Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-071
. . ~ ConocoPhilIi ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .r~1 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 SCANNED APR 0 9 2001 (leJJ ~071 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~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" na 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" na 8" na 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" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 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 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permitto Drill 2000710 MD 15350 TVD DATA SUBMITTAL COMPLIANCE REPORT 91612002 Well Name/No. COLVILLE RIV UNIT CD1-09 Operator PHILLIPS ALASKA INC. 6898 Completion Dat 6/16/2000 ~ Completion Statu 1-OIL APl No. 50-103-20339-00-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log Nc) Sample N__.9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type M ed ia.......l~n~t Name Interval Log Log Run OH / Scale Media No Start Stop CH 3179 15349 Open 3388 11934 Open SRVY RPT 0 15350 OH --9663~ 1 OH ARRAY RES-TVD 2/5 FINAL 2700 6870 OH ADN-MD 2/5 FINAL 3388 11891 OH ADN-TVD 2/5 FINAL 2790 6990 OH CDR-MD 2/5 FINAL 3388 11891 OH CDR-TVD 2/5 FINAL 2790 6990 OH ARRAY RES-MD · 2/5 FINAL 3200 15303 OH .~9.~8' 1-3 OH SRVY RPT 0 11934 OH (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number C...om ments 8/4/2000 09688~3~9-15349 7/7/2000 ~-88-11934 7/5/2000 SCHLUM 0-15350. 7/7/2000 ~66'3~CHLUM CDR/ADN PB1 8/4/2000 2700-6870 7/7/2000 3388-11891 PB1 7/7/2000 2790-6990 PB1 7/7/2000 3388-11891 PB1 7/7/2000 2790-6990 PB1 8/4/2000 3200-15303 8/4/2000 ~~CHLUM IMP- CDPJADN/GR 6/15/2000 SCHLUM 0-11934 PH Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~,~ Chips Received? Analysis ....~Y-¥-N"~' RP. nP. ivP. d ? Daily History Received? ~ N Formation Tops ~ N Permitto Drill 2000710 MD 15350 Comments: TVD DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. COLVILLE RIV UNIT CD1-09 Operator PHILLIPS ALASKA INC. 6898 Completion Dat 6/16/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20339-00-00 UIC N Compliance Reviewed By: Date: STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION COMlV~,c~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status el' well Classification of Service Well 0il ~ Gas [~ Suspended r'~ Abandoned r~ service r~ Phillips ~laska, Inc. 200-071 3. Address ~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~~ ~' 50-103-20339-00 · 4. Location of well at sudace ~ ~;~.~ .;~; ;.:.~.~ ,.,- ~~r' 9. Unit or Lease Name 279' FNL, 2517' FWL, Sec. 5, T11N, R5E, UM (ASP: 385943, 5975848) ~./ ~;~'; ~ ~ Colville River Unit At Top Producing Intewal ~&'--~. '-~ ..... ~ 10. Well Number 1721' FNL, 559' FEL, Sec.33, T12N, R5E, UM (ASP: 393472, 5979576)'~ V~.F;~?i[~;~ ~ ' CD1-09 & CD1-09PB1 At Total Depth [ .... ~ .............. ~ 11 Field and Pool 3~' FSL, 1162' FWL, Sec. 34, T12N, R5E, UM (ASP: 395153, 5976315) Colville River Field 5, Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feet~ ADL 25559, 25557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or ~and. ~15. Water Depth, il offshore 16. No. el Completions May 29, 2000 June 15, 2000 June 16, 2000 J N/A fe~ MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thic~e~ of Permalmst 15350' MD /6898' ~D 15350' MD /6898' ~D YES ~ No D~ 1756' feet MD 1 595' 22. T~e Ele~ric or Other Logs Run G~Res/NeuFDens 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5~ H-40 Surfa~ 114' 24" 10 cu yds Podland T~e 3 9.625" 36~ J-55 Surface 3378' 12.25" 500 sx AS III LW, 432 sx Cla~ G 7" 26~ L-80 Surfa~ 11894' 8.5" 137 sx Cla~ G CD1-09 PB1 cement plug dm~ed off to 10879' to sta~ CD1-09 sidetrack 24. Pedorations open to Production (MD + TVD of Top and Bo~om and i25. TUBING RECORD intewal, size and number) SIZE 3EPTH SET (MD) PACKER SET (MD) 4.5" 11277' 11190' OH completion 11894'-15350' 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11934'-11281' Plug ~1:262 sx 15.8 ppg Class G 11281'-10719' Plug ~: 246 sx 15.8 ppg Class G 27. PRODUCTION TEST Date First Produ~ion Method of Operation (Flowing, ~s li~, etc.) Waiting on Plant Start-Up Date of Test Hours Tested Production for OIL-BBL ~S-MCF WATER-BBL CHOKE SIZE I~S-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure :Calculated OIL-BBL ~S-MCF WATER-BBL OIL GRAVI~ - APl (coif) 24-Hour Rate > 28. CORE DATA Briefdesc~pti~n~f~ith~p~r~si~ract~res~parentdipsandpres~n~i~gas~rwater~ Submit core chips.R CEIVE SEP 0 7 000 ~aske ~; & Gas ~ns. Commiss~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME CD1-09 PB1 Top Alpine Base Alpine CD1-09 Top Alpine TD GEOLOGIC MARKERS MEAS. DEPTH 11673' 15350' TRUE VERT. DEPTH 6842' 6897' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS 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 Brian Robertson 265-6034 Signed ~-~J..~_ ~ ~--~ Title Alpine Drilling Team Leader Date 01 <~'/'~ '~ G. C. Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED Item 28.' If no cores taken, indicate "none". Form 10-407 SEP 0 7 Gas Cons. Commission Anchorage Date: 08/03/00 RECEIVED ARCO ALASKA INC. WELL SUMMARY REPORT SEP 0 7 Z000 Atasl~a Oi'i & Gas Oo~s~ Commission Page: 1 WELL:CD1-09 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:05/29/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20339-00 05/29/00 (D1) MW: 8.8 VISC: 300 PV/YP: 13/102 APIWL: 19.0 TD/TVD: 1159/1146 (1159) DRLG AT 2000' SUPV:LUTRICK / REILLY Move rig from CDi-19A to CD1-09. Function test diverter. Held pre-spud meeting. Drilling from 115' to 1159' 05/30/00 (D2) MW: 9.8 VISC: 110 PV/YP: 16/50 APIWL: 10.0 TD/TVD: 3388/2795 (2229) L/D BHA. SUPV:LUTRICK / REILLY Drill from 1159' to 3388'. Fire drill, spill drill. CBU hi vis sweep, rotate, reciprocate, observe well. POOH to 3062', incorrect hole fill. TIH to TD 3388'. CBU. 05/31/00 (D3) MW: 9.8 VISC: 55 PV/YP: 15/16 APIWL: 12.0 TD/TVD: 3388/2795 ( 0) PICKING UP DRILL PIPE. SUPV:LUTRICK / REILLY Continue trip out, minimal overfill and swab from 2100' to 1700', pump out to 1510'. RIH to 3388'. CBU hi vis sweep, observe well. TOOH. PJSM. Run 9-5/8" casing. PJSM. Pump cement. Displace cement, bump plug, checked floats, OK. N/U LOPE and test. 06/01/00 (D4) MW: 9.6 VISC: 47 PV/YP: 12/30 APIWL: 6.8 TD/TVD: 4332/3276 ( 944) DRILLING AHEAD ~ 4761' SUPV:LUTRICK / REILLY Continue to test LOPE, 250/3500 psi. RIH, tag stringer ~ 3253' Circ and condition mud. Test 9-5/8" casing. Drill float equipment, shoe, and 20' new hole to 3408' Perform 16.0 ppg FIT. Drill from 3408' to 4332' 06/02/00 (D5 MW: 9.7 VISC: 44 PV/YP: 9/25 APIWL: 6.2 TD/TVD: 6808/4483 (2476) SHORT TRIPPING TO 5900' SUPV:LUTRICK / REILLY Drill from 4332' to 4427' Circ hi vis sweep. Short trip to shoe. Tight ~ 3574' Pumped out from 3574' to 3370'. RIH to 4427'. Drill from 4427' to 5951'. Circ hi vis sweep. Short trip to 4332' RIH to 5951'. Drill from 5951' to 6808' 06/03/00 (D6) MW: 9.6 VISC: 44 PV/YP: 9/30 APIWL: 6.4 TD/TVD: 8995/5549 (2187) DRILLING AHEAD ~ 9598' SUPV:LUTRICK / REILLY Drill from 6808' to 7474'. Circ hi vis sweep. Wiper trip to 5760'. RIH to 7378' Wash/ream to 7474' Drill from 7474' to 8995'. Circ hi vis sweep. Wiper trip to 7380' CEiVED Date: 08/03/00 SEP 07 2000 ARCO ALASKA INC. Page: 2 WELL SUlVIMARY REPORT Alaska C~ & Gas Cons. Commission Anchorage 06/04/00 (D7) MW: 9.7 VISC: 44 PV/YP: 8/30 APIWL: 5.1 TD/TVD:10520/6319 (1525) DRILLING AHEAD ~ 11,115' SUPV:LUTRICK / REILLY Drill from 8995' to 10520' Circ hi vis sweep. TOOH to 9570' Check flow. POOH to 3377' Tight spots ~ 5560' & 5760' Check flow. RIH filling every 25 stds. 06/05/00 (D8) MW: 9.8 VISC: 40 PV/YP: 7/22 TD/TVD:l1934/7018 (1414) POH W/ BHA SUPV:DONALD LUTRICK APIWL: 5.2 Finish RIH. No problems. Drilling from 10520' to 11884' Circ hi vis sweep. POH. Improper hole fill. RIH to TD. Drill additional 50' to 11934' Circ 1.5 bottoms up. Wiper trip to 9474'. No problems. Circ hi vis sweep. Circ hole clean. POH to 11432' Flow check. Pump slug. POH. 06/06/00 (D9) TD/TVD:10879/6493 ( SUPV:DONALD LUTRICK 06/07/00 (D10) TD/TVD:l1329/6715 SUPV:SCOTT REYNOLDS MW: 9.8 VISC: 45 PV/YP: 9/20 0) PREP TO SIDETRACK WELL AT 10879. APIWL: 4.9 POH. Monitor well at shoe. RIH w/muleshoe to 11934'. Circ and condition mud to balance weight. PJSM. Pump cement to balance plug. P0H to 11281'. Pump cement for balance plug. POH to 10719' Circ out contaminated mud. Check flow. Pump slug. Monitor well at shoe. MW: 9.6 VISC: 41 PV/YP: 7/29 450) DRILLING AHEAD ~ 11508' APIWL: 6.4 RIH to 10660' Drill cement from 10660' to 10879'. Attempt to time drill. Cannot get weight to bit. Circulate around hivis sweep with nutplug. Rotate and reciprocate throughout circulation. Time drill from 10879' to 10945' Drill from 10945' to 11329' 06/08/00 (Dll) TD/TVD:l1904/6867 SUPV:SCOTT REYNOLDS 06/09/00 (D12) TD/TVD:llg04/6867 SUPV:SCOTT REYNOLDS MW: 9.7 VISC: 45 PV/YP: 9/27 575) POOH TO RUN CASING. APIWL: 5.4 Drill from 11329' to 11904'. Circulate around weighted hivis sweep with nutplug. Average amount of solids to surface. Short trip from TD to 9420'. No hole problems. Circulate around hivis sweep. Monitor well, static. POOH. MW: 9.6 VISC: 40 PV/YP: 8/18 0) CHANGE OUT VBR'S TO 3-1/2 X 6 APIWL: 6.5 Continue to POOH. Tight from 8600' to 7250'. Worked thru tight spots from 5650' to 5550' and from 3765' to 3669' Monitor well ~ shoe, static. PJSM. Run 7" casing to 3200' PJSM. Continue to run 7" casing. Establish circulation. Reciprocate casing. Hole sticky. Continue to work pipe with no improvement. Date: 08/03/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/10/00 (D13) TD/TVD:l1904/6867 SUPV:SCOTT REYNOLDS MW: 9.6 VISC: 40 PV/YP: 8/18 0 7" SHOE FIT T/12.5 PPG EMW. APIWL: 6.5 Continue circulating and conditioning mud for cement job. PJSM. Pump cement. Set packoff-would not test. Pull packoff to floor and replace seals. Retest packoff, good test. Set test plug. Test IBOPs to 250/3500 psi. 06/11/00 (D14) MW: 9.2 VISC: 56 PV/YP: 12/28 TD/TVD:12118/6868 ( 214) DRILLING AHEAD @ 12468' SUPV:SCOTT REYNOLDS APIWL: 3.9 Screw in - wash and ream from 11741' to 11801' Circulate and condition mud. Test casing to 3500 psi. Drill cement and float equipment. Drill from 11904' to 11924'. Circulate and condition mud for FIT. Perform FIT to 12.5 ppg EMW. CBU. Drill from 11924' to 12118' 06/12/00 (D15) MW: 9.2 VISC: 50 PV/YP: 11/25 TD/TVD:13458/6872 (1340) DRILLING AHEAD ~ 13,737' SUPV:REYNOLDS/REILLY Drill from 12118' to 13458' APIWL: 4.2 06/13/00 (D16) MW: 9.2 VISC: 51 PV/YP: 14/29 APIWL: 3.9 TD/TVD:14140/6862 (682) DRILLING AHEAD ~ 14,471' SUPV:REYNOLDS/REILLY Circ hi/lo vis sweep. Drill from 13458' to 14010'. Circ hi/lo vis sweep. Check flow. Pump out to 11860'. Circ lo ivs sweep. Check flow. nIH to 13918', screw in and est circ. nIH to 14010'. Drill from 14010' to 14140' 06/14/00 (D17) MW: 9.2 VISC: 52 PV/YP: 14/27 TD/TVD:15225/6892 (1085) CIRCULATE SWEEP FOR WIPERTRIP. SUPV:REYNOLDS/REILLY Drill from 14140' to 15225' APIWL: 3.8 06/15/00 (D18) MW: 9.2 VISC: 27 PV/YP: 2/ 1 APIWL: 0.0 TD/TVD:15350/6897 ( 125) LAYING DOWN BHA. LOSSES @ 14 BPH. SUPV:REYNOLDS/REILLY Drill from 15225' to 15350'. Circ lo/hi vis sweeps. Pump out to 13885'. nIH. Circ. PJSM. Displace to 9.2 ppg brine, clean equipment, hole taking 15 bph. Pump dry job. TOOH to 10638', hole taking 72 bph. Observe well, obtain loss rates, reduced to 22 bph. nIH. Spot hi vis pill. TOOH to 9367' Monitor well, initial loss rate 28 bph, final loss rate @ 14 bph. TOOH. 06/16/00 (D19) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:15350/6897 ( 0) CIRCULATING 9.6 PPG KCL BRINE AND DIESEL. SUPV: REYNOLDS / REILLY PJSM. Run 4.5" tubing. R. EGE~VED SEP 07 2000 Co.,'l~. A!askaO~l & Gas , ,., "'n, ' ' ,Anchorage Date: 08/03/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 06/17/00 (D20) MW: 9.6 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:15350/6897 ( 0) DRILLING ON CD1-06 ~ 500' SUPV:REYNOLDS/REILLY N/U tree and test to 5000 psi. Set packer. Bleed off tubing to shear DCK-2 valve, valve softly sheared. Experienced valve problem. Reverse circ brine and diesel. PJSM. Freeze protect annulus. Set BPV. Secure well. Release rig ~ 1600 hrs. 6/17/00 RECEIVED & ~ao Cor~s. Oommission Anchorage ~ ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00033 Sidetrack No. Page 1 of 4 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyen Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 PH1 MWD BHI Rep. C MILCHAK ~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] SSE] Target Description Target Coord. E/W Slot Coord. E/W 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE] 10mE] Vert. Sec. Azim. 55.46 Magn. to Map Corr. 25.800 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 (FT) (DD) (DD) (F'r) , (FI') (FT) (FT) Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 · - 0,00 0.00 0.00 0.00 TIE IN POINT 29-MAY-00 MWD 115.00 0.00 0.00 · 115.00 115.00 0.00 0.00 0.00 0.00 0.00 8" M1C 1.4 DEG AKO 29- MAY-00 MWD 199.76 0.53 105.76 84.76 199.76 0.25 -0.11 0.38 0.63 0.63 29-MAY-00 MWD 288.64 2.19 133.56 88.88 288.61 0.86 -1.39 2.00 1.96 1.87 29- MAY-00 MWD 379.06 4.83 142.14 90.42 378.85 1.44 -5.59 5.59 2.97 2.92 29-MAY-00 MWD 467.03 6.51 142.75 87.97 466.39 1.89 -12.48 10.88 1.91 1.91 0.69 29- MAY-00 MWD 556.17 8.09 143.90 89.14 554.81 2.30 -21.57 17.64 1.78 1.77 1.29 29-MAY-00 MWD 647.58 9.15 144.43 91.41 645.18 2.61 -32,68 25.66 1.16 1.16 0.58 29-MAY-00 MWD 734.04 8.91 139.64 86.46 730.57 3.41 -43.37 33.99 0.91 -0.28 -5.54 29-MAY-00 MWD 824.39 9.58 130.21 90.35 819.75 6.10 -53.56 44.27 1.83 0.74 -10.44 29- MAY-00 MWD 914.18 11.1 8 123.34 89.79 908.07 11.34 -63.17 57.24 2.25 1.78 -7.65 29- MAY-00 MWD 1003.77 12.97 113.05 89.59 995.69 20.00 -71.88 73.75 3.12 2.00 -11.49' 29-MAY-00 MWD 1098.64 15.91 102.82 94.87 1087.57 34.52 -78.94 96.24 4.09 3.10 -10.78 -- 30- MAY-00 M.WD 1193.18 16.72 99.15 94.54 1178.30 53.13 -83.97 122.30 1.39 0.86 -3.88 30-MAY-00 MWD 1289.38 17.19 95.18 96.20 1270.32 74.07 -87.46 150.12 1.30 0.49 -4.13 30-MAY-O0 I~IWD 1384.07 19.47 92.40 94.69 1360.20 97.45 -89.38 179.83 2.58 2.41 -2.94 30-MAY-O0 MWD 1479.31 23.04 85.44 95.24 1448.96 126.30 -88.56 214.28 4.58 3.75 -7.31 30-MAY-00 MWD 1669.07 25.92 82.47 94.20 1621.14 196.48 -79.91 293.53 0.91 0.73 -1.26 30-MAY-O0 MWD 1764.30 28.92 82.69 95.23 1705.66 235.51 -74.25 337.02 3.15 3.15 0.23 SEP 0 ~..