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Home My WebLink About204-238• • MICRC3FILMED 03/01/2t~48 yam .. ~ ~~~t ~~" DO Nt~T PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl~eiC~rPgs_Inserts\Arlicrofilm Marker.doc Ã b ~~k, DATA SUBMITTAL COMPLIANCE REPORT 3/7/2007 Permit to Drill 2042380 Well Name/No. KUPARUK RIV UNIT 1 D-28L 1 Operator CONOCOPHILLlPS ALASKA INC 51'~ "0 I...... 2.~\ Co( API No. 50-029-23237-60-00 MD 11663./ TVD 6601/ Completion Date 1/26/2005'- Completion Status 1-01L Current Status 1-01L UIC N ----------~------_.._. - -----------..-- ------------------.- REQUIRED INFORMATION Mud Log No Samples No Directional surv~_ --- --- -- ------ _·_________._·__··~·___~.________~____w____. - - - - - - ------------------------------------- - DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: (data taken from Logs Portion of Master Well Data Maint _______ n___________ Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments --------.- 11099 11663 Open 3/29/2005 11099 11663 Open 3/29/2005 MWD 118 11663 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics 6553 11663 Open 1/29/2007 LIS Veri, GR, FET, ROP, NCNT, NPHI, RHOB, DRHO w/Graphics 6553 11663 Open 3/11/2005 GR, EWR4, ABI, CNP, SLD, ROP, PWD 0 0 Open 3/11/2005 -. ~''--_._'--------- Sample Interval Set Start Stop Sent Received Number Comments e Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~D __________n______________________________________________________ D Asc Directional Survey X'D D Asc Directional Survey ~D C Lis 13699 Induction/Resistivity u6' C Las 14433 Induction/Resistivity ;,;t.6 D Lis 13090 Induction/Resistivity J..p(pt 13090 LIS Verification Well Cores/Samples Information: Name - Well Cored? ADDITIONAL INFORMATION y,Q) Daily History Received? (þ/N f)N Chips Received? ~ Formation Tops Analysis Received? ~ __ .____ ___,,___"'~.m...._ ". _.. ~________ _____.__"___~__.__._____..__._.._____m____~________..__.________________ -- -------------- -- - - ----. --------------------------------------------------- --- Comments: Permit to Drill 2042380 MD 11663 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3/7/2007 Well Name/No. KUPARUK RIV UNIT 1D-28L1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23237-60-00 6601 p:;;on Date 1/26/2005 Current Status 1-01L UIC N Date: 7 M~ At) (:) 7 Completion Status 1-01L e -- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21_L1_L2_L3, 1D-28_L1, 1F-01A, 3F-19A, 3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 IB-15A: dÓ"!-;;)5"C'o 11: ¡t.../¿../2D Digital Log Images: 50-029-23465-01 ""'O~ç / 0 d. '''''D£)-034 90S- -100. f;)OS" -10 I 1 Q - cI J I ¡'-ILl ?/-/ J44?:t) /4LJ3Io I¿./L/g+ 1 CD Rom 1C-21 L1 L2 L3: - - - Digital Log Images: 50-029-23253-00,60,61,62 1 CD Rom 1D-28 L1: Digital Log Images: 50-029-23237-00, 60 96</ -f);371 f}o4 -~3'1r /'-/4;Jd ¡l..IL!33 1 CD Rom IF-01A: ;)OS- -OlfJ d ¡4Lld?) Digital Log Images: 50-029-20889-01 1 CD Rom 3F-19A: f)O'-( -(:)/{,o P-fLß.l31 Digital Log Images: 50-029- 22680-01 1 CD Rom 3H-14B: 060 -Oéil it /4LlêA Digital Log Images: 50-103-20092-02 1 CD Rom I( . . WELL LOG TRANSMITTAL 6204 -;)38 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 10 (P q0 RE: MWD Formation Evaluation Logs 1D-28 Ll, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 ID-28 Ll: LAS Data & Digital Log Images: 50-029-23270-60 1 CD Rom Ð(ffi~LJ) ~\ 0Ð\Dw . . 24-Feb-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 D-28 L 1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,099.62' MD 0.00' MD 11,663.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /1 / Date ). ~ tv'l«tÀi)\\Ç- Signed ~ 6JlJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) d (:)~, - À 3 8 . . 24-Feb-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 10-28 L 1 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,099.62' MD 0.00' MD 11,663.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 :0/ Date l. 9 jlI)fN1J~Gá ¡- Signed ~'I1vJ û1LJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ?-(jUI-Æ~3 . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG' Gas U Plugged 0 Abandoned U Suspended 0 WAG 0 20AAC 25.105 20AAC 25.110 No. of Completions _ Other P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 357' FNL, 419' FEL, Sec. 23, T11N, R10E, UM At Top Productive Horizon: 1 a. Well Status: Oil 0 GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: 5. Date Comp.. Susp., or Aband.: January 26, 2005 6. Date Spudded: / December 20, 2004 7. Date TD Reached: /' 5959309 5960234 5960183 January 12, 2005 8. KB Elevation (ft): 34' RKB 9. Plug Back Depth (MD + lVD): N/A 10. Total Depth (MD + lVD): 11663' MD I 6601' TVD Total Depth: 499' FSL, 2381' FWL, Sec. 18, T11N, R11E, UM 441' FSL, 1920' FEL, Sec. 18, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- TPI: x- 568743 y- Total Depth: x- 569390 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes, Dens/Neu 22. CASING SIZE wr. PER FT. 91.5# 45.5# 29.7# GRADE H-40 L-80 L-80 20" 10.75" 7-5/8" feet MSL Permafrost: 1810' MD /<.t.J,-, 1~/'f¡-:~^" .A"þ _ v/S'e}D' ., ~.!.'" ;¿."/¿ -0:- CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM 34' 118' 34' 118' 34' 6581' 34' 4426' 34' 11065' 34' 6587' Zone- 4 Zone- 4 Zone- 4 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A HOLE SIZE 13.5" 9-7/8" 23. Perforations open to Production (MD + lVD of Top and Bottom Interval, Size and Number; if none, state "none"): open hole completion 24. SIZE 4.5" "-;.........c, 1 b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic TestD 12. Permit to Drill Number: ./ 204-238 I 13. API Number: 50-029-23237-60 14. Well Name and Number: 1 D-28L 1 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25650 & 28243 17. Land Use Permit: ALK 468 & 3814 20. Thickness of CEMENTING RECORD AMOUNT PULLED 30" 16 cu yds ABI Type III 837 sx AS Lite, 485 sx LiteCrete 52 bbls Class G TUBING RECORD DEPTH SET (MD) 10974' I PACKER SET 10941', 11880', 13522' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a RBDMS 8Ft 1 7 2005 NONE o J~L 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 7, 2005 Oil Producer - shares production with 1 D-28 Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 2/9/2005 9.5 hours Test Period --> 771 699 131 100% Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 350 psi 780 24-Hour Rate -> 1810 1899 330 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet. if necessary). Submit core chips; if none. state "none". Form 10-407 Revised 12/2003 CONTINUED ON REVERSE IGAS-O'L RATIO 1049 ...."---_._--. "'.. J COI~P! >::l",rw ' 1 .. ,ÿ, 1..1:. ¡l,,<¡ " I DA'·.... ! 1" 'n:: ;"," I , I. ,2..(. . c:,. í I ¡ , " 6 VEBlBEO þ~ ß "r1_..., -.. &F GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 D-28L 1 Top Kuparuk C Base Kuparuk C 11010' 11633' 6578' 6601' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry @ 265-6869 Printed Na~ Ra~dV Thomas Signature \ ~ \ La . Title: Greater KUDaruk Area Drillina Team Leader Phone z..... 6 r ~-iI ?» C) Date ~ ø íoJ" Prepared by Sharon AlIstÌ{rDrake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Halliburton Sperry-Sun Western North Slope ConocoPhillips 1 D-28L 1 . Job No. AKZZ3444739, Surveyed: 12 January, 2005 Survey Report 9 February, 2005 Your Ref: API 500292323760 Surface Coordinates: 5959309.20 N, 560670.72 E (70· 17' 57.8051" N, 149· 30' 31.1262" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 104. 65ft above Mean Sea Level . sperara\l-SUI! CAlL-LING seAVlces A Halliburton Company Survey Ref: svy2111 Halliburton Sperry-Sun Survey Report for 1 D-28L 1 Your Ref: API 500292323760 Job No. AKZZ3444739, Surveyed: 12 January, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11099.62 86.050 87.380 6482.63 6587.28 864.29 N 8168.10E 5960239.41 N 568831.57 E 8212.04 Tie On Point '"- 11147.69 86.310 87.450 6485.83 6590.48 866.46 N 8216.01 E 5960241.96 N 568879.47 E 0.560 8259.96 11196.04 87.770 91.710 6488.33 6592.98 866.81 N 8264.28 E 5960242.70 N 568927.73 E 9.302 8308.09 11244.34 87.350 93.700 6490.39 6595.04 864.53 N 8312.48 E 5960240.82 N 568975.95 E 4.207 8355.92 11291.07 86.980 96.690 6492.70 6597.35 860.31 N 8358.96 E 5960236.97 N 569022.46 E 6.439 8401.87 . 11338.23 88.030 96.120 6494.75 6599.40 855.05 N 8405.78 E 5960232.09 N 569069.32 E 2.533 8448.07 11388.57 88.520 96.560 6496.27 6600.92 849.49 N 8455.79 E 5960226.94 N 569119.37 E 1.308 8497.42 11436.16 89.950 96.750 6496.90 6601.55 843.98 N 8503.05 E 5960221.80 N 569166.68 E 3.031 8544.04 11484.01 90.250 97.860 6496.82 6601.47 837.90 N 8550.51 E 5960216.10 N 569214.19 E 2.403 8590.81 11533.75 89.630 100.520 6496.87 6601.52 829.95 N 8599.61 E 5960208.56 N 569263.35 E 5.491 8639.06 11578.99 90.120 102.280 6496.97 6601.62 821.01 N 8643.95 E 5960199.97 N 569307.76 E 4.038 8682.48 11663.00 90.120 102.280 6496.79 6601.44 803.14 N 8726.04 E 5960182.77 N 569389.99 E 0.000 8762.74 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 85.110· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11663.00ft., The Bottom Hole Displacement is 8762.92ft., in the Direction of 84.741· (True). '. 9 February, 2005 -16:54 Page 2 of3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1D-28L 1 Your Ref: API 500292323760 Job No. AKZZ3444739, Surveyed: 12 January, 2005 ConocoPhi/lips Western North Slope Comments Measured Depth (ft) Station Coordinates rvD Northings Eastings (ft) (ft) (ft) Comment 11099.62 11663.00 6587.28 6601.44 864.29 N 803.14 N 8168.10 E Tie On Point 8726.04 E Projected Survey . Survey tool program for 1 D-2811 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 257.00 0.00 257.00 256.98 11663.00 256.98 CB-GYRO-SS (10-28) 6601.44 MWD+IIFR+MS+SAG (1 D-28) . 9 February, 2005 -16:54 Page 3 of3 Dril/Quest 3.03.06.008 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-28 1 0-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/18/2004 21 :00 - 00:00 3.00 MOVE DMOB MOVE Secured 1 H-05a well site, prepped and skidded rig floor to center of module, cleared around rig and pad, pulled rig off well, loaded rig mats for transport to 1 D pad, moved rock washer away from rig, and held a PJSM with crew coming on tour. 12/19/2004 00:00 - 01 :00 1.00 MOVE DMOB MOVE PJSM on rig move, load shims in pipe shed, clear pad entrance for rig, prep beaver slide for moving. 01 :00 - 06:00 5.00 MOVE MOVE MOVE Notify Kuparuk base and move rig from 1 H pad to KCC parking lot, with snow blower escort to keep drifts down. Turn rig around for intersection , notify Kuparuk base, move rig from KCC to 1 D pad, with snow blower escort. 6 mile move. 06:00 - 08:00 2.00 MOVE POSN MOVE Clear snow from well site #28 and around camp with loaders and snow blower. 08:00 - 10:30 2.50 MOVE POSN MOVE Set rig mats, spot rig over conductor #28, shim level. Skid rig floor over cellar. Accept rig @ 09:00 hrs on 12/19/2004. 10:30 - 11 :30 1.00 DRILL RIRD RIGUP Hook up steam lines service and mud lines to rig floor. 11 :30 - 18:00 6.50 DRILL RIRD RIGUP N/U diverter, 21 1/4" Hydril and 16" diverter tube. Button up cellar area for high winds, remove snow from conductor and cellar box. Locate drill pipe on pad, clear snow and load 5" DP in shed. Cut off riser tube to fit, C/O saver sub on top drive, perform derrick inspection, RIU rig floor for P/U 5" DP, on-load spud mud. 18:00 - 00:00 6.00 DRILL PULD RIGUP P/U 5" DP drifting same, stnd back in derrick, DP packed with snow, thawing with steam in pipeshed, conductor had ice plug and M/U stnds in mouse-hole, for a total of 32 stnds out of 64 needed. 12/20/2004 00:00 - 06:30 6.50 DRILL PULD SURFAC Cont. P/U 5" DP and HWDP, stnd back in derrick. 06:30 - 07:30 1.00 DRILL OTHR SURFAC Cut and slip drill line. 07:30 - 09:00 1.50 DRILL PULD SURFAC P/U and M/U MWD tools, bit, mud mtr, stabs and x-o's. 09:00 - 10:30 1.50 DRILL SFTY SURFAC RIU slick-line unit for gyro, hold pre-spud mtng, function test diverter system, fill conductor with mud-no leaks, AOGCC witness waived by John Spalding. 10:30 -12:00 1.50 DRILL DRLG SURFAC Spud in at 118', drill to 169' and take gyro survey, cont drilling to 219'. 12:00 - 13:00 1.00 DRILL TRIP SURFAC POOH stnd back 2 stnds HWDP. 13:00 - 14:00 1.00 DRILL PULD SURFAC M/U MWD and orient, M/U non-mag flex DC's. 14:00 - 00:00 10.00 DRILL DRLG SURFAC Cont drilling from 219' to 258' and take gyro survey. Cont drilling to 985' MD/966' TVD with MWD survey's, P/U wt 93K, SIO wt 91 K, ROT wt 93K, torque on bot 5K, torque off bot 2K, 60 RPM, 25K on bit, pump psi on bot 1,580, pump psi off bot 1,240, ART=3.86 hrs, AST=4.04 hrs, ADT=7.90 hrs. 12/21/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC PTSM, Directional Drill 13-1/2" OH from 985'MD(920'TVD) to 2,385'MD(2,020'TVD). ART= 3.8 hrs, AST= 4.5 hrs, ADT= 8.3 hrs, ROP= 170' FPH, PUW= 105k, SOW= 92k, ROTW= 100k, TKOFFBTM= 3k, TKONBTM= 6k, PPOFFBTM= 1,700 psi, PPONBTM= 2,020 psi @ 525 GPM. 12:00 - 00:00 12.00 DRILL DRLG SURFAC PTSM, Directional Drill 13-1/2" OH from 2,385'MD(2,020'TVD) to 3,615'MD(2,740'TVD). Observed Gas Hydrates from 2,503'MD(2,100'TVD) to 2,896'MD(2,340'TVD), Max 1,600 Units. ART= 2.3 hrs, AST= 6.1 hrs, ADT= 8.35 hrs, ROP= 150' FPH, PUW= 140k, SOW= 95k, ROTW= 112k, TKOFFBTM= 7k, TKONBTM= 9k, PPOFFBTM= 1,720 psi, PPONBTM= 1,960 psi @ 525 GPM. 12/22/2004 00:00 - 03:30 3.50 DRILL DRLG SURFAC PTSM, Directional Drill 13-1/2" OH from 3,615'MD(2,740'TVD) to 3,986'MD(2,955'TVD). Achieved Directional requirements. 03:30 - 05:30 2.00 DRILL CIRC SURFAC Circulate bottoms up 2X, Rotate and reciprocate drillstring. Hole in good condition. 05:30 - 08:30 3.00 DRILL TRIP SURFAC Pump out of hole from 3,986' to the BHA. Printed: 1/31/2005 3:04:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-28 10-28 ROT - DRilLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/22/2004 08:30 - 10:00 1.50 DRILL PULD SURFAC Stand back HWDP and DC's. Lay Down UBHO sub and break off bit. 10:00 - 11 :00 1.00 DRILL PULD SURFAC M/U new 13-1/2" Bit, Reset BH on MM to 1.5? Orientate MWD Tool, RIH with DC's and HWDP. 11:00 -12:00 1.00 DRILL TRIP SURFAC RIH with BHA #2. Shallow test MWD at 1,700', OK. RIH to 2,768'. 12:00 -13:00 1.00 DRILL TRIP SURFAC PTSM, RIH to 3,986', Wash down last stand. Hole in good condition. 13:00 - 00:00 11.00 DRILL DRLG SURFAC Directional Drill 13-112" OH from 3,986'MD(2,955'TVD) to 5,298'MD(3,680'TVD). ART= 6.95 hrs, AST= 1.02 hrs, ADT= 7.97 hrs, ROP= 165' FPH, PUW= 155k, SOW= 105k, ROTW= 127k, TKOFFBTM= 8k, TKONBTM= 10k, PPOFFBTM= 2,120 psi, PPONBTM= 2,350 psi @ 550 GPM. 12/23/2004 00:00 - 01 :30 1.50 DRILL DRLG SURFAC PTSM, Drill 13-1/2" OH from 5,298' to 5,391', No signal from MWD Tool 01 :30 - 02:30 1.00 DRILL DEQT SURFAC Attempt to re-establish signal from MWD Tool, NO-GO. 02:30 - 03:30 1.00 DRILL CIRC SURFAC Circulate Bottoms up. Rotate and Reciprocate Drillstring. Hole in good condition. 03:30 - 05:00 1.50 DRILL TRIP SURFAC Flow Check, OK, Pump out from 5,391' to 3,700'. Hole in good condition. 05:00 - 06:30 1.50 DRILL TRIP SURFAC Flow check, OK, POH on elevators, WET, to HWDP, hole in good condition. 06:30 - 07:00 0.50 DRILL TRIP SURFAC Stand back HWDP, Jars, and De's. 07:00 - 08:00 1.00 DRILL PULD SURFAC Break off bit, Break out and lay down Mud Motor and MWD Tool. 08:00 -10:30 2.50 DRILL PULD SURFAC M/U new MWD Tool, Mud Motor, and rerun Bit#2. Orient MWD Tool. M/U DC's, Jars, and HWDP. Shallow Test MWD Tool, OK. 10:30 - 12:00 1.50 DRILL TRIP SURFAC RIH with BHA #3, Fill pipe, Rih to 4,547' 12:00 - 12:30 0.50 DRILL TRIP SURFAC PTSM, RIH from 4,547' to 5,391, Wash last stand to btm. Hole in good condition. 12:30 - 00:00 11.50 DRILL DRLG SURFAC Directional Drill 13-1/2" OH from 5,391 'MD(3, 740'TVD) to 6,426'MD(4,391'TVD). ART= 7.77 hrs, AST= 1.41 hrs, ADT= 7.77 hrs, ROP= 145' FPH, PUW= 175k, SOW= 1115k, ROTW= 140k, TKOFFBTM= 11 k, TKONBTM= 12k, PPOFFBTM= 2,350 psi, PPONBTM= 2,600 psi @ 550 GPM. 12/24/2004 00:00 - 02:30 2.50 DRILL DRLG SURFAC Directional Drill 13-1/2" OH from 6,426'MD(4,391'TVD) to 6,591'MD(4,426'TVD). ART= 1.88 hrs, AST= 0 hrs, ADT= 1.88 hrs, ROP= 88' FPH, PUW= 175k, SOW= 1115k, ROTW= 140k, TKOFFBTM= 11 k, TKONBTM= 12k, PPOFFBTM= 2,350 psi, PPONBTM= 2,600 psi @ 550 GPM. 02:30 - 05:00 2.50 DRILL CIRC SURFAC Circulate And Condion Mud - Circulate 2 X Bottoms Up While Rotating And Reciprocating the Drill String - 565 GPM With 2,300 Psi. At 100 RPM 05:00 - 06:30 1.50 DRILL WIPR SURFAC Monitor The Well Bore (Static) - Pump Out Of The Hole From 6,591' To Above The Last Bit Trip Depth To 5,140' - No Problems On Trip 06:30 - 07:00 0.50 DRILL WIPR SURFAC RIH From 5,140' To 6,591' With No Problems - As Precaution Wash Last Stand To Bottom 07:00 - 09:00 2.00 DRILL CIRC SURFAC Circulate And Condion Mud - Circulate 1.5 X Bottoms Up While Rotating And Reciprocating the Drill String - 565 GPM With 2,300 Psi. At 100 RPM - 210 Units Of Gas On Bottoms Up 09:00 - 11 :30 2.50 DRILL REAM SURFAC Monitor The Well Bore (Static) - Pump Out Of The Hole From 6,591' To Above The Ugnu Formation To 4,040' - No Problems On Trip 11 :30 -13:00 1.50 DRILL CIRC SURFAC Circulate Hole Clean - Monitor The Well Bore (Static) - Pump Dry Job - Blow Down Surface Equipment 13:00 - 15:30 2.50 DRILL TRIP SURFAC POH With The 13 1/2" Directional Drilling Assembly BHA NO.3 From 4,040' To 700' With No Problems 15:30 - 17:00 1.50 DRILL PULD SURFAC Stand Back The 5" HWDP And Daily Drilling Jars - Lay Down The 8" Flex Collars, Sperry Sun MWD Tools - Drain Mud Motor And Remove Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-28 10-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/24/2004 15:30 - 17:00 1.50 DRILL PULD SURFAC Bit - Clear Directional BHA From Rig Floor And Wash Down Same. 17:00 - 17:30 0.50 CASE SFTY SURFAC Hold Pre-Job Safety Meeting With All Crew Members 17:30 - 19:30 2.00 CASE RURD SURFAC RIU casing running equipment. 19:30 - 22:00 2.50 CASE RUNC SURFAC RIH with 10.75" 45# L-80 BTC Casing, installed bow spring centralizers on the first 13 jts in the hole. Check floats, OK. 22:00 - 23:15 1.25 CASE OTHR SURFAC While running in the hole with 10.75" Casing Driller observed a decrease in slack off weight. Driller was picking up casing string (+1- 5') when casing collar snagged riser which in turn separated flow line from riser. This resulted in the uncontrolled discharge of 2 gals of drilling mud from the flow line into the well cellar area. Approximately 1/2 gal of drilling mud spilled out of secondary containment onto the snow and gravel pad, 3 sq ft area. Material was immediately cleaned up with a Vac truck and will be properly disposed offsite. All proper notifications were communicated. 23:15 - 00:00 0.75 CASE RUNC SURFAC RIH with 10.75" 45# L-80 BTC Casing. Special Drift 9.875". 12/25/2004 00:00 - 04:00 4.00 CASE RUNC SURFAC PTSM,RIH with 10?" 45# L-80 BTC Casing. Special Drift 9.875". Total jts. run, 161. 04:00 - 04:30 0.50 CASE RUNC SURFAC M/U Landing Jt and FMC Mandrel Casing Hgr. Break circ at 30 spm at 430 psi SOW 160k ,Unable to reciprocate casing. 04:30 - 05:00 0.50 CASE RUNC SURFAC Continue circulating and land 10?" Casing with mandrel hgr. Float Shoe at 6,581'MD. 05:00 - 06:00 1.00 CASE CIRC SURFAC Circulate casing vol., start at 3.3 bpm 280 psi, slowly ramp pumps up to 7.5 bpm 720 psi. 06:00 - 06:30 0.50 CEMENT CIRC SURFAC Lay down top drive casing fill up tool. Make up Schlumberger plug dropping cement head with plugs preloaded. 06:30 - 09:00 2.50 CEMENT CIRC SURFAC Circulate casing vol. 1.5x @ 75 spm 480 psi. Unable to reciprocate casing. 09:00 - 09:30 0.50 CEMENTSFTY SURFAC Held PJSM on cement job with Rig crew, Schlumberger Cement crew, and AES Trucking Support Crew while circulating casing. 