2994' to Tiger tank @ 4 bbls /min @ 1220 psi - pumped 13 bbls - No returns to tank - Shut down & open rams 14:00 14:15 0.25 2,984 2,984 SLOT CSGRC` OWFF P Flow check fluid level dropping in annulus - turn on hole fill pump & fill hole - got returns to Tiger tank (fluid appeared to U -tube f/ IA to OA 14:15 15:30 1.25 2,984 2,984 SLOT CSGRC`CIRC P Closed upper pipe rams - Circ out cut @ 2994' to Tiger tank @ 3 bbls /min @ 690 psi - pumped total of 210 bbls 9.8 ppg brine - good sample of 9.8 ppg brine @ 200 bbls pumped - Tank strap was 227 bbls - Shut down 15:30 15:45 0.25 2,984 2,984 SLOT CSGRC` OWFF P Open top pipe rams - shut in well to tanks - Monitor well slight flow 15:45 16:15 0.50 2,984 2,984 SLOT CSGRC` CIRC P Circ btms up @ 4 bbls /min @ 660 psi - Shut down- flow ck - Well static fluid level dropping slightly 16:15 19:15 3.00 2,984 0 SLOT CSGRCTRIP P POOH on TT f/ 2984' to surface. LD casing cutter. 19:15 19:30 0.25 0 0 SLOT CSGRC' SFTY P PJSM on changing out pipe rams 19:30 22:00 2.50 0 0 SLOT WHDBO RURD P Change out upper pipe rams from 3.5" x 6" VBR's to 7" solid body. 22:00 22:30 0.50 0 0 SLOT WHDBO RURD P Pull wear bushing, set test plug. 22:30 23:00 0.50 0 0 SLOT WHDBO RURD P RU to test BOPE 23:00 00:00 1.00 0 0 SLOT WHDBO BOPE P Test annular to 250 -2500 psi and upper pipe rams to 250 -4000 psi for 5 min each with 7" test joint. 37/11/2012 Pull pack -off - MU spear assy - Spear 7" hgr - Unseat hgr with 150K - Pull Hgr to flowline with 135K - CBU x 3 - LD Spear Assy - LD 7" Hgr /Casing - Change top rams to 3.5" x 6" and test - set wear ring - MU spear assy - RIH - Engage fish and Pull 7" free - Pull into surface casing - CBU x2 - Slip and cut drlg line - CBU x2 - wt up to 10.0 ppg 00:00 01:00 1.00 0 0 SLOT WHDBO RURD P Engage packoff with retrieving tool - open lower annulus and confirm static - BOLDS - pull packoff with blocks - 8K over to free 01:00 02:15 1.25 0 2,964 SLOT CSGRC` PULD P MU Baker ITCO spear asssy. RIH with spear and engage casing 4' below hanger. Unseat hanger with 150K, pull hanger to flowline with 135KPUwt. Page 10 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 03:15 1.00 2,964 2,964 SLOT CSGRC' CIRC P Circulate bottoms x 3. Some gas back on first bottoms up, fine cuttings blinding shakers on second bottoms, circulate one more bottoms up to even brine weight. 5 bpm 160 psi ICP, 5 bpm 140 psi FCP. 03:15 03:30 0.25 2,964 2,964 SLOT CSGRC` OWFF P Observe well, static. 03:30 04:15 0.75 2,964 2,950 SLOT CSGRC' PULD P Pull Hgr to floor, Release spear and LD spear assy. 04:15 05:00 0.75 2,950 2,950 SLOT CSGRC' RURD P RU to pull 7" casing 05:00 05:15 0.25 2,950 2,950 SLOT CSGRC' SFTY P Held PJSM w/ crew on pulling & laying down 7" casing 05:15 09:30 4.25 2,950 0 SLOT CSGRC' PULL P Laid down hanger & pup - Pulled & laid down 71 jts 7" 26# L -80 BTCM casing 09:30 09:45 0.25 0 0 SLOT CSGRC' OWFF P Observed well - Static 09:45 10:00 0.25 0 0 SLOT CSGRC'SFTY P PJSM on changing rams 10:00 11:45 1.75 0 0 SLOT WHDBO OTHR P Change top pipe rams f/ 7" to 3 1/2" x6 "VBR 11:45 14:00 2.25 0 0 SLOT WHDBO PRTS P Set test plug w/ 4" test jt. - RU to test - Tested top pipe rams to 250 & 4000 psi w/ 4" & 3 1/2" test joints - Pull test plug & RD - Set long wear bushing (9" ID) 14:00 14:15 0.25 0 0 SLOT CSGRC' RURD P Drain stack, Install 5" elevators 14:15 14:30 0.25 0 0 SLOT CSGRC' SFTY P PJSM on making up Baker spear assy. 14:30 16:15 1.75 0 237 SLOT CSGRC' PULD P MU Baker fishing BHA - Bullnose, Spear Packoff, Spear w/ 6.22 OD grapple, Spear extention, Stop sub 8.25" OD, XO, Bump sub, Oil jar, XO, (6) 6 1/4" DC's, xo, 6 1/4" jar, xo 16:15 17:30 1.25 237 2,905 SLOT CSGRC' TRIP P RIH with 4" DP to 2905'. TOF at 2994'. 17:30 18:30 1.00 2,905 3,284 SLOT CSGRC' FISH P Establish parameters at 3 bpm 130 psi, 5 bpm 220 psi. 128K PUW, 130K SOW. Engage fish (368' of 7" casing) with spear @ 2994' - Bottom of fish at 3362' - Pulled up to 275K one hit with jars - pipe moving - pulled up a 32' - LD single - pulled to 3284' with PUW down to 140K. 18:30 19:00 0.50 3,284 3,103 SLOT CSGRC' TRIP P Attempt to circulate - packed off - POOH from 3284' to 3103' - attempting to break circulation while pulling - gained returns with fish inside casing shoe at 3110' - PUW 135K Page 11 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 3,103 3,103 SLOT CSGRC'CIRC P Establish circulation stage pumps up to 5.0 bpm / 250 psi - observed gas begin breaking out at flowline 50 bbls before 1st BU - Gas peaked at BU - 130 units - Circulated second BU with small amounts of gas breaking out at flowline - Brine wt. 9.8+ ppg in & 9.9+ out - no light fluids back 20:00 20:30 0.50 3,103 3,103 SLOT CSGRC' OWFF P Observe well static for 30 minutes with slight fizz of gas breaking out 20:30 20:45 0.25 3,103 3,103 SLOT CSGRC' SFTY P PJSM on slip and cut drilling line - Decision made to slip and cut drilling line while monitor well on trip tank then CBU and check for gas. 20:45 21:00 0.25 3,103 3,071 SLOT CSGRC'TRIP P Pull and rack back stand to 3071'. 21:00 22:30 1.50 3,071 3,071 SLOT CSGRC' SLPC P Slip and cut drilling line. Monitor well on trip tank, no gain, no loss. 22:30 23:45 1.25 3,071 3,071 SLOT CSGRC' CIRC P Circulate, stage pumps up to 6.0 bpm / 300 psi - observed gas begin breaking out at flowline 10 bbls before 1st BU - then cleared up at flowline soon after BU - Began seeing gas on Gas Watch to 110 units at 1.5 BU - Circulated second BU with Gas Watch dropping back to normal - Brine wt. 9.8+ ppg in & out - no light fluids back 23:45 00:00 0.25 3,071 3,071 SLOT CSGRC' CIRC P Weight up to 10.0 ppg (max with current brine system) circulating at 6 bpm 300 psi. X7/12/2012 Wt up to 10.0 ppg - Flow check - POOH - LD 7" casing and fish assy - Attempt drift casing to 8.75 ", no go at 36' - MU cmt stinger - RIH - cement - POOH - circ - POOH - LD cmt stinger - PU 5" DP -- Note -- Annular Injection well CD1 -15 experiencing excessive injection pressures. Freeze protect. Wait evaluation. 00:00 00:30 0.50 3,071 3,071 SLOT CSGRC'CIRC P Weight up brine to 10.0 ppg at 6 bpm, 300 psi.3 00:30 00:45 0.25 3,071 3,071 SLOT CSGRC' OWFF P Observe well, static 00:45 03:00 2.25 3,071 601 SLOT CSGRC' TRIP P POOH on TT f/ 3071' to 601' w/ hole taking proper fill - FLow ck well static 03:00 04:15 1.25 601 364 SLOT CSGRC' PULD P LD Baker fish assy 04:15 04:45 0.50 364 343 SLOT CSGRC' PULD P RU tongs -LD spear w/ cut - off 04:45 05:00 0.25 343 343 SLOT CSGRC' SFTY P PJSM on laying down 7" fish 05:00 06:00 1.00 343 0 SLOT CSGRC' PULD P LD fish - 9 jts & 2 cut offs - (recovered 3 bowspring cent. and 80 jts 7" & cut off jt. Total recovery - 3318.27' (pipe strap in pipe shed) 06:00 06:45 0.75 0 0 SLOT CSGRC' PULD P Change elevators - PU spear & release from cut -off jt. 06:45 07:00 0.25 0 0 SLOT CSGRC' SFTY P PJSM on LD casing equipment & PU tools - Clean up floor Page 12 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 0 0 SLOT CSGRC' OTHR P MU 8 3/4" PDC bit - w/ bit sub & XO - RIH to 36' (top of 9 5/8" casing hanger) NO -GO - LD 8 3/4" bit 08:00 09:00 1.00 0 0 SLOT CSGRC' RURD P RU to run 3 1/2" tbg (cmt. stinger) 09:00 10:30 1.50 0 1,048 SLOT CSGRC' PULD P PJSM MU mule shoe and RIH with 33 jts of 3 -1/2" 9.3# EUE tubing, XO to 4" XT -39 to 1048' 10:30 12:00 1.50 1,048 3,362 SLOT CSGRC'TRIP P Change elevators and RIH with w/ 4" DP to 3362'. Could not get into 7" casing stub at 3362'. 12:00 13:00 1.00 3,362 3,362 SLOT CSGRC' CIRC P Circulate and condition brine for cement job, 6 bpm at 280 psi. Some gas at BU. 13:00 13:15 0.25 3,362 3,362 SLOT CSGRC' SFTY P PJSM on cementing. 13:15 13:45 0.50 3,362 3,360 SLOT CSGRC' PULD P MU pup jts to space out at 3360' for cement job. Remove bell guide. 13:45 14:00 0.25 3,360 3,360 SLOT CSGRC' RURD P RU for cement job. 14:00 14:45 0.75 3,360 3,360 SLOT CSGRC' CMNT P Dowell cementers established circulation with 1.7 bbls of water - Tested lines to 2500 psi - Mix and pump 16.6 bbls of 12.5 ppg Mudpush - 70.2 bbls of 17.0 ppg G cement w/ adds (394 sxs -1 cf /sx yld) - 2.4 bbls of Mudpush behind and Dowell displaced to equalization with 20.1 bbls 10.0 ppg brine (cut 5 bbls short) 4.7 bpm at 250 psi - Shut down and open valves - slight flow back up DP - CIP @ 1445 hrs - full returns throughout - ETOC w/ 200% excess in OH =2910' 14:45 15:00 0.25 3,360 3,335 SLOT CSGRC' RURD P RD cement equip, LD pups 15:00 16:00 1.00 3,335 2,763 SLOT CSGRC' TRIP P POOH 6 stands on trip tank to 2763'. 16:00 16:30 0.50 2,763 2,763 SLOT CSGRC' CIRC P Flow check static, RU to and begin reverse circulate out excess cement. 3 bpm 600 psi for 14 bbls, pressured spiked to 800 psi then dropped to 490 psi, began losing some mud. Shut down reversing. 16:30 16:45 0.25 2,763 2,572 SLOT CSGRC' TRIP P POOH 2 stands from 2763' to 2572' on trip tank, gained 2 bbls. 16:45 17:00 0.25 2,572 2,572 SLOT CSGRC' OWFF P Observe well static. 17:00 17:30 0.50 2,572 2,286 SLOT CSGRC'TRIP P Cont POOH 3 more stands on trip tank to 2286' with proper hole fill. 17:30 18:30 1.00 2,286 2,286 SLOT CSGRC' CIRC P Flow check static, circulate at 2286', staging pump rate up to 8 bpm, 300 psi. No losses. Dumped 22 bbls Mud Push. Cont circ 2 BU total. 18:30 18:45 0.25 2,286 2,286 SLOT CSGRC' OWFF P Observe well static. 18:45 19:45 1.00 2,286 1,049 SLOT CSGRC'TRIP P POOH on trip tank to 1049'. 19:45 20:00 0.25 1,049 1,049 SLOT CSGRC'SFTY P PJSM on LD 3.5" tubing. Page 13 of 90 ♦ • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:15 2.25 1,049 0 SLOT CSGRC' PULD P RU and LD 3.5" tubing cement stinger. Flow check static. 22:15 22:45 0.50 0 0 SLOT CSGRC' RURD P RD tubing equipment. 22:45 23:00 0.25 0 0 SLOT CSGRC' SFTY P PJSM on LD DC's and PU 5" DP. 23:00 00:00 1.00 0 0 SLOT CSGRC' PULD P PU and stand back 5" DP 37/13/2012 PU and rack 5" DP - Test BOPE -- Note -- Could not get CD1 -15 to take fluid any better. Perform injectivety tests with LRS on CD1 -21, CD1 -18, CD1 -26, CD1- 34 & CD1 -04. None would take fluid. -- Note -- 20' of 2" vacuum hose with camlock was accidentaly dropped down hole. 00:00 05:00 5.00 0 0 SLOT CSGRC' PULD P PU and stand back 5" DP 05:00 05:30 0.50 0 0 SLOT CSGRC' SVRG P Service rig 05:30 15:00 9.50 0 0 SLOT CSGRC' PULD P Cont. PU & stand back 5" DP via mouse hole (115 stds total) 15:00 15:15 0.25 0 0 SLOT CSGRC' SFTY P PJSM - Changing saver sub 15:15 16:00 0.75 0 0 SLOT CSGRC' OTHR P Change saver sub f/ 4 " XT -39 to 4 1/2" IF 16:00 17:15 1.25 0 0 SLOT CSGRC' PULD P PJSM and clear and clean rig floor, LD and PU tools /subs and Geo Span 17:15 17:30 0.25 0 0 SLOT CSGRC' SFTY P PJSM on testing BOPE 17:30 18:30 1.00 0 0 SLOT WHDBO RURD P Drain stack, pull wear ring, (Dropped 20' of 2" vacuum hose in hole with camlock on one end) Set test plug. 18:30 19:15 0.75 0 0 SLOT WHDBO RURD P PJSM and RU to test BOPE 19:15 00:00 4.75 0 0 SLOT WHDBO BOPE P Tested BOPE as follows: w/ 5" test jt. tested Annular to 250/2500 psi - Tested upper pipe rams (3 1/2" x 6" VBR's), lower pipe rams (3 1/2" x 6" VBR's) - TD IBOP's, Floor safety & dart valves, Choke & kill line manual & HCR valves, 4" Demco kill line valve- Choke manifold valves # 1, 2, 3, 5, 7, 8, 10 thru 16 to 250/4000 psi - Performed accumulator recovery test - tested Blind rams 250/4000 psi 07/14/2012 Continued test BOPE - PU and rack 5" DP - Service rig while wait on fishing tools - Retrieve fish with Baker rope spear - MU Sperry cement clean out assy -- Note -- Performed more injectivety tests with LRS on CD1 -12, CD1 -14, CD1 -44, CD2 -72 & CD2 -468. Only CD2 -468 would take fluid. Page 14 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 SLOT WHDBO BOPE P Continue Test BOPE as follows: lower pipe rams (3 1/2" x 6" VBR's) - HCR choke valve - Choke manifold valves # 4, 6 & 9 to 250/4000 psi - Performed accumulator recovery test - tested Blind rams 250/4000 psi - Performed flow through tests on Super choke and manual choke - Matt Herrera (AOGCC) waived witnessing tests 02:00 02:45 0.75 0 0 SLOT WHDBO RURD P Pull test plug and install long wear ring at 9" ID 02:45 05:15 2.50 0 0 SLOT CSGRC' PULD P PJSM, PU & stand back remaining 5" DP via mouse hole (18 stds total) 05:15 12:15 7.00 0 0 SLOT CSGRC' SVRG P Service rig - Changing out shackles in derrick f/ 3 part to 4 part - Change out fittings on iron roughneck - Install whip checks on drip pan drain lines - change out fitting on iron roughneck while wait on fishing tools. 12:15 14:00 1.75 0 46 SLOT CSGRC' FISH P PJSM and MU Baker fishing assy consisting of Crankshaft rope spear, stop sub and drain sub. 14:00 16:45 2.75 46 2,265 SLOT CSGRC'TRIP P RIH with fishing assy, tag with 10K wt at 2317' twice, stand back stand to 2265'. 16:45 17:30 0.75 2,265 2,265 SLOT CSGRC' CIRC P Circulate surface to surface volume, at 7 bpm 110 psi. 17:30 18:45 1.25 2,265 2,265 SLOT CSGRC' PRTS P Flow check static, PJSM, RU and test casing to 3500 psi for 30 min, good. 18:45 19:00 0.25 2,265 2,265 SLOT CSGRC' RURD P PJSM and RD test equipment, blow down kill line. 19:00 19:15 0.25 2,265 2,316 SLOT CSGRC' FISH P RIH to 2317' applying 10K wt, PU 1', rotate 12 turns to right. 3K torque, 115K rot wt. 19:15 22:00 2.75 2,316 0 SLOT CSGRC'TRIP P PJSM, POOH on trip tank. Fish retrieved. 22:00 23:00 1.00 0 0 SLOT CSGRC' PULD P PJSM, LD Baker fishing tools, clear and clean floor. 23:00 00:00 1.00 0 200 SLOT CSGRC' PULD P PJSM, MU cement clean -out assy as per Sperry DD 37/15/2012 RIH with cement clean -out assy - wash and tag cmt at 2527' - Drill cement from 2527' to 2911' - RIH - Tag Cmt at 2527' - Drill 384' of cement to 2911' - Circ btms up - Test csg to 3500 psi for 30 ming POOH - LD C/O assembly - Flush stack - Perform Rig maintenance while analyze options. -- Note -- Performed more injection test w/ Little Red on CD2 -76, CD2 -465, - (Pumped 10 bbls diesel @ CD4 -302 still ok) - CD1 -03, CD1 -05, CD1 -16, CD1 -23, CD1 -25, CD1 -30, CD1 -31, CD1 -37 and CD1 -38. Only CD2 -76 would take fluid. 