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200-112
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O_ N. N O N O N N N Q1 O Cl) 0 O O O C u O O O O o O O co O L N N N N N In )n +' O 0 =ice. t� C ..•....,. Q. a 0 u CID CIDC ` E u C O O 01 w d .4 .L_' U CID W4, Y 1 .� u 3r; ah. e-L1 a co al co a fa a) ro 0 GJ R) Z9 ' ' 9 ", E 6J w ro N co N �)-! op l�7 a s N N N N N M ❑ M E Z N -2 w C .it W I r^ }, of C/� a � d� 1 I I F- 'c a�irY rIP c.3 0 u u L a Ima~roject.Well History File Coverage 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, ~;~ ~ 0 - ~//_C~_ Well History File Identifier Organizing ¢o,,~) [] RESC~N [] Color items: · Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: DIGITAL DATA* [] Diskettes, No. [] Other, No/Type BEVERLY ROBIN ~SHERYL MARIA WINDY Project Proofing BY: BEVERLY ROBIN~HERYL MARIA WINDY Scanning Preparation '~ x 30 = ¢(~} + ~ = TOTALPAGES //~'~ OVERSIZED [Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: / / _~. PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _/~~S NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREP~E FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned,wpd ~J ConocoPhillips May 12, 2008 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~ECEtVE~ MAY ~ 6 2008 Commissioner ~ z Alaska Oil & Gas Cans, Commission State of Alaska ~.y Alaska Oil & Gas Conservation Commission AnchoragQ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 c~ ©0 ~, 1 ~ a, Subject: Well Completion Reports for 1 D-141A 1 D-141 and 1 D-141 L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the West Sak well 1D-141 A. Also attached are the reports for the P&A operations for 1 D-141 and 1 D-141 L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, t ~` c~-~----- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling JUL ~ ~ 2008 RT/skad STATE OF ALASKA ~ ~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION YY WELL COMPLETION OR RECOMPLETION REPORT AIND ~~~~$ 1a. Well Status: Oil ^ Gas Plugged Q Abandoned ~ Suspended ' ` 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ~~ I ~~~ ~+~~ (3f}S. ~.OR1(Tll$S Development ~~)~r~~~cploratory Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Dat omp., Susp., ~ fj S •~• Aband.: March ,.2008 2. Permit to Drill Number: 200-112 / 308-019 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. a pudded: August 5, 2000 13. API Number: 50-029-22967-00 ' 4a. Location of Well (Governmental Section): Surface: 14' FSL, 596' FEL, Sec. 14, T71 N, R10E, UM 7. Date TD Reached: August 21, 2000 14. Well Name and Number: 1 D-141 ' Top of Productive Horizon: 1266' FNL, 2074' FEL, Sec. 24, T11 N, R10E, UM 8. KB (ft above MSL):~pf RKB Ground (ft MSL): ,~,N"'AMSL' ~'~ 5. Field/Pool(s): Kuparuk River Field Total Depth: 524' FSL, 2242' FEL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 5376' MD / 3528' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560490 y- 5959678 ' Zone- 4 10. Total Depth (MD + ND): 9550' MD / 377q' TVD 16. Property Designation: ADL 25650 TPI: x- 564304 y- 5958432 Zone- 4 Total Depth: x- 564166 - 5954943 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: ALK 468 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): 1735' TVD 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 lVD HOLE CORD G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE PULLED 16" 151.5# X-65 Surf. 110' Surf. 110' 24" 135 sx AS I 10.75" 40.5# J-55 Surf. 502' Surf. 502' 12.25" 126 sx LiteCRETE 7 5/8" 29.7# L-80 Surf. 5519' Surf. 3600' 9.875" 54o sx ASIII Lite, 49o sx Class G 7" 26# L-80 5519' 6419' 3600' 3829' 9.875" included above 4.5" x 4" 12.6# / 9.5# L-80 6196' 9548' 3809' 3779' 6" 255 sx Class G 23. Open to production or injection? Yes No O 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 perforations sou°~~ar? ^`r 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED balanced plug 5376'-5690' 22 sx AS LiteCRETE II cement retainer @ 5519' 192 bbls cement 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 Q 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 it~~o~~ (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. /~~ _ -- ! ~~{}~ . ' ~t36E • o•a NONE ~ ~Ri ~ ,~- . Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~It,- 28. GEOLOGIC MARKERS (List all formations and encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ 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 1917' 1 1735' needed, and submit detailed test information per 20 AAC 25.071. Top West Sak sand 5885' 3753' West Sak A3 9550' 3779' Base West Sak sand 9550' 3779' N/A Formation at total depth: West Sak A3 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Q~-- Printed Name Rand Th mas Title: Drilling Team Leader § ~~ ~ ~ ~ Si D t ` gnature Phone a e "ZbS6~z33o INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct welt 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 r • Corto~oPhitips Time Log Summary We1N7ew Web Reporting Well Name: 1 D-141 - _ ..` . Job Type: DRILLING SIDETRACK _._.. _~_ _- - - Time Logs _ ---- -- Date F om Tq Dur S. De th E De th Phase Code Subcode T CO_M ___ 02/26/2008 14:30 18:00 3.50 0 0 0 MOVE DMOB P Demob Doyon 15 Rig & Prep to Move f/ 3C Pad to 1 D Pad; Skid Floor, Warm H draulic S stems; Clean Pits 18:00 00:00 .6.00 0 0 0 MOVE DMOB P Demob Rig & Prep to Move f/ 3C Pad to 1 D Pad; Move Off Well, Pick up Mattin Boards, Clean Pad 02/27/2008 00:00 01:30 1.50 0 0 0 MOVE DMOB P Break Modules Apart, P/U Mats and Pre are to Move Off Location 01:30 04:30 3.00 0 0 0 MOVE MOB P Move f/ 3C to Corner of 3C Access & Oliktok Road 1.4 Miles 04:30 08:30 4.00 0 0 0 MOVE WOCC NP Wait on CPF3 &STP Crew Change 08:30. 16:30 8.00 0 0 0 MOVE MOB T Hinge Broke on Rig Floor Module Movin S stem 16:30 20:30 4.00 0 0 0 MOVE WOCC NP Wait on CPF3 &STP Crew Change 20:30 00:00 3.50 0 0 0 MOVE MOB P Move f/ Comer of 3C Access to CPF 3 (1 Mile); Wait on Traffic & Fuel Doyon 15 Equipment on 3C (1.0 Miles); Begin Moving to Kuparuk Drilling Warehouse 02/28/2008 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Move Both Modules f/CPF 3 to Kuparuk Drilling Tools Warehouse (4.2 Miles 05:00 08:30 3.50 0 0 MIRU MOVE WOCC NP Wait on CPF 3 &STP Crew Change 08:30 10:30 2.00 0 0 MIRU MOVE RGRP T Replace Hydraulic Motor on Pit Module Movin S stems 10:30 16:30 6.00 0 0 MIRU MOVE MOB P Move f/ Tool Support Warehouse to KCC 3.7 Miles 16:30 18:30' 2.00 0 0 MIRU MOVE WOCC NP Wait for Crew Change 18:30 21:30 3.00 0 0 MIRU MOVE MOB P Move f/ KCC to 1 D Pad (3.1 Miles) 21:30 00:00 2.50 0 0 MIRU MOVE OTHR P Laying Rig Mats, & Herculite; Adjusting Layouot for Rig w/ Vetco Gra Re 02/29/2008 00:00 01:00 1.00 0 0 MIRU MOVE PSIT P Move the drilling module up onto the mats, s uare u with well 1 D-141 01:00 02:00 1.00 MIRU MOVE OTHR P Shovel behind well 1 D-141 and prepare area for stom er feet. 02:00 03:00 1.00 0 0 MIRU MOVE OTHR P Call the drill site operator. Remove a support scissor for flow lines behind the rig (which is in the way of the stomper foot on the driller's side of sub . rage 1 rt ~ 1 Time Logs Ph e Code Subcode From To Dur S De th E DCpth : Date _ T COM ___ 02/29/2008 03:00 06:00 ____ 3.00 _ 0 - 0 MIRU MOVE PSIT P Move rig over well 1D-141, close doors on the cellar,set drilling module down. Level and shim area for stomper feet. Add more mattin for it module. 06:00 07:00 1.00 0 0 MIRU MOVE OTHR P pre load stomper feet w/ 750 psi. Check well center-OK. 07:00 07:15 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving pit module. 07:15 09:00 1.75 0 0 MIRU MOVE PSIT P Move the pit module onto the matting boards. Maneuver and align up along side of the drilling module (within a foot and arallel .Set module down. 09:00 09:45 0.75 0 0 MIRU MOVE PSIT P Turn tires of the pit module to mate up with the drilling module. Move and set pit module. Note: Moving shop, two small camps, and change house from 3C ad to 1 D ad. 09:45 10:00 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting for skidding the rig floor into the drilling position. Note: Continue moving shop, two small camps and change house from 3C ad to 1 D ad. 10:00 11:00 1.00 0 0 MIRU MOVE PSIT P Skid the rig floor into the drilling position. Center over the well. Note: Continue moving shop, two small camps, and change house from 3C ad to 1 D ad. 11:00 12:00 1.00 0 0 MIRU MOVE RURD P Rig up steam lines to the rig floor. Rig up beaver slide. Rig up steam for all of the rig. Note: Continue moving shop, two small camps, and change house from 3C ad to 1 D ad. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Berm around the rig. Spread herculite for the rockwasher. lay plywood in cellar area. Cleanup rig after rig move. Spot the company man/toolpusher camp, spot truck shop, spot the change house. Note: Continue moving shop, two small camps, and change house from 3C pad to 1 D pad. On pad @ approx 1700 hrs. Note: Moving rockwasher and parts houses from 3C pad to 1 D pad. Note: Doyon 15 Rig acceptance after rig move f/ 3C-14 to 1 D-141 is 1530 hrs 2/29/2008. Time was adjusted back 8 hours for waiting on field wide crew chan es Burin move. 18:00 18:15 0.25 0 0 MIRU MOVE SFTY P Prejob safety meeting. Note: Moving rockwasher and parts houses from 3C pad to 1 D pad. 13.1. mile move, ad to ad. ~- __ ?g2 Z r,~ 1 C~ Time Logs Date From To Dur S De th Depth E Phase Code Subcode T COM 02/29/2008 18:15 22:00 3.75 0 . 0 MIRU MOVE ._ RURD P . __ Continue filling in the cellar area with plywood. Filling gaps with insulation in cellar (two wells in the cellar- # 3 and #111). Working on steam lines. Rig up mud lines under the rig floor. Connect shock hose in mezzanine. Spot the rockwasher and rig up same. Change gaskets inflow line dresser sleeve. Rig up lines from the choke manifold to the pits. Pull the braces in the pipe shed. Clean up as needed after the rig move. 22:00 23:30 1.50 0 0 MIRU MOVE RURD P Well sign information changed on well sign. Permit in the dog house. Work on rig acceptance check fist. Install ground clamp on wellhead. Pull VR plug on the annulus valve (7-5/8" x 4-1 /2" . 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Install second annulus valve. Install flange on the horizontal tubing wing valve. Continue to rig up the rockwasher. Note: Doyon 15 Rig floor to top of multibowl= 36.95', to 4-1 /2" LDS= 37.10', to bowl energize screws 40.65', to the top flutes of the 7-5/8" hanger. Difference of 11.7' from Nordic 3 original measurements. Note :Nordic 3 Rig floor to top of multibowl = 25.25', to 4-1/2" LDS = 25.40'. Rig up berm and 400 bbl horizontal tank for dis lacement. 03/01/2008 00:00 01:30 1.50 0 0 MIRU MOVE RURD P Rigging up lines on the annulus and tubing for upcoming displacement. Rigging up a 400 bbl displacement tank and hardline to rig. Continue to rig up the rockwasher. Note: Doyon 15 Rig floor to top of multibowl= 36.95', to 4-1 /2" LDS= 37.10', to bowl energize screws 40.65', to the top flutes of the 7-5/8" hanger. Difference of 11.7' from Nordic 3 original measurements. Note :Nordic 3 Rig floor to top of multibowl = 25.25', to 4-1 /2" LDS = 25.40'. Rig up berm and 400 bbl horizontal tank for dis lacement. 01:30 04:00 2.50 0 0 MIRU MOVE RURD- P Put 290 bbls of 9.5 ppg brine in the pits. Plump diesel to the test pump for pressure testing hardline. Blow air through secondary kill line from mud pumps-OK. Rig up chart recorder for the annulus and tubin in the cellar. ?age 3 of ~ t C Time Lo s Date th D e th E_ D e From To Dur S Phase Code Subcode T CO_M __ _ 03/01/2008 04:00 06:00 2.00 _ _ 0 _ _ 0 MIRU MOVE _ RURD P Rig up a portable heater for the choke skid/house. Install a 4k guage on the choke manifold. Thaw out a 2" hose to be used to connect to choke house, Fill pits w/another 290 bbls of 9.5 ppg brine. 06:00 08:30 2.50 0 0 SURFA WELC OTHR P Rig up lubricator to pull 4" BVP with Vetco Gray rep. Pull BPV. Appears to have only 20 psi below the 8PV and the same on the annulus. 08:30 12:00 3.50 0 0 SURFA WELC OTHR P Continue to rig up to flush well with hot seawater (8.5 ppg). Blow air through lines to tank. Fill lines w/diesel, then test to 300 psi and 3000 psi. Changed out some guages and needle valve and 2" chicksans on the hard line. 12:00 12:15 0.25 0 0 SURFA WELCT SFTY P PJSM prior to flushing the well. 12:15 12:45 0.50 0 0 SURFA WELCT OTHR P Fill line from pumps to the annulus valve w/ 8.5 ppg/ 110 deg. Pressure test lines to 2500 si, OK. 12:45 20:15 7.50 0 0 SURFA WELCT CIRC P Flush well w/ 110 deg, 8.5 ppg seawater. Pumping w/ rig pump down the 7-5/8" x 4-1/2"annulus., taking returns up the 4-1/2" 12.6 ppf L-80 NSCT tubing to a 400 bbls open top horizontal tank. Using wells group choke skid in line to control pressures. Gauging volumes returned. Pumped 70 bbls before returns to the tank. Pumping 2 bpm w/ 300 - 650 psi. Maintained Well Back Pressure at 200 - 270 Psi; At 145 Bbls Pumped Lost Returns to Choke Skid due to Hose Plugging w/Sludge; Finished pumping a total of 320 Bbls of Hot Sea Water and Changed to Second Truck; Shut in Well w/ 600 Psi on Both Tubing and Annulus Gauges probably trapped pressure); Pumped 270 Bbls more of 8.5 ppg/ 110 deg Hot Sea Water @ 2 bpm w/ 820 -1120 Psi ;For Second truckload Mainteined Well Back Pressure at 600 - 650 Psi; Shut In Well After Full Displacement to Sea Water; 350 Psi on Annulus & 350 Psi on Tubing Gauges. Lost 80 bbls of seawater to the formation Burin dis lacement. 20:15 20:45 0.50 0 SURFA WELCT OTHR P Blow down choke line totank. 20:45 21:15 0.50 SURFA WELCT OTHR P Bleed off through choke line to the horizontal tank. Shut in well with 50 si on both the tubin and annulus. ~` _ _ '.Cat' -1 r;t 3t L I • Time Lomas Date From To Dur -Depth E. Depth S Phase Code Subcode T COM _ __ 03/01/2008 21:15 22:45 1.50 _ . SURFA WELC OTHR P Monitor well. Pressure stabilized at 85 psi. Calculated kill weight fluid @ 9 ppg. 3634' TVD w/ 8.5 ppg fluid & 85 si. 22:45 23:15 0.50 SURFA WELC CIRC P Start pumping 9.5 brine down annulus taking returns up the tubing. Pumping 2 bpm w/ 340 psi, holding 230 psi on tubing while pumping down the annulus. Pumped a total of 25 bbls of fluid. Choke manifold pressure lower than tubing pressure. Shut down um in . 23:15 00:00 0.75 SURFA WELC OTHR P Trouble shoot pressure problem. Change guages, inspected hardline, checked low torque valves, changed a 2" hose. Note: Suspect a problem w/ 2" hose. Found a rock inside of the hose. 03/02/2008 00:00 01:30 1.50 0 0 SURFA WELC KLWL P Killed Well by Reversing 240 Bbls of 9.5 PPG Brine @ 2 BPM to Displace 8.5 PPG Sea Water 01:30 02:00 0.50 0 0 SURFA WELCT OTHR P Shut in Well and Bleed Off Tubular Pressures; Monitor Well for Activity (Static); Blow Down Choke Skid & Lines 02:00 03:45 1.75 0 0 SURFA WELL CIRC P Bull Head 150 Bbl (B & D Lateral Volumes) of 9.5 Ppg Brine into Formation (ICP = 870; FCP = 910) Pum in 1.5 b m. 03:45 04:30 0.75 0 0 SURFA WELCT OTHR P Bleed Off Pressure Through Rig Choke Manifold t/ Poor Bo De asser 04:30 05:30 1.00 0 0 SURFA WELCT CIRC P Reverse Circ Through Rig Choke 221 Bbl 3 BPM w! 260 PSI Surf U Su 05:30 07:30 2.00 0 0 SURFA WELC OWFF P Shut down, bleed lines and blow down lines. Monitor Tubing; Appeared to be Flowing Diesel w/slight Vacuum on Annulus ("U" tubing). Died down and sto ed flowin .Static. OZ:30 09:45. 2.25 0 0 SURFA WELCT OTHR P Set BPV w/ Lubricator. Rig down lubricator. 09:45 10:00 0.25 0 SURFA WELC SFTY P Pre job safety meeting on nippling down tree. 10:00 11:00 1.00 0 0 SURFA WELC NUND P Nipple Down Tree 11:00 20:30 9.50 0 0 SURFA WELCT NUND P Nipple Up BOPE; Change lower pipe rams f/ 2-7/8" to 4 1!2" X 7" variables on Bottom. Attach riser, hole fill, flowline, install dri an. 20:30 22:00 1.50. 0 0 SURFA WELCT OTHR P Rig up testing equipment to test with a 4-1l2" test 'oint. ?~,gc cf ~1 I • • Time Lo s Date From To Dur S. Depth_ E. Depth Phase Code Subcode _T COM 03/02/2008 22:00 00:00 2.00 0 0 SURFA WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Tested to 250 psi low and 3000 psi high. Hold each test 5 minutes. Tested lower pipe rams (4-1/2" x 7" variables) with 4-1/2" testjoint, and upper IBOP on the top drive. Tested the accumulator. Initial system pressure 3150 psi, manifold pressure 1500 psi. After closing 1500 psi, 200 psi build up in 51 seconds, and 3 minutes 44 seconds for full charge. 5 bottles avera a ressure 2400 si. 03/03/2008 00:00 07:00 7.00 0 0 SURFA WELCT BOPE P Continue to Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Tested to 250 psi low and 3000 psi high. Hold each test 5 minutes. Tested lower pipe rams (4-1/2" x 7" variables) with 4-1/2" test joint, and upper IBOP on the top drive. Test upper pipe rams, and annular. Blind rams were tested. All kill line valves and choke line valves. Choke manifold was tested. All tests passed to this point. Oteco gasket on choke line leaked, replaced gasket. Manual valve on choke line leaked through grease fitting, tightened fitting and tested OK. 07:00 07:45 0.75 0 0 SURFA WELC OTHR P Rig down testing equipment, drain stack, blow down choke manifold. 07:45 08:30 0.75 0 0 SURFA WELC OTHR P Pull Test Tool & Plug per Vetco Grey Re 08:30 09:30 1.00 0 0 SURFA WELC OTHR P Pull BPV. 09:30 10:00 0.50 0 SURFA RPCOh RURD P Rig up to reverse circulate. Will pump down 7-5/8" x 4-1/2"annulus taking returns down the flowline. 10:00 12:00 2.00 0 0 SURFA RPCOti CIRC P Reverse Through Secondary Kill Line as Follows: 30 bbls @ 1 BPM w/ 40 Psi; then Increased Rate to 2 BPM @ 90 Psi; at 90 Bbl Pumped - 2 BPM @ 100 Psi; at 200 Bbl pumped - 2 BPM @ 90 Psi; Max Gas 1252 Units; Pum ed 236 Bbfs Total 12:00 12:45 0.75 0 0 SURFA RPCOti RURD P Blow Down Circulating Lines & rig down. R/U to Lay Down 4 1/2" Tubing er Cerntrilift & GBR 12:45 13:00 0,25 0 0 SURFA RPCOti SFTY P PJSM for Laying Down 4 1/2" Tubing 13:00 14:00 1.00 0 0 SURFA RPCO PULD P RIH w/ Landing Jt but Unable to Make Up; P/U T-Bar and Instal! Test Valve; P/U Ladning Jt. and M/U to Hanger; Back Out Lock Down Screws 14:00 14:30 0.50 0 0 SURFA RPC06 SFTY P PJSM on Pulling Hanger, Heat Trace, and ESP Cables w/ Centrilift, Ra chem, GBR ~+ - --- -` ?age fi of ~1 • • _ Time Los _ To Dur S. Depth E Depth Phase Code Subcode T__COM __ Date From 03/03/2008 _ 14:30 14:45 0.25 5,471 5,445 SURFA RPCO PULD P Pull Hanger t/ Floor & Remove Penetrators; P/U 140k, S/O 112k. Remove penetrators through the han er. 14:45 15:15 0.50 5,445 5,445 SURFA RPCOti .PULD P Lay down landing joint. Monitor well via the tri tank. 15:15 16:15 1.00 5,445 5,277 SURFA RPCOti PULD P Lay down Vetco offset hanger (2.01') w/ full jt of 4-1/2" NSCT (38.37) . 4-1/2" NSCT Pup jt (2.27') , 4-1/2" NSCT space out sub (1.17') Lay down the next 4 'ts Total of 5 full 'ts out. 16;15 17:30 1.25 5,277 5,277 SURFA RPCO RURD P Rig up sheave for heat trace cable. Sheave f/ ESP. Install trunk on ESP sheave for environmental concerns while reelin in ESP cable. 17:30 19:30 2.00 5,277 4,350 INTRM1 RPCOh TRIP P POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the tri tank. Total of 35 ~ts out of the hole. 19:30 19:45 0.25 4,350 4,350 INTRM1 RPCO SFTY P - BOP drill with post drill safety meetin . 19:45 00:00 4.25 4,350 3,108 INTRM1 RPCO TRIP P Continue to POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the trip tank. Total of 75 jts out of the hole @ midnight. Calculated fill 17 bbls, actual 24 bbls, 4 bbls over calculated/ 9.5 hour time eriod. 03/04/2008 00:00 06:00 6.00 3,108 815 INTRM1 RPCOh PULD P POOH w/4-1/2" 12.6 ppf L-80 NSCT tubing w! heat trace and ESP cable and clamps/bands. Monitorwell on the trip tank. Total of 149 jts out of the hole. Stra tubin in the shed. 06:00 07:45 1.75 815 168 INTRM1 RPCOti PULD P POOH w/ 4-1/2" 12.6 ppf L-80 NSCT tubing w/ heat trace and ESP cable and clamps/bands. Monitor well on the trip tank. Total of 170 jts out of the hole. 07:45 08:00 0.25 168 149 INTRM1 RPCOti PULD P UD Camco KBG-2-LS GLM & Attached Pu Jts 08:00 08:45 0.75 149 0 INTRM1 RPCOh PULD P POOH w/Slotted Nipple (Damaged),, Seal Section, Gearbox, ESP Motor, & Centralizer 08:45 11:00 2.25 0 0 INTRM1 RPCO RURD P R/D ESP Sheave, Heat Trace Sheave, VD ESP Assembly per Baker Centrilift Re 11:00 12:00 1.00 0 0 INTRM1 RPCOh PULD P UD Baker Tools, GBR Tools, and Heat Trace S ool 12:00 12:30 0.50 0 0 INTRM1 WELC OTHR P R1U to Test SOPE w! 4" test Jt. Make u Vetco test lu , RIH & Flood Stack 12:30 13:00 0.50 0 0 INTRM1 WELL BOPE P Test Plug & Blind Rams to 250 / 3000 Good . 13:00 15:30 2.50 0 0 INTRM1 WELCT OTHR P Drain Stack & Change Lower Rams to 3 1/2" X 6" and U er Rams to 2 718". .'age' of ~t ~ ~ ~ Time Logs Date From To Dur S Depth E De th Phase Code Subcode T COM _ 03/04/2008 .15:30 19:00 ..3.50 0 0 INTRM1 WELCT B~PE P Test BOPE; Chart test. AOGCC notified of test. Lower Rams w/ 4" DP 250 / 3000; Lower Rams w/ 5 1/2" Tubing 250 / 3000; Annular Preventer w/ 51 /2" Tubing to 250 / 3000; Upper Rams w/ 2 7/8" Tubing 250 / 3000; Annular Preventer w/ 2 7/8" tubing to 250 / 3000 Ali Passed . 19:00 19:30 0.50 0 0 INTRM1 WELCT OTHR P Blow down choke manifold, kill line. and choke line.-Rig down testing e ui ment. 19:30 20:00 0.50 0 0 INTRM1 WELCT OTHR P Pull test plug. Set Vetco Gray wear bushing (1.96' long, 10-3/4" OD x 7-13/16" ID 20:00 20:45 0.75 0 0 INTRM1 RPCOti RURD P Rig up to pickup and make up 2-7/8" 20:45 21:00 0.25 0 0 INTRM1 RPCOti SFTY P Pre job safety meeting prior to picking up 2-7/8" 6.4 ppf, L-80 Hydril 511 tubin stin er for lu in 1 D-141. 21:00 23:00 2,00 0 1,061 INTRM1 RPCO PULD P Pickup/Makeup to 800 ft Ibs 36 joints of tubing tail. 2-7/8" 6.4 ppf, L-80, hydril 511. Drifted to 2". Lost 1.5 bbls while running in the hole w/ 2-7/8" dp. Note: ID 2.441 inch, capacity .00579 b f. 23:00 00:00 1,00 1,061 1,342 INTRM1 RPCOh PULD P Pickup/Makeup 4" DP (XT-39) 4" 14 ppf, S-135. Drifted to 2.34". Note: ID 2-9/16" inch, capacity .0105 b f. 03/05/2008 00:00 03:45 3.75 1,342 5,589 INTRM1 DRILL TRIP P RIH w/ 2 7/8"mule Shoe on 4" DP f! 1342' - 5589' MD; Tagged Obstruction 5589 03:45 06:45 3.00 5,589 5,599 INTRM1 DRILL CIRC P CBU 210 GPM / 500 PSI @ 5589' MD and Attempt to Work Through Obstruction; Worked !Washed String Down to 5599' MD; P/U 140, S/O 103, 336 GPM / 1120 PSI 06:45 07:00 .25 0 5,599 5,599 INTRM1 DRILL CIRC P Pump 30 bbl 9.5 PPG 300 Vis Sweep _ w/Moderate Cuttings Increase (Mostly Sand 07:00 08:00 1.00 5,599 5,608 INTRM1 DRILL TRIP P Contine to Work String Through Tight Spot f/ 5596' - 5608' MD; Worked Past Obstruction @ 5608 and Seemed Better; Circ'ed @ 420 GPM / 1380 PSI; Max Gas 4047 Units, Average Gas 150 Units Over Interval 08:00 08:15 0.25 5,608 5,608 INTRM1 DRILL CIRC P Pump 30 Bbl 9.5 PPG 300 Vis Sweep w/Moderate Cuttings Increase (Mostly Sand r'agt• S of t ~ ~ Time Logs_ __ ale From To Dur S. De th E. De th Phase Code Subcode T COM 03/05/2008 08:15 12:00 3.75 5,608 5,713 INTRM1 _ DRILL CIRC P Wash Down in First hole Section f/ 5608' - 5745' MD; 610 GPM / 3150 PSI; P/U 145, S/O 100; Back Washed 90' and Hole Sloughed In @ 5650' MD; Washed Back in f/ 5650' - 5713' MD and Bottomed Out; Max Gas 2590 Units; Average Gas 200 -400 Units Over Interval; Noticed Thumb Sized Cement Comiri Over Shakers 12:00 12:30 0.50 5,713 5,605 INTRM1 CEME OTHR P POOH f/ 5713' - 5605' MD; Work Pipe to Find Window; Past Window Area @ 5605' MD; 545 GPM / 2500 Psi 12:30 14:30 2.00 5,605 5,713 INTRM1 CEME OTHR P Wash Down in Second Hole Section f/ 5605' - 5650' MD; Very Rough Drag & Taking Weight; 545 GPM / 2500 Psi; POOH to 5605' MD & Work Pipe to Locate Window; Worked Window Area f/ 5592' - 5622' MD; Found Ledge and Fell Through Into First Hole Section @ 560b' MD; RIH t/ 5713' MD; Max Gas Observed 1277 Units; Average Gas 200 Units Over Interval; Note: A eared to be Back in Main Wellbore 14:30 15:00 0.50 5,713 5,663 INTRM1 CEME OTHR P Contiued to Wash Down f/ 5713' - 5723 ; Back Washed t/ 5663' While Workin Pi e 15:00 15:30 0.50 5,663 5,663 INTRM1 CEME CIRC P Pumped 30 Bbl 9.8 PPPG 300 Vis Sweep, 20 Bbl 9.8 PPG Brine, Followed by 30 Bbl 9.8 PPG 300 Vis Sweep; Lost Retuns After Second Sweep Turned Corner; Hole Packed Off 15:30 17:00 1.50 5,663 -5,385 INTRM1 CEME OTHR P POOH f/ 5663' - 5385' MD; Couldn't Go Down Lost 15 -20 K String Weight Due to Packing Off; Worked Tight Hole and Re establish Circulation @ 42 GPM / 360 Psi; Stage Pumps up to 460 GPM 560 Psi 17:00 18:00 1.00 5,385 5,673 INTRM1 CEME OTHR P Wash Down in First Hole Section f/ 5385' - 5673' MD; 200 GPM / 500 Psi; Circulate Bottoms up after Every Stand; Max Gas Observed 1200 Units after Pum s Shut Off and Restarted _ ~_: Cje 4 07 1 i. r~ ~ Time Logs -_ _. bate _ From To Dur 5. Depth E. Depth Phase Code Subcode _T CQM ___ _ 03/05/2008 18:00 21:15 3.25 5,673 5,690 INTRM1 DRILL CIRC P Continue to work through obstructions, washing down f/ 5673' to 5690'. Stage pump rate up to 336 gpm w/ 850 psi, then 483 gpm w/ 1750 psi. Pump a 30 bbl sweep (300 vis/ 9.8 ppg) with no increase in cuttings. Pumped another sweep @ 5690' with no increase in cuttings. PU wt 145k, SO wt 105k. Note: AOGCC inspector John Crisp was notified that we are only able to get to 5690' and will cement a balanced plug (11 ppg cement) w/ top of cement planned to be 5381' (150' above top of 7-5/8" x 7" x-o} with pipe out of the hole. 21:15 22:15 1.00 5,690 5,690 INTRM1 CEME OTHR P Lay down (2) joints of 4"drill pipe (jt# 149 and #150). Blow down top drive. Ri u head in and 2" cementin line. 22:15 23:00 0.75 5,690 5,690 INTRM1 CEME OTHR P Circulate @ 336 bpm w/ 920 psi. Staged pumps up to 400 gpm w/ 1220 psi. Held pre job safety meeting w/ Dowell and ASRC truck drivers and drillin crew for cement 'ob. 23:00 23:45 0.75 5,690 5,690 INTRM1 CEME PLUG P Switch over to Dowell: Dowell mix and pump 5 bbls of MudPush II (10 ppg), test lines to 3000 psi, follow with 14 more bbls of MudPush II @ 10 ppg (Total of 19 bbls), mix and pump 13 bbls (22 sx) of arctic set LiteCRETE 11 ppg (3.35 cu ft/sx yield) (11.374 gal/sx mix water), follow with another 3 bbls of Mud Push II 10 23:45 00:00 0.25 5,690 5,690 INTRM1 CEME DISP P Rig displace cement to balance with top of cement @ 5376' with pipe in the hole (5381' with pipe out of the hole). Displace, pumping 4 bpm w/ 410 psi for 35 bbls pumped, then slowed to 2.5 bpm w/ 240 psi until 45 bbls were pumped (Cut short 5 bbls of calculated 50 bbls.). Shut down, cement is balanced. CIP 0005 hrs 3/6/2008. 03/06/2008 00:00 00:15 0.25 5,690 5,654 INTRM1 CEME OTHR P Break off a single of 4" drill pipe and put in the mouse hole. Change elevators to 4". 00:15 01:15 1.00 5,654 4,900 INTRM1 CEME TRIP P Pull out of the hole 8 stands of 4"drill i e. PU wt 120k, SO wt 100k. 01:15 02:00 0.75 4,900 4,900 INTRM1 CEME CIRC P Circulate 800 gpm w/ 3460 psi to clean drill pipe. No cement noticed at the shakers. Maydbe some mud push. Circulated 738 bbls. 02:00 02:15 0.25 4,900 4,900 INTRM1 CEME CIRC P Obtain slow pump rates with both um s. Monitor well- static. 02:15 02:30 0.25 4,900 4,811 INTRM1 CEME TRIP P Pull one stand of 4" drill-pipe 02:30 02:45 0.25 4,811 4,811 INTRM1 RIGMN' SFTY P Pre job safety meeting on slip and cut drillin line. Fa.~~ 10 of 31 ~ ~ Time Logs --- - - - ~ - -- -- `iI Date From To Dur _ 5. Depth E. Depth Phase Code Subcode T COM _ ____ 03/06/2008 02:45 04:30 1.75 4,811 4,811 INTRM1 RIGMN SVRG P Slip and cut 112' of 1-3/8"drilling line. 04:30 05:00 0.50 4,811 4,811 INTRM1 RIGMN' SVRG P Service Rig 05:00 06:45 1.75 4,811 4,811 INTRM1 RIGMN SVRG P Change 4" XT-39 saver sub on the top drive. 06:45 07;00 0.25 4,811 4,811 INTRM1 CEME CIRC P Circulate bottom's up prior to pulling out of the hole. Pumping 800 gpm w/ 3500 si. 07:00 07:15 0.25 4,811 4,811 INTRMI CEME OTHR P Monitor well, static. 07:15 07:30 0.25 4,811 4,811 INTRM1 CEME OTHR P Install stripper rubbers and air slips. Blow down the to drive. 