09:30 - 14:30 5.00 CEMENT PUMP SURFAC Shut down circulating, Flush out mud pumps with water. Switch to Schlumberger, pump 5 bbls water, Test surface lines to 2,500 psi. Pump 50 bbls CW100 followed by 50 bbls mud push. Kick out btm plug. Mix and pump 653 bbls (825 sx) lead cement slurry at 10.7 ppg. followed by 185 bbls (462 sx) tail cement slurry at 12.5 ppg. Schlumberger kick out top plug with 20 bbls water. Switch over to rig pumps, displace cement to float shoe at 6 bpm 980 psi. FICP prior to bumping plug 1,980 psi. Bump plug with 2,450 psi. Floats held. CIP at 14:00 hrs. Observed 410 bbls cement returns back to surface. Rig down cement lines and plug dropping head. 14:30 - 16:30 2.00 CEMENTRURD SURFAC Flush out diverter system and all surface equipment. Back out and lay down landing joint. Clear rig floor of all casing handling tools. 16:30 - 17:30 1.00 CEMENT RURD SURFAC PJSM, Nipple Down flow line, 20" riser, Hydril, and diverter line. Clear celler area. 17:30 - 19:00 1.50 WELLSR NUND SURFAC M/U FMC Gen 'V' Wellhead System. Test seal to 1,000 psi, OK 19:00 - 23:00 4.00 WELCTL NUND SURFAC Nipple up BOPE, C/O choke hose spool. 23:00 - 00:00 1.00 WELCTL BOPE SURFAC M/U test joint and plug, Set test plug. RIU surface equipment to test BOPE. 12/26/2004 00:00 - 06:30 6.50 WELCTL BOPE SURFAC PTSM, Test BOPE 250/3,500 psi. AOGCC PI , Jeff Jones, waived witnessing test. 06:30 - 07:00 0.50 WELCTL BOPE SURFAC Pull test plug, set wear ring. 07:00 - 08:00 1.00 DRILL PULD SURFAC P/U BHA # 4, Strap and caliper BHA equipment. 08:00 - 10:30 2.50 DRILL TRIP SURFAC M/U 9-7/8" HTC PDC Bit, RIH with BHA # 4. Shallow test MWD Tool, OK. Printed: 1/3112005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/26/2004 10:30 - 11 :30 1.00 DRILL TRIP SURFAC RIH picking up 4" drill pipe from pipe shed. 11 :30 - 12:00 0.50 WAlTON WOW SURFAC Suspend rig operations due to hi-winds and phase 3 driving conditions. 12:00 - 16:30 4.50 WAlTON WOW SURFAC PTSM, Suspend rig operations due to hi-winds and phase 3 driving conditions. 16:30 - 20:30 4.00 DRILL TRIP SURFAC RIH, Stage in, Break circ every 1,000', RIH to 6,345' 20:30 - 22:00 1.50 RIGMNT RSRV SURFAC PJSM, Slip and cut drilling line. Service top drive, blocks, and drawworks. 22:00 - 23:00 1.00 DRILL SFTY SURFAC Conduct table top stripping drill with all drilling crew members. Review CPAI drills and expectations SOP. 23:00 - 00:00 1.00 WAlTON WOW SURFAC Suspend rig operations due to hi-winds and phase 3 driving conditions. 12/27/2004 00:00 - 01 :00 1.00 WAlTON WOW SURFAC PTSM, Suspend rig operations due to hi-winds and phase 3 driving conditions. Conduct table top stripping drill with all drilling crew members. Review CPAI drills and expectations SOP. 01 :00 - 02:00 1.00 CASE CIRC SURFAC Weather conditions improved. Currently phase 2 conditions. Mobilize AES Vac Trucks for mud displacement. 02:00 - 02:30 0.50 CASE CIRC SURFAC RIH, tag semi-firm cement and top of float collar at 6,494', 02:30 - 05:30 3.00 CASE CIRC SURFAC Circulate and condition mud for casing test. 05:30 - 06:30 1.00 CASE DEQT SURFAC Rig up test equipment. Chart 2,500 psi 10-3/4" casing test for 30 min. Good test. Rig down test equipment. 06:30 - 09:00 2.50 DRILL OTHR SURFAC Drill out float collar (6,494'), float shoe (6,580' ), and 20' new 9-7/8" OHt06,611'. 09:00 - 11 :00 2.00 DRILL CIRC SURFAC Circulate and condition mud for LOT. Change mud over to 9.8 ppg LSND mud system. 11 :00 - 12:00 1.00 DRILL LOT SURFAC Rig up test equipment. Chart LOT as per CPAI procedure. Observed LO at 1,140 surface pressure. MWE at 4,420' TVD = 14.8 ppg. Rig down test equipment. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 6,611'MD (4,430' TVD) to 7,377'MD ( 4,826'TVD). ART= 7.78 hrs, AST= 1.22 hrs, ADT= 9 hrs, ROP= 85' FPH, PUW= 200k, SOW= 108k, ROTW= 140k, TKOFFBTM= 11k, TKONBTM= 12k, PPOFFBTM= 3,210 psi, PPONBTM= 2,930 psi @ 575 GPM. 12/28/2004 00:00 - 06:30 6.50 DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/8" OH from 7,377'MD (4,826? TVD) to 7,683'MD (5,010?TVD). ART= 4.26 hrs, AST= .68 hrs, ADT= 4.94 hrs, ROP= 62' FPH, PUW= 200k, SOW= 108k, ROTW= 140k, TKOFFBTM= 11 k, TKONBTM= 12k, PPOFFBTM= 3,210 psi, PPONBTM= 2,930 psi @ 575 GPM. Observed decrease in ROP. Adjusted drilling parameters in effort to increase ROP. No Change. Consult with CPAI Drilling Engineer. Decision was made to trip for new bit. Stop drilling at 7,683'MD. 06:30 - 08:00 1.50 DRILL TRIP INTRM1 Flow check well, static, POH, Pump out with top drive to 10-3/4" casing shoe at 6,580'. 08:00 - 11 :00 3.00 DRILL TRIP INTRM1 Flow check well, static, Mix and pump dry job, POH on elevators to BHA. Hole in good condition. 11 :00 - 12:00 1.00 DRILL TRIP INTRM1 Stand Back BHA, Break off bit. 9-7/8" PDC bit balled up and 2 jet nozzles plugged off. 12:00 - 13:30 1.50 DRILL TRIP INTRM1 PTSM, M/U new 9-7/8" HTC MX-C1 Tri-cone Rock Bit. RIH with BHA. M/U top drive. Break circulation and shollow test MWD tool. OK. Blow down top drive. 13:30 - 15:30 2.00 DRILL TRIP INTRM1 RIH, fill drillpipe. M/U top drive. Wash down last stand to bottom at 7,683'. Hole in good condition. 15:30 - 00:00 8.50 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 7,683'MD (5,010? TVD) to 8,215 'MD (5,341?TVD). ART= 4 hrs, AST= .42 hrs, ADT= 4.42 hrs, ROP= 120' Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocoph¡lIips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/28/2004 15:30 - 00:00 8.50 DRILL DRLG INTRM1 FPH, puw= 225k, sow= 108k, ROTW= 145k, TKOFFBTM= 12k, TKONBTM= 13k, PPOFFBTM= 3,200 psi, PPONBTM= 3,450 psi @ 560 GPM. 12/29/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/8" OH from 8,215'MD(5,341? TVD) to 8,820 'MD (5,690?TVD). ART= 4.6 hrs, AST= 1.57 hrs, ADT= 6.17 hrs, ROP= 98' FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM= 14k, TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,450 psi @ 560 GPM. Precautionary backream after each stand is drilled down for hole cleaning. Raising mud density as per well plan weight up schedule. 12:00 - 20:00 8.00 DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/8" OH from 8,820'MD(5,690? TVD) to 9,061'MD (5,826?TVD). ART= 3.20 hrs, AST= 1.47 hrs, ADT= 4.67 hrs, ROP= 57' FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM= 14k, TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,5400 psi @ 560 GPM. Precautionary backream after each stand is drilled down for hole cleaning. Raising mud density as per well plan weight up schedule. Hole packing off. Reduce circulating rate. Work pipe. 20:00 - 22:30 2.50 DRILL CIRC INTRM1 Slowly increase pump rate while cleaning up hole. Rotate and reciprocate drill string. Circulate and condition mud at drilling rate. CBU 2X. Hole conditions improved. Discussed hole conditions with CPAI Drilling Engineer. Decision was made to trip drill string to 10-3/4" casing shoe. 22:30 - 00:00 1.50 DRILL TRIP INTRM1 POH, wiper trip to casing shoe. Pump out with top drive at 450 gpm, 2,600 psi. Hole in good condition. 12/30/2004 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 PTSM,POH, wiper trip to 10-3/4" casing shoe. Pump out with top drive at 450 gpm, 2,600 psi. Hole in good condition. 01 :00 - 02:30 1.50 DRILL CIRC INTRM1 Circulate and condition mud at 10-3/4" casing shoe. Reciprocate drill string with 9-7/8" bit and mud motor outside casing shoe. Observed increase in cuttings at shakers while circulating btms up. Circulating rate 135 spm, 3,650 psi, 570 gpm. Hole conditions improved. 02:30 - 04:00 1.50 DRILL TRIP INTRM1 Flow check, static, RIH, M/U top drive. Wash down last stand to btm at 9,061'. Hole in good condition. 04:00 - 12:00 8.00 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 9,061'MD(5,826? TVD) to 9,491'MD (6,045?TVD). ART= 4.8 hrs, AST= .74 hrs, ADT= 5.54 hrs, ROP= 78' FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM= 14k, TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,540 psi @ 560 GPM. Hole conditions improved after wiper trip. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/8" OH from 9,491'MD(6,045'TVD) to 1 0,088'MD (6,337?TVD). ART= 5.16hrs, AST= 4.05hrs, ADT= 9.21 hrs, ROP= 65' FPH, PUW= 190k, SOW= 135k, ROTW= 160k, TKOFFBTM= 9k, TKONBTM= 10k, PPOFFBTM= 3,640 psi, PPONBTM= 3,890 psi @ 560 GPM. Start sliding at 10,008'MD(6,337'TVD) with mud motor to obtain directional objective at casing point. Precautionary backream after each slide for hole cleaning. Good hole conditions while sliding. 12/31/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/8" OH from 10,088'MD(6,337'TVD) to 10,566'MD (6,500?TVD). ART= 4.74hrs, AST= 3.65hrs, ADT= 8.39hrs, ROP= 60' FPH, PUW= 207k, SOW= 127k, ROTW= 1152k, TKOFFBTM= 12k, TKONBTM= 13k, PPOFFBTM= 3,490 psi, PPONBTM= 3,700 psi @ 560 GPM. Continue to slide 2/3 of each stand drilled down to achieve directional objectives. Precautionary backream each slide for hole cleaning. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/8" OH from 10,566'MD(6,500'TVD) to 10,879'MD (6,560?TVD). ART= 6.26hrs, AST= 1.57hrs, ADT= 7.83hrs, Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 12/31/2004 12:00 - 00:00 12.00 DRILL DRLG INTRM1 ROP= 50' FPH, PUW= 210k, SOW= 130k, ROTW= 160k, TKOFFBTM= 10k, TKONBTM= 15k, PPOFFBTM= 3,420 psi, PPONBTM= 3,550 psi @ 560 GPM. Geological markers 50' TVD deeper. Extend TD to 50' MD below top "C4" marker. 1/1/2005 00:00 - 03:00 3.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/8" OH from 10,879'MD(6,560'TVD) to 10,924'MD (6,567?TVD). ART= 2.02hrs, AST= .52hrs, ADT= 2.54hrs, ROP= 18' FPH, PUW= 195k, SOW= 130k, ROTW= 160k, TKOFFBTM= 13k, TKONBTM= 14k, PPOFFBTM= 3,500 psi, PPONBTM= 3,550 psi @ 560 GPM. ROP decreased. Stop drilling at 10,924'. Prepare to make trip for new bit. 03:00 - 04:00 1.00 DRILL CIRC INTRM1 Circulate Bottoms up. 125 spm at 3,670 psi. Rotate and reciprocate drill string while circulating. Hole in good condition. 04:00 - 09:00 5.00 DRILL TRIP INTRM1 POH, Pump out at drilling rate to 10-3/4" casing shoe at 6,580'. 09:00 - 10:00 1.00 DRILL CIRC INTRM1 Circulate bottoms up at casing shoe 1.5X. Observed increase in cuttings at btms up. Circulate until hole cleans up. 125 spm at 3,450 psi. Rotate and reciprocate drill string, with bit and motor outside casing shoe, while circulating. Hole in good condition. 10:00 - 12:00 2.00 DRILL TRIP INTRM1 Flow check, well static, Mix and pump dry job, POH to 3,400' 12:00 - 13:30 1.50 DRILL TRIP INTRM1 PTSM, POH to BHA 13:30 - 14:30 1.00 DRILL TRIP INTRM1 Stand back HWDP and flex collars, Break off bit, M/U new bit. 14:30 - 16:00 1.50 DRILL DEQT INTRM1 Download MWD Tool in rotary table. 16:00 - 17:30 1.50 DRILL PULD INTRM1 C/O MWD pulsor and logging tool. M/U new collar. Orient Mudmotor. 17:30 - 18:00 0.50 DRILL DEQT INTRM1 Upload MWD Tool in rotary table. 18:00 -18:30 0.50 DRILL TRIP INTRM1 RIH with new bit, flex collars, and HWDP from derrick. 18:30 - 19:00 0.50 DRILL DEQT INTRM1 Shallow test MWD tool, OK 19:00 - 22:00 3.00 DRILL TRIP INTRM1 RIH, P/U 9 jts. 4" drillpipe. Lay down 2 jts 5" drillpipe, pin end had washout. RIH to 6,538', fill pipe. 22:00 - 23:00 1.00 DRILL OTHR INTRM1 PJSM, Slip and cut drilling line. 23:00 - 00:00 1.00 DRILL OTHR INTRM1 Service Rig.Perform weekly rig inspection. 1/2/2005 00:00 - 02:00 2.00 DRILL TRIP INTRM1 PTSM, RIH to 10,200', tight hole conditions, M/U top drive. Wash thru tight hole, OK, Wash down to 10,650'. MADD pass depth. 02:00 - 04:00 2.00 DRILL DEOT INTRM1 Wash down +1- 200'/hr. MADD Pass from 10,650' to 10,924'. 04:00 - 10:30 6.50 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH to 11 ,075'(6,587'TVD) TD as per onsite Geologist.Top of "C4" sand 11,01 O'(6,578'TVD). AST=1.06 hrs, ART=3.25 hrs, ADT=4.31 hrs.ROP= 35'/hr.PUW=220k, SOW=120k, ROTW=160k, TQOFFBTM=13k, TQONBTM=14k, PPOFFBTM=3,410 psi, PPONBTM=3,600 psi. 10:30 - 12:00 1.50 DRILL CIRC INTRM1 Circulate and condition mud 2X, Rotate and reciprocate drill string. 90 RPM, 11k TO, 550 GPM at 3,750 psi. 12:00 - 13:00 1.00 DRILL CIRC INTRM1 PTSM, Circulate and condition mud 2X, Rotate and reciprocate drill string. 90 RPM, 11 k TO, 550 GPM at 3,750 psi. Take SPR, Flow check, Static. 13:00 - 19:00 6.00 DRILL TRIP INTRM1 POH, Pump out with top drive to 10-3/4" casing shoe. Hole in good condition. 19:00 - 20:30 1.50 DRILL CIRC INTRM1 Circulate and condition mud, Circulate bottoms up at 550 gpm, 3,380 psi. Hole in good condition. Flow check, static. Mix and pump dry job. 20:30 - 21 :30 1.00 DRILL PULD INTRM1 POH, lay down 5" drillpipe. 21 :30 - 22:00 0.50 DRILL PULD INTRM1 Change out pipe handling equipment to 4". 22:00 - 23:30 1.50 DRILL TRIP INTRM1 POH, stand back 4" drillpipe. 23:30 - 00:00 0.50 DRILL PULD INTRM1 Change out pipe handling equipment to 5". POH, lay down 5" HWDP. 1/3/2005 00:00 - 01 :00 1.00 DRILL PULD INTRM1 PTSM, POH, Lay down 5" HWDP & Flex collars. 01 :00 - 01 :30 0.50 DRILL DEQT INTRM1 Down load MWD in rotary table. 01 :30 - 02:00 0.50 DRILL PULD INTRM1 Lay down BHA, break off bit. Printed: 1/31/2005 3:04:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-28 10-28 ROT - DRilLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/312005 02:00 - 02:30 0.50 CASE RURD INTRM1 Pull wear ring, set test plug. 02:30 - 03:30 1.00 CASE RURD INTRM1 C/O top rams in BOP stack to 7-5/8". Test doors seals to 1,500 psi, OK, Pull test plug. 03:30 - 04:30 1.00 CASE RURD INTRM1 RlU 7-5/8" casing running tools and equipment. 04:30 - 04:45 0.25 CASE SFTY INTRM1 PJSM with all crew members on running 7-5/8" casing. 04:45 - 10:00 5.25 CASE RUNC INTRM1 RIH with 7-5/8" casing to 10-3/4" casing shoe at 6,581'. 10:00 - 11 :00 1.00 CASE CIRC INTRM1 Circulate casing volume at 70 spm 730 psi. 11 :00 - 12:00 1.00 CASE RUNC INTRM1 Run 7-5/8" casing into open hole section to 8,200'. Hole in good condition. 12:00 - 14:00 2.00 CASE RUNC INTRM1 PTSM, Run 7-5/8" casing to 11,065'. Hole in good condition. Land on FMC mandrel casing hanger. Reciprocate casing, PUW 315k, SOW 150k. 14:00 - 14:30 0.50 CASE RURD INTRM1 Lay down top drive casing fill up tool. M/U Schlumberger cement head with plugs loaded. 14:30 - 17:30 3.00 CEMENTCIRC INTRM1 Circulate and reciprocate casing. Break circulation at 3 bpm 400 psi. Slowly ramp pump up to 7 bpm at 650 psi. PUW 290k, SOW 140k. CBU 2X. Hole in good condition. 17:30 - 18:00 0.50 CEMENT PUMP INTRM1 PJSM, Schlumberger pump 5 bbls water. PT cement lines to 4,000 psi. Pump 40 bbls CW-100, Pump 40 bbls mud push II spacer at 12.5 ppg. Drop btm plug, Pump 52 bbls class 'G' cement at 15.8 ppg. Kick out top plug with 10 bbls water. Yield of 1.16 cu ftlsx, additives .3% D065 + .4% D165 + .2% D046 + .02% B155. Continue to reciprocate casing. Hole in good condition. 18:00 - 19:30 1.50 CEMENTDISP INTRM1 Displace cement with rig pumps at 7 bpm 500 psi. Bump plug after 495 bbls mud pumped. Pressure up to 2000 psi. Hold for 5 min. OK. CIP at 19:25 hrs. Continued reciprocating casing during displacement. Landed casing prior to bumping the plug. 19:30 - 20:30 1.00 CEMENT SEOT INTRM1 Floats did not hold, slight flow back. Pressure up on casing to 500 psi. Bleed off pressure. Floats held. 20:30 - 21 :00 0.50 CEMENT RURD INTRM1 Rig down cement head and surface lines. Break out and lay down landing joint. Flush stack. 21 :00 - 22:00 1.00 CASE RURD INTRM1 Rig down casing elevators, long bales, clear rig floor of all casing handling tools. 22:00 - 22:30 0.50 CASE NUND INTRM1 Install 7-5/8" FMC Packoff. Test to 5,000 psi, hold for 10 min, OK. Bleed off test pressure. Secure wellhead. 22:30 - 23:30 1.00 CASE RURD INTRM1 PJSM, set test plug, Change rams in BOP stack. Remove 7-5/8" rams, install 3-1/2" x 6" VBR. 23:30 - 00:00 0.50 DRILL PULD INTRM1 Install short bales, rig up 5" drillpipe handling equipment. 1/4/2005 00:00 - 06:00 6.00 DRILL PULD INTRM1 BID and UD 5" DP from mouse hole. 06:00 - 08:00 2.00 DRILL OTHR INTRM1 C/O saver sub, bell guide and back-up jaws on top drive, from 5" to 4". 08:00 - 12:30 4.50 DRILL OTHR INTRM1 RlU for BOP testing, test annular at 250 and 2,500 psi, BOP, top drive and choke valves at 250 and 3,500 psi. RID test equip. Tested all OK with state witness. 12:30 - 13:30 1.00 DRILL RIRD INTRM1 Pull test plug, install wear ring, blow down circ lines, install short bales and 4" elevators. 13:30 - 17:00 3.50 DRILL PULD INTRM1 M/U mule shoe and P/U RIH with 4" DP from pipeshed to 4,400'. 17:00 - 17:30 0.50 DRILL CIRC INTRM1 Circ surface to surface. 17:30-21:30 4.00 DRILL PULD INTRM1 Cont P/U and RIH, from 4,400' to 10,600' with 4" DP from pipeshed. 21 :30 - 23:00 1.50 DRILL CIRC INTRM1 RlU and circ surf to surf, at 380 GPM with 2,600 psi, 50 RPM with 7K torque 23:00 - 00:00 1.00 DRILL TRIP INTRM1 POOH from 10,600' to 7,700' and stnd back in derrick. 1/5/2005 00:00 - 02:00 2.00 DRILL TRIP INTRM1 Cont POOH from 7,700' stnd back 4" DP. 02:00 - 06:00 4.00 DRILL PULD INTRM1 P/U and M/U BHA #7, up-load MWD and surface test at 50 SPM with Printed: 1/3112005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-28 1 0-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/512005 02:00 - 06:00 4.00 DRILL PULD INTRM1 850 psi., load nuke source. 06:00 - 09:30 3.50 DRILL TRIP INTRM1 RIH with BHA #7, filling DP every 25 stnds, to 10,900'. 09:30 - 11 :00 1.50 DRILL CIRC INTRM1 Circ surface to surface at 61 SPM with 2,350 psi, 60 RPM with 9K torque. 11:00 -12:00 1.00 DRILL DEOT INTRM1 RIU and test casing to 3,500 psi for 30 min on chart. Test OK. 12:00 - 14:00 2.00 DRILL OTHR INTRM1 Cut and slip drill line, inspect brake bands and linkages, service rig and top drive. 14:00 - 16:00 2.00 DRILL DRLG INTRM1 RIH and tag float collar at 10,976', drill out float collar and cement to 11,063'. WOB=1 OK, 246 GPM with 2,700 psi, 60 RPM with 11 K torque. 16:00 - 18:30 2.50 DRILL CIRC INTRM1 Pump 35 bbl high vis sweep/spacer and displace well to 10.1 ppg Flo-Pro, ICP 1,800 psi at 246 GPM, 60 RPM with 11 K torque, FCP 2,080 psi at 246 GPM, 60 RPM with 6K torque. 18:30 - 19:00 0.50 DRILL DRLG INTRM1 Drill out float shoe and new hole to 11,095'. Pulled up into casing. 19:00 - 23:00 4.00 DRILL CIRC INTRM1 Circ and cond mud for FIT at 254 GPM with 2,000 psi, 60 RPM with 6K torque. Mud weight dropped due to lost calcium carb over shakers, reduced screens from 180's to 100's and continuously adding S200 to maintain 10.1 ppg in/out. 23:00 - 00:00 1.00 DRILL FIT INTRM1 RIU and perform FIT to 12.5 EMW. Press up to 820 psi at surface with 10.1 ppg. 75/8" shoe at 11,065' md 16,585' tvd. 1/6/2005 00:00 - 02:00 2.00 DRILL OTHR PROD Clean pits in preparation for mud swap from Flo-Pro to LSND. 02:00 - 08:00 6.00 DRILL CIRC PROD Circ out of pit #1 at 35 SPM with 1,000 psi while bypassing shakers, to reduce loss of weight material. Cont cleaning pits. 08:00 - 09:30 1.50 DRILL CIRC PROD On-load LSND mud into clean pits while eire, and build Safe-Sure pill. 09:30 - 13:00 3.50 DRILL CIRC PROD Displace well with 450 bbls 10.1 ppg LSND mud, chase with 30 bbl Safe-Sure pill followed by 40 bbl Hi-Vis pill at 65 SPM with 2,150 psi RPM at 60 with 7K torque. P/U wt 165K, S/O wt 11 OK, ROT wt 130K with 1 OK torque. 13:00 - 17:00 4.00 DRILL TRIP PROD Check for flow, hole static, obtain SPR and POOH from 11,060' to 245'. 17:00 - 18:00 1.00 DRILL TRIP PROD PJSM on nuke source, stnd back jars and flex DC's, UD MWD and motor. 18:00 - 19:00 1.00 DRILL PULD PROD Clean and clear floor, P/U and M/U bit and scraper assem. 19:00 - 00:00 5.00 DRILL REAM PROD Wash and ream to mechanicaly clean casing with scraper at 275 GPM, 20 RPM at 1.5 min per stnd to 5,300'. 1/7/2005 00:00 - 05:30 5.50 DRILL REAM PROD Cont wash and ream to mechanicaly clean casing with scraper at 275 GPM with 1,310 psi, 15 RPM with 5K torque from 5,300' to 11,075'. 05:30 - 06:30 1.00 DRILL CIRC PROD CBU while rot and recip at 15 RPM and 11 K torque, 65 SPM at 1,270 psi. 06:30 - 09:00 2.50 DRILL CIRC PROD Pump 30 bbl hi-vis sweep followed by 220 gal Super Pickle casing cleaner and chase with 30 bbls hi-vis sweep at 65 SPM with 1,280 psi., 20 RPM with 11 K torque while rot and recip. Obtain SPR, check for flow, hole static, pump dry job. 09:00 - 13:00 4.00 DRILL TRIP PROD POOH from 11,075' to 263'. 13:00 - 13:30 0.50 DRILL PULD PROD Stnd back jars and De's, UD scraper assem. 13:30 - 16:00 2.50 DRILL PULD PROD P/U motor, bit and stab, orient MWD, up-load and surface test MWD, PJSM and load nuke source. 