00:00 01:30 1.50 200 2,251 SLOT CSGRC' TRIP P RIH with clean -out assy to 2251'. Page 15 of 90 • . • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 2,251 2,527 SLOT CSGRC' TRIP P Fill pipe, circ at 3 bpm, 70 psi. Wash down no rotary looking for cement. Passed 2713' where fish was with just a bobble, cont wash down, began seeing weight increase from 2456' to 2527' where it held 10K WOB. 02:00 11:00 9.00 2,527 2,911 INTRMI DRILL COCF P Begin Drill cement from 2527' at 650 gpm at 1090 psi, shakers blinding with cement losing brine over shakers. Slowed pumps till cleaned up, cont drill cement, cement hard from 2560' to 2911' 11:00 11:15 0.25 2,911 2,911 INTRM1 DRILL CIRC P Circ btms up @ 2911' @ 650 gpm @ 1000 psi w/ 100 rpm's @ 8.5 k torque 11:15 12:15 1.00 2,911 2,911 INTRMI DRILL PRTS P RU & test 9 5/8" casing to 3500 psi for 30 mins - Bleed off pressure - Blow down kill line & top drive - RD 12:15 14:15 2.00 2,911 472 INTRM1 DRILL TRIP P Flow ck static - POOH w/ C/O assy f/ 2911' to 472' 14:15 15:15 1.00 472 0 INTRMI DRILL TRIP P Flow ck - static - Stand back HWDP - Jars & NM flex DC's - LD XO - stab & bit 15:15 15:45 0.50 0 0 INTRM1 DRILL OTHR P PJSM on flushing stack - MU stack washer & flush BOP stack - LD • stack washer 15:45 00:00 8.25 0 0 INTRM1 DRILL SVRG P Rig perform various maintenance items; Replace light in derrick, C/O shakles in derrick and sub, CO valves and seats #1 MP, C/O valves on boiler, work on work orders. J7/26/2012 P/U 5" DP and rack back 109 stands - P/U and M/U Kick -off assembly (Sperry 7/8 lobe - 6 stage 1.3° Motor) - RIH T/2425' 00:00 01:00 1.00 0 0 INTRM1 DRILL PULD P P/U 5" DP via mouse hole 01:00 03:00 2.00 0 0 INTRM1 DRILL SVRG P Service Rig Due to noise interference with power plant NOTE: Back on generator power @ 0300 hrs 03:00 04:45 1.75 0 0 INTRM1 DRILL PULD P P/U 5" DP via mouse hole 04:45 05:15 0.50 0 0 INTRMI DRILL SFTY P Clean and clear rig floor of obstructions - Standup for Safety meeting 05:15 09:30 4.25 0 0 INTRMI DRILL PULD P P/U 5" DP via mouse hole 09:30 10:00 0.50 0 0 INTRMI DRILL RURD P off of gen. set back to high line power due to power plant limitations 10:00 16:00 6.00 0 0 INTRMI DRILL PULD P P/U 5" DP via mouse hole (109 stds total) 16:00 19:15 3.25 0 216 INTRMI DRILL TRIP P PJSM - P/U BHA as per DD & RIH T/216' 19:15 20:30 1.25 216 216 INTRMI DRILL RGRP T Work on iron roughneck - change out solenoid 20:30 21:15 0.75 216 541 INTRM1 DRILL TRIP P Continue to P/U BHA and RIH F /216' - 541' Page 16 of 90 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 21:30 0.25 541 541 INTRM1 DRILL CIRC P Shallow pulse test MWD @ 500 GPM, 970 psi 21:30 00:00 2.50 541 2,425 INTRMI DRILL TRIP P Single in hole F/541' - 2425' 07/27/2012 Drilled cement to 3083' - displaced to 9.8 ppg LSND - Drilled cement to KOP & 50' of new hole - performed LOT to 14.6 EMW (770 psi) - rotate and slide drill F/ 3178' - 3742' - 564' @ and average of 75 ft/hr 00:00 00:30 0.50 2,425 2,893 INTRM1 DRILL TRIP P PJSM - RIH F/2425' - 2893' - P/U 15K S/O 135K 00:30 00:45 0.25 2,893 2,913 INTRM1 DRILL WASH P Wash down F/2893' - 2913' @ 500 gpm, 1210 psi, 40 rpm, 4K TQ, 140K ROT 00:45 04:00 3.25 2,913 3,083 INTRMI DRILL DRLG P Drill cement F2913' - 3083' - @ 500 gpm, 1210 psi, 40 r 4K TQ 9P p � m p 10 -12K WOB - @ 525 gpm, 1330 psi - 575 gpm. 1650 psi NOTE: obtain premission from power plant to cintinue drilling operations w/ high line power and one rig generator 04:00 04:15 0.25 3,083 3,083 INTRMI DRILL CIRC P Circulate hole clean @ 550 gpm, 1370 psi, 40 rom, 4K TQ 04:15 04:30 0.25 3,083 3,083 INTRMI DRILL OWFF P Flow Check - little bubbles for 5 minutes and gas on Totco spiked at 596 units 04:30 05:00 0.50 3,083 3,083 INTRM1 DRILL SVRG P Rig Service - clean out drag chain 05:00 05:30 0.50 3,083 3,083 INTRMI DRILL DISP P Flow check - well static Displace brine to 9.8 ppg LSND - 550 gpm, 1330 psi, 40 rpm, 4K TQ - 1560 psi ICP, 870 psi FCP 05:30 05:45 0.25 3,083 3,083 INTRMI DRILL OWFF P Flow check - well static 05:45 08:00 2.25 3,083 3,178 INTRM1 DRILL DRLG P Drill cement F/3083' to KOP of 3178' - 500 gpm, 910 psi, 40 rpm, 4.5K TQ, 10 -17K WOB 08:00 08:45 0.75 3,178 3,228 INTRM1 DRILL DRLG P Drill 50' of new hole F/3178' - 3228' - 500 gpm, 910 psi, 50 rpm, 6.5K TQ - ADT =0.56, TST =0.4, rotary time =0.16 08:45 09:30 0.75 3,228 3,228 INTRM1 DRILL CIRC P Circulate and condition mud for FIT / LOT test - 500 gpm, 930 psi, 50 rpm, 6.5K TQ 09:30 09:45 0.25 3,228 3,083 INTRM1 DRILL TRIP P POOH F/3228' - 3083 150K P /U, Nu() 148K S/O 09:45 10:00 0.25 3,083 3,083 INTRM1 DRILL OWFF P Flow check - well static S (r B/D top drive & Rig up to perform FIT /LOT 10:00 10:45 0.75 3,083 3,083 INTRM1 DRILL LOT P PJSM - Perform LOT to 14.6 ppg - pressure up to 770 psi - pump 1.7 bbls - bleed back 1 bbl in 27 minutes 10:45 11:15 0.50 3,083 3,083 INTRMI DRILL OWFF P Flow check - well static blow down and rig down lines 11:15 11:30 0.25 3,083 3,177 INTRMI DRILL TRIP P RIH F/3083' - 3177' 11:30 12:00 0.50 3,177 3,228 INTRMI DRILL REAM P Wash and ream F/3177' - 3228' - 525 gpm, 1000 psi, 40 rpm, 4K TQ Tight spot @ 3196' Page 17 of 90 • CD1 -22A Set -up for Sidetrack Well Schematic Colville River Field CD1 -22A Alpine Producer Rig Abandonment All Depths Adjusted for Doyon 19 RKB Updated - 03.21.12 16" Insulated Conductor to - 1 1 4' t - - - - -- Top of Plug @ 2.910' MD / 2.910' TVD ck ti9' 17 O ppg bb. 9 -5/8" 40# L -80 BTC Surface Casing 3,110' MD / 3,109' TVD Kick Off Pug KOP at 3,200' MD 7" Casing Stub @ 3,320' MD CIBP at 3,370' MD 4- - Cut Tubing @ 3.600' MD GL - __ Top of P &A plug @lD 67Z ( � AA P s /s/ j l 1S Planned Top of 15.8 Class G Cement 6472' MD / 5867' TVD iL 314_ PI/ TD 6 -1/8 hole 7" 26 ppf L -80 BTC Mod 11.500' MD Intermediate Casing @ +/- 8436' MD WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: CD 1 -22A Run Date: 5/13/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1 -22A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20250 -01 SCANNED APR 2 3 2013, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 Klinton Wood @halliburton.com Date: 1 `qt' - Signed: NeLtAVA) • • Q T,-1. � " ( a SEAN PARNELL, GOVERNOR 1� , j L L� ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Weifeng Dai Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 f��, ! t Re: Colville River Field, Alpine Oil Pool, CD1 -22A Sundry Number: 312 -175 Dear Mr. Dai: ,. N ED MAY 1 8 2.0 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • / 4)-t-01 Cath P. Foerster Chair DATED this ! day of May, 2012. Encl. I ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conoco Phillips Telephone 907 - 276 -1215 May 7 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 RECEiv Anchorage, Alaska 99501 MAY 082012 Re: Sundry Permit -- Request to Re -Enter CD1 -22A and Plug for Re -Drill AOGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora sundry permit to re -enter the CD1 -22A well with the intention to set a kick off plug for future sidetrack operations. Future drilling operations include drill 8.5" intermediate section and cemented with 7" casing. Production zone is Alpine C sand which will be penetrated with 6 -1/8" hole, cased and cemented with 4 -1/2" liner. The predicted start date for the re -entry and plug setting operations is 6/10/2012. Doyon Rig 19 will perform the work. This operation is planned following the pre -rig abandonment work approved in Sundry number 312 -141. The sidetracking procedures will be covered in a separate Application for a Permit to Drill CD1 -22B. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10 -403 2. A proposed re -entry and abandonment program 3. CD1- 22A Current Schematic 4. CD1 -22A Set up for Sidetrack Schematic 5. Pre -Rig abandonment procedures approved in Sundry #312 -141 Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Weifeng Dai at 263.4324 or Chip Alvord at 265 -6120. Sincerely, c Well Way /ooAPc/ qt Taff /hohT* 7`b7 9'Sf©c r7 5 :4 ?(2 -j Ono/ 7441- 90a10l . �r�' // \ f 6 Weifeng Dai Drilling Engineer Attachments: • • • cc: CD1 -22A Well File / Sharon Allsup Drake ATO 1530 Brian Noel ATO 1700 Fred Herbert ATO 1566 Chip Alvord ATO 1570 Elizabeth Galiunas ATO 1500 Jack Walker ATO 1740 Nina Anderson ATO 1702 Lanston Chin Kuukpik Corporation '' .,R ECEIVED z, STATE OF ALASKA r S'l'.t' • ALA. OIL AND GAS CONSERVATION COMMI •N MAY 0 8 2 r APPLICATION FOR SUNDRY APPROVALS 7S 5 1 4 C 20 AAC 25.280 AOG 1. Type of Request: Abandon r Plug for Redrill 7 . Perforate New Pool fl Repair w ell r Change Approved Program r Suspend r Plug Perforations fl Perforate E Pull Tubing p • Time Extension E Operational Shutdown fl Re -enter Susp. Well IT Stimulate r Alter casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r js . 7 .. 2 , 5 -2 ---- 12 _%- /(c, A osi,i 3. Address: Stratigraphic r Service �" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20250 - (- = 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: . ,e S' where ownership or landownership changes: Spacing Exception Required? Yes IT No ri CD1 -22A • 9. Property Designation (Lease Number): 10. Field /Pool(s): /r/ /tz-' / , ,, ADL 25558 , Colville River Field / F' rd Oil Pool 5' 11. PRESENT WELL'CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,500 ' 6,925 ' 11,500 6,925 Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' 1,640 630 Surface 3,073 9 -5/8" 3,110 3,110 5,750 3,090 Intermediate 8,393 7" 8 6,931 7,250 5,410 Production tubing 7,628 4 -1/2" 7,665 6,784 8,425 7,496 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4 -1/2" L -80 7,665 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker S -3 Production Packer 7,579' MD / 6,733' TVD Camco 4 -1/2" BAL-0 SSSV 1,718' MD / 1,718' TVD 12. Attachments: Description Summary of Proposal F' 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status a er proposed work: Suspended 1 ✓ WDS PL p I )/ 6/10/2012 Oil ,�'' � Gas � � • 16. Verbal Approval: Date: WINJ , c, GINJ JE WAG JE Abandoned Commission Representative: GSTOR r SPLUG IT 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Weifeng Dai @ 263 -4324 Printed Name Weifeng Dail Title: Drilling Engineer �/1� Signature �' " i' a Phone: 263 -4324 Date Commission Use Only Sundry Number: 31 ( J Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test VMechanical Integrity Test r Location Clearance JT Other: 40 ps ,r33e r° - Subsequent Form Required: /p — !y d 7- I/ APPROVED BY Approved by: CF` COMMISSIONER THE COMMISSION Date: { �Z" q For vi 11201 P 5-16- 12-- ORIGINAL Subrnit in Duplicate , t'v • • Dovon 19 CD1 -22A Abandonment Procedures The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 9.6 ppg kill weight brine through tree and monitor flow for 30 minutes. 6. Set BPV and test through inner annulus to 1,500 psi. 7. Set blanking plug. 8. Nipple down tree. 9. Nipple up BOPE and test with 4.5" x 7" test joints to 4,000 psi. 10. Remove blanking plug and BPV. 11. Pull 4 -1/2" tubing (pre -cut at —3,600' MD). 12. Pressure test lower rams with 3.5" and 5" test joints. 13. Run in hole with CIBP on 5" drillpipe and set at —3,370' MD. PT to 2,500 psi. 14. Run in hole with mechanical casing cutter on 5" drillpipe and cut casing at —3,320' and —3,000' MD. 15. Flush 7" x 9 -5/8" annulus with 9.6 ppg kill weight brine taking returns to tiger tank. 16. Swap 3.5" x 6" rams to 7" casing rams and pressure test. 17. Pull 7" casing to surface and lay down. 18. Swap 7" casing rams to 3.5" x 6" rams and pressure test. 19. Pull 7" cut section with spear and lay down. 20. RIH with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 200 ft within the surface casing. 21. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and kick off plug to 3,500 psi. 22. Ready to move into drilling phase. 7 Nom,, PTD • • CD1 -22A Current Schematic •, WNS CD1 -22A Cx)nptopiiiiips i S `, Well Attributes Max Angle & MD TD ,r_3 -. II1 1 w ken A IN. r le I. 115,5 • w.1 � 1 5i . 10i PI MD 74015 4.1 him 1115.1 . ...a 0010320215CC? ALPINE PROD I 8.308.!4 II50)C [ernanl 14e lppn: rm. 6nnalMb, 1n0 NM 5114mre1 .141.I..r0wo .. . 155.1 Cain ___try 1. =spy7awl 1 6&50: WROP 1.4704 WO' 1305 9'18'190. 15515.7.5 0*1,0, IY061 85.2.4. Am4111e Sri Ma4. [ *05.4. Last Tag'. Rev Rea. , A00 CE6ENT nram 5 Casing !Winos e...m u...r4Mee oxna 0... 54109 0.. to,11x1; 5.1 4.4.9. e41 D. W II O1... aY.r. wt. 56l. .. 5eka Tap 1km CONDUCTOR W 16`002 360 90.0 90.0 WELCIEC' I 1 t,.... nu ...anp.." ]699 64x90.. Tep111111 5.40441 ea no,. 11V01.. 54'*g 157.. 0 . 0 9... 55.w Ten 1154 SURFACE 650 9,697 330 3,1170 3.109.9 3600 J.66 ST: Ca , 11,.144.. 9 6411005.. 10p 1MM5 00 644.,0.. e.e 0.09111661.. 9450 kit. 9.159.. 50100 Tap Th. PRODUCTION 7 9,066 330 9,4300 6,030.6 25.00 L-80 6T0 taW.9 1irer4tan 915 45115 O.. .9 O.- 10 'NI 0 r 6W04151_ - .WWI 9 ' ee 64P•ITWI m ■t. 15! .. 91x9 TeprMa r : OFEN 5101E 61.0 657 64300 11,600.0 6825.2 g 14+1004, 5 T ubin 5trils TaW49 0141.„ 74159 D.. 0e149 O.. 1..06461 0•105111 II.. eo D.pK 11451... Nee, Wt.. 100 9.. 51 71,4 TUNNO a 1' 3.658 326 7,606 6763. 1267 L80 16711 � _.. Ca+npteti O tips [r9 tap 3853 Tap 46.911 161911 511 111 9.0954115 cp0.n.,e 1 611 336 32.6 0.63 5tA5OEl1 FNC 74%000 HANGER 0.660 5,717.6 1,717.3 1.41 APPLE CAJALO BAL -O NIPPLE 3.812 I I 7,636.1 6,7036 47.02 NIPPLE IE8'X NIPPLE 3.813 7,6786 6,732E 50.61 PACKER BAI.R S.3 PACKER 3,876 6440L4 ∎ PTT 7,654.3 6,776.7 56.40 NIPPLE HES - 1550 NIPPLE 3726 7,665.1 6,783.1 57.13 60167. BAKER WIREUNE ENTRY GUIDE 4600 Other In Hole (Oreille retrievable plugs, valves, pumps, fish, etc -) S 8.1,1n 07101 Tap In.i •4RpCi 1001m.111 (Wei I'1 beop10. Conn-am Ran2414 ID DM .3110 67937 505544 3964 CEMENT P1*np6620611 :7 of 15.16 clam C 5293 491710411 6910,4 4 0000 1460.. Pu1np03 an a4]6ana120 8818 in IA. TOC 96 II 6537 7.6'34 6,748.2 53.511 RETAINER BELATAILE RETAINER 40)0)12 0000 Wiwi Notes: General & !37.417 6891 . r 1a4 0014 +nnoxeon 110201203P NOTE: FBHP SURVEY TAKEN 923.21105 857812010 NOTE: "NO NR0P IN WELL" 21147611 NOTE: Yew Senamale w Kaska 54•09619 0 I 0.0107 IC ]965 1 II OW • 6153 785. 7 lir 151 III V NWAR. MO !f . II IA 11,74`0 1 101 _ III :MINT i r. 3 PCTk. . J III Mandrel Details TITT tag DWI, 1¢ pen IT.661 0111 Oa voo heel Iso TOO R., 1.40156 i 9A. 11 54, T41R011;1 ag14 ('1 M. MOM 11$ e... T4Y. 1594 1151 WO Run cos. Con. 4 3426.3 3422.4 63.77 0415100 156712 1 048 UFT OLV 817 0 15 1561.0 01142002 2 5.562.7 62/2.84519 CAMCO 100.2 1 OAr LIFT OLV BO 0. 186 1.6330 11103 T 150 3 7.4665 5.619,4 44.49 745170 1580.2 1 O48 UFT CV BK 0.262 50 7111942007 Cwt7.T T Re PRCC9c•43.1 1:314 o 4 T . T r 414 11'3[ O • a 41,•300,, ` Tolcal.a:y ., goo- '• • • CD1 -22A Set -up for Sidetrack Well Schematic Colville River Field CD1 -22A Alpine Producer Rig Abandonment All Depths Adjusted for Doyon 19 RKB J L 5uIat0d Conductor to Updated — 03.21.12 < ! Top of Plug @ 2,910' MD / 2,910' TVD r u 0 J � p Pp9 �'' 9 -5/8" 40# L -80 BTC Surface Casing 3,110' MD ! 3,109' TVD Kick Off Plug < - KOP at 3,200' MD < 7" Casing Stub @ 3,320' MD <- - CIBP at 3,370' MD < Cut Tubing @ 3,600' MD J Top of P &A plug @ 6,479' MD Planned Top of 15.8 Class G Cement iL , 6472' MD / 5867' TVD 3/L Hi *l POD TD 6 -1/8" hole 7" 26 ppf L - 80 BTC Mod 11,500' MD Intermediate Casing @ +1- 8436' MD R` • • Work Approved in Sundry # 312 -141 Objectives The objective of this procedure is to abandon the existing Alpine C interval and set up the well for a rig sidetrack. The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid, and cut the 4.5" tubing at 3,600'. Procedure 1. Shoot squeeze perfs above the packer at 7,579' MD. 2. Run in hole and set inflatable cement retainer below packer. 3. Pump 25 bbls of 15.8 ppg Class G cement through retainer and into open hole. 4. After 25 bbls through the retainer, pull up and squeeze 20 bbls of the same 15.8 ppg Class G cement into the IA above the packer. 5. Lay in 20 bbls of cement on top of the retainer. 6. Tag cement top 7. PT tubing and IA to 2,000 #. 8. Punch tubing just above the cement top. 9. Circulate in corrosion inhibited 12.6 ppg mud (based on last SBHP) and diesel freeze protect. 10. Equalize tubing to ensure freeze protect on both tubing and IA. 11. Cut tubing at —3,600'. 