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203-095
/Image J .1ject Well History File C~ )er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ O~ - 0 ç¡.5 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed I . RESCAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: BY: Helen~ o Other:~ t ^ A '1\ Date: ~ ~ ()S" /51 VvV;-' , I1I11I NOTES: Project Proofing BY: Helen ~ DateÇ( :J-Š OS;- /51 !) ~ Scanning Preparation BY: Helen~ J x30= 0n + I = 10T~L PAGES ~ I (Coun~&S no1jc.::;lud~ver sheet)I/'\!1-.:) Date: 1) ~S tJ..::, /5/ Y r r . Production Scanning II Stage 1 Page Count from Scanned File: (o:l.. (Count does include co~ sheet) Page Count Matches Number in Scanning Preparation: V Y7~ J NO t.1\ A. 'J Bÿ: Heien@ Date: <?', ~/ ðC Isl V r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES' NO BY: Helen Maria Date: 15/ 111111111111111111I 1111111111111111111 I Date: 15/ Quality Checked 1111111111111111111 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1C-172 Run Date: 6/1/2010 June 10, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-172 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23159-00 _'~~ ~u ~~ ~r ~ ~t D ~!~ ~~~~~ ; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barre. 1 ' Ica { ~, r s .yam ~ '~ Date: a,1 ~~ ~ j'.S+~ Signed: ~~ ~, :~, ~' . ~a~ ConocoPhillips April 16, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-172 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 A PR Y 7 2008 Ali~sk~ ~~ & Gas ~~e ~m~oa ~v3- v~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the West Sak well 1 C-172. If you have any questions regarding this matter, please contact me at 265-6830 or Guy Schwartz at 265-6598. Sincerely, ~i`-~---~-- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling ~N MAY ~ ~ 2008 RT/skad ~1®E~ • STATE OF ALASKA ~ APR 1 7 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION R`~4~[9"~"~10i 1a. Well Status: Oil ^ Gas Plugged / .Abandoned / • Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well C ass: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~J, ~•Zy' r Aband.: March,36; 2008 12. Permit to Drill Number. 203-095 ! 308-025 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. a Spudded: June 11, 2003 • 13. API Number: 50-029-23159-00 ' 4a. Location of Well (Governmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11N, R10E, UM 7. Date TD Reached: June 21, 2003 14. Well Name and Number: 1C-172 Top of Productive Horizon: 541' FSL, 1923' FEL, Sec. 2, T11 N, R10E, UM 8. KB (ft above MSL): 28' RKB Ground (ft MSL): 87' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 324' FSL, 2280' FEL, Sec. 11, T11N, R10E, UM 9. Plug Back Depth (MD + ND): 3535' MD / 2449' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562102 y- 5968801 Zone- 4 10. Total Depth (MD + ND): 11970' MD/ 3933' TVD 16. Property Designation: ADL 25649 ` TPI: x- 559067 y- 5970754 Zone- 4 Total Depth: x- 558758 - 5965255 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 2571 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 2915' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G CORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE PULLED 16" 62.5# B Surf. 80' Surf. 80' 42" 638sxArcticCRETE 9.625" 40# L-80 Surf. 6712' Surf. 3816' 12.25" 860 sx AS III Lite, 420 sx Class G 5.5" 15.5# L-80 6521' 11960' 3780' 3924' 8.5" pre-perforated liner bridge plug @ 3535' MD 23. Open to production or injection? Yes ^ No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6400'-9320' MD 168 bbls Class G cement retainer @6400' 41 bbls Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~(a. 4~.dovtN~=-1,E- ~7JN.i~ ~~ NONE ~~ ~~~: ~p~ ~ ~ ~~0~ a.~-,.~~~j4 I~R iEI} ~n Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~~~ i~~~ ~ ~~'~©~ QRIGIC~AI~ ~._ r~ 28. GEALOGIC MARKERS (List all formations and mar encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 4779' 2915' needed, and submit detailed test information per 20 AAC 25.071. West Sak B 6559' 3790' West Sak C 6498' 3774' West Sak D 6377 3736' N!A Formation at total depth: 30. LIST OF ATTACHMENTS ~ ~'~~' Summary of Daily Operations ~I 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: uy Schwartz @ 265-6958 Printed Name_~,_,~~ Rnd Thomas Title: Drilling Team Leader ~~ (f ~7 ~~ g ' ~ 3 ~ Date Signature j ~ vim, ~-~----- Phone ~~ ~ ~; ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 1C-172 Pre-Rig Summary DATE SUMMARY 3/4/08 SET CATCHER @ 6316'. PULLED OV @ 6221' RKB, CHECK & NOSE ERODED. PULLED GLV @ 3378' RKB, REPLACED WITH DV. WELL READY TO LOAD WITH SW. 3/4/08 Plannned Maintenance for Reel Swap 3/5/08 (PRE RWO) T POT/PPPOT -PASSED, FUNCTION TEST LDS'S (ALL CONFIRMED) 3/6/08 Planned Maintenance for 2 3/8" CT Conversion 3/6/08 Loaded tubing and IA with SW + 1 % CRW 132 inhibitor from 2500' to 6221'. Freeze protected tubing and IA to 2500'. 3/7/08 Planned Maintenance for 2 3/8" CT Conversion 3/7/08 SET DV AT 6221' RKB. CHECK SET DVs @ 6221' & 3378' RKB. TBG AND IA IN COMMUNICATION. SUSPECT GLM AT 6221' RKB ERODED. READY FOR FCO. 3/8/08 Planned Maintenance for 2 3/8" CT Conversion 3/9/08 FCO'D LINER DOWN TO 8337' CTMD UTILIZING SLICK DIESEL DIESEL GEL AND N2, POOR ROP FROM 8050' TO 8337' DUE TO HIGHER THAN EXPECTED FRICTION FACTORS OR LARGE AMOUNTS OF SAND WITH POSSIBLE COMBINATION OF BOTH, RETURNS WERE STABLE WITH MODERATE AMOUNTS OF FILL, RETURN IN THE AM TO CONTINUE FCO, 580 BBLS SLICK DIESEL AND 150 BBLS DIESEL GEL PUMPED, WELL LEFT SHUT IN AND FREEZE PROTECTED. BHA 2.375" WOC, 2" DFC, 2.5" JSN, OAL = 2.5' 3/10/08 FCO'D DOWN TO 9350' CTMD (LOCKUP ), LITTLE TO NO SOLIDS IN RETURNS, PUMPED 200 BBLS VERSA LUBE WITH NO CHANGE IN TOTAL DEPTH ACHIEVABLE, WELL LEFT SHUT IN AND FREZZE PROTECTED WITH DIESEL DOWN TO 6500' MD, RETURN IN THE AM FOR CEMENT PORTION OF JOB. BHA 2.375" WOC, 2" DFC, 2.5" JSN, OAL = 2.5' 3/11/08 ATTEMPTED TO CEMENT SLOTTED LINER, WITH 10 BBLS CEMENT OUT OF NOZZLE HARD LINE O-RING AT REEL FAILED, HAD TO CUT CEMENT AND GO ON FLUSH DISPLACING CEMENT FROM COIL. ONCE REPAIR WAS COMPLETED JETTED BIO ZAN TO 9360' CTMD TO CONTAMINATE AND JET CEMENT OUT OF LINER MAINTAINING 1:1 RETURNS DURING CEMENT FCO. RETURN IN THE AM TO RESTART CEMENT JOB. WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL TO 5300' CTMD TO SURFACE. (( IN PROGRESS )) 3/12/08 LAID IN CEMENT FROM 9320' CTMD TO 6400' CTMD PUMPED A TOTAL OF 168 BBLS ' OF 15.8 PPG (7.5 HRS THICKENING TIME) CEMENT WITH AN EST. 100 BBLS BEHIND PIPE ACHIEVING 1200 PSI SQUEEZE PRESSURE, DROPPED 5/8" BALL AND CONTAMINATED 2:1 WITH 100 BBLS OF BIOZAN DOWN TO 6450' CTMD CHASING PILL WITH WATER AT 80%, WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL FROM 4500' CTMD TO SURFACE TRAPPING 700 PSIG WHP, WELL TO BE LEFT SHUT IN 24 HRS FOR PRESSURE TEST. 3/14/08 TAGGED TOC @ 6405' SLM.ATTEMPT TBG TEST.ESTABLISHED LEAK RATE OF 1/2 BBL PER MIN Cad 1450.IN PROGRESS 3/15/08 PERFORMED PDS CALIPER FROM 6380' SLM TO SURFACE.GOOD DATA 3/21/08 TAGGED EST. TOC Cad 6429' RKB.RAN D&D & PERFORMED CMIT TO 1400 PSI- PASS. PERFORMED INJECTIVITY TEST; PUMPED 15 BBLS DIESEL DOWN TBG @ 0.75 BPM, 2000 PSI. 3/21/08 SET HES 4 1/2" EZSV CEMENT RETAINER WITH MID ELEMENT AT 6400'. LRS ON LOCATION TO PT TUBING AFTER ELINE IS RIGGED DOWN 3/22/08 CONFIRM INTEGRITY OF CEMENT RETAINER. DOUBLE BLOCK FLOWLINE AS PIT VALVE LEAKS BY. CONFIRM SLOW TBG X IA LEAK; PRESSURE UP TBG AND IA TO 2150# AND 2000# RESPECTIVELY. CEMENT RETAINER HOLDING. PRESSURE TEST COMPLETE. READY FOR P & A. 3/23/08 MU AND RIH WITH HES STINGER AND PUMPED A TOTAL OF 41 bbls OF CLASS G •CEMENT BELOW RETAINER AND ACHIEVED A SQUEEZE PSI OF 1350 psi.PULL OUT OF RETAINER AND LAYED IN 1bbl OF CEMENT ON TOP OF EZSV.USED BIOZAN TO CONTAMINATE REMAINING CEMENT DOWN TO TARGET TOC @ 6350' CTMD.LEFT WELL SHUT AND FREEZE PROTECTED FOR SL TAG. 3/24/08 TAGGED TOC @ 6353' RKB WITH 3.735"'~tlI~2~J~i:~'8[~ifi~@IyIED CMII`TO 1500# PASS SECOND TEST.BLED TBG AND IA TO O.PULLED STA #2 DV @ 6221' RKB 3/25/08 LOGGED SLB MEMORY/GR/CCL FROM TOC TO 6200'. TAGGED 3.812" CMU @ 6316' RKB WITH 3.84" GAUGE RING. CUT TBG @ 6335' RKB USING SLB 3.65" POWER CUTTER. GOOD INDICATION TOOLS CUT. ASSISTED CREW SETTING BPV. COMPLETE. l~ I _Time Logs _ _ Date From Tq Dur S De th E. D th Ph se Code Subcode T COM 03/26/2008 18:45 20:00 1.25 0 0 MIRU MOVE SKID P Skid rig floor over well 1C-17 .Install roof caps on the pipe shed. Install handrails. 20:00 23:00 3.00 0 0 MIRU MOVE RURD P Rigging up: Hooking up steam lines, mud lines, flow line, interconnects, berming around the rig. Pickup tools and debris. Raise braces in the pipe shed and secure. Moving two small camps, shop, parts houses from 1 D ad to 1 C ad. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Install beaver slide on drilling module. Continue working on the steam s stem. 03/27/2008 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Continue rigging up pump room, cellar area, cellar pump. Doyon 15 Rig accepted @ 0200 hrs 3/27/2008. 02:00 04:30 2.50 0 0 MIRU WELC OTHR P Prep Cellar for Well Kill/ fluid swap 04:30 06:00 1.50 0 0 MIRU MOVE OTHR P Spread Herculite f/ Rock Washer, Lay Ri Mats for Loadin Dock 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Rig down equipment used to pickup the beaver slide. Organize rig floor and cellar. Move and spot the rockwasher. Berm the rockwasher. Move and spot the change house. Work on steam s stem. Test Gas alarms. 09:00 10:00 1.00 0 0 INTRM1 WELCT OTHR P Pickup the lubricator. Lubricate out the BPV, la down lubricator. 10:00 11:00 1.00 0 0 INTRM1 RPCO RURD P Rig up 2" hardline from the choke, then horizontal open top tank and annulus (9-5/8" x 4-1/2"). Rig up a hot air heater to the house. 11:00 11:30 0.50 0 0 INTRM1 RPCOti SFEQ P Rig up diesel to the test pump. Pressure test the hard line w/ 100 psi air. Fill line with diesel, then test to 2000 si, no leaks. 11:30 12:00 0.50 0 0 INTRM1 RPCOh OTHR T Thaw out vacum truck suction line & Stand Pi eon the O en To Tank. 12:00 12:30 0.50 0 0 INTRM1 RPCO SFEQ P Fill secondary kill line from the pumps to the well with seawater. Pressure test lines to 1500 si. OK. 12:30 12:45 025 0 0 INTRM1 RPCOb SFTY P Pre job safety meeting for displacement from wellbore fluids (mostly diesel w/ some seawater) to 8.5 seawater. Is~g~ Z of 25 • Time Logs Da From To Dur S. De th E. De th Phase Code Su6code T COM 03/27/2008 12:45 18:00 5.25 0 0 INTRM1 RPCOh CIRC P Displace well bore fluids to 8.5 ppg seawater. Pumping down the 9-5/8" x 4-1/2" annulus with the rig pumps, taking returns through the tubing to choke skid, then to open top horizontal 400 bbls tank. Initial circulating rate and pressure 1/2 BPM / 10 Psi. Final circulating rate and pressure 4 BPM / 250 Psi. After 600 Bbl Pum ed Returns to Tank Showed a Mixture of Crude and Sea Water• Shut Down and Observed Well for Pressure Build U ;Annulus Pressure Built to 40 Psi After 30 Minutes. 18:00 18:30 0.50 0 0 INTRM1 RPCO RURD P Blow Down Lines f/Tree to Tank and R/U to Circulate Through the 4 1/2" Tubing and Up the 9 5/8" X 4 1/2" Annulus. 18:30 19:00 0.50 0 0 INTRM1 RPCO CIRC P Circulate down 4-1/2" tubing, taking returns through rig choke manifold and poor boy degasser. Pumping 4 bpm w/ 260 psi. Returns dirty diesel, dumping same. Ran out of seawater, did not clean up. Shut down. Monitor ressures. 19:00 23:00 4.00 0 0 INTRM1 RPCO OTHR P While waiting on another 580 bbls of 90 deg seawater to arrive and trucks to haul off the returns: Change saver sub on the to drive to 4-1/2" IF. 23:00 00:00 1.00 0 0 INTRM1 RPCO CIRC P Circulate down 4-1/2" tubing, taking returns through rig choke manifold and poor boy degasser. Pumping 4 bpm w/ 260 psi. Returns started to clean up a little after pumping 150 bls of seawater. Continue to pump seawater to cleanup well. A total of 240 bbls um ed midni ht 03/28/2008 00:00 01:30 1.50 0 0 INTRM1 RPCOh CIRC P Contined circulating to Clean Up Liner % Annulus; Returns Cleaned Up; Pumped another 360 Bbls @ 4 BPM / 260 Psi. Note: While circulating: Tested rig floor safety valve (4-1/2" IF) to 250 psi low and 3000 si hi h. Charted test. 01:30 02:00 0.50 0 0 INTRM1 RPCOh OWFF P Observe Well for Flow (Static); Blow Down Lines & Choke manifold. 02:00 02:30 0.50 0 0 INTRM1 WELC OTHR P .Install 4" BPV 02:30 03:30 1.00 0 0 INTRM1 RPCOA NUND P Nipple Down Vetco 4-1/16" 5m Horizontal Tree. 03:30 09:00 5.50 0 0 INTRM1 WELCT NUND P Ni le U 13-5/8" 5m BOPE & Associated Lines. Cleaning pits and loading pipe shed with a total of 255 jts (85 stands) 5" drill i e. €'~gs 3 ~a~f 25 Time Logs Date From To Dur S De th E. D th Phase Code Subcode T COM 03/28/2008 09:00 10:45 1.75 0 0 INTRM1 WELCT OTHR P Change BOP Rams and Configure as Follows; 3 1/2" X 6" Variable (Too pine rams), and 7 5/8" (Bottom pine . rams . 10:45 11:30 0.75 0 0 INTRM1 WELCT OTHR P Pickup 4-112" testjoint, make up Vetco Gray test plug, run in hole and set test dart. Fill stack with water. 11:30 12:00 0.50 0 0 INTRM1 WELCT BOPE P Shell Test BOPE: Witness of test waived by AOGCC Inspector John Crisp. Tested Upper (3 1/2" X 6") Rams Against Manual Choke & Kill Valves to 250 psi low and 3000 psi high. Held each test 5 minutes. Charted test. Tested Good. 12:00 12:30 0.50 0 0 INTRM1 WELCT OTHR P Rig Down /Blow Down Lines & E ui ment f/ BOP Test 12:30 12:45 0.25 0 0 INTRM1 WELCT OTHR P Remove Vetco test dart, lay down test 'oint. 12:45 13:30 0.75 0 0 INTRM1 WELCT OTHR P Pull BPV 13:30 15:30 2.00 0 0 INTRM1 RPCOh TRIP P Screw Into Hanger and Pull Hanger to the ri~ floor, Cut & Remove TEC Line and Clamps, UD hanger w/pup, and two 10' pup jts, Pull & Stand Back 3 Stands of 4 1/2" 12.6 ppf L-80 IBT-m tubing. Pulled free with 145k on weight indicator. Then PU wt was 125k as expected. PU wt 120k, SO wt 110k, blocks 70k. 15:30 15:45 0.25 0 0 INTRM1 RPCO RURD P Change Elevators and R/U to Run 9 5/8" Storm Packer (Baker model "EA" Retrievamatic . 15:45 17:15 1.50 0 0 INTRM1 WELCT OTHR P RIH & Set 9 5/8" Storm Packer (one turn to left, then set down all weight to block wt of 70k on the indicator) at 90' MD 17:15 17:30 0.25 0 0 INTRMI WELC TRIP P Pull out of the hole with Baker running tools. Stand back stand of 5" d . 17:30 17:45 0.25 0 0 INTRM1 RPCOti RURD P Lay down Baker Oil Tools running tools. 17:45 18:15 0.50 0 0 INTRM1 RPCOti DHEQ P Test Baker model "EA" retrievamatic storm packer. Used Blind Rams kill line manual valve and Choke HCR to 1000 Psi f/ 5 Minut 18:15 20:00 1.75 0 0 INTRM1 WELC NUND P Ni le down 13-5/8" BOP stack by removing flowline, tie down chains, and flowline. Rig up and attach bridge cranes, rig down choke hose, break bolts on the 11" 5m DSA to the wellhead. Pick up stack and move to the side. - ~ r~~g~ a of 2~ I • Mime Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/28/2008 20:00 23:00 3.00 0 0 INTRM1 WELCT OTHR P Ri u to remove the Vetco/Gray 11" 5 ro~head (tubing head assembly # 0800108-01-2, part#C-800-108-01 ). Attempted to pull with tugger, soaked lockdown holes with aerokroil, steam wellhead, hammer on wellhead, try pulling side to side. Rigged up rig up slings to top drive. Pulled 16k with top drive, re-rigged and pulled to 24k w/ top drive several times, pulled 16k with blocks and pulled with big tugger and final) ulled free a rox 30k to ull free . 23:00 00:00 1.00 0 0 INTRM1 WELCT OTHR P Move wellhead to the side in the cellar. Dress and prepare neck of 9-5/8" hanger for new wellhead. Clean Graylock ring. Install New wellhead with another profile for the 7-5/8" casin to be run. Orient wellhead with punch marks on the conductor. Verified ali nment with unch marks. 03/29/2008 00:00 00:30 0.50 0 0 INTRM1 WELC NUND P Orient New wellhead with punch marks on the conductor. Verified alignment with punch marks. Tighten lockdown screws to 9-/8" hanger extended neck to approximately 300 ft lbs. 00:30 01:15 0.75 0 0 INTRM1 WELC OTHR P Install double valves on the annulus. Test graylock connection to 500 and 1000 psi for 10 minutes each. Good test. 01:15 01:30 0.25 0 0 INTRM1 WELC NUND P Set 13-5/8" BOP stack w/ 11" 5m spool on the Vetco/Gray multibowl wellhead. 01:30 04:00 2.50 0 0 INTRM1 WELCT NUND P Install tiedowns, install choke hose, bell nipple and flowline. Install drip pan. tighten bolts on the 11" 5m flan e. 04:00 05:30 1.50 0 0 INTRM1 WELCT OTHR P Ri u to test BOPE. Fill stack with water. ;~~ga b of 25 l~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/29/2008 05:30 17:15 11.75 0 0 INTRM1 WELCT BOPE P PE. Tested annular with 4-1/2" and 4" test joint, test upper pipe rams (3-1/2" x 6") with 4-1/2", 4" and 5" test joint. Test lower pipe rams with 7-5/8" test joint. Test blind rams. Test 4" XT-39 floor safety valve and Dart valve. Test 4-1 /2" IF dart valve. Test upper and lower IBOP on top drive. Test all valves in choke manifold, and tested manual and HCR valves on kill and choke line. Performed Koomey test with 3100 psi initial, after operating rams 1600 psi, 200 psi build up in 42 seconds, full charge in 3 min 20 seconds, 5 bottle average .All tests were held 5 minutes and charted. Tested to 250 psi low and 3000 psi high.Witness of test waived b AOGCC ins ector John Cris . 17:15 17:45 0.50 0 0 INTRM1 WELCT OTHR P Rig down testing equipment. Blow down the choke and kill lines. Blow down the choke manifold. 17:45 18:00 0.25 0 0 INTRM1 RPCOh OTHR P Install Vetco Gray wear bushing. 10-1/2" OD, 9-3/4" ID, 4.73' long. Run in 2 lockdown screws. 18:00 19:30 1.50 0 0 INTRM1 WELC OTHR P i u to retrieve the 9-5/8" storm acker Model "EA" retrievamatic). Run in with running tool, close floor safety valve, screw into packer, open valve- well static, pull packer free, well static, release packer, slackoff and break and remove floor safety valve. Pull packer to the floor, break and lay down same. 19:30 21:00 1.50 0 0 INTRM1 RPCOh RURD P Rig up to pull the 4-1/2" 12.6 ppf L-80 IBT-m completion. Rig up Baker spooling unit for the TEC wire. Rig up GBR casing tools. Install stripping rubbers, Cavins air slips. Make up floor safety valve with crossover to 4-1/2" IBT. Hold re'ob safe meetin 21:00 00:00 3.00 0 0 INTRM1 RPCOh TRIP P Pull out of the hole w/ 4-1 /2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap stands. Spool up the TEC wire. Monitor well on the trip tank.A total of 109 jts plus the first GLM is out of the hole. 03/30/2008 00:00 02:45 2.75 0 0 INTRM1 RPCOh TRIP P Continue to pull out of the hole w/ 4-1 /2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap stands. Spool up the TEC wire. Monitor well on the trip tank. A total of 198 jts (66 stands) plus one GLM removed from well. Pac3e ~ ~sf 25 • Tin1e Logs Date From To Dur 5. De th E. De th Phase Code Subco e T COM d 03/30/2008 02:45 04:00 1.25 0 0 INTRM1 RPCOh _ _ PULD P Continue to pull out of the hole w/ 4-1 /2" 12.6 ppf L-80 IBT completion string. Remove clamps for the TEC wire. Strap jewlery and 5 more jts + cut off jt 22.30', another GLM, and Baker guage carrier, and Baker CMU. Spool up the TEC wire. Monitor well on the trip tank. Calculated fill 31.5 bbls, actual 34.5 bbls (difference because of clamps. A total of 203 jts plus two GLM's, guage carrier, sliding sleeve and cut off jt removed from well. Sixty six stands in the derrick, five loose jts + cut off jt. Total length removed from well= 6334.45'. Removed a total of 209 across the collar clamps, and 12 mid jt clamps. Removed The splice clamp (splice of both lines from guages) and TEC Gua a clam . 04:00 05:00 1.00 0 0 INTRM1 RPCOh RURD P Rig down GBR equipment. Clear and organize floor. Brak out crossover from floor safet valve. 05:00 08:15 3.25 0 0 INTRM1 STK OTHR P Pickup and makeup BHA#1. Make up 8-1/2" bit, 9-5/8" scra er, bit sub with float, one stand of 5"drill pipe, jars, 5 jts of 5" HWP, then continue to pickup/makeup/ run in the hole from the pipe shed, 5"drill pipe (Rabbit to 2-5/16" . 08:15 08:30 0.25 0 0 INTRM1 STK CIRC P Filled pipe @ 2663' and circulated, pumping 800 gpm w/ 760 psi. Circulated 151 bbls. 08:30 10:45 2.25 0 0 INTRM1 STK OTHR P Continue to pickup/makeup/ run in the hole from the pipe shed, 5"drill pipe Rabbit to 2-5/16" . 10:45 11:15 0.50 0 0 INTRMI STK CIRC P Filled pipe @ 5328' and circulated, pumping 1160 gpm w/ 760 psi. Circulated 262 bbls. PU wt 160k, SO wt 132k. 11:15 11:30 0.25 0 0 INTRM1 RIGMN SFTY P Pre job safety meeting on slip and cuttin drillin line. 11:30 12:45 1.25 0 0 INTRM1 RIGMN SVRG P Slip and cut 114' of 1-3/8"drilling line. Adjust brakes on the drawworks. Monitor well on the tri tank. 12:45 13:15 0.50 0 0 INTRM1 RIGMN SFTY P Perform derrick inspection. 13:15 14:15 1.00 0 0 INTRMI RIGMN SVRG P Service top drive, blocks, and drawworks. 14:15 15:30 1.25 0 0 INTRM1 STK TRIP P Pull out of the hole on elevators with BHA #1 (9-5/8" scraper). Monitor well on the tri tank. 15:30 16:00 0.50 0 0 INTRM1 STK PULD P Lay down. Baker 9-5/8" scraper. €'aya 7 cif 2a l J i Time Logs Date From To Dur S De th E De th Phase Code Subcode T COM 03/30/2008 16:00 16:30 0.50 0 8 INTRM1 STK PULD P Pickup/makeup Baker 9-5/8" Bridge plug (Baker "K-1" Mech Cement Retainer, Size 6AA/9.6", Comm No. H400-21-6322 . 