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206-114
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: KUPARUK RIVER 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,273' N/A Casing Collapse Conductor Surface Production B Liner S-3 Packer D Liner HH B Liner Lem Fish Slotted Liner A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SSSV: N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3,645' 3,656' 3,688' Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506 KUPARUK RIV U WSAK 1J-103 WEST SAK OIL N/A 3,774' 5,958' SSSV: None Packer: 6,179' 6,249' 6,469' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025661 / ADL0025662 206-114 PO Box 100360, Anchorage, Alaska 99506 50-029-23318-00-00 ConocoPhillips Alaska Inc. Other: SC Repair Length Size Proposed Pools: L-80 TVD Burst 5,971' 124' 260' MD 108' 2,243' 108' 2,925' 3,791'7 5/8" 20" 10 3/4" 80' 2,897' 7,130'7,100' 4 1/2" 3,791' - 3,775' 61' 6.28" 4 1/2" 4 1/2" 11/1/2025 11,259'4,835' 2 7/8" 3,774' Well Integrity Field Supervisor 7,125' - 11,220' Baker 47D2 FHL Retrievable Packer, Baker HRD ZXP liner top packer FHL Retrievable: 5,904' MD, 3,597' TVD / HRD ZXP liner top: 6,424' MD, 3,681' TVD m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.05.19 12:50:49-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green 325-311 By Grace Christianson at 1:09 pm, May 19, 2025 10-404 A.Dewhurst 15OCT25 DSR-6/3/25 JJL 7/21/25 Ensure well is secured downhole with plug and verified with a MIT prior to welding. 10/15/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 19, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. to repair the Surface Casing leak on well KRU W Sak 1J-103 (PTD 206- 114). Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2025.05.19 12:50:11-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. KUPARUK WELL 1J-103 (PTD 206-114) SUNDRY NOTICE 10-403 APPROVAL REQUEST This application for Sundry approval is for Kuparuk well 1J-103 and the inspection and repair of a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow (~5 8 below the OA valve). ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps (with photo documentation): 1. Secure the well as needed with mechanical plug in the tubing and kill weight in the OA. Perform barrier testing to verify safe working conditions. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~16 to 24. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine the type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to service. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 4,895.0 1J-103 3/30/2008 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set tubing plug 1J-103 4/22/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVER CANCELLATION 5/20/2015 lehallf NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 10/14/2008 lmosbor NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 4/16/2008 lmosbor NOTE: B-SAND LEM TORN & PULLED @ INSIDE HOOK HANGER @ 6328' 1/29/2007 WV5.3 Conversio n NOTE: MULTILATERAL WELL- 1J-103 (A-SAND), 1J-103L1 (B-SAND), 1J-103L2 (D-SAND) 1/29/2007 WV5.3 Conversio n 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 20 19.12 28.0 108.0 108.0 94.00 K-55 WELDED SURFACE 10 3/4 9.95 28.0 2,925.0 2,243.3 45.50 L-80 Buttress WINDOW D 8 6.00 5,991.0 6,001.0 3,613.0 29.70 L-80 WINDOW B 8 6.00 6,332.0 6,342.0 3,668.7 29.70 L-80 PRODUCTION 7 5/8 6.87 29.8 7,130.0 3,790.8 29.70 L-80 BTCM B Liner S-3 Packer 6.28 5.07 6,118.3 6,179.0 3,644.9 D LINER HH 4 1/2 3.48 5,989.3 6,248.7 3,655.7 11.60 L-80 4-1/2" BTC B LINER LEM FISH 4 1/2 3.86 6,344.5 6,468.7 3,687.7 12.60 L80 IBTM-SCC SLOTTED LINER A 4 1/2 3.48 6,423.8 11,259.0 3,773.9 11.60 L-80 Buttress Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.8 Set Depth 5,970.7 Set Depth 3,608.0 String Max No 2 7/8 Tubing Description Tubing Production Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.44 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) 22.8 22.8 0.00 HANGER 10.750 Vetco Tubing Hanger, 10-3/4" x 4- 1/2", 4" 'H' BPVG, 4.909 MCA Box up x 4-1/2" IBT Box down Vetco Gray 3.958 3,416.6 2,497.1 59.52 GAS LIFT 4.750 Camco, 2-7/8" x 1" KBMG (SN: 179AF06) Camco KBMG 2.366 5,817.8 3,581.1 79.33 GAS LIFT 4.750 Camco, 2-7/8" x 1" KBMG (SN: 018AE19; SV SN: A14G-5347) Camco KBMG 2.366 5,873.7 3,591.3 79.70 LOCATOR 4.170 GBH-22 Locator Sub (bottom of locator spaced out 6.5') Baker GBH-22 3.000 5,874.6 3,591.4 79.70 SEAL ASSY 3.750 80-40 Seal Assembly (total length = 21.75') Baker 80-440 LTSA 3.000 5,881.1 3,592.6 79.75 PBR 5.010 80-40 PBR Baker 80-40 PBR 4.010 5,904.3 3,596.7 79.90 PACKER 5.930 47D2 FHL Retrievable Packer (Shear Release = 60K) Baker 47D2 FHL 2.910 5,958.1 3,605.9 80.36 NIPPLE 3.680 2.313" 'DS' Nipple (SN: TO41414) 2.313 5,969.4 3,607.8 80.46 SHOE 3.550 Mule Shoe 2.375 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,958.0 3,605.9 80.36 TUBING PLUG 2.31" CSA-2 Plug (OAL = 28") 4/22/2025 0.000 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) 3,416.6 2,497.1 59.52 1 GAS LIFT OV BK 1 0.0 7/22/2017 Schlumb erger Camco BK 0.313 5,817.8 3,581.1 79.33 2 GAS LIFT DMY BK 1 0.0 11/18/2019 Schlumb erger Camco BEK 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) 6,118.3 3,633.9 78.83 SLEEVE 7.625 C-2 Liner Hanger Setting Sleeve 5.750 6,144.4 3,638.8 79.50 XO BUSHING 4.910 Crossover Bushing 3.980 6,157.1 3,641.1 79.83 PACKER 3.875 Baker S-3 packer 3.875 6,168.4 3,643.1 80.12 NIPPLE 5.200 Camco DB Nipple 3.562 6,177.7 3,644.6 80.36 WLEG 4.500 WLEG 3.880 6,064.5 3,623.7 79.59 ECP 4.500 External Casing Packer 3.476 6,391.3 3,675.9 81.33 NIPPLE 5.200 DB-6 Nipple 3.563 6,423.8 3,680.8 81.25 PACKER 7.650 Baker HRD ZXP liner top packer 5.500 6,442.8 3,683.7 81.20 NIPPLE 6.070 Packoff Seal Nipple 4.870 11,219.9 3,774.5 90.83 XO Reducing 5.000 CROSSOVER REDUCING 4.5"x3.5" 3.000 11,221.3 3,774.5 90.85 XO THREAD 3.500 2.992 Multiple Laterals, 1J-103, 4/24/2025 1:30:01 PM Vertical schematic (actual) SLOTTED LINER A; 6,423.8- 11,259.0 SLOTS; 8,230.0-11,220.0 SLOTS; 7,503.0-8,058.0 SLOTS; 7,125.0-7,330.0 PRODUCTION; 29.8-7,130.0 B LINER LEM FISH; 6,468.7 WINDOW B; 6,332.0-6,342.0 B LINER Slotted; 6,328.3- 11,584.0 D LINER HH; 5,989.3-6,248.7 B Liner S-3 Packer; 6,118.3- 6,179.0 WINDOW D; 5,991.0-6,001.0 TUBING PLUG; 5,958.0 NIPPLE; 5,958.1 PACKER; 5,904.3 GAS LIFT; 5,817.8 GAS LIFT; 3,416.6 SURFACE; 28.0-2,925.0 CONDUCTOR Insulated; 28.0- 108.0 HANGER; 22.8 KUP PROD KB-Grd (ft) -48.71 RR Date 1/29/2007 Other Elev 1J-103 ... TD Act Btm (ftKB) 11,272.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331800 Wellbore Status PROD Max Angle & MD Incl (°) 94.90 MD (ftKB) 8,220.00 WELLNAME WELLBORE1J-103 Annotation Last WO: End Date 11/8/2015 H2S (ppm) 50 Date 11/8/2014 Comment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,125.0 7,330.0 3,790.6 3,789.5 WS A1, 1J-103 12/28/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 7,503.0 8,058.0 3,791.7 3,786.8 WS A1, 1J-103 12/28/2006 32.0 SLOTS Alternating solid/slotted pipe 8,230.0 11,220.0 3,779.2 3,774.5 WS A1, 1J-103 12/28/2006 32.0 SLOTS Alternating solid/slotted pipe Multiple Laterals, 1J-103, 4/24/2025 1:30:02 PM Vertical schematic (actual) SLOTTED LINER A; 6,423.8- 11,259.0 SLOTS; 8,230.0-11,220.0 SLOTS; 7,503.0-8,058.0 SLOTS; 7,125.0-7,330.0 PRODUCTION; 29.8-7,130.0 B LINER LEM FISH; 6,468.7 WINDOW B; 6,332.0-6,342.0 B LINER Slotted; 6,328.3- 11,584.0 D LINER HH; 5,989.3-6,248.7 B Liner S-3 Packer; 6,118.3- 6,179.0 WINDOW D; 5,991.0-6,001.0 TUBING PLUG; 5,958.0 NIPPLE; 5,958.1 PACKER; 5,904.3 GAS LIFT; 5,817.8 GAS LIFT; 3,416.6 SURFACE; 28.0-2,925.0 CONDUCTOR Insulated; 28.0- 108.0 HANGER; 22.8 KUP PROD 1J-103 ... WELLNAME WELLBORE1J-103 New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T38970 9-26-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T38971 9-26-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T38972 9-26-2005 1E-24BL1 PB1 50-029-20857-70-00 212-009 T38973 4-17-2012 1E-24BL1 PB2 50-029-20857-71-00 212-009 T38974 4-17-2012 1E-24BL1 PB3 50-029-20857-72-00 212-009 T38975 4-17-2012 1J-102 PB1 50-029-23317-70-00 206-110 T38976 3-4-2008 1J-102 PB2 50-029-23317-71-00 206-110 T38977 3-4-2008 1J-102 PB3 50-029-23317-72-00 206-110 T38978 3-4-2008 1J-102L2 PB1 50-029-23317-73-00 206-112 T38979 3-24-2008 1J-102L2 PB2 50-029-23317-74-00 206-112 T38980 3-24-2008 1J-103 PB1 50-029-23318-70-00 206-114 T38981 12-12-2008 1J-103 PB2 50-029-23318-71-00 206-114 T38982 12-12-2008 1J-103 PB3 50-029-23318-72-00 206-114 T38983 12-12-2008 1J-103 PB1 50-029-23318-70-00 206-114 T38981 12-12-2008 1J-103 PB2 50-029-23318-71-00 206-114 T38982 12-12-2008 1J-103 PB3 50-029-23318-72-00 206-114 T38983 12-12-2008 STATE OF ALASKA SKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon l Plug Perforations f-••••. Fracture Stimulate E V Pull Tubing F Operations Shutdown Performed: Suspend E Perforate E Other Stimulate Alter Casing E Change Approved Program r Plug for Redrill I Perforate New Pool n Repair Well IV Re-enter Susp Well E 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development F Exploratory E 206-114 3.Address: 6.API Number P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23318-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25662 WSAKIJ-103 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11273 feet Plugs(measured) None true vertical 3774 feet Junk(measured) None Effective Depth measured 11266 feet Packer(measured) 5904,6157,6424 true vertical 3774 feet (true vertical) 3597,3641,3681 Casing Length Size MD TVD Burst Collapse CONDUCTOR INSI 80 20 108 108 0 0 SURFACE 2897 10.75 2925 2243 0 0 PRODUCTION 7100 7.625 7130 3791 0 0 B-SAND WINDOW 1 8 6342 3669 0 0 D-SAND WINDOW 1 8 6001 3613 SCANNEro FEE MG Perforation depth: Measured depth: 7125-7330,7503-8058,8230-11220 True Vertical Depth: 3791-3789,3792-3787,3779-3774 N L.:1,V .!'E(..... 0 7 201'1 Tubing(size,grade,MD,and TVD) 2 7/8, L-80,5971 AOG CC Packers&SSSV(type,MD,and TVD) PACKER-47D2 FHL Retrievable Packer @ 5904 MD and 3597 TVD' Baker S-3 Packer @ 6157 MD and 3641 TVD, Baker HRD ZXP Liner Top Packer@ 6424 MD and 3681 TVD SSSV-None 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development 1; Service E Stratigraphic f® Copies of Logs and Surveys Run fl 16.Well Status after work: Oil F Gas fl WDSPL 1"-- Printed Printed and Electronic Fracture Stimulation Data GSTOR f- WINJ 1 WAG E GINJ E SUSP E SPLUG 1'' 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Janelle NesvoIde,263-4641 Email Janelle.R.NesvoldCa�cop.com Printed Name Janelle Nesvold Title Sr. Completions Engineer Signature (!+ 1.. faii ,,.4.r 4 Phone:263-4641 Date /Z/7//r j 7/i5 1,7 LRBDMS c' Q,i g 101 � Form 10-404 Revised 5/2015 /7/2 LI �3�� �j(1_/��� Submit Original Only y ® • Daily Operations Summary • jig 1J-103 ConoucoPhillps Rig: NABORS 9ES Job: RECOMPLETION Daily Operations Start Date Last 24hr Sum 10/31/2015 MIRU,Pull BPV and Attempt to kill well 11/1/2015 Continue to Circulate 728 bbls @ 2 bpm @ 190 psi. Had signs of a lot of fluid swapping happening. RU Slick line and install dummy valve in open pocket @ 4,295-ft. Circulate in attempt to kill well. 11/2/2015 Reverse circulate and kill well. Set BPV, ND Tree and NU BOPE. Conduct Initial BOP Test. 24 hr Notice was given to the AOGCC @ 4:25 hrs on 10-31-15 and Right to witness was waived by Bob Noble @ 6:06 hrs 10-31-15. RU ESP Spooling equipment. POOH from 5,015-ft to 3,770-ft 79K Up wt,77K Dn wt 11/3/2015 Continue to POOH from 3770'to 3600', PU Baker storm packer,RIH to 111',set packer and PT to 500 psi(good test). Drain stack and ND BOPE to allow Vetco Gray to replace guide pin that is bent. NU BOPE stack,test BOPE breaks,and test with remaining test joints. Pull storm packer, continue POOH with 4.5"ESP Completion, LD discharge sub,drain motor/seals of oil,remove all hardware from ESP and LD ESP equipment. 11/4/2015 RD ESP pulling equipment. Install the wear ring. PU and MU cleanout assembly as per Baker Rep. Single in the hole with cleanout on 4"HT-40 DP from the pipe shed to 5743'RKB.It was observed that the DP tally did not match what was being picked up out of the pipe shed. The decision was made to TOOH to verify the joint count.TOOH standing back the DP strapping each stand from 5743'to 506'RKB.While standing back a stand of DP the DP in the slips jumped out of the slips and went downhole. TIH with DP to screw back into the DP on top of the BHA to 5235' RKB. Continue to RIH with singles from the pipe shed to tag at 5361'RKB. Slowly SO rotating,saw a pressure increase,turned the pumps off, continue to SO,and the torque increased to 5600 ft-lbs. PU,had increased weight(PU= 112K),SO,turned the pumps on,and pressure increased immediately(bull nose probably packed off with sand). 11/5/2015 TOOH with fished BHA and lay down the two single that were screwed into to fish. Screw in TD and circulate through the BHA to ensure it is clean. RIH with cleanout assembly with 12 joints of 4"HT-40 DP from the pipe shed.TIH with cleanout from 793'to tag at 5835'RKB. Cleanout sand from 5835'to 6124'RKB(bottom of string mill at 5938'RKB). Pump a hi-visc sweep and circulate sweep out of the hole. Observe the well for flow for 15 minutes;the well is on a slight vac. POOH with cleanout assembly laying down DP from 6124'to 411'RKB. Lay down the cleanout assembly and pull the wear ring. Load the pipe shed with 2-7/8"EUE 8rd mod tubing. Strap,drift,and tally all tubing. 11/6/2015 Continue to load the pipe shed with 2-7/8"EUE 8rd mod tubing. Strap,drift,and tally all tubing. Conducted a safety stand down with both the day and night crews. PU, MU,and RIH with 2-7/8"gas lift completion to 5980'RKB. Circulate 267 bbls of corrosion inhibited seawater down the tubing taking returns up the IA at 3 BPM and chase with 6 bbls of seawater to clear the surface lines. Drop the ball&rod and attempt to pressure up to set the packer but unable to get ball&rod on seat due to well bore inclination. Call out for slickline to get the ball&rod to seat. RD circulating equipment and blow down lines. 11/7/2015 Slip and cut 108'of drilling line.Wait for HES slickline to arrive. RU HES slickline. RIH with tool string and push ball&rod to seat on the RHC plug body. Pressure up on the tubing to 633 psi for 5 minutes to confirm ball&rod is holding(good test). POOH with slickline tool string. RD HES slickline. Pressure up on the tubing to 2600 psi to set the FHL packer and hold for 10 minutes. Bleed the tubing pressure to 2000 psi and PU to shear the PBR. Space out with pups,MU tubing hanger,land tubing hanger,and RILDS.PT the upper and lower tubing hanger seals to 5000 psi for 15 minutes(good test). Close the blind rams,PT the tubing to 3000 psi for 15 minutes(good test),bleed the tubing to 1500 psi,PT the IA to 2500 psi for 30 minutes(good test),bleed the IA to 0 psi,bleed the tubing to 0 psi,and quickly ramp up the pressure on the IA to shear the SOV (SOV sheared at 2500 psi). Drain the BOP stack and install the TWC with the dry rod. Pressure up on the IA to 1000 psi for 5 minutes to test the TWC from below in the direction of flow(good test). Perform CPAI BOPE inspection per CPAI Between Well Maintenance(BWM)program. 11/8/2015 Perform CPAI BOPE inspection per CPAI BWM program. Pull riser,pull mouse hole,and lay down mouse hole. ND the BOP stack and secure to the stump. NU the tree. PT the tubing hanger void to 250/5000 psi and PT the tree to 250/5000 psi(good tests). RU lubricator. PT to 1000 psi. Pull the TWC. RU LRS to pump down IA and take returns up tubing to kill tank.Reverse circulate 107 bbls of diesel to kill tank. Pump at 2 BPM, 1475 psi FCP. Allow well u-tube and equalize.Clean cellar and prepare to lay derrick over. Final well pressures: OA=75 psi, IAO psi,Tbg=O psi. Bridal up blocks.Continue to prep floor to lay down derrick. **Rig released at 1200 hrs** Page 1/1 Report Printed: 12/3/2015 KUP PROD • 1J-103 ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status Inc'7) MD(ftKB) Act Btm(ftKB) ,mw.natvalg 500292331800 WEST SAK PROD 94.90 8,220.00 11,272.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Mul/pe Laterals-1J-103,12/2/2015 735:22 AM SSSV. NONE 50 11/8/2014 Last WO: 11/8/2015 -48.71 1/29/2007 W,.. Vsltcel schemata*kW.) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.CTMD 4,895.0 3/30/2008 Rev Reason:WORKOVER,GLV C/O leha8f 12/1/2015 HANGER;22.8 ;3 i).,: Cing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR Insulated 20 19.124 28.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 28.0 2,925.0 2,243.3 45.50 L-80 Buttress Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread XO Reducing(Tubing);54.5 4 WINDOWD 8 6.000 5,991.0 6,001.0 3,613.0 29.70 L-80 4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR Insulated;26.2-_y • WINDOW B 8 6.000 6,332.0 6,342.0 3,668.7 29.70 L-80 108.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread • PRODUCTION 75/6 6.875 29.8 7,130.0 3,790.8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread B Liner S-3 Packer 6.28 5.070 6,118.3 6,179.0 3,644.9 • Liner Details • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) . Item Des Com (in) SURFACE;28.0.2,925.0 6,118.3 3,633.9 78.83 SLEEVE C-2 Liner Hanger Setting Sleeve 5.750 6,125.6 3,635.3 79.02 SBE 197-47 Casing Seal Bore extension 5.070 GAS LIFT;3,416.6 6,144.4 3,638.8 79.50 XO BUSHING Crossover Bushing 3.980 6,157.1 3,641.1 79.83 PACKER Baker S-3 packer 3.875 6,168.4 3,643.1 80.12 NIPPLE Camco DB Nipple 3.562 tril 6,177.7 3,644.6 80.36 WLEG WLEG 3.880 GAS LIFT;3817.8 4 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread li D LINER HH 4 1/2 3.476 5,989.3 6,248.7 3,655.7 11.60 L-80 4-1/2"BTC 4 Liner Details 00 Enlarging(Tubing);5,872.0 `jt: Nominal ID LOCATOR;3873.7 Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Das Corn (in) SEAL ASSY;5,874.6 _ 5,989.3- 3,611.1 80.64 HANGER Baker Model B-1 Hook Hanger(Inside) 5.600 PER;5,881.1 PACKER;5,904.3 PIM 6,006.0 3,613.8 80.79 HANGER Baker Model B-1 Hook Hanger(Out side) 3.970 . xo Reducing(Tubing);5,911.5 "It6,064.5 3,623.7- 79.59 ECP External Casing Packer 3.476 4 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread B LINER LEM FISH 4 1/2 3.860 6,344.5 6,468.7 3,687.7 12.60 L80 IBTM-SCC NIPPLE;5,958.1 Liner Details Top(ftKB) To )(ftKB) Top () Nominal I ID SHOE;5,969.4 ) p(TVD ftKB Ind Item Des Com 6,344.5 3,669.0 81.80 HANGER LEM(inside hook hanger) 3.688 6,391.3 3,675.9 81.33 NIPPLE DB-6 Nipple 3.563 WINDOW D;5,991.0-6,001.01 t 6,465.4 3,687.2 81.14 SEAL ASSY Seal assembly 3.860 Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SLOTTED LINER A 41/2 3.476 6,423.8 11,259.0 3,773.9 11.60 L-80 Buttress Liner Details Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com No(In)I ID l 6,423.8 3,680.8 81.25 PACKER Baker HRD ZXP liner top packer 5.500 6,442.8 3,683.7 81.20 NIPPLE Packoff Seal Nipple 4.870 ;-- 6,445.5 3,684.2 81.19 HANGER Flex-lock liner hanger 4.750 6,452.6' 3,685.2 81.17 SBE Seal bore extension 4.750 11,219.9 3,774.5 90.83 XO Reducing CROSSOVER REDUCING 4.5"x3.5" 3.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING RWO 2015 2 7/8 2.441 22.8 5,970.7 3,608.0 6.50 L-80 EUE 8rd Mod Completion Details B Liner S-3 Pecker;6,118.3- Nominal ID 6,179.0 Top(6KB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) D LINER HH;5,989.3-6,248.7 22.6 22.8 0.00 HANGER Vetco Tubing Hanger,10-3/4"z 4-1/2",4"'H'BPVG, 3.958 4.909 MCA Box up x 4-1/2"IBT Box down B LINER Slotted;8'343^ 5,873.7 3,591.3 79.70 LOCATOR GBH-22 Locator Sub(bottom of locator spaced out 6.5') 3.000 WINDOW B;6,332.0-6,342.0 J 5,874.6 3,591.4 79.70 SEAL ASSY 80-40 Seal Assembly(total length=21.75') 3.000 5,881.1 3,592.6 79.75 PBR 80-40 PBR 4.010 5,904.3 3,596.7 79.90 PACKER 47D2 FHL Retrievable Packer(Shear Release=60K) 2.910 5,958.1 3,605.9 80.36 NIPPLE 2.313"'DS'Nipple(SN:T041414) 2.313 5,969.4 3,607.8 80.46 SHOE Mule Shoe 2.375 Perforations&Slots Shot ' Dens it Top(TVD) Btm(TVD) (shots/f B LINER LEM FISH;6,468.7 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,125.0 7,330.0 3,790.6 3,789.5 WS A1,1J- 12/28/2006 32.0 SLOTS ALL PERFS IN WELL: 103 Alternating solid/slotted pipe-0.125"x2.5"@4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 7,503.0 8,058.0 3,791.7 3,786.8 WS A1,1J- 12/28/2006 32.0 SLOTS Alternating solid/slotted 103 pipe PRODUCTION;29.6-7,130.0 1 8,230.0 11,220.0 3,779.2 3,774.5 WS At,1J- 12/28/2006 32.0 SLOTS Alternating solid/slotted SLOTS;7,125.0-7330.0 103 pipe Mandrel Inserts st MI SLOTS;7,503.0-8,058.0 on Top(TVD) Valve Latch Pod Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,416.6 2,497.1 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 1,457.0.11/12/2015 SLOTS 8,230.0-11,220.0 2 5,817.8 3,581.1 Camco KBMG 1 GAS LIFT OV BEK 0.313 0.0 11/12/2015 SLOTTED LINER A;5,423.8- I II . 11,259.0 KUP PROD . 1J-103 ConocoPhillips Oi' Kaska,Inc. CS oraigh1H72 Multiple Laterals-1J-103,12/212015 7:35'25 AM Vertical actle1natl0(95M0(() ......................... HANGER;22.8 a(t(;t' Notes:General 84 Safety End Date Annotation 1/29/2007 1/29/2007 NOTE:MULTILATERAL WELL-1J-103(A-SAND),1J-103L1(B-SAND),1J-103L2(D-SAND) NOTE:B-SAND LEM TORN&PULLED©INSIDE HOOK HANGER©6328' 4/16/2008 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT xo Reducing(Tubing);54.5 * 10/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CONDUCTOR Ineclated;28.0-_, • 5/20/2015 NOTE:WAIVER CANCELLATION 108.0 SURFACE;28.0-2,925.0 V GAS LIFT;3,416.6 , a I GAS LIFT;5,817.8 I- it 11 11 80 Enlarging(Tubing);5,872.0 LOCATOR;5,873.7 1111/ SEAL ASSY;5,874.6 PBR;5,861.1 PACKER;5,904.3 00 Reducing(Tubing);5,911.5 III I I NIPPLE;5,958.1 I SHOE;5,969.4 WINDOW D;5,991.0-6,001.0 J. E )� 1 )) g B Liner S-3 Packer;6,118.3- ti 6,179.0 D LINER HH;5,989.3-6,248.7 A B LINER Sbtted;6,328.3- 41 11,584.0... •+ LE WINDOW 8;6,332.0-6,342.0 4'' II Xi B LINER LEM FISH;6,468.7la PRODUCTION;29.8-7,130.0,, 41 SLOTS;7,125.0-7,330.0 .-- SLOTS;7,503.0-8,058.0 _(_i SLOTS;8,230.0-11,220.0 k r SLOTTED LINER A;6,423.8- ' ' 11,259.0 '' KUP OD 1J-103L1 COnOCON1iIIips r Well Attri Max An MD TD AlaBka,lfl0 ' ?n Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Conocohhigips � 500292331860 WEST SAK PROD 95.19 6,821.89 12,444.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Lateral 1J-103L1,12/3/2015234:13 PM 'SSSV: NONE 50 11/8/2014 Last WO: 11/8/2015 -48.71 1/29/2007 Varpcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 4,895.0 3/30/2008 Rev Reason:WORKOVER,GLV CIO lehallf 12/1/2015 Casing Strings HANGER,22.8 :.1 ICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1..Grade Top Thread B LINER Slotted 4 1/2 3.476 6,328.3 11,584.0 3,651.7 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(.) Item Des Com (in) 6,3283 3,666.8 81.95 HANGER 7 5/8 x 4 1/2"Mod B-1 Hook Hanger(inside csg) 4.500 - 6,345.0 3,669.0 82.81 HANGER 7 5/8 x 4 1/2"Mod B-1 Hook Hanger(Outside csg) 4.500 XO Reducing(Tubing);54.5 ir 11,427.1 3,649.2 89.24 PACKER 4 1/2"x 6"Swell Packer 3.960 11,531.8 3,650.5 88.91 PACKER 4 1/2"x 6"Swell Packer 3.960 CONDUCTOR Insulated;28.0._I a 1080 Perforations&Slots shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 6,782.0 11,427.0 3,664.9 3,649.2 WS B,1J- 1/5/2007 32.0 SLOTS ALL PERFS IN WELL: 103L1 Alternating solid/slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3"centers SURFACE;28.0-2,925.0 staggered 18 deg,3'non -slotted ends GAS LIFT;3,4166 t- Notes:General&Safety End Date Annotation 1/29/2007 NOTE:MULTILATERAL WELL-1J-103(A-SAND,1J-103L1(B-SAND),1J-103L2(D-SAND) I1/29/2007 NOTE: B-SAND LEM TORN&PULLED @ INSIDE HOOK HANGER @ 6328' 4/16/2008 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT GAS LIFT;5,817.8 10/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11 5/20/2015 NOTE WAIVER CANCELLATION I it X0 Enlarging(Tubing),5,8720 A LOCATOR,5,873.7 ME SEAL ASSY;5,874.6 PBR;5,881.1 PACKER,5,904.3 .ti 00 Reducing(Tubng);5,911.5 NIPPLE;5,958.1 SHOE;5,969.4 WINDOW D,5,991.0-6,001 0 Eii B Liner 0-3 Packer,6,118.3- rs 6,179.0 D LINER HH,5,989.36,248.7 a- PRODUCTION;29.8-7,130.0 Li =17 SLOTS,6,782.0-11,427.0 B LINER Slotted,6,328./ 11,584.0 KUP PROD • 1J-103L2 ConocoPhillips I Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Bim(ftKB) F�Sa5tca`Inc. CC OCOR/eN3p5 500292331861 WEST SAK PROD 95.94 12,311 73 13,866.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-1J-103L2,12/2/20157:3323 AM SSSV: NONE 50 11/8/2014 Last WO: 11/8/2015 -48.71 1/29/2007 Vetlicel schemaiic(acWelf Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,,,,,m,,,.e...,,,,,,..,..,,,,,m,,,,,,e.,,,,.,,,„,,,,,,,.„,,,n,,,nmm,„a,,...m.Last Tag'CTMD 4,895.0 3/30/2008 Rev Reason:WORKOVER,GLV C/O lehallf 12/1/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 8 D LINER Slotted 41/2 3.476 6,192.8 13,556.2 3,579.5 11.60 L80 BTC HANGER;22.8 Pi...." `W Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top teat(°) Item DBS Com (in) 13 8 6,192.8 3,617.7 92.57 SLEEVE Baker"HR”Liner Setting Sleeve,5 1/2" ID 5.01" 5.750 6,256.7 3,614.9 92.28 XO BUSHING 5-1/2"H521 x 4-1/2"BTC Crossover Bushing ID 3.9 3.930 Perforations&Slots Shot Dens XO Reducing(Tubing);54.5li Top(TVD) Bim(ND) (shototf Top(9KB) atm(9KB) (ftKB) (ftKB) Zone Date t) Type Com 6,301.0 11,414.0 3,613.3 3,572.6 WS D,1J- 1/25/2007 32.0 SLOTS ALL PERFS IN WELL: 103L2 Alternating solid/slotted pipe-0.125"x2.5"@ 4 CONDUCTOR Insulated;28.0-,o • circumferential adjacent 108.0 • rows,3"centers staggered 18 deg,3'non -slotted ends 11,712.0 13,470.0 3,599.5 3,564.5 WS D,1J- 1/25/2007 32.0 SLOTS ALL PERFS IN WELL: 103L2 Alternating solid/slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends Notes:General&Safety End Date Annotation 1/29/2007 NOTE MULTILATERAL WELL-1J-103(A-SAND),1J-103L1(B-SAND),1J-103L2(D-SAND) SURFACE;28.0-2,925.0 4/16/2008 NOTE WELL CONVERTED FROM ESP TO GAS LIFT 10/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 5/20/2015 NOTE:WAIVER CANCELLATION GAS LIFT;3,416.6 I GAS LIFT;5,817.8 (' I I I X0 Enlarging(Tubing);5,872.0 I LOCATOR;5,873.7ill SEAL ASSY;5,874.6 PBR;5,881.1 PACKER;5,904.3 iti I� XO Reducing(Tubing);5,911.5 y sal NIPPLE;5,958.1 1111 SHOE;5,969.4 PRODUCTION;29.8-7,130.0, D LINER HH;5,989 3-6,248.7 s w L 4 SLOTS;6,301.0-11,414.0 SLOTS;11,712.0-13,470.0 D LINER Slotted;6,192.8- A. lk 13,558.2 X06 - 114- Loepp, Victoria T (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Monday, May 25, 2015 4:10 PM To: Loepp, Victoria T(DOA) Cc: NSK Well Integrity Proj Subject: 11-103 (PTD 206-114) Sundry 314-312 Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please cancel the Sundry approval 314-312 for an OA cement shoe.The well is scheduled for a workover and the cement will not be pumped at this time Please let me know if you have any questions. M1 MJ Loveland/Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 SCANNED MAY 2 8 2015 RBDMS i, MAY 2 7 2015 • • 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. ~~ ~ - ~ ~ ~ Well History File Identifier Organ/zing (done) RE AN Golor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria ~,wosa,o iiiuiuiiuiiiuii DIG AL DATA Diskettes, No. 1.~.... ^ Other, No/Type: Date: o Ae=~,~~eedea iuumiwiuum OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ Project Proofing 13Y: Maria ~_ Date: ~~ l ~/~ ~ /s/ ~~ ~ ~' Scanning Preparation ~_ x 30 = ~ + ~_ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ,~i ~ % ~ ~ /s! N ~ Y Production Scanning ~~ Stage ~ Page Count from Scanned File: ~--~ (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: .Maria Date: ~ ~ ~ /sl Stage 1 If NO in stage 1, pages} discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: !s/ Comments about this file: Quality Checked III IIIIII lII IIfI Ill 10!6/2005 Well History File Cover Page.doc If , ,. "Vi f_': c ','., '.. _,.. , :nY e.:_AS.._.a.It.1.s. ,e: "5 +klv..,a3.a_x .lu., ,..i,ii4niai`ASiitiaiWti;,,irr xs,a:.,, •sa. 2_4 Y m... .,,U;k 1ity: „,�,,(„%,tea �J9E SATE 1 'i', :, `r,:S" _: i i; w/ si s<,vcnn A ( nuc ( C rRyoR ct N ," .\.2Y (_? F,nchorcgc Alaska 99501 25/2 MJ Loveland G Well Integrity Project 0 6 lit ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-103 Sundry Number: 314-312 SCANNED JUL 1 6 2014 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P A,3,4 Cathy P. Foerster Chair DATED this day of May, 2014. Encl. EIEIVEL) STATE OF ALASKA MAY 1 3 2014 -, ' 5 AL,..,KA OIL AND GAS CONSERVATION DOM.-SION S 5/Z-2-114— ` • APPLICATION FOR SUNDRY APPROVALS O C 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:OA Cmt Shoe IW 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r. 206-114 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23318-00 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P/ /<Ru.. 1J-103 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025661,ADL0025662 ` Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ff): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11273 . 3774 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108' "'9 108' 2110 520 SURFACE 2897 10.75 2925' 2243' 5210 2480 PRODUCTION 7100 7.625 7130' 3791' 6890 4790 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7125'- 11220' ' 4.5 L-80 5015 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Baker S-3 liner packer&Baker HRD ZXP Liner Top Packer 6157' MD &3640'TVD 6424'MD and 3680'TVD No SSSV No SSSV 12.Attachments: Description Summary of Proposal P• 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r" • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2014 Oil r • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r- GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the bes of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name MJ_oveland / . . Well Integrity Project Supervisor Signature iffAre' .- Phone:659-7043 Date:57V Commission Use Only Sundry Number: 3�2 Conditions of approval: Notify Commission so that a representative may witness ?j�'••�^ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: / d — 4 c LI- / APPROVED BY _ /(/ Approved bye67 -- COMMISSIONER THE COMMISSION Date:S ZZ—[ 7� Approved applisimvocf2 Months from h date of approval. Form 10-403(Revised 10/2012) r/'\`L 443 5/1.3p? Submit Form and Attachments in Duplicate VLF 5721114- �fl RBCMS MAYP2 3 2014.\\�y • a • • ConocoPhiII�ps RECEIVED Alaska MAY P.O. BOX 100360 3 Z014 ANCHORAGE,ALASKA 99510-0360 AOGCC May 9, 2014 Commissioner Foester Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foester: Enclosed please find the 10-403 Sundry from ConocoPhillips Alaska, Inc. for well 1J- 103, PTD 206-114 to pump a surface casing cement shoe. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, M oveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. West Sak Well 1J-103 (PTD 206-114) SUNDRY NOTICE 10-403 REQUEST 05-02-14 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing on West Sak packerless ESP well 1J-103. A surface casing cement shoe was not pumped when the wells was drilled in late 2006. The cement shoe is required in order to perform a pressure test to confirm production casing and surface casing barriers. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. . ,. 2. Displace cement with freeze protection fluids 3. Wait 72 hours on cement 4. MITOA to 1800 psi and/or establish LLR. 5. Submit 10-404 to AOGCC. WI Project Supervisor 5/9/2014 KUP 1J-103 ° • ConocoPhillips - &Weds` .Well Attributes Max Angle&MD TD Alaska.!M. Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(ftKB) i,x,�,,,,,.I,I,• 500292331800 WESTSAK PROD 94.90 8,220.00 11,272.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date •••Well Cag:Multiple Laterals IJ-103,7/18120131 47:54 PM SSSV:NONE 80 8/142012 Last WO: -48.71 1292007 w Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 4,895.0 3/30/2008 Rev Reason:GLV C/O osborl 1/18/2013 HANGER.23 "e: Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 K-55 WELDED Insulated Casing DescriptionString O... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 103/4 9.950 28.0 2,925.0 2,243.4 45.50 L-80 Buttress CONDUCTOR IMF Cuing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String WL..String...String Top Thrd Insulated, 2138 70WINDOW D 8 _ 6.000 5,991.0 6,001.0 _ 3,613.0 29.70 L-80 -106 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW B 8 6.000 6,332.0 6,342.0 3,668.9 29.70 L-80 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 75/8 6.875 29.8 7,130.0 3,790.9 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd B Liner S-3 Packer 6.28 i 5.070 6,118.3 6,179.0 3,644.8 • Liner Details SU2&FACE2,925 R , at. Top Depth h Ink (TVD) Top Incl Nomi... ESP Mandrel MkTop(ftKB) (ftKB) (°) Item Description Comment ID(in) 3,257 - 6,118.3 3,633.9 78.83 SLEEVE C-2 Liner Hanger Setting Sleeve 5.750 Mr Mk 6,125.6 3,635.3 79.02 SBE 197-47 Casing Seal Bore extension 5.070 6,144.4 3,638.5 79.50 XO BUSHING Crossover Bushing 3.980 ESP M 4 reel. 111, 6,157.1 3,640.7 79.83 PACKER Baker S-3 packer 3.875 6,168.4 3,642.8 80.12 NIPPLE Camco DB Nipple 3.562 OM 6,177.7 3,644.5 80.36 WLEG WLEG 3.880 DISCHARGE,_ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String_.String Top Thrd -- 4,674 1111 D LINER HH 4 1/2 3.476 5,989.3 6,248.7 3,656.4 11.60 L-80 4-1/2"BTC MO Liner Details - 'Top Depth. INTAKE,4,953- IIIIM (KD) Top Incl Noml... SEALS,4,963- - , Top(ftKB) (1 Rem Description Comment ID(in) MOTOR.4.977 - IEZ::1 5,989.3 3,611.3 81.32 HANGER Baker Model B-1 Hook Hanger(Inside) 5.600 GAUGE,5,011 -O 6,006.0 3,613.8 80.94 HANGER Baker Model B-1 Hook Hanger(Out side) 3.970 Centralizer, 5.0136,064.5 3,622.4 77.46 ECP External Casing Packer 3.476 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd B LINER LEM FISH 4 1/2 3.860 6,344.5 6,468.7 I 3,687.7 12.60 L80 IBTM-SCC e ria.g00+ M11.er Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) ((KB) (°) Item Description Comment ID(in) 6,344.5 3,669.2 81.80 HANGER LEM(inside hook hanger) 3.688 6,391.3 3,675.9 81.33 NIPPLE DB-6 Nipple 3.563 6,465.4 3,687.2 81.12 SEAL ASSY Seal assembly 3.860 B Liner S-3 Packer, Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(ND)...String Wt...String... String Top Thrd 6.1166.179 SLOTTED LINER A 4 1/2 3.476 6,423.8 11,259.0 3,773.9 11.60 L-80 Buttress D LINER HH, 5.9066.2.9 Liner Details WINDOW B, Top Depth 6,332-6.342 B LINER LEM In (ND) Top Incl Nomi... FISH,-6,469 Top(ftKB) (ftKB) r Item Description Comment ID(in) PRODUCTION. 30-7.130 6,423.8 3,680.9 81.21 PACKER Baker HRD ZXP liner top packer 5.500 7,1 Oa S. IMI 6,442.8 3,683.8 81.17 NIPPLE Packoff Seal Nipple 4.870 ar 7.503.9,956 6,445.5 3,684.2 81.16 HANGER Flex-lock liner hanger 4.750 SLOTS. 8,230-11.220 II 6,452.6 3,685.2 81.15 SBE- Seal bore extension 4.750 SLOTTED LINERA 11,219.9 3,774.5 90.94 XO Reducing CROSSOVER REDUCING 4.5••x3.5'• 3.000 6,424-11.259 TD(1.1-103). Tubing Strings _ 11.272 B LINER Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt..String... String Top Thrd Slned, TUBING 41/2 3.958 22.8 5,015.2 3,311.2 12.60 L-80 IBTM 6,328-111.584 Mk - Completion Details Top Depth (TVD) Top Incl Nomi... I Top(ftKB) (RKB) (1 Rem Description Comment ID(In) 22.8 22.8 -0.06 HANGER VETCO GRAY TUBING HANGER 4.909 4,874.2 3,247.1 62.46 DISCHARGE A-Well Discharge Sub 4,952.8 3,283.2 62.97 INTAKE ESP-Intake I I 4,963.4 3,288.0 63.04 SEALS Tandem Seal Section I I I I 4,977.2 3,293.2 62.08 MOTOR ESP-Motor 11 I 5,011.0 3,309.2 62.37 GAUGE A-Well I Pump Guage 5.013.1 3,310.2 62.39 Centralizer Pump Centralizer 3.958 Perforations&Slots Shot' Top(TVD) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (sh••• Type Comment 7,125.0 7,330.0 3,790.8 3,789.3 WS A1,1J-103 12/28/2006 32.0 SLOTS ALL PERFS IN WELL:Alternating I solid/slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends / 1 - 3 1 1 `- 7,503.0 8,058.0 3,791.4 3,787.0 WS A1,1J-103 12/28/2006 32.0 SLOTS Alternating solid/slotted pipe 8,230.0 11,220.0 3,779.3 3,774.5 WS Al,1J-103 12/28/2006 32.0 SLOTS Alternating solid/slotted pipe I votes:General&Safety e a End Date Annotation arr1/29/2007 NOTE:B-SAND LEM TORN 8 PULLED©INSIDE HOOK HANGER @ 6328' Mandrel Details • --- s,.- Top Depth Top Port -'- - - (TVD) Incl OD Valve Latch Sian TRO Run Stn Top(RKB) (RKB) (°) Make Model lin) Sere Type Type (in) (psi) Run Date Com... J I I l 1 3,257,1 2,417.0 60.01 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 1/3/2013 2 4,294.8 Z953.6 59.18 CAMCO KBMG 1 Gas Lift OV BK-5 0.313 0.0 1/10/2013 oma. KUP 1J-103 ConocoPhillips .w. • Alaska,Inc. a Lark,cal,nl,p'. 613-Ord(it) Rig Rebase Date •••Well Confi9:Multiple Laterals•1J-103,1118/20131:47.54 PM -48.71 1/29/2007 SUamattc-Actual HANGER,23— —"MI. Notes:General&Safety End Date Annotation 1/29/2007 NOTE:MULTILATERAL WELL-1J-103(A-SAND),1J-103L1(B-SAND),1J-103L2(D-SAND) 4/16/2008 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT _ 4/17/2008 NOTE:WAIVERED WELL,TBG X IA COMM,FAILED ESP CONDUCTOR 1�r'' 10/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 Insulated, 28-108 SU28-2,RFACE, An 925 ESP Mandrel, 3,257 1.111 ESP Mandrel. 4.295 DISCHARGE 4 874 g� r� i INTAKE,4,953 1 ---- 5EALS,4,963 MOTOR.4.977 GAUGE,5,011 --1 Centralizer. r Ytr. 5.013 WINDOW D, 5,9916,001 ii' 8 Liner 5-3 Packer, 6,1186,179 D LINER HH, 5,9896,249 ..a WINDOW 8, 6,3326,342 B FILINDUER,TILEIOM PRODUCTION, 30-7,130 SLOTS. 111111 7,125.7.330 7,503SLOTS, SLOTS,OTS, ■ 8.2SLOTED SEED LIN1. 9 TOIIJ 1039 TD(111272 1INER 8 LINER Slotted, 58484 I II V 1 I ter • i �I Ii dir io■■1111111■111=0 oF 7 v s s THE STATE Alaska Oil and Gas ALASKA Conservation Commission wet GOVERNOR SEAN PARNELL 333 West Seventh Avenue ® e- P Anchorage, Alaska 99501 -3572 LASY' Main: 907.279.1433 Fax: 907.276.7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -103 Sundry Number: 313 -229 SEWED MAY 2 9 MI, Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P,/Foerster Chair // DATED this L`C day of May, 2013. End. STATE OF ALASKA F ;� V w � AKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVALS \,4A' 0 , 20'i 20 AAC 25.280 1. Type of Request: Abandon (- Plug for Redrill j " Perforate New Pool r Repair w ell (-' Ch ` o r Suspend (-°' Rug Perforations r Perforate r Pull Tubing j"'" Time Extension F Operational Shutdown f Re -enter Susp. Well f"" Stimulate f - " Alter casing f" !� r'51 Other:MBE MBE T Tre reattmenmen t l;o 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F,. , Exploratory r 206 - 114 3. Address: Stratigraphic f Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23318 - 00 - 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes I — No I✓ 1J - 103 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25661, 25662 Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 11273 ' 3774 - 11266' • 3772' none • 6469' Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 108' 108' SURFACE 2897 10.75 2925' 2243' PRODUCTION 7100 7.625 7130' 3790' LINER 4836 4.5 11260' 3772' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7125' - 7330', 7503' - 8058', 8230' - 11220' 3791' 3789', 3791' 3787', 3779' - 3775' 4.5 L - 80 5015 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HRD ZXP LINER TOP PACKER • MD =6424 TVD =3681 no SSSV 12. Attachments: Description Sunmary of Proposal fi 13. Well Class after proposed work: Detailed Operations Program f BOP Sketch F Exploratory E Stratigraphic E Development W. . Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil F , Gas E WDSPL r Suspended 1 16. Verbal Approval: Date: WINJ F GINJ F WAG [ Abandoned F Commission Representative: GSTOR F SPLUG f"" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John.W.Peirce @cop.com Printed Name John Peirce Title: Wells Engineer Signature 7 • , - Phone: 265 -6471 Date ,S77/1. 3 Commission Use Only Sundry Number: .3o zrzq Conditions of approval: Notify Commission so that a representative may witness 11JJ Plug Integrity F BOP Test F Mechanical Integrity Test F" - Location Clearance F Other: `\ RBDMS MAY 2 8 20'3 Spacing Exception Required? Yes ❑ No (Y Subsequent Form Required: r (' — 4— 4 i / .1 / APPROVED BY r.. Approved by:L;"\." _..? / , roVC[ra application is va0S1 the from th l 5R8 l3ORval. Date: 5 - Z 4--' ( -' Form 10 -403 (Revise 10/2012) J5-4.2 3/13 Submit Form and Attachments in Duplicate �` \0\ r144- n R I G I NAL m vrTS << �� . S • 1J -105L1 to 1J -103L1 'B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 4 -5 -12 in 1J -105L1 in the B sand lateral. A 5 -26 -12 IPROF saw the B MBE at 9550' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -25 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within a few months that resulted in shut -in of PWI to 1J -105. A 3 -24 -13 (PROF in 1J -105L1 confirmed the B MBE at —9550' RKB Crystal Sealed 9 -25 -12 was once again open taking all PWI. The 1J-105L2 D lateral was isolated with an Iso -Sly on 5 -23 -12 (for 9 -25 -12 B MBE Crystal Seal treatment), and the D Iso - Sleeve remains set. 1J -105 is configured to perform a 1J -105L1 B MBE Crystal Seal retreatment. The B Diverter remains set. It is proposed that 1J -105L1 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1J -105L1 for a retreatment. Large hole perforations already exist in 1J -105L1 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1J -105L1 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9540 - 9545' RKB in the 4.5" slotted liner just above the MBE at 9550' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w /0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to pumping Diesel FP down coil, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1J-105L1 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post job PWI and offset producer responses. KUP • 1J -103 Conoc 01 Well Attributes Max Angle & MD TD Alaska ktC Wel!bore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292331800 WEST SAK PROD 94.90 8,220.00 11272.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NONE 80 8/14/2012 Last WO: - 4871 1/29/2007 Well Con6q' Multiple Laterals - 1J-103,1,18 1 41 54 PM Schematic - Actual _ Annotation Depth (ftKB) End Date Annotation Last Mod By End Date ) r _ _ _ _ _ _,. _ riik Last Tag: CTMD 4,895.0 3/30/2008 Rev Reason: GLV C/O osborl 1/18/2013 HANGER, 23 t Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 K -55 WELDED Insulated Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd S __...� SURFACE 103/4 9.950 28.0 2,925.0 2,243.4 45.50 L -80 Buttress CONDUCTOR a_. -___ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd In 28 8-108 -108 WINDOW D 8 6.000 5,991.0 6,001.0 3,613.0 29.70 L -80 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW B 8 6.000 6,332.0 6,342.0 3,668.9 29.70 L -80 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 75/8 6.875 29.8 7,130.0 3,790.9 29.70 L - 80 BTCM �' Casing Description String 0... String ID _. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B Liner S - 3 Packer 6.28 5.070 6,118.3 6,179.0 3,644.8 r Liner Details SURFACE, _ 'Top Depth 28 2,925 (ND) Top Intl Nomi... ESP Mandrel, Top (ftKB) (ftKB) (°) Rem Description Comment ID (In) 3,257_ 6,118.3 3,633.9 78.83 SLEEVE C-2 Liner Hanger Setting Sleeve 5.750 NM 6,125.6 3,635.3 79.02 SBE 197-47 Casing Seal Bore extension 5.070 6,144.4 3,638.5 79.50 XO BUSHING Crossover Bushing 3.980 ESP Ma4295 6,157.1 3,640.7 79.83 PACKER Baker S-3 packer 3.875 i 6,168.4 3,642.8 80.12 NIPPLE Camco DB Nipple 1562 6,177.7 3,644.5 80.36 WLEG WLEG 3.880 DISCHARGE, 4,874 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D LINER HH 4 1/2 3.476 5,989.3 6,248.7 3,656.4 11.60 L -80 4 -1/7' BTC MI Liner Details Top Depth INTAKE, 4,953 -� (TVD) Top Inc! Nomi... SEALS, 4,953 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) MOTOR. 