12. Set back pressure valve in preparation for the rig. • . • 0 Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art /� or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 V form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). ii . On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. I file: //F:\ Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 11/16/2011 • 0 WELL LOG TRANSMITTAL 2 oc, To: Alaska Oil and Gas Conservation Comm. April 25, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Cement Retainer Setting& Perforation Record: CD 1-22A Run Date: 4/23/2012 &4/24/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-22A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20250-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. •&SCOW Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Klinton Wood@halliburton.com da4Date: 5(M/k7., Signed: • • r - ( ; : , - r , Li, b=13, u ALAFAL.,-:\ ; SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 TY Senden Staff Wells Engineer ConocoPhillips Alaska Inc. 1 P.O. Box 100360 © � Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1 -22A Sundry Number: 312 -141 Dear Mr. Senden: .c`A'` ,1 A v'P Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '' . Foerster Chair DATED this v day of April, 2012. Encl. STATE OF ALASKA 07 q / /a ( RECEIVED A OIL AND GAS CONSERVATION COMII�ION APP FOR SUNDRY APPROVALS APR 0 52012. 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill ji • Perforate New Pool I Repair w ell r Chant, Q oPam r Suspend T7 Plug Perforations j;: Perforate r RJII Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well f Stimulate r Alter casing r Other:Variance for lu depth P 9 P F; 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J + Exploratory r 200 -110 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20250 - 01 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J CD1 -22A . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25558, 25559 Colville River Field / Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11500 • 6925 ' 11500' 6925' Casing Length Size MD TVD Burst Collapse CONDUCTOR 45 16 80' 80' SURFACE 3077 9.625 3110' 3110' PRODUCTION 8398 7 8430' 6931' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 8430' 11500' 6931' - 6925' 4.5 L - 7665 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 7579 TVD= 6733 SSSV - CAMCO WRDP SSSV MD =1717 TVD =1717 12. Attachments: Description Summary of Proposal ' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/14/2012 Oil r Gas r WDSPL r Suspended ]d • 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is tru. a and correct to the best of my knowledge. Contact: Ty Senden © 265 -1544 Printed Nanfe , \ Tv nden Title: Staff Wells Engineer '� Phone: 265 -1544 Date 4 f 1 ` Z Signature b 1 I Commission Use Only Sundry Number: 7 (4 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r Mechanical Integrity Test r Location Clearance r IL itja - ( y i tiye Y - s ;n /,' Other l 4 - - A lfer�it / 0 1 u _ j / 0 A. e • j A A Subsequent Form Required: f 0 - Ljb APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9 " /0 " /Z--- ,/ Form 10 -403 Rhised 1/2010 c( - - "'`: {N S APR 1 ZO12 Submit in Duplicate �, ,o . oRIG1 '� �6 4.47 ��2 . • • • • CD1 -22A Abandonment The following procedure will be used to isolate the perforations and protect the production packer from the reservoir. The well will be sidetracked under a separate Sundry and permit to drill. This work will need to be done (this April) prior to the end of the Alpine ice road. 1. Shoot squeeze perfs above the packer at 7579' MD. 2. Run in hole and set inflatable cement retainer below packer. 3. Pump 25 bbls of 15.8 ppg Class G cement through retainer and into open hole. . 4. After 25 bbls into the slotted liner pull up and squeeze 20 bbls of the same 15.8 ppg Class G cement into the IA above the packer. 5. Lay in 20 bbls of cement on top of the retainer. 6. Tag cement top. IJo !-.• �� cr� (C4 O..� 7. PT tubing and IA to 2000 #.`j P 8. Punch tubing just above the cement top. 9. Circulate in corrosion inhibited 12.6 ppg mud (based on last SBHP) and diesel freeze protect. 10. Equalize tubing to ensure freeze protect on both tubing and IA. 11. fit tithing at -3600'. 12. Set back pressure valve in preparation for the rig. NOTE: This sundry will require a variance for plug depth 20 AAC 25.112 (b) (3) as the distance between the production pack r and casing shoe is greater than 500'. e w. - r re The rig will not move onto the well until mid to late summer. Once the rig is on location the following will be accomplished under this sundry. 1. MIRU Doyon 19. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 1,500 psi. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 13.0 ppg kill weight brine through tree, taking returns to tiger tank. 6. Set BPV and test through inner annulus to 1,500 psi. ✓ 7. Nipple down tree. 8. Nipple up BOPE and pressure test 9. Remove blanking plug and BPV. 10. Pull 3 -1/2" tubing. 11. Run in hole with CIBP on 5" drillpipe and set at 3.340' MD. 12. Run in hole with mechanical casing cutter on 5" drillpipe and cut casing at 3,320' MD. 13. Flush 7" x 9 -5/8" annulus with 13.0 ppg kill weight brine taking returns to tiger tank. 14. Swap 3.5" x 6" rams to 7" casing rams and pressure test. ' 15. Pull 7" casing to surface and lay down. • AA'' 16. Swap 7" casing rams to 3.5" x 6" rams and pressure test. p V 17. RIH with 3.5" cement stinger and set 17.0 ppg cement kick off plug from the top of bridge plug to 100 ft within the surface shoe, POOH and WOC. 18. Pressure test surface casing to 3,500 psi, 30 minutes. 19. P/U drilling BHA and RIH. 41 gill out kick off cement plug and 20' formation, perform LOT to 18.0 ppg. the w/ ' 7/ w¢I �'ic+s C/folk'" 7"O /!airy ft r r€, 70 9 -�- co/7 c r, r'ot,en ( .ms's , e /4r 41107)7' TD flo 7 ✓ > a pew-- i. v 0 PPr r 06 �Pf(/�T GZ° f T U � cwr 88l or - To cro dieflein �� T 7��e -Pere 7,4p ✓, rU cf V // O r of T4� l� i f rox [6'69 vei -tore 4c 10/. W NS • CD1 -22A �� '� Well Attributes Max Angle & MD TD ... F h.44 v _ i Welibore API/UWI Field Name Well Status Intl n MD (ftKB) Act Btm (ftKB) „ -.:" 501032025001 ALPINE PROD 96.66 8,308.14 11,500.0 Comment H2S (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date "' —SSSV: WRDP Last W0: 44.09 4/18/1998 Well Confie - CD1 -22A, 12/8/2009 9.27 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: RESET WRDP Imosbor 12/7/2009 Casing Strings String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top (ftKB( (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 80.0 80.0 a ; SURFACE 95/8 8.697 0.0 3,110. 3,109.6 36.00 J-55 BTC PRODUCTION 7 6.059 0.0 8,430.0 6,930.6 26.00 L -80 BTC CONDUCTOR, OPEN HOLE 6 1/8 6.125 8,430.0 11,500.0 6,925.2 80 I Tubing Strings String OD String ID Set Depth Set Depth (ND) String Wt String Tubing Description (in) (In) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd TUBING 41/2 3.958 0.0 7,666.0 6,783.6 12.60 L -80 BTCM NIPPLE, 1,717 t Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) VALVE, 1,717 \ Top Depth (ND) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 1,717 1,716.8 1.41 NIPPLE CAMCO BAL -O LANDING NIPPLE 8113/2000 3.812 1,717 1,716.8 1.41 VALVE CAMCO 3.812" WRDP -2 (HSS -241) 12/7/2009 2.125 SURFACE, 3 3,422.5 13.76 GAS LIFT CAMCO/KBG2/1 /GLVBK/.188/1631/ Comment: STA 1 1/18/2003 3.938 3.110 5 , 553 5,202.5 40.19 GAS LIFT CAMCO/ KBG2/1 /GLVBK/.188/1633/Comment: STA2 1/18/2003 3.938 7,456 6,647.6 41.46 GAS LIFT CAMCO/KBG2/1 /OVBK/.25/ Comment: STA 3 11/19/2007 3.938 7,536 6,704.9 47.11 NIPPLE HES DC NIPPLE 8/13/2000 3.813 7,579 6,733.1 50.64 PACKER BAKER S -3 PACKER 8/13/2000 3.875 7,654 6,776.6 56.38 NIP HES'XN' NIPPLE 8/13/2000 3.725 GAS LIFT. - 3.426 Notes: General & Safety - End Date Annotation t ill 11/21/2007 NOTE: FBHP SURVEY TAKEN 9.23.2005 GAS LIFT, 5,553 I -p e (0'171 tt'` GAS LIFT. �,f / U //� 7.456 a r b a ( `. A ` l 0 /5 (1 GPI NIPPLE, 7,536 PACKER, 7,519 I II � _ _ GM'T' \ t( r ( I �� 0" .f ,, 00 cbt— NIP, 7.659 q fl, ✓ y ^ e' s / / � (, - y , 5 O 4 V tv 4^ Li J )50 % ( U 6 . . tt t_ 6t-;'/-.2 0 3$1 664- if. PRODUCTION, 8,430 tI • • Open Hole, , 9.235 • n 41-4, - —z— • OPEN HOLE, e '1,500 Z' TD(CD1 -22A), . 11,500 • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 CD1-22A PTD # 200-110, notice~T X IA communication • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ll~~'~~ Sent: Monday, November 26, 2007 4:25 PM ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: CD1-22A PTD # 200-110, notice of T X IA communication Jim, ~.,~'" On 11!19107 Slickline pulled the OV and the check was seized open with scale. They performed an IA draw down test after resetting the OV and all indications showed that the TxIA communication was fixed. Due to the weather we have been unable to get out to Alpine but the DHD crew will get out there as soon as passible. Please let me know if you have any more questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ~,~~ N()~J ~ ~ 2007 From: Regg, James~B (DOA) [mailto:jim.regg@alaska.govJ Sent: Monday, November 26, 2007 3:36 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: CD1-22A PTD # 200-110, notice of T X IA communication Any update regarding this well? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:nl617@conocophillips.com] Sent: Sunday, November 18, 2007 12:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: CD1-22A PTD # 200-110, notice of T X IA communication Tom, CD1-22A PTD # 200-110,gas lift producer, is showing signs of T X IA communication. Operations swings the well often to prevent flair and noticed the IA pressure has been climbing above header pressure during shut in events. We have not performed a TIFL on the well. T/I/O = 177/850/350 11126/2007 CD 1-22A PTD # 200-110, notice T X IA communication Page 2 of 2 Slick line is on the well today and wi~place the OV & GLVs then test tubin • 9 I've enclosed the 90 day TIO plot and a schematic. The well has been added to the SCP list. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «CD1-22A 90 day TIO.jpg» «CD1-22A.pdf» 11/26/2007 ~ 2a~ -i ~~ ~~1,. r~~ 3000. t![,Ifl. 3000 ~nnD. ;snap. z7oo 3000. 30011, 2400 3000. 2100 1A00 0. 0. a~ 0. 0. 0. 0. 0. 1500 1200 WELT. NAMh WLALPCDI-22 900 600 300 0 PLOT START TIME MINOR TIME t T.f)~ 1iuT?~."i'TON 1'LO'I~ t?FJU "C"T ME 20-AUO-07 12:42 MAJOR TTME WEER +0216n:00-0Q .art, 18-NOV-07 12:42 PICK TTNE 17-N OV-07 18:37:12 SC TAG NiHE DESCRIPTION P-VALUE LATEST CD1A-MOV-IB-POS FLOW TUDING CHORE 77777?? ~ SCRATCH 80 FLOW TUBING PRESSURE 7777777 :CRA'I'CI1.._OCI FLOW "I1.TIlI.NO 'I'1~:MP 777777"~' ~ CD1-PI-34103-18 OL CASINO PRESSURE 7777777 7777777 ~ ?777?77 ~ SCRATCH_80 YNNER ANNULUS PRES 7777777 SCRATCH_00 OUTER ANNULUS PRES 7777777 ~~ ~ DRI[.LSITE WELL PREV WELL CD1 22 NEXT WELL F:N-rw ~~rT'F~ OPERATOR OPERATOR VERIFIED ",r., t~!•:M ?.(I~1"ri F:IT"1°T?"t ~ BOTH • TUBING (0-7~, OD:4.500, ID:3.958) SURF CASING (0110, OD:9.625, Wt:36.00) ~ • Conoc©P#~tlips Ataiska, tic. ALPINE _. --~ CD1-22A -- - 1 ;~' : ~ I' `, ~ : ; CD1-22A API: 501032025001 Well T e: PROD An le TS: de SSSV Type: WRDP Orig Com letion: 8/13/2000 Angle @ TD: 89 deg @ 11500 Annular Fluid: Last W/O: Rev Reason: Set WRDP Reference Lo Ref Lo Date: Last U date: 3/22/2005 Last Ta TD: 11500 ftK6 Last Tag Date: -_ _ - - Max Hole Angle - 97 deg @ 8308 - Casin~c Siring- ALL ,I j Tubing Strong -ALL PROD CASING (0-8430, OD:7.000, wt:2s.oo> Gas Lift MandrelNalve 2 (5553-5554, Gas Lift MandrelNatve 3 (7456-7457, NIP (7536-7537, OD:4.500) PKR (7579-7580, OD:7.000) NIP (7654-7655, OD:4.500) OPEN HOLE (8430-11500, OD:6.125) ........ f i ~~ 1 _ I Size To Bottom ND Wt Grade Thread ' _ _4.500 0 7666 6784 12.6 0 L-80 BTCM Gas Lift MandrelsNalves 3 456 6648 CAMCO KBG2 CAMCO OV 1.0 BK 0.250 0 1/18/2003 , St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv F Run Cmnt 1 3426 3422 CAMCO KBG2 CAMCO GLV 1.0 BK 0.188 1631 1/18/2003 2 5553 5202 CAMCO KBG2 CAMCO GLV 1.0 BK 0.188 1633 1/18/2003 7 Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.00 H-40 WELDED SURF CASING 9.625 0 3110 3110 36.00 J-55 BTC-MOD PROD CASING 7.000 0 8430 6931 26.00 L-80 BTCM OPEN HOLE 6.125 8430 11500 11500 0.00 " . . ~ ConocoPhillips Alaska ,"'( () 7 , .,. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 2, March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 ~OO-~'O Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells :trom 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 :trom 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, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" oa 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" oa 8" oa 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" oa 4" oa 1 3/8/2007 CD1-40 199-044 4" oa 4" oa 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-1 06 8" oa 8" oa 3.7 2/16/2007 CD1-44 200-055 10" oa 10" oa 4.7 2/16/2007 CD1-45 199-101 4" na 4" oa 2 2/19/2007 CD1-46 204-024 36" oa 36" na 16.9 2/16/2007 Alpine Field March 31,2007 F:\LaserFiche\CvrPgs _lnseI1s\Microfì 1m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ) ) ConoCOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- '~ Schlumberger batch-mixed A.retie Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The 'attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.~ WI 3.6 CD1-3 10' 1.4 MI ; 8.5 CD1-4 7.32' '1 P 6.0 CD1-5 4' 0.6 MI 3.6 651-6 10142' 1.-4 -" 8.5 CD1-16 14.3~3' ~" WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-2-1 l:Jr 1.8 MI 10.9 CD1-22 1.83' 0.3 P .... 1.8 CD1-23 15.42' 2.1 MI 12.7 --- -- CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 --"~8.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 cD1-34 41.83' 5.7 _re_p_._ 34.4 . CD1-36 16.75' 2.3 WI ...... 13.9 __ CD1-38 3.5' 0.5 P 3-~0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.-~' -'~'.6 P -- - 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P ....... ~.3 CD2-26 10.42' 1.4 INJ 8.5 CD2,32 8.5' 1.2 INJ 7.2 CD2-33 -- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 C D 2-4 B -'--~'~ mi' ~'~X...........qJ. 4 I'N-J' .................. §i~-- ....... CD2--49 9.33' 1 .3 INJ 7.8 CD2--50 1 .66' 0.25 P 1 .5 Alpine Cement Top Fill Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this · kind of work. Due to the number of these, is a 10-404 needed on each well? · I don't want to commit the time to doing this if it is not necessary; · 10-404's are time consuming to prepare. Would a list of the jobs suffice, · or something similar? We have the well numbers, depth to cement top, and · sacks used to fill the void. My proposal would not affect future · submissions of 10-404's for this work. What do you think? Thanks! · · Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4/24/2003 7:55 AM Alpine Cement Top Fill ~_~AOGCC ALPINE cement top outs 04-16-03.xls Name: AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 DCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WlNWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 AM WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE' Distribution - Final Print[s) 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' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 ...... LOG DIGITAL MYLAR / BLUE LiNE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUE LINE Open Hole I ' I i .... Res. Eval. CH I I 1 Mech. CH CD 1-22A 3-18-03 "Caliper SUrvey 1 CD I Rp't or 1 Color , , , Signed · Print Name: Date · RECEIVED APR 0 t 200~ A~asl~ O~ & G~ Ca~$~ Cemmis~ Pr~oAcTivE DinqNosfic SE,vicEs, Inc., } 10 K S'm£ET SuiTE 200, AnchoR^q£, AK 99~;01 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog, com Website: www. memorvlog.com OCT i & 2003 Memory Multi-Finger Caliper Log Results Summary Company: CONOCOPHILLIPS ALASKA INC Log Date: March 18, 2003 Log No.: 4976 Run No.: 1 Pipe1 Desc.: 4.5" 12.6 lb. BTCR Pipe1 Use: Tubing Well: CD 1-22A Field: ALPINE State: Alaska APl No.: 50-103-20250-01 Top Log Intvll.: Surface Bot. Log Intvll.: 7,666 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Tubing Tail @ 7,666' (Drillers Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4.5" tubing is in good condition. No significant wall penetrations (>11%) are recorded. There are no areas of significant Cross Sectional Wall loss or I,D. restriction recorded throughout the tubing, The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: No Significant (>11%) Wall Penetrations are recorded MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No Significant (>6%) Cross-Sectional Wall Loss is recorded MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. Field Engineer: N. Kesseru Analyst: J. Thompson Witness: W. Rauchenstein ProActive Diagnostic Services, Inc. / P..O. Box 1369, Stafford, TX 77~97 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mai~: PDS@memorylog.corn Prudhoe Bay Field Office Phone: (907) 659-2307 Fa)(: (907) 659-2314 ~ Body Region Analysis Well: CD 1 22A Survey Dale: March 18, 2003 Fie]d: Al PINE loo] ~ype: MFC q0 No, 99494 Company: CONOCOPHILIJP$ Al ASKA, INC. Fad Size: 2.75 Country: USA No. ot Finge/s: 40 Analys~ ~ubingl N[)~ OD weigl{~ d~ade & [bread Nora. ID Norn Upse~ Uppp~ Jen__ Lowerlen 4~ Ns 126 pp~] B rCM 3958 ~ns 4:5 Penetration and Mela[ Loss (% wall) ~ penetration body ~ me~a] loss body 250 , 150 Damage Configuration ( body ) Numbe~' °f :°inls:~ l d~rn ~oed~ ! ~ (tota~ = 1 0 0 0 0 Damage Profile (% wall) ~ peneiraNon body ~ metal loss body 0 50 100 1 f r 51 98 GtM 1 146 GLM 2 t94 GLM 3 8oiRom o~ Survey = 2263 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 2.6 ppi BICM Well: CI) 122A VVaH th]ckness: Body = 0.271 ins Upset = 0.271 ins Field: ALPINE Nomina) It): 3.958 ins Company: GONOCOPI IILLIP$ ALASKA, INC.