16:30 18:45 2.25 0 0 INTRM1 STK TRIP P Trip in the hole picking up 5"drill pipe from the pipe shed. Monitor well on the trip tank. PU wt 125k, SO wt 115k. A total of 93 'ts icked u . 18:45 19:30 0.75 0 3,535 INTRM1 STK TRIP P Continue to run in the hole with the 9-5/8" bridge plug. Run 6 stands from the derrick, then pickup a single of 5" HWDP. PU wt 135k, SO wt 120k. 19:30 19:45 0.25 3,535 3,535 INTRM1 STK OTHR P Set bridge plug top @ 3535'. Then lay down the 5" HWDP. 19:45 20:15 0.50 3,535 3,535 INTRM1 DRILL RURD P Rig up testing equipment to test casing. Fill 2" hose with fluid. circulate air out of the kill line. 20:15 21:15 1.00 3,535 3,535 INTRM1 DRILL DHEQ P Test the 9-5/8" casing and bridge plug to 3000 si. Test for 30 minutes. Chart test. Pumped @ 4 spm w/ a total of 36 strokes um ed. Good test. 21:15 21:30 0.25 3,535 3,535 INTRM1 DRILL RURD P Rig down testing equipment. Blow down the kill line. Bring whipstock tools to the floor. 21:30 22:45 1.25 3,535 3,535 INTRMI STK TRIP P Pull out of the hole with Baker running tool. 22:45 23:00 0.25 3,535 3,535 INTRM1 STK PULD P Lay down the Bridge plug running tool. 23:00 00:00 1.00 3,535 3,535 INTRM1 STK PULD P Pickup and run in the hole 30 jts of 5" drill i e. Rabbit to 2-5/6". 03/31/2008 00:00 00:45 0.75 1,050 0 INTRM1 STK TRIP P Pull out of the hole with 10 stands of 5" HWDP. Stra drill i e. 00:45 02:00 1.25 0 0 INTRM1 STK WPST P Pickup milling BHA: Make up mills with MWD, stand back in the derrick. 02:00 02:30 0.50 0 27 INTRMI STK PULD P Pickup 9-5/8"whipstock, make up to the mills. wei ht 10k . 02:30 03:00 0.50 27 27 INTRM1 STK OTHR P Orient Sperry Sun MWD to whipstock. 03:00 04:15 1.25 27 100 INTRM1 STK OTHR P Upload software for Sperry Sun MWD. 04:15 05:30 1.25 100 1,050 INTRM1 STK TRIP P Pickup Baker bumper sub, then run 10 stands of 5"drill i e. 05:30 05:45 0.25 1,050 1,050 INTRMI STK OTHR P Shallow pulse test MWD. Pumping 650 gpm w/ 1360 psi. PU wt 120k, SO wt 125k. 05:45 07:45 2.00 1,050 3,430 INTRM1 STK TRIP P Trip in the hole with 9-5/8" whipstock. Fill pipe every 25 stands.Monitor well on the trip tank.. PU wt 150k, SO wt 125k. 07:45 08:15 0.50 3,430 3,520 INTRM1 STK OTHR P Fill pipe. Orient whipstock to 60 deg right of high side. Work pipe from 3430' to 3520'. Pumping 625 gpm w/ 1540 si. I~ago $ of 2~ ~,. • • Time Lo s Date From To Dur 5. De th E. De th Phase Code Subcode T COM 03/31/2008 08:15 08:30 0.25 3,520 3,535 INTRMI STK TRIP P Pick up a single of 5" HWDP, RIH to set down on the retainer@ 3535'. Set down, observed shear @ 105k on the weight indicator (20k) to shear anchor. Slacked off a couple of times with bumper sub to shear mills bolt. Top of whipstock 3513'. After Free from whipstock: PU wt 150k, SO wt 128k. 08:30 08:45 0.25 3,535 3,505 INTRM1 STK OTHR P Lay down single of 5" HWDP. Pre job safety meeting on displacement from 8.5 ppg seawater to 9.0 ppg LSND mud. 08:45 09:00 0.25 3,505 3,505 INTRM1 STK CIRC P Displace well to 9.0 ppg LSND mud. Pumping 625 gpm w/ 1310 psi. Pum ed a total of 251 bbls. 09:00 09:15 0.25 3,505 3,513 INTRM1 STK CIRC P Obtain slow pump rates. Rotate down to the top of the whipstock @ 3513'. 60 r m 8-9k ft Ibs of for ue. 09:15 12:00 2.75 3,513 3,522 SURFA STK WPST P Mill window in the 9-5/8" 40ppf L-80 BTC-M casing from 3513' to 3522'. Rotate 80 rpm w/ 7-8k ft Ibs of torque on bottom and 6-7k ft Ibs off bottom. Weight on mills 4K. Pumping 425 gpm 1 ~ ~ .- ~ w/ 680 psi. PU wt 150k, SO wt 128k. Rotating weight 138k. Pump a 40 bbls high vis sweep while milling @ 3520' (middle of window). Observed 20% increase in cuttin s. 12:00 14:00 2.00 3,522 3,549 SURFA STK WPST P Continue to mill window in the 9-5/8" 40ppf L-80 BTC-M casing from 3522' to bottom of the window @ 3530' continue milling to 3459' to get upper i mill to the bottom of the window. Weight on mills 4K. Rotate 80 rpm w/ 7-9k ft Ibs of torque on bottom and 7k ft Ibs off bottom. Pumping 425 gpm w/ 680 psi. PU wt 150k, SO wt 128k. Roting weight 138k. Top of window @ 3513' (2448' TVD), Bottom of window @ 3530' (2455' TVD . 14:00 15:30 1.50 3,549 3,549 SURFA STK CIRC P Circulate and work window. Pump a 40 bbls high vis sweep. Pump two bottom's u .Hole cleaned u ood. 15:30 16:00 0.50 3,549 3,507 SURFA STK TRIP P Pull out of the hole one stand. Blow down the top drive. Rig up for leak off test. 16:00 16:45 0.75 3,507 3,507 SURFA DRILL LOT P Perform leak off test using 8.9 ppg LSND mud. Hole depth 3549' (2463' TVD), TOW 3513' (2448' TVD), BOW 3530' 2455' TVD). LOT was 12.2 ppg EMW with 420 si.. 16:45 17:15 0.50 3,507 3,507 SURFA DRILL RURD P Rig down testing equipment. 17:15 18:00 0.75 3,507 3,057 INTRM1 DRILL OWFF P Monitor well. Mix dry job, clean trip tank. ~+~~e 9 of 25 if V~iL~ ~~L7 T~~-1/ V~~Vf~f-1 L `~.. a., ProActive Diagnostic Services, Inc. To: ACIGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTl The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) Caliper Report 15-Mar-08 2) ~~~~~ ~~~ 6} ~ 2~a~ Signed Print Name: 1 G172 1 Report / EC1E 50-029-23159-00 ~a3-a~ S ~1~0~~/ ;;~ Date PROACTIVE DIAGNOSTIC SERVICES, fNC., 130 W. (NTERNATroNAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: p~sa~~~aosacdefc~t~ers~dc~lds~€~.~s~saa WEBSITE: ~~rv~r~.~*ae~*orH!®g.~.~laa C:1Documents and Settings\Owne~Desktop\Transmit_Conoco.doc • • Memory Mufti-Finger Caliper Log Results Summary Company: ConocoPhillipsAlaska, Inc. Well: 1C-172 Log Date: March 15, 2008 Field: Kuparuk Log No.: 6701 State: Alaska Run No.: 1 API No.: 50-029-23159-00 Pipet Desc.: 4.5" 12.61b L-80 IBT-M Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 6,400 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the Camco DB Landing Nipple w/no Go hrotile @ 6,379' (DriHer's 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 condition, with no sign cant wall penetrations (> 11°~), areas of significant cross sectional wall loss (> 7%) or I.D. restrictions recorded throughout the interval logged. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 11%) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cxoss-sectional wall loss (> 7%) are recorded throughout the interval logged. MAXIMUM RECORDED iD RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval logged. ~~t~ ~iQ~ ~ ~~QB Field Engineer: N. Kesseru Analyst: HY. Yang Witness: C. Kennedy PreACtive Diagnostic Services, Irc. / P.O. Box 1369, Stafford, TX 77497 Phase: {281} or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS;c~memorylog.com Prudhoe Bay Feld gffice Prone: ;907) 659-2307 Fax: (907) 659-2314 c703`0~~ ~ ! (00~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (9.8' - 6386.8') Well: 1 C-172 Field: Kuparuk Company: ConocoPhidips Alaska, Inc. Country: USA Survey Date: March 15, 2008 . A pprox. Tool D eviation ^ A pprox. Boreh de Profi le 16 780 1539 2300 3062 ~ GLM 1 .~ L 3854 ~ 4617 5384 GLM 2 6152 205 6387 0 5 0 1 00 Dam age Pro file (% wall) / Tod D eviation (degre es) Bottom of Survey = 205 1 25 50 75 100 v .n Z .0 125 ' ~ 150 175 • • PDS Report Overview ~ sµ Body Region Analysis Well: 1C-172 Survey Date: March 15, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ,~. metal loss body 250 200 150 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 ro 40 ro over 40% 85% 85% Number of 'oints anal se d rotal = 220 pene. 0 219 1 loss 30 190 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profli a (% wall) ~ penetration body ; metal loss body 0 50 100 0 47 97 GLM 2 145 195 GLM 1 Bottom of Survey = 205 Analysis Overview page 2 • i PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-172 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Com an ConocoPhitlips Alaska, Inc. Nominal I.D.: 3.958 in p y' Country: USA Survey Date: March 15, 2008 _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Well: 1C-172 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: March 15, 2008 Joint No. Jt. Depth (Ft.) I'~~n. III<~_,t !im ~ Pen. Body (Ins.) I'c~n. °it, ~1~•t,~l I~„s ,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1418 ~ ? 0.01 a ~ .93 47 1449 ~ ~ 0.02 t3 3.94 48 1479 U 0.01 ~~ .90 49 1509 U 0.02 tS 3.91 50 1539 i ~ 0.01 ~' -1 .91 51 1569 i ~ 0.01 _' ~ 3.93 52 1600 O 0.02 (~ I 3.93 53 1631 t ~ 0.01 -1 3.89 54 166 i ~ 0.01 ~ 3.92 55 1693 t ~ 0.01 4 1 3.89 56 1723 i? 00 U .92 57 1753 a 0.01 ~ 3.92 58 1782 t I 0.01 ~ ~' 3.94 59 1812 i I 0.01 ~' 3.92 60 1843 t I 0.01 -t 3.76 61 187 ti 0.01 ~3 I 3.93 62 190 U 0.03 ~) I 3.87 63 1934 c ~ 0.03 1 U 3. 3 64 1964 t~ 0.02 ti 3.81 65 1994 + ~ 0.01 4 1 3.88 66 2026 ii 0.02 ~~ -t 3.91 67 2057 (~ 0. 1 4 3.91 68 2087 i ~ 0.01 ~ ~ 3.94 69 2118 i~ 0.02 t3 3.94 0 14 i~ 1 ~ 1 71 2180 t ~ 0.01 ~' - 3.95 7 2209 i ~ 0.01 5 3 92 73 2239 t~ 0.01 ~ .' 3.91 74 2270 tl 0.01 .93 75 2300 a 0.01 ~ ' 3.94 7 332 t ~ 0.01 ~ 3 94 77 2362 a 0.01 ~ ~' 3.93 78 2393 U 0.01 ~ :' 3.93 79 2424 a 0.01 s ? 3.93 80 2455 U 0.01 ~' 3.93 81 2486 t ~ 0.01 3.94 82 2516 U 0.02 `~ ! 3.93 83 2547 t ~ 0.01 •1 I 3.96 84 2578 t? 0.0 t 3.95 85 2608 t~ 0.01 4 3.93 86 2636 t? 0.02 ti _' 3.83 87 2666 l~ 0.01 _' 3.93 88 2696 i I .O1 4 I 3.91 89 2727 it 0.01 3.93 90 2758 ii 0.01 _' ? 3.93 91 2 788 a 0.01 S -t 3.94 9 2818 ~ ~ 0.03 1 U 3.93 93 2849 i~ 0.01 ; (~ 3.93 94 2881 t~ 0.01 t -k 3.94 95 2910 ii 0.02 ~i ~ 3.92 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Well: 1C-172 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: March 15, 2008 Joint No. Jt. Depth (Ft.) I'~~n. lll~s~~t Iln.) Pen. Body (Ins.) N<~n. %> M~~t,~l Io,S `;~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2940 U 0.01 3 7 3.92 97 2971 ~~ 0.01 3 -1 3.93 98 3001 ~ ~ 0.01 ' 3.93 99 3031 c i 0.01 .94 100 3062 Il 0.01 ? I 3. 3 101 3092 U 0.01 ~ ~ 3.91 102 3123 U 0.01 4 ~ 3.92 103 3152 1 ~ 0.01 s 3.43 104 3183 t) 0.01 ~~ _' 3.88 105 3215 t ~ 0.01 4 _' 3.85 106 3247 U 0.01 3 ..' 3.92 107 3278 ~ t 0.01 Z I 3.93 108 3309 ~.~ 0.01 1 ~' 3.91 109 3339 ~.? 0.01 ~' ~' 3.93 109. 3369 U 0.01 4 I 3.95 PUP 109.2 3373 ~ ~ 0 ~ ~ ~ ~ N A G M 1 Latch ~ 7:30 109.3 3384 U 0.01 3.95 PUP 110 3388 U 0.01 2 3.93 111 3418 ~ ~ 0.03 9 3.92 112 3449 U 0.01 2 3.89 113 3481 a 0.01 3 _' 3.93 114 351 l? 0.01 ~ 4 3.85 115 3544 ~? 0.01 i 3.92 116 3575 ~ ~ 0.01 3 _' 3.93 117 3606 t ~ 0.01 3 3.92 118 3637 ~~ 0.01 4 i 3.94 119 3668 ~! 0.01 ? 1 3.93 120 3698 ~~ 0.01 3 3 3.92 121 3729 U 0.01 2 _' 3.93 122 3759 ~~ 0.01 4 ~' 3.93 123 3790 ~ ~ 0.02 ~) ; 3.92 124 3822 U 0.02 9 ~' 3.91 125 3854 tt 0.01 ~ ~ 3.91 126 3884 a 0.02 ti 3.92 1 7 3916 ~ ~ 0.01 3.95 128 3948 U 0.01 4 3.93 129 3979 ~ ~ 0.01 ~ 3.92 130 4009 t~ 0.01 3 3.94 131 4040 ~ ~ 0.01 ~' _' 3.93 132 4070 ~ ~ 0.01 ? I 3.91 133 4102 ~~ 0.0 ~ Z 3.93 134 4132 ~ ~ 0.01 4 ~' 3.93 135 4162 ~ ~ 0.01 ~ 3.92 136 4193 U 0.02 ~) 3.89 137 422 U 0.02 6 I 3.92 138 4253 a 0.01 3 ~ 3.91 139 4283 U 0.02 tt ~ 3.93 140 4314 ~ ~ 0.03 1 I ~ 3.92 141 4344 ~ ! 0.01 ~ 3.88 142 4373 ~ ! 0.01 3.93 _. Penetration Body Metal Loss Body Page 3 i ~ PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 1 C-172 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: March 15, 2008 Joint No. )t. Depth (Ft) I'c~n. UI>x~t (tn>.) Pen. Body (Ins.) Prin. % :Mcr~l I cx~ ?~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 143 4404 (~ 0.01 3 ? 3.94 144 4435 ) ~ 0.01 ~ 3.92 145 4465 U 0.01 4 I 3. 146 4496 U 0.01 3 3.93 147 4526 tt 0.01 3 ' .93 148 4557 l1 0.01 ~' (, 3.9 149 4588 ~) 0.03 I t) 3.93 150 4617 ~) 0.01 ~ 3.92 151 4648 U 0.01 3 5 3.93 15 4679 U 0.01 4 3.91 153 4710 O 0. 2 t3 5 3.9 154 4740 ~) 0.02 8 v 3.93 155 4771 ~) 0.01 3 ~ 3.93 156 4802 I) 0.01 2 ~ 3.91 157 4833 ~ ~ 0.01 ? '~ 3.92 158 4863 ~) 0.01 ~' I 3.94 159 4893 ~) 0.01 1 - 3.93 160 4923 t) 0.01 ~ 3.93 161 4954 ~) 0.01 i 3.93 162 4985 ! ~ 0.01 3.94 163 501 ~ ~ 0.01 s ! . 3.93 164 5046 ~) 0.02 ~) I 3.93 165 5075 ~) 0.01 2 t~ 3.96 166 5106 U 0.01 3 3.94 167 5137 ~) 0.0 3 .86 168 5169 0 0.01 3 s 3.94 169 5199 ~ ~ 0.02 8 ~ 3 92 170 5230 ~ 1 0.01 3 t 3.94 171 5261 t) 0.01 4 3.93 172 5291 t) 0.01 ~ 3.94 173 5322 ~) 0.01 I 3.93 174 5352 ~ ~ 0.01 ~ + 3.93 175 5384 ~) 0.01 ~ 3.93 176 5414 ~ 1 0.01 _' -1 3.93 177 5445 t) 0.01 ) 3.92 178 5476 O 0.01 3 3.94 179 5507 i) 0.01 3 t; 3.93 180 5538 t) 0.01 ; 3.88 181 5569 I) 0.01 s I 3.86 182 5599 ~~ 0.01 3 -l 3.90 18 5630 ~) 0.01 3 4 3.86 184 5662 ~) 0.01 2 ~ 3.94 185 5693 I) 0.01 t _' 3.94 186 5724 I) 0.02 £3 ~' 3.93 187 5755 U 0.01 3 3.94 1 5786 U 0.02 8 3.93 189 5815 U 0.01 ~ t s 3.93 190 5847 ~) 0.01 4 3.87 191 5875 ~ ~ 0.01 -? 3.92 192 5906 ~ ~ 0.01 1 3.94 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 1C-172 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhiNips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: March 15, 2008 Joint No. Jt. Depth (Ft.) I'e•n. I )I~sc•t IInS.) Pen. Body (Ins.) I'en. %~ ~Ie•).il I ~~,~ °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 5936 U 0.01 3 ~' 3.93 194 5967 ~) 0.01 ~ ? 3.94 195 5998 ~) 0.02 £3 ? 3.93 196 6028 ~ ~ 0.03 I t) ~ 3. 3 197 6059 i) 0.01 ~ 3.94 198 6090 I ~ 0.01 ~' ~ 3.93 199 6122 ~! 0.02 £i 3.94 200 152 a 0.01 .? > 3.92 201 6184 ~) 0.01 3 ~ 3.93 201.1 6215 U 0.01 ~ I 3.94 PUP 01.2 6218 ~) 0 O t) N A GLM Latch®10:30 201.3 6229 )t 0.02 £3 ~ 3.94 P P 202 6234 ~) 0.01 •~ 3.91 202.1 6265 ~~ 0.02 ~t 3.94 PUP 202.2 6271 t) 0 ~) ~) 4.50 Baker 925 Gu rdian au e Carrier 2 .3 6273 U 0.01 ? 1 3.93 PUP 203 6277 U 0.02 ti 3.94 203.1 6308 ~) 0.02 ~) ~' 3.95 PUP 03.2 6315 )) 0 t) I ~ 3.81 Bake CMU Slidi Sleeve 203.3 6322 )1 0.02 ti I 3.94 PUP 204 6330 U 0.01 ~~ I 3.95 204.1 6362 U 0.01 ~ 1 3.95 PUP 204.2 6367 ~) 0 U U 4.50 Baker 925 uar ian Gau e Carrier 204.3 6369 U 0.01 1 I 3.95 PUP 204.4 6373 ~1 0.01 2 Z 3.9 PUP 204.5 6379 U 0 l) t) 3.75 Camco DB Landin Ni le w no Go Profile 204.6 6381 U 0.02 ~) 2 3.95 PUP 205 6387 t1 0.02 £3 i 3.93 Penetration Body Metal Loss Body Page 5 e t ConocoPhillips Alaska, Inc. KRU 1 C-172 '' ~c-~ API: 500292315900 Well T : PROD An le TS: d TUBING I°-s52t, oD:a SOO SSSV Type: Nipple Orig Com letion: 624/2003 Angle @ TD: 73 deg @ 11970 . , ID:3.958) Annular Fluid: Last W/O: Rev Reason: Ta FiA Reference L : 28' RKB Ref L Date: Last U ate: 425/2004 Last T : 9395 CTMD TD: 11970 ftKB Last Ta Date: 4/19/2004 Max Hole An le: 99 d 7718 Cesin Strin -ALL STRINGS Descri tan Size To Bottom TVD Wt Grade Thr~d CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 9.625 0 6712 3823 40.00 L-80 BTC-M SLOTTED LINER 5.500 6521 11960 3930 15.50 L-80 H dri1511 ®, ~ Tubin Strin -TUBING Size T Bottom TVD Wt Grade Thrsad 4.500 0 6521 3780 12.60 L-80 IBT-M Perforetions Summ Interval TVD Zone Status Ft SPF Date T Comment 6788 - 11880 3838 - 3908 WS A4,WS A3,WS A2,WS A3,WS A4,WS A3,WS A2,WS A3,WS A4,WS A3,WS A2 5092 16 6232003 IPERF Perforated Casing, 1" Holes every other joint; total 65 perfjts run G Ma ndr el ahr St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3378 2387 CAMCO KBG-2 GLV 1.0 BK 0.156 1481 0/18/200 2 6221 3677 CAMCO KBG-2 OV 1.0 BK-5 0250 0 0/18200 Other lu s ui . etic. -JEWELRY ~'~"c De th TVD T Descri lion ID (sszt-s5~s, OD:5.500) 18 18 HANGER VETCO GRAY GEN 1 TUBING HANGER 4.500 505 505 NIP CAMCO 'DB' LANDING NIPPLE 3.875 6271 3696 Gauge Carrier BAKER 925 GUARDIAN GAUGE CARRIER 4.500 6316 3714 SLEEVE-C BAKER CMU SLIDING SLEEVE cbsed 9262003 3.812 6367 3732 Gauge Carrier BAKER 925 GUARDIAN GAUGE CARRIER 4.500 6379 3736 NIP CAMCO'DB' NIPPLE WMO GO PROFILE 3.750 6545 3786 SEAL BAKER SBR -GBH-22 SEAL ASSEMBLY 4.750 Other lu s ui .etc. -LINER JEWELRY 5.5' PERF CSG 1' hdes altema ' 43' ' iota De th TVD T Descri lion ID 6521 3780 TIE BACK TIE BACK SLEEVE 7.510 6521 3780 CASING BLANK CASING LINER, ALTERNATING IN 44' SECTIONS WITH PERFORATED SLOTTED LINER 3.958 6533 3783 PACKER ZXP LINER PACKER WMR PROFILE 6276 6535 3783 NIPPLE RS NIPPLE 6.190 6538 3784 HANGER FLEX-LOCK HYDRAULIC LINER HANGER 6260 6548 3787 XO BUSHING 4.880 6550 3787 SBE SEAL BORE EXTENSION 4.750 ~ ~ 6568 3792 XO 4.920 6788 3838 Sbtted Liner 3.958 ~ 6831 3846 CASING BLANK CASING 3.958 Pert ' ' 6875 3854 Sbtted Liner 3.958 ~s~eattaeo) _ 6919 3863 CASING BLANK CASING 3.958 11960 3930 SHOE 3.958 ^ ^'- • • ~.,.. ~~°~ -~. ~w~ ~r MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CbrPgs_In~~rts\Microfilm_Marker.doc • }~~~~ ~ "$ L ~-~ ~~a rv ~~ ~ ~ SARAH PALIN, GOVERNOR `+O1~T~+L~D~I~O ^ ~~+ I ~ 333 W 7th AVENUE, SUITE 100 1~~7~illi~~t'si~ ~.o•••~~.~~~u11~~,ii~iii----777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Wells Group Engineer Conoco Phillips Alaska, Inc. PO Box 100360 y Anchorage, Alaska 99510 ®, ,~ Re: Kuparuk River Field, West Sak Oil Pool, 1 C-172 Sundry Number: 308-025 Dear Mr. Schwartz: ~~~~ JARS ~ ~ 208 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ?3day of January, 2008 Encl. Sincerely, • ConocoPhillips January 18, 2008 Commissioner State of Alaska Alaska Oi{ & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 C-172 Dear Commissioner: • Guy Schwartz Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 1~ JAN 1 8 2~~8 AtasCka Oil ~ Gas Cor1~. GomrTtiscion Anchorage ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming well work on the Kuparuk well 1 C-172. If you have any questions regarding this matter, please contact me at 265-6958. Sincerely, - r ~~... f ,W G. S~i'~hwartz ~ ~,~._~_.:} W~IIs Group Engineer CPAI Drilling and Wells GS/skad ~ ~" ~~ Z3~~ ~ I~/D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION +: ~~ JAN 1 ~ 2Q0$ APPLICATION FOR SUNDRY APPROVA~aska oil.&Gas cons. C~IrnmisSiOti 20 AAC 25.280 Anrhnr~nn 1. Type of Request: Abandon ^/ ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 203-095 3. Address: Stratigraphic ~ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23159-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ - 1C-172 - 9. Property Desi ation: q pp Z `~' ~' ~~~ ~~~'~ ! °'~ 10. KB Elevation (ft): 11. Field/Pool(s): / k l - ADL , ALK 2571 6. 1~ - , RKB 89' Kuparuk River Field West Sa Oil Poo 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11970' 3933' 11960' 3924' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80~ 16" 80' 80' SURFACE 6712' 9-5/8" 6712' 3816' PRODUCTION 5248' 5-1/2" 11960' 3924' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6788'-11880' 3838'-3908' 4-1/2" J-55 6521' Packers and SSSV Type: Packers and SSSV MD (ft) Baker PBR/SBR @ 6545' Camco 'DB' nipple @ 505' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development Q Service ^ 15. Estimated Date for 16. We11 Status after proposed work: ~/ t/?j Z Commencin O erat Februa 1, 2008 g p ry Oil h ~ Z p Gas ~7 ^ Plugged L~ !'Z Abandoned 17. Verbal Approval: Date: WAG ^ 1' 1 GINJ ^ WINJ ^ WDSPL ~ b Commission Representative: Y~?iZ 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GUV SChWattz Title: Wells Group Engineer Signature ~~ Phone 265-6958 Date ._~~ °'Q ~, Commission Use Onl ti h i Sundry1.Uu b ~ ~ ,1~~ v ve may w at a representa tness Conditions of approval: Notify Commission so t C~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: °~ `JO~ ~~\ '1~~ ~~ ~v'~`-~.~~ ~ '~~ S~ 7 Subsequent Form Required: ~~~ APPROVED BY /~ I) ~j ~D J ~^ Approved by: C S I THE COMMISSION Date: ~ Farm 10-403 Revised 06!2006 Submit in Duplicate ~~ /•Z2,cs8 • 1 C-172 16" Conductor @ 107' 1 C-'172 Undulating A-Sand Producer 41/1", 11.1~f, L-ttU,ltil lUbing • 9 5/8", 40#, L-80, BTC @ 6,712' MD/ 3,816' TVD • ~• TOL@ ~• • • 6,527 • • •• • _• • 5 1 /2",15.5#, L-80, Hydril 511 @11960' MD/ 3,927' ND • _. Perforated with 1" holes Every other joint from 6,780' to 11,880' 1 C-172 was a precurser to the multilateral systems run later. The idea was to undulate through the entire A-sand (A4,A3,and A2) and thereby save costs by not running and individual lateral through each sand. Upon producing the well we found that the formation was not competent enough to with stand the draw down and as a result the interbedded shales came in and completely plugged the well. ,/ The well was cleaned out once with the same result when placed back on production. Future planning: The well is to be cleaned out as far as possible with coil tubing, then a cement plug will be placed from that point back to the top fo the 5 1/2" liner top at +/-6,527' The present completion has an SBR stabbed into the PBR of the liner top at 6,521', therefore in order ,/ to P&A we will be placing cement inside the 5 1/2" liner and then perform a hesitation squeeze This is all in preparation for sidetracking 1C-172 and redrilling it at a tri-lateral producer. P&A Procedure Pre-rig Component 1. MIRU coil tubing and RIH with nozzle. 2. Working through the 4 1/2" production tubing, cleanout 5 1/2" liner as far as possible 3. Begin pumping Class G cement. (Total liner volume is approx. 350 bbls.) 4. Pull up CT laying in cement 1 - 1. Stop at 6450 and squeeze away cement. 