07:30 11:00 3.50 4,811 0 INTRM1 CEME TRIP P POOH w/ 4" Dp & 2 7/8" Tubing f/ 4811' - 0.0' MD; Found last 2 Jts & Bent Mule Shoe Jt still in hole due to broken threads (88.31' of 2 7/8" 6.5 PPF Hydril 511 tubing Left in Hole) -last jt out of hole was also bent with a dent T u from Pin. 11:00 11:30 0.50 0 0 INTRM1 CEME OTHR P Clean and Clear Rig Floor; UD GBR Tubing Running Tools. Change elevators. 11:30 13:00 1.50 0 286 INTRM1 RPCOh PULD P PU BHA to tag cement and clean out to 5521'. 13:00 16:00 3.00 286 2,632. INTRM1 RPCOA PULD. P Pickup/makeup 4"drill pipe and single in the hole. Rabbit to 2-1 /2" Picked up 75 'ts from the i e shed. 16:00 16:15 0.25 2,632 2,632 INTRM1 RPCO CIRC P Attempt to circulate bottom's up. Pumping 600 gpm w/ 2600 psi. Observed high pump pressre after um in 240 strokes. 16:15 16:45 0.50. 2,632 2,632 INTRM1 RPCOh OTHR T Trouble shooting high pump pressure issue. Blow down the top drive and mud um .Line is clear. 16:45 17:30 0.75 2,632 2,632 INTRM1 RPCOh CIRC T Rig up to reverse circulate. Attempt to reverse circulate by pumping through the kill line w/ annular preventer closed. Trapped pressure was observed a ain. 17:30 20:30 3.00 2,632 0 INTRM1 RPCOh TRIP T Drop a hollow 1.9" OD rabbit with 1.10' of wire tail. Pull out of the hole wet. Retrieve hollow rabbit when at the top of flex drill collars. Found a plastic rabbit at the non-mag bit sub. Top side of plastic rabbit was 2.3" OD and bottom of rabbit was 2.04".Pictures osted to the "X"drive. 20:30 21:00 0.50 0 0 INTRM1 RPGOti OTHR T Remove the 2.3" x 2.04" rabbit from the bit sub. 21:00 23:00 2.00 0 2,632 INTRM1 RPCO TRIP T Make up BHA #1, run in the hole w/ 25 stands of 4" drill pipe from the derrick. 23:00 23:15 0.25 2,632 2,632 INTRM1 RPCOh CIRC P Make a top drive connection. Circulate 800 m w/ 2640 si. • I _ ?ge 11 of ~1 I, Time Logs __ __ _ ssUBte From To Dur S De th E. De th Phase Code Subcode T COM __ _ 03/06/2008 23:15 00:00 0.75 2,632 3,290 INTRM1 RPCOb PULD P Pickup/makeup 4"drill pipe and single in the hole. Rabbit to 2.34". Picked up 21 jts from the pipe shed (Total of 32 stands in the hole . 03/07/2008 00:00 02:00 2.00 3,290 4,792. INTRM1 RPCOh TRIP P Con't to Single in f/ 3290' - 4792' MD; Monitor Dis lacement on Tri Tank 02:00 02:30 0.50 4,792 4,792 INTRM1 RPCOh CIRC P CBU @ 765 GPM / 3550 Psi; Max Gas 4 Units 02:30 04;00 1.50 4,792 5,359 INTRMI RPCOti TRIP P Con't to Single in f/ 4792' - 5359' MD; P/U 140, S/O 105 04:00 04:15. 0.25. 5,359 5,359. INTRM1 RPCOh CIRC P Circulate BU @ 5359'. Mud push circulated out of hole, no apparent cement. 04:15 04:30 0.25 5,359 5,450 INTRM1 RPCOti OTHR P Wash Down f/ 5359' -5450` MD; 170 GPM / 450 Psi. Mud push circulated out of hole, no a arent cement. 04:30 05:15 0.75 5,450 5,450 INTRM1 DRILL CIRC P Circulate @ 750 GPM / 3450 Psi. Mud push circulated out of hole, no a arent cement. 05:15 05:30 0.25. 5,450 5,530 INTRM1 DRILL OTHR P Washed Down f/ 5450 - 5530' MD; Tagged XO on Depth. Mud push circulated out of hole, no apparent cement. 05:30 06:30 1.00. 5,530 5,530 INTRM1 DRILL CIRC P Circ & Cond Mud Mud; 650 GPM / 2980 Psi. While pumping PU wt 140k, SO wt 100k. 06:30 07:30 1.00 5,530 5,530 INTRM1 DRILL RURD P Blow Down Top Drive; R/U to Test Casin 07:30 07:45 0.25 5,530 5,530 INTRM1 DRILL OTHR P Test 7 5/8" Casing; Start @ 1/2 bbl/min Pressure Broke Over @ 560 Psi; Shut In @ 3.8 bbls Pumped w/ 420 Psi; 420 Psi Held f/ 10 Minutes 07:45 08:30 0.75 5,530 5,530 INTRM1 DRILL CIRC P Establish Injection Rate f/ 7 5/8" Casing; 1 Bpm Pressure Peaked @ 740 Psi; 1 1/2 Bpm Pressure Peaked @ 780 Psi Then Broke Over and Maintined 750 Psi; Bled 5 Bbl Back to Trip Tank. Pumped a total of 23 bbls to the formation. 08:30 08:45 0.25. 5,530 5,530 INTRM1 DRILL OTHR P Blow Down Test Equipment and Kill Line 08:45 09:00 0.25 5,530 5,530 INTRM1 DRILL OWFF P OWFF (Static) 09:00 10:00 1.00 5,530 5,530 INTRMI DRILL CIRC P CBU X 3.5;.730 GPM / 3550 Psi; Hea Cuttin s Increase on First BU 10:00 10:15 0.25 5,530 5,530 INTRM1 DRILL OWFF P OWFF (Static) 10:15 13:15 3.00 5,530 . 285 INTRM1 DRILL TRIP P POOH f/ 5530 - 285' MD; P/U 148, S/O 110, Rot 128 13:15 14:15 1..00 285 0 INTRM1 DRILL PULD P UD BHA#1, Mi117 Scraper 14:15 14:45 0.50- 0 0 INTRM1 DRILL OTHR P Clean & clear Rig Floor 14:45 15:00 0.25 0 0 INTRM1 DRILL PULD P P/U BHA #2; Retainer --- ~' i'a:;c 12 cf t • Time Logs T COM _ ___ From To Dur 5 De th E_ De th Phase Code Subcode__ Date _ 03/07/2008 15:00 18:00 3.00 0 4,042 INTRM1 DRILL TRIP _ P RIH f/ 0 - 4042' MD; String Speed 70 FPM f/ 0 - 3996 MD, then 60 PFM t/ 4042' MD; P/U 140, S/O 100, 18:00 23:00 5.00 4,042 5,530 INTRM1 RPCO TRIP P Continue to run Baker K-1 retainer (Comm No. H400-21-4322) from 4042' to 4800' with running speed 60'/minutes, then contiue running from 4800' to 5530' @ 10'/minutes. Wash down as needed, pumping 2 bpm w/ 170 psi. Tagged upon depth on 7-5/8" x 7" crossover 5530'. 23:00 23:45 0.75 5,530 5,522 INTRM1 RPCOh TRIP P Pickup and set retainer with bottom @ 5522.37'. PU wt 150k, SO wt 103k. Picku and re veri de th. 23:45 00:00 0.25 5,522 5,517 INTRMI RPCOh CIRC P Circulate bottom's up prior to testing casing. Mud wt 9.8 ppg. Pumping 420 m w/ 1300 si. 03/08/2008 00:00 00:45 .0.75 5,517 5,517 INTRM1 RPCO CIRC P Stand back stand # 59. Lay down 15' pup, makeup headpin on (15') 4"pup joint. Makeup stand #59; run in the hole, break off top single of 4", makeup the 15' pup jt w12" 1502 female threads on head in. 00:45 01:30 0.75 5,517 5,517 INTRM1 CASIN KURD P Rig up to test the 7=5/8" 29.7 ppf L-80 BTGM casin . 01:30 03:15 1.75 5,517 5,517 INTRM1 CASINC DHEO P Test casing to 3000 psi. Chart test. Hold test for 30 minutes, good test, Post 40 psi in 30 minutes..Pumped a total of 3 bbls with 3 bbls bleed back. Tested w/ 9.8 ppg brine. Bottom of retainer @ 5522' ,top @ 5520' (3600' TVD . 03:15 04:15 1.00 5,517 5,517 INTRMI CASIN DHEQ P Slack off, set 14k on the Baker K-1 retainer (Comm No. H400-21-4322) @ 5520.37' (TVD 3600') .Perform infectivity test below retainer with top side open to atmosphere. Pumped @ 1 bpm w/ 770 psi, 1-1/2 bpm w/800 psi, 2 bpm w/ 820 psi. Shut down after pumping 65 bbls. Pressure bleed off to 625 psi static. Bleed off the rest of the pressure, then pull out of retainer. PU wt 152K, SO wt 104k. 04:15 04:45 0.50 5,517 5,517 INTRM1 CEME~ OTHR P Adjust pressure on the annular to be able to strip through with 500 psi on the 7-5/8" casing x 4" drill pipe, Regulator on rig floor reading 750 psi and gauge at the accumulator was reading 525 psi. Was able to slack off and set 14k on the retainer. With the annular shut: PU wt 160k, SO wt 93k. 04:45 05:00 0.25 5,517 5,517 INTRM1 CASIN DHEQ P Perform a 5 minute test to 2000 psi on the 7-5/8" x 4" annulus after pulling out of retainer. OK. Page ~}3 of 31 ~ ~ Time Logs _ __ _ Date______ From To Dur 5 De tp h E. De th.Pt~as_e Code Subcod_e_ T COM ___ ___ 03/08/2008 05:00 06:00 1.00 5,517 5,517 INTRM1 CEME CIRC P Displace 9.5 ppg brine in the hole to 8.4 ppg seawater. Pumping 7 bpm w/ 750 psi initial, 550 psi final circulating ressure. 06:00 06:30 0.50 5,517 5,517 INTRM1 CEME OTHR P Monitor well (Static) 06:30 07:30 1.00 5,517 5,517 INTRM1 RIGMN' SVRG P Rig Service 07:30 08:00 0.50 5,517 5,517 INTRM1 CEME CIRC P Circ @ 615 GPM / 2510 Psi for 2X BU 08:00 09:00 1.00 5,517 5,517 INTRM1 CEME KURD P B/D Top Drive & Cement Lines; R/U Doyon Lines t/ P/A B & D Lateral w/ 15.8 PPG Cement 09:00 10:00 1.00 5,517 5,517 INTRM1 CEME OTHR P Obtain Injection Rate of 2 BPm w/ 900 Psi Below Retainer; Adjust Annular Preventer Pressure to Allow for DP Movement "Stripping" for Circulating Cement Prior to Stinging Into Retainer; Perform Test Run P/U 155, S/O 92 10:00 10:30 0.50 5,517 5,517 INTRM1 CEME WOEQ T Wait on DowelllSchlumberger to Arrive f/ Deahorse; Problem w/ Cement Test Caused Delay Unitl Proper Recipie & Successful Test 10:30 11:30 1.00 5,517 5,517 INTRMI CEME RURD P R/U Dowell/Schlumberger and Trucks for Cementin Well Laterals. 11:30 12:00 0.50 5,517 5,517 INTRM1 CEME SFTY P PJSM on Cementing Well w/ Dowell, PEAK, ASRC, Doyon Crew, & CPAI Re s 12:00 12:15 0.25 5,517 5,517 INTRM1 CEME CIRC P Dowell Pressure Test Cement Lines t/ 3000 PSI; Then Pump 15 Bbl Fresh Water Ahead of Cement Taking Returns Through Choke Line holding . 200 to 350 psi back pressure on annulus. 12:15 12:30 0.25 5,517 5,517 INTRM1 CEME CIRC P Follow Water Spacer Down Drill String w/ 43 Bbl of Class G Cement; Maintain 200 - 330 Psi Back Pressure w/ Choke; Stop Pumps and Re-enter Retainer, Pressure annulus to 500 si. 12:30 14:00 1.50. 5,517 5,517. INTRM1 CEME CIRC P Pumped 148 Bbl of 15.8 Ppg Cement @ 2 BPM w/ 500 Psi Max; Then 1 1/2 BPM w/ 330 Psi Max, Then 1 Bpm w/ 260 Psi Max; Called Well Engineer and Decided to Displace w/ Water and WOC to Thicken. 14:00 15:00 1.00 5,517 5,517 INTRM1 CEME DISP P Started Displacing DriII String Volume (58 Bbl) w/ Fresh Water; @ 28 Bbls Displaced Pressure Increased f/ Original Injection of 2 BPM / 1000 Psi to 1/2 BPM / 1175 Psi; Total Cement - Volume Pumped 191.6 Bbls - 927 Sacks, After shut down well held 1150 psi and then dropped to 1000 psi after 5 min. (Note; Total calculated volume below Retainer for both laterals and main bore = 177.8 bbls), AOGCC John Cris waived witness of s ueeze 'ob. 'ige t4 cat 31 • Time Logs __ _.__ ur S. Depth_ E__De th Phase Code _ Subcode T COM_ _ _ _ Date From To D_ 03/08/2008 15:00 16:30 _ 1:50 5,517 5,517 INTRM1 DRILL CIRC P Pull out of Retainer w/ 1000 psi on drill pipe, Reversed 2X String Volumes, pumping 11 bpm w/ 1930 psi, w/ Trace Cement Returns then Circulate Bottoms Up X3 the long way, pumping 10.5 bpm w/ 1370 psi - no cement observed on btm's while circ the long wa /Blow Down Choke & Kill Lines. 16:30 16:45 0.25 5,517 5,517 INTRM1 DRILL SFTY P - Pre job safety meeting on displacing well from 8.4 ppg to 9.5 ppg Mineral Oil Base Mud. 16:45 17:15 0.50 5,517 5,517 INTRM1 DRILL CIRC P Displace Well Fluid f/ 8.4 PPG Sea Water to 9.5 PPG OBM. Pumping 10.5 bpm w/ initial circulating pressure of 1520 psi and final circulating pressure of 2460 psi. Record slow um rates. 17:15 18:00 0.75 5,517 5,517 INTRM1 DRILL KURD P Rig down cementing equipment. Blow down lines. monitor well static. 18:00 21:00 3.00 5,517 0 INTRM1 DRILL TRIP P . Pull out of the hole with Baker Model K-1 Running tool. Lay down running tool. Monitor well on the trip tank. Pro er dis lacmenet. 21:00 21:30 0.50 0 0 INTRM1 DRILL OTHR P Move a stand of 4" heavy weight drill pipe and a stand of heavy weight drill pipe with the jars to the off driller's side of the derrick. 21:30 21:45 0.25 0 0 INTRM1 MOVE OTHR P Clear rig floor. 21:45 22:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up/making up 15 stands of hybrids (2 jts of 5" DC + (1) 4" HWDP on top) for weight @ the to of the hole Push i e). 22:00 00:00 2.00 0 0 INTRMI DRILL PULD P Pickup/makeup/standback in the derrick 15 stands of hybrid's (2 jts of 5" DC + (1) 4" HWDP on top). Drifted to 2". 03/09/2008 00:00 00:30 0.50 0 0 PROD1 STK PULD P Bring Baker Whipstock Assy to Rig Floor 00:30 00:45 0.25 0 0 PROD1 STK OTHR P PJSM for M/U BHA #3 w/ Baker Fishin Re & Ri Crew 00:45 01:30 0.75 0 69 PROD1 STK PULD P M/U Mills & Whipstock Assy per Baker Re 01:30 02:00 0.50 69 69 PROD1 STK OTHR P Orient Whipstock to MWD Toolface 02:00 03:00 1.00 69 69 PROD1 STK OTHR P Daylight Savings Time Adjust Clocks Forward 1 Hour 03:00 03:30 0.50 69 69 PROD1 STK OTHR P Orient Whipstock to MWD Toolface 03:30 04:45 1.25 69 206 PROD1 STK PULD P P/U Remainder of BHA #3 04:45 06:00 1.25 206 206 PROD1 STK OTHR P Up load & Test-MWD Equipment 06:00 07:00 1.00 206 300 PROD1 STK OTHR P P/U 1st Stand & Shallow Test MWD Pum in 270 m. 07:00 11:00 4.00 300 5,256 PROD1 STK WPST P P/U & RIH w/ Whipstock. (BHA #3) f/ 300" -5256' MD; 71 SPM 3030 Psi r~,c1~o4~T Time Logs ~ -- Date From To Dur S De th E. De th Ph e Code Subcode T COM 03/09/2008 11:00 11:30 0.50 5,256 5,302 PROD1 STK OTHR P Mad Pass to Confirm Top of Ugnuf/ 5256' - 5302' MD (Gamma Ray depth 5179' to 5225') Pumping 300 gpm w/ 3070 si. Lo seed 100'/hr 11:30 12:30 1.00 5,302 5,520 PROD1 STK WPST P RIH f/ 5302' - 5520' MD; Tagged Retainer @ 5520' MD; Set Whipstock @ 5520' MD w/ 22L Tool Face; and Sheared Mill w/ 45K Down; 71 SPM @ 2990 Psi; P/U 168, Rot 158, S/O 140; To of Whi stock 5502' MD 12:30 12:45 0.25 5,520 5,256 PROD1 WELCT OTHR P POOH w/ 3 Stds f/ 5520' - 5256' MD & P/U Retrievamatic Storm Packer 12:45 13:45 1.00 5,256 5,320 PROD1 WELC OTHR P M/U Storm Packer and RIH f/ 5256' - 5320 ;Packer Came Unscrewed @ 3 1/2 X 2 7/8 Mandrel and Equalizing valve Came Out of Hole; Top of Packer Set 79' MD; Baker Hand Called BOT Deadhorse for Guidance 13:45 14:45 1.00 79 0 PROD1 WELCT OTHR T P/U Equalizing Valve and Attempt to Screw On to Packer; Attempt Successful; Sheared Twin Thread Safe Joint as Planned; 14:45 15:00 0.25 0 0 PROD1 WELC OTHR P Blow Down Top Drive and Mud Lines / Pressure Test Packer t/ 500 Psi f/ 5 Minutes Good 15:00 16:00 1.00 0 0 PROD1 WELC OTHR P Blow down kill line and choke line. Drain stack, rig down elevators, Pick up slings for secondary lines to secure stack-- alon with the brid a crane. 16:00 19:30 3.50 0 0 PROD1 WELC NUND P Remove flow line, bell nipple, and drip pan. Remove choke hose. Remove bolts to wellhead and set stack back towards pipe shed. Remove the rig's annulus valve from wellhead. Remove Vetco/Gray wellhead from the 7-5/8" casin han er. 19:30 21:00 1.50 0 0 INTRM1 WELC NUND P Install new Vetco/Gray wellhead with new graylock seal sub. Energize the lockdown screws to 300 ft lbs. Note: Wellhead Orientation Witnessed by DS-1 D DSO Greg Whitehead -Would like all Wellhead valves rotated 180 de s. Will be erformed ost ri . 21:00 21:45 0.75 0 0 PROD1 WELCT BOPE P Test void to 250 psi and 1000 psi for 10 minutes each. Good Test. Witness test with Vetco Gray and Conoco Philli s re resentative. 21:45 00:00 2.25 0 0 PROD1 WELC NUND P Nipple up BOP stack. Rig down secondary slings for securing stack during change out of wellhead. Attatch choke line, bell ni le and flow line. 03/10/2008 00:00 01:00 1.00 0 0 PROD1 WELC NUND P Cont'd N/U BOP 01:00 02:30 1.50 0 0 PROD1 WELCT OTHR P R/U f/ BOPE Test ~::,~c 1~ zaf 31 Time Logs __ __ D e From To Dur S. Depth E. De th Phase Code Subcode T COM 03/10/2008 02:30 11:00 8.50 0 0 PROD1 WELCT ROPE P Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Test 250 low and 3000 Psi high. Hold each test 5 minutes. Chart tests. Tested all valves in the choke manifold, all kill line valves and choke line valves. Test floor safety valve an IBOP. Test top drive upper and lower IBOP. Tested annular with 5-1/2" test joint. Tested lower pipe rams (3-1/2" x 6" variables) with 5-1/2", 5", 4-1/2", and 4". Tested blind rams. Tested Gas and H2S alarms. All tests assed. 11:00 11:30 0.50 0 0 PROD1 RIGMN' SVRG P Service Rig; Replace Broken Koomey Line 11:30 13:15 1.75 0 0 PROD1 WELCT BOPE P Test accumulator: 200 Psi Increase in 35 seconds, and Full Chargein 2 minutes and 56 seconds.; Test Annular Preventer and Upper 2 7/8" Pipe Rams w/ 2 7/8" Test Jt. to 250 si low and 3000 Psi hi h. 13:15 14:15 1.00 0 0 PROD1 WELCT OTHR P Rig Down BOPE Testing Equipment; R/U to Retrieve Storm Packer 14:15 16:15 2.00 79 0 PROD1 WELCT TRIP P M/U and Rlh w/ Overshot to Retrieve "Retrievamatic" Storm Packer; Packer Retrieved 16:15 16:45 0.50 0 5,349 PROD1 WELC OTHR P Lay down BOT Tools (Retrievamatic) . 16:45 17:30 0.75 5,349 5,502 PROD1 STK TRIP P RIH f/ 5349' - 5502' MD; Tagged Whi stock 5502 17:30 23:30 6.00 5,502 5,536 PROD1 STK WPST P Mill Window in 7 5/8" Casing. PU wt 173k, SO wt 142k, Rot wt 158k. Pumping 300 gpm w/ 3070 psi. Whipstock set @ 22 Degrees Left. Mill from TOW @ 5502' to Bottom of window @ 5515.61', then to 5521' with upper mill (6-3/4") at the bottom of window, then full guage hole to 5536.6' (3613.4' TVD). Pump a high vis sweep (9.5 ppg/ 300 vis) while milling @ 5510': Slight increase in metal cuttings. Pump a high vis sweep (9.5 ppg/ 300 vis) while milling @ 5516'. Slight increase in metal cuttin s. 23:30 00:00 0.50 5,536 5,536 PROD1 STK WPST P Work through window. Pumping 305 gpm w/ 2970 psi. Rotating 120 rpm w/ 5-6k ft Ibs of torque. PU wt 170k, SO wt 142k. Note: Had 10k overpull at 5509'. Worked until no roblem. 03/11/2008 00:00 00:15 0.25 5,536 5,536 PROD1 STK WPST P Continue working mills thru window pumping 305 gpm, 3020 psi. PU wt 170k, So wt 142k. 00:15 01:15 1.00 5,536 5,536 PROD1 STK CIRC P Pump 35 bbl 9.5 ppg 300 vis sweep @ 321 m, 3530 si lus 3 bottoms u . F~~c~e #7 of 39 V +: ~ KRU Cc~noc4Phillips Alaska, Enc- 1D-id1 APL 5002y22yti700 Well T e: PROD SSSV T : NONE Ori Com letion: 8/27/2000 Annular Fluid: Last W/O: 12/28/2001 Reference Lo : Ref Lo Date: Last Ta 541 T SLM TD: 9550 ftK6 CABLE (3°23-s°3°, -~ a Lest Tag Date: 1(V20/20(17 Max Hole Angle.- Casin Strin COMMON STRINGS_ Desai lion Size To 95 deg n 6Fi30 Bottom SURFACE 10.750 0 502 CONDUCTOR 16.000 0 110 TUBING PRODUCTION 7.625 0 5519 (0-5466• i PRODUCTION 7.000 5519 6419 OD:4.500, ID3 958) - CSG WINDOW JNT 6.500 5580 5589 Wt I Grades Thread "' ~~fng~string - B-SAND I.IN SRe To _ Bonom - rv~ irv~ ~rt~de _ Thread PUP LINER 4.500 6196 8197 3794 9.50 L-80 HSLHT (5311'5430, DUAL SCREEN LNR 4.500 8197 9510 3778 9.50 L-80 HSLHT OD:4.750) 15 n(1 HSLHT PRODUCTION (0-5519, OD:7.625, Wt:29.70) NIP (5430-5438, OD:4.500) GEARBOX (5452-5453, OD:5.620) PKR (6196fi197, OD:7.000) XO (6218E219, OD:5.000) PKR (8089-8090, OD:5.625) SLEEVE (8154-8155, OD:4.500) • LINER 5.000 9510 9548 3779 __ - Tubing String -TUBING __ _ 1 •. _- _ -- _ TVD Wt Grade_ Size Top Bottom Thread_ _~ ~ _ 4 500 i 5466 3574 12.b0 _ _ L ~0 - NSCT ' PerfOratiO umm3ry . .- ~ ~ Interval TVD Zone Status Ft SPF Date Tn~ ' Comment 1 - --- c, ~ : n Fs197-9510 3794-3771? JSB 1 it3 ~) y~(~ 00~ Pe~rti~nru - __ ,Gas LiffMandrelsNalves St MD TVD Man Mir Man Type V Mfr V Type V OD Latch Port ~ TRO Date Run Vlv ~_ Cmnt _ ~ 1 5304 3491 CAMCO KBG-2-LS OPEN 1 0 ~ ~ 0.000 -- - n 1!27!2008 - -- ' 'Other lu s, a ui _ 1 - CA g q p. ...etc, _COMPLETION De h TVD T e Descri ion ID j: 3023 2332 CABLE Ra Chem Heat Trace Cable' 300T Ion . 0.000 '' 5311 3495 PUP 3.958 5430 3555 NIP Central'rft Slotted Ni le 0.000 ;L'~ 5438 3559 SEAL Central'rft ESP Seal Section GST3 DB IL H6 PFS 0.000 5452 3566 GEARBOX Centralift ESP Gearbox 9:1, 525 Series 0.000 5453 3567 MOTOR Centralift PCESP Motor 57 HP 1315/26 KMH 0.000 5460 3570 CNTRLZR Centrelift Motor Centrelizer (Baker Sentry Garage n 5460'1 0 OfJO Other ( plugs, equip., etc . = B-SAND LINER ---- - - - De h TVD T e Descri ion ID 6196 3809 PKR B-SAND LINER HR ZXP Liner To Packer; 5.968" OD. 5.000 6218 3811 XO B-SAND LINER 5" Cs BTC x 4.5" IBT Pin X-O 0.000 8070 3793 VALVE B-SAND LINER CMT VALVE 3.844 8089 3793 PKR B-SAND LINER Pa zone Packer ECP 4.500 8154 3793 SLEEVE B-SAND LINER Baker Model CMD Slidin Sleeve 3.430 9548 3779 SHOE B-SAND LINER Baker 5" Model BPV Set Shoe _ ___5.000 ' eneral Notes Date Note 10/27/2000 NOTE: MULTI-LATERAL WELL: 1D-141 (B-SANDS). 1D-141 L7 (D-SANDS) 1 D-141 _ An le W T5: de m Angle @ TD: 88 deg Ro„ Raa~~~• r•.i v rir LINER (6196197, OD:4.500, Wt9.50) Pert (8197-9510) 1 D-141 P&A Meeting Follow Maunder, Thornas E {DOA) From: Maunder, Thomas E {DOA) Sent: Friday, February 29, 2008 9:02 AM To: 'Reilly, Patrick J' Subjec#: RE: 1 D-141 20_.,i 0-112 & 200-113) P8~A Meeting Follow Up Pat, 1 confirm our discussion. I cannot open the visio documents you sent. Achieving isolation is the goal, attempting to spot cement as a first step Leaves squeezing cement below the retainer as a backup. Good luck with the operations. I will place a copy of this message in the file Tom Maunder, PE AOGCC From: Reilly, Patrick J [maiito:Patrick.].Reilly@conocophiliips.com] Seat; Thursday, February 28, 2008 4:50 PM To: Maunder, Thomas E (DOA) Subject: iD-141 P8cA Meeting Follow Up ~~~ ~~~ ~ ~~~~ Tom, Page 1 of 1 Per our conversation, we would like to adjust our P8RA procedure. Instead of setting a retainer at the 7-5/8A x 7" crossover and squeezing cement, we would like to start by placing a cement plug from a depth of 6,573' (that is where the B Lateral achieves 90 degrees inclination) up to 5,539' (20' below the 7-5/8n x 7" XO). After the cement plug is placed, we would Nke to then run and seta 7-518° retainer at the 7-5/8n x 7° crossover. if we can achieve circulation below the retainer, we plan to pump cement in 10-20 bbl stages anti} we are satisfied that we have effectively isolated the B lateral from the D lateral. I have enclosed copies of the schematics we referenced in our meeting earlier today. Thanks. «1D-14i P8~A Sundry Schematic Current Condition WITH TUBULAR VOLUMES.vsd» «1D-141 P&A Sundry Schematic Post P8~A.vsd» Pat Reilly ConocoPhilfips Alaska Drilling &~ Wells (907) 265-G048 WORK (907) 244-5558 CEI_1_ULAR (918) 662-8284 FAX TO E-MAIL Patrick.]. Reilly@conocophillips.com «Patrick.J.Reilly@conocophillips. com.vcf» 2/29/2008 • r. _ `~ ~;° /-a ~,. ~ 1 ~ .y ~ r ~ eW7 ~1 t a d sil ' ~ '~ ~ ~ ~.'1 k \ i B qq ~4 ~ f d ~ r + ~qs a..+E ~.i x A ~ ! 4.Y~ 3' i r t ~.± ! # ,t !_., ~ ~ r r f 1 } . y tJ } ~ ~~~ . ... 4 _ .. ~ J~-] ALASS-A OIL A1QD GA.S COlYSER'QATIOI~T COAIIrIISSI01•T • Randy Thomas Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 V~ FED ~ BOOS Re: Kuparuk River Field, West Sak Oil Pool, 1 D-141 Sundry Number: 308-019 Dear Mr. Thomas: SARAN PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 x,00 - 6 I ~-- Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the 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 thi~day of January, 2008 Encl. Sincerely. • ConocoPhillips January 16, 2008 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~A~~~ M Commissioner 'JAM ~ 7 ~~~8 State of Alaska Alaska Oil & Gas Gnnx. Obmmi~Fian Alaska Oil & Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval 1 D-141 and 1 D-141 L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming workover for the West Sak 1 D-141 and 1 D-141 L1. Rig 15 is currently on 3K-102 and there is a possibility we will need to suspend 3K- 102 depending on the ability to obtain oil samples. If we do suspend this well, we will need this application approved within a week. Dennis Hartwig will notify Tom Maunder of AOGCC if the well will need to be suspended. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Drilling Team Leader CPAI Drilling and Wells Randy Thomas Drilling Team Leader Drilling & Wells RT/PR/skad ~~C~~~D ~~~ STATE OF ALASKA ~ ~t JAN Y ~ ~~g~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ka Oil & Cas Conn. Oamm~;3~~n APPLICATION FOR SUNDRY APPRO~i ~. Anchorage 20 AAC 25.280 1. Type of Request: Abandon ^/ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ~ ~ 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 ^ 200-112 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22967-00 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? Y2S NO Q 1 D-141 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650, ALK 468 RKB 30' ~ Kuparuk River Field /West Sak Oil Pool " 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9550' 3779' 5417' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 472' 10-3/4" 502' 502' PRODUCTION 5489' 7-5/8" 5519' 3600' PRODUCTION 900' 7" 6419' 3829' LINER 3352' 4-1/2" / 5" 9548' 3779' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8197'-9510' 3794'-3778' 4-1/2" L-80 5466' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- HR ZXP LINER TOP PACKER ; PAYZONE PACKER ECP pkr= 6196' ; 8089' no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ i Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: 1, `~7 ~'~ Commencing Operat February 1, 2008 Oil ~D r~ Gas ^ Abandoned Plugged ~ 17. Verbal Approval: Date: WAG ^ 1•l~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Suspended ^ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Randv Thomas Title: Drilling Engineer Signature • t ~~„~, ~ 4, ~%.~-_.-------- Phone 265-6830 Date 1 '~1 Fi~tr°" Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness '~ O' Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ' Other: '~~'pS 1 ~\~`~)..~`1r"L~ C '~C'.`,~~ Subsequent Form Required: ~O~ APPROVED BY ~ ~ Approved by: THE COMMISSION O Date: ~ Form 10-403 Revised 06/2006 u tin Dupli ate ~~P~ /• • 1D-141 SUNDRY BJ CTIVE P ~ A WELL FOR SI CK OPERATIONS '~" (Reference attached plug back schematic) (The sundry procedures for both 1D-141 & 1D-141 L1 are identical) WELL HISTORY: Well 1 D-141 was drilled in August 2000 as a West Sak dual lateral B and D sands producer. In December 2001 a work over was attempted to shutoff water production in the B lateral. During the work over, an obstruction at the D windowjunction (5580' MD) prevented access to the main bore B lateral. Attempts to repair the junction resulted in a sidetrack out of the main bore at the depth of the D junction. The bottom of the sidetrack is 6,235'MD (39' deeper than the B lat liner top). A cement plug was placed to fill the sidetrack from 5900' MD to 6200' MD. An ESP completion was installed. The well produced until March 8, 2004. It was shut in because the ESP had sanded up. Current Status: Shut in. The last tag was on 10/20/07 @ 5417' MD. There is an OV in the mandrel at 5304' MD. P&A WORK (Pre Rig): 1. Install BPV. P&A WORK (On Rig): 2. MIRU Doyon 15. 3. Pull BPV. 4. Circulate hot seawater with 6% KCL to clean the completion string. 5. Displace well to kill weight brine (estimated 9.2 ppg). 6. Set BPV 7. ND tree. 8. NU and test BOPE. 9. POOH with tubing and ESP. 10. RIH with clean out assembly and clean out to the top of the D window. POOH. 11. RIH with a 7 5/8" cement retainer on DP and set at the 7 5/8'' x 7" XO. 12. Squeeze cement below the retainer. Plan to squeeze in 50-100 bbl increments. 13. RIH with whipstock for the new D lateral window. ~' 14. Test casing to 3000 psi for 30 minutes and record test. 15. Set whipstock at 5497' MD. 16. Shear whipstock bolt. 17. Set storm packer. 18. ND BOPE. 19. Remove wellhead and replace with new wellhead. 20. NU and test BOPE. 21. Prepare to mill the D window in accordance with the 1 D-141A permit to drill. Note: This procedure describes the placement of one retainer above the D window. If we can successfully pass a retainer past the D window, we will place 2 cement retainers. The first retainer will be placed below the D window. The second retainer will be placed above the D window. PJR 1/14/08 . 