16:00 - 21 :00 5.00 DRILL TRIP PROD RIH from 245' to 10,981 filling DP every 20 stnds, and wash from 10,981' to 11,095'. 21 :00 - 22:30 1.50' DRILL CIRC PROD CBU while rot and recip from 11,065' to 11,095' at 245 GPM with 1,980 psi. 22:30 - 00:00 1.50 DRILL CIRC PROD Displace well with 10.1 ppg Flo-Pro mud (no lubricants) at 250 GPM with 2,100 psi., rot and recìp at 60 RPM with 11 K torque. P/U wt 205K, S/O wt 95K, Rot wt 130K. 1/8/2005 00:00 - 00:30 0.50 DRILL CIRC PROD I Continue displacement of well with 10.1 ppg Flo-Pro mud (no Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/812005 00:00 - 00:30 0.50 DRILL CIRC PROD lubricants) at 250 GPM with 2,100 psi., rot and recip at 60 RPM until Flo-Pro cleared the bit, then increased RPM to 80 with 11 K torque. P/U wt 205K, S/O wt 95K, Rot wt 130K. Clean hole ECD at 10.9 ppg. 00:30 - 12:00 11.50 DRILL DRLG PROD UD top single and drill production from 11,095' to 11,436' and monitor well for 20 min. Cont drilling from 11,436' to 11,454'. P/U wt 165K, S/O wt 108K, ROT wt 132K, wt on bit 4K, torque on bott 10K, torque off bott 10K, ART = 4.15 hrs, AST = 3.29 hrs, ADT = 7.44 hrs 12:00 - 16:30 4.50 DRILL DRLG PROD Cont drilling production from 11,454' to 11,554'. PIU wt 175K, SIO wt 110K, ROT wt 135K, wt on bit 7K, torque on bott 11 K, torque off bott 7K, ART = 5.29 hrs, AST = 4.89 hrs, ADT = 10.18 hrs. Entire field now in phase 3 condition. 16:30 - 00:00 7.50 WAlTON WOW PROD WOW, CBU and recip DP working low side of hole at 200 GPM with 1,680 psi., attempting to drop angle from +90? to 87? 1/9/2005 00:00 - 05:00 5.00 WAlTON WOW PROD Phase 3 weather cond, cont trenching low side to drop INC to 87? INC I at 90.04? P/U wt 175K, S/O wt 110K, ROT wt 135K, torque 8K off bott. 05:00 - 07:00 2.00 WAlTON WOW PROD CBU 2x at 275 GPM, with 2,500 psi while rot and recip at 80 RPM. 07:00 - 16:00 9.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 87? INC at 89.96? 16:00 - 17:00 1.00 WAlTON WOW PROD CBU 1x at 275 GPM, with 2,500 psi while rot and recip at 50 RPM, torque at 6K off bolt. 17:00 - 00:00 7.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 87? INC holding at 89.96? P/U wt 175K, S/O wt 11 OK, ROT wt 135K, torque at 8K off bolt, 199 GPM with 1,680 psi., obtained SPR. 1/10/2005 00:00 - 09:00 9.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 87? INC holding at 89.96? P/U wt 160K, SIO wt 110K, ROT wt 135K, torque at 8K off bolt, 64 SPM with 2,300 psi. Still in phase 3 weather condo 09:00 - 21 :00 12.00 DRILL DRLH PROD Time drill from 11,554' to 11,573'. Lost high line power at 10:30 am, switched to rig and camp generators. ABI increased from 90.2? to 90.9? in the last 15' drilled. Total slide hrs = 17.91, Total rot hrs = 5.04. 21 :00 - 00:00 3.00 DRILL TRIP PROD Flow check, hole static, Pump OOH from 11,573' to 10,981' at 250 GPM, and check for flow, hole static, cont POOH wet from 10,981' to 5,400'. 1/11/2005 00:00 - 02:00 2.00 DRILL TRIP PROD Cont POOH from 5,400' to BHA. 02:00 - 04:00 2.00 DRILL PULD PROD Stand back jar's and DC's, PJSM remove nuke source, dwn load MWD, UD motor and bit. 04:00 - 07:00 3.00 DRILL PULD PROD M/U bit, motor and MWD, orient-program-function test MWD, PJSM load nuke source, M/U DC's and jars. 07:00 - 10:30 3.50 DRILL TRIP PROD RI H with BHA #10 from 250' to 11,106' filling every 25 stnds. 10:30 - 16:00 5.50 DRILL CIRC PROD CBU 1x at 275 GPM with 2,760 psi, while rot and recip at 30 RPM and 6K torque. Blow dwn top drive. Pull into shoe to 11,060' and monitor well. Circ through mud cross and cont WOW. 16:00 - 17:00 1.00 DRILL CIRC PROD P/U one single 4" DP and work pipe from 11,075' to 11,109' while CBU at 275 GPM with 2,660 psi and rotlrecip at 30 RPM and 6K torque. UD single, blow dwn top drive. 17:00 - 21 :00 4.00 DRILL CIRC PROD Pull into shoe and cont circ across the top, at 11,060'. 21 :00 - 22:00 1.00 DRILL CIRC PROD RIH to 11,109' and CBU while rotlrecip at 275 GPM with 2,700 psi at 30 RPM and 6K torque. 22:00 - 23:30 1.50 DRILL OTHR PROD Slip and cut drill line, inspect brake bands and linkage, lubricate draw-works and top drive. 23:30 - 00:00 0.50 DRILL TRIP PROD RIH from 11,040' to 11,573' washing the last 20' to bolt. to resume drilling. 1/12/2005 00:00 - 02:00 2.00 DRILL DRLG PROD Slide from 11,573' to 11,603' with a 1.76? bend on motor. INC increased from 90.3? to 90.48? in 30' drilled. Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/12/2005 02:00 - 02:30 0.50 DRILL TRIP PROD Pumped OOH from 11,603' to 11,140' at 275 GPM. 02:30 - 07:00 4.50 DRILL OTHR PROD Trench low side from 11,140' to 11,170' for side track. Applied weight to bit and attempted to drill to 11,200'. 07:00 - 11 :00 4.00 DRILL TRIP PROD Pump OOH from 11,200' to 11,040', check for flow, hole static, blow dwn top drive and POOH wet from 11,040' to BHA. 11:00 -13:30 2.50 DRILL PULD PROD Stand back jars and DC's, PJSM and remove nuke source, UD MWD, increase bend in motor from 1.76? to 2.0?, CIO bit from PDC to Mill Tooth, M/U MWD, orient and pulse test OK, PJSM and load nuke source, MIU DC's and jars. 13:30 - 18:00 4.50 DRILL TRIP PROD RIH from 243' to 11,603' filling DP every 25 stnds, washing from 11,554' to 11,603'. 18:00 - 20:00 2.00 DRILL DRLG PROD Drilled from 11,603' to 11,632', INC dropped from 90.48? to 90.16?, called town for engineer's recomendation, drilled from 11,632' to 11,663', INC increased from 90.16? to 91.12? 20:00 - 21 :00 1.00 DRILL TRIP PROD Pump OOH at 250 GPM, from 11,663' to 11,140' as per engineer's recomendation, to trench for OHST. 21 :00 - 00:00 3.00 DRILL OTHR PROD Trenching low side of hole from 11,140' to 11,170' with Mill Tooth bit and 2? bend in motor, INC at 86.2?, 69 SPM with 2,840 psi, P/U wt = 170K, S/O wt = 115K, AST = 2.4 hrs. 1/13/2005 00:00 - 00:30 0.50 DRILL OTHR PROD Cont trenching from 11,140' to 11,170' 00:30 - 04:00 3.50 DRILL OTHR PROD Side track from 11,170' to 11,211', 5K on bit, 70 SPM with 3,000 psi, dropped INC from 86? to 83? 04:00 - 04:30 0.50 DRILL CIRC PROD CBU 1x at 300 GPM with 3,000 psi and recip DP. 04:30 - 05:00 0.50 DRILL TRIP PROD Pump OOH from 11,211' to 11,070' and flow check, hole static, blow dwn top drive. 05:00 - 08:30 3.50 DRILL TRIP PROD POOH from 11,070' to BHA. 08:30 - 10:00 1.50 DRILL PULD PROD Stand back jars and DC's, PJSM and remove nuke source, drain-down load-and UD MWD, UD Mill Tooth bit. 10:00-11:30 1.50 DRILL PULD PROD M/U PDC, change motor angle to 1.5?, M/U-orient-prgram and function test MWD, PJSM and load nuke source, M/U DC's and jars. 11:30 -15:30 4.00 DRILL TRIP PROD RIH with BHA #12 from 243' to 10,979' filling DP every 25 stnds. 15:30 - 16:00 0.50 DRILL OTHR PROD Service rig and top drive. 16:00 - 16:30 0.50 DRILL TRIP PROD Cont RIH through shoe at 11,065', orient low side and slide into OHST at 11,170' with no pump, tag bott at 11,211'. 16:30 - 00:00 7.50 DRILL DRLG PROD Drill from 11,211' to 11,423' MD/6,600' TVD, at 80 RPM, 64 SPM with 3,040 psi, bit wt 8K, P/U wt = 165K, SIO wt = 11 OK, AST 3.39 hrs, ART 1.25 hrs, ADT 4.64 hrs. 1/14/2005 00:00 - 19:00 19.00 DRILL DRLG PROD Cont drilling from 11,423' to 12,040" wt on bit 8K, 65 SPM with 2,900 psi, 70 RPM, flow return rate dropped from 22% to 15%, with a drilling break from 12,040' to 12,043'. TPV from 626 bbls to 614 bbls for a 12 bblloss. P/U wt 175K, S/O wt 118K with no pump. 19:00 - 20:00 1.00 DRILL DRLG PROD P/U and monitored hole for 5 min, tag bott and resumed drilling slowly, 64 SPM at 3,855 psi with ROP of 52' to 12,077' with 33 bbls lost, P/U and monitored hole for 10 min, fluid loss at 24 bph static, 96 bph dynamic, resumed pump rate to 64 SPM with 2,900 psi, flow rate at 19%, drilled to 12,089' 20:00 - 22:30 2.50 DRILL CIRC PROD POOH to the above thief zone at 12,040', and build a 40 bbl cal/carb LCM pill with 10.5 wt and 50 vis. Pump 30 bbls of pill at 20: 15 hrs, at 14 SPM with 684 psi for 1,320 strokes and H20 off, as pill cleared bit increased H20 to 10 gpm, 22 RPM with 7K torque, recip DP pumping at 1.4 bpm staging pump rate to 60 SPM with 2,350 psi, return flow rate at 19%. 22:30 - 23:00 0.50 DRILL CIRC PROD Shut dwn pump and H20 with bit at 12,026' and monitor static loss at 6 Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-28 10-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/14/2005 22:30 - 23:00 0.50 DRILL CIRC PROD bph. 23:00 - 23:30 0.50 DRILL CIRC PROD Drill ahead from 12,089' to 12,100' at 74 RPM with a 10 bblloss in the last 10' drilled. 23:30 - 00:00 0.50 DRILL TRIP PROD Pump OOH to 11,400', at a low pump rate of 40 SPM with 1,432 psi, to spot cal/carb pill as per LCM decision tree. 189 bbls loss total at 00:00 hrs. Total slide hrs 9.95, total rot hrs 7.19, total drlng hrs 17.14 1/15/2005 00:00 - 00:30 0.50 DRILL CIRC PROD Cont pump OOH from 11,400' to 11,253'. Pumped #2 cal/carb pill at 250 GPM with 2,172 psi, started H20 at 20 gpm, at 1,320 strokes pill exiting drill string, slowed pump rate to 1.5 bpm to spot pill below bit. 00:30 - 01 :00 0.50 DRILL TRIP PROD Pump OOH and into casing at 10,970 40 SPM with 1,432 psi. 01 :00 - 03:00 2.00 DRILL OTHR PROD Blow dwn top drive, close bag, RlU and perform hesitation squeeze of LCM pill #2, down DP and back side, at 200 psi, 250 psi and 300 psi, 4x at each pressure range. Squeezed 12 bbls in 1 hour. RID circ lines, blow dwn surface equip and on-load 225 bbls Flo-Pro. 03:00 - 04:00 1.00 DRILL TRIP PROD RIH, orient through side track, KIU and wash last stnd to bott at 57 SPM with 2,100 psi with no problems. 04:00 - 04:30 0.50 DRILL DRLG PROD Tagged bott at 12,100', slide to 12,113' with 5K on bit, ROP at 90 fph. At 12,113' encountered drilling break with 0 wt on bit, return flow dropped from 19% to 0%, with a loss of 18 bbls. 04:30 - 06:00 1.50 DRILL CIRC PROD Built LCM pill #3 as per Engineer and lost circ decision tree, pumped pill #3 at 10.5 ppg and 50 vis, 39 SPM with 1,310 psi, rot and recip, return flow rate of 0% to 9% as pill exited bit, reduced pump rate to 14 SPM at 610 psi. 06:00 - 07:30 1.50 DRILL CIRC PROD Shut dwn pump, pull BHA above LCM to 11,729' and monitor well, 24 bph static 96 bph dynamic loss rates. Pump LCM pill #4 with 10.4 ppg and 59 vis, reducing pump rate to 1.5 bpm until pill cleared bit, shut dwn and monitor to allow pill to reach thief zone. 07:30 - 18:30 11.00 DRILL CIRC PROD POOH to shoe with no problem, monitor well with loss of 30 bph static, pump LCM pill #5, static loss at 24 bph, pump LCM pill #6 while recip drill string, reduce mud wt to 9.9 ppg in pits, static loss at 18 bph, pump LCM pill #7 with static loss at 18 bph, pump LCM pill #8 with static loss at 24 bph/18 bph/24 bph/and 12 bph doing 10 min checks, RlU and squeeze pill into formation for a loss of 8.5 bbls away at 300 psi at 1 bpm, static loss at 18 bpm. 18:30 - 20:30 2.00 DRILL TRIP PROD Orient MWD to low side and RIH to 12,027', attempt to break eire, pressured up to 3,300 psi with no indication of eire, POOH 5 stnds to 11,520', filling hole on back side, attempt to break eire, DP pressured up to 4,000 psi with no indication of circ or press loss. 20:30 - 00:00 3.50 DRILL TRIP PROD POOH from 12,034' to 2,324' wet, due to plugged BHA, contacted AOGCC Rep of up coming BOP test, calculated hole fill = 53 bbls, actual hole fill = 114 bbls, fluid loss for trip at 00:00 hrs = 61 bbls, total fluid lost for last 24 hrs = 711 bbls, Total bbls lost to well since drilling into thief zone = 900bbls. 1/16/2005 00:00 - 00:30 0.50 DRILL TRIP PROD Cont POOH from 2,324' to 243' due to plugged BHA. 00:30 - 02:30 2.00 DRILL PULD PROD Stnd back jar's and DC's, PJSM and remove nuke source, down-load and UD MWD, remove bit from motor, attempted to rotate motor in table for draining, motor would not rotate, bit had one plugged jet. 02:30 - 04:00 1.50 DRILL RIRD PROD Cleared and cleaned floor, pulled wear ring, installed test plug, RlU BOP test equip, RlU injection line to tubing spool for hole fill while testing. 04:00 - 09:00 5.00 DRILL OTHR PROD PJSM, test 13 5/8" BOP and associated equip at 250-3,500 psi, witness waived by AOGCC rep Chuck Schieve. 09:00 - 09:30 0.50 DRILL RIRD PROD Pull test plug, install wear ring, RID test equip, blow dwn surface lines, Printed: 1131/2005 3:04:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRilLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/16/2005 09:00 - 09:30 0.50 DRILL RIRD PROD static fluid loss at 13 bph. 09:30 - 12:30 3.00 DRILL PULD PROD M/U motor and bit #10 (re-run), M/U-orient-program and function test MWD, PJSM and load nuke source, M/U DC's and jars. 12:30 - 16:30 4.00 DRILL TRIP PROD RIH with 4" DP to 9,831' filling pipe every 25 stnds. 16:30 - 17:30 1.00 DRILL OTHR PROD PJSM, slip and cut drill line, service rig and top drive. 17:30 -18:00 0.50 DRILL TRIP PROD Cont RIH to 10,979', break eire, obtain SP rate's and orient to low side. 18:00 - 23:00 5.00 DRILL REAM PROD Cont RIH, washing to bot! from 10,979' to 12,113' at 275 gpm with 2,150 psi at 75 RPM rot. 23:00 - 00:00 1.00 DRILL DRLG PROD Cont drilling from 12,113' to 12,155', wt on bit 8K, 80 RPM, 65 SPM with 2,280 psi, P/U wt 175K, SIO wt 100K, ROT wt 135K, AST .21 hrs, ART .53 hrs, ADT .74 hrs, 11 K torque on bot!, fluid loss for last 24 hrs 433 bbls, Total fluid lost to well since drlng into thief zone 1,333 bbls. Mud additives at end of report time are as follows: Mix II Fine and Mix II Medium were added while washing from shoe to bottom then stopped when losses were deemed tolerable. The Flo-Pro NT was delivered to the rig with 20 ppb S-200 and 20 ppb Safe-Carb 250, then Safe-Carb 500 and Safe-Carb 1000 added at rig, 15 min per sack each while drilling. 1/17/2005 00:00 - 12:00 12.00 DRILL DRLH PROD Cont drilling from 12,155' to 12,562', bit wt 5K, 75 RPM, P/U wt 165K, S/O wt 11 OK, ROT wt 135K, torque on bot! 8K, torque off bot! 7K, 65 SPM at 275 GPM with 2,560 psi. 12:00 - 00:00 12.00 DRILL DRLH PROD Cont drilling from 12,562' to 12,802', bit wt 5K, 80 RPM, P/U wt 175k, S/O wt 108K, ROT wt 135K, torque on bot! 7K, torque off bot! 6K, 65 SPM at 275 GPM with 2,580 psi, total slide hrs 6.48, total rot hrs 8.37, bbls lost last 24 hrs= 1,230, total bbls lost since drlng into thief zone= 2,563. Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II Medium or Dyna Red Medium at 14 sacks per hour to control losses. 1/18/2005 00:00 - 11 :00 11.00 DRILL DRLH PROD Directional Drill from 12802' to 13083' - WOB 10 - RPM 75 - TQ on 7- off 6 - GPM 250 - PP on 2710 - off 2370 - PU 160 - SO 105 - ROT 133 11 :00 - 13:30 2.50 DRILL CIRC PROD Monitor well - Static 6 BPH - Dynamic Loss 38 BPH - Pump LCM Pill from surface to surface - Monitor well for 10 mins - 2.3 BPH Static Loss 13:30 - 17:00 3.50 DRILL OTHR PROD Directional Drill from 13083' to 13130' - WOB 8 - GPM 250 - PP on 2600 - off 2370 - PU 165 - SO 105 -Dynamic loss - 30 BPH 17:00 - 18:30 1.50 DRILL CIRC PROD Pump LCM pill thru bit @ 125 GPM 1310 psi - spot @ 12077' MD- Monitor well for 10 mins - Static Loss 3 BPH - Dynamic Losses @ 24 BPH 18:30 - 00:00 5.50 DRILL DRLH PROD Directional Drill from - 13130' to 13280' - WOB 8 - RPM 75 - TQ on 7.5- off 6 - GPM 254 - PP on 2440 - off 2170 - PU 16 - SO 105 - ROT 133 -Dynamic loss - 38 BPH - Total Slide hrs 7.48 - Total ROT hrs 4.37 - BBLS lost last 24 hrs = 798 - Avg BPH loss 33 - Total bbls lost since drilling into thief zone = 3361 Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II Medium or Dyna Red Medium at 18 sacks per hour to controllosses.- Avg back ground gas 65 units - Max 250 units 12972' - 190 units 12993' - 200 units 13275' 1/19/2005 00:00 - 15:00 15.00 DRILL DRLH PROD Directional Drill from 13280' to 13665' - WOB 8 to 10 - RPM 85 - TQ on ~ 8 - off 6.5 - GPM 254 - PP on 2480 - off 2150 - PU 160 - SO 102 - ROT 130-ECD11.05 15:00 - 16:30 1.50 DRILL CIRC PROD CBU - GPM 250 - PP 2180 16:30 - 19:00 2.50 DRILL WIPR PROD Pump out from 13665' to 12272' - Pump at drlg rate - Pull 3 stands without pump across theif zone from 12272' to 11983 - Con't Pump out Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/19/2005 16:30 - 19:00 2.50 DRILL WIPR PROD from 11983' to 11024' - Hole in excellent shape no problems on trip out - 52 bbls to fill hole on trip out - Calulated bbls 15.3 - 37 bbls over calulated vol 19:00 - 20:00 1.00 DRILL CIRC PROD CBU at shoe - GPM 250 - PP 1940 - RPM 55 - Lost 40 bbls on CBU - Clean hole ECD with rotary 10.51 - Without rotary 10.38 20:00 - 22:00 2.00 DRILL WIPR PROD Orient to low side - RIH slow from 11024' to 13665' - Fill every 5 stands - Hole in excellent shape - Lost 17 bbls on trip in 22:00 - 23:00 1.00 DRILL CIRC PROD CBU - GPM 250 - PP 2130 - Trip gas from 25 units to 173 units - No cut in mud weight 23:00 - 00:00 1.00 DRILL DRLH PROD Drill from 13665' to 13686 - WOB 5 - RPM 70 - TO on 8.5 - off 7 - GPM 250 - PP on 2400 - off 2150 - PU 160 - SO 102 - ROT 130 - ECD 10.8- Dynamic loss - 30 BPH - Total Slide hrs 4.80 - Total ROT hrs 4.59 - BBLS lost last 24 hrs = 613 - Avg BPH loss 28 - Total bbls lost since drilling into thief zone = 3974 Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II Medium or Dyna Red Medium at 18 sacks per hour to controllosses.