~? 30-MAY-00 MWD 1859.78 33.24 83.40 95.48 1787.41 279.18 -68.31 385.93 4.54 4.52 0.74 ~ Co~s. Commission 30-MAY-O0 MWD 1954.34 37.28 83.35 94.56 1864.61 327.40 -62.01 440.15 4.27 4.27 -0.05 30-MAY-00 MWD 2048.62 39.61 83.97 94.28 1938.45 379.06 -55.54 498.40 2.50 2.47 0.66 · , 30- MAY-O0 MWD 2145.21 43.04 84.37 96.59 2010.97 434.99 -49.07 561.85 3.56 3.55 0.41 ~ sURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00033 Sidetrack No. Page 2 of 4 . Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 PH1 MWD BHI Rep, C MILCHAK j~irr~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB [~ MSL[~ SSD Target Description Target Coord. E/W Slot Coord. E/W 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mD 10m[~ Vert, Sec. Azim. 55.46 Magn. to Map Corr. 25,800 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 (F'r) (DD) (DD) (F'I~ , (FT) (F-~ (FT) (Per 100 FT) Drop (-) Left (-) 30-MAY-00 MWD 2241.08 44.87 83.27 95.87 2079.99 493.54 -41.90 628.00 2.07 1.91 -1.15 30-MAY-00 MWD 2335.23 47.31 82.86 94.15 2145.28 553.65 -33.71 695.32 2.61 2.59 -0.44 30-MAY-00 MWD 2429.40 48.12 83.67 94.17 2208.64 615.27 -25.54 764.51 1.07 0.86 0.86 30- MAY-00 MWD 2524.96 47.89 84.77 95.56 2272.57 677.53 -18.39 835.17 0.89 -0.24 1.15 30-MAY-00 MWD 2620.67 48.69 81.38 95.71 2336.26 740.83 -9.76 906.07 2.77 0.84 -3.54 30-MAY-00 MWD 2713.76 49.70 77.92 93.09 2397.11 805.09 2.91 975.37 3.02 1.08 -3.72 30-MAY-00 MWD 2808.85 50.86 74.00 95.09 2457.89 873.58 20.67 1046.29 3.40 1.22 -4.12 ..... 30-MAY-00 MWD 2907.06 51.91 69.44 98.21 2519.20 947.22 44.75 1119.11 3.78 1.07 -4.64 ,,, 30-MAY-O0 MWD 3001.74 53.14 65.61 94.68 2576.81 1020.68 73.48 1188.51 3.46 1.30 -4.05 30-MAY-00 MWD 3098.40 53.99 63.59 96.66 2634.22 1097.45 106.84 1258.75 1.90 0.88 -2.09 30-MAY-00 MWD 3193.29 55.15 58.44 94.89 2689.26 1174.36 144.31 1326.34 4.59 1.22 -5.43 30-MAY-00 MWD 3288.35 57.39 54.66 95.06 2742.05 1253.38 187.90 1392.26 4.06 2.36 -3.98 30-MAY-00 MWD 3324.13 57.90 54.05 35.78 2761.20 1283.60 205.51 1416.82 2.03 1.43 -1.70 -- 01-JUN-00 MWD 3495.78 58.00 54.09 171.65 2852.29 1429.04 290.89 1534.63 0.06 0.06 0.02 6 3/4" M1/XL 1.2 DEG AKO 01 -JU N-00 MWD 3685.40 61.34 55.22 189.62 2948.03 1592.67 385.53 1668.12 1.83 1.76 0.60 01-JUN-O0 Iv{WD 3875.84 59.61 54,74 190.44 3041,88 1758.36 480.61 1803.83 0.93 -0,91 -0.25 01-JUN-00 MWD 4065.40 59.05 54.74 189.56 3138.57 1921.40 574.74 1936.96 0.30 -0.30 0.00 01-JUN-00 MWD 4257.59 58.03 53.40 192.19 3238.88 2085.28 670.92 2069,70 0.80 -0.53 -0.70 02-JUN-00 MWD 4449.42 59.22 54.41 191.83 3338.75 2248.99 767.40 2202.04 0.77 0.62 0.53 02-J U N-O0 MWD 4637.59 60.36 54.26 188.17 3433.43 2411.57 862.21 2334.16 0.61 0.61 -0.08 02-JUN-O0 MWD 4828.91 61.29 55.93 191,32 3526.70 2578.61 957.78 2471.1 5 0.90 0.49 0.87 SEP 0 7 02-JU N-O0 MWD 5019.86 61.85 55.49 190.95 3617.61 2746.53 1052.39 2609.88 0.36 0.29 -0.23 02-J UN-00 MWD 5210.59 61.83 55.10 190.73 3707.62 2914.68 1148.12 2748.12 0,18 -0.01 -0.20 A~aska C~; & Gas Cons. uo~.~ re!ss:an 02-JUN-00 MWD 5400.26 62.48 57.02 189.67 3796.22 3082.36 1241.75 I 2887.25 0.96 0.34 1 BOW SURVEY CALCULATION AND FIELD WORKSHEET i ~iAK~R i Job No. 0450-0(X)33 Sidetrack No. __ Page 3 of 4 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 PH1 MWD BHI Rep. C MILCHAK J~NI'T~I~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOftr~ 30m~ lom~ Vert. Sec. Azim. 55.46 Magn. to Map Corr. 25.800 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 (FT) (DD) (DD) (FT) , (F-'~ (FT) (FT) (Per 100 FT) Drop (-) Left (-) 02-JUN-00 MWD 5593.00 61.84 57.55 192.74 3886.23 3252.71 1333.86 3030.64 0.41 -0.33 0.27 02-J U N-00 MWD 5781.67 60.64 57.67 188.67 3977.00 3417.99 1422.46 3170.31 0.64 -0.64 0.06 02-J U N-00 MWD 5969.19 60.98 56.55 187.52 4068.46 3581.62 1511.36 3307.77 0.55 0.18 -0.60 02-JUN-00 MWD 6160.97 60.73 56.63 191.78 4161.86 3749.09 1603.58 3447.59 0.14 -0.13 0.04 02-J U N-00 MWD 6352.52 60.07 56.38 191.55 4256.47 3915.61 1695.50 3586.48 0.36 -0.34 -0.13 02-J U N-00 MWD 6541.29 60.19 56.30 188.77 4350.49 4079.28 1786.23 3722.73 0.07 0.06 -0.04 02-J U N-00 MWD 6732.94 60.35 55.67 191.65 4445.53 4245.70 1879.32 3860.67 0.30 0.08 -0.33 03-JUN-00 MWD 6922.52 60.62 55.03 189.58 4538.93 4410.67 1973.13 3996.39 0.33 0.14 -0.34 03-JUN-00 MWD 7113.12 60.76 54.85 190.60 4632.23 4576.87 2068.60 4132.43 0.11 0.07 -0.09 03-JUN-00 MWD 7303,07 60~84 54.17 189.95 4724.90 4742.65 2164.86 4267,44 0,32 0,04 -0.36 03-J U N-00 MW D 7494.09 60.99 55.43 191.02 4817.76 4909.57 2261.08 4403.84 0.58 0.08 0.66 03-JUN-00 MWD 7685.35 61.19 54.91 191.26 4910.22 5076.99 2356.70 4541.27 0.26 0.10 -0.27 03-JUN-00 MWD 7875.27 61.28 56.55 189.92 5001.62 5243.47 2450.44 4678.85 0.76 0.05 0.86 03-J U N-O0 MWD 8064.90 61.82 56.20 189.63 5091.96 5410.17 2542.77 4817.68 0.33 0.28 -0.18 ,. 03-J U N-O0 MWD 8255.09 61,01 56.94 190,19 5182.96 5577.15 2634.78 4957,05 0.55 -0.43 0.39 03-JU N-O0 MWD 8443.92 59.97 56.48 188.83 5275.97 5741.44 2724.98 5094.41 0.59 -0.55 -0.24 03-JUN-O0 MWD 8634.96 60.08 56.24 191.04 5371.42 5906.90 2816.65 5232.19 O. 12 0.06 -0.13 03-JUN-O0 M.WD 8824.63 60.57 55.50 189.67 5465.32 6071.69 2909.11 5368.60 0.43 0.26 -0.39 04-d U N-00 MWD 9015.89 60.88 54.99 191.26 5558.85 6238.52 3004.22 5505.66 0.28 0.16 -0.27 04-JUN-O0 MWD 9206.74 61.03 54.85 190.85 5651.50 6405.36 3100.11 5642.20 0.10 0.08 -0.07 SEP 0 04-JUN-00 MWD 9397.21 59.61 53.95 190.47 5745.82 6570.81 3196.43 5776.76 0.85 -0.75 -0.47 04-JUN-00 MWD 9588.65 59.01 54.43 191.44 5843.53 6735.39 3292.75 5910.26 0.38 -0.31 0.25 04-JUN-00 MWD 9776.94 59.31 54.21 188.29 5940.05 6897.03 3387.05 6041.58 0.19 0.16 -0.12 04-J U N-00 MWD 9968.12 59.73 53.56 191.18 6037.03 7061.72 3484.16 6174.68 0.37 0.22 -0.34 i~-~l~kr~l~l._. :3[,_.-.~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-(X)033 Sidetrack No. Page 4 of 4 [l_r~ -'1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#l/9 PH1 / 9 Survey Section Name CD1-09 PH1 MWD BHI Rep. C MILCHAK I~N"~"~~ WELL DATA Target TVD (Fl') Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~ MSL r-[ ssQ Target Description Target Coord. E/W Slot Coord. E/W 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: lOOft[~ 30mD lOmD Vert. Sec. Azim. 55.46 Magn. to Map Corr. 25.800 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 (FT) (DD) (DD) (FT) . (FT) (F'I~ (F~ (Per lO0 FT) Drop (-) Left (-) 04-JUN-O0 MWD 10160.09 59.30 56.20 191.97 6134.43 7227.12 3579.32 6309.97 1.21 -0.22 1.38 04-JUN-O0 MWD 10349.69 58.99 55.28 189.60 6231.67 7389.89 3670.95 6444.49 0.45 -0.16 -0.49 ~-' 05,JUN-O0 MWD 10538.90 59.02 56.57 189.21 6329.11 7552.07 3761.82 6578.83 0.58 0.02 0.68 05-JUN-O0 MWD 10728.81 59.61 56.10 189.91 6426.02 7715.37 3852.35 6714.76 0.38 0.31 -0.25 05-JUN-O0 MWD 10878.96 59.55 55.83 150.15 6502.05 7844.84 3924.82 6822.06 0.16 -0.04 -0.18 05-JUN-O0 MWD 10919.82 59.66 55.54 40.86 6522.72 7880.08 3944.69 6851.17 0.67 0.27 -0.71 05-JUN-O0 MWD 11110.72 60.02 55.14 190.90 6618.63 8045.14 4038.56 6986.93 0.26 0.19 -0.21 05-JUN-O0 MWD 11302.20 60.67 55.41 191.48 6713.37 8211.54 4133.35 7123.70 0.36 0.34 0.14 05-JUN-O0 MWD 11491.93 60.83 55.11 189.73 6806.08 8377.08 4227.68 7259.73 0.16 0.08 -0.16 05-JUN-O0 MWD 11679.91 61.54 55.89 ' 187.98 6896.68 8541.78 4320.97 7395.46 0.52 0.38 0.41 05-JUN-O0 MWD 11856.25 61.60 56.08 176.34 6980.64 8696.84 4407.72 7524.00 0.10 0.03 0.11 05-JUN-O0 MWD 11934.00 61.60 56.08 77.75 7017.62 8765.23 4445.88 7580.76 0.00 0.00 0.00 Projected Data - NO SURVEY -- .. LL,.~jv i " SURVEY CALCULATION AND FIELD WORKSHEET i iJob No. 0450-00033 Sidetrack No. 1 Page 1 of 3 I I Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 MWD BHI Rep. D NEWLON '~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] SS[]] Target Description Target Coord. E/W Slot Coord. EAN 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE] 10mi-1 Vert. Sec. Azim. 151.99 Magn. to Map Corr. 25.800 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (F'r) (DD) (DD) (F'I~ , (F'I~ (FT) (FT) (Per lO0 F'r) Drop (-) Left (-) MWD 10878.96 59.51 55.83 ' 6502.04 -261.37 3924.83 6822.06 TIE IN POINT 07-JUN-00 MWD 10894.33 59.87 56.70 15.37 6509,80 -262.60 3932.20 6833,09 5.42 2.34 5.66 6 3/4" M1X 1.45 DEG AKO 07-JUN-00 MWD 10928.09 60.25 59.51 33.76 6526.65 -264.59 3947.65 6857.93 7.30 1.13 8.32 07-JUN-00 MWD 10959.22 60.47 63.59 31.13 6542.05 -264.79 3960.54 6881.71 11.41 0.71 13.11 07-J U N-00 MWD 10990.13 60.53 66.28 30.91 6557.27 -263.41 3971.93 6906.08 7.58 0.19 8.70 07-JUN-00 MWD 11022.52 60.77 69.71 32.39 6573.15 -260.46 3982.51 6932.25 9.26 0.74 10.59 07-JUN-00 MWD 11053.87 60.76 71.81 31.35 6588.46 -256.29 3991.52 6958.07 5.85 -0.03 6.70 07-JUN-00 MWD 11082.96 60.95 75.39 29.09 6602.63 -251.17 3998.69 6982.44 10.77 0.65 12.31 07-JU N-00 MWD 11117.47 61.40 79.55 34.51 6619.28 -243.10 4005.25 7011.95 10.64 1.30 12.05 07-JUN-00 MWD 11179.84 62.99 86.98 62.37 6648.40 -223.08 4011.68 7066.68 10.84 2.55 11.91 07-JUN-00 MWD 11213.42 63.14 90.54 33.58 6663.62 -209.60 4012.33 7096.60 9.46 0.45 10.60 07-J U N-00 MWD 11244.41 63.00 93.67 30.99 6677.66 -195.74 4011.32 7124.21 9.02 -0.45 10.10 07-JUN-00 MWD 11273.96 62.73 97.03 29.55 6691.14 -181.28 4008.87 7150.39 10.16 -0.91 11.37 07-JUN-00 MWD 11308.29 62.17 101.58 34.33 6707.02 -162,84 4003.95 7180.41 11.86 -1.63 13.25 08-JUN-00 MWD 11339.89 62.31 105.32 31.60 6721.74 -144.33 3997.45 7207.60 10.48 0.44 11.84 08-JUN-00 MWD 11369.68 63.24 108.44 29.79 6735.37 -125.64 3989.75 7232.95 9.82 3.12 10.47 08-J U N-00 MWD 11403.67 64.29 110.57 33.99 6750.40 -103.15 3979.57 7261.68 6.41 3.09 6.27 08-JUN-O0 MWD 11465.20 67.04 116.26 29.95 6775.77 -59,07 3956.88 7312.91 7,28 4.57 6.18 08-JUN-00 MWD 11498.06 68.61 120.53 32.86 6788.18 -33.72 3942.41 7339.66 12.95 4.78 12.99 SEP 0 7' 08-JUN-Ob MWD 11529.37 69.41 122.72 31.31 6799.40 -8.50 3927.08 7364.55 7.01 2.56 6.99 08-J U N-00 MWD 11560,40 70.47 124.57 31.03 6810.04 17.15 3910.93 7388.81 6.56 3.42 5.96 08-JUN-O0 MWD 11592.59 71.95 126.78 32.19 6820.41 44.46 3893.16 7413.56 7.96 4.60 6.87 08-JUN-O0 MWD 11625.64 73.90 130.60 33.05 6830.12 73.47 3873.41 7438.21 12.52 5.90 11.56 ~ '~ sURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00033 Sidetrack No. 1 Page 2 of 3 Company PHILLIPS ALaSKa, INC. Rig Contractor & No. Doyen Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 MWD BHI Rep. D NEWLON ~Jl"~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~1 MSLO SS~ Target Description Target Coord. E/W Slot Coord. E/W 2517.50 Magn. Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 151.99 Magn. to Map Corr. 25.800 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 (FT) (DD) (DD) (FT) . (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 08-JUN-00 MWD 11655.07 75,90 133.90 29.43 6837.79 100.21 3854.31 7459.24 12.78 6.80 11.21 08-JUN-O0 MWD 11688.31 79.87 136.34 33.24 6844.76 131.31 3831.28 7482.16 13.93 11.94 7'34 '~-'- 08-JUN-O0 MWD 11719.88 81.67 137.01 31.57 6849.83 161.36 3808.62 7503.54 6.07 5.70 2.12 08-JUN-O0 MWD 11752.02 82.47 139.06 32.14 6854.26 192.25 3784.95 7524.83 6.79 2.49 6.38 08-JUN-O0 MWD 11793.41 83.59 143.07 41.39 6859.28 232.58 3753.00 7550.64 9.99 2.71 9.69 08-JUN-O0 MWD 11832.86 86.03 146.41 39.45 6862.85 271.55 3720.92 7573.31 10.46 6.19 8.47 11-JUN-O0 MWD 11998.01 90.14 150.11 165.15 6868.37 436.19 3580.60 7660.10 3.35 2.49 2.24 4 3/4" M1X 1.2 DEG AKO 11 -J UN-O0 MWD 12095.11 91.68 149.75 97.10 6866.83 533.22 3496.58 7708.75 1.63 1.59 -0.37 12-J U N-O0 MWD 12192.00 90.72 150.48 96.89 6864.80 630.03 3412.60 7757.01 1.24 -0.99 0.75 12-JUN-O0 MWD 12287.00 90.93 152.89 95.00 6863.43 725.01 3328.98 7802.07 2.55 0.22 2.54 ,__ 12-JUN-O0 MWD 12383.00 91.17 152.11 96.00 6861.67 820.99 3243.84 7846.39 0.85 0.25 -0.81 ..... 12-JUN-O0 MWD 12475.00 91.06 151.27 92.00 6859.88 912.97 3162.86 7890.01 0.92 -0.12 -0.91 .... 12-JUN-O0 MWD 12568.00 89.42 152.88 93.00 6859.50 1005.97 3080.69 7933.56 2.47 -1.76 1.73 12-JUN-O0 M.WD 12662.00 89.90 151.96 94.00 6860.05 1099.96 2997.38 7977.08 1.10 0.51 -0.98 . ., 12-JUN-O0 MWD 12755.00 88.70 153.03 93.00 6861.19 1192.95 2914.90 8020.02 1.73 -1.29 1.1 5 12-J U N-O0 MWD 12847.00 89.93 153.22 92.00 6862.29 1284.92 2832.84 8061.61 1.35 1.34 0.21 12-JUN-O0 MWD 12939.00 88.90 153.24 92.00 6863.23 1376.89 2750.71 8103.04 1.12 -1.12 0.02 12-JUN-O0 MWD 13035.00 89.45 153.35 96.00 6864.61 1472.86 2664.96 8146.18 0.58 0.57 0.11 ,,,,wo 12-JUN-O0 MWD 13220.00 88.42 155.29 92.00 6868.76 1657.66 2498.48 8226.72 1.35 -0.08 1.35 12-JUN-O0 MWD 13314.00 89.31 154.60 94.00 6870.63 1751.52 2413.34 8266.52 1.20 0.95 -0.73 SF_? 0 ,.. 12-JUN-O0 MWD 13405.00 89.86 154.96 91.00 6871.28 1842.41 2331.02 8305.30 0.72 0.60 0.40 Aiaske Ct-; & Gas C0~. 