1 D-141 P8A Sundry Schematic Current Condition • _ 1 D-141 & (L1) Producer ConocoPhillips Current Condition 10.75" J-55 casing @ 502' MD / 502' TVD 75/8"x7"XO@ +/- 5,519' MD Top of D Liner Obstructing Main Bore Access Top of Cement = 5900' MD (Designed top, not taooed) Top of D window @ +/- 5,580' MD, -~~cr~ Blank Liner 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner ECP @ @ +/- 9,460' MD +/_ 6,139' MD 6" Hole -- ~ W West Sak D Sand Screen Liner 4.5" X 7 5/8" Liner Top +/- 6,196' MD ECP +/- 8,089' MD 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner ~~~ ~ d W West Sak B Sand Screen Liner Blank Liner tom of Cement = 6200' MD Sidetrack milled during workover attempt TD=6235' MD 6" Hole 7" L-80 BTC-M casing @ 6419' MD / 3829' ND PJR 1/16/08 1 D-141 P&A Sundry Schematic Post P8A • _ 1 D-141 & (L1) Producer ConocoRhillips Post P&A 10.75" J-55 casing @ 502' MD / 502' TVD Planned 1D-141A Sidetrack KOP TOW @ +/- 5,497' MD, +/-3,589 TVD 75/8"x7"XO@ +/- 5,519' MD Top of Cement = 5900' MD (Designed top, not tagged) Top of D window @ / +/- 5,580' MD, V/ CEMENT Blank Liner 4.5" X 7 5/8" Liner Top +/- 6,196' MD Blank Liner tom of Cement = 6200' MD Sidetrack milled during workover attempt TD=6235' MD 7" L-80 BTC-M casing @ 6419' MD / 3829' TVD K-13 Shale 5,445' • MD / 3,563' TVD (14JUN07 Directional) 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner ECP @ @ +/- 9,460' MD +/_ 6,139' MD 6" Hole U West Sak D Sand Screen Liner W ECP +/- s,os9' MD 4.5" 12.6# Blank Liner x 4" 9.5# ScreenLiner @ +/- 9,548' MD ~.. V West Sak B Sand Screen Liner 6" Hole PJR 1/16/08 • • Review of Sundry Applications 308-019&018 ConocoPhillips Alaska, Inc. Wells Kuparuk River Unit 1D-141 & 1D-141L1 Kuparuk River Field, ems Sak Oil Pool AOGCC Permits 200-112 & 200-116 ------- Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to plug the existing wellbores to prepare the well for sidetracking. Recommendation: I recommend approval of CPAI's proposed actions Discussion: CPAI proposes to plug the 1 D-141 wellbore and its lateral, 1 D-141 L 1, to prepare the well to be sidetracked to a new bottomhole location. The main wellbore was completed in the West Sak `B', and the lateral was completed in the West Sak `D' sand. A workover was attempted in December 2001 to shut off water production from the `B' sand, but an obstruction in the well bore prevented access to wellbore below the window for the `D' sand lateral. The workover apparent inadvertently sidetracked the well, the sidetrack was plugged with cement and the well returned to service with an ESP completion. The well has been shut in since March 8, 2004, due to the ESP sanding up. CPAI now proposes to plug the existing wellbores to prepare the well to be sidetracked to anew `D' sand bottomhole location approximately 300 feet from the current completion. Mr. Pat Reilly with CPAI stated that the `B' sand has watered out in this portion of the field and is therefore not a candidate for a new bottomhole location. Conclusion: Plugging the existing wellbores to prepare the well for sidetracking is a prudent operational decision that should result in improved recovery from this portion of the oil pool. Therefore, CPAI' que is s uld be a proved. David S. Roby Reservoir Engineer January 29, 2008 . . ConocÓÂ1i11ips Afaska RECEIVED AUG .2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scA\'t~EO SE? () ß îGG1 dJJD ~ l.''Y- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Eacþ: òf thesè wells was fôund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the welI name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. .~~~~~ M.J.¿el~d ConocoPhillips Well Integrity Projects Supervisor . . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ~ ft bbls ft gal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 '1C-11 199-172 - SF NA NA NA ,:0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/20Q7 1C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 lI. WU. \...-UllU\.-Ur lll1l1p;:) LA\.-aVaUVll \X.. J.'\.~pall J. 1 VJ""LJ -' Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 To: Lou Grimaldi <lou_grimaldi@admin.state.ak.us>, John Spaulding <john_spaulding@admin.state.ak.us>,John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones <jeff jones@admin.state.ak.us>, Chuck Scheve <chuck _ scheve@admin.state.ak.us>, Jim Regg <jim yegg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us NSK1WelJLIntegrity Proj <N1878@conocophillips.com>, aogcc prudhoe bay@admin.state.ak.us \\)-\l.\ \ (5tÖQ- \ \ ð Subject: Date: From: To: CC: SCANNED JUN 2 7 200B Tom: I donlt remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «IC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 1 C and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/20067:51 AM ') PRIORITY 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 ---, 16 ------ }dOC)- \ \ d NAME 1 C-121 1 C-131 1 0-1 09 1 0-111 10-120 1--- " ..._. ".,_..----,.." ""--. .._... . : . · ·1,0'"1:2'1 '..: 1........._·... .c...c_~.,~..:_..."";...":':::":..... .., '''. ........ ...c... I ..11>-127....... . I 1·........_.'·....... _.~L..;....:...._.__._...... .."-"... .... ··..···1 I 1 0-132 I .____.........__...._."........_............................____"......................--.1. II . 1D-136 ,··..··..··..··..-..···-··-··1·-D~·1;37···-······..···-..··..-...... I·"· "'..... ........ "'............-.............------....---.. .... j 10-138 i ..... .-...~~---.............-...--. : tD~139 I I'''· ..... .... .... .......-...............-,.. --.. , 1 C-119 ConocoPhillips Alaska, Inc. 1 C and 1 D Surface Casing Corrosion Repair Candidates TYPE INJ INJ INJ INJ INJ Gas Lift Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump ESP Gas Lift PTD# LEAK DEPTH (ft) 201-080 4 201-185 7 197 -235 5* 198-166 5* 197-221 7 197-181 None 198-1 09 None 198-121 5 200-046 None 200-047 None - ---....- 200-048 8 200-049 None 201-139 16 . _. -..- 201-220 None 197-184 None 200-112 None COMMENTS I STATUS Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig I Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2.10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~~.",. ø": . - ~~.. 'II "" . 'II- ~. '. ") ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D RepairWell D Alter Casing D Pull Tubing D Change Approved Program 0 Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 30' 1. Operations Performed: 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: '2004 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Stimulate D Waiver D Time Extensi,bh :', ED : .'" Re-enter Suspended Well D Exploratory D Service D 5. Permit to Drill Number: 200-1121 6. API Number: 50-029-22967 -00 9. Well Name and Number: 1 0-141 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Total Depth measured 9550' feet true vertical 3779' feet Plugs (measured) Effective Depth measured 4658' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 401' 10-3/4" 502' 502' PRODUCTION 5418' 7-5/8" 5519' 3600' PRODUCTION 900' 7" 6419' 3829' LINER 3352' 4.5" / 5" 9548' Perforation depth: Measured depth: 8197'-9510' true vertical depth: 3794'-3778' SCANNED NO\! 2 L} 20D4 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5466' MD. Packers & SSSV (type & measured depth) pkr= HR ZXP LINER TOP PACKER; PAYZONE PACKER ECP pkr= 6196'; 8089' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 138 Not yet available RBDMS 8FL NOV 2 2 2004 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 26 39 CasinQ Pressure 200 Tubinq Pressure 183 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil 0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 304-394 Contact Printed Name Signature MJ Loveland/Brad Gathman Jerry Dethlefs ~ .Ý~ C-- --~Z5 Form 10-404 Revised 04/2004 WDSPLD Title Phone 907-659-7224 Problem Well Supervisors Date /~~ftr OC<IG\NAL Submit Original Only ) ) ConocoPhillips Alaska, Inc. West Sak WelllD-141 (PTD 2001120) REPORT OF SUNDRY OPERATIONS November 21, 2004 11/04/04: PULL 4.5" SLIPSTOP & PACK-OFF @ 5369' SLM. (PREP TO PULL PUMP). RID 11/07/04: PULLED 4.5" ESP PUMP @ 5362'WLM, JOB IN PROGRESS 11/08/04: PULLED 1" SOV @ 5306'RKB, SET 1" X 1/4" OV @ SAME DEPTH, OBTAINED SBHP @5150' AND 5350'WLM 11/17/04: GASLIFT STARTED DOWN WELL 11/19/04: NO FLOW DETECTED, TROUBLESHOOTING IN PROGRESS 11/21/04: NO RATE DATA AVAILABLE YET NSK Problem Well Supervisor ,~.,:.,tf ;zoo - 1(1- Œ (ill !RJ FRANK H. MURKOWSKI, GOVERNOR AT¡ASKAOILAND GAS CONSERVATION COMMISSION 333 W. ]fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk 1 D-141 Sundry Number: 304-394 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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 / Chairman BY ORDER OF THE COMMISSIO DATED this-L day of er,2004 Ene!. ~~ . SCANNED NO\! () 3 ZOD4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development - 0 Stratigraphic D Abandon D Alter casing D Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend D Repair well D Pull Tubing D 1. Type of Request: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 30' 8. Property Designation: ADL 25650, ALK 468 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9550' 3779' 4658' Casing Length Size CONDUCTOR Perforate D Stimulate D Waiver D Annular Disp. 0 Time Extension 0 Other D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D Service D 200-112 6. API Number: 50-029-22967-00 9. Well Name and Number: 1 D-141 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Perforation Depth MD (ft): 8197'-9510' Packers and SSSV Type: pkr= HR ZXP LINER TOP PACKER; PAYZONE PACKER ECP no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Lov;Jand / Signature ~ /~~ 110' 16" SURFACE PRODUCTION 401' 54181 10-3/4" 7-5/8" PRODUCTION LINER 900' 33521 7" 4.5" /5" MD 110' TVD 110' 502' 5519' 502' 3600' 3829' 6419' 9548' 3779' Perforation Depth TVD (ft): 37941-3778' Packers and SSSV MD (ft) pkr= 6196'; 8089' October 31,2004 Date: Tubing Size: 4-1/211 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: \"\~<Å~ro~~\ ~'f~\\C~ \O(~\-a~ IØJASBfL COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 54661 Service D Plugged D WINJ D Abandoned D WDSPL D MJ Loveland/Brad Gathman Problem Well Supervisors Date ~ r C7c. 1-0 y Sundry Numr -.. .3'-J '-/-391 MOV 0 1 20n~ Date: ¡(f~(þ Sub!"f.1it in Duplicate ConocoPhillips Alaska, Inc. West Sak WelllD-141 (PTD 2001120) SUNDRY NOTICE 10-403 VARIANCE REQUEST October 23, 2004 The purpose of this Sundry Notice is for approval to produce ConocoPhillips' West Sak welllD- 141 on gaslift. The well is completed as an ESP (electric submersible pump) producer and does not have a production packer. ID-141 produced via ESP until 3/8/04, at which time it was shut in for complications caused from solids production. At this time the ESP is assumed operable, however the drawdown brings in too many solids to keep it on line. The tubing is configured with one gaslift mandrel at 5304' RKB (3491' TVD). Gaslift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift valve. All production from the well will be through the tubing to surface facilities. Since there will not be annular flow with this configuration, supplemental corrosion/erosion inspections will not be undertaken. The last production test on 03/04/04 (ESP production) recorded 300 BOPD, 119 BWPD (28% WC), and 41 MSCF of gas. Attached is a wellbore diagram of the well. ConocoPhillips proposes that: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. NSK Problem Well Supervisor KRU 1 D-141 eØðQê~PI1¡llipsAI~,sl<~~ .Ino. 1 D-141 CABLE (3023-6030, OD:1.000) TUBING (0-5466, OD:4.500, ID:3.958) PUP (5311-5430, OD:4.750) PUMP (5385-5390, OD:4.500) :>ROOUCTlON (0-5519, OD:7.625, Wt:29.70) NIP (5430-5438, 00:4.500) SEAL (5438-5439, OD:5.130) GEARBOX (5452-5453, OD:5.620) MOTOR (5453-5460, 00:6.250) PKR (6196-6197, OD:7.000) XO (6218-6219, 00:5.000) PKR (8089-8090, OD:5.625) SLEEVE (8154-8155, 00:4.500) LINER (6196-8197, OD:4.500, Wt9.50) Perf (8197-9510) ~J - r . . : . . . . . I . ~ .Imnnn'" , ~",.. ! I i tj ~ ¡ m ¡ ! ¡ ¡ I ¡ ! ¡ ~ ~ Well Type: PROD Orig 8/27/2000 Completion: Annular Fluid: Last W/O: 12/28/2001 Reference Log: Ref Log Date: Last Tag: 4658 TD: 9550 ftKB Last Tag Date: 2/6/2004 Max Hole Angle: 95 deg (à) 6630 Casing String - COMMON STRINGS Description Size SURFACE 10.750 CONDUCTOR 16.000 PRODUCTION 7.625 PRODUCTION 7.000 CSG WINDOW JNT 6.500 Angle (à) TS: deg @ Angle @ TD: 88 deg @ 9550 API: 500292296700 SSSV Type: NONE Rev Reason: New Pump Last Update: 2/27/2004 Top 0 0 0 5519 5580 Bottom 502 110 5519 6419 5589 TVD Wt Grade Thread 502 40.50 J-55 BTC 110 151.50 X-65 WELDED 3600 29.70 L-80 BTC-MOD 3829 26.00 L-80 BTC-MOD 3634 26.00 to 1D-141L1 TVD Wt Grade Thread 3794 9.50 L-80 HSLHT 3778 9.50 L-80 HSLHT 3779 15.00 HSLHT Casing String - LOWER LATERAL LINER Description Size LINER 4.500 DUAL SCREEN LNR 4.500 LINER 5.000 Tubing String - TUBING Size I Top I Bottom 4.500 0 5466 Perforations Summary . Interval I TVD I Zone I Status 1Ft I SPF I Date I Type I Comment 8197 - 9510 3794 - 3778 WS B 1313 50 9/20/2000 Screen Perfs thru screens Gas. Lift MandrelsNalves St MD TVD Man Mfr 1 5304 3491 CAMCO KBG-2-LS 1. 2000 psi shearout Other (plugs, equip., etc.) - COMMON JEWELRY Depth TVD Type Description 3023 2332 CABLE RayChem Heat Trace Cable; 3007' long. 5311 3495 PUP 5385 3533 PUMP Top 6196 8197 9510 Bottom 8197 9510 9548 TVD 3574 I Wt I Grade I 12.60 L-80 Thread NSCT Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 0.000 0 12/4/2003 (1) SOV 1.0 ID 0.000 3.958 0.000 4.5" Lifteq 450DT-1800 PC 46' 1" pump set; 4.5" packoffw/KOBE knockout & slipstop wlflapper check set 2/4/2004 5430 3555 NIP Centralift Slotted Nipple 5438 3559 SEAL Centra lift ESP Seal Section GST3 DB IL H6 PFS 5452 3566 GEARBOX Centralift ESP Gearbox 9:1, 525 Series 5453 3567 MOTOR Centralift PCESP Motor 57 HP 1315/26 KMH 5460 3570 CNTRLZR Centra lift Motor Centralizer (Baker Sentry Gauge (à) 5460') Other (plugs, equip., etc.) - LOWER LATERAL JEWELRY Depth TVD Type Description 6196 3809 PKR HR ZXP Liner Top Packer; 5.968" OD. 6218 3811 XO 5" Csg BTC x 4.5" IBT Pin X-O 8070 3793 VALVE CMT VALVE 8089 3793 PKR Payzone Packer ECP 8154 3793 SLEEVE Baker Model CMD Sliding Sleeve 9548 3779 SHOE Baker BPV Set Shoe 0.000 0.000 0.000 0.000 0.000 ID 5.000 0.000 3.844 4.500 3.430 5.000 Date Note 10/27/200C This is the 'B Sand' LOWER LATERAL schematic for multilateral well.. See schematic for 1 D-141 L 1 for the 'D Sand' upper lateral. Permit to Drill 2001120 DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Well Name/No. KUPARUK RIV U WSAK 1D-141 Operator PHILLIPS ALASKA INC. MD 9550 TVD 3779 Completion Dat 9/21/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22967-00-00 UIC N REQUIRED INFORMATION Mud Log N._~o Sample N_9 Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) R R R R D D R R D D L L L L L L Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments SRVY RPT~ LIS Verification FINAL 10211 ~ FINAL LIS Verification ~/ FINAL 10212 ~ FINAL MD GPJ ROP/RES 2/5 J FINAL TVD GP,/RES · 2/5 FINAL MD GPJ ROP/RES 2/5 / FINAL 610 9497 Open 7/26/2001 ~0~;12 610-9497 6630 6849 Open 7/26/2001 0 6902 OH 10/17/2000 SPERRY 0-6902 PB1 6630 6849 OH 7/10/2001 6630-6849, Paper Copy 6630 6849 OH 7/10/2001 610 9497 OH 7/10/2001 610-9497, Paper Copy 610 9497 OH 7/10/2001 ~1~2 610-9497, Digital Data 610 9550 OH 7/18/2001 610-9550 BL 610 3778 OH 7/18/2001 610-3778.94 BL 610 6902 OH 7/18/2001 610-6902 BL Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis R ~.r.~.iv~.d ? Daily History Received? Formation Tops (~/N Comments: Permit to Drill 2001120 MD 9550 TVD DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. KUPARUK RIV U WSAK '1D-'141 Operator PHILLIPS ALASKA INC. 3779 Completion Dat 9/21/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. $0-029-22967-00-00 UIC N Compliance Reviewed By: Date: STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Pull tubing _X Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 5. Type of Well: Development ._X Exploratonj __ Stratigraphic __ Sen/icL 4. Location of well at surface 5263' FNL, 596' FEL, Sec. 14, T11 N, R10E, UM At top of productive interval 1266' FNL, 2074' FEL, Sec. 24, T11 N, R10E, UM At effective depth (asp's 560491, 5959679) (asp's 564304, 5958432) At total depth 4751' FNL, 2240' FEL, Sec. 24, T11N, R10E, UM (asp's 564166, 5954943) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-1411111~l~ 9. Permit number / approval number 200-112/~~'/301-334 10. APl number 50-029-22967-00 & 50-029-22967-60 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 110' SURFACE 401' PRODUCTION 5418' PRODUCTION 841' Upper Lateral Liner 3878' Lower Lateral Liner Lower Lateral Liner Perforation depth: 9550 for lower feet 9480 for upper feet Size 16" 10-3/4" 7-5/8" x 7" 4.5" x 4" 4.5" x 4" 5" 5576 measured no perfs true vertical no perfs Plugs (measured) plug from 6200' -5900' feet Junk (measured) feet Cemented 135 sx AS I 126 sx LiteCRETE 540 sx AS III Lite, 490 sx Class G included above 370 sx Class G 255 sx Class G (included above) tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80 Tbg @ 5467' MD. ~ackers & SSSV (type & measured depth) Measured Depth True ve~ical Depth 110' 110' 502' 502' 5519' 3600' 6360' 3826' 9460' 3776' 8197' 3794' RECEIVED FEB 0 7 200Z AlmkaOil&GasCam.~o. PAYZONE PACKER ECP @ 8089' MD; HR ZXP LINER TOP PACKER; 5.968" OD. @ 6196' MD - for lower, No SSSV Baker CTC 7' Isozone ECP @ 6139' MD; Baker CTC 20' Payzone ECP @ 6324' MD - for upper, No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-MCf Water-Bbl 288 35 181 SI Casing Pressure 188 Tubing Pressure 149 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations mX Oil _ X Gas _ 17. I hereby certify that the foregoing i~true and c~)rrect to the best of my knowledge. Signed Title Drilling Engineering Supervisor c. Mallar~ Suspended m Service Questions? Call Steve M~K'eever 265-6826 Form 10-404 Rev 06/15/88 · Date ~1~ r~ o~ Prepared b~, Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLiCAT~X~ Legal Well Name: 1 D-141 Common Well Name: 1D-141 Spud Date: Event Name: WORKOVER/RECOMP Start: 12/18/2001 End: Contractor Name: n1433@ppco.com Rig Release: 12/30/2001 Group: ~Rig Name: Nordic 3 Rig Number: 3 12/20/2001 11:00-16:00 5.00 MOVE MOVE MOVE Move rig from 1C pad to 1D pad-4.9 miles-s et matting boards-move rig over well-spot ta nks-rig up handy berm. 16:00-22:00 6.00 MOVE OTHR MOVE Rig up hard lines to tank-Load esp spoil & ' A' Frame on rig floor. 22:00-00:00 2.00 WELLSROTHR WRKOVR Pull BPV-Rig up kill manifold to tree-test lin es w/ air. PriSM-Circ. 65 bbl. hot diesel dow n annulus followed w/ 290 bbls. hot seawate r. 12/21/2001 00:00-04:30 4.50 WELLSRCIRC WRKOVR Continue displacing well w/ seawater & brin e. 04:30-06:00 1.50 WELLSRNUND WRKOVR Rig down kill manifold-set bpv & nipple dow n tree. 06:00-10:30 4.50 WELLSRNUND WRKOVR Nipple up bope-change lower pip rams to 4.5 "-install 2 way, check. 10:30-15:30 5.00 WELLSFISEQT WRKOVR Test bope 250-3500#. 15:30-16:00 0.50 WELLSFIPLGM WRKOVR Pull 2 way check-make up landing jt.-bolds. 16:00-17:00 1.00 WELLSFIPLGM WRKOVR Pull hanger to floor-remove penetratorss & wire & lay down hanger. 17:00-20:30 3.50 WELLSFICIRC WRKOVR Circ. well-hots taking 30 bph.-spot pill. 20:30-00:00 3.50 WELLSRPULD WRKOVR Hook up esp & heat trace lines thru sheave & lay down 4.5" tbg. 12/22/2001 00:00-09:00 9.00 WELLSRPULD WRKOVR POH stand back 4.5" tbg. Spooling esp cabl ~e & heat trace. Packoff assembly stuck in b iottom jt. of 4.5". Retrieve pump. Pump Tras hed-drive coupling to pump damaged. 09:00-10:30 1.50 WELLSI~OTHR, WRKOVR Change handling equip.-clean floor & servic e rig. 10:30-15:30 5.00 WELLSl;OTHR WRKOVR Make up reverse basket & rih to 5576' picki ng up 3.5" dp. (tag @ 5576' 15:30-17:00 1.50 WELLSI;CIRC WRKOVR Break circ.-wash down to 5576'-rotate down 1'-pull 25k over-attempt to clean out-appear s to be top of window. 17:00-20:00 3.00 WELLSI;TRIP WRKOVR Monitor well & poh for mills. 20:00-00:00 4.00 WELLSI;TRIP WRKOVR Load bha-make up same & rih. 12/23/2001 00:00-01:00 1.00 WELLSI;TRIP WRKOVR Running in hole w/ 3.5' dp to 5234'. 01:00-02:00 1.00 WELLSI;OTHR WRKOVR Slip & cut drlg. line. 02:00-09:00 7.00 WELLSI=EQRP WRKOVR Found cracked brake band-Repaired same & magnafuxed both bands-service rig & top dri ve-grease crown & blocks. 09:00-09:30 0.50 WELLSFTRIP WRKOVR Run in hole to 5576' 09:30-10:30 1.00 WELLSI:MILL WRKOVR Break circ.-ream & mill from 5575' to 5589' (window from 5576' to 5588'.) Mill stopped @ 5589' 10:30-13:00 2.50 WELLSF:TRIP WRKOVR POH w! mills. 13:00-13:30 0.50 WELLSI=PULD WRKOVR Lay down mills-Bull plug & x@ sub on bottom of mill left in hole. 13:30-17:30 4.00 WELLSI=TRIP WRKOVR Make up 5 3/4' bowen overshot dressed w/ 4 1/4" grapple & rih to 5589' 17:30-18:00 0.50 WELLSI=OTHR WRKOVR Wash down & latch onto fish. 18:00-19:00 1.00 WELLSI=TRIP WRKOYR POH w/ fish. 19:00-21:30 2.50 WELLSI=TRIP WRKOVR Make up milling assembly-5" starter mill-5 7 !8" string mill -6.057 string mill-2 boot bask Printed: 1/22/2002 3:15:27 PM · ( Legal Well Name: 1D-141 Common Well Name: 1D-141 Spud Date: Event Name: WORKOVER/RECOMP Start: 12/18/2001 End: Contractor Name: n1433@ ppco.com Rig Release: 12/30/2001 Group: Rig Name: Nordic 3 Rig Number: 3 · ~,~ '::~:' :'i "~: :~:i :,' ' · : !::' .~;:'~ :i'::v:'~ ;:: ::i:~- .:;i. t ~.:.::i~.::?, i~'~;~:;;~ :~ !.';;~::::~: i~.: ;.:: :: ~i~ ::i~ ~ '~ ii: '~:-:::::i'.:: ::.~. ~;- ;~i~.,; ' ' ~ !i!::!i;,i;i~!iO~i!i"'~:~::::~! i:'iF~6~!::i~::i~ii:.Houm': ........................................ ::::::Cod~ ..... :,::::::.~'~:,.~:~::,:,:P~ase~::::~ ...... !i!i i:i! !i'i!i'~ :.i i.' ?' :!i i~S~{i~!~0~i~! ;':, ii::: !!i~i:;i!iiii!i!i :?: 12/23/2001 19:00-21:30 2.50 WELLSI;TRIP WRKOVR ets-bumper sub -oil jars & 9 dc,s. (Note) re covering cement in boot baskets each trip. 21:30-00:00 2.50 WELLSI:TRIP WRKOVR RIH w/ 3.5" dp & milling assembly. 12/24/2001 00:00-02:00 2.00 WELLSFTRIP WRKOVR Continue running in hole w/ mills. 02:00-08:00 6.00 WELLSFMILL WRKOVR Start milling from 5576'-mill & clean out to 5597'. 08:00-09:30 1.50 WELLSFClRC WRKOVR Circ. sweep around. 09:30-13:00 3.50 WELLSFTRIP WRKOVR POH-/ay down bha & clean boot baskets-reco vered cement & several pieces of iron-appea rs to be csg. 13:00-15:30 2.50 WELLSFOTHR WRKOVR Wait on 4' 3/4" motor & milI-PJSM & service rig while waiting. 15:30-19:30 4.00 WELLSFTRIP WRKOVR Make up motor & mill & rih to 5597'. 19:30-00:00 4.50 WELLSFMILL WRKOVR Milling from 5597' to 5673'. Appears to be m ostly cement & fine siltstone. 12/25/2001 00:00-10:00 10.00 WELLSFMILL WRKOVR Cleaning out from 5673' to 5960' 10:00-11:00 1.00 WELLSFTRIP WRKOVR Pull 3 stands-pick up 9 singles. 11:00-20:30 9.50 WELLSRMILL WRKOYR Cleaning out from 5960' to 6235' 20:30-21:30 1.00 WELLSFCIRC WRKOVR Pump sweep & circ. around. 21:30-00:00 2.50 WELLSRTRIP WRKOVR POH-slm-Tight hole when dc,s @ window-Dri lied 39' past the top of packer-appears we d rilled out side csg. 12/26/2001 00:00-02:00 2.00 WELLSRTRIP WRKOVR Finish poh & lay down bha. (Clean junk bask ets-no iron) 02:00-03:00 1.00 WELLSRPULD WRKOVR Pick up 1 it. 6" washpipe w/ 6.05" shoe. 03:00-05:30 2.50 WELLSRTRIP WRKOVR Run in hole w/ washpipe. 05:30-12:00 6.50 WELLSRMILL WRKOVR Milling from 5576' to 5588' (Pump Sweep) 12:00-12:30 0.50 WELLSRCIRC WRKOVR Circ. sweep out. 12:30-15:30 3.00 WELLSRTRIP WRKOVR Pull out of hole & lay down bha. 15:30-16:30 1.00 WELLSROTHR WRKOVR Service rig-Check crown 'O' Matic. 16:30-18:00 1.50 WELLSRTRIP WRKOVR Run in hole w/ open ended 3.5" dp. 18:00-00:00 6.00 WELLSRClRC WRKOVR Clean trip tank-pump sweep-chase w/ clean seawater-rig up for acid pickle-rig up mi flit ration unit. 12/27/2001 00:00-02:30 2.50 WELLSFtAWSH WRKOVR PJSM-Acid Pickle in 3.5" dp. (Pump 12 bbls. to shoe & reverse out same. Pump drill pip e volumes X 2. 02:30-04:30 2.00 WELLSRClRC WRKOVR Circ. clean hole for camera run-ntu,s 4-14. 04:30-06:30 2.00 WELLSROTHR WRKOVR PJSM-rig up hes 'e' line. 06:30-13:00 6.50 WELLSROTHR WRKOVR Run in hole w/ camera on e-line-tag @ 5575- lens dirty-bullhead I bbl. fluid-poh-clean le ns-rih to 5575-bullhead 10 bbls. fluid @ 1/2 to 1 bpm-cloudy-not readable-poh w/ camera -run dp from 5489' to 5616'-change bails. 13:00-18:30 5.50 WELLSRCIRC WRKOVR Wait on seawater-start filtering seawater & displace hole w/ same @ 6 bpm-pick up 10'- cbu w/ filtered seawater. 18:30-00:00 5.50 WELLSROTHR WRKOVR Rig up wireline & rih w/ camera to 5606osho ws open hole-pull up to 5576'-shows open h ole-pull to 5566'-work down-shows going out of csg. @ top of window @ 5576' Poh & rig down hes wireline. 12/28/2001 00:00-06:00 6.00 WELLSFIOTHR WRKOVR Change bails-offload 2 3/8" workover string Printed: 1/22/2002 3:t5:27 PM Legal Well Name: 1 D-141 Common Well Name: 1D-141 Spud Date: Event Name: WORKOVER/RECOMP Start: 12/18/2001 End: Contractor Name: n1433@ppco,com Rig Release: 12/30/2001 Group: Rig Name: Nordic 3 Rig Number: 3 12/28/2001 00:00 - 06:00 6,00 WELLSF OTHR WRKOVR f r o m s h e d - s p e r r y & b a k e r t o o I s, 06:00 - 06:30 0,50 WELLSF OTHR WRKOVR S e r v i c e r i g, 06:30-07:00 0,50 WELLSFTRIP WRKOVR Run in hole to 6200', 07:00-11:00 4,00 WELLSFClRC WRKOVR Circ, dye & displace to 8.5# brine-safety me eting w/ cementers-rig up cement equipment -batch mix cement, 11:00-12:00 1.00 WELLSFOTHR WRKOVR Test lines to 2500# -pump 23,6 bbls. cement 133 sx-17# w/ 10 bbls, water ahead & 1,1 bbls, behind & lay plug in open hole from 62 00' to approx-5900', 12:00-13:30 1,50 WELLSRCIRC WRKOVR Pull 4 stands-Rig up & reverse circ, 2 dp vo iumes-recovered 2 bbls. cement contaminate d fluid.-Poh to 5457'. : 13:30 - 14:00 0.50 WELLSR OBSV WRKOVR M o n i t o r w e I I. 14:00-20:00 6.00 WELLSRPULD WRKOVR POH laying down dp & collars out of derrick. ~ 20:00 - 21:00 1.00 WELLSFIOTHR WRKOVR Slip & cut drlg, line-check crown'o' matic 21.:00-23:00 2,00 WELLSRPULD WRKOVR Rig up floor for running completion-pull wea r ring, 23:00-00:00 1,00 WELLSFIPULD WRKOVR PJSM-Running completion, 12/29/2001 00:00-15:00 15,00 CMPLTNRUNT CMPLTN Running completion w/ heat trace & ecp. 15:00-00:00 9.00 CMPLTNRUNT CMPLTN Pick up hanger-space out for heat trace-spli ce esp cable, 12/30/2001 00:00-03:00 3.00 CMPLTNOTHR CMPLTN Splicing esp cable & baker I wire. 03:00-03:30 0.50 CMPLTNSOHO CMPLTN Land tbg, & drain bop stack, (97k up 60k do wn) rilds, 03:30-07:00 3,50 CMPLTNNUND CMPLTN Install bpv-n/d bope-lossen nuts on annular preventer top. 07:00-10:00 3.00 CMPLTNNUND CMPLTN Nipple up tree & test packoff 5000# -test tre e 250-5000-pull test plug & rig up circ, equi pment, 10:00-12:30 2.50 CMPLTNFRZP CMPLTN Pump 150 bbls. diesel down annulus-allow t o equalize-break down circ, equipment, 12:30-13:30 1,00 CMPLTNOTHR CMPLTN Rig up lubricator & set bpv-190# on tbg. & a nnulus, 13:30-16:00 2,50 CMPLTNOTHR CMPLTN Clean pits & change drip pan assembly. ( rel ease rig @ 1600 hrs, 12/30/2001) Printed: 1/22/2002 3:15:27 PM Sundry Approval # 301-334, West Sak Well #1D-~~,~ · Subject: Sundry Approval # 301-334, West Sak Well #1D-141 Date: Fri, 28 Dec 2001 10:25:49 -0900 From: "Steve McKeever" <smckeev~ppco.eom> To: winton_aubert~admin, state.ak.us Following up on our conversation this morning regarding work over operations on West Sak well 1D-141, here is a brief summary of our operations to date, and our plan to put the well back on production: The objectives for the work over were to: 1) Pull the tubing and down hole pump. 2) Set a plug in a profile in the lower lateral, shutting off "B" sand production, which we thought to be the major source of the well's high water rate. 3) Set a work over whipstock at the multi-lateral junction and clean out the upper "D" sand lateral. 4) Re-run the tubing and down hole pump. Operations to date have been: 1) Moved in and rigged up Nordic Rig #3 on 12/20. Displaced well to kill weight brine. 2) Nippled down tree, nippled up BOPE 3) Pull tubing and lay down ESP. 4) RIH with reverse circulating basket, tagged up at top of window. 5) RIH with milling assembly. Lost bull nose from end of string as we attempted to mill through window area in main bore. 6) Fished bull nose. 7) RIH with milling assembly. Mill from 5576' to 5597'. POOH. 8) RIH with milling assembly on motor. Mill ~from 5597' tp 6235', thinking we were in the 7" casing. POOH. 9) RIH with 6" OD wash pipe and burn shoe. Wash o~er from 5576' to 5588'. POOH. ~ 10) RIH open ended to window area. Using down hole camera, confirm that drill sting is exiting casing. 11) RIH to 6190', estimated to be 30' off bottom of inadvertent open hole sidetrack. Circulate and condition well bor~ Our plan is to: 1) Lay in a balanced cement plug designed to cover 300' of the open hole, putting the cement top at +/- 5%00' 2) Pull out of the plug. Reverse out excess cement. 3) POOH laying down drill pipe'. 