- Avg back ground gas 100 units - Max 600 units 13575'- 1/20/2005 00:00 - 05:00 5.00 DRILL DRLH PROD Directional Drill from 13686' to 13745' - WOB 5 to 10 - RPM 75 to 80- TQ on 8.5 - off 7 - GPM 250 - PP on 2400 - off 2130 - PU 165 - SO 102 - ROT 130 - ECD 10.5 - Losses @ 60 BPH starting @ 13711' 05:00 - 05:30 0.50 DRILL CIRC PROD Pump 9.8 LCM pill - Circ pill from bit to outside of BHA @ 3 BPM 05:30 - 16:00 10.50 DRILL DRLH PROD Con't Directional Drill from 13745' to 13816' - WOB 10 to 12 - RPM 80 - TQ on 8 - off 7 - GPM 250 - PP 2430 - off 2100 - PU 165 - SO 102- ROT 128 - ECD 10.4 - Total Slide hrs 2.44 - Total ROT hrs 7.69 - BBLS lost last 24 hrs drilling = 831 - Avg BPH loss 35 - Total bbls lost = 4795 16:00 - 17:30 1.50 DRILL TRIP PROD Pump out from 13816' to 12322' - Pump at Drilling rate GPM 250 - PP 1940 - Calulated hole fill 8.3 bbls - Actual hole fill 33 bbls - 24.7 bbls over 17:30 - 18:00 0.50 DRILL CIRC PROD Pump and spot 30 bbl LCM Pill from 12322' to 11252' - Loss 25 bbls 18:00 - 19:30 1.50 DRILL TRIP PROD POH from 12322' to 11554' - Hole not taking correct fill - Pump out from 11554' to 10979' - Pump 250 GPM - PP 1820 - Flow check well - Well Static 19:30 - 20:30 1.00 DRILL CIRC PROD CBU - GPM 275 - PP 2050 - RPM 35 - Loss 42 bbls 20:30 - 00:00 3.50 DRILL TRIP PROD POH from 10979' to BHA @ 243' - Total vol for fill 89 bbls - Calulated fill 64 bbls - 25 bbls over to fill on trip out 1/21/2005 00:00 - 02:30 2.50 DRILL TRIP PROD Stand back Jars - DC's - Remove sources - Drain MWD - Breakoff Bit - Download MWD - Lay down Neutron tool 02:30 - 05:00 2.50 DRILL PULD PROD Function Blind rams - Pick up Motor - Make up bit - Re-mobilize MWD - Orient same - Program MWD - Make up Jars - Function test MWD 05:00 - 09:30 4.50 DRILL TRIP PROD RIH with BHA # 14 - From 217' to 11049' @ controlled running speed to reduce surge pressure - Fill pipe every 25 stands 09:30 - 11 :00 1.50 DRILL DRLG PROD PJSM - Cut drlg line - Top drive service 11 :00 - 14:00 3.00 DRILL DRLH PROD Orient to low side - Wash in @ 2 BPM from 11065' to 12589' - Con't RIH from 12489' to 13545' filling pipe every 5 stands 14:00 - 14:30 0.50 DRILL REAM PROD Wash and ream from 13545' to 13816' @ 275 GPM - PP 2140 - RPM 75 - TO 8 14:30 - 00:00 9.50 DRILL DRLH PROD Directional Drill from 13816' to 13927' - WOB 12 to 20 - RPM 75 to 85- TO on 9 - off 8 - GPM 275 - PP 2990 - off 2890 - PU 170 - SO 95 - ROT 130 - ECD - Total Slide hrs 1.77 - Total ROT hrs 5.10 - BBLS lost last 24 hrs drilling = 559 - Total bbls lost = 5354 - Trip gas Max 200 units 1/22/2005 00:00 - 01 :30 1.50 DRILL DRLH PROD Directional Drill from 13927' to 13937' - WOB 12 to 25 - RPM 80 to 85- GPM 250 - PP on 2970 - off 2580 - PU 168 - SO 95 - ROT 130 - ECD 10.95 Printed: 1/31/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-28 1 D-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Sta rt: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/22/2005 01 :30 - 02:30 1.00 DRILL OTHR PROD POOH to 13766' - Mad pass tfrom 13766' to 13800' as per Geolgist- GPM 250 - PP 2700 - RIH 02:30 - 00:00 21.50 DRILL DRLH PROD Directional Drill from 13937' to 14174' - WOB 12 to 23 - RPM 80 to 85- GPM 270 - PP on 3250 - off 2950 - PU 170 - SO 94 - ROT 130 - ECD 11.09 - Total Slide hrs 3.07 - Total ROT hrs 9.67 - BBLS lost last 24 hrs drilling = 541 - Total bbls lost = 5895 - Max background gas 100 units @ 13938' 1/23/2005 00:00 - 10:30 10.50 DRILL DRLH PROD Directional Drill from 14127' to 14672' - TD 6 3/4" Production hole- WOB 12 - RPM 80 to 85 - Ta on 9 - off 8 - GPM 300 - PP on 3300 - off 2990 - PU 170 - SO 95 - ROT 130 - ECD 11.38 - Total Slide hrs 4.57- Total ROT hrs 7.33 - BBLS lost last 24 hrs drilling = 527 - Total bbls lost = 6422 - Max gas 2938 units @ 14400' 10:30 - 13:00 2.50 DRILL CIRC PROD CBU 2 X - GPM 300 - PP 3050 - RPM 85 - Ta 8 - Flow check well - Well static 13:00 - 14:30 1.50 DRILL TRIP PROD Pump out from 14672' to 14119' @ 275 GPM - PP 2780 - From 14119' to 13545' Pump @ 85 GPM - PP 720 - Due to mud line wash out 14:30 - 16:30 2.00 DRILL TRIP PROD POOH without pump due to mud line washout - From 13545' to 11030' 16:30 - 23:00 6.50 DRILL OTHR PROD Circulate GPM 130 - PP 1240 - Repair mud line 23:00 - 00:00 1.00 DRILL TRIP PROD Orient to low side - RIH from 11030' to 12853' - Fill string - Blow down Top drive 1/24/2005 00:00 - 01 :00 1.00 DRILL TRIP PROD Con't RIH from 12653' to 14672' - From 13800' to 14300' taking 20 to 40k through spots in that section - No other problems on trip in 01 :00 - 03:00 2.00 DRILL CIRC PROD CBU 2 X - GPM 300 - PP 3040' - RPM 90 - TQ 8K - Trip gas 315 units- 03:00 - 04:30 1.50 DRILL TRIP PROD Flow check well - Well static - Pump out @ drilling rate to 13500' - Hole in good shape - No problems 04:30 - 05:00 0.50 DRILL TRIP PROD Flow check - Well static - RIH from 13500' to 14672' - Tight spot @ 14230' - Work through - Clean up - Con't RIH from 14230' to 14672' 05:00 - 08:30 3.50 DRILL CIRC PROD CBU 3 X - GPM 300 - PP 3000' - RPM 90 - Ta 8 - Trip gas 100 units - Flow check - Well static 08:30 - 11 :30 3.00 DRILL TRIP PROD Pump out of hole @ drlg rate - From 14672' to 11030' 11 :30 - 12:30 1.00 DRILL CIRC PROD CBU 1 X - GPM 300 - PP 2550 - RPM 40 - TQ 5K - Flow check - Well static 12:30 - 16:00 3.50 DRILL TRIP PROD POOH from 11030' to BHA 217' 16:00 - 17:30 1.50 DRILL PULD PROD LD BHA - Jars - Flex Collars - MWD - Flush motor - Break bit - Lay down motor 17:30 - 18:30 1.00 DRILL RIRD PROD Lay down handling tools - Clear rig floor - Rig up 41/2" liner running tools 18:30 - 23:00 4.50 CASE PULR PROD PJSM - Pick up 4 1/2" Slotted liner - Total Slotted 74 joints - Total Solid jts - 39 - 5 Swell Packers - Picked up 23:00 - 23:30 0.50 CASE PULR PROD Change handling equipment - PU and make up Baker 5 1/2" Seal Assembly - Baker Flex-Lock Hanger 5 1/2" X 7 5/8" - Baker ZXP Liner Top Packer 51/2" X 7 5/8" - Liner PUW 85 - SOW 82 23:30 - 00:00 0.50 CASE OTHR PROD Load hanger fluid in hanger 00:00 - CASE PROD BBLS lost last 24 hrs drilling = 381 - Total bbls lost = 6803 1/25/2005 00:00 - 03:00 3.00 CASE RUNL PROD RIH with 41/2" 12.6# L-80 IBT-M Slotted liner from 3754' to 11050' 03:00 - 03:30 0.50 CASE CIRC PROD Circ drill pipe vol- @ 146 GPM - PP 600 psi - Liner PUW 160 - SOW 115 03:30 - 05:00 1.50 CASE RUNL PROD Con't RIH with liner from 11030' to 14672' - Tag bottom pick up 1 foot- Work through tight spot @ 14235' on trip in - On Bottom POW 185 - SOW 100 05:00 - 05:30 0.50 CASE CIRC PROD Circ one drill pipe vol @ 180 GPM - PP 940 05:30 - 06:00 0.50 CASE CIRC PROD Drop packer setting ball - Pump at 180 GPM - PP 950 - for 600 stks - Printed: 1131/2005 3:04:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-28 10-28 ROT - DRILLING d 14cm@conocophillips.com Doyon 14 Sta rt: Rig Release: Rig Number: 12/15/2004 1/26/2005 Spud Date: 12/20/2004 End: 1/26/2005 Group: 1/25/2005 05:30 - 06:00 0.50 CASE CIRC PROD Reduce rate to 100 GPM - PP 620 for 300 stks 06:00 - 06:30 0.50 CASE OTHR PROD Pressure up to 2000 psi to set hanger - Con't Pressure up to 3800 psi to release HR setting tool - PU to verify release from liner - Rotate slowly slack off 70K three times to set ZXP packer - Close Annular - pressure up to 1500 psi on annulus and hold for 10 mins to confirm ZXP is set - Bleed off pressure - TOP 10922.47 - BOL 14671 06:30 - 07:30 1.00 CASE CIRC PROD CBU - GPM 381 - PP 2140 - Reciprocated DP while CBU - Flow Check - Well static 07:30 - 15:00 7.50 CASE OTHR PROD POOH - Laying down 4" drill pipe 15:00 - 15:30 0.50 CASE OTHR PROD Lay down Baker Liner running tool - Make service breaks 15:30 - 16:30 1.00 CASE OTHR PROD RIH - 40 stands 4" drill pipe out of derrick 16:30 - 19:30 3.00 CASE OTHR PROD POOH - Laying down 4" drill pipe 19:30 - 20:00 0.50 CMPL TN RURD CMPL TN Pull wear ring - Clear rig floor - Rig up completion running equipment 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN PJSM on running completion - Pick up and run 41/2" L-80 12.6# IBT-M completion - Total jts ran 135 - Depth @ 4295' 1/26/2005 00:00 - 05:00 5.00 CMPL TN RUNT PROD Con't RIH with 41/2" completion to 10900' ;' 05:00 - 06:30 1.50 CMPL TN SOHO PROD Space out - Install hanger - Land string - RILDS 06:30 - 07:00 0.50 CMPL TN SEOT PROD Test TWC to 1000 psi from top - LD Landing Jt 07:00 - 09:00 2.00 CMPL TN NUND PROD Blow down lines on rig flooor - ND Nipple down BOP stack 09:00 - 10:30 1.50 CMPL TN NUND PROD NU FMC Adapter flange test to 5000 for 10 mins - NU Tree 10:30 - 12:00 1.50 CMPL TN RURD PROD Rig up hot oil truck to test tree - 12:00 - 13:30 1.50 CMPL TN SEOT PROD Test Tree - 250 low 5000 high 13:30 - 15:00 1.50 CMPL TN FRZP PROD Pull TWC - Rig up to Annulus - Pump 84 bbls - Pump 32 bbls before getting returns - Pump @ 1.75 bpm - PP 850 15:00 - 16:00 1.00 CMPL TN FRZP PROD U-Tube freeze protect - IA 25 psi - Tubing 0 psi - PJSM change out saver sub on top drive while U-tubing well 16:00 - 19:00 3.00 CMPL TN RURD PROD Blow down lines - Install BPV with dry rod - Install 'VR" plugs in IA - OA - OA 50 psi - Secure well - Release rig 19:00 hrs Printed: 1/31/2005 3:04:35 PM 1 D-28 Horantal Well Completion Schematic . ConocóP't,illipS J I I ~ Il I 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 NSCT pin down (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91") ,. 4-1/2" Camco 'DS' nipple wI 3.875" No-Go Profile set at 506' MD 4-1/2" 12.6# L-80 IBT tubing to landing nipple (Special Drift to 3.843") 4-1/2" x 1" Camco 'KBG-2' Mandrels w/ DVs (Max. OD 5.984", ID 3.833") Spaced out wI 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows: GLM# 1 2 3 4 5 6 MO-RKB 3056 5377 6949 8203 9181 9973 4-1/2" Camco 'DB' nipple w/3.813" No-Go Profile set @ bottom of tangent section 10,018 MO Surface csg. 10-3/4" 45.5# L-80 BTC Special Drift - 9.875" 6581' MD /4413' TVD 4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple to sliding sleeve (Special Drift to 3.843") Baker 4-)12" CMU Sliding Sleeve, 3.81" DB Profile (Ran in open position) 10,890' MD 1 jt 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") 4.75" 00 Baker casing seal assembly wI 17 Ft. stroke, 4-1/2" 12.6 # L-80 IBT box up (landed 4' off fully landed position) top @ 10,936' MD 4 )12" x 6.3" Swell Packers for isolation of potential conductive faults or wet intervals Intermediate csg. 7 5/8" 29.7# L-80 BTCM 11,065' MD /6587' TVD ------- ILC-- J_ Slotted liner 4-1/2" 12.6# .-801BT Liner Assembly - Top of tie-back sleeve @ 10.922' MO Baker 5 Y2" x 7 5/8" 'ZXP' Liner Top Isolation Packer w/ HRD running profile .. Baker 5 )12" x 7 5/8" RS Nipple I Abandoned lateral 11 ,170' - 11,663' MD 1 D-28 L 1 PTD 204-238 (lateral was not cased or plugged) Main lateral is designated as 1 D-28 PTO 204-237 Baker 5 Y2" x 7 5/8" 'Flexlock' Liner Hanger Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4 )12" 12.6# L-80 IBT alternating slotted and blank pipe w/ swell packers C4/C3 Lateral to 14,672' MD ¿ 4 )12" ROT 'Silver Bullet' Shoe ran on a bent joint of 4 Y2" 12.6# L-80 liner 4 )12" x 6.3" Swell Packer ran in conjuntion with blank pipe - top of swell packer @ 11,110' MD Scott Lowry 2/08/05 y ConoccØhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Scott L Lowry Phone (907) 265-6869 Email: Scott.L.Lowry@conocophillips.com RE· r"'E.:-p ¡r=D· . ~ 'ò. _v_I \I """" JAN 2 1 2005 January 20, 2005 f\L Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Changes to Permits to Drill, Kuparuk Producers, 10-28 & 1D-28 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby requests to alter the permits to drill for Kuparuk producers 1D-28 and 10-28 Ll. Due to unexpected reservoir conditions, CPAI did not drill the originally planned 1D-28 (PTD 204-237, API 50-029-23237-00). Therefore, the 1D-28 Ll (PTD 204-238, API 50-029-23237-60) will be the only well drilled from this slot on drill site 1D. Additionally, an open-hole sidetrack was necessary due to difficulties steering the well bore. 493' of open hole was abandoned. The abandoned hole is within the oil-bearing Kuparuk reservoir sands. It was not cemented, and will likely stay open and contribute production to the main well bore. To simplify record keeping, CPAI proposes the following: - Re-name 10-28 L1 existing records as 1D-28, with a permit to drill number of 204-237 and an API number of 50-029-23237-00. This name, permit number, and API number will be used for all subsequent reporting purposes for the well. Re-name all data from the abandoned 493' interval as 1D-28 Ll, with a permit to drill number of 204-238 and an API number of 50-029-23237-60. This name, permit number, and API number will be used for all subsequent reporting purposes for this interval. ConocoPhillips Alaska, Inc. will submit a completion report (form 10-407) for both wells. If you have any questions or require any further information, please contact me at 265-6869. Sin. œrely" /J ,ð 3adf¡:,. ~ -': Scott Lowry / Drilling Engineer ORIG p,L4L Re: lD-28 (204-237) / lD-28 Ll (204-238) Scott, Let me know if I don't properly state what happened: 1. CPAI first drilled the proposed ID-28Ll (Permit to Drill 204-238, API Number 50-029-23237-60), but 2. due to unexpected reservoir conditions, CPAI is not going to drill the planned ID-28 (PTD 204-237, API Number 50-029-23237-00), and 3. therefore, ID-28L1 (PTD 204-238) will be the only well drilled from this slot on the drilling pad. 4. While drilling ID-28Ll, an openhole sidetrack was needed to get past a "hard spot" within the Kuparuk reservoir sands:and a. the open interval that was abandoned is about 500' in length and it lies within the oil-bearing Kuparuk reservoir sands, b. the abandoned open interval was not cemented, and c. the abandoned open interval will likely stay open and could contribute production to the main well bore. So, to simplify record-keeping, CPAI should (if this doesn't cause CPAI a large amount of work and confusion): 1. Re-label the ID-28Ll existing records as ID-28, with a Permit to Drill number of204-237, and an API number of 50-029-23237-00. Use that name, PTD and API for all subsequent reporting purposes for the well. 2. Re-label any data from the existing, abandoned 500' open interval as ID-28Ll, with a Permit to Drill number of 204-238, and an API number of 50-029-23237-60. Use this name, PTD and API for all subsequent reporting purposes. To close out Commission's well file for this abandoned, open interval, CPAI should also submit a Completion report (Commission form 10-407) for it. 3. Send a letter to the Commission that explains what happened and details the name and number changes for the existing well and the abandoned, open interval for our files. My intent is clear record-keeping, and my reasoning is as follows: 1. The current well bore that is completed with a slotted liner will1ikely contribute most ofthe production, so it seems best to consider it as ID-28, rather than as a lateral to the much shorter, abandoned, open interval. 2. This abandoned, open interval is similar to the pilot holes that are drilled in the Alpine Field. There, a pilot hole is drilled first to test sand quality or thickness, then it is plugged back and the main well bore (for example: CDI-99, 50-103-23456-00) is drilled. To properly segregate and track drilling and logging information, each pilot hole is given a separate name and API number (example: CDI-99PH1,50-103-23456-70). In your case, the abandoned, open interval is like a pilot hole -- it was drilled first and then abandoned, but it is still open and capable of production (like the open hole completions at Alpine), so it really should have an "L 1" appended to the name and a "-60" suffix to the API number to indicate it is a lateral. For clear record-keeping, it has been the Commission's policy to assign a separate permit to drill number to each lateral, so it won't hurt to apply PTD 204-238 to this open "lateral. " Let me know if this is not workable for you, or if it is confusing. Thanks, Steve Davies Lowry, Scott L wrote: Steve, I am a little confused on our naming convention for this well. I am hoping you can provide some assistance. We have deviated from ouroriginal plans. Originally, we planned to drill a lower lateral in the Kuparuk "C1", which was 1 of2 1/21/20053:49 PM Re: lD-28 (204-237) / lD-28 Ll (204-238) designated as 10-28, and the! would drill an upper lateral in the Kuparuk ".3" intervals which would be designated as 10-28 L 1. The zones came in deeper than expected and the "C1" is believed to be below the oil-water contact. Thus, the lateral designated as 1 0-28 (PTO 204-237) will not be drilled. However, the upper lateral (originally permitted as 10-28 L 1 PTO 204-238) is being drilled. Should the naming convention for the 10-28 L 1 lateral be changed since it is now the only lateral? To add to the confusion, we performed an open hole sidetrack in this lateral (the lateral originally named 10-28 L 1) because we were having problems steering. We had to back up about 500' to find a spot soft enough to allow an open hole sidetrack. We did not pump cement in the abandoned lateral, nor did we put casing in it. Please feel free to call me if I have confused you. I want to make sure we are consistent in naming these laterals. Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 20f2 1/21/20053:49 PM RE: lD-28 (204-237) I lD-28 Ll (204-238) Subject: RE: 1D-28 (204-2! 6£>"28 LI a04-238)~ · From: "Lowry, Scott L" <Scott.L.Lowry@conocophillips.com> Date: Mon, 17 Jan 200506:08:01 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: steve_davies@admin.state.ak.us, "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com> Tom, The "abandoned" portion of the hole does have pay and is expected to be productive. The new wellbore wìll be covered with a slotted liner. Scott L Lowry Operations Orilling Engineer ConocoPhillìps Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Friday, January 14, 2005 6:42 PM To: Lowry, Scott L Cc: steve_davies@admin.state.ak.us; Thomas, Randy L Subject: Re: 1D-28 (204-237) / 1D-28 L1 (204-238) Scott, Does the "abandoned" portion of the hole have pay in it that you expect to be productive?? I don't have the file right here. Is some portion of the new well to be covered with casing/liner?? In some of the wells in Alpine when the extra portions are going to contribute so section has been an Ll. I will have to leave this one for Steve. Tom Lowry, Scott L wrote: Steve, I am a little confused on our naming convention for this well. I am hoping you can provide some assistance. We have deviated from our original plans. Originally, we planned to drill a lower lateral in the Kuparuk "C1", which was designated as 1 0-28, and then we would drill an upper lateral in the Kuparuk "C4/C3" intervals which would be designated as 1 0-28 L 1. The zones came in deeper than expected and the "C1" is believed to be below the oil-water contact. Thus, the lateral designated as 1 0-28 (PTO 204-237) will not be drilled. However, the upper lateral (originally permitted as 10-28 L 1 PTO 204-238) is being drilled. Should the naming convention for the 10-28 L 1 lateral be changed since it is now the only lateral? To add to the confusion, we performed an open hole sidetrack in this lateral (the lateral originally named 10-28 L 1) because we were having problems steering. We had to back up about 500' to find a spot soft enough to allow an open hole sidetrack. We did not pump cement in the abandoned lateral, nor did we put casing in it. Please feel free to call me if I have confused you. I want to make sure we are consistent in naming these laterals. 10f2 1/21/20053:43 PM RE: lD-28 (204-237) I lD-28 Ll (204-238) Thanks, . . Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 20f2 1/21/20053:43 PM CJfT'®~ ciÐLLX1_ . @~ I®~ ~(~.-17 lill J IJlJ 1 II,J lJ!) _.~ . / I . / j I FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk ID-28Ll ConocoPhillips Alaska, Inc. Permit No: 204-238 Surface Location: 357' FNL, 419' FEL, SEe. 23, TIIN, RI0E, UM Bottomhole Location: 5062' FNL, 4022' FEL, SEC. 17, TI1N, RIlE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU ID-28, Permit No. 204-237, API No. 50-029-23237-60. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ø, Daniel T. Seamount, Jr. Commissioner DATED this / day of December, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 11 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510··0360 4a. Location of Well (Govemmental Section): Surface: 357' FNl, 419' FEL, Sec. 23, T11N, R10E, UM Top of Productive Horizon: 4760' FNL, 2982' FEL, Sec. 18, T11N, R'11E, UM Total Depth: 5062' FNL, 4022' FEL, Sec. 17, T11N, R"11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 / y- 5959309 / 16. Deviated wells: Kickoff depth: 10800' 18. Casing Program Size Hole 30" Casing 20" 13.5" 9-7/8" 6.75" 10.75" 7-5/8" 4.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Production Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat / ft. Maximum Hole Angle: Weight 91.5# 45.5# 29.7# 12.6# Specifications GradEl Coupling H-40 Welded L-80 BTC L-80 BTCM L-80 IBT ~l~ ExploratoryU Development Oil ~ . Multiple Zone 0 Service 0 Development Gas 0 Singfe Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1 D-28L 1 6. Proposed Depth: 12. Field/Pool(s): MD: 14873" TVD: 6609' Kuparuk River Field 7. Property Designation: ADL 25650 & 28243 8. Land Use Permit: ALK 468 & 3814 9. Acres in Property: 2560 10. KB Elevation Zone- 4 (Height above GL): 34 feet P 90.6° Downhole: 3511 psig Setting Depth Top Bottom Length MD TVD MD TVD 118' 34' 34' 152' 152' 6537' 34' 34' 6571' 4413' 10631 ' 34' 34' 10665' 6522' 4358' 10515' 6507' 14873' 6609' PRESENT WELL CIDNDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size '8-W BOP Sketch 0 U Diverte!r Sketch 0 21. Verbal Approval: Commission Representative: Kuparuk Oil Pool 13. Approximate Spud Date: 12/18/2004 14. Distance to Nearest Property: 9300' 15. Distance to Nearest / Well within Pool: 1C-12, 2060' @ 14873' Surface: 2782 psig Quantity of Cement c. t. or sacks (including stage data) 16 cu yds ABI, Type III 830 sx AS Lite, 460 sx LiteCrete 240 sx Class G slotted liner (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD rvD I Perforation Depth TVD (ft): Drilling Program 0 Timev. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: 22. I hereby certify that the foregoing is true and cormct to the best of my knowledge. Printed Name Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Signature Randy Thomas ~ \ l.;~ Contact Scott Lowry @ 265-6869 Title Greater Kuparuk Area Drilling Team Leader Phone L6Y 6 - Date l (ll.. ¿/o '1 - 1) 5 D PreDared bv Sharon Al/suD-Drake Permit to Drill Number: 2.0 <I~ 238 Conditions of approval : Commission Use Only API Number: I Permit Approval / 50-62-1, 232.37- 0D Date: /~/O/ /0 V Samples required Hydrogen sulfide measures see cover letter for other requirements o Ves ~NO Mud log required 0 Ves ~ No ØVes 0 No Directional survey required gVes 0 No ~a~ ~s\-"\f'.