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Home My WebLink About205-1881. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Performed: Install Whipstock Perforate Other Stimulate Alter Casing Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 19269'feet None feet true vertical 6628' feet None feet Effective Depth measured 19269'feet 15494'feet true vertical 6628' feet 6561' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 15555' MD 6578' TVD Packers and SSSV (type, measured and true vertical depth) 15494' MD N/A 6561' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: HRD ZXP Liner Top packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer Slotted Liner: 15700-16591', 16842-16884', 17165-17449', 17714-19214' Slotted Liner: 6612-6604', 6601-6600', 6596-6587', 6583-6616' Offset Injector remains Shut-in measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 120' ~ ~~ ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-188 50-029-23288-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650, ADL0028243, ADL0028244 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-41 Plugs Junk measured Length Production Slotted Liner 15655' 3753' Casing 6611' 4-1/2" 15695' 19247' 6624' 9613' 120'Conductor Surface Intermediate 20" 10-3/4" 80' 9655' 4503' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations shutdown Change Approved Program Other: Offset for Marcit Trtmnt By Grace Christianson at 3:20 pm, May 22, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.05.22 11:35:04-08'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 3/29/2023 SUPPORT OTHER OPERATIONS PULLED 4.5" SLIP STOP & CHOKE @ 541' RKB; BRUSH n' FLUSHED D-NIPPLE @ 11,008' RKB; SET 2.25" CA-2 PLUG @ 11,008' RKB. READY FOR E-LINE IPROF.ttttt 4/1/2023 SUPPORT OTHER OPERATIONS PERFORM INJECTION PROFILE. WELL INJECTING AT 6250 BWPD, 900 PSI. PERFORM UP/DOWN PASS AND VERIFY ALL INJECTION IS GOING INTO LATERAL 2, CONFIRMED PLUG IN LATERAL 1 IS HOLDING (NO INJECTION INTO L1). JOB COMPLETE 4/19/2023 SUPPORT OTHER OPERATIONS Continue rigging up, spotting up equipment. Stage liquid and dry product. Troubleshoot generator issues. Perform safety / operations pre job walk down. Freeze protect 1D-11 flow line and 1D-10 tubing. Fill tank farm tanks with seawater from process line. Flood SNF mixing unit. Calibrate gel mixer, verify skid function. Performed step rate test, start 4000 ppm Marcit non cross linked, SNF skid unable to deliver mixed product at rate to LRS pump. Troubleshoot issue. 200 bbl polymer injected. No cross linker. - In Progress- 4/20/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot SNF skid mixing issues. Replace automated mixing tank valve, adjust marcit mother solution concentration and dilution pump ratios, trial changes on non cross linked gel, begin to pump stage #1, 4000 ppm Marcit polymer with Chromic Acetate cross linker @ maximum rate, skid performance limited, of 3 bpm. Totals - 3,199 bbls 4k gel stage one, WH 1,225 psi. - In Progress- 4/21/2023 SUPPORT OTHER OPERATIONS Pumped 3,650 bbls, 4k ppm Marcit gel in stage #1. Well head climbed from 1,225 to 1,300 psi, total gel pumped in stage one is 6,849 bbls. Main generator powering NSF skid started shutting down @ 22:00. Trouble shoot and restart multiple times. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/22/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot generator with nights field mechanic with no success. Flush and FP X-linked Marcit from surface with 120 bbl's diesel. Request replacement generator. Wrap and heat additional surface lines. Spot replacement generator and stand by for electricians to disconnect / reconnect. Electricians determined replacement generator not compatible with bolt up connections. Stand by for days field mechanic. Mechanic restarted generator, test run for 1 hr, energize NSF skid, test run. On line with 4000 ppm Marcit to establish injection. Pumped remaining 4000 ppm cross linked stage #1 - 7,639 bbls. Start pumping stage two, 5000 ppm Marcit 1D-28 and 1D-41 floc tests both negative. Total stage #2, 2,063 bbls - total vol. treatment 9,701 bbls - In Progress- 4/23/2023 SUPPORT OTHER OPERATIONS Pumped 4,230 bbls, 5k ppm Marcit gel in stage #2. Well head climbed from 1,475 to 1,550 psi. 1D-28 and 1D-41 floc tests both negative. Total stage #2, 6,293 bbls - total vol. treatment 13,931 bbls - In Progress- 4/24/2023 SUPPORT OTHER OPERATIONS Completed stage two, 7,804 bbls 5000 ppm Marcit. Completed stage three, 798 bbls 6000 ppm Marcit. Started stage four, 8000 ppm Marcit. Total stage #4, 1,293 bbls - total vol. treatment 17,534 bbls. Well head built from 1,325 psi to 1,450 psi during stage #4. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/25/2023 SUPPORT OTHER OPERATIONS Completed stage four, 2,108 bbls total of 8,000 ppm Marcit. Started final stage five, 10,000 ppm Marcit. Total stage #5, 1,205 bbls - total vol. treatment 19,553 bbls. Well head built from 1,500 psi to 1,700 psi during stage #4 & 5. 1D-28 and 1D-41 floc tests both negative. - In Progress- 1D-11 Marcit Treatment 4/26/2023 SUPPORT OTHER OPERATIONS Pumped stage five, 10,000 ppm Marcit to completion. Flushed Marcit with 147 bbls water and 35 bbls diesel FP. Contacted PE to flag well 'do not inject'. FP seawater header flow line on 1D-10 with 10 bbls MetOH. Vac our surface lines, upright tanks and SNF skid. Job complete. Begin rig down of treating equipment. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1D-41 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: H2S, SET/PULL CAT SV 1D-41 7/18/2016 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 30" 20 15.00 40.0 120.0 120.0 WELDED SURFACE 10 3/4 9.95 42.3 9,655.1 4,503.5 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 39.7 15,695.0 6,610.6 29.70 L-80 BTC-M SLOTTED LINER 4 1/2 3.96 15,494.0 19,247.0 6,623.6 12.60 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.5 Set Depth 15,555.5 Set Depth 6,578.1 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-MOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.5 36.5 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 508.8 507.0 9.40 NIPPLE 5.210 CAMCO DB NO GO NIPPLE 3.875 4,269.1 2,608.2 67.42 GAS LIFT 5.984 CAMCO KBG-2 3.938 7,696.3 3,805.6 69.62 GAS LIFT 5.984 CAMCO KBG-2 3.938 9,927.2 4,603.9 68.07 GAS LIFT 5.984 CAMCO KBG-2 3.938 11,647.6 5,203.5 70.28 GAS LIFT 5.984 CAMCO KBG-2 3.938 12,899.4 5,653.6 68.87 GAS LIFT 5.984 CAMCO KBG-2 3.938 13,987.7 6,069.2 69.24 GAS LIFT 5.984 CAMCO KBG-2 3.938 15,415.5 6,537.1 70.74 NIPPLE 5.210 CAMCO DB NO GO NIPPLE 3.813 15,513.7 6,566.9 73.88 LOCATOR 5.500 BAKER SEAL ASSEMBLY LOCATOR 3.960 15,515.4 6,567.3 73.92 SEAL ASSY 4.720 BAKER BONDED SEAL ASSEMBLY w/ 17' OF SEALS 3.880 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,269.1 2,608.2 67.42 1 GAS LIFT GLV BK 1 1,284.0 3/3/2011 0.156 7,696.3 3,805.6 69.62 2 GAS LIFT OV BK-5 1 0.0 1/17/2008 0.250 9,927.2 4,603.9 68.07 3 GAS LIFT DMY BK-5 1 0.0 7/3/2007 0.000 11,647.6 5,203.5 70.28 4 GAS LIFT DMY BK-5 1 0.0 10/31/2006 0.000 12,899.4 5,653.6 68.87 5 GAS LIFT DMY BK-5 1 0.0 10/30/2006 0.000 13,987.7 6,069.2 69.24 6 GAS LIFT DMY BK-5 1 0.0 3/28/2006 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 15,494.0 6,561.3 73.30 PACKER 6.530 HRD ZXP LINER TOP PACKER 4.940 15,512.6 6,566.6 73.85 NIPPLE 6.100 'RS' PACKOFF NIPPLE 4.870 16,629.1 6,603.5 90.68 Swell Packer 5.000 SWELL PACKER 3.958 16,815.4 6,601.5 90.31 Swell Packer 5.000 SWELL PACKER 3.958 16,921.7 6,599.2 91.97 Swell Packer 5.000 SWELL PACKER 3.958 17,107.5 6,596.1 88.90 Swell Packer 5.000 SWELL PACKER 3.958 17,486.7 6,585.9 91.29 Swell Packer 5.000 SWELL PACKER 3.958 17,664.7 6,583.1 89.77 Swell Packer 5.000 SWELL PACKER 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 15,700.0 16,591.0 6,611.6 6,604.3 C-4, 1D-41 3/2/2006 32.0 SLOTS Alternating slotted/solid pipe w/Swell Packers 16,842.0 16,884.0 6,601.4 6,600.5 C-4, 1D-41 3/2/2006 32.0 SLOTS Alternating slotted/solid pipe w/Swell Packers 17,165.0 17,449.0 6,595.6 6,586.7 C-4, 1D-41 3/2/2006 32.0 SLOTS Alternating slotted/solid pipe w/Swell Packers 17,714.0 19,214.0 6,583.4 6,616.5 C-4, 1D-41 3/2/2006 32.0 SLOTS Alternating slotted/solid pipe w/Swell Packers 1D-41, 5/16/2023 4:37:10 PM Vertical schematic (actual) SLOTTED LINER; 15,494.0- 19,247.0 SLOTS; 17,714.0-19,214.0 SLOTS; 17,165.0-17,449.0 SLOTS; 16,842.0-16,884.0 SLOTS; 15,700.0-16,591.0 PRODUCTION; 39.7-15,695.0 GAS LIFT; 13,987.7 GAS LIFT; 12,899.4 GAS LIFT; 11,647.6 GAS LIFT; 9,927.2 SURFACE; 42.3-9,655.1 GAS LIFT; 7,696.3 GAS LIFT; 4,269.1 NIPPLE; 508.8 CONDUCTOR Insulated 30"; 40.0-120.0 KUP PROD KB-Grd (ft) 46.20 RR Date 4/2/2006 Other Elev 1D-41 ... TD Act Btm (ftKB) 19,269.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292328800 Wellbore Status PROD Max Angle & MD Incl (°) 94.33 MD (ftKB) 16,091.70 WELLNAME WELLBORE1D-41 Annotation Last WO: End DateH2S (ppm) 60 Date 11/10/2014 Comment SSSV: NIPPLE Conoco Phi • llips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount RECEIVED, Alaska Oil and Gas Commission . NOV 0 2 ?Pi 333 West 7 Avenue, Suite 100 AID48 Oil & Gas Cons. Col Anchorage, AK 99501 ao 5 I 4u � t4i t c. a37C!i Commissioner Dan Seamount: 1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, `s,�; a d '' ` 13 2 01 a/// tdti/i/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) 1 Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" - N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C-170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C -174 50029231400000 2030270 7' 1.00 8" 09/11/2011 14.8 10/15/2011 1C-190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 _ 15.2 10/16/2011 _ 1D-08 50029220266000 1770530 5'2" 1.20 6" , 5/28/2011 3.8 10/15/2011 1D -12 50029229480000 1990840 18" N/A _ 18" _ N/A 3.4 10/15/2011 1 D-41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 • • ~> ~ ~~'~"~ a.~ "'" z ,~, ' ~. ..~.. ., ; . . ~'~ N ~~; ~~" ~°'~ R~*~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o2Q~ - ~ ~ ~ Well History File Identifier Organizing (done> ^ Two-sided III IIIII II III II III ^ Rescan Needed III (I'III II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ (/~ /s/ Protect Proofing III (IIIII IIIII II III BY: Maria Date: ~ ~~ 8 /s/ Scanning Preparation ~J x 30 = J v + ~ =TOTAL PAGES _ (Count does not include cover sheet) ` BY: Maria Date: ~ ~.s O /s/ Production Scanning III (IIIII IIIII II III Stage 1 Page Count from Scanned File: ~ (count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: /n/~s og /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III () ~) II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s! Comments about this file: Quality Checked III IIIII III II'I III 10!6/2005 Wefl History Fite Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2051880 Well Name/No. KUPARUK RIV UNIT 1D-41 MD 19269 TVD 6628 Completion Date 4/1/2006 REQUIRED INFORMATION Mud Log No Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23288-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc pt• __ _ _ -_ Directional Survey 13964 LIS Verification ~[Cf D Lis 1396~nduction/Resistivity ~~ Rpt 13965 LIS Verification D Lis 13965~duction/Resistivity 13966 L IS Verification ',ly D Lis E~ 13966/Induction/Resistivity D Aso Directional Survey D Asc Directional Survey Spinner ~ ~D C Li 16117" I ti /R i ti it d ,, s n on v uc es s y ~'ED C Lis 1611 i~lnduction/Resistivit y (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 15658 19269 Open 6/27/2006 1-3 118 15694 Open 6/27/2006 PB2 1-3 2962 16060 Open 6/27/2006 PB 2 GR, EWR4, ABI, CNP, SLD, ROP, PWD, Geoplot 2-3 2955 15892 Open 6/27/2006 P61 2-3 2962 15900 Open 6/27/2006 PB 1 GR, EWR4, SLD, ROP, PWD 1-3 118 15694 Open 6/27/2006 1-3 2962 19219 Open 6/27/2006 GR, EWR4, ABI, CNP, SLD, ROP, PWD, Geoplot 41 15947 Open 6/27/2006 PB 1 13611 16118 Open 6/27/2006 PB 2 5 Blu 1 100 14555 Case 7/3/2007 Gas Lift Survey, Spin, Temp, Pres, Grad 23-Jun- 2007 2955 19183 Open 4/21/2008 LIS Veri, RPD, RPM, RPX, RPS, FET, GR, ROP, NCNT, NPHI, RHOB, DRHO, FCNT w/CGM, EMF, PDF graphics 2955 15947 Open 4/21/2008 P61 LIS Veri, RPD, FET, RPS, RPM, RPX, GR, ROP w/CGM, EMF, PDF graphics DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2051880 Well NamelNo. KUPARUK RIV UNIT 1D-41 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23288-00-00 MD 19269 TVD 6628 Completion Date 4/1/2006 Completion Status 1-OIL Curren t Status 1-OIL UIC N C Lis 16117~-(iduction/Resistivity 2955 16049 Open 4/21/2008 PB2 LIS Veri, RPD,RPX, RPM, FET, RPS, GR, ROP, NCNT, FCNT, ', RHOB, DRHO w/CGM, EMF, PDF graphics wog Induction/Resistivity 25 Col 120 6628 Open 4/21!2008 TVD DGR, EWR, CTN, SLD 31-Mar-2006 Induction/Resistivity 25 Col 120 19269 Open 4/21/2008 MD DGR, EWR, CTN, SLD 31-Mar-2006 ~g Induction/Resistivity 25 Col 120 15947 Open 4/21/2008 P61 MD ROP, DGR EWR 26-Feb-2006 og InductionlResistivity 25 Col 120 6616 Open 4/21/2008 P61 TVD EWR, 26Feb- 2006 ~g Induction/Resistivity 25 Col 120 16118 Open 4/21/2008 PB2 MD ROP, DGR, EWR, CTN, SLD 12-Mar- /LOg Induction/Resistivity 25 Col 120 6640 Open 4!21/2008 2006 PB2 TVD DGR, EWR, «</// CTN, SLD 12-Mar-2006 Well Cores/Sam ples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~~JJJ Chips Received? ~ Analysis Received? Comments: / Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? / Formation Tops Y / N Date: 1._J WELL LOG TRANSMITTAL To: State of Alaska Apri17, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-41+PB1+PB2 AK-MW-4123607INUM 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 99S 18 1D-41+PBl+PB2 2" x S" MD TC Logs: 1 Color Log 50-029-23288-00,70,71 2" x S" TVD TC Logs: 1 Color Log S 0-029-23288-00,70,71 Digital Log Images 1 CD Rom S 0-029-23288-00,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attu Rob K~alis~ =~, 6900 Art'. Anchorage, Alaska 99S 18 ~~~ ~~~~~ ~; Date: ..signed: ~ ,was-~~5~ ~l~~r~- i ~i • • ConocoPh!!Ilps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVED AUG 1 3 2007 Alaska Oil & Gas Cons. Commission Amchorage a~~'~$ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions Sincerely, ------,~ ~` .J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 8/9/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of . cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 D-32 200-173 10" n/a n/a n/a 6.8 8/8/2007 1 D-36 200-130 20" n/a n/a n/a 4.2 8/8/2007 1 D-37 200-204 20" n/a n/a n/a 4.2 8/8/2007 1 D-38 200-077 24" n/a n/a n/a 4.2 8/8/2007 1 D-39 200-216 27" n/a n/a n/a 7.6 8/8/2007 1 D-40 200-190 13" n/a n/a n/a 3.4 8/8/2007 1 D-41 205-188 12" n/a Na n/a 1.7 8/8/2007 1 D-42 200-164 16" n/a n/a n/a 3.4 8/8/2007 1 D-131 198-110 6" n/a n/a n/a 2 8/8/2007 06/28/07 ~~i~~~~~~~~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~Q~ -1~~s Well Job # Log Description Date 2L-309 11665452 GLS 06/21107 1 3C-06 71632721 PRODUCTION PROFILE 06/21/O7 1 1D-41 11632723 GLS 06/23/07 1 N0.4315 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i WELL LOG TRANSMITTAL • To: State of Alaska June 9, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1D-41 PB2, AK-MW-4123607 1 LDWG formatted Disc with verification listing. API#: 50-029-23288-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 CEIVED D~~ ~ ~_ n~_ Signed:~~~~'". AIl~kB 0ll & Gas Cons. Commission Anchorage ._ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 9, 2006 RE: MWD Formation Evaluation Logs 1D-41 PB1, AK-MW-4123607 1 LDWG formatted Disc with verification listing. API#: 50-029-23288-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~~~IVEi~ Data) U N 2 '7 2006 alga oil & figs Cons. Core Anchorage .~ ~' Signed: ______ _. ~)C .., • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1D-41, 1 LDWG formatted Disc with verification listing. API#: 50-029-23288-00 June 9, 2006 AK-MW-4123607 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~E+~EIVED Date:JUN ~ ~ ~Mi; Oil &%,as Cons. Commission Anchorage Signed: (~ ~ , ~~ ~~~ ~_ .~ • • 15-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 D-41 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 15,658.88' MD Window /Kickoff Survey: 19,203.38' MD (if applicable) Projected Survey: 19,269.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 Date ~~~cvw.~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 15-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 D-41 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 41.40' MD Window /Kickoff Survey: 15,894.15' MD (if applicable) Projected Survey: 15,947.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 02. ~,~ Date ~J>~ ~/ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 15-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 D-41 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 13,611.48' MD Window /Kickoff Survey: 16,079.44' MD (if applicable) Projected Survey: 16,118.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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 Date 2? ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ConocoPhillips May 1, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 D-41 (APD 205-188) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 D-41. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, ` ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA # ~ ~ Lt„~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A~NkQ~ LOS-A 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ ~Z,e orAband.: April , 20065 12. Permit to Drill Number: 205-188 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 2, 2006 ~ 13. API Number: 50-029-23288-00 ` 4a. Location of Well (Governmental Section): Surface: 552' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM 7. Date TD Reached: ! March 25, 2006 14. Well Name and Number: 1 D-41 ` At Top Productive Horizon: 2069' FSL, 2546' FWL, Sec. 20, T11 N, R11 E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1358' FSL, 768' FWL, Sec. 21, T11N, R11E, UM 9. Plug Back Depth (MD + TVD): ~ /`~L~ `I iy/Dn~f~z~ '~TrD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- 5959114 ' Zone- 4 10. Total Depth (MD + TVD): ~ Z~ v~ 19269' MD / 6628' TVD 16. Property Designation: ADL 25650,28243, 28244 TPI: x- 573903 y- 5956574 Zone- 4 Total Depth: x- 577414 - 5955899 Zone- 4 11. Depth where SSSV set: landing nipple @ 508' 17. Land Use Permit: ALK 468, 3814, 2293 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1845' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.6# H-40 40' 118' 40' 118' 42" 250 sx AS I 10.75" 45.5# L-80 40' 9654' 40' 4503' 13.5" 1091 sx AS Lite, 680 sx LiteCrete 7-5/8" 29.7# L-80 40' 15694' 40' 6610' 9-7/8" 240 sx AS Lite 4.5" 12.6# L-80 15494' 19247' 6561' 6628' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 15556' 15494' slotted liner from 15700' - 19214' MD 6611'-6617' TVD , 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 27, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 4!30!2006 Hours Tested 24 hours Production for Test Period --> OIL-BBL 2667 GAS-MCF 2281 WATER-BBL 2726 CHOKE SIZE not available GAS-OIL RATIO 855 Flow Tubing press. 653 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2667 GAS-MCF 2281 WATER-BBL 2726 OIL GRAVITY -API (corr) 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". ' °- - ~ »• ••....... W i i~s~ ~~~~A~ ~F~- Mai ~ ~ Zoos NONE ~ ~~~ iii Form 10-407 Revised 12/2003 CONTINUED ON REVERSE OR{G{{~~L /2~ 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 D-41 Top Kuparuk C 15653' 6602' C-4 15653' 6602' N/A 1 D-41 P61 TD 15947' 6616' 1 D-41 PB2 TD 16118' 6640' 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: Tim Billingsley @ 265-6531 Printed N Randv Thomas Title: Greater Kuparuk Area Drillino Team Leader _ J if ~oE. Signature ~ ~1..r-~ . ~.r ~i+hone ~~ -~_~ ~ ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date ..From - To Mours Code Code Phase 1/28/2006 ;10:00 - 14:15 ~ 4.25 MOVE DMOB ~ MOVE _- 14:15 - 15:45 _ -- I - 1.50 MOVE II MOVE ~ MOVE 15:45 - 17:00 ' 1.25 MOVE DMOB 17:00 - 18:00 ' 1.00 MOVE DMOB 18:00 - 18:30 0.50 MOVE SFTY 18:30 - 20:30 2.00 MOVE MOB !0:30 - 21:30 1.00 MOVE OTHR MOVE MOVE MOVE MOVE MOVE 21:30 - 22:30 ' 1.00 MOVE MOVE MOVE 22:30 - 00:00 '; 1.50 MOVE MOVE MOVE 1 /29/2006 00:00 - 01:30 ! 1.50 MOVE MOVE MOVE 01:30 - 02:30 1.00'1 MOVE MOVE MOVE ~, 02:30 - 05:00 i 2.50 ~ MOVE MOVE MOVE 05:00 - 06:00 1.00 I', MOVE , MOVE MOVE 1!30/2006 06:00 - 06:30 0.50 06:30 - 08:00 1.50 08:00 - 09:00 1.00 09:00 - 10:00 1.00 10:00 - 12:00 2.00 12:00 - 13:00 1.00 13:00 - 13:30 I 0.50 13:30 - 16:30 I 3.00 16:30 - 18:00 I 1.50 !18:00-19:00' i 19:00 - 20:45 '; 20:45 - 22:00 ', 22:00 - 23:00 ~ 23:00 - 23:30 j 23:30 - 00:00 100:00 - 01:00 01:00 - 02:00 ', MOVE MOVE MOVE MOVE MOVE MOVE MOVE I MOVE MOVE WELCTLi NUND MOVE MOVE ', OTHR MOVE MOVE OTHR MOVE MOVE ' OTHR MOVE MOVE ' OTHR MOVE MOVE MOVE ; MOVE 1.00 MOVE I MOVE !MOVE 1.75 MOVE 'MOVE !MOVE 1.25 MOVE '~ MOVE ;MOVE 1.00 MOVE ,MOVE ;MOVE 0.50 MOVE I MOVE i MOVE 0.50 1.00 1.00 02:00 - 03:30 ', 1.50 MOVE I MOVE ', MOVE MOVE ~'i POSN ,MOVE MOVE IOTHR MOVE MOVE MOVE MOVE 03:30 - 04:00 I 0.50'', MOVE I SFTY I MOVE Page 1 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Blow down steam. Prepare to skid rig floor. Skid rig. Move pits away from well 1C-20. Set pits down, turn tires and pin the steering arms. Lay down surface riser, raise stomper on drill module. Place mats in front of drilling module. Jack up module and move off of well 1 C-20. PJSM on moving rig modules f/ 1 C-20 to 1 D-41. ~ Move drilling sub module to entrance/exit of 1C pad. Repair controls for moving system on rear of pit module. Remove matting boards, herculite and dunnage around 1C-20. Inspect rig moving equipment on pit and sub module. Move sub and pit modules from 1C pad towards KOC/KCC pad. Move sub and pit modules from 1 C pad to KOC/KCC pad. Approx 2 I miles moved. Moving drilling sub module and Pit module to KOC/KCC. I Move modules around white tent @KCC to head down Spine Road to 1 D pad. I Moving drilling sub module and Pit module f/ KOC/KCC towards 1 D pad. '~ Drilling sub module on 1 D pad @ 0500 hrs. Pit complex drove off the ', road approx 1/4 mile f/ 1 D pad. Working to get pit module back on road. !One of 4 front tires (Left) is off the main road. !:Crew change, PJSM. Drive pit module back onto road. Clearing snow from around 1 D-41 'where the stomper feet will sit down. ,'Move pit module to 1 D pad. Spread herculite over well head. Lay plywood down around cellar area. i,Attempt to nipple up on FMC 16" SOW head. Landing ring is bent (Apprears to have been damaged during snow removal 1-27-2006). Stage surface equipment, in cellar w/ cherry picker. I Shoot and level pad f/ rig. Stage tubing spool, casing spool and tbg head adapter in cellar. Lay herculite and mats for rig and pits. Move pit module up to mats. Turn tires. Set up a 3" x 12" board ramp for module to climb onto mats. Walk pit module on mats, move out of way fo drilling module. Move rig sub module up to mats. Turn tires to climb up mats. Walk rig sub onto mats, set down. ~i Turn tires on rig sub to walk over hole. it Raise stomper feet on both sides to clear well 1 D-40 on the left and well i 1 D-42 on the right. '~ Move sub closer to well. Repair hydraulic hose on rig moving system. I Move sub module over well. Field Drlg suprv, drillsite operator, rig ',supervisor, and tourpusher witnessed moving over well. ,Lower right and left stomper feet. Shim both legs to support 500 psi pre !load. Move and mate pit module to the Rig sub module. "GBR welders cut off starting head (2" below FMC landing ring), weld more 16" 1:031" wall thickness pipe usining procedure written by NSK FLD Mech Engr 6-1-2003, then weld another FMC 16" SOW x 16" ext neck landing ring to same elevation as original within 1/8". Rig floor to i top of landing ring is 41.00' PJSM for skidding rig module approx 38-40' to drilling position. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska 2.25 2.25 1.00 2.00 1.00 Page 2 of 53 Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date .From - To 'Hours Code ~ Code ---- -- _ _ POSN 1 /30/2006 05:00 - 05:30 0.50 i MOVE II SFTY 05:30 - 09:00 3.50 09:00 - 10:00 1.00 Operations Summary Report MOVE DRILL Phase MOVE MOVE RURD MOVE SFTY ',RIGUP 10:00 - 12:30 ~ 2.50 MOVE '~ RURD RIGUP 12:30 - 13:00 ~ 0.50 MOVE , RURD RIGUP 13:00 - 15:00 ! 2.00 I DRILL ' RIGUP 15:00 - 16:00 ', 1.00 DRILL ~ i SFTY RIGUP I 6:00 - 17:00 ', 1.00 ~ DRILL ,I I I OTHR I RIGUP 17:00 - 18:00 1.001 DRILL OTHR 'RIGUP 18:00 - 19:15 1.25' DRILL OTHR ',RIGUP 19:15 - 20:00 0.75 ', 20:00 - 22:00 2.00 22:00 - 00:00 2.00 1/31/2006 ', 00:00 - 00:30 0.50 00:30 - 01:30 1.00 ~I 01:30 - 02:30 ~ 1.00 ~I 02:30 - 04:30 2.00 04:30 - 06:00 1.50 ~I 06:00 - 08:00 III 2.00 08:00 - 10:15 'I 10:15 - 12:30 12:30 - 13:30 ', 13:30 - 15:30 15:30 - 16:30 16:30 - 17:30 WELCT OTHR ~, RIGUP WELCT OTHR RIGUP WELCT NUND RIGUP WELCTL NUND RIGUP WELCTL!, NUND RIGUP WELCTL NUND RIGUP WELCTL, NUND RIGUP RIGMNTi RSRV RIGUP WELCTL' NUND li RIGUP WELCTL' NUND I RIGUP WELCTL NUND ~ RIGUP WELCTL, NUND I RIGUP RIGMNT', RSRV ',RIGUP DRILL I PULD ;RIGUP 1.00'', DRILL PULD 'RIGUP Description of Operations Skid rig floor approx 38' to 40', to the drilling postion. PJSM for rigging up lines between modules (Mud,Water, air, fuel, steam). Hook up lines between rig module and pit module. Lay herculite f/ Rockwasher. Spot Rockwasher w/ Peak truck. Pre spud meeting w/drilling crew, MI SWACO field rep & MI Safety, ;CPAI Feld drilling Supt, CPAI drilling safety specialist, CPF1 Safety ',Specialist, CPF1 Prod engr f/ Kuparuk, CPF1 Prod Supervisor, 1 D DS ;operator, AES Construction Supt, AES Major Projects Supt, CPAI Field Environmental Coordinator, Sperry Sun Directional driller, Sperry Sun ', MWD hands. ',Note: Rig accepted @ 0900 hrs 1-30-2006 Continue to hook up lines between rig module and pit module. PU and organize after rig move. Move Beaver slide into position after skidding rig floor. !~ Cleanup and berm around rig. I Pre spud meeting w! drilling crew, MI SWACO field rep & MI Safety, CPAI field drilling Supt, CPAI drilling safety specialist, CPF1 Safety Specialist, CPF1 Prod engr f/ Kuparuk, CPF1 Prod Supervisor, 1 D DS operator, AES Construction Supt, AES Major Projects Supt, CPAI Field Environmental Coordinator, Sperry Sun Directional driller, Sperry Sun MWD hands. Put 17 joints of 5" drillpipe in pipe shed. Scaffolding crew setting ~I scaffolding around 1 D-42 in cellar area. Chain f/ elevator on pipe !, elevator on long side broke. Repairing chain while working on other !,stuff. '~ Install 3" x 12" wood on top of scaffolding over 1 D-42. Preparing !shakers in pits. 'Installing three guards on mud line standpipe in derrick to help and ', keep service loop on top drive f/ hanging up on clamps in derrick. Working on pipe elevator on long side of pipe shed. Move into the pipe shed a new hydraulic unit to use f/ skidding rig floor and operate pipe handling mach and top drive. !FMC test landing ring to 360 psi f/ 10 min w/ nitrogen. Good test. Thaw out and remove insulation inside of 16" conductor. 'Nipple up FMC quick connect, diverter outlet spool and 20" Annular. Start mixing spud mud. ', PJSM on nippling up/picking up 20" riser. PU/ NU 20" riser. Start loading 5" dp in pipe shed. Moving pipe f/ short ~, side to long side. RU knife valve. RU flow line, hole fill line, floor drains and turnbuckles to diverter riser. ~~~ Change saver sub on top drive f/ 4" XT 39 to 5" 4-1/21F. Change jaws Ion top drive backup wrench to 5". 'Load Pipe shed with 5" drill pipe Install 5" gripper and bell guide on top i drive. it Load pipe into pipe shed. it Nipple up diverter cannon. I Continue loading pipe shed with 5" drill pipe. Set track for rough neck. Hang blocks and slip and cut drill line. Pick up lift subs, cross overs, float sub. ghost reamer bit sub and drilling tools to rig floor. j Pick up 5" drill pipe and stand back in derrick. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date :From - To Hours ' Code Code ' Phase 1/31/2006 ! 17:30 - 18:00 ,18:00 - 20:30 0.50' RIGMNT 2.50 - - RIGMNT i __ RSRV ~ RGRP RIGUP RIGUP -_ - 20:30 - 00:00 3.501 DRILL I PULD RIGUP 2/1 /2006 ; 00:00 - 06:00 106:00 - 12:30 112:30 - 14:15 14:15 - 16:00 2/2/2006 16:00 - 16:30 16:30 - 17:00 17:00- 18:00 18:00- 19:30 19:30- 19:45 19:45 - 20:00 20:00 - 20:30 20:30 - 21:30 21:30 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 01:30 6.00 i DRILL ' ~~ PULD RIGUP 6.501 DRILL I PULD RIGUP 1.75; DRILL PULD RIGUP 1.751 WELCTL BOPE RIGUP 0.50 0.50 1.00 1.50 0.25 0.25 0.50 1.00 2.00 0.50 1.00 0.50 DRILL PULD RIGUP DRILL PULD RIGUP DRILL SFTY IRIGUP DRILL PULD SURFAC WELCTL , BOPE 'SURFAC DRILL PULD !SURFAC DRILL j PULD I~ SURFAC DRILL CIRC 'SURFAC DRILL •DRLG I SURFAC WELCTL I BOPE SURFAC DRILL i PULD SURFAC DRILL 'i. URM SURFAC I I 01:30 - 02:00 ! ~~ 0.50 I 02:00 - 03:15 I I 1.25 I 03:15 - 04:00 0.75 04:00 - 05:00 1.00 05:00 - 06:00 '.06:00 - 06:30 DRILL I DRLG II DRILL PULD DRILL SURV DRILL PULD 1.00! DRILL 0.50' DRILL SURFAC SURFAC Page 3 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Service top drive. While trouble shooting skate Work on electrical system on pipe skate. Continue to pick up 5" drill pipe and stand back in derrick. Spill drill. Response time 2 minutes 30 seconds. 35 stands picked up. Continue to pick up 5" drill pipe, standing back in derrick. Rabbit pipe as picked up. Continue to pick up 5" drill pipe, standing back in derrick. Rabbit pipe as picked up. Total 300 joints. Pick up 5" HWDP, standing back in derrick. Rabbit pipe as picked up. Energize koomey tines & hydril element. Time to close 30 seconds Start psi - 3000psi: 200 psi in 30 seconds full charge in 2 minuts 43 seconds /average 2300 psi from 5 bottles. AOGCC /Chuck Schieve waived wittness to test. Install covers around mousehole and bell nipple. Pick up jars with double of HWDP, stand back in derrick. PJSM with rig crew, Sperry and gyro hand in dog house. Pick up mud motor and BHA, Make up bit. Pressure test surface lines to 120 psi with air to check for leaks. Make up UBHO sub and orient to motor. Pick up stand from derrick and make up to BHA, Ready to spud. Fill Stack with spud mud and check rig for leaks. Clean our conductor 300 GPM = 200 psi. RPM = 40 = 1-3000ft# torque. Pressure test lines to 2500 psi. Good. Pick up MWD and orient UBHO sub fro gyro. Continue to clean out conductor to 160' at conductor shoe. 500 gpm = 1380 PSI RPM = 40 Torque 2 - 3000ft# WOB = 2 - 5000# Drilling 13-1/2" Hole f/ 160' to 199' 500 gpm = 1380 PSI RPM = 40 Torque 2 - 3000ft# WOB = 2 - 5000# POH and stand back 1 stand HWDP. Pick up 3 x NMFDC SURFAC !.Run gyro survey. Can not get consistance readings with tool face. '' POH with gyro and check for tell-tale. Had been seating. Lay down gyro and change out. SURFAC 'Pull back into shoe with BHA and change out gyro. RIH with gyro and seat 3 times. '~ Set TF to 102 GTF DRLG ', SURFAC I Drill from 199' to 330 feet ~~ 550 GPM = 1420 psi i Torque at 40 rpm = 2 -3K i AST = .39 hrs ART = .55 hrs Total bit hours = .98 hrs drilling Total Jar hours 169.21 DRLG 'SURFAC Drill from 330 feet to 350 feet Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To ', Hours ' Code Sub !Code 2/2/2006 06:00 - 06:30 I 0.50 I i I 06:30 - 07:30 1.00 07:30 - 09:30 '', 2.00 DRILL DRLG RIGMNT~~ RGRP RIGMNT! RGRP '!..09:30 - 10:15 ~I 10:15 - 11:45 I j11:45-12:001, Ali 12:00 - 12:30 ~'' 112:30 - 13:00 '; 13:00 - 13:30 ~' 13:30 - 18:00 '' 18:00 - 00:00 2/3/2006 0.75 `RIGMNT RGRP 1.50' RIGMNT RGRP 0.25! RIGMNT RGRP 0.50' DRILL 0.50 RIGMNT 0.50 DRILL 4.50 DRILL 6.00 DRILL 00:00 - 06:00 ' 6.00 DRILL I I Page 4 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Phase ' Description of Operations SURFAC '' 550 GPM = 1420 psi !Torque at 40 rpm = 2 -3K !AST = .0 hrs 'ART = .09 hrs 'Total bit hours = 1.12 hrs drilling ~I, Total Jar hours 169.3 SURFAC ~,I Blow down top drive. POH and change out damaged saver sub and bad ,,joint HWDP. Pull 90K to free string. Check other connection on HWDP, all good. SURFAC Install head pin and break circulation @ 1 bpm = 100 psi. increase to 4 bpm 200 psi. Pump hi-vis sweep and spot. Lay down damaged single HWDP. SURFAC PJSM to change out saver sub. Jars are cocked, wait for jars to relax. SURFAC Change out saver sub. SURFAC Pick up elevators. Pick up string. Make and break saver sub to break in. REAM !,SURFAC Back ream to clean up hole. 1"gravel coming out. 20 RPM = 2K torque i Pumping 3 BPM 200 psi. RSRV '; " SURFAC 'Trip in hole to 314' Install corrosion ring on double above jars. SURV ,SURFAC ~ Run gyro survey and check with MWD. DRLG 'SURFAC Drill from 350 feet to 627 feet 550 GPM = 1420 psi IiTorque at 40 rpm = 2 -3K AST = 1.41 hrs !.ART=.5 hrs I ADT = 1.91 'Total bit hours = 3.03 hrs drilling ~ ! Total Jar hours 172.24 ~i I, Up weight = 110,000# ~i I Down weight = 110,000# ' 'Rotating weight = 110,000# RPM = 30 = 3 - 4000ft# 500 GPM = 1200 psi on bottom 1100 psi off. DRLG SURFAC Drill from 627 feet to 1026 550 GPM = 1680 psi Torque at 40 rpm = 2 -3K AST = 1.31 hrs 1 ART = 2.15 hrs ADT = 3.46 Total bit hours = 6.49 hrs drilling I ' Total Jar hours 175.70 CI Up weight = 115,000# Down weight = 106,000# ~ ~~ Rotating weight = 122,000# ', ;RPM = 30 = 3 - 4000ft# 550 GPM = 1600 psi on bottom 1400 psi off. DRLG SURFAC II Drill from 1026 to 1654' 550 GPM = 1680 psi '. Torque at 40 rpm = 2 -3K !AST = 2.57 hrs ':.ART = 2.71 hrs ';Total bit hours = 10.69 hrs drilling Printed: 4!28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Page 5 of 53 Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To I Hours ' Code '~ Sub '~ Phase Description of Operations 2/3/2006 2/4/2006 00:00 - 06:00 06:00 - 12:00 12:00 - 19:20 19:20 - 20:00 20;00 - 00:00 00:00 - 00:45 00:45 - 03:00 ', 03:00 - 04:00 '! 04:00 - 04:30 04:30 - 05:15 05:15 - 06:00 06:00 - 07:30 07:30 - 07:45 07:45 - 08:15 08:15 - 08:45 08:45 - 09:45 09:45 - 12:00 ,Code, ___ __ __ 6.00 ~ DRILL DRLG 'SURFAC Total Jar hours181.70 ~'~ Up weight = 128,000# ', Down weight = 120,000# i j Rotating weight = 123,000# ' ' ~ RPM = 60 = 3 - 4000ft# ~~ 550 GPM = 1750 psi on bottom 1620 psi off. 6.001 DRILL DRLG SURFAC Drill from 1654' to 2240' and 1882' tvd ', I, ~ 580 GPM = 2110 psi Torque at 60 rpm = 4 -6K ;ART = 1.03 hrs I~ AST = 2.72 hrs Total bit hours = 14.44 hrs drilling 'Total Jar hours182.62 ', ' Up weight = 128,000# 'Down weight = 120,000# ',, Rotating weight = 123,000# ~, RPM = 60 = 3 - 4000ft# ' ' 550 GPM = 1750 psi on bottom 1620 psi off. 7.33 DRILL DRLG I SURFAC !.Drill from 2240' and 1882' tvd to 3001' and i ~ 504GPM = 2600 psi I Torque at 60 rpm = 4 -6K I ~ ~ Up weight = 128,000# Down weight = 120,000# Rotating weight = 123,000# ~ li RPM = 60 = 3 - 4000ft# '~ 550 GPM = 1750 psi on bottom 1620 psi off. ~ I Total Bit hours = 18.93 Total jar hours = 187.11 0.67 DRILL I CIRC :SURFAC ~i Circulate at 700 gpm = 2500 psi ~~ ', I RPM = 55 = 5000 ft# torque 4.00 DRILL I REAM ',SURFAC Pump out of hole 3001 to 1240' I, ~, ~ 3001 - 2000' @ 650 GPM = 2500 psi ' 1 I ~ = 1730 psi. Reduce pump rate to 450 GPM at 2000 ' 0.75 , DRILL I TRIP , SURFAC Continue to pump out of hole to +/- 1240 Monitir well. Pull out on elevators 1240 to HWDP. j Hoie taking correct 5.2 - 6 bbls per 5 stands 2.25 ~ DRILL PULD 'i SURFAC Pull HWDP, stand back and lay down mwd /break bit and drain motor. 1.00''x, DRILL PULD i SURFAC Hnadle BHA #2, Make up PDC bit and set bend in motor to 1.15 degrees. 0.50':' DRILL PULD SURFAC Orient motor to MWD offset. 0.75' DRILL PULD SURFAC Up load MWD and surface test. 0.75' DRILL PULD SURFAC !Make up NMFDC and HWDP from derrick. 1.50', DRILL TRIP SURFAC Run in hole from HWDP to 2071' Below perms-frost to test MWD tools. 0.25 j DRILL CIRC SURFAC Fill pipe and test MWD tools. All Good. 0.50' RIGMNT RSRV SURFAC Service top drive and crown. 0.50 !DRILL ' SURV SURFAC ~, Trip n hole from 2071 to 2929' 1.00'', DRILL I~ CIRC SURFAC Circulate bottoms up to warm and condition mud system. 513 GPM = ' ~ I 1380 psi 2.25 DRILL ~ DRLG SURFAC i Drill from 3001 to 3020 MD 2330' tvd ~ ~ 1900 GPM = 3050 psi i i ' Up weight = 148,000# !Down weight = 115,000# Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Page 6 of 53 Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours ___- 2/4/2006 09:45 - 12:00 i l - 2.25 i Iii 12:00 - 17:30 i ' ~ 5.50 I 117:30 - 18:00 0.50 '~ 18:00 - 22:00 4.00 22:00 - 23:00 I 1.00 23:00 - 00:00 1.00 2/5/2006 ' 00:00 - 01:15 1.25 01:15-02:15. 1.00 02:15 - 03:30 I 1.25 Code Code' Phase Description of Operations DRILL DRLG SURFAC ~~ Rotating weight = 130,000# ' Torque at 90 rpm = 7-8K I , I ART =.96 hrs j I AST = 0 hrs Total bit hours = .96 hrs drilling ~ ' ' ~ Total Jar hours188.07 I DRILL DRLG SURFAC I Drill from 3020 MD 2330' tvd to 3523' MD 2330 tvd '~ 'I900 GPM = 3250 psi ' Up weight = 170,000# Down weight = 110,000# ', I Rotating weight = 150,000# ~ ' Torque at 90 rpm =9-10K ft# DRILL CIRC ''SURFAC Circulate and condition while clean suction screens on pumps. DRILL DRLG SURFAC ~~ Drill from 3523' MD 2330 tvd to 3925' MD / 2489' TVD 900 GPM = 3250 psi Up weight = 170,000# i Down weight = 110,000# Rotating weight = 150,000# Torque at 90 rpm =9-10K ft# ,ART=.81 hrs ~~AST=.83hrs Total bit hours = 6.17 hrs drilling Total Jar hours 193.28 RIGMNT RGRP SURFAC ~i Change out swab and line pump #2 DRILL DRLG SURFAC I Drill from 3925' MD / 2489' TVD to 3966' MD / 2509' TVD 'I ~ 900 GPM = 3300 psi ', ' Up weight = 170,000# '', Down weight = 100,000# 'Rotating weight = 150,000# Torque at 90 rpm =9-12K ft# ',ART =.0 hrs it 'BAST=.32hrs ',Total bit hours = 6.49 hrs drilling 'Total Jar hours 193.60 DRILL DRLG ~i SURFAC 'Drill from 3966' MD / 2509' TVD to 4066' MD ', 900 GPM = 3300 psi RIGMNT RGRP 'I SURFAC ,Change out swab on pump #2 DRILL DRLG I SURFAC 'Drill from 4066' MD to 4162' 254TTVD ~~ ' 800 GPM = 2900 psi 'i ', Up weight = 170,000# ICI I 'Down weight = 90,000# ~ 'Rotating weight = 150,000# '~ ,Torque at 90 rpm =12-15K ft# I 'ART =0 hrs i BAST=.78hrs 'i Total bit hours =7.27 hrs drilling ;Total Jar hours 194.38 03:30 - 05:00 ', 1.50', DRILL CIRC j SURFAC !Circulate and pump out of hole taking survey's to confirm tool accuracy. 'First shot at 4001' showed 65 degrees and when retaken showed 71 degrees. ,With 60-70' of slide up still below survey point. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 7 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -D RILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM @conoco phillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 1 5 Rig Number: 15 Date From - To 'Hours Code 'Code ' Phase Description of Operations 2/5/2006 03:30 - 05:00 1.50 DRILL CIRC it SURFAC Pump out to 3871 checking each survey point. All survey's checked except the original at 4001' i 05:00 - 06:00 1.00 1 DRILL CIRC SURFAC t Pump out for short trip and clean up the hole from 3872 to 3689' 06:00 - 07:30 1.50 1 DRILL CIRC SURFAC I Pump out for short trip and clean up the hole from 3872 to 3689' 07:30 - 10:00 2.50 it DRILL TRIP SURFAC RIH from 3000 tp 3495 and reshoot survey, Good. Rih to 3971 re-shoot survey :Good RIH to 4066 Re-shoot survey Shows 71 degrees. Wash to 4166 and take survey and set tool face. 10:00 - 11:45 1.75 DRILL REAM SURFAC Worked pipe from 4069 to 4161' MD with tool face at 140 Left to knock ~I inclination out og hole. 900 gpm = 3320 psi. Up weight = 180,000# ~ i i Down weight= 90,000# t trough to reduce angle. it 11:45 - 18:00 6.25 DRILL DRLG SURFAC Drill from 4161 to 4730' MD 2771' TVD I i 800 GPM = 2900 psi ' i I~ Up weight = 180,000# ~ ' Down weight = 90,000# l ~ Rotating weight = 150,000# I i I I Torque at 90 rpm =12-15K ft# ~ ~ Total Jar hours 195.59 ' 18:00 - 19:30 ' 1.50 DRILL DRLG '.SURFAC Drill from 4739 to 4850' MD I I 'I 900 GPM = 3450 psi ' ~ Up weight = 205,000# I I ~I !, 'Down weight = 92,000# ', I li ~ I Rotating weight = 140,000# I ~ I I , Torque at 90 rpm =13-14K ft# ', , I ~ ' ,ART =.21 hrs I I I iA$T=.67hrs ~ ~ I 'Total bit hours =12.24hrs drilling ~~ 19 I 30 20 00 ' 0 50 RIGMNT ',Total Jar hours 199.35 RGRP I' SURFAC 'Ch b #3 #2 d I : - : . on mu pump ange out swa 20:00 - 00:00 ~ 4.00 DRILL DRLG j SURFAC 'Drill from 4850 to 5165' MD ~, ! 800 GPM = 2900 psi Up weight = 205,000# I ~ ;Down weight = 95,000# ~ i~ ~ ' Rotating weight = 140,000# I I ~I ', Torque at 90 rpm =12-15K ft# l ~ j ',ART =.86 hrs i '~ ,AST =1.29 hrs ~ II ',Total bit hours =14.4 hrs drilling I I i ' Total Jar hours 201.5 ' ' ' ' 2/6/2006 ' 00:00 - 06:00 i 6.00 DRILL ND DRLG SURFAC ''Drill from 5165 MD to 5454 MD 3001 ~; "' 885GPM = 3580 psi '~ ', I Up weight = 220,000# -Down weight = 90,000# !, ', j 'Rotating weight = 145,000# 'i ! ~ I ': Torque at 90 rpm =12-18K ft# ', I ; MART=.99hrs ', ', ' ;AST =.82 hrs ', I "Total bit hours =16.21 hrs drilling Total Jar hours 203.31 06:00 - 12:00 ' 6.00' DRILL I DRLG 'SURFAC !Drill from 5454' MD 3001' TVD to 5874' MD 3161' TVD 900 GPM = 3650 psi Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Page 8 of 53 Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours Code `.Code Phase Description of Operations 2/6/2006 106:00 - 12:00 ~~, 6.00' DRILL DRLG SURFAC Up weight = 220 000# 12:00 - 15:30 2/7/2006 3.50 Down weight = 90,000# Rotating weight = 148,000# Torque at 90 rpm =10-15K ft# ~ ART =.96 hrs ~~AST=1.72 hrs iTotal bit hours =18.89 hrs drilling Total Jar hours 206.00 DRILL DRLG SURFAC 'Drill from 5874' MD 3161' TVD to 6125' MD 3247 TVD 900 GPM = 3790 psi ~ Up weight = 222,000# Down weight = 100,000# Rotating weight = 149,000# Torque at 90 rpm =11-14K ft# ART =1.2 hrs AST =.4 hrs Total bit hours =20.49 hrs drilling ~ Total Jar hours 207.6 RIGMNT RGRP 'j SURFAC ',Change out liner gasket on mud pump #1 Pump with #2 pump and work pipe while repairing pump. DRILL ; DRLG ~ SURFAC 'Drill from 6125' MD 3247 TVD to 6227 MD 3247 TVD 900 GPM = 3850 psi ',j Up weight = 240,000# Down weight = 100,000# ', Rotating weight = 149,000# ', Torque at 90 rpm =10-15K ft# ART =.35 hrs AST =.58hrs Total bit hours =21.42hrs drilling Total Jar hours 208.53 15:30 - 16:15 ~ 0.75 16:15 - 18:00 1.75 18:00 - 00:00 ', 00:00 - 05:45 i 05:45 - 07:00 ' ', 07:00 - 09:00 6.00 DRILL DRLG ',~ SURFAC Drill from 6227 MD 3247 TVD to 6635' 900 GPM = 3820 psi Up weight = 255,000# Down weight = 105,000# ', ~ Rotating weight = 155,000# Torque at 90 rpm =14-18K ft# j 'j 'ART=1.69 hrs j ~i, ',AST=1.60 hrs 'Total bit hours =24.71 hrs drilling Total Jar hours 211.81 DRILL i DRLG SURFAC Drill from 6635' to 6923' MD 3554' TVD 885 GPM = 3785 psi Up weight = 260,000# Down weight = 95,000# ', Rotating weight = 160,000# Torque at 90 rpm =17-22K ft# it I, ART =1.15 hrs ii - 5.75 i ,AST -1.97 hrs ;Total bit hours =27.83 hrs drilling ', ;Total Jar hours 214.94 1.25' DRILL CIRC ',SURFAC 'Circulate and condition for short trip. 430 GPM = 1130 psi one pump ', Repair seat on mud pump #2 2.00 DRILL ,REAM ji, SURFAC ', Pump out of hole for short trip from 6926 to 5588' MD Printed: 4/28/2006 8:42:24 AM ConocoPhiflips Afaska Operations Summary Report Page 9 of 53 Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To __ ___ -- 2n/loos o7:00 - 09:00 ', 09:00 - 10:15 i 10:15 - 10:30 1110:30-11:00 i '11:00-12:00' ~I 12:00 - 18:00 18:00 - 00:00 Hours Code 'Code Phase __ _ ~-- -_ 2.00 DRILL REAM ;SURFAC ~, 900 gpm 3600 psi 1.25! DRILL 0.25 RIGMNT 0.50; DRILL 1.001, DRILL 6.00' DRILL 6.00 DRILL CIRC RSRV TRIP CIRC DRLG DRLG Description of Operations SURFAC ''Circulate bottoms up @ 900 gpm 90 rpm /lots of sand over shakers. SURFAC I Blow down top drive to trip in. SURFAC ',Trip in hole on elevators 5588 tp 6923' Down weight 90 - 100K SURFAC 'Circulate bottoms up at 900 gpm 3900 psi 90 rpm Torque = 15 - 20K SURFAC ',Drill from 6923' MD 3554' TVD to 7347 MD 3690 TVD ', 850 GPM = 3800 psi I Up weight = 270,000# Down weight = 100,000# ~~ Rotating weight = 156,000# Torque at 90 rpm =15-18K ft# ART =2.35 hrs AST =1.08 hrs Total bit hours =31.26 hrs drilling Total Jar hours 218.37 SURFAC ''Drill from 7347 MD 3690 TVD to 7707 MD ~ 850 GPM = 3800 psi ' Up weight = 270,000# i Down weight = 100,000# Rotating weight = 156,000# ' Torque at 90 rpm =15-18K ft# ART =2.14hrs 'AST =1.69 hrs Total bit hours =35.09hrs drilling Total Jar hours 212.2 SURFAC i Drill from 7707 MD to 7854' 3859' TVD 850 GPM = 3800 psi Up weight = 270,000# Down weight = 105,000# Rotating weight = 156,000# Torque at 90 rpm =15-18K ft# i ART =3.57hrs AST =0.0 hrs ~i Total bit hours =38.66 hrs drilling ~iTotal Jar hours 215.77 'Very hard spot in the top West Sak @ 7810 to 7815' MD = 3845.7 TVD 'Adding tubes to mud to reduce torque and aid in drag SURFAC 'Drill from 7854' 3859' TVD to 8113 MD 3941' TVD ', 820 GPM = 3980 psi !, Up weight = 250,000# Down weight = 115,000# Rotating weight = 161,000# Torque at 90 rpm =14-19K ft# ART =4.23 hrs AST =0.0 hrs Total bit hours = 42.89 hrs drilling ,Total Jar hours 230.00 Lubes help troque and greatly help drag and increased available down weight. 2/8/2006 100:00 - 06:00 I 6.00 I DRILL I DRLG 06:00 - 12:00 I 6.001 DRILL '; DRLG 12:00 - 18:00 ', 6.00 I DRILL DRLG SURFAC ~ Drill from 8113 MD 3941' TVD to 8369' MD 4018' TVD I ~ 800 GPM = 3890 psi Reducing flow to stay under pump pressure limits ', ; Up weight = 245,000# Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours , Code Code' Phase 2/8/2006 ',12:00 - 18:00 ! 6.00: DRILL DRLG SURFAC ~, 18:00 - 00:00 2/9/2006 00:00 - 06:00 6.00'1 DRILL 'DRLG !SURFAC i I I ''' 6.00 DRILL DRLG I, SURFAC Start: 1 /28/2006 Rig Release: 4/2/2006 Rig Number: 15 Page 10 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations 'i Down weight = 115,000# Rotating weight = 160,000# i Torque at 90 rpm =14-19K ft# 'ART =1.58 hrs AST =1.42 hrs Total bit hours = 45.93 hrs drilling Total Jar hours 233.00 Lubes still helping out on drag /Mud PV is increasing. Drill from 8369' MD 4018' ND to 8713 MD 4152 TVD 800 GPM = 3890 psi Reducing flow to stay under pump pressure limits Up weight = 250,000# Down weight = 115,000# Rotating weight = 160,000# Torque at 90 rpm =14-17K ft# ART =2.33 hrs AST =1.96 hrs 'ITotal bit hours = 50.22 hrs drilling ITotal Jar hours 237.28 !Drill from 8713 MD 4152 TVD to 9015' MD 4255' TVD 750 GPM = 3890 psi Reducing flow to stay under pump pressure limits Up weight = 250,000# Down weight = 130,000# Getting better with fresh tubes Rotating weight = 170,000# Torque at 90 rpm =16-19K ft# ART =2.88 hrs 'AST =1.38 hrs Total bit hours = 56.65 hrs drilling j Total Jar hours241.46 Adding tubes reduces torque from 23,000 FT# to 17 - 18,000 FT# ~!~ Drill from 9015' MD 4255' ND to 9396' and 440T tvd I~ 728 GPM = 3870 psi Reducing flow to stay under pump pressure limits I~ Up weight = 240,000# Down weight = 120,000# ~~ Rotating weight = 160,000# Torque at 90 rpm =16-17K ft# smoothing out. 'TART=2.82 hrs AST =1.35 hrs Total bit hours = 54.39 hrs drilling Total Jar hours245.76 Drill from 9396' and 4407' tvd to 9670" MD 4419' TVD Casing point. 