4) Run tubing and ESP comple~ion 5) Nipple down BOPE, Nipple up Tree, Freeze protect and move off. 6) Put well back on production for further performance evaluation. Please let me know if any further action or paperwork is required. Thanks kindly, Steve McKeever Drilling Engineer Phillips Alaska, Inc. 907.265.6826 office 907.265.1535 fax 907.275.0369 pager smckeev@ppco.com 1 of 2 12/28/01 ll:12AM STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5263' FNL, 596' FEL, Sec. 14, T11 N, R10E, UM At top of productive interval 1266' FNL, 2074' FEL, Sec. 24, T11N, R10E, UM At effective depth At total depth 4751' FNL, 2240' FEL, Sec. 24, T11N, R10E, UM 5. Type of Well: Development __X Exploratory _ Stratigmphic _ Service_ (asp's 560491, 5959679) (asp's 564304, 5958432) (asp's 564166, 5954943) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-141 & 1D-141L1 9. Permit number / approy,~,number 200-112 / 200-116 10. APl number ~' v~ 50-029-22967-00 & 50-029-22967-60 11. Field / Pool Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured 9550 for lower feet '/ Plugs (measured) measured 9480 for upper feet Total depth true vertical 3779 for lower feet ~/ Junk (measured) true vertical 3734 for upper feet Casing Length Size Cemented CONDUCTOR 110' 16" 135 sxAS I SURFACE 401' 10-3/4" 126 sx LiteCRETE PRODUCTION 5418' 7-5/8" x 540 sx AS III Lite, 490 sx Class G PRODUCTION 841' 7" included above Upper Lateral Liner 3878' 4.5" X 4" 370 sx Class G Lower Lateral Liner 4.5" x 4" 255 sx Class G LOwer Lateral Liner 5" ::i~i~i~iii~ii~i~iii~i~i~iii~ii~(~iii~i~ii~ii~?~i~i~i~?:~'.. .........-........-...........-..............-..-.--........-..-.-.-... Perforation depth: measured no perfs true vertical no perfs Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 5407' MD. Measured Depth True vertical Depth 110' 110' 502' 502' 5519' 3600' 6360' 3826' 946O' 3776' 8197' 3794' 9548' 3779' RECEIVED DEC 0 4 2001 Alaska 0il & Gas Cons. Camm PAYZONE PACKER ECP @ 8089' MD; HR ZXP LINER TOP PACKER; 5.968" OD D - for lower, No SSSV Baker CTC 7' Isozone ECP @ 6139' MD; Baker CTC 20' Payzone ECP @ 6324' MD - for upper, No SSSV 13. Attachments Description summary of proposal __X Detailed operations program __ Schematic _ X BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation December 12, 2001 16. If proposal was verbally approved Name of approver Date approved Oil__X Gas_ Suspended__ Service 17. I hereby certify that t~loregoing is true and~,~rrect to the best o! my knowledge. Questions? Call Todd Mushovic 265,~6974 Signed c M ~-- Title: Drilling Engineering Supervisor Date · ar~ ~ Prepared b~' Sharon AIIsup-~)rake/263-46 I2 ./~./ · FOR COMMISSION USE ONLY ~-'(~1~ - Conditions of approval: Notify Commission ~,~presentative may witness '~'~,, ,..'t ..-_ ...... ~ ~,~'~-- t I Approval no "', Plua i~teadtv ~'~B~)PTesl~' . .?~.'"~Y~ "'~'~','"",~'", ~>',~I'~+,,5w'-I ug m[egmy __ ~u~ ~e~ ~ Loca[~n clearan~ ~ ~ I ~ - Mechanical Integr~ Test Subsequent fo~ required 10- w~-{ Approved by order of the Commission Form 10-403 Rev 06/15/88 ' Original Signed By Commissioner Date / ~//~/~ I C,,,,,,,,~ 0echsli ORIGINAL SUBMIT IN TRIPLICATE Workover Procedure 1D-141 . MIRU Nordic Rig #~3. RU hardline and flowback tanks. Circulate seawater. Wait until well is static and read tbg and annulus pressures. Calculate brine weight and circulate kill weight brine around. Ensure that the well is dead. ND tree. NU BOPE. Function test BOPE. Pull BPV. Install test plug. Test rams and choke manifold to 5000 psi. Test annular to 3500 psi (Minimum 24 hou,m notification to AOGCC is required pdor to nipplina u~) and testinq). 3. Screw into tubing. BOLDS, pull hanger to floor. 4. POOH standing back 4-1/2" tbg. Spool heat trace and ESP cable onto drums. 5. TIH with reverse junk basket and cleanout mainbore to lower lateral. 6. PU and TIH w/ 2-3/8" and 3-1/2" DP, plug for CMU sliding sleeve and latch cleaning equipment. 7. Set plug in lower lateral sliding sleeve at 8154', Pull out of hole until cleaning tools is across latching area - 5603' MD. Clean out latch area. TOH. 8. PU and TIH whipstock. Set whipstock in latching profile. TOH. 9. TIH with mill, 2-3/8" and 3-1/2" DP and cleanout upper lateral. TOH laying down DP and mill. 10. 11. 12. 13. 15. 16. Pull wear bushing and re-run 4-1/2" tbg and ESP completion. Pull landing joint. Install BPV. ND BOP stack and NU tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull test plug. Displace well to seawater by pumping down annulus thru dump kill valve. Take returns thru the choke, holding back pressure as necessary to maintain constant BHP. Continue circulating until clean seawater returns to surface. Freeze protect well by pumping diesel down annulus taking returns from tubing, holding back pressure as necessary to maintain constant BHP. Shut down pumps. Put tubing and annulus into communication across choke manifold and allow diesel to swap over to tubing, equalizing at approximately 2000' TVD. Be sure to allow sufficient time for diesel to fully swap. Shut in well. Monitor and record SICP and SITP. Set BPV and RDMO Nordic Rig #3. Pull BPV and turn well over to Production via handover form. 9/24/01 1 Version 1 . . Workover Procedure 1D-141 MIRU Nordic Rig #3. RU hardline and flowback tanks. Circulate static and read tbg and annulus pressures. Calculate brine weight brine around. Wait until well is circulate kill weight Ensure that the well is dead. ND tree. NU BOPE. Function test Pull BPV. Install test plug. Test rams and choke manifold to 5000 psi. Test ann~ r to 3500 psi (.Minimum 24 hours notification to AOGCC is ~nd testing). 3. Screw into tubing..BOLDS, pull hanger to floor Win! 4. POOH standing back 4-1/2" tbg. Spool heat trace 5. TIH with reverse junk basket and cleanout mainbo~ . . . PU and TIH w/ 2-3/8" and 3-1/2" DP, plu equipment. a,~e~~~to~R). ~ ~ ~e,.c- cable onto drums. '~'~) ~O~k~, lower lateral. CMU sliding sleeve and latch cleaning Set plug in lower lateral sliding sleeve at 54'. Pull out of hole until cleaning tools is across latching area - 5603' MD. Clean out area. TOH. PU and TIH whipstock. Set whipstoc latching profile. TOH. TIH with mill, 2-3/8" and 3-1/2" DP cleanout upper lateral. TOH laying down DP and mill. 10. Pull wear bushing and re-run 4 tbg and ESP completion. 11. 12. 13. 14. With the tubing open, shear dump kill valve. test annulus to 2500 psi. Increase pressure to 3000 psi to ,Pull landing joint. Inst BPV. ND BOP stack and NU tree. Pull BPV. Install test plug. Test tree to 250 and 5000 si. Test packoff to 5000 psi. Pull test plug. Displace well to the choke, hol circulating unt Freeze pressure into com at a by pumping down annulus thru dump kill valve. Take returns thru back pressure as necessary to maintain constant BHP. Continue :lean seawater returns to surface, well by pumping diesel down annulus taking returns from tubing, holding back necessary to maintain constant BHP. Shut down pumps. Put tubing and annulus unication across choke manifold and allow diesel to swap over to tubing, equalizing 2000' TVD. Be sure to allow sufficient time for diesel to fully swap. 15. Shul well. Monitor and record SICP and SITP. 16. SE m. and RDMO Nordic Rig #3. Pull BPV and turn well over to Production via handover 9/24/01 1 Version I · ( PHILLIPS AlaSka, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CONDUCTOR (0-110, OD:16.000) TUBING (O-54O7, OD:4.500, ID:3.958) NIF (54O2-54O3, OD:4.500) XO (54O7-54O8, OD:4.500) SEAL (54O8-5422, OD:5.130) GEARBOX {5422-5423, OD:5.620) MOTOR (5423-5430, OD:6.250) CNTRLZR (5430-5431, OB:6.875} SURF CSG (O-5519, OD:7.625, Wt:29.70) PKR (6196-6197, OD:7.000) XO (6218-6219, OD:5.000) KRU 1D-141 APl: 500292296700 Well T PROD t NONE Angle (~ TS: Jdeg~' Angle ~ TD: J88 deg_~ 9550 Rev Reason: Set new ESP by J lmO Last Update: 18/2/2001 SSSV Type: 8/27/2000 Annular Fluid: Last W/O: Reference Last Tag: 5360' CTM top of old TD: 9550 ftKB 3/23/2001 Max Casing:string ~ S~INGS ;, i : i~ i :. i Description Size Top Bottom TVD I Wt IGrade I Thread CONDUCTOR 16.000 0 110 110 J 0.00 J J Welded SURFCSG 10.750 0 502 502 J 40.50 J-55 J BTC SURFCSG 7.625 0 I 5519 I 3600 29.70 L-80 ] BTC-MOD SURF CSG 7.000 5519 6360 3826 26.00 L-80 BTC-MOD CSG WINDOW JNT 7.000 5566 5603 3640 26.00 to 1D-141L1 ~LINER :: ?: :::: :: :::::: : : :: : Size Thread LINER 4.500 HSLHT DUAL SCREEN LNR 4.500 HSLHT LINER 9510 HSLHT ~TUBINGii ii i::::12i !iii:.2iiiiiiiii;ii i i::i2:i iii:?: i :.:. iii i ; ii::::i!ili : Size Top Bottom TVD Wt Grade Thread 4.500 0 5407 3544 12.60 L-80 N SOT Vlv Cmnt Description CABLE Heat Trace Cable; 3007' long. NIP Centralift Slotted Nipple XO Centralift TTC Crossover 0.000 O. 000 0.000 SEAL Centralift ESP Seal Section GST3 DB IL H6 PFS 0.000 Centraliff ESP Gearbox 9:1, 525 Series 0.000 Centralift PCESP Motor 57 HP 1315/26 KMH 0.000 Centralift Motor Centralizer (Baker Sentry Gauge ~ 5430.6') CENTRILIFT ESP PUMP with pack-off/slip stop 7/28/01 HR ZXP LineF Top Packer; 5.968" OD. BTC x 4.5" IBT Pin X-O Baker Model CMD Sliding Sleeve Baker 5" Model BPV Set Shoe 0.000 0.000 5.000 0.000 Packer ECP 4.500 3.430 5.000 This is the 'B Sand' LOWER LATERAL schematic for multilateral well..9 for 1D-141L1 for the 'D Sand' upper lateral. its LATCH PKR (8089-8090, OD:5.625) SLEEVE (81548155, OD:4.500) LINER (6196-8197, OD:4.500, Wt:9.50} i 5Oc. A'"[ t PHILLIPS Alaska, Inc. A Subsidia~ of PHILLIPS PETROLEUM COMPANY CONDUCTOR (0-80, OD:16.000) Gas Lift Mandrel/Valve 1 (5305-5306, OD:5.985} NIP (54O2-54O3, OD:4.500) XO (54O7-54O8, OD:4.500) GEARBOX (5422-5423, OD:5.620) CNTRLZR (5430-5431, OD:6.875) PROD CASING (0-5519, OD:7.625, Wt:29.70) PROD CASNG (5519-5579, OD:7.000, Wt:26.00) KRU 1D-141L1 APl:: 500292296760 Well Type: PROD Angle t~ TS: deg ~. SSSV T' NONE Grig Completion: ! 9/21/2000 Angle {~ TD: 190 deg ~ 9480 Annular Fluid: Last W/O: ] Rev Reason: Set new ESP Reference Ref Log Date:I Last Update: 8/5/2OO1 Last Tag: 5360' CTM top of old TD: 9480 itKB 3/23/2001 Max Ho e Ang e: 94 deg ~ 6688 Casing Stri~ ~ CASING STRINGS : Description I Size Top Bottom TVD Wt Grade{ Thread SURF CASING I 10.750 0 502 502 40.50 J-55 BTC CON DU CT OR 16.000 0 80 80 0.00 [ Weld ed PROD CASING 7.625 0 5519 I 3600 29.70 t L-80 BTC-MOD PROD CASNG 7.000 5519 5579 I 3629 t 26.00 I L-80 I BTC-MOD CSG WINDOW JNT 6.750 5579 5595 3636 0.00 joins 1D-141 Size m°p '"I Bottom TVD .... Wt ...... Gr~d'et Thread LINER 4.500 5582 I 6451 3772 12.60 I L-80 BTC MOD DUAL SCREEN LNR 4.500 6451 9440 3734 9.50 L-80 HSLHT LINER 5.500 9440 9460 3734 15.00 L-80 HSLHT Size Top Bottom TVD Wt Grade Thread 4.500 0 5407 3544 12.60 L-80 NSCT Vlv Cmnt Shear out ~ 2000 psi CNTRLZR Description Heat Trace Cable; 3007' long. Centralift Slotted Nipple. Centralift TTC Crossover. 0.000 0.000 0.000 Centralift ESP Seal Section GST3 DB IL H6 PFS 0.000 Centralift ESP Gearbox 9:1; 525 Series 0.000 Centralift PCESP Motor 57 HP 1315/26 KMH 0.000 PUMP PKR PKR KOIV SLEEVE BakerCMD Sliding Sleeve SHOE Baker Model 'GPV' Set Shoe Centralift Motor Centralizer (Baker Sentry Gauge @ 5430.6') CENTRILIFT ESP PUMP with pack-off/slip stop 7/28/01 Baker CTC 7' Isozone ECP 0.000 0.000 0.000 20' Payzone ECP 0.000 Baker KOIV 3.500 3.500 5.000 N Gte This is a multilateral well. This is the UPPER LATERAL 'D sand' schematic. See schematic for 1D-141 for the 'B sand' lower lateral. PKR 6139-6140, OD:4.500) PKR 6324-6325, OD:4.500) SLEEVE 641& 6417, OD:4.500) LINER -/ 5582-6451, OD:4.500, Wt:12.60) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CONDUCTOR 113-141 (0-110, OD:16.000, WI:151.50) TUBING (O-5407, OD:4.500, ID:3.958) PRODUCTION (0-5519, OD:7.625, Wt29.70) NIP (5402-5403, 0D:4.500) xo (5407-5408, OD:4.500) GEARBOX (5422-5423, OD:5.620) MOTOR (5423-5430, OD:6.250) PKR (619&6197, OD:7.000) KRU 1D-141 APl: 500292296700 Well Type: I PROD SSSV T, NONE Odg Completion: t 8/27/2000 Annular Fluid: Last W/O:I Reference Lo< Ref Log Date:I Last Tag: 5360' CTM top of old TD: 19550 ftKB I 3/23/2001 Max Hole Angle: 195 deg (~ 6630 - COMMON STRINGS Size Top Bottom SURFACE 10.750 0 502 CONDUCTOR 16.000 0 110 PRODUCTION 7.625 0 5519 PRODUCTION 7.000 5519 6360 CSG WINDOW JNT 6.500 5580 5589 - LOWER LATERAL LINER Size Top Bottom LINER 4.500 6196 8197 DUAL SCREEN LNR 4.500 8197 9510 LINER 5.000 9510 9548 TVD 3794 3778 3779 Angle ~ TS:I deg ~ Angle @ TD: 188 deg @ 9550 Rev Reason: Format Chgs by linc Last Update: 11/13/2001 TVD Wt I Grade] Thread 502 40.50 J-55 BTC 110 151.50 X-65 Welded 3600 29.70 I L-80 I BTC-MOD 3826 26.00 L-80 BTC-MOD 3634 26.00 to 1D-141L1 Wt 'Grade Thread 19~ .5000 L-80 HSLHT HSLHT TUBING SiZe 4.500 o Bottom TVD Wt GradeI Thread 5407 3544 I 12.60 I L-e0 ] NSCT VIv Cmnt 1. Shears out ~ 2000 psi CABLE PUMP NIP XO Description Heat Trace Cable; 3007' long. CENTRILIFT ESP PUMP with pack-off/slip stop 8/11/01 Centraliff Slotted Nipple Centralift TTC Crossover ID 0.000 0.000 0.000 0.000 SEAL Centralift ESP Seal Section GST3 DB IL H6 PFS 0.000 GEARBOX Centralift ESP Gearbox 9:1, 525 Series 0.000 MOTOR Centralift PCESP Motor 57 HP 1315/26 KMH 0.000 CNTRLZR Centralift Motor Centralizer (Baker Sentry Gauge ~ 5430.6') Description 0.000 ID PKR HR ZXP Liner Top Packer; 5.968" OD. XO BTC x 4.5" IBT Pin X-O VALVE CMT VALVE PKR Packer' ECP SLEEVE Baker Model CMD Sliding Sleeve SHOE Model BPV Set Shoe 5.000 0.000 3.844 4.500 3.430 5,000 'B Sand' LOWER LATERAL schematic for multilateral for 1D-141L1 for the 'D Sand' upper lateral. xo (6218-6219, OD:5.000) PKR (8089-8090, 0D:5.625) SLEEVE (8154-8155, OD:4.500) LINER -/ (6196-8197, OD:4.500, Wt:9.50) PHILLIPS AlaSka, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY CONDUCTOR 1D-141L1 (o-110, OD:16.000, Wt151.50) Gas Lift MandrelNalve 1 (53055306, 0D:5.985) TUBING (0-5407, OD:4.500, ID:3.958) NIP (54O2-5403, OD:4.500) XO J-- (5407-5408, 0D:4.500) KRU 1D-141L1 APl: 500292296760 SSSV T, NONE Annular Fluid: Reference Last Tag: 5360' CTM top of old 3/23/2001 Well Type: J PROD OfigRefCOmpletion:LaStLog, Date:W/O: 9/21/2000 TD: 9480 ffKB Max Hole Angle: 94 deg ~ 6688 - COMMON STRINGS Size 10.750 Top 0 Boffom 502 TVD 502 SURFACE CONDUCTOR 16.000 0 110 110 PRODUCTION 7.625 0 5519 3600 PRODUCTION 7.000 5519 6360 3769 5589 5580 6.500 3633 CSG WINDOW JNT ~ ~UPPER LATE~ LINER Boffom 'i'VD JTop 5582 6451 9440 Size LINER 4.500 6451 3772 DUAL SCREEN LNR 4.500 9440 3734 LINER 5.500 9460 3734 ~:TUBING : ;~ Angle@TS:Jdeg ~ , Angle @ TD: J90 deg @ 9480 Rev Reason: Format corrections by ImO Last Update: 11/15/2001 Size Bottom TVD Wt Grade 4.500 0 5407 3544 12.60 L-80 Wt Grade 40.50 J-55 151.50 X-65 29.70 L-80 26.00 L-80 26.00 L-80 Thread BTC Welded BTC-MOD BTC-MOD joins 1D-141 Thread BTC MOD HSLHT HSLHT Thread NSCT GEARBOX (5422-5423, 0D:5.620) Vlv Cmnt MOTOR (5423-5430, 0D:6.250) PRODUCTION (0-5519, OD:7.625, Wt29,70) 1. Shear out ~ 2000 psi Description [ ID 3.844 3.958 3.958 3.500 3.437 5.000 VALVE CMT VALVE PKR Baker CTC 7' Isozone ECP PKR Baker CTC 20' Payzone ECP KOIV Baker 4.5" KOIV SLEEVE BakerCMD Sliding Sleeve SHOE Baker Model 'GPV' Set Shoe Description ID CABLE 0.000 PUMP 0.000 0.000 Heat Trace Cable; 3007' long. CENTRILIFT ESP PUMP with pack:~off/slip stop 8/11/01 NIP Centralift Slotted Nipple. XO Centraliff TTC Crossover. 0.000 SEAL Centralift ESP Seal Section GST3 DB IL H6 PFS 0.000 GEARBOX Centraliff ESP Gearbox 9:1; 525 Series 0.000 MOTOR i Centralift PCESP Motor 57 HP 1315/26 KMH 0.000 CNTRLZR Motor Centralizer (Baker Sentry Gauge ~ 5430.6') 0.000 Note is a multilateral well. This is the UPPER LATERAL 'D sand' schematic~ See schematic for 1 D-141 for the 'B sand' lower lateral. PKR (6139-6140, OD:5.625) PKR (6324-6325, OD:5.625) SLEEVE (6416-6417, 0D:5.500) LINER j (5582-6451, OD:4.500, WH2.60) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 December 3,2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1D-141 / 1D-141L1 Application for Sundry Approval (APD 200-112 / 200-116) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to workover the West Sak 1D-141 well. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, ,~/Q Drilling Engineering Supervisor PAI Drilling CRM/skad RECENED DEC 0 ~ 7.001 ORIGINAL 1 E-141 Workover procedure Subject: ID-141 Workover procedure Date: Tue, 11 Dec 2001 15:01:58 -0900 From: "Todd J Mushovic" <tmushov@ppco.com> To: tom_maunder@admin.state.ak, us CC: "Sharon AIIsup-Drake" <sallsup@ppco.com> Tom, I have attached the revised procedure for this well. (See attached file: 1D-141 Gen WO Procedure- REVISED.doc) Todd J. Mushovic Drilling Engineer Phillips Alaska Inc. (907) 265-6974 - office (907) 240-5740 - cellular tmushov@ppco.com !' Name: 1D-141 Gen WO Procedure- REvIsED'id°c ~1D-141 Gen VVO Procedure- REVISED.doct Type: WlNWORD File (application/msword) IEncoding: base64 1 of 1 12/11/01 3:12 PM WELL LOG TRANSMITTAL To: State of Alaska July 13, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1D-141, 1D~141PB1, 1D-141L1, 1D-l-41 L1PB1, 1D-141 L1 PB2 AK-MM-00127 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 J,D-141: x.S" MD Resistivity & Gamma Ray Logs: 50-029-22967-00 I~'[,v/ 2"x 5" TVD Resistivity a Gamma Ray Logs: 50-029-22967-00 1 Blueline 1 Blueline ,/KD-141 PBI: '2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22967-70 -'[ I~0 ¢AD-141 LI: · 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22967-60 · ~2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22967-60 ~lD-141 L1 PBI: 2"x 5" MD Resistivity & Gamma Ray'Logs: 50-029-22967-71 /liD-141 L1 PB2: 2" x 5" MD Resistivity & Gamma Ray LogS: 50-029-22967-72 RECEIVED 'JUL 1 8 2001 1 Blueline I Blueline 1 Blueline 1 Blueline 1 Blueline 2oo-112 WELL LOG TRANSMITTAL To: State of Alaska July 03,2001 Alaska Oil and Gas Conservation CoMW. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-141 PB1, 1 LDWG formatted Disc with verification listing. API#: 50-029-22967-70 AK-MM-00127 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sig~ RECEIVED 'JUL 10 200'1 WELL LOG TRANSMITTAL To: State of Alaska July 03, 2001 Alaska Oil and Gas Conservation CoMW. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-141, AK-MM-00127 1 LDWG formatted Disc with verification listing. API#: 50-029-22967-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~ RECEIVED "JUL I 0 2001 Nadm Oil & Oas Cons. Com~ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 November 14, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D- 141 and 1D- 141L1 (200-112 and 200-116) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1D-141 and multilateral drilling operations on 1D- 141L1. If you have any questions regarding this matter, please contact me at 265-6434 or Steve McKeever at 265-6826. Sincerely, J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classitication of Service Well o,, El D D ando.ed D D 2. Name of Operator~ 7. Permit Number Phillips Alaska, Inc. ~ 200-112 3. Address ~1=1~'#=1~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~t' 50-029-22967-00 4. Location of well at surface ~ H.~ ~,' 9. Unit or Lease Name 14' FSL, 596' FEL, Sec. 14, T11N, R10E, UM (ASP:560491, 5959679)~! C~T!O,q~~~ Kuparuk River Unit At Too P~uang ~nterva~ i ~'~2_~_~_ ! 10. We, Number 1266' FNL, 2074' FEL, Sec. 24, T11N, R10E, UM (ASP: 564304, 5958432) J~ l 1D-141 524' FSL, 2242' FEL, Sec. 24, T11 N, R10E, UM (ASP: 564166, 5954943) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 30 feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 5, 2000 August 21, 2000 September 21, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9550' MD / 3779' TVD 9548' MD / 3779' TVD YES [~] No DI N/A fee{ MD 1735' i22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 151.5# X-65 Surface 110' 24" 135 sx AS I 10.75" 40.5~ J-55 Surface 502' 12.25" 126 sx LiteCRETE 7.625" x 7' 29.7~f / 26# L-80 Surface 6360' 9.875" 540 sx AS III Lite, 490 sx Class G 4.5" x 4" 12.6# / 9.5# L-80 6196' 9548' 6" 255 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 5438' N/A No perfs - Pre-pack screens in horizontal laterals 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8229'-9445' 8% Formic Acid 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 2, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 10/23/2000 2.5 Test Period > 49 8 5 100 I 200 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 331.psi not available 24-Hour Rate > 451 90 48 16.1 ° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate NAME Top West Sak Sand West Sak A3 Base West Sak Sand GEOLOGIC MARKERS MEAS. DEPTH 5885' 9550' 9550' TRUE VERT. DEPTH 3753' 3779' 3779' FORMATION TESTS Include interval tested, pressure data, all fluids recoverecl and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hTY certify~llowing is true and correct to the best of my knowledge. Signed J~ I ~~'~1~"~. Title Drillin,q E n,qineerinf:l Supervisor James Trantham Questions? Call Mark Chambers 265-1319 INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21-' Indicate whether from ground level (GL) or other eleVation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-141 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:08/05/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22967-00 08/04/00 (D1) TD/TVD: 110/110 SUPV:M.C. HEIM MW: 8.5 VISC: 280 PV/YP: 50/70 ( 110) PRE SPUD MEETING W/ BOTH CREWS APIWL: 10.0 30' rig move from 1D-110A to 1D-141. Accepted rig @ 1400 hrs. 8/4/00. RU diverter and test. 08/05/00 (D2) TD/TVD: 381/381 SUPV:M.C. HEIM MW: 8.8 VISC: 260 PV/YP: 19/41 (271) DRLG. @ 480'. APIWL: 10.0 Pre-spud meeting. Tag at 102', drilling and surveys from 102' to 377'. Wash and ream 30' to bottom, drill from 377' to 381'. Run gyro. 08/06/00 (D3) TD/TVD: 502/381 SUPV:M.C. HEIM MW: 8.7 VISC: 43 pV/yp: 13/ 7 (121) MAKING UP BHA 92. APIWL: 12.0 Drilling from 381' to 414'. Run gyro survey. Drilling from 414' ~to 520'. CBU for 10.75" casing. Run 10.75" casing. Pump cement. Bumped plug. Run gyro survey. 08/07/00 (D4) TD/TVD: 621/621 SUPV:M.C. HEIM MW: 8.8 VISC: 147 PV/YP: 31/39 (119) DRILLING @ 625 APIWL: 6.4 RIH w/flex collars and jars. Tag cement @ 485'. Drill out 17' cement (firm) plugs and shoe and clean out to 521', run gyro, drill to 565'. POH. RIH w/UBHO sub on bottom of DP. Run Gyro. POH. RIH. Drilling'from 565' to 621' 08/08/00 (D5) MW: 8.9 VISC: 130 PV/YP: 32/31 APIWL: 6.0 TD/TVD: 1792/1645 (1171) DRILLING AHEAD AT 2230' SUPV:DON WESTER & BRIAN NOEL Drill 621' to 638' and run gyro. Trip out to pick up MWD. RIH w/BHA 94. CBU. Drill 638'-734' and gyro. Drill 926' - 1118' & gyro. Drill 1118'-1792' 08/09/00 (D6) MW: 9.4 VISC: 140 PV/YP: 41/45 APIWL: 4.2 TD/TVD: 3450/2532 (1658) ON BOTTOM AT 3521' PUMPING SWEEP AFTER 14 STAND SHORT SUPV:DON WESTER & BRIAN NOEL Drill from 1792' - 2752'. Encountered 50' oil sand at 2650' that blinded shaker screens. Circ & recip at low pump rate while change shaker screens & conditiOn mud. Drill 2752' - 3450' Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/10/00 (D7) MW: 9.4 VISC: 110 PV/YP: 38/40 APIWL: 4.2 TD/TVD: 4700/3179 (1250) TRIP OUT AT 4870' TO REPAIR TOP DRIVE GRABBER SUPV:DON WESTER & BRIAN NOEL Drill from 3450'-3521'. Pump sweep to clean hole. Pull 14 stands to base permafrost w/some tight spots & RIH. Wash last stand to bottom and circulate sweep around. Drill from 3521' to 4580'. Change out top drive grabber dies while survey at 4002'. Drill from 4580' to 4700' 08/11/00 (D8) MW: 9.4 VISC: 90 PV/YP: 35/40 APIWL: 4.2 TD/TVD: 4870/3263 (170) DRILLING AT 5100' SUPV:DON WESTER & BRIAN NOEL Drill from 4700'-4870'. Work on top drive, remove grabber assembly. POOH smooth to 2200'. Tight from 2200'-1500' Pump out each stand. Finish trip out. RIH to 500'. Repair and test top drive grabber assembly & change saver sub. RIH. 08/12/00 (D9) MW: 9.5 VISC: 74 PV/YP: 31/34 APIWL: 4.2 TD/TVD: 6014/3690 (1144) DRILLING AT 6300' SUPV:DON WESTER & BRIAN NOEL RIH w/4" drill pipe, tight spot at 3137'-4389'. Drill from 4870'-6014'. 08/13/00 (D10) MW: 9.5 VISC: 65 pV/yp: 28/30 APIWL: 3.4 TD/TVD: 6416/3829 ( 402) POOH W/ FISHING TOOLS SUPV:DON WESTER & BRIAN NOEL Drill from 6014'-6416'. CBU. POOH to 10,3/4" casing shoe. POOH. Left bit w/bit sub and part mud motor shaft in hole. Make up fishing assembly. 08/14/00 (Dll) MW: 9.5 VISC: 64 PV/YP: 27/30 APIWL: 3.0 TD/TVD: 6416/3829 ( 0) RUNNING SURFACE CASING SUPV:DON WESTER & BRIAN NOEL RIH w/fishing BHA. Tag fish at 6413' and work overshot w/pump pressure increase. POOH 12 stands. Circulate to balance well. Complete POOH, no fish recovery. RIH. PJSM. RIH w/9-7/8" hole opener & reamer to 6101'. Ream from 6101'-6014'. CBU and condition mud. POOH wet. 08/15/00 (D12) TD/TVD: 6416/3829 ( SUPV:M.C. HEIM MW: 9.5 VISC: 50 PV/YP: 50/17 APIWL: 3.6 0) NIPPLING DOWN ( BUMPED PLUG @ 04:30-FLOATS HELD-10 TO PJSM. Run 7" x 7-5/8" casing string. Attempt to circ, remove check valve from fill up tool. Circ & condition mud working pipe. RIH w/gyro to 1800', stopped, POH, RIH, pumping down tool. POH. Clean out and work pipe. Landed hanger. Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/16/00 (D13) MW: 9.4 VISC: 46 PV/YP: 17/16 APIWL: 4.0 TD/TVD: 6360/3826 ( 0) PICKING UP 3 1/2" HWDP ON TOP OF 3 1/2" DP. SUPV:M.C. HEIM Circ & condition hole for cementing casing. PJSM. Cement casing. Bumped plug, floats held. N/D diverter. NU BOPE and test to 250/3000#. 08/17/00 (D14) MW: 8.9 VISC: 50 PV/YP: 8/21 TD/TVD: 6510/3829 (150) RUNNING IN HOLE SUPV:M.C. HEIM APIWL: 4.2 PJSM. RIH w/4" DP, tight @ 5589', rotate, no pump thru same. RIH, tag cement @ 6266', drill out plug, float collar, cement and shoe to 6360'. Slide out of shoe from 6360' to 6431'. Pull to shoe & CBU for FIT. Perform FIT, OK. Drilling and surveys from 6431' to 6500'. Change over mud to baran-dril. RIH and drill to 6510'. Circ & work pipe, try to get tool working. POH. 08/18/00 (D15) MW: 9.0 VISC: 53 PV/YP: 8/29 APIWL: 3.8 TD/TVD: 6779/3827 (269) DRLG. & SURVEYS @ 7100' SUPV:M.C. HEIM RIH. MAD pass from 6362' to 6510'. Drilling frOm 6510' to 6902'. Pull back to 6610' & build trough to 6638' for open hole sidetrack. Drilling from 6630' to 6679'. Work on trough. Drilling from 6679' to 6779' 08/19/00 (D16) MW: 9.0 VISC: 50 PV/YP: 9/30 APIWL: 3.9 TD/TVD: 8122/3792 (1343) DRLG. & SURVEYS @ 8603' SUPV:M.C. HEIM Drilling and surveys from 6779' to 8122'. CBU for wiper trip to kick off depth @ 6638' Wiper trip to 6586', work pipe back into new hole, RIH. 08/20/00 (D17) MW: 8.9 VISC: 48 PV/YP: 10/23 APIWL: 3.8 TD/TVD: 9535/3778 (1413) POH F/ HOLE OPENER. SUPV:M.C. HEIM Wash 90' to bottom @ 8122'. Drilling & surveys from 8122' to 9535' 08/21/00 (D18) MW: 8.9 VISC: 44 PV/YP: 10/22 APIWL: 3.8 TD/TVD: 9550/3778 ( 15) CLEANING MUD TANKS. SUPV:M.C. HEIM Drilling from 9535' to 9550' TD. Circulate bottoms up for hole opener run. Pull out of hole. RIH w/BHA 911 to 7" shoe @ 6360'. Circ-condition hole. POH. 08/22/00 (D19) TD/TVD: 9550/3778 ( SUPV:DON WESTER MW: 8.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) POOH L/D BHA #12 P/U BHA #13 HOLE OPENER W/ 3-1/2" 310 POOH to 7" casing shoe @ 6360'. RIH w/ BHA #12 to 6300' PJSM Pump caustic wash pill POOH. ?~.: Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/23/00 (D20) MW: 8.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9550/3778 ( 0) P/U LOWER LATERAL SCREEN ASSSY. NOW RUNNING 2-7/8" INT SUPV:DON WESTER RIH on 6" hole opener. PJSM. Continue RIH w/ BHA #13 tight @ 7850' to 9550'. POOH. R/U to run lower lateral screens assembly. PJSM. Run lower lateral screen assy. 08/24/00 (D21) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9550/3778 ( 0) SET BAKER LINER HANGER. SET ECP PACKER OPEN HMCV CIRCU SUPV:DON WESTER Run lower lateral screen assembly 4" x 4.5" Baker dual screen pre-pack. Circulate and displace viscosified brine with clear brine. 