~NCt \ L \l\~'(~. Other: ~50() ~C;\ ~\"'\""-~,,""- '\SC)Ç> \-c'S~, OrIginal Signed By DAN SEAMOUNT Approved by: Form 10-401 Revised 12/2003 BY ORDER OF THE COMMISSION ORIGIN.AI Date: , ...,/, / /) y Submit in Duplicate · eation for Permit to Drill, Well1D-28 L 1 Revision No.O Saved: 19-Nov-04 Permit It - Kuparuk Well #1 D-28 L 1 Application for Permit to Drill Document Moximize W~II Volul; Table of Contents 1. Well Name .............................................. ... .................... ............ ........................ ......... 2 Requirements of 20 AAC 25.005 (f)................................................................................................... .....2 2. Location Summary................. ....... ........... ........................ ........ ....................... ......... 2 Requirements of 20 AAC 25. 005( c)(2) ...... ................... .............................. .............. ........... ................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................. ............. .......... .................... .......... ...... ........... ............ 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casing and Cementing Program.............................................................................3 Requirements of 20 AAC 25.005(c)(6) .... ........ ......... ...................... .............. ................ .......................... 3 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ........ ........................ .............................. ........ ...................... ....... 4 8. Dri II i ng FI uid Program .... .............. ............ ..................... .............. ....... ......... ............ 5 Requirements of 20 AAC 25.005(c)(B) ............ ................................. ............... ...................... ........ ......... 5 Lateral Mud Program (MI FloPro).................................. ..................... .................................................... 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seism ic Analysis............ ....... .................... ..... ........... ......... ......................... ...... ....... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 10-28 L1 PERM/T /T.doc Page 1 of 6 Printed: 19-Nov-04 OR\G\NAL · eation for Permit to Drill, Well 1 D-28 L 1 Revision No.O Saved: 19-Nov-04 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attach ments ......... ........ ......... ........... .................. .......... ........ .... .... .............. ....... ....... 6 Attachment 1 Directional Plan........................................................................................... ......... ............ 6 Attachment 2 Drilling Hazards Summary................................................................... ............................. 6 Attachment 3 Well Schematic.............................................................................................. ................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identitied by a unique name designated by the operator and a unique API number assigned by the commissim under 20 AAC 25.040(b). For a well with multiple well branche0 each branch must sirm/ady be identitied by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lD-28 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pemlit to Drill must be accompanied by each of the following item0 except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing {A)the coordinates of the propoó>-ed location of the well at the surface, at the top of each objective formation, and at total depth referenced to govemmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to tile state plane coordinate system for this state as maintained by the National Geodetic Survey in tile National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Nothings: 5,959,309 Eastings: 560,671 357' FNL, 419' FEL, Section 23, TUN, Rl0E, UM I RKB Elevation I 105.4' AMSL Pad Elevation 70.9' AMSL Location at Top of Productive Interval (Kuparuk "C4" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,960,251 Eastings: 568,327 4760' FNL, 2982' FEL, Section 18, TUN, RUE, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth/55: 10,615 6,517 6,412 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,959,989 Eastings: 572,570 5062' FNL, 4022' FEL, Section 17, TUN, RUE, UM Measured Depth/ RKB: 14,873 Total Vertical Depth/ RKB: 6,609 Total Vertical Depth/55: 6,504 and (D) other information required by 20 AAC 25.050(b),· Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatett the application for a Permit to Dri/I (Form 10-401) must (1) include a plat drawn to a suitable scale, sllowing tIle path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed we/~' 1D-28 L1 PERM/T /T.doc Page 2 of 6 Printed: 19-Nov-04 ORIGINAL · eation for Permit to Drill, Well 1 D-28 L 1 Revision No.O Saved: 19-Nov-04 Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet oftlle proposed wellbore (A) !íst the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mall,' or (B) state tl¡at the applicant Is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to 01'111 must be accompanied by each of tile fallowing items, except for an item already an file with the commission and Identified In the application: (3) a diagram and description of the blowout prevention equipment (SOPE) as required by 20 MC 25. 035, 20 MC 25.03~ or 20 MC 25.03~ as appllcable/ An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete we1l1D-28 L1. Please see information on the Doyon Rig 14 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app!ícatlon for a PermIt to 01'111 must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, crítería used to determine it; and maximum potential surface pressure based on a methane gradient/ The expected reservoir pressures in the Kuparuk sands in the 10-28 Ll area vary from 0.49 to 0.53 psi/ft, or 9.5 to 10.2 ppg EMW (equivalent mud weight). These pressures are predicted based on actual / bottom hole pressure data from the nearby Kuparuk wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Kuparuk sand formation is 3,510 psi, calculated thusly: MPSP =(6,624 ft)(0.53 - 0.11 psi/ft) , = 2,782 psi (B) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity far differential stlcklng/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identifìed in the application: (5) a descfiptlon of the procedure for conducting formation integrít¡ test~ as required under 20 MC 25. 030(1),' No formation integrity test will be performed in the drilling of 1D-28 Ll. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dr/II must be accompanied by each of the following items, except for an Item already on fì/e with the commission and Identifìed in the application: ORIGINAL 1D-28 L1 PERMIT /T.doc Page 3 of 6 Prínted: 19-Nov-04 . eation for Permit to Drill, Well 1 D-28 L 1 . Revision No.O Saved: 19-Nov-04 (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted ¡iner~ pre- perforated liner, or screen to be installer:;¿· 6-3/4" Lower --~ (lD-28) 4-1/2 6-3/4" slotted Upper Lateral (1D-28 L1) . -·-Di\lerl~r_~mation ~ Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. 03!i unless t!lis requirement is waived by the commission under 20 AAC 25.035(h)(2),· Casing and Cementing Program See also Attachment 3: Cement Summary Ho/e Size (in) 30 Top MOfTVO (ft) 34 / 34 Btm MOfTVO (ft) 152 / 152 CsgfTbg 00 (in) 20 Weight (/b/ft) 91.5 Length (ft) 118 Grade H40 Connection Welded 10-3/4 13-1/2 34 / 34 6571 /4413 45.5 L-80 BTC 6537 7-5/8 9-7/8 34 / 34 10665 / 6522 29.7 BTCM 10631 L-80 4-1/2 slotted 1214 10715 / 6525 11929 / 6624 12.6 L-80 IBT ~- 1ST ~ 10515 / 6507 '- 14873 / 6609 12.6 L-80 4358 .__._,,-~-~ ------- No diverter system will be used during operations on 1D-28 L1. ORIGINAL Cement Program Cemented to surface with 16 cu yd AB!, Type III Cemented to Surface with 830 sx ASLite Lead, 460 sx LiteCRETE Tail Cement Top planned @ 9815' MD / 6227' TVD. Cemented w/ 240 sx Class G + additives Slotted- no cement Slotted- no cement 10-28 L 1 PERM/T /T.doc Page 4 of 6 Printed: 19-Nov-04 · .ation for Permit to Drill, Well 1 D-28 L 1 Revision No.O Saved: 19-Nov-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid !:>}/Stem, as required by 20 MC 25.03~· Drilling will be done with muds having the following properties over the listed intervals: Production Interval Mud Program (Flopro NT) Kuparuk Sand Initial Value 10.0 - 10.2 35 - 45 20 - 30 10 - 15 <600 9-9.5 <6 <10 <5 <3 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb/100 sf) Chlorides pH API filtrate *HTHP filtrate MBT Solids ppb Final Value 10.0 - 10.2 35 - 45 20 - 30 10 - 15 <600 9-9.5 <6 <10 <5 <3 .-' Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 14. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for af) Item already Of) file with the commission and identitìed in the application: (9) for an exploratOlY or stratigraphic test well; a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Pem¡it to Dnïl must be accompanied by each of the following item~ except for an item already on file with tl¡e commission and identified in the application: (10) for an exploratorý or stratigraphic test we/~ a seismic retraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dlill must be accompanied by each of the following item~ except for an item already on tìle with the commission and identified in the application: (11) far a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, ar floating dnïling vessel, an analysis af seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 MC 25.005 (c)(12) An application for a Permit to Dtill must be accompanied by each at the following Items¡ except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. OR\GlNAL 10-28 L 1 PERM/T /T.doc Page 5 of 6 Printed: 19-Nov-04 · eation for Permit to Drill, We/l1 D-28 L 1 Revision No.O Saved: 19-Nov-04 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fìle with tbe commission and Identifìed in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. Note: Previous operations are covered under the 1D-28 Application for Permit to Drill. r / 1. Pick up 6-3/4" drilling assembly with LWD (GR/RES/DENS-NEU), MWD and PWD. RIH. 2. Sidetrack well off of aluminum billet. Drill to TD of "C4/C3" sand lateral at 14,873' MD I 6,609' ìVD, as per directional plan. 3. POOH, back reaming out of lateral. POOH. 4. PU and run 4-1/2" slotted liner. 5. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH. 6. POOH, laying down drill pipe as required. 7. P/U and run 4-1/2" completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 8. Nipple down BOPE, nipple up tree and test. 9. Move rig off. 10. Pump corrosion inhibited brine into the 4-1/2" x 7-5/8" annulus, and freeze protect the tubing and IA. 11. Pull BPV. Shift sliding sleeve closed. MmA. 12. Set gas lift valves in mandrels. 13. Flow back well to portable test separator to clean up well. 14. Secure well for facility hook-up. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by eadl of the following items, except for an item already on fìle with the commission and identifìed in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and iT statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the wel!./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1D Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1D Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL 10-28 L 1 PERM/T /T.doc Page 6 of 6 Printed: 19-Nov-04 . . Plan: Plan 1 D-28 L 1 (wp08) C·· ... '~-II- .. Ol1OCUrlll. IPS ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 Plan 1 D-28 L 1 Standard Planning Report 19 November, 2004 ORIGINAL Co~illips . SPERRY_SUN HES Planning Report . EOM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 0-28 Plan 1 D·28 L 1 Plan 1 D-28 L 1 (wp08) Well Plan 10-28 RKB-34.5 + 70.9GL-105.4 @ 105.4OOft (RKB-34.5 + 70. RKB-34.5 + 70.9GL-105.4 @ 105.4OOft (RKB-34.5 + 70. True " Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Sfte Kuparuk 1 D Pad, KRU Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,959,669.675ft 561,086.445ft 1000" Latitude: Longitude: Grid Convergence: 70018' 01.317" N 1490 30' 18.921" W 0.47 ° Well Plan 1 D-28 Well Position +N/-S +E/-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,959,309.200 ft / 560,670.720 ft / ft Latitude: Longitude: Ground Level: 700 17' 57.805" N 149030' 31.126" W 0.000 ft Wellbore Plan 1 D-28 L 1 bggm2004 11/18/2004 24.57 80.75 57,582 Plan 10-28 L1 (wp08) Version: 4 Phase: PLAN Tie On Depth: 10,803.000 34.500 0.000 87.195 10,803.000 85.000 91.823 6,533.732 874.445 7,851.154 0.00 0.00 0.00 0.00 10,853.906 80.000 86.000 6,540.380 875.388 7,901.577 15.00 -9.82 -11.44 228.76 11,069.318 88.633 92.478 6,561 .715 878.140 8,115.594 5.00 4.01 3.01 37.13 12,355.573 88.633 92.478 6,592.398 822.537 9,400.280 0.00 0.00 0.00 0.00 12,439.573 90.000 96.450 6,593.400 816.000 9,484.000 5.00 1.63 4.73 71.04 1 D-28 L 1 Upper to ~ 12,447.488 89.605 96.479 6,593.427 815.109 9,491.864 5.00 -4.99 0.37 175.74 13,587.004 89.605 96.479 6,601.276 686.522 10,624.075 0.00 0.00 0.00 0.00 13,623.103 90.000 94.718 6,601.400 683.000 10,660.000 5.00 1.09 -4.88 -77.3810-28 L1 Upper to ~ 13,650.898 88.610 94.727 6,601.737 680.712 10,687.698 5.00 -5.00 0.03 179.64 14,117.540 88.610 94.727 6,613.055 642.270 11,152.616 0.00 0.00 0.00 0.00 14,146.017 90.000 94.417 6,613.400 640.000 11,181.000 5.00 4.88 -1.09 -12.58 10-28 L 1 Upper to ~ 14,873.192 90.630 94.417 6,609.400 " 584.000 11 ,906.000 0.09 0.09 0.00 0.00 1 D-28 L 1 Upper to ~ 11/19/2004 2:48:06PM Page 2 of6 COMPASS 2003.11 Bui/d 41 OR!GINAL . . Co~illips SPERRY_SUN HES Planning Report Database: EOM 2003.11 Single User Db ConocoPhHlips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 10 Pad Plan 1 0-28 Plan 1 D-28 L1 Plan 1 D-28 L1 (wp08) 100.000 0.000 0.000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 300.000 0.000 0.000 300.000 0.000 0.000 0.000 0.00 0.00 0.00 400.000 3.000 63.000 399.954 1.188 2.332 2.388 3.00 3.00 0.00 500.000 6.000 63.000 499.635 4.750 9.322 9.543 3.00 3.00 0.00 600.000 9.000 63.000 598.768 10.675 20.951 21 .448 3.00 3.00 0.00 700.000 12.000 63.000 697.082 18.947 37.187 38.069 3.00 3.00 0.00 800.000 15000 63.000 794.308 29.545 57.984 59.361 3.00 3.00 0.00 900.000 18.000 63.000 890.179 42.437 83.288 85.265 3.00 3.00 0.00 1,000.000 21.000 63.000 984.432 57.590 113.027 115.710 3.00 3.00 0.00 1,100.000 24.000 63.000 1 ,076.809 74.962 147.120 150.613 3.00 3.00 0.00 1,200.000 27.000 63.000 1,167.058 94.504 185.475 189.878 3.00 3.00 0.00 1,300.000 30.000 63000 1,254.929 116.164 227.986 233.397 3.00 3.00 0.00 1,400.000 33.000 63.000 1,340.183 139.883 274.535 281.052 3.00 3.00 0.00 1,500.000 36.000 63.000 1 ,422.586 165.594 324.997 332.711 3.00 3.00 0.00 1,600.000 39.000 63.000 1,501.912 193.228 379.232 388.234 3.00 3.00 0.00 1,700.000 42.000 63.000 1 ,577.944 222.709 437.092 447.467 3.00 3.00 0.00 1,800.000 45.000 63.000 1,650.473 253.957 498.418 510.249 3.00 3.00 0.00 1,900.000 48.000 63.000 1,719.300 286.884 563.042 576.407 3.00 3.00 0.00 2,000.000 51.000 63.000 1,784.237 321 .402 630.788 645.760 3.00 3.00 0.00 2,100.000 53.000 63.000 1 ,845.340 357.337 701.313 717.960 2.00 2.00 0.00 2,200.000 53.000 63.000 1 ,905.521 393.594 772.472 790.808 0.00 0.00 0.00 2,300.000 53.000 63.000 1,965.703 429.851 843.631 863.656 0.00 0.00 0.00 2,400.000 53.000 63.000 2,025.884 466.109 914.790 936.504 0.00 0.00 0.00 2,500.000 53.000 63.000 2,086.066 502.366 985.949 1,009.352 0.00 0.00 0.00 2,600.000 53.000 63.000 2,146.247 538.623 1,057.108 1,082.200 0.00 0.00 0.00 2,700.000 53.000 63.000 2,206.429 574.881 1,128.267 1,155.047 0.00 0.00 0.00 2,800.000 53.000 63.000 2,266.610 611.138 1,199.426 1,227.895 0.00 0.00 0.00 2,900.000 53.000 63.000 2,326.792 647.395 1,270.585 1,300.743 0.00 0.00 0.00 3,000.000 53.000 63.000 2,386.973 683.652 1,341.744 1 ,373.591 0.00 0.00 0.00 3,100.000 53.000 63.000 2,447.155 719.910 1,412.903 1,446.439 0.00 0.00 0.00 3,200.000 53.000 63.000 2,507.336 756.167 1,484.061 1,519.287 0.00 0.00 0.00 3,300.000 53.043 66.755 2,567.501 790.074 1 ,556.368 1 ,593.166 3.00 0.04 3.75 3,400.000 53.204 70.500 2,627.524 819.214 1,630.838 1,668.973 3.00 0.16 3.74 3,500.000 53.481 74.224 2,687.241 843.509 1,707.267 1,746.500 3.00 0.28 3.72 3,600.000 53.874 77.915 2,746.487 862.893 1,785.446 1 ,825.533 3.00 0.39 3.69 3,700.000 54.378 81.565 2,805.100 877.312 1 ,865.159 1 ,905.857 3.00 0.50 3.65 3,800.000 54.991 85.164 2,862.920 886.728 1 ,946.190 1,987.251 3.00 0.61 3.60 3,900.000 55.709 88.706 2,919.788 891.114 2,028.315 2,069.492 3.00 0.72 3.54 4,000.000 56.000 90.000 2,975.786 891 .459 2,111.163 2,152.258 1.11 0.29 1.29 4,100.000 56.000 90.000 3,031.705 891.459 2,194.067 2,235.063 0.00 0.00 0.00 4,200.000 56.000 90.000 3,087.624 891 .459 2,276.970 2,317.867 0.00 0.00 0.00 4,300.000 56.000 90.000 3,143.543 891 .459 2,359.874 2,400.671 0.00 0.00 0.00 4,400.000 56.000 90.000 3,199.463 891 .459 2,442.778 2,483.476 0.00 0.00 0.00 4,500.000 56.000 90.000 3,255.382 891 .459 2,525.682 2,566.280 0.00 0.00 0.00 4,600.000 56.000 90.000 3,311.301 891 .459 2,608.585 2,649.085 0.00 0.00 0.00 4,700.000 56.000 90.000 3,367.221 891 .459 2,691 .489 2,731.889 0.00 0.00 0.00 4,800.000 56.000 90.000 3,423.140 891 .459 2,774.393 2,814.694 0.00 0.00 0.00 4,900.000 56.000 90.000 3,479.059 891.459 2,857.297 2,897.498 0.00 0.00 0.00 5,000.000 56.000 90.000 3,534.979 891 .459 2,940.200 2,980.302 0.00 0.00 0.00 5,100.000 56.000 90.000 3,590.898 891 .459 3,023.104 3,063.107 0.00 0.00 0.00 5,200.000 56.000 90.000 3,646.817 891 .459 3,106.008 3,145.911 0.00 0.00 0.00 5.300.000 56.000 90.000 3,702.736 891 .459 3,188.912 3.228.716 0.00 0.00 0.00 11/19/2004 2:48:06PM Page 3 of6 COMPASS 2003.11 Build 41 o RIG I t\1 A L . I ~.",., ~.