~ penetration body CountW: USA ~ metal ]oss body Su]~,ey Dale:March 18, 2003 joint Penetralion ~Meta) ' Proj~ction [Minimum [Damage Profik~ No. i Upset ]Other Body ]~ oss Cp)ng ~ody ID [Commems P~ wa ) inches [ inches h~ches '~ % c es i 3ches J inches D S0 I00 0 ) 01 ] 4 2 0 3 89 ' ~ ~ 4 0 0 01 4 J 2 0 0 3 88 .01 4 I 0 3.90 .01 4 2 0 0 J 3.89 02, 6= ~ . o _ o . 3~o .01 ~4 2 0 0 ~ 3:90 .01 5 t 0 0 3.90 23 0 0 .01 5 2 0 0 3.89 28 [ 0 0 )1 5 1 0 0 3.91 29 ) )1 4 ? 0. 3.90 0 0 t 0 31 0 0 .02 6 2 0 0 3 90 32 0 0 ~01 4 [ 2 0 ) i 3.88 0 0 02 6 1 0 ) ] 3,89 39 ~ o , o ) 5~i 2 , 0 : o ~.90 4o ~ 0 , 0 j .0~ ~ j 2 , 0 , 0 3.90 41 0 () () 3 2 ( 0 3.9o 4~ 0 0 0 5 R ) C 3 9( 44 0 0 0 4 0 0 ~.90 49 0 0 0 J4 2 ) ( ~.89 50 0 0 5 1 ) 0 3.90 Pipe i abulations page 1 PDS REPORT/OINT TABULATION SHEET Pipe: 4.5 ins 12,6 ppf BiCM Weli: Ct) f-22A Wall thickness: Body = (t271 ins Upset = 0.271 ins Field: Al PINE Nominal liD: 3.958 ins Company: CONOCOPI tILl IPS ALASKA, INC.~ penetration body Country: USA ~ meta)loss body Su~ey Date: March 18, 2003 joini Penelration ~Metal ' Pro~ection~linimum l)amage Profile No. Upset Other Body Loss ~Cp]ng ~ody II) Commenls (% Mches inches inches % ] % [ c es]inches inches ~ 50 10B 67 0 0 i 0/ i 4 1 0 i 0 3.90 80 0 0 /)1 i 5 i 3 88 0 0 i .01 4i I 89 0 0 [ .01 2 90 8 0 .01 2 9 I 0 0 1)0 92 0 0 .02 7 2 93 [) 0 01 4 1 94 B 0 .OX 6' 2 95 !? o 96 0 B .01 2 97 0 0 .0l 5 I 0 0 3.89 0 i0 3.89 0 i0 3.88 0 B 3.89 0 0 3.87 0 0 3.88 0 0 3~90 0 0 3.88 0 0 3.89 0 0 3.89 0 0 3.90 Pipe labuiations page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf 8TCM Wel]: CI) 't 27A Wall thickness: Body = 0.271 ins Upset - 0.271 ins Field: ALPINE Nominal ID: 3.958 ins Company: CONOCOPI IILLIPS ALASKA, INC.~ penetration body Countw: USA ~ metal loss body Su~wey Date: March 18, 2003 'joint ~ Penebation i~e~d) ~5~}ec~o~; ~%~;~;mm~ Darnage Profile No. Upset Other 8ody Loss iCplng j~ody I13 Comments i (% wall) inches ~ches i c~es l% % [ inches i inches inches 0 50 100 99 ) 0 .01 4 ( t 0 0 3.90 I00 i 0 i0 .01[2 2 [ 0 0 3.90 i101 0 '~ 0 .0t 4 2 0 0 3.88 0 j0 .01 2 i 6 0 0 3.88 ~.88 3 0 3.89 106 0 0 .02 6 2 0 0 ~.87 106.1 0 0 .02 6 I 0 0 3.87 PUl' I10 0 0 .01] 5 2 1:1i ' (5 ' i) ' .027 t12 0 0 .01 2 5 2 5 2 1 t 6 0 0 ,02 2 0 0 .02 2 118 0 0 .00 2 119 0 0 .01 5 2) 0 0 I 2 0 0 123 { 0 0 .01 2 i 2 0 [ 0 3.89 3.89 3.90 3.88 3.89 3.89 3.87 3.88 3.89 3.89 3.89 3~90 3.89 3.88 126 0 0 .01 2 127 0 O .02 ~ 0 0 3 129 ~ 0 0 . 01 i 3] 2 130 0 0 .01 2 2 132 0 0 .0 / 2 133 0 0 2)1 2 0 0 ]35 0 0 .01 4 2 136 0 0 1) I 6 ' 2 142 143 144 .01 5 .02 .02 2 i o 0 2 0 0 0 0 0 0 0 0 0 0 [0 0 0 © 0 0 0 0 0 0 0 0 0 0 3.89 3.89 3.89 3.89 3.88 3.87 3.89 3.86 3.89 3.88 3,88 3.88 0 3.89 0 3.9(3 O 3.88 0 3.87 0 3.87 0 3.9O .04 3.89 Pipe 'I abulations page 3 PDS REPORT IOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppi' B'iCM Well: CD 1 22A Wall thickness: Body--0.271 ins Upset 0.271 ins Field: ALPINE Nominal ID; 3.958 ins Company: CONOCOPItlLt IPS Al ASKA, INC.~ penelradon body Country: USA ~ rneiai ]oss body Survey Date: Match 18, 200¢ Dint Penetration ~eial' ProjectionMinimum I)amage Profile Other Body Loss iCp]ng ~ody ID Commenls (% wail) inches [inches i% % i inches i inches i inches 50 100 i 154 :0 , 0 ~ .01 ~ i 2 ~ 0 0 3.88 159 0 0 .0 I 4 1 0 0 ~.89 163 O 0 ] .01i~ 2 0 O 3 89 165 0 0 .()2 i [ 2 0 0 ~.89 168 0 0 .02 i 2 i 0 0 [ 3.89 170 0 0 [ .01i 2 0 i ) 3 f 7 i~ 0 ~ 7()~ ~ ~ 387 17~2 0 0 0 0 0 O ' ( N/A ~G M 2(~ak::h~4:0O~ IZOd3 0 ~0 .02 9 2 , 0 0 ~ 3.89 ~up ~ 73 0 0 o2 2 0 0 3.88 i 174 0 0 01 2 0 3.88 181 0 ,0 ~ .01 5 2 , 0 0 3.87 I82 0 0 i .0~ i 5 ~ 0 0 L87 18g o 0 .o2 3 0 o 3 88 Pipe Tabulations page 4 PDS REPORT JOINT TABULATION SI IEET Pipe: 4.5 ins t2.(~ ppf BICM Well: CI) 122A Wall thickrless: Body = 0.271 ins Upset = 0271 ins Field: ALPINE Nominal ID: 3.958 ins Company: CONOCOPt IILLtPS Al ASKA, tNC.~ penetration body Countw: USA ~ metal loss body Survey Dale: Mmch 18, 2003 ' loin~ ' PenelraNon Me~a] I Pro~ec~ion[Minimum' ] Damage Profile No. Upsel i O he~ 8od~ oss Cping !~ody ID ]Comments (% wall) inches inches i inches % nches inches i k~ches ~ 50 100 0 0 .02 2 il 930 0 1 194 0 0 6 2 0 0 .02 2 [ 1960 0 ,02 2 [197 [ 0 0 .03 9 1 L198 ~ 0 . 0 ,02 ] 9 199 0 0 .02 [ 9 [ 2 700 0 0 .02 8 1 2o! i o ~ o o3 lo ~ 202 0 0 ,02 2 203 0 0 .03 204 0 0 .02 8 1 0 0 .03 206 0 0 .03 207 0 0 .02 1 0 0 .02 2 )09 0 0 .03 1 0 j0 3.89 0 i0 3.87 0 0 3.88 O 0 3 ~90 0 0 3.91 0 0 3.92 0 0 0 3.90 0 0 3.90 0 0 3.92 .160 3,88 3.84 0 0 3.90 0 0 3.92 0 3,85 0 0 3.93 0 0 3.92 0 0 3.87 [ 2 6 0 0 .02 8 t 0 3.91 25~ 5 0 4 2 0 0 3.91 220 0 0 .01 4 2 0 _ 0 3~ 22411. 0 0 :9! 4t 1 0 [0 3.91 iPUP 224.2 0 [0 0 13.88PACKER 0 0 .02 6 3.91 PUP 225 0 0 .03 11 3 0 0 i 3.88 226 0 0 .!)1 0 0 L22(~:10 ,0 [0 0 I 0 0 3.72 i XN NIPPLE 226.2 0 0 [ .02 0 [ 0 .01 3.84 PUP 226.3= O .O ·0 0 0 O 0 ] ~/A [UBIN~TA!L Pipe Fabulations [)age 5 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf BTCM Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 1 25.43 32.05 3.927 3.928 3.958 4.500 2 57.48 32.10 3.939 3.938 3.958 4.500 3 89.58 31.30 3.937 3.936 3.958 4.500 4 120.88 32.25 3.936 3.935 3.958 4.500 5 153.13 31.58 3.934 3.935 3.958 4.500 6 184.71 31.22 3.937 3.936 3.958 4.500 7 215.93 31.57 3.936 3.937 3.958 4.500 8 247.50 31.93 3.931 3.933 3.958 4.500 9 279.43 31.69 3.944 3.942 3.958 4.500 10 311.12 31.55 3.935 3.938 3.958 4.500 11 342.67 31.68 3.934 3.936 3.958 4.500 12 374.35 31.38 3.934 3.936 3.958 4.500 13 405.73 31.05 3.945 3.945 3.958 4.500 14 436.78 31.59 3.937 3.937 3.958 4.500 15 468.37 31.51 3.947 3.946 3.958 4.500 16 499.88 32.09 3.939 3.940 3.958 4.500 17 531.97 31.10 3.936 3.937 3.958 4.500 18 563.07 31.78 3.944 3.943 3.958 4.500 19 594.85 32.33 3.952 3.950 3.958 4.500 20 627.18 31.24 3.943 3.941 3.958 4.500 21 658.42 31.74 3.944 3.945 3.958 4.500 22 690.16 29.66 3.935 3.935 3.958 4.500 23 719.82 31.86 3.930 3.933 3.958 4.500 24 751.68 31.67 3.932 I 3.934 3.958 4.500 25 783.35 31.86 3.934[ 3.935 3.958 4.500 26 815.21 31.69 3.934 3.939 3.958 4.500 27 846.90 31.86 3.936 3.935 3.958 4.500 28 878.76 31.66 3.950 3.948 3.958 4.500 29 910.42 31.69 3.938 3.941 3.958 4.500 30 942.11 31.10 3.931 3.933 3.958 4.500 31 973.21 31.27 3.942 3.942 3.958 4.500 32 1004.48 31.82 3.936 3.938 3.958 4.500 33 1036.30 31.17 3.929 3.932 3.958 4.500 34 1067.47 31.55 3.934 3.935 3.958 4.500 35 1099.02 31.37 3.935 3.936 3.958 4.500 Well: CD 1-22A Field: ALPINE Company: CONOCOPHILLIPS ALASKA, INC. Country: USA Survey Date: March 18, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 36 1130.39 32.56 3.935 3.935 3.958 4.500 37 1162.95 31.50 3.938 3.939 3.958 4.500 38 1194.45 32.23 3.937 3.938 3.958 4.500 39 1226.68 31.72 3.945 3.945 3.958 4.500 40 1258.40 31.79 3.941 3.942 3.958 4.500 41 1290.19 31.57 3.934 3.934 3.958 .4.500 42 1321.76 30.85 3.945 3.944 3.958 4.500 43 1352.61 31.59 3.939 3.940 3.958 4.500 44 1384.20 31.98 3.945 3.942 3.958 4.500 45 1416.18 31.73 3.942 3.943 3.958 4.500 46 1447.91 31.56 3.944 3.944 3.958 4.500 47 1479.47 31.75 3.943 3.944 3.958 4.500 48 1511.22 31.45 3.935 3.934 3.958 4.500 49 1542.67 31.89 3.934 3.934 3.958 4.500 50 1574.56 31.53 3.936 3.937 3.958 4.500 51 1606.09 31.99 3.934 3.935 3.958 4.500 52 1638.08 31.78 3.939 3.937 3.958 4.500 53 1669.86 31.09 3.931 3.933 3.958 4.500 53.1 1700.95 9.97 3.946 3.951 3.958 4.500 53.2 1710.92 5.00 3.812 3.812 3.812 4.500 isv 53.3 1715.92 9.77 3.949 3.955 3.958 4.500 54 1725.69 31.73 3.945 3.944 3.958 4.500 55 1757.42 31.87 3.935 3.934 3.958 4.500 56 I 1789.29 31.21 3.935 3.935 3.958 4.500 $7 [ 1820.50 31.90 3.934 3.933 3.958 4.500 58I 1852.40 31.62 3.931 3.928 3.958 4.500 59 t884.02 31.56 3.939 3.941 3.958 4.500 60 1915.58 31.66 3.932 3.933 3.958 4.500 61 1947.24 31.78 3.932 3.933 3.958 4.500 62 1979.02 32.13 3.937 3.935 3.958 4.500 63 2011.15 31.56 3.945 3.944 3.958 4.500 64 2042.71 31.26 3.945 3.944 3.958 4.500 65 2073.97 31.58 3.931 3.932 3.958 4.500 66 2105.55 31.37 3.936 3.934 3.958 4.500 67 2136.92 31.90 3.944 3.942 3.958 4.500 Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf BTCM Wall thickness: Body = 0.271 ins Upset -- 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal xtomi~al Type ' ' No. ID ID ID OD feet feet inches inches inches inches 68 2168.82 31.51 3.935 3.937 3.958 4.500 69 2200.33 32.67 3.932 3.933 3.958 4.500 70 2233.00 30.92 3.932 3.933 3.958 4.500 71 2263.92 31.77 3.938 3.938 3.958 4.500 72 2295.69 31.96 3.936 3.934 3.958 4.500 73 2327.65 32.35 3.937 3.938 3.958 4.500 74 2360.00 31.65 3.947 3.947 3.958 4.500 75 2391.65 31.87 3.938 3.936 3.958 4.500 76 2423.52 31.76 3.936 3.936 3.958 4.500 77 2455.28 31.95 3.935 3.934 3.958 4.500 78 2487.23 32.00 3.943 3.942 3.958 4.500 79 2519.23 31.97 3.935 3.934 3.958 4.500' 80 2551.20 31.87 3.935 3.937 3.958 4.500 81 2583.07 31.44 3.937 3.938 3.958 4.500 82 2614.51 31.78 3.937 3.937 3.958 4.500 83 2646.29 32.00 3.942 3.941 3.958 4.500 84 2678.29 32.02 3.937 3.938 3.958 4.500 85 2710.31 31.81 3.945 3.943 3.958 4.500 86 2742.12 31.40 3.937 3.938 3.958 4.500 87 2773.52 3t.47 3.937 3.935 3.958 4.500 88 2804.99 31.15 3.945 3.945 3.958 4.500 89 2836.14 32.01 3.929 3.929 3.958 4.500 90 2868.1 5 32.31 3.939 3.939 3.958 4.500 91 2900.46 31.19 3.934 3.934 3.958 4.500 92 2931.65 31.75 3.938 3.937 3.958 4.500 93 2963.40 31.55 3.944 3.944 3.958 4.500 94 2994.95 32.24 3.940 3.940 3.958 4.500 95 3027.19 31.91 3.936 3.936 3.958 4.500 96 3059.10 32.20 3.937[ 3.938 3.958 4.500 97 3091.30 32.22 3.943 3.944 3.958 4.500 98 3123.52 32.29 3.937 3.937 3.958 4.500 99 3155.81 31.98 3.949 3.949 3.958 4.500 100 3187.79 31.81 3.951 3.950 3.958 4.500 101 3219.60 32.05 I 3.939 3.939 3.958 4.500 102 3251.65 32.46I 3.942 3.941 3.958 4.500 Well: CD 1-22A Field: ALPINE Company: CONOCOPHILLIPS ALASKA, INC. Country: USA Survey Date: March 18, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 103 3284.11 31.84 3.934 3.935 3.958 4.500 104 3315.95 32.14 3.932 3.936 3.958 4.500 105 3348.09 31.82 3.940 3.940 3.958 4.500 106 3379.91 31.22 3.936 3.935 3.958 4.500 106.1 3411.13 9.97 3.930 3.929 3.958 4.500 ~up 106.2 3421.10 7.49 N/A N/A 3.958 4.500 Im 106.3 3428.59 9.73 3.939 3.944 3.958 4.500 )up 107 3438.32 31.99 3.943 3.941 3.958 4.500 108 3470.31 32.15 3.937 3.936 3.958 4.500 109 3502.46 31.95 3.938 3.940 3.958 4.500 110 3534.41 32.14 3.940 3.941 3.958 4.500 111 3566.55 32.35 3.940 3.939 3.958 4.500 112 3598.90 31.63 3.944 3.944 3.958 4.500 113 3630.53 32.03 3.936 3.938 3.958 4.500 114 3662.56 31.94 3.945 3.944 3.958 4.500 115 3694.50 31.82 3.941 3.942 3.958 4.500 116 3726.32 31.95 3.942 3.943 3.958 4.500 117 3758.27 34.79 3.933 3.934 3.958 4.500 118 3793.06 29.50 3.935 3.936 3.958 4.500 119 3822.56 32.08 3.937 3.937 3.958 4.500 120 3854.64 32.32 3.943 3.944 3.958 4.500 121 3886.96 32.14 3.946 3.945 3.958 4.500 122 3919.10 31.80 3.939 3.940 3.958 4.500 123 3950.90 32.05 3.934 3.934 3.958 4.500 i24 3982.95 31.61 3.943 3.941 3.958 4.500 125 4014.56 32.10 3.944 3.943 3.958 4.500 126 4046.66 32.18 3.945 3.945 3.958 4.500 127 4078.84 31.10 3.935 3.936 3.958 4.500 128 4109.94 32.37 3.936 3.938 3.958 4.500 i29 4142.31 31.89 3.944 3.944 3.958 4.500 130 41 74.20 32.05 3.936 3.938 3.958 4.500 131 4206.25 32.14 3.943 3.940 3.958 4.500 132 4238.39 31.94 3.939 3.940 3.958 4.500 133 4270.33 32.33 3.935 3.934 3.958 4.500 134 4302.66 31.40 3.944 3.944 3.958 4.500 Joint Tally page 2 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf BTCM Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal tType No. ID ID ID OD feet feet inches inches inches inches 135 4334.06 31.44 3.932 3.934 3.958 4.500 136 4365.50 32.26 3.940 3.940 3.958 4.500 137 4397.76 31.54 3.944 3.943 3.958 4.500 138 4429.30 32.40 3.938 3.939 3.958 4.500 139 4461.70 30.86 3.945 3.944 3.958 4.500 140 4492.56 29.69 3.939 3.940 3.958 4.500 141 4522.25 31.33 3.933 3.933 3.958 4.500 142 4553.58 31.80 3.930 3.930 3.958 4.500 143 4585.38 31.31 3.945 3.946 3.958 4.500 144 4616.69 31.79 3.936 3.937 3.958 4.500 145 4648.48 32.19 3.934 3.935 3.958 4.500 146 4680.67 31.80 3.943 3.942 3.958 4.500 147 4712.47 32.66 3.943 3.942 3.958 4.500 148 4745.13 31.57 3.947 3.944 3.958 4.500 149 4776.70 31.48 3.935 3.934 3.958 4.500 150 4808.18 31.97 3.933 3.934 3.958 4.500 151 4840.15 31.22 3.932 3.932 3.958 4.500 152 4871.37 31.93 3.936 3.937 3.958 4.500 153 4903.30 31.51 3.931 3.932 3.958 4.500 154 4934.81 31.54 3.933 3.932 3.958 4.500 155 4966.35 31.85 3.932 3.934 3.958 4.500 156 4998.20 31.61 3.936 3.937 3.958 4.500 157 5029.81 32.11 3.944 3.942 3.958 4.500 158 5061.92 32.15 3.937 3.936 3.958 4.500 159 5094.07 32.02 3.938 3.938 3.958 4.500 160 5126.09 31.84 3.932 3.933 3.958 4.500 161 5157.93 32.49 3.945 3.945 3.958 4.500 ] 162 5190.42 31.69 3.935 3.935 3.958 4.500 163 5222.11 31.94 3.937 3.937 [ 3.958 4.500 164 5254.05 31.28 3.940 3.940[ 3.958 4.500 165 5285.33 31.99 3.938 3.938 3.958 4.500 166 5317.32 32.01 3.944 3.942 3.958 4.500 167 5349.33 32.22 3.947 3.945 3.958 4.500 168 5381.55 3t.05 3.933 3.936 3.958 4.500 169 5412.60 I 31.35 3.938 3.940 3.958 4.500 Well: CD 1-22A Field: ALPINE Company: CONOCOPHILLIPS ALASKA, INC. Country: USA Survey Date: March 18, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 170 5443.95 32.35 3.932 3.933 3.958 4.500 171 5476.30 32.27 3.941 3.941 3.958 4.500 172 5508.57 31.61 3.933 3.937 3.958 4.500 172.1 5540.18 9.73 3.944 3.948 3.958 4.500 172.2 5549.91 7.30 N/A N/A 3.958 4.500 Im 172.3 5557.21 10.02 3.940 3.944 3.958 4.500 173 5567.23 32.34 3.941 3.940 3.958 4.500 174 5599.57 31.36 3.929 3.930 3.958 4.500 175 5630.93 31.58 3.930 3.929 3.958 4.500 176 5662.51 32.00 3.934 3.934 3.958 4.500 177 5694.51 32.03 3.938 3.937 3.958 4.500 178 5726.54 32.02 3.935 3.935 3.958 4.500 179 5758.56 31.83 3.932 3.931 3.958 4.500 180 5790.39 32.11 3.928 3.930 3.958 4.500 181 5822.50 32.07 3.938 3.937 3.958 4.500 182 5854.57 31.99 3.937 3.937 3.958 4.500 183 5886.56 31.59 3.939 3.939 3.958 4.500 184 5918.15 32.04 3.930 3.932 3.958 4.500 185 5950.19 32.48 3.932 3.935 3.958 4.500 186 5982.67 31.86 3.930 3.931 3.958 4.500 187 6014.53 32.21 3.940 3.938 3.958 4.500 188 6046.74 32.08 3.937 3.940 3.958 4.500 189 6078.82 31.74 3.942 3.944 3.958 4.500 190 6110.56 31.92 3.933 3.934 3.958 4.500 191 6142.48 31.60 3.933 3.932 3.958 4.500 192 6174.08 32.32 3.936 3.935 3.958 4.500 193 6206.40 32.10 3.942 3.941 3.958 4.500 194 6238.50 32.20 3.944 3.942 3.958 4.500 195 6270.70 43.84 3.965 3.962 3.958 4.500 196 6314.54 43.91 3.971 3.972 3.958 4.500 197 6358.45 43.87 3.970 3.969 3.958 4.500 198 6402.32 43.91 3.970 3.969 3.958 4.500 199 6446.23 43.85 3.968 3.967 3.958 4.500 200 6490.08 44.05 3.977 3.976 3.958 4.500 201 6534.13 43.94 3.974 3.972 3.958 4.500 Joint Tally page 3 PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf BTCM Wall thickness: Body-- 0.271 ins Upset = 0,271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal ~lominal Type No, ID ID ID OD feet feet inches inches inches inches 202 6578,07 43.97 3,968 3,969 3,958 4.500 203 6622.04 42.i0 3.956 3,949 3.958 4.500 204 6664.14 44.60 3,972 3.970 3,958 4.500 205 16708.74 43.70 3.969 3,969 3,958 4,500 206 6752,44 41.47 3.957 3.951 3.958 4,500 207 6793.91 39.20 3.977 3.976 3.958 4,500 208 6833.11 44.01 3.968 3,967 3.958 4,500 209 6877.12 43.67 3,966 3.963 3.958 4,500 210 6920,79 43,86 3,967 3,967 ] 3,958 4.500 211 6964.65 44.57 3,973 3,973 3,958 4,500 212 7009.22 43.17 3.968 3,968 3,958 4.500 213 7052.39 41.63 3,969 3.963 3,958 4.500 214 7094.02 44.51 3,972 3,970 3,958 4.500 215 7138153 44.12 3.973 3,972 3,958 4.500 216 7182.65 44.10 3.967 3.966 3,958 4.500 217 7226.75 43.08 3.962 3.961 3,958 4.500 , . 