5. Circulate clean the 4 1/2" production tubing(TOC to be 6450') 6. POOH with CT and freeze protect. 7. RU SL, tag TOC and pressure test cement plug to 1500 psi. ---~ ro~~-act ~~n~C.~O~--~ r,~~t~~S~ 8. RIH and shift CMU at 6316' and open. RD SL. r ~~~~ ~~ ~/~~ • 9. RU Eline and perform jet cut at 6350' and (below CMU) 10. RD Eline 11. Set BPV and VR plug. Rig P & A Component ~,~ ~O p ~ des ~ ~a- 35<~es ~ ~t o~~r`v M 1. Pull 4 1/2" tubing 2. PU Drill pipe and 9 5/8" BP. 3. RIH to +/-3500'., set BP, circulate, test BP to 1500 psi, POOH 5. MU whipstock assembly and RIH. Tag CIBP ,shear off and begin drilling sidetrack. . ~~ ~~» • ~~ Cunc~coRhilCps Alaska inc. 14~.1/L API: 500292315900 Well T e: PROD An le TS: de TUBING SSSV Type: Nipple Orig 6/24/2003 Angle @ TD: 73 deg @ 11970 (o~5zt, OD:4 500 ~ Com letion: . , ID:3.958) Annular Fluid: Last W/O: Rev Reason: Ta Fill ~ Reference Lo : 28' RKB Ref Lo Date: Last U date: 4/25/2004 Last Ta : 9395 CTMD TD: 11970 ftK6 Last Ta Date: 4/19V2004 Max Hole Angle: 99 dew c~7718 ~ _ ~ - ~ Casing_String -ALL STRINGS _ _ Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 9.625 0 6712 3823 40.00 L-80 BTC-M SLOTTED LINER 5_.500 6521 11960 __ 3930 15_.50 L-80 H dril 511 - Tubin Strin - TUBING ' Size __~ To _ Bottom 6 TVD _ Wt Grade Thread 521 4.500 ) 0 3780 12~ L-80 !~_ IBT-M _ Perforations Summer __ __ _~. _ Interval TVD Zone Status Ft SPF Date T Comment 6788 - 11880 3838 - 3908 WS 5092 16 6/23/2003 IPERF Perforated Casing, 1" Holes A4,WS every otherjoint; total65 4 A3,WS perfjts run ~ ~ L ~'~ A3,WS A4, WS ~_ _ ~. A3,WS _ A2,WS A3,WS A4, WS A3,WS A2 Gas Lift MandrelsNalves _ _ St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vhr Mfr Run Cmnt __ 1 3378 2387 CAMCO KBG-2 GLV 1.0 BK 0.156 1481 10/18/200 ~ ~',~ 2 6221 3677 CAMCO KBG-2 OV 1.0 BK-5 0.250 0 10/18/200 izP. Other lu s e ui .etc. -JEWELRY _ cASwc ~ -- De th TVD T e Descrl lion ~ ID (s5z~-ss~s, [ 18 18 HANGER VETCO GRAY GEN 1 TUBING HANGER 4.500 505 505 NIP CAMCO'DB' LANDING NIPPLE 3.875 6271 3696 Gauge Carrier BAKER 925 GUARDIAN GAUGE CARRIER 4.500 6316 3714 SLEEVE-C BAKER CMU SLIDING SLEEVE, closed 9/26!2003 3.812 6367 3732 Gauge BAKER 925 GUARDIAN GAUGE CARRIER 4.500 Carrier 6379 3736 NIP CAMCO'DB' NIPPLE W/NO GO PROFILE 3.750 6545 3786 SEAL BAKER SBR -GBH-22 SEAL ASSEMBLY 4.750 Oilier lu s e ui .etc. =LINER JEWELRY (5.5" PERF CSG, 1" holes alternating 43' oints ' De th TVD T e Descri lion ID ~ 6521 3780 TIE BACK TIE BACK SLEEVE 7.510 6521 3780 CASING BLANK CASING LINER, ALTERNATING IN 44' SECTIONS WITH 3.958 ~ ~'., ~;<;. PERFORATED SLOTTED LINER 6533 3783 PACKER ZXP LINER PACKER W/HR PROFILE 6.276 __ 6535 3783 NIPPLE RS NIPPLE 6.190 6538 3784 HANGER FLEX-LOCK HYDRAULIC LINER HANGER 6.260 6548 3787 XO 4.880 . :zz BUSHING r. 6550 3787 SBE SEAL BORE EXTENSION 4.750 ~ ~ 6568 3792 XO 4.920 6788 3838 Slotted 3.958 Liner ~ ~ ~ ____ 6831 3846 CASING BLANK CASING 3.958 ~ ~ - - 6875 3854 Slotted 3.958 - Pert - Liner (sass-ttsao) _ _. _ _-L = 6919 3863 CASING BLANK CASING 3.958 - - 11960 3930 SHOE 3.958 -'_ . . "- t ~ - --- ~ ti -. -- ^ ^ --.. -_L _- - [ -[; - J • KRU 1 C-172 . . ConocJPt,illips Alaska RECEIVED APR 1 8 Z007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 16,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 (~PyoC(ç Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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, ~~~-~/ 5CANNE1D APR 1 8 2007 ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field April 16,2007 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 cat 1 C-25 119-031 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1C-119 201-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1C-121 201-080 11' 2.0 18" 4/8/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 4/8/2007 6.8 4/15/2007 1C-135 201-220 11' 1.3 10" 4/8/2007 2.4 4/15/2007 1C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14' 6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/15/2007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 ;f.-. L( J"7~ ^~ ~ ~- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030950 Well Name/No. KUPARUK RIV U WSAK 1C-172 Operator CONOCOPHILLlPS ALASKA INC Spc.\.d. /1 JVNI. ÀcX) .~ API No. 50-029-23159-00-00 MD 11970·---- NO 3933 -/ Completion Date 6/24/2003-- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Rpt ED ED Directional Survey 12009 tiC VClifil;afton' M1I\1i-~p~'¡f ~J..I 12009 Induction/Resistivity 2,3,4 25 Final 25 Final C ,kJ) C Pdf Gf, ED C Pdf 12009 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? vt;) Chips Received? ,"'- V / N Daily History Received? Formation Tops Analysis Received? .~¥} N - Comments: Compliance Reviewed By: ~ . Current Status 1-01L UIC N --- --~- -- ---- - Directional Survey Ç) _____ ~_. --=--=-=_:--=-~- --- (data taken from Logs Portion of Master Well Data Maint) ,- , Interval OH / Start Stop CH Received Comments -------- 0 11970 Open 7/15/2003 2140 11970 Open 8/18/2003 138 11970 Open 8/18/2003 138 11970 Open 8/18/2003 RWD - Multiple Propagation Resistivity - MD RWD - Multiple Propagation Resistivity - TVD -------- Sample Set Number Comments @N {YN ----------- ----- -------- Date: '{¡ l) ,---:-:----=~~-~~~- --~- o I~) ~N ~.- ~ Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 August 18, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1C-172 (APD # 203-095) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-172. If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, l~\~ R. Thomas . Kuparuk Drilling Team Leader CPAI Drilling RT/skad :i:~ ORIGINAL ( STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ GINJ D 2. Operator Name: WINJ D WDSPL D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Suriace: 1436' FNL, 1096' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: 541' FSL, 1923' FEL, Sec. 2, T11N, R10E, UM Total Depth: 324' FSL, 2280' FEL, Sec. 11, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Suriace: x- 562102 y- TPI: x- 559067 y- Total Depth: x- 558758 y- 18. Directional Survey: Yes 0 NoU 5968801 5970754 5965255 Zone-4 Zone-4 Zone-4 21. Logs Run: GR/Res 22. Suspended 0 WAG D 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: June 24, 2003 ~ 6. Date Spudded: June 11, 2003 7. Date TO Reached: June 21, 2003 8. KB Elevation (ft): 87' AMSL 9. Plug Back Depth (MD + TVD): 11970' MD 1 3933' TVD 10. Total Depth (MD + TVD): 11970' MD 1 3933' TVD 11. Depth where SSSV set: Land Nipple @ 505' 19. Water Depth, if Offshore: N/A feet MSL 1 b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 203-095 1 13. API Number: 50-029-23159-00 14. Well Name and Number: 1C-172 15. FieldlPool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25649 17. Land Use Permit: ALK 467 20. Thickness of Permafrost: 2915' MD CASING SIZE WT. PER FT. 62.5# 40# 15.5# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Suriace 138' 42" 638 sx ArticCrete Suriace 6712' 12.25" 860 sx AS III Lite, 420 sx Class G 6570' 11960' 8.5" pre-perforated liner 16" 9.625" 5.5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): pre-perforated liner from 11880' - 6788' MD 24. SIZE 4.5" AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6564' PACKER SET (MD) 6534' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A Form 10-407 Revised 2/2003 CONT'NUIT~TGEí ~ A L 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 27,2003 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 7/27/2003 10 hours Test Period n> 278 38 0 0 138 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) not available not available 24-Hour Rate -> 660 91 0 not available 27. CORE DATA Submit core chips; if none, state "none". Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ~ 1.,"\1, 'J?:ì 1...·-"....--,.. ¡ "(>. 'D' f"'r'~J ~ L..';~I.ji,-L,.: :uN , i~ n.t"':""r" ~ ,¡ ...,.,. ,.. I l_b..~·;J!f81 \ \·U:J\.l' ¡ l. ;:,:~,'"~;~:.~J NONE Submit in duplicate ~f 28. ( GEOLOGIC MARKERS 29. It FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 C-172 West Sak B West Sak C West Sak D 6559' 6498' 6377' 3790' 3774' 3736' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed Na~ _ . R. ~omas~ Signature \. ~ \ Title: .E.Lt>ne Kuparuk Drilling Team Leader Date -8 ((-'j 10 s Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval), Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas I njE:!ction , Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 ORIG\NAL ( i{ Page 1 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-172 Common Well Name: 1 C-172 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 6/10/2003 08:00 . 10:00 2.00 MOVE DMOB MOVE 10:00 . 11 :00 1.00 MOVE POSN MOVE 11 :00·12:00 1.00 MOVE POSN MOVE 12:00 - 13:00 1.00 MOVE POSN MOVE 13:00 - 13:45 0.75 MOVE POSN MOVE 14:45 - 15:00 0.25 MOVE OTHR MOVE 15:00 - 16:00 1.00 MOVE OTHR MOVE 16:00 - 19:00 3.00 MOVE OTHR RIGUP 19:00-21:15 2,25 MOVE OTHR RIGUP 21 :15 - 22:15 1.00 MOVE OTHR RIGUP 22:15 - 00:00 1.75 MOVE OTHR RIG UP 6/11/2003 00:00 - 01 :30 1.50 DRILL PULD RIG UP 01 :30 - 02:30 1.00 DRILL PULD RIGUP 02:30 - 03:00 0.50 WELCTL BOPE RIGUP 03:00 - 04:00 1.00 RIGMNT RSRV RIGUP 04:00 - 05:00 1.00 DRILL PULD RIG UP 05:00 - 05:30 0.50 DRILL OTHR RIGUP 05:30 - 06:30 1,00 DRILL OTHR SURFAC 06:30 - 08:15 1.75 DRILL DRLG SURFAC 08:15 - 09:30 1.25 DRILL SURV SURFAC 09:30 - 12:00 2.50 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 6/12/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 14:30 2.50 DRILL DRLG SURFAC 14:30 - 15:15 0.75 DRILL CIRC SURFAC 15:15 - 17:45 2.50 DRILL TRIP SURFAC 17:45 - 20:00 2.25 DRILL PULD SURFAC 20:00 - 23:00 3.00 DRILL PULD SURFAC 23:00 - 23:30 0.50 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL REAM SURFAC 6/13/2003 00:00 - 05:15 5.25 DRILL REAM SURFAC 05:15 - 22:30 17.25 DRILL DRLG SURFAC 22:30 - 00:00 1.50 DRILL CIRC SURFAC 6/14/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 6/15/2003 00:00 - 08:00 8.00 DRILL DRLG SURFAC 08:00 - 08:30 0.50 DRILL SURV SURFAC Start: 6/11/2003 Rig Release: Rig Number: Spud Date: 6/12/2003 End: Group: Description of Operations Move modules off of 1 C-184. Move sub over well 1 C-172. Level and shim. Spot modules. Spot rock washer. Spot pipe shed. Hook up air, water, steam. Build berm f/rock washer, install skate rail, prepare rig for acceptance. RIG ACCEPTED 1500 HOURS 6/10/03. Tighten bolts on annular, RU hyd. lines, install riser, fill pits with water. Mix spud mud, load pipe shed with DP, RU floor. PU singles fIshed, stand back in derrick. Level sub after settle. PU singles fIshed, stand back in derrick. Continue to PU DP and stand in derrick. Pu HWDP, stand in derrick, Function test diverter. Witness waived by John Crisp. Slip and cut drilling line, service rig. PU NMDC and prep BHA. Fill conductor and check for leaks. MU BHA 1, orient motor/mwd and surface test same. Drill f/ 138-232. RU slick line and run gyro. Drill f/232-375 with gyro surveys. Directional Drill 12?" hole f/375' to 1447'. Pump rate 130 spm 550 gpm @ 1150 psi, ART 3.4 hrs, AST 5.0 hrs TDT 8.4 hrs. Released Sperry-Sun Gyro @ 800' , 1600 hrs. Hydrates @ 1185' continue to drill wI slow pump rate throuh 1300' Upwt 91 k, Dnwt 90K Torque on btm 3K OFF 1.5K Drilling f/1447-2747. TVD 2194. ART 2.2 AST 5.3 ADT 7,5. Drilling f/2747-3026. ART 1,3 AST 0.3. Pump hi vis weighted sweep. Circ hole clean @ 640 gpm, 100 rpm. Observe well. Back ream out of hole @ 100 rpm, 640 gpm to HWDP. Attempt to work bridge at 2129. Observe well, stand back 10 stands HWDP w/jars, 1 stand NMDC w/stab, LD UBHO sub, NMXO, mwd, NM short DC, break bit, drain motor, LD motor. PU AutoTrak, MU bit 2, float sub, NM stab, program mwd, RIH w/NMDC's, HWDP, jars, MU Ghost Reamer, test mwd, AutoTrak. TIH to 2156, Work tight hole at 2156. Continue to ream tight hole to bottom (3026) taking check shot surveys on connections. Reamed out hole at high rate with little or no cuttings over shakers. 700 gpm, 1800 psi, 150 rpm, 6000 ft-Ib. Drill f/3026 -04401 ART 10.8 hrs. CBU, observe well after 100 bblloss of mud while backreaming. Hole stable after CBU. Drilled from 4401 to 5300. (3193 TVD). ADT 7.7 hrs. PU 145 SO 87 ROT 108. PP off bottom 2150, on bottom 2200. TO off 11,700, on 10600. RPM 150-180, Flow rate 700-750. Drilling from 5300 to 6352. ADT7.0 hrs. Directional Drill 12?" F/ 6,352' to 6716' MD TD 3,824' TVD. RPM 180, WOB 10-20K, PP 2650 psi, GPM 755, TO 10-12K, PUW 150K, SOW 85K, ROTW 118K Survey on bottom and down link Auto-trk Printed: 7/11/2003 3:06:21 PM { ConocoPhillips Alaska Operations Summary Report Pump two 30 bbl 11,5 ppg hi vis weighted sweeps, 750 gpm @ 2600 psi, 150 rpm. Continue to circ and clean at drilling rate. Drop ESS survey tool, pump down @ 2 bpm, observe well. Backream as planned @ 150 rpms, 750 gpm to 3012' MD. (10k-25k overpull) POOH on elevators to 2641' MD (work tight spot @ 2531') Pump hi vis weighted sweep, circ hole clean. POOH on elevators to 1061' (work tight spot @ 1645') LD Ghost Reamer (Deep groove on tool, original OD 12 1/4", final OD 11 15/16"), LD remaining BHA. Clean rig floor tools. Dummy run 9 5/8" hanger on landing joint. RU 9 5/8" csg. eq. & Franks fill up tool. Run 9 5/8" 40# L-80 to 3100'. Circ surface to surface, 70 spm, 450 psi. Continue to Run csg. to TD 6712'. MU hanger and landing joint. PU 260k#, SO 105k#. Circ & cond mud increasing rate from 3-7 bpm, Thin viscosity to 40-50, Pv<15, Ty<15. 450 psi, recip. pipe. MU cmt head & continute to circ. and condo Pump 10 bbl CW 100, Test lines to 3500 psi. Continue with 40 bbl CW 100, 50 bbl MudPUSH (10.5 ppg), Drop btm plug, 665 bbl ArcticSet Lite (10.7 ppg), 87 bbl Class G + additives. Drop top plug, 20 bbl water. Displaced with rig pump at 7 bpm slowing to 3 bpm for last 20 bbls. Bumped plug with 500 psi over circulating rate. Bled off pressure. Floats held. 82 bbl to surface. LD landing joint, flush diverter, RD csg. eq. RD diverter system. Orient & NU well head. Fin NU Casing & Tbg Head NU 135/8" 5M BOP Stack Installed Test Plug & RU BOP Test Equipment Tested BOP Rams, Valves and Choke Manifold to 250 Psi Low, 5,000 Psi High, Tested Annular to 250 Psi Low & 3,500 Psi High, Note: John Spaulding with AOGCC Witnessed Test, ManuallBOP Failed Changed Out Lower ManuallBOP & Tested to 250 Psi & 5,000 Psi & CkOk Pulled Test Plug & Installed Wear Bushing Clear Rig Floor & Performed Derrick Inspection PU BHA Tools to Rig Floor Began PU & MU BHA #3with Autotrak and Surface Tested Same Fin MU BHA #3 & TIH to 339' Shallow Test Autotrac, MWD and Acuate BPA Downlink PU 162 Jts 5" G-DP & TIH with BHA #3 to 5,350' Slip & Cut 63' of Drlg Line & Serviced Top Drive TIH from 5,350' to 6,560' Washed Down 73' from 6,560' to 6,633' and Tagged Fit Collar, Circ Btms Up RU & tested 9 5/8" Csg to 2,500 Psi for 30 Min, Good Test Drilled Out Float Collar at 6,633' and Firm Cement in Shoe Trac to 6,654' with 3-15K WOB, 55 Rpm's, 509 Gpm at 1,700 Psi, Rot Wt 105K, Up Wt 155K, Dn Wt 80K, Off Btm Torque 16K Ft#'s, On Btm 17K Ft#'s 1.25 CEMENT DSHO SURFAC Drilled Out Firm Cement in Shoe Trac, Drilled Fit Shoe at 6,712' and Legal Well Name: 1 C-172 Common Well Name: 1 C·172 Event Name: ROT· DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 6/15/2003 08:30 - 13:00 4.50 DRILL CIRC SURFAC 13:00 - 18:30 5.50 DRILL TRIP SURFAC 18:30 - 21 :00 2.50 DRILL TRIP SURFAC 21 :00 - 00:00 3.00 DRILL TRIP SURFAC 6/16/2003 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 01 :00 0.50 CASE DEOT SURFAC 01 :00 - 02:00 1,00 CASE RURD SURFAC 02:00 - 06:00 4.00 CASE RUNC SURFAC 06:00 - 07:00 1.00 CASE CIRC SURFAC 07:00 - 11 :00 4.00 CASE RUNC SURFAC 11 :00 - 11 :30 0.50 CASE RUNC SURFAC 11 :30 - 12:00 0.50 CEMENTCIRC SURFAC 12:00 - 16:30 4.50 CEMENT PULD SURFAC 16:30 - 19:00 2,50 CEMENT PUMP SURFAC 19:00 - 20:15 1.25 CEMENT PUMP SURFAC 20:15 - 21 :30 1.25 CASE RURD SURFAC 21 :30 - 23:30 2.00 CASE NUND SURFAC 23:30 - 00:00 0.50 CASE NUND SURFAC 6/17/2003 00:00 - 00:30 0.50 CASE NUND SURFAC 00:30 - 03:00 2.50 WELCTL NUND SURFAC 03:00 - 03:30 0.50 WELCTL OTHR SURFAC 03:30 - 08:00 4.50 WELCTL BOPE SURFAC 08:00 - 09:00 1.00 WELCTL EORP SURFAC 09:00 - 09:30 0.50 WELCTL OTHR SURFAC 09:30 - 10:00 0.50 RIGMNT RSRV SURFAC 10:00 - 10:30 0.50 DRILL PULD SURFAC 10:30 - 12:30 2.00 DRILL PULD SURFAC 12:30 - 13:30 1.00 DRILL PULD SURFAC 13:30 - 13:45 0.25 DRILL DEOT SURFAC 13:45 - 17:45 4.00 DRILL TRIP SURFAC 17:45 - 18:45 1.00 RIGMNT RSRV SURFAC 18:45 - 19:30 0.75 DRILL TRIP SURFAC 19:30 - 20:00 0.50 DRILL CIRC SURFAC 20:00 - 21 :00 1.00 CASE DEOT SURFAC 21 :00 - 00:00 3.00 CEMENT DSHO SURFAC 6/18/2003 00:00 - 01 :15 Page 2 of 6 Start: 6/11/2003 Rig Release: Rig Number: Spud Date: 6/12/2003 End: Group: Description of Operations Printed: 7/11/2003 3:06:21 PM ( Page 3 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 C-172 Common Well Name: 1 C-172 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 6/18/2003 00:00 - 01:15 1.25 CEMENT DSHO SURFAC 01 :15 - 02:00 0.75 DRILL CIRC SURFAC 02:00 - 03:00 1.00 DRILL FIT SURFAC 03:00 - 05:00 2.00 DRILL DRLG PROD 05:00 - 06:00 1.00 DRILL CIRC PROD 06:00 - 06:30 0.50 DRILL OTHR PROD 06:30 - 12:00 5.50 DRILL DRLG PROD 12:00 - 17:30 17:30 - 18:00 5.50 DRILL DRLG PROD 0.50 RIGMNT RGRP PROD 18:00 - 00:00 6.00 DRILL DRLG PROD 6/19/2003 00:00 - 08:30 8.50 DRILL DRLG PROD 08:30 - 10:00 1.50 DRILL DEaT PROD 10:00 - 10:30 0.50 DRILL CIRC PROD 10:30 - 13:00 2.50 DRILL CIRC PROD 13:00 - 16:30 3.50 DRILL TRIP PROD 16:30 - 17:30 1.00 DRILL PULD PROD 17:30 - 18:45 1.25 DRILL TRIP PROD 18:45 - 19:00 0.25 DRILL DEaT PROD 19:00 - 21 :30 2.50 DRILL TRIP PROD 21 :30 - 22:00 0.50 RIGMNT RSRV PROD 22:00 - 22:45 0.75 DRILL TRIP PROD 22:45 - 23:30 0.75 DRILL REAM PROD 23:30 - 00:00 0.50 DRILL DRLG PROD 6/20/2003 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD Start: 6/11/2003 Rig Release: Rig Number: Spud Date: 6/12/2003 End: Group: Description of Operations Drilled 20' of New Formation to 6,736' Pumped 22 bbl Hi Vis Sweep and Displaced 9.6 ppg Spud Mud in Hole with New 9.3 ppg FloPro Mud RU & Performed FIT with 9.3 ppg Mud to 640 Psi for a 12.5 ppg EMW, Good Test Drilled 8 1/2" Hole from 6,736' to 6,930' (194') ADT 1.35 Hrs Circ Btms Up & Circ Hole Clean for PWD Clean Hole Baseline, Circ at 600 Gpm at 2,000 Psi. Performed PWD Baseline Test at Drilling Rate, Clean Hole Baseline at 600 Gpm = 10.73 ppg ECD with 9.3 ppg MW Drilled 8 1/2" Hole from 6,930' to 7,335' MD/3,942' TVD (405'), ADT 5.05 Hrs 5-12K WOB, 150 Rpm's, 143 Spm, 600 Gpm, Off Btm Press, 2,050 Psi, On Btm 2,150 Psi, Off Btm Torque 7K Ft#'s, On Btm 8.2K Ft#'s, 9.4 MW, ECD 10.8 ppg Drill from 7,335' to 7,765' MD/3,926' TVD (430') ADT 3.35 Hrs Changed Out Swivel Packing and Serviced Rig, POOH 90' to 7,675' Prior to Replacing Swivel Packing Drill from 7,765' to 8,230' MD/3,857' TVD (465') ADT 3.95 Hrs, 6-10K WOB, 150 Rpm's, 600 Gpm, Off/On Btm Press 2,350 Psi, Off Btm Torque 9K Ft#'s, On Btm 11 K Ft#'s, Rot Wt 108K, PU Wt 136K, DN Wt 92K, 11.2+ ppg MW with 11.0 ppg ECD, Last 24 Hrs (Drilled 1,514' in 13.7 Hrs, Ave 110.5'/Hr) Drill F/8,230' to 8,895' MD/3,802' TVD, (665') Lost LWD Signal, ADT 5.1 Hrs, Drilled W/5-15K WOB, 150 Rpm's, 600 Gpm, Off Btm Press 2,400 Psi, On Btm 2,450 Psi, Off Btm Torque 9.6K Ft#'s, On Btm 10.5K Ft#'s, Rot Wt 105K, PU Wt 138K, DN Wt 85K, 9.3 ppg MW, 11.2 ppg ECD Attempted to Regain LWD, Drilled 5' to 8,900',0.1 Hrs ADT with No Success on Getling Tool to Work Circ and Down Linked AutoTrak Tool Pumped Weighted,(2# Over MW) Hi Vis Sweep and Circ Hole Clean, Lowered ECD F/11.2 to 11.0 ppg, Circ at 600 Gpm at 2,350 Psi. Monitored Well- Static, Pumped Dry Job POOH to Shoe with No Problems, Monitored Well-Static, Cont POOH to LWD Tool Downloaded LWD & LD RNT Sub, Checked Bit & AutoTrak Tool & Ck Ok MU Standby RNT Sub & Programed LWD, TIH with BHA#4 to 420' Shallow Pulse Test and Downlink AutoTrak TIH F/420' to 6,650' (Shoe @ 6,712') Serviced Rig & Top Drive, Performed Accumulator Test & Ck Ok TIH F/6,650' to 8,790' with No Problems Est Circ, Took Ck Shot Survey and DownLinked AutoTrak, Washed Down F/8,790' to 8,850', Made MADD PASS with LWD F/8,850' to 8,900', No Fill or Problems TIH, Max ECD W/Circ Btms Up 11.4 ppg Drilled F/8,900' to 8,971' MD/3,811' TVD (71') ADT .5 Hrs, 5-10K WOB, 150 Rpm's 610 Gpm 2,400 Psi, Rot Wt 112K, PU Wt 142K, Dn Wt 88K, Off Btm Torque 9.2K Ft#'s, On Btm 10K Ft#'s, 9.3 Mw 11.2 ECD Drilled from 8,971' to 9,800' MD/3,923' TVD (829') ADT 8.1 Hrs, 5-20K WOB, 150 Rpm's, 143 Spm, 600 Gpm's, Off Btm Press 2,400 Psi, On Btm 2,450 Psi, Off Btm Torque 9.4K Ft#'s, On Btm 12.5K Ft#'s, Rot Wt 114K, PU Wt 152K, DN Wt 88K, 9.4 ppg MW, Ave 11.35 ECD Drilled from 9,800' to 10,630' MD/3,846' TVD (830') ADT 8.7 Hrs, Printed: 7/11/2003 3:06:21 PM { ~. ConocoPhillips Alaska Operations Summary Report Page 4 of 6 Legal Well Name: 1 C-172 Common Well Name: 1 C-172 Spud Date: 6/12/2003 Event Name: ROT - DRILLING Start: 6/11/2003 End: Contractor Name: n1334@ ppco.com Rig Release: G rou