13-JUN-O0 MWD 13497.00 90.55 154.20 92.00 6870.96 1934.31 2247.93 8344.79 1.12 0.75 -0.83 ~L~C~O~gP., 13-JU N-O0 MWD 13588.00 91.34 154.39 91.00 6869.45 2025.22 2165.94 8384.25 0.89 0.87 0.21 SURVEY CALCULATION AND FIELD WORKSHEET i ~l~l~I Job No. 0450-00033 Sidetrack No. 1 Page 3 of 3 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#1/9 PH1 / 9 Survey Section Name CD1-09 MWD BHI Rep, D NEWLON j~lllrrEi~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -278.40 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SS0 Target Description Target Coord, E/W Slot Coord. E/W 2517.50 Magn, Declination 25.800 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mQ 10mQ Vert. Sec, Azim. 151.99 Magn. to Map Corr. 25,800 MaP North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) (DD) (DD) (F'I') . (FT) (FT) (FT) (Per 400 F~i Drop (-) Left (-) 13-JUN-00 MWD 13682.00 90.75 153.22 -94.00 6867.74 2119.16 2081.61 8425.74 1.39 -0.63 -1.24 13-JUN-00 MWD 13772.00 90,93 154~42 90.00 6866.42 2209,10 2000.86 8465.44 1.35 0.20 1.33 13-JUN-00 MWD 13864.00 91.75 151.81 92,00 6864.27 2301.05 1918.83 8507.03 2.97 0.89 -2.84 13-JUN-00 MWD 13957.00 90.45 154,74 93.00 6862,48 2394.00 1835.79 8548,84 3,45 -1,40 3.15 13-JUN-00 MWD 14049.00 90.55 154.67 92.00 6861,68 2485.89 1752.61 8588.14 0.13 0.11 -0.08 14-JUN-00 MWD 14141,00 90.14 153.31 92.00 6861,13 2577.83 1669.94 8628,49 1,54 -0.45 -1.48 14-JUN-00 MWD 14232.00 90.17 152,15 91.00 6860,88 2668,82 1589,05 8670,18 1,28 0.03 -1.27 14-JUN-00 MWD 14325,00 89,45 150,69 93,00 6861.19 2761.81 1507,39 8714.67 1,75 -0.77 -1.57 14-JUN-00 MWD 14416.00 89.86 152.01 91.00 6861.74 2852.81 1427.53 8758.30 1.52 0,45 1.45 14-JUN-00 MWD 14507.00 90.21 151.64 i 91.00 6861,68 2943.80 1347.32 8801,27 0.56 0.38 -0,41 14-JUN-00 MWD 14600.00 89.42 150,35 93,00 6861,98 3036.79 1265,98 8846,36 1,63 -0,85 -1.39 14-JUN-00 MWD 14693.00 88.70 150.64 93.00 6863,51 3129.74 1185,05 8892,15 0,83 -0,77 0,31 14-JUN-00 MWD 14786.00 87.26 152,08 93,00 6866,79 3222.67 1103.49 8936.70 2,19 -1.55 1.55 14-JUN-O0 ,, .. 14-JUN-00 MWD 14975.00 85.92 151.92 95.00 6880.50 3411.12 938.80 9028.36 2.39 0.87 2.23 14-JUN-00 I~IWD 15070.00 86.53 152.45 95.00 6886.76 3505.91 854.96 9072.59 0.85 0.64 0,56 14-JUN-00 MWD 15161,00 88.18 152.89 91.00 6890.96 3596.81 774.20 9114.33 1.88 1.81 0.48 15-JUN-O0 MWD 15254.00 87.74 152.37 93.00 6894.27 3689.74 691.67 9157,06 0.73 -0.47 -0.56 15-JUN-O0 MWD 15295.00 88.05 152.12 41.00 6895,77 3730.71 655,41 9176,14 0.97 0.76 -0,61 15-JUN-00 MWD 15350.00 88.05 152.12 55.00 6897.64 3785.68 606.82 9201,84 0.00 0,00 0.00 Projected Data - NO SURVEY ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc. Field .................... : Colville River 15-Jun-2000 04:53:09 Page oo. oq \ 1 of 6 Well ..................... : CD1-09 API number ............... : 50-103-20399-00 Engineer ................. : Leafstedt Rig: .................... : Doyon 19 State: .................. : Alaska Spud date ................ : 07 Jun 00 Last survey date ......... : 15-Jun-00 Total accepted surveys...: 144 MD of first survey ....... : 0.00 ft MD of last survey ........ : 15350.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.92 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.99 degrees [(c)2000 Anadrill IDEAL ID6 0C 07] Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 27-May-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.80 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.80 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.80 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 JUL 05 000 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jun-2000 04:53:09 Page 2 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 115.00 0.00 0.00 115.00 3 199.76 0.53 105.76 84.76 4 288.64 2.19 133.56 88.88 5 379.06 4.83 142.14 90.42 6 467.03 6.51 142.75 7 556.17 8.09 143.90 8 647.58 9.15 144.43 9 734.04 8.91 139.64 10 824.39 9.58 130.21 87.97 89.14 91.41 86.46 90.35 TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 0.00 115.00 199.76 288.61 378.85 466.39 554.81 645.18 730.57 819.75 11 914.18 11.18 123.34 89.79 908.07 12 1003.77 12.97 113.05 89.59 995.69 13 1098.64 15.91 102.82 94.87 1087.57 14 1193.18 16.72 99.15 94.54 1178.30 15 1289.63 17.19 95.18 96.45 1270.56 16 1384.07 19.47 92.40 94.44 1360.20 17 1479.31 23.04 85.44 95.24 1448.97 18 1574.87 25.23 83.66 95.56 1536.17 19 1669.07 25.92 82.47 94.20 1621.14 20 1764.30 28.92 82.69 95.23 1705.66 21 1859.78 33.24 83.40 95.48 22 1954.34 37.28 83.35 94.56 23 2048.62 39.61 83.97 94.28 24 2145.21 43.04 84.37 96.59 25 2241.08 44.87 83.27 95.87 1787.42 1864.61 1938.45 2010.97 2079.99 26 2335.23 47.31 82.86 94.15 2145.28 27 2429.40 48.12 83.67 94.17 2208.64 28 2524.96 47.89 84.77 95.56 2272.57 29 2620.67 48.69 81.38 95.71 2336.27 30 2713.76 49.70 77.92 93.09 2397.11 [(c) 2000 Anadrill IDEAL ID6 0C 07] 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.27 -0.11 0.38 0.39 2.17 -1.39 2.00 2.44 7.56 -5.59 5.59 7.90 16.13 -12.48 10.88 16.56 27.33 -21.57 17.64 27.86 40.90 -32.68 25.66 41.55 54.26 -43.37 33.99 55.11 68.07 -53.56 44.27 69.48 82.65 -63.17 57.24 85.25 98.10 -71.88 73.75 102.99 114.89 -78.94 96.24 124.47 131.57 -83.97 122.30 148.36 147.76 -87.47 150.19 173.81 163.37 -89.39 179.82 200.81 178.82 -88.57 214.28 231.86 193.79 -84.83 253.16 267.00 208.41 -79.92 293.53 304.21 223.83 -74.26 337.01 345.10 241.55 -68.31 385.93 391.93 261.45 -62.01 440.14 444.49 283.10 -55.55 498.40 501.48 307.18 -49.08 561.84 563.98 331.92 -41.90 627.99 629.39 356.30 -33.71 695.32 696.13 381.58 -25.54 764.50 764.93 408.45 -18.39 835.16 835.36 434.13 -9.77 906.07 906.12 455.49 2.91 975.36 975.36 At DLS Srvy Tool Azim (deg/ tool qual (deg) i00f) type type 0.00 0.00 TIP - 0.00 0.00 MWD - 105.76 0.63 MWD 6-axis 124.72 1.96 MWD 6-axis 134.96 2.97 MWD 6-axis 138.91 1.91 MWD 6-axis 140.73 1.78 MWD 6-axis 141.86 1.16 MWD 6-axis 141.91 0.91 MWD 6-axis 140.43 1.83 MWD 6-axis 137.82 2.25 MWD 6-axis 134.26 3.12 MWD 6-axis 129.36 4.09 MWD 6-axis 124.47 1.39 MWD 6-axis 120.21 1.30 MWD 6-axis 116.43 2.58 MWD 6-axis 112.46 4.58 MWD 6-axis 108.53 2.41 MWD 6-axis 105.23 0.91 MWD 6-axis 102.43 3.15 MWD 6-axis 100.04 4.54 MWD 6-axis 98.02 4.27 MWD 6-axis 96.36 2.50 MWD 6-axis 94.99 3.56 MWD 6-axis 93.82 2.07 MWD 6-axis 92.78 2.61 MWD 6-axis 91.91 1.07 MWD 6-axis 91.26 0.89 MWD 6-axis 90.62 2.77 MWD 6-axis 89.83 3.02 MWD 6-axis RECEIVED JUL 05 ; 000 Alaska Oil & Gas Oons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jun-2000 04:53:09 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 31 2808.85 50.86 74.00 95.09 2457.89 473.12 20.66 1046.28 32 2907.06 51.91 69.44 98.21 2519.20 486.06 44.74 1119.11 33 3001.74 53.14 65.61 94.68 2576.81 493.28 73.48 1188.51 34 3098.40 53.99 63.59 96.66 2634.23 496.82 106.84 1258.75 35 3193.29 55.15 58.44 94.89 2689.26 495.48 144.30 1326.33 36 3288.35 57.39 54.66 95.06 2742.05 37 3324.13 57.90 54.05 35.78 2761.20 38 3495.78 58.00 54.09 171.65 2852.29 39 3685.05 61.34 55.22 189.27 2947.85 40 3875.84 59.61 54.74 190.79 3041.87 41 4065.40 59.05 54.74 189.56 3138.57 42 4257.59 58.03 53.40 192.19 3238.87 43 4449.42 59.22 54.41 191.83 3338.75 44 4637.59 60.36 54.26 188.17 3433.43 45 4828.91 61.29 55.93 191.32 3526.70 46 5019.86 61.85 55.49 190.95 3617.60 47 5210.59 61.83 55.10 190.73 3707.62 48 5400.26 62.48 57.02 189.67 3796.21 49 5593.00 61.84 57.55 192.74 3886.22 50 5781.67 60.64 57.67 188.67 3977.00 51 5969.19 60.98 56.55 187.52 4068.46 52 6160.97 60.73 56.63 191.78 4161.86 53 6352.52 60.07 56.38 191.55 4256.47 54 6541.29 60.19 56.30 188.77 4350.48 55 6732.94 60.35 55.67 191.65 4445.53 56 6922.62 60.62 55.03 189.68 4538.97 57 7113.12 60.76 54.85 190.50 4632.23 58 7303.07 60.84 54.17 189.95 4724.90 59 7494.09 60.99 55.43 191.02 4817.76 60 7685.35 61.19 54.91 191.26 4910.22 [(C)2000 Anadrill IDEAL ID6 0C 07] __ -- 1046.49 1120.00 1190.78 1263.27 1334.16 487.95 187.89 1392.25 1404.87 483.93 205.51 1416.81 1431.64 463.89 290.88 1534.62 1561.94 443.06 385.35 1667.87 1711.80 422.81 480.61 1803.82 1866.75 402.23 574.73 1936.95 2020.42 379.65 670.92 2069.70 2175.73 356.63 767.39 2202.04 2331.93 334.97 862.20 2334.15 2488.31 314.93 957.78 2471.15 2650.27 296.56 1052.38 2609.88 276.95 1148.12 .2748.12 259.64 1241.74 2887.25 245.65 1333.86 3030.64 233.02 1422.45 3170.30 2814.07 2978.31 3142.95 3311.19 3474.79 219.09 1511.35 3307.76 3636.69 203.33 1603.58 3447.58 3802.28 187.41 1695.49 3586.48 3967.05 171.29 1786.22 3722.73 4129.08 153.88 1879.32 3860.67 4293.79 134.80 1973.17 3996.46 4457.03 114.41 2068.59 4132.43 4621.26 92.82 2164.85 4267.43 4785.14 71.93 2261.08 4403.84 4950.38 52.05 2356.70 4541.27 5116.36 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 88.87 3.40 MWD 6-axis 87.71 3.78 MWD 6-axis 86.46 3.46 MWD 6-axis 85.15 1.90 MWD 6-axis 83.79 4.59 MWD 6-axis 82.31 4.06 MWD 6-axis 81.75 2.03 MWD 6-axis 79.27 0.06 MWD 6-axis 76.99 1.84 MWD 6-axis 75.08 0.93 MWD 6-axis 73.47 0.30 MWD 6-axis 72.04 0.80 MWD 6-axis 70.79 0.77 MWD 6-axis 69.73 0.61 MWD 6-axis 68.81 0.90 MWD 6-axis 68.04 0.36 MWD 6-axis 67.33 0.18 MWD 6-axis 66.73 0.96 MWD 6-axis 66.24 0.41 MWD 6-axis 65.84 0.64 MWD 6-axis 65.44 0.55 MWD 6-axis 65.06 0.14 MWD 6-axis 64.70 0.36 MWD 6-axis 64.37 0.07 MWD 6-axis 64.04 0.30 MWD 6-axis 63.72 0.33 MWD 6-axis 63.41 0.11 MWD 6-axis 63'.10 0.32 MWD 6-axis 62.82 0.58 MWD 6-axis 62.57 0.26 MWD 6-axis RECEIVED JUL 0 5 2000 Alaska 0il & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jun-2000 04:53:09 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 7875.27 61.28 56.55 62 8064.90 61.82 56.20 63 8255.09 61.01 56.94 64 8443.92 59.97 56.48 65 8634.96 60.08 56.24 66 8824.63 60.57 55.50 67 9015.89 60.88 54.99 68 9206.74 61.03 54.85 69 9397.21 59.61 53.95 70 9588.65 59.01 54.43 71 9776.94 59.31 54.21 72 9968.12 59.73 53.56 73 10160.09 59.30 56.20 74 10349.69 58.99 55.28 75 10538.90 59.02 56.57 76 10728.81 59.61 56.10 77 10878.96 59.55 55.83 78 10894.33 59.87 56.70 79 10928.09 60.25 59.51 80 10959.22 60.47 63.59 81 10990.13 60.53 66.28 82 11022.52 60.77 69.71 83 11053.87 60.76 71.81 84 11082.96 60.95 75.39 85 11117.47 61.40 79.55 86 11179.84 62.99 86.98 87 11213.42 63.14 90.54 88 11244.41 63.00 93.67 89 11273.96 62.73 97.03 90 11308.29 62.17 101.58 189.92 189.63 190.19 188.83 191.04 189.67 191.26 190.85 190.47 191.44 188.29 191.18 191.97 189.60 189.21 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 5001.62 5091.96 5182.96 5275.97 5371.42 33.90 2450.44 4678.84 5281.69 17.58 2542.77 4817.67 5447.54 1.80 2634.78 4957.05 5613.77 -13.31 2724.97 5094.41 5777.41 -29.55 2816.65 5232.19 5942.16 [(c}2000 Anadrill IDEAL ID6 0C 07] __ -- 5465.32 -47.12 2909.11 5368.59 6106.12 5558.85 -66.72 3004.21 5505.66 6271.97 5651.50 -87.25 3100.11 5642.20 6437.79 5745.81 -109.10 3196.42 5776.76 6602.12 5843.52 -131.44 3292.75 5910.26 6765.60 5940.05 -153.02 3387.04 6041.58 6926.23 6037.02 -176.25 3484.15 6174.67 7089.85 6134.42 -196.73 3579.32 6309.97 7254.46 6231.67 -214.45 3670.94 6444.49 7416.69 6329.10 -231.59 3761.81 6578.83 7578.41 189.91 6426.02 -247.68 3852.35 6714.76 7741.36 150.15 6502.04 -261.27 3924.82 6822.06 7870.49 15.37 6509.80 -262.60 3932.19 6833.10 7883.74 33.76 6526.65 -264.58 3947.64 6857.93 7912.97 31.13 6542.05 -264.78 3960.53 6881.71 7940.01 30.91 32.39 31.35 29.09 34.51 6557.27 -263.40 3971.92 6906.08 7966.81 6573.15 -260.45 3982.50 6932.25 7994.77 6588.46 -256.28 3991.51 6958.08 8021.66 6602.64 -251.16 3998.68 6982.44 8046.36 6619.28 -243.09 4005.24 7011.95 8075.23 6648.40 -223.07 4011.68 7066.68 8125.98 6663.62 -209.59 4012.32 7096.60 8152.33 6677.66 -195.73 4011.31 7124.21 8175.88 6691.14 -181.28 4008.86 7150.39 8197.50 6707.02 -162.83 4003.94 7180.41 8221.31 62.37 33.58 30.99 29.55 34.33 DLS Srvy Tool (deg/ tool qual i00f) type type 62.36 0.76 MWD 62.17 0.33 MWD 62.01 0.55 MWD 61.86 0.59 MWD 61.71 0.12 MWD 6-axis 6-axis 6-axis 6-axis 61.55 0.43 MWD 61.38 0.28 MWD 61.21 0.10 MWD 61.04 0.85 MWD 60.88 0.38 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 60.72 0.19 MWD 60.57 0.37 MWD 60.44 1.21 MWD 60.33 0.45 MWD 60.24 0.58 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 60.16 0.38 MWD 60.09 0.16 MWD 60.08 5.31 MWD 60.07 7.30 MWD 60.08 11.41 MWD 6-axis -- 6-axis 6-axis 6-axis 60.10 7.58 MWD 60.12 9.26 MWD 60.16 5.85 MWD 60.20 10.77 MWD 60.26 10.64 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 60.42 60.52 60.62 60.72 60.86 10.84 MWD 6-axis 9.46 MWD 6-axis 9.02 MWD 6-axis 10.16 MWD 6-axis 11.86 MWD 6-axis RECEIVED JUL 0,5 2000 Alaska Oil & Gas Cons. ~;ommission ANADRILL SCHLUMBERGER Survey Report 15-Jun-2000 04:53:09 Page 5 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 11339.89 62.31 105.32 92 11369.68 63.24 108.44 93 11403.67 64.29 110.57 94 11435.25 65.67 114.41 95 11465.20 67.04 116.26 96 11498.06 68.61 120.53 97 11529.37 69.41 122.72 98 11560.40 70.47 124.57 99 11592.59 71.95 126.78 100 11625.64 73.90 130.60 101 11655.07 75.90 133.90 102 11688.31 79.87 136.34 103 11719.88 81.67 137.01 104 11752.02 82.47 139.06 105 11793.41 83.59 143.07 106 11832.86 86.03 146.41 107 11998.01 90.14 150.11 108 12095.11 91.68 149.75 109 12192.00 90.72 150.48 110 12287.00 90.93 152.89 111 12383.00 91.17 152.11 112 12475.00 91.06 151.27 113 12568.00 89.42 152.88 114 12662.00 89.90 151.96 115 12755.00 88.70 153.03 116 12847.00 89.93 153.22 117 12939.00 88.90 153.24 118 13035.00 89.45 153.35 119 13128.00 88.49 154.05 120 13220.00 88.42 155.29 [(c)2000 Anadrill IDEAL ID6 0C 07] 31.60 29.79 33.99 31.58 29.95 32.86 31.31 31.03 32.19 33.05 29.43 33.24 31.57 32.14 41.39 39.45 165.15 97.10 96.89 95.00 96.00 92.00 93.00 94.00 93.00 92.00 92.00 96.00 93.00 92.00 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 6721.74 -144.32 3997.44 7207.60 6735.38 -125.63 3989.74 7232.95 6750.40 -103.15 3979.56 7261.68 6763.76 -81.07 3968.61 7288.11 6775.77 -59.06 3956.87 7312.91 6788.18 6799.40 6810.04 6820.41 6830.12 6837.79 6844.76 6849.83 6854.26 6859.29 6862.85 6868.37 6866.83 6864.80 6863.43 -33.72 3942.40 7339.66 -8.50 3927.07 7364.55 17.16 3910.92 7388.81 44.47 3893.15 7413.56 73.48 3873.40 7438.21 100.22 3854.30 7459.24 131.32 3831.28 7482.16 161.37 3808.61 7503.54 