\! . . . Co~illips SPERRY_SUN HES Planning Report 5,400.000 56.000 90.000 3,758.656 891.459 3,271.815 3,311.520 0.00 0.00 0.00 5,500.000 56.000 90.000 3,814.575 891 .459 3,354.719 3,394.325 0.00 0.00 0.00 5,600.000 56.000 90.000 3,870.494 891 .459 3,437.623 3,477.129 0.00 0.00 0.00 5,700.000 56.000 90.000 3,926.414 891 .459 3,520.527 3,559.933 0.00 0.00 0.00 5,800.000 56.000 90.000 3,982.333 891 .459 3,603.430 3,642.738 0.00 0.00 0.00 5,900.000 56.000 90.000 4,038.252 891 .459 3,686.334 3,725.542 0.00 0.00 0.00 6,000.000 56.000 90.000 4,094.171 891 .459 3,769.238 3,808.347 0.00 0.00 0.00 6,100.000 56.000 90.000 4,150.091 891 .459 3,852.142 3,891.151 0.00 0.00 0.00 6,200.000 56.000 90.000 4,206.010 891 .459 3,935.045 3,973.956 0.00 0.00 0.00 6,300.000 56.000 90.000 4,261.929 891 .459 4,017.949 4,056.760 0.00 0.00 0.00 6,400.000 56.000 90.000 4,317.849 891 .459 4,100.853 4,139.564 0.00 0.00 0.00 6,500.000 56.000 90.000 4,373.768 891 .459 4,183.757 4,222.369 0.00 0.00 0.00 6,600.000 56.000 90.000 4,429.687 891 .459 4,266.661 4,305.173 0.00 0.00 0.00 6,700.000 56.000 90.000 4,485.606 891 .459 4,349.564 4,387.978 0.00 0.00 0.00 6,800.000 56.000 90.000 4,541.526 891 .459 4,432.468 4,470.782 0.00 0.00 0.00 6,900.000 56.000 90.000 4,597.445 891.459 4,515.372 4,553.587 0.00 0.00 0.00 7,000.000 56.000 90.000 4,653.364 891.459 4,598.276 4,636.391 0.00 0.00 0.00 7,100.000 56.000 90.000 4,709.284 891 .459 4,681.179 4,719.195 0.00 0.00 0.00 7,200.000 56.000 90.000 4,765.203 891.459 4,764.083 4,802.000 0.00 0.00 0.00 7,300.000 56.000 90.000 4,821.122 891 .459 4,846.987 4,884.804 0.00 0.00 0.00 7,400.000 56.000 90.000 4,877.041 891 .459 4,929.891 4,967.609 0.00 0.00 0.00 7,500.000 56.000 90.000 4,932.961 891 .459 5,012.794 5,050.413 0.00 0.00 0.00 7,600.000 56.000 90.000 4,988.880 891.459 5,095.698 5,133.218 0.00 0.00 0.00 7,700.000 56.000 90.000 5,044.799 891 .459 5,178.602 5,216.022 0.00 0.00 0.00 7,800.000 56.000 90.000 5,100.719 891 .459 5,261 .506 5,298.826 0.00 0.00 0.00 7,900.000 56.000 90.000 5,156.638 891 .459 5,344.409 5,381.631 0.00 0.00 0.00 8,000.000 56.000 90.000 5,212.557 891 .459 5,427.313 5,464.435 0.00 0.00 0.00 8,100.000 56.000 90.000 5,268.477 891 .459 5,510.217 5,547.240 0.00 0.00 0.00 8,200.000 56.000 90.000 5,324.396 891 .459 5,593.121 5,630.044 0.00 0.00 0.00 8,300.000 56.000 90.000 5,380.315 891.459 5,676.024 5,712.849 0.00 0.00 0.00 8,400.000 56.000 90.000 5,436.234 891 .459 5,758.928 5,795.653 0.00 0.00 0.00 8,500.000 56.000 90.000 5,492.154 891 .459 5,841.832 5,878.457 0.00 0.00 0.00 8,600.000 56.000 90.000 5,548.073 891 .459 5,924.736 5,961 .262 0.00 0.00 0.00 8,700.000 56.000 90.000 5,603.992 891.459 6,007.639 6,044.066 0.00 0.00 0.00 8,800.000 56.000 90.000 5,659.912 891 .459 6,090.543 6,126.871 0.00 0.00 0.00 8,900.000 56.000 90.000 5,715.831 891 .459 6,173.447 6,209.675 0.00 0.00 0.00 9,000.000 56.000 90.000 5,771.750 891 .459 6,256.351 6,292.480 0.00 0.00 0.00 9,100.000 56.000 90.000 5,827.669 891 .459 6,339.254 6,375.284 0.00 0.00 0.00 9,200.000 56.000 90.000 5,883.589 891 .459 6,422.158 6,458.089 0.00 0.00 0.00 9,300.000 56.000 90.000 5,939.508 891 .459 6,505.062 6,540.893 0.00 0.00 0.00 9,400.000 56.000 90.000 5,995.427 891 .459 6,587.966 6,623.697 0.00 0.00 0.00 9,500.000 56.000 90.000 6,051.347 891 .459 6,670.869 6,706.502 0.00 0.00 0.00 9,600.000 56.000 90.000 6,107.266 891 .459 6,753.773 6,789.306 0.00 0.00 0.00 9,700.000 56.000 90.000 6,163.185 891 .459 6,836.677 6,872.111 0.00 0.00 0.00 9,800.000 56.000 90.000 6,219.104 891 .459 6,919.581 6,954.915 0.00 0.00 0.00 9,900.000 56.000 90.000 6,275.024 891.459 7,002.484 7,037.720 0.00 0.00 0.00 10,000.000 56.891 90.070 6,330.827 891 .450 7,085.466 7,120.601 0.89 0.89 0.07 10,100.000 61.881 90.435 6,381.733 891.063 7,171.501 7,206.514 5.00 4.99 0.36 10,200.000 66.872 90.769 6,424.962 890.111 7,261.634 7,296.493 5.00 4.99 0.33 10,300.000 71.864 91.078 6,460.184 888.598 7,355.180 7,389.852 5.00 4.99 0.31 10,400.000 76.856 91.370 6,487.131 886.539 7,451.426 7,485.882 5.00 4.99 0.29 10,500.000 81.848 91.650 6,505.600 883.947 7,549.639 7,583.851 5.00 4.99 0.28 10,600.000 85.000 91.823 6,516.039 880.878 7,649.028 7,682.971 3.16 3.15 0.17 10,700.000 85.000 91.823 6,524.755 877.709 7,748.597 7,782.266 0.00 0.00 0.00 10,800.000 85.000 91.823 6,533.471 874.540 7,848.166 7,881.560 0.00 0.00 0.00 10,803.000 85.000 91.823 6,533.732 874.445 7,851.154 7,884.539 0.00 0.00 0.00 StartOLS15.00 TF02211.76 11/1912004 2:48:06PM Page 4 of6 COMPASS 2003.11 Build 41 ORH31NAL . . eonoco1:1,illips SPERRY_SUN HES Planning Report -11.44 -9.82 7,901.577 7,934.948 15.00 10,853.906 80.000 Start OLS5.00 TF031.13 10,900.000 81.839 11,000.000 85.846 11,069.318 88.633 Start Hold ·1286.255 11,100.000 88.633 11 ,200.000 88.633 11,300.000 88.633 11,400.000 88.633 11,500.000 88.633 11,600.000 88.633 11,700.000 88.633 11,800.000 88.633 11,900.000 88.633 12,000.000 88.633 12,100.000 88.633 12,200.000 88.633 12,300.000 88.633 12,355.573 88.633 Start DLS 5.00TFO 71.04 12,400.000 89.355 94.577 6,593.177 819.803 9,444.613 9,473.415 12,439.573 90.000 96.450 6,593.400 816.000 9,484.000 9,512.569 Start DI..S 5.00 TFO 175.74 -1D-28L1<Upper to Mid C-Sal1dTgt1 Pt1 12,447.488 89.605 96.479 6,593.427 815.109 9,491.864 9,520.380 Start Hold 1139.51$ 12,500.000 89.605 12,600.000 89.605 12,700.000 89.605 12,800.000 89.605 12,900.000 89.605 13,000.000 89.605 13,100.000 89.605 13,200.000 89.605 13,300.000 89.605 13,400.000 89.605 13,500.000 89.605 13,587.004 89.605 Start DLS 5.00 TFO-n.38 13,600.000 89.747 95.848 6,601.349 685.127 10,636.996 10,657.779 13,623.103 90.000 94.718 6,601.400 683.000 10,660.000 10,680.652 StartOLS5.00 TF0179.64 -<1D;,28 L1 Upper to MidC-Sand Tgt2 Pt2 13,650.898 88.610 94.727 6,601.737 680.712 10,687.698 10,708.205 start HOld 466.641 13,700.000 88.610 13,800.000 88.610 13,900.000 88.610 14,000.000 88.610 14,100.000 88.610 14,117.540 88.610 Stàrt<OLS 5.00 TFO ;'12.58 14,146.017 90.000 94.417 6,613.400 640.000 11,181.000 11,198.923 StartDLSß.09"'[FOO.00 " 1D-28L1 Upperto MidC-Sand Tgt3Pt3 14,200.000 90.047 94.417 6,613.378 635.843 11,234.822 14,300.000 90.133 94.417 6,613.221 628.142 11,334.525 14,400.000 90.220 94.417 6,612.912 620.440 11,434.228 14,500.000 90.307 94.417 6,612.452 612.739 11,533.930 86.000 6,540.380 875.388 3.99 4.01 4.02 7,947.015 7,980.460 8,046.388 8,079.806 8,115.594 8,148.843 5.00 5.00 5.00 87.404 6,547.654 6,558.378 6,561.715 878.005 879.888 878.140 3.01 2.98 90.412 92.478 79.386 8,278.933 8,378.480 8,478.026 8,577.573 8,677.120 8,776.667 8,876.214 8,975.761 9,075.307 9,174.854 9,274.401 9,373.948 9,429.269 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 8,146.238 8,246.116 8,345.994 8,445.872 8,545.750 8,645.628 8,745.506 8,845.384 8,945.262 9,045.140 9,145.018 9,244.896 9,344.774 9,400.280 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 92.478 6,562.447 6,564.833 6,567.218 6,569.603 6,571.989 6,574.374 6,576.760 6,579.145 6,581.530 6,583.916 6,586.301 6,588.687 6,591.072 6,592.398 876.813 872.490 868.168 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 0.00 863.845 859.522 855.199 850.876 846.553 842.230 837.908 833.585 829.262 824.939 822.537 4.72 4.73 1.62 1.63 4.99 5.01 0.37 5.00 -4.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9,544.040 9,643.399 9,742.758 9,842.117 9,941.475 10,040.834 10,140.193 10,239.552 10,338.911 10,438.270 10,537.629 10,624.075 9,572.204 9,670.891 9,769.579 9,868.267 9,966.954 10,065.642 10,164.329 10,263.017 10,361.705 10,460.392 10,559.080 10,644.942 96.479 96.479 96.479 96.479 96.479 96.479 96.479 96.479 96.479 96.479 96.479 96.479 6,593.789 6,594.478 6,595.166 6,595.855 6,596.544 6,597.233 6,597.921 6,598.610 6,599.299 6,599.988 6,600.676 6,601 .276 809.183 797.899 786.614 775.330 764.046 752.761 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 0.00 741.477 730.193 718.908 707.624 696.340 686.522 -4.89 1.10 5.01 0.03 5.00 -5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10,756.869 10,855.977 10,955.085 11,054.193 11,153.301 11,170.684 0.00 0.00 0.00 0.00 0.00 0.00 676.667 668.429 660.191 651.953 643.715 642.270 10,736.619 10,836.249 10,935.880 11,035.510 11,135.141 11,152.616 94.727 6,602.928 6,605.353 6,607.779 6,61 0.204 6,612.629 6,613.055 94.727 94.727 94.727 94.727 94.727 4.88 -1.09 5.00 0.00 0.00 0.00 0.00 11 11,351.684 11,450.890 11,550.096 0.09 0.09 0.09 0.09 0.09 0.09 COMPASS 2003.11 Build 41 11/1912004 2:48:06PM Page 5 of6 nRI(~INAL t",..I I, iÍ "",.I ~..,.. Co~illips EDM 2003.11 Single User Db ConÖCOPhillipsAlaska Inc. (Kupafuk) Kuparuk River Unit · Kuparuk1 D Pad · Plan 1 D-28 · Plan 1 D-28 L1 Plan 1 D-28 L1 (vvp08) 14,600.000 90.393 94.417 6,611.841 605.038 11,633.631 11,649.301 0.09 0.09 0.00 14,700.000 90.480 94.417 6,611.078 597.337 11,733.331 11,748.505 0.09 0.09 0.00 14,800.000 90.567 94.417 6,610.165 589.636 11,833.030 11,847.707 0.09 0.09 0.00 14,873.192 90.630 94.417 6,609.400 584.000 11,906.000 11,920.314 0.09 0.09 0.00 Target(Toe) : 14873.192ftMD, 6609.400ft TVD,(5063ftFNl, 4022ft FEl, Sec17-T11N-R11E- 4 3/4" . 1D-28 l1Upper to Mid . . SPERRY_SUN HES Planning Report Well Plan 1 D-28 RKB-34.5 + 70.9GL-1OS.4 @ 1OS.4OOft (RKB-34.5 + 70. KB-34.5 + 70.9GL-1 OS.4 @ 1OS.400ft (RKB-34.5 + 70. True Minimum Curvature 1 D-28 L 1 Upper to M - plan hits tarç¡et - Point 1 D-28 L 1 Upper to M - plan hits target - Point 1 D-28 L 1 Upper to M - plan hits target - Point 1 D-28 L 1 Upper to M 0.00 0.00 6,609.400 584.000 11,906.000 5,959,989.243 572,570.476 70" 18' 03.456" N 149" 24' 44.015" W - plan misses by 906.275ft at 13966.853ft MD (6609.400 TVD, 654.683 N, 11002.486 E) - Point 0.00 0.00 0.00 0.00 6,613.400 640.000 11,181.000 5,960,039.383 571,845.117 70" 18' 04.018" N 149" 25' 05.149" W 0.00 6,593.400 816.000 9,484.000 5,960,201.660 570,146.915 70" 18' 05.772" N 149" 25' 54.618" W 0.00 6,601.400 683.000 10,660.000 5,960,078.171 571,323.837 70" 18' 04.448" N 149" 25' 20.337" W 14,873.192 10,803.000 10,853.906 11,069.318 12,355.573 12,439.573 12,447.488 13,587.004 13,623.103 13,650.898 14,117.540 14,146.017 14,873.192 11/1912004 2:48:06PM 6,533.732 6,540.380 6,561.715 6,592.398 6,593.400 6,593.427 6,601.276 6,601.400 6,601.737 6,613.055 6,613.400 6,609.400 43/4" 4-3/4 6-3/4 +NI"s (ft) 874.445 875.388 878.140 822.537 816.000 815.109 686.522 683.000 680.712 642.270 640.000 584.000 Start DLS 15.00 TFO 228.76 Start DLS 5.00 TFO 37.13 Start Hold 1286.255 Start DLS 5.00 TFO 71.04 Start DLS 5.00 TFO 175.74 Start Hold 1139.516 Start DLS 5.00 TFO -77.38 Start DLS 5.00 TFO 179.64 Start Hold 466.641 Start DLS 5.00 TFO -12.58 Start DLS 0.09 TFO 0.00 Target (Toe): 14873.192ft MD, 6609.400ft TVD, (5063ft FNL, 4022ft FEL Page 6 of6 COMPASS 2003.11 Bui/d 41 nR····Ir:'If\'AL u f ~ ! !,,:J 5 ¡.J, . ..' . . . ... '~-II- CoI1OCurI II. IPS ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 Plan 1 D-28 L 1 Plan: Plan 1 D-28 L 1 (wp08) Standard Planning Report - Geographic 19 November, 2004 n R J h.1 ~J ..!^ L· V :î ."""." ,,,li eonoa,;p¡,illips . SPERRY_SUN HES Planning Report - Geographic . EOM 2003.11 Single User Db nocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 Plan 1 0-28 L 1 Plan 1 D-28 L 1 (wp08) Well Plan 1 D-28 RKB-34.5 + 70.9GL-105.4@ 105.4OOft (RKB-34.5 + 70. RKB-34.5 + 70.9GL-1 OS.4 @ 1OS.4OOft (RKB-34.5 + 70. True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, Unitéd States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site. Kuparuk 1 D Pad, KRU Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,959,669.675ft 561,086.445ft 1000" Latitude: Longitude: Grid Convergence: 70· 18' 01.317" N 149° 30' 18.921" W 0.47 . wen Plan 1 D·28 Well Position +N/-S +E/-W Position Uncertainty 0.000 ft O.OOOft 0.000 ft Northing: Easting: Wellhead Elevation: 5,959,309.200 ft 560,670.720ft ft Latitude: Longitude: Ground Level: 70· 17' 57.805" N 149· 30' 31.126" W 0.000 ft Wellbore Plan 10-28 L 1 bggm2004 11/18/2004 24.57 80.75 57,582 Design· Audit Notes: Version: Plan 10-28 L1 (wp08) 4 Phase: PLAN Tie On Depth: 10,803.000 0.000 87.195 10,803.000 85.000 91.823 6,533.732 874.445 7,851.154 0.00 0.00 0.00 0.00 10,853.906 80.000 86.000 6,540.380 875.388 7,901.577 15.00 -9.82 -11.44 228.76 11,069.318 88.633 92.478 6,561.715 878.140 8,115.594 5.00 4.01 3.01 37.13 12,355.573 88.633 92.478 6,592.398 822.537 9,400.280 0.00 0.00 0.00 0.00 12,439.573 90.000 96.450 6,593.400 816.000 9,484.000 5.00 1.63 4.73 71.04 1 D-28 L 1 Upper to ~ 12,447.488 89.605 96.479 6,593.427 815.109 9,491.864 5.00 -4.99 0.37 175.74 13,587.004 89.605 96.479 6,601.276 686.522 10,624.075 0.00 0.00 0.00 0.00 13,623.103 90.000 94.718 6,601.400 683.000 10,660.000 5.00 1.09 -4.88 -77.38 10-28 L 1 Upper to ~ 13,650.898 88.610 94.727 6,601.737 680.712 10,687.698 5.00 -5.00 0.03 179.64 14,117.540 88.610 94.727 6,613.055 642.270 11,152.616 0.00 0.00 0.00 0.00 14,146.017 90.000 94.417 6,613.400 640.000 11,181.000 5.00 4.88 -1.09 -12.5810-28 L1 Upper to ~ 14,873.192 90.630 94.417 6,609.400 584.000 11,906.000 0.09 0.09 0.00 0.00 10-28 L 1 Upper to ~ 11/1912004 2:49:51PM Page 2 of6 COMPASS 2003.11 Build 41 ORIGl~JAL . . Cor1oc:ÓPhillips SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (KuparUk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 Plan 10-28 L1 Plan 1 D-28 L 1 (wp08) 100.000 0.000 0.000 100.000 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W 300.000 0.000 0.000 300.000 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W 400.000 3.000 63.000 399.954 1.188 2.332 5,959,310.407 560,673.042 70° 17' 57.817" N 149° 30' 31.058" W 500.000 6.000 63.000 499 .635 4.750 9.322 5,959,314.025 560,680.003 70° 17' 57.852" N 149° 30' 30.854" W 600.000 9.000 63.000 598.768 10.675 20.951 5,959,320.043 560,691.582 70° 17' 57.910" N 149° 30' 30.515" W 700.000 12.000 63.000 697.082 18.947 37.187 5,959,328.445 560,707.749 70° 17' 57.991" N 149° 30' 30.042" W 800.000 15.000 63.000 794.308 29.545 57.984 5,959,339.209 560,728.458 70° 17' 58.096" N 149° 30' 29.436" W 900.000 18.000 63.000 890.179 42.437 83.288 5,959,352.304 560,753.654 70° 17' 58.222" N 149° 30' 28.698" W 1,000.000 21.000 63.000 984.432 57.590 113.027 5,959,367.695 560,783.267 70° 17' 58.372" N 149° 30' 27.831" W 1,100.000 24.000 63.000 1,076.809 74.962 147.120 5,959,385.340 560,817.216 70° 17' 58.542" N 149° 30' 26.837" W 1,200.000 27.000 63.000 1,167.058 94.504 185.475 5,959,405.189 560,855.408 70° 17' 58.735" N 149° 30' 25.719" W 1,300.000 30.000 63.000 1 ,254.929 116.164 227.986 5,959,427.190 560,897.738 70° 17' 58.948" N 149° 30' 24.480" W 1,400.000 33.000 63.000 1,340.183 139.883 274.535 5,959,451.281 560,944.091 70° 17' 59.181" N 149° 30' 23.123" W 1,500.000 36.000 63.000 1,422.586 165.594 324.997 5,959,477.397 560,994.338 70° 17' 59.434" N 149° 30' 21 .652" W 1,600.000 39.000 63.000 1 ,501 .912 193.228 379.232 5,959,505.465 561,048.343 70° 17' 59.705" N 149° 30' 20.071" W 1,700.000 42.000 63.000 1,577.944 222.709 437.092 5,959,535.410 561 ,105.958 70° 17' 59.995" N 149° 30' 18.384" W 1,800.000 45.000 63.000 1 ,650.473 253.957 498.418 5,959,567.148 561,167.024 70° 18' 00.303" N 149° 30' 16.596" W 1,900.000 48.000 63.000 1,719.300 286.884 563.042 5,959,600.593 561,231.374 70° 18' 00.626" N 149° 30' 14.712" W 2,000.000 51.000 63.000 1,784.237 321.402 630.788 5,959,635.653 561 ,298.832 70° 18' 00.966" N 149° 30' 12.737" W 2,100.000 53.000 63.000 1,845.340 357.337 701.313 5,959,672.153 561,369.058 70° 18' 01.319" N 149° 30' 10.680" W 2,200.000 53.000 63.000 1,905.521 393.594 772.472 5,959,708.980 561,439.915 70° 18' 01.676" N 149° 30' 08.606" W 2,300.000 53.000 63.000 1,965.703 429.851 843.631 5,959,745.807 561 ,510.772 70° 18' 02.032" N 149° 30' 06.531" W 2,400.000 53.000 63.000 2,025.884 466.109 914.790 5,959,782.634 561,581.629 70° 18' 02.389" N 149° 30' 04.456" W 2,500.000 53.000 63.000 2,086.066 502.366 985.949 5,959,819.461 561,652.487 70° 18' 02.745" N 149° 30' 02.382" W 2,600.000 53.000 63.000 2,146.247 538.623 1,057.108 5,959,856.288 561,723.344 70° 18' 03.102" N 149° 30' 00.307" W 2,700.000 53.000 63.000 2,206.429 574.881 1 ,128.267 5,959,893.115 561,794.201 70° 18' 03.458" N 149° 29' 58.232" W 2,800.000 53.000 63.000 2,266.610 611.138 1,199.426 5,959,929.942 561,865.058 70° 18' 03.815" N 149° 29' 56.158" W 2,900.000 53.000 63.000 2,326.792 647.395 1,270.585 5,959,966.770 561 ,935.915 70° 18' 04.171" N 149° 29' 54.083" W 3,000.000 53.000 63.000 2,386.973 683.652 1,341.744 5,960,003.597 562,006.772 70° 18' 04.528" N 149° 29' 52.008" W 3,100.000 53.000 63.000 2,447.155 719.910 1,412.903 5,960,040.424 562,077.629 70° 18' 04.884" N 149° 29' 49.933" W 3,200.000 53.000 63.000 2,507.336 756.167 1,484.061 5,960,077.251 562,148.486 70° 18' 05.241" N 149° 29' 47.858" W 3,300.000 53.043 66.755 2,567.501 790.074 1 ,556.368 5,960,111.737 562,220.509 70° 18' 05.574" N 149° 29' 45.750" W 3,400.000 53.204 70.500 2,627.524 819.214 1,630.838 5,960,141.474 562,294.735 70° 18' 05.860" N 149° 29' 43.579" W 3,500.000 53.481 74.224 2,687.241 843.509 1,707.267 5,960,166.383 562,370.958 70° 18' 06.099" N 149° 29' 41.350" W 3,600.000 53.874 77.915 2,746.487 862.893 1,785.446 5,960,186.396 562,448.970 70° 18' 06.290" N 149° 29' 39.071" W 3,700.000 54.378 81.565 2,805.100 877.312 1 ,865.159 5,960,201.457 562,528.557 70° 18' 06.431" N 149° 29' 36.747" W 3,800.000 54.991 85.164 2,862.920 886.728 1 ,946.190 5,960,211 .526 562,609.501 70° 18' 06.524" N 149° 29' 34.384" W 3,900.000 55.709 88.706 2,919.788 891.114 2,028.315 5,960,216.574 562,691.580 70° 18' 06.566" N 149° 29' 31.990" W 4,000.000 56.000 90.000 2,975.786 891.459 2,111.163 5,960,217.588 562,774.415 70° 18' 06.570" N 149° 29' 29.574" W 4,100.000 56.000 90.000 3,031.705 891 .459 2,194.067 5,960,218.257 562,857.308 70° 18' 06.569" N 149° 29' 27.157" W 4,200.000 56.000 90.000 3,087.624 891.459 2,276.970 5,960,218.926 562,940.201 70° 18' 06.569" N 149° 29' 24.740" W 4,300.000 56.000 90.000 3,143.543 891.459 2,359.874 5,960,219.596 563,023.094 70° 18' 06.569" N 149° 29' 22.323" W 4,400.000 56.000 90.000 3,199.463 891.459 2,442.778 5,960,220.265 563,105.987 70° 18' 06.569" N 149° 29' 19.906" W 4,500.000 56.000 90.000 3,255.382 891.459 2,525.682 5,960,220.934 563,188.880 70° 18' 06.568" N 149° 29' 17.489" W 4,600.000 56.000 90.000 3,311.301 891 .459 2,608.585 5,960,221.604 563,271.774 70° 18' 06.568" N 149° 29' 15.071" W 4,700.000 56.000 90.000 3,367.221 891.459 2,691.489 5,960,222.273 563,354.667 70° 18' 06.568" N 149° 29' 12.654" W 4,800.000 56.000 90.000 3,423.140 891.459 2,774.393 5,960,222.942 563,437.560 70° 18' 06.568" N 149° 29' 10.237" W 4,900.000 56.000 90.000 3,479.059 891.459 2,857.297 5,960,223.612 563,520.453 70° 18' 06.567" N 149° 29' 07.820" W 5,000.000 56.000 90.000 3,534.979 891.459 2,940.200 5,960,224.281 563,603.346 70° 18' 06.567" N 149° 29' 05.403" W 5,100.000 56.000 90.000 3,590.898 891 .459 3,023.104 5,960,224.950 563,686.239 70° 18' 06.567" N 149° 29' 02.986" W 5,200.000 56.000 90.000 3,646.817 891.459 3,106.008 5,960,225.619 563,769.132 70° 18' 06.566" N 149° 29' 00.569" W 5,300.000 56.000 90.000 3,702.736 891.459 3,188.912 5,960,226.289 563,852.025 70° 18' 06.566" N 149° 28' 58.152" W 5,400.000 56.000 90.000 3,758.656 891.459 3,271.815 5,960,226.958 563,934.918 70° 18' 06.566" N 149° 28' 55.735" W 5,500.000 56.000 90.000 3,814.575 891.459 3,354.719 5,960,227.627 564,017.812 70° 18' 06.565" N 149° 28' 53.317" W 5,600.000 56.000 90.000 3,870.494 891.459 3,437.623 5,960,228.297 564,100.705 70° 18' 06.565" N 149° 28' 50.900" W 5,700.000 56.000 90.000 3,926.414 891 .459 3,520.527 5,960,228.966 564,183.598 70° 18' 06.564" N 149° 28' 48.483" W 5,800.000 56.000 90.000 3,982.333 891.459 3,603.430 5,960,229.635 564,266.491 70° 18' 06.564" N 149° 28' 46.066" W 5,900.000 56.000 90.000 4,038.252 891.459 3,686.334 5,960,230.304 564,349.384 70° 18' 06.564" N 149° 28' 43.649" W 6,000.000 56.000 90.000 4,094.171 891.459 3.769.238 5,960,230.974 564,432.277 70° 18' 06.563" N 149° 28' 41.232" W 11/1912004 2:49:51PM Page 30f6 COMPASS 2003.11 Build 41 {)f)Ir- t\f f\ , j..."" '" <:';;;;¡/l ~ 1':\ ,'~ Í'<^"~? ".' "" ':"'.. . Co~illips . SPERRY_SUN HES Planning Report - Geographic EOM 2003.11 Single User Db ConOCòPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 Plan 1 D-28 l1 Plan 1 0-28 L 1 (wp08) Well Plan 10-28 RKB-34.5 + 70.9Gl-105.4 @ 105.400ft (RKB-34.5 + 70. RKB-34.5 + 70.9Gl-105.4 @ 105.4OOft (RKB-34.5 + 70. True inimum Curvature 6,100.000 56.000 90.000 4,150.091 891.459 3,852.142 5,960,231.643 564,515.170 70" 18' 06.563" N 149" 28' 38.815" W 6,200.000 56.000 90.000 4,206.010 891.459 3,935.045 5,960,232.312 564,598.063 70" 18' 06.562" N 149° 28' 36.398" W 6,300.000 56.000 90.000 4,261.929 891.459 4,017.949 5,960,232.982 564,680.956 70" 18' 06.562" N 149° 28' 33.981" W 6,400.000 56.000 90.000 4,317.849 891.459 4,100.853 5,960,233.651 564,763.850 70" 18' 06.562" N 149° 28' 31.564" W 6,500.000 56.000 90.000 4,373.768 891.459 4,183.757 5,960,234.320 564,846.743 70" 18' 06.561" N 149" 28' 29.146" W 6,600.000 56.000 90.000 4,429.687 891.459 4,266.661 5,960,234.989 564,929.636 70" 18' 06.561" N 149° 28' 26.729" W 6,700.000 56.000 90.000 4,485.606 891.459 4,349.564 5,960,235.659 565,012.529 70" 18' 06.560" N 149° 28' 24.312" W 6,800.000 56.000 90.000 4,541.526 891.459 4,432.468 5,960,236.328 565,095.422 70" 18' 06.560" N 149° 28' 21.895" W 6,900.000 56.000 90.000 4,597.445 891.459 4,515.372 5,960,236.997 565,178.315 70" 18' 06.559" N 149° 28' 19.478" W 7,000.000 56.000 90.000 4,653.364 891.459 4,598.276 5,960,237.667 565,261 .208 70" 18' 06.559" N 149° 28'17.061" W 7,100.000 56.000 90.000 4,709.284 891.459 4,681.179 5,960,238.336 565,344.101 70" 18' 06.558" N 149" 28'14.644" W 7,200.000 56.000 90.000 4,765.203 891 .459 4,764.083 5,960,239.005 565,426.994 70" 18' 06.558" N 149° 28' 12.227" W 7,300.000 56.000 90.000 4,821.122 891 .459 4,846.987 5,960,239.674 565,509.888 70° 18' 06.557" N 149° 28' 09.810" W 7,400.000 56.000 90.000 4,877.041 891.459 4,929.891 5,960,240.344 565,592.781 70" 18' 06.557" N 149° 28' 07.392" W 7,500.000 56.000 90.000 4,932.961 891.459 5,012.794 5,960,241.013 565,675.674 70" 18' 