p: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 6/20/2003 12:00 - 00:00 12.00 DRILL DRLG PROD 5-10K WOB, 150 Rpm's, 145 Spm, 610 Gpm's, OfflOn Btm Press 2,450 Psi, Off Btm Torque 10.6K Ft#'s, On Btm 11.6K Ft#'s, Rot Wt 108K, PU Wt 146K, DN Wt 82K, 9.3+ ppg MW, 11.4 ppg ECD, Added 300 bbls New Mud to System 6/21/2003 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled F/10,630' to 11,400' MDI 3,783' TVD, (770') ADT 7.2 Hrs, 5-10K WOB, 150 Rpm's, 600 Gpm, OfflOn Btm Press 2,650 Psi, Off Btm Torque 11.2K Ft#'s, On Btm 12.5K Ft #'s, Rot Wt 105K, PU Wt 152K, DN Wt 74K, 9.3+ ppg MW, Ave 11.65 ECD, Pumped Wt'd High Vis Sweep & Circ Out Prior to Adding 290 bbls of New FloPro Mud to System 12:00 - 19:15 7.25 DRILL DRLG PROD Drilled F/11 ,400' to 11,970' MDI 3,933' TVD (T.D.) (570') ADT 5.6 Hrs, 5-10K WOB, 150 Rpm's, 610 Gpm, 2,650 Psi, Off Btm Torque 13K Ft#'s, On Btm 14K Ft#'s, Rot Wt 130K, PU Wt 179K, DN Wt 99K, 9.3+ ppg MW, 11.7 ECD, Used 5" HWDP to Drill Down Last 8 Stds, Pumped Wt'd High Vis Sweep 19:15 - 20:00 0.75 DRILL CIRC PROD Fin Circ Out Wt'd High Vis Sweep and Down Linked AutoTrac to Close Ribs on Tool, Circ at 619 Gpm 2,650 Psi with Large amount of Cuttings Back from Sweep 20:00 - 21 :00 1.00 DRILL REAM PROD Backreamed out of Hole F/11 ,970' to 11,475' WINo Problems, Backreamed Out at 619 Gpm, 2,700 Psi & 150 Rpm's 21 :00 - 21 :45 0.75 DRILL TRIP PROD TIH and Washed 30' to Btm, No Excess Drag, Fill or Problems TIH 21 :45 - 00:00 2.25 DRILL REAM PROD Monitored well-Static, Backreamed Out of Hole to Run 51/2" Liner FI 11,970' to 10,460 with No Problems, Pumping at 619 Gpm, 2,425 Psi at 150 rpm's, 10K Ft#'s Torque, Added 580 bbls New mud W IBackreaming 6/22/2003 00:00 - 09: 15 9.25 DRILL REAM PROD Backreamed Out of Hole F/10,460' to 6,710' (95/8" Csg Shoe), No Problems to 9,150', Had to Slow Backreaming F/9, 150' to Shoe Due to Packing Off, Circ at 610 Gpm and 150 Rpms, Backreaming Final Circ Press 2,300 Psi at Shoe, Had Large amount of Cuttings Back W IBackreaming 09:15 - 11 :00 1,75 DRILL CIRC PROD Pumped 20 bbl Wt'd Hi Vis Sweep (2# over Mw) had a 30% Increase in Cuttings Back F/Sweep, Circ Hole Clean, Circ Total of 3 Btms Up, Circ at 610 Gpm's, 2,200 Psi at 120 Rpm's, Monitored Well, Pumped Dry Job and Dropped 1 7/8" rabbit on 120' of Wire 11 :00 - 14:00 3.00 DRILL TRIP PROD POOH to BHA to 339', SLM No Corr, 14:00 - 15:45 1,75 DRILL PULD PROD Stood Back 1 Std HWDP, Downloaded MWD/LWD, Retrieved Rabbit and LD BHA #4, Cleared Rig Floor 15:45 - 16:15 0.50 CASE RURD CMPLTN RU Doyon's 51/2" Liner Running Equipment 16:15 - 16:30 0.25 CASE SFTY CMPL TN Held PJSM on Running of 5 1/2" Liner and MU Hanger Assembly 16:30 - 20:15 3.75 CASE PUTB CMPL TN PU & Ran 126 Jts (5,384.56') of 5 1/2" 15.5# L-80 Hydril 511 Liner, Ray Oil Tool Silver Bullet Shoe WINo Fit, 60 Jts of Perf Pipe W/1" x 16 SPF and 66 Jts of Blank Pipe, Alternated Perf & Blank Pipe, Ran 123 SpiralGiude Centralizers 1/Jt in Open Hole on Stop Rings, RIH to 5,384' 20:15 - 21:45 1.50 CASE PUTB CMPL TN MU & RIH W/Baker 7" FlexLock Hanger with ZXP Packer & Tie Back Sleeve to 5,451' 21 :45 - 00:00 2.25 CASE RUNL CMPL TN TIH with 51/2" Liner and 5" DP to 8,856' with No Problems, Taking Up & Down Wt's WfTlH, Checked Wt's & Torque at Csg Shoe, Rot Wt at 20 Rpm's 93K, PU Wt 103K, DN Wt 84K, Torque 3K Ft#'s, at 8,856' PU Wt 118K, DN Wt 78K. 6/23/2003 00:00 - 02:00 2.00 CASE RUNL CMPL TN Fin TIH with 51/2" liner on DP, last 9 stds used HWDP, tagged btm at 11,970', no problems TIH with liner, did not have to rotate liner, PU to 11,960', PU Wt 165K, Dn Wt 80K 02:00 - 04:30 2.50 CASE CIRC CMPL TN Dropped ball and pumped down to seat, took 1 112 calc strokes to Printed: 7/11/2003 3:06:21 PM ,<' l { ConocoPhillips Alaska Operations Summary Report seat, press up to 2,800 psi for 1 Min, pumped at ave 2 bpm at 300 psi, set hgr w/50K WT, press up to 3,500 psi & released from setting tool, press up and blew ball seat at 4,600 psi, set ZXP pkr with 50K wt. Press tested Pkr and Csg Ann to 2,500 psi for 10 min good test. TOL set at 6,521' with shoe at 11,960', String Wt after releasing f/liner Up Wt 140K, On Wt 11 OK Pumped 20 bbl hi vsi sweep and displaced 9.3 ppg FloPro mud with 9.3 ppb brine, circ at 600 gpm at 1,300 psi, rotated pipe on up stroke at 40 rpms and 3-5K ft#'s torque Monitored well-static, POOH LD 5" DP to 3,404', well not taking proper fill Monitored Well, had slight returns, gained less than 1/2 bbl in 30 min RU & TIH with DP to 6,470' Circ and raised brine wt from 9.3 to 9.5 ppg in & out, at btms up had +/- 20 bbls of 9.2# FloPro mud back, circ at 336 gpm at 350 psi Monitored well-static POOH from 6,470' LD 5" Dp and Baker liner setting tool, hole took calc fill TIH to 2,100' with remaining DP in derrick POOH LD DP Pulled wear bushing RU Doyon's Tbg handling equipment and Bakers TEC wire spool Held safety mtg with Baker Reps and rig crew on running 4 1/2" completion with TEC wire Began running 41/2" completion assembly with seal assembly, Camco DB nipple, Baker 925 Gaurdian gauge carrier, Baker model CMU sliding sleeve and 2nd Baker 925 Gaurdian Gauge, Connecting TEC wire to Y splice at report time 10.50 CMPL TN RUNT CMPL TN Fin RIH with 41/2" completion assembly per well plan. Ran a total of 209 Jts of 4 1/2" 12.6#, L-80, IBTM Tbg with seal assembly, glm's, Gaurdian Gauges and DB Nipple. T otallength 6,541.77' , Tested TEC Wire continuity every 20 jts W/rih, ave MU torque 4,500 ft#'s. MU Circ Head & tagged no go at 6,548'. PU to 6,510' 2.00 CMPL TN CIRC CMPL TN Pumped 20 bbl hi vis sweep and displaced 9.5 ppg brine with clean 9.5 ppg brine, circ at 5 bpm at 130 psi, had clean returns back to surface. Tbg up wt 82K, down wt 67K, block wt 35K. 1.75 CMPL TN SOHO CMPL TN Spaced out tbg string & seal assembly 4' up from no go, seal assembly "no go" @ 6,544'. Orient hanger and tied in TEC wire and landed hanger with 30K down wt. RILDS, Tested upper & lower seals on hanger to 5,000 psi & ck ok Landed tbg with seal assmbly"no go" at 6,544', CMU Sliding sleeve at 6,320', GLM W/DK shear valve at 3,384' and DB nipple with 3.875" profile at 506'. Tested seal assembly and annulus to 2,500 psi for 10 min, good test. LD Landing Jt and Installed BPV ND 135/8" BOP Stack Orient & NU Vetco Gray Gen 1A 11" 5M x 41/16" 5M Tree with 41/16" 5M VG230 Valves. Terminated TEC wire, checked continuity & ck ok Pull BPV and Installed TWC, Tested Tree to 5,000 psi, pulled TWC RU Little Red Hot oil, Press up to 3,550 psi & sheared OK valve at 3,384'. Pumped 150 bbls diesel down annulus to freeze protect well RU to tbg and allowed well to U-tube for freeze protecting tbg, Rd Lines and cleaned around cellar, well freeze protected to 2,200' on both Legal Well Name: 1 C-172 Common Well Name: 1 C-172 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 6/23/2003 02:00 - 04:30 2.50 CASE CIRC CMPL TN 04:30 - 06:00 1.50 CASE CIRC CMPL TN 06:00 - 08:00 2.00 CMPL TN PULD CMPL TN 08:00 - 08:30 0.50 CMPL TN OBSV CMPL TN 08:30 - 10:00 1,50 CMPL TN TRI P CMPL TN 10:00 - 13:15 3,25 CMPL TN CIRC CMPL TN 13:15 - 13:30 0.25 CMPL TN OBSV CMPL TN 13:30 - 18:00 4.50 CMPL TN PULD CMPL TN 18:00 - 19:15 1.25 CMPLTNTRIP CMPL TN 19:15 - 20:30 1.25 CMPL TN PULD CMPL TN 20:30 - 21 :00 0.50 CMPL TN PULD CMPL TN 21 :00 - 21 :45 0.75 CMPL TN RURD CMPL TN 21 :45 - 22:00 0.25 CMPL TN SFTY CMPL TN 22:00 - 00:00 2.00 CMPL TN RUNT CMPL TN 6/24/2003 00:00 - 10:30 10:30 - 12:30 12:30 - 14:15 14:15 - 14:45 0.50 CMPL TN DEQT CMPL TN 14:45 - 15:15 0.50 CMPL TN OTHR CMPL TN 15:15 - 17:00 1.75 CMPLTN NUND CMPL TN 17:00 - 18:30 1.50 CMPL TN NUND CMPL TN 18:30 - 20:00 1.50 CMPL TN SEaT CMPL TN 20:00 - 22:00 2.00 CMPL TN FRZP CMPL TN 22:00 - 23:00 1.00 CMPL TN FRZP CMPL TN Page 5 of 6 Start: 6/11/2003 Rig Release: Rig Number: Spud Date: 6/12/2003 End: Group: Description of Operations Printed: 7/11/2003 3:06:21 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: :( ConocoPhillips Alaska Operations Summary Report Page 6 of 6 1 C-172 1 C-172 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/11/2003 Rig Release: Rig Number: Spud Date: 6/12/2003 End: Group: Date Sub From - To Hours Code Code Phase Description of Operations 6/24/2003 22:00 - 23:00 23:00 - 00:00 1.00 CMPL TN FRZP CMPL TN annulus & tbg. 1.00 CMPL TN OTHR CMPL TN Installed Actuator valve on tree, RU Lubricator & installed SPV with 200 psi on tbg. Fin Cleaning mud pits, checked TEC wire continuity and gauges, #1 btm gauge showed 1,870 psi at 78 deg and 2nd upper gauge 1,850 psi at 76 deg's. RELEASED RIG AT 24:00 HRS, 6/24/03 to move to Oliktok Point State #1 Printed: 7/11/2003 3:06:21 PM ;,"':'. ConocoPhillips Alaska, Inc. Pad 1C 172 slot #172 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD w/IFR<389-11970'> svy6926 Date printed Date created Last revised 7-Jul-2003 12-Jun-2003 2-Jul-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.053,w149 29 47.117 Slot Grid coordinates are N 5968801.596, E 562101.718 Slot local coordinates are 1435.63 S 1096.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North -~\=~~\\\ ~) fjO.3-095 r'I'<;;~":.' JUL ;) ~.~ ConocoPhillips Alaska, Inc. SURVEY LISTING Page 1 Pad 1C,172 Your ref MWD w/IFR<389-11970'> Kuparuk River Unit,North Slope, Alaska Last revised : 2-Jul-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 562101.72 5968801.60 145.00 0.16 315.00 145.00 0.14N O.14W 0.11 0.19 562101.57 5968801.74 266.00 1.25 26.00 265.99 1.45N 0.32E 1. 00 0.36 562102.02 5968803.05 389.99 2.39 36.29 389.92 4.75N 2.44E 0.95 -0.06 562104.12 5968806.36 478.95 2.61 30.94 478.79 7.98N 4.58E 0.36 -0.53 562106.23 5968809.61 569.50 4.26 27.22 569.18 12.74N 7.18E 1. 84 -0.74 562108.79 5968814.39 659.33 5.90 24.61 658.65 19.91N 10.63E 1. 84 -0.62 562112.18 5968821.58 750.45 8.53 18,02 749.04 30.59N 14.67E 3.02 0.53 562116.13 5968832.30 840.41 11.70 14,76 837.59 45.76N 19.06E 3.58 3.37 562120.40 5968847.51 930,87 12.70 10.82 926.01 64.40N 23.26E 1.44 7.93 562124.45 5968866.17 1020.48 15.64 1. 05 1012,90 86.16N 25.33E 4.22 15.79 562126.35 5968887,95 1115.23 19.91 351.25 1103.12 114.89N 23.11E 5.49 30.60 562123.89 5968916,66 1209.45 21.43 346.42 1191.28 147.48N 16.63E 2.42 50.95 562117.14 5968949,20 1301.96 21.18 341. 57 1277.48 179.77N 7,37E 1. 92 73.64 562107.63 5968981.40 1394.09 26.12 338.05 1361.85 214.39N 5.48W 5.57 100.60 562094.50 5969015.92 1489.37 33.63 335.74 1444.41 257.96N 24.18W 7.97 136.78 562075.44 5969059.33 1581.16 35.67 335.01 1519.92 305.40N 45.94W 2.27 177 . 42 562053.30 5969106.58 1673.83 40.07 334.38 1593.05 356.81N 70.26W 4.77 222.14 562028.57 5969157.79 1766.99 44.74 331.67 1661. 83 412.74N 98.80W 5.38 272.64 561999.57 5969213.48 1860.39 50.50 330.33 1724.76 473.04N 132.27W 6,26 329.50 561965.62 5969273.50 1952.63 53.61 328,47 1781.47 535.62N 169.31W 3.73 390.59 561928.07 5969335,77 2045.08 56.75 326 . 71 1834.26 599.67N 210.00W 3.74 455.59 561886.87 5969399.48 2138.07 66,46 324.51 1878.43 667.05N 256,20W 10.65 527.01 561840.12 5969466.48 2230.68 67.44 325.15 1914,69 736.71N 305.29W 1.23 602.02 561790.48 5969535.73 2323.76 66.78 325.57 1950.90 807.26N 354.03W 0.82 677 . 13 561741.17 5969605.87 2416.32 66.75 326.52 1987.41 877.81N 401.53W 0.94 751.13 561693,10 5969676.03 2509.21 64.45 324.33 2025.79 947.46N 449.52W 3.28 825.16 561644.55 5969745.28 2603.20 63.51 323.94 2067.02 1015.91N 499,OOW 1.07 899,99 561594.52 5969813.32 2695.20 62.50 324.15 2108,78 1082.26N 547.14W 1.12 972 . 68 561545.85 5969879.27 2788.88 64.21 323.38 2150.79 1149.80N 596.63W 1. 97 1047.11 561495.82 5969946.39 2881.03 67.26 323.39 2188.65 1217.22N 646.73W 3.31 1122.04 561445.18 5970013.40 2973.64 68.00 324.42 2223.90 1286.42N 697,18W 1.30 1198.08 561394.17 5970082.18 3066.57 66.03 320.60 2260.20 1354.29N 749.22W 4.34 1274.94 561341.59 5970149.62 3159.28 66.09 321. 65 2297.82 1420.26N 802.40W 1. 04 1351.97 561287.88 5970215.15 3252.12 65.93 322.72 2335.57 1487.27N 854.40W 1. 07 1428.41 561235.34 5970281.72 3345.40 66.16 323.91 2373.44 1555.63N 905.33W 1.19 1504.50 561183.86 5970349.66 3438.75 66.32 323,79 2411.05 1624.61N 955.73W 0.21 1580,39 561132.91 5970418.23 3530.94 67.43 319.68 2447.27 1691.15N 1008.23W 4.27 1657.07 561079.87 5970484.34 3623.80 67.67 315.87 2482.74 1754.69N 1065.89W 3.80 1737.03 561021.70 5970547.39 3716.20 68.80 311.81 2517.02 1814.10N 1127.78W 4.26 1818.93 560959.34 5970606.30 3808.99 69.00 310.16 2550.42 1870.88N 1193.12W 1. 67 1902.75 560893.54 5970662.53 3901.33 69.62 306.70 2583.06 1924.55N 1260.78W 3,57 1987,25 560825.45 5970715.65 3994.80 69.74 305.83 2615.52 1976.40N 1331.46W 0.88 2073.64 560754.36 5970766.92 4087.10 69.88 306.94 2647.37 2027.79N 1401.20W 1.14 2158.98 560684.22 5970817.73 4179.42 69.75 308.45 2679.23 2080.77N 1469.76W 1.54 2243.98 560615.23 5970870.15 4271 . 87 69.89 310.18 2711.12 2135.75N 1536.89W 1.76 2328.60 560547.66 59709~24 .58 4364.81 69.83 311.60 2743.13 2192.87N 1602.85W 1.44 2413.12 560481.25 5970981.15 4457.94 68.11 310.11 2776.55 2249.73N 1668.59W 2.38 2497.33 560415.05 5971037.47 4550.96 65.67 306.03 2813.07 2302.49N 1735.91W 4.81 2581.11 560347.32 5971089.68 4643.84 63.52 300.46 2852.94 2348.49N 1806.01W 5.89 2664.38 560276.85 5971135.10 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 4874.44 on azimuth 223.79 degrees from wellhead. Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 4874.44 on azimuth 223.79 degrees from wellhead. Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 5968255.27 5968163.10 5968070.52 5967978.64 5967886.60 5968713.67 5968624.56 5968529.36 5968441,00 5968347.16 5969173.71 5969082.36 5968990.66 5968898.53 5968806.89 5969632.73 5969540.76 5969450.20 5969357.36 5969265.59 5970087.45 5969998.64 5969908.63 5969817.69 5969725.86 5970554.03 5970473.27 5970363.97 5970272.27 5970182.78 5970954.84 5970883.52 5970806.47 5970725.49 5970641.58 5971225.86 5971183,95 5971135.65 5971081,51 5971021.27 5971294.88 5971298.32 5971294.21 5971281.65 5971259.13 5971176.30 5971211.61 5971240.45 5971265.65 5971283.77 COO R D S Northing 558896.50 558897.44 558896.73 558895.35 558893.47 558895.88 558893.71 558892.39 558892.83 558894.58 558913.42 558908.41 558904.36 558901.47 558898.63 558939.95 558932.75 558927.84 558923.61 558918.56 558975.13 558969.22 558962.63 558955.73 558948.13 559010.82 559000.16 558991.80 558986.66 558981.08 559171.40 559127.84 559089.08 559056.39 559029.96 559460.42 559394.98 559331.81 559273.73 559220.51 559829.09 559753,15 559676.66 559602.17 559529.61 560200.97 560126.92 560056.43 559980.58 559905.72 G RID Easting 2640.12 2598.81 2558.80 2519.69 2480.96 2841.97 2804.79 2764.18 2724.98 2682.20 3028.22 2992.60 2955.98 2918.12 2880.43 3205.93 3172 . 02 3136.67 3099.70 3063.94 3374.00 3340.31 3306.70 3272.97 3239.48 3546.80 3520.92 3480.44 3444.79 3410.51 3578.52 3586.34 3587.34 3581.15 3568.05 3437.82 3478.23 3513.78 3542.19 3563.55 3136.87 3206,61 3273.54 3334,95 3390,26 2750.65 2832.69 2908.69 2987.92 3063.13 3.52 1. 43 0.77 0.13 0,54 3209.86W 3209.67W 3211.14W 3213.26W 3215.89W SURVEY LISTING Page 2 Your ref MWD w/IFR<389-11970'> Last revised: 2-Jul-2003 0.09 0.54 3.97 5.09 5.56 3206.75W 3209,65W 3211.74W 3212.02W 3211.03W 0.45 0.31 1. 59 0.03 0.19 3185.48W 3191.22W 3196.02W 3199.66W 3203.24W 5.22 5.51 3.09 0.74 0.57 3155.20W 3163.16W 3168.80W 3173.79W 3179.59W 0.35 0.90 0.24 3.95 4.70 3116.33W 3122.96W 3130.28W 3137.92W 3146.28W 6.63 5.75 2.39 0.40 0.39 3076.84W 3088.16W 3097.41W 3103,30W 3109.61W 5.99 5.17 5.24 5.28 5.75 2913.00W 2957.14W 2996.53W 3029.88W 3056.99W 7.98 4.83 4.33 6.08 4.95 2621.75W 2687.54W 2751.11W 2809.63W 2863.34W 4.86 5.26 5.01 6.60 6.99 2252,49W 2328.41W 2404.94W 2479.54W 2552.28W 3.06 3.19 3.95 4.36 4.89 1881.56W 1955.33W 2025.58W 2101.24W 2175,95W Dogleg Vert Deg/100ft Sect 520.305 612.485 705.065 796.935 888.965 61.875 150.975 246.165 334.535 428.395 398.06N 306.74N 215.08N 122,96N 31,34N 856,89N 764.98N 674.45N 581.64N 489.90N 1311.36N 1222.59N 1132.63N 1041.73N 949.96N 1777,67N 1696,99N 1587.76N 1496.10N 1406.65N 2177.21N 2106.24N 2029.50N 1948.77N 1865.08N 2445.90N 2404.51N 2356.72N 2303.05N 2243.24N 2511.92N 2515.97N 2512.49N 2500.53N 2478.60N 2390.31N 2426.22N 2455.63N 2481. 46N 2500.18N RECTANGULAR COO R DIN ATE S 3806.23 3818.78 3831.40 3843.96 3856.50 3822.47 3808.87 3797.48 3793.14 3796.30 3891.67 3877.99 3864,29 3850.51 3836.68 3952.47 3945.90 3933.56 3919.30 3905.51 3892.02 3909.41 3927.18 3942.32 3951.10 3798.85 3816.76 3837,91 3855.83 3873,31 3638.72 3677.61 3713.82 3746.58 3774.74 3401.40 3452.08 3501.26 3549.45 3595.87 3138.32 3190.01 3242.81 3295.76 3348.77 2897.20 2941. 65 2985.62 3035.25 3085,88 True Vert Depth 179.21 180.55 181. 27 181.38 181. 89 182.11 181,62 180.90 179.46 179.33 183.46 183.74 182.25 182.28 182.20 185.56 184.33 182.80 183.35 183.88 183,86 184.69 184.61 185.00 185.40 189.80 186.19 183.49 183.86 184.21 214.23 209.57 204.81 200.12 195.82 240.34 235.37 230.78 224.17 219.73 275.98 270.14 264.61 257.18 249.28 297.46 294.43 290.98 286.67 281.44 Azimuth Degrees 82.21 82.28 82.20 82.24 82,24 8924.21 9017.24 9110.69 9203.44 9296.36 98.66 98.69 94,95 90.68 85.46 8463.20 8553.38 8649.29 8737.79 8831.74 98.54 98.47 98.50 98.50 98.66 7997.59 8090.10 8182.91 8276.12 8368.85 91.60 96.55 98.94 98.51 98.56 7533.47 7625.99 7717,54 7811.57 7904.52 78.92 78.97 78.76 82.39 86.72 7072.17 7162.87 7254.86 7347.34 7439.93 75.98 79.24 78.92 79.01 78.92 6594.79 6678.23 6789.89 6883.47 6974,83 63.96 66.16 68.34 70.57 73.95 6130.42 6222.63 6316.21 6409.52 6501.93 56.09 57.75 58.82 58.76 61.27 5665.20 5758.01 5851.54 5944.46 6037.31 55.70 55.95 54.96 55.10 55.22 5202.03 5293.99 5387.06 5479.36 5572.05 62.22 60.90 59.12 57.26 56.15 4740.89 4834.21 4922.17 5016.28 5108.48 Measured Inclin Depth Degrees ConocoPhillips Alaska, Inc. Pad 1C,172 Kuparuk River Unit,North 5lope, Alaska All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 4874.44 on azimuth 223.79 degrees from wellhead. Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 3 Pad 1C, 172 Your ref MWD w/IFR<389-11970'> Kuparuk River Unit,North 5lope, Alaska Last revised : 2-Jul-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE 5 Deg/100ft 5ect Easting Northing 9389.45 82.34 182,91 3868.99 981.135 3219.75W 1. 09 2443.28 558890.36 5967794.42 9482.39 82.40 183.26 3881.33 1073.115 3224.71W 0.38 2406.66 558886.15 5967702.41 9575.35 82.34 183.76 3893.68 1165.085 3230.35W 0.54 2370.66 558881.26 5967610.41 9667.75 82.31 184.64 3906.02 1256.405 3237.06W 0.94 2335,90 558875.29 5967519.04 9761. 31 82.31 186.75 3918.54 1348.665 3246.26W 2,23 2302,95 558866.84 5967426.72 9854.06 84.81 186.82 3928.94 1440.175 3257.14W 2.70 2271.85 558856.70 5967335.13 9946.75 89.79 187.02 3933,31 1532.055 3268.30W 5,38 2240.82 558846.30 5967243.17 10039.42 94,82 187.34 3929.58 1623.895 3279.86W 5.44 2210.18 558835.48 5967151.25 10132.40 98,32 186.70 3918.94 1715.565 3291.15W 3.83 2179.36 558824.93 5967059.51 10225.68 98.47 186.23 3905.32 1807.255 3301.54W 0.52 2147.73 558815.29 5966967.74 10318.32 98.41 184.96 3891.73 1898.455 3310.48W 1. 36 2115.02 558807.10 5966876.48 10411.26 98.38 184.20 3878.16 1990.105 3317.82W 0.81 2080.68 558800.50 5966784.78 10504,22 98.44 184.38 3864.56 2081.805 3324.70W 0.20 2045,91 558794.37 5966693.04 10596.89 98.43 183.08 3850.97 2173.275 3330.66W 1. 39 2010.42 558789.15 5966601.53 10689.78 98.47 182.60 3837.32 2265.045 3335.21W 0.51 1973.53 558785.35 5966509.74 10782.71 98.38 181.56 3823.70 2356,915 3338.55W 1.11 1935.51 558782.76 5966417.85 10875.66 98.50 181. 28 3810.06 2448.825 3340.83W 0.32 1896.52 558781.23 5966325.93 10968.20 98.36 181.82 3796.49 2540.335 3343,31W 0.60 1857.89 558779.49 5966234.42 11061.73 98.35 181.46 3782.90 2632.835 3345.95W 0.38 1818.98 558777.60 5966141,91 11154.08 93.63 180.89 3773.27 2724.635 3347.83W 5.15 1779.68 558776.46 5966050.11 11246.84 89.45 182.00 3770.77 2817.305 3350.17W 4.66 1740.41 558774.88 5965957.42 11337.25 84.78 180.47 3775.32 2907.555 3352.12W 5.43 1701. 87 558773.66 5965867.17 11428.72 80.07 180.64 3787.38 2998.195 3353.00W 5.15 1662.20 558773.52 5965776.54 11518.81 75.80 180.80 3806.21 3086.265 3354.10W 4.74 1623.88 558773.13 5965688.47 11610.18 73.37 181,38 3830.49 3174.325 3355.78W 2,73 1586.07 558772.18 5965600.40 11700.93 73.41 182.16 3856.43 3261.245 3358.46W 0.82 1549.67 558770.20 5965513.47 11790,69 73.44 183.46 3882.04 3347.175 3362.68W 1.39 1515.09 558766.68 5965427.52 11881.39 73.37 183.43 3907.94 3433.935 3367.90W 0.08 1481.04 558762.16 5965340.73 11924.02 73.39 183.70 3920.14 3474.705 3370.44W 0.61 1465.12 558759.95 5965299.94 11970.00 73.39 183.70 3933.28 3518.675 3373.29W 0.00 1448.03 558757.47 5965255.95 17-Feb-2003 17-Feb-2003 8-May-2003 3395.40W 3104.53W 3216.14W 3474.44S 1548.84N 369.50S 3921. 