4,977 +r 5,989.3 3,611.3 81.32 HANGER Baker Model B -1 Hook Hanger (Inside) 5.600 GAUGE, 5,011 N...., 6,006.0 3,613.8 80.94 HANGER Baker Model B -1 Hook Hanger(Out side) 3.970 Centralizer, 5,013 I ' 6,064.5 3,622.4 77 .4 91/ 6 ECP External Casing Packer 3.476 Casing Descriptlon Stri 0... String !D ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 6,344.5 3,669.2 81.80 HANGER LEM (inside hook hanger) B LINER LEM FISH 4 2 3.860 6,344.5 6,468.7 3,687.7 12.60 L80 IBTM -SCC WINDOW O, 5,9918,001 Liner. Details I Top Depth (ND) Top Intl Nomi... Top (ftKB) (ftKB( P) Item Description Comment ID (in) 3.688 6,391.3 3,675.9 81.33 NIPPLE DB -6 Nipple 3.563 6,465.4 3,687.2 81.12 SEAL ASSY Seal assembly 3.860 8 Liner S -3 Packer, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd 6,1188,179 SLOTTED LINER A 4 1/2 3.476 6,423.8 11,259.0 3,773.9 11.60 L - 80 Buttress D LINER NH, 5,9898,249 Liner Details WINDOW B, Top Depth 8,3328,342 B LINER LEM (ND) Top Inc' Noml... FISH, -8,469 Top (ftKB) (ftKB) ( °) Item Description Comment ID (I ^) PRODUCTION, - 30-77,130 130 6,423.8 3,680.9 81.21 PACKER Baker HRD ZXP liner top packer 5.500 SLOTS, 6 3,683.8 81.17 NIPPLE Pkoff Seal Nipple 4.870 7,125-7,330 7,50 6,445.5 3,684.2 81.16 HANGER Flex -lock liner hanger 4.750 SLOTS, 8,230- 11.220 1 ■ ac PP 6,452.6 3,685.2 81.15 SBE Seal bore extension 4.750 SLOTTED LINER 11,219.9 3,774.5 90.94 XO Reducing CROSSOVER REDUCING 4.5 "x3.5" 3.000 8,424 - 11.259 TO (1J-103), Tubing Strings 11.272 Tubin 9 Description String 0... String R B LINER t Depth String Wt... String String To Thrd P 9 ID ... To P( (ftKB) Set Depth P (f... Set De P (TVD) 9 9 9 P Slotted, TUBING 41/2 3.958 22.8 5,015.2 3,311.2 12.60 L - 80 IBTM 8,328 - 11.584 : . Completion Details Top Depth (TVD) Top Inc! Noml... Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 22.8 22.8 -0.06 HANGER VETCO GRAY TUBING HANGER 4.909 4,874.2 3,247.1 62.46 DISCHARGE A -Well Discharge Sub 4,952.8 3,283.2 62.97 INTAKE ESP - Intake 4,963.4 3,288.0 63.04 SEALS Tandem Seal Section I i 4,977.2 3,293.2 62.08 MOTOR ESP - Motor 5,011.0 3,309.2 62.37 GAUGE A -Well I Pump Guage 5,013.1 3,310.2 62.39 Centralizer Pump Centralizer 3.958 Perforations & Slots I. Shot Top (WO) Btm (TVD) Dens OMB) Top (ftKB) B t m () (ftKB) (ftKB) Zone Date (sh... Type Comment 7,125.0 7,330.0 3,790.8 3,789.3 WS A1, 1J -103 12/28/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 1 1 - 1 1 7,503.0 8,058.0 3,791.4 3,787.0 WS Al, 1J -103 12/28/2006 32.0 SLOTS Alternating solid/slotted pipe Imo_ I I 8,230.0 11 220.0 3,779.3 3,774.5 WS Al, 1J -103 12/28/2006 32.0 SLOTS Alternating solid /slotted pipe Notes: General & Safety ' • • End Date Annotation - - -- 1/29/2007 NOTE: B -SAND LEM TORN & PULLED @ INSIDE HOOK HANGER @ 6328' o a Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) P1 Make Model (in) Sera Type Type (in) (psi) Run Date Com... . J I I l 1 3,257.1 2,417.0 60.01 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 1/3/2013 2 4,294.8 2,953.6 59.18 CAMCO KBMG 1 Gas Lift OV BK -5 0.313 0.0 1/10/2013 a KUP • 1J -103 • Conoc i Alaska, in, °Y° KB -Grd (ft) Rig Release Date "' - 48.71 1/29/2007 Well Coring'. Multiple Laterals - 14-103 1; 2013 1'47 54 PM Schematic - Actual HANGER 23 Notes: General & Safety End Date Annotation 1/29/2007 NOTE: MULTILATERAL WELL- 1J -103 (A- SAND), 1J -103L1 (B- SAND), 1J -103L2 (D -SAND) 4/16/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 4/17/2008 NOTE: WAIVERED WELL, TBG X IA COMM, FAILED ESP CONDUCTOR _. - .._ - 10/14/2008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 Insulated. 28 -108 o SURFACE, 28 -2.925 MEI ESP Mandrel, 3.257 F . ESP Mandrel, 4,295 DISCHARGE, 4,874 IIIIIII INTAKE. 4.953 - -- I SEALS. 4.963 - 4, - ---. I MOTOR. 4.977 ��� GAUGE, 5,011 asj Centralizer, • 5,013 - WINDOW D, 5,991 -6,001 B Liner S -31 r Packer. -� I3D 6,118.8,179 D LINER 2H, 5,989-6,249 OW S, 642 I B LINE- NER LEM LEM FISH, -6,469 P Ill RODUCTION, , 30 -7,130 SLOTS, MI 7,125 -7,330 SLOTS, IIE 7,503-8,058 LOTS, SLOTS, 8,230.11,220 III SLOT ED SLOTTED il LINER A, 6,424- 11,259 TD (1J-103), 11,272 B LINER Slotted, - 13,328- 11,584 I I( I I 1 If I I l ia r T r ' ~'.}, ~~ ~' ~~ ~ x ~: ~ ~ .~~. { ~ " F ~ r '=~ T ~ ~..~~ • y y~ .~S 1 ru ~b MICROFILMED 6/30/2010 DO NOT PLACE. ANY N EW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061140 Well Name/No. KUPARUK RIV U WSAK 1J-103 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23318-00-00 MD 11272 TVD 3773 Completion Date 1/29/2007 REQUIRED INFORMATION Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name _ . - D D Asc -- - - Directional Survey ',IJ~D D Asc Directional Survey ',~D D Asc Directional Survey D Asc Directional Survey •~D C Lis 15051 Induction/Resistivity ~~f pf 15051 LIS Verification ~cF.~- C Lis 15052 Induction/Resistivity 'Rpt 15052 LIS Verification !~'D C Lis 15053 Induction/Resistivity ' ~ 15053 LIS V ifi ti , er ca on ', ~B' C Lis 15054 Induction/Resistivity R t 15054 LIS Verificatio p n Well Cores/Sampl es Information: Name Completion Status 1-OIL Samples No Current Status 1-OIL UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 10443 11272 Open 3/27/2007 0 8529 Open 3/27/2007 PB 1 8002 8443 Open 3/27/2007 PB 2 8196 10668 Open 3/27!2007 PB 3 2889 11272 Open 4/20/2007 LIS Veri, GR, ROP, FET 2889 11272 Open 4/20/2007 LIS Veri, GR, ROP, FET 2889 8528 Open 4/20/2007 PB1 LIS Veri GR, FET, ROP 2889 8528 Open 4/20/2007 P61 LIS Veri GR, FET, ROP 2889 8443 Open 4/20!2007 PB2 LIS Veri GR, FET, ROP 2889 8443 Open 4/20/2007 PB2 LIS Veri GR, FET, ROP 2889 10667 Open 4/20/2007 PB3 LIS Veri GR, FET, ROP 2889 10667 Open 4/20/2007 P63 LIS Veri GR, FET, ROP Sample Interval Set Start Stop Sent Received Number Comments ;~. DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061140 Well Name/No. KUPARUK RIV U WSAK 1J-103 Operator CONOCOPHILLIPS ALASKA INC MD 11272 TVD 3773 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~f~` Analysis ~~'IV' Received? Completion Date 1/29/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23318-00-00 UIC N Comments: Compliance Reviewed By: __ __ Daily History Received? ~N Formation Tops ~•~- N Date: WELL L®G TRANSMITTAL To: State of Alaska December 5, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite I00 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-103+L1+L1PB1+L2+PB1+PB2+PB3 AK-MW-4725792 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-103+L 1+L 1 PB 1+L2+PB 1+PB2+PB3 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 318-00,60, 61, 70, 71, 72, 73 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23318-00,61 Digital Log Images 1 CD Rom 50-029-23318-00,60,61,70,71,72,73 L1, L1PB1, PBl, PB2, AND PB3 HAVE NO TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907-273-3536 (Orya,~. by i~ada® Ina,ft~~vr~'`-~ ~}~ //Gj ~ 1 ~~ Date: Signed: jc~ ~ `Z ~' ab~"1f5~" l 3"~ 1 ~-3C~ ~~ ~~~ ~t ~- 3o~-t • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~~ 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 if needed 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 August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor i • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 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 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5!2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1 J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1 J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9!6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 i ,~ E~EIVE® STATE OF ALASKA APR 2 2 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO`a OiI & Gas Cons. Commission ~. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ ESP to GL Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development^ Exploratory ^ 206-114 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23318-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 110' 1J-103 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11273' feet true vertical 3774' feet Plugs (measured) Effective Depth measured 11266' feet Junk (measured) true vertical 3774' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2815' 10-3/4" 2925' 2243' PRODUCTION 7020' 7-5/8" 7130' 3791' D-SAND WINDOI 1' 7-5/8" 5992' 3612' e-SAND WINDOI 1' 7-5/8" 6333' 3667' B-SAND LINER TOP 213' 4-1/2" 6332' 3667' Perforation depth: Measured depth: 7125'-7330', 7503'-8058', 8230'-11220' true vertical depth: 3791'-3789', 3792'-3787', 3779'-3775' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5015' MD. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) `'r~~.~~ ~ ~~N~ ,~ ~ LQO~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 515 115 19 212 188 Subsequent to operation 253 61 8 673 194 14. Attachments 15. Wel! Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~~ ~ /~ ~/' f~ Phone 659-7535 Date ,L/~ ~ /~ 7 l Form 10-404 Revised 04/2004 ~ ~ ~ A ~,,,,, ~ ~l ~3 ~ ( O~ Submit Original Only i ~ 1 J-103 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/17/08 Well Returned to production as a gas lifted oil producer 04/16/08 Pulled 48' 3" TTC ESP from 4900' RKB. i ~ >~~. ~ KRU on~~t~~'hill~~s A1~~k~,n~~ 1 J-103 _ 1 J-10_3_ -- - . API: 500292331800 Well T e: PROD An le TS: de .~ ~ SSSV Type: NONE Orig 1/29/2007 Angle @ TD: 91 deg @ 11273 ~ ~ - Com letion: ~~ Annular Fluid: Last W/O: Rev Reason: C/O SOV Reference L : 29.81' RKB Ref Lo Date: Last U ate: 11/5/2007 ~, Last Ta TD: 11273 ftKB Last Tag Date: Max Hole Angle: 95 deg cr 8221 x Casing String -COMMON STRINGS - Descn lion Size To Bottom TVD 111It Gratle Threatl CONDUCTOR 20.000 0 108 108 94.00 H-40 WELD "'+' SURFACE 10.750 0 2925 2243 45.50 L-80 BTC ;, PRODUCTION 7.625 0 .7130 3790 29.70 L-80 BTC-M ,,; D-SAND WINDOW 7.625 5991 5992 3611 0.00 B-SAND LINER TOP 4.500 6119 6332 3667 11.60 L-80 BTC xo wTaKE B-SAND WINDOW 7.625 6332 6333 3668 0 00 (4953963, OD:5.130) ~ A-SAND SLOTTED LINER 4.500 - f+424 11260 3774 . 11.60 L-80 BTC Tubing String -TUBING SEAL (49634977, ' Size Top Bottom TVG Wt Grade Thread OD:5.130) ~ 4.500 0 5015 3311 12.60 L-80 16TM-SCC Moron ~-.. .Perforations Summary (as775o11, oD 5s2o . -~"~= Interval TVD Zone Status Ft SPF Date T e Comment : ) -~,, ~ 7125 - 7330 3790 - 3790 WS A2 205 32 12/28/2006 Slots Alternatin slotted/solid i r~-_ 7503 - 8058 3792 - 3787 WS A2 555 32 12/28/2006 Slots e Alternatin slotted/solid i e 8230 - 11220 3779 - 3774 WS A2 2990 32 12/28/2006 Slots Alternating sl©tted/solid pipe G_ as Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 3257 2416 CAMCO KBMG SOV 1.0 BK 0.000 0 0/19/200 2 4295 2954 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/28/2007 _ - Other (plugs, equip., etc.) -COMPLETION ' : Oe th TVD T e Descn ion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 - 4874 3247 Discharge A-WELL DISCHARGE SUB 0.000 Sub 4900 3259 PUMP ESP PUMP, PACKOFF ASSEMBLY & TBG LOCK set 1/29/2007 0.000 4953 3283 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 4963 3288 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA 0.000 4977 3294 MOTOR 418 HP KMHFER 2610 / 98 0.000 5011 3310 Pump A-WELL 1 PUMP GAUGE 0.000 __ ., Gau e 5013 3311 Centralizer MOTOR CENTALIZER 0.000 1 ~ 5989 3611 HANGER D-SAND BAKER MOD 61 FHH INSIDE CASING 4.020 BSAND LINER TOP (6119-6332, OD:4.500, Wt:11.60) PACKER (64245443, OD:6.540) NIP (64435445, OD:6.070) HANGER (6445&453, OD:6.590) SBE (64535472, OD:6.290) 6145 3638 SBE B-SAND 197-47 CASING SEAL I 6146 3639 XO Bushing B-SAND CROSSOVER BUSHIN 6158 3641 PACKER B-SAND BAKER S-3 PRODUCT B-SAND LEM, RESET PACKER' 6169 3643 NIP B-SAND CAMCO DB NIPPLE _ 6178 3644 WLEG B-SAND WIRELINE GUIDE e 6329 ther 4 (lonth i 3667 plu~c s, Tm i HANGER equip., etc T...,o . B-SAND BAKER MOD B1 FHH .) - A-SAND LINER DETAIL . FI Perf ~ - (6230-11220) ~ 1 PACKER **PULLED TO REMOVE ~ 4.500 6424 3681 PACKER A-SAND LINER BAKER HRD ZXP LINER TOP PACKER 4.970 6443 3684 NIP A-SAND LINER'RS' PACKOFF SEAL NIPPLE 4.870 6445 3684 HANGER A-SAND LINER FLEX-LOCK LINER HANGER 4.850 6453 3685 SBE A-SAND LINER 190-47 SEAL BORE EXTENSION 4.750 6472 3688 XO A-SAND LINER CROSSOVER 5.5" x 4.5" 3.940 11220 3774 XO A-SAND LINER CROSSOVER 4.5" x 3.5" 3.000 _ ~,r rv ~ n-JMIV V LIIVCR JILV CR ~ULLC I Jrll.lt I Z.yy1 I general Notes Date Note /29/2007 NOTE: B-SAND LEM TORN &PULLED INSIDE HOOK HANGER 6328' /29/2007 NOTE: MULTILATERAL WELL- 1J-103 /A-SANDI. 1.1-1031 1 rR-saNrn 1.1_in31 ~ m_cnrun~ CPAI KRU 1J-103 (PTD-206-1 l4j Report Of Failed ESP ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 3:20 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj; NSK West Sak Prod Engr; NSK Prod Engr Tech; Regg, James B (DOA) Subject: RE: CPAI KRU 1J-103 (PTD-206-114) Report Of Failed ESP Brent, Sorry for the delay. No 403 is needed. However, please submit the 404. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conornphillips.com] Sent: Thursday, Apri103, 2008 4:10 PM To: Maunder, Thomas E (DOA) Cc: NSK Well integrity Proj; NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prat Engr Tech; Regg, James B (DOA) Subject: CPAI KRU 1J-103 (PTD-206-114) Report Of Failed ESP importance: High Tom, The electric submersible pump (ESP) in the 1J-103 well (PTD-206-114} failed on 03/31!08 due to being grounded downhole. This well was completed in January of 2007 and does not mention gaslift as a contingency in the Permit To Drill. CPAI requests permission to convert the 1J-103 to gaslift until a workover to replace the pump and motor can be performed. If approved, please confirm that a 10-404 after work is completed is sufficient. Martin Walters / Brent Rogers Problem Weils Supervisor ConocoPhilfips Alaska Inc. Office 907-659-7224 Cell 907-943-172011999 Pager 907-659-7000 #909 4/i 4/2008 WELL LOG TRANSMITTAL To: State of Alaska April 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-103, PBI, PB2, PB3, Ll PB1, Ll & L2, AK-MW-4725877 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23318-00, 70, 71, 72, 73, 60 & 61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURivING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date'~~~ ~ ~ ~~~~ ~,~ , Signed: ~Ofo ' l l~ ~ t5 °s~ ~ 15(7$c7 t5os3 ~p(o~tt5 ~ ~5'd55 y ~$Ub'~ ~~-(!(0 1 j O~~ # ~ s p~S`~ • 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-103 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,443.32' MD Window /Kickoff Survey 10,455.00' MD (if applicable) Projected Survey: 11,272.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date / A'`I-~. ~d'1 ~ Signed O Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao~ - i~~ 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-103 Pd 1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,528.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ oZA~~ Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-103PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,002.10' MD Window /Kickoff Survey 8,045.00' MD (if applicable) Projected Survey: 8,443.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date_,~, < l "iNt X07 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 2o~-iry i • 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-103P63 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,196.13' MD Window /Kickoff Survey 8,220.00' MD (if applicable) Projected Survey: 10,667.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 D I 'I~LG~.V`~ 7 S' a ate igned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao t, - t ~Y Randy Thomas Kuparuk Drilling Team Leader ~ EC E I VE D Drilling & Wells ConocoPhillips MAR 0 5 2007 Alaska Oii & Gas Cons. Commission Anchorage P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 1, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-103, 1 J-103L1, 1 J-103L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-103, 1J-103L1, 1J- 103L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, .d.,,_. ... R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION tl~CEIVED MAt7 0 5 2007 WELL COMPLETION OR RECOMPLETION REPO~~~AI~GbsL~O~ommission 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: 11C 0(8~C Development Q Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 29, 2007 ~ 12. Permit to Drill Number: 206-114 ! 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 12, 2006 ~ 13. API Number: 50-029-23318-00 4a. Location of Well (Governmental Section): Surface: 2225' FSL, 2441' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: / December 27, 2006 14. Well Name and Number: 1J-103 At Top Productive Horizon: 1235' FSL, 699' FWL, Sec. 36, T11 N, R10E, UM 8. KB Elevation (ft): /~,? ~~ f ~, a 30' RKB ~'~L. 15. FieldlPool(s): Kuparuk River Field Total Depth: 2943' FNL, 677' FWL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 11266' MD ! 3772' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 ` y- 5946037' Zone- 4 10. Total Depth (MD + TVD): i 11272' MD / 3773' TVD ~ 16. Property Designation: ADL 25661 & 25662° TPI: x- 561915 y- 5945072 Zone- 4 Total Depth: x- 561929 - 5940894 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REC RD PULLED 20" x 34" 62.6# H-40 30' 108' 30' 108' 42" 40o sx AS 1 10.75" 45.5# L-80 30' 2925' 30' 2243' 13.5" 545 sx AS Lite, 177 sx DeepCRETE 7-5/8" 29.7# L-80 30' 7130' 30' 3790' 9-7/8" 418 sx Class G 4.5" 11.6# L-80 6424' 11260' 3681' 3772' 6.75" slotted liner 23. Pertorations 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" 5015' none slotted liner from 11220'-8232', 8058'-7503', 7330'-7125' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) Oil Producer -shares production with 1 J-103L1 and 1 J-103L2 i Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APt (corr) 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". ~;t~ NONE ; .._..~_ZT'C~ ,: ~, t ___ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ 3`~1+~0'7 a~ 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 J-103 Top Kuparuk A2 7090' 3787' 1J-103PB1 TD ~ 8528' 3798' N/A 1 J-103P62 TD 8443' 3766' 1J-103PB3 TD 10667' 3764' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Na Rand Thomas Title: Greater Kuparuk Area Drillino Team Leader _ _... ~~ r Signature ~ ~~'~---y----Phone - ~ ~ Date ~~ Z.r/S` C~'.~u 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 ---~~ '~ KRU 1 J-103 C~rnc~~~a~t~;illips ~-iaska~, ~r~c~ .. ~1 J_--___103 __ API: 5tiu[82331tsuu Well T e: PRUG An le m Ts: de a SSSV T e: NONE Ori Com letion: 1/29/2007 An le TD: 91 de 11272 Annular Fluid: Last W/O: Rev Reason: NEW WELL ~, Reference Lo : 29.81' RKB Ref Lo Date: Last U date: 2/22!2007 Last Ta TD: 11272 ftKB Last Tag Date' Max HoIP Anr,la~ 95 deq n R220 Casin Strin -COMMON STRINGS _ Descri lion Size To Bottom ND _ Wi Grade Thread CONDUCTOR 20.000 0 108 108 94.00 H-40 WELD SURFACE 10.750 0 2925 2243 45.50 L-80 BTC PRODUCTION 7.625 0 7130 3790 29.70 L-80 BTC-M D-SAND WINDOW 7.625 5991 5992 3611 0.00 B-SAND LINER TOP 4.500 6119 6332 3667 11.60 L-80 BTC B-SAND WINDOW 7.625 6332 6333 3667 0.00 A-SAND SLOTTED LINER 4.500 6424 11260 3773 11:60 L-80 BTC UbIn9 rlrt~ -TUB XOtNTAKE (4953-0963 ~ 1 g _ TOp Bottom ~ TVD Wt Gratle ETh;ead , O 11 l_ PerfOrat10n5 SUnlrna SEAL (4963-4977, Interval TVD Zone Status Ft SPF Date T Comment OD:5.130) 7125 - 7330 3790 - 3789 WS A2 205 32 12/28/2006 Slots Alternatin slotted/solid i e MOTOR 7503 - 8058 3791 - 3786 WS A2 555 32 12/28!2006 Slots Alternatin slotted/solid i e (49775011, „_ ~ ' 8230 - 11220 3779 - 3774 WS A2 2Q90 32 12/2R/20(16 Slog Alternating clntt?d/cnlid PiP° oD:SSZO> Gas Lift MandrelsNa(ve s '„'~~ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3257 2416 CAMCO KBMG SOV 1.0 BK-5 0.000 0 1/28/2007 2._, ___4295 2953 CAMCO KBMG - - - DMY 1.0 RK-5 0.000 0 1/2R/2007 Other lu s e ui ., etc.) -COMPLETION De th TVD T e Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 4874 3247 Discharge A-WELL DISCHARGE SUB 0.000 Sub 4900 3259 PUMP ESP PUMP PACKOFF ASSEMBLY & TBG LOCK set 1/29/2007 0.000 4953 3283 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 4963 3287 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA 0.000 4977 3294 MOTOR 418 HP KMHFER 2610 / 98 0.000 5011 3309 Pum Gau a A-WELL 1 PUMP GAUGE 0.000 5013 3310 Centralizer MOTOR CENTALIZER 0.000 5989 3610 HANGER D-SAND BAKER MOD B1 FHH INSIDE CASING 4.020 6119 3633 SLEEVE B-SAND C-2 LINER HANGER SETTING SLEEVE 5.070 6145 3638 SBE B-SAND 197-47 CASING SEAL BORE EXTENSION 4.750 6146 3638 XO Bushin B-SAND CROSSOVER BUSHING 3.830 6158 3640 PACKER B-SAND BAKER S-3 PRODUCTION PACKER "'PULLED TOREMOVE B-SAND 4.500 LEM, RESET PACKER*" 6169 3642 NIP B-SAND CAMCO DB NIPPLE 3.562 6178 3644 WLEG B-SAND WIRELINE GUIDE 3.958 6329 3666 _. - HANGER .__ _ B-SAND BAKER MOD 61 FHH~SIDE CASINGI 4.020 , Other iu s e ui .etc.) - A-SAND i_INER DETAIL De h TVD T e Descri lion ID 6424 3680 PACKER BAKER HRD ZXP LINER TOP PACKER 4.970 6443 3683 NIP 'RS' PACKOFF SEAL NIPPLE 4.870 BSAND 6445 3684 HANGER FLEX-LOCK LINER HANGER 4.850 LINER TOP 6119332 6453 3685 SBE 190-47 SEAL BORE EXTENSION 4.750 ( , OD:4 500 6472 3688 XO CROSSOVER 5.5" x 4.5" 3:940 . , Wt:11.60) 11220 3774 XO CROSSOVER 4.5" x 3.5" 3.000 11259 3773 ~_ HOE SILVER Bl ILLET SHOE 2 992 Gener al Notes Date Note PACKER 1/29/2007 NOTE: B-SAND LEM TORN & PULLED INSIDE HOOK HANGER 6328' (6424-6443, 1/29!2007 NOTE: MULTILATERAL WELL- 1J-103 A-SAND 1J-103L1 B-SAND , 1J-103L2 D-SAND OD:6.540) NIP (6443445, OD:6.070) HANGER -- (6445-6453, OD:6.590) SBE (6453-6472, OD:6.290) Pert (8230.11220) a Ca sing Detail Report 1 J-103 s: • s' s. A-Lat Liner -- Casi~ - _ __ ---- _ _ _ _ Casing Description Set Depth (ftKB) Run Date Set Tension (kips) A-Lat Liner 11,262.0 12/29/2006 Centralizers Scratchers Casi~Components r _ _ ~ Mk-up Tp Item Description ~ OD (in) Wt (Ibs/ft) (,rade - Top Thread Jts Lin (ft) Top (ftKB) Btm (ftKe) ', (ft-Ibs) '. Class Max OD ~in~ '~ ID (In) Baker HRD ZXP liner - - - 19.02 626.4 645.4 top packer Packoff Seal Nipple 6.07 2.76 645.4 648.2 4.870 Flex-lock liner hanger 6.29 7.01 648.2 655.2 4.750 Seal bore extension 6.29 19.80 655.2 675.0 4.750 Cross Over 5.99 Hydril 563 1.44 675.0 676.4 3.940 Liner Pup Joint 4 1/2 12.60 L-80 Buttress 5.47 676.4 681.9 4.000 Thread Casing Joints 4 1/2 11.60 L-80 Buttress 5 6,445.66 681.9 7,127.6 4.000 Thread Slotted Liner 4 1/2 11.60 L-80 Buttress 5 204.97 7,127.6 7,332.5 4.000 Thread Casing Joints 4 1/2 11.60 L-80 Buttress 4 172.57 7,332.5 7,505.1 4.000 Thread Slotted Liner 4 1/2 11.60 L-80 Buttress 13 555.74 7,505.1 8,060.8 4.000 Thread Casing Joints 4 1/2 11.60 L-80 Buttress 4 171.51 8,060.8 8,232.4 4.000 Thread Slotted Liner 4 1/2 11.60 L-80 Buttress 70 2,990.54 8,232.4 11,222.9 4.000 Thread Cross Over 5 Buttress 1.45 11,222.9 11,224.3 3.000 Thread Cross Over 3 1/2 9.20 L-80 IBT 5.90 11,224.3 11,230.2 2.992 Casing Joints 3 1/2 9.20 L-80 8RD EUE 1 31.14 11,230.2 11,261.4 2.992 Guide Shoe 5 8RD EUE 0.62 11,261.4 11,262.0 Page 111 Report Printed: 2/28/2007 Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Datc: 2/71200 % ___ Timc: 14:32:57 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-103, Tr ue North Site: Kuparuk 1J Pad Vertical ('fVD) Re ference: 1J-103: 1D9:7 Well: 1J-103 Section (VS) Refer ence: Well (O.OON,O.OOE,180.OOi~z'p ~y'cllpath: 1J-103 Survey Cakolatiou Method: Minimum Curvature nh: Oracle Field: Kuparuk River Unit - - __ North Slope Alaska ~ United States I Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-103 Slot Name: WeII Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N i +E/-W -22.57 ft Easti ng : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft Wellpath: 1J-103 Drilled From: 1J-103PB3 500292331800 Tie-on Depth: 10443.32 ft Current Datum: 1 J-103: ~ Height 109.70 ft Above System Datum; Mean Sea Level ~ Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angl e: 80.81 deg Vertical Sectio Depth From (TVD) +N/-S +E/-W Direction n ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 2/7/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft i 50.70 632.70 1J-103P61 gyro (50 .70-632.70) CB-GYRO-SS Camera based gyro sin gle shot 662.65 8002.10 1J-103P61 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8045.70 8196.13 1J-103PB2 (8045.70-8389.99) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8220.70 10443.32 1J-103P63 (8220.70-10624.08) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10455.70 11229.23 1J-103 (10455.70-11229.23) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C _~ Survey ---_ - bID Incl Azim TVD Sys TVU V/S E/W ~lapiti ~lapt Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.70 0.00 0.00 5946037.60 558766.46 TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS ~ 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS I 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS I 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS ~ 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC ~ 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC ' 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company-: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 14:32:57 Pa~;c: 3 Field: Kuparu k River lJnit Co-or diuate (NE) Reference: Well: 1 J-10 3, Tr ue Nolth Site: Ku paru k 1J Pad Vertical (TVD)Reference: 1J-103: 109.7 Nell: 1J -103 Sectio n (VS)Reference: ' Well (O.OON,O.OOE,180.OOAzi) W'ellpath: 1J -103 Survey Calc ulatio n Method: Minimum C urva ture Db: Oracle Survey --_ - _ - - - MD L~c l Azim TVD Sys TV D N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 1847 .57 50 .10 34. 66 1657. 03 1547. 33 517. 74 321. 58 5946557 .78 559083 .96 MWD+IFR-AK-CAZ-SC ~ 1905 .12 50 .63 35. 76 1693. 74 1584. 04 553. 95 347. 13 5946594 .19 559109 .23 MWD+IFR-AK-CAZ-SC ~ 1936 .93 51 .49 36. 82 1713. 74 1604. 04 573. 89 361. 78 5946614 .24 559123 .71 MWD+IFR-AK-CAZ-SC 2000 .86 51 .87 39. 61 1753. 38 1643. 68 613. 29 392. 80 5946653 .88 559154 .43 MWD+IFR-AK-CAZ-SC 2093 .95 53. 72 45. 46 1809. 70 1700. 00 667. 85 442. 92 5946708. 82 559204. 11 MWD+IFR-AK-CAZ-SC 2191 .18 56 .62 51. 14 1865. 26 1755. 56 720. 85 502. 51 5946762. 28 559263. 28 MWD+IFR-AK-CAZ-SC 2284 .31 58 .44 55. 15 1915. 27 1805. 57 767. 94 565. 37 5946809 .85 559325. 77 MWD+IFR-AK-CAZ-SC 2380 .32 59 .72 60. 12 1964. 62 1854. 92 811. 99 634. 92 5946854 .44 559394. 97 MWD+IFR-AK-CAZ-SC 2419 .46 59 .50 61. 37 1984. 42 1874. 72 828. 48 664. 38 5946871 .16 559424 .29 MWD+IFR-AK-CAZ-SC 2475 .95 58 .92 62. 59 2013. 34 1903. 64 851. 28 707. 21 5946894 .29 559466 .94 MWD+IFR-AK-CAZ-SC 2571 .00 59 .73 61. 27 2061. 83 1952. 13 889. 75 779. 34 5946933 .32 559538 .76 MWD+IFR-AK-CAZ-SC 2611 .14 59 .76 60. 92 2082. 06 1972. 36 906. 51 809. 70 5946950 .32 559568 .98 MWD+IFR-AK-CAZ-SC 2666 .51 59 .94 60. 73 2109. 87 2000. 17 929. 85 851. 50 5946973 .98 559610 .60 MWD+IFR-AK-CAZ-SC 2695 .63 59 .05 61. 06 2124. 65 2014. 95 942. 06 873. 42 5946986 .35 559632 .42 MWD+IFR-AK-CAZ-SC 2761 .59 57 .83 60. 61 2159. 17 2049. 47 969. 44 922. 50 5947014 .12 559681 .28 MWD+IFR-AK-CAZ-SC 2828 .92 58 .92 61. 14 2194. 48 2084. 78 997. 35 972. 58 5947042 .41 559731 .14 MWD+IFR-AK-CAZ-SC 2857 .58 59 .64 60. 94 2209. 12 2099. 42 1009. 27 994. 14 5947054 .51 559752 .60 MWD+IFR-AK-CAZ-SC 2968 .32 59 .14 61. 42 2265. 51 2155. 81 1055. 22 1077. 64 5947101 .10 559835 .73 MWD+IFR-AK-CAZ-SC 3038 .11 58 .93 61. 21 2301. 41 2191. 71 1083. 94 1130. 14 5947130 .23 559888 .00 MWD+IFR-AK-CAZ-SC 3064 .31 58 .53 60. 89 2315. 01 2205. 31 1094. 78 1149. 74 5947141 .22 559907 .51 MWD+IFR-AK-CAZ-SC 3159 .47 58 .15 61. 48 2364. 96 2255. 26 1133. 82 1220. 71 5947180 .81 559978 .16 MWD+IFR-AK-CAZ-SC 3253 .03 58 .77 61. 25 2413. 90 2304. 20 1172. 04 1290. 69 5947219 .56 560047 .84 MWD+IFR-AK-CAZ-SC 3349 .29 59 .73 61. 83 2463. 12 2353. 42 1211. 46 1363. 42 5947259 .54 560120 .25 MWD+IFR-AK-CAZ-SC 3443 .96 59 .44 65. 76 2511. 06 2401. 36 1247. 50 1436. 65 5947296 .16 560193 .19 MWD+IFR-AK-CAZ-SC 3537 .78 59 .12 70. 40 2559. 01 2449, 31 1277. 60 1511. 44 5947326 .84 560267 .73 MWD+IFR-AK-CAZ-SC 3633 .89 58 .32 74. 65 2608. 92 2499. 22 1302. 27 1589. 75 5947352 .12 560345 .85 MWD+IFR-AK-CAZ-SC 3728 .68 58 .19 80. 31 2658. 83 2549. 13 1319. 74 1668. 40 5947370 .19 560424 .34 MWD+IFR-AK-CAZ-SC 3822 .92 58 .63 85. 34 2708. 22 2598. 52 1329. 75 1748. 00 5947380 .83 560503 .86 MWD+IFR-AK-CAZ-SC 3920 .15 58 .75 90. 21 2758. 77 2649. 07 1332. 97 1830. 97 5947384 .69 560586 .80 MWD+IFR-AK-CAZ-SC 4016 .73 57 .89 96. 43 2809. 52 2699. 82 1328. 24 1912. 96 5947380 .60 560668 .81 MWD+IFR-AK-CAZ-SC ~ 4109 .70 58 .93 105. 03 2858. 29 2748. 59 1313. 48 1990. 65 5947366 .45 560746 .61 MWD+IFR-AK-CAZ-SC 4205 .49 58 .97 109. 97 2907. 72 2798. 02 1288. 82 2068. 88 5947342 .40 560825 .02 MWD+IFR-AK-CAZ-SC 4302 .30 59 .16 115. 17 2957. 51 2847. 81 1256. 96 2145. 52 5947311 .14 560901 .90 MWD+IFR-AK-CAZ-SC 4396 .10 58 .94 118. 87 3005. 76 2896. 06 1220. 43 2217. 16 5947275 .17 560973 .82 MWD+IFR-AK-CAZ-SC 4489 .53 58 .62 122. 32 3054. 20 2944. 50 1179. 77 2285. 93 5947235 .06 561042 .89 MWD+IFR-AK-CAZ-SC 4586 .40 58 .36 128. 27 3104. 86 2995. 16 1132. 09 2353. 29 5947187 .91 561110 .61 MWD+IFR-AK-CAZ-SC 4680 .37 58 .90 131. 04 3153. 79 3044. 09 1080. 89 2415. 05 5947137 .20 561172 .77 MWD+IFR-AK-CAZ-SC ' 4775 .85 61 .69 130. 15 3201. 10 3091. 40 1026. 94 2478. 02 5947083 .75 561236 .15 MWD+IFR-AK-CAZ-SC 4868 .62 62 .42 130. 01 3244. 57 3134. 87 974. 18 2540. 72 5947031 .48 561299 .26 MWD+IFR-AK-CAZ-SC 4966 .54 63 .06 130. 13 3289. 42 3179. 72 918. 14 2607. 34 5946975 .98 561366 .30 MWD+IFR-AK-CAZ-SC ICI 5060 .87 62 .79 132. 90 3332. 36 3222. 66 862. 48 2670. 22 5946920 .81 561429 .61 MWD+IFR-AK-CAZ-SC 5156 .49 63 .60 136. 59 3375. 49 3265. 79 802. 41 2730. 81 5946861 .22 561490 .67 MWD+IFR-AK-CAZ-SC 5251 .33 64 .45 139. 73 3417. 04 3307. 34 738. 90 2787. 67 5946798 .16 561548 .01 MWD+IFR-AK-CAZ-SC 5346 .95 67 .81 145. 86 3455. 76 3346. 06 669. 27 2840. 45 5946728 .95 561601 .33 MWD+IFR-AK-CAZ-SC j 5442 .23 69 .73 151. 57 3490. 28 3380. 58 593. 40 2886. 52 5946653 .45 561647 .99 MWD+IFR-AK-CAZ-SC 5537 .26 73 .47 156. 74 3520. 29 3410. 59 512 .27 2925. 77 5946572 .64 561687 .86 MWD+IFR-AK-CAZ-SC 5631 .47 77 .44 159. 97 3543 .95 3434. 25 427 .53 2959. 37 5946488 .18 561722 .12 MWD+IFR-AK-CAZ-SC 5693 .55 78 .30 162. 00 3557 .00 3447. 30 370 .16 2979. 15 5946430 .96 561742 .34 MWD+IFR-AK-CAZ-SC 5723 .72 78 .56 161. 64 3563. 05 3453. 35 342. 07 2988. 37 5946402 .95 561751 .78 MWD+IFR-AK-CAZ-SC ~ 5820 .08 79 .35 163. 42 3581. 51 3471. 81 251. 87 3016. 76 5946312 .98 561780 .87 MWD+IFR-AK-CAZ-SC 5912 .60 79 .95 165. 42 3598. 14 3488. 44 164. 20 3041. 20 5946225 .51 561805 .99 MWD+IFR-AK-CAZ-SC 6010 .65 80 .83 165. 32 3614 .51 3504. 81 70. 66 3065. 62 5946132 .18 561831 .14 MWD+IFR-AK-CAZ-SC 6108 .38 78 .58 166. 72 3631 .97 3522. 27 -22_ 64 3088. 85 5946039 .07 561855 .09 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 14:32:57 Pate: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-103, True North Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-103: 109.7 Well: 1J-103 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103 Survey Calculation Method: Minimum Curvature n6: Oracle Sun~cv b1D h~cl A'rnn ~~ TVD SysTVD Iv/S E/W MapN D1apE fool ft deg deg ft ft ft ft ft ft 6200.88 80.95 169.74 3648.41 3538.71 -111.74 3107.40 5945950.13 561874.34 MWD+IFR-AK-CAZ-SC 6297.45 82.26 173.71 3662.51 3552.81 -206.26 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC 6391.65 81.33 178.56 3675.97 3566.27 -299.25 3127.43 5945762.80 561895.83 MWD+IFR-AK-CAZ-SC 6487.67 81.08 179.77 3690.65 3580.95 -394.13 3128.81 5945667.94 561897.95 MWD+IFR-AK-CAZ-SC 6583.07 80.89 179.23 3705.60 3595.90 -488.35 3129.64 5945573.74 561899.51 MWD+IFR-AK-CAZ-SC 6678.31 80.49 179.11 3721.00 3611.30 -582.32 3131.00 5945479.79 561901.61 MWD+IFR-AK-CAZ-SC 6773.62 81.08 178.54 3736.27 3626.57 -676.38 3132.93 5945385.75 561904.27 MWD+IFR-AK-CAZ-SC 6868.55 80.40 178.37 3751.54 3641.84 -770.04 3135.45 5945292.13 561907.53 MWD+IFR-AK-CAZ-SC 6963.65 79.76 178.52 3767.93 3658.23 -863.68 3138.00 5945198.52 561910.80 MWD+IFR-AK-CAZ-SC 6992.22 79.88 178.11 3772.97 3663.27 -891.79 3138.82 5945170.42 561911.85 MWD+IFR-AK-CAZ-SC 7025.39 80.26 178.29 3778.69 3668.99 -924.45 3139.85 5945137.77 561913.13 MWD+IFR-AK-CAZ-SC 7058.48 81.32 178.39 3783.99 3674.29 -957.10 3140.80 5945105.14 561914.33 MWD+IFR-AK-CAZ-SC 7093.85 84.49 179.55 3788.36 3678.66 -992.18 3141.42 5945070.06 561915.23 MWD+IFR-AK-CAZ-SC 7142.91 88.77 178.46 3791.24 3681.54 -1041.14 3142.28 5945021.11 561916.46 MWD+IFR-AK-CAZ-SC 7206.40 89.60 177.05 3792.15 3682.45 -1104.57 3144.76 5944957.71 561919.45 MWD+IFR-AK-CAZ-SC ! 7268.27 92.26 177.46 3791.14 3681.44 -1166.36 3147.73 5944895.95 561922.89 MWD+IFR-AK-CAZ-SC 7304.48 91.65 177.09 3789.91 3680.21 -1202.51 3149.45 5944859.83 561924.89 MWD+IFR-AK-CAZ-SC 7348.54 89.47 178.03 3789.48 3679.78 -1246.52 3151.32 5944815.83 561927.11 MWD+IFR-AK-CAZ-SC 7400.70 89.22 178.54 3790.07 3680.37 -1298.65 3152.88 5944763.72 561929.08 MWD+IFR-AK-CAZ-SC 7448.29 89.30 179.79 3790.69 3680.99 -1346.23 3153.58 5944716.15 561930.14 MWD+IFR-AK-CAZ-SC 7495.53 88.62 179.26 3791.54 3681.84 -1393.46 3153.97 5944668.93 561930.90 MWD+IFR-AK-CAZ-SC I 7545.95 88.56 179.62 3792.78 3683.08 -1443.87 3154.46 5944618.53 561931.79 MWD+IFR-AK-CAZ-SC i 7593.56 89.07 179.45 3793.77 3684.07 -1491.46 3154.85 5944570.95 561932.55 MWD+IFR-AK-CAZ-SC 7641.22 89.30 179.07 3794.45 3684.75 -1539.12 3155.46 5944523.31 561933.53 MWD+IFR-AK-CAZ-SC 7689.54 89.43 179.49 3794.98 3685.28 -1587.43 3156.07 5944475.00 561934.52 MWD+IFR-AK-CAZ-SC ~ 7758.21 91.03 179.21 3794.71 3685.01 -1656.09 3156.85 5944406.36 561935.83 MWD+IFR-AK-CAZ-SC 7787.72 91.53 178.87 3794.05 3684.35 -1685.59 3157.34 5944376.86 561936.56 MWD+IFR-AK-CAZ-SC 7836.36 91.45 179.04 3792.78 3683.08 -1734.20 3158.23 5944328.26 561937.82 MWD+IFR-AK-CAZ-SC i 7883.03 90.82 179.57 3791.86 3682.16 -1780.86 3158.80 5944281.62 561938.75 MWD+IFR-AK-CAZ-SC 7954.03 91.54 179.88 3790.40 3680.70 -1851.85 3159.14 5944210.64 561939.65 MWD+IFR-AK-CAZ-SC i 8002.10 92.04 180.06 3788.90 3679.20 -1899.89 3159.16 5944162.60 561940.05 MWD+IFR-AK-CAZ-SC ~ 8045.70 92.36 180.42 3787.22 3677.52 -1943.46 3158.98 5944119.04 561940.21 MWD+IFR-AK-CAZ-SC 8082.21 88.71 179.56 3786.88 3677.18 -1979.96 3158.98 5944082.54 561940.50 MWD+IFR-AK-CAZ-SC 8099.21 90.54 179.14 3786.99 3677.29 -1996.96 3159.18 5944065.55 561940.82 MWD+IFR-AK-CAZ-SC 8134.84 92.45 178.40 3786.06 3676.36 -2032.57 3159.94 5944029.95 561941.86 MWD+IFR-AK-CAZ-SC 8160.09 94.78 178.91 3784.47 3674.77 -2057.76 3160.53 5944004.77 561942.65 MWD+IFR-AK-CAZ-SC 8196.13 93.70 178.16 3781.81 3672.11 -2093.69 3161.45 5943968.85 561943.85 MWD+IFR-AK-CAZ-SC 8220.70 94.90 178.79 3779.96 3670.26 -2118.18 3162.10 5943944.37 561944.70 MWD+IFR-AK-CAZ-SC 8263.78 92.66 176.15 3777.12 3667.42 -2161.12 3164.00 5943901.45 561946.93 MWD+IFR-AK-CAZ-SC 8291.86 92.63 175.82 3775.83 3666.13 -2189.10 3165.97 5943873.49 561949.11 MWD+IFR-AK-CAZ-SC 8324.13 91.57 176.76 3774.64 3664.94 -2221.28 3168.05 5943841.33 561951.45 MWD+IFR-AK-CAZ-SC 8361.61 90.74 178.01 3773.89 3664.19 -2258.71 3169.76 5943803.91 561953.45 MWD+IFR-AK-CAZ-SC 8388.84 89.69 179.16 3773.79 3664.09 -2285.93 3170.44 5943776.70 561954,33 MWD+IFR-AK-CAZ-SC ~ 8456.90 89.87 178.78 3774.05 3664.35 -2353.98 3171.66 5943708.67 561956.09 MWD+IFR-AK-CAZ-SC ~ 8486.06 90.31 178.71 3774.00 3664.30 -2383.13 3172.30 5943679.53 561956,95 MWD+IFR-AK-CAZ-SC 8534.01 89.35 179.60 3774.14 3664.44 -2431.07 3173.01 5943631.60 561958.04 MWD+IFR-AK-CAZ-SC ~' 8583.29 88.94 179.71 3774.88 3665.18 -2480.35 3173.30 5943582.33 561958.72 MWD+IFR-AK-CAZ-SC 8633.77 89.43 179.28 3775.60 3665.90 -2530.82 3173.75 5943531.87 561959.56 MWD+IFR-AK-CAZ-SC 8679.74 90.40 179.62 3775.67 3665.97 -2576.79 3174.19 5943485.91 561960.36 MWD+IFR-AK-CAZ-SC 8728.80 90.11 180.55 3775.45 3665.75 -2625.85 3174.12 5943436.86 561960.67 MWD+IFR-AK-CAZ-SC ~ 8776.90 89.84 180.10 3775.47 3665.77 -2673.95 3173.84 5943388.76 561960.77 MWD+IFR-AK-CAZ-SC III - 8826.78 90.11 180.55 3775.49 3665.79 -2723.82 3173.56 5943338.89 561960.88 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7!2007 . Time: 14:32:57 Pa~c: -t Field: Kuparuk River Unit Co-ordiuate(NE) Reference: WeII: 1 J-103, True North ', Site: Kuparuk 1J Pad Vertical(T~'D) Reference: 1J-103: 109.7 ', Nell: 1J-103 Section (VS) Reference: WeII (O.OON,O.OOE,180.OOAzi) Wcllpath: 1J-103 Survey Calculation Method: Minimum Curvature Db: Oracle Sun~ev NfD Iucl Azim TVD Sys TVD N/S -. E/~V vlapN NTapE Tool '~ ft deg deg ft ft ft ft ft ft 8873. 33 90 .35 180. 45 3775. 30 3665. 60 -2770. 37 3173. 15 5943292. 34 561960. 83 MWD+IFR-AK-CAZ-SC 8922 .77 90 .39 180. 45 3774. 98 3665. 28 -2819. 81 3172. 76 5943242. 91 561960. 83 MWD+IFR-AK-CAZ-SC 8969. 62 89 .73 181. 25 3774. 94 3665. 24 -2866. 65 3172. 07 5943196. 06 561960. 50 MWD+IFR-AK-CAZ-SC 9021. 43 88 .97 180. 48 3775. 52 3665. 82 -2918. 45 3171. 29 5943144. 26 561960. 12 MWD+IFR-AK-CAZ-SC 9066 .43 89 .21 180. 09 3776. 24 3666. 54 -2963. 45 3171. 06 5943099. 27 561960. 25 MWD+IFR-AK-CAZ-SC 9116 .85 88 .98 180. 21 3777. 03 3667. 33 -3013. 86 3170. 93 5943048. 87 561960. 51 MWD+IFR-AK-CAZ-SC 9163 .03 89 .42 179. 49 3777. 68 3667. 98 -3060. 04 3171. 05 5943002. 70 561960 .99 MWD+IFR-AK-CAZ-SC 9215 .24 89 .47 179. 49 3778. 18 3668. 48 -3112. 24 3171. 52 5942950. 50 561961 .86 MWD+IFR-AK-CAZ-SC 9260 .47 89 .68 179. 22 3778. 52 3668. 82 -3157. 47 3172. 03 5942905. 29 561962 .73 MWD+IFR-AK-CAZ-SC 9309. 70 89 .77 179. 16 3778. 76 3669. 06 -3206. 69 3172. 72 5942856. 07 561963 .81 MWD+IFR-AK-CAZ-SC 9356. 62 90. 03 178. 62 3778. 84 3669. 14 -3253. 60 3173. 63 5942809. 18 561965. 08 MWD+IFR-AK-CAZ-SC 9403. 52 90 .33 178. 75 3778. 69 3668. 99 -3300. 49 3174. 71 5942762. 30 561966. 52 MWD+IFR-AK-CAZ-SC 9447. 82 90 .59 178. 73 3778. 34 3668. 64 -3344. 78 3175. 68 5942718. 03 561967. 84 MWD+IFR-AK-CAZ-SC 9495. 03 90 .82 178. 37 3777. 75 3668. 05 -3391. 97 3176. 88 5942670. 85 561969. 41 MWD+IFR-AK-CAZ-SC 9538 .18 90 .23 178. 54 3777. 36 3667. 66 -3435. 10 3178. 04 5942627. 73 561970. 91 MWD+IFR-AK-CAZ-SC 9583 .67 90 .34 178. 21 3777. 13 3667. 43 -3480. 57 3179. 33 5942582. 28 561972. 55 MWD+IFR-AK-CAZ-SC 9628 .22 90 .40 177. 79 3776. 85 3667. 15 -3525. 09 3180. 88 5942537. 78 561974 .45 MWD+IFR-AK-CAZ-SC 9674 .61 90 .09 177. 63 3776. 65 3666. 95 -3571. 45 3182. 74 5942491. 44 561976 .67 MWD+IFR-AK-CAZ-SC 9719 .74 90 .27 178. 30 3776. 51 3666. 81 -3616. 55 3184. 34 5942446. 36 561978 .62 MWD+IFR-AK-CAZ-SC 9765 .45 90 .10 179. 40 3776. 36 3666. 66 -3662. 25 3185. 26 5942400. 67 561979 .90 MWD+IFR-AK-CAZ-SC 9810 .49 90 .69 179. 71 3776. 05 3666. 35 -3707. 29 3185. 61 5942355 .64 561980 .60 MWD+IFR-AK-CAZ-SC 9854 .53 90 .44 180. 27 3775. 61 3665: 91 -3751. 32 3185. 62 5942311 .61 561980 .95 MWD+IFR-AK-CAZ-SC ~ 9901 .35 90 .41 180. 65 3775. 27 3665. 57 -3798. 14 3185. 24 5942264 .80 561980 .94 MWD+IFR-AK-CAZ-SC 9943 .78 90 .95 180. 67 3774. 76 3665. 06 -3840. 56 3184. 75 5942222 .38 561980 .78 MWD+IFR-AK-CAZ-SC i 9991 .23 91 .62 180. 06 3773. 70 3664. 00 -3888. 00 3184. 45 5942174 .94 561980 .85 MWD+IFR-AK-CAZ-SC ~ 10035 .40 90 .47 180. 39 3772. 89 3663. 19 -3932. 16 3184. 28 5942130 .79 561981 .02 MWD+IFR-AK-CAZ-SC 10079 .97 89 .59 180. 07 3772. 87 3663. 17 -3976. 73 3184. 10 5942086 .22 561981 .19 MWD+IFR-AK-CAZ-SC 10125 .10 89 .98 179. 54 3773. 04 3663. 34 -4021. 86 3184. 25 5942041 .10 561981 .69 MWD+IFR-AK-CAZ-SC 10169 .69 90 .65 180. 53 3772. 79 3663. 09 -4066. 45 3184. 22 5941996 .52 561982 .02 MWD+IFR-AK-CAZ-SC 10216 .65 90 .47 180. 86 3772. 33 3662. 63 -4113. 40 3183. 65 5941949 .56 561981 .81 MWD+IFR-AK-CAZ-SC 10261 .53 90 .10 179. 31 3772. 11 3662. 41 -4158 .28 3183. 59 5941904 .69 561982 .10 MWD+IFR-AK-CAZ-SC 10307 .54 90 .22 179. 62 3771. 98 3662. 28 -4204. 29 3184. 02 5941858 .69 561982 .88 MWD+IFR-AK-CAZ-SC 10351 .72 89 .71 178. 91 3772. 01 3662. 31 -4248. 46 3184. 58 5941814 .53 561983 .80 MWD+IFR-AK-CAZ-SC r 10398 .63 90 .90 181. 11 3771. 76 3662. 06 -4295. 37 3184. 57 5941767 .63 561984 .15 MWD+IFR-AK-CAZ-SC 10443 .32 91 .31 182. 89 3770. 90 3661. 20 -4340. 02 3183. 02 5941722 .97 561982 .94 MWD+IFR-AK-CAZ-SC ~ , 10455 .70 91 .06 182. 71 3770. 64 3660. 94 -4352. 39 3182. 41 5941710 .60 561982 .44 MWD+IFR-AK-CAZ-SC 10471 .85 88 .86 185. 12 3770. 65 3660. 95 -4368. 50 3181. 31 5941694 .48 561981 .46 MWD+IFR-AK-CAZ-SC 10533 .38 88 .98 184. 79 3771. 81 3662. 11 -4429. 78 3175. 99 5941633 .16 561976 .62 MWD+IFR-AK-CAZ-SC ~ 10580 .67 88 .34 184. 40 3772. 92 3663. 22 -4476. 91 3172. 21 5941586 .01 561973 .20 MWD+IFR-AK-CAZ-SC 10623 .71 89 .03 184. 43 3773. 91 3664. 21 -4519. 81 3168. 90 5941543 .09 561970 .23 MWD+IFR-AK-CAZ-SC I 10672 .69 89 .64 184. 72 3774. 47 3664. 77 -4568. 63 3164. 99 5941494 .25 561966 .70 MWD+IFR-AK-CAZ-SC 10715 .57 90 .05 184. 69 3774. 59 3664. 89 -4611. 37 3161. 47 5941451 .49 561963 .52 MWD+IFR-AK-CAZ-SC 10759 .08 90 .20 184. 38 3774. 50 3664. 80 -4654 .74 3158. 03 5941408 .10 561960 .42 MWD+IFR-AK-CAZ-SC 10806 I .20 90 .39 184. 47 3774. 25 3664. 55 -4701 .72 3154. 40 5941361 .09 561957 .15 MWD+IFR-AK-CAZ-SC 10857 .07 88 .82 184. 31 3774. 60 3664. 90 -4752 .44 3150. 50 5941310 .35 561953 .65 MWD+IFR-AK-CAZ-SC 10897 .30 88 .87 184. 11 3775. 42 3665. 72 -4792 .55 3147. 55 5941270 .22 561951 .01 MWD+IFR-AK-CAZ-SC 10948 .16 89 .64 183. 85 3776. 08 3666. 38 -4843 .28 3144. 02 5941219 .47 561947 .88 MWD+IFR-AK-CAZ-SC 10987 .65 89 .78 184. 06 3776. 28 3666. 58 -4882 .68 3141. 30 5941180 .06 561945 .46 MWD+IFR-AK-CAZ-SC 11038 .68 90 .51 183. 80 3776. 15 3666. 45 -4933 .59 3137. 80 5941129 .12 561942 .36 MWD+IFR-AK-CAZ-SC 11078 .39 91 .09 184. 18 3775. 59 3665. 89 -4973 .20 3135. 04 5941089 .50 561939 .91 MWD+IFR-AK-CAZ-SC 11128 .52 90 .05 183. 81 3775. 09 3665. 39 -5023 .20 3131. 54 5941039 .47 561936 .81 MWD+IFR-AK-CAZ-SC 11167 .52 90 .22 183. 26 3775. 00 3665. 30 -5062 .13 3129. 14 5941000 .53 561934 .71 MWD+IFR-AK-CAZ-SC 11229 .23 90 .94 183. 37 3774. 38 3664. 68 -5123 .73 3125. 57 5940938 .91 561931 .62 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhil!ips Alaska In,;. Date: 2/7/2007 Time: 14:32:57 1':r~c: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-103, True North Site: Kuparuk 1J Pad Vertical(TVD) Reference: 1J-103: 109.7 Nell: 1J-103 Section (VS) Reference, Wetl (O.OON,O.OOE1 SO:OOAzi) Wcllpath: 1J-103 Survey Calculation ~7ethod: Minimum Curvature llb: Oracle Survey 1~1D [ncl Azim TVD Sys'fVD N/S ElW MapN MapE, Tool ft deg deg ft ft ft ft' ft ft 11272.7 0 90.94 183.37 3773.66 3663.96 -5167.12 3123.02 5940895 .51 n 561929.41. PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . Date: 2(7/2007 Time: 09:34:46 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-103, Tr ue North Site: Kuparuk 1 J Pad Vertical (TVD) Re ference: 1 J-103P61: 109 .7 Well: 1J-103 Section (VS)Refer ence: Well (O.OON,O.OOE,180:OOAzi) Wcllpath: 1J-103P61 Survey Calculation'`lcthod: Minimum Curvature Db: 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 Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-103 Slot Name: Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N +E/-W -22.57 ft Easti ng : 558 766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft ~Wellpath: 1J-103P61 Drilled From: Well Ref. Point 500292331870 Tie-on Depth: 28.00 ft ~ Current Datum: 1 J-103P61: Height 109.70 ft ' Above System Datum: Mean Sea Level ~ Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 urvey Program for Definitive Wellpath Date: 12/18/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft ~ 50.70 632.70 1J-103P61 gyro (50 .70-632.70) CB-GYRO-SS Camera based gyro single shot 662.65 8486.40 1J-103P61 (662.65- 8486.40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey _ _- - NID incl :1zim TVD Sys T~'D n/S E/W MapA MapE Tool ft deg deg ft ft ft ft ft ft __. 28.00 0.00 0.00 I 28.00 -81.70 0.00 0.00 5946037.60 558766.46 TIE LINE I 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS i 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS li 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 i MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC iI 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC it 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC 1905.12 50.63 35.76 1693.74 1584.04 553.95 347.13 5946594.19 559109.23 MWD+IFR-AK-CAZ-SC 1936.93 51.49 36.82 1713.74 1604.04 573.89 361.78 5946614.24 559123.71 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Comp:~ny: __ _- ConacoPhillips Alaska Inc. Field: Kuparuk River Unit Site Kuparuk 1J Pad ~~'ell: 1 J-103 ~Vellpath: 1J-103PB1 Su r~ ev -- I~ID Incl Azim TVD Sys TVD ft deg deg ft ft 2000.86 51.87 39.61 1753.38 1643.68 2093.95 53.72 45.46 1809.70 1700.00 2191.18 56.62 51.14 1865.26 1755.56 2284.31 58.44 55.15 1915.27 1805.57 2380.32 59.72 60.12 1964.62 1854.92 2419.46 59.50 61.37 1984.42 1874.72 2475.95 58.92 62.59 2013.34 1903.64 2571.00 59.73 61.27 2061.83 1952.13 2611.14 59.76 60.92 2082.06 1972.36 2666.51 59.94 60.73 2109.87 2000.17 2695.63 59.05 61.06 2124.65 2014.95 2761.59 57.83 60.61 2159.17 2049.47 i 2828.92 58.92 61.14 2194.48 2084.78 2857.58 59.64 60.94 2209.12 2099.42 2968.32 59.14 61.42 2265.51 2155.81 3038.11 58.93 61.21 2301.41 2191.71 ', 3064.31 58.53 60.89 2315.01 2205.31 3159.47 58.15 61.48 2364.96 2255.26 3253.03 58.77 61.25 2413.90 2304.20 3349.29 59.73 61.83 2463.12 2353.42 3443.96 59.44 65.76 2511.06 2401.36 3537.78 59.12 70.40 2559.01 2449.31 3633.89 58.32 74.65 2608.92 2499.22 3728.68 58.19 80.31 2658.83 2549.13 3822.92 58.63 85.34 2708.22 2598.52 3920.15 58.75 90.21 2758.77 2649.07 4016.73 57.89 96.43 2809.52 2699.82 4109.70 58.93 105.03 2858.29 2748.59 4205.49 58.97 109.97 2907.72 2798.02 4302.30 59.16 115.17 2957.51 2847.81 4396.10 58.94 118.87 3005.76 2896.06 4489.53 58.62 122.32 3054.20 2944.50 4586.40 58.36 128.27 3104.86 2995.16 j 4680.37 58.90 131.04 3153.79 3044.09 4775.85 61.69 130.15 3201.10 3091.40 4868.62 62.42 130.01 3244.57 3134.87 4966.54 63.06 130.13 3289.42 3179.72 5060.87 62.79 132.90 3332.36 3222.66 5156.49 63.60 136.59 3375.49 3265.79 5251.33 64.45 139.73 3417.04 3307.34 5346.95 67.81 145.86 3455.76 3346.06 5442.23 69.73 151.57 3490.28 3380.58 5537.26 73.47 156.74 3520.29 3410.59 5631.47 77.44 159.97 3543.95 3434.25 5693.55 78.30 162.00 3557.00 3447.30 5723.72 78.56 161.64 3563.05 3453.35 5820.08 79.35 163.42 3581.51 3471.81 5912.60 79.95 165.42 3598.14 3488.44 6010.65 80.83 165.32 3614.51 3504.81 6108.38 78.58 166.72 3631.97 3522.27 6200.88 80.95 169.74 3648.41 3538.71 6297.45 82.26 173.71 3662.51 3552.81 _.. _........... . Date: 2/7/2007 Time: 09:34:46 Pare: 2 Co-ordinate(iVE)Reference: Well: 1J-103, True North Vertical (TVD) Reference. 1J-103PB1: 109.7 Section(VS)Keference: Well(O.OON,O.OOE,180.OOAzi) Sun~ey CAkulation ~icthod: Minimum Curvature Dh: Oracle ~/S E/R~ IViapN ~1apE ~ l uul ~ ft ft ft ft 613.29 392.80 5946653.88 559154.43 MWD+IFR-AK-CAZ-SC 667.85 442.92 5946708.82 559204.11 MWD+IFR-AK-CAZ-SC 720.85 502.51 5946762.28 559263.28 MWD+IFR-AK-CAZ-SC 767.94 565.37 5946809.85 559325.77 MWD+IFR-AK-CAZ-SC ~ 811.99 634.92 5946854.44 559394.97 MWD+IFR-AK-CAZ-SC 828.48 664.38 5946871.16 559424.29 MWD+IFR-AK-CAZ-SC 851.28 707.21 5946894.29 559466.94 MWD+IFR-AK-CAZ-SC 889.75 779.34 5946933.32 559538.76 MWD+IFR-AK-CAZ-SC 906.51 809.70 5946950.32 559568.98 MWD+IFR-AK-CAZ-SC 929.85 851.50 5946973.98 559610.60 MWD+IFR-AK-CAZ-SC 942.06 873.42 5946986.35 559632.42 MWD+IFR-AK-CAZ-SC 969.44 922.50 5947014.12 559681.28 MWD+IFR-AK-CAZ-SC 997.35 972.58 5947042.41 559731.14 MWD+IFR-AK-CAZ-SC 1009.27 994.14 5947054.51 559752.60 MWD+IFR-AK-CAZ-SC 1055.22 1077.64 5947101.10 559835.73 MWD+IFR-AK-CAZ-SC 1083.94 1130.14 5947130.23 559888.00 MWD+IFR-AK-CAZ-SC 1094.78 1149.74 5947141.22 559907.51 MWD+IFR-AK-CAZ-SC 1133.82 1220.71 5947180.81 559978.16 MWD+IFR-AK-CAZ-SC 1172.04 1290.69 5947219.56 560047.84 MWD+IFR-AK-CAZ-SC 1211.46 1363.42 5947259.54 560120.25 MWD+IFR-AK-CAZ-SC 1247.50 1436.65 5947296.16 560193.19 MWD+IFR-AK-CAZ-SC 1277.60 1511.44 5947326.84 560267.73 MWD+IFR-AK-CAZ-SC 1302.27 1589.75 5947352.12 560345.85 MWD+IFR-AK-CAZ-SC 1319.74 1668.40 5947370.19 560424.34 MWD+IFR-AK-CAZ-SC 1329.75 1748.00 5947380.83 560503.86 MWD+IFR-AK-CAZ-SC 1332.97 1830.97 5947384.69 560586.80 MWD+IFR-AK-CAZ-SC 1328.24 1912.96 5947380.60 560668.81 MWD+IFR-AK-CAZ-SC 1313.48 1990.65 5947366.45 560746.61 MWD+IFR-AK-CAZ-SC 1288.82 2068.88 5947342.40 560825.02 MWD+IFR-AK-CAZ-SC 1256.96 2145.52 5947311.14 560901.90 MWD+IFR-AK-CAZ-SC 1220.43 2217.16 5947275.17 560973.82 MWD+IFR-AK-CAZ-SC 1179.77 2285.93 5947235.06 561042.89 MWD+IFR-AK-CAZ-SC 1132.09 2353.29 5947187.91 561110.61 MWD+IFR-AK-CAZ-SC 1080.89 2415.05 5947137.20 561172.77 MWD+IFR-AK-CAZ-SC 1026.94 2478.02 5947083.75 561236.15 MWD+IFR-AK-CAZ-SC 974.18 2540.72 5947031.48 561299.26 MWD+IFR-AK-CAZ-SC 918.14 2607.34 5946975.98 561366.30 MWD+IFR-AK-CAZ-SC 862.48 2670.22 5946920.81 561429.61 MWD+IFR-AK-CAZ-SC 802.41 2730.81 5946861.22 561490.67 MWD+IFR-AK-CAZ-SC 738.90 2787.67 5946798.16 561548.01 MWD+IFR-AK-CAZ-SC 669.27 2840.45 5946728.95 561601.33 MWD+IFR-AK-CAZ-SC 593.40 2886.52 5946653.45 561647.99 MWD+IFR-AK-CAZ-SC 512.27 2925.77 5946572.64 561687.86 MWD+IFR-AK-CAZ-SC 427.53 2959.37 5946488.18 561722.12 MWD+IFR-AK-CAZ-SC 370.16 2979.15 5946430.96 561742.34 MWD+IFR-AK-CAZ-SC 342.07 2988.37 5946402.95 561751.78 MWD+IFR-AK-CAZ-SC 251.87 3016.76 5946312.98 561780.87 MWD+IFR-AK-CAZ-SC 164.20 3041.20 5946225.51 561805.99 MWD+IFR-AK-CAZ-SC 70.66 3065.62 5946132.18 561831.14 MWD+IFR-AK-CAZ-SC -22.64 3088.85 5946039.07 561855.09 MWD+IFR-AK-CAZ-SC -111.74 3107.40 5945950.13 561874.34 MWD+IFR-AK-CAZ-SC -206.26 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report __ - Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 09:34:46 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-103, True North Site: Kuparuk 1J Pad Vertical(TVD)Retercnce: 1J-103PB1: 109.7 Well: 1J-103 Section (~'S) Reference: Well {O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Smti~cv A'fD Incl azim TVD S}°s TVD 1/S E/W 111:~pN MapF. Tool ft deg deg ft ft ft ft ft ft 6391.65 81.33 178.56 3675.97 3566.27 -299.25 3127.43 5945762.80 561895.83 MWD+IFR-AK-CAZ-SC 6487.67 81.08 179.77 3690.65 3580.95 -394.13 3128.81 5945667.94 561897.95 MWD+IFR-AK-CAZ-SC 6583.07 80.89 179.23 3705.60 3595.90 -488.35 3129.64 5945573.74 561899.51 MWD+IFR-AK-CAZ-SC 6678.31 80.49 179.11 3721.00 3611.30 -582.32 3131.00 5945479.79 561901.61 MWD+IFR-AK-CAZ-SC 6773.62 81.08 178.54 3736.27 3626.57 -676.38 3132.93 5945385.75 561904.27 MWD+IFR-AK-CAZ-SC it 6868.55 80.40 178.37 3751.54 3641.84 -770.04 3135.45 5945292.13 561907.53 MWD+IFR-AK-CAZ-SC 6963.65 79.76 178.52 3767.93 3658.23 -863.68 3138.00 5945198.52 561910.80 MWD+IFR-AK-CAZ-SC 6992.22 79.88 178.11 3772.97 3663.27 -891.79 3138.82 5945170.42 561911.85 MWD+IFR-AK-CAZ-SC ', 7025.39 80.26 178.29 3778.69 3668.99 -924.45 3139.85 5945137.77 561913.13 MWD+IFR-AK-CAZ-SC 7058.48 81.32 178.39 3783.99 3674.29 -957.10 3140.80 5945105.14 561914.33 MWD+IFR-AK-CAZ-SC 7093.85 84.49 179.55 3788.36 3678.66 -992.18 3141.42 5945070.06 561915.23 MWD+IFR-AK-CA2-SC 7142.91 88.77 178.46 3791.24 3681.54 -1041.14 3142.28 5945021.11 561916.46 MWD+IFR-AK-CAZ-SC 7206.40 89.60 177.05 3792.15 3682.45 -1104.57 3144.76 5944957.71 561919.45 MWD+IFR-AK-CAZ-SC 7268.27 92.26 177.46 3791.14 3681.44 -1166.36 3147.73 5944895.95 561922.89 MWD+IFR-AK-CAZ-SC 7304.48 91.65 177.09 3789.91 3680.21 -1202.51 3149.45 5944859.83 561924.89 MWD+IFR-AK-CAZ-SC 7348.54 89.47 178.03 3789.48 3679.78 -1246.52 3151.32 5944815.83 561927.11 MWD+IFR-AK-CAZ-SC 7400.70 89.22 178.54 3790.07 3680.37 -1298.65 3152.88 5944763.72 561929.08 MWD+IFR-AK-CAZ-SC 7448.29 89.30 179.79 3790.69 3680.99 -1346.23 3153.58 5944716.15 561930.14 MWD+IFR-AK-CAZ-SC 7495.53 88.62 179.26 3791.54 3681.84 -1393.46 3153.97 5944668.93 561930.90 MWD+IFR-AK-CAZ-SC ', 7545.95 88.56 179.62 3792.78 3683.08 -1443.87 3154.46 5944618.53 561931.79 MWD+IFR-AK-CAZ-SC 7593.56 89.07 179.45 3793.77 3684.07 -1491.46 3154.85 5944570.95 561932.55 MWD+IFR-AK-CAZ-SC 7641.22 89.30 179.07 3794.45 3684.75 -1539.12 3155.46 5944523.31 561933.53 MWD+IFR-AK-CAZ-SC 7689.54 89.43 179.49 3794.98 3685.28 -1587.43 3156.07 5944475.00 561934.52 MWD+IFR-AK-CAZ-SC 7758.21 91.03 179.21 3794.71 3685.01 -1656.09 3156.85 5944406.36 561935.83 MWD+IFR-AK-CAZ-SC 7787.72 91.53 178.87 3794.05 3684.35 -1685.59 3157.34 5944376.86 561936.56 MWD+IFR-AK-CAZ-SC 7836.36 91.45 179.04 3792.78 3683.08 -1734.20 3158.23 5944328.26 561937.82 MWD+IFR-AK-CAZ-SC 7883.03 90.82 179.57 3791.86 3682.16 -1780.86 3158.80 5944281.62 561938.75 MWD+IFR-AK-CAZ-SC 7954.03 91.54 179.88 3790.40 3680.70 -1851.85 3159.14 5944210.64 561939.65 MWD+IFR-AK-CAZ-SC 8002.10 92.04 180.06 3788.90 3679.20 -1899.89 3159.16 5944162.60 561940.05 MWD+IFR-AK-CAZ-SC 8051.68 92.40 180.47 3786.97 3677.27 -1949.43 3158.93 5944113.07 561940.21 MWD+IFR-AK-CAZ-SC 8098.55 92.92 179.41 3784.80 3675.10 -1996.25 3158.98 5944066.25 561940.62 MWD+IFR-AK-CAZ-SC 8134.00 93.05 180.44 3782.95 3673.25 -2031.65 3159.03 5944030.86 561940.94 MWD+IFR-AK-CAZ-SC ~~ 8197.05 88.92 179.37 3781.87 3672.17 -2094.68 3159.13 5943967.84 561941.54 MWD+IFR-AK-CAZ-SC 8246.27 90.05 180.20 3782.31 3672.61 -2143.90 3159.32 5943918.63 561942.11 MWD+IFR-AK-CAZ-SC ' 8293.13 89.58 179.11 3782.46 3672.76 -2190.75 3159.60 5943871.78 561942.76 MWD+IFR-AK-CAZ-SC 8340.85 88.09 178.80 3783.43 3673.73 -2238.46 3160.47 5943824.09 561944.00 MWD+IFR-AK-CAZ-SC ~ 8389.27 87.36 177.57 3785.36 3675.66 -2286.81 3162.00 5943775.75 561945.91 MWD+IFR-AK-CAZ-SC 8486.40 83.05 176.62 3793.47 3683.77 -2383.45 3166.90 5943679.16 561951.56 MWD+IFR-AK-CAZ-SC 8528.70 83.05 176.62 3798.59 3688.89 -2425.37 3169.38 5943637.27 561954.37 PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . Date: 2!772007 __ Time: '14:23:04 Page: 1 Field: Kuparuk River Unit Co -ordiuate(NE)Reference: Well: 1J-103, Tr ue North Site: Kuparuk 1J Pad Vertical (TVD) Re ference: 1J-103PB2: 109.7 Well: 1J-103 Section (VS) Refer ence: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103PB2 Survey Calculation Method: Minimum Curva ture Uh: Oracle Field: Kuparuk River Unit North Slope Alaska I, 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: bggm2006 - Well: 1J-103 Slot Name: I, Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N i~ +E/-W -22.57 ft Easti ng : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft Wellpath: 1J-103PB2 Drilled From: 1J-103P61 1 500292331871 Tie-on Depth: 8002.10 ft ~ Current Datum: 1 J-103PB2: Height 109.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 - ---- ', Survey Program for Definitive Wellpath - Date: 2/7/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.70 632.70 1J-103PB1 gyro (50 .70-632.70) CB-GYRO-SS Camera based gyro single shot 662.65 8002.10 1J-103PB1 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8045.70 8389.99 1J-103PB2 (8045.70-8389.99) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ___ ___ A1D Inc! Azim TVD Sys"1"VD N/S El1V MapN i~tapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.70 0.00 0.00 5946037.60 558766.46 TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS ~' 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS ~ 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 ~ MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 ' MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC ~~ 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC 1905.12 50.63 35.76 1693.74 1584.04 553.95 347.13 5946594.19 559109.23 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 14:23:04 Page: 2 Field:. Ku paruk River Unit Co-or dinate(n'E) Reference: Well: 1J-10 3, Tr ue North Site: Ku paruk 1J Pad Vertieal(TVD) Reference: 1J-103PB2 : 109 :7 Well: 1J -103 Sectio n (VS ) Reference: Well (O.OON,0.00~,180.OOAzi) ~Vellpath: 1J -103P62 - __ Surve y Calculation Method: __ Minimum C urvat ure Db: Oracle Surccv NID incl Azim T~'D Sys TVD N/S Eli!' MapN MapE Too! ft deg deg ft ft ft ft ft ft 1936. 93 51.49 36.82 1713. 74 1604. 04 573. 89 361 .78 5946614. 24 559123. 71 MWD+IFR-AK-CAZ-SC 2000. 86 51.87 39.61 1753. 38 1643. 68 613. 29 392 .80 5946653. 88 559154. 43 MWD+IFR-AK-CAZ-SC 2093 .95 53.72 45.46 1809. 70 1700. 00 667. 85 442 .92 5946708. 82 559204. 11 MWD+IFR-AK-CAZ-SC 2191. 18 56.62 51.14 1865. 26 1755. 56 720. 85 502 .51 5946762. 28 559263. 28 MWD+IFR-AK-CAZ-SC 2284. 31 58.44 55.15 1915. 27 1805. 57 767. 94 565 .37 5946809. 85 559325. 77 MWD+IFR-AK-CAZ-SC 2380 .32 59.72 60.12 1964. 62 1854. 92 811. 99 634 .92 5946854. 44 559394. 97 MWD+IFR-AK-CAZ-SC 2419 .46 59.50 61.37 1984. 42 1874. 72 828. 48 664 .38 5946871. 16 559424. 29 MWD+IFR-AK-CAZ-SC 2475. 95 58.92 62.59 2013. 34 1903. 64 851. 28 707 .21 5946894. 29 559466. 94 MWD+IFR-AK-CAZ-SC 2571 .00 59.73 61.27 2061. 83 1952. 13 889. 75 779 .34 5946933. 32 559538. 76 MWD+IFR-AK-CAZ-SC 2611 .14 59.76 60.92 2082. 06 1972. 36 906. 51 809 .70 5946950. 32 559568. 98 MWD+IFR-AK-CAZ-SC 2666. 51 59.94 60.73 2109. 87 2000. 17 929. 85 851 .50 5946973. 98 559610. 60 MWD+IFR-AK-CAZ-SC 2695. 63 59.05 61.06 2124. 65 2014. 95 942. 06 873 .42 5946986. 35 559632. 42 MWD+IFR-AK-CAZ-SC 2761 .59 57.83 60.61 2159. 17 2049. 47 969. 44 922 .50 5947014. 12 559681. 28 MWD+IFR-AK-CAZ-SC 2828 .92 58.92 61.14 2194. 48 2084. 78 997. 35 972 .58 5947042. 41 559731. 14 MWD+IFR-AK-CAZ-SC 2857. 58 59.64 60.94 2209. 12 2099. 42 1009. 27 994 .14 5947054. 51 559752. 60 MWD+IFR-AK-CAZ-SC 2968. 32 59.14 61.42 2265. 51 2155. 81 1055. 22 1077 .64 5947101. 10 559835. 73 MWD+IFR-AK-CAZ-SC 3038 .11 58.93 61.21 2301. 41 2191. 71 1083. 94 1130 .14 5947130. 23 559888. 00 MWD+IFR-AK-CAZ-SC 3064. 31 58.53 60.89 2315. 01 2205. 31 1094. 78 1149 .74 5947141. 22 559907. 51 MWD+IFR-AK-CAZ-SC 3159. 47 58.15 61.48 2364. 96 2255. 26 1133. 82 1220 .71 5947180. 81 559978. 16 MWD+IFR-AK-CAZ-SC 3253 .03 58.77 61.25 2413. 90 2304. 20 1172. 04 1290 .69 5947219. 56 560047. 84 MWD+IFR-AK-CAZ-SC 3349 .29 59.73 61.83 2463. 12 2353. 42 1211. 46 1363 .42 5947259. 54 560120. 25 MWD+IFR-AK-CAZ-SC 3443. 96 59.44 65.76 2511. 06 2401. 36 1247. 50 1436 .65 5947296. 16 560193. 19 MWD+iFR-AK-CAZ-SC ~ 3537 .78 59.12 70.40 2559. 01 2449. 31 1277. 60 1511 .44 5947326. 84 560267. 73 MWD+IFR-AK-CAZ-SC 3633 .89 58.32 74.65 2608. 92 2499. 22 1302. 27 1589 .75 5947352. 12 560345. 85 MWD+IFR-AK-CAZ-SC 3728. 68 58.19 80.31 2658. 83 2549. 13 1319. 74 1668 .40 5947370. 19 560424. 34 MWD+IFR-AK-CAZ-SC 3822. 92 58.63 85.34 2708. 22 2598. 52 1329. 75 1748 .00 5947380. 83 560503. 86 MWD+IFR-AK-CAZ-SC 3920 .15 58.75 90.21 2758. 77 2649. 07 1332. 97 1830 .97 5947384. 69 560586. 80 MWD+IFR-AK-CAZ-SC ~ 4016. 73 57.89 96.43 2809. 52 2699. 82 1328. 24 1912 .96 5947380. 60 560668. 81 MWD+IFR-AK-CAZ-SC 4109. 70 58.93 105.03 2858. 29 2748. 59 1313. 48 1990 .65 5947366. 45 560746. 61 MWD+IFR-AK-CAZ-SC 4205 .49 58.97 109.97 2907. 72 2798. 02 1288. 82 2068 .88 5947342. 40 560825. 02 MWD+IFR-AK-CAZ-SC 4302 .30 59.16 115.17 2957. 51 2847. 81 1256. 96 2145 .52 5947311. 14 560901. 90 MWD+IFR-AK-CAZ-SC 4396 .10 58.94 118.87 3005. 76 2896. 06 1220. 43 2217 .16 5947275. 17 560973. 82 MWD+IFR-AK-CAZ-SC ~ 4489 .53 58.62 122.32 3054. 20 2944. 50 1179. 77 2285 .93 5947235. 06 561042 .89 MWD+IFR-AK-CAZ-SC 4586 .40 58.36 128.27 3104. 86 2995. 16 1132. 09 2353 .29 5947187. 91 561110. 61 MWD+IFR-AK-CAZ-SC 4680. 37 58.90 131.04 3153. 79 3044. 09 1080. 89 2415 .05 5947137. 20 561172. 77 MWD+IFR-AK-CAZ-SC 4775. 85 61.69 130.15 3201. 10 3091. 40 1026. 94 2478 .02 5947083. 75 561236. 15 MWD+IFR-AK-CAZ-SC 4868 .62 62.42 130.01 3244. 57 3134. 87 974. 18 2540 .72 5947031. 48 561299 .26 MWD+IFR-AK-CAZ-SC 4966 .54 63.06 130.13 3289. 42 3179. 72 918. 14 2607 .34 5946975. 98 561366. 30 MWD+IFR-AK-CAZ-SC 5060. 87 62.79 132.90 3332. 36 3222. 66 862. 48 2670 .22 5946920. 81 561429. 61 MWD+IFR-AK-CAZ-SC 5156 .49 63.60 136.59 3375. 49 3265. 79 802. 41 2730 .81 5946861. 22 561490 .67 MWD+IFR-AK-CAZ-SC 5251 .33 64.45 139.73 3417. 04 3307. 34 738. 90 2787 .67 5946798. 16 561548. 01 MWD+IFR-AK-CAZ-SC 5346 .95 67.81 145.86 3455. 76 3346. 06 669. 27 2840 .45 5946728. 95 561601. 33 MWD+IFR-AK-CAZ-SC 5442 .23 69.73 151.57 3490. 28 3380. 58 593. 40 2886 .52 5946653. 45 561647 .99 MWD+IFR-AK-CAZ-SC 5537 .26 73.47 156.74 3520. 29 3410. 59 512. 27 2925 .77 5946572. 64 561687 .86 MWD+IFR-AK-CAZ-SC 5631 .47 77.44 159.97 3543. 95 3434. 25 427. 53 2959 .37 5946488. 18 561722. 12 MWD+IFR-AK-CAZ-SC 5693. 55 78.30 162.00 3557. 00 3447. 30 370. 16 2979 .15 5946430. 96 561742. 34 MWD+IFR-AK-CAZ-SC 5723 .72 78.56 161.64 3563. 05 3453. 35 342. 07 2988 .37 5946402. 95 561751 .78 MWD+IFR-AK-CAZ-SC 5820 .08 79.35 163.42 3581. 51 3471. 81 251. 87 3016 .76 5946312. 98 561780. 87 MWD+IFR-AK-CAZ-SC '! 5912. 60 79.95 165.42 3598. 14 3488. 44 164. 20 3041 .20 5946225. 51 561805. 99 MWD+IFR-AK-CAZ-SC 6010 .65 80.83 165.32 3614. 51 3504. 81 70. 66 3065 .62 5946132. 18 561831 .14 MWD+tFR-AK-CAZ-SC 6108 .38 78.58 166.72 3631. 97 3522. 27 -22. 64 3088 .85 5946039. 07 561855 .09 MWD+IFR-AK-CAZ-SC 6200 .88 80.95 169.74 3648. 41 3538. 71 -111. 74 3107 .40 5945950. 13 561874 .34 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ __ - __ Company: ConocoPhillips Alaska Inc. Date: 2/7!2007 Time: 1423:04 N:ige: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-103, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-103P62: 109.7 Well: 1J-103 Section (VS) Reference:Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103PB2 Survey Calculation Dlethod: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S ti/W MapN i1apE Tool ft deg deg ft ft ft ft R ft j 6297.45 82.26 173.71 3662.51 3552.81 -206.26 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC 6391.65 81.33 178.56 3675.97 3566.27 -299.25 3127.43 5945762.80 561895.83 MWD+IFR-AK-CAZ-SC 6487.67 81.08 179.77 3690.65 3580.95 -394.13 3128.81 5945667.94 561897.95 MWD+IFR-AK-CAZ-SC ~ 6583.07 80.89 179.23 3705.60 3595.90 -488.35 3129.64 5945573.74 561899.51 MWD+IFR-AK-CAZ-SC 6678.31 80.49 179.11 3721.00 3611.30 -582.32 3131.00 5945479.79 561901.61 MWD+IFR-AK-CAZ-SC 6773.62 81.08 178.54 3736.27 3626.57 -676.38 3132.93 5945385.75 561904.27 MWD+IFR-AK-CAZ-SC 6868.55 80.40 178.37 3751.54 3641.84 -770.04 3135.45 5945292.13 561907.53 MWD+IFR-AK-CAZ-SC 6963.65 79.76 178.52 3767.93 3658.23 -863.68 3138.00 5945198.52 561910.80 MWD+IFR-AK-CAZ-SC 6992.22 79.88 178.11 3772.97 3663.27 -891.79 3138.82 5945170.42 561911.85 MWD+IFR-AK-CAZ-SC 7025.39 80.26 178.29 3778.69 3668.99 -924.45 3139.85 5945137.77 561913.13 MWD+IFR-AK-CAZ-SC 7058.48 81.32 178.39 3783.99 3674.29 -957.10 3140.80 5945105.14 561914.33 MWD+IFR-AK-CAZ-SC 7093.85 84.49 179.55 3788.36 3678.66 -992.18 3141.42 5945070.06 561915.23 MWD+IFR-AK-CAZ-SC 7142.91 88.77 178.46 3791.24 3681.54 -1041.14 3142.28 5945021.11 561916.46 MWD+IFR-AK-CAZ-SC 7206.40 89.60 177.05 3792.15 3682.45 -1104.57 3144.76 5944957.71 561919.45 MWD+IFR-AK-CAZ-SC 7268.27 92.26 177.46 3791.14 3681.44 -1166.36 3147.73 5944895.95 561922.89 MWD+IFR-AK-CAZ-SC 7304.48 91.65 177.09 3789.91 3680.21 -1202.51 3149.45 5944859.83 561924.89 MWD+IFR-AK-CAZ-SC 7348.54 89.47 178.03 3789.48 3679.78 -1246.52 3151.32 5944815.83 561927.11 MWD+IFR-AK-CAZ-SC 7400.70 89.22 178.54 3790.07 3680.37 -1298.65 3152.88 5944763.72 561929.08 MWD+IFR-AK-CAZ-SC 7448.29 89.30 179.79 3790.69 3680.99 -1346.23 3153.58 5944716.15 561930.14 MWD+IFR-AK-CAZ-SC i 7495.53 88.62 179.26 3791.54 3681.84 -1393.46 3153.97 5944668.93 561930.90 MWD+IFR-AK-CAZ-SC i II 7545.95 88.56 179.62 3792.78 3683.08 -1443.87 3154.46 5944618.53 561931.79 MWD+IFR-AK-CAZ-SC 7593.56 89.07 179.45 3793.77 3684.07 -1491.46 3154.85 5944570.95 561932.55 MWD+IFR-AK-CAZ-SC 7641.22 89.30 179.07 3794.45 3684.75 -1539.12 3155.46 5944523.31 561933.53 MWD+IFR-AK-CAZ-SC 7689.54 89.43 179.49 3794.98 3685.28 -1587.43 3156.07 5944475.00 561934.52 MWD+IFR-AK-CAZ-SC 7758.21 91.03 179.21 3794.71 3685.01 -1656.09 3156.85 5944406.36 561935.83 MWD+IFR-AK-CAZ-SC 7787.72 91.53 178.87 3794.05 3684.35 -1685.59 3157.34 5944376.86 561936.56 MWD+IFR-AK-CAZ-SC 7836.36 91.45 179.04 3792.78 3683.08 -1734.20 3158.23 5944328.26 561937.82 MWD+IFR-AK-CAZ-SC 7883.03 90.82 179.57 3791.86 3682.16 -1780.86 3158.80 5944281.62 561938.75 MWD+IFR-AK-CAZ-SC 7954.03 91.54 179.88 3790.40 3680.70 -1851.85 3159.14 5944210.64 561939.65 MWD+IFR-AK-CAZ-SC 8002.10 92.04 180.06 3788.90 3679.20 -1899.89 3159.16 5944162.60 561940.05 MWD+IFR-AK-CAZ-SC 8045.70 92.36 180.42 3787.22 3677.52 -1943.46 3158.98 5944119.04 561940.21 MWD+IFR-AK-CAZ-SC 8082.21 88.71 179.56 3786.88 3677.18 -1979.96 3158.98 5944082.54 561940.50 MWD+IFR-AK-CAZ-SC ~ 8099.21 90.54 179.14 3786.99 3677.29 -1996.96 3159.18 5944065.55 561940.82 MWD+IFR-AK-CAZ-SC 8134.84 92.45 178.40 3786.06 3676.36 -2032.57 3159.94 5944029.95 561941.86 MWD+IFR-AK-CAZ-SC 8160.09 94.78 178.91 3784.47 3674.77 -2057.76 3160.53 5944004.77 561942.65 MWD+IFR-AK-CAZ-SC 8196.13 93.70 178.16 3781.81 3672.11 -2093.69 3161.45 5943968.85 561943.85 MWD+IFR-AK-CAZ-SC 8229.02 95.43 179.36 3779.19 3669.49 -2126.46 3162.16 5943936.08 561944.82 MWD+IFR-AK-CAZ-SC 8274.13 94.90 179.12 3775.13 3665.43 -2171.39 3162.76 5943891.17 561945.76 MWD+IFR-AK-CAZ-SC 8291.55 93.97 179.13 3773.78 3664.08 -2188.75 3163.02 5943873.81 561946.16 MWD+IFR-AK-CAZ-SC 8329.60 91.64 178.77 3771.92 3662.22 -2226.75 3163.72 5943835.83 561947.16 MWD+IFR-AK-CAZ-SC 8389.99 93.01 179.25 3769.47 3659.77 -2287.08 3164.76 5943775.51 561948.67 MWD+IFR-AK-CAZ-SC 8443.70 93.01 179.25 3766.65 3656.95 -2340.71 3165.47 5943721.89 561949.79 PROJECTED to TD ~' Halliburton Company Survey Report r' Company: ConocoPhillips Alaska Inc. _____ Date: 2/7/2007 __ 'time: 14:20:31 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-103, Tr ue North Site: Kuparuk 1J Pad " Ve rtical (l'VD) Re ference: 1J-103PB3: 109.7 Nell: 1J-103 Section (VS) Refer ence: Well (O.OOtJ;0.00E,180.00Azi) R'ellpath: 1J-103PB3 Su rvey Calculation Method: Minimum Curva ___ _ ture Db: Oracte __ - 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 Sy stem: Welt Centre ~ j Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-103 Slot Name: Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N +E/-W -22.57 ft Easti ng : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft Wellpath: 1J-103PB3 Drilled From: 1J-103PB2 500292331872 Tie-on Depth: 8196.13 ft Current Datum: 1 J-103PB3: Height 109.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Vertical Section: Depth From (TVD) +N/-S Mag Dip Angle: 80.81 deg +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 2/7/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.70 632.70 1J-103P61 gyro (50 .70-632.70) CB-GYRO-SS Camera based gyro single shot ', 662.65 8002.10 1J-103PB1 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8045.70 8196.13 1J-103PB2 (8045.70-8389.99) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8220.70 10624.08 1J-103PB3 (8220.70-10624.08) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ h1D [ncl Azim TVD Sys 'TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.70 0.00 0.00 5946037.60 558766.46 TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 14:20:31 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-103, True Norttt Site: Kuparuk 1J Pad Vertical (1'b'D) Reference: 1J-103P63: 109.7 Well: 1J-103 Section (V'S) Reference: Wel1(O.OON,O.OOE,180.OOAzi) N'ellpath: 1 J-103PB3 Survey Calculation Method: Minimum Curvature Db: Oracle Su~-~ c~ ?~iD [ncl Azim TVD Sys'['VD N/S E/W A4apN MapF, Tool ft deg deg ft ft ft ft ft ft ~i 1905.12 50.63 35.76 1693.74 1584.04 553.95 347.13 5946594.19 559109.23 MWD+IFR-AK-CAZ-SC 1936.93 51.49 36.82 1713.74 1604.04 573.89 361.78 5946614.24 559123.71 MWD+IFR-AK-CAZ-SC ! ~~ 2000.86 51.87 39.61 1753.38 1643.68 613.29 392.80 5946653.88 559154.43 MWD+IFR-AK-CAZ-SC I 2093.95 53.72 45.46 1809.70 1700.00 667.85 442.92 5946708.82 559204.11 MWD+IFR-AK-CAZ-SC 2191.18 56.62 51.14 1865.26 1755.56 720.85 502.51 5946762.28 559263.28 MWD+IFR-AK-CAZ-SC 2284.31 58.44 55.15 1915.27 1805.57 767.94 565.37 5946809.85 559325.77 MWD+IFR-AK-CAZ-SC 2380.32 59.72 60.12 1964.62 1854.92 811.99 634.92 5946854.44 559394.97 MWD+IFR-AK-CAZ-SC 2419.46 59.50 61.37 1984.42 1874.72 828.48 664.38 5946871.16 559424.29 MWD+IFR-AK-CAZ-SC 2475.95 58.92 62.59 2013.34 1903.64 851.28 707.21 5946894.29 559466.94 MWD+IFR-AK-CAZ-SC 2571.00 59.73 61.27 2061.83 1952.13 889.75 779.34 5946933.32 559538.76 MWD+IFR-AK-CAZ-SC 2611.14 59.76 60.92 2082.06 1972.36 906.51 809.70 5946950.32 559568.98 MWD+IFR-AK-CAZ-SC 2666.51 59.94 60.73 2109.87 2000.17 929.85 851.50 5946973.98 559610.60 MWD+IFR-AK-CAZ-SC 2695.63 59.05 61.06 2124.65 2014.95 942.06 873.42 5946986.35 559632.42 MWD+IFR-AK-CAZ-SC 2761.59 57.83 60.61 2159.17 2049.47 969.44 922.50 5947014.12 559681.28 MWD+IFR-AK-CAZ-SC 2828.92 58.92 61.14 2194.48 2084.78 997.35 972.58 5947042.41 559731.14 MWD+IFR-AK-CAZ-SC 2857.58 59.64 60.94 2209.12 2099.42 1009.27 994.14 5947054.51 559752.60 MWD+IFR-AK-CAZ-SC 2968.32 59.14 61.42 2265.51 2155.81 1055.22 1077.64 5947101.10 559835.73 MWD+IFR-AK-CAZ-SC 3038.11 58.93 61.21 2301.41 2191.71 1083.94 1130.14 5947130.23 559888.00 MWD+IFR-AK-CAZ-SC 3064.31 58.53 60.89 2315.01 2205.31 1094.78 1149.74 5947141.22 559907.51 MWD+IFR-AK-CAZ-SC it 3159.47 58.15 61.48 2364.96 2255.26 1133.82 1220.71 5947180.81 559978.16 MWD+IFR-AK-CAZ-SC 3253.03 58.77 61.25 2413.90 2304.20 1172.04 1290.69 5947219.56 560047.84 MWD+IFR-AK-CAZ-SC 3349.29 59.73 61.83 2463.12 2353.42 1211.46 1363.42 5947259.54 560120.25 MWD+IFR-AK-CAZ-SC 3443.96 59.44 65.76 2511.06 2401.36 1247.50 1436.65 5947296.16 560193.19 MWD+IFR-AK-CAZ-SC 3537.78 59.12 70.40 2559.01 2449.31 1277.60 1511.44 5947326.84 560267.73 MWD+IFR-AK-CAZ-SC 3633.89 58.32 74.65 2608.92 2499.22 1302.27 1589.75 5947352.12 560345.85 MWD+IFR-AK-CAZ-SC ~ 3728.68 58.19 80.31 2658.83 2549.13 1319.74 1668.40 5947370.19 560424.34 MWD+IFR-AK-CAZ-SC 3822.92 58.63 85.34 2708.22 2598.52 1329.75 1748.00 5947380.83 560503.86 MWD+IFR-AK-CAZ-SC 3920.15 58.75 90.21 2758.77 2649.07 1332.97 1830.97 5947384.69 560586.80 MWD+IFR-AK-CAZ-SC 4016.73 57.89 96.43 2809.52 2699.82 1328.24 1912.96 5947380.60 560668.81 MWD+IFR-AK-CAZ-SC ICI 4109.70 58.93 105.03 2858.29 2748.59 1313.48 1990.65 5947366.45 560746.61 MWD+IFR-AK-CAZ-SC 4205.49 58.97 109.97 2907.72 2798.02 1288.82 2068.88 5947342.40 560825.02 MWD+IFR-AK-CAZ-SC 4302.30 59.16 115.17 2957.51 2847.81 1256.96 2145.52 5947311.14 560901.90 MWD+IFR-AK-CAZ-SC 4396.10 58.94 118.87 3005.76 2896.06 1220.43 2217.16 5947275.17 560973.82 MWD+IFR-AK-CAZ-SC 4489.53 58.62 122.32 3054.20 2944.50 1179.77 2285.93 5947235.06 561042.89 MWD+IFR-AK-CAZ-SC 4586.40 58.36 128.27 3104.86 2995.16 1132.09 2353.29 5947187.91 561110.61 MWD+IFR-AK-CAZ-SC 4680.37 58.90 131.04 3153.79 3044.09 1080.89 2415.05 5947137.20 561172.77 MWD+IFR-AK-CAZ-SC ~I 4775.85 61.69 130.15 3201.10 3091.40 1026.94 2478.02 5947083.75 561236.15 MWD+IFR-AK-CAZ-SC 4868.62 62.42 130.01 3244.57 3134.87 974.18 2540.72 5947031.48 561299.26 MWD+IFR-AK-CAZ-SC 4966.54 63.06 130.13 3289.42 3179.72 918.14 2607.34 5946975.98 561366.30 MWD+IFR-AK-CAZ-SC 5060.87 62.79 132.90 3332.36 3222.66 862.48 2670.22 5946920.81 561429.61 MWD+IFR-AK-CAZ-SC 5156.49 63.60 136.59 3375.49 3265.79 802.41 2730.81 5946861.22 561490.67 MWD+IFR-AK-CAZ-SC 5251.33 64.45 139.73 3417.04 3307.34 738.90 2787.67 5946798.16 561548.01 MWD+IFR-AK-CAZ-SC j 5346.95 67.81 145.86 3455.76 3346.06 669.27 2840.45 5946728.95 561601.33 MWD+IFR-AK-CAZ-SC 5442.23 69.73 151.57 3490.28 3380.58 593.40 2886.52 5946653.45 561647.99 MWD+IFR-AK-CAZ-SC 'll 5537.26 73.47 156.74 3520.29 3410.59 512.27 2925.77 5946572.64 561687.86 MWD+IFR-AK-CAZ-SC 5631.47 77.44 159.97 3543.95 3434.25 427.53 2959.37 5946488.18 561722.12 MWD+IFR-AK-CAZ-SC 5693.55 78.30 162.00 3557.00 3447.30 370.16 2979.15 5946430.96 561742.34 MWD+IFR-AK-CAZ-SC 5723.72 78.56 161.64 3563.05 3453.35 342.07 2988.37 5946402.95 561751.78 MWD+IFR-AK-CAZ-SC 5820.08 79.35 163.42 3581.51 3471.81 251.87 3016.76 5946312.98 561780.87 MWD+IFR-AK-CAZ-SC 5912.60 79.95 165.42 3598.14 3488.44 164.20 3041.20 5946225.51 561805.99 MWD+IFR-AK-CAZ-SC 6010.65 80.83 165.32 3614.51 3504.81 70.66 3065.62 5946132.18 561831.14 MWD+IFR-AK-CAZ-SC 6108.38 78.58 166.72 3631.97 3522.27 -22.64 3088.85 5946039.07 561855.09 MWD+IFR-AK-CAZ-SC 6200.88 80.95 169.74 3648.41 3538.71 -111.74 3107.40 5945950.13 561874.34 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 14:20:31 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-103, True North Sitr. Kuparuk 1J Pad Vertical (TVD) Reference: 1J-103PB3: 109.7 Well: 1J-103 Section (~:S)Reference: Wekl (O.OON,O.OOE,180.OOAZiJ ~~'cllpath: -1J-103PB3 Survey Calculation Dtethod: Minimum Curvature Db: Oracle S u i~ e~ __ ?~iD [ncl Azim TVD Sys TVD N/S E/W MapIV MapE Tool ft deg deg ft ft ft ft ft ft ' 6297.45 82.26 173.71 3662.51 3552.81 -206.26 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC 6391.65 81.33 178.56 3675.97 3566.27 -299.25 3127.43 5945762.80 561895.83 MWD+IFR-AK-CAZ-SC 6487.67 81.08 179.77 3690.65 3580.95 -394.13 3128.81 5945667.94 561897.95 MWD+IFR-AK-CAZ-SC 6583.07 80.89 179.23 3705.60 3595.90 -488.35 3129.64 5945573.74 561899.51 MWD+IFR-AK-CAZ-SC 6678.31 80.49 179.11 3721.00 3611.30 -582.32 3131.00 5945479.79 561901.61 MWD+IFR-AK-CAZ-SC 6773.62 81.08 178.54 3736.27 3626.57 -676.38 3132.93 5945385.75 561904.27 MWD+IFR-AK-CAZ-SC 6868.55 80.40 178.37 3751.54 3641.84 -770.04 3135.45 5945292.13 561907.53 MWD+IFR-AK-CAZ-SC 6963.65 79.76 178.52 3767.93 3658.23 -863.68 3138.00 5945198.52 561910.80 MWD+IFR-AK-CAZ-SC 6992.22 79.88 178.11 3772.97 3663.27 -891.79 3138.82 5945170.42 561911.85 MWD+IFR-AK-CAZ-SC 7025.39 80.26 178.29 3778.69 3668.99 -924.45 3139.85 5945137.77 561913.13 MWD+IFR-AK-CAZ-SC 7058.48 81.32 178.39 3783.99 3674.29 -957.10 3140.80 5945105.14 561914.33 MWD+IFR-AK-CAZ-SC 7093.85 84.49 179.55 3788.36 3678.66 -992.18 3141.42 5945070.06 561915.23 MWD+IFR-AK-CAZ-SC 7142.91 88.77 178.46 3791.24 3681.54 -1041.14 3142.28 5945021.11 561916.46 MWD+IFR-AK-CAZ-SC 7206.40 89.60 177.05 3792.15 3682.45 -1104.57 3144.76 5944957.71 561919.45 MWD+IFR-AK-CAZ-SC 7268.27 92.26 177.46 3791.14 3681.44 -1166.36 3147.73 5944895.95 561922.89 MWD+IFR-AK-CAZ-SC 7304.48 91.65 177.09 3789.91 3680.21 -1202.51 3149.45 5944859.83 561924.89 MWD+IFR-AK-CAZ-SC ~ 7348.54 89.47 178.03 3789.48 3679.78 -1246.52 3151.32 5944815.83 561927.11 MWD+IFR-AK-CAZ-SC 7400.70 89.22 178.54 3790.07 3680.37 -1298.65 3152.88 5944763.72 561929.08 MWD+IFR-AK-CAZ-SC 7448.29 89.30 179.79 3790.69 3680.99 -1346.23 3153.58 5944716.15 561930.14 MWD+IFR-AK-CAZ-SC 7495.53 88.62 179.26 3791.54 3681.84 -1393.46 3153.97 5944668.93 561930.90 MWD+IFR-AK-CAZ-SC I 7545.95 88.56 179.62 3792.78 3683.08 -1443.87 3154.46 5944618.53 561931.79 MWD+IFR-AK-CAZ-SC 7593.56 89.07 179.45 3793.77 3684.07 -1491.46 3154.85 5944570.95 561932.55 MWD+IFR-AK-CAZ-SC 7641.22 89.30 179.07 3794.45 3684.75 -1539.12 3155.46 5944523.31 561933.53 MWD+IFR-AK-CAZ-SC ~ 7689.54 89.43 179.49 3794.98 3685.28 -1587.43 3156.07 5944475.00 561934.52 MWD+IFR-AK-CAZ-SC 7758.21 91.03 179.21 3794.71 3685.01 -1656.09 3156.85 5944406.36 561935.83 MWD+IFR-AK-CAZ-SC 7787.72 91.53 178.87 3794.05 3684.35 -1685.59 3157.34 5944376.86 561936.56 MWD+IFR-AK-CAZ-SC i '~ 7836.36 91.45 179.04 3792.78 3683.08 -1734.20 3158.23 5944328.26 561937.82 MWD+IFR-AK-CAZ-SC 7883.03 90.82 179.57 3791.86 3682.16 -1780.86 3158.80 5944281.62 561938.75 MWD+IFR-AK-CAZ-SC 7954.03 91.54 179.88 3790.40 3680.70 -1851.85 3159.14 5944210.64 561939.65 MWD+IFR-AK-CAZ-SC 8002.10 92.04 180.06 3788.90 3679.20 -1899.89 3159.16 5944162.60 561940.05 MWD+IFR-AK-CAZ-SC 8045.70 92.36 180.42 3787.22 3677.52 -1943.46 3158.98 5944119.04 561940.21 MWD+IFR-AK-CAZ-SC 8082.21 88.71 179.56 3786.88 3677.18 -1979.96 3158.98 5944082.54 561940.50 MWD+IFR-AK-CAZ-SC 8099.21 90.54 179.14 3786.99 3677.29 -1996.96 3159.18 5944065.55 561940.82 MWD+IFR-AK-CAZ-SC 8134.84 92.45 178.40 3786.06 3676.36 -2032.57 3159.94 5944029.95 561941.86 MWD+IFR-AK-CAZ-SC 8160.09 94.78 178.91 3784.47 3674.77 -2057.76 3160.53 5944004.77 561942.65 MWD+IFR-AK-CAZ-SC 8196.13 93.70 178.16 3781.81 3672.11 -2093.69 3161.45 5943968.85 561943.85 MWD+IFR-AK-CAZ-SC 8220.70 94.90 178.79 3779.96 3670.26 -2118.18 3162.10 5943944.37 561944.70 MWD+IFR-AK-CAZ-SC 8263.78 92.66 176.15 3777.12 3667.42 -2161.12 3164.00 5943901.45 561946.93 MWD+IFR-AK-CAZ-SC 8291.86 92.63 175.82 3775.83 3666.13 -2189.10 3165.97 5943873.49 561949.11 MWD+IFR-AK-CAZ-SC VIII 8324.13 91.57 176.76 3774.64 3664.94 -2221.28 3168.05 5943841.33 561951.45 MWD+IFR-AK-CAZ-SC 8361.61 90.74 178.01 3773.89 3664.19 -2258.71 3169.76 5943803.91 561953.45 MWD+IFR-AK-CAZ-SC 8388.84 89.69 179.16 3773.79 3664.09 -2285.93 3170.44 5943776.70 561954.33 MWD+IFR-AK-CAZ-SC 8456.90 89.87 178.78 3774.05 3664.35 -2353.98 3171.66 5943708.67 561956.09 MWD+IFR-AK-CAZ-SC 8486.06 90.31 178.71 3774.00 3664.30 -2383.13 3172.30 5943679.53 561956.95 MWD+IFR-AK-CAZ-SC 8534.01 89.35 179.60 3774.14 3664.44 -2431.07 3173.01 5943631.60 561958.04 MWD+IFR-AK-CAZ-SC 8583.29 88.94 179.71 3774.88 3665.18 -2480.35 3173.30 5943582.33 561958.72 MWD+IFR-AK-CAZ-SC 8633.77 89.43 179.28 3775.60 3665.90 -2530.82 3173.75 5943531.87 561959.56 MWD+IFR-AK-CAZ-SC 8679.74 90.40 179.62 3775.67 3665.97 -2576.79 3174.19 5943485.91 561960.36 MWD+IFR-AK-CAZ-SC 8728.80 90.11 180.55 3775.45 3665.75 -2625.85 3174.12 5943436.86 561960.67 MWD+IFR-AK-CAZ-SC 8776.90 89.84 180.10 3775.47 3665.77 -2673.95 3173.84 5943388.76 561960.77 MWD+IFR-AK-CAZ-SC 8826.78 90.11 180.55 3775.49 3665.79 -2723.82 3173.56 5943338.89 561960.88 MWD+IFR-AK-CAZ-SC 8873.33 90.35 180.45 3775.30 3665.60 -2770.37 3173.15 5943292.34 561960.83 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. IAatc: 2/712007 Iimc: 14:20:31 Page: -t Field: Kuparuk River Unit Co-ordinate(NE}Reference: WeII: 1J-103, True North I Site:. Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-t03PB3. 109.7 ~ Wrll: 1J-103 Section (VS) Reference: Wefl (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103PB3 Survey Calculation Method: Minimum Curvature Ub: Oracle __ Gnvcv .11D [ncl azim TVD .Sys TVD N/S F./~V MapN NIapE Too! ft deg deg ft ft ft ft ft ft 8922.77 90.39 180.45 3774.98 3665.28 -2819.81 3172.76 5943242.91 561960.83 MWD+IFR-AK-CAZ-SC 8969.62 89.73 181.25 3774.94 3665.24 -2866.65 3172.07 5943196.06 561960.50 MWD+IFR-AK-CAZ-SC 9021.43 88.97 180.48 3775.52 3665.82 -2918.45 3171.29 5943144.26 561960.12 MWD+IFR-AK-CAZ-SC 9066.43 89.21 180.09 3776.24 3666.54 -2963.45 3171.06 5943099.27 561960.25 MWD+IFR-AK-CAZ-SC 9116.85 88.98 180.21 3777.03 3667.33 -3013.86 3170.93 5943048.87 561960.51 MWD+IFR-AK-CAZ-SC 9163.03 89.42 179.49 3777.68 3667.98 -3060.04 3171.05 5943002.70 561960.99 MWD+IFR-AK-CAZ-SC 9215.24 89.47 179.49 3778.18 3668.48 -3112.24 3171.52 5942950.50 561961.86 MWD+IFR-AK-CAZ-SC 9260.47 89.68 179.22 3778.52 3668.82 -3157.47 3172.03 5942905.29 561962.73 MWD+IFR-AK-CAZ-SC 9309.70 89.77 179.16 3778.76 3669.06 -3206.69 3172.72 5942856.07 561963.81 MWD+IFR-AK-CAZ-SC 9356.62 90.03 178.62 3778.84 3669.14 -3253.60 3173.63 5942809.18 561965.08 MWD+IFR-AK-CAZ-SC 9403.52 90.33 178.75 3778.69 3668.99 -3300.49 3174.71 5942762.30 561966.52 MWD+IFR-AK-CAZ-SC 9447.82 90.59 178.73 3778.34 3668.64 -3344.78 3175.68 5942718.03 561967.84 MWD+IFR-AK-CAZ-SC 9495.03 90.82 178.37 3777.75 3668.05 -3391.97 3176.88 5942670.85 561969.41 MWD+IFR-AK-CAZ-SC 9538.18 90.23 178.54 3777.36 3667.66 -3435.10 3178.04 5942627.73 561970.91 MWD+IFR-AK-CAZ-SC 9583.67 90.34 178.21 3777.13 3667.43 -3480.57 3179.33 5942582.28 561972.55 MWD+IFR-AK-CAZ-SC 9628.22 90.40 177.79 3776.85 3667.15 -3525.09 3180.88 5942537.78 561974.45 MWD+IFR-AK-CAZ-SC 9674.61 90.09 177.63 3776.65 3666.95 -3571.45 3182.74 5942491.44 561976.67 MWD+IFR-AK-CAZ-SC 9719.74 90.27 178.30 3776.51 3666.81 -3616.55 3184.34 5942446.36 561978.62 MWD+IFR-AK-CAZ-SC 9765.45 90.10 179.40 3776.36 3666.66 -3662.25 3185.26 5942400.67 561979.90 MWD+IFR-AK-CAZ-SC 9810.49 90.69 179.71 3776.05 3666.35 -3707.29 3185.61 5942355.64 561980.60 MWD+IFR-AK-CAZ-SC ', 9854.53 90.44 180.27 3775.61 3665.91 -3751.32 3185.62 5942311.61 561980.95 MWD+IFR-AK-CAZ-SC :, 9901.35 90.41 180.65 3775.27 3665.57 -3798.14 3185.24 5942264.80 561980.94 MWD+IFR-AK-CAZ-SC 9943.78 90.95 180.67 3774.76 3665.06 -3840.56 3184.75 5942222.38 561980.78 MWD+IFR-AK-CAZ-SC 9991.23 91.62 180.06 3773.70 3664.00 -3888.00 3184.45 5942174.94 561980.85 MWD+IFR-AK-CAZ-SC 10035.40 90.47 180.39 3772.89 3663.19 -3932.16 3184.28 5942130.79 561981.02 MWD+IFR-AK-CAZ-SC 10079.97 89.59 180.07 3772.87 3663.17 -3976.73 3184.10 5942086.22 561981.19 MWD+IFR-AK-CAZ-SC 10125.10 89.98 179.54 3773.04 3663.34 -4021.86 3184.25 5942041.10 561981.69 MWD+IFR-AK-CAZ-SC 10169.69 90.65 180.53 3772.79 3663.09 -4066.45 3184.22 5941996.52 561982.02 MWD+IFR-AK-CAZ-SC 10216.65 90.47 180.86 3772.33 3662.63 -4113.40 3183.65 5941949.56 561981.81 MWD+IFR-AK-CAZ-SC 10261.53 90.10 179.31 3772.11 3662.41 -4158.28 3183.59 5941904.69 561982.10 MWD+IFR-AK-CAZ-SC 10307.54 90.22 179.62 3771.98 3662.28 -4204.29 3184.02 5941858.69 561982.88 MWD+IFR-AK-CAZ-SC 10351.72 89.71 178.91 3772.01 3662.31 -4248.46 3184.58 5941814.53 561983.80 MWD+IFR-AK-CAZ-SC ~ 10398.63 90.90 181.11 3771.76 3662.06 -4295.37 3184.57 5941767.63 561984.15 MWD+IFR-AK-CAZ-SC 10443.32 91.31 182.89 3770.90 3661.20 -4340.02 3183.02 5941722.97 561982.94 MWD+IFR-AK-CAZ-SC i 10488.29 90.39 182.25 3770.23 3660.53 -4384.94 3181.00 5941678.04 561981.28 MWD+IFR-AK-CAZ-SC 10532.89 90.47 181.94 3769.90 3660.20 -4429.51 3179.37 5941633.46 561980.00 MWD+IFR-AK-CAZ-SC 10587.05 91.94 181.93 3768.76 3659.06 -4483.63 3177.54 5941579.34 561978.59 MWD+IFR-AK-CAZ-SC 10624.08 93.12 183.32 3767.12 3657.42 -4520.58 3175.85 5941542.38 561977.18 MWD+IFR-AK-CAZ-SC ~ 10667.70 93.12 183.32 3764.75 3655.05 -4564.06 3173.32 5941498.88 561975.00 PROJECTED to TD Time Logs _ ' I I Date From To Dur S De th E. Depth Phase Code Subcode T COM _ 12/12/2006 13:30 14:15 0.75 80 80 SURFA DRILL RURD P Held PJSM then RU Sperry Sun's Gyro using Sperry Gyro special E-line unit. # 10026771 Bi Do 14:15 15:00 0.75 80 223 SURFA DRILL TRIP P RIH from 80' to 175' then washed 48' to btm at 223'. 15:00 00:00 9.00 223 720 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 223' to 720' MD/717' TVD (497'), ART 2.83 hrs, AST 2.99 hrs, ran 6 gyro's and took approx 90 min's. 15-22K wob, 60 rpm's, 112, spm, 470 gpm at 1,000 psi, on/off btm torque 1 K ft-Ibs, rot wt 75K u wt 74K, do wt 76K 12/13/2006 00:00 12:00 12.00 720 1,672 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 720' to 1,672' MD/ 1,549' TVD (952') ART 1.96 hrs, AST 7.00 hrs, RD gyro at 800' 12:00 00:00 12.00 1,672 2,935 SURFA DRILL DDRL P Directionally drilled from 1,672' to 2,935' MD/ 2,248' TVD (1,263') ART 3.79 hrs, AST 4.09 hrs. (10 3/4" csg oint 12/14/2006 00:00 03:30 3.50 2,935 725 SURFA DRILL REAM P Backreamed and POOH from 2,935'to BHA at 725', BROOH every other std to BHA, BROOH at 625 psi, 1,600 psi and 60 r m's with no roblems 03:30 04:00 0.50 725 163 SURFA DRILL TRIP P LD ghost reamer and POOH wet with 5 stds of HWDP to 163'. 04:00 06:30 2.50 163 0 SURFA DRILL PULD P POOH from 163' LD 1 std HWDP and jars, LD std of 8" NMFDC's then LD MWD and motor, downloaded MWD in i e shed and cleared ri floor. 06:30 08:15 1.75 0 0 SURFA CASIN( RURD P RU Doyon's 10 3/4" csg equip. along with Franks fill up tool, changed out elevator bales 08:15 08:45 0.50 0 0 SURFA CASIN( SFTY P Held PJSM with rig crew and tong operator on csg running details and hazard assesment for the ~ob. 08:45 14:00 5.25 0 2,925 SURFA CASIN( RNCS P RIH with 10 3/4" csg and landed same at 2,925', RIH with no problems, MU 2 jt shoe track, thread locked same and checked floats, cont. RIH with 10 3/4", 45.5#, L-80, BTC csg, ran 69 jts csg then MU Vetco Gray hanger and landed csg in the hanger, initial st wt up 168K, do wt 88K. Ran a total of 71 jts, total with hanger and float equip is 2,895', Ran 24 bowspring cent. with 2 stop rings per well plan, 2 per jt 1 st jt, then 1/jt next 19 jts, 1 on jts 60 & 61 (440 & 480') and 1 cent. inside of the conductor, Landed 10 3/4"csg with shoe at 2,925' MD/ 2,243' TVD' and float collar at 2,841'. 14:00 14:45 0.75 2,925 2,925 SURFA CEME~ CIRC P Circ btms up thru Franks fill up tool staging pump rate up to 50 spm, 5 bpm at 300 psi, reciprocated pipe with a st wt u of 164K, do wt 90K ~~ ~ P~€~ ~f 37 __ _.-i J Time Logs Date Frorn To Dur _ S De th E De th Phase Code Subcode T COM ____ 12/14/2006 14:45 15:15 0.50 2,925 2,925 SURFA CEME~ RURD P RD Franks fill up tool and MU Dowell cement head. 15:15 17:15 2.00 2,925 2,925 SURFA CEME~ CIRC P Cont to circ and cond mud for cementing, staged pump rate up to 60 spm, 6 bpm at 250 psi, st wt up 164K, do wt 90K, initial mud was 9.4 ppg, 200 vis, PV 36 and YP of 60 and gels 19/35, conditioned mud to 9.0 ppg, 40 vis, PV 16 and YP 14 and gels 3/4, held PJSM with crew, Dowell and ASRC vac truck drivers on cement job while circ. 17:15 19:15 2.00 2,925 2,925 SURFA CEME~ DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 40 add. bbls of CW 100 at 8.3 ppg, pumped 50 bbls of 10.5 ppg mudpush with red dye, ave 3 bpm at 100 psi. Dropped btm plug. Mixed and pumped 456 bbls, 545 sxs of Arctic set lite cement at 10.7 ppg and 4.51 yield with additives, ave 6.5 bpm at 225 psi, followed with 77 bbls, 177 sxs of Deepcrete cement at 12.0 ppg and 2.47 yield with additives, ave 5.75 bpm at 425 psi reciprocating pipe 8' with full returns. Shut down and dro ed to lu . 19:15 20:00 0.75 2,925 2,925 SURFA CEME~ DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.0 ppg mud, ave 7 bpm, initial pressure was 500 psi, max pressure at 7 bpm was 825psi, while reciprocating pipe 155 bbls into the displacement csg began to stick off btm, landed csg in the hanger with 60K do wt., began to see It wt cmt back, Cont to displace cement and bumped plug on calc displacement of 274 bbls, pressured up to 1,300 psi and held for a few minutes, bled off and checked floats and ck'd ok. CIP at 20:00 hrs, had 110 bbls of good 10.7 ppg cement back at surface. 20:00 22:00 2.00 2,925 2,925 SURFA CEME~ RURD P RD cement head, LD landing jt, flushed out diverter and cleared rig floor. 22:00 00:00 2.00 0 0 SURFA WELCT NUND P ND Diverter and line 12/15/2006 00:00 03:45 3.75 0 0 SURFA WELCT NUND P NU Vetco Gray's MB 222 wellhead, attempted to test O-ring and wouldn't test, ND and changed out same, NU and retested to 5,000 si and ck'd ok. 03:45 05:45 2.00 0 0 SURFA WELCT NUND P NU BOP stack, choke and kill lines 05:45 08:15 2.50 0 0 SURFA RIGMN SVRG P Serviced top drive, changed out saver sub and ins ected IBOP actuator. ~~ Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T COM _ 12/15/2006 08:15 08:45 0.50 0 0 SURFA DRILL PULD P Installed riser on stack and installed wear bushin 08:45 12:00 3.25 0 2,276 SURFA DRILL PULD P MU mule shoe, PU and RIH with 72 jts of 5" DP out of the pipe shed to 2,276' 12:00 13:15 1.25 2,276 0 SURFA DRILL TRIP P POOH standing back 24 stds 5" DP 13:15 13:30 0.25 0 0 SURFA DRILL PULD P Pulled wear bushing 13:30 19:30 6.00 0 0 SURFA WELCT BOPE P RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 3,000 psi high including annular, tested with 4", 5" and 7 5/8" testjts. Tested Koomey, starting press. 3,000 psi after functioning 1,850 psi, took 40 seconds to build 200 psi, 3 min 8 sec. to full recovery NOTE: John Crisp with AOGCC witnessed the testin . 19:30 19:45 0.25 0 0 SURFA DRILL PULD P Installed wear bushing 19:45 20:45 1.00 0 0 SURFA DRILL PULD P LD 3 stds of excess HWDP out of the derrick, MU 'ars to 1 std HWDP. 20:45 00:00 3.25 0 357 SURFA DRILL PULD P MU 9 7/8" BHA #2 RIH to 357', MU bit #2 on 1.5 deg bend motor and MWD, oriented and uploaded same, RIH with std of 6 3/4" NMFDC's HWDP and jars to 357', shallow tested MWD then blew down to drive. 12/16/2006 00:00 01:30 1.50 357 2,539 SURFA DRILL TRIP P RIH with BHA #2 from 357' PU 5" DP from i e shed RIH to 2,539' 01:30 02:30 1.00 2,539 2,539 SURFA DRILL SFTY P Held stripping and well kill drill with crew, held apre- and post drill discussion with the crew on both drills. 02:30 02:45 0.25 2,539 2,818 SURFA DRILL TRIP P RIH from 2,539' to 2,818', washing down last 94' at a slow rate and did not tag any cmt. st wt up 100K, do wt 70K 02:45 03:15 0.50 2,818 2,818 SURFA DRILL CIRC P Circ hole to clear DP prior to csg test. Circ at 538 mat 1,300 si. 03:15 04:15 1.00 2,818 2,818 SURFA CASIN( DHEQ P RU and tested 10 3/4" csg to 3,000 si for 30 min, ood test. 04:15 05:15 1.00 2,839 2,935 SURFA CEME~ COCF P RIH from 2,818' and tagged plugs at 2,839', drilled out plugs, flt collar at 2,841', shoe track and flt shoe at 2,925' then cleaned out to TD at 2, 935'. 05:15 05:30 0.25 2,935 2,955 INTRM1 DRILL DRLG P Drilled 20' of new hole to 2,955' MD/2,258' TVD. 05:30 06:30 1.00 2,955 2,955 SURFA DRILL CIRC P Displaced hole over to reconditioned 9.0 LSND mud. 06:30 07:30 1.00 2,955 2,955 SURFA DRILL LOT P RU and performed a LOT to 13.7 ppg EMW, 540 psi at 2,243' TVD with 9.0 MW. _~ s ~ m ~ F~~~ 4 crf ?' CJ n Time Lo~_ _ - - - ---- Date _ _ From To______Dur S: De th E. Depth_Phase Code Subcode T COM _ 12/16/2006 07:30 15:00 7.50 2,955 3,958 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole from 2,955' to 3,958' MD/2,727' TVD, (1,003') ART 2.67 hrs, AST 2.20 hrs, clean hole ECD 9.6 ppg, ave ECD 10.0 ,ave BGG 40 units. 15:00 15:45 0.75 3,958 3,863 INTRM1 DRILL CIRC P POOH 1 std to 3,863' and circ btms up for open hole LOT, circ at 550 gpm at 1,400 si 15:45 16:30 0.75 3,863 3,958 INTRM1 DRILL LOT P Performed a open hole LOT to 13.6 ppg EMW with 9.1 ppg MW, 2,243' TVD and 520 si, RIH to 3,958'. 16:30 00:00 7.50 3,958 4,624 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole from 3,958' to 4,624" MD/ 3,124' TVD (666') ART 3.4 hrs, AST 4.06 hrs, ave BGG 40 units, max gas 85 units, 8.9 ppg MW, ave ECD 10.1 ppg, no sweeps um ed. 12/17/2006 00:00 16:30 16.50 4,624 5,956 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole from 4,624' to 5,956' MD/ 3,605' TVD (1,332') ART 6.4 hrs, AST 4.74 hrs, ave BGG 45 units max 122 units, 9.0 ppg MW, ave ECD 10.4 ppg, rig's Elora co brake on drawworks went out 16:30 20:15 3.75 5,956 2,913 INTRM1 DRILL REAM T Monitored well-static, BROOH from 5,956' to inside 10 3/4" csg shoe to 2,913', attempted to pull on elevators and swabbed, attempted to pump out and packed off, BROOH at 500 gpm, 1,150 si and 80 r m's. 20:15 00:00 3.75 2,913 2,913 INTRM1 RIGMN RGRP T Held PJSM then removed Emalgco brake from rig floor in preperation to chan a out. 12/18/2006 00:00 12:00 12.00 2,913 2,913 INTRM1 RIGMN RGRP T Cont. to work on drawworks dynamatic Emalgco brake in truck shop, attempted to remove hub from shaft with no success, monitored well on tri tank 12:00 20:00 8.00 2,913 2,913 INTRM1 RIGMN RGRP T Cont to work on Emalgco brake, received new hub and installed same on new brake, circ 1 complete circ while working on brake, circ at 100 m at 225 si. 20:00 00:00 4.00 2,913 2,913 INTRM1 RIGMN RGRP T Held PJSM then PU and installed brake on rig floor by lifting over windwall, be an to hook u same. 12/19/2006 00:00 00:15 0.25 2,913 2,913 INTRM1 RIGMN SFTY T PJSM -Non-Routine task -Repair Elora o Brake 00:15 04:00 3.75 2,913 2,913 INTRM1 RIGMN RGRP T Finish repairing and Install Elmago Brake on Drawworks 04:00 04:30 0.50 2,913 2,913 INTRM1 RIGMN OTHR T Circu BU -Circu to condition mud _ _ e _ _ T'a-~€~ ~ of ~~ ~ • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM ~ 12/19/2006 04:30 07:15 2.75 2,913 5,956 INTRM1 RIGMN OTHR T TIH -Ream spots 3677' to 3961' - FR 375 gpm, PP 750 psi, 50 RPMs -TIH on elevators 3961' with out any trouble, Wash and ream to bttm 4977' to 5956'. FR 440 gpm, PP1150 psi, 60 rpms. **NOTE** Repair to barke workin well - No roblems noted. 07:15 12:00 4.75 5,956 6,244 INTRM1 DRILL DDRL P Drlg w/ 1.5 Motor 5956' MD to 6244' MD/ 3654' TVD. ADT 2.73, ART 1.98 AST .75 Jar Hrs 23.77, Up wt 125k, Dn wt 92k, Rot wt 105k, Torq on btm 8k, off btm 7k , Av ECDs 10.02ppg, Max gas 319 units, Concreations @ 6009', 6072' 12:00 00:00 12.00 6,244 7,075 INTRM1 DRILL DDRL P Drlg w/ 1.5 Motor 6244 MD to 7075' MD/ 3787' TVD. ADT 7.39, ART 4.76 AST 2.63 Jar Hrs 31.16, Up wt 134k, Dn wt 90k, Rot wt 108k, Torq on btm 9k, off btm 7k , Av ECDs 10.40ppg, Max gas 119 units, Concreations @ 6387', 6406' 12/20/2006 00:00 00:45 0.75 7,075 7,137 INTRM1 DRILL DDRL P Drlg w/ 1.5 deg Motor 7075' to 7137' MD / 3790' TVD, ADT .89, AST .79, ART .1, Jars total hrs 32.05, Up wt 135k, Dn wt 92k, Rot wt 100k, ECDs 10.26, Torq 6-8k on btm, Max gas 94 units 00:45 06:45 6.00 7,137 2,925 INTRM1 DRILL REAM P Circu 5 min - BROOH at drlg rates PR 600 gpm, 90 RPMs, After BR 5 stds we attempted to BR 1 and then Pull one on elevators. After doing this for 3 sets we saw a drag increase of 25-30k. We BR several more out and then tried to alternate again with the same results. Decision was made to con't and BROOH all stds to the shoe at 2925' 06:45 07:15 0.50 2,925 2,925 INTRM1 DRILL CIRC P Circu and spot tube pill across csg - Monitorwell -Static 07:15 08:00 0.75 2,925 357 INTRM1 DRILL TRIP P Con't POOH on elevators 2925' to 357' - No Problems -Observe proper hole fill. 08:00 08:30 0.50 357 190 INTRM1 DRILL TRIP P POOH and std bk HWDP & Jars - LD NM Flex DC's 3 08:30 09:15 0.75 190 190 INTRM1 DRILL SRVY P Down Load MWD 09:15 10:15 1.00 190 0 INTRM1 DRILL TRIP P Con't POOH - UD BHA #2 10:15 10:30 0.25 0 0 INTRM1 DRILL PULD P Clear all tools from rig floor and Wash clean 10:30 11:00 0.50 0 0 INTRM1 DRILL PULD P Attempt to pull wear bushing -Had some kind of obstruction in BOP stack. ~~ e_ _ __~ Page ti oaf 3 ~ • :Time Logs Date From To Dur S Depth E. De th Phase _ Code Subcode T _ COM_ _____ _ 12/20/200611:00 12:00 1.00 0 0 INTRM1 WELCT EORP T Attempt to determain obstruction in BOP stack @ blinds level. Notified Team Leader. Waiver from AOGCC was ask for and given to open doors at blind level to recover ob'ect. 12:00 13:30 1.50 0 0 INTRM1 WELCT EQRP T After receiving a-mail copy of AOGCC waiver the doors on the BOPs were opened at the blinds. A 24" chain tong handle and head were found. The head was hung on the blinds slid slot with the handle looking up and laying across the BOPs ID. It appeared that the chain had broken off at the point where it is attached to the tools head. The chain was not found. 13:30 14:30 1.00 0 0 INTRM1 CASIN( RURD P RU to run 7 5/8" Csg 14:30 14:45 0.25 0 0 INTRM1 CASIN( SFTY P PJSM -Discuss csg detail - Do hazard accessment of all know hazards associated with runnin cs . 14:45 18:00 3.25 0 855 INTRM1 CASIN( RNCS P Run FS, TL & FC jts & baker-loc all Conn. Fiil and Check float equip "OK". Conn to run csg to 855' -Franks tool ck valve leakin . 18:00 18:30 0.50 855 855 INTRM1 CASIN( RURD T Attempt to repair Franks tool -Inspect Ck valve - Re-install on tool 18:30 21:15 2.75 855 2,925 INTRMI CASIN( RNCS P Run 7- 5/8" 29.6# L80 BTCM csg f/ 855' to 2925' MD -Franks tool still leaking. Made the decision to fill every 10 jts to minimize mud dripping on work area. 21:15 22:00 0.75 2,925 2,925 INTRM1 CASINC CIRC P Circu BU at surface shoe 2925' MD - PR 5 b m, PP 350 si 22:00 00:00 2.00 2,925 3,824 INTRM1 CASIN( RNCS P Run 7- 5/8" 29.6# L80 BTCM csg f/ 2925' to 3824' MD -Franks tool still leakin . Fillin eve 10 ~ts. 12/21/2006 00:00 00:15 0.25 3,824 3,824 INTRM1 CASIN( SFTY P PJSM on running csg -Discuss all know hazards & cs detail 00:15 03:30 3.25 3,824 7,134 INTRM1 CASIN( RNCS P Con't to run 7- 5/8" csg 3824' to 7134' MD per csg detail. Ran 167 jts csg, 3 - u 'ts - No Problems runnin cs 03:30 04:30 1.00 7,134 7,137 INTRM1 CASINC CIRC P Circu BU+with Franks Tool - 3550 stks, Work up PR to 7 bpm, = 700psi, U wt 180k, Dn wt 75k 04:30 05:00 0.50 7,137 7,137 INTRM1 CASINC RURD P LD Franks Tool - Blow do Top Drive - Install CMT head on Cs 05:00 06:30 1.50 7,137 7,137 INTRM1 CEME~ CIRC P Con't to Circu and condition for CMT, PR 7 b m, PP 450 si , ~ f'ay~: 7 of ~7 ~ • • Time';Logs Date From __ To _ _ Dur S De th E. De th Phase Code Subcode T _ COM 12/21/2006 06:30 09:45 3.25 7,137 _ 7,137 INTRM1 CEME~ CIRC P Prime up CMT Unit- Pump 10 bbls CW100, Test Lines to 3500 psi, Cont pump 65 bbls CW100, Pump 75 bbls Mud push @ 11.0 ppg, Drop bttm plug, Mix and pump 164.5 bbls -12.5 ppg tail cmt, Av PR 5.5 bpm, Wash up lines to cellar, Drop top plug, Kick out and displace with rig pumps. Av PR 7 bpm, Bumped at calcu stks 3029 - 30 spm = 950 psi -Hold 500 psi over for 5 min (1450psi) Bleed off -Floats held - CIP @ 9:30 AM - After csg sticking off bttm shoe 7130' MD / 3790' TVD 09:45 10:00 0.25 7,137 7,137 INTRM1 CASIN( SFTY P PJSM -Pick Up BOPS- Review PU rocedure -Discuss all know hazards 10:00 11:00 1.00 7,137 7,137 INTRM1 CASIN( NUND P PU BOPs and Well Head -Set csg on sli s as tanned w/ 80k 11:00 12:00 1.00 7,137 7,137 INTRM1 CASIN( NUND P Start cutting 7- 518" csg with WACHS numatic cutter 12:00 12:15 0.25 7,137 7,137 INTRM1 CASIN( SFTY P PJSM - On NU & ND -review rocedure, discuss all know hazards. 12:15 13:15 1.00 .7,137 7,137 INTRM1 CASIN( NUND P Con't cutting casing / LD Cut Off 13:15 13:30 0.25 7,137 7,137 INTRM1 CASIN( NUND P Vetco Gray installed packoff 13:30 14:00 0.50 7,137 7,137 INTRM1 CASIN( NUND P NU BOPS 14:00 14:30 0.50 7,137 7,137 INTRM1 CASIN( DHEO P Vetco rep inject seals -Test 7- 5/8" packoff to 3500 psi / 10 min "OK" (Ty Kunutson 14:30 15:15 0.75 7,137 7,137 INTRM1 DRILL LOT P Preform LOT on 10- 3/4" X 7- 5/8" Ann. -Followed with 40 bbls H2o flush 2.1 b m , 740 si on chart. 15:15 23:30 8.25 7,137 7,137 INTRM1 WELCT BOPE P PJSM -Open all ram doors on BOPS and inspect for debris or damage. "Non found" -Change lower pipe rams to 4.5" and close all doors. Test Annular and VBRs with 4" test joint, Test blinds, Test 4.5" rams w/ 4.5" test joint. Body test chock hose where removed. All test 250psi Lo and 3000 psi High. Si-Ops -Pump final flush 85bbls on 10-3/4" X 7- 5/8" Annulus for a total of 125 bbls. Final pumping 23 s m = 700 si 23:30 00:00 0.50 7,137 7,137 INTRM1 DRILL SFTY P PJSM -Review procedure -Discuss recent incident -Review all know hazards. 12/22/2006 00:00 00:15 0.25 7,137 7,137 INTRM1 DRILL SFTY P PJSM -Review procedure Cut Drill Line -Discuss recent incident concerning cutting drill line. Review procedure to CO saver sub. Discussed all know hazards - - _ _ ~ ~ ~_______ . ~ ~ _ Pa,1~ 3 at 37 • ~ Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 12/22/2006 00:15 00:45 0.50 7,137 7,137 INTRM1 RIGMN SVRG P Con't cut drill line (85') (Sim-ops -Hot Oil pump freeze protect on OA 10- 3/4" X 7- 5/8" - PR 1.3 bpm, PP 950 psi -Pumped total 85 bbls (bttm freeze rotect 2141' MD 00:45 01:15 0.50 7,137 7,137 INTRM1 WELCT BOPE P RU and Install wear bushing - LD settin tool and test ~t. 01:15 03:15 2.00 7,137 7,137 INTRM1 DRILL RURD P Change out Saver Sub to 4" XT39 03:15 03:30 0.25 7,137 7,137 INTRM1 DRILL SFTY P PJSM on Laying down drill pipe - Review procedure -Review and discuss all know hazards. 03:30 10:15 6.75 7,137 7,137 INTRM1 DRILL PULD P UD 5 jts HWDP, Jars and 216 jts 5" DP out of mouse hole 10:15 10:30 0.25 7,137 7,137 INTRM1 DRILL RURD P UD mouse -Clear rig floor of all tools and subs 10:30 12:00 1.50 7,137 7,137 INTRM1 DRILL RURD P CO elevators, CO IR heads to 4", PU 4"Mule Shoe. Single in hole with 4" DP (25 jts) Drift DP on skate as run w/ 2"drift 12:00 12:15 0.25 7,137 7,137 INTRM1 DRILL SFTY P PJSM -Picking up dri!! pipe -Discuss all know hazards 12:15 13:30 1.25 7,137 7,137 INTRM1 DRILL PULD P Con't Single in the hole with slick 4" DP from pipe shed -Total 95 jts (total 40 stds icked u Drift to 2" 13:30 14:45 1.25 7,137 7,137 INTRM1 DRILL PULD P POOH and Std Bk 40 stds slick 4" XT39 ODS 14:45 19:00 4.25 7,137 7,137 INTRM1 DRILL PULD P RIH PU 4" XT39 DP w/ WWT SS, 1/jt in middle. Clean rig floor -Pull up 44 Lo Tad tools to ri floor 19:00 00:00 5.00 7,137 7,137 INTRM1 DRILL PULD P POOH Std Bk in derrick 45 stds DS Installed 44 Lo Tad tools 1 /std 12/23/2006 00:00 00:15 0.25 7,137 7,137 INTRM1 DRILL SFTY P PJSM on PU Hybred Push Pipe - Discuss all know hazards 00:15 03:45 3.50 7,137 7,137 INTRM1 DRILL PULD P PU 15 stds Hybred Push Pipe (2- 4 3/4" DCs + 1 HWDP) PU 7 stds HWDP -Std all bk in derrick 03:45 04:00 0.25 7,137 7,137 INTRM1 DRILL SFTY P PJSM on PU & MU BHA #3 04:00 05:15 1.25 7,137 7,137 INTRM1 DRILL PULD P PU & MU BHA #3, PU bit, MM, NM Flt sub, stab, DM HOC, SlimPhase 4 , w/ DGR & EWR Phase, TM collar. 05:15 05:45 0.50 7,137 7,137 INTRM1 DRILL SRVY P Up Load MWD 05:45 06:45 1.00 7,137 7,137 INTRM1 DRILL TRIP P Con't TIH t/ 556' MD 06:45 07:15 0.50 7,137 7,137 INTRM1 DRILL SRVY P Shallow Test MWD - 78 SPM / 1375 si "OK" -Blow do To Drive 07:15 11:30 4.25 7,137 7,137 INTRM1 DRILL TRIP P Con't TIH f/ 556 to 6965' MD (PU total 150 jts from shed) Filled pipe every 2000' - U wt 106k, Dn wt 74k 11:30 12:00 0.50 7,137 7,130 INTRM1 DRILL TRIP P Pump down slow to tag CMT- 10 SPM / 200 si - Ta CMT 7050' 8k 12:00 12:30 0.50 7,130 7,130 INTRM1 DRILL CIRC P Circu air from system for casing test - Up wt 115k, Dn wt 75k, Rot wt 85k, Tor off bttm 50 r m = 4-5k • Time Los -g- - ---- - - - - _: Date From To Dur S. De th E. Death Phase Code Subcode T COM 12/23/2006 12;30 13:15 0.75 7,130 7,130 INTRM1 DRILL DHEQ P Test Casing to 3000 psi for 30 min and chart -Test "OK" Lost 65 si 30 min 13:15 14:15 1.00 7,137 7,137 INTRM1 CEMEI~ COCF P Drill FC, Shoe Track, FS and rat hole to 7137'MD 14:15 14:30 0.25 7,137 7,160 INTRM1 DRILL DRLG P Drlg new hole 7137' MD to 7160' MD ART .25 hr 14:30 15:30 1.00 7,160 7,160 INTRM1 DRILL CIRC P Circu BU for LOT -Circu until mud is uniform in and out - PR 300 gpm / 2600 psi, Rot 50 rpm and recip string 7125' - 7060' -Clean hole ECD =9.23 15:30 16:00 0.50 7,160 7,160 INTRM1 DRILL LOT P Preform LOT - 8.4 ppg mud, 3791' TVD, SP 1250 si = EMW 14.7 16:00 17:45 1.75 7,160 7,252 PROD1 DRILL DDRL P Drlg 6.75" hole w/Motor 7160' MD to 7252' MD / 3791' TVD - PU for Conn WO track extension down -Broke fittin on tube oil s stem. 17:45 20:30 2.75 7,252 7,252 PROD1 RIGMN RGRP T Broken fitting on tube oil system - Repairsame - Un-Controled release 1/2 gal tube on rig floor. Reported to Securit - Cleaned u 100% 20:30 00:00 3.50 7,252 7,445 PROD1 DRILL DDRL P Drlg 6.75" hole w/Motor 7252' MD to 7445' MD / 3790' TVD, ART 2.29 hrs, AST .82 hrs, ADT 3.11 hrs, Jar hrs 3.11, Up wt 120k, Dn wt 68k, Rot wt 85k, Torq on & off bttm 4-5k, ECDs 9.82, Max Gas 108 units, Concretions @ 7132', 7168', 7180', 7206', 7265' _ Total 52' 12/24/2006 00:00 00:15 0.25 7,445 7,445 PROD1 DRILL SFTY P PJSM on drlg operations (Hazard Reco nition 00:15 06:00 5.75 7,445 7,983 PROD1 DRILL DDRL P Drlg 6.75" hole w/Motor 7445' to 7983' MD / 2395' TVD,ADT 2.90 hrs, AST 0.38 hrs, ART 2.52 hrs, Jar Total hrs 6.01 06:00 07:30 1.50 7,950 7,950 PROD1 DRILL CIRC T Picked up off of concretion -Hole packing off -Taking wt 10-15k OFF bttm -Pump Wt/ High sweep to sweep hole -When sweep had pumped surface to surface WWl- SS rubber was noted at shakers. Decision made to POOH 07:30 08:45 1.25 7,950 7,137 PROD1 DRILL TRIP T Pump out of hole to shoe (9 stds) PR 5 bpm 'Note"' Had more SS rubber to shakers.POOH on elevators inspecting WWT SS & Lo Tads for damage. Found 1 SS 3/4 gone Stds # 73 (650' down) 2 more had damage done on std # 74 . At the time the trouble occured we were drilling on std # 80 @ 7983' MD. Rig engineer, Dennis Hartwig ran the numbers on side loads and they showed minimal at this de th. 08:45 09:15 0.50 7,137 7,137 PROD1 DRILL OWFF T At surface shoe -Observe well "Static" -Pump dry job - Blow do top drive __~.~_ .~ _~ .. - ._ g +yq gg C~ • Time Logs ___ -- - __ Date From To Dur S De th E Depth_Phase Code Subcode T COM ____ 12/24/2006 09:15 12:00 2.75 7,137 2,512 PROD1 DRILL TRIP T Con't POOH on elevators f/ 7137' to 2512' MD -SLM - No Problems noted 12:00 12:15 0.25 2,512 2,512 PROD1 DRILL SFTY P PJSM on POOH &SLM Hazard Reco nition 12:15 13:30 1.25 2,512 190 PROD1 DRILL TRIP T Con't POOH -SLM - 2512' to 190' MD - Stand Bk BHA - UD XO & Float sub 13:30 14:45 1.25 190 0 PROD1 DRILL SRVY T Down Load MWD -Drain Motor - Check Bit & Std Bk -Clean Ri Floor 14:45 15:00 0.25 0 0 PROD1 RIGMN RGRP T PJSM - CO roller pin & bushing on DS Top Drive (Hazard Recognition & Ri in -Pro er PPE 15:00 16:30 1.50 0 0 PROD1 RIGMN RGRP T Replace Top Drive Roller Pin and Bushin - DS Lower roller 16:30 17:30 1.00 0 220 PROD1 DRILL PULD T PU BHA #4 - Jars,Bumper sub, Globe Rev basket, XO, Float sub, -Monitor well "Static" 17:30 20:00 2.50 220 7,949 PROD1 DRILL TRIP T TIH (Fill DP every 2000') drop rev ball at 7109' and brk circu @ 7949 - Up wt 100k, Dn wt 73k, Rot wt 83k, Torq 5k, PR 6 b m, PP 1250, RPMs 70 20:00 21:00 1.00 7,949 7,985 PROD1 DRILL MILL T Pump ball to seat (1750 psi @ 6 bpm) wash & tag @ 7983' (No Fill) Mill f/ 7983' - 7984.8', WOB 2-4K - Rorary stalled 10k - Attempt to PU - Stuck -Unable to break loose and PU. Release torq and reduce PR to 1 bpm 21:00 00:00 3.00 7,985 7,980 PROD1 FISH JAR T Work and Jar slowly working up to 150k over. Attempt to work torq down string - We were able to work torq down but string would not rotate. Con't working and Jar @ 150k over -Came free (Up wt 100k, PR 6 bpm, PP 1700 si 12/25/2006 00:00 00:15 0.25 7,985 7,985 PROD1 FISH SFTY T PJSM on TOH - LD Fishing tools & Fish 00:15 02:30 2.25 7,985 208 PROD1 FISH TRIP T Pump dry job, Blow down Top Drive - POOH f/ 7985' MD to 7130' MD -Flow Ck well "Static", Con't POOH 7130' to 208' MD 02:30 03:30 1.00 208 0 PROD1 FISH PULD T Break & UD Reverse Globe Reverse basket, bumper sub, oil jars, float sub & XO 03:30 03:45 0.25 0 0 PROD1 DRILL PULD T Clean and clear rig floor 03:45 04:00 0.25 0 93 PROD1 DRILL PULD T P/U & Orient Mud Motor &MWD 04:00 05:15 1.25 93 93 PROD1 DRILL SRVY T Program MWD 05:15 06:00 0.75 93 1,672 PROD1 DRILL TRIP T TIH f/ 93' to 1672' MD 06:00 07:15 1.25 1,672 1,672 PROD1 DRILL PULD P C/O 2 jts damaged 4" XT39 DP -Fill Pipe PR 288 gpm, 2025 psi - PU shock sub and agitator, 2 XOs and Shallow test MWD. "OK" ~ w _~_ 99 ~ ~ L_____. age 11 of 37 ~ • Time Logs _ _ Date From To Dur S. Depth_ E De th Phase _ Code Subcode T COM 12/25/2006 07:15 12:00 4.75 1,672 7,661 PROD1 DRILL TRIP T Con't TIH t 7661' MD -First WWT SS & Lo Tad std - Ck & Inspect all SS & Lo Tads - Re-torq & ck hub bolts. "`Note"* CO 2 incerts, 3 collar hubs 12:00 12:15 0.25 7,661 7,661 PROD1 DRILL SFTY T PJSM ;Inspecting SS and Lo Tads Hazard Reco nition 12:15 12:30 0.25 7,661 7,951 PROD1 DRILL TRIP T Con't RIH f/ 7661' to 7951' Brk circu. 12:30 13:00 0.50 7,951 7,983 PROD1 DRILL REAM T Wash & Ream -Pump 30 bbl WUHi Vis sweep -Ream 7951' to 7985' M ( Bttm appeared clean, no excess for Pum swee around bit. 13:00 18:45 5.75 7,983 8,529 PROD1 DRILL DDRL P Drlg 6.75" hole w/ Motor f/ 7983' MD to 8528' MD / 3793' TVD -Checking Sliders Carefully as run.ART 1.64 hrs, AST 1.40 hrs, ADT 4.04 hrs - Geologist notified rig supervisor he was out of zone and would need to pull back and side track. Lost 482' hole. 18:45 19:30 0.75 8,048 8,048 PROD1 DRILL TRIP NP Pump OOH for sidetrack point @ 8075' MD 19:30 20:30 1.00 8,048 8,075 PROD1 DRILL DDRL NP Trough for side track 8048' to 8075' MD 20:30 00:00 3.50 8,075 8,095 PROD1 DRILL DDRL NP Time Drill to SideTrack well 8075' MD to 8095' / 3784' TVD AST 285 hrs - ADT 5.89 hrs, Up wt 125k, Dn wt 65k Rot wt 85k, Torq on & off bttm 5-6k, ECDs 9.79, Max gas 111 units, Jars # 14001295 11.94 hrs total 12/26/2006 00:00 00:15 0.25 8,095 8,095 PROD1 DRILL SFTY NP Prejob safety meeting on drilling ahead and hazard reco nition 00:15 02:45 2.50 8,095 8,272 PROD1 DRILL DDRL NP Drill from 8095' to 8272' TVD = 3773'. ADT= 3.36 ART=.15, AST=1.21, Total DT for bit=4.21 02:45 03:15 0.50 8,145 8,239 PROD1 DRILL REAM NP POOH 1 stand and ream from 8145' to 8239' to reduce do le s 03:15 06:00 2.75 8,272 8,443 PROD1 DRILL DDRL NP Drill from 8272' to 8443' TVD = 3776'. ADT= .89 ART = .84, AST =.05, Total DT for bit = 5.55 06:00 07:30 1.50 8,443 8,190 PROD1 DRILL TRIP NP Pump out of hole from 8443' to 8190' too enhole sidetrack 07:30 08:15 0.75 8,190 8,220 PROD1 DRILL DDRL NP Trough from 8190' to 8220'. 08:15 12:00 3.75 8,220 8,370 PROD1 DRILL DDRL NP Drill from 8220' to 8370' TVD= 3773'. ADT=1.39, AST= 0.91, ART= 0.48 hrs. PU=124K, S0= 67K, ROT= 87K, TQ (on/off) = 5,500/6,000 ft-Ib, Max Gas= 148. 12:00 12:15 0.25 8,370 8,370 PROD1 DRILL SFTY NP PJSM (Hazards recognition) 12:15 13:30 1.25 8,370 8,528 PROD1 DRILL DDRL NP Drill from 8,370' - 8,528" (3,775' ND) ADT= 1.5 hr, AST= 0.09, ART= 1.41. .....eeee..v..®e ~ P~s;~~ 1 ~ s~ Time Logs Date From To Dur S De th E. De th Phase Cade Subcode T COM 12/26/2006 13:30 00:00 10.50 8,528 9,521 PROD1 DRILL DDRL P Drill ahead from 8,528 - 9,521' (3,775' TVD), ADT= 5.09 hr, AST= 0.41, ART= 4.68. Pumped 30 bbl Hi-Vis sweep at 8,850' with 25% excess returns. PU= 132K, S0= 62K, ROT= 90K, TO (on/off) = 6,000 ft-Ib, ECD= 10.63, Max Gas= 155 Concretions at 8,470-8,490', 8,555-8,565', 8,568-8,574', 8,590-8,594' total=40' 12!27/2006 00:00 00:15 0.25 9,521 9,521 PROD1 DRILL SFTY P PJSM on hazard recognition while drillin ahead 00:15 12:00 11.75 9,521 10,583 PROD1 DRILL DDRL P Drill from 9581' to 10583' TVD = 3769', ADT= 6.67, AST= 1.33, ART = 5.43 12:00 12:30 0.50 10,583 10,667 PROD1 DRILL DDRL P Continue drilling from 10583' to 10667', ND = 3764', ART= .33, AST= .18, ADT = .51, Note: Decision made to sidetrack due to bein out of zone 12:30 13:00 0.50 10,667 10,425 PROD1 DRILL REAM NP BROOH from 10,667' to 10,425', Survey and orient for openhole sidetrack 13:00 13:30 0.50 10,425 10,455 PROD1 DRILL DDRL NP Trough from 10,425' to 10,455' 13:30 17:15 3.75 10,455 10,667 PROD1 DRILL DDRL NP Time drill from 10,455' to 10,460' and drill ahead from 10,460' to 10667', ND=3773' ART=1.38, AST=1.16, ADT=2.54 17:15 22:00 4.75 10,667 11,272 PROD1 DRILL DDRL P Drill from 10,667' to 11,272', TVD=3772', (Pumped 35 bbl hi-vis wei hted swee 11,215' 22:00 00:00 2.00 11,272 11,272 PROD1 DRILL CIRC P Circulate sweep aound @ 81 spm @ 3800 psi and 90 rpm. Continue circulatin 12/28/2006 00:00 04:30 4.50 11,272 11,272 PROD1 DRILL CIRC P PJSM for circ and displacement hazard recognition. Continue to circ and reciprocate pipe while circ 4x btms up. Pump sweep and pump 1 more btms up at 84 stks/min, 3,950 si and100 r m. 04:30 10:30 6.00 11,272 5,148 PROD1 DRILL TRIP P Flow check- static. POOH from 11,272 - 5,148' with 10-25K of drag. Calculated fill= 42 bbl, actual= 56 bbl. 10:30 16:30 6.00 11,272 5,148 PROD1 DRILL TRIP P Flow check- static. POOH from 11,272 - 5,148' with 10-25K of drag. Calculated fill= 42 bbl, actual= 56 bbl. 16:30 16:45 0.25 5,148 5,148 PROD1 DRILL SFTY P PJSM. Service TD and blocks. 16:45 19:00 2.25 5,148 300 PROD1 DRILL TRIP P Continue POOH. UD shock sub and AGI-tater and stand back Jars, HWDP and Flex DCs. 19:00 20:30 1.50 300 0 PROD1 DRILL PULD P Download MWD. LD MWD, STAB, Motor and bit. Clear and clean drill floor. 20:30 21:45 1.25 0 0 PROD1 DRILL OTHR P PJSM -hazard recognition. Cut and slip 74' of DL. Inspect and adjust brakes, chk crow-o-matic. ~~s~ 1 ~ ~f 37 ; Time Logs _ _ Date From To Dur S. De th E. De th Phase Code S~.bcode T COM 12/28/2006 21:45 22:45 1.00 0 0 PROD1 CASIN( RURD P RU casing tools for 4-1/2" liner. 22:45 00:00 1.25 0 4,640 PROD1 CASIN( RNCS P PJSM. run 4-1/2", 11.6 Ib/ft, L-80, BTC slotted liner. 12/29/2006 00:00 03:00 3.00 5,808 11,260 COMP2 CASIN( RUNL P Continue Tripping in hole w/ 4-1/2" slotted liner from 5808' to 11,260' 03:00 04:30 1.50 11,260 6,425 COMPZ CASIN( OTHR P Drop 29/32" setting ball and pump down. Would not seat. Drop 1-3/4" setting ball and pump down same. Set liner hanger and ZXP packer. Top of Liner 6425' 04:30 05:00 0.50 6,425 6,425 COMPZ CASINC OTHR P Test ZXP and annulus to 2500 psi for 15 minutes on chart 05:00 09:00 4.00 6,425 0 COMPZ CASINC OTHR P Monitor well, blowdown top drive. POOH. 09:00 10:00 1.00 0 0 COMPZ CASINC OTHR P Break and laydown liner running tools. Clean floor and monitor well. 10:00 10:15 0.25 0 0 COMPZ WELCT SFTY P PJSM on testing BOPE (High ressures and hazard reco nition 10:15 14:15 4.00 0 0 COMPZ WELCT BOPE P Test BOPE to 250psi low and 3000 psi high. Test accumulator. Chuck Scheve, AOGCC, waived witnessing the test. Pull test plug and set wear rin .Test as alarms 14:15 14:45 0.50 0 0 COMPZ WELCT OTHR P Blow down Choke manifold and choke/kill lines 14:45 16:00 1.25 0 378 PROD2 STK PULD P P/U mill and whipstock assembly. Orient and P/U MWD 16:00 16:45 0.75 378 378 PROD2 STK OTHR P Upload MWD 16:45 17:15 0.50 378 378 PROD2 STK PULD P P/U bumpers and RIH w/ 3 stands of Hybrid dc's and shallow pulse test. Blow down to drive 17:15 19:30 2.25 378 5,373 PROD2 DRILL TRIP P RIH with whipstocklmill assembly (Fill drillpipe @ 3262' and beak circulation 5322' 19:30 20:00 0.50 5,373 5,412 PROD2 DRILL OTHR P Make mad pass from 5373' to 5412' (sensor depth 5210' to 5300') and orient 15 de .left. 20:00 21:15 1.25 5,412 6,348 PROD2 DRILL KOST P Continue RIH. Break circ @ 6348' CPU = 110k and S/O = 64k) Wash and tag no go @ 6429' MD and stack 20k to set trip anchor. Pull 10 k to verify. Shear off whipstock (oriented 18 de left of hi h side . 21:15 22:15 1.00 6,348 6,348 PROD2 DRILL CIRC P Circulate and displace SFOBM with 8.35 MOBM 22:15 00:00 1.75 6,332 6,338 PROD2 DRILL KOST P Mill window from 6332' to 6338' 12/30/2006 00:00 03:00 3.00 6,338 6,370 PROD2 DRILL KOST P Continue to mill 'B' Lat window from 6338' to 6370' Have 15' of gauge hole. TOW= 6332' BOW = 6345' 03:00 04:00 1.00 6,370 6,370 PROD2 DRILL KOST P Dress window 04:00 06:45 2.75 6,370 98 PROD2 DRILL TRIP P Monitor well and pump slug. POOH to 98' j rage 't4 taf :i7 L. f ,~b .~ ~G•a? Time Logs _ _ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 12/30/2006 06:45 07:00 0.25 98 98 PROD2 DRILL PULD P Down load MWD 07:00 08:00 1.00 98 0 PROD2 DRILL PULD P UD BHA, XO, Bowen BS, float sub, TM collar, MWD HOC and mills 08:00 09:15 1.25 0 0 PROD2 DRILL OTHR P Pull wear ring and flush BOP stack. Set wear rin 09:15 10:15 1.00 0 125 PROD2 DRILL PULD P M/U bit, Geo-pilot and MWD equip 10:15 11:30 1.25 125 125 PROD2 DRILL PULD P Upload MWD 11:30 12:45 1.25 125 383 PROD2 DRILL PULD P Continue P/U BHA 12:45 14:30 1.75 383 6,312 PROD2 DRILL TRIP P RIH-fill drillpipe @ 3640 and break circulation @ 6256'. P/U = 100k, S/O=73k, rot=86k, Torque = 5-6k, Clean hole ECD= 9.34 14:30 15:00 0.50 6,312 6,370 PROD2 DRILL REAM P Check ABI and slide w/o pump from 6312 to 6358' From from 6358' to 6370' 15:00 00:00 9.00 6,370 7,005 PROD2 DRILL DDRL P Drill 6.75" hole from 6370' to 7005', ND=3469', ADT=5.12. P/U=108k, so=65k, Rot=85k, Torque on/off=6k, ECD's=9.59 12/31/2006 00:00 06:30 6.50 7,005 7,295 PROD2 DRILL DDRL P Drill from 7005' to 7295' ND = 3641' ART = 4.18 hours 06:30 07:00 0.50 7,295 7,185 PROD2 DRILL TRIP NP Stand back one stand and wait while geologists review sever dogleg caused b concretion 07:00 09:45 2.75 7,185 7,295 PROD2 DRILL KOST NP Cut trough from 7185' to 7215' Drill to 7295' ART= 1.3 09:45 12:00 2.25 7,295 7,373 PROD2 DRILL DDRL P Drilf from 7295' to 7373' ND = 3631' ART =1.46 12:00 12:15 0.25 7,373 7,373 PROD2 DRILL SFTY P PJSM on making connections. 12:15 00:00 11.75 7,373 8,196 PROD2 DRILL DDRL P Drill from 7295' to 8196' ND = 3627' ADT = 7.19 (Pumped hi vis/wt sweep @ 8050' Cuttings load increased by 10% 01/01!2007 00:00 12:00 12.00 8,196 8,851 PROD2 DRILL DDRL P Drill from 8196' to 8851' ND =3626' ART = 8.81 12:00 12:15 0.25 8,851 8,851 PROD2 DRILL SFTY P PJSM on drilling ahead and making connection including hazard reco nition 12:15 00:00 11.75 8,851 9,862 PROD2 DRILL DDRL P Drill from 8851' to 9862' ND = 3624' ART = 8.11 01/02/2007 00:00 12:00 12.00 9,862 11,000 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with Geopilot from 9,862' to 11,000' MD! 3,624' ND (1,138') ADT 8.58 hrs, drilled thru 8 concretions for 70'. 8.4 ppg MOBM, ave ECD 10.6 ppg, ave BGG 75 units max as 256 units. ~~ ~ ~ of 37 Time Logs Date From _ To ._ Dur S. Depth E. De th Phase Code Subcode T -_ , COM _, i 01/02/2007 12:00 00:00 12.00 11,000 12,030 PROD2 DRILL DDRL P Drilled 6 3/4" hole in "B" sand lateral with Geopilot from 11,000' to 12,030' MD/ 3,654' ND (1,030') ADT 7.8 hrs, drilled thru 7 concretions for 50'. 8.4 ppg MOBM, ave ECD 11.3 ppg, ave BGG 65 units, max gas 181 units. Pumped 30 bbl wt'd hi vis sweep at 11,500' and had a 10% increase in cuttings, crossed fault at 11,450' and drillin thru "C" shale at 12,030'. 01/03/2007 00:00 06:30 6.50 12,030 12,444 PROD2 DRILL DDRL P Drilled 6 3/4" hole in "B" sand lateral with Geopilot from 12,030' to 12,444' MD/ 3,649' ND (414') ADT 5.14 hrs, lateral T.D., 8.4 ppg MOBM, ave ECD 11.3 ppg, ave BGG 50 units, max gas 103 units. cont drilling thru "C" shale from 12,030' to 12,040', while drlg "B" sand formatiion was wet after crossing fault. 06:30 06:45 0.25 12,444 12,444 PROD2 DRILL OWFF P Monitored well-static, took SPR's and attem ted to surve with no res onse 06:45 15:00 8.25 12,444 6,256 PROD2 DRILL REAM P Backreamed out of hole from 12,444' to 6,256', BROOH at 110 rpm's, 310 gpm, ICP 3,200 psi, FCP 2,200 psi, BROOH to 6,629' then pulled thru window to 6,256', no problems BROOH 15:00 17:30 2.50 6,256 6,443 PROD2 DRILL CIRC P Circ btms up at 6,256' at 310 gpm at 2,200 psi, dropped ball to open circ sub and washed down to 6,443' positioning circ sub at 6,241', pumped down at 2 bpm at 380 psi, with ball on seat pressured up to 4,200 psi and could not get ball to shear, unable to pump thru tool or reverse circ due to float in strin ,monitored well-static 17:30 20:30 3.00 6,443 200 PROD2 DRILL TRIP T POOH wet from 6,443' to 200' standin back HWDP and 'ars 20:30 22:00 1.50 200 100 PROD2 DRILL OTHR T LD circ sub and ball was on seat with no visible problem, shallow tested MWD tool and had no pulse, flushed thru tools and stood back NMFDC's 22:00 00:00 2.00 100 0 PROD2 DRILL PULD P Down loaded MWD and began to LD BHA #7 01/04/2007 00:00 01:00 1.00 0 0 PROD2 DRILL PULD P Fin POOH wet and LD BHA #7 then cleaned the ri floor 01:00 01:30 0.50 0 276 PROD2 DRILL PULD T MU clean out BHA #8 and RIH to 276' 01:30 05:30 4.00 276 6,332 PROD2 DRILL TRIP T RIH with BHA #8 from 276' to window at 6,332' 05:30 06:30 1.00 6,332 9,566 PROD2 DRILL TRIP P RIH from 6,332' thru the window to 9,185' and set down, washed thru and cont. RIH to 9,566' when we lost down wt. ~ F':~g~ t~s of ~~ ~ ~ Time Logs - _ Date _ From To Dur S Cie th E. Depth Phase Code Subcode T COM 01/04/2007 06:30 08:45 2.25 9,566 11,600 PROD2 DRILL TRIP P Washed down from 9,566' to 11,600', (liner setting depth), washed down at 200 gpm 1,150 psi and 100 rpm's with no roblems 08:45 11:15 2.50 11,600 11,600 PROD2 DRILL CIRC P Pumped 30 bbl wt'd hi vis sweep (2# over MW) and circ hole clean, had 10% increase in cuttings back from sweep and circ an add. 2X btms up and was clean at the shakers, circ hole at 88 spm, 310 gpm, 2,300 psi, 120 rpm's and 6K ft-Ibs of off btm for ue 11:15 12:30 1.25 11,600 11,600 PROD2 DRILL CIRC P Displaced hole over from 8.4 ppg MOBM to 8.4 ppg SFMOBM, monitored well-static. 12:30 17:15 4.75 11,600 0 PROD2 DRILL TRIP P POOH wet with BHA #8 from 11,600' and stood back HWDP, jars and NMFDC's, LD bit sub and bit, cleaned ri floor 17:15 18:30 1.25 0 0 COMPZ RIGMN SVRG P Held PJSM, slip and cut 68' of drlg line then serviced to drive 18:30 19:00 0.50 0 329 COMPZ FISH PULD P MU fishing BHA #9 to retrieve whi stock RIH to 329' 19:00 20:00 1.00 329 3,125 COMPZ FISH TRIP P RIH from 329'to 3,125' and while attempting to fill pipe it pressured up to 1,000 psi and wouldn't bleed off, thou ht float was u side down . 20:00 21:30 1.50 3,125 3,125 COMPZ FISH TRIP NP POOH from 3,125'to 1,725' and was able to est circ at 4 bpm at 400 psi, RIH to 3,125' and was able to circ at 4 bpm at 400 psi, (possibly had ice plug in 'ars . 21:30 22:15 0.75 3,125 6,297 COMPZ FISH TRIP P Cont to RIH from 3,125' to 6,297', st wt up 105K, do wt 70K, est circ at 4 bpm at 500 si 22:15 23:00 0.75 6,297 6,337 COMPZ FISH FISH P RIH and hooked whipstock on 3rd attempt, worked st wt up to 85K over (190K) with no movement, jarred on whipstock working up to 85K over st wt and whipstock came free on 6th hit. Hole took approx 2 bbls then monitored well and well was static, had 4K increase in st wt with 5-10K add. dra . 23:00 00:00 1.00 6,337 6,017 COMPZ FISH TRIP P POOH from 6,337' to 6,019' 01/05/2007 00:00 02:45 2.75 6,017 59 PROD2 FISH TRIP P Cont. POOH with whipstock assembly from 6,017' to 59' 02:45 04:15 1.50 59 0 PROD2 FISH PULD P POOH from 59' LD fishing 8HA #9, whipstock, space out jts and seal assembl ,cleared ri floor 04:15 04:45 0.50 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 04:45 05:00 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM on running 4 1/2" liner and associated hazards Pa~~ 1 ~f '37 /~ Time Logs Date From To Dur S. De th E De th Phase Code Subcode T COM 01!05/2007 05:00 09:00 4.00 0 5,226 COMPZ CASINO PUTB P PU and RIH with 4 1/2" liner to 5,226', MU 3 1/2" bent jt with welded btm, 2-swell packers , 12 blank jts and 110 jts of slotted liner per well plan, ran 1 Hydraform cent. on stop ring perjt 122 total). 09:00 09:45 0.75 5,226 5,263 COMPZ CASIN( PUTS P PU Baker Hook Hanger assembly and MU slimhole MWD, oriented same, st wt u 75K, do wt 65K 09:45 10:15 0.50 5,263 5,263 COMPZ CASIN( RURD P RD liner running tools and repositioned 3 stds DP in the derrick 10:15 15:45 5.50 5,263 11,584 COMPZ CASIN( RUNL P RIH with 4 1/2" liner on 4" DP from 5,263' to 11,584', went thru window on 3rd try, cont to RIH and sat down at 10,428' and worked tight to 10,519', RIH and sat down again at 11,336' worked liner down to 11,584' (setting de th , st wt u 180K, do wt 65K 15:45 19:30 3.75 11,584 6,254 COMPZ CASIN( OTHR P Worked liner and hooked same, hooked and unhooked liner 6 times to verify on depth setting 30K wt do last time, verified with MWD while working hook. dropped ball and pressured up to 3,200 psi to release from hanger, attempted to blow ball seat pressuring up to 4,300 psi with no success, POOH 1 std to 6,254', st wt up 145K, RU test pump and press. up to 4,500 psi and blew ball seat. Set top of hook hanger at 6,328' with end of liner at 11, 584'. 19:30 21:15 1.75 6,254 6,254 COMPZ RIGMN RGRP T Replaced water spear, seals and bearing on Emalgco Dyna-Matic brake on drawworks 21:15 00:00 2.75 6,254 1,933 COMPZ CASIN( RUNL P POOH with Baker running tool from 6,254'to 1,933' 01/06/2007 00:00 01:15 1.25 1,933 0 COMPZ CASIN( RUNL P POOH from 1,933' and LD Baker liner runnin tool and cleared ri floor. 01:15 01:45 0.50 0 0 COMPZ RPCOh RURD P RU to run LEM and held PJSM 01:45 04:00 2.25 0 393 COMPZ RPCOh PULD P MU "B" sand LEM assembly with MWD, RIH with 4 1/2" bentjt with seals, 1-jt 4 1/2" tbg, DB-6 nipple 1, jt tbg, 1-pup jt, LEM assembly with 6 jts of 4 1/2", 12.6#, L-80 IBTM tbg, CSBR and ZXP pkr RIH to 393', st wt up and do 42K 04:00 07:30 3.50 393 6,424 COMPZ RPCOh TRIP P RIH with LEM to 490' and shallow tested MWD, cont to RIH and sat down at 6,424', st wt up 137K, do wt 95K. Top of hook is at 6,328' with Bbtm of window at 6,345', DB nipple settin down at the btm of window. ' Time Logs _- -- Date From To _ Dur S. De th E. Depth Phase Code Subcode T _ _ COM _ i ___ __ 01/06/2007 07:30 13:30 6.00 6,424 6,088 COMPZ RPCOh OTHR P Attempted to work LEM up and would hang up, pulled and rotated into BOW with DB nipple and was able to PU thu, est circ at 130 gpm at 900 psi and worked LEM down, oriented to 162 deg rt. of high side and RIH locating seals in "A" lat CSR, latched LEM & unlatched to verify orientation and ck'd ok, dropped 1 3/4" ball and pumped down to seat, pressured up to 2,500 psi to set ZXP packer, pressured up to 4,200 psi to release from LEM, st wt up 130K, do wt 70K, set to of ZXP acker at 6,088' 13:30 14:00 0.50 6,088 6,088 COMPZ RPCOh DHEQ P Pressure tested ZXP pkr and annulus to 2,500 psi for 10 min, good test and charted same 14:00 18:30 4.50 6,088 0 COMPZ RPCOA TRIP P PU to 130k and was released from LEM, POOH from 6,088' and LD Baker running tool, cleared and cleaned rig floor 18:30 19:15 0.75 0 0 COMPZ DRILL OTHR P RIH with 3 stds of 4" DP with super sliders and inspected same and checked ok. NOTE: Decision was made to run LEM diverter tool to ensure LEM and hook alignment, called out for tools. 19:15 21:15 2.00 0 0 COMPZ RIGMN SVRG P Inspected saver sub and ck'd ok, serviced to drive. 21:15 23:00 1.75 0 0 COMPZ RPCOh OTHR T Brought 2 1/16" handling tools to rig floor while W.O. tools, cont to clean ri floor. 23:00 00:00 1.00 0 0 COMPZ RPCOh OTHR T Offloaded 2 1/16" tbg, diverter and subs and stra ed same. 01/07/2007 00:00 01:00 1.00 0 0 COMPZ RPCOh RURD T RU tongs and rig floor for 2 1/16" CS H dril tb 01:00 03:30 2.50 0 333 COMPZ RPCOM1 PULD T MU #1 LEM Diverter (18' long) with XO's on 10 jts of 2 1/16" CS hydril tbg, um out sub XO to 4" DP RIH to 333' 03:30 06:15 2.75 333 6,088 COMPZ RPCOh TRIP T RIH from 333' with LEM diverter to top of "B" lat ZXP packer at 6,088', st wt u 125K, do wt 9K 06:15 07:00 0.75 6,088 6,333 COMPZ RPCOh OTHR T RIH thru ZXP packer with diverter and tagged up in LEM at 6,333', st wt up 130K, do wt 98K set down 10K wt then snapped in and out 3X to verify alignment, est circ at 3 1/2 bpm at 1,800 psi with 7K wt do on diverter to relase from GS spear, PU and saw no sna , to of diverter at 6,315'. 07:00 07:15 0.25 6,333 6,315 COMPZ RPCOR OWFF T Monitored well-static, blew down top drive 07:15 07:30 0.25 6,315 6,130 COMPZ RPCOh TRIP T POOH from 6,315' to 6,130' 07:30 12:00 4.50 6,130 6,130 COMPZ RIGMN RGRP T Changed out electrical service loop on top drive, changed out due to short in service loo . ~g~ 1 of 37 Time Logs Date From _ To Dur S, Ce th E. Depth Phase Code Subcode T _ COM 01/07/2007 12:00 15:30 3.50 6,130 0 _ __ COMPZ RPCOh TRIP T Cont to POOH from 6,130' and LD 2 1/16" CS hydril tbg and GS running tool, cleared rig floor. calc fill on trip out 45 bbls, actual fi1151 bbls with 8.4 SFMOBM in the hole. 15:30 17:30 2.00 0 3,715 COMPZ RPCOh TRIP T MU 3" OD LEM drift on 11 jts of 2 1/16" CS h dril tb and RIH to 3,715'. 17:30 18:30 1.00 3,715 3,715 COMPZ RIGMN RGRP T Repositioned and re-tied D-rings on to drive service loo . 18:30 19:15 0.75 3,715 6,088 COMPZ RPCOh TRIP T RIH with 3"drift from 3,715' to top of ZXP acker at 6,088'. 19:15 21:00 1.75 6,088 6,324 COMPZ RPCOh OTHR T RIH from 6,088' and set down at 6,324', st wt up 133K, do wt 96K, top of diverter is at 6,315' and btm at 6,333', PU and est circ at 120 gpm at 600 psi and attempted to work drift down and cont. to set down at 6,324', set down with 1 OK st wt, incresed pump rate to 260 gpm at 2,000 psi and with 10K do still wouldn't go deeper, PU to above diverter top and rotated drift 1/2 & 1/4 rounds and still wouldn't go thru LEM, dropped dart and um ed down too en circ sub. 21:00 21:15 0.25 6,324 6,324 COMPZ RPCOA OWFF T Monitored well-static, blew down top drive 21:15 00:00 2.75 6,324 1,503 COMPZ RPCOh TRIP T POOH with 3"drift from 6,324' to 1, 503' 01/08/2007 00:00 01:00 1.00 1,503 0 COMPZ RPCOh TRIP T Fin POOH and LD 2 1/16" tbg and 3" drift. 01:00 05:15 4.25 0 6,324 COMPZ RPCOR TRIP T MU 2.5" x 2.89" tapered drift and RIH on 11 jts of 2 1/16" CS hydril tbg and 4" DP, set down at 6,324', st wt up 130K, do wt 96K 05:15 07:00 1.75 6,324 6,331 COMPZ RPCOA OTHR T Est circ at 6,324' at 125 gpm at 900 psi, worked tapered drift down from 6,324' to 6,331' (7') and was unable to go deeper, set down 10K wt and increased pump rate to 190 gpm at 1,800 psi and no change, no pump and no change, dropped ball and o ened circ sub. 07:00 07:15 0.25 6,331 6,331 COMPZ RPCOh OWFF T Monitored well -static, blew down top drive. 07:15 12:00 4.75 6,331 0 COMPZ RPCOR TRIP T POOH from 6,331' and LD CS hyd. tbg and tapered drift, found 2.89 cent. portion of drift scarred up and had 1 small piece of rubber stuck in water course, cleraed ri floor. 12:00 14:30 2.50 0 6,315 COMPZ RPCOh TRIP T MU LEM diverter GS retrieving tool and RIH on CS hyd. tbg and DP to 6,315', st wt u 125K, do wt 93K -- _ ~ z~~e 2~J ~f ~7 ~' Time Logs _ Date From To Dur S De th E. De th Phase Code Subcode T COM 01/08/2007 14:30 15:15 0.75 6,315 6,333 COMPZ RPCOh OTHR T Est circ at 80 gpm at 600 psi and set wt down on diverter at 6,315', stop circ and PU 20K over and diverter came free, PU 17' to conn. and dropped ball, RIH and sat back down on diverter and circ ball down and opened circ sub, shut do pump and PU taking 10K over st wt to ull diverter free. 15:15 15:30 0.25 6,333 6,333 COMPZ RPCOh OWFF T Monitored well -static, blew down top drive. 15:30 20:15 4.75 6,333 0 COMPZ RPCO11 TRIP T POOH from 6,333' with LEM diverter, LD CS hyd. tbg and diverter, found welds on diverter broken and appears tapered drift was wedged in the slide of the diverter, cleared ri floor. 20:15 21:30 1.25 0 0 COMPZ RIGMN SVRG P Held PJSM, slipped and cut 65' of drlg line and serviced to drive. 21:30 22:15 0.75 0 0 COMPZ RPCOA RURD T PU Baker tools to rig floor an offloaded and stra ed 20 'ts of 2 7/8" PAC DP 22:15 00:00 1.75 0 435 COMPZ RPCOR PULD T MU 3 1/2" concave mill on 2 7/8" PAC DP RIH to 435', PU mill, 2 jts PAC DP, 3 5/8" string stabilizer and 12 jts of 2 7/8" x 1" PAC DP (string stab 63' back from the mill 01/09/2007 00:00 02:00 2.00 435 6,270 COMPZ RPCOh TRIP T Fin MU BHA #14 and RIH to 6,270', st wt u 128K, do wt 87K 02:00 02:15 0.25 6,270 6,329 COMPZ RPCOA TRIP T Est circ at 250 gpm at 1700 psi, 25 rpm's at 6K ft-Ibs torque, rot wt 109K, up wt 130K, do wt 86K, RIH from 6,270' and set down at 6,329' with 5K wt dn. PU 10' 02:15 03:00 0.75 6,329 6,329 COMPZ RPCOR CIRC T Displaced hole over from 8.4 ppg SFMOBM to 8.4 ppg MOBM, circ hole at 250 mat 2,100 si 03:00 07:15 4.25 6,329 6,454 COMPZ RPCOA OTHR T Worked 3 1/2" mill thru LEM from 6,329' to 6,454' with 3 5/8" stabilizer tagging up on DB nipple at 6,391', ave 24K wt, 70 rpm's, 4-6K ft-Ibs torque, circ at 69 spm, 250 gpm at 1,950 psi, while working mill would PU and RIH w/no rotation and would set down 5K wt at 6,333' then go thru setting 15K do at 6,339', was able to set wt do at 6,339' and 1-2 turns would rotate off, worked mill thru 6,330 to 6,359' for 30 min with no change, cont. to RIH, was able to RIH while circ & no rot. from 6,359' to top of DB nipple at 6,391', started to rotaed do working stabilizer 64' back from bit, rotated do to top of DB ni le with no roblems. ~ ~ ~ _~ ~ y P~~ 2~ e~f ~W Tirne Logs - - -- _ __ Date From To Dur S. Depth_ E. De th Phase Code Subco_d_e__T COM ~~ _ 01/09/2007 07:15 08:00 0.75 6,454 6,454 COMPZ RPCOh CIRC T Circ btms up at 6,454' while working 3 5/8" stabilizer thru LEM, circ at 250 gpm, 1,950 psi, with pump off worked stab. thru LEM 2X with 2-4K drag do and did not stack out. Monitored shakers while circ and working mills and did not see any rubber or pieces of metal come over. 08:00 08:15 0.25 6,454 6,454 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive 08:15 13:30 5.25 6,454 0 COMPZ RPCOA TRIP T POOH from 6,454' and LD 14 jts of 2 7/8" PAC DP, 2-boot baskets (no recovery), 3 5/8" stab. in gauge and 3 1/2" concave mill was rounded and worn to 3 3/8". Appeared to be milling on LEM. 13:30 14:30 1.00 0 85 COMPZ RPCOh TRIP T Began to MU BHA #15 with LEM diverter RIH to 85', MU diverter, xo's and 2=ts of 2 1/16" CS h d. tbh 14:30 16:15 1.75 85 85 COMPZ RPCOh OTHR NP Stood by due to insufficient hi line power, rig went on 1 motor while working on generator at CPF 1, serviced to drive. 16:15 19:00 2.75 85 6,315 COMPZ RPCOh TRIP T Fin MU BHA #15 and RIH to 6,315', st wt u 130K, do wt 98K 19:00 21:45 2.75 6,315 6,337 COMPZ RPCOh OTHR T RIH with diverter from 6,315' and set do at 6,333' with 5K wt dn, PU 10K over to pull free, RIH and sat do at 6,335' with 5K dn, PU 10K over, then RIH setting 7K do at 6,336', PU 10-12K over, RIH setting 10K wt do to 6,337', took 10-12K over to pull free, decision was made to POOH and mill over packer, with wt do on diverter, pumped down ball and sheared circ sub. 21:45 22:00 0.25 6,337 6,337 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive 22:00 00:00 2.00 6,337 4,587 COMPZ RPCOR TRIP T POOH with diverter from 6,337' to 4,587', repositioning sliders down 2' while POOH 01/10/2007 00:00 04:30 4.50 4,587 333 COMPZ RPCOti TRIP T Cont. to POOH f/ 4587' to 333' relocating WWT SS 1 space (2' ) down. The old spacing had 2 laterals drillin time on them. 04:30 06:00 1.50 333 0 COMPZ RPCOh PULD T POOH LD BHA #15 LD LEM diverter, no si nificant mark's on diverter. 06:00 06:30 0.50 0 0 COMPZ WELCT BOPE P Pulled wear bushing ~e £~~ge 2~ f 3? Time Logs -- - - Date From To Dur S. De th E De th `Phase Code Subcode T COM _ 01/10/2007 06:30 10:45 4.25 0 0 COMPZ WELCT BOPE P _ _ _ __ RU and tested all BOPE, floor valves and choke valves to 250 psi Lo / 3000 psi Hi w/ 4" test jt except lower pipe rams (4.5" rams). Test lower rams using 4.5" test jt .All equip tested good - No Leaks - Acc Test - Int 3000 psi, After close 1800 psi, 200 psi build 40 sec, Full build 3 min 20 sec, Spare bottles Av 2200 psi. NOTE: JohrrCrisp W/AOGCC waived witnessing of the test 10:45 11:15 0.50 0 0 COMPZ FISH PULD T Installed wear bushing 11:15 12:45 1.50 0 314 COMPZ FISH PULD T MU fishing BHA #16 RIH to 314', MU tie-back spear, bumper and oil jars, 3-stds hybrid push pipe and accelerator 'ars. 12:45 14:45 2.00 314 6,023 COMPZ FISH TRIP T RIH from 314' to 6,023', (top of ZXP pkr @ 6,088') rot wt 105K, up wt 125K, do wt 93K, 10 r m's, 4-5K ft-Ibs for ue. 14:45 15:15 0.50 6,023 6,090 COMPZ FISH FISH T RIH to 6,090' and latched into tie-back sleeve, rotated 16 turns to the left, PU 10K over st wt and saw sleeve pull out of mandrel 15:15 15:30 0.25 6,090 6,090 COMPZ FISH OTHR T Monitored well- static 15:30 17:30 2.00 6,090 314 COMPZ FISH TRIP T POOH from 6,090' to BHA at 314' 17:30 18:45 1.25 314 0 COMPZ FISH PULD T POOH from 314', LD acceleratorjars, stood back hybrid push, LD spear and tie-back sleeve. 13.06' 18:45 19:30 0.75 0 318 COMPZ FISH PULD T MU milling BHA #17 RIH to 318', MU 6 3/4" x 5 3/8" shoe with 12' of extensions, washover ext. boot basket, 2-boot baskets, oil and bumper jars and 3-stds of hybrid push i e. 19:30 23:15 3.75 318 6,096 COMPZ FISH TRIP T RIH from 318' and tagged up on ZXP acker at 6,096'. 23:15 00:00 0.75 6,096 6,096 COMPZ FISH MILL T Begin milling on ZXP packer assembly at 6,096', 1-2K WOM, 38 spm, 131 gpm at 550 psi, 100 rpm's with 5K ft-Ibs torque, rot wt 85K, up wt 97K, do wt 70K. 01/11/2007 00:00 00:00 24.00 6,096 6,101 COMPZ FISH MILL T Cont to mill over ZXP packer from 6,096' to 6,100.5' (4.5' of approx. 7') 2-15K WOM, 60-110- rpm's, 40 spm, 140 gpm, 500 psi, off btm free torque 3K ft-Ibs, on btm 4-6K ft-Ibs, varied WOM, rpm's and pump rates while milling, rot wt 80K, up wt 80K, do wt 80K, 8.5 ppg MOBM, ave BGG 30 units, pumped several sweeps with 0-10% increase in cuttin s. ~ y m ~ ~~~ 2 s~f I Time Logs i _ _ Date From To Dur SDe th E.'De th Phase Code Subcode T _ COM _ _ 01/12/2007 00:00 07:30 7.50 6,101 6,105 COMPZ FISH MILL T Cont to mill over ZXP packer from 6,100.5' to 6,104.5' (4' of 8.5' milled) 2-15K WOM, 60-110- rpm's, 40 spm, 140 gpm, 500 psi, off btm free torque 3K ft-Ibs, on btm 4-6K ft-Ibs, varied WOM, rpm's and pump rates while milling, rot wt 80K, up wt 80K, do wt 80K, 8.5 ppg MOBM, ave BGG 30 units, pumped 2 sweeps with 0-5% increase in cuttin s. 07:30 08:45 1.25 6,105 6,105 COMPZ FISH CIRC T Pumped 30 bbl hi vis sweep and circ out of hole, had 5% increase in cuttings back from sweep, circ hole at 210 gpm, 700 psi, worked boot baskets rior to POOH. 08:45 09:00 0.25 6,105 6,105 COMPZ FISH OTHR T Monitored well-static, blew down top drive. 09:00 11:30 2.50 6,105 271 COMPZ FISH TRIP T POOH from 6,104' to BHA #17 at 271' 11:30 13:15 1.75 271 0 COMPZ FISH PULD T POOH from 271', stood back hybrid push pipe and LD BHA, cleaned out boot basket and had full recovery of metal (6.6#), mill was 90% worn with ID of mill one. 13:15 15:00 1.75 0 325 COMPZ FISH PULD T PU and MU fishing BHA #18 with 4 1/16" spear and extensions to go inside CSR below pkr, RIH with bumper and oil jars, pump out sub, 3-stds hybrid push pipe and accel. ~ars. 15:00 17:15 2.25 325 6,096 COMPZ FISH TRIP T RIH with BHA #18 from 325' to 6,096' (top of ZXP packer). st wt up 95K, do wt73K 17:15 17:45 0.50 6,096 6,105 COMPZ FISH FISH T RIH from 6,096' to 6,105' and sat down on ZXP packer assembly, PU 20K over st wt and LEM came free, saw 5K add. st wt. st wt u 100K 17:45 18:00 0.25 6,105 6,105 COMPZ FISH OTHR T Monitored well-static, blew down top drive 18:00 22:15 4.25 6,105 325 COMPZ FISH TRIP T POOH from 6,105' to BHA at 325', did not see any drag when DB nipple & seals went thru hook. 22:15 00:00 1.75 325 0 COMPZ FISH PULD T POOH with fish from 325', LD accel. jars, stood back hybrid push pipe, LD bumper and oil jars, RU tbg tongs and LD fish, LD spear, milled over ZXP packer and csg seal bore receptacle. Pre . to LD LEM's 4 1/2" tb . 01/13/2007 00:00 01:15 1.25 0 0 COMPZ FISH PULD T POOH LD 6-jts of 4 1/2" 12.6#, L-80 IBTM-SCC tbg, then POOH with LEM and found to have parted 1/2 down thru the window leaving approx 8' of LEM, 1- u 't, 2 'ts of 4 1!2" tb and seals. 01:15 02:45 1.50 0 0 COMPZ FISH OTHR T Pulled wear bushing and flushed out the stack, re-installed wear bushin . 02:45 03:45 1.00 0 0 COMPZ RIGMN SVRG P Serviced top drive and drawworks _ ~ W W ~ ~ ®,_ _ ~e~ 24 crf 37 Time Lo s _ _ _ ~_Date From__ To Dur S Depth_E.pepth Phase Code Subcode T COM j __ _ - - 01/13/2007 03:45 07:30 3.75 0 0 COMPZ FISH WOEO T Waited on fishing tools. 07:30 09:45 2.25 0 372 COMPZ FISH PULD T PU and MU fishing BHA #19 RIH to 372', MU tapered guide on 1-jt 2 7!8" PAC DP, spear with 3.557" nom OD grapple, ext's, stop sub to btm out on top of the hook, bumper and oil jars, pump out sub, 3-stds of hybrid push i e and accel. 'ars. 09:45 12:30 2.75 372 6,339 COMPZ FISH TRIP T RIH with BHA #19 from 372' to 6,339', st wt u 95K, do wt 73K 12:30 14:45 2.25 6,339 6,380 COMPZ FISH FISH T RIH from 6,339' to 6,380' with tapered guide, tagging top of fish with grapple at 6,341', set 5K wt down to engage fish, PU and worked st wt up to 35K over st wt and had 7' of travel up, increased up wt to 50K over st wt and after 5th pull fish came free, st wt up 98K, do wt 75K 14:45 15:30 0.75 6,380 5,873 COMPZ FISH TRIP T POOH from 6,380' to 5,873' 15:30 16:30 1.00 5,873 5,873 COMPZ FISH CIRC T Dropped ball and pumped down to seat and o en circ sub. 16:30 20:00 3.50 5,873 372 COMPZ FISH TRIP T POOH from 5,873' to BHA at 372'. 20:00 21:15 1.25 372 0 COMPZ FISH PULD T POOH from 372' LD accel. jars, stood back 3-stds hybrid push pipe, LD circ. sub, bumper and oil jars, POOH to spear and had no recovery, LD grapple and showed that the grapple was inside fish and pulled out and was sli htl a ed. 21:15 22:15 1.00 0 372 COMPZ FISH PULD T MU fishing BHA #20 RIH to 372', changed out grapple from a nominal OD of 3.557" to 3.671' and redressed circ sub RIH with BHA to 372'. 22:15 00:00 1.75 372 3,167 COMPZ FISH TRIP T RIH from 372' to 3167' 01/14/2007 00:00 00:30 0.50 3,167 6,339 COMPZ FISH TRIP T RIH with BHA #20 from 3,167' to 6,339', st wt u 98K, do wt 74K 00:30 01:30 1.00 6,339 6,371 COMPZ FISH FISH T RIH from 6,339' and tagged up with tapered guide at 6,370' and spear at 6,331', worked guide and spear down with 15-20K wt do and moved do hole 1' to 6,371' and spear at 6,332', attempted to pull fish out at 25K over 6X w/no movement, increased to 50K and after 6th try string came free, (no ~ars st wt u 100K. 01:30 01:45 0.25 6,371 6,371 COMPZ FISH OTHR T Monitored well-static, blew down top drive. 01:45 06:30 4.75 6,371 372 COMPZ FISH TRIP T POOH wet from 6,371' to BHA # 20 at 372' r ~ e ~_ ..----~-° ~ - I P~~~ ~~ of 37 Time Logs Date From To Dur S. Depth., E,_De~th Phase Cod_e_ Subcode T COM _ _ ___ 01/14/2007 06:30 07:15 0.75 372 0 COMPZ FISH PULD T POOH from 372', LD accel. jars and stood back 3 stds of hybrid push pipe, POOH to spear and had no recovery, spear looked like last one, that it had been inside fish but note ed. 07:15 08:00 0.75 0 0 COMPZ FISH PULD T RU and broke out spear and grapple, cleaned ri floor. 08:00 10:15 2.25 0 0 COMPZ FISH OTHR T Serviced drawworks while having teleconference with CPAI and Baker re s. 10:15 12:00 1.75 0 0 COMPZ FISH PULD T Fin LD BHA #20 12:00 14:45 2.75 0 441 COMPZ FISH PULD T PU and MU BHA #21 with 3 5/8" string mill and RIH to 441', MU tapered guide (2 1/2" x 2 7/8"), 1-jt 2 7/8" PAC DP, ported sub, 3 5/8" OD string mill, 2-jts 3 1/2" DP, 2-boot basket's, bumper and oil jars, pump out sub, 3-stds h brid ush i e. 14:45 16:45 2.00 441 6,315 COMPZ FISH TRIP T RIH from 441' to 6,315'. 16:45 19:00 2.25 6,315 6,402 COMPZ FISH MILL T Est circ at 50 spm, 175 gpm, 600 psi, 45 rpm's, 4K ft-Ibs free torque, rot wt 84K, up wt 96K, do wt 72K, RIH from 6,315' and sat down at 6,367' (mill 36' back) with mill at 6,331', milled on LEM from 6,331' to 6,335' with 3K WOM, took approx 30 min's to mill, worked string mill thru spot 10X and did not see any drag or torque, cont to rotate and RIH setting down at 6,402' with string mill at 6,363' with 5K wt dn, PU from 6,402' and circ hole working the ~unk baskets. 19:00 19:15 0.25 6,402 6,402 COMPZ FISH OTHR T Monitored well-static, blew down top drive. 19:15 21:30 2.25 6,402 441 COMPZ FISH TRIP T POOH from 6,402' to BHA #21 at 441'. talc fill on trip out 32 bbls, actual fill 38 bbls. 21:30 22:45 1.25 441 0 COMPZ FISH PULD T POOH from 441', stood back 3-stds hybrid push pipe, LD boot baskets (no recovery) then fin. LD BHA and cleaned ri floor. 22:45 00:00 1.25 0 140 COMPZ FISH PULD T Began to MU milling BHA #22 RIH to 140', MU tapered guide, string mill, 1-jt of 2 7/8" PAC DP, 5 1/2" pilot/packer mill, 2=ts 3 1/2" DP and boot baskets. 01/15/2007 00:00 00:30 0.50 140 417 COMPZ FISH PULD T Fin MU BHA #22 RIH to 417' (Note: pilot mill is 40' back from tapered uide) 00:30 01:45 1.25 417 6,300 COMPZ FISH TRIP T RIH from 417' to 6,300', st wt up 96K, do wt 73K. ® -- ~ev P~~ ~ ~~ 37 f _. _._ _ ~~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 01/15/2007 01:45 02:00 0.25 6,300 6,373 COMPZ FISH TRIP T RIH and tagged up at 6,366' with pilot mill at 6,326'., (top of hook at 6,328') set 5K wt do and rotated off hook, cont. to RIH setting down at 6,373' with mill depth of 6,333', est circ at 49 spm, 175 gpm at 650 psi, 80 rpm's at 4K ft-Ibs torque, rot wt 83K, up wt 96K, do wt 73K 02:00 16:00 14.00 6,373 6,375 COMPZ FISH MILL T Milled on LEM from 6,333' to 6,336' (3') when fish moved down hole 4', cont to mill on fish from 6,340' to 6,341' (1') when fished moved down hole an add. 13' to 6,394' drift depth and 6,354' mill depth. Assuming approx 116' of fish left in hole and top of pilot mill at 6,354' that would put the seals at 6,470' with XO in CSR at 6,472' (2' high), milled at 6,354' for 30 min. with no movement. At 08:00 hrs, PU to just below top of hook at 6,326' with pilot mill and 10-15K drag then RIH setting down at 6,331', worked mill thru spot that was tight and torquing up from 6,331' to 6,335'. PU and was able to work mill thru top of hook and down to 6,335' with no problems. Torque had smoothed out while millin at 6,335'. 16:00 00:00 8.00 6,375 6,382 COMPZ FISH MILL T Cont to mill on top offish at 6,335' mill depth, 6,375' guide depth to 6,342' mill depth, 6,382' guide depth. (7') (took 4 hrs to mill 1' at 6,339) milled at 3-7K WOM, 100 rpm's, 75 spm, 265 gpm at 1,200 psi, rot wt 80K, up wt 95K, do wt 73K, off btm torque 4K ft-Ibs, on btm 4-7K ft-Ibs, pumped hi vis sweep with 0-5% increase in cuttin s. 01/16/2007 00:00 01:15 1.25 6,383 6,383 COMPZ FISH CIRC T Continue circulate sweep out of hole. No increase in cuttings observed. Work strin from 6383' - 6321'. 01:15 03:15 2.00 6,383 417 COMPZ FISH TRIP T Monitor well -static. POOH from 6383' - 417'. 03:15 04:30 1.25 417 0 COMPZ FISH PULD T Breakout & lay down BHA. Observed left 40' of fishing assembly in hole. Left in hole packer mill stinger, 1 joint of 2 7/8 DP, string mill, ported sub, crossover, and tapered guide with stabilizer. 04:30 05:00 0.50 0 0 COMPZ FISH PULD T Clear & clean rig floor from OBM. 05:00 06:45 1.75 0 384 COMPZ FISH PULD T Make up BHA # 23.3 1/4" Itco spear assembl with 3.942" ra le. 06:45 08:30 1.75 384 6,342 COMPZ FISH TRIP T Trip in hole from 384' - 6342'. e~_ , m.® ~ ~._ .__.__..~..._.._._.._ ~. ~~ F'~€~a cif 37 • Time Logs Date From To Dur S. De th E De th Phase Code Subcode T COM 01/16/2007 08:30 09:30 1.00 6,342 6,342 COMPZ FISH FISH T Attempt to engage fish (LEM) at 6342' DPM. Could not verify engagement. Pumps @ 74 SPM - 1600 PSI. UP WT = 96K, SO WT = 71 K. 09:30 12:00 2.50 6,342 383 COMPZ FISH TRIP T Monitor well -static. POOH from 6342' - 383'. Crew than e. 12:00 12:45 0.75 383 0 COMPZ FISH PULD T Continue breakout & lay down BHA. No Fish. Grapple indicated marks on the first 4 "wickers" on grapple on only one side of ra le. 12:45 13:15 0.50 0 0 COMPZ FISH PULD T Clear & clean rig floor from OBM. 13:15 14:30 1.25 0 0 COMPZ RIGMN SVRG T held PJSM with crew. Discuss safety issues and procedure for Slipping & cutting Drilling Line. Slip & cut drilling line. Service draw works and Top Drive. 14:30 15:45 1.25 0 383 COMPZ FISH PULD T Make up BHA #24.3 1/4" Spear assembl with 3.682" ra le. 15:45 18:00 2.25 383 6,257 COMPZ FISH TRIP T Trip in hole from 383' - 6257'. 18:00 18:45 0.75 6,257 6,342 COMPZ FISH FISH T Establish pump rates @ 60 SPM - 1050 PSI. PU WT = 97K, SO WT = 73K. RIH to tag up on fish @ 6342' DPM. Work string to attempt to engage. Repeat attempts to engage fish. Could not verify emgagement with any overpull or pump pressure increase. 18:45 19:00 0.25 6,342 6,357 COMPZ FISH OTHR T Monitor well -static. Blow down Top Drive. 19:00 21:45 2.75 6,357 383 COMPZ FISH TRIP T POOH from 6257' - 383'. Observed ro er hole fill. 21:45 23:00 1.25 383 0 COMPZ FISH PULD T Breakout & lay down BHA#24, Observed grapple left in hole. Spear indicated grapple was pulled straight off. Set screw in place, and scratch marks on Helix of spear & bullnose verified strai ht ull off. 23:00 23:30 0.50 0 361 COMPZ FISH PULD T Make up BHA #25.5 1/4" lead im ression block assembl . 23:30 00:00 0.50 361 361 COMPZ FISH OTHR T Clean & clear floor area of OBM for TIH. 01/17/2007 00:00 00:15 0.25 0 COMPZ FISH PULD T Continue MU BHA # 25. 00:15 01:30 1.25 361 6,324 COMPZ FISH TRIP T Trip in hole from 361' - 6324'. 01:30 02:00 0.50 6,324 6,338 COMPZ FISH FISH T Establish parameters. UP WT = 94K, SO WT = 74K. Fill Drill string. Slack off to tag at 6331' set 2K on and weight fell off. Continue slack off to tag @ 6337' with 2K, continued to 6338' DPm and set down 15K. Note: This is 4' higher than when we last tagged & fished for tb 6342' DPM. 02:00 04:00 2.00 6,338 361 COMPZ FISH TRIP T Blow down Top drive. POOH from 6338' - 361'. ,,•_• ,v - die j~ q `y m S-&~3Ce .40 CST ~Y S C~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Su6code T COM 01/17/2007 04:00 04:30 0.50 361 0 COMPZ FISH PULD T Breakout & lay down BHA #25. Lay down Impression block. Inspect block. Marks indicated tagging upon Spear Grapple left in hole, and junk on OD of block. 04:30 05:00 0.50 0 0 COMPZ FISH PULD T Clean & Clear Rig Flloor. Lay down Tools. Discuss options for operations with town. 05:00 06:00 1.00 0 0 COMPZ RIGMN SVRG T Service Top Drive. Re tie service lines. 06:00 08:00 2.00 0 0 COMPZ RIGMN SVRG T Change out saver sub on Top Drive. 08:00 08:30 0.50 0 0 COMPZ RIGMN SVRG T Inspect draw works chains, & replace cotter ins as needed. 08:30 10:15 1.75 0 0 COMPZ FISH WOOR T Discus options with town. SIMOPS: Clean bell an on skate, clean ri . 10:15 10:45 0.50 0 363 COMPZ FISH PULD T Make up BHA #26. Box Tap assembl . 10:45 12:00 1.25 363 2,225 COMPZ FISH TRIP T Trip in hole from 363' - 2225'. Crew Chan e 12:00 12:15 0.25 2,225 3,158 COMPZ FISH TRIP T Continue trip in hole from 2225' - 3158'. 12:15 12:30 0.25 3,158 3,158 COMPZ FISH TRIP T Fill drill string with mud. 12:30 13:00 0.50 3,158 6,330 COMPZ FISH TRIP T Continue trip in hole from 3158' - 6330'. 13:00 13:45 0.75 6,330 6,341 COMPZ FISH FISH T Pick up single from shed. Obtain parameters. UP WT = 96K, SO WT = 71 K, ROT WT=84K.TQ=3K@25 RPM's. 2 1/2 BPM - 300 PSI. Tag @ 6341' DPM. Stalled out @ 6K. Set down 10K. POOH, lay down single. Monitor well - staic. Blow down Top drive. 13:45 17:00 3.25 6,341 363 COMPZ FISH TRIP T POOH from 6341' - 363'. 17:00 17:45 0.75 363 0 COMPZ FISH PULD T Rack back Push pipe, breakout & lay down Box Tap assembly. Observed NO FISH, and marks indicated never en a ed. 17:45 20:30 2.75 0 0 COMPZ FISH PULD T Clean & send out all Baker Fishing tool equipment from rig floor. VAc out OBM from ID's of tools. for SPCC revention. 20:30 21:00 0.50 0 0 COMPZ WELCT ROPE T Drain Stack. BOLDS. Pull wear bushin . 21:00 00:00 3.00 0 0 COMPZ WELCT BOPE T Rig up test equipment. test BOP's. Witness of test waived by AOGCC Chuck Sheave. 01/18/2007 00:00 01:30 1.50 0 0 COMPZ WELCT BOPE T Continue test BOP's. Perform Koomey test & check bottles for avg acre table ressures. 01:30 02:00 0.50 0 0 COMPZ WELCT OTHR T Rig up & install wear bushing. RILDS. La down runnin tool. t~~0e 23 s~f ~~ Time Logs Date Frorn To Dur _ S. Depth _E__.__Depth Phase Code_ _Subcode - _, T COM __ 01/18/2007 02:00 02:30 0.50 0 0 COMPZ RPCOti PULD T Pull tools to floor. Casing tongs ,slips etc... Held PJSM .Discuss safety issues and procedure for MU packer assembl . 02:30 03:30 1.00 0 61 COMPZ RPCOh PULD T Make up S-3 Packer, Liner Hanger & Casing Seal Bore receptacle assembly as per BOT rep. Total length of assembly = 60.75', spaced out for to to be set at 6120'. 03:30 05:45 2.25 61 0 COMPZ RPCOh PULD T RIH with assembly on first stand of DP. Tag up at 90'. Pull out to inspect packer. All good. RIH to tag again at 104'. POOH. Decision to lay down packer assembly. Suspect junk in hole. Breakout & lay down packer assembly. Cup in inner string hung up. Sent back to shop for rebuild. Observed iron filin sin cu . 05:45 06:15 0.50 0 0 COMPZ RPCOh OTHR T Clear & clean rig floor. Send tools out. 06:15 06:45 0.50 0 325 COMPZ FISH PULD T Make up clean out assembly, with 6 3/4" bit, scraper, upper watermelon mill, and string magnet with boot baskets. Total BHA = 325.33'. 06:45 10:00 3.25 325 325 COMPZ FISH WOEO T Wait on tools to complete MU of BHA. Tools comin from BOT sho . 10:00 10:15 0.25 325 325 COMPZ FISH PULD T Complete MU of BHA #26. Install 7 5/8" Scra er. 10:15 12:00 1.75 325 3,587 COMPZ FISH TRIP T Trip in hole from 325' - 3587'. Observed ro er hole fill. Crew Chan e 12:00 12:45 0.75 3,587 6,275 COMPZ FISH TRIP T Continue trip in hole from 3587' - 6275'. Did not to on an thin . 12:45 14:15 1.50 6,275 6,275 COMPZ FISH CIRC T Establish circulation & parameters. UP WT = 95K, SO WT = 74K, 60 SPM - 800 PSI. Pump Hi Visc weighted sweep. Observe little or no Iron recovery when sweep back to surface. Pum d 'ob. 14:15 14:30 0.25 6,275 6,275 COMPZ FISH TRIP T Monitor well -static. Blow down Top Drive & lines. 14:30 16:45 2.25 6,275 325 COMPZ FISH TRIP T POOH from 6275' - 325'. Obseve ro er hole fill. 16:45 18:00 1.25 325 0 COMPZ FISH PULD T Rack back push pipe. Breakout & clean junk baskets & string magnet. Observed 10 Ibs of iron recovered. No bi feces. 18:00 18:30 0.50 0 0 COMPZ RPCOh OTHR T Clear & clean rig floor from OBM. Rig u tools to run Packer assembl . 18:30 19:30 1.00 0 61 COMPZ RPCOA PULD T Make up S-3 Packer, Liner Hanger & Casing Seal Bore receptacle assembly as per BOT rep. Total length of assembly = 60.75', spaced out for to to be set at 6120'. Page 3ff s~f 3? Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 01/18/2007 19:30 22:30 3.00 61 6,180 COMPZ RPCOR TRIP T Trip in hole with packer assembly from 61' - to locate & spot top of setting sleeve @ 6119' DPM. Running speed at 60 ft/min as per BOT rep. Observed ro er hole fill. 22:30 23:30 1.00 6,180 6,180 COMPZ RPCOh DHEQ T Obtain Parameters. UP WT - 97K, SO WT = 73K, 36 SPM - 450 PSI. Drop 1 3/4" ball down dril- string. Pump down Drill string @ 36PM -450 PSI. Observe ball seat at 436 BBIs pumped, andcontinue pressure to 4000 PSI to set packer. Hold pressure 5 minutes. Bleed pressures. Record on chart. 23:30 00:00 0.50 6,180 6,180 COMPZ RPCOh DHEQ T Pump down annulus to 1000 PSI, for 10 minutes. record on chart. Bleed all ressures. Crew Chan e 01/19/2007 00:00 01:45 1.75 6,119 0 COMPZ RPCOh TRIP NP Continue POOH from 6119' to surface. 01:45 02:00 0.25 0 0 COMPZ RPCOh PULD NP Inspect, Breakout & lay down running & settin tools. 02:00 02:45 0.75 0 0 PROD3 STK PULD P Clear & clean rig floor of OBM. Pull toots to floor. Held PJSM with crew & BOT rep. Discuss safety issues and procedure for making up whipstock assembl . 02:45 03:45 1.00 0 0 PROD3 STK PULD P Make up Whipstock assembly as per BOT rep, with space out pipe & seal assembl . 03:45 04:15 0.50 0 0 PROD3 STK PULD P Make up MWD assembly. Orient to whi stock face. 04:15 04:45 0.50 0 0 PROD3 STK PULD P Plug in and upload MWD assembly. 04:45 05:30 0.75 0 506 PROD3 STK PULD P Continue Make up remaining whi stock BHA. Total len th = 506.14' 05:30 07:30 2.00 506 5,346 PROD3 STK TRIP P Trip in hole from 506' - 5346'. 07:30 08:30 1.00 5,346 5,528 PROD3 STK OTHR P Perform MAD PASS log from 5210' - 5320'. Sensor de ths. 08:30 09:00 0.50 5,528 6,072 PROD3 STK TRIP P Continue trip in hole from 5528' - 6072'. 09:00 09:30 0.50 6,072 6,119 PROD3 STK WPST P Establish parameters. UP WT = 115K, SO WT = 91 K. Orient whipstock face with MWD to 12 left of high side as per DD. Set whipstock. Observe anchor set with 10k, and verify set. Shear off bolt with 45K set down. Pick up to neutral position. Rotate free with 4K free torque. Top of whipstock @ 5991' DPM. 09:30 12:00 2.50 5,991 5,998 PROD3 STK WPST P Mill window from 5991' - 5998'. ROT WT = 96K. 100 RPM's 4K TQ. Crew Chan e \~ 6 ~~ `~ . ryr ~~J • Time Logs Date From T -- o - - - -- Dur -- S De th E. De th - Phase Code Subcode -- T -- COM 01/19/2007 12:00 13:30 _ 1.50 _ 5,998 6,004 PROD3 STK WPST P _ Continue mill window from 5998' - 6004'. Pump 30 BBL Hi Visc weighted sweep. Observe 20% increase in cuttings upon sweep returned to surface. 13:30 15:15 1.75 6,004 6,031 PROD3 STK WPST P Continue mill open hole from 6004' - 6031'. Gauged hole to 6023'. Pump 30 BBLS Hi Visc wei hted swee . 15:15 16:00 0.75 6,031 6,031 PROD3 STK WPST P Dress window with mills allowing sweep to return. Monitor well -static. Pump dry job. Blow down top drive & lines. 16:00 18:30 2.50 6,031 0 PROD3 STK TRIP P POOh with milling assembly from 6031' to the BHA. 18:30 19:30 1.00 0 0 PROD3 STK PULD P Plug in and download MWD assembly. Breakout & lay down mills. Gau a mills to full au e. 19:30 20:30 1.00 0 0 PROD3 STK OTHR P BOLDS. Pull wear bushing. Rig up & flush BOP stack. Install wear bushing. RILDS. 20:30 22:00 1.50 0 0 PROD3 DRILL PULD P Held PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for making up BHA. Make u 6 3/4" drillin BHA with Geo ilot. 22:00 23:15 1.25 0 367 PROD3 DRILL PULD P Plug in and upload MWD assembly. Continue make up remaining BHA. Total len th = 367.74'. 23:15 00:00 0.75 367 1,300 PROD3 DRILL TRIP P Trip in hole with BHA. Perform shallow ulse test. Break in Geo ilot. 01/20/2007 00:00 00:15 0.25 1,300 1,300 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 01:00 0.75 1,300 5,962 PROD3 DRILL TRIP P Continue trip in hole from 1300' - 5962'. Observed ro er hole fill. 01:00 01:15 0.25 5,962 6,031 PROD3 DRILL TRIP P Fill drill string with mud. Check Geo-Pilot deflection. Trip in hole through window area with no issues to 6023'. PU WT = 98K, SO WT = 75K, ROT WT = 84K. TO 4K. 01:15 12:00 10.75 6,031 6,288 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6031' - 6288' MD. ADT = 8.0 HRS. Drilled 86' + of concretions. Crew Chan e 12:00 12:15 0.25 6,288 6,288 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 00:00 11.75 6,288 7,246 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6288' - 7246' MD. ADT = 7.6 HRS. Drilled 46' of concretions. Crew Chan e 01/21!2007 00:00 00:15 0.25 7,246 7,246 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 7,246 8,424 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 7246' - 8424' MD. ADT = 7.1 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 12:00 12:15 0.25 8,424 8,424 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. _~ _~ i € I P~~ 3 of 3? l I I Time Logs _ ~ Date From To Dur S. De th E De th Phase Code Subcode T _ COM __ __~ 01!21/2007 12:15 00:00 11.75 8,424 9,724 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 8424' - 9724' MD. ADT = 7.3 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 01/22/2007 00:00 00:15 0.25 9,724 9,724 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 9,724 10,953 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 9724' - 10953' MD. ADT = 6.9 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 12:00 12:15 0.25 10,953 10,953 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 00:00 11.75 10,953 11,895 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 10953' - 11895' MD. ADT = 7.8 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 01/23/2007 00:00 00:15 0.25 11,895 11,895 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 11,895 13,072 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 11895' to 13072' MD. ADT = 6.9 HRS. UP 170K, DN N/A, ROT 95K, TQ 13K On / 10K Off, ECD's 11.1 ppg, Max Gas 128 Units, Pump Hi Visc weightred sweeps as needed. Crew Chan e 12:00 12:15 0.25 13,072 13,072 PROD3 RPCOA SFTY P PJSM with crew. Discuss safety issues and hazard recognition issues of Back reamin . 12:15 13:45 1.50 13,072 13,344 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13072' to 13344' MD. ADT = 1.4 HRS. UP 175K, DN N/A, ROT 100K, TQ 13K On / 10K Off, ECD's 11.1 ppg, Max Gas 128 Units, Pump Hi Visc wei htred swee s as needed. 13:45 14:30 0.75 13,344 13,344 PROD3 DRILL CIRC P Circ sweep out of hole w/ 307 gpm @ 3750 psi & 110 RPM, Had 10% Increase in cuttings, ECD's 10.92 ppg, Monitor well - OK 14:30 00:00 9.50 13,344 6,428 PROD3 DRILL REAM P Back ream out of hole w/ 300 gpm & 110 RPM at rate of 30 to 40 fpm f/ 13,344' to 6,428'. 01/24/2007 00:00 00:15 0.25 6,428 5,961 PROD3 DRILL REAM P Back ream out of hole to 6100' w/ 300 gpm & 110 RPM at rate of 30 to 40 fpm, Pull thru window @ 5991' (No roblem .Pull to 5961'. 00:15 01:15 1.00 5,961 5,961 PROD3 DRILL CIRC P Monitor well -Static, Pump Hi-vis sweep w/ 315 gpm @ 2400 psi & 130 RPM, Up 105K, Dn 70K, Rot 82K, Tq 3.5K, Circ hole clean. 01:15 02:45 1.50 5,961 5,961 PROD3 RIGMN SVRG P Slip & Cut drilling line 71.5', Service to drive. 02:45 03:30 0.75 5,961 8,015 PROD3 DRILL TRIP P RIH to 8015' (Ran out of down weight) 03:30 09:45 6.25 8,015 13,344 PROD3 DRILL REAM P Wash & Ream to bottom due to no down wt. f/ 8015' to 13,344' w/ 135 m 1070 si & 80 RPM, T 10K. _ m ~_ P~g~ ~~ of 37 • CJ Time Logs Date From_ To Dur S. Depth E. Depth Phase Code Subcode T _ COM 01/24/2007 09:45 12:00 2.25 13,344 13,366 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13344' to 13366' MD. ADT = 0.5 HRS. UP 175K, DN N/A, ROT 100K, TQ 11 K On / 11 K Off, ECD's 11.0 ,Max Gas 128 Units. 12:00 12:15 0.25 13,366 13,366 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 18:00 5.75 13,366 13,866 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13366' to 13866' MD (TD) / 3661' TVD. ADT = 5.3 HRS. UP 188K, DN N/A, ROT 100K, TQ 10K On / 11 K Off, ECD's 11.6 ppg, Max Gas 192 Units. 18:00 18:30 0.50 13,866 13,866 PROD3 DRILL CIRC P Circ & Survey, Down link to Geo-Pilot, Obtain SPR's, Monitor well. 18:30 19:30 1.00 13,866 13,366 PROD3 DRILL REAM P Back ream out of hole to 13366' w/ 300 gpm & 100 RPM at rate of 40 to 50 f m. 19:30 22:45 3.25 13,366 13,366 PROD3 DRILL CIRC P Pump Hi-vis weighted sweep, Circ & reciprocate pipe at rate of 300 gpm @ 3500 psi & 110 RPM pump total of 3 times BTM's up, Had 5% increase in cuttings w/ sweep, Held PJSM on SFOBM Chan a over. 22:45 00:00 1.25 13,366 13,366 PROD3 DRILL CIRC P Change over to 8.4 ppg SFOBM. 01/25/2007 00:00 00:15 0.25 13,366 13,366 PROD3 DRILL SFTY P PJSM; Tripping out of the hole (Hazard Reco nition . 00:15 06:45 6.50 13,366 368 PROD3 DRILL TRIP P Monitor well- Static, Blow down top drive, Drop 1-7/8" Rabbit, POOH on elevators f/ 13,344' to 368' (Had tight spot @ 6,380' w/ 45K over -Wiped thru twice to wi a out . 06:45 07:45 1.00 368 68 PROD3 DRILL PULD P Lay down BHA #11, HWDP, Jars, Flex collars, Stabs, Float sub. 07:45 08:45 1.00 68 68 PROD3 DRILL PULD P Down load MWD. 08:45 10:00 1.25 68 0 PROD3 DRILL PULD P Finish laying down remainder of BHA, MWD, Geo-Pilot, Bit, Agitator & Shock sub. 10:00 10:15 0.25 0 PROD3 DRILL PULD P Clean & Clear floor of tools. 10:15 11:00 0.75 COMPZ CASIN( RURD P Rig to run 4-1/2"Slotted liner. 11:00 15:30 4.50 0 7,256 COMPZ CASIN( PUTB P PJSM on running liner (Held with both crews), Run total of 170 jts liner plus welded orange peeled shoe joint (9 jts Blank= 384.27' & 162 'ts= 6,871.02' . 15:30 16:15 0.75 7,256 7,370 COMPZ CASIN( PUTB P Pick up Baker "HR" Setting tools (Up 86K, Dn 53K), Pump thru tools & Blow down to drive. 16:15 22:00 5.75 7,370 13,556 COMPZ CASIN< RUNL P RIH w/liner on drill pipe, Lost down weight @ 10,410', Rotate liner at 20 RPM w/ 8 to 11 K torque to 13,556' (Up 175K, Dn 88K . ~~ 34 of a?~ ~._ ~ I • Time Logs Date From To Dur S. De th E. De h t Phase Code Subcode T COM 01/25/2007 22:00 22:45 _ 0.75 13,556 _ _ _ 6,192 COMPZ CASIN( CIRC P Drop ball & Pump down same, Release from liner w/ 2800 psi, Shear out ball w/ 4300 psi. Liner tail @ 13,556.19', To of liner 6,192.76'. 22:45 23:15 0.50 6,192 5,991 COMPZ CASIN< CIRC P POOH to 5,991', Circ btm's up at rate of 305 gpm @ 1100 psi, Wsah whi stock slide f/ 5,991' to 6,002'. 23:15 00:00 0.75 5,991 5,029 COMPZ DRILL TRIP P Monitor well- OK, Blow down top drive, POOH to 5,029' 01/26/2007 00:00 00:15 0.25 5,029 5,029 COMPZ DRILL SFTY P PJSM; Tripping out of the hole (Hazard Reco nition). 00:15 02:15 2.00 5,029 31 COMPZ DRILL TRIP P Continue to POOH to liner running tool 02:15 03:00 0.75 31 0 COMPZ DRILL PULD P Lay down Baker liner running tool, Clean & clear ri floor. 03:00 03:30 0.50 0 239 COMPZ STK PULD P Make up Baker Whipstock retrieving tools. 03:30 05:45 2.25 239 5,997 COMPZ STK TRIP P RIH to 5997' Up 120K, Dn 75K. 05:45 06:15 0.50 5,997 5,971 COMPZ STK TRIP P Hook Whipstock (On depth), Pull 105K over to pull free, Pull up 26' (Mud in hole dro ed 1' . 06:15 07:00 0.75 5,971 5,971 COMPZ STK CIRC P Circ Btm's up at rate of 252 gpm @ 1200 psi, Monitor well, Blow down top drive. 07:00 09:30 2.50 5,971 113 COMPZ STK TRIP P POOH w/ Whipstock (Good hole fill - 2 bbls over . 09:30 11:30 2.00 113 0 COMPZ STK PULD P Lay down whipstock retrieving tools and whi stock assembl . 11:30 12:00 0.50 0 COMPZ STK OTHR P Clean & Clear rig floor of tools. 12:00 14:00 2.00 267 COMPZ CASIN( PUTB P PJSM, Rig casing tongs, Pick up Hook hanger assembly, Pick up & Orient MWD, Surface test MWD tools. 14:00 17:00 3.00 267 6,004 COMPZ CASIN< RUNL P RIH w/ Hook Hanger assembly, Tag main bore crossover @ 6149' 3 times, Exit window on 3rd. attempt (Up 117K, Dn 75K . 17:00 17:30 0.50 6,004 6,248 COMPZ CASIN( RUNL P Orient Hook assembly to 16R & Hook window 2' low @ 6006', Turn Hook 180 deg. & Go past window 10', Pick back up and obtain 16R and Hook window 2 times, Stack out 30K down weight. Hook assembly tail @ 6248.69', Top of Hook Hanger @ 5989.27', Found window 6006' when hooked. 17:30 18:00 0.50 6,248 6,248 COMPZ CASIN( CIRC P Drop ball & pump down at rate of 3 bpm @ 750 psi, Pressure up to 1800 psi hold 1 min., Pressure up to 2800 psi, ECP opened and dropped to 890 psi, Pressure back up to 2800 psi w/ 6 stokes (1/2 bbl), Bled off and pick up and observed tool released. 18:00 19:00 1.00 6,248 6,248 COMPZ CASIN( CIRC P Circ Btm's up, Monitor well, Blow down to drive. 19:00 23:00 4.00 6,248 0 COMPZ DRILL TRIP P POOH (Good hole fill - 9 bbls over), Break & La down liner run n in to ols. +~ry ry ~ g i d' t~~~ .2J ~f JY ~7 ~: Time Logs _ Date _ From To Dur S. De th E'Degth Phase Code Subcode T COM 01/26/2007 23:00 00:00 1.00 0 COMPZ DRILL OTHR P Clear & Clean rig floor. 01/27/2007 00:00 09:45 9.75 COMPZ DRILL PULD P PJSM, Lay down 90 stands 4"slick drill pipe, 15 stands Hybrid Push pipe, 7 stands HWDP. 09:45 12:00 2.25 COMPZ DRILL PULD P PJSM, Lay down 9 stands 4"drill pipe & remove super sliders and Lo-Tad's. Hole took 3 bbls in 12 hour eriod. 12:00 12:15 0.25 COMPZ DRILL SFTY P PJSM; Removing super sliders and Lo-Tad's. 12:15 18:30 6.25 COMPZ DRILL RURD P Continue laying down 4"drill pipe with su er sliders and Lo-Tad's. 18:30 19:30 1.00 COMPZ DRILL OTHR P Clear & Clean rig floor. 19:30 20:15 0.75 COMPZ RPCOh RURD P PJSM on rigging up & picking up tubin Ri to run 4-1/2" Tubin . 20:15 00:00 3.75 3,420 COMPZ RPCOh PULD P Pick up & run 114 jts. 4-1/2" tubing from i e shed. 01/28/2007 00:00 01:00 1.00 3,420 4,590 COMPZ RPCOh PULD P Continue to Pick up & run total of 153 'ts. 4-1/2" tubin from i e shed. 01:00 03:15 2.25 4,590 0 COMPZ RPCOh TRIP P POOH & Rack back tubing on off driller side. 03:15 03:30 0.25 0 COMPZ RPCOh PULD P Rig & pull wear bushing, Clear rig floor. 03:30 03:45 0.25 COMPZ RPCOh SFTY P Held PJSM with Halliburton wire line, Centrilift and rig crew on running ESP Com letion rocedures. 03:45 04:45 1.00 COMPZ RPCOA RURD P Rig up Centrilift equipment. 04:45 05:30 0.75 COMPZ RPCOA PULD P Pick up Screen Intake, 2 jts. Completion tubing, A-Well Discharge sub, Pick u Pum sections. 05:30 06:00 0.50 COMPZ RPCOh RURD P Rig up Halliburton wire line. 06:00 07:30 1.50 COMPZ RPCOh PULD P Set Pump, Set pack off, Attempt to test same to 1000 psi- No good, Pull & inspect pack off- Showed to be brittle and in oor sha e. 07:30 09:30 2.00 COMPZ RPCOR WOEQ T Wait on new Pack off for ESP Pump. 09:30 12:30 3.00 COMPZ RPCOh DHEQ T Set new pack off, Attempt to test pack off- No good, Pull Discharge sub up to floor and found plug out of A-Well Discharge sub, Replace same, Run back down and test pack off to 1000 psi f/ 5 min.- OK, Rig down wire line equipment, POOH & Stand back Screen assembl . 12:30 16:30 4.00 33 COMPZ RPCOh PULD P Pick up Motor & Seal assembly, Fill with oil, Hang cable sheave, Make up cable & Capillary line to Discharge sub. 16:30 22:30 6.00 33 4,903 COMPZ RPCOh RCST P RIH w/ ESP Completion string, Check cable every 10 stands, Pick up 2 GLM's as er tall , i i'agt~ S5 of 3? ~~ • Time Logs Date From To ' Dur S De th E. De th Phase Code Subcode _ T COM 01/28/2007 22:30 23:00 0.50 4,903 4,993 COMPZ RPCOh __ PULD P Pick up 2 more joints tubing, Make up tubing hanger. (Used 83 Cannon clamps, 3 Protectolizers, 2 Flat Guards, No Flat bands as yet but may use some on s lice 23:00 00:00 1.00 4,993 4,993 COMPZ RPCOh PULD P Make up Penetrator to Hanger, Measure & slice cable to Penetrator. 01/29/2007 00:00 01:45 1.75 4,993 4,993 COMPZ RPCOh PULD P Continue to splice cable to penetrator. 01:45 02:00 0.25 4,993 4,993 COMPZ RPCOh PULD P Check cable thru penetrator. 02:00 02:30 0.50 4,993 5,015 COMPZ RPCOA PULD P Land Hanger, RILDS, Test upper & Lower han er seals to 5000 si- OK. 02:30 03:00 0.50 5,015 COMPZ WELCT NUND P Nipple down BOPE. 03:00 04:15 1.25 COMPZ RPCOh NUND P Nipple up Tree, Test ESP cable thru Tree - OK, test Tree void to 5000 psi - OK, Install Upper & Lower Accuator valves. 04:15 04:45 0.50 COMPZ RPCOR NUND P Test Tree to 250 low and 5000 psi f/ 10 min.- OK. 04:45 05:00 0.25 COMPZ RPCOh NUND P Pull 2 way check. 05:00 06:30 1.50 COMPZ RPCOh RURD P Rig to change over well to deisel using Little Red. 06:30 06:45 0.25 COMPZ RPCOh SFTY P Held PJSM w/ Little Red and Rig crew. 06:45 09:15 2.50 COMPZ RPCOh FRZP P Test lines to 2500 psi, Displace well over to deisel at rate of 3.5 bpm w/ 40% returns, Slow rate to 2.5 bpm w/ 70% returns, Slow rate to 1.5 bpm 1/ 100% returns @ 600 psi, Pump total of 250 bbls, Lost 38 bbls, Total returns 212 bbls SFOBM to surface. 09:15 09:30 0.25 COMPZ RPCOh RURD P Rig down Little Red. 09:30 10:45 1.25 COMPZ RPCOh NUND P Remove working flanges from Wellhead, Install blind flanges, Clean Pit #5, Pill it, Rock washer. 10:45 11:15 0.50 COMPZ RPCOA RURD P Rig up Scaffolding. 11:15 12:00 0.75 COMPZ RPCOR NUND P Rig up lubricator, Set BPV, Rig down lubricator, Rig down Scaffolding. Release ri at 12:00 on 1/29/2007 ~ _ __ ~ ~ ~--'--- _e ~ _ ~ ~'a~ 7 ~f 37 Re: update on 1J-103 and IJ-180 wells Subject: Re: update on 1J-103 and 1J-180 wells From: Thomas Maunder <tom_maunder~c~admin.state.ak.us> Date: Wed, l0 Jan 2007 16:25:39 -0900 To: "Greener. ~1il:e R." ~~-Mihe.R.Grcci~cr<<~~cunocophillips.com> CC: "~Ilu:~n~as. R~~n~{~ L" ~Ran~i~~.l..l~hc,masri:c~~nc~cophillips.r~~m-. "[~cilly, Patrick J~~ -Patrick..1.Refill}"~r:conocophalli~~~.com:~ Mike and Pat, Thanks for the information. Glad you are isolating that water. On deepening the surface casing, this message is sufficient. There haven't been any report hazards that would preclude setting a few hundred feet tvd deeper. Good luck with the operations. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 1/10/2007 3:57 PM: 1 any remiss in that I haven't Iept f%ou up to date on what has happened v~ith the TD depth. change on the 1J-103 ~~-ell in tl~e ~ lateraL L~Thile 1 am at it also l-~ave some info tin the 1-18C) ~~~e11 for you. 1 J-103 ~ ~ ._ ~l'he "A" lateral ended up being 'I~I:)'d at 1.1.,2°12' (original permit depth was l 5,094') `l"lie asset suspected the fort~~ation ~~rould be vet if eve crossed the fault at +/- 11,=100' , This vas based. on the results that ~~~ere seen in the offset 1 J-1.02 well. The "" lateral was planned. to cross this same fault to determine il`the sand in that zone fives `let south. of tl~e fault. ~'G1 e discovered that it u~as and TD's the ti~~ell at 12,E-4'. e ran a liner to 11.,583' anal. placed t~~~o swell pacl~ers (one o~~ each side of the fault which ~~,--as at +I- 11,400'). 1-Suring the running of the 1_;ENI (lateral entry module} for the "" lateral we lave encountered. some t~•o~able and we are cup°~•ently in the p~°ocess of retrie~%ing It and we plan to run a n~~v o~~e. Then eve ~~°ll move tc~ exiling the "D" lateral, We are currently drilling the surface section on this well.. It loops like dais section ~vi11 reach the required T~'D depth of +/- 2,142.' at a measured depth. of +/- 3,5(}0' ~~D, e ~vo~.dd like to continue drilling on this same path to etencl our setting depth oftl~e sup°face casing to somewhere bet~~-een 3,800' to 4, 100' MD w~hicl~ would e 2,192' tc.~ 2,250' T~'D, This would holy us get our interrs~ediate easing> to depth. since eve would be able to :run more roller ce~atralizers ire tl~e surface x. intermediate annulus to reduce friction, 1 of 2 3/20/2007 9:28 AM Re: update on 1J-103 and 1J-180 wells :cues this '1,VI~ depth change p®se ~ p~-c~ble~~~ f`t°on~ tl~e t~ri~,~~~.31 permit clep~l~z fc~r the surface casi~~~ c~f`3,7' MIS, 2,1.42' 'I'VI~`? ~~ike. C~r~,ez~er «Greener, Mike R..vcf» 2 of 2 3/20/2007 9:28 AM STATE OF ALASKA ~' 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~ir:3 ~~e~g~)~adrr:in.s~atc.ak.~~~~ ~c~• ~r~_4d~oe bf:a~ad:~in.state.ak.us b~:l~ eckensten:;~3adrr:i:~.state.ak.~~C Contractor: Doyon Rig No.: 141 DATE: 12/21/2006 Rig Rep.: Patrick F. Krupa Rig Phone: 659-7115 Rig Fax: 659-7103 Operator: Conoco/Phillips Alaska Op. Phone: 659-7170 Op. Fax: 659-7103 Rep.: Dearl Gladden Field/Unit & Well No.: Kuparuk 1J-103 PTD # 206-114 '~, Operation: Drlg: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250/3000 Annular: 250/3000 Valves: 250/3000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Re Location Gen.: P Well Sign P Upper Kelly 1 NT Housekeeping: P Drl. Rig P Lower Kelly 1 NT PTD On Location P Hazard Sec. P Ball Type 1 NT Standing Order Posted P Inside BOP 1 NT BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8" P Pipe Rams 1 3 1/2"X 6" P Lower Pipe Rams 1 4.5" P Blind Rams 1 Blind P Choke Ln. Valves 1 3 1 /8" P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P Check Valve 1 31/8" NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P NA Pit Level Indicators P NT Flow Indicator P NT Meth Gas Detector NT NT H2S Gas Detector NT NT Test Results CHOKE. MANIFOLD: Quantity Test RE No. Valves 14 NT Manual Chokes 1 NT Hydraulic Chokes 1 NT ACCUMULATOR SYSTEM: Time/Pressure Test Res System Pressure NT Pressure After Closure NT 200 psi Attained NT Full Pressure Attained NT Blind Switch Covers: All stations NT Nitgn. Bottles (avg): Number of Failures: 0 Test Time: 3 Hours Components tested BOP sty Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: iirn re~~~~adn:i:~.s~ate.a>~.u~~ ',Remarks: Tested the BOP stack to comply with Tom Maunder's varience to open the blind ram door to remove the chain tongs from the stack. No debris or damage to stack. 24 HOUR NOTICE GIVEN YES X NO Waived By requested by T. Maunder Date 12/20/06 Time 1200hrs. Witness V. Torres/D. Gladden Test start Finish BOP Test (for rigs) BFL 11/09/04 BOP-Doyon 141-12-21-06-1.xls [Fwd: FW: IJ-103] • Subject: [Fwd: FW: 1J-103] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 20 Dec 2006 15:07:23 -0900 To: ~1000'C' Nor~[~ Slope. Oftice ==~io~~ccprucihoebayi«a~~i~~iti.s<<itc.ak.us FYI '''1/'P'1 /" ~ ` ~ (~\ -------- Original Message -------- ~~Jtrj 1~ Subject: FW: 1J-103 Date: Wed, 20 Dec 2006 15:02:19 -0900 From: Greener, Mike R. <Milo..R.Greener~~:cor_occphilli 5.com> To: Thomas Maunder <tom maunder~~admin.state.ak.us> FYI, Tom. Still looking for the chain. -----Original Message----- *From:* Doyon 141 Company Man *Sent:* Wednesday, December 20, 2006 2:59 PM *To:* Thomas, Randy L *Cc:* Eggemeyer, Jerome C.; Greener, Mike R.; AOGCC North Slope Office *Subject:* RE: 1J-103 Randy Blind ram doors were opened and the chain tong handle was removed. The handle had no chain attached. we checked and looked at both blind ram inserts and saw no damage of any kind, no marks on anything were visible. There was also no visible damage to the chain tong handle other than the missing chain. After the doors were closed we installed the test plug and did a body test 250psi Lo and 3000 psi Hi on chart. After we run pipe and at the earliest opportunity we will do a full BOP test as Tom requested. Dearl Gladden / Dink Heim Doyon 141 Company Man Office; 907-659-7170 Fax; 907-659-7075 Cell 943-1054 -----Original Message----- *From:* Thomas Maunder [mailto;tcm maunderc~admin.state.ak.us] *Sent:* Wednesday, December 20, 2006 1:08 PM *To:* Thomas, Randy L *Cc:* Eggemeyer, Jerome C.; Doyon 141 Company Man; Greener, Mike R.; AOGCC North Slope Office *Subject:* Re: 1J-103 Randy, Jeff Jones had called just before I got your message. It doesn't appear that you have many options. From your description, it appears that the chain tong may now be wedged in the blind ram cavity and opening the door is likely the only way to remove the tong and clear the wellbore. While the BOP stack will not be effective when the ram door is opened, as you note once the wellbore is unobstructed the test joint can be run in and the 7-5/8" rams 1 oft 12/21/2006 12:30 PM [Fwd: FW: 1J-103] closed on it if needed. In our discussion of a few minutes ago, you related that the actual time the door is open should not be long, however if for some reason it were not possible to close and re-bolt the door "quickly" that the wear bushing could be retrieved and the test plug installed. These steps will actually be necessary in order to test the BOP after the door is re-bolted. You may proceed as planned. When the BOP is tested prior to running the 7-5/8" casing, it is not necessary to individually test the blind rams. Once the casing is set and cemented, a full BOP test should be conducted prior to RIH to continue drilling. Call or message with any questions. Keep us advised if any problems are encountered. If the blind rams have been damaged, we would also appreciate being notified. Tom Maunder, PE AOGCC Thomas, Randy L wrote, On 12/20/2006 12:42 PM: Doyon 141 TD'd their intermediate hole early this morning after penetrating the West Sac intervals. After POOH and LD BHA, they closed the blind rams while preparing for their next step in the operations. They opened the blind rams and attempted to run the pulling tool for the wear bushing. After failing to get this tool down, they drained the BOP stack and discovered a chain tong sticking out of the ram cavity in the BOP stack. Evidently, the tool was dropped into the stack while the blinds were closed. When the blinds were opened, it drug the tool into the ram cavity. We would like to request a variance to allow us to open the door to the ram cavity to recover the chain tongs. We would then close the door and retest the body prior to running casing. The risk of a well control incident should be minimal. The history of drilling in the West Sak would indicate a low risk of the well flowing. This well has been stable since penetrating the productive West Sak interval with only slight seepage losses. Actions to manage the risks associated with this operation include 1. A man would be stationed on the rig floor to monitor fluid level in the well at all times while performing the requested operation. 2. There is a test joint with IBOP on location that could be run into the stack against which the lower pipe rams could be closed for well control. Let me know if this is acceptable to the Commission. Thanks for your consideration, Tom. Randy L. Thomas Kuparuk Drilling Team Lead 907-265-6830 office 907-244-5205 cell 907-222-6088 home Randy . L . T~°omasC~canocophi 11 ips . com <ma ~ t:_~..~_~.~?=_~_~_~.._ ='Yioma s:~c onoc op--i 1_l i p s • c_am> 2 of 2 12/21/2006 12:30 PM • FRANK H. MURKOWSKI, GOVERNOR Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-103 ConocoPhillips Alaska, Inc. Permit No: 206-114 Surface Location: 2226' FSL, 2441' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1555' FSL, 681' FEL, SEC. 12, T l ON, R 10E, 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)-3607 (pager). Si N DATED this day of August, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. Conoco~iillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 ~~~~~~ Email: Randy.L.Thomas@conocophillips.com ~U~ 2 8 20U~ July 27, 2006 O~~~ssion Alaska Oil & Gas ~;oos. Alaska Oil and Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-103, 1J-103 L1, iJ-103 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a trilateral horizontal well in the West Sak ~~A2", ~~B"and "D" sands. The main bore of the well will be designated iJ- 103, and the lateral bores of the well will be designated 1J-103L1 and 1J-103L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-103 is November 17, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, - l V- Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ ~ RECEIVED STATE OF ALASKA JUL 2 8 ZOO6 ALASKA OIL AND GAS CONSERVATION COMMISSION ~- PERMIT TO DRILL Alaska Oil & Gas Cons. Cofnmission 20 AAC 25.005 Anchorage 1 a. Type of Work: Drill Q • Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil O Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^~ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-103 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 15094' ' TVD: 3749' • 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2226' FSL, 2441' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661•& 25662 ' West Sak Oil Pool . Top of Productive Horizon: 1449' FSL, 692' FWL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 11/17/2006 Total Depth: 1555' FNL, 681' FWL, Sec. 12, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 y- 5946037 ' Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Dis~nce to Nearest ~ // - /c2- ~-/?1~a 4~~ Well within Podl: 1J-14 , 9609' 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.os5) q• $/• Downhole: 1706 psig ' Surface: 1289 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica pec ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' ~ 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2880' 28' 28' 2880' 2242' 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 6805' 28' 28' 6805' 3790' ~ 410 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 9040' 6054' 3659' 15094' . 3749' • see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ,~ Phone "Z.6 S' (~ 5~ Date '~ / ~~ ~O j`j d h All Drak Commission Use Only Permit to Drill / Number: Z~~- ~~~ API Number: 50-~Zq~ Z33~,g'~cS Permit Approval Date: Q`, ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: 1 (~\ Samples req'd: Yes ^ No [v~ Mu g req'd: Yes ^ No Other: ~~QS~~~~°~'G-`s ~~Gr~ H2S measures: Yes ^ No Dire ~ nal s y req'd: Yes [~ No ^ ~~ ~, ~~ PPROVED BY THE COMMISSION DATE ~~((~~~/// ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ j ~~ ~ L v ~ / ~`~ ubmit in uplicate • Ap~n for Permit to Drill, Well 1J-103 Revision No.O Saved: 27-Jul-06 Permit It -West Sak Well #1J-103 Application for Permit to Drill Document MpxirriixE vwell yv~ue 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 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 ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-103 PERMIT IT Page 1 of 8 Printed: 27-Jul-06 ORIGINAL • Ap~n for Permit to Drill, Well 1 J-103 Revision No.0 Saved: 27-Jul-06 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (fi) 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(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-103. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) 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: (2) a plat identifying the property and the property'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. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,226' FSL 2,441' FEL Section 35, T11N, R1OE ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,946,037 Eastings: 558,766 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 1,449' FSL, 692' FWL, Section 36, T11N, R10E West Sak "A2" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 6,805 Northings: 5,945,286 Eastings: 561,905 Total Vertical De th, RKB: 3,790 Total Vertical De th, SS: 3,681 Location at Total De th 1,555' FNL, 681' FWL, Section 12, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 15,094 Northings: 5,937,003 Eastings: 561,968 Total Vertical De th, RKB: 3,749 Total Vertical De th, SS: 3 640 1J-103 PERMIT IT Page 2 of 8 Printed: 27-Jul-O6 ORIGINAL and (D) other information required by 20 AAC 25.050(b); Ap~n for Permit to Drill, Well 1J-103 Revision No.0 Saved: 27-Jul-O6 Requirements of 20 AAC 25.O5O(b) If a well is to be intentionally deviated, the application fora Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells 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 (e) 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.OO5(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 (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-103. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,289 psi, calculated thusly: MPSP = (3,790 ft TVD)(0.45 - 0.11 psi/ft) = 1,289 psi - (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, losf circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-103 Drilling Hazards Summary. 1J-103 PERMIT IT Page 3 of 8 Printed: 27-Jul-O6 ORIGINAL • Ap~n for Permit to Drill, Well 1 J-103 Revision No.0 Saved: 27-Jul-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); 1J-103 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.OO5(c)(6) 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: (6) a complete 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 Btm Csg/Tbg Size Weigh Length MDlTVD MD/TVD OD (in in t Ib/ft) Grade Connection ft ft (ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,880 28 / 28 2,880 /2,242 510 sx ASLite Lead, 180 sx DeepCRETE Tail drift Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 6 805 28 / 28 6,805 / 3,790 3,SOO MD / 2,588' TVD. , Cemented w/ 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 9,040 6,054 / 3,659 15,094 / 3,749 slotted- no cement slotted Lateral (iJ-103) 6-3/4" B San .6 L-80 BTC 5,054 5,954 / 3,647 11,00 , slotted Lateral (1J-103 Ll) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 5,337 5,670 / 3,587 11,007 / 3,523 Slotted- no cement Slotted Lateral (1J-103 L2) 7. Diverter System Information Requirements of 20 AAC 25.OO5(c)(7) 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: (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 iJ-166. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.OO5(c)(8) 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: (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: 1J-103 PERMIT IT Page 4 of 8 0 ~ ~ ~ ~ ~ ~ ~ Pnnted: 27-Jul-O6 7 • Surface Hole Mud Program (extended bentonite) Ap~n for Permit to Drill, Well 1 J-103 Revision No.0 Saved: 27-Jul-06 S ud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) $,9 9.2 9.5 9.6 Funnel viscosity 150 250 200 300 (seconds) yield Point 50 70 30 50 (cP) Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8 0 5.0 7.0 (cc / 30 min)) . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 1 D-3/4" Cs Shoe to 7-5/8" Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 (seconds Plastic Viscostiy 12 - 18 (Ib/100 st) Yield Point 26 - 35 cP) API Filtrate 4 - 6 (cc / 30 min ) Chlorides (mg/1) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Densit ( g) 8.6 Plastic Viscostiy 15 - 25 (Ib/100 sf) Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 150° Oil /Water Ratio 70 / 30 Electrical >600 Stability 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 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a 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: (10) for an exploratory or stratigraphic test well, 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. ORIGINAL 1J-103 PERMIT IT Page 5 of 8 Printed: 27-Jul-06 Ap~n for Permit to Drill, Well 1 J-103 Revision No.O Saved: 27-Jul-06 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already. on file with the commission and identified in the application: (I1) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed 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 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; (i2) 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. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,880' MD / 2,242' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,805' MD / 3,790' IVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 3,500' MD / 2,588' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. 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. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 15,094' MD / 3,749' TVD as per directional plan. 1J-103 PERMIT IT Page 6 of 8 Printed: 27-Jul-06 QRIGINAL • ~ Ap~n for Permit to Drill, Well 1J-103 Revision No.O Saved: 27-Jul-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. PU and run 4-1/2" slotted liner. Th ~ s eE~w-~ 17. Land liner, set liner hanger @ +/- 6,054' MD / 3,659' TVD. POOH. Note: Remaining operations are covered under the 1J-103L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,954' MD / 3,647' TVD, the top of the B sand. 19. Mill 6-3/4"window. POOH. 20. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at +/- 11,008' MD / 3,596' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-103L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,670' MD / 3,587' TVD, the top of the D sand. 29. Mill 6-3/4" window. POOH. 30. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at +/- 11,007' MD / 3,523' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 38. POOH, laying down drill pipe as required. 39. PU completion and ESP as required and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. 1J-103 PERMIT IT Page 7 of 8 O R~ G l N A L Printed: 27-Jul-O6 • 42. Set BPV and move rig off. Ap~n for Permit to Drill, Well 1 J-103 Revision No.O Saved: 27-Jul-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans 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 annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ 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 iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Aftachment 2 Drilling Hazards Summary Aftachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1J-103 PERMIT IT Page 8 of 8 Printed: 27-Jul-06 ORIGINAL ~ • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-103 -Slot 1J-103 1 J-103 Plan: 1 J-103 (wp06) Proposal Report 26 July, 2006 Sperry Drilling Services ORIGINAL v '. ', '. '. o0 d M m N '. N r.+ N ~ ~ '.. 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Q ~ ~ dr' ~ a~nrmmNmeMrmmmmo ovia p C z ~mmnmo mmmnm~Mm U' a o 0 Y 7 ~ O~ p ~~~NNp~Q OYlm mmmm ; ~ o Ya~~ ~- L00000000OOm000~ ~ N~~ _ Q g 0 0 0 0 0 0 0 0 0 0 m 0 0 0 Q ~, , (O ~ a+ y- ~ _ ~ ~°~°-m u'^ivm~°n~~nro~<m.O1-m U porno '~ ~0 3 0 V i+ ~~ ~ N~ D m N m ~ N M N t O f D m i~ h ` 0 0 0 O ~ ~ ~ ~ N M M M M M M M M M F O p~ d Z~NMV~ncor-mm°~~~° Nrn .. r, C ~ ~ ~ O a N M M i N i ~ -' O ~' O ~ - O ?i O Z~Nro ~, '~ ~ ' ~ m i°06:: '; M o o ~ '~ ~ oM I o cn° 1° ; °o N O W H O M p, O ~ m O° O 3 ~ ~- ~n ~ m~ O J N O O M n / ~ O ~ d O pdz 1° ~ v> o ~ m m __~ o ~ m J V ~ ~ O a ~ M co 0 0 0 0 J H a 00 ~ O p ~~ ~, (7 J ~W~ i'~ W N ~~~ O IILJ O v N ~ d O ~~ 3 ~ O rM ________ m O O O ~ O O z ~ O N 00 u> ~ 0o ~' ~ 30 O 3 p ~ w ° 0° '~ °v O + F- I z o - ' ,°~ ~ +o ,- ~ M - o 3 o U ' F ~ oo ~ M N ' M d > 0° ° ~ o - ~ N p L o } ~~ o a ° O O N 3 O 2° o ~ 0 0 - M ~" ' -- " - 0 3 U °06 2° ~ r °o '., ~ _-_ N 008 . ~ O M o n F N 008 .n 3 M r o o ~ O o ~ o N O V ---------- a ~7 ~° M Q] P o °C~ N '~O i ~' ~ r~i °o ~ ! o n ' Cp ; o ~ e~9 g o0 o ~'~ '. - ', Y d, ~ N U cq ~~ C ~ YS ~ Q' 0 0 ~ O 7 6 D1 .M- j ~ - '~ `J' N a N ~~ ~ Y~ i~ i o v~ cn' \ - i I -. ~ o ~ m ~ ~ ~ ~ ~ ~ ,. '~~ N ~ c° m ~ ~ ~~ ~ ~ ' ~ ~ 1 ,~,~ I I ~~ ~~~~~ k ~l~rr, o 0 J o .~ M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q o 0 0 0 0 0 0 0 0 0 0 0 0 O N N O ~ O N O N O N O N Z N N M M V v N N ORIGINAL Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003:11 Single UserDb Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Inc: _ TVD Reference: Project: Kuparuk River Unit ` MD Reference: Site: Kuparuk.lJ Pad North Reference: Well: Plan 1J-1D3 Survey Calculation Method: Wellbore: 1 J-103 Design: 1J-103 (wp06) BGGM2005 1J-103 (wp06) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-103 -Slot 1 J-103 Well Position +N/-S 0.00 ft +E/-W 0.00 ft Position Uncertainty 0.00 ft Wellbore 1J-103 Magnetics Model Name Design Audit Notes: Version: Vertical Section: Northing: Fasting: Wellhead Elevation: 5,946,037.40 ft 558,766.60 ft ft H T Sperry Drilling Services Well Plan 1J-103 -Slot 1J-103 Plan RKB ~ 109:OOft (Doyon 141 (28+81 p PlanRKB @`109.OOft (Dayon 141 (28+81)) True Minimum Curvature Latitude: 70° 15' 47.418" N Longitude: 149° 31' 29.659" W Ground Level: 81.00 ft __ _ - . -_I Sample Date Declination Dip Angie (°) (°) 11/18/2004 24.65 80.75 Phase: Depth From (TVD) (ft) 28.00 PLAN +N/-S (ft) 0.00 Tie On Depth: +E/-W (ft) 0.00 Field Strength (nT) 57,553 28.00 Direction (°) 180.00 I 7/26/2006 9:55:11AM Page 2 of 12 COMPASS 2003.11 Budd 50 a~~~~~AL ~ / Halliburton Energy Services Conoco Phi!lips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Inc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1 J-103 Survey Calculation Method: Wellbore: 1 J-103 Design: 1J-103 (wp06) !. 1 Sperry Drilling Service Well Plan 1J-103 -Slot 1J-103 Plan RKB @~109.OOft (Doyon 141 (28+81)) Plan RKB Q 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°I100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 45.00 700.00 24.87 24.87 2.50 2.50 0.00 45.00 1,629.31 47.14 45.00 1,500.00 333.25 333.25 4.00 4.00 0.00 0,00 1,804.31 47.14 45.00 1,619.03 423.96 423.96 0.00 0.00 0.00 0,00 1,944.90 54.00 47.00 1,708.28 499.28 502.09 5.00 4.88 1.42 13.34 2,184.90 54.00 47.00 1,849.35 631.70 644.09 0.00 0.00 0.00 0.00 2,401.43 56.00 60.00 1,973.89 736.62 786.30 5.00 0.92 6.00 83.15 3,476.43 56.00 60.00 2,575.03 1,182.23 1,558.12 0.00 0.00 0.00 0.00 4,627.48 63.10 127.45 3,211.73 1,101.82 2,455.52 5.00 0.62 5.86 102.59 4,825.13 63.10 127.45 3,301.16 994.64 2,595.45 0.00 0.00 0.00 0.00 5,580.64 77.00 165.03 3,566.75 412.99 2,971.69 5.00 1.84 4.97 75.94 5,670.64 77.00 165.03 3,587.00 328.27 2,994.34 0.00 0.00 0.00 0.00 5,825.64 77.00 165.03 3,621.87 182.37 3,033.35 0.00 0.00 0.00 0.00 5,954.96 80.00 169.33 3,647.66 58.85 3,061.44 4.00 2.32 3.33 55.00 6,104.96 80.00 169.33 3,673.70 -86.32 3,088.78 0.00 0.00 0.00 0.00 6,304.96 80.00 177.45 3,708.49 -281.80 3,111.43 4.00 0.00 4.06 90.71 6,680.96 80.00 177.45 3,773.78 -651.72 3,127.87 0.00 0.00 0.00 0.00 6,805.96 85.00 177.45 3,790.09 -775.49 3,133.38 4.00 4.00 0.00 0.00 6,825.96 85.00 177.45 3,791.84 -795.39 3,134.26 0.00 0.00 0.00 0.00 7,004.75 92.04 178.70 3,796.45 -973.91 3,140.26 4.00 3.94 0.70 10.03 7,285.29 92.04 178.70 3,786.45 -1,254.20 3,146.63 0.00 0.00 0.00 0.00 7,299.22 91.62 179.06 3,786.00 -1,268.12 3,146.90 4.00 -3.04 2.60 139.41 7,321.46 91.54 179.72 3,785.39 -1,290.34 3,147.14 3.00 -0.35 2.98 96.71 7,447.30 91.54 179.72 3,782.00 -1,416.14 3,147.75 0.00 0.00 0.00 0.00 7,459.21 91.64 179.38 3,781.67 -1,428.05 3,147.84 3.00 0.82 -2.89 -74.19 8,146.78 91.64 179.38 3,762.00 -2,115.29 3,155.29 0.00 0.00 0.00 0.00 8,191.17 90.41 179.88 3,761.21 -2,159.68 3,155.58 3.00 -2.78 1.14 157.73 9,346.99 90.41 179.88 3,753.00 -3,315.46 3,157.93 0.00 0.00 0.00 0.00 9,354.38 90.19 179.84 3,752.96 -3,322.85 3,157.94 3.00 -2.93 -0.64 -167.59 10,847.23 90.19 179.84 3,748.00 -4,815.69 3,162.22 0.00 0.00 0.00 0.00 10,878.72 89.25 179.78 3,748.15 -4,847.18 3,162.32 3.00 -2.99 -0.19 -176.33 11,019.27 89.25 179.78 3,750.00 -4,987.71 3,162.88 0.00 0.00 0.00 0.00 11,056.78 90.09 180.52 3,750.22 -5,025.22 3,162.78 3.00 2.24 2.00 41.76 11,200.29 90.09 180.52 3,750.00 -5,168.73 3,161.46 0.00 0.00 0.00 0.00 11,370.51 81.58 180.42 3,762.36 -5,338.34 3,160.06 5.00 -5.00 -0.06 -179.31 11,496.11 81.58 180.42 3,780.76 -5,462.57 3,159.15 0.00 0.00 0.00 0.00 11,703.18 91.93 180.45 3,792.47 -5,669.02 3,157.58 5.00 5.00 0.01 0.16 7/26/2006 9:55:11AM Page 3 of 12 COMPASS 2003.11 Suild 50 ~~L ~ 1/ Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillipsAlaska, Inc: ND Reference: Project: Kuparuk'River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wellbore: 1 J-103 Design: 1J-103 (wp06) • A Sperry Drilling Services 12,103.18 91.93 180.45 3,779.00 -6,068.79 3,154.44 0.00 0.00 0.00 0.00 12,131.60 91.08 180.45 3,778.25 -6,097.20 3,154.21 3.00 -3.00 -0.01 -179.81 13,102.46 91.08 180.45 3,760.00 -7,067.85 3,146.64 0.00 0.00 0.00 0.00 13,124.34 90.42 180.45 3,759.71 -7,089.74 3,146.47 3.00 -3.00 0.00 180.00 13,902.55 90.42 180.45 3,754.00 -7,867.90 3,140.39 0.00 0.00 0.00 0.00 13,910.40 90.66 180.45 3,753.93 -7,875.75 3,140.33 3.00 3.00 0.00 0.00 14,602.67 90.66 180.45 3,746.00 -8,567.95 3,134.93 0.00 0.00 0.00 0.00 14,637.41 89.61 180.45 3,745.92 -8,602.69 3,134.66 3.00 -3.00 0.00 180.00 15,094.73 89.61 180.45 3,749.00 -9,059.98 3,131.09 0.00 0.00 0.00 0.00 7/26/2006 9:55:11AM Page 4 of 12 ~~~~ COMPASS 2003.11 Build 50 r/ ~ Halliburton Energy Services ConocoPh~ll~ps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska; Inc.. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-103 Wellbore: 1 J-103 Design: 1J-103 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ~ ~ ~ Sperry Drilling 3®rvice~ Well Plan 1J-103 -Slot 1J-103 Plan RKB @ 1D9.OOft (Doyon 141 (28+81)) Plan RK$@ 109.OOft (Doyon 141 (28+81)) True. Minimum Curvature Planned Survey 1J-103 (wp06) MD Inclination Azimuth TVD SSTVD +N1S (ftl (°) (°) (ft) (ftl (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 SHL @ 2226' FSL & 2441' FEL 100.00 0.00 0.00 100.00 -9.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 KOP @ 300' MD, 300' TVD - Build ~ 2.50°/100' 400.00 2.50 45.00 399.97 290.97 1.54 500.00 5.00 45.00 499.75 390.75 6.17 600.00 7.50 45.00 599.14 490.14 13.86 700.00 10.00 45.00 697.97 588.97 24.62 702.06 10.05 45.00 700.00 591.00 24.87 Continue Dir ~ 4°l100': 702' MD, 700' TVD 800.00 13.97 45.00 795.78 686.78 39.28 900.00 17.97 45.00 891.90 782.90 58.73 1,000.00 21.97 45.00 985.87 876.87 82.88 1,100.00 25.97 45.00 1,077.23 968.23 111.60 1,200.00 29.97 45.00 1,165.53 1,056.53 144.75 1,300.00 33.97 45.00 1,250.34 1,141.34 182.18 1,400.00 37.97 45.00 1,331.26 1,222.26 223.71 1,500.00 41.97 45.00 1,407.89 1,298.89 269.12 1,600.00 45.97 45.00 1,479.84 1,370.84 318.20 1,629.31 47.14 45.00 1,500.00 1,391.00 333.25 Sail ~ 47.14° Inc: 1629' MD, 1500' TVD 1,655.78 47.14 45.00 1,518.00 1,409.00 346.97 Base Perm 1,700.00 47.14 45.00 1,548.08 1,439.08 369.89 1,800.00 47.14 45.00 1,616.10 1,507.10 421.72 1,804.31 47.14 45.00 1,619.03 1,510.03 423.96 Continue Dir ~ 5°/100': 1 804' MD, 1619' TVD 1,871.03 50.39 46.00 1,663.00 1,554.00 459.11 T3 1,900.00 51.81 46.40 1,681.19 1,572.19 474.72 1,944.90 54.00 47.00 1,708.28 1,599.28 499.28 Sail ~ 54°/1 00': 1945' MD , 1708' TVD 2,000.00 54.00 47.00 1,740.66 1,631.66 529.68 2,100.00 54.00 47.00 1,799.44 1,690.44 584.85 2,184.90 54.00 47.00 1,849.35 1,740.35 631.70 Continue Di r @ 5°/100', TFO 83.15°: 2185' MD, 1849' TVD 2,200.00 54.09 47.92 1,858.21 1,749.21 639.96 2,300.00 54.89 53.99 1,916.33 1,807.33 691.18 2,367.82 55.60 58.03 1,955.00 1,846.00 722.31 K15 2,400.00 55.98 59.92 1,973.09 1,864.09 736.03 Map Map +E1-W Northing Easting DLSEV Vert Section lftl (ft) (ft) (°I100ft) (ft) 0.00 5,946,037.40 558,766.60 r 0.00 0.00 0.00 5,946,037.40 558,766.60 0.00 0.00 0.00 5,946,037.40 558,766.60 0.00 0.00 0.00 5,946,037.40 558,766.60 0.00 0.00 1.54 5,946,038.95 558,768.13 2.50 -1.54 6.17 5,946,043.61 558,772.72 2.50 -6.17 13.86 5,946,051.37 558,780.35 2.50 -13.86 24.62 5,946,062.21 558,791.02 2.50 -24.62 24.87 5,946,062.46 558,791.28 2.50 -24.87 39.28 5,946,076.98 558,805.57 4.00 -39.28 58.73 5,946,096.58 558,824.87 4.00 -58.73 82.88 5,946,120.91 558,848.82 4.00 -82.88 111.60 5,946,149.85 558,877.31 4.00 -111.60 144.75 5,946,183.26 558,910.20 4.00 -144.75 182.18 5,946,220.98 558,947.34 4.00 -182.18 223.71 5,946,262.82 558,988.53 4.00 -223.71 269.12 5,946,308.59 559,033.59 4.00 -269.12 318.20 5,946,358.05 559,082.28 4.00 -318.20 333.25 5,946,373.21 559,097.21 4.00 -333.25 346.97 5,946,387.03 559,110.82 0.00 -346.97 369.89 5,946,410.13 559,133.56 0.00 -369.89 421.72 5,946,462.36 559,184.98 0.00 -421.72 423.96 5,946,464.62 559,187.20 0.00 -423.96 459.75 5,946,500.04 559,222.71 5.00 -459.11 476.02 5,946,515.77 559,238.85 5.00 -474.72 502.09 5,946,540.53 559,264.73 5.00 -499.28 534.69 5,946,571.18 559,297.08 0.00 -529.68 593.85 5,946,626.81 559,355.81 0.00 -584.85 644.09 5,946,674.04 559,405.68 0.00 -631.70 653.09 5,946,682.37 559,414.62 5.00 -639.96 716.28 5,946,734.08 559,477.40 5.00 -691.18 762.47 5,946,765.57 559,523.34 5.00 -722.31 785.27 5,946,779.46 559,546.03 5.00 -736.03 7/26/2006 9:55:11AM Page 5 of 12 ~~~~~~. COMPASS 2003.11 Build 50 ~ ~ / Hallib urton Ene rgy Servic es ,~~ ~ ~` ,> , , Conoco Phillips Planning Report -Geographic PJaska Sperry Driliing Services Database: EDM 2003.11 Single User Db Loc al Co-ordinate Reference: Well Plan 1J-103.. -Slot 1J-103 Company: ConocoPhillips Alaska, Ina ND Reference: Plan RKB @ 109: OOft (Doyon 141 (28+81 p Project: Kuparuk River Unit MD Reference: Plan RKB @ 109. OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calcu4ation Method: Minimum Curvatu re ' Wel l bore: 1 J-103 Design: 1 J-103 (wp06) Planned Survey 1J-103 (wp06) I Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft1 (ftl 2,401.43 56.00 60.00 1,973.89 1,864.89 736.62 786.30 5,946,780.06 559,547.05 5.00 -736.62 Sail ~ 56° Inc: 2401' MD, 1974' ND 2,500.00 56.00 60.00 2,029.01 1,920.01 777.48 857.07 5,946,821.47 559,617.49 0.00 -777.48 2,600.00 56.00 60.00 2,084.93 1,975.93 818.93 928.87 5,946,863.48 559,688.96 0.00 -818.93 2,700.00 56.00 60.00 2,140.85 2,031.85 860.38 1,000.66 5,946,905.48 559,760.42 0.00 -860.38 2,800.00 56.00 60.00 2,196.77 2,087.77 901.83 1,072.46 5,946,947.49 559,831.88 0.00 -901.83 2,880.89 56.00 60.00 2,242.00 2,133.00 935.36 1,130.53 5,946,981.47 559,889.69 0.00 -935.36 10 3/4" Casing ~ 2881' MD, 2242' TVD - 2119' FNL & 1309' FEL - Sec35-T11N-R10E - T3 + 550 -10 3/4" 2,900.00 56.00 60.00 2,252.69 2,143.69 943.29 1,144.26 5,946,989.50 559,903.35 0.00 -943.29 3,000.00 56.00 60.00 2,308.61 2,199.61 984.74 1,216.05 5,947,031.50 559,974.81 0.00 -984.74 3,100.00 56.00 60.00 2,364.53 2,255.53 1,026.19 1,287.85 5,947,073.51 560,046.28 0.00 -1,026.19 3,200.00 56.00 60.00 2,420.45 2,311.45 1,067.64 1,359.65 5,947,115.52 560,117.74 0.00 -1,067.64 3,300.00 56.00 60.00 2,476.36 2,367.36 1,109.09 1,431.44 5,947,157.52 560,189.21 0.00 -1,109.09 3,400.00 56.00 60.00 2,532.28 2,423.28 1,150.55 1,503.24 5,947,199.53 560,260.67 0.00 -1,150.55 3,476.43 56.00 60.00 2,575.03 2,466.03 1,182.23 1,558.12 5,947,231.64 560,315.29 0.00 -1,182.23 Continue Dir @ 5°/100', TFO 102.59°: 3476.43' MD, 2575.02' ND 3,500.00 55.75 61.39 2,588.25 2,479.25 1,191.78 1,575.13 5,947,241.32 560,332.23 5.00 -1,191.78 3,600.00 54.87 67.38 2,645.19 2,536.19 1,227.32 1,649.21 5,947,277.43 560,406.02 5.00 -1,227.32 3,700.00 54.30 73.47 2,703.18 2,594.18 1,254.62 1,725.93 5,947,305.33 560,482.52 5.00 -1,254.62 3,800.00 54.03 79.63 2,761.77 2,652.77 1,273.46 1,804.71 5,947,324.78 560,561.14 5.00 -1,273.46 3,900.00 54.08 85.81 2,820.51 2,711.51 1,283.70 1,884.94 5,947,335.65 560,641.29 5.00 -1,283.70 4,000.00 54.44 91.95 2,878.96 2,769.96 1,285.27 1,966.03 5,947,337.86 560,722.35 5.00 -1,285.27 4,022.47 54.57 93.33 2,892.00 2,783.00 1,284.43 1,984.30 5,947,337.15 560,740.63 5.00 -1,284.43 Ugnu C 4,100.00 55.11 98.02 2,936.67 2,827.67 1,278.16 2,047.35 5,947,331.37 560,803.71 5.00 -1,278.16 4,200.00 56.08 103.97 2,993.20 2,884.20 1,262.41 2,128.28 5,947,316.26 560,884.76 5.00 -1,262.41 4,300.00 57.33 109.76 3,048.13 2,939.13 1,238.15 2,208.20 5,947,292.63 560,964.86 5.00 -1,238.15 4,400.00 58.83 115.38 3,101.03 2,992.03 1,205.56 2,286.51 5,947,260.65 561,043.42 5.00 -1,205.56 4,496.94 60,52 120.65 3,150.00 3,041.00 1,166.25 2,360.33 5,947,221.93 561,117.53 5.00 -1,166.25 Ugnu B 4,500.00 60.57 120.81 3,151.51 3,042.51 1,164.89 2,362.62 5,947,220.58 561,119.83 4.97 -1,164.89 4,600.00 62.53 126.05 3,199.17 3,090.17 1,116.45 2,435.94 5,947,172.72 561,193.52 5.00 -1,116.45 4,627.48 63.10 127.45 3,211.73 3,102.73 1,101.82 2,455.52 5,947,158.25 561,213.21 5.00 -1,101.82 Sail ~r7 63.10° Inc: 4627' MD, 3212' ND 4,643.56 63.10 127.45 3,219.00 3,110.00 1,093.11 2,466.90 5,947,149.62 561,224.66 0.00 -1,093.11 Ugnu A 4,700.00 63.10 127.45 3,244.54 3,135.54 1,062.50 2,506.86 5,947,119.33 561,264.85 0.00 -1,062.50 4,800.00 63.10 127.45 3,289.79 3,180.79 1,008.27 2,577.66 5,947,065.66 561,336.06 0.00 -1,008.27 4,825.13 63.10 127.45 3,301.16 3,192.16 994.64 2,595.45 5,947,052.17 561,353.96 0.00 -994.64 Continue Dir ~ 5°/100', TFO 75.94°: 482 5' MD, 3301' ND 4,900.00 64.06 131.49 3,334.48 3,225.48 952.03 2,647.19 5,947,009.96 561,406.02 5.00 -952.03 4,938.13 64.60 133.52 3,351.00 3,242.00 928.81 2,672.52 5,946,986.95 561,431.53 5.00 -928.81 K13 5,000.00 65.52 136.77 3,377.09 3,268.09 889.04 2,712.07 5,946,947.49 561,471.39 5.00 -889.04 5,100.00 67.17 141.93 3,417.24 3,308.24 819.56 2,771.69 5,946,878.48 561,531.55 5.00 -819.56 5,200.00 68.97 146.96 3,454.61 3,345.61 744.11 2,825.59 5,946,803.46 561,586.02 5.00 -744.11 7/26/2008 9:55:11AM Page 6 of 12 COMPASS 2003.11 Build 50 ORIGINAL ~ / Halliburton Energy Services Conoco Ph~llips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Inc: TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wellbore: 1J-103 Design: 1J-103 (wp06) Planned Survey 1J-103 (wp06) ~`~~d Sperry Driliing Servic®s Well Plan 1J-103 -Slot 1J-103 Plan RKB @ 109:OOft (Doyon 14Y (28+81)) Plan RKB @ 109.OOft (Doyoh 141 (28+81)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ftl (ftl (ft) (ft) (ftl (ftl (°/100ft) (ft) 5,300.00 70.92 151.86 3,488.92 3,379.92 663.26 2,873.34 5,946,723.00 561,634.40 5.00 -663.26 5,400.00 72.99 156,65 3,519.92 3,410.92 577.65 2,914.60 5,946,637.72 561,676.33 5.00 -577.65 5,500.00 75.17 161.33 3,547.36 3,438.36 487.90 2,949.05 5,946,548.25 561,711.47 5.00 -487.90 5,580.64 77.00 165.03 3,566.75 3,457.75 412.99 2,971.69 5,946,473.53 561,734.69 5.00 -412.99 Sail ~ 77.00° Inc: 5581' M D, 3567 TVD 5,600.00 77.00 165.03 3,571.11 3,462.11 394.77 2,976.56 5,946,455.35 561,739.70 0.00 -394.77 5,670.64 77.00 165.03 3,587.00 3,478.00 328.27 2,994.34 5,946,389.00 561,758.00 0.00 -328.27 WSAK D -1J -103 T1 (D to p) (wp06) 5,700.00 77.00 165.03 3,593.60 3,484.60 300.64 3,001.73 5,946,361.43 561,765.60 0.00 -300.64 5,799.56 77.00 165.03 3,616.00 3,507.00 206.92 3,026.79 5,946,267.92 561,791.39 0.00 -206.92 WSAK C 5,800.00 77.00 165.03 3,616.10 3,507.10 206.51 3,026.90 5,946,267.50 561,791.50 0.00 -206.51 5,825.64 77.00 165.03 3,621.87 3,512.87 182.37 3,033.35 5,946,243.42 561,798.15 0.00 -182.37 Continue Dir ~ 4°1100', TFO 55°: 5826' MD, 3622' TVD 5,900.00 78.72 167.51 3,637.51 3,528.51 111.76 3,050.60 5,946,172.95 561,815.94 4.00 -111.76 5,954.96 80.00 169.33 3,647.66 3,538.66 58.85 3,061.44 5,946,120.13 561,827.19 4.00 -58.85 Sail ~ 80° Inc: 5955' MD, 3648' TVD - WSAK B -1J-103 T2 (B top) (wp08) 6,000.00 80.00 169.33 3,655.48 3,546.48 15.26 3,069.65 5,946,076.61 561,835.74 0.00 -15.26 6,100.00 80.00 169.33 3,672.84 3,563.84 -81.52 3,087.88 5,945,979.99 561,854.73 0.00 81.52 6,104.96 80.00 169.33 3,673.70 3,564.70 -86.32 3,088.78 5,945,975.20 561,855.67 0.00 86.32 Continue Dir ~ 4°/100', TFO 90.71°: 6105' MD, 3674' TVD 6,152.68 79.98 171.27 3,682.00 3,573.00 -132.64 3,096.70 5,945,928.94 561,863.95 4.00 132.64 WSAK A4 6,200.00 79.98 173.19 3,690.23 3,581.23 -178.81 3,103.00 5,945,882.83 561,870.60 4.00 178.81 6,300.00 80.00 177.25 3,707.63 3,598.63 -276.92 3,111.20 5,945,784.80 561,879.57 4.00 276.92 6,304.96 80.00 177.45 3,708.49 3,599.49 -281.80 3,111.43 5,945,779.92 561,879.83 4.00 281.80 Sail ~ $0° Inc: 8305' MD, 3708' TVD 6,365.48 80.00 177.45 3,719.00 3,610.00 -341.34 3,114.07 5,945,720.41 561,882.94 0.00 341.34 WSAK A3 6,400.00 80.00 177.45 3,724.99 3,615.99 -375.30 3,115.58 5,945,686.46 561,884.72 0.00 375.30 6,500.00 80.00 177.45 3,742.36 3,633.36 -473.69 3,119.96 5,945,588.12 561,889.86 0.00 473.69 6,600.00 80.00 177.45 3,759.72 3,650.72 -572.07 3,124.33 5,945,489.79 561,895.00 0.00 572.07 6,680.96 80.00 177.45 3,773.78 3,664.78 -651.72 3,127.87 5,945,410.17 561,899.16 0.00 651.72 Continue Dir ~ 4°/100', TFO 0°: 8681' MD, 3774' TVD 6,700.00 80.76 177.45 3,776.96 3,667.96 -670.47 3,128.71 5,945,391.43 561,900.14 3.99 670.47 6,800.00 84.76 177.45 3,789.56 3,680.56 -769.56 3,133.11 5,945,292.39 561,905.32 4.00 769.56 6,805.96 85.00 177.45 3,790.09 3,681.09 -775.49 3,133.38 5,945,286.46 561,905.63 4.00 775.49 Sail ~ 85° inc: 6806 MD, 3790' TVD - 7 5/8" Casing - 1449' FSL & 692' FWL - WSAk A2 - 7 518" -1J-103 T3 (A2 Top) (wp08) 6,825.96 85.00 177.45 3,791.84 3,682.84 -795.39 3,134.26 5,945,266.57 561,906.67 0.00 795.39 Continue Dir ~ 4°/100°, TFO 10.03°: 68 28' MD, 3792' TVD 6,900.00 87.92 177.97 3,796.41 3,687.41 -869.23 3,137.21 5,945,192.77 561,910.20 4.00 869.23 7,000.00 91.86 178.66 3,796.61 3,687.61 -969.16 3,140.15 5,945,092.87 561,913.91 4.00 969.16 7/26/2008 &55:11AM Page 7 of 12 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhitlips Alaska Halliburton Energy Services Planning Report -Geographic Database: EDM 2003.11 Single UserDb Local Co-ordinate Reference Company: ConocoPhllips Alaska, Ina ND Reference: Project: Kuparuk River Unit< MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wel lbore: 1 J-103 Design: 1J-103 (wp06) Planned Survey 1J-103 (wp06) Sperry Drilling Services Well Plan 1J-103 -Slot 1J-103 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB Q 109.OOft (Doyon 141 (28+81)) True Minimum Curvature ' Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ftl (ft) lft) lft) (ft) (ft) (°/100ft) (ft) 7,004.75 92.04 178.70 3,796.45 3,687.45 -973.91 3,140.26 5,945,088.12 561,914.06 4.00 973.91 Sail @ 92.04° Inc: 7005' M D, 3796' TVD 7,100.00 92.04 178.70 3,793.05 3,684.05 -1,069.07 3,142.42 5,944,992.99 561,916.97 0.00 1,069.07 7,200.00 92.04 178.70 3,789.49 3,680.49 -1,168.98 3,144.69 5,944,893.11 561,920.02 0.00 1,168.98 7,285.29 92.04 178.70 3,786.45 3,677.45 -1,254.20 3,146.63 5,944,807.91 561,922.62 0.00 1,254.20 Continue Dir @ 4°/100', TFO 139.41°: 72 85' MD, 3786' TVD 7,299.22 91.62 179.06 3,786.00 3,677.00 -1,268.12 3,146.90 5,944,794.00 561,923.00 4.00 1,268.12 Continue Dir @ 3°1100', TFO 96.71°: 7299' MD, 3786' TVD -1J-103 T4 (wp06) 7,300.00 91.62 179.08 3,785.98 3,676.98 -1,268.90 3,146.91 5,944,793.22 561,923.02 3.00 1,268.90 7,321.46 91.54 179.72 3,785.39 3,676.39 -1,290.34 3,147.14 5,944,771.78 561,923.41 3.00 1,290.34 Sail @ 91.54° Inc: 7321' MD, 3785' TVD 7,400.00 91.54 179.72 3,783.27 3,674.27 -1,368.86 3,147.52 5,944,693.28 561,924.40 0.00 1,368.86 7,447.30 91.54 179.72 3,782.00 3,673.00 -1,416.14 3,147.75 5,944,646.00 561,925.00 0.00 1,416.14 Continue Dir @ 3°/100', TFO -74.19°: 7447.30' MD, 3782.00' TVD - 1J-103 TS (wp06) 7,459.21 91.64 179.38 3,781.67 3,672.67 -1,428.05 3,147.84 5,944,634.10 561,925.19 3.00 1,428.05 Sail ~ 91.64° Inc: 7459.' MD, 3782' TVD 7,500.00 91.64 179.38 3,780.50 3,671.50 -1,468.82 3,148.28 5,944,593.34 561,925.95 0.00 1,468.82 7,600.00 91.64 179.38 3,777.64 3,668.64 -1,568.77 3,149.37 5,944,493.41 561,927.81 0.00 1,568.77 7,700.00 91.64 179.38 3,774.78 3,665.78 -1,668.72 3,150.45 5,944,393.47 561,929.67 0.00 1,668.72 7,800.00 91.64 179.38 3,771.92 3,662.92 -1,768.68 3,151.53 5,944,293.54 561,931.54 0.00 1,768.68 7,900.00 91.64 179.38 3,769.06 3,660.06 -1,868.63 3,152.62 5,944,193.61 561,933.40 0.00 1,868.63 8,000.00 91.64 179.38 3,766.20 3,657.20 -1,968.58 3,153.70 5,944,093.68 561,935.26 0.00 1,968.58 8,100.00 91.64 179.38 3,763.34 3,654.34 -2,068.54 3,154.78 5,943,993.75 561,937.13 0.00 2,068.54 8,146.78 91.64 179.38 3,762.00 3,653.00 -2,115.29 3,155.29 5,943,947.00 561,938.00 0.00 2,115.29 Continue Dir @ 3°/100', TFO 157.73°: 81 47' MD, 3762 ' TVD - 1J-103 T6 (wp06) 8,191.17 90.41 179.88 3,761.21 3,652.21 -2,159.68 3,155.58 5,943,902.62 561,938.63 3.00 2,159.68 Sail ~ 90.41° Inc: 8191.17' MD, 3761.21' TVD 8,200.00 90.41 179.88 3,761.14 3,652.14 -2,168.50 3,155.59 5,943,893.80 561,938.72 0.00 2,168.50 8,300.00 90.41 179.88 3,760.43 3,651.43 -2,268.50 3,155.80 5,943,793.81 561,939.70 0.00 2,268.50 8,400.00 90.41 179.88 3,759.72 3,650.72 -2,368.50 3,156.00 5,943,693.83 561,940.69 0.00 2,368.50 8,500.00 90.41 179.88 3,759.01 3,650.01 -2,468.50 3,156.20 5,943,593.85 561,941.67 0.00 2,468.50 8,600.00 90.41 179.88 3,758.30 3,649.30 -2,568.49 3,156.41 5,943,493.86 561,942.65 0.00 2,568.49 8,700.00 90.41 179.88 3,757.59 3,648.59 -2,668.49 3,156.61 5,943,393.88 561,943.64 0.00 2,668.49 8,800.00 90.41 179.88 3,756.88 3,647.88 -2,768.49 3,156.81 5,943,293.90 561,944.62 0.00 2,768.49 8,900.00 90.41 179.88 3,756.17 3,647.17 -2,868.49 3,157.02 5,943,193.92 561,945.60 0.00 2,868.49 9,000.00 90.41 179.88 3,755.46 3,646.46 -2,968.48 3,157.22 5,943,093.93 561,946.59 0.00 2,968.48 9,100.00 90.41 179.88 3,754.75 3,645.75 -3,068.48 3,157.42 5,942,993.95 561,947.57 0.00 3,068.48 9,200.00 90.41 179.88 3,754.04 3,645.04 -3,168.48 3,157.63 5,942,893.97 561,948.55 0.00 3,168.48 9,300.00 90.41 179.88 3,753.33 3,644.33 -3,268.47 3,157.83 5,942,793.98 561,949.54 0.00 3,268.47 9,346.99 90.41 179.88 3,753.00 3,644.00 -3,315.46 3,157.93 5,942,747.00 561,950.00 0.00 3,315.46 Continue Dir @ 3°/100', TFO -167.59°: 9 347' MD, 3753' TVD - 1J-103 T7 (wp06) 9,354.38 90.19 179.84 3,752.96 3,643.96 -3,322.85 3,157.94 5,942,739.61 561,950.08 3.00 3,322.85 Sail ~ 90.19 ° Inc: 9354' MD, 3753' TVD 9,400.00 90.19 179.84 3,752.81 3,643.81 -3,368.47 3,158.07 5,942,694.00 561,950.56 0.00 3,368.47 9.500.00 90.19 179.84 3,752.48 3,643.48 -3,468.47 3,158.36 5,942,594.02 561,951.63 0.00. 3,468.47 7/26/2006 9:55:11AM Page 8 of 12 COMPASS 2003, i 1 Build 50 ~ ~ - ' / Hallib urton Ene rgy Servic es H ~.,,' -.~ ` :, Conoco Phill~ps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-103 -Slot 1J-103 Company: ConocoPhillips Alaska,: Inc. ND Reference: Plan RKB @ 109; OOft (Doyon 14 1 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109. OOft (Doyon 14 1 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calculatio n Method: Minimum Curvature Wellbore: 1 J-103 Design: 1J-103(wp06) Planned Survey 1J-103 (wp06 ) Map Map MD Inclination Azimuth ND SSND +NI-S +E/-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) (ft) lft) (ft) (ft) (ft) (°/100ft) (ft) ~ 9,600.00 90.19 179.84 3,752.15 3,643.15 -3,568.47 3,158.65 5,942,494.03 561,952.70 0.00 3,568.47 9,700.00 90.19 179.84 3,751.81 3,642.81 -3,668.47 3,158.93 5,942,394.05 561,953.76 0.00 3,668.47 9,800.00 90.19 179.84 3,751.48 3,642.48 -3,768.47 3,159.22 5,942,294.06 561,954.83 0.00 3,768.47 9,900.00 90.19 179.84 3,751.15 3,642.15 -3,868.47 3,159.51 5,942,194.08 561,955.90 0.00 3,868.47 10,000.00 90.19 179.84 3,750.82 3,641.82 -3,968.47 3,159.79 5,942,094.09 561,956.96 0,00 3,968.47 10,100.00 90.19 179.84 3,750.48 3,641.48 -4,068.47 3,160.08 5,941,994.11 561,958.03 0.00 4,068.47 10,200.00 90.19 179.84 3,750.15 3,641.15 -4,168.47 3,160.36 5,941,894.13 561,959.10 0.00 4,168.47 10,300.00 90.19 179.84 3,749.82 3,640.82 -4,268.46 3,160.65 5,941,794.14 561,960.16 0.00 4,268.46 10,400.00 90.19 179.84 3,749.49 3,640.49 -4,368.46 3,160.94 5,941,694.16 561,961.23 0.00 4,368.46 10,500.00 90.19 179.84 3,749.15 3,640.15 -4,468.46 3,161.22 5,941,594.17 561,962.30 0.00 4,468.46 10,600.00 90.19 179.84 3,748.82 3,639.82 -4,568.46 3,161.51 5,941,494.19 561,963.36 0.00 4,568.46 10,700.00 90.19 179.84 3,748.49 3,639.49 -4,668.46 3,161.80 5,941,394.21 561,964.43 0.00 4,668.46 10,800.00 90.19 179.84 3,748.16 3,639.16 -4,768.46 3,162.08 5,941,294.22 561,965.50 0.00 4,768.46 10,847.23 90.19 179.84 3,748.00 3,639.00 -4,815.69 3,162.22 5,941,247.00 561,966.00 0.00 4,815.69 Continue Dir @ 3°/100', TFO -176.33°: 10 847' MD, 3748' ND - 1J-10 3 T8 (wp05) 10,878.72 89.25 179.78 3,748.15 3,639.15 -4,847.18 3,162.32 5,941,215.51 561,966.35 3.00 4,847.18 Sail @ 89.25° Inc: 10879' MD, 3748' ND 10,900.00 89.25 179.78 3,748.43 3,639.43 -4,868.46 3,162.41 5,941,194.24 561,966.60 0.00 4,868.46 11,000.00 89.25 179.78 3,749.75 3,640.75 -4,968.45 3,162.80 5,941,094.26 561,967.77 0.00 4,968.45 11,019.27 89.25 179.78 3,750.00 3,641.00 -4,987.71 3,162.88 5,941,075.00 561,968.00 0.00 4,987.71 Continue Dir @ 3°/100', TFO 41.76°: 11019' MD, 3750' TVD - 1J-103 T9 (wp06) 11,056.78 90.09 180.52 3,750.22 3,641.22 -5,025.22 3,162.78 5,941,037.50 561,968.19 3.00 5,025.22 Sail @ 90.09° Inc: 11057' MD, 3750' ND 11,100.00 90.09 180.52 3,750.15 3,641.15 -5,068.44 3,162.38 5,940,994.28 561,968.14 0.00 5,068.44 11,200.00 90.09 180.52 3,750.00 3,641.00 -5,168.44 3,161.47 5,940,894.29 561,968.00 0.00 5,168.44 11,200.29 90.09 180.52 3,750.00 3,641.00 -5,168.73 3,161.46 5,940,894.00 561,968.00 0.00 5,168.73 Continue Dir @ 5°1700', TFO -179.31°: 11 200' MD, 3750' ND -1J-10 3 T10 (wp05) 11,300.00 85.10 180.46 3,754.18 3,645.18 -5,268.31 3,160.60 5,940,794.42 561,967.92 5.00 5,268.31 11,370.51 81.58 180.42 3,762.36 3,653.36 -5,338.34 3,160.06 5,940,724.40 561,967.92 5.00 5,338.34 Sail @ 81.58° Inc: 11371' MD, 3782' ND 11,400.00 81.58 180.42 3,766.68 3,657.68 -5,367.51 3,159.85 5,940,695.23 561,967.94 0.00 5,367.51 11,496.11 81.58 180.42 3,780.76 3,671.76 -5,462.57 3,159.15 5,940,600.17 561,967.98 0.00 5,462.57 Continue Dir @ 5°/100'. TFO 0.16°: 11498.11' MD, 3780.76' ND 11,500.00 81.77 180.42 3,781.32 3,672.32 -5,466.43 3,159.12 5,940,596.32 561,967.98 4.94 5,466.43 11,600.00 86.77 180.44 3,791.30 3,682.30 -5,565.89 3,158.37 5,940,496.86 561,968.01 5.00 5,565.89 11,700.00 91.77 180.45 3,792.57 3,683.57 -5,665.85 3,157.60 5,940,396.91 561,968.02 5.00 5,665.85 11,703.18 91.93 180.45 3,792.47 3,683.47 -5,669.02 3,157.58 5,940,393.73 561,968.02 5.00 5,669.02 Sail ~ 91.93° Inc: 11703' MD, 3792' ND 11,800.00 91.93 180.45 3,789.21 3,680.21 -5,765.79 3,156.82 5,940,296.98 561,968.01 0.00 5,765.79 11,900.00 91.93 180.45 3,785.84 3,676.84 -5,865.73 3,156.03 5,940,197.04 561,968.01 0.00 5,865.73 12,000.00 91.93 180.45 3,782.47 3,673.47 -5,965.67 3,155.25 5,940,097.11 561,968.01 0.00 5,965.67 12,100.00 91.93 180.45 3,779.11 3,670.11 -6,065.61 3,154.46 5,939,997.18 561,968.00 0.00 6,065.61 12,103.18 91.93 180.45 3,779.00 3,670.00 -6,068.79 3,154.44 5,939,994.00 561,968.00 0.00 6,068.79 Continue Dir ~ 3°H00', TFO -179.81°: 12103.18' MD, 3779.00' ND -1J-103 T71 (wp05) 7/26/2006 9:55:11AM Page 9 of 12 COMPASS 2003.11 Build 50 ORIGINAL • • . Halliburton Energy Services T Conoco Ph~llips Planning Report -Geographic Alaska Sperry Drilling Service Database: EDM 2003.11 Single UsecDb Local Co-ordinate Reference: Well Plan 1J-103- Slot 1J-103 Company: CnnocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: KuparukRiver Unit MD Reference: Plan RKB @ 109:OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-103 Design: 1 J-103 (wp06) Planned Survey 1J-103 (wp06) __ Map Map MD I nclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) tft) (ft) (ft) (°/100ft) (ft) 12,131.60 91.08 180.45 3,778.25 3,669.25 -6,097.20 3,154.21 5,939,965.58 561,968.00 3.00 6,097.20 Sail @ 91.08° Inc: 12132' MD, 3778' TVD 12,200.00 91.08 180.45 3,776.97 3,667.97 -6,165.58 3,153.68 5,939,897.21 561,968.00 0.00 6,165.58 12,300.00 91.08 180.45 3,775.09 3,666.09 -6,265.56 3,152.90 5,939,797.24 561,968.00 0.00 6,265.56 12,400.00 91.08 180.45 3,773.21 3,664.21 -6,365.54 3,152.12 5,939,697.26 561,968.00 0.00 6,365.54 12,500.00 91.08 180.45 3,771.33 3,662.33 -6,465.52 3,151.34 5,939,597.29 561,968.00 0.00 6,465.52 12,600.00 91.08 180.45 3,769.45 3,660.45 -6,565.50 3,150.56 5,939,497.32 561,968.00 0.00 6,565.50 12,700.00 91.08 180.45 3,767.57 3,658.57 -6,665.48 3,149.78 5,939,397.35 561,968.00 0.00 6,665.48 12,800.00 91.08 180.45 3,765.69 3,656.69 -6,765.46 3,149.00 5,939,297.37 561,968.00 0.00 6,765.46 12,900.00 91.08 180.45 3,763.81 3,654.81 -6,865.44 3,148.22 5,939,197.40 561,968.00 0.00 6,865.44 13,000.00 91.08 180.45 3,761.93 3,652.93 -6,965.42 3,147.44 5,939,097.43 561,968.00 0.00 6,965.42 13,100.00 91.08 180.45 3,760.05 3,651.05 -7,065.40 3,146.66 5,938,997.45 561,968.00 0.00 7,065.40 13,102.46 91.08 180.45 3,760.00 3,651.00 -7,067.85 3,146.64 5,938,995.00 561,968.00 0.00 7,067.85 Continue Dlr ~ 3°/100'. TFO 180°: 13102 .48' MD, 3760.00' TVD - 1J-103 712 (wp06) 13,124.34 90.42 180.45 3,759.71 3,650.71 -7,089.74 3,146.47 5,938,973.12 561,968.00 3.00 7,089.74 Sail @ 90.42° Inc: 13124.34' MD, 3759.71 ' TVD 13,200.00 90.42 180.45 3,759.16 3,650.16 -7,165.39 3,145.88 5,938,897.47 561,968.00 0.00 7,165.39 13,300.00 90.42 180.45 3,758.42 3,649.42 -7,265.38 3,145.10 5,938,797.48 561,968.00 0.00 7,265.38 13,400.00 90.42 180.45 3,757.69 3,648.69 -7,365.38 3,144.32 5,938,697.49 561,968.00 0.00 7,365.38 13,500.00 90.42 180.45 3,756.96 3,647.96 -7,465.37 3,143.54 5,938,597.51 561,968.00 0.00 7,465.37 13,600.00 90.42 180.45 3,756.22 3,647.22 -7,565.37 3,142.76 5,938,497.52 561,968.00 0.00 7,565.37 13,700.00 90.42 180.45 3,755.49 3,646.49 -7,665.36 3,141.98 5,938,397.53 561,968.00 0.00 7,665.36 13,800.00 90.42 180.45 3,754.75 3,645.75 -7,765.35 3,141.20 5,938,297.54 561,968.00 0.00 7,765.35 13,900.00 90.42 180.45 3,754.02 3,645.02 -7,865.35 3,140.41 5,938,197.55 561,968.00 0.00 7,865.35 13,902.55 90.42 180.45 3,754.00 3,645.00 -7,867.90 3,140.39 5,938,195.00 561,968.00 0.00 7,867.90 Continue Dir ~ 3°/100', TFO 0°: 13902.55' MD, 3754.00' TVD -1J-10 3 713 (wp05) 13,910.40 90.66 160.45 3,753.93 3,644.93 -7,875.75 3,140.33 5,938,187.16 561,968.00 3.00 7,875.75 Sail ~ 90.55° Inc: 13910' MD, 3754' TVD 14,000.00 90.66 180.45 3,752.90 3,643.90 -7,965.34 3,139.63 5,938,097.57 561,968.00 0.00 7,965.34 14,100.00 90.66 180.45 3,751.76 3,642.76 -8,065.33 3,138.85 5,937,997.59 561,968.00 0.00 8,065.33 14,200.00 90.66 180.45 3,750.61 3,641.61 -8,165.32 3,138.07 5,937,897.60 561,968.00 0.00 8,165.32 14,300.00 90.66 180.45 3,749.47 3,640.47 -8,265.31 3,137.29 5,937,797.62 561,968.00 0.00 8,265.31 14,400.00 90.66 180.45 3,748.32 3,639.32 -8,365.30 3,136.51 5,937,697.64 561,968.00 0.00 8,365.30 14,500.00 90.66 180.45 3,747.18 3,638.18 -8,465.29 3,135.73 5,937,597.65 561,968.00 0.00 8,465.29 14,600.00 90.66 180.45 3,746.03 3,637.03 -8,565.28 3,134.95 5,937,497.67 561,968.00 0.00 8,565.28 14,602.67 90.66 180.45 3,746.00 3,637.00 -8,567.95 3,134.93 5,937,495.00 561,968.00 0.00 8,567.95 Continue Dir ~ 3°/100', TFO 180°: 14602.67' MD, 3745.00' TVD - 1J-103 714 (wp05) 14,637.41 89.61 180.45 3,745.92 3,636.92 -8,602.69 3,134.66 5,937,460.27 561,968.00 3.00 8,602.69 Sail ~ 89.81° Inc: 14637 MD, 3748' TVD 14,700.00 89.61 180.45 3,746.34 3,637.34 -8,665.28 3,134.17 5,937,397.68 561,968.00 0.00 8,665.28 14,800.00 89.61 180.45 3,747.01 3,638.01 -8,765.27 3,133.39 5,937,297.69 561,968.00 0.00 8,765.27 14,900.00 89.61 180.45 3,747.69 3,638.69 -8,865.27 3,132.61 5,937,197.70 561,968.00 0.00 8,865.27 15,000.00 89.61 180.45 3,748.36 3,639.36 -8,965.26 3,131.83 5,937,097.71 561,968.00 0.00 8,965.26 15,094.73 89.61 180.45 3,749.00 3,640.00 -9,059.98 3,131.09 5,937,003.00 561,968.00 0.00 9,059.98 BHL ~ 15095' MD, 3749' TVD -1555' FNL & 681' FWL - Sec12-T10N-R10E - 4 112" - 1J-103 715 (Toe) (wp06) 7/26/2006 9:55:11AM Page 70 of 12 COMPASS 2003.11 Build 50 ORIGINAL `/ Halliburton Energy Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alas)<a, lnc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wellbore: 1 J-103 Design: 1J-103 (wp06) Geologic Targets 1J-103 L ~ T Sp®rry Drilling S®rvic®s TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,790.09 1J-103 T3 (A2 Top) (wp06) -775.49 3,133.38 5,945,286.46 561,905.63 - Point 3,779.00 1J-103 T11 (wp06) -6,068.79 3,154.44 5,939,994.00 561,968.00 - Point 3,750.00 1J-103 T9 (wp06) -4,987.71 3,162.88 5,941,075.00 561,968.00 - Point 3,750.00 1J-103 T10 (wp06) -5,168.73 3,161.46 5,940,894.00 561,968.00 - Point 3,749.00 1J-103 T15 (Toe) (wp06) -9,059.98 3,131.09 5,937,003.00 561,968.00 - Point 3,782.00 1J-103 TS (wp06) -1,416.14 3,147:75 5,944,646.00 561,925.00 - Point 3,748.00 1J-103 T8 (wp06) -4,815.69 3,162.22 5,941,247.00 561,966.00 - Point 3,786.00 1J-103 T4 (wp06) -1,268.12 3,146.90 5,944,794.00 561,923.00 - Point 3,647.66 1J-103 T2 (B top) (wp06) 58.85 3,061.44 5,946,120.13 561,827.19 - Point 3,754.00 1J-103 T13 (wp06) -7,867.90 3,140.39 5,938,195.00 561,968.00 - Point 3,762.00 1J-103 T6 (wp06) -2,115.29 3,155.29 5,943,947.00 561,938.00 - Point 3,746.00 1J-103 T14 (wp06) -8,567.95 3,134.93 5,937,495.00 561,968.00 - Point 3,760.00 1J-103 T12 (wp06) -7,067.85 3,146.64 5,938,995.00 561,968.00 - Point 3,587.00 1J-103 T1 (D top) (wp06) 328.27 2,994.34 5,946,389.00 561,758.00 - Point 3,753.00 1J-103 T7(wp06) -3,315.46 3,157.93 5,942,747.00 561,950.00 - Point 7/26/2006 9:5&11AM Page 11 of 12 ~~ ~. COMPASS 2003.11 Build 50 ' ~ ~-' Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: CanocoPhillips Alaska, Inc. ND Reference: Project: Kupa~uk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wellbore: 1 J-103 Design: 1J-103 (wp06) Prognosed Casing Points Sperry Drilling Servic®~ Well Plan 1 J-103 -Slot 1 J-103 Plan RKB Q 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109:OOft (Doyon 141 (28+81)) True Minimum Gunrature Measured Vertical Casing Hole Depth Depth Diameter Diameter (ftj (ft) ('~) (") 2,880.89 2,242.00 10-3/4 13-1l2 6,805.96 3,790.09 7-518 9-7l8 15,094.69 3,749.00 4-112 5-314 -- Prognosed Formation Intersection Points _ _ _ _ .- Measured Vertical Depth Inclination Azimuth Depth +N7-E +E/-W (ft) (°) (°) (ft1 (ftl (ft1 Name 1,655.78 47.14 45.00 1,518.00 346.97 346.97 Base Penn 1,871.03 50.39 46.00 1,663.00 459.11 459.75 T3 2,367.82 55.60 58.03 1,955.00 722.31 762.47 K15 2,880.89 56.00 60.00 2,242.00 935.36 1,130.53 T3+550 4,022.47 54.57 93.33 2,892.00 1,284.43 1,984.30 Ugnu C 4,496.94 60.52 120.65 3,150.00 1,166.25 2,360.33 Ugnu B 4,643.56 63.10 127.45 3,219.00 1,093.11 2,466.90 Ugnu A 4,938.13 64.60 133.52 3,351.00 928.81 2,672.52 K13 5,670.64 77.00 165.03 3,587.00 328.27 2,994.34 WSAK D 5,799.56 77.00 165.03 3,616.00 206.92 3,026.79 WSAK C 5,954.96 80.00 169.33 3,647.66 58.85 3,061.44 WSAK B 6,152.68 79.98 171.27 3,682.00 -132.64 3,096.70 WSAK A4 6,365.48 80.00 177.45 3,719.00 -341.34 3,114.07 WSAK A3 6,805.96 85.00 177.45 3,790.09 -775.49 3,133.38 WSAkA2 7/26/2006 9:55:11AM Page 12 of 12 COMPASS 2003.11 Burld 50 a~~~~~~~ • • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-103 1 J-103 1 J-103 (wp06) Anticollision Report 26 July, 2006 ;~J = L~ _. rte' ~x..,:~ cw~r:,~''` ~ ~ Sf ~ Sperry Drilling Services. SURVEY PROGRAM Date: 20116-O+IYJTINI:INI:INI Validated: Ycs Vcrsinn: Depth From Dcplh To Sunny/Plan Tad ?8.011 0.IN1 1J-1113 (1vpIM) CB-GYRO-SS BW.IN1 1i0Y4.70 IJ-1113 h1'Idw) 8iN'D+IFR-AK-CAZSC NAD 27 ASP Zone 4 : WELL DETAILS: Plan iJ-103 Ground Level: 81.00 +N/S +E/-W Nonhing Easting Latinude Longitude Slot 0.00 0.00 5946037.40 658766.60 70°75'47.418N 149°31'29.659W 1J-103 ~l ~ 0 V z D 1J-152 _ 270 iJ-03 - - - ANTI-COLLISION SETTINGS Imerpolation Methotl: MD Interval: SOStations Depth Range From: 26.00 To 15094.73 Maximum Range:1706.67261519101 Reference: Plan: 1J-103 (wp06) a From Colour To M[ 28 250 250 500 500 750 750 - - -~ - _- 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 i] 5000 6000 6000 7000 7000 - _ - 8000 8000 9000 9000 10000 looo0 125oD 1J-105 (wpO3) 1J-101 ~~ - tsvs~ ]+'/ _ ) i) "~-'~\ , 1J-158 (wp03) ~ ~ ~i -i ~C~i,~f:,'y ~~' ` ~Y - - 1J-109 Rig Surveys I ]T /I 1J-160 (wpO1) BHI / ~~~~r `~ _ ~i' ~ _ ~ t~ \ 1J-159 .~ I ~ „yU 1J-1O7(wpO2) I WSP-1S ,~ WSP-15 WSP 02 ~~ ',JSP-03 180 ~ 1J-111 (wpO3) 1J-102 (wpO7) 1J-164 ~ 1J-115 (wp05) Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre tD Centre Separation ~ISU ft/ink REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Plan 1J-103 -Slot 1J-103, True North Vertical (ND) Reference: Plan RKB @ 109.OOR (Doyon 141 (28+81)) Section (VS) Reference: Slot - 1J-103(O.OON, O.OOE) Measured Depth Reference: Plan RKB ~ 109.OOR (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 90 I • sSCTau ol;Ta~.9 St< 61° Inc qu TVD +W-9 +EI-W °Leg TFxe Vfiec TxOH 1 28 OQ 0.00 0.00 28.00 0.00 000 0.00 2 300.00 0.00 0.00 ]00.00 0.00 0.00 0.00 0.00 0.00 eD0 0.00 J ]O2.% 10.09 46.00 ]00.00 U.e1 2d.8] 2.50 4 162931 4T.1d 45OD 1500.% 33325 33325 400 4500 -26.81 0.00 JJ325 5 1804 31 d].14 4fi 00 1619 03 423 % 433.% 000 6 1964.% 66.00 /]00 1)08.28 l%.28 602.09 6. 0.00 12).96 1].34 -09928 ) x1e6 % u.DO 4] o0 180956 6n TO 64a.a9 ao 8 2401 J3 %.00 6000 197389 ]3662 186.30 500 o.oo a31 To BJ 15 ]3662 9 34]543 %.00 %00 25]5.01 118223 1558.12 000 10 4611 d8 6).10 12).45 3211.)] 110182 245652 600 0.00 -110223 10259 -110183 11 4816 3 63.10 13145 3301.16 99466 269545 0.00 12 65%W ]].00 18503 3%6.16 299 29]1.69 600 0.00 -994.fid ]5.90 -01399 1] %10 fi4 ]100 165D3 358].00 3283] M96.J0 000 16 682564 )700 18503 %3187 182.3] 3031.35 000 e00 JZB.2) 1J.1D]T11D top)1wp%I eD0 183.1] 15 5961.% 8000 169 J1 366766 5885 306tH 600 55.00 -58.05 1)-103 7219 mp)Iwp%I 1fi 6104.% ae00 1fi9.31 J6i1.10 B6 J2 2008]8 000 n s3a.% a°oo m.as aoe a9 xet e0 3n1.u 4.00 iB 6680.% 80.00 17/.65 1]]978 d51 ]3 3131.8) 000 0.00 86]2 90.]1 2816D 0.00 651.]3 19 68%58 85.00 17).0.5 3)90.09 )]549 3133.)8 400 30 6826.% 86.00 17/.66 3]91.84 )%J9 3134.26 0.00 0.00 1]6.49 1J-103 T31A2 TOpIlwpOfi) 0.00 195.39 31 ]004.]5 92.04 1]8.70 3]9645 9)1.91 3140.28 4.00 22 ]306.29 9204 1]8.10 3]8665 -1256.20 3146.61 0.00 23 )3%.22 9162 1]906 )186.00 -1268.12 )166.% 4.00 10.03 973.91 0.00 1350.20 139.41 1360.12 1J-103 T41wp06) 24 )331.68 9150 119.]2 )]85.39 -1290.34 )14].10 3.00 25 )YT30 91.51 1]9.13 3]82.00 -141fi.id 316].16 0.% 96.11 1290.36 0.00 1416.]4 11103 T51wp061 26 ]0.5911 9164 1]9.18 3]01.6] -1428.05 Ii4].&t 800 2T 8146.]8 9164 1]938 3]62.00 3115.29 11%19 0.00 -]4.19 162805 0.00 211519 1J-103 T61rN061 IB 8191.1) 9041 1]9.88 3161.21 -2159.68 31 %.% 3.00 29 9N6.% 9061 1]9.% 3153.00 -3315.66 315].93 0.00 15].]3 2159.fi8 000 331546 1)-103 TI (wpoel 30 93').38 90.19 1]9.84 ]75296 )322.85 315].96 3.00 31 1084).33 90.19 1]9.84 3]68.00 -0015.69 3162.11 0.00 -16].59 3]21.85 000 4815.69 1).103 TB Itwo61 33 108)8.]2 8915 1]9.iB 3]60.15 )801.18 316211 3.00 JI 11019.2] 0915 1]9.)0 ]]5000 -090].)1 ]16288 0.00 -1]6.33 484].18 0.00 698].)1 1J-103 i81wp081 36 110%.18 90.09 180.52 ]]5012 -502522 3162]8 J.00 35 11200.39 90.09 1%.52 )]50.00 -6160.]3 3161.46 0.00 61.16 502512 000 5160.]3 1J~103 T101wp06) I6 113]0.51 8158 1%xt 3]62.36 533834 3160.% 6.00 l] 116%.ii 8158 180.63 ]]8016 -506]5) )169.15 0.00 ]8 11)0]18 91.93 10005 31924] ~%69.02 J15T.% 6.00 -1)9]1 5338.36 0.00 56615] 0.16 %6902 39 1210].18 9153 180.48 )119.00 -6068.)9 31566M1 0.00 0.00 606819 1J-103 T111wy061 00 12131.60 91.08 180.66 3118.25 -609710 3156.21 3.00 41 1]10246 9100 180-05 3)6000 -TO6>.85 3146.64 0.00 42 13124.34 90.43 18046 )169.]1 -]009.)6 3146.6] 900 -1]9.81 609]20 0.00 ]067.85 iJ-103 T121wpOfil 18000 ]089.)4 03 13902.55 90.62 180.66 3)56.00 ]861.90 3140.39 0.00 d4 1391040 90.66 18065 )]5].93 ~TBTS]5 3140.)) 900 000 ]861.90 1J-103 T131wp06) 000 ]8]5)5 45 14602 6) 9 6 180 65 )]46.00 -B%] 95 3114.9) 000 d6 1463]x1 89.61 180.65 3]05.92 860369 3114.66 3.00 41 160M.]I 89.61 18065 ]]69.00 -9059.98 ]1)1.09 0.00 0 00 0%7.95 1}103 T141wp06) 180.00 8602.69 0.00 9059.98 1}103 T151TceIlwp061 ConocoPhillips Alaska, Inc. Drilling 8 Wells West Sak Calculation Methotl: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylintler North Error Surface: Elliptical Conic Warning Method: Rules Based 1so Travelling Cylinder Azimuth ('PFO+AZI) ~°) vs Centre to Centre Separafion ConocoPhillips Alaska Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Pian 1J-103 Well Error: O.OOft Reference Wellbore 1 J-103 Reference Design: 1 J-103 (wp06) Halliburton Energy Services • H Anticollision Report Sperry Drilling 8®rvices Local Co-ordinate Reference: Welf Plan 1J-103 -Slot 1J-103 TVD Reference: Plart RKB (c~ 109:OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109:OOft (Doyon 141. (28+81)) North Reference: Ttue Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003:11 Single User Db Offset TVD Reference: Offset Datum Reference 1J-103 (wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,706.67ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 7/24/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 0.00 1J-103 (wp06) (1J-103) CB-GYRO-SS Camera based gyro single shot 800.00 15,094.70 1J-103 (wp06) (1J-103) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/28/2006 11;58:48AM Page 2 of 6 COMPASS 2003.11 Build 50 • r ~' Halliburton Energy Services L T ConocoPh ~ll~ps Anticollision Report Alaska Sperry Drilling Services Company: GonocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1 J-103 -Slot 1 J-103 Project: Kuparuk River Unit ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141..(28+81)) Site Error: O:OOft North Reference: True Reference Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore 1J-103 Database: EDM 2003.11 Single UserDb Reference Design: 1J-103 (vvp06) Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad. 1 J-03 - 1 J-03 - 1 J-03 390.34 400.00 118.79 7.10 111.68 Pass -Major Risk 1 J-09 - 1 J-09 - 1 J-09 293.93 300.00 153.51 5.37 148.14 Pass -Major Risk 1J-101 - 1J-101 - 1J-101 701.31 700.00 50.97 15.28 35.68 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 701.31 700.00 50.97 15.28 35.68 Pass -Major Risk 1J-101 - 1J-101 L1 PB1 - 1J-101 L1 P61 701.31 700.00 50.97 15.28 35.68 Pass -Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 701.31 700.00 50.97 15.28 35.68 Pass -Major Risk 1J-101 - 1J-101P61 - 1J-101PB1 701.31 700.00 50.97 15.28 35.68 Pass- Major Risk 1J-127 - 1J-127 - 1J-127 4,199.37 4,800.00 512.42 95.39 428.15 Pass -Major Risk 1J-127 - 1J-127 L1 - 1J-127 L1 4,199.37 4,800.00 512.42 95.39 428.15 Pass -Major Risk 1J-127 - 1J-127 L1 P61 - 1J-127 L1 PB1 4,199.37 4,800.00 512.42 95.38 428.15 Pass -Major Risk 1J-127 - 1J-127 L2 - 1J-127 L2 4,199.37 4,800.00 512.42 95.37 428.15 Pass -Major Risk 1J-127 - 1J-127 P61 - 1J-127 P61 4,199.37 4,800.00 512.42 95.38 428.15 Pass -Major Risk 1J-127 - 1J-127 PB2 - 1J-127 PB2 4,199.37 4,800.00 512.42 95.39 428.15 Pass -Major Risk 1J-14 - 1J-14 - 1J-14 9,608.95 6,200.00 369.89 166.21 219.23 Pass -Major Risk 1J-152 - 1J-152 - 1J-152 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1 J-152 - 1 J-152 L1 - 1 J-152 L1 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1 J-152 - 1 J-152 L2 - 1 J-152 L2 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1J-152 - 1J-152 L2 P61 - 1J-152 L2 PB1 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1J-152 - 1J-152 PB1 - 1J-152 PB1 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1 J-152 - 1 J-152 PB2 - 1 J-152 PB2 394.78 400.00 148.21 8.61 139.60 Pass -Major Risk 1 J-154 - 1 J-154 - 1 J-154 393.74 400.00 154.89 8.71 146.18 Pass -Major Risk 1J-154 - 1J-154 L1 - 9J-154 L1 393.74 400.00 154.89 8.71 146.18 Pass -Major Risk 1 J-154 - 1 J-154 L2 - 1 J-154 L2 393.74 400.00 154.89 8.71 146.18 Pass -Major Risk 1 J-159 - 1 J-159 - 1 J-159 842.48 900.00 202.98 18.25 185.15 Pass -Major Risk 1 J-159 - 1 J-159 L1 - 1 J-159 L1 842.48 900.00 202.98 18.25 185.15 Pass -Major Risk 1J-159 - 1J-159 L1 P61 - 1J-159 L1 P61 842.48 900.00 202,98 18.25 185.15 Pass -Major Risk 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 P62 842.48 900.00 202.98 18.25 185.15 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 842.48 900.00 202.98 18.25 185.15 Pass -Major Risk 1J-159 - 1J-159 P61 - 1J-159 PB1 842.48 900.00 202.98 18.25 185.15 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 300.00 300.00 315.83 6.64 309.19 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 300.00 300.00 315.83 6.64 309.19 Pass -Major Risk 1 J-164 - 1 J-164 L2 - 1 J-164 L2 300.00 300.00 315.83 6.64 309.19 Pass -Major Risk 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 P61 300.00 300.00 315.83 6.64 309.19 Pass -Major Risk Plan 1 J-102 - 1 J-102 - 1 J-102 (wp07) 500.92 500.00 22.56 10.87 11.70 Pass -Major Risk Plan 1 J-102 - 1 J-102 - 1 J-102 Rig Surveys 28.00 28.00 20.01 1.01 19.00 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) 500.92 500.00 22.56 10.87 11.70 Pass -Major Risk Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp07) 500.92 500.00 22.56 10.87 11.70 Pass -Major Risk Plan 1J-103 - 1J-103 L1 - 1J-103 L1 (wp06) 5,999.96 5,999.98 1.30 4.47 -1.80 FAIL - No Errors Plan 1J-103 - 1J-103 L2 - 1J-103 L2 (wp06) 5,699.97 5,699.98 0.78 3.41 -1.74 FAIL- No Errors Plan 1 J-105 - 1 J-105 - 1 J-105 (wp03) 498.00 500.00 42.94 10.81 32.14 Pass -Major Risk Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp03) 498.00 500.00 42.94 10.81 32.14 Pass -Major Risk Plan 1 J-105 - 1 J-105 L2 - 1 J-105 L2 (wp03) 498.00 500.00 42.94 10.81 32.14 Pass -Major Risk Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) 398.20 400.00 81.07 8.64 72.44 Pass -Major Risk Plan 1 J-109 -Plan 1 J-109 - 1 J-109 (wp05) 385.29 400.00 140.99 8.51 132.49 Pass -Major Risk Plan 1J-109 -Plan 1J-109 - 1J-109 Rig Surveys 385.04 400.00 137.94 8.55 129.39 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) 396.05 400.00 181.22 8.71 172.51 Pass- Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J 383.17 400.00 200.77 8.36 192.41 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot- 1J-12 Pilot 383.17 400.00 200.77 8.36 192.41 Pass -Major Risk Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral 383.17 400.00 200.77 8.36 192.41 Pass -Major Risk Plan 1 J-115 -Plan 1 J-115 - 1 J-115 (wp05) 394.37 400.00 260.89 8.58 252.31 Pass -Major Risk Plan 1J-115 -Plan 1J-115 L1 - 1J-115 L1 (wp05) 394.37 400.00 260.89 8.58 252.31 Pass -Major Risk Plan 1 J-115 -Plan 1 J-115 L2 - 1 J-115 L2 wp05) 394.37 400.00 260.89 8.58 252.31 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/26/2006 11:56:46AM Page 4 of 6 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Company: GonocoPhillips Alaska, Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-103 Well Error: O:OOft Reference Wellbore 1J-103 Reference Design: 1J-103 (wp06) • Halliburton Energy Services Anticollision Report ..:... ~.. t ~.... Sperry Drilling Services local Co-ordinate Reference: Well Plan 1 J-103 -Slot 1 J-103 ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141(28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 J Pad Plan 1 J-118 - 1 J-118 - 1 J-118 (wp03) 393.18 400.00 321.73 8.56 313.17 Pass -Major Risk Plan 1J-118 - 1J-118 L1 - 1J-118 L1 (wp03) 393.18 400.00 321.73 8.56 313.17 Pass- Major Risk Plan 1J-118 - 1J-118 L2 - 1J-118 L2 (wp03) 393.18 400.00 321.73 8.56 313.17 Pass -Major Risk Plan 1 J-130 - 1 J-130 - 1 J-130 (wp02) 378.03 400.00 561.63 8.39 553.24 Pass -Major Risk Plan 1J-133 - 0141 - 1J-133 - 1J-133 (wp06) 300.00 300.00 620.09 6.60 613.48 Pass -Major Risk Plan 1J-133 - 0141 - 1J-133 L1 - 1J-133 L1 (wp06 300.00 300.00 620.09 6.60 613.48 Pass -Major Risk Plan 1J-135 - 1J-135- Plan 1J-135 (wp01) 13,120.29 8,900.00 194.69 19.97 194.17 Pass-Minor 1/200 Plan 1J-136 - 1J-136 - 1J-136 (wp05) 376.17 400.00 680.83 8.36 672.47 Pass -Major Risk Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp05) 376.17 400.00 680.83 8.36 672.47 Pass -Major Risk Plan 1 J-150 (Ugnu Disposal) -Plan 1 J-UgnuDisposal 300.00 300.00 151.46 5.80 145.66 Pass -Major Risk Plan 1 J-156 - 1 J-156 - 1 J-156 Rig Surveys 299.98 300.00 178.17 6.64 171.53 Pass -Major Risk Plan 1J-156 - 1J-156 L1 - 1J-156 L1 299.98 300.00 178.17 6.64 171.53 Pass -Major Risk Plan 1J-156 - 1J-156 L1 PB1 - 1J-156 L1 P61 299.98 300.00 178.17 6.64 171.53 Pass- Major Risk Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) 300.00 300.00 176.94 6.49 170.45 Pass -Major Risk Plan 1J-156 - 1J-156 L2 - 1J-156 L2 Rig Surveys 299.98 300.00 178.17 6.64 171.53 Pass -Major Risk Plan 1 J-158 - 1 J-158 - 1 J-158 (wp03) 300.00 300.00 202.25 6.34 195.91 Pass -Major Risk Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI 299.99 300.00 232.12 6.49 225.63 Pass- Major Risk WSP-02 -WSP-02 -WSP-02 389.77 400.00 166.15 7.95 158.20 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 496.14 500.00 227.51 13.75 213.76 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 484.90 500.00 108.43 12.36 96.07 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S 689.78 700.00 56.06 25.68 31.87 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/26/2006 11:56:46AM Page 5 of 6 COMPASS 2003.11 Build 50 !~p.~ • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-103 -Slot 1J-103 Plan: 1J-103 (wp06) 1/4 Mile Scan 26 July, 2006 • Sperry Drilling Services oRiciNA~. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-103 Wellbore: 1 J-103 Plan: 1J-103 (wp06) Plan 1J-115 (wp05) 11 O I I -750 I I I i I -1500 I 1 I I -2250 C_ 0 0 L O Z r o' 1 I i 1 J-102 (wp07) I I I 1 1J-103 1/4 Mile Scan @ Heel 15~ _ - - ..- - 177° 179° 179° 180° 1ao° T ~.z:r'~uth c_ io Trua North Magnetic North: 24.65° Magnetic Field Strength: 57552.5nT Dip Angle: 80.75° Date: 11/18/2004 Model: BGGM2005 1 J-105 (wp03) I 1 _ ~ 'Existing & Planed wells that may be drilled prior o i Spud of the 1J-103 are the 1J-14 and the 1J-10 i i i 1ao° i I i I 1so° 1 J-14 180° I 1 J-103 (wp06) 180° i I I I 180° 1 J-103 1 /4 Mile Scan @ Toe HALL.I~URTC3N °'~ -,05°° 1J-136 (wp05) ConocoPhillips Sperry OrElitng Services Alaska -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 97 West(-)/East(+) (1500 ft/in) ORIGINAL OD N r N 0 Ln r i ~c ~ a n~ ~~°~ Q. ~~ ~~ 3 mv- - ~Y ~ (n Q ~M~N ~ ~ z°~v M i ~ = O Q aa ° '~ ~ . . > > o~ w prncflrn co rn co YY_~ - - p ~ .. .. ~ o ui v CO ° ~ :3 ~ ~ ea -...-......-° Z o O mo m~ a ~ N ~ ~ O U a QOOO°o N O O N ~ ~ N M M O i ~ ' r ~ r 0 Q ~ 3 ~ ~ ~ N Q. ~ 3 ~ v 7 ~ 0 r ~ r !" . M O r ~~ r `'~d. .-. O Q r ~ \ r ~\ ~ v ~ C ~ \,, ~ Q _. ... ~ 3 _ N ~ O r r r O \. ~ \ __ _ ~ ~ O r Q 3 ca M r ORIGINAL Closest in POOL `n..i J Closest A roach: Reference Well : 1J-103 w 06 Plan Offset Well: 1J -14 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(_) (180°) Comments POOL Min Distance POOL Min Distance (930.02 ft) in POOL (930.02 ft) in POOL (6805.96 - 15094.73 (6805.96 - 15094.73 MD) to 1 J-103 (wp06) MD) to 1 J-14 (3683 - Plan (3683 - 3693 930.02 10125 90.19 179.84 3641.327 5941969 561958.8 4093.461 3693 NDss) 7125 68.92 126.29 3691.693 5941972 562887.5 4097.405 NDss) Closest A roach: Reference Well : 1J-103 w 06 Plan Offset Well: 1J -102 w 07 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E(+)/W(_) 180° Comments POOL Min Distance POOL Min Distance (1262.49 ft) in POOL (1262.49 ft) in POOL (6805.96 - 15094.73 (6805.96 - 15094.73 MD) to 1J-102 (wp07) MD) to 1 J-103 (wp06) (5975.88 - 13676.17 Plan (5975.88 - 1262.49 15094.73 89.61 180.45 3639.859 5937002 561968.6 9059.979 MD) 13676.17 90.39 179.82 3606.928 5937002 560706.5 9050.393 13676.17 MD) Closest A roach: Reference Well : 1J-103 w 06 Plan Offset Well: 1J -105 w 03 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. TVD E(+)/W(-) (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(_) 180°) Comments POOL Min Distance POOL Min Distance (1257.03 ft) in POOL (1257.03 ft) in POOL (6805.96 - 15094.73 (6805.96 - 15094.73 MD) to 1J-105 (wp03) MD) to 1J-103 (wp06) (8140.12 - 11701.42 Plan (8140.12 - 125T.03 "_' `, ,., 7225 92.04 178.7 3679.582 5944868 561921.2 1193.957 MD) 8140.12 86 177 3715.142 5944893 563177.5 1178.891 11701.42 MD) Closes t A roach: Reference Well : 1J-103 w 06 Plan Offset Well: 1J -115 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E(+ /W _ (180° Comments De th Incl. An le TRUE Azi. ND E + /W(- 180°) Comments POOL Min Distance POOL Min Distance (2930.94 ft) in POOL (2930.94 ft) in POOL (6805.96 - 15094.73 (6805.96 - 15094.73 MD) to 1J-103 (wp06) MD) to 1 J-115 (wp05) Plan (7458.19 - 2930.94 6805.96 85 177.45 3681.072 5945287 561906 775.4848 (7458.19 - 13762 MD) 7458.19 85 350 3700.638 5948208 562139.4 -2144.157 13762 MD) Closes t A roach: Reference Wel l: 1J-103 w 06 Plan Offset Well: Plan 1J-135 w 01 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist De th Incl. Angle TRUE Azi. TVD E + /W - 180° Comments De th Incl. Angle TRUE Azi. ND E + /W - 180° Comments P L Min Distance PO L Min Distance (194.4 ft) in POOL (194.4 ft) in POOL (6805.96 -15094.73 (6805.96 - 15094.73 MD) to Plan 1J-135 MD) to 1J-103 (wp06) (wp01) (7900 - Plan (7900 - 194.4 lS., - 13100 91.08 180.45 3650.915 5938997 561968.6 7065.391 14862.06 MD) 8875 90.92 180.42 3514.706 5939003 562107.2 7060.271 14862.06 MD) POOL Summary103.x1s 7/26/2006 6:49 AM • Closest in POOL ~...~..r ^,,,-.~5-~l ~..~°~. Closest A roach: Reference Well : 1J-103 L1 w 06 Plan Offset Well: 1J -14 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) 180°) Comments Depth Incl. Angle TRUE Azi. TVD E(+ /W(-) (180°) Comments P OL Min Distance POOL Min Distance (613.4 ft) in POOL (613.4 ft) in POOL (5954.96 - 11008.37 (5954.96 - 11008.37 MD) to 1 J-103 L1 MD) to 1 J-14 (3536 - {wp06) Plan (3536 - 613.4 9875 90.27 179.84 3489.493 5942208 561956.3 3854.39 3574 TVDss) 6700 69.43 127.72 3539.372 5942207 562567.7 3860.104 3574 TVDss) Closest A roach: Reference Well : 1J-103 L1 w 06 Plan Offset Weli: 1J -102 L1 w 07 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments POOL Min Distance POOL Min Distance (1239.78 ft) in POOL (1239.78 ft) in POOL (5954.96-11008.37 (5954.96-11008.37 MD) to 1J-102 L1 MD) to 1J-103 L1 (wp07) (5173.46 - (wp06) Plan (5173.46 1239.78 6550 90.62 178.59 3543.397 5945532 561901.5 530.2152 12480.3 MD) 5173.45 80 183 3500.109 5945491 560663.2 561.4853 -12480.3 MD) Closest A roach: Reference Well : 1J-103 L1 w 06 Plan Offset Well: 1J -105 L1 w 03 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/5(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. TVD E(+)/W - (180° Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(- (180° Comments POOL Min Distance POOL Min Distance (1224.08 ft) in POOL (1224.08 fq in POOL (5954.96-11008.37 (5954.96-11008.37 MD) to 1J-105 L1 MD) to 1J-103 L1 (wp03) (7370.13 - (wp06) Plan (7370.13 1224.08 _~ ~~. 7300 91.67 179.36 3531.778 5944782 561923.7 1279.925 11533.66 MD) 8225 92.24 179.36 3565.968 5944798 563147.2 1273.563 - 11533.66 MD) Closes t A roach: Reference Well : 1J-103 L1 w 06 Plan Offset Well: 1J -115 L1 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E + /W(-) (180°) Comments De th Incl. An le TRUE Azi. TVD E + /W(-) 180° Comments POOL Min Distance POOL Min Distance (1254.32 ft) in POOL (1254.32 ft) in POOL (5954.96 - 11008.37 (5954.96 - 11008.37 MD) l0 1J-115 L1 MD) to 1J-103 L1 (wp0~) (6494.2 - (wp06) Plan (6494.2 - 1254.32 5954.96 80 169.33 3538.693 5946120 561827.6 -58.82893 13954.35 MD) 6498.19 80 350 3539.381 5947278 562311.1 -1212.382 13954.35 MD) POOL Summary103L1.xls 7/26/2006 6:50 AM • • Closest in POOL •~~ r ^~~~/ .,,ice-°' i...,.,,wyr~ Closest A roach: Reference Well : 1J-103 L2 w 06 Plan Offset Well: 1J -14 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)!S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (180°) Comments De th Incl. Angle TRUE Azi. TVD E(+)/W(- (180° Comments OL Min Distance POOL Min Distance (544.16 ft) in POOL (544.16 ft) in POOL (5670.64 - 11007.43 (5670.64 - 11007.43 MD) to 1 J-103 L2 MD) to 1J-14 (3478 - (wp06) Plan (3478 - 544.16 ~ '? 9800 90.28 176.56 3417.114 5942280 561896.4 3782.297 3511 NDss) 6525 69.86 127.33 3478.246 5942305 562436.5 3760.771 3511 NDss) Closest A roach: Reference Well : 1J-103 L2 w 06 Plan Offset Well: 1J -102 L2 w 07 Coords, - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments De th Incl. An le TRUE Azi. TVD E(+ /W - 180° Comments POOL Min Distance POOL Min Distance (1196.18 ft) in POOL (1196.18 ft) in POOL (5670.64 - 11007.43 (5670.64 - 11007.43 MD) to 1J-102 L2 MD) to 1J-103 L2 (wp07) (4853.06 - (wp06) Plan (4853.06 1196.18 6050 93.2 169.14 3488.045 5946021 561841 40.53073 12175.28 MD) 4865.05 78.91 180 3432.598 5945792 560668.3 260.7167 -12175.28 MD) Closest A roach: Reference Well : 1J-103 L2 w 06 Plan Offset Well: 1J -105 L2 w 03 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. ND E +)/W(-) (180° Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1224.14 ft) in POOL (1224.14 ft) in POOL (5670.64 - 11007.43 (5670.64 - 11007.43 MD) to 1 J-105 L2 MD) to 1 J-103 L2 (wp03) (7067.36 - (wp06) Plan (7067.36 1224.14 7282.42 91.74 179.15 3460.053 5944794 561923.4 1268.146 11489.11 MD) 8200 92.28 179.36 3495.897 5944818 563146.8 1254.161 -11489.11 MD) Closes t A roach: Reference Well : 1J-103 L2 w 06 Plan Offset Well: 1J -115 L2 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments Depth Incl. An le TRUE Azi. TVD E + M/ -) 180° Comments POOL Min Distance POOL Min Distance (823.82 ft) in POOL (823.82 ft) in POOL (5670.64 - 11007.43 (5670.64 - 11007.43 MD) to 1J-115 L2 MD) to 1J-103 L2 (wp05) (6159.62 - (wp06) Plan (6159.62 823.82 5670.64 77 165.03 3478.04 5946389 561758.4 -328.2579 14020.17 MD) 6171.61 78.91 0 3467.526 5946962 562350.3 -896.4452 -14020.17 MD) POOL Summary103L2.xls 7/26/2006 6:51 AM 1J-103 milling Hazards Su~marv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate i Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced ~ drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure ' Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low ~ Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, P~VD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-103 Drilling Hazards Summary prepared by Shane Cloninger 5/12/2006 1:14 PM ~`'+~ Ir CemCADE Preliminary Job Design 10 3/4" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/18/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 80' MD < Base of Permafrost at 1,656' MD (1,518' TVD) < Top of Tail at 2,006' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,806' MD (2,200' TVD) Mark of 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 2,006' MD. Lead Slurrv Minimum pump time: 210 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 (1656' - 80') x 3.50 (250% excess) = 2006.2 ft3 0.3637 ft3/ft x (2006' - 1656') x 1.35 (35% excess) = 171.8 ft3 51 ft3 + 2006.2 ft3+ 171.8 ft3 = 2229 ft3 2229 ft3 / 4.45 ft3/sk = 500.9 sks Round up to 510 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. 0.3637 ft3/ft x (2806' - 2006') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sk = 176.5 sks Round up to 180 sks Tail Slurrv Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time Ibbll (mini CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 .33.3 ASL 7.0 407.4 58.2 91.5 DeepCRETE 6.0 77.7 12.9 104.4 Drop top plug 0.0 0.0 5.0 109.4 Water 5.0 20.0 4.0 113.4 Switch to rig pump 0.0 0.0 5.0 118.4 Mud 7.0 233.2 33.3 151.7 Slow & bump plug 3.0 9.0 3.0 154.7 MUD REMOVAL Recommended Mud Properties: 9.6 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 2 per joint on the shoe track and 1 per joint thru the tail slurry cement column. ~J Scl~umberger CemCADE*well cementing recommendation for 10 3/4" Surface Casing Operator : CPAI Well 1J-103 TLP Country :USA Field West Sak State :Alaska Prepared for :Mike Greener Location 1J Pad Proposal No. : V1 (wp03) Service Point Prudhoe Bay Date Prepared :May 18, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martin13c~slb.com ~`~ ~ C'y C ~G q~U ATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not [o be inferred. * Mark of Schlumberger O;IGINAL L' Client CPAI Well 1J-103 TLP String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft o- 0 a o- 0 0 o- N O O O C+'1 - • Schlumtierg~r :Casing Single Land 0.0 ft 2806.0 ft 47 degF 13 1/2 in Well Lithology (x 1000) psi Formation Press. 1j~103 [Ip cemen[.cfw; OS-18-2006; Loadcase 1075 Surface: Version wcs~cem46_89 Page 2 ORIGINAL ~~ • Client CPAI Sclr~r Well 1 J-103 TLP String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 80.0 20 94.0 19.124 Landing Collar MD :2726.0 ft Casing/liner Shoe MD :2806.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2806.0 10 3/4 40.0 45.5 9.950 M-65 2270 4230 STC Mean OH Diameter :13.500 in Mean Annular Excess :159.3 Mean OH Equivalent Diameter: 16.985 in Total OH Volume :763.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1656.0 13.500 250.0 18.681 2806.0 13.500 35.0 14.338 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1656.0 1518.1 29 0.3 2376.0 1959.5 41 0.8 2806.0 2200.0 47 1.0 1j-103 tlp cementdw ; 0518-2006; Loadcase 1075 Surtace ;Version wcs<em45_89 Page 3 ~,~l~lNAL Client CPAI ~G~I~~p~rg~r Well 1J-103 TLP String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Max. Deviation Angle : 56 deg Max. DLS :5.006 deg/100ft MD (ft) Directional Survey Data TVD Deviation Azimuth (ft) (deg) (de Dogleg Sev. (de /100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 2.5 45.0 2.500 500.0 499.7 5.0 45.0 2.500 600.0 599.1 7.5 45.0 2.500 702.1 700.0 10.1 45.0 2.499 800.0 795.8 14.0 45.0 4.002 900.0 891.9 18.0 45.0 4.000 1000.0 985.9 22.0 45.0 4.000 1100.0 1077.2 26.0 45.0 4.000 1200.0 1165.5 30.0 45.0 4.000 1300.0 1250.3 34.0 45.0 4.000 1400.0 1331.2 38.0 45.0 4.000 1500.0 1407.9 42.0 45.0 4.000 1600.0 1479.8 46.0 45.0 4.000 1629.3 1500.0 47.1 45.0 3.990 1700.0 1548.1 47.1 45.0 0.000 1804.3 1619.0 47.1 45.0 0.000 1900.0 1681.2 51.8 46.4 5.006 1944.9 1708.3 54.0 47.0 4.991 2000.0 1740.6 54.0 47.0 0.000 2100.0 1799.4 54.0 47.0 0.000 2184.9 1849.3 54.0 47.0 0.000 2200.0 1858.2 54.1 47.9 4.971 2300.0 1916.3 54.9 54.0 5.005 2401.4 1973.8 56.0 60.0 5.000 2500.0 2028.9 56.0 60.0 0.000 2600.0 2084.8 56.0 60.0 0.000 2700.0 2140.8 56.0 60.0 0.000 2800.0 2196.7 56.0 60.0 0.000 2806.0 2200.0 56.0 60.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) (!b/gal) 1656.0 12.50 8.20 P-Frost 1872.0 12.50 8.70 T3 Sandstone 2367.0 12.50 8.70 K15 Sandstone 2806.0 12.50 8.70 TD Sandstone Page 4 tj-103 tlp cement.cfw ; OSd 8-2006 ; Loadcase 1075 SurfaceAVersion wcscem45_89 1 A • Client CPAI Well 1 J-103 TLP String 10 3l4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 2: centralizer placement Top of centralization :2006.0 ft Bottom Cent. MD :2796.0 ft Casing Shoe :2806.0 ft NB of Cent. Used :22 NB of Floating Cent. :0 S~hlumberg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2726.0 18 1/1 S1104610-10 3/4-636 31.3 2026.0 (3/16")B 2806.0 4 2/1 S1104610-10 3/4-616 85.7 2736.0 (3/16")B Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1104610-10 3/46- 10 3/4 15.874 11.874 No Houma 13.500 708.15 1450.02 46 (3/16")B (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 5 tj-103 tlp cement cfw ; OS-1 B-2006 ; Loadcase 1075 Surface ; Version wcscem45_89 ORIGINAL • Client CPAI Well 1J-103 TLP String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density Mud Type : WBM Job volume CW100 DESIGN Fluid No: 2 Density Job volume MUDPUSH II DESIGN Fluid No: 3 Density Job volume Water Fluid No:4 Density Job volume ASL DESIGN Fluid No: 5 Density Rheo. Model :BINGHAM p„ At tem p. : 65 d eg F Ty DESIGN BLEND SLURRY Name : G Mix Fluid :20.722 gal/sk Dry Density : 199.77 Ib/ft3 Yield :4.45 ft3/sk Sack Weight : 94 Ib Porosity :62.3 BASE FLUID Type : Fresh water Density : 8.32 Ib/gal DeepCRETE DESIGN Fluid No:6 Density Rheo. Model :BINGHAM p„ At temp. : 63 degF Ty DESIGN BLEND SLURRY Name : G Mix Fluid :8.231 gal/sk Dry Density : 199.77 Ib/ft3 Yield :2.47 ft3/sk Sack Weight : 94 Ib Porosity :44.5 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D046 0.600 %BWOC ANTIFOAM B 160 0.170 %BWOC Low Temp Dis D186 0.100 gal/sk blend ACCELERATOR 9.60 Ib/gal 242.2 bbl 8.32 Ib/gal 50.0 bbl 10.50 Ib/gal 50.0 bbl 8.32 Ib/gal 20.0 bbl ~~I rg~r 10.70 Ib/gal 28.660 cP 16.97 Ibf/100ft2 Job volume :407.4 bbl Quantity :514.54 sk Solid Fraction :37.7 Base Fluid :20.153 gal/sk 12.00 Ib/gal 105.064 cP 11.81 Ibf/100ft2 Job volume :77.7 bbl Quantity :176.48 sk Solid Fraction :55.5 Base Fluid :8.131 gal/sk 1j-103 tlp cement.cfw ; OS-18-2006 ; Loadcase 1075 Surface ;Version wcscem45_69 • Page 6 ORIGINAL • • Client CPAI Well 1J-103 TLP String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface ~c~l~~r~r Section 4: fluid se uence Original fluid Mud 9.60 Ib/gal P~ :15.000 cP Tv :30.00 Ibf/100ft2 Displacement Volume 262.2 bbl Total Volume 847.2 bbl TOC 0.0 ft Name Volume (bbl) Ann. Len (ft) Top (ft) fluid Sequence Density (Ib/gal) Rheology CW100 50.0 0.0 8.32 viscosity:5.000 cP MUDPUSH II 50.0 0.0 10.50 pv.23.000 cP Tv:30.00 Ibf/100ft2 ASL 407.4 2006.0 0.0 10.70 Pv.28.660 cP Tv:16.97 Ibf/100ft2 DeepCRETE 77.7 800.0 2006.0 12.00 Pv.105.064 cP Tv:11.81 Ibf/100ft2 Water 20.0 2518.0 8.32 viscosity:1.000 cP Mud 242.2 0.0 9.60 Pv.15.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2032 psi at 2726.0 ft Burst 4230 psi at 2726.0 ft Cs .Pump out 36 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 ASL 7.0 407.4 58.2 407.4 80 DeepCRETE 6.0 77.7 12.9 77.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 7.0 233.2 33.3 233.2 80 Mud 3.0 9.0 3.0 242.2 80 Slow & bump plug Total 02:34 847.2 bbl hr:mn Dynamic Security Checks Frac 7 psi at 80.0 ft Pore 0 psi at 80.0 ft Collapse 2032 psi at 2726.0 ft Burst 4009 psi at 0.0 ft __ Page 7 1 j-103 tlp cement.cfw ; 0516-200fi ; Loadcase 1075 Surface ;Version wcscem45_89 • ~ Client CPAI Well 1 J-103 TLP String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface ft o, 0 0 O' 0 °o• N O O O M- Fluid Sequence d a d a` C C Q i i i Dynamic Well Security Time (min) c c E a ~_ m K 3 0 LL C Time (min) Schlu~h~rg~r :~ a 2 ue to = ~zsue n ~ o _-Annular Velocity i I ~ --°°---•-•---°----•-~ r i i i i ~` O i n i 'V Oi ~~. _.~-_ i O ~ i ~J~ ~~ ~~ i N ' J / it c fit !i ' I I r ~ i C n ii I~, r 0 40 80 120 160 Time (min) Page 8 tj-103 rlp cement.cfw ; OS-18-2006; Loadcase 1075 Surface ;Version wcs-cem45_89 ORIGINAL Ib/gal 8 12 0 40 80 120160 Time (min) • ~~~~~~ CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/18/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 26314207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,806' MD < Top of Tail at 3,500' MD Y€ < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,805' MD (3,789' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C - (3305' MD annular length). Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3305' x 1.25 (25% excess) = 887.4 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 887.4 ft3 + 20.6 ft3 = 908.0 ft3 908.0 ft3/ 2.25 ft3/sk = 403.6 sks Round up to 410 sks BHST = 89°F, Estimated BHCT = 76°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) fbbll (min) fminl CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 65.0 13.0 25.0 Drop bottom plug 0.0 0.0 5.0 30.0 MUDPUSH II 5.0 75.0 15.0 45.0 DeepCRETE 5.0 161.7 32.3 77.3 Drop top plug 0.0 0.0 5.0 82.3 Water 5.0 20.0 4.0 86.3 Switch to rig 0.0 0.0 5.0 91.3 Mud 6.0 279.8 46.6 137.9 Slow & bump plug 3.0 9.0 3.0 140.9 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 2 Tandem Rise Centraliziers per joint on the shoe track and 1 Tandem .Rise Centralizer per joint across the West Sak and the Ugnu formations. ORIGINAL i • Schlam~erger CemCADE*well cementing recommendation for 7 5/8" Intermediate Casing Operator : CPAI Well 1J-103 TLP Country :USA Field West Sak State :Alaska Prepared for :Mike Greener Location Proposal No. : V1 (WP03) Service Point Prudhoe Bay Date Prepared :May 18, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martin13c~slb.com ~~~~ ~ n c ~G 94~ AT~ Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, [he assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify [he owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger ~?nI~INAL • • Client CPAI Well 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft o- u~ c, c,- 0 ~n _ 0 ~, - 0 ~- 0 ~• 0 M f~ Schlumberg~r :Casing Single Land :O.Oft 6805.0 ft 88 degF 9 7/8 in Well '. Ugnu B K-13 West Sak D • • West Sak A4 •• West Sak A3 • TD Lithology I;x 1000) psi 2.5 Frac I - •- ti ~; t . •. '. 7 - S I ~ -- ~ ~- Formation Press. Page 2 1j-703 tlp cement.cfw ; OS-18.2006 ; Loadcase 758 Intermediate ; Version wcs-cem45_69 ORIGINAL • Client CPAI ~~~1~~~~1 Well 1J-103 TLP I~ String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2806.0 10 3/4 45.5 9.950 Landing Collar MD :6725.0 ft Casing/liner Shoe MD :6805.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 6805.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 BTC Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1656.0 1517.4 29 0.3 2806.0 2200.0 47 1.0 4022.0 2891.5 65 1.4 5670.0 3586.8 83 1.6 6805.0 3789.3 88 1.7 ij-103 tlp cementcPou ; 05-i 6-2006 ; Loadcase 758 Intermediate ;Version wcstem45_89 Page 3 '?RIGINAL • Client CPAI Wel I 1 J -103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Mean OH Diameter :9.875 in Mean Annular Excess :25.0 Mean OH Equivalent Diameter: 10.361 in Total OH Volume :417.1 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS :5.006 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 2.5 45.0 2.500 500.0 499.7 5.0 45.0 2.500 600.0 599.1 7.5 45.0 2.500 702.1 700.0 10.1 45.0 2.499 800.0 795.8 14.0 45.0 4.002 900.0 891.9 18.0 45.0 4.000 1000.0 985.9 22.0 45.0 4.000 1100.0 1077.2 26.0 45.0 4.000 1200.0 1165.5 30.0 45.0 4.000 1300.0 1250.3 34.0 45.0 4.000 1400.0 1331.2 38.0 45.0 4.000 1500.0 1407.9 42.0 45.0 4.000 1600.0 1479.8 46.0 45.0 4.000 1629.3 1500.0 47.1 45.0 3.990 1700.0 1548.1 47.1 45.0 0.000 1804.3 1619.0 47.1 45.0 0.000 1900.0 1681.2 51.8 46.4 5.006 1944.9 1708.3 54.0 47.0 4.991 2000.0 1740.6 54.0 47.0 0.000 2100.0 1799.4 54.0 47.0 0.000 2184.9 1849.3 54.0 47.0 0.000 2200.0 1858.2 54.1 47.9 4.971 2300.0 1916.3 54.9 54.0 5.005 2401.4 1973.8 56.0 60.0 5.000 2500.0 2028.9 56.0 60.0 0.000 2600.0 2084.8 56.0 60.0 0.000 2700.0 2140.8 56.0 60.0 0.000 2800.0 2196.7 56.0 60.0 0.000 2805.8 2199.9 56.0 60.0 0.000 2900.0 2252.6 56.0 60.0 0.000 3000.0 2308.5 56.0 60.0 0.000 3100.0 2364.4 56.0 60.0 0.000 3200.0 2420.4 56.0 60.0 0.000 3300.0 2476.3 56.0 60.0 0.000 3400.0 2532.2 56.0 60.0 0.000 3476.4 2574.9 56.0 60.0 0.000 3500.0 2588.2 55.8 61.4 -4.998 3600.0 2645.1 54.9 67.4 -5.002 3700.0 2703.0 54.3 73.5 -4.995 3800.0 2761.6. 54.0 79.6 -5.001 3900.0 2820.3 54.1 85.8 5.003 4000.0 2878.7 54.4 91.9 4.996 4100.0 2936.4 55.1 98.0 5.003 ~~Irg~r 1j-103 tlp cemen[cfw; 05-18-2006; Loadcase 7561ntermediate;version wcs~em45_89 Page 4 ~~~ • Client CPAI Weli 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate MD (ft) Directional Survey Data TVD Deviation Azimuth (ft) (de) (de) Dogleg Sev. (de /100ft) 4200.0 2992.9 56.1 104.0 5.003 4300.0 3047.8 57.3 109.8 4.998 4400.0 3100.6 58.8 115.4 5.000 4500.0 3151.1 60.6 120.8 5.000 4600.0 3198.7 62.5 126.1 5.006 4627.5 3211.3 63.1 127.4 4.980 4700.0 3244.1 63.1 127.4 0.000 4800.0 3289.3 63.1 127.4 0.000 4825.1 3300.7 63.1 127.4 0.000 4900.0 3334.0 64.1 131.5 5.001 5000.0 3376.6 65.5 136.8 4.995 5100.0 3416.7 67.2 141.9 5.006 5200.0 3454.1 69.0 147.0 5.001 5300.0 3488.4 70.9 151.9 4.998 5400.0 3519.3 73.0 156.6 5.002 5500.0 3546.8 75.2 161.3 5.000 5580.6 3566.2 77.0 165.0 4.997 5586.2 3567.4 77.0 165.0 0.000 5600.0 3570.5 77.0 165.0 0.000 5670.6 3586.4 77.0 165.0 0.000 5700.0 3593.0 77.0 165.0 0.000 5800.0 3615.5 77.0 165.0 0.000 5825.6 3621.3 77.0 165.0 0.000 5900.0 3636.9 78.7 167.5 3.999 5955.0 3647.1 80.0 169.3 4.001 6000.0 3654.9 80.0 169.3 0.000 6105.0 3673.1 80.0 169.3 0.000 6200.0 3689.6 80.0 173.2 -4.000 6305.0 3707.9 80.0 177.4 3.996 6400.0 3724.4 80.0 177.4 0.000 6500.0 3741.7 80.0 177.4 0.000 6600.0 3759.1 80.0 177.4 0.000 6680.0 3773.0 80.0 177.4 0.000 6700.0 3776.3 80.8 177.4 3.998 6805.0 3789.3 85.0 177.4 3.999 • MD (ft) Frac. (Ib/ al) Formation Data Pore Name (Ib/ al) Lithology 4022.0 12.50 8.20 Ugnu C Sandstone 4508.0 12.50 8.20 Ugnu B Sandstone 4652.0 12.50 8.20 Ugnu A Sandstone 4951.0 12.50 8.40 K-13 5670.0 12.50 8.40 West Sak D Sandstone 5817.0 12.50 8.40 West Sak C Sandstone 5940.0 12.50 8.40 West Sak B Sandstone 6158.0 12.50 8.40 West Sak A4 Sandstone 6377.0 12.50 8.40 West Sak A3 Sandstone 6805.0 12.50 8.40 TD Sandstone Sclrg~r 1j-103 [Ip cemen[.dw ; OSd 8-2006 ; Loadcase 758 Intermediate ;Version wcscem45_69 Page 5 ~~~~ ~. ~ ~„~ • • Client CPAI Well 1J-103 TLP String 7 5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 2: centralizer placement Top of centralization :3800.0 ft Bottom Cent. MD :6795.0 ft Casing Shoe :6805.0 ft NB of Cent. Used :59 NB of Floating Cent. :0 Schlumherg~r Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 4805.0 25 1/1 7-5/8 TR 76TR 0.0 4787.2 5525.0 0 0/0 0.0 4805.0 6725.0 30 1/1 7-5/8 TR 76TR 0.0 5542.8 6805.0 4 2/1 7-5/8 TR 76TR 92.7 6805.