06.556" N 149° 28' 04.975" W 7,600.000 56.000 90.000 4,988.880 891.459 5,095.698 5,960,241.682 565,758.567 70" 18' 06.556" N 149° 28' 02.558" W 7,700.000 56.000 90.000 5,044.799 891 .459 5,178.602 5,960,242.352 565,841.460 70" 18' 06.555" N 149° 28' 00.141" W 7,800.000 56.000 90.000 5,100.719 891.459 5,261.506 5,960,243.021 565,924.353 70" 18' 06.554" N 149° 27' 57.724" W 7,900.000 56.000 90.000 5,156.638 891.459 5,344.409 5,960,243.690 566,007.246 70" 18' 06.554" N 149° 27' 55.307" W 8,000.000 56.000 90.000 5,212.557 891.459 5,427.313 5,960,244.359 566,090.139 70" 18' 06.553" N 149° 27' 52.890" W 8,100.000 56.000 90.000 5,268.477 891.459 5,510.217 5,960,245.029 566,173.032 70° 18' 06.553" N 149° 27' 50.473" W 8,200.000 56.000 90.000 5,324.396 891 .459 5,593.121 5,960,245.698 566,255.926 70" 18' 06.552" N 149° 27' 48.056" W 8,300.000 56.000 90.000 5,380.315 891.459 5,676.024 5,960,246.367 566,338.819 70° 18' 06.551" N 149° 27' 45.639" W 8,400.000 56.000 90.000 5,436.234 891.459 5,758.928 5,960,247.037 566,421.712 70° 18' 06.551" N 149° 27' 43.221" W 8,500.000 56.000 90.000 5,492.154 891.459 5,841.832 5,960,247.706 566,504.605 70" 18' 06.550" N 149" 27' 40.804" W 8,600.000 56.000 90.000 5,548.073 891.459 5,924.736 5,960,248.375 566,587.498 70° 18' 06.550" N 149° 27' 38.387" W 8,700.000 56.000 90.000 5,603.992 891 .459 6,007.639 5,960,249.044 566,670.391 70° 18' 06.549" N 149° 27' 35.970" W 8,800.000 56.000 90.000 5,659.912 891.459 6,090.543 5,960,249.714 566,753.284 70° 18' 06.548" N 149° 27' 33.553" W 8,900.000 56.000 90.000 5,715.831 891.459 6,173.447 5,960,250.383 566,836.177 70" 18' 06.548" N 149° 27' 31.136" W 9,000.000 56.000 90.000 5,771.750 891.459 6,256.351 5,960,251.052 566,919.070 70" 18' 06.547" N 149" 27' 28.719" W 9,1 00.000 56.000 90.000 5,827.669 891.459 6,339.254 5,960,251.722 567,001.964 70° 18' 06.546" N 149° 27' 26.302" W 9,200.000 56.000 90.000 5,883.589 891.459 6,422.158 5,960,252.391 567,084.857 70° 18' 06.546" N 149" 27' 23.885" W 9,300.000 56.000 90.000 5,939.508 891.459 6,505.062 5,960,253.060 567,167.750 70° 18' 06.545" N 149° 27' 21 .468" W 9,400.000 56.000 90.000 5,995.427 891.459 6,587.966 5,960,253.730 567,250.643 70" 18' 06.544" N 149° 27' 19.050" W 9,500.000 56.000 90.000 6,051.347 891.459 6,670.869 5,960,254.399 567,333.536 70° 18' 06.543" N 149° 27'16.633" W 9,600.000 56.000 90.000 6,107.266 891.459 6,753.773 5,960,255.068 567,416.429 70" 18' 06.543" N 149° 27' 14.216" W 9,700.000 56.000 90.000 6,163.185 891 .459 6,836.677 5,960,255.737 567,499.322 70° 18' 06.542" N 149° 27' 11.799" W 9,800.000 56.000 90.000 6,219.104 891.459 6,919.581 5,960,256.407 567,582.215 70° 18' 06.541" N 149° 27' 09.382" W 9,900.000 56.000 90.000 6,275.024 891.459 7,002.484 5,960,257.076 567,665.108 70" 18' 06.540" N 149° 27' 06.965" W 10,000.000 56.891 90.070 6,330.827 891.450 7,085.466 5,960,257.737 567,748.079 70° 18' 06.540" N 149° 27' 04.546" W 10,1 00.000 61.881 90.435 6,381.733 891 .063 7,171.501 5,960,258.045 567,834.106 70° 18' 06.535" N 149° 27' 02.037" W 10,200.000 66.872 90.769 6,424.962 890.111 7,261.634 5,960,257.820 567,924.236 70° 18' 06.525" N 149° 26' 59.409" W 10,300.000 71.864 91.078 6,460.184 888.598 7,355.180 5,960,257.063 568,017.782 70° 18' 06.509" N 149° 26' 56.682" W 10,400.000 76.856 91.370 6,487.131 886.539 7,451.426 5,960,255.781 568,114.032 70° 18' 06.488" N 149° 26' 53.876" W 10,500.000 81.848 91.650 6,505.600 883.947 7,549.639 5,960,253.983 568,212.253 70° 18' 06.461" N 149° 26' 51.013" W 10,600.000 85.000 91.823 6,516.039 880.878 7,649.028 5,960,251.716 568,311.655 70" 18' 06.430" N 149° 26' 48.115" W 10,700.000 85.000 91.823 6,524.755 877.709 7,748.597 5,960,249.352 568,411.237 70° 18' 06.398" N 149" 26' 45.212" W 10,800.000 85.000 91.823 6,533.471 874.540 7,848.166 5,960,246.987 568,510.818 70° 18' 06.366" N 149° 26' 42.309" W 10,803.000 85.000 91.823 6,533.732 874.445 7,851.154 5,960,246.916 568,513.806 70° 18' 06.365" N 149° 26' 42.222" W Start DLS 15,00 TFO 228]6 10,853.906 80.000 86.000 6,540.380 875.388 7,901.577 5,960,248.266 568,564.215 70° 18' 06.374" N 149° 26' 40.752" W StartDLS5.00 TF037.13 10,900.000 81.839 87.404 6,547.654 878.005 7,947.015 5,960,251.249 568,609.626 70° 18' 06.399" N 149° 26' 39.427" W 11,000.000 85.846 90.412 6,558.378 879.888 8,046.388 5,960,253.934 568,708.972 70° 18' 06.416" N 149° 26' 36.530" W 11,069.318 88.633 92.478 6,561.715 878.140 8,115.594 5,960,252.745 568,778.182 70° 18' 06.398" N 149° 26' 34.512" W Start Hold 1286,255 11,100.000 88.633 92.478 6,562.447 876.813 8,146.238 5,960,251.666 568,808.833 70° 18' 06.385" N 149° 26' 33.619" W 11,200.000 88.633 92.478 6,564.833 872.490 8,246.116 5,960,248.150 568,908.733 70" 18' 06.342" N 149° 26' 30.707" W 11/19/2004 2:49:51PM Page 4 0'6 COMPASS 2003.11 Build 41 r if¡. 1\ ø tJ! r\JJ~ L eonoOO'Phlllips . SPERRY_SUN HES Planning Report - Geographic .. EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (KuparUk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-28 . Plan 10-28 L1 Plan 1 D-28 L 1 (wp08) Well Plan 1 D-28 RKB-34.5 + 70.9GL-105.4 @ 105.400ft (RKB-34.5 + 70. RKB-34.5 + 70.9GL-1 05.4 @ 105.400ft (RKB-34.5 + 70. True Minimum Curvature 11,300.000 88.633 92.478 6,567.218 868.168 8,345.994 5,960,244.634 569,008.633 70° 18' 06.298" N 149° 26' 27.795" W 11 ,400.000 88.633 92.478 6,569.603 863.845 8,445.872 5,960,241.118 569,108.534 70° 18' 06.254" N 149° 26' 24.883" W 11,500.000 88.633 92.478 6,571.989 859.522 8,545.750 5,960,237.602 569,208.434 70° 18' 06.211" N 149° 26' 21.971" W 11,600.000 88.633 92.478 6,574.374 855.199 8,645.628 5,960,234.086 569,308.334 70° 18' 06.167" N 149° 26' 19.059" W 11,700.000 88.633 92.478 6,576.760 850.876 8,745.506 5,960,230.570 569,408.234 70° 18' 06.123" N 149° 26' 16.148" W 11,800.000 88.633 92.478 6,579.145 846.553 8,845.384 5,960,227.054 569,508.134 70° 18' 06.080" N 149° 26' 13.236" W 11,900.000 88.633 92.478 6,581 .530 842.230 8,945.262 5,960,223.538 569,608.034 70° 18' 06.036" N 149° 26' 10.324" W 12,000.000 88.633 92.478 6,583.916 837.908 9,045.140 5,960,220.022 569,707.934 70° 18' 05.992" N 149° 26' 07.412" W 12,100.000 88.633 92.478 6,586.301 833.585 9,145.018 5,960,216.506 569,807.834 70° 18' 05.949" N 149° 26' 04.500" W 12,200.000 88.633 92.478 6,588.687 829 .262 9,244.896 5,960,212.990 569,907.734 70° 18' OS.905" N 149° 26' 01 .588" W 12,300.000 88.633 92.478 6,591 .072 824.939 9,344.774 5,960,209.474 570,007.635 70° 18' 05.861" N 149° 25' 58.677" W 12,355.573 88.633 92.478 6,592.398 822.537 9,400.280 5,960,207.520 570,063.152 70° 18' 05.837" N 149° 25' 57.058" W Start DLS5.00 TFO 71.04 12,400.000 89.355 94.577 6,593.177 819.803 9,444.613 5,960,205.145 570,107.502 70° 18' 05.809" N 149° 25' 55.766" W 12,439.573 90.000 96.450 6,593.400 816.000 9,484.000 5,960,201.660 570,146.915 70° 18' 05.772" N 149° 25' 54.618" W Start DLS 5;00 TFO 175.74-10_28 L1 Upper to Mid C-5and Tgt1 pt1 12,447.488 89.605 96.479 6,593.427 815.109 9,491.864 5,960,200.833 570,154.785 70° 18' 05.763" N 149° 25' 54.389" W Start Hold .1139.516 12,500.000 89.605 96.479 6,593.789 809.183 9,544.040 5,960,195.329 570,207.002 70° 18' 05.704" N 149° 25' 52.868" W 12,600.000 89.605 96.479 6,594.478 797.899 9,643.399 5,960,184.848 570,306.439 70° 18' OS.592" N 149° 25' 49.971" W 12,700.000 89.605 96.479 6,595.166 786.614 9,742.758 5,960,174.368 570,405.876 70° 18' 05.479" N 149° 25' 47.075" W 12,800.000 89.605 96.479 6,595.855 775.330 9,842.117 5,960,163.887 570,505.313 70° 18' 05.367" N 149° 25' 44.178" W 12,900.000 89.605 96.479 6,596.544 764.046 9,941.475 5,960,153.406 570,604.751 70° 18' 05.255" N 149° 25' 41.282" W 13,000.000 89.605 96.479 6,597.233 752.761 10,040.834 5,960,142.925 570,704.188 70° 18' 05.143" N 149° 25' 38.386" W 13,100.000 89.605 96.479 6,597.921 741.477 10,140.193 5,960,132.444 570,803.625 70° 18' 05.030" N 149° 25' 35.489" W 13,200.000 89.605 96.479 6,598.610 730.193 10,239.552 5,960,121.964 570,903.062 70° 18' 04.918" N 149° 25' 32.593" W 13,300.000 89.605 96.479 6,599.299 718.908 10,338.911 5,960,111.483 571,002.500 70° 18' 04.806" N 149° 25' 29.69ì' W 13,400.000 89.605 96.479 6,599.988 707.624 10,438.270 5,960,101.002 571,101.937 70° 18' 04.693" N 149° 25' 26.800" W 13,500.000 89.605 96.479 6,600.676 696.340 10,537.629 5,960,090.521 571,201.374 70° 18' 04.581" N 149° 25' 23.904" W 13,587.004 89.605 96.479 6,601 .276 686.522 10,624.075 5,960,081.403 571,287.888 70° 18' 04.483" N 149° 25' 21.384" W Start DLS5.00 TFO "77.38 13,600.000 89.747 95.848 6,601.349 685.127 10,636.996 5,960,080.112 571,300.819 70° 18' 04.469" N 149° 25' 21 .007" W 13,623.103 90.000 94.718 6,601 .400 683.000 10,660.000 5,960,078.171 571,323.837 70° 18' 04.448" N 149° 25' 20.337" W Start DLS 5.00 TFO 179.64 -1D-28L1 Upper to .Mid C-5and Tgt2 PI2 13,650.898 88.610 94.727 6,601.737 680.712 10,687.698 5,960,076.107 571,351.550 70° 18' 04.425" N 149° 25' 19.529" W Start Hold 466.641 13,700.000 88.610 94.727 6,602.928 676.667 10,736.619 5,960,072.458 571,400.497 70° 18' 04.385" N 149° 25' 18.103" W 13,800.000 88.610 94.727 6,605.353 668.429 10,836.249 5,960,065.025 571,500.181 70° 18' 04.302" N 149° 25'15.199" W 13,900.000 88.610 94.727 6,607.779 660.191 10,935.880 5,960,057.592 571,599.866 70° 18' 04.220" N 149° 25' 12.295" W 14,000.000 88.610 94.727 6,610.204 651.953 11,035.510 5,960,050.160 571,699.550 70° 18' 04.137" N 149° 25' 09.390" W 14,100.000 88.610 94.727 6,612.629 643.715 11,135.141 5,960,042.727 571,799.234 70° 18' 04.055" N 149° 25' 06.486" W 14,117.540 88.610 94.727 6,613.055 642.270 11,152.616 5,960,041.423 571,816.718 70° 18' 04.040" N 149° 25' OS.977" W start OLS 5.00TFO -12.58 14,146.017 90.000 94.417 6,613.400 640.000 11,181.000 5,960,039.383 571,845.117 70° 18' 04.018" N 149° 25' 05.149" W Start DLS 0.09 TFO 0.00 -1D-28L1 Upper to Mid C-5and Tgt3 pt3 14,200.000 90.047 94.417 6,613.378 635.843 11 ,234.822 5,960,035.661 571,898.966 70° 18' 03.976" N 149° 25' 03.580" W 14,300.000 90.133 94.417 6,613.221 628.142 11,334.525 5,960,028.765 571,998.719 70° 18' 03.899" N 149° 25' 00.674" W 14,400.000 90.220 94.417 6,612.912 620.440 11,434.228 5,960,021.870 572,098.471 70° 18' 03.822" N 149° 24' 57.767" W 14,500.000 90.307 94.417 6,612.452 612.739 11 ,533.930 5,960,014.975 572,198.222 70°18' 03.744" N 149° 24' 54.861" W 14,600.000 90.393 94.417 6,611.841 605.038 11,633.631 5,960,008.080 572,297.972 70° 18' 03.667" N 149° 24' 51 .954" W 14,700.000 90.480 94.417 6,611.078 597.337 11,733.331 5,960,001.185 572,397.722 70° 18' 03.590" N 149° 24' 49.048" W 14,800.000 90.567 94.417 6,610.165 589.636 11,833.030 5,959,994.290 572,497.470 70° 18' 03.513" N 149° 24' 46.142" W 14,873.192 90.630 94.417 6,609.400 584.000 11 ,906.000 5,959,989.243 572,570.476 70° 18' 03.456" N 149° 24' 44.015" W Target (Toe) : 14873.192ft MO, 6609.400ftTVD, (5063ftFNL, 4022ft FEL,Sec17-T11N-R11E- 43/4" -1D-28L1Upper toM.id 11/1912004 2:49:51PM Page 5 of6 r' r~\ ì 1" ¡¡ t\ A I ;: ! . .I J, ~ it ~\ '_~ ·vf\" a 'JJ~' ........".. COMPASS 2003.11 Build 41 . Conocñ'Phillips SPERRY_SUN HES Planning Report - Geographic e EDM 2003.11 Single User Ob ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 0 Pad . Plan 1 D-28 Plan 1 0-28 L 1 Plan 1 D-28 L 1 (wp08) Well Plan 10-28 RKB-34.5 + 70.9GL-105.4 @ 1 OS. 400ft (RKB-34.5 + 70. RKB-34.S + 70.9GL-105.4@ 105.4OOft (RKB-34.5 + 70. True Minimum Curvature 1 D-28 L 1 Upper to M - plan hits target - Point 1 D-28 L 1 Upper to M - plan hits target - Point 1 D-28 L 1 Upper to M - plan hits target - Point 10-28 L 1 Upper to M 0.00 0.00 6,609.400 584.000 11 ,906.000 5,959,989.243 572,570.476 70° 18' 03.456" N 149° 24' 44.015" W - plan misses by 906.275ft at 13966.853ft MD (6609.400 TVD, 654.683 N, 11002.486 E) - Point 0.00 0.00 6,613.400 640.000 11,181 .000 5,960,039.383 571,845.117 70° 18' 04.018" N 149° 25' 05.149" W 0.00 0.00 6,593.400 816.000 9,484.000 5,960,201.660 570,146.915 70° 18' 05.772" N 149° 25' 54.618" W 0.00 0.00 6,601.400 683.000 10,660.000 5,960,078.171 571,323.837 70° 18' 04.448" N 149° 25' 20.337" W 14,873.192 43/4" 4-3/4 6-3/4 10,803.000 1 0,853.906 11,069.318 12,355.573 12,439.573 12,447.488 13,587.004 13,623.103 13,650.898 14,117.540 14,146.017 14,873.192 11/1912004 2:49:51PM 6,533.732 6,540.380 6,561.715 6,592.398 6,593.400 6,593.427 6,601.276 6,601.400 6,601.737 6,613.055 6,613.400 6,609.400 874.445 875.388 878.140 822.537 816.000 815.109 686.522 683.000 680.712 642.270 640.000 584.000 ) 7,851.154 7,901.577 8,115.594 9,400.280 9,484.000 9,491.864 10,624.075 10,660.000 10,687.698 11,152.616 11,181.000 11,906.000 Start OLS 15.00 TFO 228.76 Start OLS 5.00 TFO 37.13 Start Hold 1286.255 Start DLS 5.00 TFO 71 .04 Start OLS 5.00 TFO 175.74 Start Hold 1139.516 Start DLS 5.00 TFO -77.38 Start DLS 5.00 TFO 179.64 Start Hold 466.641 Start DLS 5.00 TFO -12.58 Start DLS 0.09 TFO 0.00 Target (Toe) : 14873.192ft MD, 6609.4OOft TVD, (5063ft FNL, 4022ft FEL Page 6 of6 COMPASS 2003.11 BuDd 41 . . ^ " if\. ¡ !\InL " ,', '.- '.-" . . lD-28 Ll Drillina Hazards Summary 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Trouble sidetracking off of aluminum billet Moderate Trouble Sliding / Steering Moderate Differential Sticking Moderate Difficulties getting upper liner to bottom with swell packers Moderate Lost Circulation Moderate Mitigation Strategy AKO setting on motor and bit selection will be tailored to this operation. Hole will be trenched prior to engaging the billet to aid in sidetracking. BiY'BHA design will take into account historical problems in offset horizontal wells with steering. Although LOTAD's should not be needed, torque/drag will be monitored to pro-actively identify a need for friction reduction devices to prevent weight transfer problems. Periodic wiper trips. Do not leave pipe static for extended period of time. Torque/drag will be monitored while drilling the interval. Check with the drilling assembly to ensure the hole section through the billet is fully open. A bent joint with a silver bullet shoe will be used on the end of the liner. Use PWD to monitor hole cleaning. Reduced pump rates[ Mud rheology, pre-treat with LCM prior to drilling fault crossings. Use LC decision tree designed for production laterals. An extensive LC strategy will be documented in the well plan. 1 D-28L 1 Drilling Hazards Summary. doc prepared by Scott Lowry 11/18/04 OR~ I r' IN·.·'A~··I^ . ë \;;.J f; , . '" f ·..v ~~ !~, ,.~ Page 10f1 1 D..28 Horizon Well Base Case Proposed Completion Schematic Con I ~ i ~ a ~ ~ ~ ~ ~ f ~ i ~ ~ ~ 4-1/2" FMO Gen V Tubing Hanger, 4-1/2" L-80 IBT pin down (Special 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91") 4-1/2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91") ~ 4-1/2" Camco 'DB' nipple w/3.875" No-Go Profile set at +1- 500' MD Surface csg. 10-3/4" 45.5# L-80 BTC Special Drift - 9.875" 6571' MD 14413' TVD (200' TVD below Base West Sak) 4-1/2" 12.6# L-80 IBT tubing to landing nipple (Special 4-1/2" xi" Camco 'KBG-2' Mandrels wI DV's (Max. OD 5.984", out wI 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as 20" conductor 118' BGL GLM # TVD-RKB MD-RKB GLM Setting Depths TBD 4-1/2" Camco 'DB' nipple wI 3.813" No-Go Profile set @ bottom of tangent section +1- 10,000 MD 16330' TVD 4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple tO$liçJing$It';$ve (Special Drift to 3.843") Baker 4-%" CMU Sliding Sleeve, 3.81" DB Profile 1 jt 4-1/2" 12.6# L-80 IBT tubing 4.75" OD Baker casing $eal assemblyw/1TFt stroke,4-1/2"12.6 # L-80 IBT box up (landed 3-4' off fully landed position) Intermediate csg. 7518" 29.7# L-80 8TCM 10,665' MD 16522' TVD (App. 50' MD below top of C4) 4 %" x 6.3" Swell Packers for isolation of potentially conductive faults or wet intervals ---- ----- Liner Assembly Hanqer Set +1- 150' above intermediate CSq shoe Baker 5 %" x 7 5/8" 'ZXP' Liner Top Isolation Packer wI HRD running profile , .......----- Baker 5 W x 7 5/8" 'Flexlock' Liner Hanger " Slotted Liner '4-1/2" 12.6#L-80IBT " ---,-- 01 Lateral "Plop & Drop" liner to11 ,929' MD (top of billet appro 50' below 75/8" csg shoe) Baker 5 W x 7 5/8" RS Nipple Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4 %" 12.6# L-80 IBT alternating slotted and blank pipe wI swell packers (installation of blank pipe & swell pkrs TBD with well logs) 4 W ROT 'Silver Bullet' Shoe ran on a bent joint of 4 %" 12.6# L-80 liner 4 %" x 6,3" Swell Packer ran in conjuntion with blank pipe and a pre-perforated joint to isolate lateral Scott Lowry 11/18/04 Slotted Liner KRU 1 D..28L 1 Proposed 1...011 . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k£U I D,- Zf(L / PTD# 2-Dt/ -2% /' Development Service CHECKWBAT APPLIES ADD-ONS (OPTIONS) M1JLTI LATERAL i/... (If API number last two. (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weUboresegment of existing weD ~ IV -:- 2'8 6r- Permit No,l,,7i37 API No. s-o-æfl-?-3Z3'1-¿'ó Production. sbould continue to be reponed as a function 'of tbe original API number. stated above. HOLE ]n accordance with 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to full compliance witb 20 AAC 25..05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater 1ban 30' sample intervals from below tbe permafrost or from where samples are fint caught and ] 0' sample hiter:vals tbrough target zones. Field & Pool KUPARUK RIVER. KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-28L 1 PTD#: 2042380 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit .11160 1 PemJitfee attachesL . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . Ml,Jltilateral well.segment; feellllaived per 20 AAC25.005(e) 2 .Lease .numberappropri<lte . . . . . . . . . . . . . . . . . Yes . Ml,Jltil<'lter.al wen .segment: top produ.ctiveJnterval <llJd TO in ADL .0282.43 3 .U.niqµe welln.ame.anQ oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Wellloc<lted in a defilJed.pool . Yes . . . . Kuparuk River Oil F?Qol. gov.emed by Con.servatioo Ord.er /\/0. .432C . . . . . . . . . . . . . . . . . . . . . 5 Wellloc<lted prpper .distance. from driJling µnitb.ound.aiy . Yes. . /\/Q interweJl restrictions. more than 50.0' from exlemaJ bounda.ry.. . 6 WelUoc<lted prpper .distance. from otber welJs. . . . . . . . Yes ............... . . . . . . . . . . . . . . . 7 .S.ufficient <lcreageayail<lble indrilJiog unit . . . . . . . . . . . . . Yes. 8 Jf.devi<'lted. js. wellbore pl<'ltilJcJuded . . . . . . . . . . . . . . . . No 9 .0J)erator only affected party. . Yes. 10 .0J)erator has.appropriate.bond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............... 11 PemJit c.an be issued witbQut conserva.tion order. ........ . Yes. Appr Date 12 Permit~an be issued witbQut administratÍlle.apprpval . . . . . . . . . . . . . . . . . . . . Yes. SFD 11/26/2004 13 Can permit be approved before 15-day wait NA 14 WelUocated within area <'Ind strat<l authorized by.lnjectiolJ Order # (puUO# incpmmeots) (For. .NA . . . . . . . 15 .AJI welJs.lIIlit!1in.1l4.mite.area.of review ideotified (Fpr servjc.e.w.ell only). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-produ.ced injector; .dµr<ltiQnof pre-J)rodµctiOIJ less t!1an 3. montbs (For.service wel! onJy) . . NA . . . . . . . 17 ACMP.F:indingofConsi$tencyh.as beenissµed.fortbis pr.oject . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . Administration Appr TEM 18 19 20 21 22 23 24 25 26 27 Date 28 11/29/2004 29 30 31 32 33 34 Engineering tk~· Geology 35 36 Date 37 11/26/2004 38 39 Appr SFD Geologic Commissioner: .ÇrlCj Program DEV On/Off Shore On Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . Inçlµded witb main welJbore application.(KBU '1 D-26:.P.TD2042370) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Condu.ctor string provided . . . . . . . . . NA S.urface casing protects alLknown. USOWs . . . . . . . . . . . . . . . . .NA CMTvo!adequateto circulate.on.cOnductor.