728 GPM = 3900 psi Reducing flow to stay under pump pressure limits Up weight = 240,000# Down weight = 130,000# Still improving Rotating weight = 160,000# Torque at 90 rpm =16-17K ft# ART =1.94 hrs AST =O.Ohrs ITotal bit hours = 54.39 hrs drilling ITotal Jar hours 247.71 '~ Circulate bottoms up 750 gpm = 3518 RPM = 120 'from 9670 to 9535' Sand one stand back every hour. !Conditioning mud while circulating. I 06:00 - 12:00 I 6.001 DRILL DRLG I SURFAC 12:00 - 15:00 ', 3.00'', DRILL ',.DRLG ',SURFAC 15:00 - 18:00 I 3.001 DRILL I CIRC I SURFAC Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 11 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophiiiips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 2/9/2006 From - To ' Hours ' Code 18:00 - 23:30 ' 5.50! DRILL 23:30 - 00:00 2/10/2006 00:00 - 01:30 !.01:30 - 04:30 I II 04:30 - 05:15 1 '~ 05:15 - 11:00 11:00 - 12:00 !, 12:00 - 15:15 ', 15:15 - 15:45 15:45 - 16:00 16:00 - 16:30 16:30 - 18:00 i 18:00 - 19:15 19:15-22:45' DRILL DRILL DRILL DRILL CASE CASE CASE CASE 22:45 - 23:30 ' 0.75 !CASE !CIRC 23:30 - 00:00 ' 0.50' CASE RUNC 2/11/2006 00:00 - 02:15 '1 2.25' CASE 'RUNC i ', I' I '~ ~I 02:15 - 02:45 02:45 - 04:00 04:00 - 05:00 05:00 - 06:00 '; Sub ', Phase Coder Description of Operations REAM I SURFAC I Circulate and pump out of hole from 9535 to 6825' @ last short trop. 0.501 RIGMNT' RSRV 1.50 ~I DRILL ' WIPR 3.00 ~ DRILL I CIRC 0.75 DRILL ~ CIRC 5.75 DRILL TRIP 1.00 3.25 0.50 0.25 0.50 1.50 1.25 3.50 ' Rotate and back ream at 40-50 RPM 'Pumping at 750 gpm = 3500 psi '!, No tight spots seen. SURFAC '~ Circulate while servicing top drive. Blow down and prepare to run in hole. SURFAC Continue to run in hole 6825' to 9670' on wiper trip. hole in good condition. SURFAC Circulate and condition mud. First bottoms up mud was thick. Adding 120 bpg water to reduce viscosity. Weighting up to 10.2 ppg for trip margin. SURFAC 1 PJSM: Start pumping out of hole 800 gpm 3850 psi. 240,000# up weight. 120,000# down weight. SURFAC I, Pull out of hole on elevators. No tight spots seen, hole looks to be in good condition. SURFAC "Lat down 14 joint HWDP. SURFAC 'Break bit and lay down BHA #2 SURFAC 'Clear rig floor and prepare to run casing. SURFAC 'PJSM on hanger and picking up franks tool. SURFAC ~ Make up hanger and verify landing depth. SURFAC ', Rig up remaining casing equipment and franks tool. SURFAC ', PJSM new crew,. Continue to rig to run casing. SURFAC I~ Make up shoe track and run casing to 1815 below permafrost. Up weight = 145,000# Down weight = 115,000# SURFAC SURFAC SURFAC 0.501, CASE II CIRC 'SURFAC 1.251 CASE RUNC '..SURFAC '' I 1.00 CASE CIRC I SURFAC 1.001 CASE PULD PULD PULD SFTY RURD RURD RURD RUNC RUNCISURFAC 06:00 - 12:00 ', 6.00 ~ CASE RUNC SURFAC , 1 Circulate and condition below permafrost at 5.5 bpm = 245 psi. Mud coming back was very thick. Treat and condition. Continue to run in with 10 3/4" casing to 2306' Run casing 2306 to 3806' Weight up = 240,000# Weight average down 110,000# Run 10 3/4" casing tight at 2370 - 85 Few spots stacking out. By 4800' using all down weight available. Shut down and circulate. ~', Break circulation at 6 bpm stage up. Circulate @ 6 bpm = 260 psi. I Pump 160 bbls fresh mud. !Run casing from 3806 to 4883' Up weight 270,000# 'Down weight = 125,000# ':Work through tight hole from 4760 to 4883. Stacking out, Stop to 'circulate before conditions are too bad or packing off. Circulate @ 6 bpm = 315 Up weight = 250,000# down weight = 125,000# Fresh tubes and mud gained 25 - 30,000# slack off. ~'1 Pump 350 bbls total. I, Run 10 3/4" casing, from 4883 to 5900 feet. Up weight = 330,000# Down weight = 100,000# Continue to run casing from 5900 to 8560' joint # 215 Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/11/2006106:00 - 12:00 1 D-41 1 D-41 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours Code Codel! Phase - _ _~ __ __ 6.00 CASE I RUNC SURFAC 12:00 - 14:00 2.00' CASE RUNC !.SURFAC 14:00 - 15:15 1.25', CASE ', RUNC ',SURFAC 15:15 - 15:30 I CASE CIRG 0.25 i SURFAC 15:30 - 18:00 1 2.50'1 CASE CIRC SURFAC 18:00 - 20:15 ' 2.25 CASE CIRC SURFAC ' 20:15 - 20:30 20:30 - 21:00 21:00 - 00:00 2/12/2006 100:00 - 01:00 ' ' 01:00 - 01:45 01:45 - 02:30 ''1 0.251 CASE ', SFTY 0.50', CEMEN SEAT L 3.00 CEMENYPUMP 1.OOIII CEMENTDISP 0.7511 CEMENT. DISP 11 I I I I ~ I 11 0.7511 CEMENTDISP SURFAC SURFAC SURFAC SURFAC 'SURFAC SURFAC Page 12 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Tight @ 6035 Weight up 405,000# stacking out down. ',Tight @ 8060' No up movement in string. ''Work through tight spot at 8630' Washing with Franks tool as require to run. Run and wash casing from 8560 to 9653' Tight spot @ 8940 Work up with 403,000# no pipe movement up. Stacking out down. Working pipe making progress down. ' Tam Port collar @ 1010' MD 992" TVD ,Float Collar @ 9527 MD / 4454.2' TVD ', Shoe ~ 9653' MD ! 4502" TVD TD hole section 13 1/2" Hole @ 9670' MD / 4509' TVD Land casing on hanger. Split slips and set on bottom, Break down franks tool from top drive. Blow down top drive, Install lower and upper plugs in cement head. Install cement head onto casing. Hook up lines. ', Break circulation @ 60 spm = 470 psi. ',Increase pump rate to 80 spm = 580 psi. Circulate and prepare for cement job. iVG .,movement. Continue to circulate and condition while rigging up cementers. 8 BPM = 450 psi. PJSM with cementers, truck drivers, Truck pusher, Mud Engineers, Rig Crew for cement job and displacement. (Test lines to 3500 PSI and start mixing cement. Pump 50 bbls CW 100 Pump 50 bbls Mud push @ 10.5 ppg j Drop top plug @ 20:57 hrs 20:59 Start pumping lead cement 863 bbls AS Lite @ 10.7 ppg 23:13 Start pumping Tail Lite Crete @ 12.7 PPG Pump 255 bbls Tail slurry 23:59 Drop top plug and pump out with 20 BBLs water from cementers i Switch to rig to displace. Pump 863 bbls lead cement at 10.7 ppg @ 6.6 BPM 205 psi. Full ' returns while pumping. '1 Displacing cement with rig pumps at 7.5 BPM 553 psi @ 2000 stks I Pump to 5000 stks Chemical was at surface. it Continue to displace 15400 stks / 543 bbls displaced lots of clay back to surface with ' chemical wash. 5700 stks / 574 bbls traces of cement back at surface ' 6000 stks / 604 bbls good cement back to surface with lots of clay balls 17000 stks / 704 bbls Lost returns 1:40 hrs Reduce pump rate to 3.5 BPM 1350 psi 11 Displacing @ 3.5 BPM = 1450 psi. II Saw pressure drop @ 02:10 hrs rom 1900 psi to 1480 psi as we were 11 pumping cement away. 02:13 Could see lift pressure increase as tail cement turned corner ' indication the losses were up the hole. Increase from 1400 to 1980 ;before breaking over. 1102:25 Bump plug 10 1750 psi. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To 2/12/2006 ~~ 01:45 - 02:30 Hours ~; Code ' Sub 'Code 0.75!~CEMEN IDISP I I I 02:30 - 02:45 '~ 0.25 02:45 - 04:00 ', 1.25 ~ 04:00 - 04:45 I 0.75 ~ i 04:45 - 06:00 ', 1.25 06:00 - 11:00 ~ 5.00 11:00 - 11:45 0.75 11:45 - 14:00 I 2.25 14:00 - 15:45 ~' 1.75 15:45 - 18:00 ! 2.25 18:00 - 00:00 ' 6.00 2/13/2006 ' 00:00 - 02:45 2.75 02:45 - 07:00 4.25 CEMENT DISP CEMENTRURD CEMENTRURD CEMENTiRURD WELCTL NUND WELCT NUND WELCTL NUND WELCTL NUND WELCTL' NUND WELCTL,! NUND WELCT NUND WELCTL BOPE Page 13 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Phase Description of Operations SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC '...Can see cement in annulas right at the hanger. ~~ 1:40 hrs Reduce pump rate to 3.5 BPM 1350 psi ~' Displacing @ 3.5 BPM = 1450 psi. Saw pressure drop @ 02:10 hrs from 1900 psi to 1480 psi as we were pumping cement away. 02:13 Could see lift pressure increase as tail cement turned corner ,.indication the losses were up the hole. Increase from 1400 to 1980 ~ before breaking over. ', 02:25 Bump plug 10 1750 psi. 'Can see cement in annulus right at the hanger. 1:40 hrs Reduce pump rate to 3.5 BPM 1350 psi Displacing @ 3.5 BPM = 1450 psi. Saw pressure drop @ 02:10 hrs from 1900 psi to 1480 psi as we were pumping cement away. 02:13 Could see lift pressure increase as tail cement turned corner indication the losses were up the hole. Increase from 1400 to 1980 ' before breaking over. j 02:25 Bump plug 10 1750 psi. Can see cement in annulus right at the hanger. Hold pressure 10 minutes and check float equipment, holding. Rig down cement head, elevators, slips. Pull landing joint and lay down. Flush riser cellar and hydril) with sapp pill to prepare to nipple up. Nipple down riser flow lines and lay down same. Continue to nipple down riser, diverter, knife valve abd 20 inch "T" '~ Clean up casing hanger and landing ring. Install acme nut and split ring on hanger. Set well head and orient. Install double stud adapter. PJSM: Pick up BOP and make up hoses & conections. Continue to nipple up BOP. @ 19:00 hrs FMC tested well head metal to metal seal. to 1000 psi for 01 minutes. !..Continue to nipple up BOP. Install turn buckles and replace flow line boot. ~ Continue to nipple up BOP and pick up test equipment. Test BOPE, witness of test by AOGCC inspector. Test annular to 250 psi low and 3500 psi high w/ 5" dp. Test upper rams (4-1/2" x 7" variables), outer kill HCR valve and inner manual valve on choke side to 250 psi low and 3500 psi high. Continue testing 13 5/8" 5m BOPE. Test 250 psi low and 3500 psi high all components except hydril, high test on ''hydril 3500 psi. Testing against upper pipe rams, manual kil valve, HCR choke valve, choke manifold valves 16,17, 18, and 5" dart valve. Test i choke manifold valves 12,13,14,15, and TIW valve. Test choke manifold valves 5,6,10, & 11 w/ 4" dart valve. Test choke manifold valves 1,4,7 & 4" TIW valve. Test choke valves 2,3,8, & 9, Test lower pipe rams (3-1 /2" x 6" variables) w/ 4" DP. Work on Koomy unit. Checked pre charge, charged 2 bottles f/ 925 psi ~, to 1000 psi, change manifold pressure guage, adjust air pump pressure sensor f/ cut in & out pressure. Test Hydril 250 psi low, 3500 psi high w/ 4"joint of pipe ', Test blind rams to 250 psi low and 3500 psi high. ~, Test upper IBOP valve on top drive drive to 250 psi low and 3500 psi Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To 2/13!2006 ~I 02:45 - 07:00 07:00 - 09:15 09:15 - 10:00 ',10:00 - 12:45 '~ 12:45 - 13:15 i 13:15 - 15:00 15:00 - 20:00 20:00 - 21:45 21:45 - 00:00 2/14/2006 00:00 - 03:30 03:30 - 05:15 05:15 - 06:15 Hours 4.25 2.25 0.75 2.75 0.50 1.75 5.00 I, 1.75 I 2.25 i 3.50 1.75 1.00 06:15 - 07:00 ,' 0.75 07:00 - 08:00 " 1.00 08:00 - 10:45 ! 2.75 10:45 - 11:00 ! 0.25 11:00 - 11:45 ~~ 0.75 I 11:45 - 12:15 ~, 0.50 Code Sub 'Code __ WELCTLI BOPE WELCT~ NUND WELCTL~ NUND DRILL 'i PULD ~I DRILL CIRC DRILL URM RIGMNT RGRP DRILL PULD DRILL PULD DRILL PULD DRILL TRIP DRILL CIRC DRILL OTHR CASE MIT CEMEN DSHO DRILL CIRC CEMEN DSHO Phase SURFAC SURFAC SURFAC it SURFAC SURFAC SURFAC SURFAC SURFAC 'SURFAC li SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC DRILL 'CIRC '.SURFAC 12:15 - 16:30 4.25 i DRILL CIRC ',SURFAC 16:30 - 17:00 17:00 - 17:30 i 17:30 - 18:00 !.18:00- 19:30 0.501 DRILL OTHR SURFAC , 0.5011 DRILL it FIT SURFAC 0.50 ~i DRILL RIRD SURFAC 1.501 DRILL DRLG INTRM1 Page 14 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations high. Test lower IBOP valve on top drive to 250 psi low and 3500 psi high. Rig down testing tools and equipment. Blow down top drive ,choke line, and lay down test joint. 1 Install wear bushing and rig down test equipment, PJSM: Pick up BHA #3 Make up bit, motor and MWD. Up load MWD ',and continue to make up NMFDC's and HWDP> 'Set MWD tool face offset and scribe. ',Shallow hole test MWD tools all tools working well. I Continue to pick up HWDP ,jars and bumper sub. !Rig service: Slip and cut drill line, service top drive and change oil in top drive, adjust brake. i1 Pick up 5" drill ipe from pipe shed and RIH> Rotate past TAM port collar. test casing 1500 psi 10 minutes. Blow down lines. Continue to pick up 5" drill pipe from pipe shed and rabbit to 3095'. Continue to pick up 5" drill pipe from pipe shed and rabbit (2-13/16") f/ 3095' to 6422". Picked up a total of 189 joints Weatherford 5" dp. Continue trip in hole w/ BHA #3 f/ 6422' to 9527' running 5" dp f/ derrick. ~~ Tagged up on float collar @ 9527. PU wt 250k, SO wt 145k. j Circ and condition mud prior to testing 10-3/4" casing. Circ 650 gpm w/ 3350 psi, 50 rpm, 10-17k torque. 'Blow down top drive. RU to test 10-3/4" casing. ':Test 10-3/4" casing to 2500 psi f/ 30 min. Chart test. Good test. i. Drill cement,wiper plugs, float collar, soft cement f/ 9518' to 9625'. Drill w/ 600 gpm, 2816 psi, 30 rpm w/ 22k fUlb torque. PU wt 250k, SO wt 115k, rot wt 160k. 'i Circ out cement contaminated mud. Circ 446 gpm w/ 1686 psi. Continue drilling float equip, soft cement, float shoe and 20' new hole f/ 9625' to 9690' (451 T TVD). Drill w/ 600 gpm w/ 2816 psi, 30 rpm w/ 22k ft/ Ib torque. Pu wt 250k, SO wt 115k, Rot wt 160k. ART = .21 hrs. Jar & Accelerator hrs = 89.28 hrs. Bit hr = .21 hrs. Circ out cement contaminated mud @ 9690', pumping 446 gpm w/ 1686 psi. Displace well to new 9.5 ppg mud. Start w/ 40 bbl spacer, then 9.5 ppg LSND mud. Pump 503 gpm w/ 1116 psi, rotate @ 40 rpm w/ 10k ft/Ib torque. Stand back a stand to 9653'. RU f/ FIT test. Perform FIT w/ 9.5 ppg mud, 1150 psi = 14.4 ppg EMW @ 4502.6' TVD(Shoe depth). Bleed back .5 bbls. '; Rig down testing equipment. Blow down lines. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 9690' to 9752' (4538 TVD) (62') ART .53 hrs AST 0 hrs, Total j hrs on bit =.74 hrs., Total hrs on jars = 90.02 hrs, 5-10 k WOB, 50 ', rpm's, 203-206 motor rpm, 617-625 gpm, 9.5 ppg mw, on bottom ',pressure 1612-1720 psi, off bottom pressure 1460-1580 psi, on bottom torque 10-11 k ft/Ib, off bottom torque 10k fUlb, PU wt 22-230k, SO wt 130-135k, Rot wt 160-162k. i Background gas = 34 units, max gas = 135 units. Perform PWD baseline test @ 9745': 550 gpm w/ 70 rpm = 9.97 ppg Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska. Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date 2/14/2006 2/15/2006 From - To Hours Code ', Code' Phase __ _ __ 18:00 - 19:30 1.50', DRILL DRLG INTRM1 19:30 - 19:45 19:45 - 20:15 20:15 - 20:30 20:30 - 00:00 00:00 - 03:00 ', 03:00 - 03:30 03:30 - 03:45 03:45 - 06:00 06:00 - 12:00 i 12:00 - 18:00 18:00 - 19:30 0.25' DRILL TRIP 0.50! DRILL ~OTHR 0.25. DRILL ':REAM 3.50' DRILL j DRLG 3.00: DRILL I DRLG 0.50!.. DRILL 0.25 DRILL 2.25': DRILL 6.00 DRILL SURV TRIP DRLG DRLG 6.00' DRILL I DRLG 1.50'' DRILL i DRLG INTRMI INTRM1 INTRMI INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 Page 15 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations ECD, 550 gpm w/ 90 rpm = 9.99 ppg ECD, 650 gpm w/ 70 rpm = 10.06 ~ ppg ECD, 650 gpm w/ 90 rpm = 10.08 ppg ECD. POOH f/ 9752' to 9652'. Blow down top drive and high pressure mud line. Change out "O" ring in ~ mud line and test connection. Wash f/ 9652' to 9752', pumping 625 gpm w/ 1750 psi, rotating 50 rpm w/ 10k fUlb torque. Directional drill 9-7/8"" hole w/ Sperrydrill 718-6.0 stage mtr w/ 1.22 deg bend f/ 9752' to 10155' (4688 TVD) (403') ART 2.07 hrs AST .40 hrs., Total hrs on bit = 3.21 hrs., Total hrs on jars = 92.49 hrs, 5-10 k WOB, 50-90 rpm's, 203-206 motor rpm, 617-625 gpm, 9.5 ppg mw, on bottom pressure 1612-1720 psi, off bottom pressure 1460-1580 psi, on bottom torque 10-11 k ft/Ib, off bottom torque 10k fUlb, PU wt 22-230k, SO wt 130-135k, Rot wt 160-162k. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 10155' to 10354' (4759 TVD) (199') ART .83 hrs AST .90 hrs., Total hrs on bit = 4.94 hrs., Total hrs on jars = 94.22 hrs, 10 k WOB, 90 rpm's, 215 motor rpm, 650 gpm, 9.5 ppg mw, on bottom pressure 2107 psi, off bottom pressure 1980 psi, on bottom torque 11-12k ft/Ib, off bottom torque 10k ft/Ib, PU wt 235k, SO wt 140k, Rot wt 170k. ECD's = 10.23 ppg EMW. Background gas = 54 units, max gas = 84 units. POOH f/ 10354 to 10319', re-survey @ 10319', PU wt 235k, SO wt 140k. Trip in f/ 10319' to 10354'. Directional drill 9-7/8"" hole w/ Sperrydrill 7l8-6.0 stage mtr w/ 1.22 deg bend f/ 10354' to 10605' (4849 TVD) (251') ART 1.11 hrs AST .28 hrs., Total hrs on bit = 6.33 hrs., Total hrs on jars = 95.61 hrs, 10-15 k WOB, 90 rpm's, 215 motor rpm, 650 gpm, 9.5 ppg mw, on bottom pressure 2107-2320 psi, off bottom pressure 1980-2000 psi, on bottom torque I, 11-13k ft/Ib, off bottom torque 10k ft/Ib, PU wt 235-240k, SO wt 140k, Rot wt 170k. ECD's = 10.2 ppg EMW. Background gas = 79 units, max gas = 181 units. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 10605' to 11355' (5103 TVD) (750') ART 3.05 hrs AST .58 hrs., Total hrs on bit = 9.96 hrs., Total hrs on jars = 99.03 hrs, 5-15 k WOB, 90 rpm's, 215-211 motor rpm, 650-640 gpm, 9.5 ppg mw, on bottom pressure 22320-2425 psi, off bottom pressure 2000-2322 psi, on bottom torque 12-14k ft/Ib, off bottom torque 9-13k ft/Ib, PU wt 230-238k, SO wt 135-140k, Rot wt 170-180k. ECD's = 10.17-10.64 ppg EMW. Calc clean hole ECD's = 10.2 ppg. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 11355' to 11843' (5270 TVD) (488') ART 2.65 hrs AST 0.0 hrs., Total hrs on bit = 12.61 hrs., Total hrs on jars = 101.68 hrs, 5-15 k WOB, 90 rpm's, 212-211 motor rpm, 640-642 gpm, 9.5 ppg mw, on ~ bottom pressure 2425-2755 psi, off bottom pressure 2322-2430 psi, on bottom torque 14-19k ft/Ib, off bottom torque 13-18k ft/Ib, PU wt 238-240k, SO wt 132-140k, Rot wt 180k. ECD's = 10.42-10.85 ppg EMW.CaIc clean hole ECD's = 10.68 ppg. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 11843' to 12032' (5334 TVD) (189') ART .92 hrs AST 0.0 hrs., Total hrs on bit = 13.53 hrs., Total hrs on jars = 102.6 hrs, 10 k WOB, 90 rpm's, 216-213 motor rpm, 640-642 gpm, 9.5 ppg mw, on bottom pressure 2820-2840 psi, off bottom pressure 2540-2500 psi, on bottom Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 2/15/2006 From - To Hours Code 'Code' Phase _ . __ 18:00 - 19:30 ~ 1.501, DRILL 'DRLG II INTRM1 19:30 - 19:45 ' 0.25 19:45 - 22:00 ',~ 2.25 22:45 - 00:00 2/16/2006 00:00 - 00:30 1~ 00:30 - 01:00 1 01:00-03:15 I 03:15 - 05:00 05:00 - 06:45 106:45 - 07:15 07:15 - 09:15 09:15 - 10:00 110:00- 12:00 1.251 DRILL TRIP ,INTRMI 0.5011 DRILL TRIP ' INTRM1 0.5011 I DRILL CIRC INTRM1 2.25', DRILL ' REAM L INTRMI 1.75; DRILL CIRC ~ INTRMI RIGMNT DRILL RSRV DRLG 1122:00 - 22:30 'I 0.50 DRILL OTHR i INTRM1 122:30 - 22:45 '~ 0.25 DRILL CIRC 'INTRMI 12:00 - 18:00 18:00 - 00:00 1, 1.75'' RIGMNT''11 RSRV 0.501, RIGMNTI, RSRV 2.001 DRILL (TRIP 0.751, DRILL 'REAM 2.00 it I 1 I DRILL '1 DRLG I 1 6.00 i DRILL 'DRLG INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI I NTRM 1 INTRM1 6.001 DRILL I DRLG INTRMI Page 16 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations torque 15-18k ft/Ib, off bottom torque 12-16k ft/Ib, PU wt 240-242k, SO ~i wt 140-142k, Rot wt 180k. ECD's = 10.91-11.12 ppg EMW. I Service rig and top drive. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 12032' to 12318' (5441 TVD) (286') ART 1.16 hrs AST .19 hrs., Total hrs on bit = 15.01 hrs., Total hrs on jars = 103.95 hrs, 10-15 k WOB, 90 rpm's, 216 motor rpm, 650 gpm, 9.5 ppg mw, on bottom pressure 2900-3050 psi, off bottom pressure 2630-2700 psi, on bottom torque 14-17k ft/Ib, off bottom torque 10-12k ft/Ib, PU wt 240k, SO wt ~ 140-145k, Rot wt 180k. ECD's = 11.09-11.49 ppg EMW. Lost circulation due to hole packing off. Attempt to regain circ pumping 2 bpm w/ 600-800 psi. POOH f/ 12300' to to 11980' (hole swabbing). PU wt 270k-300k. SO wt 125k. Establish circulation @ 5 bpm w/ 1100 psi w/ 21 % flow. Continue to POOH slow while pumping @ 5bpm w/ 1900 psi, flow went to 8%. i Pumped a total of 64 bbls. Continue POOH f/ 11980' to 11265' attempting to regain circulation @ 2 bpm w/ 800 psi. PU wt up to 330k, SO wt 110-100k w/ no returns. Continue POOH f/ 11265' to 11158' attempting to regain circulation @ 2 bpm w/ 500 psi. PU wt up to 250k, SO wt 145k w/ slight returns (8%). Establish circulation w/ full returns @ 11158' bit depth (Ghost reamer depth= 9688') (Shoe depth = 9653'). Ghost reamer is 35' f/ shoe of 10-3/4". Circ 260 bbls @ 650 gpm w/ 2400 psi, flow indicator 39%. Rotate @ 50 rpm w/ 10k ft Ib torque Backream out of hole f/ 11158' to 9685' (bit 32' below shoe). Pump 640 gpm w/ 2400-2150 psi, 40% flow indicator. Rotate @ 85 rpm w/ 10-11 k ft/Ib torque. Up wt 230k, SO wt 135k Circ and condition hole pumping 650 gpm w/ 2200 psi. Working pipe f/ 9685' to 9752'. Rotating 90 rpm w/ 9k ft Ib torque. Pump 1.5 bottoms up I (1200 bbls total pumped). .Pull one stand to 9653' (Shoe). Change out saver sub on top drive. Service rig, top drive and crown. 11 Trip in hole f/ 9653' to 11939'. No problems. ~~, MU top drive, fill pipe. Precautionary ream f/ 11939' to 12318'. Pumping 1640 gpm w/ 2640 psi, rotating 90 rpm w! 12-13k torque. No problems. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg ~, bend f/ 12318' to 12439' (5484' TVD) (121') ART 1.4 hrs AST 0 hrs., Total hrs on bit = 16.41 hrs., Total hrs on jars = 105.48 hrs, 10-15 k WOB, 120 rpm's, 216 motor rpm, 645 gpm, 9.5 ppg mw, on bottom pressure 2805 psi, off bottom pressure 2660 psi, on bottom torque 1,15-16k ft/Ib, off bottom torque 14-15k ft/Ib, PU wt 245k, SO wt 145k, Rot wt 190k. ECD's = 10.31 ppg EMW. !1 Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg I bend f/ 12439' to 13080' (5718' TVD) (641') ART 3.43 hrs AST .21 hrs., ',Total hrs on bit = 20.05 hrs., Total hrs on jars = 109.12 hrs, 9-15 k 11 WOB, 120 rpm's, 214-211 motor rpm, 650-645 gpm, 9.5 ppg mw, on 'bottom pressure 2805-2770 psi, off bottom pressure 2660-2680 psi, on !bottom torque 15-14k ft/Ib, off bottom torque 14-11 k fUlb, PU wt 245-240k, SO wt 145-150k, Rot wt 190-192k. ECD's = 10.31-10.64 ppg EMW. Directional drill 9-7l8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 13080' to 13475' (5870' TVD) (395') ART 4.28 hrs AST 0 hrs., Total hrs on bit = 24.33 hrs., Total hrs on jars = 113.4 hrs, 10-15 k Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 17 of 53 2.00 Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours; Code 'Code ' Phase Description of Operations 2/16/2006 18:00 - 00:00 ~I 6.00 DRILL DRLG INTRM1 WOB, 120 rpm's, 214-211 motor rpm, 650-648 gpm, 9.5-9.8 ppg mw, 2/17/2006 ' 00:00 - 00:15 ', I ~I 0.25 i 00:15 - 00:30 'I 0.25 ~ 00:30 - 00:45 ! 0.25 00:45 - 02:45 02:45 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 05:45 05:45 - 12:00 12:00 - 15:30 Operations Summary Report on bottom pressure 2770-2480 psi, off bottom pressure 2650-2250 psi, ion bottom torque 12-15k fUlb, off bottom torque 10-12k ft/Ib, PU wt ii i 240-260k, SO wt 150-152k, Rot wt 192-190k. ECD's = 10.51-10.8 ppg A ~ li EMW. Note: Pumped weighted 11.5 ppg hi vis sweep @ 13367 DRILL DRLG I INTRMI Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 13475' to 13489' (5875' TVD) (14') ART .18 hrs AST 0 hrs., Total hrs on bit = 24.51 hrs., Total hrs on jars = 113.58 hrs, 10-15 k j WOB, 120 rpm's, 214-211 motor rpm, 641 gpm, 9.5-9.8 ppg mw, on bottom pressure 2480-1850 psi, off bottom pressure 2500-1700 psi, on ', ~~ bottom torque 14-15k ft/Ib, off bottom torque 11 k ft/Ib, PU wt 265k, SO i wt 152k, Rot wt 190k. ECD's = 10.71 ppg EMW. Slow RPM's to 90 ' ''when backreaming stand. Pressure loss f/ 2280 psi on bottom to 1850 ;.psi on bottom. DRILL I OTHR INTRM1 Trouble shoot pressure loss. Clean suction screens on # 1& #@ mud I pumps. Test surface equipment and mud lines to 3000 psi, ok. DRILL OTHR INTRMI ,Record SPR's. # 1 @ 20 spm = 230 psi, at 30 spm = 320 psi. #2 mud pump @ 20 spm = 240 psi, at 30 spm = 330 psi. All w/ 9.8 ppg mud 13459' depth (5874' TVD) DRILL TRIP ''INTRMI Monitor well. POOH wet f/ 13489' to 11433' looking f/ hole in drill string. Found washout (washed hole and crack) just below box upset of middle joint on stand # 116. Remove and laydown joint. Replace joint w/ anotherjt of 5" Weatherford drill pipe. No correction to pipe tally. PU wt 250k, SO wt 135k. 0.251 DRILL ! CIRC ' INTRM1 Verify that this is only problem. Circulate @ 640 gpm w/ 2750 psi. OK. 1.00 ~ DRILL 'TRIP INTRM1 ~ Trip in hole f/ 11433' to 13368'. PU wt 165k, SO wt 130K @ 13368' 0.50'' DRILL 'REAM INTRM1 I Precautionary ream last stand plus 25' to bottom f/ 13368' to 13489'. Circ @640 gpm w/ 2950 psi, rotate @ 90 rpm w/ 11 k ft/ Ib torque. 1.25' DRILL 'CIRC INTRM1 ~ !Circ and condition hole-- ECD's after trip f/ 13489' to 11433' (2056') 6.25 3.50 ' i I were 11.0 ppg. Circ @ 640 gpm w/ 2960 psi. Rotate 90 rpm's w/ 13-14k ', ft Ib torque. Work pipe f/ 13455' to 13485'. Max gas 1250 units on bottoms up. ECD's after circ BU = 10.56 ppg. DRILL I DRLG INTRM1 'Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg ~I bend f/ 13489' to 14032' (6069' TVD) (543') ART 3.93 hrs AST .52 hrs, Total hrs on bit = 28.96hrs., Total hrs on jars = 118.03 hrs, 5-15 k WOB, 120 rpm's, 208 - 211 motor rpm, 630-640 gpm, 9.8-10.0 ppg mw, on bottom pressure 3130-3280 psi, off bottom pressure 3000-3088 psi, ion bottom torque 15-17k ft/Ib, off bottom torque 13-14k ft/Ib, PU wt ~ 265-270k, SO wt 150k, Rot wt 195-198k. ECD's = 10.8-10.97 ppg EMW. Slow RPM's to 90 when backreaming stand. DRILL ', DRLG '~, INTRM1 ~ Directional drill 9-7l8" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg '~ ,bend f/ 14032' to 14317 (6169' TVD) (285') ART 2.14 hrs AST 0.0 hrs, Total hrs on bit = 31.1 hrs., Total hrs on jars = 120.17 hrs, 5-15 k WOB, '.120 rpm's, 208 - 211 motor rpm, 630-640 gpm, 10.0 ppg mw, on bottom 'pressure 3280-3450 psi, off bottom pressure 3088-3300 psi, on bottom torque 15-19k ft/Ib, off bottom torque 15k fUlb, PU wt 270k, SO wt 150k, I~ ~ !Rot wt 198k. ECD's = 11.12-11.18 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = 1953 units while drilling @ 14221'. 15:30 - 18:00 !, 2.50' DRILL I CIRC ~, INTRMI ~~ Circulate and condition mud and hole @ 1431 T. Pump 45 bbl weighted to 11.5 ppg sweep w/ 79 vis. Pump @ 636 gpm w/ 3250 psi. Sweep ~ back to surface @ 12200 strokes. Continue circulating two bottoms up. i~ I Stand back a stand every hour to 14224'. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 18 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours Code :Code' Phase ~, Description of Operations 2/17/2006 ',18:00 - 19:00. 1.00 '19:00-19:15 'I 0.25 19:15 - 19:45 0.50 19:45 - 20:45 20:45 - 21:45 2/18/2006 1.00 DRILL TRIP INTRM1 I Monitor well- static. POOH f/ 1431 T to 13367. PU wt 310k, SO wt 135k @ 13367'. RIGMNT RSRV INTRM1 !Grease top drive blocks, swivel packing and crown. DRILL TRIP INTRM1 Monitor well- static. Trip in hole f/ 13367' to 14129'. PU wt 290k, SO wt 130k @ 14129'. DRILL ~ CIRC '! INTRM1 Fill pipe @ 14129'. Circ and condition hole f/ 14129' to 14220'. Stagging pumps up f/ 515 gpm w/ 2380 psi to 630 gpm w/ 3290 psi. Rotate and ', ;reciprocate pipe @ 90 rpm w/ 18k fU Ib torque. Pumped total of 630 bbls. ECD's 11.2 ppg @ start cleaned up to 11.14 ppg ECD. 1.00 DRILL ',CIRC ~I, INTRM1 ',Continue circulating f/ 14220' to 14315', pumping 625 gpm w/ 3300 psi. '; ~', Rotate and reciprocate pipe @ 90 rpm w/ 18k ft/ Ib torque. Including !last interval, pumped total of 1300 bbls, lots of cuttings from hole @ bottoms up. Max gas units 2350. Final ECD's 10.89 ppg ECD. DRILL DRLG INTRM1 ;Record SPR's. Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 14315' to 14509' (6202' TVD) (194') ART 1.51 'hrs AST 0.0 hrs, Total hrs on bit = 32.61 hrs., Total hrs on jars = 121.68 li hrs, 5-10 k WOB, 120 rpm's, 208 - 211 motor rpm, 627-630 gpm, 10.0 II I ~ ppg mw, on bottom pressure 33280-3325 psi, off bottom pressure !, 3070-3150 psi, on bottom torque 20-18k fUlb, off bottom torque 15-16k fUlb, PU wt 290k, SO wt 150k, Rot wt 195k. ECD's = 10.98-10.92 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = 1056 units while drilling @ 14500'. 21:45 - 00:00 ', 2.25 00:00 - 06:00 6.00; DRILL DRLG INTRM1 'Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 14509' to 14982' (6407 TVD) (473') ART 4.42 hrs AST 0.0 hrs, Total hrs on bit = 37.03 hrs., Total hrs on jars = 127.61 hrs, 5-10 k '; j I WOB, 120 rpm's, 206 motor rpm, 625 gpm, 10.0 ppg mw, on bottom j pressure 3280-3245 psi, off bottom pressure 3140-3075 psi, on bottom 'torque 17-18k fUlb, off bottom torque 15k ft/Ib, PU wt 290k, SO wt 150k, Rot wt 198-195k. ECD's = 10.96-10.91 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = 1724 units after drilling @ 14785'. DRILL DRLG INTRM1 ', Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg i I ,bend f/ 14982' to 15260' (6510' TVD) (278') ART 2.71 hrs AST 1.15 I I ';hrs, Total hrs on bit = 40.89 hrs., Total hrs on jars = 131.47 hrs, 5-15 k ~~ WOB, 120 rpm's, 206 motor rpm, 625 gpm, 10.0 ppg mw, on bottom ', pressure 3476-3430 psi, off bottom pressure 3071- 3370 psi, on bottom torque 15-19k ft/Ib, off bottom torque 15-17k ft/Ib, PU wt 280-290k, SO wt 158-155k, Rot wt 208k. ECD's = 10.86-10.89 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = 285 units while drilling @ 14955'. 06:00 - 11:45 5.75 11:45 - 12:45 12:45 - 17:30 '!. 1.00! DRILL ' OTHR 'INTRMI Trouble w/ Sperry Sun MWD tools. Cannot get a good pulse. Clean 4.75 , II suction screens on mud pump # 2, slow data rate down on tool. DRILL Ili DRLG 'i INTRMI 'Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg I bend f/ 15260' to 15445' (6554' TVD) (186') ART 1.36 hrs AST 1.82 'hrs, Total hrs on bit = 44.07 hrs., Total hrs on jars = 134.65 hrs, 5-10 k II WOB, 120 rpm's, 206 motor rpm, 625 gpm, 10.0 ppg mw, on bottom I ',pressure 3430-3630 psi, off bottom pressure 3370-3500 psi, on bottom ~~ ~I torque 18-19k ft/Ib, off bottom torque 17-18k fUlb, PU wt 290k, SO wt ', ~I ' 155k, Rot wt 208k. ECD's = 10.99 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = 154 units while drilling @ 15325'. 17:30 - 18:30 i, 1.00' DRILL i OTHR ~ INTRM1 'Trouble w/ Sperry Sun MWD tools. Cannot get a pulse. Change out i standpipe sensor f/ MWD. Mode switch and attempt to get signal. No '~I ; good. Try higher flow rate to 657 gpm w/ 3820 psi. Rotate and recip pipe @ 90 rpm w/ 18-19k ft/Ib torque. Working pipe f/ 15440' to 15365' Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 19 of 53 Operations. Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To 'Hours ' Code Sub ,Phase ' Description of Operations 2/18/2006 ',18:30 - 21:00 21:00 - 22:30 22:30 - 00:00 2/19/2006 00:00 - 00:45 00:45 - 01:15 01:15 - 02:00 02:00 - 03:00 03:00 - 03:30 !. 03:30 - 04:00 04:00 - 05:00 05:00 - 06:00 '.06:00 - 12:00 .12:00 - 15:30 Code 2.50 ~ DRILL 'CIRC I INTRMI Circ w/ standing back a stand every 1/2 hour. Pumping 625 gpm w/ 3360 psi. Rotate 90 rpm w/ 18-19k ft Ib torque. Rot wt while pulling = I 220k. Pumped 1700 bbls total. TRIP I l 1.50' DRILL INTRM1 Monitor well. POOH on elevators f/ 14985' to 14465'. PU wt 345k to i I, I 360k. SO wt 145k. Tight spots @ 14594' to 14574' and 14449'. Pulled 140k over, worked tight spots clean. 1.50 ~ DRILL REAM INTRM1 'Continue to pull tight @ 14469'. MU top drive @ 14479', fill pipe, ~i ~, establish circ w/ 600 gpm (ECD 10.9 ppg) 3160 psi. Stage rotary f/ 50 rpm w/ 19-21 k ft Ib torque. Backream out slow f/ 14479' to 14395'. ~I I 'Pulling speed 5 feet per min. Sperry Sun tools started working while l ',pumping through tight spot. 0.75 ~~ DRILL I REAM INTRM1 'Backreaming f/ 14395' to 14315' ,pumping 600 gpm w/ 3180 psi (PWD: i ~ ' ECD's 10.9 ppg), rotating 90 rpm w/ 20-23k ft/Ib torque, pulling slow (1' ~~ ', per min). Torque freeded up to normal (18-19k ft/ Ib) torque and drag 'I l ',while reaming @ 14340' (stand # 147), then were able to pull @ 5' per I TRIP 0.501 DRILL II INTRM1 min. 'Pump out of hole f/ 14315' to 14220' w/ 600 gpm w/ 3200 psi. PU wt I 280-290k. 0.75 DRILL REAM INTRM1 '; Backreaming f/ 14220' to 13938' ,pumping 615 gpm w/ 3220 psi (PWD: 1 ECD's 10.9 ppg), rotating 90 rpm w/ 18-19k ft/Ib torque, pulling 10' per min. Pulling speed 10' per min. w/ 200k while rotating up. 1.00 DRILL ~I~ TRIP INTRM1 ' Monitor well. Trip in hole f/ 13938' to 15270'. PU wt 310k, SO wt 130k. 0.50 DRILL I REAM INTRMI ' Wash and ream f/ 15270' to 15445'. Pumping 635 gpm w/ 3320 psi, ~ 1 ~ I I rotating 90 rpm w/ 18-19k ft/Ib torque. ECD's 10.96 ppg. 0.50 DRILL 'DRLG '~ INTRM1 I Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg ', I ~ bend f/ 15445' to 15458' (6556.82' TVD) (13') ART .26 hrs AST 0.0 hrs, ', 'i Total hrs on bit = 44.33 hrs., Total hrs on jars = 134.91 hrs, 15-20 k ', I WOB, 120 rpm's, 206 motor rpm, 625 gpm, 10.0 ppg mw, on bottom I pressure 3430 psi, off bottom pressure 3230 psi, on bottom torque ' 24-25k fUlb, off bottom torque 22-23k ft/Ib, PU wt 295k, SO wt 155k, ', Rot wt 205k. ECD's = 10.85 ppg EMW. Slow RPM's to 90 when backreaming stand. Max gas = ??? units while drilling @ ??? 1.00 ~~, DRILL CIRC ' INTRM1 Circ to clean hole up on bottoms up. 2600 units max gas while circ @ ', 625 gpm w/ 3430 psi. Rotate 90 rpm w/ 20k torque after hole cleaned ~ up. ECD's 10.9 ppg EMW. 1.00', DRILL ', DRLG INTRM1 Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg bend f/ 15458' to 15512' (6566' TVD) (54') ART .61 hrs AST 0.18 hrs, Total hrs on bit = 45.12 hrs., Total hrs on jars = 135.71 hrs, 25-28 k ', l~, WOB, 120 rpm's, 198 motor rpm, 600gpm, 10.0 ppg mw, on bottom l ', pressure 3207 psi, off bottom pressure 3120 psi, on bottom torque ~ 19-20k ft/Ib, off bottom torque 17-18k ft/Ib, PU wt 290k, SO wt 150k, i Rot wt 205k. ECD's = 10.64 ppg EMW. Slow RPM's to 90 when I ! backreaming stand. Max gas = ??? units while drilling @ ??? 6.00; DRILL ', DRLG '~, INTRM1 'Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg ~~ I bend f/ 15512' to 15778' (6597 TVD) (266') ART 3.64 hrs AST 1.06 ~~ 'hrs, Total hrs on bit = 49.82 hrs., Total hrs on jars = 140.41 hrs, 25-35 k I, II ! WOB, 120 rpm's, 198 motor rpm, 600gpm, 10.0 ppg mw, on bottom I !pressure 3207-3500 psi, off bottom pressure 3120-3200 psi, on bottom ~ torque 18-21k ft/Ib, off bottom torque 16-18k ftllb, PU wt 290-295k, SO II ', wt 150k, Rot wt 205k. ECD's = 10.64-10.74 ppg EMW. Slow RPM's to I I I ', 90 when backreaming stand. Max gas = ??? units while drilling @ ??? 3.50 DRILL 'I DRLG INTRMI 'Directional drill 9-7/8"" hole w/ Sperrydrill 7/8-6.0 stage mtr w/ 1.22 deg II j ', bend f/ 15778' to 15947 (6616' TVD) (169') ART 2.14 hrs AST 1.06 Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 20 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillip s.com Rig Name: Doyon 15 Date From - To Hours Code Code Phase 2/19/2006 12:00 - 15:30 3.50 ~ DRILL it DRLG ,INTRMI 15:30 - 18:00 I 2.501; DRILL I ~' CIRC ', INTRM1 i II 18:00 - 18:15 I 0.25 ! RIGMNTI RGRP INTRM1 ; 18:15 - 18:45 ~ 0.50, DRILL ''CIRC I INTRMI I 18:45 - 19:30 0.75 DRILL II CIRC INTRM1 19:30 - 20:00 ', 0.50 DRILL TRIP INTRM1 20:00 - 20:15 i 20:15 - 22:30 ~ 0.25 DRILL 2 25 DRILL TRIP CIRC ' INTRM1 ' INTRMI . ; I : 22:30 - 00:00 I 1.5011 DRILL REAM II '~ INTRM1 11 2/20/2006 ~ i L1 00:00 - 01:15 II 1.25 DRILL I' ~ REAM II I, INTRMI I 1 01:15 - 06:00 I I 4.75 DRILL ! TRIP l ' INTRM1 I I 1 I I III II 1 '1106:00 - 07:00 'll 1.00 I DRILL TRIP 1, INTRM1 07 00 1 08 00 1 1 00 DRILL TR : 1 - : . IP INTRM1 108:00 - 11:00 I i 3.00 DRILL TRIP ~I INTRM1 11:00 - 12:15 '. 1.25 DRILL I CIRC II I INTRM1 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations hrs, Total hrs on bit = 51.96 hrs., Total hrs on jars = 142.55 hrs, 20-35 k WOB, 120 rpm's, 198 motor rpm, 600gpm, 10.0 ppg mw, on bottom 11 pressure 3500-3450 psi, off bottom pressure 3200 psi, on bottom 'torque 19-23k ft/Ib, off bottom torque 16-18k ft/Ib, PU wt 290k, SO wt 150k, Rot wt 205k. ECD's = 10.74-10.78 ppg EMW. Slow RPM's to 90 'when backreaming stand. Max gas = ??? units while drilling @ ??? -Pump hi vis weighted sweep. Pump 615 gpm ww/ 3200 psi. Rotate 120 ,rpm w/ 22-23k ft/ Ib torque. Set back a stand every 30 min. Max gas units 4970, MW cut .2ppg, tossing 50 bph @ 615 gpm. Slowed pumps 'to 400 gpm, still losing 50 bph. Total lost to well 83 bbls. Pumped 1772 ', bbls total. ',Change out "O" ring in high pressure mud line. ,Circ and condition mud and hose .Rotate and reciprocate pipe f/ 15840' 11 to 15900'. Pump 575 gpm w/ 2970 psi. Rotate 90 rpm w/ 19-20k ft Ib torque. Pump 45 bbl LCM pill w/ 25 ppb mix II f/ 15900' to 15745'. Pump 575 gpm w/ 2780 psi. Pump total of 283 bbls. Well static @ 15840'. ,Pumped out of hole f/ 15745' to 15540' @ 5 bpm w/ 550 psi. Hole l swabbing and pulling tight 315-330k Up wt. SO wt =130k Light flow ~I back. ~~, RIH f/ 15540' to 15840'. SO wt 130k, PU wt 340k. '~ Circ and weight up f/ 10.0 ppg to 10.2 ppg. Circ @ 575 gpm w/ 2800 II psi. Rotate @ 90 rpm w/ 18-19k ft Ib torque.Work pipe f! 15840' to ',15905'. After pumping 337 bbls, max gas 4980 units. After pumping ',total of 1020 bbls, max gas again @ 4980 units. Circ until 10.2 ppg was ~~! around. Washed and reamed back to 15947, then up to 15900' to verify !hole still in good shape, OK. ECD's = 10.88 ppg. I~ Backream f/ 15900' to 15621' w/ 85 rpm w/ 20k ft Ib torque. Pumping 575 gpm w/ 2880 psi, 36% flow line. PU wt 320k, SO wt 135k. Fluid losses f/ 1800 to midnight = 155 bbls Total fluid loss @ midnight = 238 bbls. I'L Continue backreaming f/ 15621' to 15366'. Rotate @ 85 rpm w/ 19-20k ''lift/ Ib torque. Pumping 575 gpm w/ 2850 psi, w/ 36% flow. PU wt 320k, SO wt 140k. SLM Gas units to 1000 units @ 28475 strokes. Monitor well @ 6 stands out = 15366', OK, static. .Continue pumping out f/ 15366' to 12985'. Pumping 360 gpm w/ 1330 psi. While pumping out, spot a 37 bbl LCM pill (25 ppb) f/ 13987' to 113704' in open hole. PU wt 280k, SO wt 140k. SLM. Monitor well @ 11 stands out = 14890' OK, static. 11 Monitor well @ 19+ stands out = 14200', OK- static, appears to swab if 'i pulled w/o pumps. 1 Fluid losses f/ midnight to 0600 hrs = 80 bbls 11 Total fluid losses to well @ 0600 hrs = 318 bbls. ' Continue pumping out f/ 12985' to 12225'. Pumping 360 gpm w/ 1200 !psi. PU wt 280k, SO wt 140k. SLM. POOH w!o pumping f/ 12225' to 11654'. Hole took 5 bbls. Btow down top drive. SLM. Continue pumping out f/ 11654' to 9657. Pumping 360 gpm w/ 1200 II psi. SLM. Tight spots in hole pulling 40k over @ 10987 to 10797, and 110701' to 1027 were reamed out. Circ hole clean @ shoe (9653'). Stage pumps up while monitoring 11 losses. Pumping 550 gpm w/ 2200 psi, rotate 120 rpm w/ 12k ft/Ib Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 21 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 2/20/2006 From - To II Hours ' Code '' ' Phase , Code __- '111:00 - 12:15 ~ 1.25 DRILL 'CIRC INTRMI 12:15 - 12:30 !!; 0.25 DRILL i CIRC INTRM1 t 12:30 - 13:30 j 1.00 RIGMNT ~ RSRV INTRM1 i 13:30 - 14:15 ~ 0.75 RIGMNT RSRV I INTRM1 i 14:15 - 17:00 ~ 2.75 DRILL ~ TRIP I INTRM1 17:00 - 17:45 ~, 0.75 DRILL 17:45 - 18:00 II 0.25 DRILL 18:00 - 21:30 3.50 DRILL 21:30 - 23:00 1.501 DRILL 23:00 - 00:00 2/21/2006 i 00:00 - 00:15 00:15 - 00:45 00:45 - 02:45 102:45-05:15 105:15 - 06:00 06:00 - 06:30 06:30 - 06:45 06:45 - 07:15 07:15 - 08:30 1.00 DRILL '~OBSV TRIP INTRM1 INTRM1 TRIP INTRM1 CIRC ' INTRM1 CIRC ' INTRM1 ' 0.25! DRILL ' 1, CIRC i ' i11NTRM1 ~I 0.50~'i DRILL ~' ',TRIP IINTRM1 2.00111 DRILL I CIRC I INTRM1 2.50, DRILL 'TRIP I INTRM1 0.75 DRILL '.TRIP 0.501 DRILL I TRIP 0.25 DRILL '~ OBSV 0.50 DRILL TRIP 1.251 DRILL !TRIP 08:30 - 09:00 ' 0.50 DRILL j OBSV 09:00 - 09:15 ' 0.25 ,DRILL I, TRIP 09:15 - 13:15 ' 4.00 DRILL CIRC INTRMI INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI Description of Operations torque. ~I Pump dry job. Blow down top drive. Slip and cut 110' of 1-3/8" drilling line. Service top drive and crown. Adjust brakes. Install stripper rubbers and 5" air slips. POOH on elevators f/ 9657' to 5471'. I~ Monitor well @ 5471', flowing very slow. Static after 25 min. ~ POOH f/ 5471' to 4902'. Hole took 2.3 bbls. Monitor well. Flowing very slowly. Total losses f/ 0600 hrs to 1800 hrs = 97 bbls Total fluid lost to well @ 1800 hrs = 415 bbls. Trip in hole f/ 4902' to stand 67 (6800') fill pipe, trip in to stand 87 (8700'), trip in to stand 97 (9657'), MU top drive on stand 98. Fill pipe, establish circulation„ Rotate @ 120 rpm w/ 13-14k ft Ib torque. Pump staging up to 500 gpm w/ 1800 psi. ECD's 10.99-10.55 ppg. ~ Significant increase in cuttings on bottoms up. Circulated total of 972 li bbls. PU wt 230k, SO wt 130k. Rot wt 160k. Gas: 150 to 220 units. Make connection on stand # 99. Circ and condition mud and hole. Rotate and reciprocate f/ 9745' to 9840'. Rotate @ 120 rpm. Circ @ 625 gpm w/ 2650-2560 psi. ECD's 10.6 ppg to 10.75 ppg. Gas: 211 units to 12350 units. Fluid lost f/ 1800 to midnight = 26 bbls. Total fluid lost to well @ midnight = 441 bbls. 1, Formation losses decreased to minimal losses (2-6 bph) while circ @ 9840'. Stand # 99. Circ and condition mud and hole. Rotate and reciprocate f/ 9745' to 9840'. Rotate @ 120 rpm. Circ @ 625 gpm w/ 2650-2560 psi. ECD's 10.6 ppg to 10.75 ppg. Circulated on stand # 99, 1016 bbls total. Gas: 2350 units to 211 units. Trip in hole 10 stands to 10700'. Hole appeared to be static, accounting f/ pipe displacement and filling pipe. Good displacemnt. MU top drive on stand #109. Circ and recip f/ 10705' to 10790'. Rotate 120 rpm. Circ 625 gpm w/ 2750-2700 psi. Circ 1600 bbls. Gas: 282 units to max of 4970, then down to 224 units when through. ECD's 10.71 ppg when starting, max of 10.83 ppg, 10.69 ppg when finished. ~, Ran stand #110 in hole to 10889', POOH to 10760' watching pipe displacement. Monitor well. POOH one stand. ~~ Pump out of hole f/ 10701' to shoe w/ 360 gpm, from shoe continue iii pumping @ 170 gpm w/ 290 psi to 9235'. PU wt 210k, SO wt 120k. Total fluid loss f/ midnight to 0600 hrs = 4 bbls ', Total fluid lost to well = 445 bbls I, Pump out of hole f/ 9235' to 8896' pumping @ 170 gpm (4 bpm) w/ 295 I psi. Monitor well. Static. POOH w/ stand # 89, f/ 8896' to 8801'. Swabbing unless pumping. Continue pumping out of hole f/ stand #88 to stand # 79 (8801' to 17849'). Pumping 4 bpm (169 gpm) w/ 320 psi. Bit turning 56 rpm. 'Blow down top drive. Monitor well. Static. 'POOH slow stand # 78, f/ 7849' to 7754'. Swabbing if without pumping. 'Phase 3 weather. Stand #77 in hole @ 7754'. Circ 61 SPM (258 gpm) ', w/ 500 psi. Bit turning 85 rpm. Rotate string 90 rpm w/ 9k torque. Work 'pipe to 7690' while circ. Circ total of 1374 bbls. BU = 554 bbls. Max gas ', = 290 units, fiinal 120 units. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 22 of 53 Opera#ions Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 2/21/2006 From - To Hours Code Sub '..Code'. -- 13:15 - 00:00 10.75 ~I DRILL ~ OBSV 2/22/2006 00:00 - 00:30 00:30 - 05:00 05:00 - 05:15 05:15 - 08:45 0.50'i DRILL I OBSV 4.50!. DRILL I CIRC 0.25 DRILL TRIP 3.50 DRILL ~ CIRC ~ 08:45 - 12:45 ,12:45 - 14:00 ',,14:00-14:45 14:45 - 17:00 17:00 - 17:45 ~', 17:45 - 18:00 '' 18:00 - 19:30 ~~ ;119:30 - 22:15 ~i22:15-23:15 23:15 - 00:00 2/23/2006 1100:00-01:30 01:30 - 02:30 02:30 - 04:00 04:00 - 06:00 4.OO DRILL OBSV 1.25',. DRILL ( TRIP 0.75! . DRILL I' TRIP 2.25 ' DRILL ; TRIP 0.75 DRILL TRIP 0.25 DRILL TRIP 1.50 ~ DRILL i TRIP 2.75',' DRILL ~I TRIP 1.00 DRILL TRIP 0.75 ''I DRILL ' ,OTHR 1.50 DRILL 'TRIP 1.00 DRILL PULD 1.50 DRILL PULD 2.00 ~, DRILL TRIP '~ 06:00 - 10:00 '.:10:00 - 12:30 I~ ',12:30-15:00 ~~, ',15:00-17:30' 4.00' DRILL '',TRIP 2.50', RIGMNT'~, RSRV 2.501 DRILL TRIP 2.501 DRILL ', REAM Phase Description of Operations INTRMI ~ Continue to wait on weather (Phase 3). Monitor well. Static. 77 stands 5" DP w/ BHA = 7754'. INTRM1 Continue to wait on weather (Phase 3). Monitor well. Static. 77 stands 5" DP w/ BHA = 7754'. INTRMI ~~ Phase 3 weather. Stand #77 in hole @ 7754'. Circ 30 SPM (127 gpm) w/ 260 psi. Bit turning 42 rpm. Rotate string 50 rpm w/ 8k torque. Work '.pipe to 7690' while circ. Circ total of 825 bbls. BU = 554 bbls. Max gas = '.129 units, fiinal 60 units. INTRMI ', L/D single in mouse hole. INTRM1 I Phase 3 weather. Stand #77 in hole @ 7724'. Circ 30 SPM (127 gpm) '~ w/ 260 psi. Bit turning 42 rpm. Rotate string 50 rpm w! 8k torque. Rot wt 150k. Work pipe to 7678' while circ. Circ1025 bbls. Fluid loss f/ midnight to 0600 hrs = 9 bbls Total fluid lost to well @ 0600 hrs = 454 bbls. INTRM1 Phase 3 weather. Blow down top drive. PU single. monitor well. Static. INTRM1 Phase 3 weather. MU top drive. Pump out f/ 7754' to 6802'. Pumping 360 gpm w/ 806 psi. Bit turning 119 rpm's. INTRM1 ~ Phase 2 weather: main roads CPF-1 area @ 1349 hrs. POOH f/ 6802' ', to 6327. Hole not taking correct fill. INTRM1 Pump out of hole f/ 632T to 4426'. Pumping 360 gpm w/ 750 psi. Bit '!.turning 119 rpm's. SLM out of hole. INTRM1 ', POOH f/ 4426' to 3855'. Hole not taking correct fill. SLM out of hole. INTRMI !, Phase 1 weather: main roads CPF-1 area @ 1747 hrs. Pump out of '~ hole f/ 3855' to 3760'. Pumping 360 gpm w/ 715 psi. Bit turning 119 rpm's. PU wt 132k, SO wt 115k. ~ SLM out of hole. No fluid losses f/ 0600 hrs to 1800 hrs. 1 Total fluid losses @ 1800 hrs = 454 bbls. INTRM1 Continue pumping out of hole f/ 3760' to 2860'. Pumping 360 gpm w/ 1715 psi. SLM out of hole. INTRM1 POOH on elevators f/ 2860' to 1470', Remove 9-7/8" Weatherford ghost 'reamer. INTRM1 POOH f/ 1470', work BHA. UD accelerators and jars, stand back HWDP, flex collars, break bit. INTRM1 Download Sperry Sun MWD. ':Fluid loss f/ 1800 to midnight = 12 bbls over talc displacement. %Total fluid loss Up to midnight = 466 bbls. INTRMI ', L/D stab, float sub, motor. INTRM1 PU BHA #4 (cleanout assembly), Up load Sperry Sun MWD, clear/clean ', rig floor. INTRMI !,Work BHA, MU crossover, bit sub, Trip in hole, shallow test MWD @ 1, 495' INTRM1 Trip in hole f/ 495' to 2299'. Fill pipe every 20 stands. Torque and drag PU/SO wt's every 10 stands. PU wt @ 2299' 115k, SO 110k. Fluid loss f/ midnight to 0600 hrs = nonoe. Total fluid loss to well = 466 bbls. INTRM1 Continue trip in hole f/ 2299' to 9623'. Fill pipe every 25 stands. INTRM1 'i Service top drive and crown. Change out saver sub on top drive--(4-1/2" J F) INTRMI 'Continue RIH f/ 9623' to 14040'. Fill pipe every 25 stands. INTRMI ; MU top drive. Pump 215 gpm w/ 900 psi. Rotate 40 rpm w/ 15k fUlb 'torque. Work through bridge. Increase pump rate to 510 gpm w/ 2500 psi. Ream f/ 14040' to 15380'. Packed off @ 15380'. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From.