00 3840.00 3797.00 WS W9 A2-TOE RVSD 10 558735.000,5965300.000,0.0000 WS W9 A4-HEEL RVSD 1 558985.000,5970325.000,2.0000 WS W9 A4 MIDPT TGT 0 558889.000,5968406.000,0.0000 Revised ----------------------------------------------------------------------------------------------------------- Target name Rectangular Coordinates T.V.D. Geographic Location Targets associated with this wellpath 11970.00 3933.28 3373.29W Projection to TD 3518.67S ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD Comments in wellpath SURVEY LISTING Page 4 Your ref: MWD w/IFR<389-11970'> Last revised: 2-Jul-2003 ConocoPhillips Alaska, Inc. Pad 1C,172 Kuparuk River Unit, North Slope, Alaska Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1 C-172 I Contains the following: -~._._.,_..., , .:1:::t=- 1 LDWGCompactDisc- JðCOC¡ i (Includes Graphic Image files) 11 LDWG lister summary 111 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 487454 Sent By: Glen Borel Received B~\J't ~,() ~~ ~\5~m8:> ~03-0C¡5 r&l. BAKER HUGHES Anchorage GEOScience Center I Ii Date: Aug 15, 2003 Date: ----------------- IØ1&f~·lfO.300IIIU1'1ItI.:J . "... .n....'_...n....·..____ .. :o.~ ...... ~'P" ___ .......,_ . .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 '".....,... ""'......... . : ~œ~"r.'}NII ~_._.__._~... I' , . _.:~ .-,.,' I ¡ : I 1 : I I LJ (--.,\ rr~:J ¡·n. I· ¡ I I : l._, I ¡ r \ ¡ ,-'" i" l¡) \ : ....--".. ~ /~ n IX\ ~ m /~\ I r·\ \ ¡ L-, I (\. \ C\..I) ¡ ! \, \ f r'\ \ w 1.-. L---< L-, L_' "--_ L_, \....\....., ,- FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS ,/ CONSERVATION COMMISSION i Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field 1 C-172 ConocoPhillips (Alaska), Inc. Permit No: 203-095 Surface Location: 1436' FNL, 1096' FWL, Sec. 12, TIIN, RI0E, UM Bottomhole Location: 369' FSL, 2302' FEL, Sec. 11, TlIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required. permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, t û /J ~ "..' ,£-s ¿r4~-V:Ü- //L 1:_/, / Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this ..J day of June, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section ,/ ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 27, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1C-172 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, an undulating horizontal well in the West Sak "A" sands. The well will be designated 1C-172. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for this well. The expected spud date of 1C-172 is June 10, 2003. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Sincerely, ~\~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED MAY 2 7 2003 Alaska Oil & Gas Cons. Commission Anchorage P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 1436' FNL, 1096' FWL, Sec. 12, T11 N, R10E, UM Top of Productive Horizon: 133' FSL, 2007' FEL, Sec. 2, T11 N, R10E, UM Total Depth: 369' FSL, 2302' FEL, Sec. 11, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): 1a. Type of Work: Drill0 Re-entry D 2, Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Surface: x- 562102 16. Deviated wells: Kickoff depth: 200 18. Casing Program Size Hole Casing 42" 16" 12.25" 9.625" 8.5" 5.5" 19 Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat D Exploratory U Development Oil ~ Multiple Zone D Service Q Development Gas D Single Zone 0 5. Bond: ~ B~ket U Single Well 11. Well Name and Number. Bond No. ,;.1 59-52-180 1 C-172 6. Proposed Depth: 12. Field/Pool(s): MD: 11874' TVD: 3921' Kuparuk River Field Wesf~o/I Kup::uul( nivcr roo I , ..1b- 13. Approximate Spud Date:' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill U 1b. Current Well Class: Stratigraphic Test D 7. Property Designation: ,Aj)~25649 8. Land Use Permit: ADL 467 9. Acres in Property: 2560 10. KB Elevation y- 5968801 (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1941 psig Setting Depth Zone- 4 ft. Maximum Hole Angle: 98.5° Weight 62.5# 40# 15.5# Specifications Grade Coupling H-40 Weld L-80 BTC-M L-80 Hydril511 Top Bottom Length MD TVD MD TVD 110' 28' 28' 138' 138' 6739' 28' 28' 6767' 3836' 5574' 6300' 3696' 11874' 3921' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) ~.~\) 6/10/2003 14. Distance to Nearest Property: 369' at TD 15. Distance to Nearest I k:;.-Jl7 ....~ Well within Pool: H~-17~~16.6' @ 50SA'> 1 Max. Surface Pressure: 1505 psig Quantity of Cement c. f. or sacks (including stage data) 400 cf AS 1 & 240 cf ArcticCrete 860 sx AS Lite & 420 sx Class G not cemented (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Length Cement Volume Size MD TVD RCCCIVCD ~IAY 2 7 2003 Perforation Depth TVD (ft): Alaska Oil & G3S Cons. Commission Anchorage BOP Sketch D Diverter Sketch D Drilling Program~ Seabed Report D Time v. Depth Plot D Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Permit to Drill Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 R. Thomas ~\k...- Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader Phone Date c; (~ , (0 ., PreDared bv Sharon AflsuD-Drake - 2-D 3-o9S- Commission Use Only API Number: Permit APp~roval ~ / /J _.. 50- D 2-9 - 2 3 /51 -00 Date: ,(¡¡ ()-f Samples required DYes %NO Mud log r quired Hydrogen sulfide measures DYes ø No Directional survey required '~S\JC)~~ \. ,~~\.""-~~ ~"CJ~ ~(è..~\-' Number: Conditions of approval: Other: Approved by: ~~ COMMISSIONER BY ORDER OF THE COMMISSION .011) !.""\.. '. ~... il" .~..". ".., A· L i\~ 'I " , .1 . ·""~ii"S#!(ii..:. ~.". , II \,~ Ii .~). " Form 10-401 Revised 3/2003 · See cover letter for other requirements D Yes ~No Wes [J No Date: t?¡4y Submit in duplicate 1C-172PERMIT IT. doc Page 1 of 7 Printed: 27-May-03 ¡ A D $..('" '1. 'A . a:.,~ IfJ l .,:1 :' i1 ", ; .IIILLU'i~ ,j¡ø 12. Evidence of Bond i ng .......... .......... ................ ........................ ... .... ........ .................... 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................ ................................................ 6 Requirements of 20 AAC 25.005 (c)(10) ..... .................................................... ....................................... 6 10. Seism ic Analysis......................... ............... ........... .................. ........................... ...... 6 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ....... ....................................... ....... ............................................. 5 Requirements of 20 AAC 25.005(c)(B) ............................................... ....... ............................................. 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Lateral Mud Program (6% KCI/NaCI FLOPROP NT) ........................................................................... 5 8. Dri II i ng FI uid Program .. ...... ......... ....... .......... ........ .................. .... ..... .................. ...... 4 7. Diverter System Information...... ... .... .......... ............ ... ............ ............ ..................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................... ......... ....................................... 4 6. Casing and Cementi ng Program............................................................................. 4 Requirements of 20 AAC 25. 005( c)(6) ..... ..................................................... ......................................... 4 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .............. .............................................. ...................................... 3 4. Dri II i ng Hazards Information....... ....... .......... ... ................ ....... ... ............... ....... ........ 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ..... .............................................................................................. 3 Requirements of 20 AAC 25.005(c)(2) ...................................................................................................2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 3 2. Location Su m mary ........ ........... .... ..... ........... ............ ...... ............ ..... .......... ............... 2 Requirements of 20 AAC 25.005 (f)...... .............. ............................. .................................. ............ .........2 1. Well Name............................ ...... ......... ...... .......................... ..... ............ ..................... 2 Table of Contents Application for Permit to Drill Document Permit It - West Sak Well #1C-172 Application for Permit to Drill, Well 1 C-172 f Revision No.O , Saved: 27-May-03 ( :t Application for Permit to Drill, Well 1 C-172 ill Revision No.O ~ Saved: 27-May-03 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments.... ........................................ ............ ........ ............................................. 7 Attachment 1 Directional Plan (14 pages) ................... ....................................................... .................... 7 Attachment 2 Drilling Hazards Summary (1 page) .................................................................................7 Attachment 3 Cement Loads and CemCADE Summary (1 page) ........................................................ 7 Attachment 4 Well Schematic (1 page) ..................................................... ................. ........................... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well mU!J"t be identified by a unique name designated by the operator and a unique API number as!Jigned by the commission under 20 MC 2S,040(b), For a well with multiple well branche~~ each branch must simiMrly be identified by a unique name and API number by adding a suffix to the name designated for tile well by the operator and to the number assl[lf7ed to tile well by the commission. The well for which this Application is submitted will be designated as lC-172. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pelmlt to 0/111 must be accompanied by each of the fiJllowing Items, exœpt for an Item already on file with the commi..'ision and identified in the application: (2) a plat identifying tl7e property and the property~'i owners and showing (A)the coordinates of the proposed location of the well at the surtàœ, at the tvp of each objective formation, and at total depth ret'erenced to governmental section lines. (8) tile coordinòte!J" of the propOS'ed location of the well at the surface, referenced to the state plane coordinate system for tiu's state as maintained by the National Geodetic Survey in the National Oceanic and Atmosphetic Admli7istration; (C) the proposed depth olthe well at the top of each objective formation and at total depth' Location at Surface ASP Zone 4, NAD 27 Coordinates Northings: 5,968,801 Eastings: 562,102 1436' FNL, 1096' FWL, Section 12, TllN, Rl0E, UM RKB Elevation 87.1' AMSL Pad Elevation 59.1' AMSL Location at Top of Productive Interval (West Sak "A" Sands) ASP Zone 4, NAD 27 Coordinates Northings: 5,970,345 Eastings: 558,986 133' FSL, 2007' FEL, Section 2, TllN, Rl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6767 3836 3749 Location at Total Depth ASP Zone 4, NAO 27 Coordinates Northings: 5,965,300 Eastings: 558,735 369' FSL, 2302' FEL, Section 11, TllN, R1DE, UM Measured Depth, RKB: 11,874 Total Vertical Depth, RKB: 3,921 Total Vertical Depth, 55: 3,834 and J'lAR·¡IW ~~í' j .~~"A I l' ,:,'1 ~I" M .~ A \~ì. .. 10-172 PERMIT IT. doc Page20f 7 Printed: 27-May-03 ~" Application for Permit to Drill, Well 1 C-172 f Revision No.O . Saved: 27-May-03 (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated" the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposeti wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells witl7in 200 feet of the proposed wellbore (A) list the names of the operators of those well~-, to the extent that those names are known or discoverable in public records, and Sl70W that each named operator has been furnished a copy of the application by celtifled malt or (B) state that the applicant is tl7e only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dtill must be accompanied by each of the following items, except for an item already on file with the commission anti Identified in the application: (3) a diagram and descriptíon of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 AAC 25.03(i or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi RSRRA BOP stack will be utilized to drill and complete weIl1C-172. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fol/owing item!:>'", exæpt for an item already on file with the commission and identified in the applicattlm: (4) infol7nation on dtilling hazards, including (A) the maximum downhole pre5"57.Jre that may be encountere(~ critetia used to detelmine if;, and maximum potential surface pressure based 0/7 a methane gl"<.-:¡dient; The expected reservoir pressures in the West Sak sands in the 1C-172 area vary from 0.44 to 0.49 psi/ft, or 8.6 to 9.3 ppg EMW (equivalent mud weight). These are pressures are predicted based on actual well test data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A sand formation is 1339 psi, calculated thusly: MPSP =(3961 ft)(0.49 - 0.11 psi/ft) = 1505 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems SUä7 as abnormally qeo-pres:siJred strata, IO.5t circulation zones, and zones that have a propensity for differential stickinq; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An applicz¡tion for a Permit to Olilf must be accompanied by eaä, or the fOllowing items~ except lor an item already on fìle with the commission and Identifìed in the application: (5) a description of't!7e procedure for conducting formation integnty test5~ as required under 20 MC 25.030(f); O ~".. .~"" f ^ L l~i I \J ; 1'\1 j,,;;\ 1C-172 PERMIT IT. doc Page 3 of 7 Printed: 27-May-03 Application for Permit to Drill, Well 1 C-172 (- Revision No.O Saved: 27-May-03 lC-172 will be completed with 9-5/8" surface casing landed in the West Sak A Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items/ except for an item a/ready on file wIth the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 2S.03~ and a description of any slotted line0 pre- perforated /ine0 or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 42 CsglTbg 00 (in) 16 Weight (Ibltt) 62.5 Grade H-40 Connection Welded Length (ft) 110 Top MO/TVO (ft) 28 / 28 8tm MOITVO (tt) 138 / 138 Cement Program Cemented to surface with 400 cf ArcticSet 1 & 240 cf of ArcticCrete Cemented to Surface with 3680 cf ASLite Lead, 490 cf Class GTail Pre-perforated, Not Cemented 9-5/8 12-1/4 40 L-80 BTC,AB Modified 6739 28 / 28 6767 / 3836 5-1/2 Pre perforated 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item!:>~ exæpt for an item already on file with the commission and identified in the application: (1) a diagram and description of the diverter :..ystem as required by 20 AAC 25. 035; unless this requirement is waived by the commis..<:,ion under 20 MC 25~035{h)(2)/ 8-1/2" 15.5 L-80 Hydril 511 5574 6300/ 3696 11874 / 3921 A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lC-172. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pelmlt to Dlill must be accompanied by each of the folloWlí7g Item.~ except for a/7 Item already on file with the commission and Identified in the application: (8) a drillinq fluid program, Ji7c1uding a diagram and desaiption of tl7e drilling fluid system, as required by 20 AAC 25:033/ Drilling will be done with muds having the following properties over the listed intervals: Oh",...ç ....~~.......~. ft.......' ! i ;'~'~,:' \IS t~' '1 ¡ \;ri L 1C-172 PERMIT IT. doc Page 4 of 7 Printed: 27-May-03 Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value 8.5 - 8.6 ~9.4 150 - 200 150 - 200 Density (ppg) Funnel Viscosity (seconds) Yield Point (lb1100 sf) Plastic Viscostiy (cp) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH API Filtrate(cc) Solids (%) 30 - 60 30 - 60 8 - 15 11 - 22 15 - 30 15 - 25 25 - 55 25 - 55 8.5 - 9.5 8.5 - 9.5 8-15 <8 5-8 5-8 *9.6 ppg if hydrates are encountered Lateral Mud Program (6% KCl/NaCI FloPro NT) BID sand laterals Initial Value Final Value 9.6 9.6 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (lb1100 sf) Plastic Viscostiy (cp) LSRV Chlorides pH API filtrate **HTHP filtrate MBT ***Solids ppb 25 - 35 25 - 35 8 -12 8 -12 30K - 35K 60K - 70K 9-9.5 <6 <10 <5 <12 30K - 35K 60K - 70K 9-9.5 <6 <10 <5 <12 .... HTHP to be run at 800 F ...... The drilled LGS Application for Permit to Drill, Well 1 C-172 Revision No.O Saved: 27 -May-03 ,( Base of Permafrost to Total Depth Initial Value Final Value ~9.4* 9.6 150 65 - 75 20 - 35 18 - 30 12 - 30 12 - 24 15 - 25 15 - 25 20 - 45 20 - 45 8.5 - 9.5 8.5 -9.5 <8 <8 5-8 5-8 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application tor a Pel717it to Drill must be aex;ompanied by each of the following Items¡ except for an Item already on file with the cvmmission and identified in the applkation: (9) for an exploratory or stratigrapl7íc test well, a tabulation setting out the depths of predicted abnormally geo·pressured strata as reqllired by 20 MC 25.033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. Of" . (:~> ;~ . tÎ$i~~i,~ L 1C-172 PERMIT IT. doc Page 5 of 7 Printed: 27-May~03 { Application for Permit to Drill, Well 1 C-172 ,.' Revision No.O Saved: 27-May-03 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (10) for an exploratory or stratigraplJic test wel¿ a seismic refraction or reflection analysis as required by 20 AAC 25. 061 (a/' Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already 017 file with the commission and identified in tIle application: (11) for a well drilled from an offshore platform, mobIle bottom-founded structure, jack-up rig, or floating dolling vessel an analysis of seabed conditions as required by 20 MC 25: 061 (b),-' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following Item5~ except for an Item already on file with the commission and identified in thi'; application: (12) evidence showllJg that the requli'ement'i of 20 AAC 25.025 {BondIÌJg}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit tv Drill must be accompanied by each of the following item.~ except for an item already on file with the commission and identified in the applic'':Jtion: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 138' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 12-1/4" hole to casing point at +/- 6767' MD / 3836' TVD as per directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. 4. Run and cement 9-5/8", 40#, L-80, BTC AB Modified casing to surface. Displace cement with mud and perform top job if required. 5, Remove diverter system, install and test 5,000 psi wellhead and 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). AOGCC will be notified 24 hrs before test. 6. PU 8-1/2" bit and 6-1/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment, pressure test casing to 3500 psi, for 30 minutes and record results. 7. Drill out cement and between 20' and 50' of new hole. Perform FIT to 12.0 ppg EMW, recording results. (ECD's modeled to be less than 11.3 ppg) 8. Directionally drill 8-1/2" hole to TD at +/- 11,874' MD / 3,921' TVD as per directional plan. 9. POOH, back reaming out of lateral. 10. PU and run 5-1/2" pre-perforated liner (every other joint in open hole perforated with sixteen 1 inch diameter holes per foot). 11. Displace liner by open hole annulus to 9.6 ppg brine. Set liner hanger and liner top packer. Test liner top packer to 2500 psi for 10 minutes. Displace inside of liner to 9.6 ppg brine. POOH, laying down drill pipe as required. 12. Make up completion equipment and RIH to depth. t f i,1!!)!I 1C-172 PERMIT IT. doc Page 6 of 7 Printed: 27-May-03 0" ~ i1i r'\ r ~\ , . i· ~ Application for Permit to Drill, Well 1 C-172 ( Revision No.O \ Saved: 27-May-Q3 13. Space out seal assembly in PBR, and land tubing in wellhead. 14. Nipple down stack, nipple up and test tree to 5,000 psi. Pressure test annulus to 2000 psi for 10 minutes, recording results. Continue to pressure annulus up and shear RP shear valve in top gas lift mandrel. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in top mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). 17. Open CMU sliding sleeve. Set jet pump in CMU profile. Rig down wire line unit. 18. Initiate production and clean up well to tanks. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the (vllowing item5~ except for an item already on file Witll the cvmmi8..s"'Íon and identified in the application: (14) a general description of 110W the operator plans to dif,ìJose of drilling mud and cutting!; and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lC Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan (15 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (1 page) Attachment 4 Well Schematic (1 page) C· . g. '.'.. ......'. .":1.,..,.. ..n... ...\Ij... ...~ .: J I ..,: .