08/25/00 (D22) TD/TVD: 9550/3778 ( SUPV:DON WESTER MW: 8.7 VISC: 0 PV/YP: 0/ 0 0) TEST BOPE, P/U WASH CUP TOOLS. APIWL: 0.0 Continue circulating clear brine w/4.5" casing x 4" screen assy on bottom @ 9550'. Drop ball and displace to seat. PJSM. Set ECP. Pumped cement. Set packer. POOH to ·6190'. Circulate and wash liner top @ 6196' Monitor Well flowing. Continue to circulate bottoms up. Blend kill weight fluid. POOH. Test BOPE. 08/26/00 (D23) TD/TVD:· 9550/3778 ( SUPV:DON WESTER MW: 8.7 VISC: 0 PV/YP: 0/ 0 0) PUMP FORMIC ACID TO WASH SCREENS. APIWL: 0.0 Continue test BOPE to 250/3000 psi. RIH with Baker sliding sleeve shifting tool on cup test assembly. PJSM. Pump Xan-vis and HC1. Pump brine. Washing formation out side screens and back through sliding sleeve @ 8154'. Pump formic acid. 08/27/00 (D24) TD/TVD: 9550/3778 ( SUPV:DON WESTER MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) SET SECOND SAND PLUG ON TOP OF BRIDGE PLUG @ 5763'-577 Continue 8% formic acid soak "B" sand from 9550' to 8112' OPen well flowing. Bull head brine down annulus. Pump formic acid and displaced with brine. Pump second formic acid treatment and displaced with brine. POOH. RIH to 5771' set bridge plug. Dump sand down DP and displaced with brine. 08/28/00 (D25) TD/TVD: 5595/3635 ( SUPV:DON WESTER MW: 8.9 VISC: 48 PV/YP: 9/23 APIWL: 4.4 0) POOH W/ WINDOW MILLS, RIH W/ DRILLING BHA @ 5580' AT 0 Lay second sand plug over Baker retrievable 7 .... G" plug· Seer 5763'. Dump 20-40 sand down drill pipe and displaced with brine· Pull 10 stands. RIH tag sand @ 5740'. RIH with whipstock. Held safety meeting. RIH. Displace brine with milling fluid· Mill outof pre-drilled window from 5583' to 5595' PPOH. ~ ..................... ~ ~ ~ ~. Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 08/29/00 (D26) MW: 8.9 VISC: 44 PV/YP: 8/20 APIWL: 3.5 TD/TVD: 6135/3754 (540) DRLG. @ 6487'. SUPV:M.C. HEIM RIH. Drilling from 5595' to 5622'. Perform LOT @ 12 ppg equiv. Drilling and surveys from 5622' to 5936'. Circ bottoms up. Drilling and surveys from 5936' to 6135'. 08/30/00 (D27) MW: 8.9 VISC: 52 PV/YP: 10/28 APIWL: 3.8 TD/TVD: 6871/3786 (736) POH FOR MOTOR CHANGE. (DEPTH-6961.) SUPV:M.C. HEIM Drilling and surveys from 6135' to 6779'. Pull 3 stands to 6487'. Wash & ream trough for sidetracking well from 6487' to 6550'. Sidetracking well from 6550' to 6871' 08/31/00 (D28) MW: 8.9 VISC: 44 PV/YP: 9/24 APIWL: 4.4 TD/TVD: 6667/3770 ( 0) DRLG & SURVEYS @ 6900 SUPV:M.C. HEIM Drilling and surveys from 6871' to 6961'. Circ, mix and pump dry job. POH. RIH to 6478'. Wash & ream from 6478' to 6638'. POH to 6380' Drilling sidetrack from 6380' to 6667' 09/01/00 (D29) MW: 9.0 VISC: 50 PV/YP: 11/28 APIWL: 3.1 TD/TVD: 7737/3737 (1070) DRLG. & SURVEYS @ 8080' SUPV:M.C. HEIM Drilling and surveys from 6667' to 7148'. Wiper trip to top of sidetrack @ 6379', no problems. Drilling and surveys from 7148' to 7737' 09/02/00 (D30) MW: 9.0 VISC: 48 PV/YP: 10/25 TD/TVD: 9163/3727 (1426) CIRC. BOTTOMS UP.@ 9480 MD. SUPV:M.C. HEIM Drilling and surveys from 7737' to 9163' APIWL: 3.8 09/03/00 (D31) MW: 8.9 VISC: 48 PV/YP: 11/23 APIWL: 3.8 TD/TVD: 9480/3733 (317) CIRC. & RECIPROCATE WHILE MIXING PUSH PILL FOR DISPLAC SUPV:M.C. HEIM Drilling and surveys from 9163' to 9480' TD. Survey @ TD, circ & reciprocate, pump sweep and dry job. POH to 5966', tight. Circ and ream up to 5677', pull thru window, no problem. POH to BHA #18. Test BOPE 250/3000 psi. RIH with BHA #19 to window @ 5580'. Circ and slide thru window & ream to bottom w/hole opener to 6583' 09/04/00 (D32) TD/TVD: 9480/3733 ( SUPV:M.C. HEIM MW: 8.8 VISC: 0 PV/YP: 0/ 0 0) LAYING DOWN 3 1/2" DP.' APIWL: 0.0 Finish reaming hole w/hole opener & roller reamer from 6583' to 9480' TD. Rotate, reciprocate, pump hi vis sweep, mix pill, PJSM. Pump pill followed by'brine. POH to shoe, tight spot @ 6025" Anchor~ Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 09/05/00 (D33) TD/TVD: 9480/3733 ( SUPV:M.C. HEIM MW: 8.8 VISC: 0 PV/YP: 0/ 0 0) RUNNING UPPER LATERAL LINER. APIWL: 0.0 POH. RIH with BHA %20 to 5517'. Displace casing with filtered brine, cbu. Trip to top scraper & back to 5517' PJSM. Pump caustic wash around system. Circ viscosified brine. 09/06/00 (D34) MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) WORKING TIGHT HOLE W/ SCREENS & LINER @ 6090' SUPV:M.C. HEIM POH w/ 7-5/8" scrapers & brush assembly. PJSM. Run screens & 4" tubing. PJSM. Continue to run screens and 4" tubing. Run 2-7/8" tubing. PJSM. Continue running liner & inner string. 09/07/00 (D35) TD/TVD: 9480/3733 ( SUPV:M.C. HEIM MW: 9.1 VISC: 0 PV/YP: 0/ 0 0) LAYING DOWN SCREENS & 4" BLANKS. APIWL: 0.0 Run in hole w/4" liner and screens to 5580'. Pipe running over, CBU balance fluid. Run in hole w/liner, tight @ 5930' to 6096', wash from 6096' to 6277', string sticking on each conn., lost weight. POH. PSJM. Run in hole to 2407', latch fish and jar same loose. POH w/fish. 09/08/00 (D36) MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) CIRC. 8.8% CLEAN BRINE SUPV:M.C.. HEIM POH to top of fish. PJSM. RIH. Work thru window & wash and ream from 5580' to 7572' 09/09/00 (D37) MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) RUNNING 2 7/8" INNER STRING SUPV:M.C. HEIM Wash & ream to bottom from 7572' to 9480' MD. Circ bottoms up, displace hole with clean brine & spot viscosified fluid in open hole. POH to shoe @ 5580'. POH. RIH with screen assembly. 09/10/00 (D38) MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) SERVICE RIG & TOP DRIVE SUPV:M.C. HEIM/DON MICKEY RIH w/2-7/8" inner string & 4.5" tubing. Establish circ & cbu. Run in hole w/liner & screens to 9460'. PJSM. Attempt to set ecp, no go. Drop ball & release from liner. POH. Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 09/11/00 (D39) MW: 8.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) RIH W/ 6" BIT AND STRING MILL SUPV:M.C. HEIM/DON MICKEY Cont. POOH w/2-7/8" tbg. Set test plug. Test BOPE to 250/3000 psi. Pull test plug. RIH w/inflation/cement tool. PJSM. Set lower ECP, set top ECP. Circ bttms up. Cement upper lateral. Bumped plug. POOH. 09/12/00 (D40) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 9.0 VISC: 0 PV/YP: 0/ 0 0) TRIP OUT W/ 3.75" CMT. MILL APIWL: 0.0 RIH w/6" bit to 4777'. Circ bttms up. Wash and rotate from 4777' to 5347'. Circ bttms up. Cont. RIH, C/O soft cement from 5350' to 5447' Circ bttms up, observed soft cmt at shakers. Pull up to 5321'. RIH from 5321' to 5447', c/o soft cmt to 5470', med. hard cmt from 5470' to 5500', hard cmt from 5500' to 5580'. Circ clean. POOH. RIH w/BHA ~ 27 to 5580'. C/O cmt from 5580' to 5582' 09/13/00 (D41) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 9.3 VISC: 0 PV/YP: 0/ 0 0) PULL OUT W/ 6" TAPERED MILL APIWL: 0.0 C/O cement from 5582' to 5605'. Circ hole clean. Pull out w/3.75" cement mill. RIH w/whipstock retrieving assembly to 5480'. RIH to 5565', ream from 5565' to 5580'. Pull out w/whipstock. 09/14/00 (D42) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 8.7 VISC: 0 PV/YP: 0/ 0 0) RIH W/ 3 3/4" & MOTOR APIWL: 0.0 RIH w/6" taper mill to 5573'. Slide thru window @ 5580', circ and slide from 5587' to 5603', rotate mill back to 5585', slide from 5587' to 5734', tag sand plug, reverse out sand from 5734' to 5763'. POOH w/taper mill, work.mill @ window coming'out. RIH, set production whipstock w/top @ 5576' PJSM. Pump acid pickle. POOH w/production whipstock setting assembly. RIH with mule shoe to 5570', rotate thru window @ 5580', tag cement @ 5606'. POOH. 09/15/00 (D43) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) CLEANING OUT UPPER LATERAL 4-1/2" LINER @ 5861' SUPV:DON MICKEY Finish POOH w/mule shoe. RIH w/mill & motor assembly. Tag 5590' C/O cement from 5599' to 5698'. Stuck pipe @ 5615' while pulling up to make connection, work pipe free. Continue C/O cement from 5698' to 5794' Date: 10/17/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 8 09/16/00 (D44) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 8.7 VISC: 0) POOH W/ 3.25" MILL 0 PV/YP: 0/ 0 APIWL: 0.0 C/O cement in upper lateral linr from 5794' to 5977', broke thru cement. Wash & ream from 5977' to 6377'. Mill out KOIV. Displace DP & 4.5 liner annulus w/clean brine. Pull out to 5510'. POOH to 2-3/8" tubing. RIH w/2-3/8" tubing. 09/17/00 (D45) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) LET ACID SOAK SUPV:DON MICKEY - RIH, tag bottom @ 9448'. Pull out w/3.25" mill to 6372', drop ball & shear circ sub. Held safety meeting. Test BOPE to 250/3000 psi. PJSM. RIH. 09/18/00 (D46) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) TRIP OUT W/ PROD. WS RETREIVING TOOL SUPV:DON MICKEY RIh w/cup wash assembly to 9448'. Circ hole with brine'. PJSM. Pump formic acid job. Bullhead brine down annulus. PJSM Perform acid wash of' GP screens. Pumped 3 stages. Monitor well. Safety meeting. POOH w/cup wash assembly. 09/19/00 (D47) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 8.7 VISC: 0) RUNNING COMPLETION 0 PV/YP: 0/ 0 APIWL: 0.0 Finish POOH With cup wash tool. Rig up to run 4" DP. RIH with WS retrieving assembly, function HRT. Wash down engage WS. Jar on fish, HRT would not engage, wash and work, attempt to engage WS, no good. POOH. RIH w/spear, engage fish, jar on fish, pulled free. POOH w/fish. RIH with BP retrieving tool. Held safety meeting. POOH w/BP. R/U to run 4.5" tubing. PJSM. RIH with 4.5" tubing. 09/20/00 (D48) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9480/3733 ( 0) SPLICING POWER CABLE FOR ESP SUPV:DON MICKEY Finish RIH 4.5" tubing. PJSM. RIH w/ESP on 4.5" tubing. RIH with heat trace on 4.5" tubing. 09/21/00 (D49) TD/TVD: 9480/3733 ( SUPV:DON MICKEY MW: 15.4 VISC: 0) RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 Finish space out heat trace and tubing hanger. Test heat trace cable. Test ESP cable. Set BPV. N/D BOPE. Test ESP/heat trace and Baker sentry cables. N/U tree and test to 250/5000 psi. Freeze protect well. Release rig @ 1800 hrs. 9/21/00. 12-Oct-00 Phillips Alaska, Inc. Sharon AIIsup-Drake, ATO 12 Kuparuk Development Drilling 700 G Street Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-141 Dear Sharon AIIsup-Drake: Enclosed is one survey hard copy. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,603.21 'MD 6,630,00' MD 9,550.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-141 Job No. AKMMO0127, SURVEY REPORT 12 October, 2000 Your Ref: AP1-500292296700 Surface CoordInatee: 5959678.92 N, $60490.60 E (70° 18' 01.4558" N, 210° 29' 23.7094" E) Kelly Bushing: 101.05ft above Mean Sea Level spar r f=mun. A I. MIIIburton Company Survey Reh svy9317 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 6603.21 94,060 185.280 3728.19 6630.00 94.880 185.000 3726.10 6660.74 91.720 185.580 3724.33 6699.31 88.210 188.660 3724.35 6732.14 87.660 192.720 3725.54 194.220 195.360 196.780 198.180 200.810 6763.41 89.250 6794.69 90.800 6830.07 91.350 6859.72 91.600 6890.29 90.800 3726.38 3726.37 3725.70 3724.94 3724.3O Sperry-Sun Drilling Services SurveY Report for 1D-141 Your Ref: API.500292296700 Job No. AKMMO0127, Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eas, tings (ft) (ft) (ft) (ft) (ft) 3829.24 1905.39 S 4060.53 E 5957806.28 N 564566.34 E 3827.15 1931.99 S 4058.14 E 5957779.66 N 564564.16 E 3825.38 1962.55 S 4055.31E 5957749.08 N 564561.58 E 3825.40 2000.81 S 4050.53 E 5957710.78 N 564557.11 E 3826.59 2033.04S 4044.45 E 5957678.50 N 564551.28 E 3827.43 3827.42 3826.75 3825.99 3825.35 6929.50 90.220 200.740 3723.95 3825.00 6957.27 89.780 199.680 3723.95 3825.00 6985.83 90.000 199.640 3724.01 3825.06 7036.04 91.190 200.210 3723.48 3824.53 7081.47 91.970 201.660 3722.23 3823.28 7116.92 90.750 201.620 3721.39 3822.44 7179.25 90~860 201.720 3720.51 3821.56 7214.91 - 93.140 203.070 3719.27 3820.32 7247.02 93.200 203.130 3717.49 3818.54 7276.47 93.820 202.590 3715.69 3816.74 7311.94 94.070 202.580 3713.25 7344.49 94.060 202.840 3710.94 7372.50 94.680 202.520 3708.81 7407.95 94.370 202.470 3706.01 7440.43 94.070 201.740 3703.62 3814.30 3811.99 3809.86 3807.06 3804.67 2063.44 S 4037.17 E 5957648.05 N 564544.25 E 2093.68 S 4029.18 E 5957617.74N 564536.51 E 2127.67 S 4019.39 E 5957583.67 N 564526.99 E 2155.94 S 4010.49 E 5957555.33N 564518.31 E 2184.75 $ 4000.29 E 5957526.44 N 564508.35 E 2221.41 S 3986.38 E 2247.47 S 3976.79 E 2274.36 S 3967.18 E 2321.57 S 3950.07 E 2363.98 S 3933.84 E 2396.92 S 3920.78 E 2454.84 S 3897.76 E 2487.79 S 3884.18 E 2517.28 S 3871.61E '2544.36.S 3860.19 E 2577.04 S 3846.60 E 2606.99 S 3834.06 E 2632.76 S 3823.29 E 2665.41 S 3809.77 E 2695.42 S 3797.58 E 5957489.67 N 564494.74 E 5957463.54 N 564485.35 E 5957436.57 N 564475.96 E 5957389.23 N 564459.23 E 5957346.69 N 564443.35 E 5957313.64N 564430.54 E 5957255.54 N 564408.00 E 5957222.48 N 564394.69 E 5957192.89 N 564382.35 E 5957165.71N 564371.14 E 5957132.93 N 564357.82 E 5957102.88 N 564345.52 E 5957077.03N 564334.96 E 5957044.27N 564321.71 E 5957014.16 N 564309.76 E Dogleg Rate (°/lOOtt) 3.23 10.45 12.11 12.47 6.99 6.15 4.30 4.79 8.99 1.49 4.13 0.78 2.63 3.62 3.44 0.24 7.43 0.26 2.79 0.71 0.80 2.49 0.89 2.42 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3979.58 Tie-on Survey 3999.26 Window Point 4021.82 4049.32 4071.23 4090.96 4110.14 4131.20 4148.26 4164.95 4185.63 4200.51 4216.05 4243.16 4267.01 4285.24 4317.29 4335.22 4351.01 4365.60 4383.30 4399.49 4413.42 4431.16 4447.60 Continued... DrillQuest 2.00.02 -2- 12 October, 2000 - 12:19 · North Slope Alaska Measured Depth (fi) 7468,39 7504.20 7536.21 7564.08 7600.13 Sub-Sea Incl. Azim. Depth (fi) 94.130 201.710 3701.62 93.690 201.880 3699.18 93.140 201.770 3697.27 91.720 200.720 3696.09 91.480 200.250 3695.09 7632.53 92.280 201.050 3694.02 7660.64 92.220 201.230 3692.92 7696.33 91.850 201.150 3691.65 7728.65 91,780 201.010 3690.63 7756,49 91.660 200.370 3689,79 7793.80 92.030 199.920 7826.34 90.550 198.640 7854.13 87.970 197.570 7886.84 88.280 197.420 7922.43 87.400 196.510 3688.59 3687.86 3688.22 3689.29 3690.63 Sperry-Sun Drilling Services Survey Report for 1D-141 Your Ref: AP1-$00292296700 Job No. AKMMO0127, Ve~ical Depth (fi) 3802.67 3800.23 3798.32 3797.14 3796.14 3795.07 3793.97 3792.70 3791.68 3790.84 3789.64 3788.91 3789.27 3790.34 3791.68 7950.66 87.110 197.120 3691.98 3793.03 7987.68 89.870 196.510 3692.96 3794.01 8011.69 90.930 i96.330 3692.79 3793.84 8043.96 90.370 194.470 3692.42 3793.47 8078.00 90.660 191.220 3692.12 3793.17 8116.77 90.310 189.810 3691.79 8143.19 89.570 187.320 3691.82 8174.36 88.990 184.350 3692~1 8207.07 89.260 180.520 3692.71 8238.63 90.370 177.870 3692.81 3792.84 3792.87 3793.26 3793.76 3793.86 Local Coordinates Nodhings (~) 2721.32 S 2754.50 S 2784.16 S 2810.11S 2843.87 S 2874.17 S 2900.37 $ 2933.62 S 2963.77S 2989.80 $ 3024.81S 3055.51S 3081.92 $ 3113.10 S 3147.12 S 3174.11 S 3209.53 S 3232.56 S 3263.67S 3296.85 S 3334.97 S 3361.09 S 3392.09S 3424.76 S 3456.32S Global Coordinates Eastings Northings Ea.stings (ft) (ft) (ft) 3787.26 E 5956988.17N 564299.64 E 3774.00 E 5956954.89 N 564286.65 E 3762.12 E 5956925.14 N 564275.01E 3752.03 E 5956899.10 N 564265.13 E 3739.42 E 5956865.25 N 564252.79 E 3728.00 E 5956834.85 N 564241.61 E 3717.87E 5956808.58 N 564231.69 E 3704.97 E 5956775.22 N 564219.07E 3693.35 E 5956744.98 N 564207.69 E 3683.52 E 5956718.87 N 564198.07 E 3670.68 E 5956683.76 N 564185.51 E 3659.94 E 5956652.97 N 564175.02 E 3651.31E 5956626.49 N 564166.60 E 3641.48 E 5956595.23 N 564157.02 E 3631.10 E 5956561.13 N 564146.92 E 3622.94 E 5956534.08N 564138.98 E 3612.24 E 5956498.57N 564128.56 E 3605.45 E 5956475.49 N 564121.96 E, 3596,88 E 5956444.31N 564113.64 E 3589.32E 5956411.07N 564106.34 E 3582.24 E 5956372.90 N 564099.57 E 3578.31 E 5956346.74N 564095.85 E 3575.14 E 5956315.72N 564092.93 E 3573.75 E 5956283.04 N 564091.80 E 3574.19 E 5956251.49 N 564092.50 E Dogleg Rate (°/100ft) 0.24 1.32 1.75 6.33 1.46 3.49 0.67 1.06 0.48 2.34 1.56 6.01 10.05 1.05 3.56 2.39 7.64 4.48 6.02 9.59 3.75 9.83 9.71 11.74 9.10 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4461.91 4480.21 4496.57 4511.06 4530.22 4547.36 4562.03 4580.62 4597.52 4612.23 4632.25 4650.12 4665.86 4684.66 4705.39 4721.88 4743.52 4757.70 4777.21 4798.98 4824.97 4843.34 4866.o5 4891.16 4916.50 Continued,.. · 12 October, 2000 - 12:19 - 3 - DrillQuest 2.00.02 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 8269.81 90.220 177.13o 3692.65 8296.06 90.840 176.95o 3692.41 8334.91 91.29o 177.57o 3691.68 8369.58 91.37o 177.30o 3690.88 8400.83 91.28o 177.48o 369o.16 8430.93 91.41o 176.63o 3689.45 8465.56 91.72o 176.95o 3688.51 8498,08 91.10o 176.95o 3687.70 8526.48 92.15o 177.07o 3686.90 8561.96 91.72o 176.74o 3685.70 8594113 91.350 176.000 3684.84 8622.07 90.920 176.250 3684.29 8658.75 90.550 175.34o 3683.82 8692.11 90.680 175.450 3683.46 8719.51 90.490 175.750 3683.18 175.54o 176.120 176.100 177.110 177.610 8755.o5 89.940 8787.43 911410 8815.08 . 91.11o 8851.14 91.970 8883.45 91.600 Sperry-Sun Drilling Services SurveY Report for 1D-141 Your Ref: AP1.$00292296700 Job No, AKMMO0127, 3683.04 3682.66 3682.06 3681.09 3680.08 8911.72 91.660 177.510 3679.28 8946.97 92.090 177.960 3678.12 8979.07 91.790 177.730 3677.04 9006.80 91.910 177.950 3676.14 9042.48 90.490 177.240 3675.39 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eas. tings (ft) (ft) (ft) (ft) (ft) 3793.70 3487.47 S 3575.55 E 5956220.35 N 564094.11 E 3793.46 3513.68 S 3576.91 E 5956194.15 N 564095.68 E 3792.73 3552.48 S 3578.77 E 5956155.36 N 564097.85 E 3791.93 3587.11S 3580.32 E 5956120.75 N 564099.68 E 3791.21 3618.32 S 3581.74 E 5956089.56 N 564101.35 E 3790.50 3648.37 S 3583.29 E 5956059.52 N 564103.14 E 3789.56 3682.93 S 3585.22 E 5956024.97 N 564105.36 E 3788.75 3715.39 S 3586.95 E 5955992.52 N 564107.35 E 3787.95 3743.74 S 3588.43 E' 5955964.19 N 564109.06 E 3786.75 3779.15 $ 3590.35 E 5955928.79 N 564111.26 E 3785.89 3811.24 S 3592.39 E 5955896.72 N 564113.55 E 3785.34 3839.12 S 3594.27E 5955868.86 N 564115.66 E 3784.87 3875.69 $ 3596.96 E 5955832.31N 564118.65 E 3784.51 3908.94 S 3599.64 E 5955799.08 N 564121.59 E 3784.23 3936.26 S 3601.74 E 5955771.78 N 564123.91 E 3784.09 3783.71 3783.11 3782.14 3781.13 3780.33 3779.17 3778.09 3777.19 3776.44 3971.70 $ 3604.44 E 5955736.37 N 564126.90 E 4003.99 S 3606.80 E 5955704.10 N 564129.51 E 4031.57 $ 3608.67E 5955676.53 N 564131.61E 4067.55 S 3610.81E 5955640.57 N 564134.03 E 4099.81S 3612.29 E 5955608.32 N 564135.78 E 4128.04 S 3613.50 E 5955580.10 N 564137.21 E 4163.25 S 3614.89 E 5955544.91N 564138.89 E 4195.31S 3616.09 E 5955512.86 N 564140.35 E 4223.00 $ 3617.14 E 5955485.17 N 564141.62 E 4258.64 S 3618.64 E 5955449.55 N 564143.40 E Dogleg Rate (°/lOOft) 2.42 2.46 1.97 0.81 0.64 2.86 1.29 1.91 3.72 1.53 2.57 1.78 2.68 0.51 1.30 1.66 4.88 1.09 3.68 1.92 0,41 1.77 1.18 0.90 4.45 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4942.o7 4963.72 4995.68 5024.13 5049.79 5074.61 5103.24 5130.09 5153.51 5182.81 5209.54 5232.83 5263.53 5291.57 5314.55 5344.35 5371.43 5394.48 5424.37 5450.90 5474.07 5502.88 5529.09 5551.72 5580.95 Continued... DrillQuest 2,00,02 12 October, 2000 - 12:19 - 4 - Sperry-Sun Drilling Services Survey Report for 1Do 141 Your Ref: API-500292296700 Job No. AKMMO0127, North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (~t) (~t) (~t) (~t) (~t) 9074.56 89.750 176.610 3675.33 3776.38 4290.68 S 3620.36 E 9102.30 89.450 176.330 3675.52 3776.57 4318.36 S 3622.07 E 9135.75 88.810 176.250 3676.03 3777.08 4351.74 $ 3624.23 E 9170.72 88.720 176.600 3676.78 3777.83 4386.63 S 3626.41 E 9198.46 89.080 177.450 3677.31 3778.36 4414.33 S 3627.85 E 9231.18 88.900 176.950 3677.89 3778.94 4447.00 S 3629.45 E 9266.24 91.370 178.890 3677.81 3778.86 4482.04 S 3630.72 E 9294.79 91.910 178.500 3676.99 3778.04 4510.57 S 3631.37 E 9327.30 92.780 178.710 3675.66 3776.71 4543.04 S 3632.16 E 9363.39 90.480 179.070 3674.63 3775.68 4579.11 S 3632.86 E 9390.83 90.120 178.960 3674.49 3775.54 4606.54 S 3633.33 E 9433.43 89.140 178.630 3674.77 3775.82 4649.13 S 3634.23 E 9474.09 88.520 178.250 3675.60 3776.65 4689.77 S 3635.33 E 9550.00 88.520 178.250 3677.56 3778.61 4765.62 $ 3637.65 E Global Coordinates Northings Ea.stings (ft) (ft) 5955417.53 N 564145.38 E 5955389.86 N 564147.31 E 5955356.50 N 564149.74 E 5955321.62 N 564152.21 E 5955293.94 N 564153.87 E 5955261.28 N 564155.73 E 5955226.26 N 564157.28 E 5955197.73 N 564158.16 E 5955165.27 N 564159.21 E 5955129.21 N 564160.20 E 5955101.78 N 564160.90 E 5955059.20 N 564162.13 E 5955018.57 N 564163.57 E 5954942.74 N 564166.50 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The DOgleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an AzimUth of 142,610° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9550.00ft., The Bottom Hole Displacement is 5995.30ft., in the Direction of 142,645° (True). Dogleg Rate (°/100ft) 3.03 1.48 1.93 1.03 3.33 1.62 8.96 2.33 2.75 6.45 1.37 2.43 1.79 0.00 Alaska State Plane 4 Kuperuk 1D Vertical Section Comment 5607.45 5630.48 5658.31 5687.36 571o.24 5737.17 5765.78 5788.84 5815.12 5844.20 5866.29 5900.67 5933.63 5995.30 Projected Survey Continued... 12 October, 2000 - 12:19 . $. DrillQuest 2.00.02 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 1D-141 Your Ref: AP1,$00292296700 Job No, AKMMO0127, Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings . (fi) (fi) (ft) 6603.21 3829.24 1905.39 S 4060.53 E 6630.00. 3827.15 1931.99 S 4058.14 E 9550.00 3778.61 4765.62 S 3637.65 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (fi) (fi) Vertical Depth (ft) 0.00 0.00 671.01 670.46 671.01 670.46 6410.83 3828.86 6410.83 . 3828.86 9550.00 3778.61 Survey Tool Description AK-1 BP_HG AK-6 BP_IFR:AK MWD Magnetic Dr#/Quest 2.00.02 12 October, 2000 - 12:19 -6- 12-Oct-00 Phillips Alaska, Inc. Sharon AIIsup-Dmke, ATO 12 Kuparuk Development Drilling 700 G Street Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-141PB1 Dear Sharon AIIsup-Drake: Enclosed is one survey hard copy. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 6,902.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) North Slope Alaska AlaSka State Plane 4 Kuparuk 1D 1D.141PB1 Job No. AKMMO0127, SURVEY REPORT 12 October, 2000 Your Reft API.500292296770 Surface Coordinates: 5959678.92 N, 560490.60 E (70° 18' 01.4558" N, 210° 29' 23.7094" E) Kelly Bushing: 101.05ft above Mean Sea Level ORII--I. INO A HIIIIbunon Core.ny Survey Ref: svy9316 North Slope Alaska Measured Depth {ft) Incl. Azim. 0.0o 0.0o0 0.000 95.0o 0.100 330.500 19o.0o 0.300 315.400 285.00 0.300 25.100 308.00 0.300 303.600 338.00 0.300 303.000 38o.o0 o.000 o.00o 404.0o 0.400 346.800 450.00 0.400 31.600 483.00 1.900 38.600 520.00 1.100 32.000 539.00 1.200 35.200 577.00 3.100 111.900 636.00 6.400 116.600 671.01 8.310 120.170 704.17 8.450 119.15o 737.75 9.270 116.770 767.02 10.620 117.250 800.89 11.840 '1i6.o80 833.21 13.990 112.150 863.!6 17.200 110.68o 898.18 20.110 109.710 930.36 20.540 110.980 960.44 21.520 110.46o 994.99 23.240 111.690 Sperry-Sun Drilling Services Survey Report for 1D-141PB1 Your Ref: API-500292296770 Job No. AKMMO0127, Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (~) (~) (~) (~) -101.05 0.00 0.00 N 0.00 E '-6.05 95.00 0.07N 0.04W 88.95 190.00 0.32 N 0.26W 183.95 285.00 0.72 N 0.33W 206.95 308.00 0.81N 0.35W 236.95 338.00 0.90 N 0.48W 278.95 380.00 0.96 N 0.57W 302.95 404.00 1.04N 0.59W 348.95 450.00 1.33 N 0.55W 381.94 482.99 1.86 N 0.14W 418.93 519.98 2.64N 0.43 E 437.92 538.97 2.96 N 0.64E 475.90 576.95 2,90 N 1.82 E 534.69 635.74 0.83 N 6.24 E 569.41 670.46 1.32 S 10.18 E 602.21 635.39 664.22 697.44 728.95 757.79 790.97 821.14 849.22 881.17 703.26 736.44 765.27 798.49 830.00 858.84 892.02 922.19 950.27 982.22 3.71 $ 14.38 E 6.13 S 18.94 E 8.42 S 23.45 E 11.38 S 29.34 E 14.31 S 35.94 E 17.24 S 43.44E 21.10 S 53.95 E 24.99 $ 64.43 E 28.81S 74.53 E 33.54 S 86.80 E Global Coordinates Northings Eas, tings (ft) (ft) 5959678.92 N 560490.60 E 5959678.99 N 560490.56 E 5959679.24 N 560490.34 E 5959679.64N 560490.27 E 5959679.73N 560490.24 E 5959679.81 N 560490.11 E 5959679.87 N 560490.02 E 5959679.95 N 560490.00 E 5959680.25 N 560490.04 E 5959680.78 N 560490.44 E 5959681.56 N 560491.01 E 5959681.88 N 560491.21 E 5959681.83 N 560492.40 E 5959679.80 N 560496.84 E 5959677.69 N 560500.79 E 5959675.33 N 560505.00 E 5959672.95 N 560509.59 E 5959670.69 N 560514.11E 5959667.78 N 560520.03 E 5959664.90 N 560526.66 E 5959662.03N 560534.18 E 5959658.25 N 560544.72 E 5959654.45 N 560555.23 E 5959650.72 N 560565.36 E 5959646.08 N 560577.67E Dogleg Rate (°/lOOfl) 0.11 0.22 0.36 1.70 0.01 0.71 1.67 0.66 4.56 2.21 0.63 8.04 5.63 5.61 0.62 2.67 4.62 3.66 7.18 10.80 8.36 1.91 3.32 5.16 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 0.00 Gyro Surveys AK-1 BP_HG -0.08 -0.41 -0.77 -0.86 -1.01 -1.11 -1.19 -1.39 -1.56 -1.84 -1.96 -1.20 3.13 7.22 11.67 16.37 20.93 26.86 33.20 40.08 49.53 58.98 68.14 79.36 AK-6 BP_IFR-AK Continued... 12 October, 2000 - 11:57 - 2 - DrillQuest 2.00.02 North Slope Alaska Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) 1026,90 24.130 112.220 910,39 1011,44 1056,86 24.700 111.430 937,67 1038,72 1153.22 26.430 113,690 1024,59 1125,64 1249.45 30.340 115,140 1109,24 1210,29 1345.27 33.440 116,080 1190,59 1291,64 1271,51 1351,61 1428,45 1500,33 1569,98 1442,22 33,400 1539,43 35.630 1636,24 39,280 1731.64 42.920 1827,70 44.120 114,530 111,320 112,000 113,310 113,980 1372,56 1452,66 1529,50 1601,38 1671,03 1923,77 44.490 113.150 1638,73 1739,78 2019,90 48,000 116,140 1705,21 1806.26 2116,35 51,410 113,670 1767,58 1868,63 2212,69 55,850 113,160 1824,70 1925,75 2308,36 59.530 111,660 1875,83 1976,88 2403.48 60.150 2498,89 60;670 2594,95 60,880 2690,44 61,360 2786,04 60,580 107.250 106,350 106,690 107,310 104,620 Survey Report for 1D-141PBI Your Ref: API-500292296770 Job No. AKMMO0127, 1923,63 1970,75 2017,65 2063,77 2110,17 2024,68 2071,80 2118,70 2164,82 2211,22 2882,34 59.470 103,820 2158,28 2259,33 2978.59 58.760 103,500 2207,69 2308,74 3074,18 57,960 105,900 2257,84 2358,89 3170,48 59,650 105,810 2307,71 2408,76 3266,65 58,120 106,870 2357,41 2458,46 Local Coordinates Northings Eastings (ft) 38,33 $ 98.69 E 42,94 S 110.19 E 58,91 S 148,57 E 77,85 S 190,20 E 99,74 S 235.83 E 122,56 S 284,10 E 143,97 S 334,83 E 165,71S 389,53 E 189,89 $ 447,38 E 216,42 S 507,97 E 243,24 S 569.48 E 272,24 S 632,54 E 303,17 S 699,27 E 333,98 S . 770,44 E 364,78 S 845,18 E 392,15 $ 922,70 E 416,13 S 1002,13 E 439,97 S 1082,50 E 464,41S 1162,46 E 487,41S 1242,81E 507,90 S 1323,67 E 527,41 $ 1403,93E 548,05 S 1482,64E 570,56 S 1561,88 E 593,71S 1640,89 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 5959641,38 N 560589,59 E 5959636,87N 560601,13 E 5959621,21N 560639,64 E 5959602,61N 560681,42 E 5959581,08 N 560727,23 E 5959558,65 N 560775,68 E 5959537,65 N 560826,58 E 5959516,35N 560881,45 E 5959492,64N 560939.50 E 5959466,60 N 561000,30 E 5959440,27 N 561062.02 E 5959411,78 N 561125,32 E 5959381,39 N 561192.28 E 5959351,15 N 561263.70 E 5959320,96 N 561338.69 E 5959294,21N 561416.43 E 5959270,87 N 561496,04 E 5959247,68 N 561576,60 E 5959223,88 N 561656.76 E 5959201,53 N 561737,29 E 5959181,69 N 561818.32 E 5959162,83 N 561898.73 E 5959142,82 N 561977.61 E 5959120,95 N 562057,03 E 5959098,44 N 562136,22 E 2.87 2.19 2,06 4.13 3.28 0,88 2.96 3.79 3.92 1,34 0,72 4.29 4.04 4.63 4.07 4,06 0.98 0.38 0.76 2.59 1.36 0.79 2,30 1.76 1.85 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 90.38 101.02 137,02 177,35 222.45 269,90 317.71 368,20 422,54 48o,41 539,07 600,40 665,50 733,19 803,05 871.87 939,15 1006.90 1074,87 1141.94 1207.32 1271.56 1335,76 1401,75 1468,13 Continued,,. 12 October, 2000 - 11:57 -3- DrillQuest ZOO,02 North Slope Alaska Measured ' Depth (fi) Incl. Azim. 3363.44 60.560 106.900 3459.45 59.320 106.84o 3555.55 59.390 107.38o 3652.40 59.400 107.480 3748.20 60.670 106.530 3844.68 61,020 106.300 3940.99 60.980 105,980 4037.63 61.100 106.620 4134.00 59.870 106.080 4229.96 59.610 105,600 4325.77 60.460 104.930 4421.44 58.750 106.660 4518.06 58.540 106.720 4614.13 58.800 106.320 4709.00 58.690 107.400 4805.98 59.020 106.890 4901.43 58.610 107.640 4997.16 59.200 105.810 5094.55 59.330 105.410 5189.93 59.010 105.240 5283.77 58.340 105.580 5379.71 59.750 104.290 5475.74 59.500 104.230 5572,42 '61.550 108.650 5606.61 63.130 110.690 Sperry-Sun Drilling Services Survey Report for 1D-141PB1 Your Ref: AP1.