218 7269.83 44,19 3.972 3.972 3.958 4,500 219 7314.02 44.08 3.974 3.972 3,958 4,500 220 7358.10 42.80 3.962 3.957 3.958 4.500 221 7400.90 44,27 3,971 3,970 3,958 4,500 221.1 7445.17 9.22 3.946 3,953 3,958 4.500 )up 221.2 7454.39 7.74 N/A N/A 3,958 4.500 [ Im 221.3 7462.13 9,29 3,946 3.952 3,958 4.500 )up 222 7471.42 31.58 3.939 3.939 3,958 4,500 223 7503,00 31,93 3,943 3,947 3,958 4,500 223.1 7534.93 1.22 3,813 3,813 3.813 4,500 (nipple 224 7536.15 31.44 3,945 3.944 3,958 4,500 224.1 7567.59 9.84 3.958 3,961 3,958 4,500 )up 224.2 7577.43 3.82 3.875 3.875 3.875 4,500 )acker 224.3 758~125 10,01 3,957 3,962 3,958 4.500 ~up 225 7591.26 31.73 3.948 3,947 3,958 4,500 226 7622.99 29.96 3.962 3.960 3,958 4,500 226.1 7652.95 9.67 3,725 3.725 3,725 4.500 in 226.2I 7662,62 3.87 3,931 3,949 3.958 4.500 )up 226,3] 7666.49 N/A N/A N/A 3,958 4.500 t~il Well: Field: Company: Country: Survey Date: CD 1-22A ALPINE CONOCOPHILLIPS ALASKA, INC. USA March 18, 2003 Joint Depth Length Modal Mean Nominal Nominal Type No~ ID ID ID OD feet feet inches inches inches inches I Joint Tally page 4 ConocoPhi~]ips Alaska, l~c. CDI-22A ALPINE CD1-22A 501032025001 Completion: Angle @ TS: deg @ WRDP __ ILast W/O: Rev Reason: Pui! Gauges, reset t Ref Lo9 DaIe:tTD~· 115601tKB / Last Update: 3/13/2003 I Max Hoie Angle:/97 de~g ~ 8308 t Thread BTC~MOD Size Thread 4.500 BTCM ~ITVDI M.. I M'" t V~r )VType~LatchtPort]TRO1 D~te I VIV I~ I 34281 ~22 CAMCO KBG2 CAMCO t OLV I ~0 ! BK 0.~SS~ 2 I 5553l 5202 CAMCOKBG2 CAMCO GLV ~1.0~BK 0188 I ~33 tl/18/2OU31 ~ 6648 CAMCO KBG2 CAMCO OV I1.0tBK 0.250I ~1/~/2003l 7Other (plugs, eguip., etc.) -JEWELRY ~ 17 [1717 SSSV ICAMCOWRDP_2(HSS.129) set 3/4/2003 ~ z~__ 7536 6705 NtP - HES'X' NtPPLE ~_ PKR BAKER S 3 PACKER 3.87b NiP HES 'XN' NIPPLE ~ Permit to Drill 2001100 MD 11500 'rVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CDI-22A Operator PHILLIPS ALASKA INC. 6924 Completion Dat 8/13/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-t03-20250-0t-00 UIC N REQUIRED INFORMATION Mud Log N__~o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMA?~N Well Cored? Y I~[,/ Chips Received? ~ Analysis ~ Rer~.ived? Daily History Received? eYe/N Formation Tops ~1 Comments: Compliance Reviewed By: Date: 05/17/02 Schlumkerger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 AI'rN: Beth NO. 2089 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-03 / c~c/./i IO INJECTION PROFILE 04/16102 I 1 CD1-22A O~0~'" lO PRODUCTION PROFILE 04/21/02 I 1 CD1-28 ~../~ ~ PRODUCTION PROFILE/DEFT 04/19/02 I 1 CD1-4S -IClOl-I~~)/. INJECTION PROFILE 04/14/02 I 1 CD1-45 ~,~ ' INJECTION PROFILE 04/15/02 I I i ECEIVED DATE: g'.'! ~':¥ I 1,-%~ ? 7 , £007. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~yo~u. OJJ&G~CoI~S.~ MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~',.. \ Commissioner Tom Maunder, P. I. Supervisor Chuck Scheve; DATE: SUBJECT: PetroleUm InSpector March 30, 2001 Safety Valve Tests Colville River Unit CD1 Pad Friday, Mamh 30, 2001; I traveled to the Phillips Alaska's Alpine Field and witnessed a portion of the safety valve system tests on CD1. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow-pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The .surface .safety valves on .these wells operate very. slowly.' probably .due to being exposed to the elements and the length 'of the . control line from the hyd pane!..to. the wellhead. ' ~' ' Gary Saltenreick conducted the testing today he demonstrated a good working knowledge of the system and was a pleasure to work with. Summa.w:. i witnessed, a portion of the semi-annual SVS testing at the CD1 Pad in the Alpine Field. cRu CD1 Pad, 8 wells, 24 components, 0 failures Attachme. n~t~:t: SVS CRU CD1 Pad 3-30-01 CS Unclassified Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator Rep: Jack,Kralick AOC,-CC Rep: Chuck Seheve .i i _ l: i ~ ., Submitted By: Chuck Scheve Separator psi: LPS ~ 143 Date: 3/30/01 ii..':.' ' : '... ' 'd"..' ;" .u.'..:$ I I I Il I I I I J I . I_l. . _[ II .I. I ..... , ~.. ! __ · ...... . 1:3 ..... ,'~...... :......~'.~.,'~. i~.<,.~.:.'..':"., '.:'.'.~., ..::, '_?..,'.."." '""~";"""":" '~":'" '' ' ""~"' :": '""?" ' "'"": ::"~" :'1";' ';'~":: :"" '";! ' ~ i' i'11! Well Permit Separ Set IdP Test Test Test Date c~k WAG, Number . .Number ..PSI PSI Tn'p . . Code , Code Code Passed .. GAS or CYCLE CDI'01 1990460 . i i ........ . ,I ~1 i i i ill I ii cD1-06 2000830 ' ' ' ' ~ ....... i · ~ , , . ....... CD 1-09 2000710 I i i ii ' -' ' - .... . I i ~l i i .. il CDI-13 1990520 CD 1-16 1990940 CDI'17 ' '2001450 '143 100 100 P P" P ............ oIL 1~ '2001100" 143 100 1O0 P ' "P "i~ ........ ' .... OiL CD1-24 1990260 143 100 100 P ., P P OIL : - · i i ............. i i i I i. , ! i i ii i CD1-25 2000080 143 100 ' 100 P P P ' ' '0IL 20oo060 ........ ' .... ' ......... CDl-30 2001320. ' ' ...... . .,. .... : .. :, .-. :.: CD1'-52 199'1040 .... ~: ' ........ CD1-34 2000430 CD1-'3,..5 , 1990380 !43I,,. 100 .100 ........ P . P i:;' ~ ' OIL CD1-38 2000030 CD 1-40' 1990440 ' i , , . i i i i , ~ i, i i1 , . , 11 . , CD 1-41 ' 200bi 70 ' ' CDi.~3-" ~2001060 ...... I .......... ] ..... ,, , , i , i ill i .i , ~1 i '. : CD1-44 ', .2000550 - i , i. i i , il i i , , bi 11 il . , .... i. ~cD1-04 .,2,001170 ..... 1431 100. 100 P P- OIL cDI.-IO 2001710 143 '100 100 "'P' ' ' P P ...... 0I'L CD1-29 ............. 143 ,' .... 100 100 'P .............. P P, : ...... OIL -¥ . l, Il i i i 1! _ i , . . i i , , , , % , .' . '. . Wells: , · ,8, Components: 24 Failures: 0 Failure' Rate: 0.00% [~90 Day RJF 1/16/01 Page 1 ofl 010330-svs CRU CD1-CS PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 November 3, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for CD 1-22A (200-110) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on CD1- 22A. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader PAI Drilling RECEIVED ~a~a 0il J Gas Cons. An~or~e GCA/skad ORIGINAL STATE OF ALASKA (, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas r-] Suspended D Abandoned r'~ Service ~] 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. - ...... 200-110 / 3. Address ~a~,~,e~,~,ee 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ¥~., , 50-103-20250-01 4. Location of well at surface 7'T.': ...... . .......... '~ I' 9. Unit or Lease Name 373' FNL, 2425' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385851, 5975756) ! ~ -:'I'. "" ' ~ ,Colville River Unit At Top Producing Interval i _~" ~'.-~'. ~ 10. Well Number 3324' FNL 1319' FEL, Sec. 32, T12N, R5E, UM==.' ' .................~..::. · ' CD1-22A 212' FNL, 2319' FWL, Sec. 32, T12N, RSE, UM (ASP: 385808, 598119~i ...................... :' Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 55.5 feetI ADL 25558, 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 27, 1998 August 10, 2000 August 13, 2000 I N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of PermafroSt ' 11500' MD / 6924' TVD 11500' MD / 6924' TVD YES r~ No r'~ I 1717, feet MD 830' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'n'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 9 cu yds High Early Cold Set 9.625" 40# L-80 Surface 3110' 12.25' 542 sx Class G & 45O sx AS III & 60 sx AS I 7" 26# L-80 Surface 8430' 8.5" 477 sx Class G 24. Perloratlons open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE :DEPTH SET (MD) PACKER SET (MD) 4.5" 7666' 7579' .on, RECEIVED *o,., DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ¥ O [00'3 NaSa 0il & Gas Cons. Commi~o~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 24-Hour Rate > 28. CORE DATA Brief dascription of lithology, porosity, fractures, apparent dips and pressence of oil, gas orwater. Submit corn chips. N/A R 161N A L CONTINUED ON REVERSE SIDE Submit In duplicate 29. [ 30. [. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and tirue of each phase. Alpine D 7910' 6839' Base Alpine 8146' 6897' N/A RECEIVED asl a Oil & Cons. Comm ion / chorage 31. LIST OF A'I-FACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ~ ~ ~_~ Title Alpine Drlllln,q Team Leader Date I1~! ~o° G. C. ANord Prepared by Sharon AIIsup-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. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none'. Form 10-407 Date: 09/21/00 F 'ECEIVED ARCO ALASKA INC. Page: 1 WELL SUMMARY REPORT & C0mm~n Anoh age WELL:CD1-22A STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:08/05/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20250-01 08/05/00 (D1) MW: 9.6 VISC: 0 PV/YP: 0/ 0 TD/TVD: 9235/6924 (9235) CHANGING OUT UPPER IBOP SUPV:MIKE WHITELEY APIWL: 0.0 Move rig from CD1-24 to CD1-22A. Accept rig at 11:00 hrs. 8/5/00. PJSM/spill drill. Circ freeze protection diesel out with brine. Observe well, hole taking 18 bpm brine. ND tree. NU BOP's. Test BOPs to 250/5000 psi. Hole taking 20 bph brine. 08/06/00 (D2) TD/TVD: 9235/6924 ( SUPV:MIKE WHITELEY MW: 9.3 VISC: 27 PV/YP: 0/ 0 0) MAKE UP PACKER MILLING BHA APIWL: 0.0 Finish testing BOP's. Upper IBOP leaked. Change out upper IBOP, retest, held. Pulled tubing hanger to rig floor. Circ bttms up. Spot LCM pill on top of packer. Observe well, hole taking 6 bph. POOH with 4.5" tubing. RIH with overshot to 6429'. 08/07/00 (D3) TD/TVD: 9235/6924 ( SUPV:MIKE WHITELEY MW: 9.2 VISC: 41 PV/YP: 7/16 APIWL: 4.2 0) L.D. FISH ( FULL RECOVERY) AND FISHING TOOLS Finish RIH with overshot. Worked overshot over top of fish at 7628'. Released anchor seal assembly. POOH with overshot. Recovered seal assembly. RIH with fishing tools, packer milling. Speared packer at 7637' Sheared off of spear. Hole taking 60 bph brine. PJSM. Displace well with Flopro mud. Mill over packer from 7637'-7639.5' Moved packer up hole 30'. Unable to go down. Attempt to POOH. Packer hung up at 7610'. Mill and jar on packer, unable to mill over packer. Mill wore out. Hole swabbing. Jarred free at 7265', pumped out from 7265'-6805'. POOH with fishing tools. 08/08/00 (D4) MW: 9.2 VISC: 46 PV/YP: 8/18 APIWL: 3.6 TD/TVD: 9341/6931 (106) DRILLING AHEAD AT 9613' SUPV:MIKE WHITELEY POOH slow with fishing tools. PJSM. RIH. Circ bottoms up. Wash to 9425', hole in good shape, no problems, mud loss 6 bph. Pump out of hole. Washed to bottom at 9251'. Drilled from 9251' to 9341'. No mud loss. Circ hole clean. PJSM. ,ECEIVED Date: 09/21/00 ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT ~a~ ~ & G~$ C0~$. C0mm~n 08/09/00 (DL) MW: 9.3 VISC: 49 PV/YP: 11/16 APIWL: 3.8 TD/TVD:10470/6924 (1129) DRILLING AHEAD AT 10800 SUPV:MIKE WHITELEY Displace well to flopro mud. Drill from 9341'-10273'. Pump lo/high sweep around, circ clean for wiper trip. Wiper trip, pumped out 21 stands to 7" shoe, RIH, no problems. Drill from 10273'-10470'. No mud loss. 08/10/00 (D6) MW: 9.2 VISC: 48 PV/YP: 11/18 APIWL: 3.6 TD/TVD:l1500/6923 (1030) WELL DISPLACED WITH 9.2 PPG BRINE - OBSERVING WELL AT SUPV:MIKE WHITELEY Drilled from 10470'-11500' TD. No mud losses. Pump lo/hi sweep around and circ clean for wiper trip. Wiper trip, pump out of hole to shoe. No problems. RIH. 08/11/00 (D7) TD/TVD:l1500/6923 ( SUPV:MIKE WHITELEY MW: 9.2 VISC: 27 PV/YP: 0/ 0 0) POOH WITH CSG SCRAPER APIWL: 0.0 RIH to 11500'. Pump sweeps around 'and circ hole clean for change over to brine. Pumped hi-vis spacer. Displace well with brine. Observed well, 12 bph loss rate. POOH to 8400'. Observed well. POOH. Bit stuck in 7" casing at 37'. Work bit free. RIH to 8340'. Circ bttms up. 08/12/00 (D8) MW: 9.2 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1500/6923 ( 0) FREEZE PROTECT SUPV:MIKE WHITELEY Circ bttms up. POOH to 5098'. Monitor well, losses 120 bph. RIH to 8340'. Spot hi vis LCM pill. Monitor well, losses 6 bph. POOH. RIH with 6" OD gauge ring and junk basket to 7625'. PJSM. RIH with 4.5" completion assembly. ND BOPs. 08/13/00 (D9) MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1500/6923 ( 0) RIG RELEASED @ 09:30 8-13-2000 SUPV:MIKE WHITELEY / DENNIS CUNNING ND BOPs. NU tree and test to 5000 psi. Set packer at 7577'. Unable to test tubing, ball leaking. Test pkr/casing to 3500 psi. Freeze protect well. Rig release 8 0930 hrs. 8/13/00. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-95842 Sidetrack no. Page I of 2 i Company PHILLIPS ALASKA, INCi Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/22 Survey Section Name Anadrill MWD BHI Rep. C MILCHAK ~il~'r~~ WELL DATA Target 1'VD . Il=T) Target Coord. N/S Slot Coord. N/S -371.75 Grid Correction. 0.000 Depths Measured From: RKB ~ MSL ~ SSI-] Target Description Target Coord. F_JW Slot Coord. E/W 2426.98 Magn. Declination 25.670 Calculation Method MINIMUM CURVATURE Target Direction {OD) Build\Walk\DL per: 100ft~ 30m[-] lomF] Vert. Sec. Azim. 332.01 Magn. to Map Corr. 25.670 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) . El+) / W(-) DL Build (+) Right (+) Comment Type' (F'r) (OD) (DD) (F'r) . (F~ (FY) (FT) (Per ~00 FT) Drop (-) Left (-) MWD 8371.78 92.06 329.60 - ' 6931.06 1743.59 2685.53 1339.83 TIE IN POINT 08-AUG-00 MWD 8464.46 91.58 328.28 92.68 - 6928.12 1835.09 2764.88 1292.04 1.51 -0.52 -1.42 4 3/4' M1X 1.2 DEG AKO 08-AUG-00 MWD 8526.03 93.16 328.23 61.57 6925.57 1896.48 2817.19 1259.67 2.57 2.57 -0.08. 