192.26 3784.94 7524.83 232.59 3752.99 7550.64 271.56 3720.91 7573.31 436.20 3580.59 7660.10 533.22 3496.57 7708.75 630.04 3412.59 7757.01 725.02 3328.97 7802.06 6861.68 821.00 3243.83 7846.38 6859.89 912.98 3162.85 7890.01 6859.50 1005.97 3080.68 7933.56 6860.05 1099.97 2997.37 7977.08 6861.19 1192.95 2914.89 8020.02 6862.29 1284.93 2832.83 8061.61 6863.23 1376.90 2750.70 8103.04 6864.61 1472.87 2664.95 8146.18 6866.28 1565.81 2581.59 8187.38 6868.76 1657.67 2498.47 8226.72 Total displ (ft) At Azim (deg) 8241 8260 8280 8298 8314 .91 .36 .64 .58 .77 60.99 61.12 61.28 61.43 61.58 DLS (deg/ iOOf) 10.48 9.82 6.41 11.85 7.28 Srvy reel type MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 8331 8346 8360 8373 8386 .46 .17 .02 .62 .32 61.76 61.93 62.11 62.29 62.49 12.95 7.01 6.56 7.96 12.52 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 8396 8406 8414 8423 8431 .18 .04 .79 .11 .91 62.67 62.89 63.09 63.30 63.57 12.78 13.93 6.07 6.79 9.99 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 8438 8455 8464 8474 8482 .02 .64 .68 .49 .58 63.83 64.95 65.60 66.25 66.89 10.46 3.35 1.63 1.24 2.55 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 8490 8500 8510 8521 8533 .48 .34 .70 .62 .31 67.54 68.16 68.78 69.41 70.03 0.85 0.92 2.47 1.10 1.73 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 8544 8557 8571 8584 8597 .85 .20 .01 .74 .75 70.64 71.25 71.88 72.50 73.11 1.35 1.12 0.58 1.28 1.35 MWD MWD MWD MWD MWD £D 6-axis 6-axis 6-axis 6-axis 6-axis JUL 0 5 2000 Alaska Oil & Gas Cons. tommission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 13314.00 89.31 154.60 122 13405.00 89.86 154.96 123 13497.00 90.55 154.20 124 13588.00 91.34 154.39 125 13682.00 90.75 153.22 94.00 91.00 92.00 91.00 94.00 126 13772.00 90.93 154.42 127 13864.00 91.75 151.81 128 13957.00 90.45 154.74 129 14049.00 90.55 154.67 130 14141.00 90.14 153.31 90.00 92.00 93.00 92.00 92.00 131 14232.00 90.17 152.15 132 14325.00 89.45 150.69 133 14416.00 89.86 152.01 134 14507.00 90.21 151.64 135 14600.00 89.42 150.35 91.00 93.00 91.00 91.00 93.00 136 14693.00 88.70 150.64 137 14786.00 87.26 152.08 138 14880.00 85.09 149.80 139 14975.00 85.92 151.92 140 15070.00 86.53 152.45 93.00 93.00 94.00 95.00 95.00 141 15161.00 88.18 152.89 142 15254.00 87.74 152.37 143 15295.00 88.05 152.12 91.00 93.00 41.00 Pro~ected to TD 144 15350.00 88.05 152.12 15-Jun-2000 04:53:09 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 6870.63 6871.28 6870.96 6869.45 6867.74 6866.42 6864.27 6862.48 6861.68 6861.13 6860.88 6861.19 6861.74 6861.68 6861.98 6863.51 6866.79 6873.06 6880.50 6886.76 1751.53 2413.33 8266.52 1842.42 2331.01 8305.29 1934.32 2247.92 8344.79 2025.23 2165.93 8384.25 2119.17 2081.60 8425.74 2209.11 2000.85 8465.44 2301.06 1918.82 8507.03 2394.01 1835.78 8548.83 2485.90 1752.60 8588.14 2577.84 1669.93 8628.49 8611.59 73.73 8626.21 74.32 8642.25 74.92 8659.50 75.52 8679.06 76.12 8698.68 76.70 8720.74 77.29 8743.72 77.88 8765.15 78.47 8788.60 79.05 2668.83 1589.04 8670.18 8814.59 79.61 2761.82 1507.38 8714.67 8844.07 80.19 2852.81 1427.52 8758.30 8873.87 80.74 2943.81 1347.30 8801.26 8903.79 81.30 3036.79 1265.97 8846.36 8936.48 81.86 6890.96 6894.27 6895.77 3129.75 1185.04 8892.15 3222.68 1103.48 8936.70 3316.45 1021.50 8982.25 3411.13 938.79 9028.36 3505.92 854.95 9072.59 3596.81 774.19 9114.33 3689.75 691.66 9157.05 3730.72 655.40 9176.13 8970.77 82.41 9004.57 82.96 9040.15 83.51 9077.04 84.06 9112.79 84.62 9147.15 85.14 9183.14 85.68 9199.51 85.91 55.00 6897.65 3785.69 606.81 9201.84 9221.83 86.23 6 of 6 DLS Srvy Tool (deg/ tool qual 100f) type type 1.20 MWD 0.72 MWD 1.12 MWD 0.89 MWD 1.39 MWD 1.35 MWD 2.97 MWD 3.45 MWD 0.13 MWD 1.54 MWD 1.28 MWD 1.75 MWD 1.52 MWD 0.56 MWD 1.63 MWD 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 0.83 MWD 6-axis 2.19 MWD 6-axis 3.34 MWD - 2.39 MWD - 0.85 MWD 6-axis 1.88 MWD 0.73 MWD 0.97 MWD 0.00 MWD 6-axis 6-axis 6-axis [ (c)2000 Anadrill IDEAL ID6 0C 07] __ -- RECEIVED 'JUL- 05 Alask~ (}il & G~s Co?,s. Anchorage SChlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 372 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-09 20290 CDRIADN/IMPULSEIGR ..~ O[(m~ 000616 1 CD1-09 20290 MD ARRAY RES 000615 I 1 CD1-09 20290 TVD ARRAY RES 000615 I 1 [~ r'rr' I\!!' ~ F~L! V ~ SlGNE----D~..J DATE: AUG 04 2000 Alaska 0il & Gas Cons. [;0mmissi0n .~ Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. /nanKyou. 7/27/00 6/29/00 Schh berger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 303 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job if Log Description Date BL Sepia Prints CD CD1-09.61 20268 CD./^DN ~ ~L~L~ 000606 1 CD1-09 PB1 20268 MD CDR 000606 I 1 CD1-09 PB1 20268 TVD CDR 000606 I 1 CD1-09 PB1 20268 MD ADN 000606 I 1 CD1-09 PB1 20268 TVD ADN 000606 I I 13 I:/' E !~,1 r' I~ SIGNE ' Please sign and return one copy of this transmitta to JUL 07 ~000 DATE: Alaska Oil & Gas Cons. Commission Anchorage Sherrie at the above address or fax t° (907) 561-8317, Thank you, MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-09 Date Dispatche 2-Jul-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 ~O, O~I Received By: ~~ D~"~!VED Please sign and return to: I% !-. ~-, ~. Anadrill LWD Division 3940 Arctic Blvd, Suite 300 JUL 0 5 Anchorage, Alaska 99503 rose@anchorage.anadrill.slb.com Alaska, 0il & Gas Cons. Commission Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS -:1-~-¥~/-i~-~¥-i;~-[i-~{i .......... -,~J~"-- ........................ -§~J~a--- ......................... 6~ationaJ ~hutdown _ Re-enter suspe'nded well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 56' feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service_ Colville River Unit 4. Location of well at surface 8. Well number 279' FNL, 2517' FWL, Sec.5, T11N, RSE, UM CD1-09 At target (7" casing point in Alpine)) 9. Permit number / approval number 1924' FNL, 416' FEL, Sec 33, T12N, RSE, UM .... per APD 200-071 iAt effective depth 10. APl number 50-103-20339-00 [At total depth 11. Field / Pool i601' FSL, 1039' FWL, Sec.34, T12N, R5E, UM ...... per APD Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 15350 feet true vertical 6897 feet0RI INAL Effective depth: measured 15350 feet true vertical 6897 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 3341' 9.625" 500 sx ASL3, 432 sx Class G 3378' 2791' Production 11860' 7" 137 sx Class G 11894' 6867' CD1-09 is as an open hole production well. It was suspended after being completed with 4-1/2" tubing. R~,~] It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for i, 2 1 2000 annular waste disposal permit application. Alaska Oil & Gas Cons. Commission 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 31, 2000 16. If proposal was verbally approved Oil ~X Gas __ Suspended Name of approver Date approved Service __ 17. I hereby certi~that the foregoing is true and correct to the best of my knowledge. S~gned~////1~ ---"Title: Drilling Team Leader Date .o. co. .ss.o. I Conditions of app Notify Commission so representative may witness Appro Plug integrity__ BOP Test__ Location clearance _ Mechanical Integrity Test __ ' Subsequent form required 10- ~ ~=, '~ ORIGINAL SIGNED BY Approved by order of the Commission r~ Taylor SeEtmount ............... commis,s,ioner Date ..... Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Casing Detail ,?UN 2 iJ -~000 Well: CD1-09 9 5/8" Surface Casin.qAJaska 0~ & Gas Cons. Commission Date: 5/31/00 'PHILLIPS Alaska, Inc. Anch0rage ~ A Subsidiary of PHILLIPS PETROLEUM'COMPANY .......... ~- DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.42 FMC Gen V Hanger 2.38 36.42 Jts 3 to 79 77 Jts 9-5/8" 36# J-55 BTC Csg 3259.51 38.80 Davis Lynch Float Collar 1.56 3298.31 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 75.89 3299.87 Davis Lynch Float Shoe 1.75 3375.76 3377.51 TD 12 1/4" Surface Hole 3388.00 RUN TOTAL 51 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - ~24 (On stop rings of Jt #1 & #2) 26,28,30,32,34,36,38,40,42,44,46,48,50,52,54,56, 58,60,62,64,66,68,70,72,74,76, and 78 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - /~ 5"-/-(' Dn Wt- / ~-1~/~' Block Wt - Supervisor'. Lutrick/eilly Phillips Alaska Drilling Cementing Details Well Name: CD1-09 Report Date: 05/31/2000 Report Number: 3 Ri~ Name: Doyon 19 AFC No.: 998C08 Field: Alpine Centralizers State type used, intervals covered and spacing Comrn~nts: Total ~ 5~1 Bow Springs i Ran 1 bow spring per jt 1st 20 its and every other jt to surface. · MUd i ' Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): COmments: 9.8/9.8 16 15 50 16 · Gels before: Gels after: Total Volume Circulated: · : 32/79/94 5/14/52 1200 bbls Wash 0 Type: Volume: Weight: Comments: GELH20 40 8.4 · Spacer 0 Type: Volume: Weight: C~mments: ARCO Spacer 50 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: comments: AS III LW 70 500 10.7 4.42 Additives: · Tail Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 432 15.8I 1.15 Additives: DiSplaCement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: comments: 9.0 bpm 9.0 bpm 165k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 10 fpm 150k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: · 255 254 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:5/31/00 Yes Yes Time:17:41 Remarks:Had full returns through out job. Approx 200 bbls 10.7 cement to surface. ! Cement Company: I Rig Contractor: Dowell I DOYON Approved By: Lutrick / Reill¥ REC iV, D JUN 2 1 2000 Alaska 0il & 6~s C0r~. ~m~,ssi0n ~ch0f~e Phillips Alaska Drilling Daily Drilling Report AFC No. I Date Rpt No Rig Accept - hrs Days Since Accept/Est: 2.58 / 3 998C08 ~05/31/2000 3 05/29/2000 10:00:00 Rig Retase - hrs: I AM Well: CD1-09 Depth (MD/TVD) 3388/2795 Prev Depth MD: 3388 Progress: 0 Contractor: DOYON Dali7 Cost $ 305195 Cum Cost $ 567136 Est Cost To Date $ 650000 i Ri~ Name: Doyon 19 Last Cs~: 9 5/8" @ 3378' Next Cs~: 7" @ 11,925' Shoe Test: n/a I Operation At 0600: Picking up drill pipe. Upcoming Operations: Test csg-drill out. i MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 3388 I N TST 05/3112000 06/01/2000 WEIGHT ROT WT SIZE i SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8pp~ 12.25 05116/2000 05/31/2000 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sqc 165 HTC N SPACE 05/3112000 03~07~2000 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 15/16 135 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2602 5 / 14 / 52 J54DR APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1200 12.0 3388 05131/2000 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 103 n/ami/30 min 115 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 3273 CD1-27 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 33 261bbl I I I 21.28/10.41 / CD1-09 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 5 26.0 I I 2 I I 20- 25 4.0 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) ~WIND DIRECTION 180° 8.5 5.5161 I 187- 267 1275 LGS SPM I TEA TEA INJECTION FLUIDS CHILL FACTOR °F 30.06 4.4% III .547 Water Base Muds 705 PIT VOL GPM 2 JETS JETS Other ARCO PERSONNEL 2 485 III 101121121181 I IIIII ~10 Other 300 DAILY MUD SPS 1 BIT COST BIT COST Fresh Water CONTRACTOR 29 $6227 III 11910 30 PERSONNEL Diesel 20 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $22713 III 314IWTIA III 1165 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 MI 9.8 I I I EI I I ER lTD I I I 13848 PERSONNEL TOTAL 54 TIME: I E:ND :I :HOURs ::1 OPSCODE I : HOLESECT IPHASEOPS I OPERATIONS FROM 0000- 0000 12:00 AM 01:30 AM 1.50 TRIP_OUT SURF Making Hole Cont' POH. Pump out fl 1700' to 1510'. No problems. 01:30 AM 02:00 AM 0.50 TRIP_IN SURF Making Hole RIH T/3388'. 02:00 AM 03:00 AM 1.00 ClRC SURF Making Hole Circ hi vis sweep. Monitor well. Pump slug 03:00 AM 05:00 AM 2.00 TRIP_OUT SURF Making Hole POH. No problems 05:00 AM 07:00 AM 2.00 BHA SURF Making Hole LD BHA for inspection. Clear floor. 07:00 AM 07:30 AM 0.50 RIGS SURF Making Hole Tighten bolts on man rider sheave in derrick as per Dreco derrick inspection.. 07:30 AM 08:30 AM 1.00 PREP SURF Casing and RU to run 9 5/8" csg. Cementing 08:30 AM 12:30 PM 4.00 CASG SURF Casing and PJSM. Rill wi 9 5/8" csg to 3388'. No problems. Cementing 12:30 PM 01:00 PM 0.50 CASG SURF Casing and LD Franks fill up tool. Blow down. RU cement head. Cementing 01:00 PM 03:30 PM 2.50 CEMENT SURF Casing and Circ and condition mud at 10 bpm. No losses. Cementing Daily Drilling Report: CD1-09 05/31/2000 RECEIVED Page 1 03:30 PM 06:00 PM 2.50 CEMENT 06:00 PM 07:00 PM 1.00 CEMENT 07:00 PM 07:30 PM 0.50 OTHER 07:30 PM 08:30 PM 1.00 NU_ND 08:30 PM 09:00 PM 0.50 NU_ND 09:00 PM 10:00 PM 1.00 NU_ND 10:00 PM 10:30 PM 0.50 BOPE 10:30 PM 12:00 AM 1.50 BOPE 24.00 SURF SURF SURF SURF SURF SURF SURF SURF Casing and Cementing Casing and Cementing Casing and Cementing Making Hole Making Hole Making Hole Making Hole Making Hole PJSM. Dowell tested lines to 3500 psi. Pumped 40 bbls viscosified brine (6 sx nut plug) 50 bbls 10.5 ARCO spacer 393 bbls (500 sx) 10.7 lead cement 88.5 bbls (432 sx) 15.8 tail cement top plug 20 bbls H20 and 235 bbls mud. Displaced wi rig pumps. Bumped plug. Floats. OK. LD cement head and landing jr. Wash out diverter w/wash tool. ND diverter. NU well head and test to 5000 psi. OK NU BOPE. Install test plug. Fill and check for leaks. Test BOPE to 250 - 3000 psi.. Witnessing of BOP test waived by AOGCC rep John Spalding Supervisor: LUTRICK! REILLY Daily Drilling Report: CD1-09 05/31/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-09 Date: 6/1/00 Reason(s) for test: Supervisor: Donald Lutrick [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5~8" 36# J-55 BTC CSG Casing Setting Depth: 3,378' TMD 2,791' TVD Mud Weight: 9.6 ppg Hole Depth: 3,408' TMD 2,806' TVD Length of Open Hole: 30' 2418 EMW = Press 940 psi 0.052 xTVD + Mud Weight -- + 9.6 ppg 0.052 x 2,791' EMW = 15.99 ppg Pump output = .101 BPS Fluid Pumped = 1.2 BBL BLED BACK = .8 BBLS 2,800 psi 2,700 psi 2,500 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,g00 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 40O psi 300 psi 200 psi 100 psi 0 psi · =e--CASING TEST .... iud... LOT SHUT IN TIME -~.,-- CASING TEST SHUT IN TIME ~ TIME LINE Ostk 2stk 4stk 6stk 8stk 1~s~k12stk14s~k16stk18stk2~stk22stk24stk26stk28stk3~s~k32stk34stk36stk38stk4~s~(42stk44stk46~s~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .................. t'"~'~i~'--,', .... '~'~'~7'"! .................. Jr .............. ~ ................. -i .................. [ j_s.!