- To ,.Hours ' Code ' Code I Phase 2/23/2006 ~I 17:30 - 18:00 0.50 ~I DRILL '! OTHR ~I INTRM1 18:00 - 23:00 I, 5.001 DRILL REAM I INTRM1 23:00 - 00:00 2/24/2006 100:00 - 00:45 !, I I ~i00:45-01:15 01:15-06:00 I 06:00 - 09:30 09:30 - 12:00 ' 12:00 - 15:30 15:30 - 15:45 I 15:45 - 18:00 18:00 - 19:30 '19:30-21:45 i 21:45 - 00:00 I 1.00'1 DRILL REAM 11 INTRM1 i ~~ i 0.7511 DRILL REAM ~ INTRMI 0.50 ! DRILL REAM 'INTRMI ', 4.751~I DRILL I REAM INTRM1 3.50'1 DRILL REAM ',INTRMI 2.501 DRILL OTHR :..INTRMI 3.50' DRILL OTHR !INTRMI i 0.25' DRILL REAM i ~ INTRM1 2.25 DRILL CIRC INTRM1 1.50 2.25 2.25 DRILL I~ CIRC INTRM1 DRILL ~, CIRC ',INTRMI DRILL ',CIRC INTRM1 Start: 1 /28/2006 Rig Release: 4/2/2006 Rig Number: 15 Page 23 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations II Work pipe up to 400k, down to 90k. Establish circ @ 21 gpm w/ 511 psi. Attempt to rotate w/ 27k ft Ib torque. Work pipe f/ 15,380' to 15,400'. Increase circ rate to 1 bpm w/ 490 psi. Stage rate up to 3 bpm w/ 640 psi (full returns) Intiate rotation 110 rpm @ 27,000 ft/Ibs. Up wt. 330K, Dn Wt 130k, Rot Wt 190k. Slowly increase pump rate and continue to rotate and recip string. Increase I, string movement to 15,424'. ',Continue to wash and ream f/ 15,424 to 15,492'. Slowly increase flow j rate as able. Torque remains high and string is still moderately packing off at times. '.Continue to wash and ream f/ 15,424 to 15,492'. Slowly increase flow ', rate as able. Torque remains high and string is still moderately packing off at times. Continue working pipe High torque stalling RPM out, use torque limit 'set @ 26k ft Ib.. Increase pump rate to 620 gpm w/ 2750 psi. Packed off after pumping 175 bbls. Continue working pipe f/ 15492' to 15332'. High torque stalling RPM out, use torque limit set @ 26k ft Ib. Pump rate 320-334-360 gpm w/ 1000-1300 psi when not packing off. PU wt 330k, SO wt 130k, Rot wt 200k. Fluid losses f/ midnight to 0600 hrs = 12 bbls. !,Continue working pipef/ 15332' to 14913'. High torque stalling RPM out, use torque limit set @ 26k ft Ib. Pump rate 320-334 gpm w/ 1150-1300 psi when not packing off. Packed off. :.Work pipe f/ 15047 to 14952' trying to establish circ. Work pipe and pump out f/ 14952' to 14761'. Pump 131 gpm w/ 4755 ,psi. Max pull on weight indicator of 450k. Avg PU wt 350k. '1 Continue to wash and ream f/ 14761 to 15,666'. Pumping 173 gpm w/ 515 psi. RPM's f/ 20 to 100 w/ Torque remains high (26k ft Ib) and string is still moderately packing off at times. Circ and condition hole staging pumps up f/ 168 gpm w/ 515 psi to 357 gpm w/ 1265 psi. Rotate 20 to 100 rpm's w/ torque limit set @ 26k ft/ Ib. PU wt 350 k. SO wt 140k, Rot wt 190k. No losses f/ 0600 hrsto 1800 hrs. Total losses to well @ 1800 hrs = 518 bbls. Circ and condition mud and hole. Recip and work pipe f/ 14761' to 14666'. Pumping 357 bpm w/ 1265 psi, then follow w/ 504 gpm w/ 2180 li psi. Rotate 70-100 rpm with torque limit set @ 26k. Pump 30 bbls high vis weighted sweep. Continue rotating, reciprocating ;and pumping to clean up hole. Recip f/ 14761' to 14666'. Circ 504 gpm '; w/ 2230 psi. Rotate 50-70 rpm w/ torque limit set @ 26k ft/Ib torque !limit. Rotating weight 187k. Pump 50 bbls high vis weighted sweep. Continue rotating, reciprocating 1 and pumping to clean up hole. Pump 50 bbl hi vis weighted sweep. Recip f/ 14755' to 14663'. Circ 625 gpm w! 2990 psi. Rotate 60-75 rpm it w/ torque limit set @ 27k ft/Ib torque limit. Rotating weight 187k. ECD's ,10.88. ppg, ecd's after sweep around = 10.76 ppg. Rotate 70-90 rpm w/ torgque 26.5k ft Ib, Rot weight 187k. No fluid losses f/ 1800 to midnight. ECD's on first sweep(30 bbls) increased f/ 10.8 ppg to 11.02 ppg, then back to 10.76ppg j ECD's on second sweep (50 bbls) increased f/ 10.8 ppg to 10.95 ppg, Printed: 4/26/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 'Sub 2/24/2006 2/25/2006 2/26/2006 From - To Hours Code ' 'Phase I~ 21:45 - 00:00 00:00 - 04:00 1 04:00 - 05:00 ~~ I 05:00 - 06:00 ~I' I 'I 06:00 - 07:15 ', I i ', 07:15 - 09:00 '', 09:00 - 12:00 I ~' 12:00 - 14:00 1~ '14:00-15:45 '' 1,15:45-18:00 ~~ Ii 18:00 - 18:30 '18:30-19:301 Code 2.25 ~~ DRILL 'CIRC INTRM1 4.001 DRILL REAM INTRM1 1.001 DRILL REAM I I 1.001 DRILL CIRC INTRM1 INTRM1 1 25 DRILL REAM INTRM1 . ~ 1.75'i DRILL I REAM ', INTRM1 I 3.00 DRILL I ,REAM INTRMI 2.00 `DRILL REAM ' INTRM1 I 1.751 DRILL , OTHR 11, INTRMI 2.25 DRILL 'CIRC (INTRMI 0.50', DRILL 1.00', DRILL OTHR INTRM1 REAM INTRM1 1,19:30 - 20:30 ' 1.00 II DRILL ' OTHR INTRM1 20:30 - 22:00 1.50 1 DRILL ' OTHR INTRMI 122:00 - 00:00 ' 2.00 DRILL ' OTHR I INTRMI 00:00 - 00:30 I 0.50 DRILL I ~ OTHR INTRM1 00:30 - 01:30 1.00 DRILL I OTHR ' INTRM1 ~ 1101:30 - 03:30 I,I 2.00', DRILL CIRC ', INTRM1 Page 24 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations then back to 10.8 !,Another sweep was pumped after midnight(0200 hrs) (60 bbls), ECD's increased f/ 10.82 ppg to 11.1 ppg then back to 10.8 Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 14666' to 14470'. Circ 625 gpm w/ 2980 psi. Rotate 80-100 rpm w/ ~ torque limit set @ 27k ft/Ib torque limit. Rotating weight 187k. Rotate 170-90 rpm w/ torque 26.5k ft Ib, Rot weight 187k. Pumped 60 bbls hi vis weighted sweep. Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 14470' to 14375'. Circ 625 gpm w/ 2900 psi. Rotate 80-120 rpm w/ torque limit set @ 27k ft/Ib torque limit. Rotating weight 187k. ECD's 11.01 ppg, ecd's after sweep around = 10.76 ppg. Rotate 70-90 rpm w/ torque 26.5k ft Ib, Rot weight 187k. Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 14375' to 14280'. Circ 625 gpm w/ 2900 psi. Rotate 80-120 rpm w/ torque limit set @ 27k ft/Ib torque limit. Rotating weight 187k. ECD's 10.8 ppg, Rotate 80-120 rpm w/ torque 26.5k ft Ib, Rot weight 186k. PU wt 295k, SO wt 145k. No fluid loss to well. Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 114285' to 14190'. Circ 630 gpm w/ 2930 psi. Rotate 80-120 rpm w/ torque limit set @ 27k fUlb torque limit. Rotating weight 187k. ECD's 110.8 ppg, Rotate 80-120 rpm w/ torque 26.5k ft Ib, Rot weight 186k. PU !, wt 295k, SO wt 145k. ', Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 14190' to 14095'. Circ 630 gpm w/ 2930 psi. Rotate 80-120 rpm w/ torque limit set @ 27k ft/Ib torque limit. Rotating weight 187k. ECD's ',10.8 ppg, Rotate 80-120 rpm w/ torque 26.5k ft Ib, Rot weight 186k. PU ', wt 295k, SO wt 145k. 'Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 14095' to 15047. Circ 630 gpm w/ 2900 psi. Rotate 40-150 rpm w/ ~ torque limit set @ 27k ft/Ib torque limit. Pump 50 bbls Steei cube EP @ 15000'. I, Continue rotating, reciprocating and pumping to clean up hole. Recip f/ 15047 to 15507. Taking weight. Circ 630 gpm w/ 3000 psi. Rotate 40-150 rpm w/ torque limit set @ 27k ft/Ib torque limit. Work pipe. Attempt to get past 15507. MWD survey. Pump 40 bbl weighted hi vis sweep. Pump @ 469 gpm w/ ',1886 psi. Rotate 40-150 rpm w/ torque limit set @ 27k ft/ Ib torque. Work pipe to 15522'. Set down 30k. ~i No fluid losses. Total fluid lost to well = 518 bbls. ~I Continue working pipe f/1550T to 15522'. Reaming f/ 15522' to 15600'. Pumping 505 gpm w/ 2090 psi. Rotating 70-120 rpm w/ torque limit @ 27k ft/Ib. PU wt 300k. SO wt 150k. Rot wt 190k. Ream w/ 30-40k wt on bit. Packed off @ 15600'. Work pipe @ 15600' to 15585'. Establish flow rate of 2 bpm w/ 750 psi. I Work pipe @ 15585' to 15570'. Establish flow rate of 2 bpm w/ 925 psi. !Work pipe @ 15580' to 15570'. Establish flow rate of 2 bpm w/ 650 psi. ~I Work pipe @ 15580' to 15570'. Packed off. ~ Work pipe f/ 15580' to 15570'. Regain circ @ 0130 hrs. ~, Working pipe free f/ 15580' to 15520'. Flow rate up to 625 gpm w/ 3000 psi. Printed: 4/28/2006 6:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To 'Hours Code Sub Phase 2/26/2006 ~ 03:30 - 04:30 i 04:30 - 05:30 05:30 - 06:00 06:00 - 08:30 08:30 - 10:45 10:45 - 11:00 11:00 - 12:00 12:00 - 12:30 Code __ __ 1.00; DRILLCIRC INTRM1 i 1.001 DRILL CIRC INTRMI 0.50 2.50 2.25 0.25 1.00 0.50 DRILL ~I CIRC DRILL CIRC DRILL CIRC DRILL OBSV DRILL ;TRIP DRILL ';TRIP 12:30 - 13:00 ! 0.50 DRILL x,13:00 - 14:45 1.75 DRILL !,14:45 - 15:00 0.25 . DRILL 15:00 - 18:00 ~ 3.00 J DRILL 18:00 - 20:30 I 2.50 ~ DRILL 20:30 - 00:00 I 3.50 DRILL INTRMI INTRMI INTRM1 INTRM1 INTRM1 I NTRM 1 TRIP IINTRM1 CIRC IINTRM1 OTHR '' INTRM1 TRIP (INTRMI TRIP INTRMI CIRC INTRM1 2/27/2006 ! 00:00 - 01:15 I 1.251 ~ DRILL 'TRIP INTRM1 I 01:15 - 01:45 0.50!; DRILL ' CIRC INTRMI 01:45 - 05:00 3.25; DRILL , TRIP INTRM1 05:00 - 06:30 1.50' DRILL ~', TRIP INTRMI 106:30 - 07:15 II 07:15 - 07:45 ~: 07:45 - 08:15 08:15 - 09:30 ~~, 09:30 - 13:00 '~, ',13:00-14:0011 I Ali 14:00 - 14:30 li 14:30 - 16:00 I 16:00 - 17:00 ~' 17:00 - 18:15 ', 18:15 - 00:00 '. 0.75 ~ DRILL ' OTHR 0.5011 WELCTLI OTHR 0.50 WELCTLI OTHR 1.25, WELCTL~OTHR 3.501 WELCTI~ BOPE I 1.00!. WELCTLIOTHR 0.50' WELCTL~OTHR 1.50' DRILL PULD 1.00 DRILL OTHR 1.251 DRILL ', OTHR 5.751, DRILL (TRIP INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRM1 !, INTRM1 INTRM1 Page 25 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Working pipe, rotating up to 140 rpm w/ 27k torque limit. Pumping 625 gpm w/ 3030 psi, 39% flow line indicator. Pump a 44 bbls weighted high vis sweep, then 100 bbls mud. Stand back one stand in derrick. ~~ Circ and condition hole f/ 15427 to 15330' while pumping sweep. Pumping @ 625 gpm w/ 3000 psi. Rotate 80-140 rpm w/ torque limit @ ', 27k ft Ib torque. Rot wt 190k. Hole packed off @ 15370'. Work to establish flow rate. 'Establish flow of 189 gpm w/ 750 psi. Work pipe f/ 15420' to 15400'. Circ @ 118 gpm w/ 500 ps, Work pipe f/ 15400' to 15500'. Increase rate to 624 gpm w/ 3120 psi. Rotate 40-100 rpm w/ 27k torque limit. I Circ and weight up f/ 10.2 to 10.5 ppg while circ to clean hole. Pumping 590 psi w/ 2900 psi. Max gas = 3570 units. I Slow pump rates @ 15500' w/ 10.5 ppg MW. Observe well. !POOH f/ 15500' to 14805'. Avg PU wt 390k. SO wt 130k. Work tight ',spots @ 15297 to 15105'. Max pull 440k. POOH f/ 14805' to 14285'. Avg PU wt 390k. SO wt 130k. Work tight ,spots @ 14769' to 14762'. Max pull 440k. Well not taking correct fill while pulling on elevators through Kalubik and HRZ. Pump out of hole f/ 14285' to 13095'. Pump 420 gpm w/ 1500 psi. CBU w/ working pipe f/ 14095' to 14190'. Pump 518 gpm w/ 2170 psi. Rotate 100 rpm w/ 26-28k ft Ib torque. Blow down top drive. Monitor well. Pump out f/ 14190' to 11334', Pumping 292 gpm w/ 777 psi. ~' Fluid losses f/ 0600 hrs to 1800 hrs = 131 bbls 'Total fluid losses to well @ 1800 hrs = 747 bbls Pump out f/ 11334' to 9623', Pumping 292 gpm w/ 680 psi. ', CBU x 4 w/ working pipe f/ 9623' to 9528'. Not completly clean after 4 BU. Pumping 625 gpm w/ 2440 -2340 psi. Rotate 120 rpm w/ 14-15k ft! Ib torque. Final torque 10-11 k ft Ib. No losses while circulating. Max i ECD 11.4 ppg, Final ECD 11.18 ppg (calc clean hole is 11.18 ppg). Total fluid loss to well @ midnight = 767 bbls. ~ Monitor well, Static. While pulling pipe, appears to be swabbing. Pump 620 gpm w/ 2340 psi. Rotate 85 rpm w/ 10k torque. Pulling f/ 9528' to 8862'. Pump dry job. Blow down top drive. ', POOH on elevators f/ 8862' to 398'. 'Work BHA. Lay down accelerators, jars, stand back HWDP, stand back 'flex drill collars, break bit, bit sub, float sub. ', Download Sperry Sun MWD, Lay down hang off collar and MWD. Clear floor, drain stack. RU to test BOPE. MU pup and single dp. Pull wear bushing. Rig up test joint and equipment to test BOPE. Fill stack with water. ~ Test BOPE. Witness of test waived by AOGCC inspector John Crisp. ,Test all components to 250 psi low and 3500 psi high. Hold each test 5 min. Rig down test equipment. Pull FMC test plug. Install FMC wear bushing. Blow down choke and kill lines and manifold and top drive. 'Lay down test joint. I PU/MU BHA #5. PU to Sperry Sun, plug into tools and upload. Clear and clean rig floor. Shallow test Sperry tools, blow down top drive, RIH, MU jars to 425'. ~, Continue RIH w/ BHA #5 to sidetrack well. RIH f/ 425' to 995', rotate 20 ', rpm f/ 995' to 1090', continue RIH to 7842', fill pipe every 20 stands. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date 2/27/2006 2/28/2006 3/1 /2006 From - To ,Hours Code ~' Code I~, Phase ' __ ___ _ 18:15 - 00:00 5.75 ~ DRILL ..TRIP ' INTRM1 00:00 - 01:30 01:30 - 01:45 01:45 - 03:30 '' 03:30 - 04:30 ' 04:30 - 06:00 06:00 - 06:30 ' 06:30 - 07:30 II 07:30 - 09:15 09:15 - 12:00 ', 12:00 - 18:00 18:00 - 00:00 I 00:00 - 06:00 i 06:00 - 12:00 1.50 0.25 1.75 DRILL TRIP ~~i INTRM1 RIGMNT!~ SFTY INTRM1 RIGMNTI~ RSRV ! INTRM1 1.00 ~ RIGMNT RSRV III INTRM1 1.501. DRILL ~ TRIP ~' INTRM1 0.50'' DRILL OTHR I, INTRM1 1.00, DRILL (TRIP IINTRM1 1.751 DRILL I REAM I INTRM1 2.751 DRILL I DRLG I INTRM1 6.001 DRILL I DRLG I INTRM1 6.001 DRILL I DRLG I INTRMI 6.00 DRILL DRLG INTRM1 6.00 DRILL DRLG INTRM1 Page 26 of 53 Spud Date: 1/31!2006 End: 4/2/2006 Group: Description of Operations ~ PU wt 173k, SO wt 118k. Note TAM port collar @ 1010'. Continue RIH w/ BHA #5 to sidetrack well. RIH f/ 7842' to 9646'., fill pipe every 20 stands. Calc displacement @ shoe 84 bbls, actual 56.9 bbls PJSM on cutting drilling line. Slip and cut 102' of 1-3/8"drilling line. Inspect brakes. Inspect derrick. Circ 45 spm w/ 500 psi f/ total of 467 bbls while cutting drilling line. PU i wt 200k, SO wt 125k @ shoe. Service top drive. I Continue RIH w/ BHA #5 (Sidetrack assembly) f/ 9646' to 11835'. Record PU & SO wt's every 5 stands. Fill pipe every 20 stands. ', Fill pipe on stand # 120 (11835'). Circ @ 527 gpm w/ 2250-2300 psi. Rotate 90 rpm w! 16-17k ft Ib torque. PU wt 250k, SO wt 120k, Rot wt ~~ 170k. RIH stand # 121. Blow down top drive. 'Continue RIH w/ BHA #5 (Sidetrack assembly) f/ 11930' to 13265'. I, Record PU & SO wt's every 5 stands. Fill pipe every 20 stands. ',Wash & Ream 9 7/8" hole from 13265' - 13707 (442'). Pumps @ 525 GPMs, 2580 PSI, PU WT = 250K, SO WT = 150K, Torque at 20K @ 90 RPM's. III Trough hole and perform open hole sidetrack at 13707 to 13738' MD. TVD = 5968'. ADT = 1.46 HRS, AST = 1.46 HRS, Total Bit HRS = 1.46, Total JAr HRS = 142.50,. Pumps at 617 GPM with 2680 PSI. PU WT = 270K, SO WT = 140K. Continue Sidetracking 9 7/8" Hole from 13738' - 13768'MD (30'). TVD = !:5979'. ADT = 2.51 HRS, AST = 2.51 HRS, Total Bit HRS = 3.97, Total JAr HRS = 145.01, Pumps at 600 GPM with 2980 PSI. PU WT = 260K, SO WT = 140K. ;.Continue Directional Drill 9 7/8" Hole from 13768' - 14028' MD (260'). TVD = 6083'. ADT = 2.16 HRS, AST = .94 HRS, ART = 1.22 HRS. Total Bit HRS = 8.36, Total Jar HRS = 149.40, WOB = 5 - 18K. Pumps at 610 GPM with 3050 PSI. PU WT = 260K, SO WT = 140K, ROT WT = 190K. 90 RPM's with 16 -17K torque on bottom, and 15K torque off bottom. ECD = 11.32. Max Gas = 510 UNITS. Mud Wt = 10.5 PPG, i Visc = 53, YP 29, Gels @ 12/17/18. %SPR #1 pump - 20 SPM - 410 PSI, 30 SPM - 500 PSI, SPR #2 - 20 !SPM - 410 PSI, 30 SPM - 500 PSI @ 14116' MD, 6111' TVD. Total Fluid loss for tour = 0 BBLS. Continue Directional Drill 9 7/8" Hole from 14028'-14403' MD (375'). i TVD = 6207'. ADT = 4.07 HRS, AST = .83 HRS, ART = 3.24 HRS. 'Total Bit HRS = 12.43, Total Jar HRS = 153.47, WOB = 20-25K. ' Pumps at 620 GPM with 3400 PSI. PU WT = 285K, SO WT = 145K, ROT WT = 188K. 90 RPM's with 16 -17K torque on bottom, and 15K 'torque off bottom. ECD = 11.50. Max Gas = 3000 UNITS. Mud Wt = :10.5 PPG, Visc = 54, YP 29, Gels @ 17/18.SPR #1 pump - 20 SPM - 410 PSI, 30 SPM - 500 PSI, SPR #2 - 20 SPM - 410 PSI, 30 SPM - 500 PSI @ 14116' MD, 6111' TVD. Total Fluid loss for tour = 0 BBLS. -Crew Change Continue Directional Drill 9 7/8" Hole from 14403'-14738' MD (335'). TVD = 6316'. ADT = 2.99 HRS, AST = .50 HRS, ART = 2.49 HRS. Total Bit HRS = 15.42, Total Jar HRS = 156.46, WOB = 20-25K. 'Pumps at 606 GPM with 3350 PSI. PU WT = 290K, SO WT = 150K, ', ROT WT = 200K. 90 RPM's with 16 -17K torque on bottom, and 15K Printed: 4/28/2006 8:4224 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To 'Hours ' Code 'Sub 'Code 3/1/2006 106:00 - 12:00 6.00 DRILL ~I DRLG 12:00 - 18:00 !. 6.001 DRILL I DRLG 18:00 - 00:00 ! 6.00 DRILL ;DRLG 3/2/2006 ~ 00:00 - 06:00 ''~, 6.00 ~I DRILL 'DRLG j III 06:00 - 06:15 j, 0.251~I DRILL I~ DRLG 06:15 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 18:00 2.251 DRILL II CIRC Phase INTRM1 INTRM1 INTRM1 I NTRM 1 I NTRM 1 I NTRM 1 1.00: DRILL I CIRC '~ INTRM1 i 0.50! DRILL II CIRC i INTRM1 2.00 DRILL j WIPR INTRM1 I 6.00' DRILL III WIPR 11 INTRM1 II I i Page 27 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations torque off bottom. ECD = 11.50. Max Gas =3445 UNITS. BGG = 160 units. Mud Wt = 10.5 PPG, Visc = 52, YP 29, Gels @ 17/18. SPR #1 pump - 20 SPM - 410 PSI, 30 SPM - 520 PSI, SPR #2 - 20 SPM - 420 PSI, 30 SPM - 520 PSI @ 14500' MD, 6233' TVD. Pump Hi Visc weighted sweep at 14500', observing no increase in cuttings upon return of sweep. Continue Directional Drill 9 7/8" Hole from 14738'-15068' MD (330'). TVD = 6419'. ADT = 3.83 HRS, AST = .27 HRS, ART = 3.56 HRS. Total Bit HRS = 19.25, Total Jar HRS = 160.29, WOB = 10-15K. Pumps at 610 GPM with 3300 PSI. PU WT = 295K, SO WT = 155K, ROT WT = 200K. 90 RPM's with 17 -19K torque on bottom, and 15K torque off bottom. ECD = 11.59. Max Gas = 2550 UNITS. BGG = 160 units. Mud Wt = 10.5 PPG, Visc = 52, YP 29, Gels @ 17/18. Continue Directional Drill 9 7/8" Hole from 15068'-15397' MD (329'). TVD = 6530'. ADT = 4.15 HRS, AST = .58 HRS, ART = 3.57 HRS. Total Bit HRS = 23.40, Total Jar HRS = 164.44. WOB = 6-15K. Pumps at 620 GPM with 3400 PSI. PU WT = 300K, SO WT = 148K, ROT WT = 192K. 90 RPM's with 17 -19K torque on bottom, and 15K torque off bottom. ECD = 11.54. Max Gas = 1600 UNITS. BGG = 160 units. Mud Wt = 10.5 PPG, Visc = 52, YP 29, Gels @ 17/18. SPR #1 pump - 20 SPM - 430 PSI, 30 SPM - 520 PSI, SPR #2 - 20 SPM - 440 PSI, 30 SPM - 530 PSI @ 15160' MD, 6453' TVD. Continue Directional Drill 9 7/8" Hole from 15397'-15593' MD (196'). TVD = 6587'. ADT = 3.58 HRS, AST = 2.26 HRS, ART = 1.29 HRS. Total Bit HRS = 26.95, Total Jar HRS = 167.99. WOB = 6-15K. Pumps I at 620 GPM with 3440 PSI. PU WT = 305K, SO WT = 148K, ROT WT Ilj = 192K. 90 RPM's with 19-20K torque on bottom, and 17K torque off ~I bottom. ECD = 11.56. Max Gas = 1025 UNITS. Mud Wt = 10.5 PPG, I~ Visc = 51, YP 29, Gels @ 13/11. SPR #1 pump - 20 SPM - 430 PSI, i 30 SPM - 520 PSI, SPR #2 - 20 SPM - 440 PSI, 30 SPM - 530 PSI @ 15160' MD, 6453' TVD. Continue Directional Drill 9 7/8" Hole from 15593'-15600' MD (7'). TVD I= 6590'. ADT = .17 HRS, AST = .17 HRS, ART = 0 HRS. Total Bit HRS I = 27.12, Total Jar HRS = 168.16. WOB = 6-15K. Pumps at 620 GPM with 3440 PSI. PU WT = 305K, SO WT = 148K, ROT WT = 192K. 90 RPM's with 19-20K torque on bottom, and 17K torque off bottom. ECD = 11.56. Max Gas = 1025 UNITS. Mud Wt = 10.5 PPG, Visc = 51, YP ~~, 29, Gels @ 13/11. ~~ Circulate & condition mud, pumping 12.5 ppg Hi Visc Weighted Sweep I~ @ 598 GPM's - 3250 PSI. Reciprocate & rotate Drill string @ 90 RPM's. ~I Observe 15% increase in cuttings upon return of sweep. '~ Rack Back stand # 160, Continue Circulate & condition mud, @ 600 '~ GPM's -3210 PSI. Reciprocate & rotate Drill string @ 90 RPM's. Rack Back stand # 159, Continue Circulate & condition mud, @ 600 ! GPM's - 3210 PSI. Reciprocate 8~ rotate Drill string @ 90 RPM's. Pump out of hole from 15549' - 14407 (1142'). UP WT = 290K, SO WT ! = 130K. Observe pumping through tight spots @ 14407, pulling up to 340K. SO WT =130K. Work drill string through spot to clean up. 'Continue Pump out of hole from 14407 - 11457 (2950'). UP WT = 290K, SO WT = 130K. Observe pumping through tight spots @ 14312',1421T,Tight spot from 13551'- 12885', over pulling from 265K up to 320K. SO WT =130K. Work through tight spots with 573 GPM - 3040 PSI. Crew Change Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 28 of 53 Opera#ions Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date .From - To Hours Code '', Code Phase Description of Operations 3/2/2006 18:00 - 19:45 ! 1.75 DRILL 'WIPR INTRM1 ~~ Continue pump out of hole from 11457 - 10875', and observed hole 119:45 - 22:00 22:00 - 23:30 23:30 - 00:00 3/3/2006 00:00 - 03:30 ~I III 03:30 - 06:00 II, packing off, and pumping fluid away. Rotate & work through spot 2 times to ensure cleaned up. Observed well swabbing when continue .POOH. 2.25 DRILL WIPR !INTRMI ' BROOH from 10875' - 9650' (1225'). Back ream @ 30-40 ft/minute with 1.50 0.50 3.50 2.50 ~~ 1560 GPM - 2400 PSI. 50 RPM's - 10-12K torque. UP WT = 170K, SO it L li WT = 150K. Without pumps UP WT = 230K, SO WT = 135K. Note: ' 'I Shoe @ 9670' MD. ' RIGMNT~ RSRV ; INTRM1 Service & Inspect Top Drive, while circulating bottoms up @ 547 GPM s I - 2180 PSI. PU WT = 210K, SO WT = 125K. DRILL WIPR INTRM1 Monitor well -static. Blow down Top Drive & Lines. DRILL WIPR INTRMI Trip in hole from 9650' -15600' (5950'). TVD = 6590'. Obtain Torque & Drag Measurements every 5 stands, filling drill string every 20 stands. ' Observed hole looked clean with issues on trip to bottom. UP WT = II 315K, SO WT = 135K. DRILL ~ DRLG INTRM1 ~ Continue Directional Drill 9 7/8" Hole from 15600'-15700' MD (100'). i ', TVD = 6610'. ADT = 1.69 HRS, AST = 1.30 HRS, ART = .39 HRS. ' ~ Totat Bit HRS = 28.81, Total Jar HRS = 169.85. WOB = 8-15K. Pumps ' , at 617 GPM with 3650 PSI. PU WT = 310K, SO WT = 150K, ROT WT ', ', = 192K. 90 RPM's with 21-23K torque on bottom, and 18K torque off ', 'bottom. ECD = 11.52. Max Gas = 1540 UNITS. BGG = 160 units. Mud ~ Wt = 10.5 PPG, Visc = 53, YP 29, Gels @ 21/27. Crew Change DRILL Al CIRC '~ INTRM1 Pump a 11.5 ppg Hi Visc Weighted sweep @ 600 GPM - 3450 PSI, 90 ~ i ' RPM's. 06:00 - 06:15 0.25 '~, 06:15 - 09:45 ', li 09:45 - 12:00 I 12:00 - 16:15 li 16:15 - 18:00 18:00 - 19:00 ', 19:00 - 19:30 ~I~ 19:30 - 23:30 i~ 23:30 - 00:00 ICI 3/4/2006 3.50' DRILL TRIP INTRM1 Continue to pump sweep while POOH slow, racking back 1 stand per ' hour. 2.25'', DRILL I, TRIP INTRM1 I Continue pump out of hole from 15525' - 14008' (151 T), @ 570 GPM's 4.25 1.75 1.00 0.50 4.00 0.50 - 2950 PSI. Observe hole clean with no overpull issues. UP WT = 290K, SO WT = 140K. DRILL ,TRIP INTRM1 Continue pump out of hole from 14008' - 13075' (933'), @ 570 GPM's - ~ 2780 PSI. Observe hole clean with no overpull issues. UP WT = 270K, i DRILL (TRIP INTRM1 I, POOH on elevators from 13075' - 9650' (3425'). Observe no issues of ' I overpulling and hole looked good and clean, with proper hole fill. DRILL '.CIRC I INTRMI CBU at the shoe with 600 GPM's - 2700 PSI. 25 RPM's. DRILL TRIP ' INTRM1 !Monitor well -static. Blow down Top Drive and lines. DRILL 'TRIP 'INTRMI , Continue POOH on elevators from 9650' - 424' (9226'). Observe proper ',hole fill on TOH. DRILL I PULD ',INTRMI PJSM with crew. Discuss Safety issues and procedure for laying down i ', I BHA. Breakout & lay down BHA. Lay down 6 1!4" Accelerator (35.60'), ' ii 3 Jnts of 5" HWDP (92 6 1/4" Hydraulic Jar with Bumpers (30 60') 35') , , . . , and 3 Jnts of 5" HWDP (91.78'). 00:00 - 01:00 1.00', DRILL ' PULD i INTRM1 Continue Breakout & Lay down BHA #5. Lay down 3 - 6 3/4" Non Mag 01:00 - 01:45 01:45 - 02:30 ', 02:30 - 03:00 ~I~i 0.50 DRILL OTHR INTRM1 .Clean & clear Rig Floor Area, send tools out. 03:00 - 03:45 ~I 0.75 WELCTL! OTHR ! INTRM1 'Drain stack, install 10' pup on 7 5/8" test joint. BOLDS & pull wear 'bushing. i I Flex Drill Collars (93.22'). POOH, break out, inspect & gauge bit to 1 / ~ 1/ER/N/X/I/NOlTD 0.75!.. DRILL I PULD INTRM1 Plug in and download MWD assembly. 0.75', DRILL PULD INTRM1 Continue breakout & lay down 6 3/4" TM-HOC (9.99'), 6 3/4" DGR/EWR/PWD/HCIM (27.58'), 6 3/4" Directional (9.03'), 6 3/4" ', I j Integral Blade Stabilizer (5.61'), 6 3/4" Non MAg Fioat Sub (2.49'), and 17" Sperry Drill Lobe 7/8 - 6.0 stg (25.39'). Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 29 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To ,Hours ,Code 'Code Phase Description of Operations OTHR _. _ _ _ _ _ --- 3/4/2006 03:45 - 05:00 1.25 WELCTLI' I INTRM1 I! PJSM with crew. Discuss safety issues and procedure for changing & installing 7 5/8" rams. 05:00 - 06:00 1.00 WELCTL BOPE INTRM1 'Install test plug, fill stack with water. Test 7 5/8" rams to 250 PSI low, ii 06:00 - 06:30 I, 0.50 WELCTL 06:30 - 09:30 'I I 3.00 CASE ' ~I 09:30 - 10:30 1.00 i I CASE 10:30 - 12:00 I 1.501, CASE I 1,12:00 - 17:15 I I, 5.25'', CASE 17:15 - 18:00 I 0.75 ~~ CASE 18:00 - 23:30 ! 5.50 CASE 23:30 - 00:00 ' 0.50 CASE 3/5/2006 i 00:00 - 00:45 0.75 CASE I! 00:45 - 02:30 1.75 I'; CASE '! 02:30 - 04:45 I 04:45 - 05:15 I, 05:15 - 06:00 ' 06:00 - 12:00 !, i 2.25! CASE 0.50' CASE 0.75 6.00 12:00 - 13:15 I 1.25 13:15 - 18:00 ', 4.75 BOPE RURD SFTY RUNC RUNC ',CIRC (RUNC ~I I ~~i CIRC i CIRC CIRC I iRUNC I~ CIRC CASE RUNC CASE LRUNC CASE RUNC CASE ~~ CIRC !:3500 PSI high. Record on chart. Crew Change INTRMI Bleed all pressures. Pull & lay down test plug, test joint. INTRM1 'PJSM with Crew. Discuss Safety Issues and procedure for running 7 ', 5!8" casing. Rig down short bales on Top drive, MU Franks Fill up tool. ', Rig up to run casing. INTRM1 I PJSM with Crew. Discuss Safety Issues and procedure for running 7 5/8" casing. INTRMI Make up 7 5/8" casing shoe joint, 3 joints, and float collar. Made up with Baker lock. AVG make up torque = 8500 ft/Ibs. Install Tandem rise centralizers as per plan on collar of joints 1 -21. Obtain up & down weights as per Rig Engineer, filling each joint as ran. 20 joints in hole. INTRMI I Continue run 7 5/8" casing from joint # 20 -joint # 120. Obtain up & down weights every 10 joints as per Rig Engineer, filling each joint as 'ran. Circulate bottoms up on joint # 120 = 5150'. AVG make up torque = '! 8000 ft/Ibs. INTRM1 j Continue CBU at 5150' @ 4 BBLs /Min - 270 PSI. UP WT = 161 K, SO WT = 129K. Crew Change. INTRM1 !,Continue run 225 jnts 7 5/8" casing from 5150' - 9650' (4500'). Running 'speed @ +/- 60' /min. UP WT = 235K, SO WT = 132K. AVG make up 'torque = 8000 fUlbs. INTRM1 ',Circulate bottoms up staging pumps from 1 BPM - 7 BPM - 780 PSI. !Observe no fluid loss. Mud Wt in 10.5 PPG /out 10.6 PPG. I~ Reciprocate casing string 30' while circulating. INTRMI i Continue Circulate bottoms up staging pumps from 1 BPM - 7 BPM - 780 PSI. Observe no fluid loss. Mud Wt in 10.6 PPG /out 10.6 PPG. Reciprocate casing string 30' while circulating. INTRM1 Continue circulate pumping 1% Metal Lube pill in 280 BBLS of mud, spotting Metal Lube on annulus by chasing with 443 BBIs casing volume. Pumps at 7 BPM - 780 PSI. Observe no losses. Obtain new up '~I & down weights of 235K UP WT, and 135K DN WT. No significant ~i difference in parameters observed. INTRM1 '~I Continue run 7 5/8" casing into open hole from 9650' - 11570'. Joint # !i 270. UP WT = 290K, SO WT = 140K. INTRMI ,Circulate 75 BBLS, moving mud & breaking Gels @ 3 BPM - 500 PSI, 14 BPM - 580 PSI, 5 BPM- 700 PSI. Pump 1000 Stks. INTRMI !Continue run 7 5/8" casing into open hole from 11570' - 12439'. Joint # 1290. UP WT = 300K, SO WT = 145K. Crew Change. INTRMI ',Continue run 7 5/8" casing into open hole from 12439' - 15652'. Joint # ', 365. UP WT = 300K, SO WT = 145K. Observe good hole conditions, and no issues getting casing to bottom. INTRMI ~I PJSM with crew. Discuss Safety Issues and procedure for making up landing joint & circulating. Designate a Spill Champion. Make up ~ landing joint. Rig up Cement head. Plugs installed as per Dowell Rep. INTRMI Circulate & condition mud while reciprocate casing string. UP WT = 410K, SO WT = 145K. Stage pumps up from 2 BPM - 530 PSI to 6 BPM - 780 PSI. Circulate entire hole volume 1320 BBLS at 60 SPM - 670 PSI. Pre job Up WT = 370K, SO WT = 145K. Pre cementing mud condition = 10.5 PPG, 48 VISC, 21 YP, and 12 PV. Tops of Float Shoe ~, @ 15692.51 ", Float Collar @ 15562.09'. Printed: 4/28!2006 6:42:24 AM ConocoPhillips Alaska. Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours I 3/5/2006 18:00 - 18:15 ', 0.25 ill ,18:15-19:00 ~ 0.75 19:00 - 21:15 1,21:15-22:45 22:45 - 23:30 ' 23:30 - 00:00 3/6!2006 !, 00:00 - 01:00 01:00 - 02:00 02:00 - 06:00 06:00 - 12:00 12:00 - 17:45 17:45 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 22:30 ', 22:30 - 00:00 ii 3/7/2006 , 00:00 - 03:00 !i 03:00 - 06:00 i 06:00 - 08:00 '; 2.25 Code 'Sub Code CEMENI}SFTY CEMEN PUMP CEMENTPUMP I ~I 1.50; CEMENTRURD 0.75 CEMENTRURD 0.50 CASE NUND 1.00 CASE NUND 1.00 CASE i~ SFTY 4.00 i CASE ' OTHR 6.00!CASE 'OTHR 5.75 0.25 1.00 3.00 0.50 ~~ 1.50 3.00 3.00 I 2.00', CASE RIGMNT RIGMNT CASE OTHR Phase INTRM1 I NTRM 1 INTRM1 INTRMI ~~ INTRM1 I NTRM 1 INTRM1 ~~ INTRM1 INTRM1 INTRM1 INTRM1 RSRV ! INTRM1 RSRV ''INTRMI OTHR (INTRMI RIGMNT' RGRP INTRM1 CASE ~IOTHR INTRM1 WELCTLI, OTHR ', INTRM1 i WELCTLI( OTHR ', INTRM1 i WELCTL BOPE INTRMI Page 30 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations PJSM with entire crew & Dowell crew. Discuss Safety issues and procedure for cement job, while circulate & condition mud. Crew Change. Shut down Rig pumps. Turn over to Dowell. Pump 10 BBLS of 8.3 PPG ', CW-100 @ 5 BPM - 535 PSI. Pressure test lines to 3500 PSI. Good test. Pump 30 BBLS of 8.3 PPG CW-100 @ 5 BPM - 600 PSI. Continune pump 40 BBLS of 12.5 PPG MudPUSH @ 5.9 BPM-700 i PSI. Shut down pumps, drop bottom plug in head. Continue mix & pump 65.09 BBLS of 15.8 PPG SILO - 1960 Tail cement at 6 BPM - 345 PSI. Shut down Pumps. Drop Top plug from head. Pump 10 BBLS of 8.3 PPG water @ 5 BPM - 188 PSI. Reciprocate casing string. UP WT = 380K, SO WT = 145K. Shut down Dowell pumps. Total Mud volume increase in pits = 155 BBLS. Turn over to rig pumps. Pump # 2, Displace cemnet with 10.5 PPG mud @ 6.5 BPM - 475 PSI Ito 6700 Strokes, observing no issues while CW-100, MudPush & cement going around shoe, reciprocating casing string. Slow pump to 3 ' BPM - 475 PSI to observe bumping plug at 6965 Strokes = 703.46 i Barrels. Continue pressure up to 1000 PSI. Hold 5 minutes. Bleed ~~ pressures. Check floats. Floats held - no bleed off. Cement in place @ ~ 2100 HRS. Rig down, blow down all lines, cement head and all casing equipment. Send tools out. RD Dowell cementers. Change out Bales on Top Drive. Pick up 5" Drill Pipe elevators. Pick up 1 stand of 5" Drill pipe. 'Make up FMC 7 5/8" casing packoff & running tool. Drain & Flush stack. RIH with Packoff to set as per FMC rep. RKB to LDS = 38.70'. !Continue install 7 5/8" Packoff. RILDS. Rig up & test packoff to 5000 ,PSI. POOH lay down running tool and landing joint. PJSM with crew. Discuss Safety Issues and procedure for laying down 5" Drill pipe from Derrick using mousehole. '~ Lay down 37 stands of 5" drill pipe from derrick. Crew Change. PJSM with crew. Discuss Safety Issues and procedure for laying down 5" Drill pipe from Derrick using mousehole. Continue lay down 38 stands of 5" Drill pipe. Marking bad joints for inspection as noted by rig 'I crew. 'Continue lay down 44 stands of 5" Drill pipe. Marking bad joints for !~ inspection as noted by rig crew, watching hard banding, & tool faces. '.Service Top Drive, Rig, & Draw works. Crew Change. Continnue Service Top Drive, Rig, & Draw works. PJSM with crew. Discuss Safety Issues and procedure for laying down 5" Drill pipe from Derrick using mousehole. Continue lay down 69 joints of 5" Drill pipe. Marking bad joints for inspection as noted by rig crew, ~~ watching hard banding, & tool faces. Change out dies in heads on Iron Roughneck. Observed old dies cutting into tool joint. I~ Continue to lay down 63 joints of 5" drill pipe from derrick. ', Pull & lay down Mouse hole. Install test plug. Change out & install 3 ', 1/2" x 6" VAriable bore rams in top set, and install 4" solid body rams in '..lower set. SIMOPS: Clean all mud pits, unload & load pipe shed. Change out saver sub on Top Drive from 4 1/2" IF, to 4" XT-39. Pull all Floor valves & dart valves to rig floor area, RU to test BOP's. Crew ',Change Make up crossover & install test joint. Continue Rig up to test BOP's. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 31 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To Hours Code Sub Phase Description of Operations 3/7/2006 06:00 - 08:00 ~~ 08:00 - 08:15 08:15 - 12:00 12:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 23:00 Code 2.00 WELCTy BOPE !. INTRM1 - __ Fill all lines and stack with water. 0.25 WELCT SFTY ' INTRM1 ~ PJSM with crew. Discuss salty issues and procedure to test BOP's. 3.751 WELCTL BOPE INTRM1 Test BOPE, witness of test waived by AOGCC inspector John ~ ~~ Spaulding. Test annular to 250 psi low and 3500 psi high w/ 4" dp. I HCR choke valve, choke manifold valves 16,17, 18, and 5" dart valve. I INTRM1 4.00 li WELCTL BOPE Continue Test BOPE, Continue testing 13 5/8" 5m BOPE. Test 250 psi i low and 3500 psi high all components except hydril, high test on hydril ' '; 3500 psi. Test choke manifold valves 12,13,14,15, and Floor valve. ', Test choke manifold valves 5,6,10, & 11 w/ dart valve. Test choke ' , manifold valves 1,4,7 & 4" Floor valve. Test choke valves 2,3,8, & 9. ' Test HT-38 & XT-39 Floor & Dart Valves. Observed 1 failure. HT 38 ', Floor valve failed and was taken out of service. Test upper & lower ' IBOP on Top Drive. Record all tests on chart. 2.00 WELCTL' BOPE ' INTRM1 , Rig Down all test equipment. Breakout all XT-39 & HT-38 valves. Blow 1.00' DRILL I PULD 1.50' DRILL I PULD 2.50 I DRILL I PULD 23:00 - 00:00: 1.00 3/8/2006 00:00 - 01:00 I 1.00 ICI 01:00 - 01:45 ' 0.75 101:45 - 02:30 ' I I 0.75 ~~ 02:30 - 06:00 II 3.50 06:00 - 06:30 ~I 0.50 06:30 - 07:00 I 0.50 '..07:00 - 09:30 ~'~ 2.50 09:30 - 10:00 ~ 0.50 ,10:00 - 10:30 i 0.50 DRILL OTHR DRILL OTHR DRILL OTHR DRILL PULD DRILL TRIP DRILL TRIP DRILL ', PULD I DRILL ~ITRIP DRILL (TRIP RIGMNT', RURD '~ down all lines. Pull & lay down test plug. Crew Change INTRM1 i Make up wear bushing on landing joint. RIH & set wear bushing, RILDS. ID of wear bushing = 7 1/16". Lay down landing joint. Load pipe ;shed with 4" Drill pipe. INTRM1 ,Pick up all 4" Drill pipe handling tools, crossovers and lift subs. Change out elevators. Lay down all 5" Drill pipe equipment. Contrinue load pipe j shed with 4" Drill pipe. SIMOPS: -Load Mud pits with 580 BBLs of 9.6 'PPG Flo-Pro. INTRMI j PJSM with crew & Sperry Hands. Discuss Safety Issues and procedure for Picking up BHA including Nuclear Sources. Make up BHA #6. Make up 6 3/4" Security FSF2641 bit with 3 x 16's for a TFA of .589 sq in. ' (1.25'), 4 3/4" 5200 series Geo-Pilot TL017 (16.18'), 4 3/4" Non-Mag ;Geo Pilot Flex Collar (11.54'), 4 3/4" Smart Stabilizer (3.59'), MWD 'Gamma/Res (33.07), 4 3/4" Nuke Tool (36.31'), MWD TM HOC (10.43'), 4 830" Integral Balade Stabilizer (5.24'), and 4 5/8" Non Mag Float Sub (1.45'). INTRM1 'Plug in and up load MWD assembly. Rig up Geo Span unit on rig floor. INTRMI ;Continue perform Shallow pulse test on MWD assembly. Pump @ 220 'GPM - 850 PSI. Make up 2 - 4 1/4" Non Mag flex drill collars (61.62') :and 5" crossover (2.99'). INTRM1 :Held PJSM with crew. Discuss safety issues involving loading Nuclear !sources in MWD assembly. Rig up, clear floor and install nuclear i sources as per Spery Sun MWD reps. INTRMI Continue make up BHA #6. Make up 1 -joint of 4" HWDP (30.68'), 5" Dailey DNT drilling jar (32.08'), 2 -joints of 4" HWDP (61.36'), and crossover sub (1.84'). INTRM1 '...Single in hole making up 4" HT -38 Drill pipe from 277-3430' (3154'). 99 ',joints total picked up. Crew Change. INTRM1 Fill drill string with 10.5 PPG mud, pump to test Geo-Span unit. Send ',downlink. Good test. PJSM with crew. Discuss safety issues and !, procedure for picking up 4" drill pipe from pipe shed. INTRMI ~ Continue make up remaining BHA. Make up second set of 5" Dailey ; DNT drilling jars (31.92'), 6 -joints of 4" HT-38 DP (189.27), and 4 3/4" ',Accelerator (31.62'). Total BHA #6 = 3683.17. INTRM1 'Continue single in hole making up 4" HT -38 Drill pipe from 3683'-5607 (1924'). 61 joints picked up. Total joints in hole 160 joints. INTRM1 !, Fill drill string with 10.5 PPG mud. Blow down Top Drive. INTRM1 ~, Stop Picking up drill pipe. Rig down scaffolding under pipe skate as per 'i scaffolding crew for welder on rig. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 D-41 1 D-41 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Date .From - To ' Hours Code ' Code I Phase 3/8/2006 10:30 - 12:00 1.50 12:00 - 13:45 1.75 13:45 - 14:00 II 0.25 I 14:00 - 14:15 I' 0.25 14:15 - 15:45 ' 1.50 15:45 - 17:00 ~~, 1.25 17:00 - 17:30 0.50 17:30 - 18:00 0.50 18:00 - 21:45 ; 3.75 21:45 - 22:15 0.50 22:15 - 00:00 ~I 1.75 DRILL TRIP INTRM1 DRILL TRIP INTRM1 DRILL TRIP i INTRMI RIGMNT SFTY i INTRMI RIGMNT RSRV i' INTRM1 DRILL TRIP INTRM1 DRILL TRIP INTRMI DRILL ITRIP I INTRMI DRILL i,TRIP INTRM1 DRILL 'i CIRC I INTRM1 I DRILL TRIP IINTRMI 3/9/2006 100:00 - 03:30 3.50' i DRILL 'TRIP 'I INTRM1 I 03:30 04:30 1.OO DRILL 'I TRIP INTRM1 04:30 - 04:45 ' 0.25 DRILL '! , OTHR INTRM1 04:45 - 06:00 '' 1.25 DRILL ',TRIP ii INTRM1 06:00 - 09:30 3.50;DRILL ITRIP 'INTRM1 09:30 - 10:30 1.00 10:30 - 12:00 ', 1.50 DRILL ITRIP DRILL ITRIP INTRM1 INTRM1 Page 32 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations II Continue single in hole making up 4" HT -38 Drill pipe from 5607-7341' (1734'). 55 joints picked up. Total joints in hole 215 joints. Continue single in hole making up 4" HT -38 Drill pipe from 7341'-8224' (883'). 28 joints picked up. Total joints in hole 243 joints of HT-38. Install Weathertord Crossover(2.60'), and make up 1 joint of XT-39 Drill pipe. Make up Top Drive. PJSM with crew. Discuss safety issues and procedure for Slipping & 'Cutting Drilling Line. ',Hang off blocks. Slip & Cut drilling line. Inspect & service Top Drive. Inspect brakes ~ linkage on drawworks. Continue single in hole making up 4" XT -39 Drill pipe from 8258' - 9379 (1121'). 37 joints picked up. Total joints in hole 243 joints of HT-38, & 37 Joints of XT-39. (286 Total). Fill drill string with 10.5 PPG mud. Blow down Top Drive. Continue single in hole making up 4" XT -39 Drill pipe from ':9379'-10033' (654'). 21 joints picked up. Total joints in hole 243 joints of ', HT-38, & 58 Joints of XT-39. (307 Total). Crew Change l PJSM with Crew. Discuss safety issues and procedure for picking up 4" Drill pipe from shed. Discuss procedure for making up new 4" XT-39 DP. Continue single in hole making up 4" XT -39 Drill pipe from 10033'-13173' (3140'). 101 joints picked up. Total joints in hole 243 joints of HT-38, & 159 Joints of XT-39. (408 Total). i Fill Drill string with 10.5 PPG mud, and circulate drill pipe volume to ~ ensure no junk or debris on top of MWD assembly. Check Geo-span ',unit. Good test. Pumps @ 255 GPM - 2870 PSI. UP WT = 230K, SO ~! WT = 100 K. Pumped a total of 155 BBLS. ~, Continue single in hole making up NEW 4" XT -39 Drill pipe from ';13173'-13739' (566'). 18 joints picked up. Total joints in hole 243 joints of HT-38, & 76 Joints of XT-39. (426 Total). NOTE: Recommended ~i make up procedure for NEW drill pipe- Make up to torque, Breakout & clean pin end, re-dope, Make up to torque, Breakout, clean pin end. Re-dope, and make up to full torque. Avg 12-15 joints per hour. Continue single in hole making up NEW 4" XT -39 Drill pipe from 13739' - 15058' (1319'). 42 joints picked up. Total joints in hole 243 I joints of HT-38, & 225 Joints of XT-39. (510 jts Total). NOTE: , Recommended make up procedure for NEW drill pipe- Make up to torque, Breakout & clean pin end, re-dope, Make up to torque, !.Breakout, clean pin end. Re-dope, and make up to full torque. Avg ',12-15 joints per hour. P/U=255k, S/0=105k POOH from 15059' to 13137' and stand back in derrick Pull stripping rubber. Clear and clean rig floor Single in hole making up new 4" XT-39 drillpipe from 13127' to 13550'. (Making, breaking ,cleaning/inspecting, making, breaking, cleaning/inspecting and making each connection) Have a total of 480 jts of 4" picked up. P/U=280k, SlO=105k. Crew Change i Single in hole making up new 4" XT-39 drillpipe from 13550' to 15025'. (Making, breaking ,cleaning/inspecting, making, breaking, 'cleaning/inspecting and making each connection) Have a total of 528 Ijts of 4" picked up. POOH from 15025' to 13173' P/U=300k, S/0=105k ~ Single in hole making up new 4" XT-39 drillpipe from 13173' to 15025'. (Making, breaking ,cleaning/inspecting, making, breaking, cleaning/inspecting and making each connection) Have a total of 550 Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date 3/9/2006 From - To Hours ', Code 10:30 - 12:00: 1.50 ,DRILL 12:00 - 15:15 3.25 i DRILL I '.15:15 - 15:30 1 0.25 ',15:30 - 18:00 1 2:50 18:00 - 19:30 ' 1.50 19:30 - 20:00 I, 0.50 ', 20:00 - 21:15 1.25 21:15 - 23:00 '~ 1.75 ', 23:00 - 00:00 3/10/2006 00:00 - 03:00 I~1, 03:00 - 05:00 ', 05:00 - 05:15 '~ 05;15 - 05:45 i 05:45 - 06:00 ', 06:00 - 07:30 1, 07:30 - 07:45 07:45 - 09:30 ~i I~ 09:30 - 10:00 1,10:00-12:00 1.00 3.00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL Sub Code TRIP TRIP ~I 'TRIP IITRIP CIRC ',OTHR IDEOT CIRC DRLG DRLG 2.00 FRMTST, CIRC 0.251!, FRMTST PULD 0.50'' FRMTST~OTHR 0.25 ~I FRMTST PULD 1.501 DRILL 'CIRC 0.25 i DRILL CIRC 1.75; DRILL CIRC 0.50 ~ DRILL OTHR 2.001 DRILL ,DRLG Page 33 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Phase Description of Operations INTRM1 jjts of 4" picked up. INTRMI I Continue Single in hole making up new 4" XT-39 drillpipe from 13173' . Joints 550 -588 Making, breaking ,cleaning/inspecting, making, ',breaking, cleaning/inspecting and making each connection) Have a '~ total of 588 jts of 4" picked up. INTRM1 ~ POOH, stand back 2 stands of 4" XT -39 DP. INTRM1 Continue Single in hole making up new 4" XT-39 drillpipe from 13173' . Joints 588 - 609 Making, breaking ,cleaning/inspecting, making, ~ breaking, cleaning/inspecting and making each connection) Have a total of 609 jts of 4" picked up including stands in Derrick. Note: All DP drifted with 2 3/8" drift. UP WT = 300K, SO WT = 105K. Crew Change INTRMI i Circulate bottoms up @ 15510'. Pumps at 260 GPM's - 3090 PSI. Rotate at 40 RPM's with 11 K Free Torque. Pump a total of 436 BBLS. INTRM1 Blow down Top Drive and lines. Rig up to test casing. Fill all lines with mud. INTRM1 Test casing to 3500 PSI, for 30 Minutes. Record on chart. Test good. Bleed all pressures and rig down test equipment. Blow down all lines. INTRMI ',Slack off drill strring to tag up on Float collar @ 15561' MD. Pumps at 270 GPM - 2880 PSI. 80 RPM's with 18-19K Torque off bottom. ',Observed high torque with 10.3 PPG LSND mud at 3% tube. Circulate & reciprocate drill string while adding 2% additional tube to aid in drilling 'float equipment & cement. Observe torque reduction to 14K free torque with 60 RPM"s. INTRM1 Drill out float equipment with 60 RPM's, 15-16K torque, 225 GPM's - 2550 PSI. Continue drill cement to 15615, observing firm cement, for an avg ROP of 75 fUhr. INTRM1 ~i Continue drill Firm cement, and float shoe, then 20' of new hole from 15596' - 15720' (124'). Observe hard stringer from 15706' - 15707, and hard formation to 1571 T. Softer formation @ 1571 T - 15720'. Observe no fluid loss issues. TVD 6615'. ADT = 1.04 HRS, ROT Hrs = 1.04. Jars '~ & acceleartor Hrs = 1.04. UP WT = 285K, SO WT = 105K, ROT WT= 152K, 60 RPM's - 17-18K torque. WOB = 5-8K. Pumps at 260 GPM's - 12920 PSI. INTRM1 ~ Pull back to 15690' standing 1 stand back. Circulate bottoms up @ 260 GPM's - 2920 PSI. Reciprocate & rotate drill string, condition mud for '~ FIT test. Mud wt = 10.3 PPG in /out. Visc = 61, YP =23, Gels @ 18/51 INTRMI Rig up test equipment & chart recorder. INTRMI I Perform FIT test to 12.5 PPG MWE. Pump 17 strokes to 764 PSI, shut ~, in and hold 10 minutes observing no bleed off. 15695' MD, 6610 TVD at shoe. INTRM1 Rig down all test equipment. Blow down all lines. Crew Change PROD ~ Make up 1 stand, RIH. Circulate low visc LSND mud @ 80 GPM's-810 li PSI. Hold PJSM with crew & truck drivers. Discuss Safety issues and ~ procedure for displacing well with 9.6 ppg Flo-Pro mud. Designate a ,'spill champion. PROD i Pump 40 BBLS Duo -Visc spacer pill @ 80 GPM - 810 PSI. PROD !,Displace well with 9.6 ppg, 55 visc, Flo-pro mud @ 280 GPM -3185 PSI. 67 SPM. Reciprocate & rotate drill string @ 90 RPM's & 14K 'torque. UP WT = 250K, SO WT = 135K. PROD ~ Shut down pumps. Clean surface equipment for 9.6 PPG Flo-Pro mud. PROD Directional Drill 6 3/4" Hole from 15720'-15872' MD (152'). TVD = 6641'. ,ADT = 1.47 HRS, AST = 0 HRS, ART = 1.47 HRS. Total Bit HRS = Printed: 4/28/2006 6:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To !Hours ' Code Code Phase 3/10/2006 j 10:00 - 12:00 'i 2.00 DRILL DRLG PROD I 12:00 - 16:30 4.50 i DRILL ,DRLG I, PROD I i ', I 16:30 - 17:30 I 1.00', DRILL 117:30 - 18:00 0.50', DRILL 1,18:00 - 20:00 2.00 ICI DRILL 20:00 - 20:15 ', 0.25 20:15 - 00:00 ' 3.75 I 3/11/2006 .00:00 - 01:00 I 1.00 01:00 - 01:15 01:15 - 01:30 01:30 - 06:00 06:00 - 12:00 12:00 - 18:00 18:00 - 18:45 0.25 0.25 4.50 CIRC I, PROD WIPR ,PROD CIRC ~I PROD DRILL I CIRC PROD DRILL 'ICIRC ;PROD DRILL 'CIRC I !-PROD DRILL OBSV I PROD DRILL WIPR PROD DRILL I CIRC PROD 6.00' DRILL ;.,, CIRC ;PROD 6.00' , DRILL i CIRC ~ PROD 0.75 1 DRILL i ( TRIP (PROD 18:45 - 19:45 1.00 DRILL ~ OTHR PROD 19:45 - 23:00 I 3.25 !DRILL I DRLG I PROD Page 34 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations 2.51, Total Jar HRS = 2.51. WOB = 15-20K. Pumps at 280 GPM with ~i 2850 PSI. PU WT = 220K, SO WT = 125K, ROT WT = 160K. 120 RPM's with 11-12K torque on bottom, and 10K torque off bottom. ECD = 11.90. Max Gas = 4975 UNITS. Mud Wt = 9.6 PPG, Visc = 51, YP 22, Gels @ 8/9. Directional Drill 6 3/4" Hole from 15872'-15999' MD (152'). TVD = 6640'. INC = 90.7 Deg. AZ = 111 DEG. ADT = 3.26 HRS, AST = 0 HRS, ART = 3.26 HRS. Total Bit HRS = 5.77, Total Jar HRS = 5.77. WOB = 15-20K. Pumps at 255 GPM with 2450 PSI. PU WT = 250K, SO WT = 130K, ROT WT = 163K. 120 RPM's with 9-12K torque on bottom, and j 9K torque off bottom. ECD = 11.20. Max Gas = 4972 UNITS. Mud Wt = I, 9.6 PPG, Visc = 51, YP 22, Gels @ 8/9. Slow pump rates @ #1 -20 SPM -890 PSI, 30 SPM - 1180 PSI. #2 Pump - 20 SPM -840 PSI, 30 SPM - 1100 PSI. Observe well flowing with pumps off. Circulate to increase mud weight to 9.8 PPG. ,Pump out of hole to 15906' @ 280 GPM- 3200 PSI, 80 RPM's while I continue to increase mud weight to 9.8 PPG. Crew Change. 'Continue Rotate & Reciprocate drill string while increasing mud weight ', to 9.8 PPG. Pumps at 270 GPM=2960 PSI. 80 RPM's with 9K torque. ', UP WT = 250K, SO WT = 120K, ROT WT = 160K. 9.8 PPG mud all the away around. Monitor well. Observe light flow back with pumps off. Continue Rotate 8 Reciprocate drill string while increasing mud weight to 10.0 PPG. Pumps at 270 GPM=2880 PSI. 80 RPM's with 9K torque. UP WT = 250K, SO WT = 120K, ROT WT = 160K. Continue Rotate & Reciprocate drill string while increasing mud weight Ito 10.0 PPG. Pumps at 270 GPM=2880 PSI. 80 RPM's with 9K torque. li UP WT = 250K, SO WT = 120K, ROT WT = 160K. Monitor well -static. :Pump out of hole 5 stands to bring bit back into the shoe. Pumping at 200 GPM - 1550 PSI. 220K UP WT. Continue Rotate & Reciprocate drill string while maintaining mud weight ~', to 10.0 PPG. Pumps at 260 GPM=2750 PSI. 80 RPM's with 7-8K torque. UP WT = 250K, SO WT = 120K, ROT WT = 160K. Waiting on orders from town. Continue Rotate & Reciprocate drill string while maintaining mud weight to 10.0 PPG. Pumps at 260 GPM=2750 PSI. 80 RPM's with 7-8K ~ torque. UP WT = 250K, SO WT = 120K, ROT WT = 160K. Waiting on ~! orders from town. ;Continue Rotate & Reciprocate drill string while maintaining mud weight Ito 10.0 PPG. Pumps at 260 GPM=2750 PSI. 80 RPM's with 7-8K ~, torque. UP WT = 250K, SO WT = 120K, ROT WT = 160K. Waiting on 'i orders from town. I Held Safety Meeting in Shop with both crews and all Doyon, CPAI safety personnel. Discussed Safety issues and policies, and expectations. Blow down Top Drive, TIH with 4" DP from 15620' - 15906', (286'). UP I, WT = 255K, SO WT = 125K. !,Obtain check shot surveys for MWD @ depths of 15910', 15915', ',15920', 15930', @ 250 GPM - 2620 PSI. Continue to wash & ream to 'bottom at 15999' MD, 6640' TVD. !.Directional Drill 6 3/4" Hole from 15999'-16118' MD (119'). TVD = 6640'. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date 3/11/2006 From - To 'Hours ' Code ' Sub 'Code 19:45 - 23:00 ~ 3.25 i DRILL ~ DRLG 23:00 - 23:15 0.25 li 23:15 - 00:00 0.75 I 3/12/2006 00:00 - 00:15 ~ 0.25 DRILL DRILL DRILL 00:15 - 01:00 ~ 0.75! DRILL 01:00 - 01:30 0.50', DRILL 01:30 - 03:45 I ', 03:45 - 04:00 I, III 04:00 - 06:00 i i ~, 06:00 - 07:15 I 07:15 - 08:00 i ~, 08:00 - 11:30 ' 11:30 - 11:45 111:45 - 12:00 1,12:00-18:00 '18:00-19:00 ~ 2.25 i DRILL 0.251 DRILL 2.00' DRILL 1.25 DRILL i 0.75', DRILL 3.50', DRILL Phase PROD OTHR'PROD WIPR i PROD ',CIRC 'i PROD WIPR !PROD 'OBSV PROD CIRC PROD LOBSV !PROD CIRC I PROD CIRC PROD !IOBSV I,PROD ',CIRC I PROD 0.25' DRILL ' OBSV 0.25 DRILL CIRC 6.00 DRILL ,TRIP PROD PROD PROD 1.00' DRILL 'TRIP PROD Page 35 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations ADT = 2.59 HRS, AST = 0 HRS, ART = 2.59 HRS. Total Bit HRS = 8.36, Total Jar HRS = 8.36. WOB = 15-18K. Pumps at 250 GPM with 2680 PSI on bottom. 2580 PSI off bottom. PU WT = 255K, SO WT = 130K, ROT WT = 160K. 60 RPM's with 12-13K torque on bottom, and ~;10K torque off bottom. ECD = 11.39. Max Gas = 4990 Units. BGG = 1.477 Units. Mud Wt = 10.0 PPG, Visc = 46, YP 24, Gels @ 12/15. Observe fluid losses while drilling of +/- 60 BBLS /HR. Mix & pump 40 PPB LCm pill and spot on bottom. Observe fluid losses drop to 24 -30 BBLS / HR. Control driling for inclination from 16090' - 16118', slowing pumps to 230 GPMs-2350 PSI, to aid in buiding inclination. Observe inclination drop from a 92.69 Deg at 16052' ABI depth to a 89 Deg Inclination at 16118' Depth. Also observed a swing in azimuth from a 111 degrees to a 119 degrees in a 2T drilled distance. All surveys corrected with IFR -Cassandra. Directional driller drilling with 100 'deflection on Geo-Pilot straight up. Hard line for Geologist = 6640' ~~~ TVD. All indications proved we were not building as expected, and a 'I definite change in geology of the well, including fluid losses. Slow pump rates @ #1 -20 SPM -800 PSI, 30 SPM - 1090 PSI. #2 Pump - 20 SPM -790 PSI, 30 SPM - 1080 PSI. Obtain check shot survey @ 16110' MD, 6640 TVD. Pump out of hole from 16110' - 15999' MD. Circulate @ 230 GPM - 2450 PSI. Discuss options with town Geologists, and Engineer. ~I Continue Circulate at 255 GPMs - 2570 PSI. Discuss options with town ',Geologists, and Rig Engineer. 