$00292296770 Job No, AKMMO0127, Sub-Sea Depth (fi) 2406.76 2454.85 2503.84 2553.15 2600.99 2648.00 2694.69 2741.48 2788.96 2837.32 2885.17 2933.58 2983.85 3033.80 3083.03 3133.19 3182.61 3232.05 3281.83 3330.71 3379.50 3428.84 3477.40 3524.99 3540.86 Vertical Depth (~) 2507.81 2555.90 2604.89 2654.20 2702.04 2749~05 2795.74 2842.53 2890.01 2938.37 2986.22 3034.63 3084.90 3134.85 3184.08 3234.24 3283.66 3333,10 3382.88 3431,76 3480,55 3529,89 3578.45 3626.04 3641.91 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) 617.90 S 642.01S 666.33 S 691.30 S 715.57 S 739.38 S 762.80 S 786.53 S 810.14 S 832.76 $ 854.61S 877.06 S 900.76 S 924.09 S 947.61S 972.08 S 996.31 $ 1019.90 S 1042.43 S 1064.07S 1085.37 S 1106.57 $ 1126.98 S 1150.82 S 1161.01S 1720.55 E 5959074.90 N 1800.07E 5959051.42N 1879.09 E 5959027.73 N 1958.62E 5959003.41N 2037.99 E 5958979.78 N 562216.07 562295.78 562375.00 562454.72 562534.28 2118.81 E 5958956.62N 562615.29 E 2199.72 E 5958933.86 N 562696.39 E 2280.88 E 5958910.78 N 562777.74 E 2361.35 E 5958887.82 N 562858.39 E 2441.09 E 5958865.84 N 562938.31 E 2521.16 E 5958844.63 N 2600.56 E 5958822.82 N 2679.59 E 5958799.76 N 2758.27 E 5958777.06 N 2835.88 E 5958754.17 N 2915.20 E 5958730.34 N 2993.17 E 5958706.73 N 3071.68 E 5958683.78 N. 3152.30E 5958661.91N 3231.29 E 5958640.90 N 3308.57 E 5958620.22 N 3388.06 E 5958599.66 N 3468.36 E 5958579.90 N 3549.04E 5958556.71 N 3577.55 E 5958546.75 N 563018.56 563098.14 563177.36 563256.22 563334.02 563413.53 563491.7O 563570.39 563651.19 563730.35 563807.80 563887.46 563967.92 564048.79 564077.38 Dogleg Rate (°/lOOft) 2.52 1.29 0.49 0.09 1.58 0.42 0.29 0.59 1.37 0.51 1.07 2.37 0.22 0.45 0.98 0.56 0.80 1.75 0.38 0.37 0.78 1.87 0.27 4.51 7.02 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1535.71 1603.16 1670.47 1738.60 18o6.o8 1874.07 1941.81 2009.95 2077.57 2143.97 2209.95 2276.0o 2342.82 2409.13 2474.95 2542.55 26o9.16 2675.57 2742.42 2807.58 2871.43 2936.55 3001.52 3O69.46 3094.87 Continued... 12 October, 2000 - 11:57 -4- DrillQuest 2.00.02 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for 1D-141PB1 Your Ref: API.500292296770 Job No. AKMMO0127, 5638.44 64.370 109.490 3554.94 3655.99 5668.35' 65.870 112.820 3567.53 3668.58 5702.11 66.060 114.100 3581.28 3682.33 5733.01 65.950 115.910 3593.84 3694.89 5763.92 65.490 116.790 3606.55 3707.60 5797.24 65.420 120.300 3620.40 3721.45 5831.65 67.960 123.430 3634.02 3735.07 5860.54 70.290 124.730 3644.31 3745.36 5894.18 72.560 126.140 3655.03 3756.08 5922.90 73.290 128.160 3663.46 3764.51 5950.81 74.410 130.960 3671.22 3772.27 5982.00 76.480 133.450 3679.06 3780.11 6014.00 78.370 136.280 3686.03 3787.08 6044.00 80.380 139.190 3691.56 3792.61 6076.11 82.540 142.250 3696.33 3797.38 6107.10 84.200 146.790 3699.91 3800.96 6134.63 84.490 149.620 3702.63 3803.68 6167.35 85.310 153.780 3705.54 3806.59 6199.98 85.640 157.100 3708.11 3809.16 6229.75 84.410 161.010 3710.69 3811.74 6262.58 84.130 164.240 3713.97 3815.02 6298.26 83.240 !67.450 3717.90 3818.95 6325.90 83.380 170.480 3721.12 3822.17 6347.23 83.780 171.000 3723.50 3824.55 6353.63 84.310 171.490 3724.17 3825.22 Local Coordinates Northings Eastings (ft) (ft) 1170.82 S 3604.36 E 1180.61S 3629.66 E 1192.89 S 3657.94 E 1204.82 S 3683.52 E 1217.32S 3708.77 E 1231.80 S 3735.39 E 1248.49 S 3762.22 E 1263.62S 3784.57 E 1282.10 S 3810.55 E 1298.68S 3832.43 E 1315.76 S 3853.09 E 1336.04 S 3875.45 E 1358.07 S 3897.58 E 1379.89 S 3917.41 E 1404.46 S 3937.51 E 1429.52 $ 3955.37 E 1452.81S 3969.80 E 1481.49 S 3985.25 E 1511.08 S 3998.76 E 1538.77 S 4009.36 E 1569.94 S ~4019.12 E 1604.32 S 4027.79 E 1631.26 S 4033.04 E 1652.18 S 4036.45 E 1658.47S 4037.42 E Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°llOOft) 5958537.16 N 564104.27 E 5958527.57 N 564129.64 E 5958515.52 N 564158.02 E 5958503.79 N 564183.70 E 5958491.49 N 564209.05 E 5958477.23 N 564235.79 E 5958460.76 N 564262.75 E 5958445.81 N 564285.22 E 5958427.53 N 564311.35 E 5958411.13 N 564333.36 E 5958394.22 N 564354.16 E 5958374.13 N 564376.68 E 5958352.27N 564398.99 E 5958330.61N 564418.99 E 5958306.20 N 564439.29 E 5958281.29 N 564457.35 E 5958258.12 N 564471.97 E 5958229.56 N 564487.64 E 5958200.08 N 564501.40 E 5958172.48 N 564512.22 E 5958141.39 N 564522.23 E 5958107.08 N 564531.17 E 5958080.18 N 564536.65 E 5958059.29 N 564540.22 E 5958053.00 N 564541.24 E 5.16 11.28 3.51 5.36 2.99 9.58 11.15 9.10 7.83 7.19 10.44 10.19 10.46 11.65 11.58 15.51 10.28 12.91 10.19 13.72 9.83 9.28 10.90 3.06 11.25 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3118.94 3142.08 3169.01 3194.02 3219.29 3246.96 3276.51 3302.1o 3332.56 3359.02 3385.14 3414.83 3445.77 3475.14 3506.87 3537.63 3564.89 3597.07 3628.78 3657.22 3687.91 3720.49 3745.08 3763.78 3769.36 Continued... 12 October, 2000 - 11:57 -5- DrfllQuest 2.00.02 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 1D-141PB1 Your Ref: API-500292296770 Job No. AKMMO0127,' Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (fi) (ft) (fi) 6410.83 88.400 166.410 3727.81 3828.86 1714.47 S 4048.36E 6446.30 90.740 169.740 3728.07 3829.12 1749.16 S 4055.69 E 6478.24 88.460 173.010 3728.29 3829.34 1780.73 S 4060.48 E 6506.16 88.460 176.360 3729.05 3830.10 1808.52 S 4063.07 E 6541.75 89.880 180.400 3729.56 3830.61 1844.08 S 4064.07 E 6573.78 90.680 183.870 3729.40 3830.45 1876.09 S 4062.88 E 6603.21 94.060 185.280 3728.19 3829.24 1905.39S 4060.53 E 6638.55 95.050 184.910 3725.38 3826.43 1940.48 S 4057.40 E 6670.89 95.240 184.990 3722.48 3823.53 1972.57 S 4054.63E 6699.20 95.920 185.390 3719.73 3820.78 2000.63 $ 4052.08 E Global Coordinates 6734.43 95.730 184.930 3716.15 3817.20 2035.54 S 4048.92 E 6766.56 95.170 184.570 3713.10 3814.15 2067.41S 4046.28 E 6795.42 94.810 184.670 3710.59 3811.64 2096.07 S 4043.96 E 6826.43 94.250 184.470 3708.14 3809.19 2126.88 S 4041.50 E 6902.00 94.250 184.470 3702.54 3803.59 2202.02 S 4035.62E Northings Eastings (ft) (ft) 5957997.10 N 564552.63 E 5957962.46N 564560.24 E 5957930.93N 564565.28 E 5957903.17 N 564568.09 E 5957867.61 N 564569.38 E 5957835.60N 564568.45 E 5957806.28 N 564566.34E 5957771.16 N 564563.49 E 5957739.05 N 564560.97 E 5957710.97N 564558.65 E 5957676.04 N 564555.78 E 5957644.15 N 564553.39 E 5957615.47 N 564551.30 E 5957584.64N 564549.09 E 5957509.46 N 564543.82 E All data is in feet Unless otherwise Stated. Directions and coordinates are relative to TrUe North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 142.610° (True). Based upOn Minimum Curvature type calculations, at a Measured Depth of 6902.00ft., The Bottom Hole Displacement is 4597.30ft., in the Direction of 118.619° (True). Dogleg Rate (°/lOOft) 11.39 11.47 12.48 11.99 12.03 11.12 12.44 2.99 0.64 2.78 1.41 2.07 1.29 1.92 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 382o.5o 3852.51 3880.50 3904.15 3933.o2 3957.72 3979.58 4005.56 4029.37 4o5O. ll 4075.93 4099.65 4121.Ol 4144.oo 4200.13 MWD Magnetic Projected Survey Continued... 12 October, 2000 - 11:57 - 6 - DrillQuest 2.00.02 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 1D.141PB1 Your Ref: AP1.$00292296770 Job No. AKMMO0127, Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (fi) 0.00 0.00 0.00 N 0.00 E 6902.00 3803.59 2202.02 S 4035.62 E Comment Gyro Surveys Projected Survey Survey tool program · From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 671.01 670.46 6410.83 3828.86 To Measured Depth (fi) 671.01 6410.83 6902.00 Ve~ical Depth (fi) 670.46 3828.86 3803.59 surVey Tool Description AK-1 BP_HG AK-6 BP_IFR-AK MWD Magnetic .7- DriflQuest 2. 00. 02 12 October, 2000 - 11:57 12-Oct-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-141 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,603.21 'MD 6,630.00' MD 9,550.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) · RECEIVED OCT 17 MEMORANDUM TO: Dan Seamount Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 17,2000 SUBJECT: THRU: Blair Wondzell P.I. Supervisor FROM: Jeff Jone~(~°---~ J. Petroleum Inspector NON- CONFIDENTIAL Blowout Preventer Test Nordic 3 Phillips Alaska Inc. 1 D Pad 1D-141 200-112 KRF/KRU Operator Rep.: Don Micke¥ Contractor Rep.: Lance Johnson Op. phone: 659-7872 Rig phone: 659-7653 Op. e-mail: nordic3companyman@ppco.com Rig e-mail: nordic3toolpusher@ppco.com Test Pressures Rams: 250/3000 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P Standing Order: P BOP STACK: Annular: 250/3000 Choke: 25013000 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 1 P Meth Gas Detector P P Inside BOP 1 F H2S Gas Detector P P Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 11" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 2 7/8xS"(v) P ..... Quantity P/F System Pressure 3050 P Lower Pipe Rams 1 4" P No. Valves 12 P After Closure 1800 P Blind Rams 1 blind P Man. Chokes 1 P 200 psi Attained 20 sec. P Choke Ln. V~ves 2 3 1/8" P Hyd. Chokes 1 P Full Pressure 2:38 P HCR Valves 1 3 1/8" P Blind Covers (All Stations): P Kill Line Valves 1 3 1/8" P N2 Bottles (avg): 4 (~ 2150 P Check Valve N/A Test's Details Sunday, September 17, 2000: I traveled to Phillips Alaska Inc.'s Kupamk River Unit, 1D Pad to witness a BOPE test on Nordic Rig #3, drilling development well 1D- 141. Nordic personnel were ready to test on my arrival and performed thc test in a safe and proficient manner with one failure witnessed. Thc Inside BOP floor safety valve failed to hold pressure. A spare valve on lo~ation was tested and passed, and can bc used with a XO sub until a replacement valve arrives. Lan, c Johnson, Drilling Supervisor, indicated that he would have a replacement floor safety valve by tomorrow. A successful test of thc gas detection alarm system was also performed today. Summary: I witnessed a BOPE Test on Nordic Rig #3 drilling Phillips Alaska Inc.'s development well 1D-141 in thc Kupamk River Unit. Thirty-eight components were tested, with one failure witnessed. Total Test Time: 3.5 hrs. Number of failures: CC: Attachments: BOP Nordic 3 9-17-00 J J1 .xls 9/18/00 JUL-27-OO THU 02:52 PM P. P. ~/10 ALASKA OIL AND GAS CO$SlllVATIOi[ COIlNISISlOa[ sOOt POt~UPlN~ txqlVE ANCHORAGE, ,RLA~KA 99,~0 ! ~N 192 PNOr¢; C907) 279-14~3 FRX; C~) 2Z6-TM2. James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box ]00360 And~orage, AK 99510-0360 Re: Kupamk River Unit ID-141 Phillips Alaska, Inc. Permit No; 200-112 Sur.Loc; 12'FSL, 595'FF, I.,, Sec. 14, TIIN, RI0E, UM Btmhole Loc. 532'FSL, 2243'FEL, Sec. 24, TI IN, R10E, UM Dear Mr, Trantham: Enclosed is the appruved application for permit to drill the above referenced well, The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize oondut;ting drilling operations until ali other required permitting dctorminations are made. BIowont prevention equipment (BOPE) must be tested in accordance with 20 AAC 2,5 03 5. Sutticient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of' BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 65.9-]607, ~~,~,~Sincerely, ~ Daniel T. Seamount, Jr. Commissioner 'BY ORDER OF 'i'ltE COMMISSION DATED this '~.? '/~ day of July, 2000 dlflEaclosure$ .LTc~l~Mlrlenl of Fish & O~, Habitat S~tion w/o erect. D~afln~t ofE~lronm~utl Con~ation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill r~ Reddll r'l '1 lb. Type ofwell. 'Exploratory ri Stratigraphic Test ~'1 Development Oil J=~J Re-entry D Deepen DI Service BI Development Gas D Single Zone r~ Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 30 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 12' FSL, 595' FEL, Sec. 14, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1648' FNL, 1917' FEL, Sec. 24, T11N, R10E, UM 1D-141 #U-630610 At total depth 9. Approximate spud date Amount 532' FSL, 2243' FEL, Sec. 24 T11 N, R10E, UM August 1,2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2..~-'~(01, ~,,~532'@ TD feetI 1D-03 11.2' @ 500' feet 2560 9459'MD/3777'TVD 16. To lie ~ompleted~" for deviated wells 17. Anticipated pressure (see 20 AAC 2,5.035 (e)(2)) Kickoff depth: 300' MD Maximum hole angle 92 o Maximum surface 1339 psig At total depth (I'VD) 1760 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casincj Weight Grade Coupling Len~lth MD TVD MD TVD (include sta~le data) 20" 16" 62.5# L-80 BTC 80' 30' 30' 110' 110' Pre-set 12.25" 10.75" 40.5# J-55 BTC 470' 30' 30' 500' 500' 130 sx ArtiCRETE 9.875" 7.625"x7" .29.7#/26~ L-80 BTC Mod 6291' 30' 30' 6321' 3826' 540 sx ASLite & 490 sx Class G 6" 4.5" x 4" 12.6#/9.5~ L-80 HSLHT 3289' 6170' 3818' 9459' 3777' screen 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface IntermediateRECEIVED LPirn°etct.°n 0 R IGINAL -- JUL t000 Perforationdepth: measured~l~l~[a 0i';, & Gas Cons. C~mmi~i0n Anchorage true vertical 20. Attachments Filing fee J~J Property Plat r"J BoP Sketch r~J Diverter Sketch J~ Drilling program Drilling flu'::l program J~] Time vs depth plot DRefraction analysis D Seabed report J-'J 20 AAO 25.050 requirements 21. I hereby cer ify that the foregoing is true and correct to the best of my knowledge QueStions? Call Mark Chambers 265-131~. ~S Title: Drilling Englneering Supervisor Date1 9 J Signed ~J~ rnes Trantham Pm.n~red bv Sharon AIl.~un-I')r~k~ Commission Use Onl) Permit Number 2.,~~ --//~, APl number ~ Approvaldate .~ I See cover letter 5o- (~)2~? '--,~-'~z2 7-- ¢~_f~(J~/'i~)0 Ifor other requirements Conditions of approval Samples required B Yes 1~ No Mud Icg required D Yes [~ No Hydrogen sulfidemeasures D Yes ~ No Directional surveyrequired ~ Yes D No Required working pressure for BOPE E]2M; [~ SM; [] 5M; D lOM;D Approved by (')~I('~INAi ~1('~1~,~.~ '~ ~ Commissioner the oommission Date D Taylor Seamount Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY RECEIVED July 18, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 JUL 2 0 2000 Alaska 0~; & Gas Cons. Commission Anchorage Re: Application for Permit to Drill: West Sak 1 D-141 Surface Location: Target Location: Bottom Hole Location: 12' FSL, 595' FEL, Sec 14, T11 N, R10E 1648' FNL, 1917' FEL, Sec. 24, T11 N, R10E 532' FSL, 2243' FEL, Sec. 24, T11 N, R10E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak B-Sand in the vicinity of 1D Pad. The well is designated as a horizontal producer using a 7-5/8" x 7" tapered casing string. A 4-1/2" x 4" Production Liner will be run and the well will be completed with 4-1/2" tubing and ESP. The well will be drilled and completed using Nordic Rig 3. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing program is attached as per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that Phillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, Phillips considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are Phillips designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is August 01, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Randy Thomas at 265-6830 or James Trantham at 265-6434. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: cc: KRU 1 D-141 Well File Randy Thomas James Trantham RECEIVED - . ,JUL 2 0 2000 Alaska O~ & Gas Cons. Commission Anchorage Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1D-141 Multilateral Producer (Main Well Bore) Well Plan Summary RECEIVED JUL 2 0 2000 Alaska Or~ & ~as Cons. Commission Surface Location: 12' FSL 595' FEL Sec 14 T11N R10E B-Sand Lateral - Target :t 1648' FNL 1917' FEL Sec 24 T11N R10E B-Sand Lateral - TD 532' FSL 2243' FEL Sec 24 TllN R10E I AFE Number: I I Ieig: I Nordic Estimated Start Date: 8101100 I I Operating days: I 37 I I I I I I I I KBE: I 30' I Type of Well I Producer I Well Design I Formation Markers: (all depths adjusted for Nordic RKB) Horizontal Multilateral- Pre-Packed Screen Formation Tops True Vertical True Vertical Measured Hole Angle Depth (SS) Depth (RKB) Depth (RKB) Degrees Primary Wellbore and B-Sand Lateral Base Permafrost 1535 1636 1765 43 Ucjnu C-Sand 2996 3097 4527 60 Ugnu B-Sand 3270 3371 5070 60 Ugnu A-Sand 3359 3460 5246 60 K-13 Shale 3487 3588 5499 60 West Sak D-Sand 3652 3753 5858 70 West Sak C-Shale 3676 3777 5938 75 West Sak B-Sand 3718 3819 6179 84 West Sak B-Sand Heel 3725 3826 6321 90 West Sak B-Sand Toe TD 3676 3777 9459 90 Casing/Tubing Program: (all depths adjusted for Nordic RKB) Hole Size Csg/Tbg Wt/Ft Grade Conn. Length Top Btm OD MD/TVD MD/I'VD 12-1/4" 10-3/4" 40.5 ]-55 BTC 500' Surface 500'/500' 9-7/8" 7-5/8" x 7" 29.7 / L-80 BTC - Mod 6,321' Surface 6,321' / 3,826' 26 6" Lower 4" Screen 9.5 1_-80 HSLHT 3,289' 6,170'/3,818' 9,459'/3,777' Lat. Logging/Formation Evaluation Program: IOpen Hole Cased Hole Logs: MWD/GR/RES/PWD (Pressure while Drilling) None Drilling Fluid TyDe 12-1/4" x 9-7/8" Surface Hole will be drilled wrch a standard Bentonite Slurry. 6" Production Hole will be drilled wrch a 6% KCL Drill'N Fluid. Drilling Fluid ProDerties: Spud to 10-3/4" Casing Point (+/- 500): Initial Final Density Viscosity YP PV 8.5 - 8.8 250 - 300 40 - 60 7 - 14 8.5 - 8.8 250 - 300 40 - 60 7 - 14 10-3/4" Casing Point - Base of Permafrost (+/- 1782): Initial Final Density Viscosity YP PV 9.4 - 9.6* 75 - 150 18 - 25 15 - 35 9.4 - 9.6* 75 - 150 18 - 25 15 - 35 Base of Permafrost - 7" x 7-5/8" Surface Casing Point (+/- 6330): Density Viscosity YP PV Initial 9.4 - 9.6* 75 - 150 18 - 25 15 - 35 Final 9.4 - 9.6* 75 - 150 18 - 25 15 - 35 * 9.8 ppg if hydrates are found Production Interval (B-Sand Horizontal Lateral): Density Viscosity. 8.9 - 8.9+ 40 - 55 HTHP Chlorides < 10 27 - 32K Y_._~P P_.~_V 22 - 27 7 - 13 LGS 12 ppb (drilled LGS) tau0 4-7 10 S Gel 20 - 28 20 - 28 10 S Gel 10 - 25 10 - 25 10 S Gel 10 - 25 10 - 25 8.0 - 8.5 API Filtrate 8 - 15 8 - 15 API Filtrate 5-7 5-7 API Filtrate 5-7 5-7 API Filtrate 4-6 Drillinq Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: RECE,VED JUL 2 0 2000 Alaska Oi~ & Gas Cons. Commission M~omge Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. MASP (Maximum Anticioated Surface Pressure): Only one string of surface casing is planned for the West Sak 1D-141 well. Therefore, the surface hole to be drilled from surface through the West Sak Reservoir will be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSl-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/il, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.4 ppg can be predicted as a maximum mud weight required to safely drill this formation. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Calculating MASP based on the highest recorded reservoir pressure from the WSl-01 well, and assuming a gas gradient of 0.11 psi/Il from maximum TVD in the B-Sand to surface, the following MASP can be computed: MASP = (3826 ft)(0.46 - 0.11 psi/il) .= 1339 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" x 7" surface casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be'pressure tested for 30 minutes at a pressure of 1,500 psi. The 7" 26" Sperry Preformed Window has a maximum burst rating of 2,500 psi; 70 % of this burst rating is 1,750 psi. Drillina Area Risks: Drilling risks in the West Sak 1D-141 area are primarily limited to hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of the pipe, controlling drilling rates and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 9.6 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Phillips has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-141. Well Proximity Risks: The nearest existing wells to 1D-141 are listed below: Well # DePth (MD) Center-Center Allowable Deviation 1D-112 399.30' 25.61' 19.55' 1D-111 399.84' 17.50' 11.97' 1D-03 500.09' 11.21' 4.49' 1D-11 6270.53' 205.59' 25.61' Annular Pum_~ina Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-141 surface casing / production tubing annulus will be filled with diesel and / or non-freezing brine ailer running the ESP completion and prior to the drilling rig moving off of the well. RECEIVED ,JUL 2 0 2000 Alaska G*~ & Gas Cons. Commission An~omge Drill, Case and Completion Plan for West Sak 1D-141 Multilateral Producer (07/18/00) General Procedure (Primary Well Bore): 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic 3. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 500'. 4. Condition hole for casing. 5. Run and cement 10-3/4" Casing String to surface. Displace cement with mud. 6. Drill out and directionally drill 9-7/8" hole to the casing point at +/- 6,321' MD / 3,826' TVD as per directional plan. Run MWD, LWD and PWD tools as required for directional monitoring and formation data gathering. 7. Condition hole for casing. 8. Run, orient and cement 7-5/8", 29.7#, L-80, BTC Mod x 7", 26#, L-80, BTC Mod Casing String to surface. Displace cement with mud and perform stage job or top job if required. - 7-5/8" Port Collar to be installed @ +/- 1,000' TVD. - Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. - Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 9. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 10. PU 6" PDC Bit and Directional BHA. RIH to top of float equipment. 11. Pressure test casing to 1500 psi for 30 minutes. Record test results. 12. Drill out cement and approximately 20' of new hole. Perform FIT not to exceed 11 ppg EMW and record results. This establishes a maximum allowable drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 13. Directionally drill 6" hole to TD at +/- 9,459' MD / 3,777' TVD as per directional plan. 14. Circulate and condition hole to run liner. 15. Lay down MWD, LWD and PWD tools. 16. Displace mud with clean filtered brine and spot viscosified brine in open hole. 17. Perform casing clean-up including Caustic SL Wash and pickle. 18. Run 4-1/2" x 4" Liner with pre-packed screen (run liner with 2-7/8" inner wash string). 19. Land liner, set liner top packer and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screen while POOH. REOE!VED 20. Displace the well, above the liner top packer, with clean filtered brine. ,JUL 2 0 200O Alaska Oi~ & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Scale: linch = 1200ft Kuparuk 1 D 1D-141 WPs Prolxmal Data foe 1D-141 ~ v~ ~m ~ w~ ~h ~h ~ oma ~.~ 3.~ ~1~ ~.~ 59.676 107.137 ~.~ 1173.~8~.Zl E31~.~O~ ~.~ ~,~ 14~ 37~.61 1337.~ S 3~.~E 33~3 11~ ~1~ 91.8~ ~1 3~ 1~3.~ s391~ E3~3o 1o~ ~31.~91.~~t 381931 1~7.~ S38~E 391~8O~ ~.~ 91.1~ ~.3323g[831 I~S 3~.~E 3~I.93 6,~ ~.et 9~.16~ ~3~2 ~2S~S 2~2~S ~.~ ~ 0.~ ~,~l 91.239 189.0~ 3510~7 ~.63S 3~70E 4121.91 6.~ 7~,~ 91.~9 189.~3~1.76 2911.618 37~*~ E ~,~ o,~ ~3.~ 91.~1~.~ ~01.~ ~S ~7~.~ ~ ,~.1~ 6.~ 7~.~ 91.10~ 195.614 3~2 ~69.15 S 37~.21 E ~.9~ 6.~ 7~.8591.101 1~5.614 3791~ 3~8.50 S 3~3.~ E 47~.~ 0.~ ~0~4.18 91.1~ 183,~37~ 3313.63 S ~.19E 4~.01 4.~ ~81.19 ~681I~353~8~.~ 3380.~ S 3~.~E 4~3 4.~ ~35.35 ~5~ 180,~t ~.~ 413~6983~1.58E ~38 4,~ B~.~ ~).274 l~O,~l 3979.~ 4~4~33 S 3~1.53 E 55m.~34.~ ~59~1~.274 180.~1 37~.~ 475173 S 3~.~E 59~,16o,~ ~ -1200 - -2400 - .c_ o -3600 Z Eastings 2400 I 1200 I Begin Dir @ 1.50°/100ft : 300.00ft MD, 300.00ft TVD in Dir Rate @ 2.50°/100ff : 500.00ff MD 499.91ff TVD Increase in Dir Rate @ 3.50°/100ft : 706.06ff ~ID, 704.92ft TVD End Dir. Start Sail @ 42.844°: 1697.29ftMD,1586.00ftTVD Begin Dir @ 4.00°/10Oft : 1833.67ft MD, 1686.00ftTVD End Dir, Start Sail @ 59.676°: 2264.80ffMD,1954.92ffTVD 36OO I Begin Dir @ 11.000/100fl : 5652.00ft MD, 3665.07ft TVD Increase in Dir Rate @ 12.00°/100ft : 5969.37ft MD, 3784.61f1TVD 7 5/8" X 7"Casing - 6320.63MD, 3826.00TVD Dir Rate Decrease @ 10.000/100ff : 6320.62ftMD,3826.00flTVD End Dir. Start Sail @ 91.899°: 6541.40ftMD Begin Dir @ 6.00°/100ff : 6631.40fl MD End Dir, Start Sail @ 91.163°: Begin Dir @ 6.00°/100ff : 6808.61ft MD, 3815.48ff TVD End Dir, Start Bail @ 91.239°: 6996.81ffMD,3810.67ftTVD Begin Dir @ 4.00°/100ft : 7948.85ft MD, 3791.26ft TVD End Dir, Start Sail @ 90.681°: 8081.19ftMD,3788.96ftTVD I .Dri!lQuest:' -0 - -1200 ~ ~. ~/, ~ ,~ 't'~.'D. -2400 Begin Dir @ 4.00°/100fi : 8830.07ft MD, 3780.05fl TVD '~ I End Dir, Start Sail @ 90.274°: 8840.99ftMD,3779.96flTVD /Begin Dir @ 1.50°/100ft : 300.00ft MD, 300.00ft TVD I I/Increase in Dir Rate @ 2.50°/100ft : 500.O0ft MD, 499.91ft TVD / I/ -4800 - -4800 Total Depth 9459 41ffMD 3777 00ftTVD ] [//Increase in Dir Rate @ 3.50°/100ft : 706.06ft MD 704.92ft TVD : ' ' ' ! \ ° / \ Scale: linch = 1200ft Reference is True North 12oo -7 \,400.00 Eastings / "~ /End Dir, Start Sail @ 42.844°: 1697.29ftMD,1586.00ftTVD / ~ / /Begin Dir@ 4.00°/100ft :1833.67ffMD, 1686.00ftTVD ............................... ~ .......................................................................................................................................... ,,:,.,-,,;, ...... ,/,,o,,, DI~"P[:= i~/Ei~ ! '~_lOO.~nd Dir, Start Sail @ 59.676": 2264.80ftMD,1954.92ftTVD 2400 IUL 2 0 2000 '500 O0 tk,I,~ · ~ ~ ~ , ~ '~ Alaska O, & Gas Cuns. commmmon II ~,~oo ~ Anchorage 0 ................... ~ ................................................... Ugn,..: Sands · ~ ~00.00 Begin Dir @ 11.00°/100ft : 5652.00ft MD. 3665.07ftTVD .......... ~.eo Increase in Dir Rate @ 12.00°/100ft : 5969.37ff MD, 3784.61ft TVD '~ 3600 .............................. ~.~ z---'r-~s~:~. st Sak C Shale I I I 0 1200 2400 3600 Scale: linch = 1200ff Vertical Section Section Azimuth: 142.613° (True North) ¢2. ,, .~,'c~'~'''_ ~ ',~.'~"~,~ ~o~j~%"~ ~1.~%'~., ~ ¢.~,-,' @ e?.~6~,~ ~ - ' ~-,, o~;%~ =° ,~e~'~, 0~' ~"~'~ ~ - ~ ~'Z,.~.? u~?~,~,~,y,~ o~,~_~_~ ~o~ 5~ /~T2~9 ~ ' .~ .~.: .................................. II .......................... ~ ............ ~ ...... ~"-7~ ~m~ -~[~ ~' ......... 7-7" .......... .~'~'~7 ........ ~Wes~ Sak C Shale ~ ............... ~ ~'~ ~' ....... .:~,~"¢i,~m 7;'~7>~ 4zs,/.,~ :~< ;~;~'~.:~ ~? -', ..... ,~es~ ~ ~ Sand )fD.~.?4~ '?'2 .,, ~.~.l.(/0 TV.O. 274~ ~fi S'~ ~ ?02 77 ~ Total Depth: 9459.41flMD,3777.00ff~D .~ .... m I I I I I i 3800 4200 4600 5000 5400 5800 Scale: linch = 400ff Vertical Section Section Azimuth: 142.613° lTrue No~h) North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-141 WPs- 1D-141 WP7 Revised: 18 July, 2000 PROPOSAL REPORT 18 July, 2000 Surface Coordinates: 5959678.83 N, 560490.62 E (70° 18' 01.4549" N, Kelly Bushing: 101.0Oft above Mean Sea Level 149° 30' 36.2901" W) RECEIVED ,JUL 2 0 ~000 Alaska 0~; & Gas Cons. Commission Anchorage Proposal Ref: pro9255 RECEIVED ,JUL ;! 0 2000 Alaska Oi*~ & Gas Cons. Commission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -101.00 50.00 0.000 0.000 -51.00 100.00 0.000 0.000 -1.00 150.00 0.000 0.000 49.00 200.00 0.000 0.000 99.00 250.00 0.000 0.000 149.00 300.00 0.000 0.000 199.00 350.00 0.750 112.000 400.00 1.500 112.000 450.00 2.250 112.000 500.00 3.000 112.000 550.00 4.250 112.000 600.00 5.500 112.000 650.00 6.750 112.000 700.00 8.000 112.000 706.06 8.152 112.000 750.00 9.689 112.000 800.00 11.439 112.000 850.00 13.189 112.000 900.00 14.939 112.000 249.00 298.99 348.96 398.91 448.81 498.63 548.34 597.92 603.92 647.33 696.48 745.33 793.83 Sperry-Sun Drilling Services Proposal Report for 1D, 141 WPs - 1D- 141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 50.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 100.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 150.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 200.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 250.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 300.00 0.00 N 0.00 E 5959678.83 N 560490.62 E 350.00 0.12 S 0.30 E 5959678.71N 560490.92 E 399.99 0.49 S 1.21 E 5959678.35 N 560491.84 E 449.96 1.10 S 2.73 E 5959677.75 N 560493.36 E 499.91 1.96 S 4.85 E 5959676.91 N 560495.49 E 549.81 3.15 S 7.78 E 5959675.75 N 560498.43 E 599.63 4.74 S 11.72 E 5959674.19 N 560502.38 E 649.34 6.74 S 16.67 E 5959672.23 N 560507.34 E 698.92 9.14 S 22.62 E 5959669.87 N 560513.31 E 704.92 9.46 S 23.41E 5959669.56 N 560514.10 E 748.33 12.01 S 29.73 E 5959667.06 N 560520.44 E 797.48 15.44 S 38.23 E 5959663.70 N 560528.97 E 846.33 19.44 S 48.11 E 5959659.78 N 560538.88 E 894.83 23.99 S 59.38 E 5959655.32 N 560550.18 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 1.50 1.50 2.50 2.50 2.50 2.50 2.50 3.50 3.50 3.50 3.50 Alaska State Plane 4 Kuparuk 1D Vertical Section 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.28 1.13 2.53 4.51 7.23 10.88 15.47 21.00 21.73 27.59 35.48 44.66 55.12 Comment Begin Dir @ 1.50°/100ft : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 2.50°/100ft : 500.00ft MD, 499.91ft TVD Increase in Dir Rate @ 3.50°/100ft : 706.06ft MD, 704.92ft TVD Continued... 