08-AUG-00 MWD 8587.71 90.58 327.14 61.68 6923.56 1957.94 2869.29 1226.72 4.54 -4.18 -1.77 08-AUG-00 MWD 8682.40 91161 326.79 94.69 6921.75 2052.25 2948.65 1175.11 1.15 1.09 -0.37 08-AUG-00 MWD 8775.06 87.81 325.99 92.66 6922.22 2144.44 3025.81 1123.83 4.19 -4.10 -0.86 08-AUG-00 MWD 8867.53 89.35 324.83 92.47 6924.51 2236.27 3101.90 1071.35 2.08 1.67 -1.25 08-AUG-00 MWD 8959.98 89.04 325.35 92.45 6925.81 2328.03 3177.71 1018.45 0.65 -0.34 0.56 · 08-AUG-00 MWD 9083.52 89.55 325.99 123.54 6927.33 2450.81 3279.72 948.79 0.66 0.41 0.52 ~ . 08-AUG-00 MWD 9114.37 90.00 326.04 ' 30.85 6927.45 2481.49 3305.30 931.54 1.47 1.46 0.16 08-AUG-00 MWD 9192.86' 89.59 326.36 78.49 6927.73 2559.57 3370.52 887.88 0.66 -0.52 0.41 . 09-AUG-00 MWD 9290.02 87.67 331.94 97.16 6930.05 2656.54 3453.88 838.09 6.07 -1.98 5.74 09-AUG-00 MWD 9386.24 89.01 333.80 96.22 6932.84 2752.70 3539.47 794.23 2.38 1.39 1.93 . 09-AUG-00 M,WD 9479.41 89.14 333.57 93.17 6934.35 2845.82 3622.97 752.94 0.28 0.14 ~ .0.25 09-AUG-00 ' MWD 9570.94 90.38 333.72 91.53 6934.73 2937.31 3704.99 712.30 1.36 1.35 0.16 '~' ',...' II1~ 09-AUG-00 I~WD 9664.39 90.41 333.04 93.45 6934.09 3030.73 3788.53 670.43 0.73 0.03 -0.73 09-AUG-00 MWD 9758.15 90155 333.11 93.76' 6933.30. 3124.47 3872.12 627.98 0.17 0.15 0.07 .~=~-~ 09-AUG-00 MWD 9849.25 91.44 334.37 91.10 6931.72 3215.52 3953.80 587.68 1.69 0.98 1.38 --- (.-5 ~..~ ~,~ 09-AUG-O0 MWD 9943.06 91.88 335.28 93.81 6929.00 3309.17 4038.67 547.79 1.08 0.47 0.97 . 09-AUG-00 MWD 10037.00 90.17 336.15 93.94 6927.32 3402.90 4124.28 509.16 2.04 -1.82 0.93 09-AUG-00 MWD 10128.88 90.31 336.74 91.88 6926.93 3494.50 4208.50 472.45 0.66 0.15 0.64 09-AUG-00 MWD 1'-'0220.75 90.55 336.76 91.87 ' 6926.24 3586.05 4292.91 436.18 0.26 0.26 0.02 09-AUG-00 MWD 10314.00 90,75 336,28 93,25 6925.19 3679,01 4378.43 399.03 0,56 0,21 -0,51 09-AUG-00 MWD - i~l~i~-- 9 337.53 94.96 6923.91 3773.61 4465.77I 361.79 1.32 0.04 1.32 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-95842 Sidetrack No. Page 2 of 2 Company PHILLIPS ALASKA-, INC: Rig C~)ntractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/22 Survey Section Name Anadrill MWD BHI Rep. C MILCHAK ~lrr~l~ WELL DATA Target TVD . (FT) Target Coord. N/S Slot Coord. N/S -371.75 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSI-] Target Description Target Coord. E/W Slot Coord. F_JW 2426.98 Magn. Declination 25.670 Calculation Method MINIMUM CURVATURE · Target Direction (DD) Buil~Walk\DL per: 100ftl~ 30m~ lomFI Vert. Sec. Azim. 332.01 Magn. to Map Corr. 25.670 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type' ~ (DD) (DD) (FT) ~ (FT) (FI') (Per ~00 FT) Drop (-) Left (-) 10-AUG-00 MWD 10498.95 90.41 336.1 i -89.99 6922.97 3863.28 4548.49 326.37 1.63 -0.42 -1.58 10-AUG-00 MWD 10591.12 ' 90.62 . 335A6 92.17 6922.14 3955.26 4632.44 288.34 1.06 0.23 -1.03 10-AUG-00 MWD 10683.78 90.69 336.34 92.66 6921.08 4047.71 4716.92 250.29 1.28 0.08 1.27, . 10-AUG-00 MWD 10774.36 89.49 332.61 90.58 6920.94 4138.19 4798.64 211.27 4.33 -1.32 -4.12 10-AUG-00 MWD 10866.27 89~31 332.04 91.91 6921.90 4230.09 4880.03 168.58 0.65 -0.20 -0.62 lO-AUG-00 MWD 10959.87 89.83 331.02 93.60 6922.60 4323.69 4962.31 123.96 1.22 0.56 -1.09 10-AUG-00 MWD 11050.15 90.31 331.73 90.28 6922.49 4413.96 5041.56 80.71 0.95 0.53 0.79 10-AUG-00 MWD 11142.70 90.79 331.65 92.55 6921.60- 4506.50 5123.03 36.82 0.53 0.52 -0.09 10-^UG-00 MWD 11232.15 90.58 331.46 89.45 6920.54 4595.94 5201.68 -5.78 0.32 -0.23 -0.21 ~ . 10-AUG-00 MWD 11322.98 88.77 331.84 90.83 6921 ..05 4686.77 5281.61 -48.91 2.04 -1.99 0.42 10-AUG-00 MWD 11417.62 89.21 334.23 94.64 6922.72 4781.37 5365.94 - -91.81 2.57 0.46 2.53 10-AUG-00 MWD 11445.09 89.25 334.82 27.47 6923.09 4808.81 5390.74 -103.63 2.15 0.15 2.15 10-AUG-00 MWD 11500.00 89.25 334.82 54.91 6923.81 4863.65 5440.43 -126.99 0.00 0.00 0.00 · ,. · . ~1~ . ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-22A API number ............... : 50-103-20250-01 Engineer ................. : Rathert Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation methods- Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth Permanent da Depth refere GL above pex KB above pe] DF above pe] Verti¢ Latitude (+} Departure ( Platf Latitude (+~ Departure ( Azimuth fro: [ (c)2000 An~ reference tum .......... : Mean Sea Level nce .......... : Drill Floor manent ....... : 19.50 ft manent ....... : 0.00 ft manent ....... : 56.00 ft al section origin. /s-) ......... : E/W-) ........ : 0.00 ft 0.00 ft rm reference point /S-) ......... : -999.25 ft iE/W-) ........ : -999.25 ft rotary table to target: 332.01 degrees idrill IDEAL ID6_lB_48] Il-Aug-2000 08:07:48 Page 1 of 7 ORIGINAL Spud date ................ : 06-August-00 Last survey date ......... : 10-Aug-00 Total accepted surveys...: 166 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11500.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 07-Aug-2000 Magnetic field strength.,: 1147.14 HCNT Magnetic dec (+E/W-) ..... : 25.67 degrees Magnetic dip ............. : 80.54 degrees ..... MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147. Reference Dip ............ : 80. Tolerance of G ........... : (+/-) 2. Tolerance of H ........... : (+/-) 6. Tolerance of Dip ......... : (+/-) 0. 14 HCNT 54 degrees 50 mGal 00 HCNT 45 degrees Corrections · Magnetic dec (+E/W-) ..... : 25.67 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.67 degrees (Total az corr= magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED AUG 5 2000 Alaska Oil & Gas C...,~. Commissior~ Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0o00 2 111.90 0.00 37.15 3 177.04 0.15 261.55 4 271.34 0.29 288.33 5 361.30 0.14 316.63 Il-Aug-2000 08:07:48 6 452.51 0.32 312.09 7 542.61 0.29 153.93 8 632.84 0.57 172.85 9 721.53 0.72 151.27 10 812.84 0.36 153.07- Course TVD Vertical Displ Displ length depth section +N/S- +E/W- (ft) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 111.90 111.90 0.00 0.00 0.00 65,14 177.04 0.03 -0.01 -0.08 94.30 271.34 0.24 0.04 -0.43 89.96 361,30 0.51 0.20 -0.72 11 902.60 0.42 135.73 12 991.78 1.01 111.52 13 1079.80 0.93 104.81 14 1169.68 0.96 94.66 15 1266.11 0.81 96.94 91.21 452.51 0.86 0.45 -0.99 90.10 542.61 0.87 0.41 -1.08 90.23 632.83 0.22 -0.24 -0.92 88.69 721.52 -0.75 -1.17 -0.60 91.31 812.82 -1.61 -1.92 -0.19 16 1359.52 1.32 93.88 17 1454.59 1.11 95.12 18 1547.23 1.27 90.91 19 1639.27 1.27 92.07 20 1731.87 1.39 91.21 902.58 -2.21 -2.41 0.17 991.76 -3.12 -2.93 1.12 1079.76 -4.19 -3.40 2.54 1169.63 -5.10 -3.65 3.99 1266.05 -5.92 -3.80 5.47 21 1826.42 1.25 92.22 22 1921.00 1.24 87.98 23 2014.94 1.19 92.86 24 2109.32 1.17 88.54 25 2204,09 1.06 88.67 89.76 89.18 88.02 89.88 96.43 26 2298.43 1.00 93.96 27 2393.35 0.98 87.68 28 2486.43 0.87 85.47 29 2579.47 0.82 91.94 30 2673.41 0.78 86.28 93.41 1359.44 -6.87 -3.95 7.20 95.07 1454.49 -7.95 -4.11 9.21 92.64 1547,11 -8.94 -4.20 11.13 92.04 1639.13 -9.94 -4.25 13.17 92.60 1731.70 -11.00 -4.32 15.32 [(c)2000 Anadrill IDEAL ID6 lB 48] 94.55 1826.23 -12.08 -4.38 17.50 94.58 1920.79 -13.05 -4.38 19.55 93.94 2014.70 -13.99 -4.40 21.54 94.38 2109.06 -14.92 -4.42 23,48 94.77 2203.82 -15.75 -4.38 25.33 Page 2 of 7 Total At DLS displ Azim (dog/ (ft) (deg) IOOf) 0.00 0.00 0.00 0.00 0.00 0.00 0.09 261.55 0.23 0.44 275.85 0.18 0.75 285.13 0.20 1.09 294.33 0. 1.15 290.92 0. 0.95 255.44 0. 1.31 207.15 0. 1.93 185.70 0. Srvy Tool tool qual type type TIP - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 2.42 176.08 0. 3.14 159.02 0. 4.24 143.28 0. 5.41 132.42 0. 6.66 124.74 0. 20 MWD 6-axis 66 MWD 6-axis 34 MWD 6-axis 32 MWD 6-axis 39 MWD 6-axis 8.21 118.73 0. 10.09 114.02 0. 11.90 110.68 0. 13.84 107.90 0. 15.92 105.73 0. 15 MWD 6-axis 73 MWD 6-axis 16 MWD 6-axis 19 MWD 6-axis 16 MWD 6-axis 18.04 104.05 0. 20.04 102.64 0. 21.99 101.53 0. 23.90 100.66 0. 25.70 99.80 0. 55 MWD 6-axis 22 MWD 6-axis 20 MWD 6-axis 03 MWD 6-axis 13 MWD 6-axis 94.34 2298.14 -16.58 -4.41 27.02 27,38 99.27 94.92 2393.05 -17.37 -4.44 28.66 29.00 98.80 93.08 2486.12 -17.99 -4.35 30.16 30.47 98.21 93.04 2579.15 -18.61 -4.32 31.53 31.82 97.79 93.94 2673.08 -19.21 -4.30 32.84 33.12 97.45 15 MWD 6-axis 10 MWD 6-axis 12 MWD 6-axis 10 MWD 6-axis 12 MWD 6-axis 0.12 MWD 6-axis 0.12 MWD 6-axis 0.12 MWD 6-axis 0.12 MWD 6-axis 0.09 MWD 6-axis RECEIVED AUG 2 5 Alaska Oil & ~.~ C,,~s, GammissJor ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 31 2767.88 0.82 83.91 32 2860.53 0.84 83.12 33 2955.68 0.80 83.90 34 3048.07 0.93 80.00 35 3101.14 0.87 78.91 Course length (ft) 94.47 92.65 95.15 92.39 53.07 36 3163.81 0.67 90.77 37 3195.41 1.16 68.78 38 3226.76 2.80 48.11 39 3258.27 5.31 39.22 40 3289.82 8.14 40.34 TVD depth (ft) 2767.54 2860.18 2955.32 3047,70 3100.76 Il-Aug-2000 08:07:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) -19.72 -4.18 34.15 -20.21 -4.03 35.48 -20.71 -3,88 36.84 -21.18 -3.68 38.22 -21.43 -3.53 39.04 62.67 3163.42 -21.75 -3.44 39.87 31.60 3195.02 -21.88 -3.33 40.35 31.35 3226.35 -21.73 -2.70 41,22 31.51 3257.78 -20.98 -1.06 42.71 31.55 3289.11 -19.59 1.78 45.08 41 3320.48 10.96 38.07 30.66 3319.34 -17.60 5.73 48.29 42 3351.84 12.05 38.26 31.36 3350.07 -15.08 10.64 52.15 43 3383.40 13.22 38.88 31.56 3380.87 -12.33 16,04 56,46 44 3414.07 14.24 38.83 30.67 3410.66 -9.47 21.71 61.02 45 3444.13 14.20 37.16 30.06 3439.80 -6.46 27.53 65.57 46 3474.04' 14.23 37.24 29.91 3468.79 47 3505.41 15.38 36.10 31.37 3499.12 48 3536.87 16.35 35.50 31.46 3529.38 49 3567.22 16.43 33.77 30.35 3558.50 50 3598.95 16.29 33.89 31.73 3588,94 51 3629.42 16.28 34.09 30.47 3618.19 52 3660.61 17.56 36.72 31.19 3648.03 53 3692.27 18.65 38.09 31.66 3678.12 54 3723.76 18.43 39.07 31.49 3707.98 55 3816.98 20.01 38.01 93.22 3796.00 56 3879.36 20.65 36.08 62.38 3854.50 57 3939.92 22.46 33.17 60.56 3910.82 58 4003.19 25.36 33,63 63.27 3968.65 59 4066.73 27.33 34.30 63.54 4025.59 60 4130.01 29.17 36.24 63.28 4081.33 [(c)2000 Anadrill IDEAL ID6 lB 48] -3.38 33.38 70.01 0.05 39.81 74.79 3.85 46.79 79.82 7.79 53.83 84.69 12.01 61.26 89.67 16.02 68.34 94.44 20.08 75.73 99.71 24.17 83.54 105.69 28.15 91.37 111.93 40.39 115.38 131.04 Page 3 of 7 Total At DLS displ Azim (deg/ (ft) (deg) 100f) 34.41 96.98 0.05 35.71 96.48 0.02 37.04 96.01 0.04 38.39 95.50 0,15 39.20 95.16 0.12 40.02 94.93 0.41 40.49 94.71 1.88 41.31 93.75 5.62 42.73 91.42 8.19 45.12 87.74 8.98 S rvy tool type MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 48.62 83.24 9.28 53.23 78.46 3.48 58.69 74.14 3.73 64,77 70.42 3.33 71.11 67.23 1.37 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 77.56 64.51 0.12 84.73 61.98 3.78 92,52 59.62 3.13 100.35 57.56 1.63 108.59 55.66 0.45 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 116.57 54.11 0.19 125.21 52.78 4.78 134.72 51.67 3.70 144.49 50.77 1,21 174.60 48.64 1.74 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 49.54 132.68 144.09 195.87 47.36 59.79 151.00 156.71 217.62 46.06 72.06 172.40 170.83 242.70 44.74 85.31 195.78 186.58 270.45 43.62 98.77 220.22 203.89 300.11 42.79 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 1.49 MWD 3.47 MWD 4.59 MWD 3.14 MWD 3.25 MWD RECEIVED 6-axis 6-axis 6-axis 6-axis 6-axis AUG .o ,:. 5.2..000 Alaska Oil & Gas Co~s. Commission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 61 4192.56 29.50 35.27 62.55 4135.86 62 4255.27 29.92 36.31 62.71 4190.33 63 4316.17 32.03 36.11 60.90 4242.54 64 4379.26 34.43 37.15 63.09 4295.31 65 4441.09 35.62 36.46 61.83 4345.94 Il-Aug-2000 08:07:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 112.33 245.09 221.79 126.06 270.30 239.97 139.70 295.59 258.48 154.51 323.32 279.12 169.62 351.74 300,37 Page 4 of 7 Total At DLS displ Azim (deg/ (ft) (deg) i00f) 330,55 42.14 0.92 361,45 41.60 1.06 392.66 41.17 3.47 427.14 40,80 3.91 462.54 40.50 2,03 66 4504.44 37.89 38.14 63.35 4396.70 ' 185.45 381.88 323.35 500.39 40.26 67 4566.17 39.05 39.72 61.73 4445.03 200.50 411.75 347.49 538,78 40.16 68 4628.72 40.77 37.83 62.55 4493.01 216.34 443.04 372.61 578.89 40.07 69 4691.27 40.42 37.28 62.55 4540.50 233.19 475.30 397.42 619.56 39.90 70 4785.23 40.07 37'.42 93.96 4612.22 258,52 523.56 434.25 680.21 39.67 71 4878.00 39.80 35.94 92.77 4683.36 283.99 571.31 469.82 739.68 39.43 72 4971.73 39.49 35.38 93.73 4755.53 310.53 619.90 504.68 799.36 39.15 73 5064.95 39.19 33.20 93.22 4827.63 338.02 668.72 537.97 858.25 38.82 74 5157'.28 38.71 34.53 92.33 4899.44 365.40 716.91 570.31 916.09 38.50 75 5251.53 39.81 33.22 94.25 4972.41 393.53 766.43 603.55 975.55 38.22 76 5345.87 40.29 33.18 94.34 5044.63 422.78 817.23 636.79 1036,03 37.93 77 5437.73 39.89 34.38 91.86 5114.90 450,76 866.40 669.67 1095.04 37.70 78 5530.94 40.09 34.87 93.21 5186.32 478.32 915.69 703.71 1154.86 37.54 79 5624.51 39.81 33.33 93.57 5258.05 506.44 965,44 737.40 1214.83 37.37 80 5717.42 40.59 34.14 92.91 5329.02 534.84 1015.30 770.70 1274.69 37.20 81 5809.48 41.38 34.96 92.06 5398.51 562.68 1065.03 804.95 1335.00 37.08 82 5903.55 41.05 33.80 94.07 5469.27 591.42 1116,18 839.95 1396.91 36.96 83 5998.40 40.38 34.30 94.85 5541.17 620.43 1167.44 874.59 1458.71 36.84 84 6092.80 40.15 35.11 94.40 5613.20 648.42 1217.60 909.32 1519.68 36.75 85 6185.66 39.64 37.29 92.86 5684.45 674.35 1265.66 944.49 1579.23 36.73 86 6278.16 39.11 36.07 87 6372.38 38.76 36.19 88 6466.79 39.14 35.74 89 6559.72 39.82 37.03 90 6652.83 41.75 39.13 92.50 94.22 94.41 92.93 93.11 699.45 1312.72 979.54 725.30 1360.54 1014.45 751.36 1408.58 1049.31 776.90 1456.14 1084.36 801.55 1504.00 1121.88 [(c)2000 Anadrill IDEAL ID6 lB 48] 5755.95 5829.24 5902.66 5974.39 6044.89 Srvy tool type MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 3.92 2.46 3.36 0.80 0.38 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 1.06 0.50 1.52 1.04 1.46 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis .51 .95 .40 .10 .01 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 1.04 0.88 0.79 0.61 1.60 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 1637.91 36.73 1697.11 36.71 1756.46 36.68 1815.54 36.67 1876.33 36.72 1.01 MWD 0.38 MWD 0.50 MWD 1.15 MWD 2.54 MWD 6-axis 6-axis 6-axis 6-axis 6-axis RECEIVED AUG 2 5 2000 Com,,~bSlO,. Alaska Oil & G~-::~ Co~s. ~ "'"'° '" _.- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - ( ft ) (deg) (deg) ( ft ) ._ ( ft ) 91 6744,56 41,62 38,12 91,73 6113,40 92 6835,97 41,24 39.03 91,41 6181,93 93 6931,06 41,57 38.66 95,09 6253,26 94 7025,94 41,60 38,74 94,88 6324,22 95 7119.55 41,03 38,20 93,61 6394,53 96 7213,83 40.06 38.00 94.28 6466,18 97 7308,32 39.97 37.79 94.49 6538.54 98 7371,08 39,56 37.18 62.76 6586,79 99 7400,97 39.42 36,70 29,89 6609,85 100 7431,78 39,85 36,46 30.81 6633.58 Il-Aug-2000 08:07:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 825.76 1551,65 1159,96 849,82 1598,94 1197,68 874.56 1647,92 1237,12 899.48 1697,07 1276,50 924,16 1745,45 1314.94 949,00 1793.68 1352,76 973.82 1841.63 1390.08 990,48 1873,48 1414,51 998,54 1888,67 1425.93 1006,98 1904.45 1437,64 101 7462,76 42,08 35,77 30,98 6656,97 1015,85 1920,86 1449,61 102 7494,25 44,56 33,16 31,49 6679,88 1025,85 1938,68 1461,83 103 7525,00 47,02 30,09 30,75 6701,33 1037,00 1957,45 1473,37 104 7556,37 49,74 27,50 31,37 6722,16 1049,85 1978,00 1484.65 105 7587,84 52,36 24.49 '31.47 6741,94 1064,25 1999,99 1495,37 106 7620,22 54,76 21.14 32.38 6761.18 1080.72 2024,00 1505,45 107 7651.96 57.30 18,43 31.74 6778,92 1098,41 2048,77 1514,35 108 7681,08 59,36 15,02 29,12 6794,21 1116.02 2072,50 1521.47 109 7712,77 60,91 11,74 31,69 6809,99 1136,64 2099,23 1527,83 110 7744,84 63.24 8,07 32,07 6825,01 1159.00 2127.14 1532,69 111 7775,69 66.15 5.33 30.85 6838,20 112 7807,33 68,35 2,04 31,64 6850,44 113 7839,35 69.90 358,88 32,02 6861.85 114 7870,69 70,78 356.26 31.34 6872.40 115 7902.50 71,60 353,42 31,81 6882,65 1181,94 2154.83 1535.93 1206,77 2183.94 1537,80 1233,07 2213,85 1538,04 1259,69 2243,34 1536,78 1287.44 2273.32 1534.08 116 7934,11 72,16 350,83 31,61 6892,49 1315,65 2303,08 1529,96 117 7965,35 72,81 347.86 31,24 6901.89 1344,08 2332,35 1524,45 118 7995,89 73,51 343.88 30,54 6910,74 1372.45 2360,69 1517,31 119 8027,53 74.14 340,38 31,64 6919.56 1402,36 2389,60 1507.99 120 8059,06 75.03 336.23 31.53 6927.94 1432,57 2417,84 1496,75 [(C)2000 Anadrill IDEAL ID6_1B_48] Page 5 of 7 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg} 100f) type type 1937,30 36,78 0,75 MWD 6-axis 1997,76 36,83 0,78 MWD 6-axis 2060,61 36,90 0,43 MWD 6-axis 2123,56 36.95 0.06 MWD 6-axis 2185,34 36.99 0,72 MWD 6-axis 2246,61 37,02 1,04 MWD 6-axis 2307,36 37,05 0,17 MWD 6-axis 2347,50 37,05 0.90 MWD 6-axis 2366.51 37,05 1,12 MWD 6-axis 2386,16 37.05 1,48 MWD 6-axis 2406.47 37.04 7.34 MWD 6-axis 2428.04 37.02 9.71 MWD 6-axis 2449.98 36.97 10.73 MWD 6-axis 2473.19 36.89 10.64 MWD 6-axis 2497.22 36.78 11.16 MWD 6-axis 2522,49 36,64 11,14 MWD 6-axis 2547,69 36.47 10.68 MWD 6-axis 2571.02 36.28 12.22 MWD 6-axis 2596,35 36,05 10.22 MWD 6-axis 2621,80 35,77 12,45 MWD 6-axis 2646,20 35,48 12,39 MWD 6-axis 2671,04 35.15 11.84 MWD 6-axis 2695,68 34.79 10,41 MWD 6-axis 2719,24 34,41 8,36 MWD 6-axis 2742,51 34,01 8,84 MWD 6-axis 2764.95 33.60 7.99 MWD 6-axis 2786.36 33.17 9.30 MWD 6-axis 2806.26 32.73 12.68 MWD 6-axis 2825.64 32.25 10.81 MWD 6-axis 2843.63 31.76 13.00 MWD 6-axis RECEIVED r_ Alaska Oil & G[~s Cons. Commission /l n~l~v'_~ ~l ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD $ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 121 8090.73 78.11 333.11 31.67 6935.30 122 8122.55 81.74 330.57 31.82 6940.86 123 8153.89 85.74 328.11 31.34 6944,28 124 8185.06 90.09 328.35 31.17 6945.41 125 8215.84 93.54 327.65 30.78 6944.44 il-Aug-2000 08:07:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 1463.33 2445.67 1483.57 1494.65 2473.28 1468.79 1525.76 2500.07 1452.90 1556.84 2526.55 1436.51 1587.52 2552.64 1420.21 Page 6 of 7 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) I00f) type 2860.47 31.24 13.65 MWD 2876.54 30.70 13.85 MWD 2891,59 30.16 14.96 MWD 2906.37 29.62 13.98 MWD 2921.12 29.09 11.44 MWD 126 8245.35 94,97 327.60 29.51 6942.25 1616.86 2577.49 1404.45 2935.29 127 8276.40 95.92 328.38 31.05 6939'.30 1647.70 2603.70 1388.07 2950,59 128 8308.14 96.66 329.34 31.74 6935.83 1679.20 2630.70 1371.75 2966.87 129 8339.00 94,31 330.11 30,86 6932.88 1709.89 2657.23 1356.27 2983.34 130 8371.78 92.06 329.60 32.78 6931.06 1742.59 2685.53 1339.83 3001.20 131 8464.46 91.58 328.28 92.68 6928.11 1835.09 2764.88 1292.04 3051.87 132 8526.03 93.16 328.23 61.57 6925,57 1896.48 2817.19 1259.67 3085,99 133 8587.71 90.58 327.14 61.68 6923.55 1957.94 2869.29 1226.72 3120.52 134 8682.40 91.61 326.79 94.69 6921.74 2052.25 2948.65 1175.11 3174.18 135 8775.06 87.81 325.99 92,66 6922.21 2144.44 3025.81 1123.83 3227.77 136 8867.53 89.35 324.83 92.47 6924.50 2236.27 3101.90 1071.35 3281.71 137 8959.98 89.04 325.35 92.45 6925.80 2328.03 3177,71 1018.45 3336.93 138 9083.52 89.55 325.99 123,54 6927.32 2450.81 3279.72 948.79 3414.20 139 9114.37. 90.00 326.04 30.85 6927,44 2481.49 3305.30 931.54 3434.06 140 9192.86 89.59 326.36 78.49 6927.73 2559.57 3370.52 887.88 3485.51 141 9290.02 87.68 331.94 97.16 6930.04 2656.54 3453.88 838.09 142 9386.24 89.01 333.80 96.22 6932.82 2752.70- 3539.47 794.23 143 9479.41 89.14 333.57 93.17 6934.32 2845.82 3622.97 752.94 144 9570.94 90.38 333.72 91.53 6934.71 2937.31 3704.99 712.30 145 9664.39 90.41 333.04 93.45 6934.06 3030.73 3788.53 670.43 3554.10 3627.48 3700.38 3772.84 3847.39 146 9758.15 90.55 333.11 93.76 6933.28 3124.47 3872.12 627.98 3922.71 147 9849.25 91.44 334.37 91.10 6931.70 3215.52 3953.80 587.68 3997.24 148 9943,06 91.88 335.28 93.81 6928.98 3309,17 4038,67 547.79 4075.65 149 10037.00 90.17 336.15 93.94 6927.30 3402.90 4124.28 509.16 4155.59 150 10128.88 90.31 336.74 91.87 6926.91 3494.49 4208.49 472.45 4234.93 28.59 4.85 MWD 28.06 3.95 MWD 27.54 3.80 MWD 27.04 8.01 MWD 26.51 7.04 MWD 25.05 1.51 IMP 24.09 2.57 IMP 23.15 4.54 IMP 21.73 1.15 IMP 20.38 4.19 IMP 19.05 2.08 IMP 17.77 0.65 IMP 16.13 0.66 IMP 15.74 1.47 IMP 14.76 0.66 IMP [(¢)2000 Anadrill IDEAL ID6_lB_48] 13.64 6.07 IMP 12.65 2.38 IMP 11.74 0.28 IMP 10.88 1.36 IMP 10.04 0,73 IMP 9.21 0.17 IMP 8.45 1.69 IMP 7.72 1.08 IMP 7.04 2.04 IMP 6.41 0..66 IMP RECEIVED AUG 2 5 2000 Alaska C, il & Gas Cons. Commissior .~ n ,~ h,~i'."l fir Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 151 10220.75 90.55 336.76 91.88 6926.22 152 10314.00 90.75 336.28 93.25 6925.17 153 10408.96 90.79 337.53 94.96 6923.89 154 10498.95 90.41 336.11 89.99 6922.95 155 10591.12 90.62 335.16 92.17 6922.12 156 10683.78 90.69 336.34 92.66 157 10774.36 89.49 332.61 90.58 158 10866.27 89.31 332,04 91.91 159 10959.87 89.83 331.02 93.60 160 11050.15 90.31 331.73 90.28 161 11142.70 ' 90.79 331.65 92.55 162 11232.15 90.58 331.46 89.45 163 11322.98 88.77 331.84 90.83 164 11417.62 89.21 334.23 94.64 165 11445.09 89.25 334.82 27.47 Survey projected to total depth: 166 11500.00 89.25 334.82 54.91 il-Aug-2000 08:07:48 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3586.05 4292.91 436.18 3679.01 4378.43 399.03 3773.61 4465.77 361.79 3863.28 4548.49 326.37 3955.26 4632.44 288.35 6921.06 4047.71 4716.92 250.29 6920.92 4138.19 4798.65 211.27 6921.88 4230.09 4880.03 168.58 6922.58 4323.69 4962,31 123.96 6922.47 4413.96 5041.56 80.71 Page 7 of 7 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 4315.01 5.80 0.26 IMP 6-axis 4396.58 5.21 0.56 IMP 6-axis 4480.40 4.63 1.32 IMP 6-axis 4560.18 4.10 1.63 IMP 6-axis 4641.41 3.56 1.06 IMP 6-axis 4723.56 3.04 4803.29 2.52 4882.95 1.98 4963.86 1.43 5042.20 0.92 6921.58 4506.50 5123.03 36.83 5123.17 0.41 6920.51 4595.95 5201.68 -5.78 5201.68 359.94 6921.03 4686.77 5281.61 -48.91 5281,84 359.47 6922.70 4781.37 5365.94 -91.81 5366.73 359.02 6923.07 4808.81 5390.74 -103.62 5391.73 358.90 6923.79 4863.65 5440.43 -126.98 5441.91 358.66 1.28 IMP 6-axis 4.33 IMP 6-axis 0.65 IMP 6-axis 1.22 IMP 6-axis 0.95 IMP 6-axis 0.53 IMP 6-axis 0.32 IMP 6-axis 2.04 IMP 6-axis 2.57 IMP 6-axis 2.15 IMP 6-axis 0.00 Projection [(c)2000 Anadrill IDEAL ID6_lB_48] RECEIVED Alaska Oil & Gas Cons. Commission Anchorage MWDILWD Log Product Delivery Customer Arco Alaska, Inc. (~ Dispatched To: AOGCC Well No CD1-22A ~O'~ ° Date Dispatche 20-Audi-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale' Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 I ECEIVI:D 2 5 20( Alaska I~il & Gas Cons. C; ~mmissm Anchorage Received By: _~'~v~ (~ AnadrillPlease sign and return tO:LwD DM,on 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose~ianchomge.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASI~A OIL AND GAS CONSERVATION CO]~llSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD 1-22A Phillips Alaska, Inc. Permit No: 200-1 l0 Sur Loc: 372'FNL, 2427'FWL, Sec. 5, T11N, R5E, UM Btmhole Loc. 354'FNL, 2379'FWL, Sec. 32, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissioner BY ORDER OF THE COMMISSION DATED this ~ ,"c4 day of August, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o end. Department of Environmental Conservation w/o encl. P i'_LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax-' (907) 265-6224 August 2, 2000 Mr. Blair Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Permit to Drill for CD1-22A Dear Mr. Wondzell: Phillips Alaska, Inc. requests the Commission expedite the processing of the Permit to Drill for CD1-22A. We shortened the drilling operations for CD1-24 and we will be moving to CD1-22A several days in advance of the original timeframe. We would appreciate receiving the permit by this Friday, August 4, 2000. If there are any questions, please contact me at 265-6120 or Pat Reilly at 265-6048. Sincerely, G. C. Alvord Alpine Drilling Team Leader Phillips Drilling GCA/skad RECE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill ~ .f~]> J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 45' (OKB) feet Colville River Field 3. Address 6: PmpertyDesignation ,t¢?~_~,~~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25,025) 372' FNL, 2427' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=intermediate target in Alpine sand ) 8. Well number Number 1325' FNL, 2388' FEL, Sec. 32, T12N, R5E, UM CD1-22.4 ~ #U-630610 At total depth 9. Approximate spud date Amount 354' FNL, 2379' FWL, Sec. 32, T12N, R5E, UM 08/07/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) Property line Alpine CD1- 01 11,340' MD Crosses T11N to feet 1223' @ 9239' Feet 2560 6,921' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 3200' feet Maximum hole angle 97° Maximum su~ace 2441 p$ig At total depth (TVD) 3215 at p$ig 7000' 'rVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# B Weld 75' 30' 30' 104' 104' 120sx AS1 12.25" 9.625" 40# L-80 BTC 3075' 35' 35' 3110' 3110' 18':78 sx AS3, 513 sx G 2"d:370 sx AS3, 61 sx AS1 8.5" 7" '26# L-80 BTC-M 8406' 34' 34' 8430' 6927' 477 sx Class G N/A 4.5" 12.6# L-80 IBT-M 7542' 32' 32' 7574' 6733' Tubing (packer depth) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary: Open hole completion with 4-1/2" tubing. Well closed in. Caelna detalia aiven above. Total depth: measured 9235 feet Plugs (measured) true vertical 6924 feet Effective depth: AS ABOVE 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify~{hat the foregoing is true and correct to the best of my knowledge Signed //~ ~'~,/ -~ C~4,;.~ ~ J~ Title Drilling Team Leader Date y" Commission Use Only PermitNum~ /(,(..~lAP, number__ I See cover ,etter for -- 50- / ~:)',.~ '"~2"~'O --(~::3 I I Approval date {~f?)/00 Other requirements Conditions of approval Samples required Yes ~ Mud Io{l?eq~lired~ Yes Hydrogen sulfide measures Yes /~ Directional survey required ~ No Required working pressure for BOPE 2M 3M 10M 15M ORIGINAL SIGNED BY by order of Approved by ~ 'r',,.,,~,.,. e, ........ Commissioner the commission Date Form 10-401 Rev. 7-24-89 lit in triplicate ORIGINAL RECEIVED JUL 1 9 2000 A~aska 0it & Gas Cons. Co~.mission Anchorage (" CD1-22 Program Outline ("' . . 3. 4. 5. . . 10. 11. 12. 13. 14. 15. 16. Note: Move on Doyon 19. Check for pressure at the wellhead. Rig up to cimulate to an upright tank. Circulate out the diesel freeze protection from the well (use heated 9.6 ppg brine). Install the 2-way check. Remove X-mas tree. Install BOPE. Pressure test BOPE to 3500 psi. Recover the 2-way check with the 'through BOP' lubricator. M/U the landing joint. Circulate the well with 9.6 ppg brine. Release the tubing hanger and pull the completion. Rack back the tubing and lay down all completion components. RIH with a fishing assembly / overshot. Back out and recover the anchor seal. RIH with a packer milling / picking assembly. Mill and recover the packer and completion tailpipe. M/U and run the drilling assembly. RIH to the casing shoe at 8430'. Displace the well to 9.2 ppg FIo-Pro drill in fluid. ,3tc~S~ Clean out the well to the current TD of 9235'. Drill 6 1/8" horizontal section to the new well TD at 11340' MD / 6921' TVD. Displace the well to 9.2 ppg brine and pull out of hole. Run 4 Y~, 12.6 #, L-80 tubing with S-3 packer, gas lift mandrels (bottom with DCK-2 shear valve, others with dummy valves), BAL-O ported SSSV nipple (packing sleeve installed) and control line. M/U hanger and pressure test the control line to 5000 psi. Land hanger. Back out landing joint. Install 2-way check with rods. Pressure test hanger to 3500 psi. Nipple down BOP. Install the X-mas tree. Pressure test to 5000 psi. Remove 2-way check with lubricator, Drop RHC ball and set packer. Test tubing to 3500 psi / 30 rains. Test casing annulus to 3500 psi / 30 rains. (hold 2500 psi tubing pressure to avoid shearing out the DCK-2 valve). Bleed off tubing pressure to shear out the DCK-2 valve. Circulate in 9.6 ppg inhibited brine and sufficient diesel to fill the tubing to the lowermost gas lift mandrel plus provide 2000' TVD of diesel freeze protection on the annulus. Set BPV and secure well. Move rig off. A slickline unit will return to the well to remove the packing sleeve and RHC nipple prior to preparing the well for production. This will be done after the.rig moves off location. RECEIVED JUL 1 9 2000 Alaska 0il & Gas Cons. Commission Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-01 will be the closest well to CD1-22 (1223' at 9239' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 1002' at 10838' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation is expected. Drilling stopped after losses were encountered at 9235' MD during the 1998 rig visit. These losses are consistent with the level of losses encountered in later Alpine development wells. Standard c~¢l~t~ents have proved effective in dealing with these fault effected zones. 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. Production Hole Fluid Properties: The horizontal extension will be drilled with a 9.2 ppg M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCl, with _ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. RECEIVED ,JUL 1 9 2000 Alaska Oil & Gas Cons. Commission Anchorage Colville River Field CD1-22 Production Well Completion - As built 16" Conductor to 104' MD Completed 03/22/98 Pre-Rig Prep. 07/14/00 4-1/2" Camco BP-6i SSSV Nipple (3.812" ID) at 509' MD Original KB Elevation -45' AMSL 9-5/8" 40 ppf L-80 BTC Surface Casing @ 3110' MD / 3110' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3384' MD / 3859' TVD for E Dummy with 1" BK-5 Bottom Latch WRDP-2 SSSV (2.125"1D) w/DB- 6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 DDO KCI Brine . . - with 2000' diesel cad Calculated TO~ 5566' MD 4-1/2" 12.6 ppf L-80 IBT Mod. R...~2 tubing run with Best-o-Life pipe dope Camco KBG-2 GLM (3.909' ID) at 5553' MD / 5203' TVD.SS for E Dummy with 1" BK-5 Latch Camco KBG-2 GLM (3.909' ID) at 7493' MD / 6679 TVD Dummy removed Tubing SuDended with diesel to 2000' Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BP-6i SSSV Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing HES "X" (3.813" ID) 4-1/2" 12.6#/ft, IBT-Mod Tubing SABL-3 Packer c/w KBH-22 Anchor Seal Assy. 4-1/2", 12.6#/ft, IBT-Mod Tubing HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+1- 63 deg) MD 23' 509' 3384' 5553' 7493' 7583' 7637' 7730' 7741' Tubing cut at 7627' RECEIVED JUL 1 c) 20Oo Well TD at 9235' MD I 6924' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8430' MD / 6927' TVD @ 91 deg tLost ..~~ Zone Ala~a Oil & Gas Con.,. Commissi.