_k_?_ ....... Ls__O__e_.si._4 .................. [..~_~!K~. ...... ..~.o..e.s..~ .... j [ 6 stks 530 psi ................................ t .................. ! i · i , 8stks , 680ps, , .................. {" .............. ~ .................. [ 10 stks 840 psi ! ! ! ! ! .................. F .............. t ................. -I i i i ! i .................. ~ .............. T ................. I .................. t .............. :, ................. I .................. t .............. ',, ................. I ! .................. [ .............. i .................. ! ! ! .................. Jr ................................. ! ! ! ! ! ! ! , ! .................. ~ .............. T ................. I .................. Jr .............. Jr ................. 4 ! ! , ! ! .................. Jr ................................ -I ! ! ! ! ! .................. Jr .............. * ................. -I ! ! .................. [ .............. ~ ................. 4 ! ! ! SHUT IN TIME.J SHUT IN PRESSURE t .............. T .................. .... .o..9...m. in.._.[ .............. i .... ?--4-°--~-s-i--4 .... .~..g___m_Ln_____[ .............. i .... -8-8-°--P-S- i---4 .... .2...9_.m. Ln....[ .............. i .... .~Z.o_m...4 .... ~-9...m.L._._.[ .............. i .... _~..~.o_m_._4 .... .4.-9.mLn.._.[ .............. i .... .~.?.o..m_.4 5 0 rain ~ ~ 870 nsi ...... '- ........... Jr .............. ~ .......... c~ ..... -! .... ~-9.._m. Ln.....[ .............. i .... _~Z.o_m...4 .... Z-9._m.L"..._.[ .............. i .... .~.s..m...4 80min ~ i 865nsi ...... ' ........... Jr .............. Jr .......... c; ..... .... ?_..O...m.i.____[ .............. i .... -8-?-S--P-s-i---4 10.0 min J .......................... .................. ~. ..... i 865 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE i i · i , Ostks , 70ps, , .................. Jr .............. Jr ..................... I i i · i , 2 stks , 180 psi , .................. ~ .............. ~ ..................... i i 4 stks 400 psi .................. f .............. 6 stks ! ..................... 670 ! = ; psi .................. t .............. t ..................... i i · i , 8stks , 870 DS, .................. Jr .............. ~ ........... -': ........ I ~ 10 stks 1,030 psi i 12 stks 1,170 psi ................. ~' .............. - ..................... i 14 stks 1,300 psi ................. t"i'~';ii,'~' ...... .7,-,ii~b"~,'~i .... I I I · I ., 22stks : 1,990ps, , .................. [...~.4..~t..k.s._ ...... .~:~Z.o.£~! .... i [ 26 stks 2,260 psi ::::::::::::::::::::::::::::::::::::::::::::::::::::: [ 29stks 2,510 psi i I I I I I I ................. Jr .............. t ..................... I I I i i i I i i i i SHUTINTIME J , , ................. Jr .............. ~ ..................... I 0.0min J i 2,510psi ................. ~ .............. ~ ..................... I 5.0min : , 2,490 psi ............ · - .... Jr .............. Jr ................ .- .... I 10.0m~n t ~ 2,490pm ' 15.0min ~ ~ 2,490 Esi 20.0min I ~ 2,480r~si ................. f ........................... c ...... _..2__s_.9__m_Ln_..[ .............. : .... .2_,_4~.0..~.s.[ .... j ,..~2.9..~i.,...[ .............. i .... ~:.~z~. .... ................. Jr .............. Jr ..................... ! i i i i i i i I i ................. ~ .............. ~ ..................... I I J ................. i .............. i ..................... I i i J ................. Jr .............. t ..................... I i i I I I I ................. Jr .............. ~ ..................... ! i i i i i i .................. Jr ..............? ..................... I I I i i i ................. ~ .............. ~ ..................... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-09 Date: 6/10/00 Supervisor: S. D. Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5~8" 36# J-55 BTC CSG X Casing Setting Depth: 3,378' TMD 2,791' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 11,170' TMD 6,648' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 7,792' EMW = Leak-off Press· + Mud Weight 0.052 x TVD = 591 psi + 9.6 ppg 0.052 x 2,791' EMW for open hole section = 13.7 ppg Pump output = ****** Fluid Pumped = 9.0 bbl ..... Used cement unit Fluid Bled Back = n/a 900 psi 600 ps~ f~ ,-e-- LEAK-OFF TEST j ~ ~ ~ ,-e-o --a~CASING TEST ~ .500 psi ~ ~ i "":~ LOTSHUT IN TIME .. :i. ~ CASING IESI SH~I IN lIME ~. 400 ~$i :~ I TIME LINE 300 psi - 200 psi 0 psi ~. 0 I 2 3 4 5 6 7 8 9 10 11 12 t3 14 15 16 17 18 19 20 BARRELS LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR LOT STROKES PRESSURE ................ ... ................ ................... .O...O...b..b!s. ........ .o..R.s.i' ..... ................... .O.:.S.._b..b!.s. ....... .2..~Z..p.s.! .... ................... ~..O...b..b!s. ....... &8..~._p..s.! .... ................... &p...b..b!s._ ...... ~!.~.£.s.! .... ................... &P...b..b!s. ....... ~Z?...P.S.! .... ................... ?.:.S_.b..b!s' ....... ?..0..~...p.s.] .... ~. 3.0 bbls , 464 psi ................... .3=s_..b..b!s. ...... .4..e..~...p.s.L..j 4.0 bbls 510 ................... ?.:.S...b..~!s' ...... ~.~..s...p.s.!.._j .................. _5.:_O__b_bJ.s. ...... .5._5..5___p_s_i .... 5,5 bbls b....5..9..1.~.s.! .... 6.5 bbls ....5..3..5.~.s.! .... ................... Z:.S...bl.b!s. ...... .s..2..o.p..s.! .... .................. .s.:.O_b..b!.s. ...... .s_2_o..p..s.! .... ................... .8_:.s._.b..b.~.s._.,....s..2..o..,..s.!___i , ' FOR CSG TEST STROKES PRESSURE ZZZZZZZE. i. 3ZZZ i . !Zii I I , ! ! ................ i. ............... .4 ............... i , i i i ................ i. ............... j ................. Ii , i ! ! i , ................................. 1 ................. ................................. I ................. ! ! ! , , ! , ................. r ............... ~ ................. -1 I SHUT IN TIME SHUT IN PRESSURE '-"~iT~i~ ......................... '~%T .... 1 .... ii'EBi'~ ..................................... i 2.0 min -' SHUT IN TIME L SHUT IN PRESSURE 3.0 min ........... T .... , ............... T ............. ,"'"' .................................................. 0,0 m~n I .,, 520 psi .....4:.O__.m._i.n. .................................... 4 ....1....O...m.!_n...~ ............... j....2..6..8. ~_s_!.. _ 5.0 min .... .4.:9...m.!p...i ............... l_.&6.~_D.__s.! .... ,_..~:9..~!.rL.,L ............... l...&s..~.u..~l .... ,_...6.:9...m. Ln_. ,.L ............... j...&6_.8_p..s.L.j 7.0min i i 268~si i 8.0min : i 263~si ' , ................ ~ ............... ~ ......... ., ........ 9.0min , ~ 263~si 3. ;E LE?ZZZZZ]ZA i . 3E:; 6.0 min 7.0 min ................ I .................. , .._..8:.o...m.j_n____,,' ............... j .................. 9.0 min I ' ! ................ ~ ............... ~ .................. L _ _1.o. :.O__m_ i._n_. L· ............... J ................. 15.0 min · i i ~20.0 mlnl l ............... i. ................................. j 25.0 min ,..3..°.:.°...m. Ln...: ................ l .................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CD1 -09 .... Colville River Field Production Well Completion - As built 16" Conductor to 114' Completed on 06/17/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1756' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines Cdl-09PH - cement kick off plug at 10879' MI 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3378' MD / 2791' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve (sheared out) Baker S3 Packer at +/- 11190' WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later P~.(;ker Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Completion Tubing 4-1/2", Camco 4-1/2", Camco 4-1/2", Camco 4-1/2", Hanger 12.6#/ft, IBT-Mod Tubing BAL-O SSSV Nipple 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 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 (+/- 62 deg) No centralizers run on tubing. MD 33' 1756' 4569' 8289' 11030' 11135' 11190' 112665' 11276' Calculated TOC @ +/ 11170' MD Well TD at 15350' MD / 6897' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11894' MD / 6867' TVD @ 87 deg Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 19,2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-09 Dear Sirs: Phillips Alaska, Inc. hereby requests that CD1-09 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-09 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC. CD1-09 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-09PH API number ............... : 50-103-20339-70 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska 5-Jun-2000 14:48:22 Page ORIGINAL Spud 'date ................ : 29 May 00 Last survey date ......... : 05-Jun-00 Total accepted surveys...: 84 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11934.00 ft 1 of 4 Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.92 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 55.46 degrees Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 27-May-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.80 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.80 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.80 degrees (Total az corr= magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadriil IDEAL ID6 0C 07] -- _ °'ANADRILL SCHLUMBERGER Survey Report 5-Jun-2000 14:48:22 Page 2 of 4 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 199.76 0.53 105.76 4 288.64 2.19 133.56 5 .379.06 4.83 142.14 6 467.03 6.51 142.75 7 556.17 8.09 143.90 8 647.58 9.15 144.43 9 734.04 8.91 139.64 10 824.39 9.58 130.21 11 914.18 11.18 123.34 12 1003.77 12.97 113.05 13 1098.64 15.91 102.82 14 1193.18 16.72 99.15 15 1289.63 17.19 95.18 16 1384.07 19.47 92.40 17 1479.31 23.04 85.44 18 1574.87 25.23 83.66 19 1669.07 25.92 82.47 20 1764.30 28.92 82.69 21 1859.78 33.24 83.40 22 1954.34 37.28 83.35 23 2048.62 39.61 83.97 24 2145.21 43.04 84.37 25 2241.08 44.87 83.27 26 2335.23 47.31 82.86 27 2429.40 48.12 83.67 28 2524.96 47.89 84.77 29 2620.67 48.69 81.38 30 2713.76 49.70 77.92 Course length (ft) 0.00 115.00 84.76 88.88 90.42 87.97 89.14 91.41 86.46 90.35 89.79 89.59 94.87 94.54 96.45 94.44 95.24 95.56 94.20 95.23 95.48 94.56 94.28 96.59 95.87 94.15 94.17 95.56 95.71 93.09 TVD depth (ft) 0.00 115.00 199.76 288.61 378.85 466.39 554.81 645.18 730.57 819.75 908.07 995.69 1087.57 1178.30 1270.56 1360.20 1448.97 1536.17 1621.14 1705.66 1787.42 1864.61 1938.45 2010.97 2079.99 2145.28 2208.64 2272.57 2336.27 2397.11 Vertical section (ft) 0.00 0.00 0.25 0.86 1.44 1.89 2.30 2.61 3.41 6.10 11.34 20.00 34.52 53.13 74.13 97.44 126.29 160.44 196.48 235.50 279.17 327.40 379.05 434.98 493.54 553.64 615.26 677.52 740.82 805.08 Displ +N/S- (ft) 0.00 0.00 -O.ii -1.39 -5.59 Displ +E/W- (ft) 0.00 0.00 0.38 2.00 5.59 -12.48 -21.57 -32.68 -43.37 -53.56 10 17 25 33 44 .88 .64 .66 .99 .27 -63.17 -71.88 -78.94 -83.97 -87.47 57 73 96 122 150 .24 .75 .24 .30 .19 -89.39 -88.57 -84.83 -79.92 -74.26 179 214 253 293 337 .82 .28 .16 .53 .01 -68.31 -62.01 -55.55 -49.08 -41.90 385 440 498 561 627 .93 .14 .40 .84 .99 -33.71 -25.54 -18.39 -9.77 2.91 695.32 764.50 835.16 906.07 975.36 Total displ (ft) 0.00 0.00 0.39 2.44 7.90 At DLS Srvy Azim (deg/ tool (deg) 100f) type 0.00 0.00 TIP 0.00 0.00 MWD 105.76 0.63 MWD 124.72 1.96 MWD 134.96 2.97 MWD 16.56 27.86 41.55 55.11 69.48 138.91 1.91 MWD 140.73 1.78 MWD 141.86 1.16 MWD 141.91 0.91 MWD 140.43 1.83 MWD 85.25 '102.99 124.47 148.36 173.81 137.82 2.25 MWD 134.26 3.12 MWD 129.36 4.09 MWD 124.47 1.39 MWD 120.21 1.30 MWD 200.81 231.86 267.00 304.21 345.10 116.43 2.58 MWD 112.46 4.58 MWD 108.53 2.41 MWD 105.23 0.91 MWD 102.43 3.15 MWD 391.93 444.49 501.48 563.98 629.39 100.04 4.54 MWD 98.02 4.27 MWD 96.36 2.50 MWD 94.99 3.56 MWD 93.82 2.07 MWD 696.13 764.93 835.36 906.12 975.36 92.78 2.61 91.91 1.07 91.26 0.89 90.62 2.77 89.83 3.02 · . 