'Pump out of hole to 15690'. 'Blow down Top Drive & Lines. Monitor well -flowing. Observe well for 20 minutes. Circulate bottoms up observing over 5000 Units of gas at bottoms up. Reciprocate & rotate drill string @ 80 RPM's - 9K Torque. Pumps at 275 GPM's - 3100 PSI. Spotting remaining 25 BBLS LCM at 15690', with looses while circulating @ 50-60 BBLS / HR. Blow down Top Drive & Lines. Monitor well -flowing. Observe well for 20 minutes. Light flow back. Circulate while increasing mud weight to 10.2 PPG, observing over 5000 Units of gas at bottoms up. Reciprocate & rotate drill string @ 70 RPM's - 9K Torque. Pumps at 245 GPM's - 2540 PSI. Spotting ,'remaining 25 BBLS LCM at 15690', with losses while circulating @ ~~ 50-60 BBLS / HR. Crew Change Continue Circulate while increasing mud weight to 10.2 PPG, observing over 5000 Units of gas at bottoms up. Reciprocate & rotate drill string @ 70 RPM's - 9K Torque. Pumps at 245 GPM's - 2540 PSI. Observe losses slowing while circulating @ 24-30 BBLS / HR. I Blow down Top Drive & Lines. Monitor well -flowing. Observe well for 20 minutes. Light flow back. 'Continue Circulate while increasing mud weight to 10.4 PPG. I Reciprocate & rotate drill string @ 25 RPM's - 7-8K Torque. Pumps at 240 GPM's - 2410 PSI. UP WT = 200K, SO WT = 140K Flow check well -static. Pump dry job. Blow down Top Drive & Lines. POOH form 15690' - 4913'. (10777'). Obtain torque & drag parameters for Rig engineer every 10 stands. Observe proper hole fill with little or no losses. Crew Change ,Continue to POOH from 4913' - 3683' (1230'). Observe proper hole fill. Printed: 4!26/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To 3/12/2006 ~~ 19:00 - 20:00 ~, 20:00 - 22:00 22:00 - 22:15 , 22:15 - 22:45 22:45 - 23:15 3/13!2006 i 23:15 - 00:00 ',00:00-01:15 ',01:15-02:00 02:00 - 03:15 ', 03:15 - 06:00 106:00 - 10:00 10:00 - 12:00 12:00 - 14:45 '.14:45 - 15:00 ',15:00 - 18:00 18:00 - 20:30 20:30 - 21:00 21:00 - 21:30 21:30 - 22:15 Hours ", Code 'Code' Phase 1.00 DRILL ~ PULD ', PROD 2.00', DRILL TRIP II PROD 0.25. DRILL OBSV PROD 0.50', DRILL PULD ,PROD ~I ~ 0.50; DRILL ~ , SFTY PROD 0.75! DRILL IOTHR PROD 1.25' DRILL ~I PULD ,PROD 0.75' DRILL ~, PULD 1.25" DRILL I PULD PROD PROD 2.75 ,DRILL ',,TRIP '~~ PROD 4.00' DRILL 'TRIP 'PROD 2.00 DRILL 'CIRC ',PROD 2.75' DRILL 'CIRC 'PROD 0.25'' DRILL ',TRIP '...PROD 3.00 I DRILL CIRC !PROD 2.50', CEMENTOTHR !PROD 0.50' CEMENTSFTY PROD 0.501 CEMENTSFTY PROD 0.75', CEMENT PLUG PROD Page 36 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations ', Breakout & lay down 4 3/4" Accelerator (31.62'), Rack back 3 stands of ', 4" HT-38 DP (189.27), and lay down 4 3/4" Dailey DNT Drilling Jars (31.92'). ,Continue POOH racking back 33 stands of 4" HT-38 DP. (3120.73'). Hole fill good. ', Monitor well -static. , Break out & lay down crossover (1.84'), rack back 2 joints Of 4" HWDP (61.36') and Dailey DNT Drilling Jars (32.08') in derrick, Continue rack ', back 1 joint of 4" HWDP (30.68') and 2 4 3/4" Non Mag Flex Drill Collars (61.62') in derrick. PJSM with entire crew. Discuss safety issues and procedure for remoiving nuclear sources from BHA. Remove Nuclear sources from BHA as per Sperry Sun MWD reps. Plug in and download MWD assembly. Continue POOH Breakout & lay down BHA #6. Lay down 6 3/4" Security FSF2641 bit with 3 x 16's for a TFA of .589 sq in. (1.25'), 4 3/4" 5200 series Geo-Pilot TL017 (16.18'), 4 3!4" Non-Mag Geo Pilot Flex Collar (11.54'), 4 3/4" Smart Stabilizer (3.59'), MWD Gamma/Res (33.07), 4 3/4" Nuke Tool (36.31'), MWD TM HOC (10.43'), 4 830" Integral Blade Stabilizer (5.24'), and 4 5/8" Non Mag Float Sub (1.45'). Inspect & grade bit at 1/ 1/ NO /ALL / X / I / NO / HP. Clear 8~ clean rig floor area. Pull 2 7/8" tools to rig floor. Rig up to run 2 7/8" tbg with mule shoe. PJSM -Discuss safety issues and procedure for making up 2 7/8" tbg. Make up 2 7/8" tbg mule shoe, and continue make up 30 joints of 2 7/8" 6.5# tbg. ID = 2 7/16". Make up crossover 3 1/2 IF x 2 7/8 EUE (1.86'). Make up HT-38 x 3 1/2 IF (2.16')crossover. Continue trip in hole with 4" HT-38 DP, (83 stands), crossover to XT-39 'Drill pipe, TIH to 6533' MD. Crew Change Continue TIH with 2 7/8" tubing and Drill Pipe form 6533' - 15695' (9162'). Circulate & condition mud @ 120 GPM - 1060 PSI. 30 RPM's - 7K torque. Observed pumping 10.4 PPG mud in hole, with 9.3 PPG mud coming out, and over 5000 units of gas on bottoms up. Pumped 310 BBLS, while reciprocate & rotate string. Circulate & condition mud @ 120 GPM - 1060 PSI. 30 RPM's - 7K 'torque. Observed pumping 10.4 PPG mud in hole, with 9.3 PPG mud coming out, and over 5000 units of gas on bottoms up. Pumped while reciprocate & rotate string, until good 10.4 ppg mud in & out of hole. Fluid losses at 20 -50 BBL / HR. Tih with 2 7/8" tubing stinger from 15695' - 16118' (423'). 'Circulate bottoms up @ 212 GPM - 1350 PSI. Fluid losses at 30 BBUHR. Pump 30 BBLS of 40 PPB LCM pill to displace well from 10.4 PPG Flo-PRo mud to 10.4 PPG LSND at 258 GPM - 2090 PSI. Observed good 10.4 PPG mud in & out of hole with fluid losses slowing to 12-15 BBLS / HR. Rig up cement lines and break circulation. Held PJSM with entire crew and Dowell. Discuss safety issues and 'procedure for cementing job upcoming. Designate a Spill champion while Circulate @ 173 GPM - 1230 PSI. UP WT = 200 K, SO WT = 135K. 'Turn over to Dowell Cementers. Pump 13.7 BBLS of 8.3 PPG water at Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska 0.25 0,25 1.75 Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To Hours Code C d 'Phase o e i - 3/13/2006 "21:30 - 22:15 0.75; CEMENli PLUG PROD ' I 22:15 - 22:45 '! 0.50 ~, !..22:45 - 23:15 ', 0.50 123:15 - 00:00 ' 0.75 I~~, i 3/14/2006 I~100:00-01:00 ~ 1.00 1.00 0.25 0.50 01:00 - 02:00 1.00:` DRILL CIRC PROD 02:00 - 04:30 II : 2.50' DRILL ~I CIRC ~I PROD 04:30 - 04:45 04:45 - 05:00 05:00 - 06:15 06:15 - 07:00 07:00 - 11:00 11:00 - 11:30 11:30 - 11:45 11:45 - 13:00 0.25 0.25 1.25 0.75 4.00 0.50 0.25 1.25 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL 'OBSV 'CIRC TRIP :CIRC iTRIP !SFTY !,OTHR 'PULD PROD PROD PROD PROD PROD PROD PROD PROD 113:00 - 13:15 ',13:15-13:30 113:30 - 15:15 ~i 15:15 - 16:15 I 16:15 - 16:30 16:30 - 17:00 '17:00-17:30 17:30 - 19:45 I 19:45 - 20:15 I 20:15 - 00:00 3/15/2006 ~ 00:00 - 02:45 0.50 2.25 0.50 3.75 Operations Summary Report i CEMENTDISP PROD CEMENT;TRIP (PROD CEMENT PLUG ',PROD I ~I DRILL CIRC II PROD DRILL ', OTHR '~ PROD DRILL ~;SFTY `PROD DRILL 'PULD PROD DRILL OTHR 'PROD DRILL PULD 'PROD DRILL I OTHR I~ PROD RIGMNT RSRV PROD DRILL ,TRIP PROD DRILL I PULD PROD DRILL TRIP PROD 2.75 ! DRILL ~ TR1P PROD Start: 1 /28/2006 Rig Release: 4/2/2006 Rig Number: 15 Page 37 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations 3 BPM. Shut valve. Pressure test all lines to 3500 PSI. Good test. ~' Batch mix & pump 25.6 BBLS of Class G 17.0 PPG cement @ 3.5 BPM, 1200 PSI. Chase cement with 3.9 BBLS of water to flush lines. Turn over to rig. Turn over to rig. Displace cement with 150 BBLs calculated to balance cement in tubing & annulus. Pump at 5 BPM - 1300 PSI, 6 BPM - 1660 PSI. Shut down pump. UP WT = 210K, SO WT = 135K. ~~ Breakout & lay down cement valve & lines. Observe drill pipe static. POOH with 10 stands at a speed of 40 -60 ft/ minute. Observe annulus 'flowing as we POOH, with drill pipe fluid wet for 3 full stands, and dry on '; last 2 stands, allowing cement to lay out in open hole. UP WT 210K, ' SO WT = 130K. Cement calculated top at 15529'. '.NOTE: Checked mud in annulus and weighed at 9.6 PPG. 'Circulate bottoms up @ 5 BPM - 1290 PSI observing mud weights in & ',out, now out of balance. Mud weight out between 9.1 PPG & 9.8 PPG, ',with Mud weights going in at 9.6 PPG - 9.9 PPG. Begin mixing mud ',products to balance system. li Continue Circulate @ 5 BPM - 1580 PSI observing mud weights in & out, Mud weight out between 10.2 PPG & 10.4 PPG, with Mud weights !,going in at 10.4 PPG - 10.6 PPG. Observe max gas units at over 5000 ~I units on bottoms up. Shut down pumps, drop wiper plug to wipe DP, pumping at 5 BPM - 1400 PSI. We did not see any indcation of a pump pressure increase ' when dart went into 2 7/8" tubing. Contiue to condition mud attempting I to maintain a 10.4 PPG in /out. Continue to circulate @ 5 BPM - 1200 PSI, while rotate & reciprocate string @ 40 RPM's - 6500 FT/ Ibs of torque, monitoring mud weights. PJSM, monitor well- static. i Pump dry job. Blow down top drive. Pipe wet. ~ POOH w/ 2-7/8" cement stinger (/15160' to 12820'. Pump dry job #2. Blow down top job. POOH f/ 12820' to 952'. Record PU and SO wt's f/ T&D. PJSM on laying down 2-7/8", 6.5 ppf tubing. RU skate f/ lay down machine. Change elevators to 2-7/8". I Lay down 30 joints of 2-7/8" tubing and mule shoe. Calc fill 86.9 bbls, actual fill 107 bbls. ~I Change elevators to 4". ', PJSM on picking up BHA #8 to sidetrack w/ motor. PU/MU 6-3/4" Hughes MX-18HDX bit, Sperry Sun motor (1.76 deg bend), float sub, term. sub, gamma/Res, directional, PWD, TM HOC. Uplaod Sperry Sun MWD tools. PU/MU (2) 4-1/2" flex collars and one 4" HWDP to 186'. ',Shallow test MWD tools @ 186'. Pump 257 gpm w/ 860 psi. OK. Blow down top drive. 'Service top drive and crown. PU/MU Daily DNT jars, two 4" HWDP, x-o, then 4" HT38 dp to 3403'. ~I PU wt 100k and SO wt 90k @ 3403'. I PU Daily DNT jars, RIH 2 stands 4" HT38, accelerators to 3655'. ~ Continue RIH w/ BHA #8 f/ 3655' to 10411'. Fill pipe every 25 stands. ~ PU wt 170k, SO wt 110k @ 10411'. Flow checked well @ 6115' and ~ 10400'. Static. Continue RIH f/ 10411' to 15030'. Filling pipe every 25 stands. PU and So wts. PU wt 215k, SO wt 125k @ 15030'. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 3/15/2006 From - To !Hours ' Code !Sub (Code 02:45 - 06:00 3.25 DRILL I CIRC I I 06:00 - 08:00 2.00 08:00 - 08:15 0.25 08:15 - 08:30 !, 0.25 08:30 - 09:30 1.00 09:30 - 10:30 1.00 10:30 - 11:30 1.00 11:30 - 11:45 0.25 11:45 - 12:00 ', 0.25 12:00 - 14:45 2.75 14:45 - 18:00 ' 18:00 - 22:00 22:00 - 22:45 22:45 - 00:00 3/16/2006 100:00 - 05:15 3.25 Phase PROD DRILL (CIRC ',!PROD DRILL CIRC ~ PROD DRILL SFTY PROD RIGMNT RSRV PROD RIGMNT! RSRV !PROD RIGMNT RGRP PROD RIGMNT RSRV PROD DRILL ,TRIP (PROD DRILL !,DRLG PROD DRILL DRLG PROD 4.00':: DRILL 'DRLG ' PROD 0.751 DRILL 'CIRC I, PROD 1.251 DRILL I DRLG I PROD 5.25 DRILL I DRLG ',PROD Page 38 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Circulate and condition mud in hole @ 15030' to 10.4 ppg. Circ 85 gpm w/ 850 psi, rotate @ 50 rpm w/ 7k ft Ib torque. Maintain 10.4 ppg. Mud tube blinding shakers, unable to increase pump rate. Max gas units 14978. Pumped total of 542 bbls. 'Continue to circulate and condition mud in hole @ 15030' to 10.4 ppg. ', Bypass shaker sceens. Circ 211 spm w/ 1800 psi, rotate @ 50 rpm w/ 7k ft Ib torque. Maintain 10.4 ppg. Max gas units 4000, final 150 units. Pumped total of 1122 bbls. Record SPR's. # 1 @ 20 spm = 710 psi, 30 spm = 960 psi. # 2 mp @ 20 spm = 680 psi, 30 spm = 910 psi. MD 15030', TVD= 6410', MW 10.4 !'ppg• Monitor well, static. PJSM w/ hands on slip and cut drilling line. ~~~ Hang blocks. Slip and cut 104' of 1-3/8" drilling line. Service top drive, crown and drawworks. Change out Top Drive IBOP actuator cam rollers. Adjust brakes on drawworks. Set depth encoder f/ Totco and Sperry Sun. !,Trip in hole f/ 15030' to 15177. Tag cement stringers w/ 30k wt @ i!1517T. MU top drive. Drill cement stringers f/ 15177' to 15670' (493'), drill firm cement f/ 15670' to 15699' (29'). Initial drilling w/ 10k WOB, pumping 104 gpm w/ 700 psi, motor turning 80 rpm, turning string 30 rpm w/ 8-9k ft Ib torque. Stage pumps to 255 gpm w/ 2200 psi, motor turning 196 ', rpm, turning string 30 rpm w/ 7-8k ft Ib torque. Max gas units = 320 'units. !Sidetrack well @ 15699', 30 deg left of highside. Drill /sidetrack f/ 15699' to 15787' (88') (TVD = 6622'). ART = .51 hrs, AST = 1.56 hrs, total hrs on bit = 2.07 hrs. Total hrs on jars = 10.43 hrs. PU wt 220k, SO wt = 120k, Rot wt = 160k. Rotate @ 50 rpm w/ 10-11k ft Ib torque on I bottom, 7-8k ft Ib off bottom torque. Pumping 283 gpm w/ 3070 psi on bottom, 2700 psi off bottom. ECD = 12.22 ppg. ''~ Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg bend f/ 15787' to 15940' (6630' TVD) (153') ART 1.33 hrs AST 1.84 hrs, Total hrs on bit = 5.24 hrs., Total hrs on jars = 13.6 hrs, 10-15 k WOB, 60rpm's, 210 motor rpm, 273 gpm, 10.4 ppg mw, on bottom pressure 3000-3070 psi, off bottom pressure 2700-2755 psi, on bottom !,torque 10-15k ft/Ib, off bottom torque 7-13k ft/Ib, PU wt 220-225k, SO wt 120k, Rot wt 160k. ECD's = 12.22-11.53 ppg EMW. Max gas = 3197 ',units while drilling, background 494 units. ''Check flow. Circ 275 gpm w/ 2780 psi. Rotate @ 60 rpm w/ 12-14k ft Ib torque. Circ to clean up hole and reduce ECD's down to 11.99 ppg. Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg bend f/ 15940' to 15976' (6624' TVD) (36') ART .92 hrs AST .15 hrs, Total hrs on bit = 6.16 hrs., Total hrs on jars = 14.52 hrs, 12-15 k WOB, 60rpm's, 210 motor rpm, 273 gpm, 10.4 ppg mw, on bottom pressure 3010 psi, off bottom pressure 2760 psi, on bottom torque 14-15k fUlb, '~ off bottom torque 11-13k ftllb, PU wt 225k, SO wt 120k, Rot wt 160k. ! ECD's = 11.88 ppg EMW. Max gas = 3400 units while drilling, background 318 units. Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 176deg bend f/ 15976' to 16118' (661 T TVD) (142') ART 3.18 hrs AST .43 hrs, ', Total hrs on bit = 9.22 hrs., Total hrs on jars = 17.58 hrs, 10-15 k WOB, !! 60 rpm's, 208 motor rpm, 270 gpm, 10.4 ppg mw, on bottom pressure Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To 'Hours 3/16/2006 ; 00:00 - 05:15 ', 5.25 05:15 - 06:00 0.75 i 06:00 - 12:00 ~ 6.00 12:00 - 18:00 6.00 18:00 - 00:00 3/17/2006 100:00 - 03:30 6.00 3.50 Code 'Code ' Phase DRILL ~i, DRLG PROD DRILL i DRLG PROD DRILL DRLG DRILL DRILL DRILL PROD DRLG % PROD DRLG 'PROD DRLH PROD Page 39 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations 3010 psi, off bottom pressure 2760 psi, on bottom torque 14-15k ft/Ib, off bottom torque 11-13k ft/Ib, PU wt 230k, SO wt 120k, Rot wt 155k. ECD's = 11.9ppg EMW. Max gas = 507 units while drilling, background 209 units. Start displacing @ 0145 hrs, finished @ 0400 hrs.Control drill 15'/hr while displacing f/ 10.4 ppg LSND mud to 10.5 ppg Flo Pro mud, while drilling 16067' to 16100'. Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg bend f/ 16118' to 16150' (6615' TVD) (32') ART .24 hrs AST .36 hrs, Total hrs on bit = 9.82 hrs., Total hrs on jars = 18.18 hrs, 10-12 k WOB, 60 rpm's, 179 motor rpm, 232 gpm, 10.4 ppg mw, on bottom pressure 2550 psi, off bottom pressure 2460 psi, on bottom torque 10k ft/Ib, off bottom torque 8-9k fUlb, PU wt 230k, SO wt 120k, Rot wt 162k. ECD's = 11.98 ppg EMW. Max gas = 507 units while drilling, background 209 units. Directional drill 6-3/4" hole w/Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg bend f/ 16150' to 16317' (6610' TVD) (167') ART 2.57 hrs AST 1.24 hrs, Total hrs on bit = 13.63 hrs., Total hrs on jars = 21.99 hrs, 15 k WOB, 60 rpm's, 205 motor rpm, 266 gpm, 10.4 ppg mw, on bottom pressure 2550-2950 psi, off bottom pressure 2460-2846 psi, on bottom torque 10-12k fUlb, off bottom torque 8-11 k ft/Ib, PU wt 230-225k, SO wt 120k, Rot wt 162-160k. ECD's = 11.98-12.14 ppg EMW. Max gas = 1257 units while drilling. Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg ~~ bend f/ 1631 T to 16536' (6601' TVD) (219') ART 4.01 hrs AST .5 hrs, Iii Total hrs on bit = 18.14 hrs., Total hrs on jars = 26.5 hrs, 10-15 k WOB, ', 60 rpm's, 201-209 motor rpm, 261-271 gpm, 10.4 ppg mw, on bottom ', pressure 2950-3100 psi, off bottom pressure 2846-2900 psi, on bottom 'torque 10-13k ft/Ib, off bottom torque 10-11 k fUlb, PU wt 225-230k, SO wt 120-125k, Rot wt 160k. ECD's = 12.01-12.3 ppg EMW. Max gas = ~,1336units while drilling. Fluid loss f/ 0600 hrs to 1800 hrs = 90 bbls. Directional drill 6-3l4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg bend f/ 16536' to 16723' (6600' TVD) (18T) ART .82 hrs AST 1.96 hrs, i Total hrs on bit = 20.92 hrs., Totat hrs on jars = 29.28 hrs, 10-15 k WOB, 60 rpm's, 210 motor rpm, 273 gpm, 10.4 ppg mw, on bottom ;pressure 2950-3100 psi, off bottom pressure 2730 psi, on bottom torque 11-12k ft/Ib, off bottom torque 9-10k ft/Ib, PU wt 225k, SO wt 120k, Rot wt 160k. ECD's = 11.89 ppg EMW. Max gas = 1337 units '~~,while drilling, background gas 550 units. ',Mud losses f/ 1800 hrs to midnight = 53 bbls 'Total fluid lost in 24 hrs = 143 bbls ', Directional drill 6-3/4" hole w/ Sperrydrill 6/7-6.0 stage mtr w/ 1.76deg ,bend f/ 16723' to 16864' (6601' TVD) (141') ART 1.26 hrs AST .66 hrs, ~' Total hrs on bit = 22.84 hrs., Total hrs on jars = 31.2 hrs, 10-15 k WOB, ', 60 rpm's, 210-183 motor rpm, 273-238 gpm, 10.4 ppg mw, on bottom 'pressure 3100-2500 psi, off bottom pressure 2730-2380 psi, on bottom ', torque 11-12k ft/Ib, off bottom torque 9-10k ft/Ib, PU wt 230k, SO wt ',120k, Rot wt 160k. ECD's = 11.89-11.78 ppg EMW. Max gas = 850 'I units while drilling, background gas 76 units. Pump and spot 30 bbls LCM pill (40 ppb total: 12ppb Dyna Red F, 12 Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Opera#ions Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 3/17/2006 From - To '! Hours .Code 00:00 - 03:30 3.5011 DRILL 03:30 - 04:00 0.50 DRILL 04:00 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 08:45 08:45 - 10:00 10:00 - 12:00 2.00! DRILL 0.50'1 DRILL 2.001, DRILL 0.25 DRILL 1.25 DRILL 2.00, DRILL 12:00 - 12:30 12:30 - 13:00 13:00 - 15:30 Sub .Phase 'Code _ _ ~',DRLH PROD ~!~TRIP PROD (TRIP PROD OBSV PROD TRIP PROD OBSV PROD TRIP I PROD TRIP ';PROD 0.50'' DRILL !.TRIP 0.50', DRILL OBSV 2.50', DRILL I CIRC PROD PROD PROD 15:30 - 15;45 ' 0.25 DRILL ~ OBSV PROD 15:45 - 16:15 0.50 DRILL TRIP , PROD 16:15 - 17:30 1.25 DRILL TRIP PROD 17:30 - 18:00 0.50 DRILL , ',TRIP 'PROD ;18:00 - 18:30 "18:30 - 19:00 19:00 - 21:30 21:30 - 22:00 22:00 - 23:30 23:30 - 00:00 ' 0.50 DRILL TRIP PROD i 3/18/2006 00:00 - 00:15 'i 0.251, DRILL 'TRIP ', PROD 00:15 - 01:15 ', 1.001 DRILL ; OTHR ', PROD !01:15-02:15 02:15 - 02:30 02:30 - 04:45 04:45 - 05:45 05:45 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 07:30 ..07:30 - 13:15 I 0.50 DRILL 'TRIP ;PROD 0.50'1 DRILL ' OBSV PROD 2.50; DRILL TRIP PROD 0.50! DRILL PULD PROD 1.50' DRILL ~iTRIP (PROD 1.00 ~ DRILL PULD 0.25' DRILL ' SFTY 2.25: DRILL II PULD 1.00 II DRILL I OTHR I 0.25 DRILL OTHR 0.50 DRILL ~ OTHR 0.50, DRILL 'SFTY 0.501, DRILL 'PULD 5.75'... DRILL iTRIP PROD PROD PROD PROD PROD PROD PROD PROD PROD Page 40 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations ppb SafeCarb 250, 8 ppb, Nut plug F, 8 ppb G-Seal) @ 16840' Take SPR's. POOH f/ 16864' to 16630'. Hole swabbing, pulling 20k over to 250k. SO wt 120k. Pump and spot 30 bbls LCM pill (40 ppb total: 12ppb Dyna Red F, 12 !ppb SafeCarb 250, 8 ppb, Nut plug F, 8 ppb G-Seal) @ 16840' Monitor well-static 'Attempt to POOH on elevators. Hole not taking correct fill. Pump out of hole from 15690' to 14559'. Monitor well-static Pump out of hole from 14559' to 13617'. Pump 168 gpm, 1030 psi. losing 22.5 bph Monitor well static Pump out of hole from 13617' to 12680'. Pumping 84 gp @ 575 psi. Fluid losses 0600 hrs to noon = 56 bbls. POOH from 12680' to 12213' on elevators. Hole not taking correct fill i Monitor well. Fluid level dropping. i CBU @ 12213'. Circ 84 gpm w/ 580 psi to 167 gpm w/ 1186 psi. !Pumped 500 bbls. Losing mud @ 32 bph. ', Monitor well. Fluid dropping very slow. POOH f/ 12213' to 11747'. Hole swabbing. Pump out of hole f/ 11747' to 10813'. Pump 175 gpm w/ 1140 psi. POOH f/ 10813' to 9880'. PU wt 195k, SO wt 115k @ 9880'. Fluid losses f/ noon to 1800 hrs = 30 bbls Total fluid loss today, up to 1800 hrs = 276 bbls. POOH f/ 9880' to 9360'. PU wt 190k, SO wt 115k @ 9360'. Monitor well, Static. Pump dry job. Blow down top drive. j POOH f/ 9360' to 3655'. PU wt 120k, SO wt 85k. UD Accelerators, stand back two stands, UD Jars. POOH wet to 282'. PU wt 80k, SO wt 80k. i Calculated fill 98.64 bbls, actual 185.04bbls. 86.4 bbls over calculated. i~ Stand back HWDP, jars, flex collars in derrick. ;Fluid loss to hole f/ 1800 hr to midnight = 44 bbls Total fluid loss for day = 320 bbls Continue POOH to 6-3/4" bit. Drain motor, break and remove bit # 7. Download Sperry Sun MWD tools. Monitor well on trip tank. Loss rate = 7 bph. UD BHA # 8. PJSM on PU BHA # 9. PU/MU BHA # 9: Make up 6-3/4" Sec FSF 2641 bit, Sperry Sun 5200 GeoPilot ser # TL-012, NM Geo flex collar, Smart stab, Gamma/Res, MWD directional, Nuke tool, PWD, HOC to 113'. Upload Sperry Sun MWD tools. Monitor well. Loss rate = 5.25 bph. ,Shallow test MWD tools w/ 210 gpm w! 650 psi @ 113'. Mud losses f/ midnight to 0600 hrs = 29 bbls. ~ Blow down top drive. PJSM on handling nuke sources. Load sources. Continue PU/MU BHA # 9: MU 6.438" stab, NM float sub, (2) 4-1/2" flex DC's, Weatherford x-o, (1) Weatherford 4" HWDP, Daily DNTjar, (2) Weatherford 4" HWDP MU Weatherford x-o, follow w/ 33 stands Weatherford 4" HT 38 dp to 3431', MU Daily DNT jars, follow w/ 2 stands Weatherford 4" HT38 dp, ',Daily Accelerators to 3683.81', then Weatherford 4" HT 38 dp to 8225', follow w/ x-o, then Weatherford 4" XT39 dp to 8414'. Record PU and ', SO wt's while RIH. Fill pipe every 25 stands. Printed: 4/28/2008 8:42:24 AM ConocoPhillips Alaska Page 41 of 53 Operations Summary Report Legal Well Name: 1D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date 3/18/2006 From - To ,Hours Code 'Code Phase 07:30 - 13:15 ' 5.75 DRILL TRIP 'PROD 13:15 - 15:30 2.25 DRILL CIRC !PROD '~ 15:30 - 18:00 18:00 - 18:45 18:45 - 21:15 ~I 21:15 - 00:00 3/19/2006 ' 00:00 - 00:30 ~, 00:30 - 01:00 ', 01:00 - 06:00 '•.06:00 - 07:15 ', 07:15 - 09:00 09:00 - 09:45 09:45 - 10:15 10:15 - 10:30 I 10:30 - 11:00 11:00 - 11:15 11:15 - 22:30 22:30 - 22:45 2.5011 DRILL TRIP 'PROD 0.75'DRILL IiTRIP (PROD 2.50 2.75 DRILL j CIRC ,PROD RIGMNT RSRV i PROD 0.50 0.50 5.00 RIGMNT RSRV I PROD DRILL ',TRIP ', PROD DRILL TRIP ~~ PROD 1.25' DRILL REAM I. PROD 1.75, DRILL I DRLH ''.PROD 0.7511 DRILL I OTHR PROD 0.50' DRILL !OTHR 0.25' DRILL 'DRLH 0.501 DRILL j I i OTHR I 0.25'; DRILL ;TRIP 11.25 DRILL TRIP PROD PROD PROD PROD PROD 0.25 DRILL SFTY ~ PROD Description of Operations Mud losses f/ 0600 hrs to 1200 hrs = 25 bbls. Circulate bottom's up. Wait up light spots until 10.4 ppg MW in and out. Note lightest weight 10.1 ppg. Continue RIH w/ BHA #9 f/ 8414' to 14305'. Fill pipe every 25 standss. Record PU and SO wt's. PU wt @ 14305' = 220k, SO wt = 115k. Mud losses f/ 1200 hrs to 1800 hrs = 71 bbls. Continue RIH w/ BHA #9 f/ 14305' to 15624'. Fill pipe every 25 standss. Record PU and SO wt's. PU wt @ 14305' = 225k, SO wt = 115k. Fill pipe. Circ and condition mud to 10.4 ppg. Max mud wt out on BU was 11.5 ppf. Pump @ 200 gpm w/ 2080 psi. Pump total of 670 bbls. Rotate 80 rpm w/ 10k torque. Max gas = 290 units on BU. Mud loss while pumping = 18 bbls. Increase rate to 260 gpm w/ 2640 psi near end of circ. Appeared to be no increase in losses. Blow down top drive. Change out saver sub on top drive, adjust link tilt, service top drive. Monitor well on trip tank, no losses. !Total fluid loss f/ 24 hr period = 143 bbls. ': Total fluid losses since 3!15/2006 = 606 bbls. 'Clear rig floor of tools. PJSM on tripping in hole. ~~ Trip in hole f/ 15624' to 15900'. PU wt 230k, SO wt 120k. Continue trip in hole by washing down to pre picked Cassandra survey points. Reaming, if hole taking more than 10k down wt. Watching ECD's close. Depths of surveys 15,900', 15995', 16088', 16184', 16276',16342',16373',16466', 16554', 16610', 16654', 16748'. ',Pumping 200 gpm w/ 2-80 psi. 80 rpm w/ 10k ft Ib torque. PU wt 220k, ', SO wt 115k, Rot wt 158k. Fluid loss to hole f/ midnight to 0600 hrs = 19 bbls. 'Wash and ream f/ 16745' to 16864'. Pumping 200 gpm w/ 2080 psi. Rotate 120 rpm w/ 10k ft Ib torque. Max gas = 250 units. ~ Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 16864' to 16940' (6598.58' TVD) (76') ART 1.16 hrs, Total hrs on bit = 1.16 hrs., Total hrs on jars = 32.36 hrs, 8 k WOB, 120 rpm's, 240 gpm, 10.4 ppg mw, on bottom pressure 2856 psi, off bottom ~ pressure 2800 psi, on bottom torque 13k ft/Ib, off bottom torque 13k ft/Ib, PU wt 220k, SO wt 122k, Rot wt 155k. ECD's = 12.29 ppg EMW. ~ Max gas = 4970 units while drilling. Mode switch MWD to trouble shoot problem. Resistivity value stuck, not reading correct. Reset tools. ', MAD pass f! 16940' to 16855'. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 16940' to 16964' (6597.4' TVD) (24') ART .22 hrs, Total hrs on bit = 1.38 hrs., Total hrs on jars = 32.58 hrs, 8 k WOB, 120 rpm's, 240 gpm, 10.4 ppg mw, on bottom pressure 2856 psi, off bottom pressure 2800 psi, on bottom torque 13k ft/Ib, off bottom torque 13k ft/Ib, PU wt 220k, SO wt 122k, Rot wt 155k. ECD's = 12.29 ppg EMW. ~ Max gas = 2400 units while drilling. ;Attempt to mode shift tools again. Have lost communication to Sperry 'Sun GeoPilot. No success in re-start. ', Pump out of hole f/ 16964' to 16870'. Pump out of hole @ 222-226 gpm w/ 2570-2450 PSI. Rotate 65 rpm w/ 'i 12-11 k ft Ib torque. Pulling speed less than 150 ft per hour f/ MAD I~~ Pass. PU wt 220k, So wt 122k, Rot wt 150k @ 15694'. 'I PJSM on pumping out of hole. Monitor well, static. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 1 D-41 1 D-41 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours j' Code ', Code I Phase 3/19!2006 !.22:45 - 00:00 1.25', DRILL iTRIP (PROD ', 3/20/2006 00:00 - 02:00 'i~ 2.00 DRILL I TRIP 02:00 - 02:30 ' 0.50 DRILL CIRC 02:30 - 03:30 i 1.00 DRILL ~~ TRIP 03:30 - 06:00 i 2.50! DRILL TRIP 06:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 11:45 11:45 - 12:00 12:00 - 12:15 12:15 - 12:30 12:30 - 13:00 13:00 - 14:00 '~ 14:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 18:00 ,18:00-21:30 ~~ 21:30 - 22:30 22:30 - 23:15 23:15 - 00:00 ~~ ~I 3/21 /2006 00:00 - 00:30 00:30 - 02:45 2.00! DRILL 'TRIP 0.50 0.50 2.75 DRILL TRIP DRILL 'OTHR DRILL TRIP 0.25 0.25 0.25 0.50 1.00 PULD 0.50 ~I DRILL ' OTHR 0.50!. DRILL OTHR 1.00! WELCTLOTHR 2.00 ~~, WELCT~' BOPE I I ~, i i I 3.50 WELCTL BOPE ~! 1.00 j WELCTI,! OTHR 0.75 WELCTLOTHR 0.75 ~' WELCT~ SFTY 0.501 DRILL 2.251 DRILL DRILL TRIP I PROD DRILL SFTY PROD DRILL OTHR ~, PROD DRILL i OTHR ': PROD DRILL I, PULD :PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD 'PROD PROD '~ PROD PROD ~~ PROD PULD PROD Page 42 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations 'Pumping out of hole f/ 15694' to 14964'. Pumping 200 gpm w/ 1950 psi. Pu wt = 210k, SO wt = 120k @ 14964'. ', Fluid loss f/ 0600 hrs to midnight = 201 bbls I Total fluid loss today = 220 bbls ~I Total fluid lost since 3!15/2006 = 696 bbls ii Pump out of hole from 14,964' to 13,725'. Pumping 195 gpm @ 1820 psi. P/U 205k, S/O 115k Spot 30 bbl LCM pill at bit, 40 ppb. Pump out of hole from 13,725' to 13,065' leaving LCM pill below bit. ~', Pumping 120 gpm @ 1020 psi. Pulling speed 85'/min. P/U 195k, S/O 115k ;Pump out of hole from 13,065' to 11,495'. Pumping 190 gpm @ 1560 psi. P/U 185k, S/O 115k. Have lost 18 bbl mud since midnight. ',Continue pumping out of hole f/ 11495' to 10002'. Pumping 200 gpm w/ 11500 psi. POOH wet f/ 10002' to 9068'. ~ Pump dry job. Monitor well., static. Blow down top drive. POOH on elevators f/ 9068' to 310'. Actual fill 78.24 bbls, calculated 57.56 bbls. Stand back HWDP, jars and flex drill collars. ', PJSM w/ Sperry Sun on removing nuke sources. Remove nuke sources. Download Sperry Sun MWD. UD stabilizer, remove innards of HOC, UD same. Lay down MWD, I smart stab, geopilot flex collar,geopilot and break off bit. Clear rig floor of tools. ,Attempt to pull FMC wear bushing w/ new running tool, Change out tools and use original to pull wear bushing. RU to test BOPE. Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Test 250 psi low and 3500 psi high. Tested choke manifold while laying down BHA. Hold each test 5 min. Test upper pipe rams (3-1/2" x 6" variables), choke and kill line HCR valves. ~, Floor safety valve and IBOP w/ HT 38 connection both failed. Tested others, OK. Fluid loss f/ 0600 to 1800 hrs = 36 bbls. Continue testing BOPE. Test 250 psi low and 3500 psi high. Hold each 'test 5 min. Test manual choke valves, test lower pipe rams (4"), test ,blinds. Test accumulator. ,Test Top drive manual IBOP. Test top drive actuated IBOP, failed test. Will change out TD IBOP when @ 7-5/8" casing shoe. Floor safety valve and IBOP w/ HT 38 connection both failed. Tested i others, OK. Testing floor safety valve and IBOP w/ XT 39 Conn. while preparing to PU BHA. ~ Fluid loss f/ 1800 hrs to 2359 hrs = 7 bbls while testing BOP's. 'Total fluid loss past 24 hrs = 61 bbls. Total fluid loss since 3/15/2006 = 757 bbls. PU Sperry Sun MWD directional tool, nuke tool, and PWD tool as one. ,Break off directional tool (8.56'), break off nuke tool (25.49'), and break ', off PWD tool 1 PU/MU BHA # 10: Make up 6-3/4" Sec FSF 2641 bit, Sperry Sun 5200 i GeoPilot ser # TL-012, NM Geo flex collar, Smart stab, Gamma/Res, Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report. Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 D-41 1 D-41 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Start: 1 /28/2006 Rig Release: 4/2/2006 Rig Number: 15 Date From - To 3/21 /2006 00:30 - 02:45 02:45 - 05:00 j 05:00 - 05:45 '~i 05:45 - 06:00 06:00 - 07:00 107:00 - 07:45 !, 07:45 - 10:30 1, I 10:30 - 10:45 I .10:45 - 11:30 ~, 11:30 - 12:00 I '12:00-12:15',. '12:15-12:45'1, ,12:45-14:301, 14:30 - 15:00 1,15:00-16:45 116:45 - 17:45 I' 17:45 - 18:00 ~~18:00-21:00 21:00 - 21:30 I' 21:30 - 22:00 11!122:00 - 23:00 1, 23:00 - 23:30 ' 123:30 - 00:00 3/22/2006 00:00 - 02:30 Page 43 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Hours , Code Code Phase Description of Operations 2.25' DRILL ', PULD , PROD MWD directional, Nuke tool, PWD, HOC to 113'. 2.25 ~ DRILL ~' OTHR ~ PROD A Attempt to upload Sperry Sun tools. Unsuccessful in getting info to li ' ~I PWD tool. j ~ While attempting to troubleshoot PWD tool in toolstring, preparing to 'put BU PWD tool into pipeshed to warmup and possibly change out. j Tool dropped 19' off of elevator to ground. This near miss occurred 1 aprrox 0500 to 0515 hrs. 0.75 !; DRILL ~ OTHR PROD Sperry Sun work/ troubleshoot PWD tool. 0.25 DRILL I OTHR PROD PU hang off collar. Attempt to upload MWD tools. Fluid loss f/ midnight to 0600 hrs = 6 bbls. 1.00 DRILL OTHR ; PROD ~ Continue attempt to load software into MWD tools. 0.75 DRILL '1 PULD PROD 'Lay down all of BHA # 10. 2.75 DRILL ~~ OTHR I PROD Check Sperry Sun tools in pipe shed. Upload in pipe shed to new PWD ;tool. Note: Replacement PWD tool recd f/ Sperry Sun shop in Prudhoe, arrived on location @ 0830 hrs. 0.25 DRILL I SFTY PROD PJSM on PU/MU BHA # 10. 0.75 I, DRILL ,;.PULD PROD PU/MU BHA # 10: Make up 6-3/4" Sec FSF 2641 bit, Sperry Sun 5200 ~ !, GeoPilot ser # TL-012, NM Geo flex collar, Smart stab, Gamma/Res, '~ !MWD directional, Nuke tool, PWD, HOC to 113'. 0.50 DRILL OTHR PROD 1, Pulse test MWD. Good. PJSM on handling nuke sources. 0.25 DRILL OTHR PROD I Load nuke sources. 0.50 DRILL TRIP PROD ~I Continue PU/MU BHA #10: MU 6.438" stab, (1) 4-1/2" flex DC, NM float i sub, (1) 4-1/2" flex DC's, Weatherford x-o, (1) Weatherford 4" HWDP, Daily DNT jar, (2) Weatherford 4" HWDP, Weatherford x-o, to 310'. 1.75'' , DRILL ~~ TRIP , PROD RIH w/ 33 stands Weatherford 4" HT 38 dp to 3431'. Record PU & SO 1 1 wt's every 10 stands. 0.50 DRILL ! I PULD PROD i MU Daily DNT jars, follow w/ 2 stands Weatherford 4" HT38 dp, Daily Accelerators to 3683.81'. 1.75 DRILL ~ TRIP '! PROD !RIH w/ Weatherford 4" HT 38 dp to 8225', follow w/ x-o, then ~~ 'Weatherford 4" XT39 dp to 8414'. Fill pipe every 25 stands. Fill @ ~ , 5103', 7468' and 8414'. Record PU and SO wt's every 10 stands. 1.00 !. DRILL CIRC i PROD i Circulate bottoms up @ 8414'. Pumping 206 gpm w/ 1500 psi. Break in ' s f/ 25 rpm to 50 rpm w/ 5k ft Ib torque. PU wt = geopilot. Stage rpm ' ! I s 13.51 ppg to 13.35 ppg 155k, SO wt = 105k, Rot wt = 130k. ECD 0.25 '1 DRILL ' OTHR ' PROD ~~~ Blow down top drive. ! i Fluid losses f/ 0600 hrs to 1800 hrs = 7 bbls. 3..00 DRILL 1! TRIP ',PROD !Trip in hole f/ 8414' to 12148'. PU wt 190k, SO wt 110k. Record PU & SO wt's every 10 stands. ' 1 0.50 DRILL CIRC PROD s 12.16 , Fill pipe. Establish circ @ 30 spm (126 gpm) w/ 1250 psi. ECD 'PP9 I 0.50', DRILL i TRIP PROD ; Trip in hole f/ 12148' to 14493'. PU wt 205k, SO wt 120k. Record PU & ~' SO wt's every 10 stands. DRILL CIRC i PROD 1.00 Fill pipe and establish circulation @ 30 spm (126 gpm) w/ 1250 psi. i ' ~ ECD s 11.66ppg. 0.50 DRILL !TRIP PROD ~ !1 Trip in hole f/ 14493' to 15624'. PU wt = 210k, SO wt = 125k. ~I CIRC ~ PROD 0.501 DRILL !Fill pipe, establish circ @ 30 spm (126 gpm) w/ 1300 psi. ECD's 11.6 1 I ~ ppg. Pump 50 bbls prior to rotating. ~~ j Fluid loss f/ 1800 to midnight = 13 bbls ~, !, Total fluid loss f/ day = 26 bbls ' I ~ Total fluid lost since 3/15/2006 = 783 bbls. 2.50 i DRILL 'CIRC I PROD ~ Circ @ 30 spm (126 gpm) w/ 1300 psi: ECD's 11.6 ppg. Start rotating j ', and ECD's increased to 11.9 ppg. Recip pipe 45'. Stage pumping rate Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date From - To ' Hours Code 3/22/2006 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 12:00 '...12:00 - 15:00 'i15:00-16:00 16:00 - 16:30 16:30 - 18:00 i 18:00 - 19:00 ~,! 19:00 - 20:00 20:00 - 21:00 ',21:00-21:30 ', 21:30 - 22:00 ~I 22:00 - 00:00 2.50 DRILL 0.50,1 DRILL 0.50 1.50 1.00 3.00 3.00 3.00 1.00 0.50 1.50 1.00 1.00 1.00 0.50 0.50 2.00 3!23/2006 00:00 - 00:30 Page 44 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Sub Phase ' Description of Operations Code ~~, CIRC !PROD ! to final of 56 spm (240 gpm) w/ 2540 psi. Final MW out 10.5 ppg, MW ~I ' in 10.4 ppg. ECD's up to max 12.2 ppg. 'CIRC ',PROD ' SPR's: #1 pump @ 20 spm = 980 psi, 30 spm = 1350 psi. # 2 pump @ '~ ~ 20 spm = 990 psi, 30 spm = 1346 psi. DRILL OTHR PROD Blow down top drive. Hang blocks and hold PJSM on cutting drilling line. RIGMNT'; RSRV PROD Remove guards and brass on dead man. Slip and cut 112' of 1-3/8" ', !, drilling line. Perform visual inspection of brake bands, brake pads, adjust rollers and check equalizer bar. Double check bolts and lock ', ', nuts. Pump up weight indicator. Install brass on deadman. Torque bolts to 300 tt Ib. Install all covers aand grease drawworks. Unhang i 'blocks and double check weight indicator. Monitor well on trip tank f/ ', losses. No fluid loss. WELCTL, BOPS ii PROD I Install floor safety valve one joint down in string (open). RU and attempt ~ to test upper IBOP on top drive (remote acctuated valve). No test. ' Fluid loss f/ midnight to 0600 hrs = 33 bbls WELCTL OTHR PROD I Remove upper IBOP valve f/ Varco TDS 8 top drive. WELCTL OTHR ',PROD Clean upper IBOP valve. Send valve to shop for rebuild. While I rebuilding IBOP valve, test both pressure relief valves on mud pumps. Both popped @ 4200 psi. Reset pressure relief valves. WELCT OTHR PROD Rebuilding upper IBOP valve for Varco TDS 8 top drive. WELCT OTHR ';PROD 'Install upper IBOP, lower IBOP and saver sub on quill of top drive. !Torque upper and lower IBOP to 64000 tt Ib torque. Change heads in ;grabber assembly. WELCTL BOPE !, PROD ~ Rig up and test upper IBOP to 250 psi low and 3500 psi high. Hold ' each test 5 minutes. Good test. Rig down test equipment. Blow down i WELCTL OTHR Iii PROD I top drive. Install "joint locks" across connections f/ upper IBOP and Lower IBOP, and saver sub. Torque compression rings to 382 tt Ib torque. WELCTLI OTHR PROD ~ Finish putting top drive back together. RIGMNT RSRV 'PROD Remove floor safety valve from string. Grease and service top drive and DRILL DRILL DRILL DRILL 'washpipe. CIRC ;PROD ! MU top drive, break circ w/ 20 spm (82 gpm) w/ 980 psi. TRIP ~~! PROD Blow down top drive. TRIP ',PROD ''~ RIH from 15624' to 16848'. Record PU and SO wt's every 5 stands in ~'~ 'I open hole. REAM ! PROD I Precautionary wash and ream f/ 16848' to 16964' (116') while circ ~ bottoms up. Stagging pumps up f/ 30 spm (127 gpm) w/ 980 psi and ' ! s 12.25 ppg --- to final of 61 spm (258 gpm) w/ 2780 psi and ECD ~I ECD's 12.06 ppg. Max ECD's were 12.44 ppg. Max gas = 2458 units !,Fluid loss 0600 to 2359 hrs = 19 bbls. ' ~ Fluid loss to well this 24 hr period = 52 bbls I~ 'Total fluid loss since 3/15/2006 = 835 bbls ~I CIRC 'PROD ! SPR's : # 1 @ 20 spm w/ 950 psi, 30 spm w/ 1270 psi. # 2 mp @ 20 0.501 DRILL 00:30 - 02:15 ' 1.75 DRILL I DRLH '. PROD spm = 950 psi, 30 spm = 1310 psi. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 16964' to 17048' (6595.54.' TVD) (84') ART 1.06 hrs, Total hrs on bit = 1.06 hrs., Total hrs on jars = 33.54 hrs, 0-8 k WOB, 120 rpm's, 240 gpm, 10.4 ppg mw, on bottom pressure 2440 psi, off bottom pressure 2390 psi, on bottom torque 15k ftJlb, off bottom torque 11 k ft/Ib, PU wt 235k, SO wt 130k, Rot wt 170k. ECD's = 12.29- 11.95 ppg EMW. Max gas = 178 units while drilling. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 3/23!2006 ' 02:15 - 03:00 ' 03:00 - 06:00 1 D-41 1 D-41 ROT -DRILLING D15CM@conocophillips.com Doyon 15 Hours ' Code Code Phase - 0.75' DRILL ~' CIRC PROD 3.00 DRILL 'DRLH PROD '. 06:00 - 12:00 I ~I ~~ ', 112:00 - 16:00 ' 16:00 - 16:15 116:15-17:30 it ',17:30-18:00 I, 6.00'. DRILL i DRLH PROD 4.001 DRILL 'DRLH ~~ PROD 0.25 DRILL '; OBSV .PROD 1.25 DRILL ',CIRC 'PROD 0.50 DRILL DRLH 'PROD 18:00 - 18:30 '' 0.50'. DRILL DRLH PROD I~ li ~ ' 18:30 - 19:30 ~' 1.00 III DRILL ~ DRLH I'~, PROD 19:30 - 00:00 4.50' DRILL ~I DRLH PROD Page 45 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Pump 40 bbl LCM pill : 40 ppb ' Directional drill 6-3/4" hole w/SperrySun 5200 series GeoPilot ser # 1~ TL-012 f/ 17048' to 17128' (6594' TVD) (80') ART 2.26 hrs, Total hrs on bit = 3.32 hrs., Total hrs on jars = 35.8 hrs, 6-10 k WOB, 120 rpm's, 190-240 gpm, 10.4 ppg mw, on bottom pressure 2450 psi, off bottom pressure 2380 psi, on bottom torque 15k ft/Ib, off bottom torque 11 k ' ftllb, PU wt 230k, SO wt 140k, Rot wt 170k. ECD's = 11.67 ppg EMW. Max gas = 1885 units while drilling. Fluid loss f/midnight to 0600 hrs = 260 bbls Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # ', TL-012 f/ 17128' to 17412' (6587 TVD) (284') ART 3.85 hrs, Total hrs ', on bit = 7.17 hrs., Total hrs on jars = 39.65 hrs, 3-6 k WOB, 120 rpm's, 190-240 gpm, 10.4-10.2 ppg mw, on bottom pressure 1950-2450 psi, 1 off bottom pressure 2325-1900 psi, on bottom torque 14-16k ft/Ib, off ~~ bottom torque 14-15k fUlb, PU wt 235-230k, SO wt 130k, Rot wt 165k. ECD's = 11.88-11.69 ppg EMW. Max gas = 4970 units while drilling. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # ' TL-012 f/ 17412' to 17695' (6584' ND) (283') ART 2.5 hrs, Total hrs on 'bit = 9.67 hrs., Total hrs on jars = 42.15 hrs, 0-8 k WOB, 120-80 rpm's, 190-240 gpm, 10.2-10.0 ppg mw, on bottom pressure 2300-1850 psi, off bottom pressure 2244-1838 psi, on bottom torque 15-16k ft/Ib, off ' bottom torque 16-12k ft/Ib, PU wt 235-240k, SO wt 130k, Rot wt 165k. ECD's = 11.42-11.71 ppg EMW. Max gas = 4970 units while drilling. Monitor well. Fluid dropping slowly. Record slow pump rates. ',Circulate and condition mud at a reduced rate. Pumping 143 gpm w/ ~~ 1200 psi. Rotate 40 rpm w/ 10k ft Ib torque. ~I Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # ~, TL-012 f/ 17695' to 17741' (6584' ND) (46') ART .37 hrs, Total hrs on bit = 10.04 hrs., Total hrs on jars = 42.52 hrs, 8-10 k WOB, 80 rpm's, 158 gpm, 10.2-10.0 ppg mw, on bottom pressure 1338 psi, off bottom pressure 1324 psi, on bottom torque 12k fUlb, off bottom torque 12k fUlb, PU wt 240k, SO wt 125k, Rot wt 170k. ECD's = 11.23 ppg EMW. Max gas = 4970 units while drilling. Fluid loss 0600 hrs to 1800 hrs = 670 bbls ', Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 17741' to 17789' (6584' TVD) (48') ART .5 hrs, Total hrs on 1 bit = 10.54 hrs., Total hrs on jars = 43.02 hrs, 8-10 k WOB, 80 rpm's, ~~ 158 gpm, 10.0 ppg mw, on bottom pressure 1338 psi, off bottom pressure 1324 psi, on bottom torque 12k ft/Ib, off bottom torque 12k I ft/Ib, PU wt 240k, SO wt 125k, Rot wt 170k. ECD's = 11.23 ppg EMW. Max gas = 4970 units while drilling. I, Circulate LCM pill till out of drill string. Circ @ 156 gpm w/ 1310 psi. ' Rotate 80 rpm w/ 12k ft Ib torque. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 17789' to 17978' (6583' TVD) (189') ART 3.35 hrs, Total hrs on bit = 13.89 hrs., Total hrs on jars = 46.37 hrs, 0-8 k WOB, 80 rpm's, 154gpm, 10.0 ppg mw, on bottom pressure 1290-1340 psi, off bottom 'pressure 1250-1265 psi, on bottom torque 13-14k ft/Ib, off bottom 'torque 12k ft/Ib, PU wt 250-230k, SO wt 130k, Rot wt 165-168k. ECD's ' = 11.23-11.26 ppg EMW. Max gas = 4970 units while drilling. ~', Fluid loss f/ 1800 to 0600 hrs = 213 bbls Total fluid loss in last 24 hrs = 1143 bbls Total fluid loss since 3-15-2006 = 1978 bbls Printed: 4/28/2006 8:42:24 AM GonocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 3!24/2006 3/25/2006 From - To ', Hours Code Code Phase 00:00 - 06:00. 6.00 DRILL ', DRLH PROD 06:00 - 07:45 ' 1.75 DRILL I 07:45 - 08:45 08:45 - 10:00 10:00 - 11:00 11:00 - 12:15 12:15 - 13:00 13:00 - 18:00 ', 18:00 - 00:00 ',.00:00 - 06:00 DRLH 1.00 DRILL 'CIRC 1.251 DRILL I DRLH i 1.001 DRILL ;CIRC 1.25 DRILL ~ REAM 0.751 DRILL ,REAM 5.001 DRILL 'DRLH 6.001 DRILL 'DRLH PROD PROD PROD PROD PROD PROD PROD PROD 6.00 ~~ DRILL ,DRLH I PROD Page 46 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Directional drill 6-3/4" hole w/SperrySun 5200 series GeoPilot ser # TL-012 f/ 17978' to 18353' (6582.78' ND) (375') ART 3.73 hrs, Total hrs on bit = 17.62 hrs., Total hrs on jars = 50.1 hrs, 0-8 k WOB, 80 rpm's, 154 gpm, 10.0 ppg mw, on bottom pressure 1290-1340 psi, off bottom pressure 1250-1265 psi, on bottom torque 13-14k ft/Ib, off bottom torque 12k ft/Ib, PU wt 250-230k, SO wt 130k, Rot wt 165-168k. ECD's = 11.23-10.98 ppg EMW. Max gas = 4970 units while drilling. Fluid loss midnight to 0600 hrs = 211 bbls Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 18353' to 18448' (6578' TVD) (95') ART 1.11 hrs, Total hrs on bit = 18.73 hrs., Total hrs on jars = 51.21 hrs, 0-8 k WOB, 80 rpm's, 154 gpm, 10.0 ppg mw, on bottom pressure 1290-1340 psi, off bottom pressure 1250-1265 psi, on bottom torque 13-14k ft/Ib, off bottom torque 12k fUlb, PU wt 250-230k, SO wt 130k, Rot wt 165-168k. ECD's = 11.23-10.98 ppg EMW. Max gas = 4970 units while drilling. Circ and condition mud and hole. Increase pump rate to 208 gpm w! 1800 psi. Increase RPM f/ 80 to 120 w/ 15-16k ft Ib torque. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 18448' to 18537' (6578' TVD) (89') ART .95 hrs, Total hrs on bit = 19.68 hrs., Total hrs on jars = 52.16 hrs, 0-8 k WOB, 80 rpm's, 154 gpm, 10.0 ppg mw, on bottom pressure 1290-1340 psi, off bottom pressure 1250-1265 psi, on bottom torque 13-14k ft/Ib, off bottom torque 12k ft/Ib, PU wt 250-230k, SO wt 130k, Rot wt 165-168k. ECD's = 11.23-10.98 ppg EMW. Max gas = 4970 units while drilling. Survey. Circulate and condition hole. Pumping 175 gpm w/ 1470 psi. Stand back a stand, leaving stand #191 in hole (# 192 made up in string). Ream dog leg f/ 18340' to 18425'. Pumping 219 gpm w/ 1930 psi. Rotate 120 rpm w/ 15-16k ft Ib torque. Make up stand # 193. Ream 2-1/2 to 3 fpm w/ 5k WOB, from 18450' to 18537'. Pumping 220 gpm w/ 1930 psi. Rotate 40 rpm w/ 12-12k ft Ib torque. Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 18537' to 18777' (6572' TVD) (240') ART 3.81 hrs, Total hrs on bit = 23.49 hrs., Total hrs on jars = 55.97 hrs, 6-10 k WOB, 120-80 rpm's, 154-180 gpm, 10.0 ppg mw, on bottom pressure 1290-1485 psi, off bottom pressure 1250-11430 psi, on bottom torque 14-15k ft/Ib, off bottom torque 12-15k ft/Ib, PU wt 240-250k, SO wt 120-118k, Rot wt 168-170k. ECD's = 11.12 ppg EMW. Max gas = 4970 units while drilling. Fluid loss f/ 0600 hrs to 1800 hrs = 360 bbls Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 18777' to 18828' (6572' TVD) (51') ART 3.85 hrs, Total hrs on bit = 27.34 hrs., Total hrs on jars = 59.82 hrs, 6-8 k WOB, 80 rpm's, 230gpm, 10.0 ppg mw, on bottom pressure 2100 psi, off bottom pressure 2050 psi, on bottom torque 18-19k fUlb, off bottom torque 16-17k ft/Ib, PU wt 250k, SO wt 110k, Rot wt 165k. ECD's = 11.3 ppg EMW. Max gas = 4970 units while drilling. Fluid loss 1800 hrs to midnight = 235 bbls. Total fluid loss last 24 hrs = 806 bbls Pumped total of 4 LCM sweeps today. Total fluid loss since 3/15/2006 = 2784 BBIs Directional drill 6-3/4" hole w/SperrySun 5200 series GeoPilot ser # Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska 6.00 Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date From - To ' Hours -- 3/25/2006 ', 00:00 - 06:00 6.00 06:00 - 12:00 " 6.00 12:00 - 18:00 18:00 - 20:30 20:30 - 00:00 3/26/2006 00:00 - 00:30 00:30 - 02:00 02:00 - 06:00 '..06:00 - 11:30 ',11:30-12:00 ',12:00-14:30 Operations Summary Report Code '' Phase Code DRILL DRLH i PROD I I~ DRILL ~I DRLH i PROD DRILL DRLH ' PROD 2.50'i DRILL ', DRLH ',PROD 3.50 i. DRILL i CIRC ~ PROD I I II, i 0.50' DRILL I CIRC ''~ PROD 1.50 ! DRILL ~ CIRC I PROD 4.00' DRILL I TRIP I PROD 5.501 DRILL I TRIP I PROD 0.501 DRILL I OBSV I, PROD 2.501 DRILL I CIRC I PROD Page 47 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations TL-012 f/ 18828' to 18910' (6576.22' TVD) (82') ART 5.28 hrs, Total hrs on bit = 32.62 hrs., Total hrs on jars = 65.1 hrs, 6-10 k WOB, 80-120 rpm's, 230 gpm, 10.0 ppg mw, on bottom pressure 2148 psi, off bottom pressure 2110 psi, on bottom torque 17-18k ft/Ib, off bottom torque 16k ft/Ib, PU wt 250k, SO wt 110k, Rot wt 168k. ECD's = 11.35 ppg EMW. Max gas = 4970 units while drilling. Fluid loss f/ midnight to 0600 hrs = 310 bbls Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 18910' to 19053' (6589' TVD) (143') ART 5.03 hrs, Total hrs ion bit = 37.65 hrs., Total hrs on jars = 70.13 hrs, 10 k WOB, 80 rpm's, 1227 gpm, 10.0 ppg mw, on bottom pressure 2125 psi, off bottom ~, pressure 2050 psi, on bottom torque 14-17k ft/Ib, off bottom torque 15-13k ft/Ib, PU wt 245k, SO wt 115k, Rot wt 168k. ECD's = 11.33-11.37 ppg EMW. Max gas = 558 units while drilling. Pumped a 30 bbl volume 40 ppb LCM pill while drilling @ 18960' Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # TL-012 f/ 19053' to 19203' (6610' ND) (150') ART 5.45 hrs, Total hrs on bit = 43.1 hrs., Total hrs on jars = 75.58 hrs, 8-10 k WOB, 80-120 rpm's, 225-229 gpm, 10.0 ppg mw, on bottom pressure 2100 psi, off ' bottom pressure 2077 psi, on bottom torque 15-13k ft/Ib, off bottom ', torque 13-14k ftllb, PU wt 245-250k, SO wt 115k, Rot wt 168k. ECD's = ..11.33-11.21 ppg EMW. Max gas = 4970 units while drilling. Fluid loss f/ 0600 hrs to 1800 hrs = 420 bbls Directional drill 6-3/4" hole w/ SperrySun 5200 series GeoPilot ser # ' TL-012 f/ 19203' to 19269' (6628' TVD) (66') ART 1.96 hrs, Total hrs on 'bit = 45.06 hrs., Total hrs on jars = 77.54 hrs, 8-10 k WOB, 120 rpm's, ', 225-229 gpm, 10.0 ppg mw, on bottom pressure 2100 psi, off bottom pressure 2050 psi, on bottom torque 14k ft/Ib, off bottom torque 14-16k ft/Ib, PU wt 250k, SO wt 115k, Rot wt 168k. ECD's = 11.21 to 11.31 ppg ',EMW. Max gas = 2064 units while drilling. ', Rotate 120 rpm w/ 14k torque. Circulate @ 54 spm (228 gpm) w/ 2030 psi. ,Pumped 40 bbls, 40 ppb LCM pill, continue circulating till out of hole. Fluid loss f/ 1800 to midnight = 132 bbls ', Total fluid loss in last 24 hrs = 862 Total fluid loss sine 3/15/2006 = 3646 bbls Rotate 120 rpm w/ 14k torque. Circulate @ 54 spm (228 gpm) w/ 2030 '~, psi. Working string f/ 19269' to 19204'. Maintain 10.0 ppg MW. 1, Rotate 120 rpm w/ 14k torque. Circulate @ 54 spm (228 gpm) w/ 2030 psi. Pull a stand every hour f/ 19269' to 19016'. Maintain 10.00 ppg it MW. Pump out of hole f/ 19016' to 18260'. Pump 54 spm (228 gpm)w/ 2240 psi to 2000 psi. PU wt 250-270k, SO wt 115-110k @ 18260'. Record PU ~, and SO wt's every 5 stands. SLM on trip out of hole. Fluid loss f/ midnight to 0600 hrs = 146 bbls. li Pump out of hole f/ 18260' to 15624'. Pump 54 spm (228 gpm)w/ 2000 psi to 1980 psi. Record PU and SO wt's every 5 stands. SLM on trip out of hole. Observe well, flowing very little. Break circulation w/ 249 gpm and 2200 psi. Rotate @ 80 rpm w/ 11-12k ft Ib torque. Pump a 37 bbl, weighted to 12 ppg hi vis sweep. Pump @ 249 gpm w/ 2250 psi. Observed 50% increase at shakers. Sweep to surface w/ 715 bbls pumped. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 48 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To 'Hours '! Code I Sub Phase Description of Operations 3/26/2006 ',14:30 - 18:00 18:00 - 21:00 '..,21:00-21:30 !.21:30 - 22:00 22:00 - 23:30 23:30 - 00:00 3/27/2006 00:00 - 02:00 02:00 - 02:45 02:45 - 06:00 06:00 - 11:15 11:15 - 12:00 3/28/2006 -12:00 - 12:15 '',12:15-14:00 14:00 - 16:00 16:00 - 16:15 16:15 - 16:45 16:45 - 18:30 18:30 - 20:00 20:00 - 21:00 21:00 - 00:00 00:00 - 02:15 02:15 - 03:00 ' Code 3.50 DRILL I CIRC PROD Weight up mud system from 10.0 ppg to 10.4 ppg. Pumping 200 gpm I ~ w/ 1630 psi. Pu wt 250k, SO wt 120k. ' I Fluid loss f/ 0600 to 1800 hrs = 310 bbls. 3.00 DRILL ,CIRC PROD ~ Continue to weight up mud system f/ 10.00 ppg to 10.4 ppg. Pump 180 I, gpm w/ 1475 psi. 0.50 DRILL ' OBSV PROD ! Observ well-- static. Record SPR's. 0.50 DRILL ',TRIP PROD ~, POOH f/ 15624' to 15150' 1.50 DRILL ', OTHR PROD ',Work on getting trip tank pump to pump. Possible aired up mud. Bring ~' new 10.4 ppg mud into trip tank for hole fill. ' 0.50 DRILL 1 TRIP PROD s every 10 POOH f/ 15150' to 14680'. SLM. Record PU and SO wt I I I~ I I stands. Rabbit was dropped on stand # 156 in hole. ~~ ! Fluid loss f/ 1800 hrs to midnight = 101 bbls ', I Fluid loss f/ day = 557 bbls 2.00 DRILL ~1 TRIP I PROD '1 Fluid loss since 3/15/2006 = 4203 bbls. '~ POOH f/ 14680' to 13362'. SLM. Record PU and SO wt's every 10 I stands. A 2-5/16" rabbit was dropped on stand # 156 in hole. Pulling ' 1 speed 25-35 fpm. PU vrt 260k, SO wt 120k. 0.75 DRILL CIRC 1 PROD i I Monitor well. Pump 35 bbl dry job (13.0 ppg). Blow down top drive. 1 3.25 DRILL I TRIP ~ ~ ' PROD 1 Continue POOH f/ 14680' to 10095'. SLM. Record PU and SO wt's ! ~ every 10 stands. A 2-5/16" rabbit was dropped on stand # 156 in hole. 1 ~ ', PU wt 215k, SO wt 115k. 1 I 1 Fluid loss f/ midnight to 0600 hrs = 15 bbls. I 5.251 DRILL I TRIP ~ PROD li Continue POOH f/ 10095' to 3683'. SLM. Record PU and SO wt's every ' ', 1,10 stands. A 2-5/16" rabbit was dropped on stand # 156 in hole. 0.751 DRILL I, PULD ~ PROD ~ Lay down Weatherford Accelerators, stand back (2) stands ,Weatherford 4" HT38 drill pipe, lay down Daily DNT jars. 0.25', DRILL ',CIRC PROD I Pump dry job, blow down top drive. 1.75', DRILL 'TRIP PROD I POOH 33 stands Weatherford 4" dp (HT-38) f/ 3430' to 310'. 2.00', DRILL 'PULD PROD ', Lay down BHA # 10: L/D Weatherford x-o, (2) Weatherford 4" HWDP, ',Daily DNT jars (ser # 147-10019), (1) Weatherford 4" HWDP, i ',Weatherford x-o, NM flex collar, float sub, NM flex collar, and integral 'blade stabilizer. 0.25 !DRILL SFTY PROD ! PJSM on laying down Sperry Sun nuke sources. 0.50' DRILL OTHR PROD Remove nuke sources. 1.75 i DRILL ;, OTHR PROD Download Sperry Sun MWD/LWD tools. Fluid loss f/ 0600 hrs to 1800 hrs = 52 bbls. 1.50 !DRILL PULD ~ PROD ' VD Sperry Sun TM HOC, PWD tool, nuke tool, directional tool, ~~; '..Gamma/Res, smart stabilizer, GeoPilot flex collar, Sperry Sun Geopilot (ser # TL-012), and break off Security FSF 2641 bit (ser # 10799399). ', No correction to pipe tally from SLM. Calculated fill f/trip out f/ shoe = 95.5 bbls. Actual fill f/ shoe = 164.9 bbls. 69.4 bbls over talc. Over 22.5 'hrs of time lost 69.4 bbls 1.00', RIGMNT' RSRV PROD ':, Service top drive. Install new air intake filter. Clean rig floor. 3.00' CASE RURD CMPLTN RU to run 4-1/2", 12.6 ppf, BTC, slotted and blank liner w/ (6) swell j packers (easy well solutions). Total fluid loss f/ 1800 hrs to midnight = 14 bbls. II Total fluid loss today = 81 bbls. Total fluid loss since 3/15/2006 = 4284 bbls. 2.25'',. CASE ' RUNC ~ CMPLTN ' MU 5" Silver Bullet Guide shoe on 4 1/2" BTC 12.6# L-80 Blank casing, and continue RIH with 34 joints of blanks and slots as per detail to 1 11095'. Make up torque 5000 - 8000 ft/Ibs. Torque rings installed. 0.751,, CASE RURD CMPLTN :Observe 5 1/2" power tongs failed. Broken rollers due to torque. Rig ~ I down tongs and RU back up set of power tongs. Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Contractor Name: D15CM@conocophillips.com Rig Name: Doyon 15 Date 3/28/2006 03:30 - 04:00 0.50'' CASE ' 04:00 - 06:00 ' . 2.00'.' WAITf 06:00 - 06:30 0.50 ! WAITc From - To ~', Hours; Code ''Code' Phase 03:00 - 03:30 0 50I CASE RUNC CMPLTN '::06:30 - 07:00 107:00 - 07:15 07:15 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 12:30 i 12:30 - 18:00 ~~ I ~I~ 18:00 - 21:00 ii 21:00 - 21:45 21:45 - 00:00 3/29/2006 00:00 - 01:15 01:15 - 03:30 03:30 - 03:45 03:45 - 06:00 106:00 - 07:15 107:15 - 07:30 0.50 j CASE 0.25' CASE 3.25' CASE 1.00; CASE 0.50' CASE RUNC CMPLTN EOIP CMPLTN EOIP CMPLTN RURD CMPLTN RUNC CMPLTN RUNC CMPLTN RUNL CMPLTN RUNL CMPLTN 0.50' CASE CIRC CMPLTN 5.50', CASE RUNL CMPLTN I 3.00 CASE I RUNL I CMPLTN 0.75' RIGMNT RGRP CMPLTN 2.25!. CASE RUNL I CMPLTN 1.25', CASE ~, RUNL I CMPLTN 2.25' CASE I CIRC I CMPLTN 0.25' CASE I RUNL I CMPLTN 2.25', CASE ~ RUNL I CMPLTN 1.25', CASE I RUNL CMPLTN 0.251 CASE RUNL CMPLTN Page 49 of 53 Spud Date: 1/31/2006 Start: 1/28/2006 End: 4/2/2006 Rig Release: 4/2/2006 Group: Rig Number: 15 Description of Operations Continue RIH with 4 1/2" BTC 12.6# L-80 & 4 joints of slots as per detail to 1200'. Make up torque 5000 - 8000 fUlbs. Torque rings installed. Make up #1 Swell Packer as per detail. MU torque = 4000 FT/LBS. Observe back up set of power tongs failed. Broken rollers. Install crossover and Floor valve. Rig down power tongs. Call for back up set. Wait on tongs. Crew change. Continue wait on back up set of power tongs coming from Deadhorse. PJSM with crew. Discuss safety issues and procedure for 4 1/2" liner run. Pull tools to floor & Rig up back up set of 7 5/8" power tongs. Remove & lay down floor valve and crossover. RU to run 4 1/2" liner. Continue run 4 1/2" L-80 12.6# liner form 1550' - 3753' (2203'). Total of 92 joints run. 26 Blank joints, and 67 Slotted joints. Ran 6 Total Swell Packers spaced for depths of 17,678', 17,498', 17,119', 16,932', 16,796', and 16,640' when liner is landed. Total of 92 Spiral Glider Centralizers ran. 1 per joint -floating. Make up Baker 190-47 Casing Seal Bore Extension with crossover (21.05'), Baker 5 1/2" x 7 5/8" Flexlock Liner Hanger (9.82'), RS Packoff Seal Nipple 5 1/2" x 7 5/8" (2.84', and HRD ZXP Liner Top Packer 5 1/2" x 7 5/8" (18.62'), as per BOT rep. MU Liner running tool, and setting tool (11.07'). Install crossover from 3 1/2" IF to HT-38 (2.17'). RIH with 4" drill pipe from derrick. Running speed = 50 -60 ft/minute. Fill drill string every 10 stands. Continue RIH with liner on drill string from 4000' - 4713'. Fill drill string, obtain torque & drag parameters as per rig engineer. UP WT = 107K, SO WT = 102K. Continue RIH with liner on drill string from 4713' - 8497'. Fill drill string every 10 stands, obtain torque & drag parameters as per rig engineer. UP WT = 150K, SO WT = 110K. Fluid losses for day to 1800 HRS = 61 BBLS. Crew Change. Continue RIH with liner on drill string from 8497' - 11617'. Fill drill string every 10 stands, obtain torque & drag parameters as per rig engineer. UP WT = 175K, SO WT = 115K. Observe hydraulic hose broke on Iron Roughneck. Repair hose. Continue RIH with liner on drill string from 11617' - 14420'. Fill drill string every 10 stands, obtain torque & drag parameters as per rig engineer. UP WT = 205K, SO WT = 120K. Total fluid loss for day = 81 BBLS. Continue RIH with liner on drill string from 14420' - 15634'. Fill drill string every 10 stands, obtain torque & drag parameters as per rig engineer. UP WT = 225K, SO WT = 120K. At the shoe, Circulate bottoms up @ 3 BPM - 840 PSI, as per BOT rep. Spot 50 BBL pill with 2 drums of EP mud lube in annulus. UP WT = 220K, SO WT = 130K. Observe no gas on bottoms up. Monitor well - static. Record Parameters. UP WT = 220K, SO WT = 128K, ROT WT =160K, 25 RPM's @ 9K TO. Mud wt = 10.4 PPG, 58 Visc. Continue RIH with liner on drill string from 15634' - 18451'. Obtain torque & drag parameters as per rig engineer. UP WT = 250K, SO WT = 118K. Crew Change Continue RIH with 4 1/2" liner to tag bottom @ 19247' DPM. Record and confirm depths with BOT rep, and Co. Man. Pull up to Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Page 50 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To '! Hours Code ' Sub 'Code --- - _ ___ 3/29/2006 ~i 07:15 - 07:30 '~ 0.251 CASE ' RUNL 07:30 - 09:15 1.75 CASE OTHR 09:15 - 10:00 '', 0.751 CASE ', OTHR ~ ~I ~ 10:00 - 10:30 '~ 0.50 ~ 1 ~ CASE 1 OTHR 1.50 110:30 - 12:00 1 CASE 1 CIRC ~I 12:00 - 13:45 I 1.75 j CASE 1 CIRC 13:45 - 14:00 ~!~ 0.25 CASE OTHR 14:00 - 14:15 '' 0.25 CASE CIRC 14:15 - 14:30 ~1 0.25 CASE SFTY 14:30 - 18:00 ' 3.50 CASE OTHR 18:00 - 00:00 I 6.00 CASE OTHR 3/30/2006 ~, ~ 00:00 - 02:00 ' 2.00 1 CASE OTHR 02:00 - 02:30 '~ 0.50 CASE OTHR 02:30 - 05:30 I 3.00 CASE OTHR 105:30 - 06:00 '' 0.50 I CASE 1 OTHR li 06:00 - 08:15 2.25 CASE OTHR 08:15 - 08:30 ', 0.25 RIGMNT SFTY 108:30 - 09:30 1.00 11 RIGMNT RSRV 09:30 - 12:00 ', 2.50 1 CASE OTHR 12:00 - 13:15 ' 1.251 CASE I OTHR 13:15 - 13:30 ', 0.25 CMPLTNI OTHR 13:30 - 13:45 I 0.25, CMPLTNI OTHR 13:45 - 14:45 ' 1.00 ~ CMPLTNI RURD 14:45 - 15:00 I 0.251 CMPLTNI SFTY Phase ' Description of Operations CMPLTN 1~ position 4 1/2" Liner Tail @ 19247 as per running detail for Swell ~~ Packer placements. Liner top = 15494' DPM. CMPLTN Drop a 1 3!4" Ball in drill string. Allow to fall, and pump ball down 4 BPM - 850 PSI. Slow rate to 2 BPM to observe ball seated. Pressure to ~ 1500 PSI, set down 70K weight, and continnue to pressure to 4000 PSI as per BOT rep to set Liner Hanger and ZXP. Bleed all pressures. UP i WT = 250K, SO WT = 118K. CMPLTN ;Close annular, and pressure down annulus to 1500 PSI for 10 minutes ; as per BOT rep.. Bleed pressures. Pull up to observe setting tool free from liner. UP WT = 220K. CMPLTN 'POOH, stand back stand # 165. Breakout 8~ lay down 1 more single. CMPLTN 'Make up Top Drive, and Circulate @ 6.5 BPM - 1750 PSI. No rotation. ' UP WT = 220K, SO WT = 128K. CMPLTN 'I Continue Circulate @ 6.5 BPM - 1750 PSI. No rotation. UP WT = 220K, SO WT = 128K. Observe no gas on bottoms up. CMPLTN I Monitor well for 15 minutes. Static. CMPLTN !..Mix & pump dry job for POOH. CMPLTN I Blow down Top Drive and all lines. PJSM with crew. Discuss safety issues and procedure for POOH laying down drill pipe. CMPLTN ', POOH from 15438' - 12147 (3291'). Breakout & lay down 4" Drill pipe ',visually inspecting pipe for wear issues. Total Fluid Loss for day = 161 'BBLS. CMPLTN I POOH from 12147 - 6351' (5796'). Breakout & lay down 4" Drill pipe ',visually inspecting pipe for wear issues. Total Fluid Loss for day = 161 '~ BBLS. CMPLTN ~ POOH from 12147 - 3701' (2650'). Breakout & lay down 4" Drill pipe 'visually inspecting pipe for wear issues. CMPLTN 'Caught up with dry job in hole. Drill pipe coming wet. Mix & pump small !,dry job to POOH. CMPLTN ', POOH from 3701' to surface. Breakout & lay down 4" Drill pipe visually ',inspecting pipe for wear issues. Total layed down = 492 joints. CMPLTN 'Inspect & Breakout liner running tool and setting tools. Calculated hole 'fill = 90.42 BBLS, Actual hole fill 115.13 BBLS. Crew Change. Total ',Fluid losses from midnight = 59 BBLS. CMPLTN '~, Run in hole with 4"drill pipe from derrick to 3675'. 39 stands. CMPLTN ': PJSM with crew. Discuss safety issues and procedure for slipping & cutting drilling line with new hands on crew. CMPLTN 'Slip 8 cut 102' of drilling line. Inspect brake linkage & Top Drive. CMPLTN ', POOH from 3675' - 1189'. (2486'). Break out & lay down 4" drill pipe ;visually inspecting pipe for wear issues. CMPLTN ', POOH from 1189'. Break out & lay down 4" drill pipe visually inspecting 1 pipe for wear issues. Total layed down = 117 joints. CMPLTN I Make up test joint with wear ring puller. CMPLTN '~, Drain BOP stack. BOLDS. RIH engage wear ring and pull same out of hole. Lay down wear ring, puller and test joint. CMPLTN 1, Pull equipment to floor and Rig up to run 4 1/2" completion string. CMPLTN 'PJSM with crew. Discuss safety issues and procedure for running 4 1/2" Completion string. Double check equipment in pipe shed and ' running orders as per Co. Man. 15:00 - 18:00 ', 3.001 CMPLTNI RUNT CMPLTN ' Make up Baker seal assembly (40.13') with Locator sub (1.71'), and pup 1, (5.82'). MAke up 3 joints of 4 1/2" IBT 12.6# L80 tubing (90.86'), and 1 Camco DB nipple with 3.813" ID profile (1.53'). Continue pick up 46 ', ' more joints and make up Camco 4 1/2" x 1" GLM with Dummy valve. I Printed: 4/28/2006 8:42:24 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Event Name: ROT -DRILLING Start: 1/28/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Rig Name: Doyon 15 Rig Number: 15 Date 3/30/2006 3131 /2006 From - To Hours Code Code' Phase 15:00 - 18:00 18:00 - 00:00 3.00 6.00 CMPLTN RUNT CMPLTN RUNT Page 51 of 53 Spud Date: 1/31/2006 End: 4/2/2006 Group: Description of Operations CMPLTN ~ Make up torque = 3800 Ft/Lbs. Crew change. CMPLTN Continue RIH with 4 1/2" L80 12.6# IBT tubing from 1577' - 6802' (5225'). Installing Camco 4 1/2" x 1" GLM's with Dummy valves as per running detail. Make up torque = 3800 FT/LBS. NOTE: SIMOPS. PJSM with Little Red Services. RU to flush 10 3/4" x 7 5/8" annulus, and freeze protect. Pressure test @ 3000 PSI. Good test. Pump at 1 BPM to observe break over at 1600 PSI, (14.95 PPG MWE) and drop to ~ 1200 PSI. Increase pump to 2.0 BPM, 1600 PSI pumping 270 BBLS 8.3 PPG water, and then 100 BBLS freeze protect diesel, for a final shut in pressure of 1000 PSI. Recorded on chart. 10.3 PPG mud in annulus. 6.00',, CMPLTNI RUNT 'CMPLTN Continue RIH with 4 1/2" L80 12.6# IBT tubing from 6802' - 12240' (5438'). Installing Camco 4 1/2" x 1" GLM's with Dummy valves, and 06:00 - 10:45 '; 4.75 i CMPLTN'i RUNT ~ II '.10:45 - 11:15: 0.5011 CMPLTN' RUNT ICI 00:00 - 06:00 11:15 - 12:00 I ~I 0.75 12:00 - 12:30 i I 0.50 12:30 - 15:45 3.25 15:45 - 16:45 '~ 1.00 16:45 - 17:15 0.50 17:15 - 18:00 I 0.75 18:00 - 20:15 20:15 - 20:30 20:30 - 22:00 22:00 - 22:15 22:15 - 23:00 CMPLTN'..,, RUNT i CMPLTNI SFTY CMPLTNI CIRC ~i CMPLTNI CIRC CMPLTN CIRC CMPLTN CIRC 2.25 !CMPLTNI, CIRC 0.25 CMPLTNI, SFTY I 1.50'' CMPLTNII CIRC 0.25', CMPLTN! RUNT 0.75' CMPLTN! OTHR 3.813" DB Nipple as per running detail. Make up torque = 3800 FT/LBS. ;CMPLTN Continue RIH with 4 1/2" L80 12.6# IBT Tubing From 12240' - ~I 15555.51'. (3311'). Observe seals going into Seal bore, and RIH to tag ~ on Locator with tubing tail @ 15555.5. UP WT = 200K, SO WT = 112K. I'~, CMPLTN Rig up, Close Annular Preventer. Pressure down tubing annulus to 1000 PSI - 10 Minutes. Verify Seals on depth and holding. Bleed i I pressure and blow down lines. Tagged 13' Deep as per Tubing Tally. I, ;Baker Seal Assembly Locator depth = 15513.67 I 'Mule shoe depth = 15555.51' 10 3/4" x 7 5/8" Annulus = 700 PSI. CMPLTN POOH & lay down 3 Joints of 4 1/2" tubing. Install 5.83' space out pup, 'and MU 1 joint of tubing for correct space out as per Co. Rep & Baker Rep. Make up 11" Tubing hanger, and landing joint. Install pump in sub, ',and RU to to displace. CMPLTN ,Held PJSM with crew and all Truck Drivers. Designate Spill Champions, 'and Discuss safety issues and procedure for Displacing well with 10.4 ', PPG Brine. CMPLTN ', Pull up high enough to allow tubing tail above top of liner @ 15494'. 'Pump 79 BBLS of High Visc Spacer, Displace well with 10.4 PPG Brine ', @ 7 BPM - 750 PSI. CMPLTN ',Continue circulating swapping over to 10.4 PPG brine with Corrossion Inhibitor, at 7 BPM - 750 PSI, spotting inhibitor with 2961 strokes, 296 'BBLS. CMPLTN '~, Continue Displacing 1%Corrossion Inhibted Brine with 230 BBLS to 1 spot @ base of permafrost per well program. 1 CMPLTN I Slow pumps to 2 BPM - 100 PSI. It was observed that Corrosion I Inhibitor was never added to Brine at the MI mud plant as requested: Circulate while Standby for truck to return to location with Inhibited Brine. SIMOPS: Prepare cellar for ND / NU. Send tools out for shipping back to Materials. Crew Change. ,CMPLTN Continue Circulate @ 2 BPM - 100 PSI. Wait on Vac Truck to return with Corrosion Inhibited Brine. i CMPLTN ,Held PJSM with new crew. Discuss Safety Isuues and procedure for 'pumping 10.4 PPG Corrosion Inhibited Brine. Designate Spill Champion. 'CMPLTN Pump 225 BBLS of 10.4 PPG brine with 1 %Corrossion Inhibitor, ', Chaing with 250 BBLS of Brine to spot at base of permafrost, at 7 BPM - 750 PSI. Fluid loss rate = 12 BPH. '~ CMPLTN Drain BOP stack and land tubing. UP WT = 220K, SO WT = 120K. I, CMPLTN 1, Verify hanger landed ~ run in Lock Down Screws, as per FMC reps. Printed: 4/28!2006 8:42:24 AM ConocoPhillips Alaska Page 52 of 53 Operations Summary Report Legal Well Name: 1 D-41 Common Well Name: 1 D-41 Spud Date: 1/31/2006 Event Name: ROT -DRILLING Start: 1/28/2006 End: 4/2/2006 Contractor Name: D15CM@conocophillips.com Rig Release: 4/2/2006 Group: Rig Name: Doyon 15 Rig Number: 15 Date From - To -- 3/31 /2006 i 23:00 - 23:30 ,' 23:30 - 23:45 23:45 - 00:00 4/1/2006 00:00 - 02:30 '~ I i ~, 02:30 - 06:00 'I ~~ 06:00 - 09:45 09:45 - 10:00 10:00 - 10:45 i 10:45 - 11:00 11:00 - 11:30 11:30 - 12:00 12:00 - 13:30 ' 13:30 - 14:00 II ;14:00 - 14:30 .!14:30-15:30 15:30 - 16:00 16:00 - 18:00 18:00 - 20:15 Hours Code Sub 'Code 0.50 ~ CMPLTN. OTHR 0.25 CMPLTN! OTHR 0.25 CMPLTN'' OTHR 2.501 CMPLTN' NUND 3.50 ~1 CMPLTN NUND I I 3.7511 CMPLTN NUND 0.25' CMPLTN SEOT 0.75'; CMPLTN SEOT 0.25! CMPLTNSEOT 0.50 i CMPLTN SEOT 0.50j CMPLTN NUND 1.50' CMPLTN NUND 0.50 !CMPLTNI DEOT 0.50' CMPLTNI FRZP 1.00' CMPLTN FRZP 0.50'' CMPLTNI FRZP 2.00 ;CMPLTNI NUND 2.25 ~, CMPLTNI RURD Phase ' Description of Operations CMPLTN Rig up and pressure test down tubing annulus to 1000 PSI - 10 minutes. Record on chart. Good test. Seals landed and located correctly. Bleed all pressures. CMPLTN ', Breakout Lay down pump in sub and lines. Back out and lay down 'landing joint. CMPLTN 'Make up dry rod as per FMC rep and install TWC. Lay down rod. Total Fluid Loss for day = 18 BBLS. CMPLTN ,PJSM with crew. Discuss safety issues and procedure for changing out ', rams, and nippling down and up. Change out rams in BOP stack to j install 4 1/2" x 7" variable bore rams in top set, and 3 1/2" x 6" rams in '~ bottom set. CMPLTN I Nipple down BOP stack and Iines.Pull Mouse hole & flow lines. ND Bell Nipple & Riser. NOTE:. Drill site operator shut in and safed out the ' 1 D-42 well in cellar. Crew Change CMPLTN Prepare Well head ~ DSA for NU. Nipple up Double studded adapter I, flange & Tree. CMPLTN ~ Pressure up to 5000 PSI - 10 minutes & test Adapter Flange. CMPLTN Rig up Lines from Little Red Services on Tree. Rig Up lines on Annulus. CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN ~~ 20:15 - 00:00 I I 3.75 I MOVE I DMOB I DEMOB 4/2!2006 '~ 00:00 - 02:00 I 2.00 MOVE ' DMOB '', DEMOB 02:00 - 06:00 4.00 MOVE DMOB ' DEMOB 106:00 - 00:00 ' 18.00 MOVE ..MOVE ',DEMOB Pressure test lines from Little Red to 5000 PSI. Pressure test Tree to 250 PSI low test, & 5000 PSI. Hold pressure 10 minuntes, good test. Bleed all pressures. Pull Tree cap & RU Lubricator. Pull TWC as per FMC rep. Lay down Lubricator. Install Tree cap with 1502 unions & lines. PJSM with crew and Little Red. Discuss safety issues and procedure for testing and freeze protecting well. Designate Spill Champions. Pump down annulus with freeze protect diesel to 1500 PSI -hold for 10 minutes. Continnue Pressure to 2000 PSI, hold for 10 minutes. Continnue pumping to 2500 PSI and observe DCK valve shear @ 2500 PSI. NOTE: MITIA test to 2500 PSI not completed as planned as the DCK valve sheared early. Planned shear @ 3000 PSI. Continue pumping down annulus with 105 BBLS of Freeze protect Diesel at 2 BPM - 1000 PSI. Final Circulating Pressure = 1050 PSI. Allow well to U-Tube from Annulus to tubing. Monitor well. Final Pressure = 275 PSI. Using Little Red, suck out all lines with Diesel, and rig down all lines and Little Red Services. Rig up FMC lubricator and install BPV as per FMC rep. Lay down Lubricator. Crew Change. Remove secondary valve on annulus. Install flanges & gauges on 4 112" x 7 5/8" annulus, and 7 5/8" x 10 3/4" annulus. Close all valves record shut in pressures. 10 3/4" x 7 5/8" annulus = 605 PSI. 7 5/8" x 4 1/2" annulus = 275 PSI. Tubing Shut in pressure= 300 PSI. NOTE: Rig Weldewr cut off 45 degree nipples form conductor and welded caps on holes. Secure Tree and Clean cellar box. SIMOPS Cleaning all pits. Continue Clean pits and demob rig, preparing for move. Continue Suck out & clean all pits. Rig released @ 0200 HRS. 4/2/06 Continue Demobilize rig. Skid Rig Floor and Derrick. Prepare Pit Module and Sub base. Raise stompers in cellar. Move Pit Module away from sub base. Move Sub Base away from well Printed: 4/28/2006 8:42:24 AM Printed: 4/28/2006 8:42:24 AM Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 "time: 14:07:43 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Iiefcrencc: Well: 1 D-41, True N orth Site: Kuparuk 1 D Pad Vertical (TVD) Reference: 10-41:110.9 Well: 1D-41 Section (VS) Reference: Well (O.OON,0.04E,1 00.OOAzi) Wellpath: 1 D-41 Survey Calculation M ethod: Minimum Curvature llb: Oracle Field: Kuparuk River Unit ', North Slope Alaska United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ', Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 ', Well: 1 D-41 Slot Name: Well Position: +N/-S -552.14 ft Northing : 5959114.19 ft' Latitude: 70 17 55.887 N +E/-W -419.85 ft Easting : 560671.14 ft ' Longitude: 149 30 31.160 W Position Uncertainty: 0.00 ft Wellpath: 1 D-41 Drilled From: 1 D-41 PB2 ', 500292328800 Tie-on Depth: 15658.88 ft ', Current Datum: 1 D-41 : Height 110.90 ft Above System Datum: Mean Sea Level Magnetic Data: 1/10/2006 Declination: 24.24 deg Field Strength: 57568 nT Mag Dip Angle: 80.80 deg I Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' ft ft ft deg r 41.40 0.00 0.00 100.00 I Survey Program for Definitive Wellpath ', I Date: 4/25/2006 Validated: No Version: 1 ' I Actual From To Survey Toolcode Tool Name ~ ft ft - ~ - 81.00 800.00 1 D-41 PB1 gyro (81.00-800.00) ( - CB-GYRO-SS Camera based gyro single shot 858.35 13611.48 1 D-41 P61 (858.35-15894.15) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13707.00 15658.88 1 D-41 PB2 (13707.00-16079.44) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ 15699.00 19203.38 1 D-41 (15699 .00-19203 .38) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ Survey ____ __ __ ', b1D Incl Azim TVD Sys TVD N/S E/W MapN N1apE Tool ', ft deg deg ft ft ft ft ft ft 41.40 0.00 0.00 41.40 -69.50 0.00 0.00 5959114.19 560671.14 TIE LINE 81.00 0.30 7.84 81.00 -29.90 0.10 0.01 5959114.29 560671.15 CB-GYRO-SS 100.00 0.35 343.30 100.00 -10.90 0.21 0.00 5959114.40 560671.14 CB-GYRO-SS i 200.00 0.68 151.14 200.00 89.10 -0.02 0.20 5959114.17 560671.34 CB-GYRO-SS I 300.00 4.70 121.94 299.87 188.97 -2.71 3.97 5959111.51 560675.13 CB-GYRO-SS 400.00 7.27 113.68 399.32 288.42 -7.42 13.24 5959106.88 560684.44 CB-GYRO-SS I~ 500,00 9.16 108.38 498.29 387.39 -12.47 26.59 5959101.94 560697.83 CB-GYRO-SS 600.00 11.90 102.22 596.60 485.70 -17.16 44.22 5959097.39 560715.50 CB-GYRO-SS 700.00 13.10 102.58 694.23 583.33 -21.81 65.36 5959092.91 560736.67 CB-GYRO-SS 800.00 13.61 100.59 791.52 680.62 -26.44 87.99 5959088.46 560759.33 CB-GYRO-SS 858.35 14.43 106.22 848.14 737.24 -29.74 101.72 5959085.28 560773.08 MWD+IFR-AK-CAZ-SC ~~, 953.59 18.53 107.33 939.44 828.54 -37.56 127.57 5959077.66 560799.00 MWD+IFR-AK-CAZ-SC ', 1047.87 21.75 105.42 1027.95 917.05 -46.67 158.72 5959068.81 560830.22 MWD+IFR-AK-CAZ-SC ICI 1142.65 22.99 104.08 1115.59 1004.69 -55.84 193.60 5959059.92 560865.17 MWD+IFR-AK-CAZ-SC ' 1237.05 26.08 101.99 1201.46 1090.56 -64.64 231.79 5959051.43 560903.42 MWD+IFR-AK-CAZ-SC , 1334.26 30.19 104.11 1287.17 1176.27 -75.04 276.42 5959041.39 560948.13 MWD+IFR-AK-CAZ-SC 1427.24 30.78 104.12 1367.30 1256.40 -86.55 322.16 5959030.25 560993.96 MWD+IFR-AK-CAZ-SC ~, 1473.11 31.70 103.32 1406.51 1295.61 -92.19 345.27 5959024.80 561017.11 i MWD+IFR-AK-CAZ-SC 1523.43 32.55 101.68 1449.13 1338.23 -97.97 371.40 5959019.23 561043.28 t MWD+IFR-AK-CAZ-SC 1552.87 32.82 102.11 1473.91 1363.01 -101.25 386.95 5959016.08 561058.86 MWD+IFR-AK-CAZ-SC 1619.86 37.14 100.74 1528.79 1417.89 -108.83 424.59 5959008.80 561096.55 MWD+IFR-AK-CAZ-SC ' 1714.34 43.88 100.77 1600.58 1489.68 -120.28 484.85 5958997.84 561156.90 MWD+IFR-AK-CAZ-SC I 1808.80 47.09 99.94 1666.79 1555.89 -132.37 551.10 5958986.28 561223.24 MWD+IFR-AK-CAZ-SC ~i 1903.90 52.69 100.97 1728.04 1617.14 -145.59 622.59 5958973.64 561294.83 MWD+IFR-AK-CAZ-SC 1994.29 60.49 101.41 1777.77 1666.87 -160.23 696.55 5958959.60 561368.90 MWD+IFR-AK-CAZ-SC 2093.58 63.19 102.40 1824.63 1713.73 -178.30 782.19 5958942.23 561454.67 MWD+IFR-AK-CAZ-SC 2187.11 66.49 100.64 1864.39 1753.49 -195.19 865.13 5958926.01 561537.74 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. ', Field: Ku paruk River Unit Sire: Ku paruk 1 D Pad Well: 1D -41 ~Vellpath: 1 D -41 Survc~ ~~ MD Incl Azim ft deg deg 2280.61 64.38 101.47 2379.50 68.45 101.55 2474.74 71.32 99.37 2569.80 72.07 100.05 2664.83 71.50 98.43 2762.41 70.21 97.27 2857.46 69.85 97.19 2953.89 70.22 97.64 3052.32 69.17 97.43 3147.29 67.94 98.97 3242.02 66.93 100.45 3336.35 68.93 103.83 3432.15 72.35 105.43 3527.68 3622.62 3710.80 3745.36 3810.24 71.35 68.05 66.91 67.85 66.23 106.14 107.47 108.11 107.83 108.19 TVD Sys TVD ft ft 1903.26 1792.36 1942.82 1831.92 1975.57 1864.67 2005.42 1894 .52 2035.13 1924 .23 2067.13 1956 .23 2099.60 1988 .70 2132.52 2021 .62 2166.68 2055 .78 2201.40 2090 .50 2237.75 2126 .85 2273.20 2162 .30 2304.96 2194 .06 2334 .72 2223. 82 2367 .65 2256. 75 2401 .43 2290. 53 2414 .72 2303. 82 2440 .03 2329. 13 3909. 00 65. 02 106 .96 2480. 79 2369. 89 4005. 84 70. 78 106 .26 2517. 20 2406. 30 4096. 87 71. 44 106 .02 2546. 67 2435. 77 4193. 26 68. 45 106 .37 2579. 73 2468. 83 4289. 61 67. 14 105 .67 2616. 14 2505. 24 4384. 85 69. 19 104 .50 2651. 56 2540. 66 4480. 25 70. 35 103 .53 2684. 55 2573. 65 4574. 60 71. 22 101 .45 2715. 60 2604. 70 4668. 23 70. 87 101 .00 2746. 02 2635. 12 4762. 10 69. 79 101 .19 2777. 61 2666. 71 4855. 30 70. 08 100 .01 2809. 59 2698. 69 4951. 60 70. 06 99 .36 2842. 42 2731. 52 5047. 06 72. 54 99 .75 2873. 02 2762. 12 5141. 55 73. 62 100 .19 2900. 52 2789. 62 5235. 35 71. 76 98 .20 2928. 43 2817. 53 5329. 58 69. 06 98 .77 2960. 02 2849. 12 5426. 15 67. 26 99 .55 2995. 95 2885. 05 5523. 21 64. 68 99 .76 3035. 47 2924. 57 5617. 68 63. 80 99 .25 3076. 52 2965. 62 5709. 88 68. 56 98 .71 3113. 75 3002. 85 5804. 06 71 .40 98.13 3145. 99 3035. 09 5903. 97 71 .25 98 .01 3177. 98 3067. 08 5999. 13 72 .21 98 .37 3207. 81 3096. 91 6090. 59 73 .08 98 .89 3235. 09 3124. 19 6142. 39 71 .76 98 .53 3250. 74 3139. 84 6184. 87 71 .26 98 .56 3264. 21 3153. 31 6286. 31 68 .27 100 .16 3299. 29 3188. 39 6314. 23 68 .05 99 .80 3309. 68 3198. 78 6380. 14 68 .27 99 .98 3334. 20 3223. 30 6475. 73 67 .56 101 .26 3370. 14 3259. 24 6570. 65 66 .22 102 .37 3407. 40 3296. 50 6664. 00 66 .61 101 .93 3444. 75 3333. 85 6761. 41 63 .90 102 .69 3485. 52 3374. 62 6856. 16 64 .75 103 .62 3526. 57 3415. 67 6945. 51 68 .41 103 .86 3562. 08 3451. 18 Date: 4/25/2006 'l'ime: 14:07:43 Page: 2 Co-ordinate(NE) Reference. Well: 1D-41, True North Vertical (TVD) Reference: 1 D-41:110.9 Section (VS) Reference: Well (O.OON,0.04E,100.OOAzi) Surrey Calculation Method: Minimum Curvature Db: Oracle V/S ENV MapN ft ft ft -211 .49 948. 59 5958910. 39 -229 .57 1037. 38 5958893. 03 -245 .79 1125. 31 5958877. 52 -261 .01 1214. 26 5958863. 02 -275 .50 1303. 36 5958849. 24 -288. 10 1394. 67 5958837. 39 -299. 34 1483. 29 5958826. 86 -311. 04 1573. 17 5958815. 89 -323. 14 1664. 69 5958804. 53 -335. 75 1752. 17 5958792. 63 -350. 49 1838. 39 5958778. 58 -368. 89 1923. 83 5958760. 88 -391. 73 2011. 27 5958738. 75 -416. 42 2098. 62 5958714. 76 -442. 15 2183. 85 5958689. 73 -467. 03 2261. 41 5958665. 47 -476. 88 2291. 75 5958655. 88 -495. 35 2348. 56 5958637. 87 -522. 51 2434. 32 5958611. 40 -548 .14 2520. 26 5958586. 47 -572 .08 2603. 00 5958563. 20 -597 .33 2689. 94 5958538. 65 -621 .95 2775. 68 5958514. 73 -644 .95 2861. 03 5958492. 42 -666 .62 2947. 88 5958471. 45 -685 .89 3034. 86 5958452. 89 -703 .12 3121. 72 5958436. 36 -720 .13 3208. 46 5958420. 05 -736 .24 3294. 50 5958404. 65 -751 .47 3383. 75 5958390. 14 -766 .48 3472. 90 5958375. 85 -782 .13 3561. 94 5958360. 92 -796 .44 3650. 33 5958347. 32 -809 .54 3738. 12 5958334. 93 -823 .80 3826. 62 5958321. 38 -838 .67 3914. 00 5958307. 23 -852 .72 3997. 91 5958293. 86 -865. 87 4081. 20 5958281. 37 -878. 83 4168. 73 5958269. 13 -892. 11 4262. 44 5958256. 60 -904. 99 4351. 88 5958244. 45 -918. 09 4438. 19 5958232. 05 -925. 56 4487. 00 5958224. 97 -931. 55 4526. 84 5958219. 30 -947. 01 4620. 74 5958204. 60 -951. 51 4646. 26 5958200. 31 -962 .01 4706. 53 5958190. 29 -978 .34 4793. 59 5958174. 68 -996 .21 4879. 04 5958157. 50 -1014 .21 4962. 67 5958140. 17 -1033 .06 5049. 10 5958122. 02 -1052 .50 5132. 25 5958103. 26 -1071 .97 5211. 88 5958084. 43 MapE Tool ft ___ 561621.31 MWD+IFR-AK-CAZ-SC 561710.24 MWD+IFR-AK-CAZ-SC 561798.29 MWD+IFR-AK-CAZ-SC 561887.35 MWD+IFR-AK-CAZ-SC 561976.55 MWD+IFR-AK-CAZ-SC 562067.96 MWD+IFR-AK-CAZ-SC 562156.66 MWD+IFR-AK-CAZ-SC 562246.62 MWD+IFR-AK-CAZ-SC 562338.22 MWD+IFR-AK-CAZ-SC 562425.80 MWD+IFR-AK-CAZ-SC 562512.13 MWD+IFR-AK-CAZ-SC 562597.70 MWD+IFR-AK-CAZ-SC 562685.31 MWD+IFR-AK-CAZ-SC 562772.85 MWD+IFR-AK-CAZ-SC '~ 562858.28 MWD+IFR-AK-CAZ-SC 562936.03 MWD+IFR-AK-CAZ-SC ~', 562966.45 MWD+IFR-AK-CAZ-SC 563023.40 MWD+IFR-AK-CAZ-SC 563109.36 MWD+IFR-AK-CAZ-SC 563195.50 MWD+IFR-AK-CAZ-SC 563278.42 MWD+IFR-AK-CAZ-SC '~ 563365.56 MWD+IFR-AK-CAZ-SC ~ 563451.48 MWD+IFR-AK-CAZ-SC 563537.01 MWD+IFR-AK-CAZ-SC 563624.02 MWD+IFR-AK-CAZ-SC ~ 563711.15 MWD+IFR-AK-CAZ-SC ' 563798.13 MWD+IFR-AK-CAZ-SC 563885.00 MWD+IFR-AK-CAZ-SC 563971.16 MWD+IFR-AK-CAZ-SC 564060.52 MWD+IFR-AK-CAZ-SC 564149.79 MWD+IFR-AK-CAZ-SC 564238.93 MWD+IFR-AK-CAZ-SC 564327.43 MWD+IFR-AK-CAZ-SC 564415.32 MWD+IFR-AK-CAZ-SC i 564503.91 MWD+IFR-AK-CAZ-SC 564591.41 MWD+IFR-AK-CAZ-SC 564675.42 MWD+IFR-AK-CAZ-SC '' 564758.81 MWD+IFR-AK-CAZ-SC 564846.43 MWD+IFR-AK-CAZ-SC '' 564940.24 MWD+IFR-AK-CAZ-SC '' 565029.77 MWD+IFR-AK-CAZ-SC 565116.17 MWD+IFR-AK-CAZ-SC j 565165.03 MWD+IFR-AK-CAZ-SC 565204.92 MWD+IFR-AK-CAZ-SC 565298.93 MWD+IFR-AK-CAZ-SC 565324.49 MWD+IFR-AK-CAZ-SC 565384.83 MWD+IFR-AK-CAZ-SC 565472.01 MWD+IFR-AK-CAZ-SC 565557.59 MWD+IFR-AK-CAZ-SC 565641.36 MWD+IFR-AK-CAZ-SC 565727.93 MWD+IFR-AK-CAZ-SC 565811.23 MWD+IFR-AK-CAZ-SC 565891.00 MWD+IFR-AK-CAZ-SC ~ i Halliburton Company. Survey Report Company: ConocoPhillips Alaska Inc. llate: 4/25/2006 Time: 14: 07:43 Page: 3 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 1D-41, T rue North Site: Ku paruk 1 D Pa d Vertical (TVD) Reference: 1 D-41 :110.9 Well: 1D -41 Section (VS) Reference: Well ( O.OON,O. OOE ,100.OOAzi) Wellpath: 1D-41 Survey Calculation Methud: Minim um Curv ature Db: Oracle Survey ~~ID incl Azim TVD Sys TVU N/S E/~V 11apN (V1apE Tool ft deg deg ft ft ft ft ft ft 7040.71 71. 27 103. 88 3594 .88 3483 .98 -1093.40 5298.63 5958063 .71 565977. 92 MWD+IFR-AK-CAZ-SC I 7137.79 72. 61 104. 18 3624 .98 3514. 08 -1115.77 5388.17 5958042 .06 566067. 63 MWD+IFR-AK-CAZ-SC 'I 7232.93 71. 86 102. 93 3654 .01 3543. 11 -1137.01 5476.25 5958021 .54 566155. 86 MWD+IFR-AK-CAZ-SC 7283.16 71. 93 103. 03 3669 .62 3558 .72 -1147.73 5522.77 5958011 .19 566202. 47 MWD+IFR-AK-CAZ-SC i ~, 7333.09 72. 29 101. 91 3684 .96 3574. 06 -1157.99 5569.17 5958001 .31 566248. 94 MWD+IFR-AK-CAZ-SC ', 7379.49 71. 41 99. 87 3699 .41 3588. 51 -1166.32 5612.46 5957993 .33 566292. 29 MWD+IFR-AK-CAZ-SC li 7417.79 71. 33 99. 31 3711 .65 3600. 75 -1172.37 5648.25 5957987 .57 566328. 12 MWD+IFR-AK-CAZ-SC ~ 7515.84 70. 07 98. 35 3744 .05 3633. 15 -1186.58 5739.68 5957974 .10 566419. 67 MWD+IFR-AK-CAZ-SC 7550.75 70. 45 98. 64 3755 .85 3644. 95 -1191.43 5772.18 5957969 .51 566452. 20 MWD+IFR-AK-CAZ-SC 7618.42 70. 30 99. 28 3778 .57 3667. 67 -1201.36 5835.14 5957960 .09 566515. 23 MWD+IFR-AK-CAZ-SC 7660.73 69. 40 101. 27 3793 .15 3682. 25 -1208.44 5874.22 5957953 .33 566554. 37 MWD+IFR-AK-CAZ-SC ~' 7713.60 69. 73 102. 17 3811 .61 3700. 71 -1218.50 5922.73 5957943 .66 566602. 95 MWD+IFR-AK-CAZ-SC ': 7808.33 70. 59 102. 40 3843 .76 3732. 86 -1237.46 6009.80 5957925 .40 566690. 16 MWD+IFR-AK-CAZ-SC i 7897.42 70. 27 102. 42 3873 .60 3762. 70 -1255.50 6091.78 5957908 .03 566772. 27 MWD+IFR-AK-CAZ-SC ', 7993.11 71. 51 101. 48 3904 .93 3794. 03 -1274.22 6180.24 5957890 .02 566860. 87 MWD+IFR-AK-CAZ-SC 8093.41 72. 51 103. 25 3935 .91 3825. 01 -1294.65 6273.41 5957870 .35 566954. 20 MWD+IFR-AK-CAZ-SC 8189.03 72. 47 100. 92 3964 .68 3853. 78 -1313.74 6362.57 5957851 .98 567043. 50 MWD+IFR-AK-CAZ-SC ! 8285.68 72. 66 99. 92 3993 .64 3882. 74 -1330.42 6453.26 5957836 .04 567134. 31 MWD+IFR-AK-CAZ-SC ', 8382.44 69. 57 97. 78 4024 .96 3914. 06 -1344.52 6543.70 5957822 .67 567224. 86 MWD+IFR-AK-CAZ-SC 8425.54 67. 56 97. 74 4040 .71 3929. 81 -1349.93 6583.45 5957817 .58 567264. 65 MWD+IFR-AK-CAZ-SC i 8473.81 67. 95 97. 13 4058 .98 3948. 08 -1355.71 6627.75 5957812 .15 567308. 99 MWD+IFR-AK-CAZ-SCE. 8570.32 67. 15 99. 29 4095 .84 3984. 94 -1368.45 6716.03 5957800 .14 567397. 35 MWD+IFR-AK-CAZ-SC '. 8664.85 67. 91 100. 27 4131 .97 4021. 07 -1383.29 6802.11 5957785 .99 567483. 54 MWD+IFR-AK-CAZ-SC 8677.01 67. 84 100. 59 4136 .55 4025. 65 -1385.33 6813.19 5957784 .04 567494. 64 MWD+IFR-AK-CAZ-SC j 8760.89 68. 05 102. 03 4168 .05 4057. 15 -1400.57 6889.42 5957769 .42 567570. 98 MWD+IFR-AK-CAZ-SC i '~ 8855.30 69. 34 102. 64 4202 .35 4091. 45 -1419.36 6975.34 5957751 .32 567657. 05 MWD+IFR-AK-CAZ-SC 8950.67 69. 14 102. 82 4236 .15 4125. 25 -1439.01 7062.33 5957732 .37 567744. 18 MWD+IFR-AK-CAZ-SC I j 9046.49 67. 64 102. 63 4271 .44 4160. 54 -1458.64 7149.22 5957713 .45 567831. 22 MWD+IFR-AK-CAZ-SC 9141.11 68. 27 103. 31 4306 .96 4196. 06 -1478.32 7234.69 5957694 .46 567916. 83 MWD+IFR-AK-CAZ-SC !. 9236.73 67. 18 101. 95 4343 .20 4232. 30 -1497.67 7321.03 5957675 .81 568003. 32 MWD+IFR-AK-CAZ-SC 9331.80 67. 06 101. 21 4380 .17 4269. 27 -1515.26 7406.83 5957658 .92 568089. 25 MWD+IFR-AK-CAZ-SC 9426.98 67. 77 101. 65 4416 .72 4305. 82 -1532.67 7492.97 5957642 .20 568175. 52 MWD+IFR-AK-CAZ-SC '~ 9522.24 67. 72 101. 98 4452 .80 4341. 90 -1550.72 7579.26 5957624 .85 568261. 95 MWD+IFR-AK-CAZ-SC 9604.97 67. 38 101. 23 4484 .39 4373. 49 -1566.11 7654.16 5957610 .08 568336. 96 MWD+IFR-AK-CAZ-SC 9708.89 i 68. 35 101. 34 4523 .55 4412. 65 -1584.94 7748.56 5957592 .00 568431. 50 MWD+IFR-AK-CAZ-SC " 9804.06 68. 72 102. 32 4558 .37 4447. 47 -1603.10 7835.25 5957574 .55 568518. 32 MWD+IFR-AK-CAZ-SC 9899.05 68. 03 100. 54 4593 .38 4482. 48 -1620.60 7921.79 5957557 .75 568605. 00 MWD+IFR-AK-CAZ-SC 9993.81 68. 15 100. 17 4628 .74 4517. 84 -1636.40 8008.28 5957542 .65 568691. 60 MWD+IFR-AK-CAZ-SC ' 10088.05 68. 11 100. 38 4663 .85 4552. 95 -1652.00 8094.33 5957527 .74 568777. 77 MWD+IFR-AK-CAZ-SC i 10184.05 68. 83 98. 72 4699 .08 4588. 18 -1666.82 8182.39 5957513 .64 568865. 94 MWD+IFR-AK-CAZ-SC 10278.87 69. 10 97. 73 4733 .11 4622. 21 -1679.48 8269.98 5957501 .69 568953. 62 MWD+IFR-AK-CAZ-SC '' 10374.41 69. 70 99. 86 4766 .73 4655. 83 -1693.15 8358.35 5957488 .73 569042. 09 MWD+IFR-AK-CAZ-SC 10469.09 69. 08 102. 63 4800 .07 4689. 17 -1710.43 8445.26 5957472 .16 569129. 13 MWD+IFR-AK-CAZ-SC 10564.94 69. 08 103. 05 4834 .29 4723. 39 -1730.32 8532.56 5957452 .97 569216. 57 MWD+IFR-AK-CAZ-SC '; 10660.07 69. 09 102. 75 4868 .25 4757. 35 -1750.16 8619.17 5957433 .83 569303. 34 MWD+IFR-AK-CAZ-SC ', 10754.32 68. 94 103. 62 4902 .00 4791. 10 -1770.23 8704.85 5957414 .46 569389. 17 MWD+IFR-AK-CAZ-SC '~ 10850.80 68. 92 104. 27 4936 .69 4825. 79 -1791.93 8792.23 5957393 .47 569476. 71 MWD+IFR-AK-CAZ-SC ', 10945.83 68. 77 104. 83 4970 .99 4860. 09 -1814.19 8878.01 5957371 .90 569562. 66 MWD+IFR-AK-CAZ-SC 11040.93 68. 62 105. 94 5005 .54 4894. 64 -1837.70 8963.44 5957349 .09 569648. 26 MWD+IFR-AK-CAZ-SC 11136.63 72. 02 102. 43 5037 .77 4926. 87 -1859.75 9050.78 5957327 .75 569735. 77 MWD+IFR-AK-CAZ-SC 11231.39 72. 56 101. 93 5066 .60 4955. 70 -1878.79 9139.01 5957309 .42 569824. 15 MWD+IFR-AK-CAZ-SC 11326.99 70. 77 100. 53 5096 .67 4985. 77 -1896.47 9228.01 5957292 .46 569913. 28 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company : ConocoPhillips Alaska Inc. Uate: 4/25/2006 Time: 14: 07:43 Page: 4 Field: Ku paruk River Unif Co-ordinate(NE) Re ference: Well: 1 D-41, T rue North Site: Ku paruk 1D Pa d Vertical (TVU) Refe rence: 1D-41 :110.9 Well: 1D -4i Section (VS) Reference: Well (O.OON,O. OOE ,100.OOAzi) W'ellpath: 1 D -41 Survey Calculation Method: Minim um Curv atur e llb: Oracle tiurvev - _ NID Incl Azim TVD Sys TVD N/S E/W _ MapV MapE __ Tool ', ', ft deg deg ft ft ft ft ft ft ! 11421 .50 70. 64 100. 41 5127 .90 5017.00 -1912.68 9315.73 -- - - _ 5957276 .96 570001. 11 _ _- MWD+IFR-AK-CAZ-SC I 11515 .94 70. 52 100. 45 5159 .30 5048.40 -1928.80 9403.33 5957261 .55 570088. 83 MWD+IFR-AK-CAZ-SC 11613 .13 70. 36 100. 49 5191 .84 5080.94 -1945.44 9493.38 5957245 .64 570179. 01 MWD+IFR-AK-CAZ-SC ! 11708 .29 70. 13 100. 23 5224 .00 5113.10 -1961.55 9581.48 5957230 .24 570267. 23 MWD+IFR-AK-CAZ-SC ' 11803. 33 70. 08 100. 18 5256. 35 5145.45 -1977.38 9669.43 5957215 .12 570355. 30 MWD+IFR-AK-CAZ-SC ! 11898. 11 69. 93 100. 38 5288. 75 5177.85 -1993.28 9757.07 5957199 .94 570443. 05 MWD+IFR-AK-CAZ-SC 11991. 15 69. 82 100. 64 5320. 77 5209.87 -2009.21 9842.97 5957184 .70 570529. 06 MWD+IFR-AK-CAZ-SC 12087. 56 69. 84 100. 67 5354. 01 5243.11 -2025.94 9931.90 5957168 .68 570618. 12 MWD+IFR-AK-CAZ-SC ' ~ I 12179. 61 68. 02 101. 34 5387. 10 5276.20 -2042.34 10016.22 5957152 .97 570702. 56 MWD+IFR-AK-CAZ-SC ! 12278. 53 67. 95 101. 40 5424. 18 5313.28 -2060.42 10106.12 5957135 .62 570792. 60 MWD+IFR-AK-CAZ-SC '; 12373 .84 67. 98 101. 67 5459. 94 5349.04 -2078.08 10192.69 5957118 .66 570879. 29 MWD+IFR-AK-CAZ-SC !, 12469. 56 68. 17 101. 59 5495. 68 5384.78 -2095.98 10279.66 5957101 .46 570966. 40 MWD+IFR-AK-CAZ-SC ~ 12564. 86 68. 22 101. 77 5531. 08 5420.18 -2113.90 10366.31 5957084 .25 571053. 18 MWD+IFR-AK-CAZ-SC I I 12660. 56 68. 35 101. 65 5566. 49 5455.59 -2131.94 10453.37 5957066 .91 571140. 38 MWD+IFR-AK-CAZ-SC ! !, 12755 .76 68. 59 101. 64 5601. 42 5490.52 -2149.82 10540.10 5957049 .74 571227. 24 MWD+IFR-AK-CAZ-SC I 12850 .72 68. 74 101. 56 5635. 97 5525.07 -2167.60 10626.75 5957032 .65 571314. 02 MWD+IFR-AK-CAZ-SC 12945 .81 69. 00 101. 99 5670. 25 5559.35 -2185.70 10713.58 5957015 .26 571400. 99 MWD+IFR-AK-CAZ-SC 13041 .11 67. 76 101. 99 5705. 36 5594.46 -2204.11 10800.24 5956997 .55 571487. 79 MWD+IFR-AK-CAZ-SC 13136 .64 67. 71 102. 44 5741 .56 5630.66 -2222.81 10886.64 5956979 .55 571574. 33 MWD+IFR-AK-CAZ-SC 13230 .18 67. 77 102. 27 5776. 99 5666.09 -2241.34 10971.21 5956961 .71 571659. 03 MWD+IFR-AK-CAZ-SC 13325 .33 67. 87 102. 50 5812 .91 5702.01 -2260.23 11057.27 5956943 .51 571745. 23 MWD+IFR-AK-CAZ-SC ', 13420 .42 67. 43 102. 29 5849 .07 5738.17 -2279.11 11143.16 5956925 .33 571831. 27 MWD+IFR-AK-CAZ-SC 13515 .85 66. 99 102. 57 5886 .04 5775.14 -2298.05 11229.08 5956907 .09 571917. 33 MWD+IFR-AK-CAZ-SC 13611 .48 68. 79 101. 47 5922 .03 5811.13 -2316.49 11315.73 5956889 .35 572004. 12 MWD+IFR-AK-CAZ-SC 13707 .00 68. 22 101. 21 5957 .03 5846.13 -2333.97 11402.87 5956872 .57 572091. 39 MWD+IFR-AK-CAZ-SC 13791 .78 64. 34 102. 08 5991 .13 5880.23 -2349.62 11478.88 5956857 .54 572167. 51 MWD+IFR-AK-CAZ-SC 13887 .98 66. 16 99. 86 6031 .41 5920.51 -2366.24 11564.64 5956841 .62 572253. 40 MWD+IFR-AK-CAZ-SC ! 13981 i .73 69. 10 100. 51 6067 .08 5956.18 -2381.57 11649.96 5956826 .98 572338. 83 MWD+IFR-AK-CAZ-SC ! 14077 .73 71. 26 101. 10 6099 .63 5988.73 -2398.50 11738.66 5956810 .76 572427. 66 MWD+IFR-AK-CAZ-SC I 14168 .84 70. 66 99. 85 6129 .36 6018.46 -2414.16 11823.35 5956795 .79 572512. 46 MWD+IFR-AK-CAZ-SC ! 14267 .33 70. 49 100. 58 6162 .11 6051.21 -2430.63 11914.76 5956780 .06 572603. 99 MWD+IFR-AK-CAZ-SC j, 14362 .70 70. 03 100. 15 6194 .32 6083.42 -2446.78 12003.06 5956764 .62 572692. 41 MWD+IFR-AK-CAZ-SC I 14458 ! .16 71. 73 99. 18 6225 .59 6114.69 -2461.92 12091.97 5956750 .20 572781. 43 MWD+IFR-AK-CAZ-SC ' 14548 .47 71. 46 99. 44 6254 .11 6143.21 -2475.78 12176.53 5956737 .02 572866. 09 MWD+IFR-AK-CAZ-SC I 14645 .85 70. 99 98. 44 6285 .45 6174.55 -2490.11 12267.61 5956723 .43 572957. 27 MWD+IFR-AK-CAZ-SC 14740 .19 70. 59 98. 15 6316 .49 6205.59 -2502.96 12355.76 5956711 .29 573045. 52 MWD+IFR-AK-CAZ-SC ', 14833. 98 70. 02 99. 47 6348. 10 8237.20 -2516.49 12443.02 5956698 .48 573132. 88 MWD+IFR-AK-CAZ-SC ~ ~, 14934. 64 72. 12 99. 45 6380. 75 6269.85 -2532.14 12536.94 5956683 .59 573226. 91 MWD+IFR-AK-CAZ-SC I 15029. 01 71. 66 99. 60 6410. 09 6299.19 -2546.98 12625.40 5956669 .46 573315. 48 MWD+IFR-AK-CAZ-SC ~ 'j 15122. 67 71. 19 98. 88 6439. 92 6329.02 -2561.23 12713.02 5956655 .92 573403. 21 MWD+IFR-AK-CAZ-SC I I 15216. 91 70. 30 99. 67 6471. 00 6360.10 -2575.57 12800.83 5956642 .29 573491. 12 ~ MWD+IFR-AK-CAZ-SC !, 15314. 83 70. 69 99. 69 6503. 69 6392.79 -2591.09 12891.81 5956627 .51 573582. 22 MWD+IFR-AK-CAZ-SC ~ 15410. 25 70. 57 100. 27 6535. 34 6424.44 -2606.69 12980.47 5956612 .62 573670. 99 MWD+IFR-AK-CAZ-SC 15504. 77 73. 65 100. 27 6564. 37 6453.47 -2622.73 13068.97 5956597 .30 573759. 60 MWD+IFR-AK-CAZ-SC ''~ i 15600. 79 76. 08 101. 89 6589. 44 6478.54 -2640.54 13159.92 5956580 .22 573850. 68 MWD+IFR-AK-CAZ-SC 15658. 88 77. 22 102. 06 6602. 86 6491.96 -2652.27 13215.21 5956568 .94 573906. 06 MWD+IFR-AK-CAZ-SC j 15699. 00 78. 27 102. 77 6611. 37 6500.47 -2660.70 13253.49 5956560 .82 573944. 41 MWD+IFR-AK-CAZ-SC '; 15808. 88 85. 00 97. 86 6627. 36 6516.46 -2680.11 13360.36 5956542 .28 574051. 42 MWD+IFR-AK-CAZ-SC 15904. 26 91. 67 93. 45 6630 .13 6519.23 -2689.49 13455.16 5956533 .67 574146. 28 MWD+IFR-AK-CAZ-SC '', 15998. 77 92. 72 92. 39 6626 .51 6515.61 -2694.30 13549.48 5956529 .62 574240. 63 MWD+IFR-AK-CAZ-SC ! j, 16091. 71 94. 33 91. 50 6620 .79 6509.89 -2697.45 13642.18 5956527 .22 574333. 35 MWD+IFR-AK-CAZ-SC 16187. 17 92. 90 93. 63 6614 .78 6503.88 -2701.72 13737.35 5956523 .72 574428. 54 MWD+IFR-AK-CAZ-SC 16279. 88 94. 20 92. 63 6609 .03 6498.13 -2706.77 13829.74 5956519 .42 574520. 96 MWD+IFR-AK-CAZ-SC ! Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date: 4/25/2006 Time: 14:07:43 Pale: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1D-41, True North Site: Kuparuk 1 D Pad Vertical (TVD) Reference: 1 D-41:110.9 WeIL• 1D-41 Section (VS) Reference: WeII (O.OON,O.OOE,100.OOAzi) ~Vcllpath: 1 D-41 Survey Calculation Alethod: Minimum Curvature llb: Oracle Sun~e~~ ~ID lncl Azim TVD Sys TVD N/S E!~'4' ~1apN IV1apE Tool ', ft deg deg ft ft ft ft ft ft _ - _____ 16345.24 87.96 92.84 6607.80 6496.90 -2709.89 13894.98 5956516.83 574586.21 MWD+IFR-AK-CAZ-SC III III 16376.18 89.20 92.64 6608.57 6497.67 -2711.36 13925.88 5956515.60 574617.12 MWD+IFR-AK-CAZ-SC 16469.37 92.04 95.59 6607.56 6496.66 -2718.05 14018.80 5956509.66 574710.08 MWD+IFR-AK-CAZ-SC 16557.03 91.23 92.15 6605.06 6494.16 -2723.96 14106.21 5956504.46 574797.53 MWD+IFR-AK-CAZ-SC '~ 16613.99 91.36 93.29 6603.77 6492.87 -2726.66 14163.09 5956502.21 574854.42 MWD+IFR-AK-CAZ-SC 16657.89 89.38 93.13 6603.49 6492.59 -2729.12 14206.92 5956500.11 574898.27 MWD+IFR-AK-CAZ-SC ', 16752.32 91.73 97.08 6602.57 6491.67 -2737.52 14300.95 5956492.47 574992.35 MWD+IFR-AK-CAZ-SC ii 16835.77 89.85 96.24 6601.42 6490.52 -2747.20 14383.82 5956483.46 575075.29 MWD+IFR-AK-CAZ-SC !, i 16878.35 92.01 97.90 6600.73 6489.83 -2752.44 14426.07 5956478.57 575117.57 MWD+IFR-AK-CAZ-SC 16927.53 91.97 98.86 6599.02 6488.12 -2759.60 14474.69 5956471.80 575166.25 MWD+IFR-AK-CAZ-SC 16971.53 91.60 98.43 6597.65 6486.75 -2766.21 14518.17 5956465.54 575209.78 MWD+IFR-AK-CAZ-SC 17020.97 91.11 101.03 6596.48 6485.58 -2774.56 14566.88 5956457.58 575258.55 MWD+IFR-AK-CAZ-SC 17066.63 90.49 101.39 6595.85 6484.95 -2783.44 14611.67 5956449.07 575303.40 MWD+IFR-AK-CAZ-SC 17109.42 88.82 100.35 6596.10 6485.20 -2791.51 14653.68 5956441.34 575345.48 MWD+IFR-AK-CAZ-SC 17160.81 91.92 104.59 6595.77 6484.87 -2802.60 14703.84 5956430.65 575395.72 MWD+IFR-AK-CAZ-SC 17204.94 91.47 104.37 6594.47 6483.57 -2813.63 14746.55 5956419.97 575438.51 MWD+IFR-AK-CAZ-SC 17255.22 91.79 105.67 6593.04 6482.14 -2826.65 14795.09 5956407.34 575487.15 MWD+IFR-AK-CAZ-SC 17298.88 91.66 105.83 6591.72 6480.82 -2838.50 14837.10 5956395.83 575529.25 MWD+IFR-AK-CAZ-SC 17349.77 93.33 106.06 6589.51 6478.61 -2852.47 14885.98 5956382.26 575578.24 MWD+IFR-AK-CAZ-SC 'i 17392.38 91.29 105.59 6587.79 6476.89 -2864.08 14926.94 5956370.99 575619.28 MWD+IFR-AK-CAZ-SC 17444.39 90.98 105.06 6586.76 6475.86 -2877.82 14977.09 5956357.65 575669.54 MWD+IFR-AK-CAZ-SC 17486.91 91.29 105.39 6585.92 6475.02 -2888.98 15018.11 5956346.82 575710.64 MWD+IFR-AK-CAZ-SC 17538.75 90.98 105.28 6584.89 6473.99 -2902.69 15068.09 5956333.52 575760.73 MWD+IFR-AK-CAZ-SC ',' 17588.07 91.79 104.53 6583.70 6472.80 -2915.37 15115.74 5956321.22 575808.47 MWD+IFR-AK-CAZ-SC i 17631.35 90.00 101.34 6583.02 6472.12 -2925.06 15157.91 5956311.88 575850.72 MWD+IFR-AK-CAZ-SC i I~ 17676.96 89.69 102.35 6583.15 6472.25 -2934.42 15202.55 5956302.88 575895.42 MWD+IFR-AK-CAZ-SC 17727.42 89.62 103.72 6583.45 6472.55 -2945.80 15251.71 5956291.89 575944.67 MWD+IFR-AK-CAZ-SC '. 