~ ,t~} I. if \A ø .4" L 1C-172 PERMIT IT. doc Page 7 of 7 Printed: 27-May-03 { ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 172 Conoc;Phillips -C;~;;¡-ed-bÿ-b;;;;~h~~--F~~~---~;-M~K;~:;~~·~ Dote plotted: 21-tJoy-2003 ! Plot Reference is 1C-172 Version'!. Coordinates orc in feet referenc.e slot' 172. I ]True Verticol Depths orc reference [:¡,t. RK8-87'.~ ..-.. ~ i lNT~:Q _ ..! 0 - 250 - 500 - 750 - 1000 - 1250 - ..--.. ID Q) 1500 - 'I- '--" ..c õ.. 1750 - Q) 0 0 2000 - Ü +- I.... Q) 2250 - > Q) :3 2500 - I.... l- I V 2750 - 3000 - 3250 - 3500 - 3750 - 4000 - 4250 250 Field : Kuparuk River Unit Location: North Slope, I Estimated RKB Elevation: 87' .. KOP .. Drop 1/100 1.00 .. Build 3/100 .. 3.00 6.00 DLS: 3.00 deg per 100 ft : 9.00 Build/Turn 4/100 12.02 15.42 19 05 DLS: 4.00 deg per 100 ft . Build/Turn 4.5/100 22.88 26.93 31.09 DLS: 4.50 deg per 100 ft 35.32 39.61 43.94 48.29 52·~j.04Base Permafrost EOC 296.51 AZIMUTH 3477' (TO CASING PT) ***Plane of Proposal*** Top T-3 TANGENT ANGLE 65 DEG Kop K-15 Build~~~m 4.5/100 EOC Curve 5/100 68.76 64.52 60.98 58.32 57.36 5656;27 Top Ugnu C 56.16 56.34 56.81 57.56 58.58 61.35 64.98 69.29 74.12 EOC TANGENT ANGLE 70.04 DEG DLS: 5.00 deg per 100 ft 250 500 750 1000 1 250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Vertical Section (feet) -> Azimuth 296.51 with reference 0.00 N, 0.00 E from slot #172 ~·R·.r J . . :,./ ~ '. r I , !,I,~~-m 8( <::) ~'t:J ~- L;~) ~,~ ~ ~- ,.--... +- Q) Q) '+- '--" 2100- 2450 - .£: +- 0.. Q) 2800 - o o ü 3150- +- L Q) > 3500 - Q) :J L I- 3850 - I V 4200 - Created by bmichael For: S McKeever ! Date platted: 2t -May-2003 : Plat Reference is 1 C-172 Versian#1. ¡ Coordinates are in feet reference slot #172. i Vertical Depths are reference Est. RKB=87'.¡ ¡;¡r..-;;¡; , ...,.¡¡¡.-- IiüGiti INTEQ DLS: 5.00 deg per 100 ft 56.81 58.58 S0'f. \) ~ 61 .35 ~es\. (, (,0';'\0 64.98 K1~o\> ~o.<o\> 'O\>-~_~ '\ 69.29 <:I \:.-1d",'Y" '\ 76.69 r \>-'J.:' 2800 2450 2100 1750 1400 1050 Structure : Pad 1 C ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit TARGET ANGLE 79.00 DEG eÒ \00 (ceò w...¡e~ Ò ':11 ~ w...¡e \>-1>< 00 ~ 'O0~ ').. \>- \>-y').. '0':1' Y <Ç. 0° \>-'J.:' \>- 700 350 o 350 Vertical Section (feet) - > Well: 172 Location: North Slope, Alaska! /~ 00 ¡>-').. 'ò':1. 1750 2100 ~r ConocoPhillips \.eÒ Áeò ...¡e~ e\ - I>< \0 ...¡ I>< I" 00 '0 \>-~/ '0'0. \>-~..- 2450 3150 700 1050 1400 2800 Azimuth 183.31 with reference 0.00 N, 0.00 E from slot #172 '0e~ " \) '0 'ò '0 \ I').. ¡>-1:1 '0 :J.: ..- ~\) 3500 3850 4550 4900 4200 .···ë;~~t~·~··~;··~;,;;~·~~~i··F~~:···ii·M~K~·~~~·~··: Dot. plotted: 21-t,Aoy-2DD3 Plot Reference is 1C-172 Ver,ion'1. Coordinatos era in foot reforonco slol #172. ¡True Vertical Depths ore reference Est. RKB"S7'.] : e-.. . BAlla HUGIES INn:/) ................................. ............. \ Structure : Pad 1 C ConocoPhillips Alaska, Inc.· Conoc~Phillips Field: Kuparuk River Unit Location: North Slope, Top Ugnu C 296.51 AZIMUTH 3477' (TO CASING PT) ***Plane of Proposal*** \? Curve 5/100 -?\? .& (j 42 \ cr TRUE Tap West Sak D fgß ~ j lA49 5/8 Casing EOC A3-1 I TARGET LOCATION: ¡..... 113' FSL, 2008' FEL CO SEC. 2, T1 1 N, R10E W A2-1 W Build 5/100 ¡..... > EOB N A2-2 A3 Inverted A3-2 A4 Inverted WS W9 A4 MIDPT TGT 07 MAY 03 A3-3 A2-3 A2-4 A3 Inverted A3-4 A4 Inverted A3-5 I TO LOCATION: A2 5 369' FSL, 2302' FEL - SEC. 11, TllN, R10E 172 l TO, 5 1/2 Liner Well: 172 N ~ Build/Turn 4.5/100 4.Q BUlld/Turn 4/;1 00 ~ Build 3'i100 Drop 1/Kl~~ ^v ~ ~ SURFACE LOCATION: 1436' FNL, 1096' FWL SEC. 12, T11N, R10E 5250 4900 4550 4200 3850 3500 3150 2800 2450 2100 1750 1400 1050 <- West (feet) ORlef" L 700 350 - 3150 - 2800 - 2450 - 2100 - 1750 - 1400 1050 - 700 - 350 (J) 0 C -+ :::r ..--... - 350 - ( ) ( ) -+ '--'" - 700 I V - 1050 - 1400 - 1750 - 2100 - 2450 - 2800 - 3150 - 3500 - 3850 350 700 1 C-172 Vers 1 Grid Lat Lon~ ...{eport.doc pp 1 of 5 ConocoPhillips Alaska, Inc. Pad lC 172 slot #172 Kuparuk River Uni t North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License lC-l72 Version#1 prop5389 Date printed Date created Last revised 2l-May-2003 17-Feb-2003 2l-May-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.l73,w149 30 19.124 Slot location is n70 19 31.053,w149 29 47.117 Slot Grid coordinates are N 5968801.596, E 562101.718 Slot local coordinates are 1435.63 S 1096.55 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North OR r ,rft, i1 L i i ~.1 ¡ sf A ORIGINAL All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87, (87.00 Ft above mean sea level). Bottom hole distance is 4858.03 on azimuth 224.34 degrees from wellhead. Total Dogleg for wellpath is 278.93 degrees. Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad lC, 172 Your ref lC-172 version#l Kuparuk River Unit,North Slope, Alaska Last revised : 21-May-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COORDS G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Eas t ing Northing COO R DIN ATE S 0.00 0.00 30.00 0.00 o .OON O.OOE 562101.72 5968801.60 n70 19 31.05 w149 29 47.12 200.00 0.00 30.00 200.00 O.OON O.OOE 562101.72 5968801.60 n70 19 31.05 w149 29 47.12 300.00 2.00 30.00 299.98 1.5lN 0.87E 562102.58 5968803.11 n70 19 31. 07 w149 29 47.09 400.00 1.00 30.00 399.94 3.78N 2.18E 562103.87 5968805.39 n70 19 31.09 w149 29 47.05 500.00 0.00 15.00 499.94 4.53N 2.62E 562104.30 5968806.15 n70 19 31.10 w149 29 47.04 600.00 3.00 15.00 599.89 7.06N 3.30E 562104.95 5968808.68 n70 19 31.12 w149 29 47.02 700.00 6.00 15.00 699.57 14.64N 5.33E 562106.92 5968816.28 n70 19 31.20 w149 29 46.96 800.00 9.00 15.00 798.71 27.25N 8.70E 562110.20 5968828.91 n70 19 31.32 w149 29 46.86 833.33 10.00 15.00 831.58 32.56N 10.13E 562111.58 5968834.23 n70 19 31.37 w149 29 46.82 900.00 12.02 5.83 897.02 45.06N 12.33E 562113 . 68 5968846.75 n70 19 31.50 w149 29 46.76 1000.00 15.42 356.85 994.17 68.70N 12.66E 562113 .82 5968870.39 n70 19 31. 73 w149 29 46.75 1100.00 19.05 351. 14 1089.67 98.10N 9.42E 562110.34 5968899.76 n70 19 32.02 w149 29 46.84 1125.69 20.00 350.00 1113 .88 106.57N 8.01E 562108.86 5968908.22 n70 19 32.10 w149 29 46.88 1200.00 22.88 345.36 1183.05 133.07N 2.15E 562102.78 5968934.67 n70 19 32.36 w149 29 47.05 1300.00 26.93 340.65 1273.74 173.27N 10.27W 562090.04 5968974.76 n70 19 32.76 w149 29 47.42 1400.00 31. 09 337.11 1361.18 218.44N 27.83W 562072 .12 5969019.79 n70 19 33.20 w149 29 47.93 1500.00 35.32 334.33 1444.84 268.31N 50.41W 562049.14 5969069.46 n70 19 33.69 w149 29 48.59 1600.00 39.61 332.08 1524.19 322.56N 77.87W 562021.23 5969123.48 n70 19 34.23 w149 29 49.39 1700.00 43.94 330.21 1598.76 380.87N 110.05W 561988.58 5969181.52 n70 19 34.80 w149 29 50.33 1800.00 48.29 328.61 1668.07 442.87N 146.75W 561951. 39 5969243.21 n70 19 35.41 w149 29 51. 40 1900.00 52.65 327.21 1731. 70 508.18N 187.74W 561909.87 5969308.18 n70 19 36.05 w149 29 52.59 1972 .39 55.83 326.30 1774.00 557.29N 219.94W 561877.27 5969357.03 n70 19 36.53 w149 29 53.53 2000.00 57.04 325.97 1789.27 576.39N 232.77W 561864.29 5969376.02 n70 19 36.72 w149 29 53.91 2100.00 61. 43 324.84 1840.41 647.10N 281. 56W 561814.94 5969446.32 n70 19 37.42 w149 29 55.33 2180.99 65.00 324.00 1876.90 705.89N 323.62W 561772.40 5969504.77 n70 19 38.00 w149 29 56.56 2484.11 65.00 324.00 2005.00 928.14N 485.10W 561609.14 5969725.67 n70 19 40.18 w149 30 01.27 2500.00 65.00 324.00 2011.72 939.79N 493.56W 561600.58 5969737.26 n70 19 40.30 w149 30 01.52 3000.00 65.00 324.00 2223 .03 1306.40N 759.92W 561331. 28 5970101.65 n70 19 43.90 w149 30 09.30 3167.94 65.00 324.00 2294.00 1429.54N 849.38W 561240.82 5970224.05 n70 19 45.11 w149 30 11. 91 3500.00 65.00 324.00 2434.33 1673.01N 1026.28W 561061. 97 5970466.05 n70 19 47.51 w149 30 17.07 3544.67 65.00 324.00 2453.21 1705.76N 1050.07W 561037.91 5970498.60 n70 19 47.83 w149 30 17.77 3600.00 66.10 321. 55 2476.12 1745.86N 1080.55W 561007.12 5970538.45 n70 19 48.22 w149 30 18.66 3700.00 68.19 317.22 2514.97 1815.77N 1140.53W 560946.57 5970607.86 n70 19 48.91 w149 30 20.41 3784.48 70.04 313.66 2545.09 1871. 99N 1195.91W 560890.74 5970663.62 n70 19 49.46 w149 30 22.02 4000.00 70.04 313.66 2618.66 2011.85N 1342.45W 560743.08 5970802.27 n70 19 50.84 w149 30 26.30 4344.44 70.04 313.66 2736.24 2235.37N 1576.65W 560507.10 5971023.87 n70 19 53.04 w149 30 33.14 4400.00 68.76 311.03 2755.79 2270.41N 1615.08W 560468.39 5971058.58 n70 19 53.38 w149 30 34.26 4500.00 66.56 306.17 2793.82 2328.11N 1687.31W 560395.70 5971115.69 n70 19 53.95 w149 30 36.37 4600.00 64.52 301.16 2835.25 2378.58N 1763.02W 560319.59 5971165.53 n70 19 54.45 w149 30 38.58 4700.00 62.65 295.98 2879.76 2421.4lN 1841.61W 560240.66 5971207.73 n70 19 54.87 w149 30 40.88 4800.00 60.98 290.63 2927.01 2456.30N 1922.51W 560159.49 5971241.95 n70 19 55.21 w149 30 43.24 4900.00 59.53 285.12 2976.65 2482.96N 2005.08W 560076.71 5971267.94 n70 19 55.47 w149 30 45.65 5000.00 58.32 279.46 3028.30 2501.21N 2088.70W 559992.95 5971285.50 n70 19 55.65 w149 30 48.09 5100.00 57.36 273.66 3081. 57 2510.89N 2172.75W 559908.84 5971294.50 n70 19 55.75 w149 30 50.55 5200.00 56.67 267.75 3136.04 2511.94N 2256.56W 559825.03 5971294.87 n70 19 55.76 w149 30 52.99 5272.40 56.35 263.43 3176.00 2507.31N 2316.75W 559764.89 5971289.75 n70 19 55.71 w149 30 54.75 5300.00 56.27 261.77 3191.31 2504.35N 2339.52W 559742.14 5971286.60 n70 19 55.68 w149 30 55.42 5400.00 56.16 255.76 3246.95 2488.17N 2420.98W 559660.82 5971269.77 n70 19 55.52 w149 30 57.80 5500.00 56.34 249.75 3302.54 2463.54N 2500.33W 559581.69 5971244.49 n70 19 55.28 w149 31 00.11 5600.00 56.81 243.78 3357.66 2430.63N 2576.96W 559505.33 5971210.96 n70 19 54.96 w149 31 02.35 1 C-172 Vers 1 Grid Lat Lon~ -'-'.eport.doc pp 2 of 5 l K[:\II¡ t' ,I o All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 4858.03 on azimuth 224.34 degrees from wellhead. Total Dogleg for wellpath is 278.93 degrees. Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. 1 C-172 Vers 1 Grid Lat Lon~ Aeport.doc \ pp 3 of 5 Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad lC, 172 Your ref lC-172 version#l Kuparuk River Unit, North Slope, Alaska Last revised : 2l-May-2003 Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5 5700.00 57.56 237.90 3411. 89 2389.69N 2650.29W 559432.35 5971169.44 n70 19 54.55 w149 31 04.49 5773.62 58.28 233.64 3451.00 2354.61N 2701.83W 559381.09 5971133.94 n70 19 54.21 w149 31 06.00 5800.00 58.58 232.13 3464.81 2341.05N 2719.76W 559363.28 5971120.23 n70 19 54.08 w149 31 06.52 5848.71 59.16 229.37 3490.00 2314.67N 2752.04W 559331. 21 5971093.59 n70 19 53.82 w149 31 07.46 5900.00 59.85 226.50 3516.03 2285.06N 2784.84W 559298.66 5971063.72 n70 19 53.53 w149 31 08.42 6000.00 61.35 221.03 3565.15 2222.l6N 2845.05W 559238.97 5971000.34 n70 19 52.91 w149 31 10.18 6100.00 63.07 215.72 3611.80 2l52.82N 2899.91W 559184.68 5970930.56 n70 19 52.22 w149 31 11.78 6179.77 64.58 211.60 3647.00 2093.24N 2939.56W 559145.52 5970870.67 n70 19 51.64 w149 31 12.93 6200.00 64.98 210.58 3655.62 2077 .57N 2949.01W 55913 6.20 5970854.93 n70 19 51.48 w149 31 13.21 6300.00 67.06 205.60 3696.28 1996.99N 2991.98W 559093.89 5970774.00 n70 19 50.69 w149 31 14.46 6400.00 69.29 200.78 3733.48 1911.68N 3028.49W 559058.07 5970688.41 n70 19 49.85 w149 31 15.53 6430.25 69.99 199.35 3744.00 1885.04N 3038.22W 559048.56 5970661.70 n70 19 49.59 w149 31 15.81 6500.00 71.65 196.10 3766.92 1822.30N 3058.27W 559029.03 5970598.80 n70 19 48.97 w149 31 16.40 6539.38 72.61 194.30 3779.00 1786.13N 3068.10W 559019.50 5970562.56 n70 19 48.62 w149 31 16.69 6598.72 74.09 191.61 3796.00 1730 . 74N 3080.83W 559007.21 5970507.07 n70 19 48.07 w149 31 17.06 6600.00 74.12 191.56 3796.35 1729.53N 3081.08W 559006.97 5970505.86 n70 19 48.06 w149 31 17.06 6700.00 76.69 187.12 3821.56 1634.07N 3096.76W 558992.08 5970410.28 n70 19 47.12 w149 31 17.52 6719.68 77.20 186.26 3826.00 1615.03N 3098.99W 558990.00 5970391.23 n70 19 46.93 w149 31 17.59 6767.11 78 .45 184.20 3836.00 1568.86N 3103.21W 558986.15 5970345.03 n70 19 46.48 w149 31 17.71 6787.57 79.00 183.31 3840.00 1548.84N 3104.53W 558985.00 5970325.00 n70 19 46.28 w149 31 17.75 6929.05 79.00 183.31 3867.00 1410.19N 3112.56W 558978.10 5970186.30 n70 19 44.92 w149 31 17.98 7000.00 79.00 183.31 3880.54 1340.66N 3116.58W 558974.64 5970116.75 n70 19 44.24 w149 31 18.10 7264.42 79.00 183.31 3931.00 1081.54N 3131. 59W 558961.74 5969857.54 n70 19 41.69 w149 31 18.53 7311. 00 79.00 183.31 3939.89 1035.89N 3134.23W 558959.47 5969811.87 n70 19 41. 24 w149 31 18.61 7331. 03 80.00 183.31 3943.54 1016.22N 313 5 . 37W 558958.49 5969792.20 n70 19 41.05 w149 31 18.64 7431. 03 85.00 183.31 3956.59 917.28N 3141.10W 558953.57 5969693.22 n70 19 40.07 w149 31 18.81 7531. 03 90.00 183.31 3960.95 817.57N 3146.87W 558948.60 5969593.48 n70 19 39.09 w149 31 18.98 7557.23 91.31 183.31 3960.65 791.42N 3148.39W 558947.30 5969567.32 n70 19 38.83 w149 31 19.02 7631. 03 95.00 183.31 3956.59 717.86N 3152.65W 558943.64 5969493.74 n70 19 38.11 w149 31 19.15 7715.23 99.21 183.31 3946.18 634.47N 3157.48W 558939.49 5969410.32 n70 19 37.29 w149 31 19.29 7885.00 99.21 183.31 3919.00 467.17N 3167.16W 558931.17 5969242.96 n70 19 35.65 w149 31 19.57 8000.00 99.21 183.31 3900.60 353.84N 3173.73W 558925.52 5969129.59 n70 19 34.53 w149 31 19.76 8397.35 99.21 183.31 3837.00 37.735 3196.40W 558906.04 5968737.89 n70 19 30.68 w149 31 20.42 8500.00 99.21 183.31 3820.57 138.89S 3202.26W 558901.00 5968636.70 n70 19 29.68 w149 31 20.59 8555.11 99.21 183.31 3811. 75 193.205 3205.40W 558898.30 5968582.37 n70 19 29.15 w149 31 20.68 8639.31 95.00 183.31 3801.34 276.59S 3210.23W 558894.15 5968498.94 n70 19 28.33 w149 31 20.82 8732.31 90.35 183.31 3797.00 369.31S 3215.60W 558889.53 5968406.20 n70 19 27.42 w149 31 20.97 8739.31 90.00 183.31 3796.98 376.305 3216.00W 558889.19 5968399.20 n70 19 27.35 w149 31 20.99 8839.31 85.00 183.31 3801. 34 476. DOS 3221. 78W 558884.22 5968299.46 n70 19 26.37 w149 31 21.15 8895.31 82.20 183.31 3807.58 531. 55S 3225.00W 558881.46 5968243.89 n70 19 25.82 w149 31 21.25 9000.00 82.20 183.31 3821.79 635.10S 3230.99W 558876.31 5968140.31 n70 19 24.80 w149 31 21.42 9008.90 82.20 183.31 3823.00 643.90S 3231.50W 558875.87 5968131. 50 n70 19 24.72 w149 31 21.44 9031.03 82.20 183.31 3826.00 665.79S 3232.77W 558874.78 5968109.61 n70 19 24.50 w149 31 21. 47 9104.71 82.20 183.31 3836.00 738.67S 3236.99W 558871.15 5968036.70 n70 19 23.79 w149 31 21.60 9333.13 82.20 183.31 3867.00 964.60S 3250.07W 558859.91 5967810.70 n70 19 21. 56 w149 31 21.97 9500.00 82.20 183.31 3889.65 1129.65S 3259.63W 558851.69 5967645.60 n70 19 19.94 w149 31 22.25 9517.35 82.20 183.31 3892.00 1146.81S 3260.62W 558850.84 5967628.43 n70 19 19.77 w149 31 22.28 9713 .77 82.20 183.31 3918.66 1341. 08S 3271.87W 558841.17 5967434.09 n70 19 17.86 w149 31 22.61 9769.77 85.00 183.31 3924.90 1396.635 3275.09W 558838.40 5967378 .52 n70 19 17.31 w149 31 22.70 9869.77 90.00 183.31 3929.26 1496.34S 3280.86W 558833.44 5967278.78 n70 19 16.33 w149 31 22.87 O R' n f'IL~' II l ~é! J' .~ ':;2:': f l' . ,. J S li.ri'~ ,~ i~ '.; j ''', ,WIll All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #172 and TVD from Est. RKB=87 , (87.00 Ft above mean sea level). Bottom hole distance is 4858.03 on azimuth 224.34 degrees from wellhead. Total Dogleg for wellpath is 278.93 degrees. ~I 1 C-172 Vers 1 Grid Lat Lon,5 4"eport.doc pp 4 of 5 Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROP05AL LI5TING Page 3 Pad 1C. 172 Your ref 1C-172 Version#l Kuparuk River Uni t. North 51ope. Alaska Last revised : 21-May-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5 9874.57 90.24 183.31 3929.25 1501.135 3281.14W 558833.20 5967273.98 n70 19 16.29 w149 31 22.88 9969.77 95.00 183.31 3924.90 1596.055 3286.64W 558828.48 5967179.04 n70 19 15.35 w149 31 23.04 10040.37 98.53 183.31 3916.58 1666.035 3290.69W 558825.00 5967109.03 n70 19 14.67 w149 31 23.15 10219.60 98.53 183.31 3890.00 1842.985 3300.94W 558816.19 5966932.02 n70 19 12.92 w149 31 23.45 10500.00 98.53 183.31 3848.41 2119.825 3316.97W 558802.41 5966655.09 n70 19 10.20 w149 31 23.92 10738.70 98.53 183.31 3813.00 2355.485 3330.61W 558790.68 5966419.34 n70 19 07.88 w149 31 24.31 10854.65 98.53 183.31 3795.80 2469.955 3337.24W 558784.98 5966304.83 n70 19 06.76 w149 31 24.51 10925.25 95.00 183,31 3787.49 2539.935 3341.29W 558781. 50 5966234.83 n70 19 06.07 w149 31 24.62 11018.25 90.35 183.31 3783.15 2632.655 3346.66w 558776.89 5966142.08 n70 19 05.16 w149 31 24.78 11025.25 90.00 183.31 3783.13 2639.645 3347.07W 558776.54 5966135.09 n70 19 05.09 w149 31 24.79 11125.25 85.00 183.31 3787.49 2739.345 3352.84W 558771.58 5966035.35 n70 19 04.11 w149 31 24.96 11197.16 81.40 183.31 3796.00 2810.625 3356.97W 558768.03 5965964.05 n70 19 03.41 w149 31 25.08 11225.25 80.00 183.31 3800.54 2838.295 3358.57W 558766.65 5965936.37 n70 19 03.14 w149 31 25.13 11239.45 79.29 183.31 3803.09 2852.245 3359.38W 558765.96 5965922.42 n70 19 03.00 w149 31 25.15 11298.15 79.29 183.31 3814.00 2909.825 3362.71W 558763.09 5965864.81 n70 19 02.43 w149 31 25.25 11300.00 79.29 183.31 3814.34 2911. 645 3362.82W 558763.00 5965863.00 n70 19 02.41 w149 31 25.25 11362.72 79.29 183.31 3826.00 2973.165 3366.38W 558759.94 5965801.45 n70 19 01.81 w149 31 25.35 11400.00 79.29 183 .31 3832.93 3009.735 3368.50W 558758.12 5965764.87 n70 19 01.45 w149 31 25.41 11416.52 79.29 183.31 3836.00 3025.945 3369.44W 558757.31 5965748.66 n70 19 01.29 w149 31 25.44 11500.00 79.29 183.31 3851.52 3107.825 3374.18W 558753.24 5965666.74 n70 19 00.49 w149 31 25.58 11583.30 79.29 183.31 3867.00 3189.535 3378.91W 558749.17 5965585.01 n70 18 59.68 w149 31 25.72 11600.00 79.29 183.31 3870.11 3205.925 3379.86W 558748.36 5965568.62 n70 18 59.52 w149 31 25.74 11696.25 79.29 183 .31 3888.00 3300.335 3385.32W 558743.66 5965474.17 n70 18 58.59 w149 31 25.90 11700.00 79.29 183.31 3888.70 3304.015 3385.53W 558743.48 5965470.49 n70 18 58.56 w149 31 25.91 11800.00 79.28 183.31 3907.29 3402.105 3391.21W 558738.60 5965372 .37 n70 18 57.59 w149 31 26.07 11873.73 79.28 183.31 3921. 00 3474.425 3395.40W 558735.00 5965300.02 n70 18 56.88 w149 31 26.19 11873.75 79.28 183.31 3921. 00 3474.445 3395.40W 558735.00 5965300.00 n70 18 56.88 w149 31 26.19 I .i&Ji'rI o 3395.40W 17-Feb-2003 3216.14W 8-May-2003 3474.44S 369.50S WS W9 A2-TOE RVSD 10 558735.000,5965300.000,0.0000 3921.00 WS W9 A4 MIDPT TGT 0 558889.000,5968406.000,0.0000 3797.00 3104.53W 17-Feb-2003 1548.84N WS W9 M-HEEL RVSD 1 558985.000,5970325.000,2.0000 3840.00 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name - - - - ---- - - -- - -- - -- - -- - - -- -- - - - - - -- - -- - - - - - --- - --- - -- - - - - -- - - -- -- - - - - - -- - -- Targets associated with this we11path 3103.21W 9 5/8' Casing 3395.40W 5 1/2" LINER 1568.86N 3474.39S O.OOE 6767.11 3836.00 O.OOE 11873.70 3920.99 O.OON O.OON 0.00 0.00 0.00 0.00 ----------------------------------------------------------------------------------------------------------- 200.00 200.00 O.OON O.OOE KOP 300.00 299.98 1. 51N 0.87E Drop 1/100 500.00 499.94 4.53N 2.62E Build 31100 833.33 831.58 32.56N 10.13E Build/Turn 4/100 1125.69 1113.88 106.57N 8.01E Build/Turn 4.5/100 1972.39 1774.00 557.29N 219.94W Base Permafrost 2180.99 1876.90 705.89N 323.62W EOC 2484.11 2005.00 928.14N 485.10W Top T- 3 3167.94 2294.00 1429.54N 849.38W Kop K-15 3544.67 2453.21 1705.76N 1050.07W Build/Turn 4.5/100 3784.48 2545.09 1871.99N 1195.91W EOC 4344.44 2736.24 2235.37N 1576.65W Curve 5/100 5272.40 3176.00 2507.31N 2316.75W Top Ugnu C 5773.62 3451. 00 2354.61N 2701.83W Top Ugnu B 5848.71 3490.00 2314.67N 2752.04W Top Ugnu A 6179.77 3647.00 2093.24N 2939.56W K13 6430.25 3744.00 1885.04N 3038.22W Top West Sak D 6539.38 3779.00 1786.13N 3068.10W Top C 6598.72 3796.00 1730.74N 3080.83W Top B 6719.68 3826.00 1615.03N 3098.99W M 6767.11 3836.00 1568.86N 3103.21W 9 5/8 Casing 6787.57 3840.00 1548.84N 3104.53W WS W9 A4-HEEL RVSD 19 MAR 03 6929.05 3867.00 1410.19N 3112.56W A3-1 7264,42 3931.00 1081.54N 3131. 59W A2-1 7311.00 3939.89 1035.89N 3134.23W Build 5/100 7715.23 3946.18 634.47N 3157.48W EOB 7885.00 3919.00 467.17N 3167.16W A2-2 A3 Inverted 8397.35 3837.00 37.73S 3196.40W A3-2 A4 Inverted 9008.90 3823.00 643.90S 3231.50W A3-3 9517.35 3892.00 1146.81S 3260.62W A2-3 10219.60 3890.00 1842.98S 3300.94W A2-4 A3 Inverted 10738.70 3813.00 2355.48S 3330.61W A3-4 A4 Inverted 11298.15 3814.00 2909.82S 3362.71W A3-5 11696.25 3888.00 3300.33S 3385.32W A2-5 11873.73 3921.00 3474.42S 3395.40W TD, 5 1/2 Liner 11873.75 3921.00 3474.44S 3395.40W WS W9 A2-TOE RVSD 10 APR 03 Casing positions in string 'A' - -- - - --- --- - - - - - - - - -- - - - - - - --- - - - - - --- -- - --- - -- - --- -- - - - - --- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - -- - - - -- - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - -- Comment Rectangular Coords. TVD MD -------------------- -------------------- Comments in wellpath PROPOSAL LISTING Page 4 Your ref 1C-172 Version#1 Last revised : 21-May-2003 ConocoPhillips Alaska, Inc. Pad 1C, 172 Kuparuk River Unit, North Slope, Alaska Vertical section is from wellhead on azimuth 296.