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 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 5-Jun-2000 14:48:22 Page 3 of 4 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) {deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) i00f) type type 31 2808.85 50.86 74.00 95.09 2457.89 32 2907.06 51.91 69.44 98.21 2519.20 33 3001.74 53.14 65.61 94.68 2576.81 34 3098.40 53.99 63.59 96.66 2634.23 35 3193.29 55.15 58.44 94.89 2689.26 36 3288.35 57.39 54.66 95.06 2742.05 37 3324.13 57.90 54.05 35.78 2761.20 38 3495.78 58.00 54.09 171.65 2852.29 39 3685.05 61.34 55.22 189.27 2947.85 40 3875.84 59.61 54.74 190.79 3041.87 41 4065.40 59.05 54.74 189.56 3138.57 42 4257.59 58.03 53.40 192.19 3238.87 43 4449.42 59.22 54.41 191.83 3338.75 44 4637.59 60.36 54.26 188.17 3433.43 45 4828.91 61.29 55.93 191.32 3526.70 190.95 190.73 189.67 192.74 188.67 46 5019.86 61.85 55.49 47 5210.59 61.83 55.10 48 5400.26 62.48 57.02 49 5593.00 61.84 57.55 50 5781.67 60.64 57.67 3617.60 3707.62 3796.21 3886.22 3977.00 51 5969.19 60.98 56.55 187.52 4068.46 52 6160.97 60.73 56.63 191.78 4161.86 53 6352.52 60.07 56.38 191.55 4256.47 54 6541.29 60.19 56.30 188.77 4350.48 55 6732.94 60.35 55.67 191.65 4445.53 56 6922.62 60.62 55.03 57 7113.12 60.76 54.85 58 7303.07 60.84 54.17 59 7494.09 60.99 55.43 60 7685.35 61.19 54.91 189.68 190.50 189.95 191.02 191.26 4538.97 4632.23 4724.90 4817.76 4910.22 873.57 20.66 1046.28 1046.49 947.21 44.74 1119.11 1120.00 1020.67 73.48 1188.51 1190.78 1097.44 106.84 1258.75 1263.27 1174.36 144.30 1326.33 1334.16 88.87 3.40 MWD 87.71 3.78 MWD 86.46 3.46 MWD 85.15 1.90 MWD 83.79 4.59 MWD 1253.37 187.89 1392.25 1404.87 82.31 4.06 1283.59 205.51 1416.81 1431.64 81.75 2.03 1429.04 290.88 1534.62 1561.94 79.27 0.06 1592.36 385.35 1667.87 1711.80 76.99 1.84 1758.36 480.61 1803.82 1866.75 75.08 0.93 1921.39 574.73 1936.95 2020.42 2085.27 670.92 2069.70 2175.73 2248.99 767.39 2202.04 2331.93 2411.57 862.20 2334.15 2488.31 2578.60 957.78 2471.15 2650.27 2746.52 1052.38 2609.88 2814.07 2914.67 1148.12 2748.12 2978.31 3082.36 1241.74 2887.25 3142.95 3252.70 1333.86 3030.64 3311.19 3417.98 1422.45 3170.30 3474.79 3581.61 1511.35 3307.76 3636.69 3749.08 1603.58 3447.58 3802.28 3915.60 1695.49 3586.48 3967.05 4079.28 1786.22 3722.73 4129.08 4245.69 1879.32 3860.67 4293.79 4410.76 1973.17 3996.46 4457.03 4576.86 2068.59 4132.43 4621.26 4742.65 2164.85 4267.43 4785.14 4909.56 2261.08 4403.84 4950.38 5076.99 2356.70 4541.27 5116.36 MWD MWD MWD MWD MWD 73.47 0.30 MW© 72.04 0.80 MWD 70.79 0.77 MWD 69.73 0.61 MWD 68.81 0.90 MWD 68.04 0.36 MWD 67.33 0.18 MWD 66.73 0.96 MWD 66.24 0.41 MWD 65.84 0.64 MWD 65.44 0.55 MWD 65.06 0.14 MWD 64.70 0.36 MWD 64.37 0.07 MWD 64.04 0.30 MWD 63.72 0.33 63.41 0.11 63.10 0.32 62.82 0.58 62.57 0.26 MWD MWD MWD MWD MWD 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 5-Jun-2000 17:41:34 Page 4 of 4 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 61 7875.27 61.28 56.55 189.92 5001.62 62 8064.90 61.82 56.20 189.63 5091.96 63 8255.09 61.01 56.94 190.19 5182.96 64 8443.92 59.97 56.48 188.83 5275.97 65 8634.96 60.08 56.24 191.04 5371.42 66 8824.63 60.57 55.50 189.67 5465.32 67 9015.89 60.88 54.99 191.26 5558.85 68 9206.74 61.03 54.85 190.85 5651.50 69 9397.21 59.61 53.95 190.47 5745.81 70 9588.65 59.01 54.43 191.44 5843.52 71 9776.94 59.31 54.21 72 9968.12 59.73 53.56 73 10160.09 59.30 56.20 74 10349.69 58.99 55.28 75 10538.90 59.02 56.57 76 10728.81 59.61 56.10 77 10878.96 59.55 55.83 78 10919.82 59.66 55.54 79 11110.72 60.02 55.14 80 11302.20 60.67 55.41 81 11491.93 60.83 55.11 82 11679.91 61.54 55.89 83 11856.25 61.60 56.08 188.29 191.18 191.97 189.60 189.21 189.91 150.15 40.86 190.90 191.48 189.73 187.98 176.34 5940.05 6037.02 6134.42 6231.67 6329.10 Last Survey Pro~ected to TD 84 11934.00 61.60 56.08 5243.46 2450.44 4678.84 5281.69 5410.17 2542.77 4817.67 5447.54 5577.14 2634.78 4957.05 5613.77 5741.43 2724.97 5094.41 5777.41 5906.90 2816.65 5232.19 5942.16 6071.69 2909.11 5368.59 6106.12 6238.52 3004.21 5505.66 6271.97 6405.36 3100.11 5642.20 6437.79 6570.80 3196.42 5776.76 6602.12 6735.39 3292.75 5910.26 6765.60 6897.02 3387.04 6041.58 6926.23 7061.72 3484.15 6174.67 7089.85 7227.12 3579.32 6309.97 7254.46 7389.88 3670.94 6444.49 7416.69 7552.06 3761.81 6578.83 7578.41 6426.02 7715.36 3852.35 6714.76 7741.36 6502.04 7844.84 3924.82 6822.06 7870.49 6522.72 7880.08 3944.69 6851.17 7905.64 6618.63 8045.14 4038.56 6986.93 8070.14 6713.37 8211.54 4133.34 7123.70 8235.99 6806.08 8377.07 4227.68 7259.73 8401.00 6896.68 8541.77 4320.96 7395.46 8565.25 6980.63 8696.84 4407.71 7524.00 8720.01 77.75 7017.61 8765.23 4445.88 7580.76 At DLS Azim (deg/ (deg) lOOf) Srvy tool type 62.36 0.76 MWD 62.17 0.33 MWD 62.01 0.55 MWD 61.86 0.59 MWD 61.71 0.12 MWD 61.55 0.43 MWD 61.38 0.28 MWD 61.21 0.10 MWD 61.04 0.85 MWD 60.88 0.38 MWD 60.72 0.19 MWD 60.57 0.37 MWD 60.44 1.21 MWD 60.33 0.45 MWD 60.24 0.58 MWD 60.16 0.38 MWD 60.09 0.16 MWD 60.07 0.67 MWD 59.97 0.26 MWD 59.88 0.36 MWD 59.79 0.16 MWD 59.70 0.52 MWD 59.64 0.10 MWD 8788.27 59.61 0.00 MWD 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 [(c)2000 Anadrill IDEAL ID6 0C 07] -- -- MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-09PH ,~C)o· ~ t Date Dispatche 14-Jun-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 Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose~anchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL AND GAS CONSERVATION CO~IPllSSION Doug Chester Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Colville River Unit CD 1-09 ARCO Alaska, Inc. Permit No' 200-071 SurLoc: 279'FNL, 2517'FWL, Sec. 05, TllN, R5E, UM Btmhole Loc. 601'FSL, 1039'FWL, Sec. 34, T12N, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to redrill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one year. 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. Daniel T. Seamount. Commissioner BY ORDER OF THE COMMISSION DATED this //c~' day of May, 2000 dlf/Enclosures cc~ Department of Fish & Game. Habitat Section w/o encl. Department of Envir0nn!cntal Consen'ati0n w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone .>, Name of_Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ~Alaska, Inc~/./~ DF 56' feet Colville River Field 3. ' Address 6. Property Designation ,,,j~,~) Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559, 25557-8~:~:~6 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 279' FNL, 2517' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1924' FNL, 416' FEL, Sec. 33, T12N, R5E, UM CD1-09 #U-630610 At total depth~L"'~ ,r'~ 9. Approximate spud date Amount 601' FSL, 1039' FWL, Sec. 34, T12N,~4~,""E)"~IV~ 05/24/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1 - 13 15,045 MD Crosses T11N to feet 38.8' @ 525' Feet 2560 6,849' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 91 o Maximum surface 2419 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Len~lth MD TVD MD TVD linclude sta~]e data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 3363' 37' 37' 3400' 2810' 535 Sx Arcticset III l & 432 Sx Class G 8.5" 7" 26# L-80 BTC-M 11888' 37' 37' 11925' 6866' 122 sx Class G N/A 4.5" 12.6# L-80 IBT-M 11187' 37' 37' 11224' 6663' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: t~ueeaSv~rd~cdal ffee:tt Plugs (measured) 0 RIG IN A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length .~Lze ~ ._ .~ Cemented Measured depth True Vertical depth Structural ~ ~" "~"~ 1 V ~ Conductor ~ ~ ~ %.,,~ .~, ~ ......... Surface Intermediate Production ?,AY 11 200 Liner Perforation depth: measured ~'~ ~ ~;~$ C0~. true vertical /'~i~,.~ ~ ~ ~ '~ '" 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. Ih ereby c~rtify/~ that the~//?~_~fo regoi ng is true and co rrect to the best of my knowl edge Signed ,,,~I~/L,/, _ ,. . Title Drilling Team Leader Date m~r~oIAPl number C°mmissi°n Use Only I Per ~7/ 50- /'0~'--~0~ ~ Approvaldate~'.~/~ ~)~) See cover letter for " Other requirements Conditions of approvalHydrogen sulfide measures Samples required Yes/"~"~~ ,..-~ ~, Yes ~ir ectional survey Mud log require(~ Yes ~) required No Required working pressure for BOPE 2M 3M (5M~ 10U 15M Other: or. er o, Approved by ; ~vi~r. S~O~t Commissioner the commission Date~l~'~ Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine · CD1-09PH (Pilot Hole) & CD1-09 Procedure . . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 1~,, hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 600 ft cement plug #1 from TD to +/- 11219'. Set 500 ft cement plug #2 from +/- 11219' to +/- 10719'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 10879' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Y2, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-13 will be the closest well to CD1-09 (38.8' at 525' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 35.8' at 588' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular PumDin_~ Operations: Incidental fluids developed from drilling operations on well CD1-09 will be injected into the annulus of another permitted well on the CD1 pad.. The CD1-09 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-09 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2810') + 1,500 psi = 3,253 psi Pore Pressure = 1,271 psi .,,IAY '11 200( Therefore Differential = 3253 - 1271 = 1982 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-09 & CD1-09 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1~,, Section - 6 1/8" point- 12 ~,~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and Dual-FIo starch will be used for viscosity and fluid loss control respectively. ~ Colville River Field CD1-09PH Pilot Hole - Prior to Sidetracking Updated 05/08/00 RKB - GL = 3T ~ Wellhead ~ ~ 16" Conductor to 1141 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3400 ' MD / 2810' TVD cemented to surface 9.8 ppg drilling mud in hole ... v Cement Plug Top of cement plug dressed off to 108791 MD / 64931 TVD (+/- 60.5 deg inc.) ~----, R_____- " P'}'~:g. #~ . ..:...:...:..L...:...:..:........"...:..:. -, /\. Top of Cement Plug #1 at +1.. 112191 . . , ':. . r Top Alpine Reservoir at ;: : .':. '. .! 11582' MD /6839' TV~ . Þ'lr'~ 111 , 6iO It Pilot Hole TD at 118191 MD / 69561 L_....;.. :...:; ..:..:.".... ---~~- TVD (+/- 60.5 deg inc.) MAY 11 2000. Oii& it Colville River Field CD1-09 Production Well Completion Plan 16" Conductor to 114' Updated 05/08/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10) at 1700' TVD = 1757' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3400' MD / 2810' TVD cemented to surface WRDP-2 SSSV (2.125"1 D) w/ DB-6 No-Go Lock (3.812" OD) - to be installed later Cameo KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch Packer Fluid mix~ 9.6 DDg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Tubing SUDended with diesel to lowest GLM Cameo KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1757' 17001 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4585' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 8253' 52001 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 11123' 66141 4-1/2" tubing joints (2) HES "X" (3.813" ID) 11192' 6648' 4-1/2" tubing joint (1) Baker S3 Packer 11224' 6663' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 11289' 6692' 4-1/2" 10' pup joint WEG (+/- 62 deg) 113001 6697' Cameo KBG-2 GLM (3.909" 10) & 1" Cameo DCK-2 Shear Valve Pinned for casing side shear @ +1- 2000 psi set 2 joints above the X landing nipple TOC @ +1- 11225' MD (500' MD above top Alpine) --------------------------------------------Y;¡ëlï-ff)-ã¡-----1 150451MDI ¡ - -----------------------------------------------~~-~~-~~~----j Top Alpine at 11725' MD / 6840' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11925' MD / 6866' TVD @ 87 deg il. Colville River Field CD1-09 Production Well Completion Plan Formation Isolation Contingency Options Updated 05/08/00 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" I D) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" s/s control line @ 1700' TVD = 1757' MD R. . ~ ~\/t~: M/\y ì 1 2000 /\ts3h~fi; 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3400' MD / 2810' TVD cemented to surface (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe Cameo KBG-2 GLM (3.909" 10) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope (B) 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 Cameo KBG-2 GLM (3.909" 10) at 5200' TVD for E Dummy with 1" BK-2 Latch (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +1-11225' MD (500' MD above top Alpine) Cameo KBG-2 GLM (3.909" 10) & 1" Cameo DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple nn11""" Baker S3 Packer set at +1- 11224' -':""""",,------- Well TD at 150451 MD I 68491 TVD .."..".~ ._,.,-..<.,-..,-~-,-,-,-..., _1-,. ----------~-----~ . --------~------~: .......---.------ 7" 26 ppf L-80 BTC Mod Production Casing @ 11925' MD / 6866' TVD @ 87 deg CD1-09 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) 16 114 / 114 10.9 52 53 9 5/8 3400 / 2810 14.5 1271 1838 7" 11925 / 6866 16.0 3106 2419 N/A 15045 / 6849 16.0 3098 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 -- 53 psi OR ASP = FPP - (0.1 x D) - 1271 - (0.1 x 2810') = 990 psi 2. Drilling below surface casing (9 5/8") . ASP = ASP = [(FG x 0.052) - 0.1} D [(14.5 x 0.052) - 0.1] x 2810 = 1838 psi OR FPP - (0.1 x D) 3106- (0.1 x 6866') = 2419 psi Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) -- 3106 - (0.1 x 6866') = 2419 psi :f Alpine CD1-09 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 J: I- a.. ~ -3500 c ~ PO PR . I , \ '- 1\ ~ ~'-1Io... , \ '-~ ~ '-..... , " - '\. 'Iti.. '\. 'Iti.. ~ " II " fA. ~c -u RE - -,_ .- ~ II ,... ,... , I ~L // \ J( " \ /v \ ~E , SSlR MW[ VI ElmkT [L ./; , ., /' ~ ~ \ JL 1 111l1li -500 -1500 -2500 -4500 -5500 -6500 -7500 8 9 10 11 12 13 EQUIVALENT MUD WEIGHT 14 15 16 17 MAY '11 200~' Alpine, CD1-09PH & CD1-09 Well Cementing Requirements 9 5/8" Surface Casing run to 3400 MD ! 2810' TVD. Cement from 3400' MD to 2400' (1000' of fill) with Class G + Adds @ 15.8 PPG, and from 2400' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2400'-1595') X 0.3132 ft3/ft X 1.5 (50% excess) = 378.2 ft3 below permafrost 1595' X 0.3132 ft3/ft X 4 (300% excess) = 1998.2 ft3 above permafrost Total volume = 378.2 + 1998.2 = 2376.4 ft3 => 535 Sx @ 4.44 ft3/sk System: Tail slurry: 535 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 ant!foamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 1000' X 0.3132~ ft3/ft X 1.5 J50% excess) = 469.8 ft3 annular volume 80' X 0.4341 ft°/ft = 34.7 ft°shoe joint volume Total volume = 469.8 + 34.7 = 504.5 ft3 => 432 Sx @ 1.17 ft3/sk System: 432 Sx Class G + 0.2% D046 ant!foamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 11925' MD ! 