18 July, 2000 - 12:13 - 2 - DrillQuest ZOO.03 RECEIVED ,JUL 2 0 000 Alaska 0;'; & Gas Cons. Commission Anchorage Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs - 1D-141 WP7 Revised: 18 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 950.00 16.689 112.000 841.93 1000.00 18.439 112.000 889.60 1050.00 20.189 112.000 936.79 1100.00 21.939 112.000 983.44 1150.00 23.689 112.000 1029.53 1200.00 25.439 112.000 1075.00 1250.00 27.189 112.000 1119.82 1300.00 28.939 112.000 1163.94 1350.00 30.689 112.000 1207.32 1400.00 32.439 112.000 1249.92 1450.00 34.189 112.000 1291.70 1500.00 35.939 112.000 1332.63 1550.00 37.689 112.000 1372.65 1600.00 39.439 112.000 1411.75 1650.00 41.189 112.000 1449.87 1697.29 42.844 112.000 1485.00 1700.00 42.844 112.000 1486.99 1750.00 42.844 112.000 1523.65 1765.48 42.844 112.000 1535.00 1800.00 42.844 112.000 1560.31 1833.67 42.844 112.000 1585.00 1850.00 43.478 111.766 1596.91 1900.00 45.419 111.081 1632.60 1950.00 47.365 110.440 1667.09 2000.00 49.314 109.839 1700.32 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 942.93 29.09 S 72.01E 5959650.32 N 560562.86 E 990.60 34.75 S 86.00 E 5959644.78 N 560576.89 E 1037.79 40.94 S 101.34 E 5959638.71 N 560592.27 E 1084.44 47.67 S 118.00 E 5959632.11 N 560608.98 E 1130.53 54.94 S 135.97 E 5959625.00 N 560627.02 E 1176.00 62.72 S 155.24 E 5959617.37 N 560646.35 E 1220.82 71.02 S 175.79 E 5959609.23 N 560666.96 E 1264.94 79.84 S 197.60 E 5959600.59 N 560688.84 E 1308.32 89.15 S 220.65 E 5959591.47 N 560711.96E 1350.92 98.95 S 244.92 E 5959581.86 N 560736.30 E 1392.70 109.24 S 270.38 E 5959571.78 N 560761.84 E 1433.63 120.00 S 297.01 E 5959561.24 N 560788.56 E 1473.65 131.22 S 324.79 E 5959550.24 N 560816.42 E 1512.75 142.90 S 353.69 E 5959538.80 N 560845.41 E 1550.87 155.02 S 383.68 E 5959526.92 N 560875.50 E 1586.00 166.87 S 413.03 E 5959515.30 N 560904.93 E 1587.99 167.56 S 414.74 E 5959514.63 N 560906.65 E 1624.65 180.30 S 446.26 E 5959502.15 N 560938.27 E 1636.00 184.24 S 456.02 E 5959498.28 N 560948.06 E 1661.31 193.04 S 477.79 E 5959489.66 N 560969.90 E 1686.00 201.62 S 499.02 E 5959481.26 N 560991.19 E 1697.91 205.78 S 509.38 E 5959477.18 N 561001.59 E 1733.60 218,56 S 541.97 E 5959464.66 N 561034.28 E 1768.09 231.39 S 575.83 E 5959452.10 N 561068.23 E 1801.32 244.25 S 610.90 E 5959439.53 N 561103.40 E Dogleg Rate (°/100fi) 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 0.00 0.00 0.00 0.00 0.00 4.00 4.00 4.0O 4.00 Alaska State Plane 4 Kuparuk 1 D Vertical Section Comment 66.84 79.83 94.06 109.53 126.21 144.10 163.17 183.42 204.81 227.34 250.97 275.69 301.47 328.30 356.14 383.37 384.96 414.23 423.28 443.49 End Dir, Start Sail @ 42.844 · 1697.29ftMD,1586.00ftTVD Base Permafrost 463.19 472.79 502.74 533.49 565.00 Begin Dir @ 4.00°/100ff · 1833.67ff MD, 1686.00ff TVD Continued... 18 July, 2000 - 12:13 - 3 - DrillQuest 2.00.03 RECEIVED ,JUL 2 0 2000 Alaska G-~ & Gss Cons. Commission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 2050.00 51.265 109.271 1732.27 2100.00 53.220 108.734 1762.88 2150.00 55.176 108.223 1792.13 2200.00 57.135 107.737 1819.97 2250.00 59.096 107.271 1846.38 2264.80 59.676 107.137 1853.92 2300.00 59.676 107.137 1871.69 2350.00 59.676 107.137 1896.94 2400.00 59.676 107.137 1922.18 2450.00 59.676 107.137 1947.42 2500.00 59.676 107.137 1972.67 2550.00 59.676 107.137 1997.91 2600.00 59.676 107.137 2023.16 2650.00 59.676 107.137 2048.40 2700.00 59.676 107.137 2073.65 2750.00 59.676 107.137 2098.89 2800.00 59.676 107.137 2124.14 2850.00 59.676 107.137 2149.38 2900.00 59.676 107.137 2174.62 2950.00 59.676 107.137 2199.87 3000.00 59.676 107.137 2225.11 3050.00 59.676 107.137 2250.36 3100.00 59.676 107.137 2275.60 3150.00 59.676 107.137 2300.85 3200.00 59.676 107.137 2326.09 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs- 1D-141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1833.27 257.12 S 647.14 E 5959426.95 N 561139.74 E 1863.88 269.99 S 684.52 E 5959414.39 N 561177.22 E 1893.13 282.84 S 722.98 E 5959401.85 N 561215.78 E 1920.97 295.66 S 762.47 E 5959389.35 N 561255.37 E 1947.38 308.42 S 802.96 E 5959376.91 N 561295.96 E 1954.92 312.19 S 815.13 E 5959373.24 N 561308.15 E 1972.69 321.14 S 844.16 E 5959364.53 N 561337.26 E 1997.94 333.86 S 885.41 E 5959352.14 N 561378.60 E 2023.18 346.58 S 926.65 E 5959339.76 N 561419.94 E 2048.42 359.29 S 967.89 E 5959327.38 N 561461.28 E 2073.67 372.01 S 1009.14 E 5959314.99 N 561502.62 E 2098.91 384.73 S 1050.38 E 5959302.61 N 561543.96 E 2124.16 397.44 S 1091.62 E 5959290.23 N 561585.30 E 2149.40 410.16 S 1132.87 E 5959277.84 N 561626.64 E 2174.65 422.88 S 1174.11 E 5959265.46 N 561667.98 E 2199.89 435.59 S 1215.35 E 5959253.08 N 561709.32 E 2225.14 448.31 S 1256.60 E 5959240.69 N 561750.66 E 2250.38 461.03 S 1297.84 E 5959228.31 N 561792.00 E 2275.62 473.75 S 1339.08 E 5959215.93 N 561833.34 E 2300.87 486.46 S 1380.33 E 5959203.54 N 561874.68 E 2326.11 499.18 S 1421.57 E 5959191.16 N 561916.02 E 2351.36 511.90 S 1462.81 E 5959178.78 N 561957.36 E 2376.60 524.61S 1504.06 E 5959166.39 N 561998.70 E 2401.85 537.33 S 1545.30 E 5959154.01 N 562040.04 E 2427.09 550.05 S 1586.54 E 5959141.63 N 562081.38 E Dogleg Rate (°/100ft) 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 597.23 630.15 663.72 697.88 732.61 742.99 767.73 8O2.88 838.03 873.17 908.32 943.47 978.61 1013.76 1048.91 1084.06 1119.20 1154.35 1189.50 1224.64 1259.79 1294.94 1330.08 1365.23 1400.38 Comment End Dir, Start Sail @ 59.676° : 2264.80ftMD,1954.92ftTVD Continued... 18 July, 2000 - 12:13 - 4 - DrillQuest ZOO. 03 RECEIVED ,JUL 2 0 2000 Alaska 0;-~ & Gss Cons. ~mmi~,qon Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 3250.00 59.676 107.137 2351.33 3300.00 59.676 107.137 2376.58 3350.00 59.676 107.137 2401.82 3400.00 59.676 107.137 2427.07 3450.00 59.676 107.137 2452.31 3500.00 59.676 107.137 2477.56 3550.00 59.676 107.137 2502.80 3600.00 59.676 107.137 2528.05 3650.00 59.676 107.137 2553.29 3700.00 59.676 107.137 2578.53 107.137 107.137 107.137 107.137 107.137 3750.00 59.676 3800.00 59.676 3850.00 59.676 3900.00 59.676 3950.00 59.676 2603.78 2629.02 2654.27 2679.51 2704.76 Sperry-Sun Drilling Services Proposal Report for 1D- 141 WPs - 1 D- 141 WP7 Revised: 18 July, 2000 4000.00 59.676 107.137 2730.00 4050.00 59.676 107.137 2755.24 4100.00 59.676 107.137 2780.49 4150.00 59.676 107.137 2805.73 4200.00 59.676 107.137 2830.98 4250.00 59.676 107.137 2856.22 4300.00 59.676 107.137 2881.47 4350.00 59.676 107.137 2906.71 4400.00 59.676 107.137 2931.95 4450.00 59.676 107.137 2957.20 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2452.33 562.76 S 1627.79 E 5959129.24 N 562122.72 E 2477.58 575.48 S 1669.03 E 5959116.86 N 562164.06 E 2502.82 588.20 S 1710.27 E 5959104.48 N 562205.40 E 2528.07 600.92 S 1751.52 E 5959092.09 N 562246,74 E 2553.31 613.63 S 1792.76 E 5959079.71 N 562288.08 E 2578.56 626.35 S 1834.00 E 5959067.33 N 562329.42 E 2603.80 639.07 S 1875.24 E 5959054,94 N 562370.76 E 2629.05 651.78 S 1916.49 E 5959042.56 N 562412.10 E 2654.29 664.50 S 1957.73 E 5959030.18 N 562453.44 E 2679.53 677.22 S 1998.97 E 5959017.79 N 562494.78 E 2704.78 689.93 S 2040.22 E 5959005.41N 562536.12 E 2730.02 702.65 S 2081.46 E 5958993.03 N 562577.46 E 2755.27 715.37 S 2122.70 E 5958980.64 N 562618.80 E 2780.51 728.08 S 2163.95 E 5958968.26 N 562660.14 E 2805.76 740.80 S 2205.19 E 5958955.88 N 562701.48 E 2831.00 753.52 S 2246.43 E 5958943.49 N 562742.82 E 2856.24 766.24 S 2287.68 E 5958931.11 N 562784.16 E 2881.49 778.95 S 2328.92 E 5958918.73 N 562825.50 E 2906.73 791.67 S 2370.16 E 5958906.34 N 562866.84 E 2931.98 804.39 S 2411.41E 5958893.96 N 562908.18 E 2957.22 817.10 S 2452.65 E 5958881.58 N 562949.52 E 2982.47 829.82 S 2493.89 E 5958869.19 N 562990.86 E 3007.71 842.54 S 2535.14 E 5958856,81 N 563032.20 E 3032.95 855.25 S 2576,38 E 5958844.43 N 563073.54 E 3058.20 867.97 S 2617.62 E 5958832.04 N 563114.88 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1435,52 1470.67 1505,82 1540.96 1576,11 1611.26 1646.40 1681.55 1716.70 1751.84 1786,99 1822.14 1857.28 1892.43 1927.58 1962.73 1997.87 2033.02 2068.17 2103.31 2138.46 2173.61 2208.75 2243.90 2279.05 Confinued... 18 July, 2000 - 12:13 - 5 - DrillQuest ZOO. 03 RECEIVED ,JUL 2_ 0 2000 Alaska Oi'i & G~s Cons. ~mmimion Anchora§e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 4500.00 59.676 107.137 2982.44 4526.85 59.676 107.137 2996.00 4550.00 59.676 107.137 3007.69 4600.00 59.676 107.137 3032.93 4650.00 59.676 107.137 3058.18 4700.00 59.676 107.137 4750.00 59.676 107.137 4800.00 59.676 107.137 4850.00 59.676 107.137 4900.00 59.676 107.137 3083.42 3108.67 3133.91 3159.15 3184.40 4950.00 59.676 107.137 3209.64 5000.00 59.676 107.137 3234.89 5050.00 59.676 107.137 3260.13 5069.54 59.676 107.137 3270.00 5100.00 59.676 107.137 3285.38 Sperry-Sun Drilling Services Proposal Report for 1 D- 141 WPs - 1D- 141 WP7 Revised: 18 July, 2000 5150.00 59.676 107.137 3310.62 5200.00 59.676 107.137 3335.86 5245,82 59.676 107.137 3359,00 5250,00 59.676 107.137 3361.11 5300.00 59.676 107.137 3386.35 5350.00 59.676 107.137 5400.00 59.676 107.137 5450.00 59.676 107.137 5499.34 59.676 107.137 5500.00 59.676 107.137 3411.60 3436.84 3462.09 3487.00 3487.33 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3083.44 880.69 S 2658.87 E 5958819.66 N 563156.22 E 3097.00 887.52 S 2681.01E 5958813.01N 563178.42 E 3108.69 893.41 S 2700.11 E 5958807.28 N 563197.56 E 3133.93 906.12 S 2741.35E 5958794.89 N 563238.90 E 3159.18 918.84 S 2782.60 E 5958782.51N 563280.24 E 3184.42 931.56 S 2823.84 E 5958770.13 N 563321.58 E 3209.67 944.27 S 2865.08 E 5958757.74 N 563362.92 E 3234.91 956.99 S 2906.32 E 5958745.36 N 563404.26 E 3260.15 969.71 S 2947.57 E 5958732.98 N 563445.60 E 3285.40 982.42 S 2988.81E 5958720.59 N 563486.94 E 3310.64 995.14 S 3030.05 E 5958708.21 N 563528.28 E 3335.89 1007.86 S 3071.30 E 5958695.83 N 563569.62 E 3361.13 1020.57 S 3112.54 E 5958683.44 N 563610.96 E 3371.00 1025.55 S 3128.66 E 5958678.60 N 563627.12 E 3386.38 1033.29 S 3153.78 E 5958671.06 N 563652.30 E 3411.62 1046.01S 3195;03 E 5958658.68 N 563693.64 E 3436.86 1058.73 S 3236.27 E 5958646.29 N 563734.98 E 3460.00 1070.38 S 3274.06 E 5958634.95 N 563772.87 E 3462.11 1071.44 S 3277.51E 5958633.91N 563776.32 E 3487.35 1084.16 S 3318.76 E 5958621.53 N 563817.66 E 3512.60 1096.88 S 3360.00 E 5958609.14 N 563859.00 E 3537.84 1109.59 S 3401.24 E 5958596.76 N 563900.34 E 3563.09 1122.31S 3442.49 E 5958584.38 N 563941.68 E 3588.00 1134.86 S 3483.19 E 5958572.16 N 563982.48 E 3588.33 1135.03 S 3483.73 E 5958571.99 N 563983.02 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2314.19 2333.06 2349.34 2384.49 2419.63 2454.78 2489.93 2525.07 2560.22 2595.37 2630.51 2665.66 2700.81 2714.55 2735.95 2771.10 2806.25 2838.46 2841.40 2876.54 2911.69 2946.84 2981.98 3016.67 3017.13 Ugnu C Sands Ugnu B Sands Ugnu A Sands K-13 Shale Continued... 18 July, 2000 - 12:13 - 6 - DrillQuest 2.00.03 RECEIVED JUL 20 2000 Alaska Oi{ & Gas Cons. ~mmi~ion Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 5550.00 59.676 107.137 3512.57 5600.00 59.676 107.137 3537.82 5650.00 59.676 107.137 3563.06 5652.00 59.676 107.137 3564.07 5700.00 61.814 112.672 3587.54 5750.00 64.267 118.196 3610.22 5800.00 66.919 123.488 3630.89 5850.00 69.741 128.569 3649.37 5857.68 70.188 129.332 3652.00 5900.00 72.704 133.464 3665.47 5937.88 75.027 137.066 3676.00 5950.00 75.782 138.201 3679.05 5969.37 77.000 140.000 3683.61 6000.00 77.962 143.634 3690.25 6050.00 79.631 149.510 3699.97 6100.00 81.406 155.322 3708.22 6150.00 83.266 161.079 3714.89 6178.89 84.373 164.384 3718.00 6200.00 85.194 166.790 3719.92 6250.00 87.168 172.470 3723.25 6300.00 89.171 178.129 3724.85 6320.62 90.000 180.461 3725.00 6350.00 90.259 183.388 3724.93 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs - 1D-141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3613.57 1147.74 S 3524.97 E 5958559.61 N 564024.36 E 3638.82 1160.46 S 3566.22 E 5958547.23 N 564065.70 E 3664.06 1173.18 $ 3607.46 E 5958534.84 N 564107.04 E 3665.07 1173.69 S 3609.il E 5958534.35 N 564108.69 E 3688.54 1187.96 S 3648.45 E 5958520.40 N 564148.15 E 3711.22 1207.10 S 3688.66 E 5958501.58 N 564188.51 E 3731.89 1230.45 S 3727.72 E 5958478.55 N 564227.75 E 3750.37 1257.79 S 3765.27 E 5958451.52 N 564265.52 E 3753.00 1262.32 S 3770.88 E 5958447.03 N 564271.16 E 3766.47 1288.85 S 3800.96 E 5958420.74 N 564301.45 E 3777.00 1314.70 S 3826.56 E 5958395.10 N 564327.26 E 3780.05 1323.37 S 3834.46 E 5958386.51 N 564335.23 E 3784.61 1337.60 S 3846.79 E 5958372.38 N 564347.67 E 3791.25 1361.10 S 3865.27 E 5958349.03 N 564366.33 E 3800.97 1402.01S 3892.27 E 5958308.33 N 564393.66 E 3809.22 1445.71S 3915.09 E 5958264.83 N 564416.82 E 3815.89 1491.69 S 3933.47 E 5958218.99 N 564435.58 E 3819.00 1519.12 S 3942.00 E 5958191.64 N 564444.33 E 3820.92 1539.48 S 3947.23 E 5958171.33 N 564449.72 E 3824.25 1588.53 S 3956.20 E 5958122.36 N 564459.09 E 3825.85 1638.31S 3960.30 E 5958072.61N 564463.58 E 3826.00 1658.93 S 3960,55 E 5958052.00 N 564464.00 E 3825.93 1688.29 S 3959.56 E 5958022.64 N 564463.25 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 10.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3052.28 3087.42 3122.57 3123.97 3159.20 3198.83 3241.10 3285.62 3292.63 3331.97 3368.05 3379.74 3398.53 3428.42 3477.32 3525.90 3573.60 3600.57 3619.92 3664.34 3706.38 3722.92 3745.65 Begin Dir @ 11.00°/100ff : 5652.00ffMD, 3665.07ff TVD West Sak D Sand West Sak C Shale Increase in Dir Rate @ 12.00°/100ft : 5969.37ft MD, 3784.61ft TVD West Sak B Sand Dir Rate Decrease @ 10.00°/100ft : 6320.62ftM D,3826.00ftTVD 7 5/8" X 7"Casing Target - 1 D-141 T1 18 July, 2000 - 12:13 - 7- DrillQuest 2.00.03 -t · RECE,VED ,JUL 2 0 2000 Alaska 0;4 & Gas Cons. Commi~on Anchorage North Slope Alaska Measured Sub-Sea Depth Incl. Azim, Depth (ft) (ft) 6400.00 90.698 188.368 3724.52 6450.00 91.131 193.350 3723.72 6500.00 91.556 198.334 3722.54 6541.40 91.899 202.461 3721.30 6550.00 91.899 202.461 6600.00 91.899 202.461 6631.40 91.899 202.461 3721.01 3719,35 3718.31 6650.00 91.535 201.406 3717.76 6668.94 91.163 200.332 3717.31 6700.00 91.163 200.332 3716.68 6750.00 91.163 200.332 3715.67 6800.00 91.163 200.332 3714.65 6808.61 91.163 200.332 3714.48 6850.00 91.400 197.859 3713.55 6900.00 91.683 194.871 3712.20 6906.87 91.722 194.461 3712.00 6950,00 91,492 191.882 3710.79 6996.81 91.239 189.084 3709.67 7000.00 91.239 189.084 3709.61 7050.00 91.239 189.084 3708.53 7100.00 91.239 189.084 3707.44 7150.00 91.239 189.084 3706.36 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs- 1D-141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (fi) (ft) (ft) (ft) (ft) (°/100ft) 3825.52 1738.01 s 3954.44 E 5957972.88 N 564458.53 E 10.00 3824.72 1787.09 S 3945.03 E 5957923.73 N 564449,51 E 10.00 3823.54 1835.16 S 3931.39 E 5957875.55 N 564436.26 E 3822.30 1873.94 S 3916.97 E 5957836.67 N 564422.16 E 3822.01 1881.89 S 3913.69 E 5957828.70 N 564418.94 E 3820.35 1928.07 S 3894.59 E 5957782.37 N 564400.22 E 3819.31 1957.07 S 3882.60 E 5957753.27 N 564388.46 E 3818.76 1974.32 S 3875.66 E 5957735.97 N 564381.66 E 3818.31 1992.00 S 3868.92 E 5957718.23 N 564375.06 E 3817.68 2021.13 S 3858.12 E 5957689.03 N 564364.50 E 3816.67 2068.00 S 3840.76 E 5957642.02 N 564347,51E 3815.65 2114.88 S 3823.39 E 5957595.01N 564330.52 E 3815.48 2122.95 S 3820.39 E 5957586.91 N 564327.60 E 3814.55 2162.05 S 3806.86 E 5957547.71N 564314.38 E 3813.20 2210.00 S 3792.78 E 5957499.65 N 564300.68 E 3813.00 2216.64 S 3791.04 E 5957493.00 N 564299.00 E 3811.79 2258.62 S 3781.22 E 5957450.95 N 564289.52 E 3810.67 2304.63 S 3772.70 E 5957404.87 N 564281.37 E 3810.61 2307.78 S 3772.20 E 5957401.72 N 564280.90E 3809.53 2357.14 S 3764.31E 5957352.30 N 564273.40 E 3808.44 2406.50 S 3756.41E 5957302.88 N 564265,91E 3807.36 2455.86 S 3748.52 E 5957253.47 N 564258.41E 10.00 10.00 0.00 0.00 0.00 6.00 6.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 3782.05 3815.33 3845.24 3867.30 3871.62 3896.72 3912.48 3921.97 3931.93 3948,51 3975,21 4001.91 4006.51 4029.36 4058,91 4063.13 4090.52 4121.91 4124,10 4158.53 4192.96 4227.39 Comment End Dir, Start Sail @ 91.899° · 6541.40ftMD,3822.30ftTVD Begin Dir @ 6.00°/100ft · 6631.40ft MD, 3819.31ft TVD End Dir, Start Sail @ 91.163° · 6668.94ftMD,3818.31ftTVD Begin Dir @ 6.00°/100ft · 6808.61ft MD, 3815.48ft TVD ~ Target - 1 D-141 T2 End Dir, Start Sail @ 91.239° · 6996.81ftMD,3810.67ftTVD Continued... 18 July, 2000 - 12:13 - 8 - DrillQuest 2.00.03 RECEIVED ~ - ,JUL 2 0 2000 Alaska 0;4 & Gss Cons. ~mmission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 7200.00 91.239 189.084 3705.28 7250.00 91.239 189.084 3704.20 7300.00 91.239 189.084 3703.12 7350.00 91.239 189.084 3702.04 7400.00 91.239 189.084 3700.96 7409.06 91.239 189.084 3700.76 7443.80 91.281 187.000 3700.00 7450.00 91.233 186.631 3699.86 7467.09 91.101 185.614 3699.52 7500.00 91.101 185.614 3698.88 7550.00 91.101 185.614 3697.92 7600.00 91.101 185.614 3696.96 7650.00 91.101 185.614 3696.00 7700.00 91.101 185.614 3695.04 7750.00 91.101 185.614 3694.08 7800.00 91.101 185.614 3693.12 7850.00 91.101 185.614 3692.16 7900.00 91.101 185.614 3691.20 7948.85 91.101 185.614 3690.26 7950.00 91.101 185.568 3690.24 8000.00 91.105 183.567 3689.27 8014.18 91.105 183.000 3689.00 8050.00 90.879 181.585 3688.38 8081.19 90.681 180.353 3687.96 8100.00 90.681 180.353 3687.73 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs- 1D-141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3806.28 2505.22 S 3740.63 E 5957204.05 N 564250.92 E 3805.20 2554.58 S 3732.74 E 5957154.63 N 564243.42 E 3804.12 2603.95 S 3724.84 E 5957105.21N 564235.93 E 3803.04 2653.31S 3716.95 E 5957055.79 N 564228.44 E 3801.96 2702,67 S 3709.06 E 5957006.37 N 564220.94 E 3801.76 2711.61S 3707.63 E 5956997.42 N 564219.58 E 3801.00 2746.00 S 3702.77 E 5956963.00 N 564215.00 E 3800.86 2752.16 S 3702.03 E 5956956.84 N 564214.32 E 3800.52 2769.15 S 3700.21 E 5956939.83 N 564212.63 E 3799.88 2801.89 S 3696.99 E 5956907.07 N 564209.68 E 3798.92 2851.64 S 3692.10 E 5956857.28 N 564205.19 E 3797.96 2901.39 S 3687.21 E 5956807.50 N 564200.70 E 3797.00 2951.14 S 3682.32 E 5956757.72 N 564196.21 E 3796.04 3000.89 S 3677.43 E 5956707.93 N 564191.72 E 3795.08 3050.65 S 3672.54 E 5956658.15 N 564187.23 E 3794.12 3100.40 S 3667.65 E 5956608.37 N 564182.74 E 3793.16 3150.15 S 3662.76 E 5956558.58 N 564178.25 E 3792.20 3199.90 S 3657.87 E 5956508.80 N 564173.77 E 3791.26 3248.50 S 3653.09 E 5956460.16 N 564169.38 E 3791.24 3249.65 S 3652.98 E 5956459.01 N 564169.28 E 3790.27 3299.48 S 3649.00 E 5956409.16 N 564165.70 E 3790.00 3313.63 S 3648.19 E 5956395.00 N 564165.00 E 3789.38 3349.42 S 3646.76 E 5956359.21N 564163,86 E 3788.96 3380.60 S 3646.23 E 5956328.03 N 564163.58 E 3788.73 3399.41 S 3646.11 E 5956309.22 N 564163.61 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4261.81 4296.24 433O.67 4365.10 4399.53 4405.77 4430.14 4434.58 4446.98 4471.04 45O7.6O 4544.16 4580.72 4617.28 4653.84 4690.40 4726.96 4763.52 4799.24 4800.09 4837.26 4848.01 4875.58 4900.03 4914.91 Begin Dir @ 6.00°/100ft : 7409.06ft MD, 3801.76ft TVD Target - 1 D-141 T3 End Dir, Start Sail @ 91.101° : 7467.09ftMD,3800.52ftTVD Begin Dir @ 4.00°/100ft : 7948.85ft MD, 3791.26ft TVD Target- 1D-141 T4 End Dir, Start Sail @ 90.681 ° : 8081.19ftMD,3788.96ftTVD Continued... 18 July, 2000 - 12:13 - 9 - DrillQuest ZOO.03 RECEIVED _ . JUL 2 0 2000 Alaska 0;-i & Gas Cons. ~mmission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 8150.00 90.681 180.353 3687.14 8200.00 90.681 180.353 3686.54 8250.00 90.681 180.353 3685.95 8300.00 90.681 180.353 3685.35 8350.00 90.681 180.353 3684.76 8400.00 90.681 180.353 3684.17 8450.00 90.681 180.353 3683.57 8500.00 90.681 180.353 3682.98 8550.00 90.681 180.353 3682.38 8600.00 90.681 180.353 3681.79 8650.00 90.681 180.353 3681.19 8700.00 90.681 180.353 3680.60 8750.00 90.681 180.353 3680.01 8800.00 90.681 180.353 3679.41 8830.07 90.681 180.353 3679.05 8835.35 90.500 180.461 8840.99 90.274 180.461 3679.00 3678.96 8850.00 90.274 180.461 3678.92 8900.00 90.274 180.461 3678.68 8950.00 90.274 180.461 3678.44 9000.00 90.274 180.461 3678.20 9050.00 90.274 180.461 3677.96 9100.00 90.274 180.461 3677.72 9150.00 90.274 180.461 3677.48 9200.00 90.274 180.461 3677.24 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs - 1D-141 WP7 Revised: 18 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 3788.14 3449.40 S 3645.81E 5956259.23 N 564163.71E 3787.54 3499.40 S 3645.50 E 5956209.24 N 564163.80 E 3786.95 3549.40 S 3645.19 E 5956159.25 N 564163.90 E 3786.35 3599.39 S 3644.88 E 5956109.25 N 564163.99 E 3785.76 3649.39 S 3644.57 E 5956059.26 N 564164.09 E 3785.17 3699.38 S 3644.27 E 5956009.27 N 564164.18 E 3784.57 3749.38 S 3643.96 E 5955959.28 N 564164.28 E 3783.98 3799.37 S 3643.65 E 5955909.29 N 564164.37 E 3783.38 3849.37 S 3643.34 E 5955859.30 N 564164.47 E 3782.79 3899.36 S 3643.03 E 5955809.31 N 564164.56 E 3782.19 3949.36 S 3642.73 E 5955759.31 N 564164.65 E 3781.60 3999.36 S 3642.42 E 5955709.32 N 564164.75 E 3781.01 4049.35 S 3642.11E 5955659.33 N 564164.84 E 3780.41 4099.35 S 3641.80 E 5955609.34 N 564164.94 E 3780.05 4129.42 S 3641.62 E 5955579.27 N 564164.99 E 3780.00 4134.69 S 3641.58 E 5955574.00 N 564165.00 E 3779.96 4140.33 S 3641.53 E 5955568.36 N 564165.00 E 3779.92 4149.34 S 3641.46 E 5955559.35 N 564165,00 E 3779.68 4199.34 S 3641.06 E 5955509.35 N 564165.00 E 3779.44 4249.34 S 3640.66 E 5955459.36 N 564165.00 E 3779.20 4299.34 S 3640.26 E 5955409.37 N 564165.00 E 3778.96 4349.33 S 3639.85 E 5955359.37 N 564165.00 E 3778.72 4399.33 S 3639.45 E 5955309.38 N 564165.00 E 3778.48 4449.33 S 3639.05 E 5955259.38 N 564165.00 E 3778.24 4499.33 S 3638.65 E 5955209.39 N 564165.00 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 4954.44 4993.98 5033.52 5073.06 5112.59 5152.13 5191.67 5231.21 5270.74 5310.28 5349.82 5389.35 5428.89 5468.43 5492.21 5496.38 5500.83 5507.95 5547.43 5586.91 5626.39 5665.87 5705.36 5744.84 5784.32 Comment Begin Dir @ 4.00°/100ft : 8830.07ft MD, 3780.05ft TVD Target - 1 D-141 T5 End Dir, Start Sail @ 90.274° : 8840.99ftMD,3779.96ftTVD Continued... 18 July, 2000 - 12:13 - 10 - DrillQuest 2.00.03 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs - 1D-141 WP7 Revised: 18 July, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9250.00 90.274 180.461 3677.00 3778.00 4549.32 S 3638.24 E 5955159.39 N 564165.00 E 9300.00 90.274 180.461 3676.76 3777.76 4599.32 S 3637.84 E 5955109.40 N 564165.00 E 9350.00 90.274 180.461 3676.52 3777.52 4649.32 $ 3637.44 E 5955059.40 N 564165.00 E 9400.00 90.274 180.461 3676.28 3777.28 4699.32 S 3637.04 E 5955009.41 N 564165.00 E 9450.00 90.274 180.461 3676.05 3777.05 4749.32 S 3636.64 E 5954959.42 N 564165.00 E 9459.41 90.274 180.461 3676.00 3777.00 4758;73 S 3636.56 E 5954950.00 N 564165.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 142.613° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9459.41ft., The Bottom Hole Displacement is 5989.16ft., in the Direction of 142.613° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1 D Vertical Section Comment 5823.80 5863.28 5902.77 5942.25 5981.73 5989.16 Total Depth: 9459.41ftMD,3777.00ftTVD 4 1/2" prepack screens Target - 1 D-141 T6 RECEIVED ,JUL 2 0 2000 Alaska O?J & Gas Cons. Commi~si0n Anchorage Continued... 18 July, 2000- 12:13 - 11- DrillQuest 2.00.03 Sperry-Sun Drilling Services Proposal Report for 1D- 141 WPs - 1 D- 141 WP7 Revised: 18 July, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 300.00 500.00 706.06 1697.29 1833.67 2264.80 5652.00 5969.37 6320.62 6541.40 6631.40 6668.94 6808.61 6996.81 7409.06 7467.O9 7948.85 8081.19 8830.07 8840.99 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 300.00 0.00 N 0.00 499.91 1.96 S 4.85 704.92 9.46 S 23.41 1586.00 166.87 S 413.03 1686.00 201.61 S 499.02 1954.92 312.19 S 815.13 3665.07 1173.69 S 3609.11 3784.61 1337.59 S 3846.79 3826.00 1658;93 S 3960.55 3822.30 1873.94 S 3916.97 3819.31 1957.07 S 3882.60 3818.31 1992.01S 3868.91 3815.48 2122.95 S 3820.40 3810.67 2304.63 S 3772.70 3801.76 2711.61S 3707.63 3800.52 2769.15 S 3700.21 3791.26 3248.51 S 3653.09 3788.96 3380.60 S 3646.23 3780.05 4129.41 S 3641.62 3779.96 4140.33 S 3641.53 Comment Begin Dir @ 1.50°/100ft : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 2.50°/100ft : 500.00ft MD, 499.91ft-FVD Increase in Dir Rate @ 3.50°/100ft : 706.06ft MD, 704.92ft TVD End Dir, Start Sail @ 42.844°: 1697.29ftMD,1586.00ftTVD Begin Dir @ 4.00°/100ft : 1833.67ft MD, 1686.00ft TVD End Dir, Start Sail @ 59.676°: 2264.80ftMD,1954.92ftTVD Begin Dir @ 11.00°/100ft : 5652.00ft MD, 3665.07ft TVD Increase in Dir Rate @ 12.00°/100ft : 5969.37ft MD, 3784.61ft TVD Dir Rate Decrease @ 10.00°/100ft : 6320.62ftMD,3826.00ftTVD End Dir, Start Sail @ 91.899°: 6541.40ftMD,3822.30ftTVD Begin Dir @ 6.00°/100ft : 6631.40ft MD, 3819.31ft TVD End Dir, Start Sail @ 91.163°: 6668.94ftMD,3818.31 ftTVD Begin Dir @ 6.00°/100ft : 6808.61ft MD, 3815.48ft TVD End Dir, Start Sail @ 91.239°: 6996.81ftMD,3810.67ftTVD Begin Dir @ 6.00°/100ft : 7409.06ft MD, 3801.76ft TVD End Dir, Start Sail @ 91.101°: 7467.09ftMD,3800.52ftTVD Begin Dir @ 4.00°/100ft : 7948.85ft MD, 3791.26ft TVD End Dir, Start Sail @ 90.681 o: 8081.19ftMD,3788.96ftTVD Begin Dir @ 4.00°/100ft : 8830.07ft MD, 3780.05ft TVD End Dir, Start Sail @ 90.274°: 8840.99ftMD,3779.96ftTVD RECEIVED ,JUL 2 0 2000 Alaska 0;i & Gas Cons. ~mmissi0n Anchorage Continued.., 18 July, 2000 - 12:13 - 12 - DrillQuest ZOO.03 Sperry-Sun Drilling Services Proposal Report for 1 D- 141 WPs - 1D- 141 WP7 Revised: 18 July, 2000 North Slope Alaska Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment Alaska State Plane 4 Kuparuk 1D Comments (Continued) Formation Tops Formati on Plane P r o f i I e (Below Well Origin) Measured Vertical Sub-Sea Dip Dip Dir. Depth Depth (ft) Deg. Deg. (ft) (ft) 1535.00 0.000 0.461 1765.48 1636.00 2996.00 0.000 0.461 4526.85 3097.00 3270.00 0.000 0.461 5069.54 3371.00 3359.00 0.000 0.461 5245.82 3460.00 3487.00 0.000 0.461 5499.34 3588.00 3652.00 0.000 0.461 5857.68 3753.00 3676.00 0.000 0.461 5937.88 3777.00 3718.00 0.000 0.461 6178.89 3819.00 Penetration Sub-Sea Depth Northings (ft) (ft) Point Eastings (ft) 1535.00 184.24 S 456.02 E 2996.00 887.52 S 2681.01 E 3270.00 1025.55 S 3128.66 E 3359.00 1070;38 S 3274.06 E 3487.00 1134.86 S 3483.19 E 3652.00 1262.32 S 3770.88 E 3676.00 1314.70 S 3826.56 E 3718.00 1519.12 S 3942.00 E Formation Name Base Permafrost Ugnu C Sands Ugnu B Sands Ugnu A Sands K-13 Shale West Sak D Sand West Sak C Shale West Sak B Sand RECEIVED ,JUL 2 0 2000 Naska Oi~ & Gss Cons. Commission Anchorage Continued**. 18 July, 2000 - 12:13 - 13 - DrillQuest 2.00.03 Sperry-Sun Drilling Services Proposal Report for 1D-141 WPs - 1D-141 WP7 Revised: 18 July, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> <Surface> <Surface> 6320.63 3826.00 9459.41 3777.00 Targets associated with this wellpath Target Name 1 D-141 T1 1D-141 T2 1D-141 T3 1D-141 T4 1 D-141 T5 Casing Detail 7 5/8" X 7"Casing 4 1/2" prepack screens Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3826.00 3725.00 3813.00 3712.00 3801.00 3700.00 3790.00 3689.00 3780.0O 3679.0O RECEIVED JUL ?