17765.30 89.13 102.77 6583.86 6472.96 -2954.48 15288.57 5956283.52 575981.60 MWD+IFR-AK-CAZ-SC 17820.11 91.61 101.06 6583.51 6472.61 -2965.79 15342.20 5956272.64 576035.31 MWD+IFR-AK-CAZ-SC ', 17864.80 88.88 103.35 6583.32 6472.42 -2975.24 15385.87 5956263.54 576079.05 MWD+IFR-AK-CAZ-SC 17914.43 90.92 104.09 6583.40 6472.50 -2987.01 15434.08 5956252.16 576127.35 MWD+IFR-AK-CAZ-SC '~ 17958.90 91.04 104.84 6582.64 6471.74 -2998.12 15477.13 5956241.41 576170.49 MWD+IFR-AK-CAZ-SC 'i 18008.78 90.92 102.32 6581.79 6470.89 -3009.82 15525.61 5956230.09 576219.05 MWD+IFR-AK-CAZ-SC 18053.16 88.45 101.81 6582.03 6471.13 -3019.10 15569.00 5956221.16 576262.52 MWD+IFR-AK-CAZ-SC , 18104.78 89.87 102.41 6582.79 6471.89 -3029.93 15619.47 5956210.75 576313.06 MWD+IFR-AK-CAZ-SC 18148.10 90.24 100.94 6582.75 6471.85 -3038.69 15661.89 5956202.32 576355.55 MWD+IFR-AK-CAZ-SC ', 18196.82 89.37 99.62 6582.92 6472.02 -3047.39 15709.83 5956194.02 576403.55 MWD+IFR-AK-CAZ-SC 18244.79 90.43 97.89 6583.00 6472.10 -3054.69 15757.24 5956187.10 576451.01 MWD+IFR-AK-CAZ-SC 18289.74 92.03 98.67 6582.03 6471.13 -3061.16 15801.70 5956180.99 576495.53 MWD+IFR-AK-CAZ-SC ~~ 18343.70 89.93 96.27 6581.11 6470.21 -3068.17 15855.19 5956174.41 576549.07 MWD+IFR-AK-CAZ-SC II 18385.20 92.54 99.54 6580.22 6469.32 -3073.88 15896.28 5956169.04 576590.19 MWD+IFR-AK-CAZ-SC I, 18428.89 91.54 92.54 6578.66 6467.76 -3078.47 15939.67 5956164.80 576633.62 MWD+IFR-AK-CAZ-SC i 18479.73 88.14 92.66 6578.80 6467.90 -3080.77 15990.45 5956162.90 576684.41 MWD+IFR-AK-CAZ-SC 18523.21 90.44 95.55 6579.34 6468.44 -3083.89 16033.81 5956160.14 576727.79 MWD+IFR-AK-CAZ-SC I 18572.32 90.43 98.00 6578.97 6468.07 -3089.68 16082.57 5956154.74 576776.59 MWD+IFR-AK-CAZ-SC II 18619.24 89.93 99.65 6578.82 6467.92 -3096.88 16128.93 5956147.92 576823.00 MWD+IFR-AK-CAZ-SC 18668.34 92.48 100.41 6577.79 6466.89 -3105.43 16177.27 5956139.76 576871.40 MWD+IFR-AK-CAZ-SC 18755.48 90.00 104.71 6575.90 6465.00 -3124.37 16262.28 5956121.51 576956.55 MWD+IFR-AK-CAZ-SC 18807.01 89.87 110.16 6575.96 6465.06 -3139.80 16311.42 5956106.47 577005.81 MWD+IFR-AK-CAZ-SC 18856.11 89.13 115,07 6576.39 6465.49 -3158.67 16356.73 5956087.97 577051.27 MWD+IFR-AK-CAZ-SC '. I I, 18951.60 86.35 115.80 6580.15 6469.25 -3199.65 16442.89 5956047.69 577137.75 MWD+IFR-AK-CAZ-SC ~_ 19046.13 83.94 117.97 6588.15 6477.25 -3242.23 16526_89 5956005.79 577222.08 MWD+IFR-AK-CAZ-SC ', Halliburton Company i Survey Report Company: ConocoPhillips Alaska Inc. Uate: 4/25/2006 Time: 14:07:43 Page: 6 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Welh 1D-41, True North Site: Kuparuk 1 D Pad Vertical (TVD) Reference: 1 D-41:110.9 Well: 1 D-41 Section (VS) Reference: Well (OAON,O.OOE,100.OOAz~ ~'~'ellpath: 1 D-41 Survey Calculation Method: Minimum Curvature Ub: Oracle Survey MD Incl :1zim TVll Sys TVD __ N/S E/~'~' MapN h1apE Tool ft deg deg ft ft ft ft ft ft 19139.65 79.55 119.93 6601.58 6490.68 -3287.01 16607.85 5955961.67 577303.40 MWD+IFR-AK-CAZ-SC ~I 19203.38 77.59 123.00 6614.21 6503.31 -3319.61 16661.13 5955929.51 577356.93 MWD+IFR-AK-CAZ-SC 19269.00 f 77.59 123.00 6628.31 6517.41 -3354.51 16714.88 5955895.05 577410.95 PROJECTED to TD ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 Time: 13:59:46 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1D-41, True North Site: Kuparuk 1 D Pad Vertical (TVD) Reference: 1 D-41: 110.9 WeII: 1 D-41 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Wellpath: 1 D-41 PB1 Survey Calculation Dlethod: Minimum Curvature Db: Oracle _. i Field: Kuparuk River Unit - ---. _ ',, North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ', Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ' Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 D-41 Slot Name: Well Position: +N/-S -552.14 ft Northing: 5959114.19 ft Latitude: 70 17 55.887 N I~ ', +E/-W -419.85 ft Easting : 560671.14 ft Longitude: 149 30 31.160 W ', 'Position Uncertainty: 0.00 ft ', Wellpath: 1 D-41 PB1 Drilled From: Well Ref. Point 500292328870 Tie-on Depth: 41.40 ft Current Datum: 1 D-41: Height 110.90 ft Above System Datum: Mean Sea Level j Magnetic Data: 1/10/2006 Declination: 24.24 deg i Field Strength: 57568 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction Ii ft ft ft i deg 41.40 0.00 0.00 100.00 Survey Program for Definitive Wellpath Date: 6/21/2005 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 81.00 800.00 1 D-41 PB1 gyro (81.00-800.00) CB-GYRO-SS Camera based gyro single shot 858.35 15894.15 1 D-41 PB1 (858.35-15894.15) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD ft 41.40 81.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 858.35 953.59 1047.87 1142.65 1237.05 1334.26 1427.24 1473.11 1523.43 1552.87 16i 9.86 1714.34 1808.80 1903.90 1994.29 2093.58 2187.11 2280.61 2379.50 Incl Azim TVD Sys TVD N/S __ E/~V MapV de g deg ft ft ft ft ft 0 .00 0 .00 41. 40 -69 .50 0. 00 0.00 5959114. 19 0 .30 7 .84 81. 00 -29 .90 0. 10 0.01 5959114. 29 0 .35 343 .30 100. 00 -10 .90 0. 21 0.00 5959114. 40 0 .68 151 .14 200. 00 89 .10 -0. 02 0.20 5959114. 17 4 .70 121 .94 299. 87 188 .97 -2. 71 3.97 5959111. 51 7 .27 113 .68 399. 32 288 .42 -7. 42 13.24 5959106. 88 9 .16 108 .38 498. 29 387 .39 -12. 47 26.59 5959101. 94 11 .90 102 .22 596. 60 485 .70 -17. 16 44.22 5959097. 39 13 .10 102 .58 694. 23 583 .33 -21. 81 65.36 5959092. 91 13 .61 100 .59 791. 52 680 .62 -26. 44 87.99 5959088. 46 14 .43 106 .22 848. 14 737 .24 -29. 74 101.72 5959085. 28 18 .53 107 .33 939. 44 828 .54 -37. 56 127.57 5959077. 66 21 .75 105 .42 1027. 95 917 .05 -46. 67 158.72 5959068. 81 22 .99 104 .08 1115. 59 1004 .69 -55. 84 193.60 5959059. 92 26 .08 101 .99 1201. 46 1090 .56 -64. 64 231.79 5959051. 43 30 .19 104 .11 1287. 17 1176 .27 -75. 04 276.42 5959041. 39 30 .78 104 .12 1367. 30 1256 .40 -86. 55 322.16 5959030. 25 31 .70 103 .32 1406. 51 1295 .61 -92. 19 345.27 5959024. 80 32 .55 101 .68 1449. 13 1338 .23 -97. 97 371.40 5959019. 23 32 .82 102 .11 1473. 91 1363 .01 -101. 25 386.95 5959016. 08 37 .14 100 .74 1528. 79 1417 .89 -108. 83 424.59 5959008. 80 43 .88 100 .77 1600. 58 1489 .68 -120. 28 484.85 5958997. 84 47 .09 99 .94 1666. 79 1555 .89 -132. 37 551.10 5958986. 28 52 .69 100 .97 1728. 04 1617 .14 -145. 59 622.59 5958973. 64 60 .49 101 .41 1777. 77 1666 .87 -160. 23 696.55 5958959. 60 63 .19 102 .40 1824. 63 1713 .73 -178. 30 782.19 5958942. 23 66 .49 100 .64 1864. 39 1753 .49 -195. 19 865.13 5958926. 01 64 .38 101 .47 1903. 26 1792 .36 -211. 49 948.59 5958910. 39 68 .45 101 .55 1942. 82 1831 .92 -229. 57 1037.38 5958893. 03 MapE '1'001 ft 560671.14 TIE LINE 560671.15 CB-GYRO-SS ~I 560671.14 CB-GYRO-SS 560671.34 CB-GYRO-SS 560675.13 CB-GYRO-SS 560684.44 CB-GYRO-SS 560697.83 CB-GYRO-SS 560715.50 CB-GYRO-SS j 560736.67 CB-GYRO-SS 560759.33 CB-GYRO-SS 560773.08 MWD+IFR-AK-CAZ-SC I, 560799.00 MWD+IFR-AK-CAZ-SC ' 560830.22 MWD+IFR-AK-CAZ-SC ~, 560865.17 MWD+IFR-AK-CAZ-SC ~~ 560903.42 MWD+IFR-AK-CAZ-SC j 560948.13 MWD+IFR-AK-CAZ-SC ~i 560993.96 MWD+IFR-AK-CAZ-SC 'I 561017.11 MWD+IFR-AK-CAZ-SC ' 561043.28 MWD+IFR-AK-CAZ-SC 561058.86 MWD+IFR-AK-CAZ-SC 561096.55 MWD+IFR-AK-CAZ-SC 561156.90 MWD+IFR-AK-CAZ-SC 561223.24 MWD+IFR-AK-CAZ-SC ', 561294.83 MWD+IFR-AK-CAZ-SC 561368.90 MWD+IFR-AK-CAZ-SC i 561454.67 MWD+IFR-AK-CAZ-SC 561537.74 MWD+IFR-AK-CAZ-SC '~, 561621.31 MWD+IFR-AK-CAZ-SC ''I 561710.24 MWD+IFR-AK-CAZ-SC ', Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1 D Pad W'eIL• 1 D-41 ~~'ellpath: 1 D-41 P61 Survev MD Incl Azim ft deg deg 2474.74 71.32 99.37 I I~ 2569.80 72.07 100.05 2664.83 71.50 98.43 III 2762.41 70.21 97.27 ~ 2857.46 69.85 97.19 2953.89 70.22 97.64 'I 3052.32 69.17 97.43 3147.29 67.94 98.97 ~I 3242.02 66.93 100.45 3336.35 68.93 103.83 3432.15 72.35 105.43 3527.68 71.35 106.14 3622.62 68.05 107.47 3710.80 66.91 108.11 ', 3745.36 67.85 107.83 3810.24 66.23 108.19 i '~, 3909.00 65.02 106.96 ~'~ 4005.84 70.78 106.26 4096.87 71.44 106.02 4193.26 68.45 106.37 4289.61 67.14 105.67 4384.85 69.19 104.50 4480.25 70.35 103.53 4574.60 71.22 101.45 ~ 4668.23 70.87 101.00 4762.10 69.79 101.19 ~~ !I 4855.30 70.08 100.01 4951.60 70.06 99.36 5047.06 72.54 99.75 5141.55 73.62 100.19 5235.35 71.76 98.20 5329.58 69.06 98.77 5426.15 67.26 99.55 5523.21 64.68 99.76 5617.68 63.80 99.25 5709.88 68.56 98.71 5804.06 71.40 98.13 5903.97 71.25 98.01 5999.13 72.21 98.37 6090.59 73.08 98.89 6142.39 71.76 98.53 6184.87 71.26 98.56 6286.31 68.27 100.16 6314.23 68.05 99.80 6380.14 68.27 99.98 ', 6475.73 67.56 101.26 TVD S}'s TVD ft ft 1975.57 1864.67 2005.42 1894.52 2035.13 1924.23 2067,13 1956.23 2099.60 1988.70 2132.52 2021.62 2166.68 2055.78 2201.40 2090.50 2237.75 2126.85 2273.20 2162.30 2304.96 2194.06 2334.72 2223.82 2367.65 2256.75 2401.43 2290.53 2414.72 2303.82 2440.03 2329.13 2480.79 2369.89 2517.20 2406.30 2546.67 2435.77 2579.73 2468.83 2616.14 2505.24 2651.56 2540. 66 2684.55 2573. 65 2715.60 2604. 70 2746.02 2635. 12 2777.61 2666. 71 2809.59 2698.69 2842.42 2731.52 2873.02 2762.12 2900.52 2789.62 2928.43 2817.53 2960. 02 2849.12 2995. 95 2885. 05 3035. 47 2924. 57 3076. 52 2965. 62 3113. 75 3002. 85 3145. 99 3035. 09 3177. 98 3067. 08 3207. 81 3096. 91 3235. 09 3124. 19 3250. 74 3139. 84 3264. 21 3153. 31 3299. 29 3188. 39 3309. 68 3198. 78 3334. 20 3223. 30 3370. 14 3259. 24 6570.65 66. 22 102 .37 3407.40 3296. 50 6664.00 66. 61 101 .93 3444. 75 3333. 85 6761.41 63. 90 102 .69 3485. 52 3374. 62 6856.16 64. 75 103 .62 3526. 57 3415. 67 6945.51 68. 41 103 .86 3562. 08 3451. 18 7040.71 71. 27 103 .88 3594. 88 3483. 98 llate: 4/25/2006 'l'ime: 13:59:46 Page: 2 Co-ordinate(NE) Reference: Well: 1 D-41, True North Vertical (TVD) Reference: 1 D-41:110.9 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle \/S E/W' Maps ft ft ft -245 .79 1125 .31 5958877 .52 -261 .01 1214 .26 5958863 .02 -275 .50 1303 .36 5958849 .24 -288 .10 1394 .67 5958837 .39 -299 .34 1483 .29 5958826 .86 -311 .04 1573 .17 5958815 .89 -323. 14 1664. 69 5958804 .53 -335. 75 1752. 17 5958792. 63 -350. 49 1838. 39 5958778. 58 -368. 89 1923. 83 5958760. 88 -391. 73 2011. 27 5958738. 75 -416. 42 2098. 62 5958714. 76 -442. 15 2183. 85 5958689. 73 -467. 03 2261. 41 5958665. 47 -476. 88 2291. 75 5958655. 88 -495 .35 2348. 56 5958637. 87 -522. 51 2434. 32 5958611. 40 -548 .14 2520. 26 5958586. 47 -572 .08 2603 .00 5958563. 20 -597 .33 2689. 94 5958538. 65 -621 .95 2775 .68 5958514. 73 -644 .95 2861 .03 5958492. 42 -666 .62 2947 .88 5958471 .45 -685 .89 3034 .86 5958452 .89 -703 .12 3121 .72 5958436 .36 -720 .13 3208 .46 5958420. 05 -736 .24 3294 .50 5958404 .65 -751 .47 3383 .75 5958390 .14 -766 .48 3472 .90 5958375 .85 -782 .13 3561 .94 5958360 .92 -796 .44 3650 .33 5958347 .32 -809 .54 3738 .12 5958334 .93 -823 .80 3826 .62 5958321 .38 -838 .67 3914 .00 5958307 .23 -852 .72 3997 .91 5958293 .86 -865 .87 4081. 20 5958281. 37 -878 .83 4168. 73 5958269. 13 -892 .11 4262. 44 5958256. 60 -904 .99 4351. 88 5958244. 45 -918 .09 4438. 19 5958232. 05 -925 .56 4487. 00 5958224. 97 -931 .55 4526 .84 5958219. 30 -947 .01 4620 .74 5958204. 60 -951 .51 4646. 26 5958200. 31 -962 .01 4706 .53 5958190. 29 -978 .34 4793 .59 5958174. 68 -996 .21 4879 .04 5958157 .50 -1014 .21 4962 .67 5958140 .17 -1033 .06 5049 .10 5958122. 02 -1052 .50 5132 .25 5958103. 26 -1071 .97 5211 .88 5958084 .43 -1093 .40 5298 .63 5958063 .71 MapF, ___ Tool ft 561798.29 MWD+IFR-AK-CAZ-SC 561887.35 MWD+IFR-AK-CAZ-SC ', 561976.55 MWD+IFR-AK-CAZ-SC 562067.96 MWD+IFR-AK-CAZ-SC ', 562156.66 MWD+IFR-AK-CAZ-SC ', 562246.62 MWD+IFR-AK-CAZ-SC ~ 562338.22 MWD+IFR-AK-CAZ-SC I 562425.80 MWD+IFR-AK-CAZ-SC 562512.13 MWD+IFR-AK-CAZ-SC 562597.70 MWD+IFR-AK-CAZ-SC 562685.31 MWD+IFR-AK-CAZ-SC 562772.85 MWD+IFR-AK-CAZ-SC 562858,28 MWD+IFR-AK-CAZ-SC 562936.03 MWD+IFR-AK-CAZ-SC 562966.45 MWD+IFR-AK-CAZ-SC 563023.40 MWD+IFR-AK-CAZ-SC 563109.36 MWD+IFR-AK-CAZ-SC 563195.50 MWD+IFR-AK-CAZ-SC I 563278.42 ~ MWD+IFR-AK-CAZ-SC 563365.56 MWD+IFR-AK-CAZ-SC '': 563451.48 MWD+IFR-AK-CAZ-SC 563537.01 MWD+IFR-AK-CAZ-SC 563624.02 MWD+IFR-AK-CAZ-SC ', 563711.15 MWD+IFR-AK-CAZ-SC 563798.13 MWD+IFR-AK-CAZ-SC 563885.00 MWD+IFR-AK-CAZ-SC 563971.16 MWD+IFR-AK-CAZ-SC I 564060.52 I MWD+IFR-AK-CAZ-SC 564149.79 MWD+IFR-AK-CAZ-SC 564238.93 MWD+IFR-AK-CAZ-SC 564327.43 MWD+IFR-AK-CAZ-SC 564415.32 MWD+IFR-AK-CAZ-SC 564503.91 MWD+IFR-AK-CAZ-SC 564591.41 MWD+IFR-AK-CAZ-SC 564675.42 MWD+IFR-AK-CAZ-SC 564758.81 MWD+IFR-AK-CAZ-SC 564846.43 MWD+IFR-AK-CAZ-SC 564940.24 MWD+IFR-AK-CAZ-SC I 565029.77 ~ MWD+IFR-AK-CAZ-SC 565116.17 MWD+IFR-AK-CAZ-SC i 565165.03 MWD+IFR-AK-CAZ-SC ~I 565204.92 I MWD+IFR-AK-CAZ-SC 565298.93 MWD+IFR-AK-CAZ-SC 565324.49 MWD+IFR-AK-CAZ-SC 565384.83 MWD+IFR-AK-CAZ-SC 565472.01 MWD+IFR-AK-CAZ-SC, 565557.59 I MWD+IFR-AK-CAZ-SC 565641.36 MWD+IFR-AK-CAZ-SC 565727.93 MWD+IFR-AK-CAZ-SC 565811.23 MWD+IFR-AK-CAZ-SC 565891.00 MWD+IFR-AK-CAZ-SC 565977.92 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 Tiroe: 13: 59:46 Page: 3 Field: Ku paruk River Unif Co-ord inate(NE) Reference: Well: 1D-41, T rue North Site: Ku paruk 1 D Pa d Vertica l (TVD) Reference: 1 D-41 :110.9 Well: 1D -41 Sectim~ (VS) Reference: Well (0.OON,O. OOE,100.OOAzi) Wellpath: 1D -41PB 1 Survey Calculation Method: Minim um Curv atu re Db: Oracle Survev __ NID __ lncl Azim 'TVD Sys'I'VD \/S E/~V ___ ivtapN hiapE Tool ' ft deg deg ft ft ft ft ft ft ' 7137 .79 72. 61 104. 18 3624 .98 3514. 08 -1115.77 5388.17 5958042.06 566067. 63 MWD+IFR-AK-CAZ-SC 7232 .93 71. 86 102. 93 3654 .01 3543. 11 -1137.01 5476.25 5958021.54 566155. 86 MWD+IFR-AK-CAZ-SC ' 7283 .16 71. 93 103. 03 3669 .62 3558. 72 -1147.73 5522.77 5958011.19 566202. 47 MWD+IFR-AK-CAZ-SC ' 7333 .09 72. 29 101. 91 3684 .96 3574. 06 -1157.99 5569.17 5958001.31 566248. 94 MWD+IFR-AK-CAZ-SC 7379 .49 71. 41 99. 87 3699 .41 3588. 51 -1166.32 5612.46 5957993.33 566292. 29 MWD+IFR-AK-CAZ-SC 7417 .79 71. 33 99. 31 3711 .65 3600. 75 -1172.37 5648.25 5957987.57 566328. 12 MWD+IFR-AK-CAZ-SC 7515 .84 70. 07 98. 35 3744 .05 3633. 15 -1186.58 5739.68 5957974.10 566419. 67 MWD+IFR-AK-CAZ-SC ' 7550 .75 70. 45 98. 64 3755 .85 3644. 95 -1191.43 5772.18 5957969.51 566452. 20 MWD+IFR-AK-CAZ-SC ', 7618 .42 70. 30 99. 28 3778 .57 3667. 67 -1201.36 5835.14 5957960.09 566515. 23 MWD+IFR-AK-CAZ-SC II ' ! 7660 .73 69. 40 101. 27 3793 .15 3682. 25 -1208.44 5874.22 5957953.33 566554. 37 MWD+IFR-AK-CAZ-SC I ', 7713 .60 69. 73 102. 17 3811 .61 3700. 71 -1218.50 5922.73 5957943.66 566602. 95 MWD+IFR-AK-CAZ-SC ', 7808 .33 70. 59 102. 40 3843 .76 3732. 86 -1237.46 6009.80 5957925.40 566690. 16 MWD+IFR-AK-CAZ-SC ', 7897 .42 70. 27 102. 42 3873 .60 3762. 70 -1255.50 6091.78 5957908.03 566772. 27 MWD+IFR-AK-CAZ-SC ~ ', 7993 ~ .11 71. 51 101. 48 3904 .93 3794. 03 -1274.22 6180.24 5957890.02 566860. 87 MWD+IFR-AK-CAZ-SC ' ~ ', 8093 .41 72. 51 103. 25 3935 .91 3825. 01 -1294.65 6273.41 5957870.35 566954. 20 MWD+IFR-AK-CAZ-SC '' ' 8189 .03 72. 47 100. 92 3964 .68 3853. 78 -1313.74 6362.57 5957851.98 567043. 50 MWD+IFR-AK-CAZ-SC I~ 8285 .68 72. 66 99. 92 3993 .64 3882. 74 -1330.42 6453.26 5957836.04 567134. 31 MWD+IFR-AK-CAZ-SC 8382 .44 69. 57 97. 78 4024 .96 3914. 06 -1344.52 6543.70 5957822.67 567224. 86 MWD+IFR-AK-CAZ-SC '~ 8425 I .54 67. 56 97. 74 4040 .71 3929. 81 -1349.93 6583.45 5957817.58 567264. 65 MWD+IFR-AK-CAZ-SC ' 8473 .81 67. 95 97. 13 4058 .98 3948. 08 -1355.71 6627.75 5957812.15 567308. 99 MWD+IFR-AK-CAZ-SC ' ', 8570 .32 67. 15 99. 29 4095 .84 3984. 94 -1368.45 6716.03 5957800.14 567397. 35 MWD+IFR-AK-CAZ-SC ii 8664 .85 67. 91 100. 27 4131 .97 4021. 07 -1383.29 6802.11 5957785.99 567483. 54 MWD+IFR-AK-CAZ-SC I, 8677 .01 67. 84 100. 59 4136 .55 4025. 65 -1385.33 6813.19 5957784.04 567494. 64 MWD+IFR-AK-CAZ-SC ~~ 8760 .89 68. 05 102. 03 4168 .05 4057. 15 -1400.57 6889.42 5957769.42 567570. 98 MWD+IFR-AK-CAZ-SC 8855 .30 69. 34 102. 64 4202 .35 4091. 45 -1419.36 6975.34 5957751.32 567657. 05 MWD+IFR-AK-CAZ-SC 8950 .67 69. 14 102. 82 4236 .15 4125. 25 -1439.01 7062.33 5957732.37 567744. 18 MWD+IFR-AK-CAZ-SC '~ ~ 9046 .49 67. 64 102. 63 4271 .44 4160. 54 -1458.64 7149.22 5957713.45 567831. 22 MWD+IFR-AK-CAZ-SC I, 9141 .11 68. 27 103. 31 4306 .96 4196. 06 -1478.32 7234.69 5957694.46 567916. 83 MWD+IFR-AK-CAZ-SC ', 9236 .73 67. 18 101. 95 4343 .20 4232. 30 -1497.67 7321.03 5957675.81 568003. 32 MWD+IFR-AK-CAZ-SC ''~ 9331 .80 67. 06 101. 21 4380 .17 4269. 27 -1515.26 7406.83 5957658.92 568089. 25 MWD+IFR-AK-CAZ-SC 9426 .98 67. 77 101. 65 4416 .72 4305. 82 -1532.67 7492.97 5957642.20 568175. 52 MWD+IFR-AK-CAZ-SC ' 9522 .24 67. 72 101. 98 4452 .80 4341. 90 -1550.72 7579.26 5957624.85 568261. 95 MWD+IFR-AK-CAZ-SC ' 9604 .97 67. 38 101. 23 4484 .39 4373. 49 -1566.11 7654.16 5957610.08 568336. 96 MWD+IFR-AK-CAZ-SC 9708 .89 68. 35 101. 34 4523 .55 4412. 65 -1584.94 7748.56 5957592.00 568431. 50 MWD+IFR-AK-CAZ-SC I 9804 .06 68. 72 102. 32 4558 .37 4447. 47 -1603.10 7835.25 5957574.55 568518. 32 MWD+IFR-AK-CAZ-SC ' ' 9899 .05 68. 03 100. 54 4593 .38 4482. 48 -1620.60 7921.79 5957557.75 568605. 00 MWD+IFR-AK-CAZ-SC 9993 .81 68. 15 100. 17 4628 .74 4517. 84 -1636.40 8008.28 5957542.65 568691. 60 MWD+IFR-AK-CAZ-SC ' 10088 .05 68. 11 100. 38 4663 .85 4552. 95 -1652.00 8094.33 5957527.74 568777. 77 MWD+IFR-AK-CAZ-SC '' 10184 .05 68. 83 98. 72 4699 .08 4588. 18 -1666.82 8182.39 5957513.64 568865. 94 MWD+IFR-AK-CAZ-SC ', III 10278 .87 69. 10 97. 73 4733 .11 4622. 21 -1679.48 8269.98 5957501.69 568953. 62 MWD+IFR-AK-CAZ-SC 10374 .41 69. 70 99. 86 4766 .73 4655. 83 -1693.15 8358.35 5957488.73 569042. 09 MWD+IFR-AK-CAZ-SC 10469 .09 69. 08 102. 63 4800 .07 4689. 17 -1710.43 8445.26 5957472.16 569129. 13 MWD+IFR-AK-CAZ-SC ' 10564 .94 69. 08 103. 05 4834 .29 4723. 39 -1730.32 8532.56 5957452.97 569216. 57 MWD+IFR-AK-CAZ-SC ! 10660 .07 69. 09 102. 75 4868 .25 4757. 35 -1750.16 8619.17 5957433.83 569303. 34 MWD+IFR-AK-CAZ-SC ', 10754 .32 68. 94 103. 62 4902 .00 4791. 10 -1770.23 8704.85 5957414.46 569389. 17 MWD+IFR-AK-CAZ-SC I'i 10850 .80 68. 92 104. 27 4936 .69 4825. 79 -1791.93 8792.23 5957393.47 569476. 71 MWD+IFR-AK-CAZ-SC '', 10945 .83 68. 77 104. 83 4970 .99 4860. 09 -1814.19 8878.01 5957371.90 569562. 66 MWD+IFR-AK-CAZ-SC 11040 .93 68. 62 105. 94 5005 .54 4894. 64 -1837.70 8963.44 5957349.09 569648. 26 MWD+IFR-AK-CAZ-SC I, 11136 .63 72. 02 102. 43 5037 .77 4926. 87 -1859.75 9050.78 5957327.75 569735. 77 MWD+IFR-AK-CAZ-SC 11231 .39 72. 56 101. 93 5066 .60 4955. 70 -1878.79 9139.01 5957309.42 569824. 15 MWD+IFR-AK-CAZ-SC ~ 11326 .99 70. 77 100. 53 5096 .67 4985. 77 -1896.47 9228.01 5957292.46 569913. 28 MWD+IFR-AK-CAZ-SC I~ 11421 .50 70. 64 100. 41 5127 .90 5017. 00 -1912.68 9315.73 5957276.96 570001. 11 MWD+IFR-AK-CAZ-SC I ' 11515 .94 70. 52 100. 45 5159 .30 5048. 40 -1928.80 9403.33 5957261.55 570088. 83 ~ MWD+IFR-AK-CAZ-SC I~ - - -- ----1 ----- -- - -- - ----- --. ----- Halliburton Company Survey Report -- - __ - Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 Time: 13:59:46 Page: 4 '~' Eield: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1D-41, True North ~,' Site: Kuparuk 1 D Pad Vertical (T~'D) ReCerence: 1 D-41:110.9 '~~ Well: 1D-41 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) 'i ~Vellpath: 1 D-41 P61 Survey Calculation Method: Minimum Curvature Db: Oraale Survey Sys 7ti'D _ -_ N/S E/~V MapN i~tapE _ Tool _ _ __ ,I~ID Incl ,~zim TVD _ ', ft deg deg ft ft ft ft ft ft -___ 11613.13 70.36 100.49 5191.84 5080.94 -1945.44 9493.38 5957245.64 570179.01 MWD+IFR-AK-CAZ-SC ', 11708.29 70.13 100.23 5224.00 5113.10 -1961.55 9581.48 5957230.24 570267.23 MWD+IFR-AK-CAZ-SC ~' 11803.33 70.08 100.18 5256.35 5145.45 -1977.38 9669.43 5957215.12 570355.30 MWD+IFR-AK-CAZ-SC 11898.11 69.93 100.38 5288.75 5177.85 -1993.28 9757.07 5957199.94 570443.05 MWD+IFR-AK-CAZ-SC 11991.15 69.82 100.64 5320.77 5209.87 -2009.21 9842.97 5957184.70 570529.06 MWD+IFR-AK-CAZ-SC 12087.56 69.84 100.67 5354.01 5243.11 -2025.94 9931.90 5957168.68 570618.12 MWD+IFR-AK-CAZ-SC ' 12179.61 68.02 101.34 5387.10 5276.20 -2042.34 10016.22 5957152.97 570702.56 MWD+IFR-AK-CAZ-SC ~, , 12278.53 67.95 101.40 5424.18 5313.28 -2060.42 10106.12 5957135.62 570792.60 MWD+IFR-AK-CAZ-SC I 12373.84 67.98 101.67 5459.94 5349.04 -2078.08 10192.69 5957118.66 570879.29 MWD+IFR-AK-CAZ-SC ~ 12469.56 68.17 101.59 5495.68 5384.78 -2095.98 10279.66 5957101.46 570966.40 MWD+IFR-AK-CAZ-SC 12564.86 68.22 101.77 5531.08 5420.18 -2113.90 10366.31 5957084.25 571053.18 MWD+IFR-AK-CAZ-SC '~, 12660.56 68.35 101.65 5566.49 5455.59 -2131.94 10453.37 5957066.91 571140.38 MWD+IFR-AK-CAZ-SC li 12755.76 68.59 101.64 5601.42 5490.52 -2149.82 10540.10 5957049.74 571227.24 MWD+IFR-AK-CAZ-SC i 12850.72 68.74 101.56 5635.97 5525.07 -2167.60 10626.75 5957032.65 571314.02 MWD+IFR-AK-CAZ-SC ~~ 12945.81 69.00 101.99 5670.25 5559.35 -2185.70 10713.58 5957015.26 571400.99 MWD+IFR-AK-CAZ-SC 13041.11 67.76 101.99 5705.36 5594.46 -2204.11 10800.24 5956997.55 571487.79 MWD+IFR-AK-CAZ-SC ' 13136.64 67.71 102.44 5741.56 5630.66 -2222.81 10886.64 5956979.55 571574.33 MWD+IFR-AK-CAZ-SC ' 13230.18 67.77 102.27 5776.99 5666.09 -2241.34 10971.21 5956961.71 571659.03 MWD+IFR-AK-CAZ-SC 13325.33 67.87 102.50 5812.91 5702.01 -2260.23 11057.27 5956943.51 571745.23 MWD+IFR-AK-CAZ-SC ', 13420.42 67.43 102.29 5849.07 5738.17 -2279.11 11143.16 5956925.33 571831.27 MWD+IFR-AK-CAZ-SC ', ~, 13515.85 66.99 102.57 5886.04 5775.14 -2298.05 11229.08 5956907.09 571917.33 MWD+IFR-AK-CAZ-SC ', ', 13611.48 68.79 101.47 5922.03 5811.13 -2316.49 11315.73 5956889.35 572004.12 MWD+IFR-AK-CAZ-SC ', 13707.00 68.22 101.21 5957.03 5846.13 -2333.97 11402.87 5956872.57 572091.39 MWD+IFR-AK-CAZ-SC ~ ', 13802.23 70.21 102.27 5990.83 5879.93 -2352.09 11490.04 5956855.16 572178.69 MWD+IFR-AK-CAZ-SC ', 13897.58 70.13 102.55 6023.17 5912.27 -2371.36 11577.64 5956836.59 572266.43 MWD+IFR-AK-CAZ-SC '' 13993.01 69.97 102.41 6055.73 5944.83 -2390.75 11665.22 5956817.92 572354.16 MWD+IFR-AK-CAZ-SC II 14088.08 69.68 102.92 6088.52 5977.62 -2410.31 11752.28 5956799.06 572441.37 MWD+IFR-AK-CAZ-SC ', 14183.03 69.42 102.26 6121.70 6010.80 -2429.71 11839.11 5956780.37 572528.35 MWD+IFR-AK-CAZ-SC 14276.32 69.38 102.85 6154.52 6043.62 -2448.69 11924.35 5956762.08 572613.72 MWD+IFR-AK-CAZ-SC ', 14370.88 69.38 102.56 6187.82 6076.92 -2468.15 12010.68 5956743.31 572700.21 MWD+IFR-AK-CAZ-SC 14465.98 69.14 102.25 6221.50 6110.60 -2487.26 12097.54 5956724.91 572787.21 MWD+IFR-AK-CAZ-SC II ~' 14556.14 68.99 102.27 6253.71 6142.81 -2505.14 12179.83 5956707.70 572869.63 MWD+IFR-AK-CAZ-SC 14657.34 68.83 101.89 6290.13 6179.23 -2524.90 12272.16 5956688.69 572962.11 MWD+IFR-AK-CAZ-SC 14751.11 68.84 101.44 6323.98 6213.08 -2542.58 12357.80 5956671.70 573047.88 MWD+IFR-AK-CAZ-SC 14847.25 68.73 102.07 6358.77 6247.87 -2560.84 12445.54 5956654.15 573135.76 MWD+IFR-AK-CAZ-SC I ', 14941.37 68.57 101.88 6393.04 6282.14 -2579.03 12531.30 5956636.66 573221.65 MWD+IFR-AK-CAZ-SC 15038.42 68.53 101.05 6428.53 6317.63 -2596.98 12619.82 5956619.42 573310.31 MWD+IFR-AK-CAZ-SC 15133.39 68.30 101.16 6463.47 6352.57 -2613.99 12706.48 5956603.11 573397.09 MWD+IFR-AK-CAZ-SC ii I 15228.90 70.15 101.40 6497.34 6386.44 -2631.46 12794.05 5956586.35 573484.79 MWD+IFR-AK-CAZ-SC 15322.04 73.91 100.32 6526.08 6415.18 -2648.14 12881.04 5956570.38 573571.91 MWD+IFR-AK-CAZ-SC 15408.81 77.92 99.62 6547.19 6436.29 -2662.70 12963.92 5956556.48 573654.89 MWD+IFR-AK-CAZ-SC 15513.90 81.28 99.88 6566.16 6455.26 -2680.21 13065.77 5956539.81 573756.87 MWD+IFR-AK-CAZ-SC 15609.22 83.65 100.32 6578.65 6467.75 -2696.78 13158.80 5956523.99 573850.02 MWD+IFR-AK-CAZ-SC 15705.28 83.79 98.98 6589.16 6478.26 -2712.78 13252.93 5956508.74 573944.27 MWD+IFR-AK-CAZ-SC ~I 15800.44 83.71 98.30 6599.52 6488.62 -2726.99 13346.45 5956495.29 574037.89 MWD+IFR-AK-CAZ-SC ~~ 15894.15 83.37 97.47 6610.07 6499.17 -2739.77 13438.68 5956483.26 574130.21 MWD+IFR-AK-CAZ-SC i, 15947.00 83.37 97.47 6616.17 6505.27 -2746.59 13490.73 5956476.86 574182.31 PROJECTED to TD Halliburton Company Survey Report 'i Company: ConocoPhillips Alaska Inc. ' Field: Kuparuk River Unit I Site: Kuparuk 1 D Pad R'cll: 1 D-41 ~ li ~Yellpath: 1 D-41 PB2 - __ _ _ -- I~ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 i Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level _~- "Well: 1 D-41 ----- ' Well Position: +N/-S -552.14 ft Northing: 5959114.19 ft +E/-W -419.85 ft Easting : 560671.14 ft L Position Uncertainty: 0.00 ft ellpath: 1 D-41 P62 i 500292328871 Current Datum: 1 D-41 PB2: Height 110.90 ft Magnetic Data: 1/10/2006 I, Field Strength: 57568 nT Vertical Section: Depth From (TVD) +N/-S ft ft 41.40 0.00 Survey Program for Definitive Wellpath Date: 4/25/2006 Validated: No Actual From To Survey ft ft 81.00 800.00 1 D-41 P61 gyro (81.00-800.00) 858.35 13611.48 1 D-41 P61 (858.35-15894.15) (0) 13707.00 16079.44 1 D-41 P62 (13707.00-16079.44) ' Survey SID Incl Azim TVD Sys TVD N! ', ft deg deg ft ft __ ft 41.40 0.00 0.00 41.40 -69.50 ~, ~ 81.00 0.30 7.84 81.00 -29.90 ' i 100.00 0.35 343.30 100.00 -10.90 ', j 200.00 0.68 151.14 200.00 89.10 '' 300.00 4.70 121.94 299.87 188.97 Date: 4/25/2006 Time: 10:32:46 Yagr. 1 Co-ordinate(NE) Reference: Well: 1D-41, True North Vertical (TVD) Reference: 1 D-41 PB2: 110.9 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Survey Calculation D4ethod: Minimum Curvature Db: Oracle Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: bggm2005 Slot Name: Latitude: 70 17 55.887 N Longitude: 149 30 31.160 W Drilled From: 1 D-41 P61 Tie-on Depth: 13611.48 ft Above System Datum: Mean Sea Level Declination: 24.24 deg Mag Dip Angle: 80.80 deg +E/-W Direction ft deg 0.00 100.00 Version: 1 Toolcode Tool Name CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC S E/VV ft 0.00 0.00 0.10 0.01 0.21 0.00 -0.02 0.20 -2.71 3.97 400.00 7.27 113.68 399.32 288.42 -7.42 13.24 500.00 9.16 108.38 498.29 387.39 -12.47 26.59 600.00 11.90 102.22 596.60 485.70 -17.16 44.22 700.00 13.10 102.58 694.23 583.33 -21.81 65.36 800.00 13.61 100.59 791.52 680.62 -26.44 87.99 858.35 14,43 106.22 848.14 737.24 -29.74 101.72 953.59 18.53 107.33 939.44 828.54 -37.56 127.57 1047.87 21.75 105.42 1027.95 917.05 -46.67 158.72 1142.65 22.99 104.08 1115.59 1004.69 -55.84 193.60 1237.05 26.08 101.99 1201.46 1090.56 -64.64 231.79 1334.26 30.19 104.11 1287.17 1176.27 -75.04 276.42 1427.24 30.78 104.12 1367.30 1256.40 -86.55 322.16 1473.11 31.70 103.32 1406.51 1295.61 -92.19 345.27 1523.43 32.55 101.68 1449.13 1338.23 -97.97 371.40 1552.87 32.82 102.11 1473.91 1363.01 -101.25 386.95 1619.86 37.14 100.74 1528.79 1417.89 -108.83 424.59 1714.34 43.88 100.77 1600.58 1489.68 -120.28 484.85 1808.80 47.09 99.94 1666.79 1555.89 -132.37 551.10 1903.90 52.69 100.97 1728.04 1617.14 -145.59 622.59 1994.29 60.49 101.41 1777.77 1666.87 -160.23 696.55 2093.58 63.19 102.40 1824.63 1713.73 -178.30 782.19 2187.11 66.49 100.64 1864.39 1753.49 -195.19 865.13 2280.61 64.38 101.47 1903.26 1792.36 -211.49 948.59 MapN MapE Tool ft ft 5959114.19 560671.14 TIE LINE 5959114.29 560671.15 CB-GYRO-SS 5959114.40 560671.14 CB-GYRO-SS 5959114.17 560671.34 CB-GYRO-SS 5959111.51 560675.13 CB-GYRO-SS 5959106.88 560684.44 CB-GYRO-SS I 5959101.94 560697.83 CB-GYRO-SS 5959097.39 560715.50 CB-GYRO-SS 5959092.91 560736.67 CB-GYRO-SS 5959088.46 560759.33 CB-GYRO-SS I 5959085.28 560773.08 MWD+IFR-AK-CAZ-SC II 5959077.66 560799.00 MWD+IFR-AK-CAZ-SC ~I 5959068.81 560830.22 MWD+IFR-AK-CAZ-SC 5959059.92 560865.17 MWD+IFR-AK-CAZ-SC 5959051.43 560903.42 MWD+IFR-AK-CAZ-SC 5959041.39 560948.13 MWD+IFR-AK-CAZ-SC 5959030.25 560993.96 MWD+IFR-AK-CAZ-SC 5959024.80 561017.11 MWD+IFR-AK-CAZ-SC 5959019.23 561043.28 MWD+IFR-AK-CAZ-SC 5959016.08 561058.86 MWD+IFR-AK-CAZ-SC 5959008.80 561096.55 MWD+IFR-AK-CAZ-SC 5958997.84 561156.90 MWD+IFR-AK-CAZ-SC ' . 5958986.28 561223.24 MWD+IFR-AK-CAZ-SC I 5958973.64 561294.83 MWD+IFR-AK-CAZ-SC 5958959.60 561368.90 MWD+IFR-AK-CAZ-SC 5958942.23 561454.67 MWD+IFR-AK-CAZ-SC 5958926.01 561537.74 MWD+IFR-AK-CAZ-SC 5958910.39 561621.31 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 4/25/2006 'l'ime: 10:32:46 Page: 2 Field: Kuparuk River Unit Co-ordioate(NE) Reference: Well: 1 D-41, True North ' Site: Kuparuk 1 D Pad Vertical (TVD) Reference: t0-41 P62: 110.9 Well: 1 D-41 Section (VS) Reference: Well (OAON,O.OOE,100.OpAzi) Wellpath: 1 D-41 P62 Survey Calculation Method: Minimum Curvature Db: Oracle Survey - _ __ __ J1D Incl Azim TVD Sys 'TVD N/S E/W ~IapN MapE Tool ' ft deg deg ft ft ft ft ft ft ', 2379.50 68.45 101.55 1942.82 1831.92 -229.57 1037.38 5958893.03 561710.24 MWD+IFR-AK-CAZ-SC 2474.74 71.32 99.37 1975.57 1864.67 -245.79 1125.31 5958877.52 561798.29 MWD+IFR-AK-CAZ-SC 2569.80 72.07 100.05 2005.42 1894.52 -261.01 1214.26 5958863.02 561887.35 MWD+IFR-AK-CAZ-SC 2664.83 71.50 98.43 2035.13 1924.23 -275.50 1303.36 5958849.24 561976.55 MWD+IFR-AK-CAZ-SC ~~ 2762.41 70.21 97.27 2067.13 1956.23 -288.10 1394.67 5958837.39 562067.96 MWD+IFR-AK-CAZ-SC 2857.46 69.85 97.19 2099.60 1988.70 -299.34 1483.29 5958826.86 562156.66 MWD+IFR-AK-CAZ-SC 2953.89 70.22 97.64 2132.52 2021.62 -311.04 1573.17 5958815.89 562246.62 MWD+IFR-AK-CAZ-SC i 3052.32 69.17 97.43 2166.68 2055.78 -323.14 1664.69 5958804.53 562338.22 MWD+IFR-AK-CAZ-SC j 3147.29 67.94 98.97 2201.40 2090.50 -335.75 1752.17 5958792.63 562425.80 MWD+IFR-AK-CAZ-SC ~ 3242.02 66.93 100.45 2237.75 2126.85 -350.49 1838.39 5958778.58 562512.13 MWD+IFR-AK-CAZ-SC ', ', 3336.35 68.93 103.83 2273.20 2162.30 -368.89 1923.83 5958760.88 562597.70 MWD+IFR-AK-CAZ-SC 3432.15 72.35 105.43 2304.96 2194.06 -391.73 2011.27 5958738.75 562685.31 MWD+IFR-AK-CAZ-SC li 3527.68 71.35 106.14 2334.72 2223.82 -416.42 2098.62 5958714.76 562772.85 MWD+IFR-AK-CAZ-SC 3622.62 68.05 107.47 2367.65 2256.75 -442.15 2183.85 5958689.73 562858.28 MWD+IFR-AK-CAZ-SC 3710.80 66.91 108.11 2401.43 2290.53 -467.03 2261.41 5958665.47 562936.03 MWD+IFR-AK-CAZ-SC 3745.36 67.85 107.83 2414.72 2303.82 -476.88 2291.75 5958655.88 562966.45 MWD+IFR-AK-CAZ-SC 3810.24 66.23 108.19 2440.03 2329.13 -495.35 2348.56 5958637.87 563023.40 MWD+IFR-AK-CAZ-SC ~ 3909.00 65.02 106.96 2480.79 2369.89 -522.51 2434.32 5958611.40 563109.36 MWD+IFR-AK-CAZ-SC li 4005.84 70.78 106.26 2517.20 2406.30 -548.14 2520.26 5958586.47 563195.50 MWD+IFR-AK-CAZ-SC 4096.87 71.44 106.02 2546.67 2435.77 -572.08 2603.00 5958563.20 563278.42 MWD+IFR-AK-CAZ-SC 4193.26 68.45 106.37 2579.73 2468.83 -597.33 2689.94 5958538.65 563365.56 MWD+IFR-AK-CAZ-SC 4289.61 67.14 105.67 2616.14 2505.24 -621.95 2775.68 5958514.73 563451.48 MWD+IFR-AK-CAZ-SC 4384.85 69.19 104.50 2651.56 2540.66 -644.95 2861.03 5958492.42 563537.01 MWD+IFR-AK-CAZ-SC 4480.25 70.35 103.53 2684.55 2573.65 -666.62 2947.88 5958471.45 563624.02 MWD+IFR-AK-CAZ-SC 4574.60 71.22 101.45 2715.60 2604.70 -685.89 3034.86 5958452.89 563711.15 MWD+IFR-AK-CAZ-SC 4668.23 70.87 101.00 2746.02 2635.12 -703.12 3121.72 5958436.36 563798.13 MWD+IFR-AK-CAZ-SC '; 4762.10 69.79 101.19 2777.61 2666.71 -720.13 3208.46 5958420.05 563885.00 MWD+IFR-AK-CAZ-SC '. I 4855.30 70.08 100.01 2809.59 2698.69 -736.24 3294.50 5958404.65 563971.16 MWD+IFR-AK-CA2-SC ' 4951.60 70.06 99.36 2842.42 2731.52 -751.47 3383.75 5958390.14 564060.52 MWD+IFR-AK-CAZ-SC ' 5047.06 72.54 99.75 2873.02 2762.12 -766.48 3472.90 5958375.85 564149.79 MWD+IFR-AK-CAZ-SC '' 5141.55 73.62 100.19 2900.52 2789.62 -782.13 3561.94 5958360.92 564238.93 MWD+IFR-AK-CAZ-SC ', 5235.35 71.76 98.20 2928.43 2817.53 -796.44 3650.33 5958347.32 564327.43 MWD+IFR-AK-CAZ-SC 5329.58 69.06 98.77 2960.02 2849.12 -809.54 3738.12 5958334.93 564415.32 MWD+IFR-AK-CAZ-SC ', 5426.15 67.26 99.55 2995.95 2885.05 -823.80 3826.62 5958321.38 564503.91 MWD+IFR-AK-CAZ-SC !, 5523.21 64.68 99.76 3035.47 2924.57 -838.67 3914.00 5958307.23 564591.41 MWD+IFR-AK-CAZ-SC '~~ 5617.68 63.80 99.25 3076.52 2965.62 -852.72 3997.91 5958293.86 564675.42 MWD+IFR-AK-CAZ-SC !I 5709.88 68.56 98.71 3113.75 3002.85 -865.87 4081.20 5958281.37 564758.81 MWD+IFR-AK-CAZ-SC II 5804.06 71.40 98.13 3145.99 3035.09 -878.83 4168.73 5958269.13 564846.43 MWD+IFR-AK-CAZ-SC 5903.97 71.25 98.01 3177.98 3067.08 -892.11 4262.44 5958256.60 564940.24 MWD+IFR-AK-CAZ-SC 5999.13 72.21 98.37 3207.81 3096.91 -904.99 4351.88 5958244.45 565029.77 MWD+IFR-AK-CAZ-SC 6090.59 73.08 98.89 3235.09 3124.19 -918.09 4438.19 5958232.05 565116.17 MWD+IFR-AK-CAZ-SC 6142.39 71.76 98.53 3250.74 3139.84 -925.56 4487.00 5958224.97 565165.03 MWD+IFR-AK-CAZ-SC 6184.87 71.26 98.56 3264.21 3153.31 -931.55 4526.84 5958219.30 565204.92 MWD+IFR-AK-CAZ-SC 6286.31 68.27 100.16 3299.29 3188.39 -947.01 4620.74 5958204.60 565298.93 MWD+IFR-AK-CAZ-SC 6314.23 68.05 99.80 3309.68 3198.78 -951.51 4646.26 5958200.31 565324.49 MWD+IFR-AK-CAZ-SC 6380.14 68.27 99.98 3334.20 3223.30 -962.01 4706.53 5958190.29 565384.83 MWD+IFR-AK-CAZ-SC 6475.73 67.56 101.26 3370.14 3259.24 -978.34 4793.59 5958174.68 565472.01 MWD+IFR-AK-CAZ-SC ~i 6570.65 66.22 102.37 3407.40 3296.50 -996.21 4879.04 5958157.50 565557.59 MWD+IFR-AK-CAZ-SC 6664.00 66.61 101.93 3444.75 3333.85 -1014.21 4962.67 5958140.17 565641.36 MWD+IFR-AK-CAZ-SC 6761.41 63.90 102.69 3485.52 3374.62 -1033.06 5049.10 5958122.02 565727.93 MWD+IFR-AK-CAZ-SC 6856.16 64.75 103.62 3526.57 3415.67 -1052.50 5132.25 5958103.26 565811.23 MWD+IFR-AK-CAZ-SC ', i 6945.51 68.41 103.86 3562.08 3451.18 -1071.97 5211.88 5958084.43 565891.00 MWD+IFR-AK-CAZ-SC ------- -- _ -- -- --_ _ _ I. Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 'l'ime: 10:32:46 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 D-41, True North Site: Kuparuk 1 D Pad Vertical (TVD) Reference: 1 D-41 PB2: 110.9 Wcll: 1 D-41 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) ~Vellpath: 1 D-41 PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Survcv ___ __ __ _ __ S9ll Incl Azim 'TVD Sys TVD N/S E/~V A~IapN 1IapE Tool ft deg deg ft ft ft ft ft ft 7232.93 71.86 102.93 3654.0$ 3543.08 -11037.010 54$6.25 5958021.54 5661055.86 MWD+IFR AK-CAZ-SC 7283.16 71.93 103.03 3669.62 3558.72 -1147.73 5522.77 5958011.19 566202.47 MWD+IFR-AK-CAZ-SC ~i 7333.09 72.29 101.91 3684.96 3574.06 -1157.99 5569.17 5958001.31 566248.94 MWD+IFR-AK-CAZ-SC 7379.49 71.41 99.87 3699.41 3588.51 -1166.32 5612.46 5957993.33 566292.29 MWD+IFR-AK-CAZ-SC 7417.79 71.33 99.31 3711.65 3600.75 -1172.37 5648.25 5957987.57 566328.12 MWD+IFR-AK-CAZ-SC 7515.84 70.07 98.35 3744.05 3633.15 -1186.58 5739.68 5957974.10 566419.67 MWD+IFR-AK-CAZ-SC 7550.75 70.45 98.64 3755.85 3644.95 -1191.43 5772.18 5957969.51 566452.20 MWD+IFR-AK-CAZ-SC 7618.42 70.30 99.28 3778.57 3667.67 -1201.36 5835.14 5957960.09 566515.23 MWD+IFR-AK-CAZ-SC 7660.73 69.40 101.27 3793.15 3682.25 -1208.44 5874.22 5957953.33 566554.37 MWD+IFR-AK-CAZ-SC 7713.60 69.73 102.17 3811.61 3700.71 -1218.50 5922.73 5957943.66 566602.95 MWD+IFR-AK-CAZ-SC 7808.33 70.59 102.40 3843.76 3732.86 -1237.46 6009.80 5957925.40 566690.16 MWD+IFR-AK-CAZ-SC ~I 7897.42 70.27 102.42 3873.60 3762.70 -1255.50 6091.78 5957908.03 566772.27 MWD+IFR-AK-CAZ-SC 7993.11 71.51 101.48 3904.93 3794.03 -1274.22 6180.24 5957890.02 566860.87 MWD+IFR-AK-CAZ-SC 8093.41 72.51 103.25 3935.91 3825.01 -1294.65 6273.41 5957870.35 566954.20 MWD+IFR-AK-CAZ-SC ~ 8189.03 72.47 100.92 3964.68 3853.78 -1313.74 6362.57 5957851.98 567043.50 MWD+IFR-AK-CAZ-SC 8285.68 72.66 99.92 3993.64 3882.74 -1330.42 6453.26 5957836.04 567134.31 MWD+IFR-AK-CAZ-SC 8382.44 69.57 97.78 4024.96 3914.06 -1344.52 6543.70 5957822.67. 567224.86 MWD+IFR-AK-CAZ-SC 8425.54 67.56 97.74 4040.71 3929.81 -1349.93 6583.45 5957817.58 567264.65 MWD+IFR-AK-CAZ-SC 8473.81 67.95 97.13 4058.98 3948.08 -1355.71 6627.75 5957812.15 567308.99 MWD+IFR-AK-CAZ-SC 8570.32 67.15 99.29 4095.84 3984.94 -1368.45 6716.03 5957800.14 567397.35 MWD+IFR-AK-CAZ-SC 8664.85 67.91 100.27 4131.97 4021.07 -1383.29 6802.11 5957785.99 567483.54 MWD+IFR-AK-CAZ-SC it 8677.01 67.84 100.59 4136.55 4025.65 -1385.33 6813.19 5957784.04 567494.64 MWD+IFR-AK-CAZ-SC 8760.89 68.05 102.03 4168.05 4057.15 -1400.57 6889.42 5957769.42 567570.98 MWD+IFR-AK-CAZ-SC 8855.30 69.34 102.64 4202.35 4091.45 -1419.36 6975.34 5957751.32 567657.05 MWD+IFR-AK-CAZ-SC ' i 8950.67 69.14 102.82 4236.15 4125.25 -1439.01 7062.33 5957732.37 567744.18 MWD+IFR-AK-CAZ-SC ', 9046.49 67.64 102.63 4271.44 4160.54 -1458.64 7149.22 5957713.45 567831.22 MWD+IFR-AK-CAZ-SC ', ~ 9141.11 68.27 103.31 4306.96 4196.06 -1478.32 7234.69 5957694.46 567916.83 MWD+IFR-AK-CAZ-SC 9236.73 67.18 101.95 4343.20 4232.30 -1497.67 7321.03 5957675.81 568003.32 MWD+IFR-AK-CAZ-SC 9331.80 67.06 101.21 4380.17 4269.27 -1515.26 7406.83 5957658.92 568089.25 MWD+IFR-AK-CAZ-SC 9426.98 67.77 101.65 4416.72 4305.82 -1532.67 7492.97 5957642.20 568175.52 MWD+IFR-AK-CAZ-SC ~; 9522.24 67.72 101.98 4452.80 4341.90 -1550.72 7579.26 5957624.85 568261.95 MWD+IFR-AK-CAZ-SC 9604.97 67.38 101.23 4484.39 4373.49 -1566.11 7654.16 5957610.08 568336.96 MWD+IFR-AK-CAZ-SC ', 9708.89 68.35 101.34 4523.55 4412.65 -1584.94 7748.56 5957592.00 568431.50 MWD+IFR-AK-CAZ-SC ' i ', 9804.06 68.72 102.32 4558.37 4447.47 -1603.10 7835.25 5957574.55 568518.32 MWD+IFR-AK-CAZ-SC 9899.05 68.03 100.54 4593.38 4482.48 -1620.60 7921.79 5957557.75 568605.00 MWD+IFR-AK-CAZ-SC '~, 9993.81 68.15 100.17 4628.74 4517.84 -1636.40 8008.28 5957542.65 568691.60 MWD+IFR-AK-CAZ-SC 10088.05 68.11 100.38 4663.85 4552.95 -1652.00 8094.33 5957527.74 568777.77 MWD+IFR-AK-CAZ-SC 10184.05 68.83 98.72 4699.08 4588.18 -1666.82 8182.39 5957513.64 568865.94 MWD+IFR-AK-CAZ-SC ', 10278.87 69.10 97.73 4733.11 4622.21 -1679.48 8269.98 5957501.69 568953.62 MWD+IFR-AK-CAZ-SC 10374.41 69.70 99.86 4766.73 4655.83 -1693.15 8358.35 5957488.73 569042.09 MWD+IFR-AK-CAZ-SC ': 10469.09 69.08 102.63 4800.07 4689.17 -1710.43 8445.26 5957472.16 569129.13 MWD+IFR-AK-CAZ-SC ' 10564.94 69.08 103.05 4834.29 4723.39 -1730.32 8532.56 5957452.97 569216.57 MWD+IFR-AK-CAZ-SC 10660.07 69.09 102.75 4868.25 4757.35 -1750.16 8619.17 5957433.83 569303.34 MWD+IFR-AK-CAZ-SC 'i 10754.32 68.94 103.62 4902.00 4791.10 -1770.23 8704.85 5957414.46 569389.17 MWD+IFR-AK-CAZ-SC i II 10850.80 68.92 104.27 4936.69 4825.79 -1791.93 8792.23 5957393.47 569476.71 MWD+IFR-AK-CAZ-SC I ', 10945.83 68.77 104.83 4970.99 4860.09 -1814.19 8878.01 5957371.90 569562.66 MWD+IFR-AK-CAZ-SC '; 11040.93 68.62 105.94 5005.54 4894.64 -1837.70 8963.44 5957349.09 569648.26 MWD+IFR-AK-CAZ-SC ' 'I 11136.63 72.02 102.43 5037.77 4926.87 -1859.75 9050.78 5957327.75 569735.77 MWD+IFR-AK-CAZ-SC ~! 11231.39 72.56 101.93 5066.60 4955.70 -1878.79 9139.01 5957309.42 569824.15 MWD+IFR-AK-CAZ-SC 11326.99 70.77 100.53 5096.67 4985.77 -1896.47 9228.01 5957292.46 569913.28 MWD+IFR-AK-CAZ-SC ', 11421.50 70.64 _ 100.41 _ 5127.90 5017.00 -1912.68 9315.73 5957276.96 570001.11 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date: 4/25/2006 Time: 10:32:46 Yaffe: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1D-41, True North Site: Kuparuk 1 D Pad Vertical ('fVD) Reference: 1 D-41 P62. 110.9 R'ell: 1D-41 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) ~Vellpath: 1D-41PB2 Survey Calculation tilethod: Minimum Curvature Db: .Oracle Surve~• - _ _ __ J~iD lncl Azim TVD SysTVD N/S E/W TV1apN N1apE 'Tool ft deg deg ft ft ft ft ft ft __ __ __ 11515.94 70.52 100.45 5159.30 5048.40 -1928.80 9403.33 5957261.55 570088.83 MWD+IFR-AK-CAZ-SC ', i 11613.13 70.36 100.49 5191.84 5080.94 -1945.44 9493.38 5957245.64 570179.01 MWD+IFR-AK-CAZ-SC 11708.29 70.13 100.23 5224.00 5113.10 -1961.55 9581.48 5957230.24 570267.23 MWD+IFR-AK-CAZ-SC 11803.33 70.08 100.18 5256.35 5145.45 -1977.38 9669.43 5957215.12 570355.30 MWD+IFR-AK-CAZ-SC 11898.11 69.93 100.38 5288.75 5177.85 -1993.28 9757.07 5957199.94 570443.05 MWD+IFR-AK-CAZ-SC '' 11991.15 69.82 100.64 5320.77 5209.87 -2009.21 9842.97 5957184.70 570529.06 MWD+IFR-AK-CAZ-SC 12087.56 69.84 100.67 5354.01 5243.11 -2025.94 9931.90 5957168.68 570618.12 MWD+IFR-AK-CAZ-SC I 12179.61 68.02 101.34 5387.10 5276.20 -2042.34 10016.22 5957152.97 570702.56 MWD+IFR-AK-CAZ-SC I, 12278.53 67.95 101.40 5424.18 5313.28 -2060.42 10106.12 5957135.62 570792.60 MWD+IFR-AK-CAZ-SC 12373.84 67.98 101.67 5459.94 5349.04 -2078.08 10192.69 5957118.66 570879.29 MWD+IFR-AK-CAZ-SC 12469.56 68.17 101.59 5495.68 5384.78 -2095.98 10279.66 5957101.46 570966.40 MWD+IFR-AK-CAZ-SC 12564.86 68.22 101.77 5531.08 5420.18 -2113.90 10366.31 5957084.25 571053.18 MWD+IFR-AK-CAZ-SC 12660.56 68.35 101.65 5566.49 5455.59 -2131.94 10453.37 5957066.91 571140.38 MWD+IFR-AK-CAZ-SC i 'I 12755.76 68.59 101.64 5601.42 5490.52 -2149.82 10540.10 5957049.74 571227.24 MWD+IFR-AK-CAZ-SC 'I II 12850.72 68.74 101.56 5635.97 5525.07 -2167.60 10626.75 5957032.65 571314.02 MWD+IFR-AK-CAZ-SC 12945.81 69.00 101.99 5670.25 5559.35 -2185.70 10713.58 5957015.26 571400.99 MWD+IFR-AK-CAZ-SC I ~~ 13041.11 67.76 101.99 5705.36 5594.46 -2204.11 10800.24 5956997.55 571487.79 MWD+IFR-AK-CAZ-SC II 13136.64 67.71 102.44 5741:56 5630.66 -2222.81 10886.64 5956979.55 571574.33 MWD+IFR-AK-CAZ-SC li 13230.18 67.77 102.27 5776.99 5666.09 -2241.34 10971.21 5956961.71 571659.03 MWD+IFR-AK-CAZ-SC ~I 13325.33 67.87 102.50 5812.91 5702.01 -2260.23 11057.27 5956943.51 571745.23 MWD+IFR-AK-CAZ-SC 13420.42 67.43 102.29 5849.07 5738.17 -2279.11 11143.16 5956925.33 571831.27 MWD+IFR-AK-CAZ-SC 13515.85 66.99 102.57 5886.04 5775.14 -2298.05 11229.08 5956907.09 571917.33 MWD+IFR-AK-CAZ-SC 13611.48 68.79 101.47 5922.03 5811.13 -2316.49 11315.73 5956889.35 572004.12 MWD+IFR-AK-CAZ-SC 13707.00 68.22 101.21 5957.03 5846.13 -2333.97 11402.87 5956872.57 572091.39 MWD+IFR-AK-CAZ-SC '' 13791.78 64.34 102.08 5991.13 5880.23 -2349.62 11478.88 5956857.54 572167.51 MWD+IFR-AK-CAZ-SC 13887.98 66.16 99.86 6031.41 5920.51 -2366.24 11564.64 5956841.62 572253.40 MWD+IFR-AK-CAZ-SC 13981.73 69.10 100.51 6067.08 5956.18 -2381.57 11649.96 5956826.98 572338.83 MWD+IFR-AK-CAZ-SC 14077.73 71.26 101.10 6099.63 5988.73 -2398.50 11738.66 5956810.76 572427.66 MWD+IFR-AK-CAZ-SC 14168.84 70.66 99.85 6129.36 6018.46 -2414.16 11823.35 5956795.79 572512.46 MWD+IFR-AK-CAZ-SC 14267.33 70.49 100.58 6162.11 6051.21 -2430.63 11914.76 5956780.06 572603.99 MWD+IFR-AK-CAZ-SC j 14362.70 70.03 100.15 6194.32 6083.42 -2446.78 12003.06 5956764.62 572692.41 MWD+IFR-AK-CAZ-SC 14458.16 71.73 99.18 6225.59 6114.69 -2461.92 12091.97 5956750.20 572781.43 MWD+IFR-AK-CAZ-SC ~~', 14548.47 71.46 99.44 6254.11 6143.21 -2475.78 12176.53 5956737.02 572866.09 MWD+IFR-AK-CAZ-SC ', 14645.85 70.99 98.44 6285.45 6174.55 -2490.11 12267.61 5956723.43 572957.27 MWD+IFR-AK-CAZ-SC '~ 14740.19 70.59 98.15 6316.49 6205.59 -2502.96 12355.76 5956711.29 573045.52 MWD+IFR-AK-CAZ-SC 14833.98 70.02 99.47 6348.10 6237.20 -2516.49 12443.02 5956698.48 573132.88 MWD+IFR-AK-CAZ-SC II 14934.64 72.12 99.45 6380.75 6269.85 -2532.14 12536.94 5956683.59 573226.91 MWD+IFR-AK-CAZ-SC 15029.01 71.66 99.60 6410.09 6299.19 -2546.98 12625.40 5956669.46 573315.48 MWD+IFR-AK-CAZ-SC 15122.67 71.19 98.88 6439.92 6329.02 -2561.23 12713.02 5956655.92 573403.21 MWD+IFR-AK-CAZ-SC 15216.91 70.30 99.67 6471.00 6360.10 -2575.57 12800.83 5956642.29 573491.12 MWD+IFR-AK-CAZ-SC 15314.83 70.69 99.69 6503.69 6392.79 -2591.09 12891.81 5956627.51 573582.22 MWD+IFR-AK-CAZ-SC ', 15410.25 70.57 100.27 6535.34 6424.44 -2606.69 12980.47 5956612.62 573670.99 MWD+IFR-AK-CAZ-SC it 15504.77 73.65 100.27 6564.37 6453.47 -2622.73 13068.97 5956597.30 573759.60 MWD+IFR-AK-CAZ-SC I 15600.79 76.08 101.89 6589.44 6478.54 -2640.54 13159.92 5956580.22 573850.68 MWD+IFR-AK-CAZ-SC 15658.88 77.22 102.06 6602.86 6491.96 -2652.27 13215.21 5956568.94 573906.06 MWD+IFR-AK-CAZ-SC I, 15731.76 79.12 103.35 6617.80 6506.90 -2667.96 13284.79 5956553.82 573975.76 MWD+IFR-AK-CAZ-SC ~~ 15771.72 79.69 103.97 6625.14 6514.24 -2677.24 13322.95 5956544.85 574014.00 MWD+IFR-AK-CAZ-SC 15863.18 87.18 108.91 6635.60 6524.70 -2702.95 13410.00 5956519.84 574101.24 MWD+IFR-AK-CAZ-SC i 15899.48 86.11 109.76 6637.72 6526.82 -2714.95 13444.19 5956508.12 574135.53 MWD+IFR-AK-CAZ-SC !, 15961.27 88.98 114.51 6640.37 6529.47 -2738.21 13501.36 5956485.33 574192.87 MWD+IFR-AK-CAZ-SC ' '~ 16051.46 92.07 119.99 6639.55 6528.65 -2779.48 13581.49 5956444.71 574273.33 MWD+IFR-AK-CAZ-SC 16079.44 88.80 111.47 6639.33 6528.43 -2791.61 13606.67 5956432.78 574298.60 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/25/2006 Time: 10:32:46 Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference:. Well: 1D-41, True North Sife: Kuparuk 1 D Pad Vertical (TVD) Reference: 1 D-41 PB2: 110.9 Well: 1D-41 Section (VS) Kefereuce: WeII (O.OON,O.OOE,100.OOAzi) Wellpath: 1 D-41 PB2 Survey Calculation14ethod: Minimum Curvature Db: Oracle Survev J~ID Incl Azim TVD Svs TVD ~ N/S E/W 1~1apN ?~iapE Tool ft deg deg ft ft ft ft ft ft 16118.00 88.80 111.47 6640.14 6529.24 __ ___ ___ -2805.72 13642.55 5956418.96 574334.59 PROJECTED to TD Re: Kuparuk 1D-41 status (205-188) • • Subject: Re: Kuparuk 1D-41 status (205-188) From: Thoulas Maunder <tom_~ziaunder@admin.stateakus Date: Mon, ~7 Feb ?00(, 10:1 l :?~ -(i900 To: 'Billi~~~sley. Tim A" Tim.A.Billil~gsle_y(aconocopli~llips.con% Tim, Thanks for the information and update. Your plan, at the present time, is to open hole sidetrack and drill new hole to the planned 7-5/8" casing point. Based on the behavior of the wellbore, it is CPAI's assessment that the original penetration is sealed. The plan is to set and cement the casing using original planned cement volumes/height unless there is drilling information to indicate otherwise. Good luck with the operations. Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 2/26/2006 12:42 PM: Tom Maunder, We have decided the 1D-41 present wellbore is too unstable to continue trying to clean it out to run 7-5/8' casing. Our plan is to low-side open hole sidetrack at 13,707' without pumping any cement. and drill to a new intermediate casing point of 15,784'. After running and cementing 7-5/8" casing, then drill the 6-3/4" production hole to the same Kuparuk horizontal targets as permitted. The proposed orphaned 9-7/8" wellbore will be from 13,707' proposed sidetrack point to the old 9-7/8" TD of 15,947'. The top of Kuparuk pay in the old wellbore is at 15,870' and we did see some losses when we drilled the Kuparuk with 10.2 ppg mud. We did ream our way down last night to 15,600' before getting packed off again. The high pressures of up to 3000 psi indicates there is not communication between the deepest cleanout bit depth of 15,600' and the Kuparuk pay from 15,870' to 15,947' because the wellbore will not take fluid when high packoff pressure are applied to the wellbore (unlike when the top of Kuparuk was originally drilled when there were some losses with 10.2 ppg mud.) Once we work our way out of the hole, we will perform a BOP test. Then we propose to commence the open hole sidetrack at 13,707' without pumping cement to sidetrack or to abandon the original well bore.. Please let me know if this open hole sidetrack plan is acceptable to you. Tim Billingsley 265-6531 230-9378 cell PS I discussed this with Winton Aubert who was on call this weekend for AOGCC and he preliminarily agreed to our plan. -----Original Message----- *From: * Billingsley, Tim A *Sent: * Friday, February 24, 2006 4:24 PM *To: * tom maunderzadmin.state.ak.us; Regg (Jim Reggnadrlin.state.ak.us) *Cc: * Doyon 15 Company Man; Thomas, Randy L *Subject: * Kuparuk 1D-41 status Tom/Jim, As per our recent phone conversation, Tom, here is an update at Doyon 15, drilling 1D-41 intermediate. TD was reached on the 9-7/8' intermediate hole at 15,947' on 2/19/06. While tripping out of the hole to run 7-5/8" intermediate casing, the hole was swabbing and had to pump out most of the way. 1 of 2 2/27/2006 10:12 AM Re: Kuparuk 1D-41 status (205-188) At 7700', phase 3 weather conditions began and tripping stopped for 1 day with just slow rotation and circulation. After tripping to surface, the bit and ghost reamer was balled up. A cleanout run before running casing was decided upon due to the length of time being out of the hole and the swabbing problem. The hole had deteriorated and the bit could not ream below 15,492'. The hole was packing off. Gradually some circulation was re-established and we have been slowly working our way up to 14,700' this Friday afternoon. We will continue slowly pulling out try to establish better circulation and rotation and then may go back and try to take small bites and work our way to bottom. The 2-week BOP test is due Monday 2/27. We will inform you of our progress over the weekend but I wanted to give you a heads up of the problems we are encountering as you requested. Tim 2 of 2 2/27/2006 10:12 AM "~ ~ ~ ~ ~ ~ ~ ~~ '~ ' ~ ~'~ ~~~ )~ FRANK H. MURKOWSKI, GOVERNOR ~ ~ ~a ~' ~~ OIL ~ ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA'1'IOIQ CO1~II-iISSIOI~T ~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAx (907) 27s-7542 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU 1 D-41 ConocoPhillips Alaska, Inc. Permit No: 205-188 Surface Location: 552' FNL, 421' FEL, Sec. 23, T 11 N, R 1 OE, UM Bottomhole Location: 3577' FNL, 4398' FEL, Sec. 21, T 11 N, R 11 E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 petrol field inspector at (907) 659- 3607 (pager). n K. DATED thisZ%~' da of November 2 .. Y 005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com November 18, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 1D-41 Dear Commissioners: • l~E~'~,~/ED NOV ~ 1 2005 Alaska Oit & Cas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well, a horizontal well in the Kuparuk ~~C4/C3" sands. The well will be designated as 1D-41. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for this well. The expected spud date of 1D-41 is December 25, 2005. If you have any questions or require any further information, please contact Tim Billingsley at 265-6531. Sincerely, \ _._~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED STATE OF ALASKA ~ NOV !~ 1 200 ~' tv ALASKA OIL AND GAS CONSERVATION COMMISSION lam PERMIT TO DRILL Alaska oil & Gas Cons. GOiT1(INSSIA~1 20 AAC 25.005 pnchara~e 1 a. Type of Work: Drill ~ Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ~ Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone ^/ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number. 1D-41 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 19304' ' ND: 6573' ~ 12. Field/Pool(s): Kuparuk River Field - 4a. Location of Well (Governmental Section): Surface: 552' FNL, 421' FEL, Sec. 23, T11 N, R10E, UM ~ 7. Property Designation: ADL 25650, 28243, 28244 Kuparuk Oil Pool Top of Productive Horizon: 3287' FNL, 2644' FEL, Sec. 20, T11 N, R11 E, UM 8. Land Use Permit: ALK 468, 3814, 2293 13. Approximate Spud Date: 12/25/2005 Total Depth: _ 3577 FNL, 4398' FEL, Sec. 21, T11 N, R11 E, UM 9. Acres in Properly: ~ .1gE6-' Z~~=" i!,,~:`~ 14. Distance to .,, j ,u, j~ . /tr:'C< Nearest Property: ~993rb~ ~ Ndr 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 ~ y- 5959114 Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest Well within Pool: 1 D-40 @ , 450' 16. Deviated wells: Kickoff depth: 400 ft. ~ Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3431 psig Surface: 2705 psig ~ 18. Casing Program if ti ns S Setting Depth Quantity of Cement Size ica pec o Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.6# H-40 Welded 76' 40' 40' 116' 116' 9 cu yds High Early 13.5" 10.75" 45.5# L-80 BTC 9600' 40' 40' 9640' - 4510' ' 1080 sx ASLite, 620 sx LiteCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 15703' 40' 40' 15743' . 6580' ~ 240 sx Class G 6.75" 4.5" 12.6# L-80 IBT 3711' 15593' 6569' 19304' ~ 6573' ' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Billingsley @ 265-6531 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ` Phone =Z~.r_6~~~ Date ll~l8/0~- P h n All Commission Use Only Permit to Drill Number: ~ ~ ~ ~ API Number: 50- n ~cJj, - ~ =~ ~ 1=~~j "J ~~-- Permit Approval Dater ~a ' ~ See cover letter for other requirements Conditions of approval ampl required Yes ^ No ~ Mud log required Yes ^ No Hydro en sulfide measures Yes ~ No ^ Directional survey required Yes ,~ No ^ Other. O~ t .` r~v~t-t ~~ ~CS~"• APPROVED BY // ~~ _/~ Appro ed by: THE COMMISSION Date: ~'V Form 10-401 Revis~ 004 Q ~ ~ ~ ~ ~ ~ ~ Submit in Duplicate ~lication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 16-Nov-05 Permit It - Kuparuk Well #1 D-41 Application for Permit to Drill Document well yolue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 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 ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI FloPro) ........................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10. Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1D-41 PERMIT IT.doc Page 1 of 8 Printed: 16-Nov-05 ORIGINAL • ~lication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 16-Nov-05 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c) (14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Aftachment 1 Directional Plan ................................................................................................................ 8 Aftachment 2 Drilling Hazards Summary ............................................................................................... 8 Aftachment 3 Cement Summary ........................................................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must Simi/ar/y be identified by a unique name and API number by adding a su>f<x to the name designated for the wet/ 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 1D-41. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Oril/ must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the properfy's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the wel! at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Nationa/ 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 552' FNL 421' FEL Section 23 T11N R10E UM ASPZone 4 NAD 27 Coordinates ~ RKB Elevation 109.5' AMSL Northings: 5,959,114' Eastings: 560,671 Pad Elevation 69.5' AMSL Location at Top of Productive Interval (7- 3287' FNL, 2644' FEL, Section 20, T11N, R11E, UM 5/8" shoe near top Ku aruk "C4" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 15, 743 Northings: 5,956,499 Eastings; 573,993 Total 1/ertica/ De th RKB: 6580 Total l/ertica/ De th SS: 6470 Location at Total De th 357T FNL 4398' FEL Section 21 T11N, R11E, UM ASPZone4NAD27Coordinates Measured De th, RKB: 19,304 ' Northings: 5,956,244 Eastings: 577,523 Total t/ertical De th RKB; 6573 ' Total 1/ertical De th, SS.• 6463 and 1 D-41 PERMIT /T. doc Page 2 of 8 Printed: 16-Nov-05 OR161NAL • (D) other information required by 20 AAC 25.050(b); ~lication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 17-Nov-05 Requirements of 20 AAC 25.050(b) If a well is to be intentional/y deviated, the application for a Permit to Dril/ (Form 10-401) must (i) include a plat, drawn to a suitab/e scale, showing the path of the proposed we//bore, including a/l adjacent wellbores within 200 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for a/l wells within 200 feet of the proposed wellbore (A) list 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 mail; or (B) state that 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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.03s, 20 AAC 2s.036, or 20 AAC 25.037, as app/icable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete well 1D-41. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fr/e with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the Kuparuk sands in the 1D-41 area vary from 0.50 to 0.52 psi/ft, or ' 9.6 to 10.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby Kuparuk wells and reservoir modeling estimates to the toe of the well. 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 calculated thusly: MPSP =(6,598 ft)(0.52 - 0.11 psi/ft) = 2,705 psi (B) data on potentia/ gas zones; The well bore is not expected to penetrate any gas zones. and (C) data canceming potential causes of ho% problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differentia/sticking; 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 fol%wing items, except for an item already on F/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 2s.030(>); 1D-41 PERMIT /T.doc Page 3 of 8 Printed: 17-Nov-05 ORIGINAL • ication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 17-Nov-05 A procedure is on file with the commission for performing LOT's. For 1D-41 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs or 18.0 ppg EMW maximum is achieved. (see step 6 in the procedure) 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dri/l must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (6) a comp/ete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top etm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in) in (Ib/ft Grade Connection ft) ft ft Cement Pro ram 16 24 62.58 H40 Welded 76 40 / 40 116 / 116 Cemented to surface with 9 cu yd High Earl 10-3/4 13-1/2 45.5 L-80 BTC 9600 40 / 40 9640 /4510 Cemented to Surface with 1080 sx ASLite Lead, 620 sx LiteCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 15703 40 / 40 15743 / 6580 Cement Top planned @ 14893' M D / 6378' TVD. Cemented w/ 240 sx Class G + additives 4-1/2 6-3/4" 12.6 L-80 IBT 3711 15593 / 6569 19304 / 6573 Slotted- no slotted Lateral cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dril! must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1D-41. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 1D-41 PERMIT IT.doc Page 4 of 8 Printed: 17-Nov-05 o~ ~lication for Permit to Drill, Well 1 D-41 Revision No.0 Saved: 16-Nov-05 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Oril/ must be accompanied by each of the fol%wing items, 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 system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Interval Drilling. Fluid System Spud Mud INTERVAL MUD PROPERTIES Properties Spud to Base of Permafrost Base of Permafrost to TD Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 - 8.6 9.4 - 9.6 9.4 - 9.6 9.6-10.2 Funnel Viscosity (seconds) 250 - 300 250 - 300 200 - 250 200 -250 Yield Point (cP) 50 - 80 50 - 80 30 - 60 30 - 60 Plastic Viscosity (Ib/100 sf) 8 - 15 11 - 22 12 - 30 12 - 30 10 sec Gels (Ib/100 sf) 15 - 30 15 - 30 15 - 30 15 - 30 10 min Gels (Ib/100 sf) 25 - 55 25 - 55 25 - 65 25 - 65 pH 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 API Filtrate(cc) 8-15 <8 <8 <6 Solids(%) 5-8 5-8 5-8 6-10 Intermediate Interval Drilling Fluid System LSND INTERVAL MUD PROPERTIES Properties Initial Value Final Value through HRZ Density (ppg) 9.4 - 9.5 9.6 - 10.2 Funnel Viscosity (seconds) 35 - 41 38 - 45 Yield Point (cP) 24 - 30 24 - 30 Plastic Viscosity (Ib/100 sf) 10 - 15 15 - 20 Chlorides <600 <600 pH 9-9.5 9-10 API filtrate <6 4 - 5 HTHP filtrate <10 <10 MBT <20 <20 Solids ppb <11 <12 1D-41 PERMIT/T.doc Page 5 of 8 ®~ ~ w ~ ~ ~ ~ Printed: 16-Nov-05 • ~lication for Permit to Drill, Well 1 D-41 Revision No.0 Saved: 16-Nov-05 Production Drilling Interval Drilling Fluid System Flo Pro Drill-in Fluid PRODUCTION INTERVAL MUD PROPERTIES Ku arulsSand Properties Initial Value Density (ppg) 9.8-10.2 Funnel Viscosity (seconds) 35 - 45 Yield Point (cP) 20 - 30 Plastic Viscosity (Ib/100 sf) 10 - 15 Chlorides <600 pH 9 - 9.5 API filtrate <6 HTHP filtrate <10 MBT <5 Solids ppb <3 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 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 fol%wing items, except for an item already on file with the commission and identified in the application: (9) for an exp/oratory or stratigraphic test wel% a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(0); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (10) for an exp/oratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (11) for a well dril/ed from an offshore p/ah`orm, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dril/ must be accompanied by each of the fol%wing 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. 1D-41 PERM/TIT.doc Page 6 of 8 Printed: 16-Nov-05 ~lication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 16-Nov-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in /rig up Doyon Rig 15. Install 21-1/4"Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Run MWD tools as required for directional monitoring. 3. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud. Perform top job if required. ~©~`~ ~,~~`sg.~a~ ~v(c ~~~ 4. Remove diverter s-ystem, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 his before test. 5. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD (GR/RES) & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. 6. Drill out cement and .between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. Do not exceed 18.0 ppg EMW. 7. Directionally drill to 7-5/8" casing point as per directional plan. 8. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud. 9. Install wellhead 7-5/8" packoff and test to 5000 psi. 10. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 11. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD (GR/RES/DENS-NEU) logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 12. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. Do not exceed 16.0 ppg EMW. 13. Directionally drill 6-3/4" hole to TD as per directional plan. 14. POOH, back reaming out of lateral. POOH. 15. PU and run 4-1/2" slotted liner with swell packers as needed. 16. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH. 17. POOH, laying down drill pipe as required. 18. P/U and run 4-1/2" completion equipment with dummied GLMs and one shear out valve in GLM, RIH to depth. Circulate corrosion inhibited brine into the 4-1/2" x 7-5/8"annulus. 19. Land tubing. Set BPV. 20. Nipple down BOPE, nipple up tree and test. 21. Shear out valve in GLM, freeze protect the tubing and IA with diesel. 22. Move rig off. 23. Pull BPV. Change out shear valve for dummy valve. MITIA. 24. Set live gas lift valves in mandrels. 25. Flow back well to portable test separator to clean up well. 26. Secure well for facility hook-up. 1 D-41 PERMIT /T. doc Page 7 of 8 Printed: 16-Nov-05 ~~~~~~ • ~lication for Permit to Drill, Well 1 D-41 Revision No.O Saved: 16-Nov-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dril/ mustc be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator p/ans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1C 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 iC 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 weA for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Summary Attachment 4 Well Schematic 1D-41 PERMIT /T.doc Page 8 of 8 Printed: 16-Nov-05 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk] Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-41 Pian: 1 D-41 (wpo5) Proposal Report 26 September, 2005 Ha,~.L~~u~-ron~ Sorry Drilling Services ORIGINAL lips a~s~ stir.tC0552ftrNS..~t21Fr,=L~..s~c23-T~t1t~-F.~ta;_ b 13977.60 743ZS.13U IOpF 6 6408.50 14878.07 Base -2000 ,~ -- KOP @ 400ft MD, 400ft TVD - Bulld ~ 3°110 7 6483.50 15226.17 K1 8 6570.50 15607.17 Q Shy 9 6577.80 15693.03 C4 ~ Contlnue Bulltl ~4°MOOft, 883ft MD, 973ft i -1000 ~ ~ Sall ~ 54° Inc : 1833ft MD, 1842ft i Contlnuo Bulld @ 4°/100ft , 2039ft MD, 1759ft 0 t5" _ , - ' ~ ~ Sail @ 88.17°inc : 2412ft MD,1839ft 1000 ~ -- _--' _ .. -' ~ , -' ~ 0HL ~ 1930dFt MD, 65731t TVD : 1703`t FSL & 68'Ift FVdt - b Baeo of Permafroa .' - _ ' ~ - ~ ~ ` _ ~}'~ _ - ` _ _ .. - 1d 31d C;SG ~ 96dOft MD; d510ft TVD - 2129tt FNL & 1986ft P4VL -Sac 1~-T11 N-R1 E ~ ~ 2000 ~ ~~ Contlnue Bulld ~ 3°/100ft , 1$111ft MD, 6466ft ~ `~ ~ ` ~ ~ '~ ' ~ ` Top Ugnu C ~ ~ ` ` .~ 3000 _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ r ` Continue Geosteering In C4 :18778ft MD, 8681Tt `~ i ~ i ~ i ~ - Top Weot Sak ~ ` i ` ~ ~ 4000 w ~ \ Baao Wsot Sa m ~ r ~ ~ , ' ~ ~ 2 =----------------------------°------------- - ~ i ~ ~ ~ TopHR2 BaeeHRZ(TopKalublk ~ ~~ ` , `1 5000 r ~ ~ K1 ` ~ i ~ ~ ` ~ ~~ D Shale i `~ i ~ 6000 ~ - - ® `~ ~ ~ ` ms's ~ _ = C = _" _ - _ - _ _ ' - _ ° _ _ _ _ ° _ - - _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ^ _ _ - _ _- _ - - _ _ __a 7 5t9" CSG (FO 157d3ft MD, 6S86ft TVD - 105dit FSL & 2635ft FNlL -Set 20-T71 N-Rt E i ANNOTATIONS TVD MD Annotation 40.00 40.00 SHL 662ft FNL & 421ft FEL-Sec 23 - T11 N - 810E 400.01 400.01 KOP~ 400ft MD, 400ft TVD - Build ~ 3°/100ft 872.82 983.34 Contlnue Build ~ 4°/100H , 893ft MD, 973Tt TVD 1841.74 1833.33 Sall @ 84° Inc : 1833ft MD, 1842ft TVD 1788.30 2033.34 Contlnue Build ~d°/100H, 2033ft MD, 17898 TVD 1939.20 2412.47 Sall ~ 89.17° Inc :24128 MD, 1838ft TVD 4810.00 8840.37 10 3f4 CSG @ 9840ft MD, 4610ft TVD - 2129ft FNL l11968ft FWL -Sec 18-T17 N•R11 8468.9618N1.47 Contlnue Build @3°/100ft, 18111ft MD, 6488ft TVD 8879.8018743.00 7 816" CSG ~ 16749ft MD, 6880ft TVD -1894tt FSL & 2836ft FWL-Sec 20•T11 N-871 6880.8818774.87 Continue Geoafeoring In C4 :16778ft MD, 6691tt TVD 8872.8019303.86 BHL ~ 19304ft MD, @673ft TVD : 1703ft FSL & 881ft FWL -Sec 21-T11 N-R11E -1000 Vertipl Section at 95.00° (2000 ftlin) /, i~ i 1t141 Heel {wp05 i i i i i 1D-41 Ti (wp05 !~- ` ~~ \. ~ ~ ~ ~ 4 112" r __~ ` ~ 1 D+11 Tce (wp05 ~ ~~ ~ ~ ~ ` ~ ` ~~ 1 D-41 TS (wpp5 1D-41 T2(wp05 HALLIBURTON ~Y Orllilny Sorvk~o 12000 13000 14000 15000 16000 17000 18000 z CiM~N F r+ ~ ~" o N~A~ in n O o~ ®N~oo -~ - - V CC ~ Z~ ~N IL~ONN Vt+J °~t~~ r -' ~ - - h 6 O O O ~ N J a~ ~ ~o m~ ai~(7 w~m ~ _ , ~' lOp ZTAe} $ o k? ~Fnn~ m u7 --~~ C G GLOW ~~ ~~Qg ~ _--' - _ q~q ~ O 0 ~MO{O HR ~~ ~ o 6 h y o c0 y mPM Q wrr ~ G F °~ ' ~ FN- ~N! 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UUUUU 0 g f ` ~ ~ ~ ~ ~, ~ J a ~ i ~ > NN~N~ ` + +n Q ~ tD Q1 h Qf I~ O S ~ ~ , ' ~ lJ l ~, s!'NN W n OO ' ~ 'mo N M ~ ° ~ V ~ ` ~ ~ . ~ d t CY t D e 9 T T T T T ~ \ ~ ` ` 1 « 1 ~ 'O `' W ' ~ O m 'i m U? tD 1`M1~t0 f0 Y ~ -~ ~ t(~ T T OD N 'c ~ ~ ` ~- ~- ~- Z + O tD tl0 O a0 etON000 ~ U ~\ ~ rv W ~ OOP0IOS M M N N N p CG ~ ~ t O m f~ z ` ~ J M c v ~~ ~ ,~ ` ~ `T J ~ ~> 1- ~~N~~ NNOd'f~ o ~ ~ ~ a . ~ N~ O ~ ~ u p ~ t t~~ t fS tO tp t t ~ ~ ~ E p p CR J Y ~ ~ ~ ~ W i ~ m p C ~O ~~ ~ ~'_ _ ~ ..ZOO' ~ . O O 33333 O ~~ ~ Z __ _ N ^ ~ r ~ S f 1"~ fsl LL ~, vV _- O ~ TTTTT O ~- M +~ GOG~G r Z T T T T T ~ Z ~ O O ~~ 0 0 O O 0 0 W ' 0 0 0 0 0 ~ 0 0 o J o tub 6002) ~+)4yoN/~-}4inoS Q ~ I a OR161NAL r' ConocoPhitlips Alaska Database: EDM 2003.11 Singk: User ~ Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site;. Kuparuk 1 D Pad We1L• Plan 1 D-41 Wel{bore: Plan 1 D-41 Destgn: 1 D-41 (wP05) Halliburton Company Planning Report -Geographic Local Co-0rdinate Re#ererice: TVD Reference: MD Reference: North Reference: Survey Camulation Method:. HALLIBURTClN Sperry- Drilling Servia:es Welt Plan 1 D-41 RKB {Doyon 15 - Planned) ~ 109.50ft (Doyon 15 {69.5 R KB {Dayon 15 - Planned) ~ 109.50R (Doyon 95 (69.5 True Minimum Curvature project Kuparuk River Unit, North Sbpe Alaska, United States Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 3eo Datum: NAD 1927 (NADCON CONUS} Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic soak; factor Welt Plan 1 D-41, Welt Pinned from slot 1 D-41 Well Position +N/S 0.00 ft Northing: 5,959,194.19 ft LatRude: 70° 1T 55.887" N +EJ-W 0.00 ft Easting: 560,671.14 ft Longitude: 949° 30' 31.1 ~" W Position Uncertainty 0.00 ft Wellhead Elevation: O.OOft Ground Level: 69.SOft Weltbore Plan 1 D-41 Magnetics Model Name Sample Date Dedinatiort Dip Angle Field ti BGGM2005 10/16/2003 25.10 80.77 57,533 Design 1 D-41 (wp05) Audit Notes: Version: 8 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TYD) +IWS +EJd1Y Direction 40.00 0.00 0.00 95.00 Plan Summary .Measured Vertical Do91e9 Build Tum t)epth Incl'mation Azimuth Depth +NfS +E/411t Rate Rate Rate ~O ' {fl} {~j {•} {ftT {ftj {ft) {°lloott} {°I'Itlaftj (°notltlj ~j 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 4oo.oa o.oo o.o0 400.00 0.00 0.00 0.00 0.00 0.00 0.00 733.33 10.00 101.56 731.64 -5.81 28.43 3.00 3.00 0.00 101.56 983.33 20.00 101.56 972.82 -18.76 91.74 4A0 4.00 0.00 0.00 1,833.33 54.00 101.56 1,641.74 -119.78 585.58 4.00 4.00 0.00 0.00 2,033.33 54.00 101.56 1,759.30 -152.20 744.10 0.00 0.00 0.00 0.00 2,412.46 69.17 101.56 1,939.20 -218.84 1,069.83 4.00 4.00 0.00 0.02 15,111.46 69.17 101.56 6,455.95 -2,598.11 12,697.50 0.00 0.00 0.00 0.00 15,769.99 88.92 101.75 6,580.50 -2,728.13 13,327.55 3.00 3.00 0.03 0.55 15,774.57 89.06 101.73 6,580.58 -2,729.06 13,332.03 3.00 2.98 -0.38 -7.20 16,619.57 89.06 101.73 6,594.50 -2,900.87 14,159.26 0.00 0.00 0.00 0.00 16,638.16 89.61 101.80 6,594.72 -2,904.6`6 14,177.46 3.00 2.98 0.36 6.95 17,046.96 89.61 101.80 6,597.50 -2,98826 14,577.61 0.00 0.00 0.00 0.00 17,348.52 92.86 93.35 6,591.00 -3,027.98 14,876.16 3.00 1.08 -2.80 -68.92 17,719.66 92.86 93.35 6,572.50 -3,049.66 15,246.20 0.00 0:00 0.00 0.00 17,922.41 89.80 88.09 6,567.79 -3,052.21 15,448.78 3.00 -1.51 -2.60 -120.04 19,303.66 89.80 88.09 6,572.50 -3,006.17 16,829.26 0.00 0.00 0.00 0.00 9/262005 3:01:41 PM Page 2 of 9 COMPASS 2003.11 Bu1Jd 48 '?R!6!NAL ~-' COt10tOPI11~~1p5 Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska {Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: Plan 1 D-41 Welibore; Plan 1 D-41 Design.: 1 D-41 {wp05) Halliburton Company Planning Report -Geographic L~aI Co-wdmate Reference: TVD Reference: MD References North Reference: Survey Calculation Method: HAi-L.iBtJRTON $po~ry ~lie8 Sarvices Well Plan 1 D-d1 RKB {Doyon 15 - Planned) ~ 109.SOft {Doyon 15 (69.5 RKB (Doyon 15 - Planned) ~ 109_SOR {Doyon 15 (69.5 True Minimum Curvature Planned. Survey 1 D-41 {wp05) Map Map MD Inclination . ,Aaimuth TVD SSTVD +N/-S +Et-W Northing Fasting DLSEY Vert Section {ft) (°) (~ {ft} {it} {it) {ft} tft) {ft) (`/411011} tft) 40.00 0.00 0.00 40.00 X9.50 0.00 0.00 5,959,114.19 ~ 560,671.14 l 0.00 0.00 SHL @ 552ft FNL & 421ft FEL -Sec 23 - T11N - R10E 100.00 0.00 0.00 100.00 -9.50 0.00 0:00 5,959,114.19 560,671.14 0.00 0.00 200.00 0.00 0.00 200.00 90.50 0.00 0.00 5,959,114.19 560,671.14 0.00 0.00 300.00 0.00 0.00 300.00 190.50 0.00 0.00 5,959,114.19 560,671.14 0.00 0.00 400.00 0.00 0.00 400.00 290.50 0.00 0.00 5,959,114.19 560,671.14 0.00 0.00 KOP ~ 400ft MD, d04ft TVD - Build ~ 3°/i00ft i 500.00 3.00 101.56 499.95 390.45 -0.52 2.56 5,959,113.69 560,673.71 3.00 2.60 600.00 6.Q0 101.56 599.63 490.13 -2.10 10.25 5,959,112.18 560,681.41 3.00 10.39 700.00 9.00 101.56 698.77 589.27 -4J1 23.04 5,959,108.66 560,694.21 3.00 23.36 733.33 10.00 101.56 731.64 622.14 -5.81 28.43 5,959,108.61 560,699.61 3.00 28.83 800.00 12.67 101.56 797.00 687.50 -8.44 41.26 5,959,106.08 560,712.46 4.00 41.84 900.00 16.67 101.56 893.73 784.23 -13.51 66.06 5,959,101.21 560,737.30 4.00 66.99 983.33 20.00 101.56 972.82 863.32 -18.76 91.74 5,959,096.17 560,763.02 d.00 93.02 Continue Build ~ 4°/1 00ft , 983ft MD, 973ft TVD 1,000.00 20.67 101.56 988.45 878.95 -19.92 97.41 5,959,095.05 560,768.70 4.00 9$.78 1,100.00 24.67 101.56 1,080.70 971.20 -27.65 135.16 5,959,087.64 560,806.51 4.00 137.05 1,200.Q0 28.67 101.56 1,170.05 1,060.55 -36.64 179.12 5,959,079.00 560,850.53 4.00 181.63 1,300.00 32.67 101.56 1,256.05 1,146.55 -46.86 229.08 5,959,069.19 560,900.57 d.00 232.29 1,400.00 36.67 101.56 1,338.28 1,228.78 -58.25 284.79 5,959,058.24 560,956.37 4.00 288.79 1,500.00 40.67 101.56 1,416.34 1,306.84 -70.77 345.99 5,959,046.22 561,017.66 4.00 350.85 1,600.00 44.67 101.56 1,489.86 1,380.36 -84.35 412.38 5,959,033.18 561,084.15 4.00 41$.16 1,700.00 48.67 101.56 1,558.47 1,448.97 -98.92 483.63 5,959,019.18 561,155.50 4.00 490.41 1,800.00 52.67 101.56 1,621.84 1,512.34 -114.42 559.39 5,959,004.30 561,231.38 4.00 567.23 1,833.33 54.00 .101.56 1,641.74 1,532.24 -119.78 585.58 5,958,999.16 561,257.62 4.00 593.79 Sail @ 54° Inc : 1833ft MD, 1642ft TVD 1,844.83 54.00 101.56 1,648.50 1,539.00 -121.64 594.70 5,958,997.37 561,266.74 0.~ 603.03 Base of Permafrost 1,900.00 54.00 101.56 1,680.93 1,571.43 -130.59 638.42 5,958,988.78 561,310.54 O.QO 647.38 2,000.00 54.00 101.56 1,739.71 1,630.21 -146.80 717.68 5,958,973.21 561,389.92 0.00 727.75 2,033.33 54.00 101.56 1,759.30 1,649.80 -152.20 744.10 5,958,968.02 561,416.38 0.00 754.54 Continue Build @ 4°M OOft , 2033ft MD, 1759ft TVD 2,100.00 56.67 101.56 1,797.22 1,687.72 -163.19 797.82 5,958,957.46 561,470.17 4.00 809.01 2,200.00 60.67 101.56 1,849.21 1,739.71 -180.30 881.48 5,958,94L02 561,553.97 4.00 893.85 2,300.00 64.67 101.56 1,895.11 1,785.61 -198.11 968.50 5,958,923.93 561,641.11 4.00 982.08 2,400.00 68.67 101.56 1,934.71 1,825.21 -216.51 1,058.44 5,958,906.25 561,731.19 4.00 1,073.28 2,412.46 69.17 101.56 1,939.20 1,829.70 -218.84 1,069.83 5,958,904.02 561,742.60 d.00 1,084.83 Saii @ 69.17° Inc : 2412ft MD, 1939ft TVD 2,500.00 69.17 101.56 1,970.33 1,860.83 -235.24 1,149.9$ 5,958,888.26 561,822.88 0.00 1,166.11 2,600.00 69.17 101.56 2,005.90 1,896.40 -253.98 1,241.55 5,958,870.27 561,914.58 0.00 1,258.96 2,700.00 69.17 101.56 2,041.47 1,931.97 -272.71 1,333.11 5,958,852.27 562,006.28 0.00 1,351.81 2,800.00 69.17 101.56 2,077.04 1,967.54 -291.45 1,424.67 5,958,834.28 562,097.98 0.00 1,444.65 2,900.00 69.17 101.56 2,112.60 2,003.10 -310.18 1,516.24 5,958,816.29 562,189.69 0.00 1,537.50 3,000.00 69.17 101.56 2,148.17 2,038.67 -328.92 1,607.80 5,958,798.29 562,281.39 0.00 1,630.35 3,100.00 69.17 101.56 2,183.74 2,074.24 -347.66 1,699.37 5,958,780.30 562,373.09 0.00 1,723.20 3,200.00 69.17 101.56 2,219.31 2,109.81 -366.39 1,790.93 5,958,762.30 562,464.80 0.00 1,816.05 3,300.00 69.17 101.56 2,254.87 2,145.37 -385.13 1,882.49 5,958,744.31 562,556.50 0.00 1,908.90 9/2612005 3.01:41 PM Pege 3 of 9 COMPASS 2003.11 Build 48 OR161NAL ~•' ConotoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ' ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit SRe: Kuparuk 1 D Pad Welk Plan 1 D-41 Wellbore: Plan 1 D-41 Design: 1 D-41 (wp05) Halliburton Company Planning Report -Geographic t_ocal Go-0rdinate Reference: TVD Reference: MD Reference: North Reference: Survey Gak:ulation Method: • HQLLIBURTUN Sporty brillimg Sorvicos Well Plan 1 D-41 RKB {Doyon 15 - Planned) ~ 109_SOtt (Doyon 15 (69.5 RKB {Doyon 15 - Planned} ~ 109.50ft (Doyon 15 (69.5 True Minimum Curvature Planned Survey 1 D-41 (wp05) Map.. Mlap MD inclination Azimuth TVD SSTVD +NJS +E/-W Northing Feting f1LSEV :Pert Section {~) t~ {°~ ~~r t~) t~) {~~ {~) (~~ (~ro {ix) 3,400.00 6.9.17 101.56 2,290.44 2,180.94 -403.86 1,974.06 5,958,726.31 562,648.20 0.00 2,1)01.74 3,500.00 69.17 101.56 2,326.01 2,216.51 -422.60 2,065.62 5,958,708.32 562,739.91 0.00 2,094.59 3,600.00 69.17 101.56 2,361.58 2,252.08 -441.34 2,157.18 5,958,690.33 562,831.61 0.00 2,187.44 3,700.00 69.17 101.56 2,397.15 2,287.65 -460.07 2,248.75 5,958,672.33 562,923.31 0.00 2,280.29 3,800.00 69.17 101.56 2,432.71 2,323.21 -478.81 2,340.31 5,958,654.34 563,015.02 O.QO 2,373.14 3,900.00 69.17 101.56 2,468.28 2,358.78 -497.54 2,431.87 5,958,636.34 563,106.72 0.(M 2,465.98 4,000.00 69.17 101.56 2,503.85 2,394.35 -516.28 2,523.44 5,958,618.35 563,198.42 0.00 2,558.83 4,100.00 69.17 141.56 2,539.42 2,429.92 -535.02 2,615.00 5,958,600.35 563,290.13 0.00 2,651.68 4,200.00 69.17 101.56 2,574.98 2,465.48 -553.75 2,706.57 5,958,582.36 563,381.83 0.00 2,744.53 4,300.00 69.17 101.56 2,610.55 2,501.05 -572.49 2,798.13 5,958,564.37 563,473.53 0.00 2,837.38 4,400.00 69.17 101.56 2,646.12 2,536.62 -591.22 2,889.69 5,958,546.37 563,565.23 0.00 2,930.23 4,500.00 69.17 101.56 2,681.69 2,572.19 -609.96 2,981.26 5,958,528.3$ 563,656.94 0.00 3,023.07 4,600.00 69.17 101.56 2,717.26 2,607.76 -628.69 3,072.82 5,958,510.38 563,748.64 0.00 3,115.92 4,700.00 69.17 101.56 2,752.82 2,643.32 -647.43 3,164.38 5,958,492.39 X3,840.34 0.00 3,208.77 4,800.00 69.17 101.56 2,788.39 2,678.89 -666.17 3,255.95 5,958,474.39 563,932.05 0.00 3,301.62 4,900.00 69.17 101.56 2,823.96 2,714.46 -684.90 3,347.51 5,958,456.40 564,023.75 0.00 3,394.47 5,000.00 69.17 101.56 2,859.53 2,750.03 -703.64 3,439.08 5,958,43$.41 564,115.45 0.00 3,487.31 5,100.00 69.17 101.56 2,895.09 2,785.59 -722.37 3,530.64 5,958,420.41 564,207.16 0.00 3,580.16 5,200.00 69.17 101.56 2,930.66 2,821.16 -741.11 3,622.20. 5,958,402.42 564,298.86 0.00 3,673.01 5,300.00 69.17 101.56 2,966.23 2,856.73 -759.85 3,713.77 5,958,384.42 564,390.56 0.00 3,765.86 5,400.00 69.17 101.56 3,001.80 2,892.30 -778.58 3,805.33 5,958,366.43 564,482.27 0.00 3,858.71 5,500.00 69.17 101.56 3,037.37 2,927.87 -797.32 3,896.89 5,958,348.43 564,573.97 0.00 3,951.56 5,600.00 69.17 101.56 3,072.93 2,963.43 -816.05 3,988.46 5,958,330.4A 564,665.67 O.00 4,044.40 5,700.00 69.17 101.56 3,108.50 2,999.00 -834.79 4,080.02 5,958,312.45 564,757.38 0.00 4,137.25 5,716.87 69.17 101.56 3,114.50 3,005.00 -837.95 4,095.47 5,958,309.41 564,772.84 0.00 4,152.91 Top Ugnu C 5,800.00 69.17 101.56 3,144.07 3,034.57 -853.53 4,171.58 5,958,294.45 564,849.08 0.00 4,230.10 5,900.00 69.17 101.56 3,179.64 3,070.14 -872.26 4,263.15 5,958,276.46 564,940.78 0.00 4,322.95 6,000.00 69.17 101.56 3,215.20 3,105.70 -891.00 4,354.71 5,958,258.46 565,032.49 0.00 4,415.80 6,100.00 69.17 101.56 3,250.77 3,141.27 -909.73 4,44628 5,958,240.47 565,124.19 0.00 4,508.64 6,200.00 69.17 101.56 3,286.34 3,176.84 -928.47 4,537.84 5,958,222.47 565,215.89 0.00 4,601.49 6,300.00 69.17 101.56 3,32L91 3,212.41 -947.21 4,629.40 5,958,204.48 565,307.59 0.00 4,694.34 6,400.00 69.17 101.56 3,357.47 3,247.97 -965.94 4,720.97 5,958,186.49 565,399.30 0.00 4,787.19 6,500.00 69.17 101.56 3,393.04 3,283.54 -984.68 4,812.53 5,958,168.49 565,491.00 0.00 4,880.04 6,600.00 69.17 101.56 3,428.61 3,319.11 -1,003.41 4,904.09 5,958,150.50 565,582.70 0.00 4,972.89 6,700.00 69.17 101.56 3,464.18 3,354.68 -1,022.15 4,995.66 5,958,132.50 565,674.41 0.00 5,065.73 6,800.00 69.17 101.56 3,499.75 3,39025 -1,040.88 5,08722 5,958,114.51 565,766.11 0.00 5,158.58 6,900.00 69.17 101.56 3,535.31 3,425.81 -1,059.62 5,178.78 5,958,096.51 565,857.81 0.00 5,251.43 7,000.00 69.17 101.56 3,570.88 3,461.38 -1,078.36 5,270.35 5,95$,078.52 565,949.52 0.00 5,344.28 7,100.00 69.17 101.56 3,606.45 3,496.95 -1,097.09 5,361:91 5,958,060.52 566,041.22 0.00 5,437.13 7,200.00 69.17 101.56 3,642.02 3,532.52 -1,115.83 5,453.48 5,958,042.53 566,132.92 0.00 5,529.97 7,300.00 69.17 101.56 3,677.58 3,568.08 -1,134.56 5,545.04 5,958,024.54 566,224.63 0.00 5,622.82 7,400.00 69.17 101.56 3,713.15 3,603.65 -1,153.30 5,636.60 5,958,006.54 566,316.33 0.00 5,715.67 7,500.00 69.17 101.56 3,748.72 3,639.22 -1,172.04 5,728.17 5,957,988.55 566,408.03 0.00 5,808.52 7,600.00 69.17 101.56 3,784.29 3,674.79 -1,190.77 5,819.73 5,957,970.55 566,499.74 0.00 5,901.37 7,700.00 69.17 101.56 3,819.86 3,710.36 -1,209.51 5,911.29 5,957,952.56 566,591.44 0.00 5,994.21 7,732.74 69.17 101.56 3,831.50 3,722.00 -1,215.64 5,941.27 5,957,946.67 566,621.46 0.00 6,024.61 Top West Sa k D 7,800.00 69.17 101.56 3,855.42 3,745.92 -1,228.24 6,002.86 5,957,934.56 566,683.14 0.00 6,087.06 9/26/2005 3:01:49PM Page 4 of 9 COMPASS 2003.11 Build 48 ORIGINAL ~ ~' Halliburton Company COI"tOCO~'tl~~lpS Plannin R ort Geo ra hic MAI.LIBtJRTON __ _. __ g ep - g p Alaska Sperry DrSling Services Database:. EDM 2003.11 Single User Db Local Co-0rd'xiate Reference: Well Plan 1 D-41 Company: ConocoPhillips Alaska {Kuparuk) TYD Reference:. RKB {Doyon 15 - Planned) ~ 109.50ft (Doyon 15 {69.5 Project:. Kuparuk River Unit MD Referer~e: RKB (Doyan 15 - Planned] ~ 109.50tt {Doyon 15 {69.5 Site: Kuparuk 1 D Pad North Reference: True Well; Plan 1 D-41 Suwey Calculation Method: Minirrwm Curvature Wellbore: Phan 1 D-d1 Design: 1D-d1 (wp05) Planned Survey 1 D-41 {wp05) Map.. Map MD Inclination Azimuth TVD SSTVD +N/S +E/ W Northing' EastirEg DLSEV Vert Section {ft) {~ (°) {it) (ft) (ftj {ft) {tt} {ft} {°Fl00it} {ft} 7,900.00 69.17 101.56 3,890.99 3,781.49 -1,246.98 6,094.42 5,957,916.57 566,774.85 0.00 6,179.91 8,000.00 69.17 101.56 3,926.56 3,817.06 -1,265.72 6,185.98 5,957,898.58 566,866.55 0.00 6,272.76 8,100.00 69.17 101.56 3,962.13 3,852.63 -1,284.45 6,277.55 5,957,880.58 566,958.25 0.00 6,365.61 8,200.00 69.17 101.56 3,997.69 3,888.19 -1,303.99 6,369.11 5,957,862.59 567,049.95 0.00 6,458.46 8,300.00 69.17 101.56 4,033.26 3,923.76 -1,321.92 6,460.68 5,957,844.59 567,141.66 0.00 6,551.30 8,400.00 69.17 101.56 4,068.83 3,959.33 -1,340.66 6,552.24 5,957,826.60 567,233.36 0.00 6,644.15 8,500.00 69.17 101.56 4,104.40 3,994.90 -1,359.39 6,643.80 5,957,808.60 567,325.06 0.00 6,737.00 8,600.00 69.17 101.56 4,139.97 4,030.47 -1,378.13 6,735.37 5,957,790.61 567,416.77 0.00 6,829.85 8,700.00 69.17 101.56 4,175.53 4,066.03 -1,396.87 6,826.93 5,957,772.62 567,508.47 0:00 6,922.70 8,800.00 69.17 101.56 4,211.10 4,101.60 -1,415.60 6,918.49 5,957,754.62 567,600.17 0.00 7,015.54 8,900.00 69.17 101.56 4,246.67 4,137.17 -1,434.34 7,010.06 5,957,736.63 567,691.88 0.00 7,108.39 9,000.00 69.17 101.56 4,282.24 4,172.74 -1,453.07 7,101.62 5,957,718.63 567,783.58 0.00 7,201.24 9,076.65 69.17 101.56 4,309.50 4,200.00 -1,467.44 7,171.81 5,957,704.84 567,853.87 0.00 7,272.41 Base West Sak 9,100.00 69.17 101.56 4,317.80 4,208.30 -1,471.81 7,193.18 5,957,700.64 567,875.28 0.00 7,294.09 9,200.00 69.17 101.56 4,353.37 4,243.87 -1,490.55 7,284.75 5,957,682.64 567,966.99 0.00 7,386.94 9,300.00 69.17 101.56 4,388.94 4,279.44 -1,509.28 7,376.31 5,957,664.65 568,Q58.69 0.00 7,479.79 9,400.00 69.17 101.56 4,424.51 4,315.01 -1,528.02 7,467.88 5,957,646.66 568,150.39 0.00 7,572.63 9,500.00 69.17 101.56 4,460.07 4,350.57 -1,546.75 7,559.44 5,957,628.66 568,242.10 0.00 7,665.48 9,600.00 69.17 101.56 4,495.64 4,3$6.14 -1,565.49 7,651.00 5,957,610.67 568,333.80 0.00 7,758.33 9,640.37 69.17 101.56 4,510.00 4,400.50 -1,573.05 7,687.97 5,957,603.40 568,370.82 0.00 7,795.81 10 314 CSG @ 9640it MD, 4510ft TVD - 2129ft FNL S 1986ft FWL -Sec t9-T11N-R11E -10 314" 9,700.00 69.17 101.56 4,531.21 4,421.71 -1,584.23 7,742.57 5,957,592.67 568,425.50 0.00 7,851.18 9,800.00 69.17 101.56 4,566.78 4,457.28 -1,602.96 7,834.13 5,957,574.68 568,517.20 0.00 7,944.03 9,900.00 69.17 101.56 4,602.35 4,492.85 -1,621.70 7,925.69 5,957,556.68 568,608.91 0.00 8,036.87 10,000.00 69.17 101.56 4,637.91 4,528.41 -1,640.43 8,017.26 5,957,538.69 568,700.61 0.00 8,129.72 10,100.00 69.17 101.56 4,673.48 4,563.98 -1,659.17 8,108.82 5,957,520.70 568,792.31 0.00 8,222.57 10,200.00 69.17 101.56 4,709.05 4,599.55 -1,677.90 8,200.38 5,957,502.70 568,884.02 0.00 8,315.42 10,300.00 69.17 101.56 4,744.62 4,635.12 -1,696.64 8,291.95 5,957,484.71 568,975.72 0.00 8,4138.27 10,400.00 69.17 101.56 4,780.18 4,670.68 -1,715.38 8,383.51 5,957,466.71 569,067.42 0.00 8,501.12 10,500.00 69.17 101.56 4,815.75 4,706.25 -1,734.11 8,475.08 5,957,448.72 569,159.13 0.00 8,593.96 10,600.00 69.17 101.56 4,851.32 4,741.82 -1,752.85 8,566.64 5,957,430.72 569,250.83 0.00 8,686.81 10,700.00 69.17 101.56 4,886.89 4,777.39 -1,771.58 8,658.20 5,957,412.73 569,342.53 0.00 8,779.66 10,800.00 69.17 101.56 4,922.46 4,812.96 -1,790.32 8,749.77 5,957,394:74 569,434.24 0.00 8,872.51 10,900A0 69.17 101.56 4,958.02 4,848.52 -1,809.06 $841.33 5,957,376.74 569,525.94 0.00 8,965.36 11,000.00 69.17 101.56 4,993.59 4,884.09 -1,827.79 8,932.89 5,957,358.75 569,617.64 0.00 9,058.20 11,100.00 69.17 101.56 5,029.16 4,919.66 -1,846.53 9,024.46 5,957,340.75 569,709.35 0.00 9,151.05 11,200.00 69.17 101.56 5,064.73 4,955.23 -1,865.26 9,116.02 5,957,322.76 Sfi9,801.05 0.00 9,243.90 11,300.00 69.17 101.56 5,100.29 4,990.79 -1,884.00 9,207.59 5,957,304.76 569,892.75 0.00 9,336.75 11,400.00 69.17 101.56 5,135.86 5,026.36 -1,902.74 9,299.15 5,957,286.77 569,984.46 0.00 9,429.60 11,500.00 69.17 101.56 5,171.43 5,061.93 -1,921.47 9,390.71 5,957,268.78 570,076.16 0.00 9,522.45 11,600.00 69.17 101.56 5,207.00 5,097.50 -1,940.21 9,482.28 5,957,250.78 570,167.86 0.00 9,615.29 11,700.00 69.17 101.56 5,242.57 5,133.07 -1,958.94 9,573.84 5,957,232.79 570,259.56 0.00 9,708.14 11,800.00 69.17 101.56 5,278.13 5,168.63 -1,977.68 9,665.40 5,957,214.79 570,351.27 0.00 9,800.99 11,900.00 69.17 101.56 5,313.70 5,204.20 -1,996.41 9,756.97 5,957,196.80 570,442.97 0.00 9,893.84 12,000.00 69.17 101.56 5,349.27 5,239.77 -2,015.15 9,848.53 5,957,178.80 57Q534.67 0.00 9,986.69 12,100.00 69.17 101.56 5,384.84 5,275.34 -2,033.89 9,940.09 5,957,160.81 570,626.38 0.00 10,079.53 12,200.00 69.17 101.56 5,420.40 5,310.90 -2,052.62 10,031.66 5,957,142.82 570,718,08 0.00 10,172.38 12,300.00 69.17 101.56 5,455.97 5,346.47 -2,071.36 10,123.22 5,957,124.82 570,809.78 0.00 10,265.23 9/26f2005 3:01:41 PM Page 5 of 9 COMPASS 2003. i i t3uild 48 ~~ Halliburton Company IE-r~-~uBUAron~- Planning Report -Geographic - - Sperry Qritiing S~rvics7t t.ocai Coordinate Reference:. Well Plan 1 D-41 TVD Reference: RKB (Doyon 15 - Planned} ~ 109,5E?ft (Dayon 15 (69.5 AIID Reference: RKB (Doyon 15 - Planned) ~ 109.50Ft (Doyon 15 (69.5 North Reference: True Survey Calculation Method: Minimum Curvature •-' ConocoPhiilips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk} Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well:. Plan 1 D-41 Weilbore: Plan 1 D-41 Design: 1 D-41 (wp05) __ __ Planned Survey 1 D-41 (wp05} .Map Map MD inclination Azimuth TYD SSTVD +FUS +Et-W Northir~} Fasting DLSEY Vet Section {ft} (°} (°} {ft} (ft} (ft) {ft) (ft} {ft} ('Mti0ft} (tt} 12,400.00 69.17 101.56 5,491.54 5,382.04 -2,090.09 1Q214.79 5,957,106.83 570,901.49 0.00 10,358.08 12,500.00 69.17 101.56 5,527.11 5,417.61 -2,108.83 70,306.35 5,957,088.83 570,993.19 0.00 10,450.93 92,600.00 69.17 101.56 5,562.67 5,453.17 -2,127.57 10,397.91 5,957,070.84 571,084.89 0.00 10,543.77 12,700.00 69.17 101.56 5,598.24 5,488.74 -2,146.30 10,489.48 5,957,052.84 571,176.60 0.00 10,636.62 12,800.00 69.17 tOL56 5,633.81 5,524.31 -2,165A4 10,581.04 5,957,034.85 577,26$.30 0.00 10,729.47 12,900.00 69.17 101.56 5,669.38 5,559.88 -2,183.77 10,672.60 5,957,076.86 571,364.00 0.00 10,822.32 13,000.00 69.17 101.56 5,704.95 5,595.45 -2,202.51 10,764.17 5,956,998.86 571,451.71 0.00 1Q,915.17 13,100.00 69.17 101.56 5,740.51 5,631.01 -2,221.25 10,855.73 5,956,980.87 571,543.41 0.00 11,008.02 13,200.00 69.17 101.56 5,776.08 5,666.58 -2,239.98 10,947.29 5,956,962.87 571,635.11 0.00 11,100.86 13,300.00 69.17 101.56 5,811.65 5,702.15 -2,258.72 11,038.86 5,956,9x4.88 571,726.81 0.00 11,193.71 13,400.00 69.17 101.56 5,847.22 5,737.72 -2,277.45 11,130.42 5,956,926.88 571,87.8.52 0.00 11,286.56 13,500.00 69.17 101.56 5,882.78 5,773.28 -2,296.19 11,221.99 5,956,908.89 571,910.22 0.00 11,379.41 13,600.00 69.17 101.56 5,918.35 5,808.85 -2,314.93 11,373.55 5,956,890.90 572,007.92 0.00 71,472.26 13,700.00 69.17 101.56 5,953.92 5,844.42 -2,333.66 11,405.11 5,956,872.90 572,093.63 0.00 11,565.10 13,800.00 69.17 101.56 5,989.49 5,879.99 -2,352.40 11,496.68 5,956,854.91 572,185.33 0.00 11,657.95 13,900.00 69.17 101.56 6,025.06 5,915.56 -2,371.13 11,588.24 5,956,836.91 572,277.03 0.00 17,750.80 14,000.00 69.17 101.56 6,060.62 5,951.12 -2,389.87 11,679.80 5.,956,818.92 572,368.74 D.00 11,843.65 14,100.00 69.17 101.56 6,096.19 5,986.69 -2,408.60 11,771.37 5,956,800.92 572,460.44 0.00 11,936.50 14,200.00 69.17 101.56 6,131.76 6,022.26 -2,x27.34 11,862.93 5,956,782.93 572,552.14 0.00 12,029.35 14,300.00 69.17 101.56 6,167.33 6,057.83 -2,446.08 11,954.49 5,956,764.94 572,643.85 0.00 12,122.19 14,328.60 69.17 101.56 6,177.50 6,068.00 -2,451.44 11,980.68 5,956,759.79 572,670.08 0.00 12,14$.75 Top HRZ 14,400.00 69.17 101.56 6,202.89 6,093.39 -2,464.81 12,046.06 5,956,746.94 572,735.55 0.00 12,215.04 14,500.00 69.17 101.56 6,238.46 6,128.96 -2,483.55 12,137.62 5,956,728.95 572,827.25 0.00 12,307.89 14,600.00 69.17 101.56 6,274.03 6,164.53 -2,502.28 12,229.19 5,956,710.95 572,918.96 0.00 12,400.74 14,700.00 69.17 101.56 6,309.60 6,200.10 -2,521.02 12,320.75 5,956,692.96 573,010.66 0.00 12,493.59 14,800.00 69.17 101.56 6,345.17 6,235.67 -2,539.76 12,412.31 5,956,674.96 573,102.36 0.00 12,586.43 14,900.00 69.17 101.56 6,380.73 6,271.23 -2,558.49 12,503.88 5,956,656.97 573,194.07 0.00 12,679.28 14,978.07 69.17 101.56 6,408.50 6,299.00 -2,573.12 12,575.36 5,956,642.92 573,265.66 0.00 12,751.77 Base HRZ {Top Kalubik) 15,000.00 69.17 101.56 6,416.30 .6,306.80 -2,577.23 12,595.44 5,956,638.98 573,285.77 0.00 12,772.13 15,100.00 69.17 101.56 6,451.87 6,342.37 -2,595.96 12,687.00 5,956,620.98 573,377.47 0.00 12,864.98 15,111.46 69.17 101.56 6,455.95 6,346.45 -2,598.11 12,697.50 5,956,618.92 573,387.98 0.00 12,875.62 Continue Build @ 3°/1 00ft , 15111ft MD, 6456ft 1VD 15,200.00 71.82 101.59 6,485.51 6,376.01 -2,614.86 12,779.25 5,956,602.83 573,469.86 3.00 12,958.52 15,226.17 72.61 101.60 6,493.50 6,384.00 -2,619.87 12,$Q3.66 5,956,598.02 573,494.30 3.01 12,983.27 K1 15,300.00 74.82 101.62 6,514.21 6,404.71 -2,634.13 12,873.07 5,956,584.32 573,563.82 3.00 13,053.67 15,400.00 77.82 101.65 6,537.85 6,428.35 -2,653.72 12,968.23 5,956,565.50 573,659.13 3.00 13,150.17 15,500.00 80.82 101.68 6,556.38 6,446.88 -2,673.58 13,064.46 5,956,546.42 573,755.50 3.00 13,247.76 15,527.01 81.63 101.68 6,560.50 6,451.00 -2,678.99 13,090.60 5,956,541.23 573,781.68 3.01 13,274.27 15,541.10 82.05 101.69 6,562.50 6,453.00 -2,681.81 13,10426 5,956,538.51 573,795.37 3.00 13,28$.13 15,580.13 83.22 101.70 6,567.50 6,458.00 -2,689.66 13,142.16 5,956,530.97 573,833.33 3.00 13,326.57 15,600.00 83.$2 101.70 6,569.74 6,460.24 -2,693.66 13,161.49 5,956,527.13 573,852.69 2.99 13,346.18 8/26/2006 3:01.41 PM Page S of 9 COh1PASS 2003.11 Build 48 ORIGINAL y' ConocoPhilfips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 D Pad Well: Plan 1 D-41 Wellbore: Plan 1 D-41 Design: 1 D-41 (wp05) tiatiiburton Company Planning Report -Geographic HALLIBURTCiN ____ Sperry Drilling Services Local Coordirwte Reference: Well Plan 1 D-41 TVD Reference: RKB (Doyon 15 - Planned) ~ 109.50ft (Doyon 15 {69.5 MD Reference: RKB (Doyon 15 - Planned) ~ 109.50ft {Doyon 15 (69.5 North Reference: True Swnrey Calculation Me~od: Minimum Curvature Planned Survey 1D-41 (wp05) Map Map MD Inclination Aamuth TYD SSTYD +N15 +Et-W Northing Fasting DI.SEV Vert Section (R) t°) {% {ft) (ft) (ft) {ft) (ft) {ft} {°1tOtIR} (ft} 15,607.17 84.04 101.71 6,570.50 6,461.00 -2,695.11 13,168.47 5,956,525.74 573,859.68 3.03 13,353.26 D Shale 15,693.03 86.61 101.73 6,577.50 6,468.00 -2,712.49 13,252.26 5,956,509.04 573,943.60 3.00 13,438.24 C4 15,700.00 86.82 101.73 6,577.90 6,468.40 -2,713.90 13,259.07 5,956,507.68 573,950.42 2.97 13,445.15 15,743.00 88.11 101.74 6,579.80 6,470.30 -2,722.64 13,301.13 5,956,499.28 573,992.54 3.00 13,487.81 7 5/8" CSG ~ 15743ft MD, 6580ft TVD -1994ft FSL 8 2635ft FWL -Sec 20-T11 N-R11 E - 7 518" 15,769.99 88.92 101.75 6,580.50 6,471.00 -2,728.13 13,327.55 5,956,494.00 574,019.00 3.00 13,514.60 1 D-41 Heel {wp05) 15,774.57 89.06 101.73 6,580.58 6,471.08 -2,729.06 13,332.03 5,956,493.11 574,023.49 3.00 13,519.15 Continue Geosteering in C4 :15775ft MD, 6581ft TVD 15,800.00 89.06 101.73 6,581.00 6,471.50 -2,734.23 13,356.93 5,956,488.14 574,048.42 0.00 13,544.40 15,900.00 89.06 101.73 6,582.65 6,473.15 -2,754.57 13,454.82 5,956,468.60 574,146.47 0.00 13,643.70 16,000.00 89.06 101.73 6,584.29 6,474.79 -2,774.90 13,552.72 5,956,449.06 574,244.52 0.00 13,743.00 16,100.00 89.06 101.73 6,585.94 6,476.44 -2,795.23 13,650.62 5,956,429.52 574,342.57 0.00 13,842.29 16,200.00 89.06 101.73 6,587.59 6,478.09 -2,815.56 13,748.51 5,956,409.98 574,440.62 0.00 13,941.59 16,300.00 89.46 101:73 6,589.24 6,479.74 -2,835.89 13,846.41 5,956,390.44 574,538.67 0.00 14,040.89 16,400.00 89.06 101.73 6,590.88 6,481.38 -2,856.23 13,944.31 5,956,370.90 574,636.72 0.00 14,140.18 16,500.00 89.06 101.73 6,592.53 6,483.03 -2,876.56 14,042.21 5,956,351.36 574,734.77 0.00 14,239.48 16,600.00 89.06 101.73 6,594.18 6,484.68 -2,896.89 14,140,10 5,956,331.82 574,832.81 0.00 14,338.78 16,619.57 89.06 101.73 6,594.50 6,485.00 -2,900.87 14,159.26 5,956,328.00 574,852.00 0.00 14,358.21 iD-41 T1 (wp05) 16,638.16 89.61 101.80 6,594.72 6,485.22 -2,904.66 14,177.4fi 5,956,324.36 574,870.23 3.00 14,376.67 16,700.00 89.61 101.80 6,595.14 6,485.64 -2,917.31 14,237.99 5,956,312.20 574,930.86 0.00 14,438.07 16,800.00 89.61 101.80 6,595.82 6,486.32 -2,937.76 14,335.88 5,956,292.54 575,028.89 0.00 14,537.37 16,900.00 89.61 101.80 6,596.50 6,487.00 -2,958.21 14,433.76 5,956,272.89 575,126.93 0.00 14,636.66 17,000.00 89.61 101.80 6,597.18 6,487.68 -2,978.66 14,531.65 5,956,253.23 575,224.97 0.00 14,735.96 17,046.96 89.61 101.80 6,597.50 6,488.00 -2,988.26 14,577.61 5,956,244.00 575,271.00 0.00 14,782.58 1D-41 T2 (wp05) 17,100.00 90.18 100.32 6,597.60 6,488.10 -2,998.43 14,629.67 5,956,234.25 575,323.13 3.00 14,835.33 17,200.00 91.26 97.52 6,596.34 6,486.84 -3,013.93 14,728.44 5,956,219.55 575,422.02 3.00 14,935.07 17,300.00 92.34 94.72 6,593.20 6,483.70 -3,024.57 14,827.87 5,956,209.71 575,521.46 3.00 15,034.99 17,348.52 92.86 93.35 6,591.00 6,481.50 -3,027.98 14,876.16 5,956,206.69 575,569.83 3.00 15,083.45 17,400.00 92.86 93.35 6,588.43 6,478.93 -3,030.99 14,927.49 5,956,204.10 575,621.18 0.00 15,134.85 17,500.00 92.86 93.35 6,583.45 6,473.95 -3,036.83 15,027.19 5,956,199.06 575,720.92 0.00 15,234.68 17,600.00 92.86 93.35 6,578.46 6,468.96 -3,042.67 15,126.89 5,956,194.03 575,820.66 0.00 15,334.52 17,700.00 92.86 93.35 6,573.48 6,463.98 -3,048.51 15,226.60 5,956,188.99 575,920.39 a.oa 15,434.35 17,719.66 92.86 93.35 6,572.50 6,463.00 -3,049.66 15,246.20 5,956,188.00 575,940.00 0.00 15,453.98 1D~1 T3 (wp05) 17,800.00 91.65 91.27 6,569.34 6,459.84 -3,052.90 15,326.41 5,956,185.41 576,020.23 3.00 15,534.16 17,900.00 90.14 88.67 6,567.78 6,458.28 -3,0.52.84 15,426.38 5,956,186.28 576,120.19 3.00 15,633.76 17,922.41 89.80 88.09 6,567.79 6,458.29 -3,05221 15,448.78 5,956,187.Q9 576,142.58 3.01 15,656.01 18,000.00 89.80 88.09 6,568.05 6,458.55 -3,049.62 15,526.33 5,956,190.30 576,220.10 0.00 15,733.04 18,100.00 89.80 88.09 6,568.39 6,458.89 -3,04629 15,626.28 5,956,194.44 576,320.00 0.00 15,832.31 18,200.00 89.80 88.09 6,568.74 6,45924 -3,042.96 15,726.22 5,956,198.58 576,419.91 0.00 15,931.59 18,300.00 89.80 88.09 6,569.08 6,459.58 -3,039.62 15,826.16 5,956,202.72 576,519.81 0.00 16,030.$6 9/26/2005 3:01:49PM Page 7 of 9 COMPASS 2003.11 Bufid 48 OR!r~NAL ..- i ConocoPhillips Alaska .Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska {Kuparuk) Project:. Kuparuk River Unit Site: Kuparuk 1 D Pad Well: - Plan 1 D-41 Wetlbore: Plan 1 D-41 Design:.. 1 D-41 (wp05} Halliburton Company ~ HAl.,~.IBUF~TQIV Planning Report -Geographic - - - -- Sp~rry OeNtieg Seeviees Local Co-ordinate Reference: Well Plan 1 D-41 7'1tD Reference: RKB (Doyon 15 - Planned) ~ 109.50ft (Doyon 15 (69.5 MD Reference: RKB (Doyon 15 -Planned} ~ 109.50ft {Doyon 15 {69.5 North Reference: True Survey Calcutation Method: Minimum Curvature Planrfed Survey 1 D-41 {wp05) Map: Map '. MD Inclination Azimuth T1/D SSTVD +N/S +E/-W Northing Fasting DISEV Ve-t Sedrort 18,400.00 89.80 88.09 6,569.42 6,459.92 -3,036.29 15,926.11 5,956,206.86 576,619.71 0.00 16,130.13 18,500.00 89.80 88.09 6,56'9.76 6,460.26 -3,032.96 16,026.05 5,956,211.00 576,719.62 0.00 16,229.41 18,600.00 89.80 88.09 6,570.10 6,460.60 -3,029.62 16,126.00 5,956,215.14 576,819.52 0.00 16,328.68 18,700.00 89.80 88.49 6,570.44 6,460.94 -3,026.29 16,225.94 5,956,219.28 576,919.43 0.00 16,427.95 18,800.00 89.80 88.09 6,570.78 6,461.28 -3,022.96 16,325.88 5,956,223.42 577,019.33 0.00 16,52723 18,900.00 89.80 88.09 6,571.12 6,461.62 -3,019.62 16,425.83 5,956,227.56 577,119.23 0.00 16,626.50 19,000.00 89.80 88.09 6,571.46 6,461.96 -3,01629 16,525.77 5,956,231.70 577,219.14 0.00 16,725.77 19,100.00 89.80 88.09 6,571.81 6,462.31 -3,012.96 16,625.71 5,956,235.84 577,319.04 0.00 16,825.05 19,200.00 89.80 88.09 6,572.15 6,462.65 -3,009.62 16,725.66 5,956,239.98 577,418.95 0.00 16,924.32 19,300.00 89.80 88.09 6,572.49 6,462.99 -3,00629 16,825.60 5,956,244.12 577,518.85 0.00 17,023.59 19,303.66 ' 89.80 88.09 6,572.50 ' 6,463.00 -3,006.17 16,82926 5,956,244.27 577,522.51 0.00 17,027.23 BHL @ 19304ft MD, 6573ft TVD : 1703ft FSL 8 881ft FWL - Sec 21-T11N-R11 E - 41f2" -1 D-41 Toe (wp05) C~.wbgic Targets PYan 1 D-41 TVD Target Name +N/S +Et-MV Northing Fasting (ft) =Shape ft ft (ft) (ft} 6,572.50 1D~41 T3 {wp05) -3,049.66 15,24620 5,956,188.00 575,940.00 - Circle (radius 100.00) 6,580.50 1D-41 Heel (wp05) -2,728.13 13,327.55 5,956,494.00 574,019.00 -Circle (radius 100.0 6,594.50 1D~41 T1 (wp05) -2,900.87 14,159.26 5,956,328.00 574,852.00 -Circle (radius 100.00} 6,597.50 1D-41 T2 {wp05) -2,988.26 14,577.61 5,956,244.00 575,271.00 - Circle {radius 100.00) 6,572.50 1 D,41 Toe (wp05) -3,006.17 16,829.26 5,956,244.27 577,522.51 - Gircle (radius 100.00) ~ ~€ ~ • ~-~' COIIOCO~'lll~I 5 p Hafliburton Company hic Plannin Re ort Ge o ra HA><.LIBURTC-N - g p 9 P Alaska Spfrry Wiifi~ Ssrvices Database: EDM 2003.11 Single User Db t.