¢;.t~,. Anchorage ( Colville River Field CD1-22 Production Well Completion Plan 16" Conductor to 104' MD Prepared' 07/13/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 509' MD Original KB Elevation- 45' AMSL Calculated TO~ 5566' MD 9-5/8" 40 ppf L-80 BTC Surface Casing @ 3110' MD / 3110' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/BB- 6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 .DOg KCl Brine with 2000' diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R._[2 tubing run with Best-o-Life pipe dope Camco KBG-2 GLM (3.909" ID) at 5203' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" DCK-2 Shear Valve for casing side shear @ 2000 psi Completion Tubing Su.Dended with diesel to 2000' Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) HES "X" (3.813" ID) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 57 deg) Major Lost Circulation Zone at 9235' MD 32' 1700' 3403' 5549' 7473' 7542' 7574' 7639' 7650' TVD 32' 1700' 3400' 5200' 6664' 6712' 6733' 6771' 6777' REC : VED JUL 1 9 2000 Oi~ & Gas Cons. Cc~nrnission. Anchorage 7" 26 ppf L-80 BTC Mod Production Casing @ 8430' MD / 6927' TVD @ 91 deg Well TD at 11340' MD / 6921' TVD ( Colville River Field CD1-22 Production Well Completion Plan Updated 07/13/00 Formation Isolation Contingency Options i i ,, Original KB Elevation -45' AMSL i i 16 Conductor to 104' / I Ii ll~iI I] 4-1/2"Camco BAL-O SSSV Nipple (3.812" ID), / II "'1~1'~ I I ~ WRDP-2 SSSV (2.25" ID,! / I II I I I il and DB-6 No-Go Lock(3.812 OD) ! I I I I ] I il with single 1/4" x0.049" sis control line /J I I I I Lil9'5/8'' 40ppf L-80 BTC 141 I I I I ~J Surface Casing JUL 19 2000 @ 3110' MD / 3110' TVD cemented to surface Camco KBG-2 GLM (3.909' ID) at 3400' TVD for E Dummy with 1' BK-2 Latch Aias~a Oil & Gas Cons. Commission Anchorage 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Best-o-Life pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (B) Open Hole Bridqe Pluq Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple TOO @ +/- 5566' MD Baker S3 Packer set at +/- 7574' Well TD at 11340' MD I 6921' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8430' MD / 6927' TVD @ 91 deg CD1-22 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 104 / 104 10.9 52 N/a - already drilled 9 5/8 3110 / 3110 13.5 (actual LOT) 1407 N/a - already drilled 7" 8430 / 6927 16.0 3134 2441 N/A 11340 / 6921 16.0 3131 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. ASP CALCULATION Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3134 - (0.1 x 6927') = 2441 psi Where; ASP = Anticipated Surface pressure in psi FPP = Formation Porn Pressure at the next casing point D = true Vertical depth of casing seat in ft RKB 0.1 = Gas gradient in psi/ft 0.052 = Conversion from lb./gal to psi/ft RaC, r= VED JUL 9 2000 Ala~a 0/I & Gas Cor~s. Co~,~r~,issi0r~ ~ For: B. P. obertsonI Doll ~: 12-Jul-2000 F~ I~femno* M 22 Ve~l. Coon~not~ om ~n feet ref~,-~-.~ 750 600 450 500 150 I I I I I I I I I PHILLIPS Alaska, Inc. Sfrualure: CD#I Field: Alpine Field Well: 22 Looation: North Slope, Alaska East (feet) -> 0 150 500 450 600 750 go0 1050 1200 1550 1500 I I I I I I I I I I I I I I I I I I I I I CD1-22 TD PT LOCATION: 554' FNL, 2579' FWL SEC. 52, T12N, RSE TD - Csg Pt. CD1-22 Interm Pt LOCATION: 1525' FNL, 2588' F'EL SEC. 52, T12N, R5E Intermed Pt.- EOC Beg Final Drop 332.01 AZIMUTH 4709' (TO TD) ***Plane of Proposal*** RECkIV D dUL 1 9 2000 Alaska O, & Gas Cons. Commission Anchorage \ \ \ \ \ \ EOC in Build I00 O0 165cI 5550 5400 5250 5100 4950 4800 4650 4~500 435O 4200 4050 5900 -$750 5600 3450 3500 3150 5000 285O 2700 ^ I Z 0 PHILLIPS Alaska, Inc. Sfrucfure: CD#I Well: 22 Field: Alpine Field Looofion: Norfh Slope, Aloeko 332.01 AZIMUTH 4709' (TO TD) ***Plane of Proposal*** RECi= V:r , JUL 19 200:0 Ala~ Oil & Gas Cons, Oommission Anchorage 68OO 6900 7000 TANGENT ANGLE ;.oO'~_~ FINAL ANGLE ~-o ,~- 90.32 DEG ~,o.O<"' ¢""- 90 DEC i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i i i i ii i i i i i i i i i [ 2500 2600 2700 2500 2900 3000 5100 ;~200 5500 ;5400 ;5500 ;5600 ;5700 ;5800 5go0 4000 41 O0 4200 4500 4400 4500 4600 4700 4800 Vertical Section (feet) -> Azimuth ;552.01 wTfh reference 0.00 N, 0.00 E from slot #2200 Created by bm~choel For: B Robert~on] Dmte plotted: 12-Jul-2000 Pict Reference is 22 VenlJ'on~l. Goordirmtg~ am ~n feet reference .lot ]ff22DO. True ¥~col OEIptJl~ gr~ r~foronc~ ~9(Doyon lg).I PHILLIPS Alaska, Inc. Structure: CD#I Field: Alpine Field Well: 22 Location: North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 Begin Build 9238.50 89.49 331.89 6925.83 3443.57 922.14 2608.00 0.00 EOC 9521.54 90.32 ,351.98 6925.97 ,351 6.84 885.07 2691.05 1.00 Beg Final Drop 10208.06 90.32 331.98 6921.09 4299.45 466.58 3577.55 0.00 Intermed Pt.- EOC 10239.73 90.00 332.01 6921.00 4327.38 451.71 3609.21 1.00 TD - Csg Pt. 11559.57 90.00 552.01 6921.00 5298.56 -64.49 4709.05 0.00 JUL 1 9 2000 ~ .~.-, Cons. PHILLIPS Alaska, Inc. CD#i 22 slot #22D0 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 22 Version#l Our ref : prop3991 License : Date printed : 12-Jul-2000 Date created : 11-Jul-2000 Last revised : 11-Jul-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is nT0 20 33.440,w150 55 35.151 Slot Grid coordinates are N 5975756.510, E 385851.104 Slot local coordinates are 371.75 S 2426.61 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,19A,CD#1 PMSS <0-10897'>,,3,CD%1 PMSS <0-8350'>,,26PH1,CD#1 PMSS <7755-11134'>,,26,CD#1 PGMS <0-10255'>,,WD2,CD#1 CD1-2 Version %6 CD1-15 Version %2 CD1-10 Version %3 CD1-20 Version 93 CD1-21 Version %3 CD1-29 Version %2 CD1-17 Version %8 CD1-31 Version %2 CD1-30 Version %4 CD1-33 Version 94 CD1-28 Version %5 ,2,CD#1 ,15,CD%1 ,10 CD%i ,20 CD%1 ,21 CD%1 ,29 CD#i ,17 CD#i ,31 CD#i ,30 CD#i ,33 CD%1 ,28 CD%1 PMSS <476 - 11190'>,,34 CD#i PMSS <297 - 9882'>,,44PH1,CD#1 PMSS <9081 - 12811'>,,44,CD%1 PMSS <0-11300'>,,13,CD%1 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD%1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-10224'>,,39PH1,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-Apr-2000 2182.4 9771 30-Apr-2000 2389.1 9238 4-Jan-2000 2825.1 9238 6-Mar-2000 5781.9 9238 1-Nov-1999 5781.9 9238 28-Jun-1999 2869.8 9238 8-Aug-1999 1340.2 9238 5-Apr-2000 2187.8 9238 10-Aug-1999 2333.0 9238 10-Aug-1999 4966.8 11100 10-Aug-1999 3911.7 9238 13-Jan-2000 5491.5 9555 19-Apr-2000 4929.0 9238 11-Aug-1999 5518.4 9238 11-Aug-1999 5055.7 9238 11-Au~-1999 4572.3 9238 13-jan-2000 3908.4 9238 11-May-2000 5604.1 9238 23-May-2000 6485.9 9238 23-May-2000 6485.9 9238 15-Ju1-1999 3034.2 9238 3-May-2000 5497.5 9238 15-Mar-2000 5599.2 9238 16-Mar-2000 6107.0 9238 4-Jan-2000 4685.5 9238 22-Dec-1999 4327.9 9423 4-Jan-2000 6603.0 9238 26-Aug-1999 6409.7 9238 4-Jan-2000 6330.5 9238 0 9771 5 9238 5 9238 5 9238 5 9238 5 9238 5 10300 5 9238 5 9238 0 11100 5 9238 0 9555 5 9238 5 9238 5 9238 5 9238 5 9238 5 9238 5 9238 5 9238 5 . 9238 5 9238 5 9238 5 9238 5 9238 0 10288 5 9238 5 9238 5 9238 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PHI,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD#1 CD1-32 Version #6,,32,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-10504'>,,SPH1,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-11934'>,,9PH,CD#1 PMSS <10894 - 15350'>,,9,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 CD1-43 Version #11,,43,CD#1 PMSS <0-7331'>,,1PH1,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-13308'>,,6PH,CD#1 PMSS <12550 - 16023'>,,6,CD#1 35 Version#6,,35,CD#1 PMSS <0-8168'>,,35,CD#1 CD1-24 Version #5,,24,CD#1 PMSS <9810 - 10796'>,,24,CD#1 CD1-4 Version 910,,4,CD#1 PMSS <0-9236'>,,22,CD#1 40 Version#6,,40,CD#l PMSS <0-12055'>,,40,CD#1 22 PMSS(0 - 9239'>DepthShifted,,22,CD#1 22-Sep-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 3-Apr-2000 26-Mar-2000 8-Jun-2000 4-Jan-2000 7-Jun-2000 23-Jan-2000 23-Jan-2000 20-Jun-2000 20-Jun-2000 13-Feb-2000 14-Feb-2000 4-Jan-2000 25-0ct-1999 6-Jul-2000 29-Feb-2000 27-Jun-1999 30-Jun-2000 11-Jul-2000 6-Jun-2000 28-Jun-1999 29-Jun-2000 14-Jun-2000 12-Jul-2000 11-Jul-2000 22-May-2000 28-Jun-2000 11-Jul-2000 6330.5 6190.3 6333.5 6333.5 5527.0 5527.0 8824.7 5985.1 5985.1 3530.1 3530.1 4175.7 4175.7 6636.0 6636.0 5288.7 5288.7 6588.4 2323.7 1222.5 4593.5 4593.5 2884.1 2984.3 7967.1 5338.2 2628.1 0.0 11989.2 6783.4 0.0 9238 9238 9238 9238 9238 9238 11338 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238.5 9238.5 9238.5 9238.5 10638.0 9238.5 11338.0 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 11339.6 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 JUL 1 9 2000 Alaska Oi~ & Gas Cons. Commission Anchor~e JUL 1 9 2000 Oi! & Gas Cons. Commission PHILLIPS Alaska, Inc. CD% 1 22 slot #22D0 Alpine Field North SloDe, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 22 Version#l Our ref : Drop3991 License : Date printed : 12-Jul-2000 Date created : 11-Jul-2000 Last revised : 11-Jul-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.440,w150 55 35.151 Slot ~rid coordinates are N 5975756.510, E 385851.104 Slot local coordinates are 371.75 S 2426.61 E Projection tl~oe: alaska - Zone 4, SDheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse seDaration in reverse brackets, e.g. )10.2(, where available. DECREASIN~ CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-10548'>,,19,CD%1 PMSS <2827 - 11956'>,019A,CD%1 PMSS <0-10897'>,,3,CD#1 PMSS <0-8350'>,,26PH1,CD%1 PMSS <7755-11134'>,,26,CD%1 P~MS <0-10255'>,,WD2,CD#1 CD1-2 Version %6 CD1-15 Version %2 CD1-10 Version %3 CD1-20 Version %3 CD1-21 Version %3 CD1-29 Version %2 CD1-17 Version %8 CD1-31 Version %2 CD1-30 Version %4 CD1-33 Version %4 CD1-28 Version 95 PMSS <476 - 11190'> PMSS <297 - 9882'>,,44PH1,CD#1 PMSS <9081 - 12811'>,,44,CD#1 PMSS <0-11300'>,,13,CD#1 2,CD#1 15,CD#1 10,CD#i 20,CD%1 21,CD#1 29,CD#1 17,CD#1 31,CD%1 30,CD#1 33,CD%1 28,CD#1 , 34,CD#1 Closest aD, roach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-Apr-2000 )1969 30-Apr-2000 )2124 4-Jan-2000 )2712 6-Mar-2000 )5640 1-Nov-1999 )5640 2S-Jun-1999 )2741 S-Aug-1999 )990 5-A~r-2000 )1914 10-Aug-1999 )2112 10-Aug-1999 )4538 10-Aug-1999 )3665 13-Jan-2000 )5195 19-ADr-2000 )4774 11-Aug-1999 )5330 11-Aug-1999 )4820 11-Aug-1999 )4493 13-Jan-2000 )3827 11-May-2000 )5502 23-May-2000 )6384 23-May-2000 )6384 15-Ju1-1999 )2734 3( 10179.0 10179.0 6( 9238.5 9238.5 9( 9238.5 9238.5 8( 9238.5 9238.5 8( 9238.5 9238.5 1( 9238.5 9238.5 4( 10400.0 10400.0 6( 9238.5 9238.5 2( 9238.5 9238.5 2( 11339.6 11339.6 7( 9816.0 9816.0 3( 10800.0 10800.0 1( 9238.5 9238.5 6( 9238.5 9238.5 4( 9638.0 9638.0 3( 9238.5 9238.5 3( 9238.5 9238.5 6( 9238.5 9238.5 7( 9238.5 9238.5 7( 9238.5 9238.5 1( 9238.5 9238.5 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PH1,CD%1 PMSS <7950-11950'>,,45,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD#1 CD1-32 Version #6,,32,CD#1 PMSS <0-11067'>,,32PH1,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-10504'>,,SPH1,CD%1 PMSS <9499 - 14515'>,,5,CD%1 PMSS <0-11934'>,,gPH,CD#1 PMSS <10894 - 15350'>,,9,CD%1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 CD1-43 Version #11,,43,CD#1 PMSS <0-7331'>,,1PH1,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-13308'>,,6PH,CD#1 PMSS <12550 - 16023'>,,6,CD%1 35 Version%6,,35,CD#1 PMSS <0-8168'~,,35,CD#1 CD1-24 Version #5,,24,CD#1 PMSS <9810 - 10796'>,,24,CD#1 CD1-4 Version #10,,4,CD#1 PMSS <0-9236'>,,22,CD#1 40 Version%6,,40,CD#1 PMSS <0-12055'>,,40,CD#1 22 PMSS(0 - 9239'>DeDthShifted,,22,CD#1 3-May-2000 15-Mar-2000 16-Mar-2000 4-Jan-2000 22-Dec-1999 4-Jan-2000 26-Aug-1999 4-Jan-2000 22-SED-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 3-Apr-2000 26-Mar-2000 8-Jun-2000 4-Jan-2000 7-Jun-2000 23-Jan-2000 23-Jan-2000 20-Jun-2000 20-Jun-2000 13-Feb-2000 14-Feb-2000 4-Jan-2000 25-Oct-1999 6-Jul-2000 29-Feb-2000 27-Jun-1999 30-Jun-2000 11-Jul-2000 6-Jun-2000 28-Jun-1999 29-Jun-2000 14-Jun-2000 12-Jul-2000 11-Jul-2000 22-May-2000 28-Jun-2000 11-Jul-2000 5403.5 5407.5 6002.1 4563.7 3942.2 6553 3 6326 8 6272 4 6272 4 6062 9 6229 1 6229.1 5406.5 5406 5 8278 5 5825 0 5825 0 3245 0 3245 0 3887 4 3887 4 6566 9 6566 9 5088.4 5088.4 6508.6 2227.7 1002.3 4344.7 4344.7 2437.0 2806.8 7752.2 5205.1 2364.9 )o.o )11816.2 )6727.5( )o.o( 9238.5 9238.5 9238.5 9238.5 11038.0 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 11339.6 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 9238.5 10738.0 9238.5 9238.5 11339.6 9238.5 9238.5 9238.5 9238.5 9423.0 9238.5 9238.5 9423.0 9238 9238 9238 9238 11038 9238 9238 9238 9238 9238 9238 9238 11038 9238 11339 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 9238 10738 9238 9238 11339 9238 9238 9238 9238 9423 9238 9939 9423 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 18, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Approval to Deepen a Well: CD1-22~ Ori,qinal Permit No. 197-252~ APl No. 50-103-20250 Phillips Alaska, Inc. hereby applies for a Permit to Drill an extension of the horizontal production section on well CD1-22, located at the Alpine CD1 drilling pad. The intended re-entry date for this well is August 07, 2000. CD1-22 was drilled and completed in March 1998. The well is currently completed as an open hole producer, with a TD of 9235' MD in the Alpine Sand. The well will be re- entered and the completion removed prior to drilling an extension of the horizontal production section. The proposed new TD is 11340' MD. The well will then be completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to. this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. This includes a discussion on well risks and fluid properties. 4. Current well status diagram. " 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options'.. 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 this 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. If you have any questions or require further information, please contact Chip Alvord at 265-6120. Sincerely, /~ ~ Brian Robert~on~ ~'')b'.~ / Senior Drilling Engineer RECEIVED JUL 1 9 000 Alaska 0il & Gas Cons. C0mr~ssi0n Anch0ra~e Attachments CC: CD1-22 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com ECEIVED JUL 1 9 2000 Alaska Oil & Gas Cons. Commission Anchorage i CASH ADVANCE DRAFT ii '" 108 PAY TO IE ORDER OF Payable at Horwesl: Bank of Grand Grand Junction. Colorado , D~ARS VAUD FOP. AI~IOUNT OVEP. $1000 3,0 2 : :L 5. '" ?SDODN WELL PERMIT CHECKLIST FIELD & POOL COMPANY ~:~,'/~'~ WELL NAME ~Z~/-27,-~ PROGRAM: exp devv/ reddl v/ serv wellbore seg ann. disposal para req INIT CLASS ~ I/ ~"~)//'~.... GEOL AREA ~;~ .~/-~ UNIT# O ~'"~) ~ ~*'"~ ON/OFF SHORE ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. '7, / q, ~:X;~ 13. Permit fee attached ....................... Lease number appropriate...,.~/ .............. Unique well name and.number.~l%- ............... Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet'regulation ................. BOPE press rating appropriate; test to '~ I~sig. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30 Permit can be issued wlo hydrogen sulfide measures ..... "~"~ N ~ 311 Data presented on potential overpressure zones ....... , '32. Seismic ana~lYSiS OfuSrvh~llo~ og~.Ss~(~rn~S. ' ......... IIAPE~R DATE 33. Seabed con ition s y ('. - ) ........ .~,,'~. · · II ~ ~2,10,Oo 34. Contact name/phone for weekly progress reports [,e~ploratory only] Y N II II ANNULAR DISPOSAL35. With proper cementing records, this plan APPR ' DATE (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste ~ .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) ..will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular TEmpi ~ COMMISSION: Commentsllnstructions: c:Vnsoffice\wordian~diana\checklist (rev. 02117100)