--0 2000 Alaska 07; & Gas Cons. Commission Anchorage Target Target Shape Type 1658.93 S 3960.55 E Point 5958052.00 N 564464.00 E 70° 17'45.1293"N 149° 28'40.8519"W 2216.64 S 3791.04 E Point 5957493.00 N 564299.00 E 70o17'39.6451"N 149o28'45.8009"W 2746.00 S 3702.77 E Point 5956963.00 N 564215.00 E 70o17'34.4393"N 149o28'48.3812"W 3313.63 S 3648.19 E Point 5956395.00 N 564165.00 E 70°17'28.8570"N 149° 28'49.9797"W 4134.69 S 3641.58 E Point 5955574.00 N 564165.00 E 70° 17' 20.7820"N 149° 28' 50.1839"W Continued... 18 July, 2000 - 12:13 - 14 - DrillQuest 2.00.03 Sperry-Sun Drilling Services Proposal Report for 1 D- 141 WPs - 1D- 141 WP7 Revised: 18 July, 2000 North Slope Alaska Target Name Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Alaska State Plane 4 Kuparuk 1D Target Target Shape Type Targets associated with this wellpath (Continued) 1D-141 T6 Mean Sea Level/Global Coordinates: Geographical Coordinates: 3777.00 3676.00 4758.73 S 3636.56 E 5954950.00 N 564165.00 E 70°17'14.6446"N 149° 28'50.3390"W Point RECEIVED ,JUt_ 2 0 2000 A~aska 0;-; & Gas Cons. Commission Anchorage 18 July, 2000- 12:13 - 15- DrillQuest 2.00.03 1D-141 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase I 16" Conductor @ 80' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface KOP @ 5577' MD / 3627' 'I'VD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 6320' MD / 3826' TVD 7-5/8" 29.7# L-80 LTC Mod or BTC Mod Casing as required from TAM Port Collar to Surface. TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' 'I-VD 7-5/8" 29.7# L-80 BTC Mod Casing as required from Orienting Crossover to TAM Port Collar. Sperry RMLS System Sperry Orienting Crossover 7-5/8" 29.7# BTC Box x 7" 29# BTC Pin w/Orienting Integral Profile. Sperry Casing Alignment Sub 7" 29# BTC Box x Pin 4 Joints 7# 26# L-80 BTC Mod Casing. Sperry RMLS Window Joint 7" 29# L-80 BTC w/Aluminum External Sleeve and Latch Coupling. 7" 26# L-80 BTC Mod Casing as required from Landing Collar to Latch Coupling. Sperry Float / Landing Collar 7" 29# L-80 BTC Box x Pin. 2 Joints 7# 26# L-80 BTC Mod Casing. RECEIVED Sperry Float Shoe 7" 29# L-80 BTC Box Up. ,JUL 2 0 2000 Alaska Oi-~ & Gas Cons. Commission MAC 07/18/00 1D-141 West Sak Producer Multi Lateral w/Pre-Packed Screen RECE!VED 16" Conductor @ 80' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) Planned Completion - Phase 2 ,JUL 2-0 2000 Alaska & Gas Cons. Commission Anchorage TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' ']'VD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface KOP @ 5577' MD / 3627' TVD Lower Lateral Completion (Run w/2-7/8" Hyd 511 Inner Wash Strin,q) Baker SC-1R ~70B-40' Single Bore - Rotationally Locked, Liner Top Packer (6.0" Max OD, 4" Min ID) w/5-1/2" HSLHT Box Down. Baker 6' Extension w/5-1/2" HSLHT Pin x Pin Crossover Sub w/5-1/2" HSLHT Box x 4-1/2" HSLHT Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" HSLHT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4-1/2" HSLHT Box x 4" HSLHT Pin. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. 4" x 4-1/2" Bakerweld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. Plan to alternate Prepack Screen and Blank Pipe through production interval. Production Casing 7" 26# L-80 BTC Mod TD to RMLS 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Baker Model 'GPV' Set Shoe Assembly (5.560" Max OD). Assembly Includes Shoe, 5" Blank Pipe Above Shoe and Crossover Back to 4" Blank Pipe. 7" Casing Point @ 6320' MD / 3826' TVD Liner Top Packer Set @ +/- 6170' MD TD B-Sand Lateral @ +/- 9459' MD / 3,777' TVD MAC 07/18/00 16" Conductor @ 80' 10-3/4" 40.5~ J-55 BTC @ 500' (Gravel Isolation String) TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface KOP @ 5577' MD / 3,627' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 6320' MD / 3826' TVD 1 D-141 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 3 upper Sperry Sperry 4-1/2" Baker Baker Baker Baker Lateral 'Bonzai' Com .1 (Run w/2-7/8" Hyd 511 Inner Wash Strinq) RMLS Transition Joint. (TAM) Hydraulic Release Sub. 12.6# L-80 BTC Mod Tbg as required from Indicator Sub to Hyd Release Sub. Handling Pup 4-1/2" 12.6# L-80 IBT Box x Casing BTC Pin (Length 10% Indicator Sub (10K-15K Snap Force) 4-1/2' 12.6# L-80 Casing BTC Box x Pin. Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 107. HMCV Cementing Valve 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker 3' Bottom Sub 4-1/2' 12.6# L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (as required), 4-1/2" 12.6# L-80 IBT BOx x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 107. Baker CTC 7' Isozone ECP 4-1/2" 12.6# L-80 Casing BTC Box x Box (3.833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (as required), 4-1/2" 12.6# L-80 IBT Box x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 10'). Baker CTC 20' Payzone ECP 4-1/2" 12.6# L-80 Casing BTC Box x Box (3.833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. 1 Joint 4-1/2" 12.6# L-80 BTC Mod Tubing. Baker Model C 'KOIV' Knock Out Isolation Valve w/3.50" ID and 4-1/2" IBT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 BTC Mod Tubing. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" IBT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 BTC Mod Tubing. Crossover Pup, 4-1/2" IBT Box x 4" HSLHT Pin. 4" x 4-1/2" Bakerweld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from Drillable Packoff Bushing to Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/HSLHT Connections as required from Drillable Packoff Bushing to Sliding Sleeve. Plan to alternate Prepack Screen and Blank Pipe through production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4" HSLHT Box x 5" HSLHT Pin 1 Joint 5" 15# L-80 HSLHT Tubing. Baker Drillable Packoff Bushing w/5" HSLHT Box x Pin. 1 Joint 5" 15# L-80 HSLHT Tubing. Baker Model 'GPV' Set Shoe (5.560" Max OD). Sand ~~J~~~' ~ Bridge Plug Set @ +/- 5737' MD Bridge Plug I Liner Top Packer Set @ +/- 6170' MD TD D-Sand Lateral @ +/- 9,502' MD / 3,707' TVD RECEIVED ,JUL 2 0 2000 Alaska 0r~ & ~as uo~s. ~;omm~ssJOn Anchorage TD B-Sand Lateral @ +/- 9459' MD / 3,777' TVD MAC 07/18/OO 1D-141 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 4 16" Conductor @ 80' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface 4-1/2" Vetco Gray Tubing Hanger w/4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 4-1/2" 12.6# L-80 NSCT Spaceout Pups as required for Heat Trace (Heat Trace Cannot Be Spliced). Raychem Heat Trace @ +/- 3,000' MD. 4-1/2" 12.6# L-80 NSCT Tubing to Surface.. 4-1/2" x 1" Camco 'KBG-2' GLM run open. After rig moves off location, the Wells Group will install a Shear Circulating Valve pinned for 3000 psi Tubing to Casing Differential. 6' handling pups installed on top and bottom of GLM. 2 Joints 4-1/2" 12.6# L-80 NSCT Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple) 10' Spaceout Pup 4-1/2" 12.6# L-80 NSCT Tubing 10' Handling Pup 4-1/2" 12.6# L-80 NSCT Tubing Centrilift ESPCP (components as listed below). Centrilift 4-1/2" Slotted Nipple. Centrilift 4-1/2" 'I-I'C Crossover Centrilift Tandem Seal Section: GST3 DB IL H6PFS Centrilift PC Pump Assembly: R&M 375 Series 40-S-340 Single Lobe PC Pump Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP 1315/26 KMH Centrilift Motor Centralizer KOP @ 5577' MD / 3627' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 6320' MD / 3826' TVD TD D-Sand Lateral @ +/- 9,502' MD / 3,707' TVD Liner Top Packer Set @ +/- 6170' MD RECEIVED . , ,JUL 2 0 2000 Alaska Oi-; & Gas Co s. Commission Anchorage TD B-Sand Lateral @ +/- 9459' MD / 3,777' TVD MAC 07/18/00 16" DIV('RTER SCHEMATIC - rdic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 10" 150 ANSI Blanked 3 Open I ~_ _ _c I_o..s..e d_ _~' '~ % _ Closed _ _ ..~' 3" Ball Valve Blanked · To Accumulator I ~_ .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately , Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16"x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line - Nordic RECEIVED JUL 2 0 2000 Alaska 0[-~ & Gas Cmos. Commission Anchorage MAC 7/18/0O (' 11" 5000 psi BO P Sta( x Kuparuk River Unit West Sak Operations - Producer Wells 5 [ Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. RECEIVED 1. 13-3/8" Landing Ring 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Pipe Rams 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines 5. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 6. 11" 5000 psi Annular Preventer JUL 2 0 2000 Alaska 0~i & Gas Cmos. Commission Anchorage MAC 7/18/0O Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement / above Port / Collar / (1000' TVD)/ ~erform Top dob as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One1 Stage Cement JobI I to Surface Cement below Port Collar ¢OOO'TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion RECEIVED . . ,JUL 2 0 2000 Alaska Oi'J & Gas Co~'~s. Commi.ssion Anchorage RECEIVED Port Collar Cementinq Practices ,JUL 2 0 2000 Alaska 0~; & ~oas Con~. Commission · We will run a TAM Port Collar (see below for running details). Anchorage · Circulate with casing on bottom at 10 bpm or greater if possible without losing returns. Equipment for the stage job consists of: · TAM Port collar · TAM Combo tool · TAM Choke Ensure that all connections are compatible or that there are appropriate crossovers available. If needed, TAM personnel can be available on site to check the equipment and confirm shear pin settings with prior notice. Run and cement with the Port Collar as follows: I. Check that all materials are at the rig site ·7 5/8" TAM Combo Tool, with 3-1/2" EUE Box by Pin and 7 5/8" 29.7 ppf Packer Cups · 7 5/8" TAM Port Collar with 7 5/8" BTCM Box x Pin Connections · Choke Sub with 3-1/2" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers II. Ensure that all connections are compatible or there are appropriate crossovers available III. Pick up and run 7 5/8" 29.7 ppf casing with Port Collar placed at 1000' TVD. Note: If packing off problems were seen around this depth when drilling or tripping, consult with the Drilling Engineer. · Install centralizers in the center of the joints above and below the port collar. IV. Pump first stage of cement job (spacer, lead and tail) as specified in Drilling Plan. Pump until the plug bumps and pressure up to 500 psi above circulating pressure to insure the plug has landed. If floats do not hold, maintain 1500 psi on casing for a minimum of 4 hours before rechecking. V. If cement is not returned to surface, a top job or use of the port collar will be required. The Arco company representative should review the attached decision tree is order to determine which method should be used. · Do top job using 1" tubing if good lead slurry cement did not circulate to surface. Run 1" tubing and tag top of previous cement job. If tubing does not tag, run it as deep as possible and contact the Arco drilling engineer or engineer on call to discuss options. Circulate while RIH to keep tubing from packing off. Flush annulus with water, then circulate annulus to cement. · AOGCC and Arco drilling engineer (or engineer on call) must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. VI. If the Arco company representative determines that it is necessary to use the Port Collar, run in the hole with the 4" drillpipe until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. Port Collar Practices 1 MAC, 07/18/00 · In order to trip in with the 4" drillpipe and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. VII. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure VIII.Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. IX. Establish circulation rate and pressure X. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing XI. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar XII. Pressure up on workstring to confirm collar is closed XIII.With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar XIV. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub XV. Reverse out excess cement as required XVl. Pull out of hole with tools RECEIVED ,.JUL 2 0 2000 Alaska Oi-; & G~s Cons. Commission Anchorage Port Collar Practices 2 MAC, 07/18/00 Leak Off Test Procedure West Sak 1 D-141 After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 1500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the Leak Off Test (LOT) form (you can locate form on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. o . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 1 1.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a Formation Integrity Test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. RECEIVED ~ . JUL 2 0 2000 Alaska 0~i & ~as Cm,s. Commission Anchorage MAC Page 1 07/19/00 i CASH ADVANCE DRAFT 111 4' p^YTOTHE A,, -- /'; _ /~~..~~ ..... .... ~)RD'R~F'~~.. ........ U~LLARS ~ I/~.~ 1 -- - "--~: ~~ ~o ~ ~OT VALID FOR AM~NT OVEK $l~ WELL PERMIT CHECKLIST COMPANY ~'~//~'~ WELL NAME/~-!~'~ PROGRAM: exp .. dev ... FIELD & POOL 47/'~'~.~//~'-~ INIT CLASS '~&U .~/~/~__ GEOL AREA ~:~(~ ADMINISTRATION DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE %-, 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet.regulation ................ 26. BOPE press rating appropriate; test to %~(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. v/redrll ... serv wellbore sag ann. disposal para req. UNIT# ~)_/.//~ ~__~ ON/OFF SHORE ~)//~ GEOLOGY 30. Permit can be issued wio hydrogen sulfide measures ..... /Y) N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .......... II Ap.D-B DATE _ 33. Seabed cOndition survey (if. off-shore) ...... , . . ~"~AJ.. ri Y N ' ~/(~) ~ ~)'~) 34. Contact name/phone for weekly progress reports [~loratory only] Y N II II'ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE Y N (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste .... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UlClAnnular COMMISSlON: Y N Y N YN Comments/Instructions: Z -I -1- ~n c:~soffiCe\wordian~iana\checklist (rev. 02117100) .. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability.of the Well History file and to simplify'finding information, information of this nature is accumulated at the end of the file under APPENDIX. .o Nospecial'eflort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue May 08 17:13:38 2001 Reel Header Service name ............. LISTPE Date ..................... 01/05/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/05/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-00127 A. WEAVER D. WESTER 1D-141 500292296700 PHILLIPS Alaska, Inc. Sperry Sun 30-APR-01 MWD RUN 4 AK-MM-00127 R. MCNEILL D. WESTER MWD RUN 5 AK-MM-00127 R. MCNEILL D. HElM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 6 AK-MM-00127 R. MCNEILL D. HEIM MWD RUN 7 AK-MM-00127 R. MCNEILL D. HEIM 14 liN 10E 12 595 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: .00 101.05 70.70 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 10.750 502.0 9.875 7.625 6360.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3 - 7 ARE DIRECTIONALWITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. 1D-141 FINAL WELLBORE IS TIED INTO 1D-141PB1 AT THE KICKOFF POINT. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS, ALASKA INC. OF 11/13/00. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM 1D-141PB1 AT 6630' MD, 3827' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 7 REPRESENT WELL 1D-141 WITH API 50-029-22967-00. THIS WELL REACHED A TOTAL DEPTH OF 9550' MD, 3779' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 610.0 9497.0 RPD 620.5 9504.0 RPM 620.5 9504.0 RPS 620.5 9504.0 RPX 620.5 9504.0 ROP 656.5 9549.5 FET 656.5 9504 . 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 610.0 4870.0 4 4870.5 6416.0 5 6416.5 6510.0 6 6510.5 6629.5 7 6630.0 9549.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 610 9549.5 ROP MWD FT/H 4.5 1353.1 GR MWD API 19.21 199.59 RPX MWD OHMM 0.35 447.83 RPS MWD OHMM 0.45 1715.18 RPM MWD OHMM 0.51 2000 RPD MWD OHMM 0.49 2000 FET MWD HR 0.18 100 Mean Nsam 5079.75 17880 122.591 17787 66.0135 17775 25.503 17768 36.4405 17768 47.3667 17768 56.3082 17768 1.30944 17696 First Reading 610 656.5 610 620.5 620.5 620.5 620.5 656.5 Last Reading 9549.5 9549.5 9497 9504 9504 9504 9504 9504 First Reading For Entire File .......... 610 Last Reading For Entire File ........... 9549.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous.File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 610.0 RPM 620.5 RPS 620.5 RPD 620.5 RPX 620.5 ROP 656.5 FET 656.5 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 4825.0 4834.5 4834.5 4834.5 4834.5 4870.0 4834.5 il-AUG-00 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL'STANDOFF (IN): EWR FREQUENCY (Hz): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 4.05.2 65.41 Memory 4870.0 8.3 61.4 TOOL NUMBER PB01592HWGVR6 PB01592HWGVR6 9.875 LSND 9.40 130.0 9.5 700 6.0 2.800 2.159 2.100 3.100 75.0 99.3 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 610 4870 ROP MWD030 FT/H 4.5 736.62 GR MWD030 API 19.21 199.59 RPX MWD030 OHMM 0.35 447.83 RPS MWD030 OHMM 0.45 1715.18 RPM MWD030 OHMM 0.51 2000 RPD MWD030 OHMM 0.49 2000 FET MWD030 HR 0.18 10.96 Mean Nsam 2740 8521 117.757 8428 66.8203 8431 27.7614 8429 47.7173 8429 67.9245 8429 84.5552 8429 0.588371 8357 First Reading 610 656.5 610 620.5 620.5 620.5 620.5 656.5 Last Reading 4870 4870 4825 4834.5 4834.5 4834.5 4834.5 4834.5 First Reading For Entire File .......... 610 Last Reading For Entire File ........... 4870 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........ ...STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4825.5 6369.0 RPM 4835.0 6379.0 RPS 4835.0 6379.0 RPX 4835.0 6379.0 FET 4835.0 RPD 4835.0 ROP 4870.5 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6379.0 6379.0 6416.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 13-AUG-00 Insite 4.05.2 65.41 Memory 6416.0 58.6 85.6 TOOL NUMBER PB01592HWGVR6 PB01592HWGVR6 9.875 6360.0 LSND 9.50 63.0 9.3 400 3.8 3.000 2.275 5.000 3.500 78.0 105.0 78.0 78.0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HR Min Max Mean Nsam 4825.5 6416 5620.75 3182 6.26 1353.1 103.1 3092 29.16 114.95 74.1257 3088 3.04 69.63 11.3686 3089 2.98 74.38 12.1239 3089 3.26 65.98 12.2485 3089 4.15 66.87 12.8965 3089 0.19 24.01 1.31523 3089 First Reading 4825.5 4870.5 4825.5 4835 4835 4835 4835 4835 Last Reading 6416 6416 6369 6379 6379 6379 6379 6379 First Reading For Entire File .......... 4825.5 Last Reading For Entire File ........... 6416 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6369.5 6457.5 FET 6379.5 6464.5 RPD 6379.5 6464.5 RPM 6379.5 6464.5 RPS 6379.5 6464.5 RPX 6379.5 6464.5 ROP 6416.5 6510.0 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS Data Format Specification Record 17-AUG-00 Insite 4.05.2 65.44 Memory 6510.0 88.4 88.4 TOOL NUMBER PB1600HAGRV4 PB1600HAGRV4 6.000 BARADRIL-N 9.00 50.0 9.5 13500 8.0 .240 .188 .350 .180 72.0 93.9 72.0 75.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HR Min Max Mean Nsam 6369.5 6510 6439.75 282 7.04 273.42 101.302 188 44.84 65.01 54.9477 177 7.72 22.58 10.0253 171 8.37 23.75 10.1894 171 9.22 23 10.7105 171 10.35 20.72 11.5713 171 0.48 100 44.1987 171 First Reading 6369.5 6416.5 6369.5 6379.5 6379.5 6379.5 6379.5 6379.5 Last Reading 6510 6510 6457 5 6464 5 6464 5 6464 5 6464 5 64 64 5 First Reading For Entire File .......... 6369.5 Last Reading For Entire File ........... 6510 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6458.0 6629.5 RPM 6465.0 6629.5 RPS 6465.0 6629.5 RPD 6465.0 6629.5 FET 6465.0 6629.5 RPX 6465.0 6629.5 ROP 6510.5 6629.5 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 18-AUG-00 Insite 4.05.2 65.44 Memory 6630.0 89.9 95.9 TOOL NUMBER PB1600HAGRV4 PB1600HAGRV4 6.000 BARADRIL-N 9.00 53.0 9.0 14000 8.0 .160 .126 .200 .110 68.0 88.0 64.0 68.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 6458 6629.5 ROP MWD060 FT/H 5.36 313.66 GR MWD060 API 44.16 77.84 RPX MWD060 OHMM 7.7 49.11 RPS MWD060 OHMM 8.92 100.26 RPM MWD060 OHMM 9.06 122.39 RPD MWD060 OHMM 9.47 54.01 FET MWD060 HR 0.32 18.36 Mean 6543.75 139.804 61.2403 13.5615 14.9436 16.4152 16.0475 5.77712 Nsam 344 239 344 330 330 330 330 330 First Reading 6458 6510.5 6458 6465 6465 6465 6465 6465 Last Reading 6629 5 6629 5 6629 5 6629 5 6629 5 6629 5 6629 5 6629.5 First Reading For Entire File .......... 6458 Last Reading For Entire File ........... 6629.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 6630.0 9504.0 RPM 6630.0 9504.0 RPS 6630.0 9504.0 RPX 6630.0 9504.0 GR 6630.0 9497.0 ROP 6630.0 9549.5 FET 6630.0 9504.0 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: 21-AUG-00 Insite 4.05.2 65.44 Memory 9550.0 87.1 94.7 TOOL NUMBER PB1600HAGRV4 PB1600HAGRV4 6.000 BARADRI L-N 9.00 53.0 9.0 14000 8.0 .160 .126 .200 68.0 88.0 64.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .110 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HR 4 1 68 28 8 68.0 Name Service Unit Min Max DEPT FT 6630 9549.5 ROP MWD070 FT/H 6.26 596.06 GR MWD070 API 37.36 90.82 RPX MWD070 OHMM 6.15 131.54 RPS MWD070 OHMM 8.3 179.8 RPM MWD070 OHMM 9.43 2000 RPD MWD070 OHMM 10.32 2000 FET MWD070 HR 0.2 10.3 Mean Nsam 8089.75 5840 139.869 5840 61.0871 5735 30.9322 5749 34.987 5749 38.9619 5749 41.8605 5749 0.822341 5749 First Reading 6630 6630 6630 6630 6630 6630 6630 6630 Last Reading 9549.5 9549.5 9497 9504 9504 9504 9504 9504 First Reading For Entire File .......... 6630 Last Reading For Entire File ........... 9549.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/08 Maximum PhYsical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/05/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/05/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File ;Z -tt Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Apr 25 19:25:34 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 1D-141 PB1 500292296770 PHILLIPS Alaska, Inc. Sperry Sun 25-APR-01 MWD RUN 3 MWD RUN 4 MWD RUN 5 AK-MM-00127 AK-MM-00127 AK-MM-00127 A. WEAVER R. MCNEILL R. MCNEIL D. WESTER D. WESTER D. HEIM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 6 AK-MM-00127 R. MCNEILL D. HEIM 14 liN 10E 12 595 0 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 101.05 70.70 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 10.750 502.0 9.875 7.625 6360.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3 - 6 ARE DIRECTIONALWITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D.. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 11/13/00. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 6 REPRESENT WELL 1D-141PB1 WITH API % 50-029-22967-70. THIS W REACHED A TOTAL DEPTH OF 6902' MD, 3804' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX ROP FET $ START DEPTH STOP DEPTH 610.0 6849.5 620.5 6856.5 620.5 6856.5 620.5 6856.5 620.5 6856.5 656.5 6901.5 656.5 6856.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 610.0 4870.0 4 4870.5 6416.0 5 6416.5 6510.O 6 6510.5 6901..5 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam First Reading Last Reading DEPT FT 610 6901.5 ROP MWD FT/H 4.5 1353.1 GR MWD API 19.21 199.59 RPX MWD OHMM 0.35 447.83 RPS MWD OHMM 0.45 1715.18 RPM MWD OHMM 0.51 2000 RPD MWD OHMM 0.49 2000 FET MWD HR 0.18 100 3755.75 12584 113.726 12491 68.7225 12480 22.6709 12473 36.4287 12473 50.2226 12473 61.682 12473 1.53066 12401 610 656.5 610 620.5 620.5 620.5 620.5 656.5 6901 5 6901 5 6849 5 6856 5 6856 5 6856 5 6856 5 6856 5 First Reading For Entire File .......... 610 Last Reading For Entire File ........... 6901.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 610.0 4825.0 RPX 620.5 4834.5 RPS 620.5 4834.5 RPM 620.5 4834.5 RPD 620.5 4834.5 FET 656.5 4834.5 ROP 656.5 4870.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): il-AUG-00 Insite 4.05.2 65.41 Memory 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 4870.0 8.3 61.4 TOOL NUMBER PB01592HWGVR6 PB01592HWGVR6 9.875 LSND 9.40 130.0 9.5 700 6.0 2.800 2.159 2.100 3.100 75.0 99.3 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 24 28 Name Service Unit Min Max DEPT FT 610 4870 ROP MWD030 FT/H 4.5 736.62 GR MWD030 API 19.21 199.59 RPX MWD030 OHMM 0.35 447.83 RPS MWD030 OHMM 0.45 1715.18 RPM MWD030 OHMM 0.51 2000 RPD MWD030 OHMM 0.49 2000 FET MWD030 HR 0.18 10.96 Mean Nsam 2740 8521 117.757 8428 66.8203 8431 27.7615 8429 47.7173 8429 67.9245 8429 84.5552 8429 0.588371 8357 First Reading 610 656.5 610 620.5 620.5 620.5 620.5 656.5 Last Reading 4870 4870 4825 4834.5 4834.5 4834.5 4834.5 4834.5 First Reading For Entire File .......... 610 Last Reading For Entire File ........... 4870 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 ServiCe Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4825.5 6369.0 RPS 4835.0 6379.0 FET 4835.0 6379.0 RPD 4835.0 6379.0 RPX 4835.0 6379.0 RPM 4835.0 6379.0 ROP 4870.5 6416.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type. .... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 13-AUG-00 Insite 4.05.2 65.41 Memory 6416.0 58.6 85.6 TOOL NUMBER PB01592HWGVR6 PB01592HWGVR6 9.875 LSND 9.50 63.0 9.3 400 3.8 3.000 2.275 5.000 3.500 78.0 105.0 78.0 78.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HR Min 4825.5 6.26 29.16 3.04 2.98 3.26 4.15 0.19 Max 6416 1353.1 114 95 69 63 74 38 65 98 66 87 24 01 Mean Nsam 5620.75 3182 103.11 3092 74.1258 3088 11.3686 3089 12.124 3089 12.2485 3089 12.8965 3089 1.31479 3089 First Reading 4825.5 4870.5 4825.5 4835 4835 4835 4835 4835 Last Reading 6416 6416 6369 6379 6379 6379 6379 6379 First Reading For Entire File .......... 4825.5 Last Reading For Entire File ........... 6416 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ............ ' .... LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6369.5 6457.5 FET 6379.5 RPX 6379.5 RPS 6379.5 RPD 6379.5 R?M 6379.5 ROP 6416.5 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6464.5 6464.5 6464.5 6464.5 6464.5 6510.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 17-AUG-00 Insite 4.05.2 65.44 Memory 6510.0 88.4 88.4 TOOL NUMBER PB1600HAGRV4 PB1600HAGRV4 6.000 BARADRIL-N 9.00 50.0 9.5 13500 8.0 .240 .188 .350 .180 72.0 93.9 72.0 75.0 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD050 FT/H 4 1 68 MWD050 API 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 6369.5 6510 ROP MWD050 FT/H 7.04 273.42 GR MWD050 API 44.84 65.01 RPX MWD050 OHMM 7.72 17.54 RPS MWD050 OHMM 8.37 20.23 RPM MWD050 OHMM 9.22 20.5 RPD MWD050 OHMM 10.35 17.98 FET MWD050 HR 0.48 100 Mean 6439.75 101.299 54.8969 9.99579 10.1688 10.6959 11.553 44.5598 Nsam 282 188 177 171 171 171 171 171 First Reading 6369.5 6416.5 6369.5 6379.5 6379.5 6379.5 6379.5 6379.5 Last Reading 6510 6510 6457.5 6464.5 6464.5 6464.5 6464.5 6464.5 First Reading For Entire File .......... 6369.5 Last Reading For Entire File ........... 6510 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6458.0 6849.5 RPD 6465.0 6856.5 RPM 6465.0 6856.5 RPS 6465.0 6856.5 RPX 6465.0 6856.5 FET 6465.0 6856.5 ROP 6510.5 6901.5 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 18-AUG-00 Insite 4.05.2 65.44 Memory 6902.0 89.9 95.9 TOOL NUMBER PB1600HAGRV4 PB1600HAGRV4 6.000 BARADRIL-N 9.00 53.0 9.0 14000 8.0 .160 .126 .200 .110 68.0 88.0 64.0 68.0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 AP1 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 6458 6901.5 6679.75 888 ROP MWD060 FT/H 5.36 313.66 115.234 783 GR MWD060 API 43.49 117.7 71.0164 784 RPX MWD060 OHMM 4.46 83.35 15.237 784 RPS MWD060 OHMM 4.8 100.26 16.5514 784 RPM MWD060 OHMM 4.99 122.39 18.1459 784 R?D MWD060 OHMM 5.12 70.78 18.9172 784 FET MWD060 HR 0.32 18.36 3.04029 784 First Reading 6458 6510.5 6458 6465 6465 6465 6465 6465 Last Reading 6901.5 6901.5 6849.5 6856.5 6856.5 6856.5 6856.5 6856.5 First Reading For Entire File .......... 6458 Last Reading For Entire File ........... 6901.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/04/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