& SUJf.csg . . . . . . . . . NA CMT v.o! adequ.ateto tie-in./ong .string tosµrf csg. . . . . . . . . . . . . .NA .CMTwill coyer.aJl knownprQdlJctiye hori~ons. . . . . . . . . . . . . No Casiog designs adeç¡ua.te fpr C.T. B&. permafrost . . . . . . . . . . . Yes. Adequ<ltetank<'lge.oJ re.serve pit. . . . . . . . . . Yes Jf.are-drill" hasa 10:403 fQr abandonment beeo <lPPJoved .. .................. .NA Adequ<lte.w.ellbore Sep<'Ir<ltio.n.proJ)osed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. If.diverter req.uired, does it meet regula.tions . . . . . . . NA .DJilJiog fluid. program s~hematic& eq.uip listadequale. . . . . . . . . Yes. BOPEs. do .they meet regulation . . . . . . . . Yes .B.OPEpress ra.tilJg apJ)ropriate;teslto.(pu.t psig in.comments). . . . . . . . . . . . . . . . . Yes Choke manifold complies wlAPI BF?-53. (May 84). . . . . . .. ................... Yes. WQrk wiJl OCCur withoytoperatjonshutdo.w.n . . . . . . . . . . . . . . Yes. Is preseoçe of H2S gas. probable . . . . . . . . . . . . . . . . . . . . . . . . . . No MecbanicalCOlJditlon Of wells within AOB verified (for. service welJ only). .NA · . . . Con.ductorsetio motherbore, 1.D.-28.(204-237). . .. .Allaq.uifersexempted..4.oCFR1.47.'102(ÞH3.)·...... · . . . Surtace ca.sing instalJe.din 10-28.. . . . . . . . . . . . . · . . . Intermediate. ~asing installed in. 1.D-28.. . . . . . . . . · Slottedlioer .completion plaoned. . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - · . . . Big is eqIJippedllllith steelpjts. . NQ reseJ\le.pjtp!anned, Waste to ¡:¡pproved é;lnMlus or.disposal well, - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - . . . . . . . I?rp~imi.ty. analysi$ pertorme.d, Nearest welJbpre.is mot.herbore loç¡;¡ted below. this JateJal.. . . . . . . . . . . . _ . . . . . BOP st<lckwill al(e<lQybeJn place, . . . . . . . . · M¡:¡ximum expected fPmJation pre~sµr.e.10.2EMW.. Planned mud weight.up to 10.2. ppg. . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - . . . M.;SI? çalc;uJate.d.at 27'82 psi, 35QO.p$iapproprjate.CPAJ usualJytes.ts to 5000 psi. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - ~ - - · 1:f2S m¡:¡y. be pJeseotin KUP per .offsets. .Mu.d .shouJd pre~lu.de 00 rig. . Big is equipped witb sensors <lod alarms. - - - - - - Permit can be issued w/o. hyd(ogen s.u!fide meas.ures. . . . . . . . . . .D.ata.presented on. pote.ntial overpre~sµre .zones. . . . . . . . . . .Sei.sr:nic.an¡:¡lysjs. of sballow gas.z.ooes. . . . . .. ....... Se¡:¡bed .conditioo survey (if off-sh.ore) . . CQntact namelp!1one.for.lIIleelsly progress reports [exploratoiy Only] · . . . Wells l.C:1.2a.nd1 D-.D4.0.3. mi. to east and 1. milllle$t, respectil(e!y, meas.ured90 <Ind. 47.ppmH2.S.in 2003.. . . · Expected reservoir J)re.S$ure is9,5to 10.2 ppg.EMW~ wilJ be driJled. with10.2ppg mud. . .. . . . . - - - - - - · No. · Yes. NA NA. · NA - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - Date: Engineering Commissioner: Date Public Commissioner Date pJ;;6j 1)I¿l/~ Original Signed B¥ John K. NormAn o . . . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . 0101-2-3 ~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 16 14:45:43 2005 -# ¡)t\qD Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name.............LISTPE Date.................... .05/02/16 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.................... .05/02/16 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA ID- 2 8 ¡;¡M" I- ( 500292323770 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 16-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 MW0003444739 C.A. DEMOSKI D. GREEN MWDRUN 5 MW0003444739 T. MCGUIRE E. VAUGHN MWD RUN 6 MW0003444739 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 7 MW0003444739 T. MCGUIRE E. VAUGHN MWDRUN 8 MW0003444739 T. MCGUIRE E. VAUGHN MWDRUN 9 MW0003444739 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 MW0003444739 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 23 IIN 10E 357 419 104.65 70.90 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 6581.0 . . 2ND STRING 3RD STRING PRODUCTION STRING 6.750 7.625 11065.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. 1D-28 EXITS THIS WELLBORE AT 11140'MD/6590'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1 - 3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 4 - 10 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE-WHILE-DRILLING (PWD). MWD RUNS 7 - 10 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND AT-BIT INCLINATION (ABI). MAD-PASS DATA ACQUIRED AFTER RUNS 6 & 8 TO FILL DATA GAPS WERE MERGED WITH MWD DATA FROM RUNS 6 & 8. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 4 - 10 REPRESENT WELL 1D-28 PB1 WITH API#: 50-029-23237-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11663'MD/6601'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.75" MUD WEIGHT: 10.0 - 10.1 PPG MUD SALINITY: 300 - 131,000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ . . File Header Service name..... ....... .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS FET RPD RPX RPM ROP FCNT NCNT NPHI RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6553.5 6560.0 6560.0 6560.0 6560.0 6560.0 6591.5 11002.5 11002.5 11003.5 11049.5 11049.5 11049.5 STOP DEPTH 11606.5 11613 .5 11613 .5 11613 .5 11613.5 11613.5 11663.0 11570.5 11570.5 11570.5 11585.0 11585.0 11585.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 4 6553.5 7683.5 MWD 5 7683.5 10924.5 MWD 6 10924.5 11075.0 MWD 7 11075.5 11095.0 MWD 8 11095.0 11573.0 MWD 9 11573.0 11603.0 MWD 10 11603.0 11663.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction... ............. .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.... ........ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 . GR PEF ROP NPHI MWD MWD MWD MWD API BARN FT/H PU-S 4 4 4 4 . 1 1 1 1 68 68 68 68 11 12 13 14 40 44 48 52 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6553.5 11663 9108.25 10220 6553.5 11663 FCNT MWD CNTS 116.64 527.7 327.019 1137 11002.5 11570.5 NCNT MWD CNTS 12841.8 27389.1 20263.3 1137 11002.5 11570.5 RHOB MWD G/CM 1. 62 4.97 2.54325 1072 11049.5 11585 DRHO MWD G/CM -0.598 2.08 0.131708 1072 11049.5 11585 RPD MWD OHMM 0.08 2000 23.88 10108 6560 11613 .5 RPM MWD OHMM 1. 01 2000 16.9363 10108 6560 11613 . 5 RPS MWD OHMM 0.07 1814.88 4.93478 10108 6560 11613 .5 RPX MWD OHMM 0.07 1112 .37 3.80258 10108 6560 11613.5 FET MWD HOUR 0.26 135.54 5.95947 10108 6560 11613 .5 GR MWD API 37.4 404.67 128.978 10107 6553.5 11606.5 PEF MWD BARN 1. 52 13 .47 4.46988 1072 11049.5 11585 ROP MWD FT/H 0.04 516.2 91.4666 10144 6591. 5 11663 NPHI MWD PU-S 14.72 52.44 27.8739 1135 11003.5 11570.5 First Reading For Entire File......... .6553.5 Last Reading For Entire File.......... .11663 File Trailer Service name...... ...... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name. ......... .STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPM RPD RPS RPX ROP $ 2 header data for each bit run in separate files. 4 .5000 START DEPTH 6553.5 6560.0 6560.0 6560.0 6560.0 6560.0 6591. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : STOP DEPTH 7645.5 7638.0 7638.0 7638.0 7638.0 7638.0 7683.5 28-DEC-04 Insite 66.37 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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.....O Logging Direction............ .....Down Optical log depth units...... .....Feet Data Reference Point........ ......Undefined Frame Spacing.................... .60 .1IN Max frames per record..... ....... . Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 7683.0 6553.0 7683.0 55.3 57.3 TOOL NUMBER 132482 66259 9.875 6581.0 LSND 9.75 50.0 9.0 300 5.8 2.700 1. 800 3.500 2.500 72.0 111.2 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6553.5 7683.5 7118.5 2261 6553.5 7683.5 RPD MWD040 OHMM 0.08 1877.35 14.4109 2157 6560 7638 RPM MWD040 OHMM 1. 64 1020.56 5.05975 2157 6560 7638 RPS MWD040 OHMM 1.58 19.74 3.97631 2157 6560 7638 RPX MWD040 OHMM 1. 53 12.61 3.83097 2157 6560 7638 FET MWD040 HOUR 0.27 82.25 3.30987 2157 6560 7638 GR MWD040 API 45.4 149.42 95.91 2185 6553.5 7645.5 ROP MWD040 FT/H 0.04 318.42 118.714 2185 6591.5 7683.5 . . First Reading For Entire File......... .6553.5 Last Reading For Entire File......... ..7683.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/02/16 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPS RPM FET RPX GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 7638.5 7638.5 7638.5 7638.5 7638.5 7646.0 7684.0 STOP DEPTH 10651.0 10651.0 10651.0 10651.0 10651.0 10887.0 10924.5 # 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: 01-JAN-05 Insite 66.37 Memory 10925.0 7683.0 10925.0 56.5 82.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 132482 66259 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 6581.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: LSND 10.00 54.0 9.0 . . 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: 300 4.7 2.600 1.815 2.800 2.100 73.0 107.5 73.0 73.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point......... .....Undefined Frame Spacing.................... .60 .1IN Max frames per record..... ....... . Undefined Absent value... . . . ....... . . . . ..... -999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7638.5 10924.5 9281. 5 6573 7638.5 10924.5 RPD MWD050 OHMM 0.91 2000 6.82743 6026 7638.5 10651 RPM MWD050 OHMM 1. 01 2000 5.72694 6026 7638.5 10651 RPS MWD050 OHMM 0.94 24.03 3.39419 6026 7638.5 10651 RPX MWD050 OHMM 0.86 12.4 3.09317 6026 7638.5 10651 FET MWD050 HOUR 0.26 10.84 1.48896 6026 7638.5 10651 GR MWD050 API 37.4 404.67 147.522 6483 7646 10887 ROP MWD050 FT/H 1. 68 516.2 90.2176 6482 7684 10924.5 First Reading For Entire File......... .7638.5 Last Reading For Entire File.......... .10924.5 File Trailer Service name... ........ ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record. .65535 File Type...... . .. . . . . . . . LO Next File Name. ..........STSLIB.004 Physical EOF File Header Service name.... .... .....STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 . Date of Generation. . . . . . .05/02/16 Maximum Physical Record. .65535 File Type....... . . . . . . . . . La Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPM RPD RPS GR Rap $ 4 . header data for each bit run in separate files. 6 .5000 START DEPTH 10651.5 10651.5 10651.5 10651. 5 10651.5 10887.5 10925.0 STOP DEPTH 11029.5 11029.5 11029.5 11029.5 11029.5 11037.5 11075.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down 02-JAN-05 Insite 66.37 Memory 11075.0 10925.0 11075.0 82.1 82.3 TOOL NUMBER 132477 134760 9.875 6581. 0 LSND 10.60 63.0 9.0 300 4.0 1.600 1.018 2.600 2.800 72.0 117.0 72.0 72.0 . . Optical log depth units.......... . Feet Data Reference Point........... ...Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10651.5 11075 10863.3 848 10651. 5 11075 RPD MWD060 OHMM 3.86 10.35 5.21254 757 10651.5 11029.5 RPM MWD060 OHMM 3.62 9.65 4.8844 757 10651. 5 11029.5 RPS MWD060 OHMM 2.95 9.2 3.89874 757 10651. 5 11029.5 RPX MWD060 OHMM 2.53 8.29 3.46553 757 10651. 5 11029.5 FET MWD060 HOUR 1.48 35.88 23.2968 757 10651. 5 11029.5 GR MWD060 API 71 139.17 119.376 301 10887.5 11037.5 ROP MWD060 FT/H 1.13 297.79 51.4741 301 10925 11075 First Reading For Entire File.. ........10651.5 Last Reading For Entire File...........11075 File Trailer Service name. ............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/16 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. ..... .05/02/16 Maximum Physical Record..65535 File Type...... ........ ..LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE Rap $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 11075.5 STOP DEPTH 11095.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 05-JAN-05 Insite 66.37 . 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 $ # 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 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 Memory 11095.0 11075.0 11095.0 82.1 82.1 TOOL NUMBER 6.750 11065.0 Flo-Pro 10.10 55.0 8.0 300 8.2 .080 .048 .080 .120 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD070 FT/H Min 11075.5 20.04 Max 11095 198.61 First Reading For Entire File......... .11075.5 Last Reading For Entire File.......... .11095 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record. .65535 File Type.............. ..LO Mean 11085.3 118.669 Nsam 40 40 . 68.0 117.0 68.0 68.0 First Reading 11075.5 11075.5 Last Reading 11095 11095 . 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...... .05/02/16 Maximum Physical Record. .65535 File Type...... . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI RPS FET RPX RPM RPD GR PEF DRHO RHOB ROP $ 6 . header data for each bit run in separate files. 8 .5000 START DEPTH 11002.5 11002.5 11003.5 11030.0 11030.0 11030.0 11030.0 11030.0 11038.0 11049.5 11049.5 11049.5 11095.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 11481. 5 11481.5 11481. 5 11522.0 11522.0 11522.0 11522.0 11522.0 11515.0 11493.5 11493.5 11493.5 11573.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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: 10-JAN-05 Insite 66.37 Memory 11573.0 11095.0 11573.0 85.7 90.3 TOOL NUMBER 64004 112439 113413 59475 6.750 11065.0 FLO-PRO 10.10 62.0 9.0 126000 3.0 .060 .037 68.0 114.8 . . MUD FILTRATE AT MT: MUD CAKE AT MT: .070 .080 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... .. .....0 Data Specification Block Type.....O Logging Direction.......... ...... .Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD080 CNTS 4 1 68 4 2 NCNT MWD080 CNTS 4 1 68 8 3 RHOB MWD080 G/CM 4 1 68 12 4 DRHO MWD080 G/CM 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MWD080 OHMM 4 1 68 32 9 FET MWD080 HOUR 4 1 68 36 10 GR MWD080 API 4 1 68 40 11 PEF MWD080 BARN 4 1 68 44 12 ROP MWD080 FT/H 4 1 68 48 13 NPHI MWD080 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11002.5 11573 11287.8 1142 11002.5 11573 FCNT MWD080 CNTS 116.64 527.7 322.259 959 11002.5 11481.5 NCNT MWD080 CNTS 12841.8 27389.1 20132.5 959 11002.5 11481.5 RHOB MWD080 G/CM 1.908 4.97 2.56421 889 11049.5 11493.5 DRHO MWD080 G/CM -0.598 2.08 0.0939955 889 11049.5 11493.5 RPD MWD080 OHMM 5.37 2000 164.704 985 11030 11522 RPM MWD080 OHMM 4.56 2000 120.849 985 11030 11522 RPS MWD080 OHMM 0.07 1814.88 15.7633 985 11030 11522 RPX MWD080 OHMM 0.07 1112.37 7.78924 985 11030 11522 FET MWD080 HOUR 0.74 135.54 18.3986 985 11030 11522 GR MWD080 API 45.47 124.14 89.3835 955 11038 11515 PEF MWD080 BARN 1. 78 13.47 4.7107 889 11049.5 11493.5 ROP MWD080 FT/H 0.13 171.05 54.0769 956 11095.5 11573 NPHI MWD080 PU-S 14.72 52.44 28.2558 957 11003.5 11481.5 First Reading For Entire File... .......11002.5 Last Reading For Entire File.......... .11573 File Trailer Service name...... .......STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record..65535 File Type........ . ...... .LO Next File Name.... .......STSLIB.007 . Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record..65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT DRHO PEF RHOB GR RPM RPX FET RPS RPD RAT $ 7 . header data for each bit run in separate files. 9 .5000 START DEPTH 11482.0 11482.0 11482.0 11494.0 11494.0 11494.0 11515.5 11522.5 11522.5 11522.5 11522.5 11522.5 11573.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 11511.5 11511.5 11511.5 11525.0 11525.0 11525.0 11546.0 11553.5 11553.5 11553.5 11553.5 11553.5 11603.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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: # 12-JAN-05 Insite 66.37 Memory 11603.0 11573.0 11603.0 89.6 89.6 TOOL NUMBER 64004 112439 113413 59475 6.750 11065.0 Flopro 10.10 52.0 9.0 129000 2.8 .060 .000 .070 .120 75.0 .0 71.0 70.0 . . NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...... .....Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record....... . .... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 NCNT MWD090 CNTS 4 1 68 8 3 RHOB MWD090 G/CM 4 1 68 12 4 DRHO MWD090 G/CM 4 1 68 16 5 RPD MWD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MWD090 OHMM 4 1 68 28 8 RPX MWD090 OHMM 4 1 68 32 9 FET MWD090 HOUR 4 1 68 36 10 GR MWD090 API 4 1 68 40 11 PEF MWD090 BARN 4 1 68 44 12 ROP MWD090 FT/H 4 1 68 48 13 NPHI MWD090 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11482 11603 11542.5 243 11482 11603 FCNT MWD090 CNTS 259.87 492.47 344.911 60 11482 11511.5 NCNT MWD090 CNTS 16947.9 25250.1 20365.6 60 11482 11511.5 RHOB MWD090 G/CM 1. 62 2.832 2.27133 63 11494 11525 DRHO MWD090 G/CM 0.029 0.522 0.23646 63 11494 11525 RPD MWD090 OHMM 11.88 21. 23 15.9275 63 11522.5 11553.5 RPM MWD090 OHMM 10.63 26.49 16.0757 63 11522.5 11553.5 RPS MWD090 OHMM 8.38 19.34 12.0095 63 11522.5 11553.5 RPX MWD090 OHMM 4.01 7.25 5.56778 63 11522.5 11553.5 FET MWD090 HOUR 80.99 81.79 81.4398 63 11522.5 11553.5 GR MWD090 API 79.19 97.65 88.2353 62 11515.5 11546 PEF MWD090 BARN 1. 52 5.01 2.59 63 11494 11525 ROP MWD090 FT/H 0.88 46.65 25.509 60 11573.5 11603 NPHI MWD090 PU-S 22.24 32.39 25.6782 60 11482 11511.5 First Reading For Entire File.. ........11482 Last Reading For Entire File.......... .11603 File Trailer Service name... ......... .STSLIB.007 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation. ..... .05/02/16 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.008 Physical EOF . File Header Service name... ....... ...STSLIB.008 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/16 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR RPS RPX FET RPM RPD ROP $ 8 . header data for each bit run in separate files. 10 .5000 START DEPTH 11512.0 11512.0 11512.0 11525.5 11525.5 11525.5 11546.5 11554.0 11554.0 11554.0 11554.0 11554.0 11603.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 11570.5 11570.5 11570.5 11585.0 11585.0 11585.0 11606.5 11613 .5 11613 .5 11613 .5 11613 .5 11613 .5 11663.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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: 12-JAN-05 Insite 66.37 Memory 11663.0 11603.0 11663.0 90.1 90.1 TOOL NUMBER 64004 112439 113413 59475 6.750 11065.0 Flopro 10.10 52.0 9.0 129000 3.0 .080 .058 .070 .090 74.0 104.0 74.0 74.0 . . HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units...... .....Feet Data Reference Point.......... ... .Undefined Frame Spacing..................... 60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD100 CNTS 4 1 68 4 2 NCNT MWD100 CNTS 4 1 68 8 3 RHOB MWD100 G/CM 4 1 68 12 4 DRHO MWD100 G/CM 4 1 68 16 5 RPD MWD100 OHMM 4 1 68 20 6 RPM MWD100 OHMM 4 1 68 24 7 RPS MWD100 OHMM 4 1 68 28 8 RPX MWD100 OHMM 4 1 68 32 9 FET MWD100 HOUR 4 1 68 36 10 GR MWD100 API 4 1 68 40 11 PEF MWD100 BARN 4 1 68 44 12 Rap MWD100 FT/H 4 1 68 48 13 NPHI MWD100 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11512 11663 11587.5 303 11512 11663 FCNT MWD100 CNTS 270.35 479.49 356.61 118 11512 11570.5 NCNT MWD100 CNTS 17334.3 25733.7 21274.4 118 11512 11570.5 RHOB MWD100 G/CM 2.242 4.172 2.53074 120 11525.5 11585 DRHO MWD100 G/CM -0.039 1.701 0.3561 120 11525.5 11585 RPD MWD100 OHMM 8.26 22.32 16.4182 120 11554 11613.5 RPM MWD100 OHMM 6.78 26.75 16.844 120 11554 11613.5 RPS MWD100 OHMM 4.57 26.06 13.464 120 11554 11613.5 RPX MWD100 OHMM 2.47 12.48 7.39225 120 11554 11613 . 5 FET MWD100 HOUR 2.14 86.03 26.9788 120 11554 11613.5 GR MWD100 API 78.71 102.67 89.7617 121 11546.5 11606.5 PEF MWD100 BARN 1.97 7.03 3.67275 120 11525.5 11585 ROP MWD100 FT/H 7.01 186.45 84.9112 120 11603.5 11663 NPHI MWD100 PU-S 21.72 31.72 25.8935 118 11512 11570.5 First Reading For Entire File.. ....... .11512 Last Reading For Entire File.......... .11663 File Trailer Service name. ............STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/02/16 Maximum Physical Record..65535 File Type...... . . . . . . . . . . LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/16 . . origin.................. .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name...........UNKNOWN Comments...... ...........STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .05/02/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN continuation Number..... .01 Next Reel Name..... ..... . UNKNOWN Comments...... .......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File