6866' TVD Cement from 11925' MD to +/- 11225' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (11925' - 1122~5') X 0.126~8 ft3/ft X 1.4 (40% excess) = 124.3 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft° shoe joint volume Total volume = 124.3 + 17.2 = 141.5 ft3 => 122 Sx @ 1.16 ft3/sk System: 122 Sx Class G + 0.2% D046 ant!foamer, 0.27% D065 dispersant, 0.20% D800 retarder, 0.20% D046 anti-foam and 0.25% D156 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk CD1-09PH Cement Plug #1: 11819' MD to 11219' MD = 600'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 600' X 0.3941 ft3/ft X 1.15 (15% excess) = 271.9 ft3 => 235 Sx @ 1.16 ft3/sk CD1-09PH Cement Plug #2: 11219' MD to 10719' MD = 500'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.0 ft3 => 160 sx @ 1.00 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement Creoted by bmlchoel For: B Robert,son Dote plotted: 2-May-2000 Plot Refsrenos is CD1-9 V~ion ~6. ~ordlnates ore in fe~ r~erence slot ~9. True Verti~l Depths are reference RKB {~yon ~19). PHILLIPS Alaska, Inc. Structure: CD#I Well: 9 Field : Alpine Field Location: North Slope, Alaska East (feet) -> 500 0 500 1000 1500 2000 2500 ,3000 ,,3500 4000 4500 5000 5500 6000 8500 7000 7500 8000 8500 9000 9500 5000 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 I I I I I I I I I I 5000 CD~-9 PH TD LOCATION: 1194' FNL, 552' FEL Ba.~- AlnlneTD CD1 -9 TARGET 4500 55,46 AZIMUTH SEC. 55, T12N, RSE ,., Alpln, eP~'leJ~=__]_~]7.4'l ;~ LOCATION: 4500 8637' (TO PH TD) .,,uv.o..LCU/~" 1924'SEC. 55,FNL'T12N,416' RsEFEL K-1 4ooo ***Plane of Proposal*** KOP A 4000 HRZ ~Jan-96 Pt. 5500 :'OC 3500 In-97 Alpine Interm Pt/Beg Fnl BI EOC CD1-9 INTERM PT LOCATION: 2585' FSL, 98' FWL SEC. 54, T12N, RSE SURFACE LOCATION: 279' FNL, 2§17' FWL 1000 SEC. 5, T11N, RSE 1000 I CD1-9 TD LOCATION: ,~\~O(3 601' FSL, 1059' FWL 500 SEC. 54, T12N, RSE 500 Casing Pt. o c2o o 500 , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 500 ~0 0 500 1000 1500 2000 2500 .3000 ,,3500 4000 4500 5000 5500 5000 6500 7000 7500 8000 BSO0 9(200 9500 East (feet) -> 5000 I 2500 2000 1500 3ooo A I 2500 2000 1500 c,.0wd b~ W.~=ho.* For: B Robert,eon (:~te plotted: Plat Ref~'en~e ~ CD1-g PHI Vemfen Ceerdrnam. ore In feet reference .Nat True Vert;coi Oel~hS or. mfermnce RKIB (Doyen PHILLIPS Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : gPH Location : North Slope, Alaska 55.46 AZIMUTH 8637' (TO TD) ***Plane of Proposal*** 600 600 1200 1800 2400 5000 5600 4200 4800 5400 60OO 6600 7200 600 RKB ELEVATION: 56' KOP 2.00 6.00 BId/Trn 2.5/100 12.75 Wes[ Sak 16.54 20.84 DLS: 2.50 deg per 100 ft 25'40Bose Permafrost 50.09 54,86 59,67 C40 4zk55 49.40 BId/Trn 3/100 51.98 C30 56.06 C~8c 9 5/8 Casing Pt. K3 AVERAGE ANGLE 60.50 DEG K-2 i i i i i i 0 600 1200 i i i i i i i I I ii i ii i I I i i 1800 2400 5000 5600 4200 4800 5400 6000 6600 7200 Vertical Section (feet) -> Azimuth 55.46 with reference 0.00 S, 0.00 E from slot//9 Albion-97 Albion-96 HRZ i I I i 7800 8400 A D Alpine TD i i i 9000 Creete~l by bmichasl FOX'.' B Robex-f~o~l Dote plotted '. Plot Reference ie CD1-9 PH1 Version 1~6. Coord[nctee ore in feet reference slot True Vertlcol Del)the ore reference RKB (Doyen INTEQ PHILLIPS Alaska, Inc. Structure : CD#I Field : Alpine Field Well : 9PH Looaflon: Nor'th Slope, Alaska Point KOP BId/Trn 2.5/100 West Sok Bose Permofrost C40 BId/Trn 5/100 C50 C20 EOC 9 5/8 Cosing Pt. K5 K-2 Albion-97 Albion-g6 HRZ K-1 LCU Miluveoch A Alpine D Alpine Bose Alpine TD PROFIL MD 500.00 800.00 1055.81 1595.05 2554.64 2624.42 2679.38 5509.55 3578.63 3400.00 5581.72 5848.80 9565.12 0255.58 0805 89 1210 04 1572 5O 1455 74 1555 24 1581 67 1 601.98 1819.27 Jnc 0.00 10 O0 15 68 25 28 45 42 50 O0 50 58 59 55 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 60.50 E COMMENT DATA Dir TVD North Eest V. Sect 40.00 500.00 0.00 0.00 0.00 40.00 797.47 -55.54 27.98 4.14 14.28 1046.00 - 62.59 69.54 21.79 92.55 1556.00 -95.80 244.16 147.94 82.06 2181.00 -64.15 668.70 514.48 80.00 2565.89 -55.54 862.51 691.59 77.99 2401.00 -25.27 904.01 750.55 57.45 2765.00 172.98 1574.86 1250.61 55.46 2799.65 206.05 1424.70 1290.40 55.46 2810.1 6 216.57 1440.02 1508.99 55.46 5786.00 1194.47 2860.81 5055.79 55.46 401 6.00 1424.96 5195.68 5440.52 55.46 5846.00 5258.81 5860.10 6674.84 55.46 6186.00 5599.52 6555.15 7275.79 55.46 6456.00 3870.09 6748.24 7753.01 55.46 6656.00 4070.51 7059.45 8106.51 55.46 6736.00 4150.68 7155.91 8247.91 55.46 6776.00 4190.77 7214.14 8318.61 55.46 6825.00 4259.87 7285.49 8405.22 55.46 6859.00 4255.90 7505.87 8429.96 55.46 6849.00 4265.92 7520.45 8447.64 55.46 6956.00 4571.15 7476.22 8656.76 Deg/lO0 0.00 2.00 2.50 2.50 2.50 2.50 3.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Created I~ bmlchael For: B Robertson Dote plotted: 2-May-2000 Plot Reference is CDt-9 Version ~6. Coordinates ars in feet reference slot ~g. true VerUcol Depths ore r~eren~ RKB (Do~n ~19). I~gq PHILLIPS Alaska, Inc. Structure: CD#1 Well: 9 Field : Alpine Field Looafion: North Slope, Alaskc 151.99 AZIMUTH 361' (TO TARGET) ***Plane of Proposal*** 6200 6400 '~ 6600 0 6800 "' 7000 I V 7200 LZ ~ KoP TARGET ANGLE t}60.53 ~59.9~ 8 7 DE G /~60.45 OLS: 9.00 deg per 100 ft ~/ ~k 61.71 K-1 / x% 63.71 LCU .~ ~ M~luveach A ]' ~6..~.~'~-~ Alpine ~, . Interm Pt/~e...g Fnl Bid }l ..... 75.~mP'ne EOC Base Alpine ~u~ ..... -'~Torget Cs'cJ Pt : ~ TD 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 I i i I i i i i i i i i i i i 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2BO0 5000 5200 5400 5600 5800 Vertical Section (feet) -> Azimuth 151.99 with reference 0.00 N, 0.00 E from slot #9 Creot~ by ~,mlc~ce~ For: B Robertson Dote plottecl: II-Mo¥-2000 Plot Reference ia CD1-9 Verelon Coordlnotas ore in f~t ~fare.ce ~ot ~9. True Verfloel Oepths ere r~eren~ RKB (~on ~t9). PHILLIPS Alaska, Inc. Structure: CO#l Field : Alpine Field Well : 9 Location: North Slope, Alaska Point KOP K-1 LCU Miluveach A Alpine D Alpine Target-Csg Pt. EOC Base Alpine Interm Pt/Beg Fnl BI ~ EOC PROFILE MD Inc 10879.22 60.50 11209.80 61.88 COMMENT DATA Dir TVD North East V. Sect Deg/1 O0 55.46 6495.02 5907.54 6802.24 -255.15 89.50 6656.00 3992.09 7072.62 -205.00 11591.08 66.09 107.06 6736.00 5968.51 7252.86 -106.75 11499.43 69.53 116.92 6777.00 3930.72 7325.69 -29.96 11 662.60 75.66 130.91 6826.00 5843.87 7454.27 107.09 11724.51 78.22 136.00 6840.00 3802.40 7498.05 164.26 11925.48 87.00 151.96 6866.00 5641.74 7614.50 360.80 12175.87 89.50 151.96 6873.64 3420.85 7732.15 611.06 12555.23 89.50 151.96 6875.00 3281.96 7806.10 768.41 13025.95 89.50 151.96 6881.00 2670.57 8131.71 1461.10 13171.63 90.96 151.99 6880.41 2541.98 8200.15 1606.77 0.00 9.00 9.00 9.00 9.00 9.00 9.00 1.00 0.00 0.00 1.00 TD 15045.00 90.96 151.99 6849.02 888.24 9079.75 3479.88 0.00 PHILLIPS Alaska, Inc. CD#I 9 slot #9 Alpine Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : CD1-9 Vers#6 Our ref : prop3507 License : Date printed : 2-May-2000 Date created : 10-Aug-1999 Last revised : 2-May-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 34.358,w150 55 32.495 Slot Grid coordinates are N 5975848.431, E 385943.431 Slot local coordinates are 278.40 S 2517.50 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object weltpath PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <0-8844'>,,45PHi,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-10224'>,,39PH1,CD#l PMSS <9146 - 13289'>,,39,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-9236'>,,22,CD#1 PMSS <0-11300'>,,13,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance 4-Jan-2000 22-Dec-1999 4-Jan-2000 4-Jan-2000 16-Nov-1999 4-Jan-2000 22-Sep-1999 26-Aug-1999 18-Aug-1999 28-Jun-1999 15-Ju1-1999 270 1 270 1 270 1 359 9 359 9 300 0 300 0 280 0 64 8 130 2 38 8 M.D. Diverging from M.D. 100.0 100.0 100.0 100.0 100.0 100.0 200.0 200.0 200.0 200.0 100.0 14160.0 100.0 14160.0 0.0 14060.0 1262.5 15045.0 537.5 12260.0 525.0 14800.0 PMSS <5946 - 10289'>,,1,CD~1 PMSS <0-7331'>,,1PHi,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-8350'>,,26PHi,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <475 - 8166'>,,41PHi,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 CD1-6 Version #5,,6,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <2827 - l1956'>,,19A, CD#1 PMSS <0-10548'>,,19,CD#1 PMSS <476 - ???'>,,34,CD#1 44 Version#6,,44,CD#1 27-Jun-1999 29-Feb-2000 28-Jun-1999 4-Jan-2000 4-Jan-2000 25-0ct-1999 6-Mar-2000 1-Nov-1999 23-Jan-2000 23-Jan-2000 23-Dec-1999 15-Mar-2000 26-Mar-2000 3-Apr-2000 16-Mar-2000 13-Feb-2000 14-Feb-2000 19-Apr-2000 28-Jun-1999 28-Jun-1999 21-Apr-2000 23-Dec-1999 4-Jan-2000 30-Apr-2000 6-Apr-2000 2-May-2000 1-May-2000 79 79 949 59 42 42 170 170 38 38 330 158 319 319 179 289 289 30 310 259 70 229 229 99 99 249 8115 .6 200.0 13700.0 6 200.0 200.0 5 2350.0 12180.0 9 300.0 15045.0 4 962.5 15045.0 4 962.5 15045.0 2 100.0 15045.0 .2 100.0 15040.0 .9 300.0 3460.0 .9 300.0 14020.0 .0 100.0 12320.0 .4 812.5 15045.0 .7 100.0 100.0 .7 100.0 100.0 .9 200.0 15045.0 .6 200.0 12180.0 .6 200.0 12180.0 .3 300.0 13420.0 .0 100.0 13480.0 .9 100.0 100.0 .9 1550.0 15045.0 .5 400.0 12042.2 .5 400.0 12042.2 .8 100.0 3920.0 .8 100.0 412.5 .9 200.0 200.0 .2 2075.0 2075.0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 8, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-09 (& CD1-09 PH) Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 24, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-09 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 60.5°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well 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: , . 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. 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. ~T~ ~ ~ ~~'~'~.~ ''~'''~'~ ~,~L~ MAY 200(t If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer Attachments CC: CD1-09 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 · T om m y_Thompson @ anadarko, com · ' '--' :'" . ' ..... :' -; .................... ' ......... : .......... - .'. .... '::' .... :' -: ' : ..... : · - : '. '~e~bl~cB~i~,~'~~~ · : : ' · P.,O;?~×:~,~:!;!~2~8','ii?.i.....i~i':;:!;:.i:':.':.i"~i..:':!i.? '?, ..~?:: :il. .;::.:... . : i!: .;? !i~ :~:~i?'::...?i. ";i:.i~ ::':i;' ~:. -,i ..... :::= .,i? :. ' .i: i: ~.. ::::' ',:.~':,::;:;:: '... ?:.';:~'" i :~ ;' ".. . ..:'. /.: .:: ::.:...:. :..' .; : ........ .- ~.ne~Or~-~=:~iAK.i~':i.995..10 ~'.";?.:,;-::;.....A.:-=.i. ~.~/.:.?:~.;:.,?' ?.:.~,:.':/:? . ...:...? ::..::?. :.:. i:. ::.::.; f/.-: .. . - ' : ? ..; ~:...: !~- ...... :.;;..'.:~. ~..:.~.' :.!.~:,,:....~ . ! .~ .;..~ ~.::~:.: ~ ~ay .HUNDRED .:DOLLARS [ ND 010094/1 To the order of: STATE OF hJ_ur~KA .ALASKA OIL & G;~S CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 · , ' ............. ~ .... ~ ..... ~ .............. ~:.~.~.~ .......................... ~.,'~,. ' ;'. :' :'i ..... :'; '; ' : ".' "-' i:'.i ?:i. i' i:::. :.;:.'. **************100 00' Date o 5 - l 0 - o o Amount ' "'0000 ;00qc~,' l:O,°,~qoL,S& 81: OR qo00o"' Void after 90 days Two signatures required for amounts over $25,000.00 WELL PERMIT CHECKLIST COMPANY WELL NAME ~/-L~)~-'~' PROGRAM: exp __ / dev v/'' redrll serv wellbore seg ann. disposal para req ~ FIELD & POOL INIT CLASS~V" ADMINISTRATION A.~) DATE 1. Permit fee attached ...................... 2. Lease number appropriate?~. ............. i . . . 3. Unique well name and number .................. 4. Well located in a defined pool .... .~:. .............. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to -z,~:.:~(,.~ psig. GEOL AREA ~'~_.~} UNIT# (-.~.~O ,.-:.~;'O ON/OFF SHORE N N DATE S{~-O0 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ~ 29. Is presence of H2S gas probable ................. .-~---.,--.Y GEOLOGY '3-~. ~"e~b'~'i"~e-~-'~/~e~ , ,, Y~~ 31. Data presented on potential overpressure zones . . /¢'./¢ Y N 32. Seismic analysis of shallow gas zones ........ i i i i '.~ Y N AP,PR D._AT/.~ 33. Seabed condition survey (if off-shore) ............ /V//I Y N ~ 5',~r' ~ 34. Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL35. With proper cementing records, this plan /v/-.r- r'.,"% ~,c, ,.~ ko.~- ~ ~,~\,¢-.c,., ~._c__~,,..~-%~...~ (A) will contain waste in a suitable receiving zone; ....... ~ N J APPR DATE (B) will not contaminate freshwater; or cause drilling waste... ~..~N to surface; ~ ~ 4 ~J ~ 2~ ~ ~ (C) will not impair mechanical integrity of the well used for disposal; ~ N (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. (,~Y') N _ GEOLO, G~;: ENGINEERING: UIC/Annular COMMISSION: Comments/instructions: I§ c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not parliculariy germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding infonnation. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ( ( ~ 0 CJ P 0 -1 ( .' Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe1 Use: CONOCOPHILLlPS ALASKA INC. May 28, 2005 5762 1 4.5" 12.6 lb. L-80 Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log Intvl1 .: CD 1-09 Alpine Alaska .:2. ù) ~, -' ~ c 50-1 03-203000 Surface 11,278 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the WLEG @ 11,276' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing logged is in good to fair condition, with a maximum recorded penetration of 43% @ 2,279', no other significant wall penetrations (>13%) are recorded. There are no significant areas of Cross Sectional Wall loss or 1.0. restrictions recorded throughout the tubing. A 3-D log plot as well as a cross-sectional drawing of the most significant event recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 43%) Jt. 67 @ 2,279 Ft. (MD) No other significant wall penetrations (>13%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. ('-4"'f>h~¡)~~¡¡:;'O-' I¡~'r\~~ 'it ",; 90[1"- .:sx..II>M,~~n'Jc:..' "'tH::J' (lÞ J., L _' ~;a I Field Engineer: Wm McCrossan Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudlloe Bay Field Office Ptlone: (907) 659-2307 Fax: (907) 659-2314 £,~ Description : ~onunents Joint 66 Joint 67 Isolated Pits (2,279') Joint 68 .r ( it PDS Multltinger Caliper 3D Log Plot Company: BP Exploration (Alaska), Inc. Field: Alpine Well: CD 1-09 Date: May 28, 2005 Detail of Caliper Recordings Across Isolated Pit in Joint 67 (2,2797 1 /, / 88 2280 , ~ ~ ~ 2290 ~ 2300 2310 2320 .,..,"t^ MaI. Pen. (Ok) 100, "500 MIN In (1/1000 inJ 450 "500 MAX In (1/1000 inJ 450" ~OO NQJ11inall.n. 450B ~ f- ). -¿------ )- ~ . --,-,----,--- ----.,¡---------- I Co -- '-" f -,I -r t'----- ------~ ''':' ~ I ._.'