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ill 1 C-172 Vers 1 Grid Lat Long, Aeport.doc pp 5 of 5 { ~ ConocoPhillips Alaska, Ine. Conoc~:Phillips For: S McKeever Dcte plotted : 21 - '-Acy- 2003 Plot Reference is 1C-172 Versionl1. Coordinates ore in feet reference slot 1172. Vertical Depths ore reference Est. =r~= BADR HUGHES INn:Q Structure: Pad 1 C Well : 172 Field: Kuparuk River Unit Location: North Slope, @ ! TRUE NORTH <=:r c::::J 350 0 1 0 fì7'. .... 3~00····,·,·,·,·,·,· ~'~"""" , , , 4:swo l 320 l I I ; I / / 340 20 210 30 40 310 59.......\0 .................3000 60 70 280 80 270 90 260 100 250 \§ I 0... D.........., ~\~I .l~800 . 24 I' / \ ~ 0200 ~6~~ !~~J~O \ I ~. *..·')(3~ 1. 500 \\ \ / / / ~ / " \ 21 0 . r L/"~'" \ \> / ,;/600 '<:~. ~O...O\( J 1200 d ~. .../\ I ð ~~. ~90 120 '" 300 130 I /900 , \1\ 1800 \\1 60 170 \ ~ .,.... .. 6GO········_-~~\ßf0 "."... /l''4~Ö ~ )<?...oo ". 1 5 0""'" 300 t'...),<300..··?&Ð I '),300 8 @ ''''~ 180 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well OR ~ ¡f"'t. .~ I '1 r '1! .. E K....,.·;~ .1.1 .~ \iÞ/j M j~ l i{,,~ i i'; :~~ ( ( ·uaker Hughes Incorporatèu Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 C 172 1C-172 Vers#1 Date: 5/21/2003 Time: 15:08:08 Page: Co-ordinate(NE) Reference: Well: 172. True North Vertical (TVD) Reference: Wellhead(87') 87.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 11873.75 ft Maximum Radius: 5000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 4/29/2003 Validated: No Planned From To Survey ft ft 0.00 11873.75 Planned: 1C-172 Vers#1 V43 Version: 5 Toolcode Tool Name MWD+SAG+IFR MWD+SAG+IFR (AK) Casing Points MD ft 6767.11 11873.73 TVD ft 3835.97 3920.98 Diameter in 9.625 7.000 Ho)eSize in 12.250 8.500 Name 95/8" 7" Summary Reference .. . Offset Ctr"Ctr ... No':'Go AIJowable lVID MD Distance Area Deviation . ft .·ft .ft· . ·.ft ft Pad 1 C 01 1 C-01 V2 561.37 575.00 390.71 9.71 381.00 Pass: Major Risk Pad 1 C 02 1 C-02 VO 539.58 550.00 274.12 9.37 264.75 Pass: Major Risk Pad 1 C 03 1 C-03 VO 516.92 525.00 165.62 9.01 156.61 Pass: Major Risk Pad 1 C 04 1 C-04 VO 266.07 275.00 85.36 5.25 80.11 Pass: Major Risk Pad 1 C 05 1 C-05 VO 614.94 625.00 132.11 10.60 121.52 Pass: Major Risk Pad 1 C 06 1 C-06 VO 1684.24 1650.00 83.79 40.98 48.30 Pass: Major Risk Pad 1 C 07 1 C-07 VO 2568.01 2375.00 271.33 85.63 189.37 Pass: Major Risk Pad 1 C 08 1 C-08 VO 7253.44 5375.00 377.46 156.66 234.85 Pass: Major Risk Pad 1 C 09 1 C-09 VO 1624.66 1575.00 542.54 45.11 497.54 Pass: Major Risk Pad 1 C 10 1C-10 VO 536.88 550.00 428.52 9.34 419.18 Pass: Major Risk Pad 1 C 102 1C-102 V5 11319.39 10600.00 142.85 70.81 89.65 Pass: Minor 1/200 Pad 1 C 102 1C-102L 1 V3 11214.05 10500.00 173.13 72.28 116.11 Pass: Minor 1/200 Pad 1 C 104 1C-104 VO 579.78 600.00 474.14 10.25 463.90 Pass: Major Risk Pad 1 C 104 1C-104L1 V1 579.78 600.00 474.14 10.25 463.90 Pass: Major Risk Pad 1 C 104 1C-104PB1 VO 579.78 600.00 474.14 10.25 463.90 Pass: Major Risk Pad 1 C 109 1C-109 VO 2403.55 2300.00 407.22 95.62 316.05 Pass: Major Risk Pad 1 C 109 1C-109L 1 VO 2403.55 2300.00 407.22 95.62 316.05 Pass: Major Risk Pad 1 C 111 1C-111 VO 209.21 225.00 378.15 4.31 373.85 Pass: Major Risk Pad 1 C 11 1C-11 VO 2717.17 2400.00 132.43 116.06 32.81 Pass: Major Risk Pad 1 C 113 1C-113 VO Plan: 1C-113 0.00 0.00 356.91 No Offset Stations Pad 1 C 117 1C-117 VO 509.12 525.00 322.98 9.31 313.68 Pass: Major Risk Pad 1 C 119 1C-119 VO 278.08 300.00 304.27 5.57 298.71 Pass: Major Risk Pad 1 C 121 1C-121 VO 255.07 275.00 290.71 5.06 285.65 Pass: Major Risk Pad 1 C 12 1C-12 VO 1638.28 1650.00 72.59 42.03 30.90 Pass: Major Risk Pad 1 C 123 1C-123 VO 232.10 250.00 279.97 4.61 275.37 Pass: Major Risk Pad 1 C 125 1C-125 VO 232.06 250.00 272.24 4.81 267.43 Pass: Major Risk Pad 1 C 127 1C-127 VO 209.16 225.00 267.08 4.33 262.75 Pass: Major Risk Pad 1 C 131 1C-131 VO 185.00 200.00 267.64 3.91 263.73 Pass: Major Risk Pad 1 C 13 1C-13 VO 707.47 725.00 215.82 12.90 202.93 Pass: Major Risk Pad 1 C 133 1C-133 VO 530.67 550.00 272.13 9.32 262.84 Pass: Major Risk Pad 1 C 135 1C-135 VO 216.41 225.00 282.15 4.57 277.59 Pass: Major Risk Pad 1 C 14 1C-14 V1 530.39 550.00 142.44 10.68 131.80 Pass: Major Risk Pad 1 C 15 1C-15 V2 Plan: 1C-15L 1 482.04 500.00 246.15 9.26 236.90 Pass: Major Risk Pad 1 C 16 1C-16 VO 1176.17 1200.00 51.66 29.92 23.68 Pass: Major Risk Pad 1 C 170 1C-170 V10 750.56 750.00 32.75 13.70 19.06 Pass: Major Risk Pad 1 C 17 1C-17 VO 4817.77 4325.00 219.33 244.52 37.46 Pass: Major Risk Pad 1 C 174 1C-174 V24 596.65 600.00 15.51 11.97 3.57 Pass: Major Risk Pad 1 C 178 1C-178 V13 691.44 700.00 110.08 12.96 97.17 Pass: Major Risk Pad 1 C 178 1C-178L1V1 691.44 700.00 110.08 12.96 97.17 Pass: Major Risk Pad 1 C 178 1C-178PB1 V1 691.44 700.00 110.08 12.96 97.17 Pass: Major Risk Pad 1 C 18 1C-18 VO 533.86 550.00 100.84 9.17 91.68 Pass: Major Risk Pad 1 C 184 1C-184 Vers#1 V5 Plan: 595.78 600.00 241 .32 11.34 229.98 Pass: Major Risk Pad 1 C 190 1C-190 V8 224.57 225.00 360.94 4.53 356.42 Pass: Major Risk Pad 1 C 19 1C-19 V6 570.93 575.00 318.48 10.37 308.12 Pass: Major Risk o ./ ~1 L LÇomp~ny~ ·:I1ie~d:.. . ...... ....... ...... . .' J:{e(~..enç~Si~e: . ·R:ef~rên~e\Veïl; . .. ~efirençeWØllp~th;' .,1ker Hughes Incorporate) Anticollision Report ..:" ::':"." .... ....... . Ccin()çoPhiIHpsAlåska.,lnc' ··ISl!P¡arllkRiÿ~rUl]it .pªøJG, . 112 . 1C"112 Vers#1 Summary ~.,j;~.,-~ ·...-.L...+~..ºffset We,ïpath Site. .... ....... . Well Pad 1C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C 22 23 23 24 25 26 27 WS-1 WS-24 1C-22 V3 1 C-23A V2 1C-23PB1 V1 1 C-24 VO 1 C-25 VO 1 C-26 V2 1 C-27 V1 WS1 V1 WS-24 VO Date; .·.···5/g1l2003 'Time:1q:Q8:0&' .'. . Page: < ,... '2' ' .' :.. . . .. . . . . . .. . . . . . . . . : . : . : . :.; :::.: ~ . :. . :." ::' : :. ;: ~ . ~. : "':.:. . : : : :.' .:'. . -.:: .:::: . :: :.: : : . .. ::. .'. . . :..: : . : : '. : . .' . .:: Ç()"Ørai~~te<NEj Reference;· ...... vý~I!:17~;TrUe·Nohh ;ÿêrtiç~lct'YJ»)Røfêre~ce~. . .... ... \i\føl!qead(87')&7.Q (~: I \V·IJ . Rêfereriçe ,MD it . 374.73 491.42 491.42 268.51 440.89 313.47 216.36 5800.00 ··Offset "'MD ft 375.00 500.00 500.00 275.00 450.00 325.00 225.00 3525.00 Ctt-'CtrN'<hG;o, . Distånëe.Area ". ft ... ft 280.85 7.15 289.92 9.08 289.92 9.08 303.42 6.23 345.76 8.11 361.04 6.09 377.47 4.49 3850.39 127.91 ""!C · Allowable . 'D~via~iøn ft 273.70 280.84 280.84 297.19 337.66 354.98 372.98 3744.98 .... .. .... . ... . ...... ...... ..... ...... .... ::.:: :....:.. '. ... : : ': ":"":: : ': : ......: .... ........ ..... .. ... . .. .... ..... . . · .... ......:.:. '.' '. ..... .. . .. ...., . '. . ... .......... . ... ... ............ ......... .'. · . , ........ .. ... .. .... .. . · ........... . . ·.Db;Q'racle .. ...... ...... .. .. .... ... ..... . ...... .. . .. ··Waröing · Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range ~ $ e ~ \ 1 / \ \/ / \ t\ / \ j \ 1900/ \ I \.1 \ .¡ 2500 \< \ I / \ \ 1 500 1500 I ¡ 1306\ \ ······*·_·······..··_···f·..···-l············...~..~~~............ \ \ \ I / '\ 1 ~.~.~........"'............*".J?~Q I / \ ...,.~...... .. + ¡Loo \ \, \ .........................J..~.?~.... 1/ 00 \ \ tl 1 2 \ " 1 400 / I \ \ / I \\1700' / I \ / I \' / f 2300 \\ \ ¡ 11 O~ \ \ / ¡'2200 \\600 '.'. 'y / ./ , 11 000 \ 1 500/J (·11 00 \ . I \ /// \ / \/ . 1200 / .././ \ I // \ 1 400 \ " . . I .. 21 00 )1\/1 000 .\ \ ".'.,.,., ;/900 // \ "., 1.200 // \ \ ., / \ '" . 1 600 ", . . i ../, 1300 \ ,~ê'oo / """'" \. . /",,~OO \ ; 1100 ...\)\ t' 800 ", ,:000 /// ~ 1200 \ I "'''' 11 00 / \ I ~ 1 '0.0 \ "" ,.(800 \ I \" \.,,... \ I i700 "- 2900 \ "'X/· " 1100 , 1000 /'k 1 400 .."'\... \\1 900. // ".'" \ I " 600 , . ..>700.,. 1.000 .J.. 1000 I "*300 \ .." ,.../ ¡ I.. T I '\ 1200 "-... . /Î """ \ I -'II 900 "",'600 1800" ¡ 900 ". 900 eo 300*'2800.. ", '\', ¥'50'" \ "'.. 900 \ I / \ """ '!' 800 I ~OO.. \ 1700 "'" b f 800 '~2700 "'. 800 9···::5 0 I \, ""',." 700 "<'1 !300"',.. 700 ; 600 \ 2600 '"-'" ,.<j( 300 \ 1 0 " 0 .......... 1 0 '....,~OO ~30 ...........~OO )00,. 2400 ··..··...~OO " I~ I 80 <- West (feet) m·ë~~~¡~d·¡;;;··¡;·;;;·i·~¡;·~~ïï?~·;;····S···M~i(~·~~~·;·1 Dot. platt.d : 21-Moy-2DD3 Plat R.r.rence is 1C-172 Versian#1. Coordinates ore in feet reference ::¡Iot *172. True Vertical Depths are r.f.r.nce Est. RKB-87'. ..... IW(D HUGIE5 INT~:Q /fJ / / I / / / / 1400...l.2Q.QQ @.....................J.30o-.......·.....··············· *..... I I l j I i I I / j 1900 I i ¡ I I I I roo I 11700 Q&, ", ".'.'¡ I 1300 ~.31 00 ""'" '. '...'............ ~ I 280 I 260 I 240 I 220 I 200 ) ) ........."....,.........................................................................m........................".......................... ConocoPhillips Alaska, Inc. ~/ ConocoPhillips ...............................................................-....... .............................................................. Structure : Pad 1 C Well : 172 Field : Kuparuk River Unit Location: North Slope, Alaska .............-.....-------..-..--......-....-....-..-..-..---..-.--..-..-----..-..-..-------.----..------..--..--....---------------..- - 360 - 340 - 320 - 300 - 280 - 260 .~"~. ...........-/)})- 240 &- ../ - 220 ../ ./ / ./ /../ %/1200 /..// / / - 200 ^ I z o :::¡. :r - 180 - 160 - 140 .......... -h CD CD -+ '--" -120 -100 - 80 - 60 - 40 - 20 - 20 I 180 40 I , 60 I 140 I 120 I 60 I 40 I o I 20 , 40 I 60 100 20 O· r; :~,.,. r~ /~ .~ i 1\ L : "'1 i" J \;A, .~ 'i ') ') ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 172 ../ ConocoPhillips ~ '~1900 @3700 ~ 1000 , I i \ \ I 'J / ~ I \ \ J 3600 \ '\ 2000 ; \ 180: 13500 ~ \ ;1 ~ - 840 ~ II 1700 \ ¡,,~~OO It _ ::: ~ 1900 \ "~~OO... \ ¡1320010e -"'. t 1 600 r "\2000·", ¡ / \ "'-... I / \ "",- f 31,r \\\ 1'500 ""'. 2300 I / \1900-"" 1800 f ~MOO \"'-" I / \ ~ ¡/,/ \ D - 560 \ .¡\ 1 400·"", , 1/ VI'" \ 1800 . '\ If 2900 \ \ ~2~ \ /1 177 -520 \\ IiI 1 300 ~',)¡, 170rl2¡~§00 / - 480 \ 1700 '" T I / 160e \ \ 1200 ~oo I\J2700 / \ , 600 ."'. t, tl 1500 \\ " I !, I '\ \.. ~62~00 ! '\. y~OO ~\1100 "'\ "'- 'III;, \"'",1, 500 /\ + 2600 /- \ " / 'i "1 4,00 : \,1 / \ '- 35qq¡'èw 1\ 1 g'OO \ '>1<.,1 q \ 1400 I' \ '- I , . . 2~0 \. 1500 >J. 9 \, 1 ~??_}.~~?2QQ.~ 50p i 1 ~O \ , '-'-', \'Ì¡3J .g~O . /....~.l(J'O.....-1.20{)···"'· / ·-r:/·-·-"'\~··"-SO(h,.l.l.~_O - 280 'i 800 '- \ ,..."1000 i .... \ \ .....-.-[J]).- I ~ I ~ I I I ~ ~ I I ,~, ~ I 480 440 400 360 320 280 240 200 160 120 80 40 0 <- West (feet) f·Uë;~~i·~~i··bÿ·ï:;;;:;¡~·h~·;ïii·~·;;···SmM·~K~~·~·~~··ì Dote plotted: 21-Moy-2003 I Plot Raference I_ 1 C-172 Vcr_lonN 1. I Coordinates ore in feat rafarence slot #172. True Vertical Depths ore reference Est. RKB-ST. mii¡¡ BAßR HUGHES INT~:Q Field: Kuparuk River Unit Location: North Slope, ............................................. '1900 Q0,\ ,.,'\. \",1700 \ '......, \", \ , '\ 1800'" \ ., \, '-'...... \\ ''-....... \ '....... \, " \ '- \<,:e I ~, 560 520 3600 Cb",..~200 .....~ .~~ I 680 I 640 I 600 .0 ¡ '~ ,-, . t - 960 - 920 - 880 - 720 - 680 ^ I z o -, -+ ::J - 640 - 600 ,..-.... -+. CD CD -+ '--'" - 440 - 400 - 360 - 320 240 ~~'~A,.' 1/1 , ,:}'" ~, !.:II OR.~ l~ ;f '. ~~: " "., .f \"'~ <- West (feet) 600 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 - 3000 f} ~ ~ ~ \ \ \ \ '\ ~ 4500 \ \ '\ \ 3000 \3000 \ II \ \ \ \ \ '\ \\4000 \ ~.,. - - - - \--....3000 \ 1 70 _ _ _ _ _ \ :'. - / - \ "" \ \ ·~~65.0.. 0 \ ""', \ /~oo", \ ,\ \ " \.~ \ \, "....................."......"". .300.9 .. \ ~,3500 ~ -/'.' \"'... ......~ \ \ " " /; \ "'" , " 2500 '''-. / " \ '" 6000 2500 \ ", \ ~/ \ \. \ " "" · 35 ;\ "\ " \ \. 2500 -0;" I " , ", \ \, \ "" /, "'-.3000 ·'.35àQ', \ \ \ '.',. 3000 / I ..'." . "" \ " 5500 \ ~ 3000 \ \ .. '" " ... , \ \ '-., /, '......" ".'.\. 250d'. \ \ Ì'., ''-. "'., \ \, \ ! ,..,..,... 1 . .',., \\ """ " '\ _ 1400 ' . " \, "'."" \ """ ' \ \ ,', . "", . , í:;;-.... l I 3840,. . ""'" \ '~'~"\~ßOOO. . \ \ \ .J!.¡", 1 '....... "" \ "'" , , 120C ~@Jo., ·'····,·,·,·,"t:·'" . : .,..,.,..,. , ""'>.25Od\ ~" "'''''''' \ 25, 00 \ ~OOO- ""3 " "., " "\ \ "" , _ ..... -"""'. "',., 4500 " 2500 '" \ ~ "" \ \ ""'".,",,-, -.., " \ \ 'Zoo ,\ ,~ _ 1000 I """'~:::-"'" "" "\ \ ,4500. '~ . , "",.,SQ2., "', \, \. '\ ~ _ I I ..,.......>.".. 4000 ", \' \ "- \ 2500 ~ "", , , , ' """''''' ", \ ", \ 3000"',,2500 \ _ 'OC ~'" '>. , "~" "" \ "" \(. .~ \ '. ... " """'''.~" 2000 \. 200b~sooo \ \ ",_ .. "'" ~ , ".. ~ ". , '" 14000 V '> ~""...:"""" , ".. ~, -:;-5eQ.... 'I "'" \ \ 0 _ 600 """""'''f", ~""~~~~:~::~:Ä-"\~""",,,~:,t:\ _ I .. ......... " 1"3!53Q~Ò "" \ \, 0 _ 400 ..... 2'00 '00, '" " ,\) , """'~. "00 " , '"'''' \, 'q¿, : """--'''''''~, "\!"... "~' \:'!'~'::~~ 200 : !illl"... 3500 -----...."..>.¡¡"!1J~ '\. \ "'-~ '2500 '---, ]200,,,, ,¡sEa +" __-~,,"'~~>~.~;:::-,::~ _ 0 I ___ I I I I I I I , ,${. I ~;J.. ~ : ",!,! , ,', ' , , ~ 101111 ~ I I 4000 ....*-........-... IT] 6000 5000 *~_~.?O ".........-.....................-..... - I i ¡ ~ -+. CD CD -+- '----' ^ I z o , -+- :r - 1600 - 1800 - 2000 - 2200 - 2400 rl)... ""<ý, '.'.'.'.", " "".'., - 2600 - 2800 - 3200 ........................... ../. ConocoPhillips Structure : Pad 1 C Well : 172 ····.·....m.....·........·...........................................................................1 Created by bmichoel For: S McKeever i Dote plotted: 21-Moy-2003 I Plat Roloroneo Is 1C-172 Vorsian#1. Coordinates are in feet referenco slot #172. ! True Vertical Depths ore reference E:!It. RK8-87'. i ail. ' IIAKDi HUGHES INTI':Q Field : Kuparuk River Unit Location: North Slope, ConocoPhillips Alaska, Inc. ') ) ) ) ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 172 ~/ ConocoPhillips ···ë~~~t~d··¡;ÿ·ï;·;;;ï~h~~i·i;~·~;····s··ï¡;{~K~~~~·~ Dote plotted: 21-Moy-2D03 Plot Reference is 1C-172 Verslon*1. Coordinates ere in feat raføronce slot #172. True Vertical Depths ore reference Est. RK8-87', a.w BAKIR HUGHES INT~:Q , ~ \ \ \\ \4500 \ \ \I¡.. 3000 \ '\, \ \ \ ~ \ \4000 ~\ ~ ; ~ - - - - - - \ ~32~0 \ '~~OO \' \ """'" /?/,.~\:"-~~ \\ ''<\'';00 ~,. ~o...OII..1 \\", . ~.....60..00 '\ \"" ""<Y- ""', /35( Ì'-. " ""'~.... \ 2500 , ·"·'.',*,.300.0 // / ~ '" 3000 '''-, \~'. ..,.. \ \", ,.,.,., I I ."" .."" 350'Q '.., \ *,2500 /., I '., ., \ .., \ ' .,.,.,.,.,. I .".,'",.,., '.".".", \ ····~5.00 \ ~ 3000 \, "''''~ "",,"\l500\.. \ \ Îð'".. l "3·'S·"'rI. ,., ".",.. \....,'",..,."-. \ \' ~. "'." fj , ~, ',.,. \ "'" \', <Îò:i7ß¡¡¡ "" i ,......, ".'.. \ "'~ \ \', ~~.... ·f·:'" '''''. """. ""'" ~ \ "'--1 ~::':.:::~iL" ""~:oo '-~~ ~\?~"-'-' \ '\ I .....,. "'25QO .'.. ...... \. \..... """'" \,2500 '\ : ...........<:::::>... '''''',,'' ,~\ '\ ~OO ""~\..,.. \ \, ~ I ······.:::~.'i'.,~000 "'".'\" \ 4500' , ~'''J~.. !~'-~" '\~>'" \~~_'..'. 250~\ 2500'~~1000 r '.. I ", ....., 2000 ' ,. ]V.'. ::1".. '1<. , I ··...."..,··,<:"·,r'··'..;;..,,, ······:·~~~;~2,~~:::........,........... \\~~~~~:~\~~ ····~.~~O~~\ ;6~ ~ 800 ."".""'<~""..::..,. '...~"""" ............. . i\ \ ""'.' ~ \ ~ I ','2'boo ....,...1... \ \ ",. !1 - 600 I ......".,.,...".,""-J.~~..~.~.......... 'lit'.." ..,.....,.. I ..."'.....,. '\ "'." 200 \ ~ '. - '."" ··1~~'Qjr'.""":~,,,~\,?c9 h - I .............. ....., I ....\..". '\" \' ,Q - 400 : ..... .. ....... .. ......, \:---····'.\'2500'~ i [illL~._.,,_,-£o,_.~}.oo~.-..,. ........... ···········'··J~~M ~\<'~·~··:;~i~ 200 ..-..,L_........_......_..}5...0..0 _ "'" ! ...,...,..~... ,\ '" _ ~ '. ....2500, ......... '."- i 4500·20g~~~~-' -"'-: L: --::'~ ;~~~;:~:I: 200 i IT\.'~0~_;~00-- -~-~- ~ 'I . -/_------/ ~~;: 400 ~, ~2 ; ..-' ~- tJ ª~ ~ I " 600 1 400 1200 1000 800 600 400 rl).... ~ ,.......,..... ,.,., ,.,....,..,.., .'. @ I i \ \ ; ! If- I! : i , ! : ! ,®$ 3800 3600 Field : Kuparuk River Unit Location: North Slope, 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 <- West (feet) OR r .r~ ,,.,1 i,'1 .,' ~ 'J \..... ¡ ;~ , '~.J"S ~ \ \ \ I \ \ \ 3000 \ \ \ \ \500 \ - 3200 - 3000 - 2800 - 2600 - 2400 - 2200 - 2000 - 1800 - 1600 ^ I z o , -+ :::J - 1400 ~ - CD CD -+ '--" I I I I I I I I ¡. 3800 I I I I I I I ~ 3850 I .....···············i·..············ - 1000 .... ..,.... i 3200 ~.~.~~ <I- 3900 3300 .....;~>éJ}> /'- - 1200 : 34~~......-.,:>/& _ I ...""'3'500,./·/ // : . ~.·3'600 // / - 1400 "",.·370U./ // \ ' !l!:.08'OO / ,/ I ..;:190u // / , ...",.-4<)0'5 / / / / I I "",.-4·15Õ )1<'3000 \ I ~<fÓ'Ò4'~Õ ,///.4600 .......-41$·5"'" : /'.1~~~50 ",.4=9'00 \ I /' r.;;-:;'jf/4'"25 0 ""ßt5oo \ I // ~ ./M"'5'fóg'100 , : ..-//...... ....-5"3'50 \1 I /// .......-5'500 . : // .5"7'55"650 I /' ",.ß31S0 ,A'/ / ./ I ~..",.B950 ;¡«3ÓOOI ~ . .JIt,~J50 I JIt'310q I .<Š150 I 65QO .................. ",,5"200 ........t·············:········ ...,'3250 [E[ \ I ",,<5300 I .....:3350\ " / il .......3400 ¡\ I 3800 /3450 1\ ; ,"~500 IT23Jb I /-~ E::J I l 3550 I ¡ 3600 ~ 3850 13650 ' f f 3700 : f 3750 1- 3900 ~ 3800 I ; 3850 [ill ~ 3900 J 3950 $ 1·-c~~~t·~·dmby-¡;~i~i;;;;ïF-;;:;::~S-~~f'~K~;~~·~- Dot. plotted: 21-May-2003 I Plat Reference is 1C-172 Version#1. I Coordinates ore in f.et reference slat #172. ITrue Vertical Depths are roforence Est. RK8-87'. ! ruJ£.... 1 IlU6llES I lNTIo:Q .................,........"................... ) ') ConocoPhillips Alaska, Inc. ~/ ConocoPhillips Structure: Pad 1 C Well: 172 Field : Kuparuk River Unit Location: Narth Slope, ~ rr 1 I II f I i j II 1/ II ~ <lJlJ................ - 0 . ·······..··-<lli~- - 200 ~ ~ 5100 4700 4450 4250 ~~3.ß...r¡- '11'-.........................·..···.-······-·····"'·········........*..........._....*.. "'-='-- - 400 .......@ 600 .~.. ......~.. ...,......... ............. ........~...~.~..". - 800 "'..3"06õ········ ",".31"00 .,,,,,,3200 )I<"'~350 15~ðgo l3750 l' 3900 4000 ~4100 4200 121 4800 4600 4400 - 1600 (f) o C -+ :J - 1800 ,..-..., --+. <D <D -+ '---" - 2000 !}J- / ;,/ 619.9...",·Œ ···..···7 - 2400 / ;' / // / / / /' i 3000 13050 ,/3100 /3150 I,' 3200 3250 ¡ 3300 ,. 3350 /3450 ,,/3550 ¡ 3650 ¡. 3800 f1 4050 [ill} I V - 2200 6450 .......*...... - 2600 - 2800 - 3000 - 3200 - 3400 - 3600 3800 4200 4000 3200 1600 3000 2800 2600 2400 2200 2000 1800 3800 3600 3400 <- West (feet) Q'f""1 .... 11:·.~ . I:' ,(1 , .,~ \~...-j ) '\ , lC-172 Drillinq Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 12-1/4" Open Hole / 9-5/8" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Stuck Pi pe Risk Level Low Low Low Low Low Moderate Moderate In Mitig~ti()n St~~~~gy Monitor cellar continuously during interval. Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Maintain planned mud parameters, increase mud weight, use weighted sweeps. Diverter drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumpinq out Good hole cleaning, controlled ROP, lost circulation material, constant pipe movement. 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pi pe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate Mitiqation Strateqy Stripping drills, shut-in drills, increased mud weiqht. Good hole cleaning, controlled ROP, constant pipe movement, decreased mud weiqht Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumpinq out O R·:~ · ....... . "', . .'.1, , "~S , f I " ¡: . J ,. . ., ~ \;;..,.. J .'>n 1 C-172 Drilling Hazards Summary. doc prepared by Steve McKeever 5/26/2003 3:31 PM Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/21/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265..ß205 Mobile: (907) 229-6266 email: martin13@slb.com < Toe at Surface Previous Csg. < 16",62.6# casing at 110' MD < Base of Permafrost at 1,900' MD (1,732' TVD) < Top of Tail at 5,700' MD ~ < 95/8",40.0# casing in 12 1/4" OH TD at 6,767' MD (3,835' TVD) Mark of Schlumberger ) SBlI..1'D8P CemCADE Preliminary Job Design 95/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 5,700' MD. Lead Slurry Minimum pump time: 280 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk 0.7632 ft31ft x (110') x 1.00 (no excess) = 0.3132ft3/ft x (1900' -110') x 3.50 (250% excess) = 0.3132 ft3/ft x (5700' - 1900'~ x 1.35 (35% excess) = 84 ft3 + 1962.2 ft3+ 1606.7 ft = 3652.9 ft3 I 4.28 ft3/sk = Round up to 860 sks 84 ft3 1962.2 ft3 1606.7 ft3 3652.9 ft3 853.5 sks Have 250 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 90 min.) 15.8 ppg Class G + 0.5%S1, 0.2%D46, 0.3%D65, 0.4%D167 - 1.17 ft3/sk 0.3132 ft3/ft x (6767' - 5700') x 1.35 (35% excess) = 0.4257 ft31ft x 80' (Shoe Joint) = 451.1 ft3 + 34.1 ft3 = 485.2 ft31 1.17 ft3/sk = Round up to 420 sks 451.1 ft3 34.1 ft3 485.2 ft3 414.7 sks BHST = 85°F, Estimated BHCT = 83°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 40 8.0 20.0 Drop Bottom Plug 5.0 25.0 MudPUSH XL 6 50 8.3 33.3 Lead Slurry 7 656 93.7 127.0 Tail Slurry 5 88 17.6 144.6 Drop Top Plug 5.0 149.6 Displacement 7 492 70.3 219.9 Slow Rate 3 15 5.0 224.9 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 2 centralizers on shoe joints and 1 per joint to the top of tail cement to enhance mud removal. OR"i' . . ,j \1.,,:"iJ c ;~ t, Tree Assy, (476-S770). Vetco Gray Gen la 'Producer" Tubing Head Assy (503-5120) Vetco Gray, Gen I, 11' APISM ".go r - Insulated Conductor Casing, 16' @ +/-110 ' MO o ::::t:J Tubing String: 4-1/2", -.,"""" 12.6 #, L-80, IBT,AB C-) Modiifed (1054-2463) : . Control Line / TEC wire for 'GaurdJan Gauges. held in place w~h / . .:c-anoí'l Clamps on every coupling :~_.