~al Co-ordi~te Reference: Well Plan 1 D-41 Company: ConocoPhillips Alaska {Kuparuk} TVD Reference: RKB (Doyon 15 - P{anned} ~ 109.50ft (Doyon 15 {69.5 Project: Kuparuk River Unit MD Reference: RKB (Doyon 15 - Planned) ~ 109.50ft (Doyon 15 (69.5 Site: Kuparuk 1 D Pad North Reference: True Well: Plan 1 D-41 Survey Gak:ulation Method: Mininwm Curvature Wellbore: Plan 1 D-41 Design: 1 D-41 (wp05) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 9,640.37 4,510.00 10314 13-112 15,743.00 6,579.80 7-5l8 9-7/8 19,303.65 6,572.50 4-1/2 6314 Prognosed Formation Intersection Points Measured Vertical depth inclination A,amuth ~~ +Nl~ +FJ~flf (ft) (•) (") (ft} (ft) (ft) N~ 1,844.83 54.00 101.56 1,648.50 -121.64 594.70 Base of Permafrost 5,716.87 69.17 101.56 3,114.50 -837.95 4,095.47 Top Ugnu C 7,732.74 69.17 101.56 3,831.50 -1,215.64 5,941.27 Top West Sak D 9,076.65 69.17 101.56 4,309.50 -1,467.44 7,171.81 Base West Sak 14,328.60 69.17 101.56 6,177.50 -2,451.44 11,980.68 Top HRZ 14,978.07 69.17 101.56 6,408.50 -2,573.12 12,575.36 Base HRZ (Top Kalubik) 15,226.17 72.61 101.60 6,493.50 -2,619.87 12,803.6fi Kt 15,607.17 84.04 101.71 6,570.50 -2,695.11 13,168.47 D Shale 15,693.03 86.61 101.73 6,577.50 -2,712.49 13,252.26 C4 9/2612045 3:01:41 PM Page 9 of 9 CQMPASS 2003.1 i Build 48 ~~~~ ~~: ~ . .~ n ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 D Pad Plan 1 D-41 Anticollision Summary 26 September, 2005 1-#AL..t,..IBURTC~N Sperry Drilling Services ~~ ~-' ~ Halliburton Company ConoeoPhittlps AnticoAision Report HALLtBtJRTON Alaska Slptairry Deitfing S°rvicaa. __ Company: ConocoPhillips Aaaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1 D Pad Site Error: O.OOft ReferenceWett: Plan 1D-41 WeH. Error. O.OOft Reference FNetcbore Plan 1 D-41 Reference Design: 1D-41 {wp05) Local Co~rrdnate Reference: 7'YD Reference: MD Reference: North Reference: Storey Catcutation Method: Output errors are at Oa#atsase- Offset TVD Reference: WeN Plan 1 D-41 RKB (Doyon 15 - Planned) ~ 109.50ft {Doyon 15 (69.5 RKB (Doyon 15 - Planned) ~ 109.SOR (Doyon 15 {69.5 True Minirnum Curvature 1.00 sigma EDM 20031.11 Single User Db Offset Datum Reference 1 D-41 (wp05} Fitter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD lntetvat SO.OOft Error Model: 1SCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximumcenter-center distance of 2,126.37ft Error Surface: Elliptical Conic Warning Levels evacuated at: 0.00 Sigma 5t~rvey Toof Program Date 9!26!2005 .From To (ft) (ft) Survey {INe11t>ore) Tool Name ' Description 40.00 800.00 1 D-41 (wp05) (Plan 1 D-41} CB-GYRO-SS Camera based gyro single shot 690.50 19,303.66 1 D-41 (vap05) (Plan 1 D-41) MUVD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to cen#er distance or covergent point, SF -min separation factor, ES -min eclipse separation S/2&/2Ot15 i:37:42PM Page 2 of 3 COMPASS 2f1©3. t t Bur/d 48 ORIGINAL ~•' ~ Halliburton Company COI"1000~ll~~t(35 Anticol9ision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) local Co-ar+~naile Referees: Project: Kuparuk River Unft T1fD Reference: Reference Site:. Kuparuk 1 D Pad MD Reference: Site Error. O.OOff North Reference: Reference Welt: Plan 1 D-41 Survey t.alcutation Method: Weti Error. O.flOft output errors are at Reference Wellbore Plan 1 D-41 Database: Reference Design: 1 D-41 {vap05} Offset TVD Reference: • HALLIBURTON Sparry ~ritli~ Servic+as V11e11 Plan 1 D-41 RKB (Doyon 15 - Planned} ~ 109.50ft {Doyon 15 (69.5 RKB {Doyon 15 -Planned} ~ 109.50ft (Doyon 15 {69.5 True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference offset Cerdre to No-Go Aftavrable Measured Measured Centre Distance Deviation blaming. Site Name Depth Depth Distance (ft} from Plan offset Well - Wellbore -Design (ft) {ft) (ft} {ft) Kuparuk 1 C Pad 1C-135 - 1 C-135 -1C-135 5,392.79 11,700.00 990.89 129.41 861.48 Pass -Major Risk Kuparuk 1 D Pad 1 D-07 - 1 D-07 - 1 D-07 453.18 450.00 194.13 7.62 186.51 Pass -Major Risk 1 D-0$ - 1 D-08 - 1 D-O8 447.37 450.00 186.39 8.07 178.31 Pass -Major Risk 1 D-10 - 1 D-10 - 1 D-10 1,083.31 1,150.00 144.88 21.55 123.33 Pass -Major Risk 1 D-10 -1 D-10 - 1 D-102 Wp1 443.85 450.00 181.07 8.05 173.02 Pass -Major Risk 1 D-1 i - 1 D-11 - 1 D-11 633.49 650.00 180.32 11.45 168.87 Pass -Major Risk 1 D-129 - 1 D-129 - 1 D-129 248.00 250.00 241.29 4.41 236.89 Pass -Major Risk 1 D-130 - 1 D-130 - 1 D-130 443.36 450.00 231.09 7.86 223.23 Pass -Major Risk 1 D-131 -1 D-131 - 1 D-131 197.50 200.00 222.76 3.50 219.25 Pass -Major Risk 1 D-132 - 1 D-132 - 1 D-132 396.69 400.00 217.68 7.42 210.26 Pass -Major Risk 1 D-133 -1 D-133 -1 D-133 443.41 450.00 210.07 7.49 202.58 Pass -Major Rsk 1 D-133 - 1 D-133PB1 - 1 D-133PB1 443.41 450.00 210.07 7.49 202.58 Pass -Major Risk 1 D-134 - 1 D-134 - 1 D-134 347.49 350.00 185.36 5.96 179.39 Pass -Major Rsk 1 D-135 -1 D-135 -1 D-135 443.85 450.00 181.01 7.94 173.07 Pass -Major Risk 1 D-136 - 1 D-136 - 1 D-136 407.57 400.00 194.06 7.43 186.64 Pass -Major Risk 1 D-137 - 1 D-137 -1 D-137 407.63 400.00 197.87 7.05 190.82 Pass -Major Risk 1 D-138 - 1 D-138 -1 D-138 546.59 550.00 203.62 9.75 193.87 Pass -Major Risk 1 D-138 - 1 D-138P61 - 1 D-138 WPZ 454.12 450.00 203.64 8.06 195.58 Pass -Major Rik 1 D-138 - 1 D-138P61 - 1 D-138P61 454.00 450.00 206.91 8.31 198.60 Pass -Major Risk 1 D-139 - 1 D-139 - 1 D-139 308.63 300:00 213.30 5.64 207.65 Pass -Major Risk 1 D-141 - 1 D-141 - 1 D-141 2,375.77 2,700.00 402.73 79.96 322.76 Pass -Major Risk 1 D-141 - 1 D-141 L1 -1 D-141 L1 2,375.77 2,700.00 402.73 79.96 322.76 Pass -Major Risk 1 D-141 - 1 D-141 L1 PB1 - 1 D-141 L1 P61 2,375.77 2,700.00 402.73 79.96 322.76 Pass -Major Risk 1 D-141 - 1 D-141 L1 P62 - 1 D-141 L1 PB2 2,375.77 2,700.00 402.73 79.96 322.76 Pass -Major Risk 1 D-141 - 1 D-141 P81 -1 D-141 PB1 2,375.77 2,700.00 402.73 79.96 322.76 Pass -Major Risk 1 D-28 - 1 D-28 - 1 D-28 254.84 250.00 195.76 5.16 190.60 Pass -Major Risk 1 D-28 - 1D-28L1 -1 D-28L1 254.84 250.00 195.76 5.15 190.60 Pass -Major Rik 1 D-30 - 1 D-30 - 1 D-30 600.00 600.00 165.00 10.62 154.38 Pass -Major Risk 1 D-30 - 1 D-30L1 -1 D-30L1 600.00 600.00 165.00 10.62 154.38 Pass -Major Risk 1 D-32 - 1 D-32 - 1 D-32 503.82 500.00 137.41 9.25 128.16 Pass -Major Risk 1 D-34 - 1 D-34 - 1 D-34 702.15 700.00 108.87 12.78 96.09 Pass -Major Risk 1 D-36 - 1 D-36 - 1 D-36 2,962.49 2,950.00 123.07 72.03 51.04 Pass -Major Risk 1 D-37 - 1 D-37 -1 D-37 503.79 500.00 61.37 929 52.07 Pass -Major Risk 1 D-37 - 1 D-37L1 - 1 D-37L1 502.71 500.00 61.34 9.27 52.07 Pass -Major Risk 1 D-37 - 1 D-37L2 - 1 D-37L2 502.71 500.00 61.34 9.27 52.07 Pass -Major Risk 1 D-37 -1 D-37L2P61 - 1 D-37L2PB1 502.71 500.00 61.34 9.27 52.07 Pass -Major Risk 1 D-38 - 1 D-38 - 1 D-38 504.09 500.00 44.35 8.43 35.92 Pass -Major Risk 1 D-39 - 1 D-39 - 1 D-39 400.00 500.00 31.37 7.34 24.03 Pass -Major Risk 1 D-40 - 1 D-40 - 1 D-40 454.11 450.00 15.78 7.85 7.93 Pass -Major Risk 1 D-40 - 1 D-40A -1 D-40A 454.96 450.00 15.79 7.86 7.93 Pass -Major Risk 1 D-42 - 1 D-42 -1 D-42 454.47 450.00 16.84 8.43 8.41 Pass -Major Risk 1 D-42 -1 D-42L1 - 1 D-42L1 453.47 450.00 16.82 8.20 8.63 Pass -Major Risk 1 D-42 - 1 D-42L1 P61 - 1 D-42L7 P61 453.47 450.00 16.82 8.41 8.41 Pass -Major Risk Kuparuk 1 M Pad 1 M-17 -1 M-17 - 1 M-17 19,146.98 10,600.00 746.47 535.64 210.84 Pass - Majos Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9126/2005 1:37:42PM Page 3 of 3 CO1F1PliSS 2D03.1 F Build 48 u~ ~"'o ~`~~ i Date: 200508-22700:00:00 Velldeled: t'a Vadon: 8.000 Depth From Depth To 9urvrylAen Tod 40.00 800.00 1DJ1 (wpOS) C&GYR0.SS e9o.5o 19303.44 1D-41lwpos MWI}r1FR-nK-cnzsc 1628 1638 1639 '~ ', 16135 `~ `, 16130 ~ ~ 1608 ;.1642 j 16133 -~ 16129 - . ,1607 , , 1640 , 1610 ,' 16139 , 16131 16137 '~ 16136 161' 90 i ~ i ~ ~ ` ~ ~~ 1638 ~~ 180 1632 16132 16134 1634 16138 Travelling Cylinder Azimuth (TFO+AZn [°] vs Centre to Centre Separation [250 tY/in] REFER ENCEINFORMATON Co-ordnate (WE) Rsfaerxs: Vrsll Flan 1Dd1, True North Vertical INDI Refaacs: RKB loovon 15- Flamed) ~ 109.508 (Doyen 15 (69.5 +401) Section (V9) Rdaencs: 9101 • (O.OON, QOOE) Msaarad Depth Refaenw: RKB (Doyen 15 - Flamed) ~ 109.SOft (Doyen 15 (89.5 +401) Cdalation Method: Minirnrn Curvatve NAD 27 ASP 2one4: WELL DETN LS: Plan lDdl ConocoPlrllips Nasky lKupanrk) Ground Level: 89.50 Ergneerirg +W-S +E/-W Northing EesBng Leti[[ude Longitude Slot West Sak Q00 0.00 5959114.19 580971.14 70°1T55.887N 149°30'31.iBW Caleulalion Method: Minimun Curvature Error System: ISCYVSA Scat Method: Trav. Cylinder North Error Surface: EIIipOcal Conic Warvng Metfwd: Rules Based 330 1640 300 ~ / X V/ 1 I I N f 1 I [1111 I II II \ \ \ 60 164240~~\,P~ `~ ~ / / ~20 From Colour To MD 210' ~ ~ 150 40 500 500 _ 750 750 --~-- 1000 1000 -~-- - 1250 1250 1500 1500 1750 nso zooo 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 -~ 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 15000 15000 16000 16000 17000 17000 18250 180 TraveBiog Cylieder Azimuth (TFO+AZI) I°I vs Centre to Centre Separation I15 f1/inl SECTION DETNLS 9sc MD Inc AzJ ND +N/-S +EI-W DLSg TFace VSec Taget 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 3 733.33 10.00 101.58 731.84 -5.81 28.43 3.00 101.58 28.83 4 983.33 20.00 101,58 972.82 -18.78 91.74 4.00 0.00 93.02 5 1833.33 54.00 101.58 1641.7d -119.78 585.58 4.00 0.00 593.79 8 2033.33 54.00 101.58 1759.30 -15220 744.10 0.00 0.00 754.54 7 241248 89.17 101.58 1939.20 -21584 1089.83 4.00 0.02 1084.83 8 15111.48 89.17 101.58 8455.95 -2598.11 12897.50 0.00 0.00 12875.82 9 15769.99 88.92 101.75 8580.50 -2728.13 13327.55 3.00 0.55 13514.80 1Dd1 Hed Iwp05) 10 15774.57 89.08 101.73 8580.58 -2729.08 1333203 3.00 -7.20 13519.15 11 18619.57 88.08 101.73 8594.50 -2900.87 14158.28 0.00 0.00 14358.21 1641 T11wpD51 12 18838.16 89.81 101.80 8594.72 -2804.88 14177.48 3.00 8.95 14378.87 13 17048.98 89.61 101.80 8597.50 -2988.28 14577.81 O.OD Q00 1478258 1D-41 T21wr+051 14 17348.52 9288 93.35 8591.00 -3027.98 14878.18 3.00 -88.92 15083.45 15 17719.813 9288 93.35 857250 -3049.86 15248.20 0.00 0.00 15453.98 10.41 T31wp05) 18 1792241 89.80 86.09 8587.79 -305221 15448.78 3.00 -12(1.04 15856.01 17 19303.68 89.60 88.09 857250 -3008.17 18829.28 0.00 0.00 17027.23 10.41 Toe IwPD51 ANTI-coLUS1oN sErru+Gs Irvarpalaeion Metltod: MD IrYSrvd: SOSIaBans Depth Range From: 40.00 To 19303.88 Ma>amun Rarge:2128.38824073332 Reference: Plan: 1D.t11wP05) • • iD-41 Drilling Hazards Summarx 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval.. Gas Hydrates Moderate ,; If observed -control drill, reduce pump rates, reduce drillin fluid tem eratures Additions of Lecithin. Gravel /Sand Sloughing Moderate Increase mud weight /viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of tri sheets Pum in out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur -reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Miti ation Strate Shale stabili in HRZ and K-1 Low Control with hi her MW and ro er drillin radices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Abnormal. Reservoir Pressure Low Follow mud weight schedule and do not fall behind. j Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drillin a interval Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Miti ation Strate Trouble Sliding /Steering Moderate Bit/BHA design will take into account historical problems in offset horizontal wells with steering. Rotary steerable assembly will be used unless equipment failures occur. LOTAD's friction reduction devices will be used. Water based Mud lubricants will be used. Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended period of time. Lube pills will be ready to be spotted if a stuck i e incidents occurs. Difficulties getting liner to bottom Moderate Torque/drag will be monitored while drilling the interval. with swell packers Pump out of hole on final trip out prior to running liner to ensure hole is clean. Utilize torque rings to allow rotation of liner. S of tube ills in o en and cased hole if needed. Lost Circulation Moderate 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. 1D-41 Drilling Hazards Summary.doc prepared by Tim Billingsley 6/29/05 Page 1 of 1 Rig: Doyon 15 Location: Kuparuk Client: CPAI. Revision Date: 9/1/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing i at 80' MD ~1 < Base of Permafrost at ~ 1,845' MD (1,584' ND) < Top of Tail at 6,932' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 9,640' MD (4,487' ND) * Mark of Schlumberger CemCADE~ Preliminary Job Design 10 3/4" Surface reliminary Job Design based on limited input data. For estimate purposes onl Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 6,932' MD. Lead Slurry Minimum pump time: 400 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (80') x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x (1845' - 80') x 3.50 (250% excess) = 2246.5 ft3 0.3637 ft3/ft x (6932' -1845' x 1.35 (35% excess) = 2497.8 ft3 51 ft3 + 2246.5 ft3+ 2497.8 ft = 4795.3 ft3 4795.3 ft3/ 4.45 ft3/sk = 1077.6 sks Round up to 1080 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 280 min. (pump time plus 90 min.) LiteCRETE @ 12.5 ppg - 2.24 ft3/sk 0.3637 ft3/ft x (9640' - 6932') x 1.35 (35% excess) = 1329.6 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 1329.6 ft3 + 43.2 ft3 = 1372.8 ft3 1372.8 ft3/ 2.24 ft3/sk = 612.9 sks Round up to 620 sks BHST = 105°F, Estimated BHCT = 93°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) Ibbl1 (min) Iminl CW100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 7 856 122.3 157.3 Tail Slurry 6 247 41.2 198.5 Drop Top Plug 10.0 208.5 Displacement 7 904 129.1 337.6 Slow Rate 3 15 5.0 342.6 MUD REMOVAL Recommended Mud Properties: 10.1 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ~ 17-21, TY ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 9/6/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com Previous Csg. < 10 3/4", 45.5# casing at 9,640' MD < Top of Tail at 14,893' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 15,743' MD (6,581' TV D) Mark of Schlumberger CemCADE Preliminary Job Design 7.625" Intermediate Casing reliminary Job Design based on limited input data. For esfimate purposes onl Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 850' shoe tack. Tail Slurry Minimum thickening time: 230 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.02%B155, 0.40% D167 - 1.16 ft3/sk 0.2148 ft3/ft x 850' x 1.40 (40% excess) = 255.6 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 255.6 ft3 + 20.6 ft3 = 276.2 ft3 276.2 ft3/ 1.16 ft3/sk = 238.1 sks Round up to 240 sks BHST = 160°F, Estimated BHCT = 123°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) CW100 5 30 6.0 6.0 Drop Bottom Plug 15.0 21.0 MudPUSH II 5 30 6.0 27.0 Tail Slurry 5 50 10.0 37.0 Drop Top Plug 10.0 47.0 Displacement 6 699 116.5 163.5 Slow Rate 3 20 6.7 170.2 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH" II, Pv ~ 19-22, TY ~ 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. QR161h'AL 1 D-41 Horizont~IVell Base Case Proposed Completion Schematic • ConocoPhilli s p 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 IBT 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'DB' nipple w/ 3.875" No-Go Profile set at +/- 500' 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/ DV's (Max. OD 5.984", ID 3.833") Spaced out w/ 4-1 /2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows: 6" conduc 78' BGL Surface csg. 10-3/4" 45.5# L-80 BTC Special Drift - 9.875" 9640' MD / 4510' TVD (200' TVD below Base West Sak) Intermediate csg. 7 5/8" 29.7# L-80 BTCM 15743' MD / 6580' TVD (App. 50' MD below top of C4) anti r~aacni~i~ i ianyc~ .~c~ Ti- i.w avvvc iuiciuicwaic ~.ay anva Baker 5'/2' x 7 5/8" `ZXP' Liner Top Isolation Packer w/ HRD running profile Baker 5'/z' x 7 5/8" RS Nipple Baker 5'/i' x 7 5/8" 'Flexlock' Liner Hanger Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore) 4'/2' 12.6# L-80 BTC with torque rings alternating slotted and blank pipe w/ swell packers (installation of blank pipe & swell pkrs TBD with well logs) 4'/i' ROT `Silver Bullet' Shoe, IBT with torque ring and Xover to BTC GLM # ND-RKB MD-RKB 1 2530 4299 2 3800 7764 3 4750 10355 4 5475 12333 5 6000 13766 6 6400 14860 4-1/2" Camco'DB' nipple w/ 3.813" No-Go Profile set @ bottom of tangent section +/- 15,100 MD / 6450' TVD, 69.2 deg 4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple to sliding sleeve (Special Drift to 3.843") 1 jt 4-1 /2" 12.6# L-80 IBT tubing (Special Drift to 3.843") 4.75" OD Baker casing seal assembly w/ 17 Ft. stroke, 4-1/2" 12.6 # L-80 IBT box up (landed 3-4' off fully landed position) 4'/z' x 6.3" Swell Packers for isolation of potentially conductive faults or wet intervals Slotted Liner 4-1 /2" 12.6# L-80 BTC with torquer gs C4/C3 Lateral to 19,304' MD/6573' TVD . Tim Billingsley 8/26/05 ORIGINAL M N e 1119 SHARON K. ALLSUP-DRAKE G~~- CON000PHILLIPS G? e2-ialai~ ATO 1530 oaTE 700 G ST. ANCHORAGE AK 99501 ~~ ~ CG $ j~ C)C~ PAY TO THE ~ w ORDER OF I t pC1Js 3 ~ V Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars ~_r CHASE 200 WM1~~eCWY Cen[er Dr Newark, DE 19»~ __._~.__...__J^ ___ ____.._._ MEMO '" ~:03LLOOL44~:2L847L9079276~~'LLL9 ~~.,_ ~r,.~~, • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LET~T/ER WELL NAME ~~~~ ~ ~ ~~ 7"~ ~' ~ '- C;~ ~ - PTD# ~j2J~~aP `r^L~~~'C~~~ CHECK WHAT ADD-ONS "CLUE" ' APPLIES ~ ' (OPTIONS) MULTI i The permit ~s for a new wellbore segment of LATERAL existing well , ~ Permit No, API No. f (If API number ~ Production should continue to be reported as ' last two (2) digits a function of .the original API number stated i ~ are between 60-69) above. ~ I all 005(f) AAC 25 ~ PILOT HOLE i , . In accordance with 20 s acquired for the pilot nd lo t d d ~ ~ (per ~ g a a a s, recor hole must be clearly differentiated in both ;I ~ j name (name on permit plus PH) and API number (SO '~ ~ 70/80) from records, data and logs acquired ~ ~ for well (name on permit). I ~ ect to full b d SPACING i ~ j su The permit ~s approve I , ~ EXCEPTION compliance with 20 AAC 25.055. Approval to i ent contin t i /i f g s ec n perforate and produce ~! ~ ~ ;upon issuance of a conservation order ~I i ': approving a spacing exception. , (Company Name) assumes !. i ~ the liability of any protest to the spacing I 'exception that may occur. 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O, Qf d ~ ~ f0 (6 f6, p' Of N~ O ~~ ~ G U T ~ N. ~, _, a O N O N p. a a a~ ~ O w4 ~~ ~, .C~ d d N. ~, x W ~ y. N , 3~ C, ~~ O) ~• ~ ~ Ur N' C Y, ~~ ~, ~ 7 ~ °~ ~, ~, ~, , 7, ° c4` N' N, ~ `_' , N E ii U ~ a ~ ' -, a' a' a v. ~ c' ~, ~ ~, ~ m, a, o. ~ a Q ~ t, c. c a' w, a>' E ~ v. a • ' ' ~,, •y. ~, ` a> m. >, a a o ' ' ' .m ~. y ' , t , 3, ~ ~ ~, y, o. y c ' ' , ~ o. ~ m. o' .a c' ~ ~ c. a> c. O, ~ ' ~' O Z ~' ~' c ;' cmi' m cmi' ~' °~' o ~ m, 0 o E 3 ~ ~ ~ y a' ~ o, o, m f0 o _, o a~ a' - -- a~ c, ~ ~ ~, a ~ m fl: ~ i u - _ c. m y ~a u ~ m ~ c ~ U ' N' m' a a a a~ ~, ' o' >' ~' ~ m, .~. d a o. N, a d' ~ ~ a' ~' ~, ~ 3 0,, ~ c. . v, ~, . ~, •~, ~ ~, o ~ v a' Y' W 3' N ~ Y' a~ t' ~ a '~' y' ~' ~, J U E m. `6 a = - - m o ~, ~ ~ 4 ~ ~, ~ ~ _ ~, 3, ~, U o; ~ H; F- H, ~ ~; ~ 0 m; v. p ~ v; ~ - O . °c. O O ° °= m ~ ~ o' ~ ° ~ Y >, c a i a ~ ~~'~'~;cn;=O, O,a'a;U ~¢~a;Q, U, m; , U'U,U. U,¢ =¢, =o; . , mm,U ~; ~''~', ao;in;in; , U' w _ Q ~ O N M '~t ~ c0 h GO O) O N M tt ~ c0 I~ O O O N M a ' ~ O~ W O O ~ N M V ~ CO I~ _ 00 01 ~ ~ N N N N N N N N N N M M M M M M M M M_ M U H U ~ ° ~n ° ~n ° ~' p C m ~ N d ISO N d R N c V O ~ ~ ~ N N ~ O N ~ N O O N ~ a ~ o Y y r ~ m r ;;~~\\ i T N U E N D ~ ~ ~ a ~ ~°s.i c a. 0 U W ~ E Q m W Q H ~ Q m Q • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 08 10:46:54 2006 Reel Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library z~C~J ~ ~~ ~ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1D-41 API NUMBER: 500292328800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-JUN-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: MW0004123607 MW0004123607 MW0004123607 LOGGING ENGINEER: P. SMITH B. HENNINGSE P. SMITH OPERATOR WITNESS: F. HERBERT G. WHITLOCK F. HERBERT MWD RUN 7 MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0004123607 MW0004123607 MW0004123607 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 23 TOWNSHIP: 11N RANGE: l0E FNL: 552 FSL: FEL: 421 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 110.90 GROUND LEVEL: 69.50 WELL CASING RECORD OPEN HOLE CASING DRILLER S ~ BIT S (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 20.000 118.0 2ND STRING 9.875 10.750 9670.0 3RD STRING 6.750 7.625 15694.0 PRODUCTION STRING 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. THIS WELLBORE IS A SIDETRACK OFF OF A CEMENT PLUG, EXITING 1D-41 PB 2 AT 15699'MD/6611'TVD (5' OUT OF THE 7.625" CASING SHOE). 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,5,7-9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 3,5,7-9 ALSO INCLUDED PRESSURE-WHILE-DRILLING (PWD) MWD RUNS 8,9 ADDITIONALLY INCLUDED STABILIZED LITHO-DENSITY (SLD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AT-BIT INCLINATION (ABI), AND GEO-PILOT ROTARY STEERABLE BHA (GP) MAD PASS POROSITY DATA OVER THE MWD RUN 7 INTERVAL WERE ACQUIRED WHILE POOH AFTER THE COMPLETION OF MWD RUN 8. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5,7-9 REPRESENT WELL 1D-41 WITH API#: 50-029-23288-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19269'MD/6628'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) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-R~TED INTERVALS REFLECTING BIT D~HS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 10.0 - 10.4 PPG MUD SALINITY: 23,000 - 70,000 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 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.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 2955.0 19226.5 RPM 2955.0 19226.5 RPX 2955.0 19226.5 RPS 2955.0 19226.5 FET 2955.0 19226.5 GR 2962.5 19219.5 ROP 3001.5 19269.0 NCNT 15675.0 19183.0 NPHI 15675.0 19183.0 RHOB 15675.0 19198.0 DRHO 15675.0 19198.0 PEF 15675.0 19198.0 FCNT 15675.0 19183.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2955.0 3 9670.0 5 13707.5 7 15699.0 8 16864.0 9 16964.0 REMARKS: MERGED MAIN PASS. MERGE BASE 9670.0 13707.0 15699.0 16864.0 16964.0 19269.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction...... .......Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 19269 11112 32629 2955 19269 FCNT MWD CNTS 115.23 692.47 355.532 7017 15675 19183 NCNT MWD CNTS 13981.5 30468.9 21929.1 7017 15675 19183 RHOB MWD G/CM 1.643 3.648 2.50356 7047 15675 19198 DRHO MWD G/CM -0.813 0.928 0.0479272 7047. 15675 19198 RPD MWD OHMM 1.14 2000 17.5875 32544 2955 19226.5 RPM MWD OHMM 0.11 2000 14.1965 32544 2955 19226.5 RPS MWD OHMM 0.78 1130.41 8.82193 32544 2955 19226.5 RPX MWD OHMM 0.68 554.82 6.56671 32544 2955 19226.5 FET MWD HOUR 0.13 298.53 2.97091 32544 2955 19226.5 GR MWD API 21.91 399.52 92.4112 32515 2962.5 19219.5 PEF MWD BARN 0.45 14.5 3.11044 7047 15675 19198 ROP MWD FT/H 0.17 2714.44 145.377 32536 3001.5 19269 NPHI MWD PU-S 19.18 51.76 28.6732 7017 15675 19183 First Reading For Entire File..........2955 Last Reading For Entire File...........19269 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type .............. ~ • Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 2955.0 9623.0 FET 2955.0 9623.0 RPX 2955.0 9623.0 RPS 2955.0 9623.0 RPD 2955.0 9623.0 GR 2962.5 9631.0 ROP 3001.5 9670.0 LOG HEADER DATA DATE LOGGED: 09-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9670.0 TOP LOG INTERVAL (FT) 3001.0 BOTTOM LOG INTERVAL (FT) 9670.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.8 MAXIMUM ANGLE: 73.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 118.5 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 160.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.240 129.2 MUD FILTRATE AT MT: 4.500 67.0 MUD CAKE AT MT: 2.600 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 9670 6312.5 13431 2955 9670 RPD MWD020 OHMM 1.85 1335.62 18.1035 13337 2955 9623 RPM MWD020 OHMM 1.41 1246.56 17.8286 13337 2955 9623 RPS MWD020 OHMM 2.58 508.34 13.1312 13337 2955 9623 RPX MWD020 OHMM 2.31 158.43 9.07963 13337 2955 9623 FET MWD020 HOUR 0.13 17.73 1.12484 13337 2955 9623 GR MWD020 API 21.91 141.85 73.0835 13338 2962.5 9631 ROP MWD020 FT/H 0.6 1257.35 167.943 13338 3001.5 9670 First Reading For Entire File..........2955 Last Reading For Entire File...........9670 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD ~ ~ Curves and log for header da each bit run in separate f s. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9623.5 13707.0 FET 9623.5 13707.0 RPD 9623.5 13707.0 RPM 9623.5 13707.0 RPX 9623.5 13707.0 GR 9631.5 13707.0 ROP 9670.5 13707.0 LOG HEADER DATA DATE LOGGED: 19-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13707.0 TOP LOG INTERVAL (FT) 9670.0 BOTTOM LOG INTERVAL (FT) 13707.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.0 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 9653.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S) 46.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.850 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .980 149.0 MUD FILTRATE AT MT: 1.700 76.0 MUD CAKE AT MT: 2.050 76.0 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point... .......Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9623.5 13707 11665.3 8168 9623.5 13707 RPD MWD030 OHMM 1.68 2000 12.5983 8168 9623.5 13707 RPM MWD030 OHMM 0.11 182.98 4.42804 8168 9623.5 13707 RPS MWD030 OHMM 0.78 14.58 3.77093 8168 9623.5 13707 RPX MWD030 OHMM 0.78 13.3 3.50628 8168 9623.5 13707 FET MWD030 HOUR 0.2 123.91 2.30571 8168 9623.5 13707 GR MWD030 API 41.97 278.32 115.9 8152 9631.5 13707 ROP MWD030 FT/H 2.71 585.51 183.809 8074 9670.5 13707 First Reading For Entire File..........9623.5 Last Reading For Entire File...........13707 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH FET 13707.5 15645.0 GR 13707 15652.5 RPM 13707.5 15645.0 RPX 13707.5 15645.0 ROP 13707.5 15699.0 RPS 13707.5 15645.0 RPD 13707.5 15645.0 LO G HEADER DATA DATE LOGGED: 03-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15699.0 TOP LOG INTERVAL (FT) 13707.0 BOTTOM LOG INTERVAL (FT) 15699.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.3 MAXIMUM ANGLE: 77.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 9653.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 10.50 MUD VISCOSITY (S) 52.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.450 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .800 133.0 MUD FILTRATE AT MT: 1.400 70.0 MUD CAKE AT MT: 1.700 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.....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...0 ~ Name Service Order Units S Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 I 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 13707.5 15699 14703.3 3984 13707.5 15699 RPD MWD050 OHMM 1.66 1893.67 10.2321 3876 13707.5 15645 RPM MWD050 OHMM 1.56 280.83 9.17913 3876 13707.5 15645 RPS MWD050 OHMM 1.59 18.66 5.49798 3876 13707.5 15645 RPX MWD050 OHMM 1.27 11.8 4.38445 3876 13707.5 15645 FET MWD050 HOUR 0.37 269.62 1.99318 3876 13707.5 15645 GR MWD050 API 65.69 399.52 161.708 3891 13707.5 15652.5 ROP MWD050 FT/H 0.89 2714.44 93.9273 3984 13707.5 15699 First Reading For Entire File..........13707.5 Last Reading For Entire File...........15699 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 15645.5 16817.5 FET 15645.5 16817.5 RPS 15645.5 16817.5 RPD 15645.5 16817.5 RPM 15645.5 16817.5 GR 15653.0 16810.5 ROP 15699.5 16864.0 LO G HEADER DATA DATE LOGGED: 17-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16864.0 TOP LOG INTERVAL (FT) 15699.0 BOTTOM LOG INTERVAL (FT) 16864.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 79.8 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 15694.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record.............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 F1oPro 10.40 51.0 8.6 42000 3.0 .170 76.0 .100 128.9 .160 76.0 .150 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 ~ GR MWD070 API 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15645.5 16864 16254.8 2438 15645.5 16864 RPD MWD070 OHMM 1.28 2000 60.8264 2345 15645.5 16817.5 RPM MWD070 OHMM 0.86 2000 45.9407 2345 15645.5 16817.5 RPS MWD070 OHMM 2.35 1130.41 8.17461 2345 15645.5 16817.5 RPX MWD070 OHMM 1.95 554.82 6.77779 2345 15645.5 16817.5 FET MWD070 HOUR 0.37 298.53 15.5697 2345 15645.5 16817.5 GR MWD070 API 29.9 79.35 55.1535 2316 15653 16810.5 ROP MWD070 FT/H 3.21 626.68 80.31 2330 15699.5 16864 First Reading For Entire File..........15645.5 Last Reading For Entire File...........16864 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 15675.0 16893.0 DRHO 15675.0 16893.0 FCNT 15675.0 16878.5 NPHI 15675.0 16878.5 NCNT 15675.0 16878.5 RHOB 15675.0 16893.0 GR 16811.0 16914.5 RPX 16818.0 16921.5 FET 16818.0 16921.5 RPS 16818.0 16921.5 RPM 16818.0 16921.5 RPD 16818.0 16921.5 ROP 16864.5 16964.0 LO G HEADER DATA DATE LOGGED: 19-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 16964.0 TOP LOG INTERVAL (FT) 16864.0 BOTTOM LOG INTERVAL (FT) 16964.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.9 MAXIMUM ANGLE: 92.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 SLD STABILIZED LITHO DEN 109110 CTN COMP THERMAL NEUTRON 116332 EWR4 Electromag Resis. 4 59475 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 15694.0 BOREHOLE CONDITIONS MUD. TYPE: Flo-Pro MUD DENSITY (LB/G) 10.40 MUD VISCOSITY (S) 61.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 68000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 133.5 MUD FILTRATE AT MT: .090 74.0 MUD CAKE AT MT: .100 74.0 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing.......... .........60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 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 15675 16964 16319.5 2579 15675 16964 FCNT MWD080 CNTS 115.23 570.5 361.049 2408 15675 16878.5 NCNT MWD080 CNTS 13981.5 26505.2 21838.5 2408 15675 16878.5 RHOB MWD080 G/CM 1.643 3.648 2.43746 2437 15675 16893 DRHO MWD080 G/CM -0.813 0.928 0.0531018 2437 15675 16893 RPD MWD080 OHMM 7.02 9.19 7.85072 208 16818 16921.5 RPM MWD080 OHMM 5.7 9.16 7.20082 208 16818 16921.5 RPS MWD080 OHMM 5.22 8.13 6.39053 208 16818 16921.5 RPX MWD080 OHMM 4.02 6.85 4.98418 208 16818 16921.5 FET MWD080 HOUR 1.95 55.14 25.879 208 16818 16921.5 GR MWD080 API 42.18 63.76 55.4164 208 16811 16914.5 PEF MWD080 BARN 1.06 14.5 3.26288 2437 15675 16893 ROP MWD080 FT/H 6.5 157.91 86.7111 200 16864.5 16964 NPHI MWD080 PU-S 20.71 51.76 27.8355 2408 15675 16878.5 First Reading For Entire File..........15675 Last Reading For Entire File...........16964 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 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.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH NPHI 16879.0 NCNT 16879.0 STOP DEPTH 19183.0 19183.0 ~ • FCNT 16879 19183.0 RHOB 16893.5 19198.0 PEF 16893.5 19198.0 DRHO 16893.5 19198.0 GR 16915.0 19219.5 RPS 16922.0 19226.5 RPD 16922.0 19226.5 RPM 16922.0 19226.5 RPX 16922.0 19226.5 FET 16922.0 19226.5 ROP 16964.5 19269.0 LO G HEADER DATA DATE LOGGED: 25-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 19269.0 TOP LOG INTERVAL (FT) 16964.0 BOTTOM LOG INTERVAL (FT) 19269.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.4 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 SLD STABILIZED LITHO DEN 188894 CTN COMP THERMAL NEUTRON 100547 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH {FT) 15694.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G) 10.10 MUD VISCOSITY (S) 44.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 70000 FLUID LOSS (C3) 30.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .120 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 149.0 MUD FILTRATE AT MT: .100 68.0 MUD CAKE AT MT: .150 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point...~.......Undefined • Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value...... ................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 NCNT MWD090 CNTS 4 1 68 8 3 RHO$ 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 16879 19269 18074 4781 16879 19269 FCNT MWD090 CNTS 199.74 692.47 352.65 4609 16879 19183 NCNT MWD090 CNTS 16387.1 30468.9 21976.5 4609 16879 19183 RHOB MWD090 G/CM 2.174 3.124 2.53851 4610 16893.5 19198 DRHO MWD090 G/CM -0.202 0.297 0.0451918 4610 16893.5 19198 RPD MWD090 OHMM 1.14 43.06 9.56314 4610 16922 19226.5 RPM MWD090 OHMM 0.86 920.39 9.38292 4610 16922 19226.5 RPS MWD090 OHMM 0.82 25.52 8.53809 4610 16922 19226.5 RPX MWD090 OHMM 0.68 15.11 6.51802 4610 16922 19226.5 FET MWD090 HOUR 0.3 87.98 2.87005 4610 16922 .19226.5 GR MWD090 API 44.16 109.21 68.6945 4610 16915 19219.5 PEF MWD090 BARN 0.45 6.96 3.02985 4610 16893.5 19198 ROP MWD090 FT/H 0.17 214.42 92.6716 4610 16964.5 19269 NPHI MWD090 PU-S 19.18 41.54 29.1109 4609 16879 19183 First Reading For Entire File..........16879 Last Reading For Entire File...........19269 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/08 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 .....................06/06/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name......... .UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File ~ i Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 08 13:41:11 2006 Reel Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library ~~`~ -~`sS"~f • i "~ `i ~ ~~ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1D-41PB1 API NUMBER: 500292328870 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-JUN-06 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004123607 MW0004123607 LOGGING ENGINEER: P. SMITH B. HENNINGSE OPERATOR WITNESS: F. HERBERT G. WHITLOCK SURFACE LOCATION SECTION: 23 TOWNSHIP: 11N RANGE: l0E FNL: 552 FSL: FEL: 421 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 110.90 GROUND LEVEL: 69.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.500 118.0 2ND STRING 9.875 10.750 9653.0 3RD STRING PRODUCTION STRING 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. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUN 3 ALSO INCLUDED PRESSURE-WHILE-DRILLING (PWD). MWD RUN 4 WAS A HOLE-OPENER RUN WITH DIRECTIONAL AND PWD - NO NEW FOOTAGE WAS MADE, AND NO DATA ARE PRESENTED. BECAUSE OF HOLE PROBLEMS ENCOUNTERED DURING MWD RUN 4, IT WAS DECIDED TO PERFORM AN OPENHOLE SIDETRACK FROM THIS WELLBORE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1D-41 PB1 WITH API#: 50-029-23288-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15947'MD/6616'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 2955.0 15892.5 FET 2955.0 15892.5 ~ • RPS 2955 15892.5 RPM 2955.0 15892.5 RPX 2955.0 15892.5 GR 2962.5 15900.0 ROP 3001.5 15947.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2955.0 9670.0 3 9670.0 15947.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 15947.5 9451.25 25986 2955 15947.5 RPD MWD OHMM 1.68 2000 14.8511 25876 2955 15892.5 RPM MWD OHMM 0.11 1246.56 11.9775 25876 2955 15892.5 RPS MWD OHMM 0.78 508.34 8.83248 25876 2955 15892.5 RPX MWD OHMM 0.78 158.43 6.5021 25876 2955 15892.5 FET MWD HOUR 0.13 123.91 1.53521 25876 2955 15892.5 GR MWD API 21.91 412.73 101.008 25876 2962.5 15900 ROP MWD FT/H 0.6 1257.35 164.452 25893 3001.5 15947.5 First Reading For Entire File..........2955 Last Reading For Entire File...........15947.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ............... • 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.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2955.0 9623.0 RPX 2955.0 9623.0 RPS 2955.0 9623.0 RPM 2955.0 9623.0 RPD 2955.0 9623.0 GR 2962.5 9631.0 ROP 3001.5 9670.0 LOG HEADER DATA DATE LOGGED: 09-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9670.0 TOP LOG INTERVAL (FT) 3001.0 BOTTOM LOG INTERVAL (FT) 9670.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.8 MAXIMUM ANGLE: 73.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 118.5 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 160.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.200 70.0 MUD AT MAX CIRCULA~G TERMPERATURE: 1.240 1~2 MUD FILTRATE AT MT: 4.500 67.0 MUD CAKE AT MT: 2.600 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.....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...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 9670 6312.5 13431 2955 9670 RPD MWD020 OHMM 1.85 1335.62 18.1035 13337 2955 9623 RPM MWD020 OHMM 1.41 1246.56 17.8286 13337 2955 9623 RPS MWD020 OHMM 2.58 508.34 13.1312 13337 2955 9623 RPX MWD020 OHMM 2.31 158.43 9.07963 13337 2955 9623 FET MWD020 HOUR 0.13 17.73 1.12484 13337 2955 9623 GR MWD020 API 21.91 141.85 73.0835 13338 2962.5 9631 ROP MWD020 FT/H 0.6 1257.35 167.943 13338 3001.5 9670 First Reading For Entire File..........2955 Last Reading For Entire File...........9670 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 .File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/06/08 Maximum Physical Record..65535 File Type.... ....... ...LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY • run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9623.5 15892.5 RPD 9623.5 15892.5 RPM 9623.5 15892.5 FET 9623.5 15892.5 RPS 9623.5 15892.5 GR 9631.5 15900.0 ROP 9670.5 15947.5 LOG HEADER DATA DATE LOGGED: 19-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15947.0 TOP LOG INTERVAL (FT) 9670.0 BOTTOM LOG INTERVAL (FT) 15947.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.0 MAXIMUM ANGLE: 83.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 9653.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S) 46.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.850 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .980 149.0 MUD FILTRATE AT MT: 1.700. 76.0 MUD CAKE AT MT: 2.050 76.0 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames .per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9623.5 15947.5 12785.5 12649 9623.5 15947.5 RPD MWD030 OHMM 1.68 2000 11.3917 12539 9623.5 15892.5 RPM MWD030 OHMM 0.11 182.98 5.75399 12539 9623.5 15892.5 RPS MWD030 OHMM 0.78 18.24 4.26022 12539 9623.5 15892.5 RPX MWD030 OHMM 0.78 13.3 3.76053 12539 9623.5 15892.5 FET MWD030 HOUR 0.2 123.91 1.9717 12539 9623.5 15892.5 GR MWD030 API 41.97 412.73 130.714 12538 9631.5 15900 ROP MWD030 FT/H 2.71 585.51 160.744 12555 9670.5 15947.5 First Reading For Entire File..........9623.5 Last Reading For Entire File...........15947.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments ...............~5 LIS Writing Library. Scient~c Technical Services Reel Trailer Service name .............LISTPE Date .....................06/06/08 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 Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 08 14:32:29 2006 ;9c~ -t Reel Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF 13`~tc~( Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1D-41 PB2 API NUMBER: 500292328871 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: OS-JUN-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: MW0004123607 MW0004123607 MW0004123607 LOGGING ENGINEER: P. SMITH B. HENNINGSE P. SMITH OPERATOR WITNESS: F. HERBERT G. WHITLOCK F. HERBERT MWD RUN 6 JOB NUMBER: MW0004123607 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 23 11N l0E 552 421 110.90 69.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~ (IN) BIT S SIZE (IN) DEPTH (FT) 1ST STRING 13.500 20.000 118.0 2ND STRING 9.875 10.750 9653.0 3RD STRING 6.750 7.625 15694.0 PRODUCTION STRING 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. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING 1D-41 PB1 AT 13707'MD/ 5957'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,5,.6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3,5,6 ALSO INCLUDED PRESSURE-WHILE-DRILLING (PWD). MWD RUN 6 ADDITIONALLY INCLUDED STABILIZED LITHO-DENSITY (SLD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AT-BIT INCLINATION (ABI), AND GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 1D-41 PB2 WITH API#: 50-029-23288-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16118'MD/6640'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) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: • • HOLE SIZE: 6.75" MUD WEIGHT: 10.0 - 10.4 PPG MUD SALINITY: 23,000 - 70,000 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 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.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 2955.0 16068.0 RPX 2955.0 16068.0 RPM 2955.0 16068.0 FET 2955.0 16068.0 RPS 2955.0 16068.0 GR 2962.5 16060.5 ROP 3001.5 16118.5 NPHI 15616.0 16033.0 NCNT 15616.0 16033.0 FCNT 15616.0 16033.0 RHOB 15675.0 16049.0 DRHO 15675.0 16049.0 PEF 15675.0 16049.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA'(MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2955.0 9670.0 3 9670.0 13707.0 5 13707.5 15700.0 6 15700.0 16118.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value........... ~.......-999 • Depth Units ..... .......... . ....... Datum Specificat ion Block sub-type...0 Name Service Order Units Size Nsam Rep Co de 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 MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 16118.5 9536.75 26328 2955 16118.5 FCNT MWD CNTS 121.3 567.87 345.993 835 15616 16033 NCNT MWD CNTS 14301.8 27332.8 22339.2 835 15616 16033 RHOB MWD G/CM 1.576 3.82 2.53015 749 15675 16049 DRHO MWD G/CM -0.851 1.048 0.0145207 749 15675 16049 RPD MWD OHMM 1.66 2000 19.1084 .26227 2955 16068 RPM MWD OHMM 0.11 2000 14.3904 26227 2955 16068 RPS MWD OHMM 0.38 1840.52 9.03857 26227 2955 16068 RPX MWD OHMM 0.32 1839.03 6.66291 26227 2955 16068 FET MWD HOUR 0.13 269.62 2.46693 26227 2955 16068 GR MWD API 21.91 399.52 99.2089 26197 2962.5 16060.5 PEF MWD BARN 0.47 12.95 3.78992 749 15675 16049 ROP MWD FT/H 0.6 2714.44 158.996 26235 3001.5 16118.5 NPHI MWD PU-S 21.63 53.33 31.164 835 15616 16033 First Reading For Entire File..........2955 Last Reading For Entire File...........16118.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type.... ..........LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER ~ • FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2955.0 9623.0 RPD 2955.0 9623.0 RPX 2955.0 9623.0 RPS 2955.0 9623.0 RPM 2955.0 9623.0 GR 2962.5 9631.0 ROP 3001.5 9670.0 LOG HEADER DATA DATE LOGGED: 09-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9670.0 TOP LOG INTERVAL (FT) 3001.0 BOTTOM LOG INTERVAL (FT) 9670.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.8 MAXIMUM ANGLE: 73.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 EWR4 ELECTROMAG. RESIS. 4 81797 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 13.500 118.5 LSND 10.00 160.0 9.0 350 4.6 2.200 70.0 1.240 129.2 4.500 67.0 2.600 68.0 Logging Direction...... • .......Down • Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep .Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2955 9670 6312.5 13431 2955 9670 RPD MWD020 OHMM 1.85 1335.62 18.1035 13337 2955 9623 RPM MWD020 OHMM 1.41 1246.56 17.8286 13337 2955 9623 RPS MWD020 OHMM 2.58 508.34 13.1312 13337 2955 9623 RPX MWD020 OHMM 2.31 158.43 9.07963 13337 2955 9623 FET MWD020 HOUR 0.13 17.73 1.12484 13337 2955 9623 GR MWD020 API 21.91 141.85 73.0835 13338 2962.5 9631 ROP MWDO20 FT/H 0.6 1257.35 167.943 13338 3001.5 9670 First Reading For Entire File..........2955 Last Reading For Entire File...........9670 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY ~ VENDOR TOOL CODE START TH RPS 9623.5 RPD 9623.5 RPX 9623.5 FET 9623.5 RPM 9623.5 GR 9631.5 ROP 9670.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 19-FEB-06 Insite 66.37 Memory 13707.0 9670.0 13707.0 67.0 83.8 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 81390 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... STOP DEPTH • 13707.0 13707.0 13707.0 13707.0 13707.0 13707.0 13707.0 9.875 9653.0 LSND 9.80 46.0 9.5 350 4.0 1.850 76.0 .980 149.0 1.700 76.0 2.050 76.0 Datum Specification Bloc~ub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9623.5 13707 11665.3 8168 9623.5 13707 RPD MWD030 OHMM 1.68 2000 12.5983 8168 9623.5 13707 RPM MWD030 OHMM 0.11 182.98 4.42804 8168 9623.5 13707 RPS MWD030 OHMM 0.78 14.58 3.77093 8168 9623.5 13707 RPX MWD030 OHMM 0.78 13.3 3.50628 8168 9623.5 13707 FET MWD030 HOUR 0.2 123.91 2.30571 8168 9623.5 13707 GR MWD030 API 41.97 278.32 115.9 8152 9631.5 13707 ROP MWD030 FT/H 2.71 585.51 183.809 8074 9670.5 13707 First Reading For Entire File..........9623.5 Last Reading For Entire File...........13707 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 13707.5 15645.0 RPM 13707.5 15645.0 FET 13707.5 15645.0 RPS 13707.5 15645.0 GR 13707.5 15652.5 RPD 13707.5 15645.0 ROP 13707 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: 15700.0 03-MAR-06 Insite 66.37 Memory 15700.0 13707.0 15700.0 64.3 77.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing.. .................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 10718517 81390 9.875 9653.0 LSND 10.50 52.0 9.1 500 3.0 1.450 70.0 .800 133.0 1.400 70.0 1.700 70.0 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 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWDO50 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 13707.5 15700 14703.8 3986. 13707.5 15700 RPD MWD050 OHMM 1.66 1893.67 10.2321 3876 13707.5 15645 RPM MWD050 OHMM 1.56 280.83 9.17913 3876 13707.5 15645 RPS MWD050 OHMM 1.59 18.66 5.49798 3876 13707.5 15645 RPX MWD050 OHMM 1.27 11.8 4.38445 3876 13707.5 15645 FET MWD050 HOUR 0.37 269.62 1.99318 3876 13707.5 15645 GR MWD050 API 65.69 399.52 161.708 3891 13707.5 15652.5 ROP MWD050 FT/H 0.89 2714.44 93.9367 3986 13707.5 15700 First Reading For Entire File..........13707.5 Last Reading For Entire File...........15700 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 15616.0 16033.0 NCNT 15616.0 16033.0 FCNT 15616.0 16033.0 RPM 15645.5 16068.0 RPS 15645.5 16068.0 RPD 15645.5 16068.0 FET 15645.5 16068.0 RPX 15645.5 16068.0 GR 15653.0 16060.5 DRHO 15675.0 16049.0 RHOB 15675.0 16049.0 PEF 15675.0 16049.0 ROP 15700.5 16118.5 LO G HEADER DATA DATE LOGGED: 11-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 16118.0 TOP LOG INTERVAL (FT) 15700.0 BOTTOM LOG INTERVAL (FT) 16118.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.1 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 SLD STABILIZED LITHO DEN 188894 CTN COMP THERMAL NEUTRON 100547 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 15694.0 BOREHOLE CONDITIONS MUD TYPE: F1oPro MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 49.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .250 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .120 150.4 MUD FILTRATE AT MT: .260 70.0 MUD CAKE AT MT: .230 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 ~ • RHOB MWD060 G/CM 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HOUR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 BARN 4 1 68 44 12 ROP MWD060 FT/H 4 1 68 48 13 NPHI MWD060 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15616 16118.5 15867.3 1006 15616 16118.5 FONT MWD060 CNTS 121.3 567.87 345.993 835 15616 16033 NCNT MWD060 CNTS 14301.8 27332.8 22339.2 835 15616 16033 RHOB MWD060 G/CM 1.576 3.82 2.53015 749 15675 16049 DRHO MWD060 G/CM -0.851 1.048 0.0145207 749 15675 16049 RPD MWD060 OHMM 2.3 2000 138.472 846 15645.5 16068 RPM MWD060 OHMM 0.24 2000 80.249 846 15645.5 16068 RPS MWD060 OHMM 0.38 1840.52 11.5994 .846 15645.5 16068 RPX MWD060 OHMM 0.32 1839.03 9.47962 846 15645.5 16068 FET MWD060 HOUR 0.37 172.9 27.3517 846 15645.5 16068 GR MWD060 API 25.43 92.34 61.4812 816 15653 16060.5 PEF MWD060 BARN 0.47 12.95 3.78992 749 15675 16049 ROP MWD060 FT/H 1.88 291.29 86.8843 837 15700.5 16118.5 NPHI MWD060 PU-S 21.63 53.33 31.164 835 15616 16033 First Reading For Entire File..........15616 Last Reading For Entire File...........16118.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/06/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services • • Physical EOF Physical EOF End Of LIS File