. .._m,_.._.._._.__.~.._.._,~___ _.__~ r - - ----- -, -,--- ~--.- '~._~- - -,,- '--~ --"- .,....--- --.--...-- -,---_..._.~ -,....~ I :.- -" 1--- .R'___ -.~.~ --____ "__ , -~------- ---ç-- ~ '\ ----- ,-,----- ~ ; - -"-"- ,".,-,,- _._~.- -- --- -- -- --- ---. - -,-- _.~- ~.~-'----- '''Þ''- ._..~"._ .__ " ' <.. ~ - ~ \, ,. I -, . .. ~ . .---- "-"-- -----_.,- ---.--- --- -. -.-. -.)- " \ -"----- - ---..... - ---. - --- ,-----.---,---------- -,------ ---- --r------ --- --- . I : ~ 1 ---{-- , ~ ~ . , ____ r---.......---- .~ ~ ~ ~ .. .' ~ I ( ,__ _'- _ __ _,______ ___ ____ __ ___ _____L ___ ~ I ,i '!!.tJ1 ~ "' c., ~ I b(~~~. :~~I \ ''''JI!, ,~~~ . clds. Well: Field: Company: Country: CD 1-09 ALPINE CONOCOPHILLlPS ALASKA INC USA I Tubing: Weight 12.6 ppf Grade & Thread L-80 Nom.OD 4.5 ins Penetration and Metal Loss (% wall) _ penetration body 300 250 200 150 lOa 50 o .., metal loss body o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total:::;:: 308) pene. 0 285 22 0 1 0 loss 86 222 0 0 0 0 Damage Configuration ( body) 20 ':11 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total:::;:: 10) 10 0 0 0 0 ( PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 3.958 ins May 28,2005 MFC 40 No 99494 2.75 40 J. Thompson Nom. Upset Upper len. 4.5 ins 1.2 ins lower len. 1.2 ins Damage Profile (% wall) _ penetration body o 'p t !lima metal loss body 50 100 ~ ( ¡.... 99 GlM3 197 GlM2 GlM 1 293 Bottom of Survey:::;:: 297.3 Analysis Overview page 2 ~ ( PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.271 in Field: ALPI NE Upset Wall: 0.271 in Company: CONOCOPH ILL! PS ALASKA I NC NominaII.D.: 3.958 in Country: USA Survey Date: May 28, 2005 Joint Jt. Depth [)en. Pen. Pen. Melal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ills. ) (Ins.) Of (Ins.) 0 50 100 /0 1 18 () 0.02 8 1 3.92 2 62 0 0.02 8 1 3.90 3 105 () 0.01 3 1 3.94 4 149 () 0.03 10 2 3.93 5 193 0 0.03 10 1 3.93 6 237 0 0.01 4 1 3.93 7 281 0 0.02 8 1 3.93 8 325 0 0.03 11 2 3.94 9 369 0 0.01 5 1 3.86 10 411 0 0.02 8 1 3.94 11 455 0 0.03 10 2 3.93 12 499 0 0.02 8 2 3.86 13 543 0 0.02 8 1 3.90 14 587 0 0.02 8 1 3.93 15 629 0 0.01 3 1 3.94 16 674 0 0.01 5 1 3.93 . 17 718 0 0.03 9 1 3.93 18 761 0 0.01 4 1 3.91 19 792 0 0.01 4 1 3.92 20 822 0 0.01 4 1 3.91 21 852 0 0.01 3 1 3.92 22 882 0 0.01 3 1 3.90 23 911 0 0.01 3 1 3.91 24 941 0 0.01 3 1 3.92 25 971 0 0.01 4 1 3.93 26 1001 0 0.01 5 1 3.91 27 1032 0 0.01 3 1 3.89 28 1063 0 0.01 4 2 3.90 29 1093 0 0.01 2 1 3.89 , 30 1124 0 0.01 3 1 3.90 31 1154 0 0.01 5 1 3.91 32 1184 0 0.02 6 1 3.92 . 33 1215 0 0.01 2 1 3.91 34 1246 0 0.01 3 1 3.91 35 1277 0 0.01 3 1 3.92 36 1307 0 0.01 3 1 3.90 37 1337 0 0.01 3 1 3.90 38 1367 0 0.01 4 1 3.90 39 1398 0 0.01 3 1 3.90 40 1428 0 0.01 4 1 3.92 41 1459 0 0.01 4 1 3.90 42 1489 0 0.01 3 2 3.91 43 1519 0 0.01 4 1 3.89 44 1550 0 0.01 5 1 3.90 45 1579 0 0.01 5 1 3.89 46 1609 () 0.01 6 1 3.90 ~ 47 1640 0 0.02 6 1 3.90 48 1671 0 0.02 8 1 3.89 49 1701 0 0.01 4 1 3.90 49.1 1732 0 0.04 13 3 3.91 PUP Shallow pitting. I Penetration Body ,.it1} Metal Loss Body Page 1 { I( PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.271 in Field: ALPINE Upset Wall: 0.271 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 3.958 in Country: USA Survey Date: May 28,2005 Joint Jt. Depth Pen, Pen. Pen. !'vIp!al Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) %> (Ins.) 0 50 100 49.2 1741 0 0 0 0 3.81 SSSV ~ 49.3 1746 0 0.03 11 :) 3.93 PUP 50 1756 0 0.01 3 1 3.90 51 1787 0 0.01 4 1 3.89 52 1817 0 0.01 5 2 3.90 53 1849 0 0.02 7 2 3.91 . 54 1879 0 0.01 2 1 3.91 55 1909 0 0.01 3 4 3.90 56 1940 0 0.01 3 1 3.89 57 1971 0 0.01 3 1 3.89 58 2002 () 0.01 4 1 3.87 59 2032 0 0.01 6 1 3.91 60 2063 0 0.01 3 1 3.90 61 2093 0 0.01 4 1 3.88 62 2124 0 0.01 5 1 3.89 63 2155 0 0.01 3 3 3.91 64 2185 0 0.01 3 2 3.88 ~ 65 2214 0 0.04 13 2 3.89 Shallow pitting. 66 2244 0 0.01 4 1 3.88 67 2274 0 0.12 43 6 3.89 Isolated pitting. 68 2304 () 0.02 6 1 3.89 69 2334 0 0.01 3 2 3.89 70 2364 0 0.01 4 4 3.87 71 2395 0 0.01 3 2 3.89 72 2425 0 0.01 5 2 3.88 ~ 73 2456 0 0.02 8 2 3.88 74 2485 0 0.01 5 2 3.89 75 2515 0 0.01 4 1 3.89 76 2545 0 0.01 3 1 3.89 77 2577 0 0.01 3 1 3.90 78 2607 0 0.01 3 1 3.90 79 2637 0 0.01 3 1 3.89 80 2668 0 0.01 3 "I 3.89 81 2698 0 0.02 6 "I 3.90 82 2728 0 0.01 2 1 3.88 83 2759 0 0.01 4 1 3.88 84 2788 0 0.01 3 1 3.89 85 2819 0 0.01 4 1 3.88 86 2849 0 0.01 4 :3 3.86 87 2881 0 0.01 5 2 3.89 88 2911 0 0.01 5 2 3.90 89 2941 0 0.01 2 'I 3.90 90 2971 0 0.01 3 1 3.90 91 3002 Ç) 0.01 4 "I 3.89 92 3033 0 0.02 8 2 3.89 . 93 3063 () 0.01 3 1 3.87 94 3093 0 0.01 5 2 3.89 95 3123 0 0.01 3 1 3.84 96 3153 () 0.01 5 1 3.91 97 3181 0 0.01 5 1 3.87 I Penetration Body t;{i: Metal Loss Body Page 2 { ( PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.271 in Field: ALPI NE Upset Wall: 0.271 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 3.958 in Country: USA Survey Date: May 28,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (IllS, ) (I ns. ) 'Yo (Ins.) 0 50 100 98 3212 0 0.01 5 2 3.89 99 3242 0 0.02 6 ') 3.90 .) 100 3273 () 0.01 4 2 3.88 101 3302 0 0.01 4 2 3.88 102 3333 0 0.01 4 4 3.89 103 3364 0 0.01 4 :3 3.87 ~ 104 3394 0 0.01 4 2 3.86 105 3425 0 0.02 6 2 3.88 106 3455 0 0.01 4 2 3.87 ~ 107 3485 0 0.01 3 :3 3.88 108 3515 0 0.01 4 2 3.88 109 3546 0 0.01 4 2 3.87 110 3576 0 0.01 4 3 3.88 111 3606 0 0.02 8 2 3.85 112 3637 P 0.02 8 3 3.84 113 3668 0 0.02 9 :3 3.87 114 3698 () 0.01 4 3 3.86 115 3729 0 0.02 8 2 3.87 116 3760 () 0.01 4 3 3.85 117 3789 0 0.02 8 :3 3.83 118 3820 0 0.02 7 3 3.87 119 3851 0 0.01 4 :3 3.87 120 3881 () 0.03 10 :3 3.86 121 3911 0 0.02 8 2 3.86 122 3941 0 0.01 5 3 3.87 123 3971 0 0.01 3 :3 3.87 124 4002 0 0.01 3 :3 3.86 125 4032 0 0.01 5 2 3.88 126 4062 0 0.01 4 :3 3.87 127 4093 0 0.01 3 3 3.87 128 4123 0 0.01 4 :3 3.86 I. 129 4154 0 0.02 7 :3 3.86 130 4184 0 0.01 3 3 3.85 131 4214 0 0.01 3 3 3.86 132 4245 0 0.01 4 3 3.84 133 4276 0 0.01 3 2 3.87 134 4306 0 0.01 5 3 3.86 135 4337 0 0.01 4 :3 3.87 136 4368 0 0.01 5 3 3.87 ~ 137 4398 0 0.02 8 :3 3.87 138 4428 () 0.01 3 3 3.85 139 4458 0 0.01 3 :3 3.88 140 4488 0 0.02 8 :3 3.86 141 4519 0 0.03 13 :3 3.89 Shallow pittin~. 141.1 4550 0 0.02 7 2 , 3.87 PUP 141.2 4559 0 0 0 () N/A GLM 1 (Latch @ 9:00) 141.3 4566 0 0.01 4 3 3.88 PUP r 142 4576 0 0.02 7 1 3.87 143 4605 0 0.03 9 5 3.88 144 4637 0 0.01 3 :3 3.85 I Penetration Body Metal Löss Body Page 3 ( ( \ PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.271 in Field: ALPI NE Upset Wall: 0.271 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 3.958 in Country: USA Survey Date: May 28, 2005 Joint Jt. Depth Pen. Pen. Pen. Mel¡:¡1 Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 145 4668 0 0.02 9 4 3.87 . 146 4698 0 0.01 5 4 3.88 147 4730 0 0.01 5 " 3.88 ,) 148 4760 0 0.01 4 2 3.87 149 4790 0 0.02 9 2 3.89 . 150 4834 0 0.03 11 4 3.83 I 151 4878 0 0.02 8 :1 3.88 152 4922 0 0.02 8 :3 3.86 153 4963 0 0.03 10 4 3.83 154 5006 0 0.01 4 3 3.86 155 5047 0 0.03 9 3 3.87 156 5091 0 0.01 3 2 3.87 157 5132 0 0.01 3 6 3.84 . Lt. Deposits. è 158 5173 0 0.02 8 3 3.87 159 5214 0 0.02 8 2 3.87 160 5258 0 0.02 8 3 3.87 161 5302 0 0.02 9 3 3.86 162 5346 0 0.03 10 4 3.86 163 5390 0 0.03 9 :) 3.87 164 5434 0 0.03 13 3 3.89 Shallow pitting. 165 5478 0 0.03 1,0 3 3.86 166 5520 0 0.03 12 3 3.87 Shallow pitting. 167 5564 0 0.01 3 3 3.86 168 5606 0 0.01 2 2 3.88 169 5647 0 0.01 4 2 3.85 170 5688 0 0.01 4 2 3.87 171 5730 0 0.01 3 2 3.83 172 5768 0 0.02 8 ') 3.88 .) 173 5812 0 0.03 11 3 3.87 174 5853 0 0.01 2 3 3.87 175 5893 0 0.03 10 3 3.90 176 5937 0 0.03 11 3 3.87 177 5981 0 0.01 4 3 3.87 178 6022 0 0.03 9 2 3.87 179 6066 0 0.01 4 :3 3.85 180 6107 0 0.02 8 ') 3.85 .) 181 6149 0 0.03 10 4 3.89 182 6193 0 0.01 4 4 3.88 183 6236 0 0.03 10 2 3.85 184 6280 0 0.01 3 3 3.86 185 6322 0 0.03 10 3 3.87 186 6366 0 0.02 8 :3 3.88 187 6409 0 0.02 9 3 3.84 188 6451 0 0.01 4 2 3.88 189 6495 0 0.03 10 2 3.88 190 6539 0 0.03 9 ') 3.88 .) 191 6583 0 0.03 10 4 3.87 192 6626 0 0.03 11 2 3.87 Shallow pitting. 193 6670 () 0.02 9 2 3.87 194 6714 0 0.03 9 3 3.87 I Penetration Body Metal Loss Body Page 4 ( ( PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.2 71 in Field: ALPI NE Upset Wall: 0.271 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 3.958 in Country: USA Survey Date: May 28,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U pSC' t Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) '1() (Ins.) 0 50 100 195 6758 () 0.01 4 :) 3.87 196 6802 0 0.02 9 3 3.89 197 6846 () 0.03 10 :) 3.84 198 6888 () 0.03 10 2 3.90 199 6932 0 0.02 9 :3 3.87 200 6977 0 0.02 9 :3 3.83 201 7019 0 0.02 8 :) 3.87 202 7062 0 0.03 10 :3 3.87 203 7107 0 0.01 4 4 3.89 204 7150 0 0.03 11 3 3.89 205 7195 0 0.02 8 2 3.90 206 7239 0 0.01 4 2 3.88 207 7283 () 0.03 10 2 3.87 208 7327 0 0.03 11 :3 3.88 209 7371 0 0.02 9 2 3.89 210 7415 0 0.03 10 2 3.87 211 7459 0 0.02 8 3 3.87 212 7503 0 0.03 9 :3 3.87 213 7547 0 0.03 10 2 3.88 214 7591 () 0.03 11 2 3.88 215 7635 0 0.03 10 .3 3.86 216 7679 0 0.03 ,10 .3 3.87 217 7723 () 0.02 9 :3 3.81 218 7765 () 0.02 9 3 3.87 219 7809 0 0.02 8 2 3.88 220 7852 0 0.01 5 2 3.90 221 7897 0 0.02 8 2 3.88 222 7940 0 0.02 6 2 3.87 223 7982 0 0.01 2 2 3.85 224 8022 0 0.02 6 2 3.86 ~ 225 8063 0 0.01 6 3 3.86 226 8104 0 0.01 4 2 3.87 227 8146 0 0.02 8 3 3.87 228 8189 0 0.03 10 3 3.87 229 8230 0 0.03 10 2 3.89 229.1 8274 0 0.01 5 1 3.88 PUP 229.2 8283 0 0 0 0 N/A GlM 2 (Latch @ 1 :00) 229.3 8291 0 0.01 4 2 3.87 PUP 230 8300 0 0.02 7 2 3.90 231 8344 0 0.03 10 2 3.88 232 8388 0 0.02 9 2 3.87 233 8432 0 0.03 10 :3 3.87 234 8476 0 0.02 8 :3 3.89 235 8520 0.03 0.03 10 2 3.84 Deposits. 236 8562 0 0.03 9 3 3.82 Lt. Deposits. 237 8606 0 0.03 10 .3 3.88 238 8651 0 0.02 8 2 3.87 239 8694 0 0.02 9 1 3.88 Deposits. 240 8738 0 0.02 8 1 3.89 241 8782 0 0.02 8 1 3.90 I Penetration Body Metal Loss Body Page 5 ~ PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: CD 1-09 Body Wall: 0.271 in Field: ALPI NE Upset Wall: 0.271 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 3.958 in Country: USA Survey Date: May 28, 2005 Joint Jt. Depth I:>('n, Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 242 8827 0 0.03 10 2 3.87 243 8870 0 0.02 6 2 3.88 244 8914 () 0.03 9 1 3.90 245 8958 0 0.02 8 2 3.89 246 9002 0 0.03 12 2 3.89 Shallow pitting. 247 9047 0 0.03 11 :3 3.90 248 9091 0 0.02 9 1 3.88 249 9134 0 0.03 11 2 3.89 250 9179 0 0.03 10 :3 3.80 251 9221 0 0.02 8 2 3.89 252 9265 0 0.03 10 2 3.80 253 9306 0 0.03 10 2 3.89 254 9350 0 0.03 9 2 3.89 255 9394 0 0.03 10 1 3.90 256 9438 () 0.02 8 2 3.85 257 9482 0 0.02 9 'I 3.84 258 9525 0 0.03 10 2 3.89 259 9569 0 0.03 10 2 3.88 260 9613 0 0.01 4 2 3.87 261 9657 0 0.02 8 :3 3.90 262 9701 0 0.02 8 2 3.85 263 9745 0 0.03 10 :3 3.81 264 9785 0 0.03 10 2 3.88 265 9829 0 0.01 5 2 3.87 266 9873 0 0.03 10 2 3.86 267 9912 0 0.03 9 2 3.90 268 9948 0 0.03 10 2 3.90 269 9992 0 0.02 9 2 3.89 270 10036 0 0.03 10 2 3.86 271 10075 0 0.03 10 3 3.87 272 10119 0 0.02 9 ') 3.87 ,.) 273 10163 0 0.01 4 2 3.87 Light deposits 274 10202 0 0.03 9 2 3.88 275 10246 0 0.02 6 1 3.87 276 10290 0 0.02 8 2 3.83 277 10332 0 0.02 9 1 3.88 278 10376 0 0.03 10 :3 3.87 279 10414 0 0.02 9 2 3.81 280 10455 0 0.02 9 1 3.87 281 10499 0 0.02 6 2 3.85 282 10539 0 0.02 8 1 3.86 283 10583 0 0.03 11 2 3.87 284 10627 0 0.02 7 2 3.87 285 10671 0 0.01 3 2 3.87 286 10716 0 0.01 5 2 3.85 f 287 10759 0 0.02 9 2 3.85 288 10804 0 0.01 4 2 3.85 289 10848 () 0.03 11 2 3.88 290 10891 0 0.02 8 2 3.85 291 10935 0 0.02 9 2 3.85 I Penetration Body Metal Loss Body Page 6 { PDS REPORT JOINT TABULATION SHEET 1',1' ~ Pipe: 4.5 in 12.6 ppf l-80 Well: CD 1-09 Body Wall: 0.271 in Field: AlPI NE Upset Wall: 0.271 in Company: CONOCOPHIlLlPS ALASKA INC NominaII.D.: 3.958 in Country: USA Survey Date: May 28, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins,) (Ins.) 0: (Ins.) 0 50 100 !o 292 10979 0 0.02 6 2 3.82 292.1 11024 0 0.01 5 2 3.84 PUP 292.2 11032 () 0 0 () N/A GlM 3 (Latch @ 2:00) 292.3 11 040 () 0.02 7 2 3.85 PUP Deposits. 293 11050 0 0.02 9 :) 3.86 294 11 093 0 0.02 8 2 3.71 It. Deposits. 294.1 11266 0 0 0 0 3.73 X NI PPLE 295 11138 0 0.02 9 4 3.81 295.1 111 82 0 0.02 8 2 3.81 PUP 295.2 11192 0 0 0 0 3.88 PACKER 295.3 11195 0 0.02 9 3 3.79 PUP 296 11206 0 0.03 11 3 3.79 297 11237 0 0.04 13 3 3.79 Shallow pittin~. 297.1 11266 0 0 0 0 3.73 XN NIPPLE 297.2 11268 0 0.04 13 2 3.81 PUP Shallow pittih~. 297.3 11276 0 0 0 0 N/A WlEG I Penetration Body Metal loss Body Page 7 .I--·'ls ~ p. PDS Report Cross Sections Well: Field: Company: Country: Tubing: CO 1-09 ALPINE CONOCOPHILUPS ALASKA INC USA 4.5 ins 12.6 ppf L-8O Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 28, 2005 MFC 40 No 99494 2.75 40 }. Thompson Cross Section for Joint 67 at depth 2278.78 ft Tool speed = 52 Nominal 10 = 3.958 Nominal 00 = 4.500 Remaining wall area = 94 % Tool deviation = 460 Finger 3 Penetration = 0.11 7 ins Isolated Pit 0.12 ins = 43% Wall Penetration HIGH SIDE = UP Cross Sections page 1