~;;? ~- ... - Tubing Hanger, (1063·0317) Vetco Gray Gen la. 4-1/2', w/4.909" MCA Top Connection; 4-1/2", 12.6#, L-80 IBT-Mod box down, drilled for TEC wire passage. - o-c I =r- . (x) Joints Tubing, special drifted to 3.920" "-'" .-..- (1) Profile Nipple, 4-1/2" Camco OBw/3.87S" No-Go Profile, IBT- Mod, set at +/. 500' MO, w~h 10 It special drift pups top & bottom. (x) Joints Tubing (i) Gas Lift Mandrel, (1062-2035) CAMCO 4-112" x 1" Model KBG-2 (00 = 5.984") w~h OCR shear valve installed, pinned to shear when annular pressure is 2500 psi greater than tubing pressure, 4-112" IBT Pin x Pin, with 6 foot 4-112" handling pups, top and bottom, set at +/- 2400 It TVD. "'",,,,,"""" " .m (x) Joints Tubing (i) Gas Lift Mandrel, (1062-2035) CAMCO 4-112" x 1" Model KBG-2 (00 = 5.984") with RO dummy valve installed, 4-112' IBT Pin x Pin, with 6 foot 4-1/2" handling pups, top and bottom. / m (i) Joint Tubing __ (1) Sidemount / Pressure Gauge, Baker 925 Gaurdian, measuring internal / tubing pressure, with handling pups installed on Sidemount collar. / / (i) Joint Tubing (i) (1063-3420) Sliding Sleeve with Profile, Baker Model 'CMU' w/3.812" Camco No-Go profile, IBT-Mod (1063-3420), with 6 It pups and Relief Slot Subs (BOT) top and bottom. wRh (1) Jet Pump installed ""errig release, WeatJreñoni. 3I Revsr.;e Circulation, lbx Nozzle. #xx Th.roat. with fçp XO to CAMCO 3.812 Lock.. ,~ (1) Joint Tubing ///// .m (1) Sidemount / Pressure Gauge, Intake, Baker 925 Gaurdian, measuring / ,~~ intemal tubing pressure, with handling pups installed on Side mount collar. .//- (2) Joints Tubing Packer / Liner Hanger / Seal Bore Assembly, Baker, consisting of: (1) Crossover, 5-'h', 17#, Hydril 521 x 5- 'h",15.5#, Hydril511, Box x Pin. (1) Casing Seal Bore Receptacle. Baker Model 190-47, 5-y,", 17#, Hydril521 Pin x Pin. (t) Crossover, 5-y,", 17#, Hydril521 Box x 7", TKC Buttress Box. (1) Liner Hanger, Baker 9-5/8' x 7' Flexlock. (1) Packer. Liner Top, Baker Model ZXP, 9-5/8" x 7", w/ HR profile. I Top @ +/. 6.300, 3700 TVD, 671 degrees Inclination (1) Seal Assembly, 17 It Baker Model GBH-22, /- 4-112" L-80 IBT- Mod, 6 It handling pups // installed on top. Minimum ID = 3.8S" /' Liner, blank. 5-10>... 15.5#, LBO, Hydril511, inside 9-5/S" casing 9-5/8", 40#, L-80, BTCM Casing Shoe @ 6767' MD /3836' TVD Set @ 78 degrees TD 12-1/4" hole Liner, every other joint perforated /. (1" OD holes, 16 per foot), 5-10>... .m-' 15.5#, laO, Hydríl511 1 / Crossover Joint, 5- H;~;il1;1~B~=~ -.--,/- BTC Pin Reamer Shoe, Ray Oil Tools "Silver Bullet", No Float, 5· 10>",15.5#, BTC 1C-W9 Estimated: Easlings: 560,xxx Northings: 5,xxx,xxx Pad Elevation: 59.2' AMSL Doyon Rig 141 RKB @O' Elevation: 87' AMSL Directional Plan vi Packoff Bushing, Baker, installed in pin end of deepest perforated joint. ,-"-"-- 11 / / / 8-1/2" lateral TD /.@11,874MD/ 3,921 TVD "t'....uCW> .....~;¡:o :~~~ ~~~~ U)~"ë6 .!::t u¡ê¡, ",,,, .QU "å ~o Q. e Q. ~ ( ) U 0):::::1 ~-cu 02.- ....a.Ë = C) ( ) ~.5 .c >1âu g"5~ .- -c 0 Ü c ,- :::::I=>Gí -giüã. ...ëE a.00 .:.::.!::!O CIS...... tJ)0- ...::J:æ (/)-c- ( )ca. :!:CIS tJ) <C '<-/ UI C. .- - - )~ 8 o c: a ) ) '10' S. K. ALLSUP-DRAKE 1045 CONOCOPHILLlPS 711 G STREET· AT01530 ~}. '~7 .> ANCHORAGE AK 99501 DATE 1 V<7 2t I 2£0;; 62-14/311 6~1~~~E ~ 511T6 ðf- l/utS!(f /ltoC1fC I 1$ ¡CO. CO ~OkL- ~,,",-l.J-cL(La--Þ5 h-'_~~//OO - )OLLARS 6J ~... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . , 200WhltoClay Contor Dr.. Newark, DE 19711. / M:~~~,l)1 I: 0 ~ . . 0 0 . I.. 1..': 2 . 8 0 0 0 0 I.. 2 7 2 5 7 II' . 0 ... 5 I LWII'~R!;,IL ) :) TRANSMIT AL LETTER CHECK· LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k;2tJ.... J e.-/7 2- 2-0 3 - 09Ç PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 MC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated . in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 OJ ody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. V\lEª~~E:9.nltl"(t'Çt-lE~~IlI~,. Company _~Qt'lQCº-PHLL,_Lt~$_Al,h_5-KbJNJ~___.___ Well Name: KUJ?ABUKRl~Ul.JJL._j_k-:_H2 Program QEV Well bore seg PTD#: 2030950 Field & Pool _¡g)PAgUK RIVER. WEST SA.I:SJ)JJ.~ - 490150 . Initial ClassfType -D-'~Y-.L't.:..QLL- GeoArea lt90 Unit 111 Q.º-- On/Off Shore P..n_ Annular Disposal Administration 1 Per:rnit fee attache.d.. ........................... . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - . . . . . . . . . 2 .Lease.numberappropriate.... _ . . . . . . . . . . _ . Yes . . . . . . . . . _ . _ _ . . . . . . . . . _ _ . _ . . . . . . . . . . _ _ . _ _ . . . . . . _ _ . . . . . _ . . . . ,3 .u.ni.que well.n.ame.and oumb.er . . . . . . . . . . . . . _ . . _ . . . _ _ . _ . . . . . . . . . _ _ Yes. . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . - - . - - - . . . . . - . . . . - . . . . . - - . . . . . 4 .Well .located i.n.a. d.efinep pool. . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ . _ . . . . . . Yes _ . _ . _ . _ Kupa(UK River., We~t Sa ( QiI Pool. . . _ _ . . . . . . . . . . . .. ...... _ _ _ _ . _ . . . . _ . _ . . . 5 WelUocated pr.oper .di.stance.froJ11. dri.lling unitb.oundalY. _ _ _ . . . . _ . . . . . . . . . _ . . . . . Yes . . . . . . _ . . _ . . . . . . . . . . . . _ . . . . . . _ . . _ _ _ _ _ _ . . . . . . . . .. .. . . . . . _ _ . . . 16 .WeIlJocatedpr.oper_di.stance.froJ11.Qtherwel!s.. _.... _. _. .. _ _ _. _... yes..... _ . RequiJed.spacing.is1Qacres:oeare.stwellpeneJratin.Q_W$ak.A$andi.s.1C:-t17..whicnJs_-:8PO'.away.. _... 7 .S.ufficient.acreaQ.e.ayailable in_driIJioQ. unit. . . . . . . . . . . _ . _ . . . _ _ . . _ . . . . . . . . . _ Yes _ . _ . . . . . . . . _ . _ . _ . _ . . . . . . _ _ . . . . . . . . . . . . . . . _ _ . . . _ . . . . _ . . . . . . . . - - . . . . . . . 8 H.deviated, is. weJlbore platJncluded . . . . . . . . . . . . . . . . . . . . . . Yes _ _ . . . . . . . . . . . . . . . . . . . - - . . . . . . . . - . . . . . . . 9 .oper:ator only affected party. . _ . . _ _ . . . . . . . . . . . _ . . . . . . . _ . _ _ . . . . Yes. . . . . . _ _ _ _ . _ . . . . . . . . . . . . . . . . - . . . . - - - - . - - - . . . - . - - - . - - . . . . . . - - - - - - . . - . . . . . . 10 .oper:ator bas. appropriate_ p-ond in JQrce . . . _ . _ . _ _ _ . _ . . _ . . . . . . . . . _ . _ _ . . . . . Yes . . . _ . . . _ . . . . . . . _ . . . . . . _ . . . _ . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . - - - - . . - . . . . . 11 Permit c.ao be issued witbout co.nservaJion order. . . . . . . . . . . . _ . . . . . . _ . . Yes _ _ . _ . . . . _ . _ _ _ _ _ _ . _ . . _ . . . . . . . - - . - . . . . . . . . . - . . . . - .. . . . . . . Appr Date 12 Pem)itc.ao be issu_ed witbout administr:ati~e_approvaJ _ . _ . _ _ _ _ . . . _ . _ _ . . Yes. . . . . . - - - . . . - - . . . . . . - - - . . . . . - - . - - - . . - . . - - - . . - - - . - - - - - . . . . . . . . . . . . . . . . . . . . . . SFD 5/29/2003 13 _C.ao permitÞe apPJQved befon:! _15-day- wa.it.. _ . _ . . . . . . _ _ . . . . . _ . . . _ . . . - . . - . - Yes - - - - - . . . . - . - . . - . - . . - . - - - . . . . . . . . . . . . . . . . . . . . . . . . . . - - . . . . . - - . . - - . - . - . - . . - . 14 WeIUQcatedwiJhinareaal1d.strataautnori.zedby.lojectiooOr der# (putlO# in.commeots)_<For. NA...... _. _ _..................... _ _ _. _... _. _ _ _. _.. _.... ... _. _. _.... 15 .AJI welJs.Witni.n .1~4.I1Jil.e.area.of reyiewideotified (For: $ervjce.w.e J only). . . _ . _ _ _ _ . _ . . . _ NA . . . . _ _ . . . . . _ . . _ . . . . _ _ _ _ _ _ _ _ _ _ . . . _ - - . - _ - - - - - - . . . . . . . . . . - . - - . . - . - . - - - . - . . . _ _ . 16 Pre-produ.cedinjector; .duraljon_ofpre-prodUGtionless_tnan3months_<For.ser:vLceweII_only) _ _ NA . . . . . _ _ _ . . _ _ . _ . . _ . . _ . . _ . . _ _ _ . _ . . . . . . . . _ . _ _ _ . . _ _ _ . . _ _ _ _ . _ . . - . - . . _ . . . . . . . 17 .ACMP. Finding.of CQn.si.steocy_ has bee.n J$sued. for. tbis pr.olect. . _ . _ _ . . . . . . . _ . . .. . _ _ NA . . . . . . _ . _ _ . . . . . . . . .. _ _ . . . . _ . . . _ _ . . . . . _ . . _ . . _ . . . _ _ _ _ . _ _ _ . . . . _ . _ _ . . . . . Engineering Appr Date TEM 5/30/2003 f:R:t.J\ S"bO Geology Appr SFD Date 5/29/2003 Geologic Commissioner: j)TS - - - . - - - 18 .C.oodu.ctor str:in.g.PJQvi.ded _ . . . . _ _ _ _ . . . . _ . . . _ . _ _ . . . _ _ . . . _ .. . . . _ _ _ _ . . . Yes. . . . _ _ _ _ _ _ . . _ - . . . . . . . . - . . . . - - - - - . . . . . . . . . - . . - - - - - - - - - - . - . - - - . - - . . . . - . - . . . . - 19 .S.urface.ca$ing.PJQtecJs_all_knownUSQWs _... _. _.. _. _ _ _ _ _ _... _. ..... _ _ NA... _ _. _AllaqJ,JifeJ$ex.er:npted~QCfR147.,1.02-<b)(3) _... _..... _ _ _. _ _ _ _ _ _. _.... _ _.... _ _..... _ _' 20 .CMT. v.oL adequ.ate.to circ.uLate.on .cond_uctor_ & SUJf.CSg . .. . _ . . .. _ _ . _ . . . . . . . . . . . _ Yes. . _ . _ . _ . . _ . . . _ _ . _ - _ - _ - . - . . - . . - - . . . - . . . - . - - . - - - - - - - - - . - - - . - - - - - - - - - . - . _ . _ _ . _ 21 .CMT.v.oLa.dequ.ate.t9tie-LnJong.stringto.s!Jd~g........................... _ NA. _.... .Suriaceca.singisJIJe.prQd.uction.CÇl$il1.g,..... _............................... _ _. _... 22 .CMT.wiHcoYer.a!l.Kno.w.n.pro.ductiyebori;ZQn.s......... _ _... _...... _ _. _ _... _ _ No..... _ _ _Slotte.dJioer.completionplaon.ed._ _ _ _. _.. _.......... _. _ _ _. _ _ _.... _.. _ _... _........ 23 .c.asiog desi.Qn$ a.d_eqlJa.te for: C,.T, B _&_ permaJr.osí. . . .. .. _ . _ .. _ . _ . . . . . . _ _ . _ . . . . . .Yes. _ _ _ _ . . . . . . - . _ . - - . - - - - . . . . . . . . . . . . - . . . - . . . . . . . . - - . . . - . . - - - . - - . - - . - . . . . . . . . . 24 AdequateJé;!n.kage.oJ re.serye. pit _ _ _ . _ _ . _ _ _ . . . . . _ . . . _ . . . _ . . _ _ . . . . . . . . . .Yes. _ . . . . _ Big is_equippe.dwitb ~teel.pit~.. No resewe.pH.plaooe.d, Wa.steJo an. approyed_ annuh.l$ Qr .disposaI. weJ!.. . _ . . . . 25 Jf.a. re-drilt has.a.. 1.0:-4.03 for abandon.ment beeo apPJQved . . . _ . _ _ . . . . . _ . . . _ _ . _ _ . NA . . _ _ _ _ _ . _ _ _ . _ . . . . . . - - - . - - . . - . - - . - . . . . . - . . - - . - . - . . . . - . . . . . . . . . . . . . . . . . . _ . 26 .AdequateweUbore $eparat.io.n .prOPO$ed _ . . . . . . . _ . _ . . . . _ _ _ _ . . . . . . . . . . . . _ . .Yes. _ . . . _ _ I?ro~imi.ty- analysi~ perf.orme_d, Clo~e approacl)e.s jd.eotified.. Tra'leJinQ. cyIJn.der: plot.in_cLuded.. _Gyro~ JikeJy_. _ . . _ _ 27 Jf_djver:ter JeqJ,JiJed, doe~ jt meet. reguJa.tiOl1s. _ _ _ . _ . . . . . . . . . . _ _ . _ . . _ _ . . . _ . _ . .Yes _ . . _ . . . . . _ _ . . . . . . . . . _ . . . . . . _ - . - - . . . . . . . . . . . . . . _ _ . _ _ _ . _ _ . . . . _ . . . . _ . _ _ . _ 28 .DJilliOg flu.id_PJogral1J SGhematic.& eqJJipJisí.adequate_ . . . . . . . . . _ _ _ _ . _ . . . . . . . . _ .Yes. . . _ . . _ BtiP e$xpecte.d.betweeI18.6 and. 9.3.. Plan.ned MW. for: WS .9,6.ppg._ _ . . . . . . _ . _ _ . . . . . . . _ _ . . . . 29 _B.OPEs,_d.o .they meet reguJa.tion _ . _ _ _ . . . . . . _. . . . . . _ _ . _ _ . . . _. ........ .Yes. . _ _ _ . . . . _ . _ . . . . . . . . . - - - - . - - - . - - - . . . . . . . - . . . . - . - - . . - - . . . . . . . . . . . . . . . _ _ _ _ _ . . 30 .B.oPE_pres$ ra.tiog a.pprop(iate.; .test t.o.(pu.t p~ig i.n .comments). . . . _ _ _ _ . _ . _ _ . . . . . . _ .Yes. . _ . . . . MASP e$tim.at.ed .at 1.5.05 psi.. 3qOP psi .appropriate, PI?Co likely to. te$t to. qOPQ p~i._ . _ . . . . . _ _ _ .. _ . . . _ _ 31 .Ghoke..man.ifold CQmpJies. w/API.R~-53. (May 64). . . _ . . . . . . _ _ _ _ _ _ . . . . . . _ . . . _ . .Yes. . . . _ .. _ _ _ _ . . . _ . . . . _ _ . . . . . - . . . . . - .. - . . . . . . . . . . . . . . _ . . . . _ . . . . . _ . . . . . _ . _ . . . . . . _ 32 Work will occ.ur witholJt.operation.sbutdown_ _ _ . _ _ . . . . _ _ . _ . . . _ _ _ _ _ . . . _ . . _ . . .Yes. . _ _ . . . _ . _ . . . _ _ _ . . . . . . . . . _ ...... - . . _ . . _ . _ . . . _ . . . . . . . _ _ . _ . _ . _ _ . . _ _ _ . . . _ . . _ _ 33 J$I:m~$.e[1ce. of H2$ gas. prob_aÞle _ _ _ _ . . _ . . . . . . . . .. . . . _ . _ _ _ . . . . . . . . . . . _ . No. . _ _ _ _ _ _. _ _ _ . . . . . . . . . . - - . _ - . - . . - - - - . - . . . . . . - . . - . . . - . - . . _ . . _ . . . _ _ . . . . . . . . . . . . 34 Meçba.nical.cood.iti.on.ot wells wi.thil1 AQB yerified (For.$ervice welJ QnJy). . .. _ _ . _ . _ NA .. . . . _ _ . . . . _ . . . . . . _ _ . . . . _ . . . _ . . .. .... _ . . _ . . . . . _ . _ . _ _ . . . . . . _ . . . .. . . . . . _ _ _ . . . . 35 Permit. Qao Þe issued wlo. hydr:oge.n. s.ul..fide. meaSJJ(e$ _ . . . . . _ . . . . . . . _ _ _ _ . . . . _ _ _ Yes . . _ . . _ _ . . . . . . _ . . . . . . - . - - - . - . . . - . - . . - . - . . . . . . - - - - - - . . . . - . . . . . . _ . . . . _ _ _ . _ . . . . 36 .D.ata..PJes~mted on. pote_ntial O'le.rpres.SUre _ZOl1e~ _ _ . .. .. .. _ _ . _ . . . . . _ _ . . . .. . _ _ .Yes. . _ _ . . . ExPectedJesel"'lojr .pre.sSUJe.s_are. 8.6 :- 9.3 ppg EMW: will be dri.lled with_ 9.4 -: 9.6 ppg.EMW .lTlud.. _ _ . . . . . . . _ 37 .Sei.sr:nic.analysj$. of ~hallow gas.zpoes. . _ . . . . . . .. _ . . . . . _ _ _ . . _ . _ _ _ . . . . . . . NA _ . . . _ . _ . . . _ _ . _ . . . _ . - . - . . . . . . . . . . . . . . . . . . . . - . . . . - _ . _ . . . . . . . . _ . _ . _ . _ _ _ _ . . . . _ . 38 .Seabed .cOl1djtioo survey.(if of{-s¡hor:e) . . . _ _ _ . _ _ . . . _ . . . _ _ _ _ . . _ _ _ _ _ . _ . _ . . . NA . . _ . . . _ . . _ . _ . . . . _ _ . . _ _ . . _ _ _ . _ . _ _ . . . _ . . . . . . _ . . . . _ _ _ _ _ . . . . . . _ . . . _ . . _ . . . _ . . . _ .. 39 _ Conta..ct l1.a.rn.e~phQl1.e.fQr.weekly progre$.s.reports [exploratory .only]. . _ . . _ _ _ _ _ . . . . . . . NA . . _ . . . . _ . . . . _ . . . . _ . . . . . . _ . _ _ . . _ . .. . . . . . .. . . . . . . . _ _ _ _ . _ _ _ . . . . . _ . . . . . _ . . . _ . . _ . _ Date: Engineering Commissioner: ~ W Public Commissioner Date Date as/JatO) ~ ~ D D ( ( ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infomlation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~~~ \"'f\.~;=::cr(¡m¡S3~Ori f" I (' '1 p .~ /", t: :~, h :...) ',/ . U L \.i \i~.I PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE f¡:.~:f; ~:::' r~; t: ~,!~>~~ tt"~~ ¡; \;" ¿"o, '*.."..0::' !iI--:¡¡ ~ ~. ~=., U # REMARKS: 6712.0 11970.0 9.625 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) # WELL CASING RECORD 12 11N 10E # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 87.20 59.20 MWD RUN 4 4 S. TUFT ON F. HERBERT MWD RUN 3 3 C. MEYER F. HERBERT MWD RUN 2 2 C. WONG D. WESTER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: LDWG File Version 1.000 Extract File: LISTAPE.HED ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-172 500292315900 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 18-Aug-03 *** *** LIS COMMENT RECORD 01 **** TAPE HEADER **** LDWG 03/08/15 AWS 01 **** REEL HEADER **** LDWG 03/08/15 &03 -oc(s JdCXJ~ ) ) ) GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 31.053" LONG: W149 DEG 29' 47.117" LOG MEASURED FROM D.F. AT 87.2 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a directional only service from 130 - 3025 feet MD (130 - 2244' TVD). (2) Baker Hughes INTEQ runs 2, 3, and 4 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity and Gamma Ray services from 3025 - 11970 feet MD (2244 - 3933' TVD). (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) The interval from 2161 to 3025 feet MD (1888-2244' TVD) was logged up to 17.8 hours after being drilled. This data was acquired on a MAD pass while reaming to bottom prior to run 2. (2) Commenced formation evaluation logging while drilling at 3025 feet MD (2244' TVD). (3) Depth of 9 5/8" Casing Shoe-Logger: 6716 feet MD (3824' TVD) Depth of 9 5/8" Casing Shoe-Driller: 6712 feet MD (3823' TVD) The interval from 6698 to 6716 feet MD (3821-3824' TVD was not logged due to the 9 5/8" casing. (4) The interval from 8845 to 8900 feet MD (3798 - 3803' TVD) was logged up to 13.2 hours after being drilled due to an LWD tool malfunction. (5) The interval from 11940 to 11970 feet MD (3925 - 3933' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 83 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !!!!!! !!!!!! !!! !! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 ) # FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 2140.0 STOP DEPTH 11970.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MAD MWD MWD MWD $ BIT RUN NO 2 2 3 3R MERGE TOP 2140.0 3025.0 6698.0 8868.0 MERGE BASE 3025.0 6698.0 8868.0 11970.0 # REMARKS: MERGED PASS. FOR PURPOSES OF PRESENTING THE COMPLETE LOGGED INTERVAL THE MAD PASS DATA ACQUIRED WHILE REAMING TO BOTTOM PRIOR TO RUN 2 IS MERGED WITH THE MWD DATA. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lC172 5.xtf 150 ConocoPhillips Alaska, Inc. lC-172 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPS RPS RPS 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F MSB 18704 8.50 ATK MEMORY 6716.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 15-JUN-03 STOP DEPTH 6698.0 START DEPTH 2140.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 2 ! !!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 593 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2140.000000 11970.000000 0.500000 547 Total Data Records: ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 ROP MWD 68 1 FPHR 4 4 5 FET MWD 68 1 HR 4 4 6 MTEM MWD 68 1 DEGF 4 4 ------- 24 · . TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ # BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. TOOL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # 2140.0 6698.0 o 68.0 79.2 TOOL NUMBER ASU 3479 RNT 20089 RNT 20089 12.250 138.0 Spud Mud 9.50 .0 .0 300 .0 .000 .000 .000 .000 114.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT. The interval from 2140 to 3025 feet MD was logged up to 17.8 hours after being drilled. This data was acquired on a MAD pass while reaming to bottom prior to run 2. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VAL U WDFN 1C172.xtf -------------------------------- LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska, I lC-172 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 652 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2140.000000 6698.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 746 records... Minimum record length: 8 bytes 106.0 .0 .0 .0 .000 .000 .000 .000 FloPro 9.35 .0 .0 55000 .0 8.500 6712.0 TOOL NUMBER HBC 55875 RNT 20047 RNT 20047 79.2 85.5 MSB 18704 6.75 AT lAP MEMORY 8900.0 6698.0 8868.0 o 19-JUN-03 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. TOOL GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8868.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 6698.0 log header data for each bit run in separate files. 3 .2500 3 ! !!!!!! !! !!!!!!! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!! !!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 4124 bytes Maximum record length: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 3) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1C172.xtf 150 ConocoPhillips Alaska, I 1C-172 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F 21-JUN-03 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : MSB 18704 6.75 AT/AP MEMORY STOP DEPTH 11970.0 START DEPTH 8868.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 3R .2500 4 !!!!!!!!!!!!!!!!! !! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013.HED *** LIS COMMENT RECORD *** 1024 LDWG .004 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 401 records... Tape Subfile: 4 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6698.000000 8868.000000 0.250000 311 Total Data Records: ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 ) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 11970.0 8868.0 11970.0 o 85.5 73.4 TOOL NUMBER HBC 55875 RNT 20046 RNT 20046 8.500 6712.0 FloPro 9.35 .0 .0 32000 .0 .000 .000 .000 .000 106.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3R (MWD Run 4). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN lCl72.xtf LCC 150 CN ConocoPhillips Alaska, I WN lC-172 FN COUN STAT Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 444 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8868.000000 11970.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 534 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes ) **** TAPE TRAILER **** LDWG 03/08/15 01 **** REEL TRAILER **** LDWG 03/08/15 AWS 01 Tape Subfile: 6 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes