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 7-5/8 TR 76TR 7 5/8 10.500 9.000 tVo Weatherford t'~ 9.875 375.00 3168.00 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft 0 0 0 60 80 100 ~"+ -Between CeM. M +At CeM. 0 u~ v 0 u~ rn v u~', 0 ~n M f~ Pipe Standoff Page 6 tj-103 tlp cementcfw ; 05-19-2006 ; Loadcase 7581merrnediate ; Version wcs<em45_89 o~a~i~~L • • Client CPAI Well 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8.90 Ib/gal Mud Type : WBM Job volume :288.8 bbl CW100 DESIGN Fluid No: 2 Density : 8.32 Ib/gal Job volume :75.0 bbl MUDPUSH II DESIGN Fluid No:3 Density : 11.00 Ib/gal Job volume :75.0 bbl Fluid No:4 Rheo. Model : HERSCHEL_B. At temp. : 80 degF DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water ~~Ir~~r DeepCRETE DESIGN Density :12.501b/gal k :8.69E-31bf.s^n/ft2 n :0.833 Tv :O.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) SLURRY Mix Fluid :7.558 gal/sk Job volume :161.7 bbl Yield :2.25 ft3/sk Quantity :403.45 sk Porosity :44.9 % Solid Fraction :55.1 Density : 8.32 Ib/gal Base Fluid :7.418 gal/sk Code Additives Conc. Function D124(0. 31.000 %BWOC Extender 76) D178 24.000 %BWOC SILICA D046 0.600 %BWOC ANTIFOAM B160 0.600 %BWOC Low Temp Dis D167 0.300 %BWOC FLUID LOSS D186 0.140 gal/sk blend ACCELERATOR Water Fluid No: 5 Density : 8.33 Ib/gal Job volume :20.0 bbl Page 7 1j-103 tlp cement.cfw ; 0516-2006 ; Loadcase 758 Intermediate ; Version wcs-cem45_89 Client CPAI ~~~I~lr~~r Well 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 4: fluid se uence Original fluid Mud 8.90 Ib/gal k : 1.13E-2 Ibf.s^n/ft2 n :0.517 Tv :6.47 Ibf/100ft2 Displacement Volume 308.8 bbl Total Volume 620.5 bbl TOC 3500.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 75.0 1752.5 8.32 k:6.68E-31bf.s"n/ft2 n:0.177 Tv:0.001bf/100ft2 MUDPUSH II 75.0 1747.5 1752.5 11.00 k:8.59E-2 Ibf.s^n/ft2 n:0.279 Tv:11.82 Ibf/100ft2 DeepCRETE 161.7 3305.0 3500.0 12.50 k:8.69E-31bf.s^n/ft2 n:0.833 Tv:0.001bf/100ft2 Water 20.0 6289.4 8.33 k:6.94E-31bf.s^n/ft2 n:0.281 Tv:0.071bf/100ft2 Mud 288.8 0.0 8.90 k:1.13E-2lbf.s"n/ft2 n:0.517 Tv:6.47Ibf/100ft2 Static Security Checks Frac 392 psi at 2806.0 ft Pore 100 psi at 2806.0 ft Collapse 4331 psi at 6725.0 ft Burst 6842 psi at 1752.5 ft Csg.Pump out 42 ton Section 5: pumping schedule Name Flow Rate (bbUmin) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min} (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 65.0 13.0 75.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 75.0 15.0 75.0 80 DeepCRETE 5.0 161.7 32.3 161.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 6.0 279.8 46.6 279.8 80 Mud 3.0 9.0 3.0 288.8 80 Slow & bump plug Total 02:20 620.5 bbl hr:mn Dynamic Security Checks Frac 139 psi at 6805.0 ft Pore 42 psi at 2806.0 ft Collapse 4302 psi at 541.8 ft Burst .6255 psi at 1978.7 ft 1j-103 tlp cementcrw; 0548-2006; Loadcase 7581ntermediate;version wcs-cem45_69 Page 8 a ~~ a J • • Client CPAI Well 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 6: WELLCLEAN II Simulator ft o- ~- M _ O - ~_ O - lL"1 _ !~ ~ . O ~f] ti - ~I1 . O ' ~l i 4C7 - (a . O - ~. M 1+ - Cement Coverage Fluids Cont:enkrations i 3 e00o ,~ d000 ~ eSO~ ~ .500 5000 ~ - 5000 s n 5500 r 5500 0 fi000 6000 fi500 6500 3 9 O 2 0 PAud ~ MUDPUSH II ~~ '~.~ater ® CW100 ~ DrepCRETE Schlumhergur Risk Mud on the Wall z ~ _ -r-.-., e500 = I ~ e500 5000 - ` `' 5000 ... -s `-- s L n 5500- ' ' 5500 n 5000- 6000 5500- 6500 3 • 0 a O 2 ~ High ® Low 0 hAedium None Page 9 1j-103 tlp cement.cfw ; 0516-2006 ; Loadcase 758 1n[ennedia[e ;Version wcstem45_89 ~~~I~A~. ~~o 0 20 40 60 80 100 • • Client CPAI Well 1J-103 TLP String 75/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate ft o -, O O O O O O O to Fluid Sequence m a a~ f/1 Vl N C C Q C Ib/gal 8 12 16 .L_----1----T'-~ -Hydrostatic i - Min. Hydrostatic - Max. Dynamic I I - - Min. Dynamic i -~~ Frac 1 i Pore i i 'r i i ~ +'-+ i + i I i 1 t-°t 1 1 1 i i i t._i I i i P i ~._~ i -i i i i i °}....3 i r i i i l .R..,,A i i i i. __;._; 1 1 1 i i i L __l._I Dynamic Well Security Time (min) Fluids at 6805 ft u r c E a ~_ m m 3 0 LL C Time (min) S Q G_ = O ~~ N 0 C N I• ~ i ~`O it V O-il o~,~ ~ Ij > i; C i ~'. Q OH' 0 ~chl~~a~rg~r i .w. ,a._, _. , 1 1 '-'-t •"-•--ti 50 100 150 Time (min) )e~th = 6805 ft______ Annular Velocity 4y i i _7_._._.~.~.T_._._._.~.y 50 100 150 Time (min) Page 10 7ja03 tlp cemenccfw ; 05-18-2006 ; Loadcase 7581ntermediate ; Version wcstem45_69 ORlGlN~L Q l++~~ V ~~~ z r~~+ ~~ ~~ i ~ y r~ w~ C/~ F C/I n S S ~ B 3 y C o ~ a " ~ ~ .. ~ rn ~~ ao w 8 i4 3~ 'v ~~ ~ '}' 3 tia o~~- a Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/x", 5,000 ksi Insulated Conductor Casing 20", 94#, K55 x 34", 0.312" WT (!~ +/_ 80' MD 10-3/4", 45.5#, L-80, BTC, R3 @ 2,880' MD / 2,242' TVD ~~ SG degrees TD 13-I/2" hole Top of Uguu C ~ ~ 4,022' MD / 2,892' TVD Lateral Entry Module #1 (LEM), Baker, with seal bore acid ZXP packer above. Tubing 4-%" IBTA1 from LENT to A' Liner, with seal stem and CAAII'O 3.562" "DB" nipple Seal bore and ZXP packer for A2 liner +/- 90' below "B" window -I'op of ~Vrxt Sak A G,805' MD / 3,790 TVD ~ 7-5/8", 29.7#, L-80, BTCIvI, R3 Csg a. 6,805' MD / 3,790' TVD a 85 degrees TD 9-7/8" hole Tubing String. 4-1/2", 12.G #, L-80, IBTM (1) Gas Lift Mandrel, CAAICO 4-I/2" x I" Alodel KAIBG w/ dummy valve @, one (l) set ~ 2,400' AID, 1973' TVD. (l) Gas Lift Mandrel, CAMCO 4-I/2" x t" Model KMBG w/ dummy valve, L ~ 72 deg, 5,300' MD, 3,489' TVD. Electric Submersible Pump, CatlriliB 418 HP motor, with FCG000 wireline deployed pump. Bottom at 5,600' MD, 3,571' TVD 103 L2 "D" Sand Window n 5,670'MD/3,58T TVD 77 degrees "D" Liner, 4-1/2", I LG#, L80, BTC, R3 I1-103 L2'. (0.125" x 2.5" slots, 32 per foot, 5.9%open area) G-3/4" D sand lateral TD 11,007 MD / 3,523' TVD Angle 88 degrees 103 LI "B° Sand Window I1-103 LI: (~~ 5,955' MD / 3,647 TVD G-3/4" "B" sand lateral 80 degrees "B" Liner, 4-1/2", I L6#, L80, BTC, R3 TD 11,008' MD / 3,59G' TVD (0.125" x 25" slots, 32 per foot, 5.9% open area) Angle 89 degrees 1 \ ` l ~ ~ 1J-103-. J 6-3/4 A2 sand lateral AZ Sand Liner, 4-I/2", 1 LG#, L80, BTC, ~ TD 15,095' MD / 3,749' TVD ~~ R3 slotted, cotta~nicrors for iso/ution Angle 89 degrees ~ ~ - _ `~I'' °~~ Tom- sfL ~ , . T ~ ~ X'ed - ~~, f 3~ ~~ V m ~ li o ~ ~ U 8 ~ ~ a ~- ~~ ~ ,J ..a V ~~ ~ ~~~ ~~ ~. ~~ o ~ ,~ Y ~ ~ ,- ~ ~ ~ j ~ r" r o t~ ~ ~ "~' ~ ~ ~ N~ .. ~ cn o = z •-• J a ~ ~ ~ V ~ r. ,~ J J Y , ~ m Lfl Q= Q ~ ~ ~ Y~o C7 ~`~_ '~ Z~~ Q LUG ,~ aC W C N ~Orv~i0 ~p CC~ ~ ~ 1 Z C7= o¢ G °'~ 200ov ~0 0. ~ ~ ~ S cnUQ°a ao ~ '~aU ~ ~ ~_ _u...a.,_.,......,._,.,~acar..~'' ~ > "ado ~nrM 3xmna ® .aa.,.,_. L..h • • • TRANSMITTAL LETTER CIIECKLIST WELL NAME ,~~~ /.~"~/D3 PTD# 2-d~ - / ~ ~ '/Development Service Exploratory Stratigraphic Test _ Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI-IECK ADD-ONS WHAT ~ (OPTIONS) APPLIES MtiLTILATERAL (If [ast two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing we l l Permit No. , API No. 50- - - I Production should continue to be reported as a function of the original API number stated above. PILOT HOLE '; In accordance with 20 AAC 25.005(f), all records, data and logs ~ I ;acquired for the pilot hole must be clearly differentiated in both j well name ( PH) and API number ~ ~ i (50- - -) from records, data and logs acquired for well ~ i SPACING ;EXCEPTION ': ' I ;The permit is approved subject to full compliance with 20 AAC ~ ~ 25.05. Approval to perforate and produce /inject is contingent I upon issuance of a conservation order approving a spacing j ~ exception. assumes the I liability of any protest to the spacing exception that may occur. ~ DRY DITCH ~ All dry ditch sample sets submitted to the Commission must be in I SAti1PLE no greater than 30' sample intervals from below the permafrost or I ~ from where samples are first caught and 10' sample intervals ' ~ through target zones. ' I i ~ Non-Conventional Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Com any NameZhas designed and j tmplemented a water well testing program to provide baseline data ~ 1 ~ on water quality and quantity. (Company Name) must contact the ~ Commission to obtain advance approval of such water well testing , Rev: 1; 25/06 C:',jody\transmittal checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL- 490150 Well Name: KUPARUK RIV U WSAK 1J-103 -Program DEV WeII bore see ^ PTD#:2061140 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached____________________________________ ______-_Yes._- --_____--_____-__--__._ - - - - - -- 2 Lease number appropriate- _ _ - - - - - Yes - Surface location and top productive interval in ADL X25661;_ TD in AD_L_025662.- - - - _ . - - - 3 Uniquewell_nameandnumber___.._____________ __________ _________Yes_, ___-__- 4 Well located in a-definedpool-_- _______---______________ _--_____ Yes__- __-_Kupa[ukRiver,WestSakOilPOOl-490150,_governed_byCO406B-____------_.__________- 5 WeII located proper distance-from drilling unit_boundary- - - - - - - - - - - - - - - - - - - - - - - -Yes . _ _ _ _ - - Vllell is mo[e-than-500 feet from an external prgperty line. _ _ _ _ - _ _ _ . -- 6 WeII located proper distance-from other wells- _ _ - Yes - _ _ - - CO 4066, Rule 3:_ no restrictions as-to well spacing except that no-pay shall be opened in a well closer - - - - _ _ _ 7 Sufficient acreage available in-drilling unit - - _ - - . - - _ - - _ - - Yes than 500 feet to-an external_prope[ty line where ownershi _or landownershi than es, P P.- g 8 If_deviated,is_weJlboreplat,included______-_-________________ _________Yes_-- --__._.--_____-_____-_.-_-._--_-_____-__-_..__-______ 9 Operator only affected party-_-____-_--_______--_ _- Yes--- ---------------- -------------------------------------------------- 10 OpQratorhasappr9priate-bondinfRrce.--------- --~ -------- ---- Yes -- ---- --- ------- -- -- --------- ~ - --- ----~ --- ------- ----- 11 Pe[mitcanbeissuedwithqutconservationorder___-_____-_-_-____ ________Yes___ _______________________________-_-___----__--__--_-__-_-_-___---------- Appr Date 12 Permit-can be issued without administrativ_e_approval________________ _________Yes___ _--__--_---_-_--_____________---_--_-________--__,_----._ --------------- SFD 7/3112006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strataauthorizedby-InjectionOrder#(putlQ#in-comments)-(For_NA___- --.-_--.--____--___---------------------------------------_--.-.--.- 15 All wells within 114_mile area.of review identified (For service well only)_ _ _ _ _ _ __ _ _ _ _ _ _ _ NA_ _ _ _ _ . - . 16 Pre-produced injector; duration of pre p[oduction less tha4 3 months_(For service well only) NA- - _ _ _ _ - _ - - - _ - -- - - - 17 Nonconyen,gasconformstoAS31,05,030Q.1_.A),(~.2.A-D)_____________ _________NA____ _____-----_--_-___-_______-_--___-_---________ ------------------------ Engineering 18 _C_onductorstring_provided__.-_--________-______________ ______-_Yes___ __-_-_----__----_-__-______-__--_-._ - - 19 Surface casing-protects all-knownUSDWs______________________ ______ __NA____ __ _Allaquifersexempted,40CFR_147.102_(b~(3)..-..-_.__--__--_-.----.-_-__--__---_-- 20 CMT v_ol_adequatetocircul_ate_onccnducto[&surf_csg--------------- ---------Yes__ _.______ __--__---_---.-________.__--_- _______-___-----________-____ 21 CMT-v_ol adeguate_to tie-in long string to surf csg_ - _ - - _ _ . - No_ All hydrocarbon zones will be-covered. _A_nnular disposal- may_be_proposed: _ _ - - - _ 22 CMT_willcoverallknown_productivehorizons_-______---_____ _____No__-_ _-.-Slottedlinercompletion planned,----________--_.______________________--_---- 23 Casing designs adequatefo[C,_T,B&permafrost------------------ -- - - --Yes-- -----------------------------------------------.--------------------_-- 24 Adequate tankage_or reserve pit - .. - - - - Yes - - - - - -Rig is_equipped with steel-pits.- No reserve_pitplanned, All waste to approved annulus or disposal well. 25 If a-re-drill, has_a_ 10-403 for abandonment been approved _ - _ _ - _ _ - - - - NA_ _ - . _ - - - --- 26 Adequate wellbore- separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - - ..Proximity analysis Perfo[med, Traveling cylinder path calculated, Gyros possible: _ _ _ . _ _ _ _ _ _ _ _ _ _ _ - _ _ _ 27 Ifdiverterrequired,doesitmeetregulations__________ ___________ _________Yes--- __-_---_________-_-_----___---_____-_--_--_-_--_-___ - - Appr Date 28 Drilling fluid program Schematic & equip listadequate_ _ , _ - _ - _ Yes ... - .. -Maximum expected formation pressure 8:7_EMW._ Planned-MW $:6ppg or-as needed-- - - - - - - - - - - - - - - - - TEM 81212006 29 BOPEs,-do theymeet_regulation------------------------- --.---,--Yes--- ---------------------------------.,---------------------------- ~A ,~ 30 -BOPE_press rafing appropriate; test to-(put prig in comments)- - -- - -- - - - - - - - - - - - - -Yes _ - _ _ - - _ MA$P calculatedat 1289psi, 3K stack arrangement and BOP test pressure_planned_. _ _ _ - _ - _ - - _ - - _ _ _ - - ~`/ , 31 Choke-manifold complieswlAPI_RP-53 (M_ay 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - .. - . 32 Work willoccurwithoutoperationshutdown______________________ _________Yes_-- __.._.._-..__-___-__--__--_.._--_-___ __-___.__________-_--.-___.-_-. 33 Is presence_of H2S gas-prgbable - - - - .. _ - - - No- _ - - _ _ - - H2S has notbeen reported ak 1J, Rig is equipped with sensors and alarms. - _ - _ - 34 Mechanical condition of wells within AOR verified (Fo[ service well on_ly~ NA_ _ - - - Geology 35 Permit_can be issued wlohrdrogen-sulfide measures - Yes - . - _ - - No H2S has been measured in-W Sak wells drilled south from 1J-Pad. Ri has sensors and-alarms.- _ _ _ 9 36 t)ata_presented on potential overpressure zones, _ _ - _ _ Yes - - - - - ..Expected res._pressure is ~8.7ppg EMW; will be drilled with $.6 ppgoil-based mud. Mud weight will be _ - - - _ . - Appr Date 37 Seismic-analysis- of shallow gas_zones- - - - - - - - -- - -- - - - - - - - - - - - - - - -- - - - - - NA- _ _ - _ _ _ - adjusted as needed.. No shallow_gas expected. _ .. _ - . - _ _ . -- SFD 7131!2006 38 Seabed condition surrey-(ifoff-share) - - - - - - - - - - - - - - - - - - - - - - NA_ _ - _ _ - - -Mud program notes use of 9.$ ppg mud if hydrates a[e-encountered, - - _ _ - - _ _ _ _ _ _ _ _ 39 Contactnamelphoneforweekly_progressrepods-[exploratory only]________ _________NA-_-- _-.__-_____'_-__--__-.__-_-_____--_-_-.-----______----_-_-__--____-___ Geologic Engineering Publ' Da te Date: ' Date West Sak A2 sand roducer. This well will the the main well bore for a tri-lateral roduction well. SFD p p Commissioner: Commissioner: Co s n / ,~ ~ j ~~tJ~"' • i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special-effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 11 15:43:59 2007 Reel Header Service name ....... ......LISTPE Date ............... ......07/04/11 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......07/04/11 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN MWD RUN 5 JOB NUMBER: W-0004725792 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-103 500292331800 ConocoPhillips Alaska, Inc Sperry Drilling Services 11-APR-07 MWD RUN 3 MWD RUN 4 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN MWD RUN 6 MWD RUN 7 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 7130.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE ~0~ -try( ~ tSds` l NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-103 PB3 WELLBORE AT 10455'MD/3770'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3-7 ALSO INCLUDED AT-BIT INCLINATION (ABI). 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 1-7 REPRESENT WELL 1J-103 WITH API#: 50-029-23318-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11272'MD/3773'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.......07/04/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2889.0 11208.5 RPD 2910.0 11216.0 RPS 2910.0 11216.0 RPM 2910.0 11216.0 FET 2910.0 11216.0 RPX 2910.0 11216.0 ROP 2935.5 11272.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2889.0 7137.0 MWD 3 7137.0 7983.0 MWD 4 7983.0 8045.0 MWD 5 8045.5 8220.0 MWD 6 8220.5 10455.0 MWD 7 10455.5 11272.0 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 2889 11272 7080.5 16767 2889 11272 RPD MWD OHMM 0.31 2000 24.3017 16613 2910 11216 RPM MWD OHMM 1.29 2000 18.1922 16613 2910 11216 RPS MWD OHMM 1 2000 14.3446 16613 2910 11216 RPX MWD OHMM 2.05 2000 13.9566 16613 2910 11216 FET MWD HOUR 0.14 88.57 1.96831 16613 2910 11216 GR MWD API 19.57 123.41 73.9295 16640 2889 11208.5 ROP MWD FT/H 0.18 637.38 193.801 16674 2935.5 11272 First Reading For Entire File..........2889 Last Reading For Entire File...........i1272 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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..... ..07/04/11 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 GR 2889.0 7090.0 RPD 2910.0 7082.0 RPM 2910.0 7082.0 RPS 2910.0 7082.0 FET 2910.0 7082.0 RPX 2910.0 7082.0 ROP 2935.5 7137.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7137.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 7137.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 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 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 2889 7137 5013 8497 2889 7137 RPD MWD020 OHMM 1.56 2000 20.7493 8345 2910 7082 RPM MWD020 OHMM 1.29 1645.31 12.8934 8345 2910 7082 RPS MWD020 OHMM 1 180.57 12.252 8345 2910 7082 RPX MWD020 OHMM 3 166.05 11.6234 8345 2910 7082 FET MWD020 HOUR 0.14 55.89 1.54127 8345 2910 7082 GR MWD020 API 19.57 123.41 76.8508 8403 2889 7090 ROP MWD020 FT/H 1.07 561,51 183.759 8404 2935.5 7137 First Reading For Entire File........,.2889 Last Reading For Entire File.........,.7137 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/11 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.......07/04/11 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 DEPTH STOP DEPTH RPD 7082.5 7925.0 FET 7082.5 7925.0 RPS 7082.5 7925.0 RPM 7082.5 7925.0 RPX 7082.5 7925.0 GR 7090.5 7917.5 ROP 7137.5 7983.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7983.0 TOP LOG INTERVAL (FT) 7137.0 BOTTOM LOG INTERVAL (FT) 7983.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 7082.5 7983 7532.75 1802 7082.5 7983 RPD MWD030 OHMM 0.31 2000 73.5182 1686 7082.5 7925 RPM MWD030 OHMM 1.3 2000 52.8754 1686 7082.5 7925 RPS MWD030 OHMM 2.1 63.91 18.2548 1686 7082.5 7925 RPX MWD030 OHMM 2.05 72.51 17.59 1686 7082.5 7925 FET MWD030 HOUR 0.38 88.57 6.79246 1686 7082.5 7925 GR MWD030 API 40.88 118.29 74.581 1655 7090.5 7917.5 ROP MWD030 FT/H 2.51 311.76 182.858 1692 7137.5 7983 First Reading For Entire File ..........7082.5 Last Reading For Entire File. ..........7983 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7918.0 8045.0 RPX 7925.5 8045.0 FET 7925.5 8045.0 RPD 7925.5 8045.0 RPS 7925.5 8045.0 RPM 7925.5 8045.0 ROP 7983.5 8045.0 LOG HEADER DATA DATE LOGGED: 25-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8045.0 TOP LOG INTERVAL (FT) 7983.0 BOTTOM LOG INTERVAL (FT) 8045.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7918 8045 7981.5 255 7918 8045 RPD MWD040 OHMM 11.09 23.05 14.363 240 7925.5 8045 RPM MWD040 OHMM 9.27 23.7 13.4869 240 7925.5 8045 RPS MWD040 OHMM 8.17 19.03 13.2493 240 7925.5 8045 RPX MWD040 OHMM 7.7 18.04 13.1191 240 7925.5 8045 FET MWD040 HOUR 0.42 32.68 16.514 240 7925.5 8045 GR MWD040 API 54.71 94.55 73.2685 255 7918 8045 ROP MWD040 FT/H 47.93 295.11 163.482 124 7983.5 8045 First Reading For Entire File..........7918 Last Reading For Entire File...........8045 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 f iles. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8045.5 8220.0 GR 8045.5 8220.0 FET 8045.5 8220.0 RPS 8045.5 8220.0 RPD 8045.5 8220.0 ROP 8045.5 8220.0 RPM 8045.5 8220.0 LOG HEADER DATA DATE LOGGED: 26-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8220.0 TOP LOG INTERVAL (FT) 8045.0 BOTTOM LOG INTERVAL (FT) 8220.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.5 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resi s. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S): 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8045.5 8220 8132.75 350 8045.5 8220 RPD MWDO50 OHMM 6.63 20.36 9.55223 350 8045.5 8220 RPM MWDO50 OHMM 6.2 25.55 8.81631 350 8045.5 8220 RPS MWDO50 OHMM 5.88 21.03 8.51531 350 8045.5 8220 RPX MWDO50 OHMM 5.53 17.75 8.44731 350 8045.5 8220 FET MWDO50 HOUR 0.72 10.03 1.75654 350 8045.5 8220 GR MWDO50 API 60.16 103.79 82.0256 350 8045.5 8220 ROP MWDO50 FT/H 2.01 258.29 122.658 350 8045.5 8220 First Reading For Entire File..........8045.5 Last Reading For Entire File...........8220 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8220.5 10455.0 RPS 8220.5 10455.0 FET 8220.5 10455.0 RPM 8220.5 10455.0 GR 8220.5 10455.0 RPD 8220.5 10455.0 ROP 8220.5 10455.0 S LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 27-DEC-06 Insite 66.37 Memory 10455.0 8220.0 10455.0 89.0 94.9 TOOL NUMBER 160788 156401 6.750 7130.0 Mineral Oil Base 8.50 93.0 .0 23000 3.4 .000 .0 .000 114.8 .000 .0 .000 .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 N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading • • DEPT FT 8220.5 10455 9337.75 4470 8220.5 10455 RPD MWD060 OHMM 7.77 74.22 17.6411 4470 8220.5 10455 RPM MWD060 OHMM 6.45 2000 17.7356 4470 8220.5 10455 RPS MWD060 OHMM 6.08 2000 17.7248 4470 8220.5 10455 RPX MWD060 OHMM 5.72 2000 17.6658 4470 8220.5 10455 FET MWD060 HOUR 0.29 7.92 0.641573 4470 8220.5 10455 GR MWD060 API 47.74 100.43 69.3526 4470 8220.5 10455 ROP MWD060 FT/H 0.49 434.12 207.4 4470 8220.5 10455 First Reading For Entire File..........8220.5 Last Reading For Entire File...........10455 File Trailer Service name ........... ..STSLIB.006 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/11 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.......07/04/11 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 for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10455.5 11216.0 ROP 10455.5 11272.0 RPX 10455.5 11216.0 RPS 10455.5 11216.0 RPD 10455.5 11216.0 GR 10455.5 11208.5 FET 10455.5 11216.0 LOG HEADER DATA DATE LOGGED: 27-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11272.0 TOP LOG INTERVAL (FT) 10455.0 BOTTOM LOG INTERVAL (FT) 11272.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 91.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 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 6.750 7130.0 Mineral Oil Base 8.50 93.0 .0 23000 3.0 000 .0 000 114.8 000 .0 000 .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 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 S First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10455.5 11272 10863.8 1634 10455.5 11272 RPD MWD070 OHMM 6.3 20.36 13.7806 1522 10455.5 11216 RPM MWD070 OHMM 5.93 19.72 13.0635 1522 10455.5 11216 RPS MWD070 OHMM 5.79 21.78 13.0728 1522 10455.5 11216 RPX MWD070 OHMM 5.32 24.75 13.2297 1522 10455.5 11216 FET MWD070 HOUR 0.19 4.91 0.617326 1522 10455.5 11216 GR MWD070 API 41.06 91.69 68.7327 1507 10455.5 11208.5 ROP MWD070 FT/H 0.18 637.38 237.119 1634 10455.5 11272 First Reading For Entire File..........10455.5 Last Reading For Entire File...........i1272 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/11 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 .....................07/04/11 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 Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 11 09:42:18 2007 Reel Header Service name ............. LISTPE Date ..................... 07/04/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 07/04/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1..J Scientific Technical Services Scientific Technical Services 1J-103 PB1 500292331870 ConocoPhillips Alaska, Inc Sperry Drilling Services 10-APR-07 MWD RUN 3 MWD RUN 4 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 7130.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE • PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3 & 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 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 1-4 REPRESENT WELL 1J-103 PB1 WITH API#: 50-029-23318-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8528'MD/3798'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.......07/04/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2889.0 8464.5 FET 2910.0 8472.0 RPD 2910.0 8472.0 RPS 2910.0 8472.0 RPM 2910.0 8472.0 RPX 2910.0 8472.0 ROP 2935.5 8528.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2889.0 7137.0 7137.0 7983.0 7983.0 8528.0 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 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 2889 8528 5708.5 11279 2889 8528 RPD MWD OHMM 0.31 2000 27.8027 11125 2910 8472 RPM MWD OHMM 1.29 2000 18.7018 11125 2910 8472 RPS MWD OHMM 1 180.57 12.9457 11125 2910 8472 RPX MWD OHMM 2.05 166.05 12.3548 11125 2910 8472 FET MWD HOUR 0.14 88.57 2.58721 11125 2910 8472 GR MWD API 19.57 123.41 76.8362 11152 2889 8464.5 ROP MWD FT/H 1.07 561.51 184.471 11186 2935.5 8528 First Reading For Entire File..........2889 Last Reading For Entire File...........8528 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 GR 2889.0 7090.0 FET 2910.0 7082.0 RPX 2910.0 7082.0 RPS 2910.0 7082.0 RPM 2910.0 7082.0 RPD 2910.0 7082.0 ROP 2935.5 7137.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: 6.000 MUD CAKE AT MT: 4.000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Re cord 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 Si ze 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 20-DEC-06 Insite 72.13 Memory 7137.0 2935.0 7137.0 59.1 84.5 TOOL NUMBER 119546 228272 • 74.0 78.8 74.0 74.0 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 7137 5013 8497 2889 7137 RPD MWD020 OHMM 1.56 2000 20.7493 8345 2910 7082 RPM MWD020 OHMM 1.29 1645.31 12.8934 8345 2910 7082 RPS MWD020 OHMM 1 180.57 12.252 8345 2910 7082 RPX MWD020 OHMM 3 166.05 11.6234 8345 2910 7082 FET MWD020 HOUR 0.14 55.89 1.54127 8345 2910 7082 GR MWD020 API 19.57 123.41 76.8508 8403 2889 7090 ROP MWD020 FT/H 1.07 561.51 183.759 8404 2935.5 7137 First Reading For Entire File..........2889 Last Reading For Entire File...........7137 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 DEPTH STOP DEPTH FET 7082.5 7925.0 RPS 7082.5 7925.0 RPX 7082.5 7925.0 RPM 7082.5 7925.0 RPD 7082.5 7925.0 GR 7090.5 7917.5 ROP 7137.5 7983.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7983.0 TOP LOG INTERVAL (FT) 7137.0 BOTTOM LOG INTERVAL (FT) 7983.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 • CJ S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta 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 7082.5 7983 7532.75 1802 7082.5 7983 RPD MWD030 OHMM 0.31 2000 73.5182 1686 7082.5 7925 RPM MWD030 OHMM 1.3 2000 52.8754 1686 7082.5 7925 RPS MWD030 OHMM 2.1 63.91 18.2548 1686 7082.5 7925 RPX MWD030 OHMM 2.05 72.51 17.59 1686 7082.5 7925 FET MWD030 HOUR 0.38 88.57 6.79246 1686 7082.5 7925 GR MWD030 API 40.88 118.29 74.581 1655 7090.5 7917.5 ROP MWD030 FT/H 2.51 311.76 182.858 1692 7137.5 7983 First Reading For Entire File..........7082.5 Last Reading For Entire File...........7983 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7918.0 8464.5 RPM 7925.5 8472.0 RPX 7925.5 8472.0 RPD 7925.5 8472.0 FET 7925.5 8472.0 RPS 7925.5 8472.0 ROP 7983.5 8528.0 LOG HEADER DATA DATE LOGGED: 25-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8528.0 TOP LOG INTERVAL (FT) 7983.0 BOTTOM LOG INTERVAL (FT) 8528.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT): 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 n DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7918 8528 8223 1221 7918 8528 RPD MWD040 OHMM 6.72 23.05 11.1528 1094 7925.5 8472 RPM MWD040 OHMM 6.12 23.7 10.342 1094 7925.5 8472 RPS MWD040 OHMM 6.07 19.03 10.0551 1094 7925.5 8472 RPX MWD040 OHMM 5.91 18.04 9.86507 1094 7925.5 8472 FET MWD040 HOUR 0.22 32.68 4.08477 1094 7925.5 8472 GR MWD040 API 54.71 102 80.1362 1094 7918 8464.5 ROP MWD040 FT/H 6.56 315.78 192.468 1090 7983.5 8528 First Reading For Entire File..........7918 Last Reading For Entire File...........8528 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/11 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 .....................07/04/11 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 Y Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 S LisLib $Revision: 4 $ wed Apr 11 10:01:05 2007 Reel Header Service name ............ .LISTPE Date .................... .07/04/11 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Tape Header Service name ............ .LISTPE Date .................... .07/04/11 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN MWD RUN 5 JOB NUMBER: W-0004725792 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-103 PB2 500292331871 ConocoPhillips Alaska, Inc Sperry Drilling Services 11-APR-07 MWD RUN 3 MWD RUN 4 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 7130.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE c~b~- t~`~l ~tSb53 NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-103 PB1 WELLBORE AT 8045'MD/3787'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3-5 ALSO INCLUDED AT-BIT INCLINATION (ABI). 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 1-5 REPRESENT WELL 1J-103 PB2 WITH API#: 50-029-23318-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8443'MD/3766'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.......07/04/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2889.0 8380.0 RPD 2910.0 8387.0 RPS 2910.0 8387.0 RPM 2910.0 8387.0 FET 2910.0 8387.0 RPX 2910.0 8387.0 ROP 2935.5 8443.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2889.0 7137.0 7137.0 7983.0 7983.0 8045.0 8045.5 8443.0 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 ~1 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 2889 8443 5666 11109 2889 8443 RPD MWD OHMM 0.31 2000 28.8483 10955 2910 8387 RPM MWD OHMM 1.29 2000 19.3758 10955 2910 8387 RPS MWD OHMM 1 2000 13.4775 10955 2910 8387 RPX MWD OHMM 2.05 2000 12.8879 10955 2910 8387 FET MWD HOUR 0.14 88.57 2.66766 10955 2910 8387 GR MWD API 19.57 123.41 76.7134 10983 2889 8380 ROP MWD FT/H 1.07 561.51 181.189 11016 2935.5 8443 First Reading For Entire File..........2889 Last Reading For Entire File...........8443 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 GR 2889.0 7090.0 RPD 2910.0 7082.0 RPM 2910.0 7082.0 RPX 2910.0 7082.0 RPS 2910.0 7082.0 FET 2910.0 7082.0 ROP 2935.5 7137.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7137.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 7137.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 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 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 2889 7137 5013 8497 2889 7137 RPD MWD020 OHMM 1.56 2000 20.7493 8345 2910 7082 RPM MWD020 OHMM 1.29 1645.31 12.8934 8345 2910 7082 RPS MWD020 OHMM 1 180.57 12.252 8345 2910 7082 RPX MWD020 OHMM 3 166.05 11.6234 8345 2910 7082 FET MWD020 HOUR 0.14 55.89 1.54127 8345 2910 7082 GR MWD020 API 19.57 123.41 76.8508 8403 2889 7090 ROP MWD020 FT/H 1.07 561.51 183.759 8404 2935.5 7137 First Reading For Entire File..........2889 Last Reading For Entire File...........7137 File Trailer Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/11 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.......07/04/11 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 DEPTH STOP DEPTH RPX 7082.5 7925.0 FET 7082.5 7925.0 RPM 7082.5 7925.0 RPD 7082.5 7925.0 RPS 7082.5 7925.0 GR 7090.5 7917.5 ROP 7137.5 7983.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7983.0 TOP LOG INTERVAL (FT) 7137.0 BOTTOM LOG INTERVAL (FT) 7983.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta 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 7082.5 7983 7532.75 1802 7082.5 7983 RPD MWD030 OHMM 0.31 2000 73.5182 1686 7082.5 7925 RPM MWD030 OHMM 1.3 2000 52.8754 1686 7082.5 7925 RPS MWD030 OHMM 2.1 63.91 18.2548 1686 7082.5 7925 RPX MWD030 OHMM 2.05 72.51 17.59 1686 7082.5 7925 FET MWD030 HOUR 0.38 88.57 6.79246 1686 7082.5 7925 GR MWD030 API 40.88 118.29 74.581 1655 7090.5 7917.5 ROP MWD030 FT/H 2.51 311.76 182.858 1692 7137.5 7983 First Reading For Entire File..........7082.5 Last Reading For Entire File...........7983 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7918.0 8045.0 RPS 7925.5 8045.0 FET 7925.5 8045.0 RPM 7925.5 8045.0 RPX 7925.5 8045.0 RPD 7925.5 8045.0 ROP 7983.5 8045.0 LOG HEADER DATA DATE LOGGED: 25-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8045.0 TOP LOG INTERVAL (FT) 7983.0 BOTTOM LOG INTERVAL (FT) 8045.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 ~ ~ FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7918 8045 7981.5 255 7918 8045 RPD MWD040 OHMM 11.09 23.05 14.363 240 7925.5 8045 RPM MWD040 OHMM 9.27 23.7 13.4869 240 7925.5 8045 RPS MWD040 OHMM 8.17 19.03 13.2493 240 7925.5 8045 RPX MWD040 OHMM 7.7 18.04 13.1191 240 7925.5 8045 FET MWD040 HOUR 0.42 32.68 16.514 240 7925.5 8045 GR MWD040 API 54.71 94.55 73.2685 255 7918 8045 ROP MWD040 FT/H 47.93 295.11 163.482 124 7983.5 8045 First Reading For Entire File..........7918 Last Reading For Entire File...........8045 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 r 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 f iles. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8045.5 8387.0 ROP 8045.5 8443.0 RPX 8045.5 8387.0 RPS 8045.5 8387.0 RPD 8045.5 8387.0 GR 8045.5 8380.0 FET 8045.5 8387.0 LOG HEADER DATA DATE LOGGED: 26-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8443.0 TOP LOG INTERVAL (FT) 8045.0 BOTTOM LOG INTERVAL (FT) 8443.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.5 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8045.5 8443 8244.25 796 8045.5 8443 RPD MWDO50 OHMM 5.71 2000 22.6339 684 8045.5 8387 RPM MWDO50 OHMM 5.25 2000 17.9557 684 8045.5 8387 RPS MWDO50 OHMM 5.31 2000 16.7337 684 8045.5 8387 RPX MWDO50 OHMM 5.26 2000 16.643 684 8045.5 8387 FET MWDO50 HOUR 0.51 10.03 1.38434 684 8045.5 8387 GR MWDO50 API 58.02 112.51 81.5687 670 8045.5 8380 ROP MWDO50 FT/H 2.01 329.07 153.272 796 8045.5 8443 First Reading For Entire File..........8045.5 Last Reading For Entire File...........8443 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/11 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 .....................07/04/11 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 Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 11 11:58:22 2007 Reel Header Service name .............LISTPE Date .....................07/04/11 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/04/11 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN MWD RUN 5 JOB NUMBER: W-0004725792 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-103 PB3 500292331872 ConocoPhillips Alaska, Inc Sperry Drilling Services 11-APR-07 MWD RUN 3 MWD RUN 4 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN MWD RUN 6 W-0004725792 P. ORTH D. GLADDEN 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 7130.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE ~ ~ -~ 11~-{ ~` t5 65 i ~ NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-103 PB2 WELLBORE AT 8220'MD/3779'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 3-6 ALSO INCLUDED AT-BIT INCLINATION (ABI). 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 1-6 REPRESENT WELL 1J-103 PB3 WITH API#: 50-029-23318-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10667'MD/3764'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.......07/04/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2889.0 10603.5 FET 2910.0 10611.0 RPX 2910.0 10611.0 RPM 2910.0 10611.0 RPD 2910.0 10611.0 RPS 2910.0 10611.0 ROP 2935.5 10667.0 BASELINE CURVE FOR SH IFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2889.0 7137.0 MWD 3 7137.0 7983.0 MWD 4 7983.0 8045.0 MWD 5 8045.5 8220.0 MWD 6 8220.5 10667.0 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 Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 10667 6778 15557 2889 10667 RPD MWD OHMM 0.31 2000 25.0086 15403 2910 10611 RPM MWD OHMM 1.29 2000 18.4677 15403 2910 10611 RPS MWD OHMM 1 2000 14.3096 15403 2910 10611 RPX MWD OHMM 2.05 2000 13.8721 15403 2910 10611 FET MWD HOUR 0.14 88.57 2.07527 15403 2910 10611 GR MWD API 19.57 123.41 74.7002 15430 2889 10603.5 ROP MWD FT/H 0.49 561.51 189.16 15464 2935.5 10667 First Reading For Entire File..........2889 Last Reading For Entire File...........10667 File Trailer Service name .............STSLIB.001 Service Sub Level Name.,. Version Number.........,.1.0.0 Date of Generation.......07/04/11 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.... ...07/04/11 Maximum Physical Recor d..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 GR 2889.0 7090.0 RPD 2910.0 7082.0 RPM 2910.0 7082.0 RPX 2910.0 7082.0 RPS 2910.0 7082.0 FET 2910.0 7082.0 ROP 2935.5 7137.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7137.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 7137.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 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 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 2889 7137 5013 8497 2889 7137 RPD MWD020 OHMM 1.56 2000 20.7493 8345 2910 7082 RPM MWD020 OHMM 1.29 1645.31 12.8934 8345 2910 7082 RPS MWD020 OHMM 1 180.57 12.252 8345 2910 7082 RPX MWD020 OHMM 3 166.05 11.6234 8345 2910 7082 FET MWD020 HOUR 0.14 55.89 1.54127 8345 2910 7082 GR MWD020 API 19.57 123.41 76.8508 8403 2889 7090 ROP MWD020 FT/H 1.07 561.51 183.759 8404 2935.5 7137 First Reading For Entire File..........2889 Last Reading For Entire File...........7137 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 DEPTH STOP DEPTH FET 7082.5 7925.0 RPX 7082.5 7925.0 RPD 7082.5 7925.0 RPS 7082.5 7925.0 RPM 7082.5 7925.0 GR 7090.5 7917.5 ROP 7137.5 7983.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7983.0 TOP LOG INTERVAL (FT) 7137.0 BOTTOM LOG INTERVAL (FT) 7983.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 7082.5 7983 7532.75 1802 7082.5 7983 RPD MWD030 OHMM 0.31 2000 73.5182 1686 7082.5 7925 RPM MWD030 OHMM 1.3 2000 52.8754 1686 7082.5 7925 RPS MWD030 OHMM 2.1 63.91 18.2548 1686 7082.5 7925 RPX MWD030 OHMM 2.05 72.51 17.59 1686 7082.5 7925 FET MWD030 HOUR 0.38 88.57 6.79246 1686 7082.5 7925 GR MWD030 API 40.88 1 18.29 74.581 1655 7090.5 7917.5 ROP MWD030 FT/H 2.51 311.76 182.858 1692 7137.5 First Reading For Entire File..........7082.5 Last Reading For Entire File...........7983 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7918.0 8045.0 RPX 7925.5 8045.0 RPM 7925.5 8045.0 RPS 7925.5 8045.0 RPD 7925.5 8045.0 FET 7925.5 8045.0 ROP 7983.5 8045.0 LOG HEADER DATA DATE LOGGED: 25-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8045.0 TOP LOG INTERVAL (FT) 7983.0 BOTTOM LOG INTERVAL (FT) 8045.0 BIT ROTATING SPEED (RPM}: HOLE INCLINATION (DEG MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 7983 • M MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7918 8045 7981.5 255 7918 8045 RPD MWD040 OHMM 11.09 23.05 14.363 240 7925.5 8045 RPM MWD040 OHMM 9.27 23.7 13.4869 240 7925.5 8045 RPS MWD040 OHMM 8.17 19.03 13.2493 240 7925.5 8045 RPX MWD040 OHMM 7.7 18.04 13.1191 240 7925.5 8045 FET MWD040 HOUR 0.42 32.68 16.514 240 7925.5 8045 GR MWD040 API 54.71 94.55 73.2685 255 7918 8045 ROP MWD040 FT/H 47.93 295.11 163.482 124 7983.5 8045 First Reading For Entire File..........7918 Last Reading For Entire File...........8045 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 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 f iles. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8045.5 8220.0 FET 8045.5 8220.0 RPS 8045.5 8220.0 RPM 8045.5 8220.0 GR 8045.5 8220.0 RPD 8045.5 8220.0 ROP 8045.5 8220.0 LOG HEADER DATA DATE LOGGED: 26-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8220.0 TOP LOG INTERVAL (FT) 8045.0 BOTTOM LOG INTERVAL (FT) 8220.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.5 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resi s. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7130.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPER ATURE: .000 93.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 ~.r.I DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8045.5 8220 8132.75 350 8045.5 8220 RPD MWDO50 OHMM 6.63 20.36 9.55223 350 8045.5 8220 RPM MWDO50 OHMM 6.2 25.55 8.81631 350 8045.5 8220 RPS MWDO50 OHMM 5.88 21.03 8.51531 350 8045.5 8220 RPX MWDO50 OHMM 5.53 17.75 8.44731 350 8045.5 8220 FET MWDO50 HOUR 0.72 10.03 1.75654 350 8045.5 8220 GR MWDO50 API 60.16 103.79 82.0256 350 8045.5 8220 ROP MWDO50 FT/H 2.01 258.29 122.658 350 8045.5 8220 First Reading For Entire File..........8045.5 Last Reading For Entire File...........8220 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/11 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.......07/04/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log he ader data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8220.5 10611.0 ROP 8220.5 10667.0 RPS 8220.5 10611.0 RPD 8220.5 10611.0 GR 8220.5 10603.5 FET 8220.5 10611.0 RPX 8220.5 10611.0 S LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 27-DEC-06 Insite 66.37 Memory 10667.0 8220.0 10667.0 89.0 94.9 TOOL NUMBER 160788 156401 6.750 7130.0 Mineral Oil Base 8.50 93.0 .0 23000 3.4 .000 .0 .000 114.8 .000 .0 .000 .0 Data Format Specification Re cord 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 Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading + • DEPT FT 8220.5 10667 9443.75 4894 8220.5 10667 RPD MWD060 OHMM 5.51 74.22 17.0038 4782 8220.5 10611 RPM MWD060 OHMM 5.14 2000 17.0206 4782 8220.5 10611 RPS MWD060 OHMM 5.18 2000 16.9865 4782 8220.5 10611 RPX MWD060 OHMM 5.11 2000 16.9203 4782 8220.5 10611 FET MWD060 HOUR 0.29 7.92 0.642685 4782 8220.5 10611 GR MWD060 API 47.74 118.19 70.4896 4767 8220.5 10603.5 ROP MWD060 FT/H 0.49 434.12 206.019 4894 8220.5 10667 First Reading For Entire File..........8220.5 Last Reading For Entire File...........10667 File Trailer Service name .......... ...STSLIB.006 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/04/11 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.007 Physical EOF Tape Trailer Service name........ Date ................ Origin .............. Tape Name........... Continuation Number. Next Tape Name...... Comments............ .....LISTPE .....07/04/11 .....STS .....UNKNOWN .....01 .....UNKNOWN .....STS LIS writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/11 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
