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206-153
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: OA Cement Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14379'feet None feet true vertical 6218' feet 7805' feet Effective Depth measured 14379'feet 6864' feet true vertical 6218' feet 5954' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" x 3-1/2" L-80 7565' MD 6199' TVD Packers and SSSV (type, measured and true vertical depth) 6864' MD 2148' MD 5954' TVD 2044' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Nanuq Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 325-249 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Surface- 2542' Packer: Baker Premier Packer SSSV: Camco TRMAXX-5E Safety VLV Mark Shulman Mark.Shulman@conocophillips.com (907) 263-3782Senior Well Intervention Engineer Alternating perforated pup joints: 7719-14372' Alternating perforated pup joints: 6213-6218' 108 bbl 15.8 ppg Class G Cement w/ Gas Blocker Squeeze (36 bbls beyond casing) TOC in SC +/- 3" measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 635 Gas-Mcf MD 406 Size 114' 28 11653212 0 3430 230 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-153 50-103-20538-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380077, ADL0384209, ADL0384211, ADL0388903 Colville River Field/ Nanuq Oil Pool CRU CD4-211 Plugs Junk measured Length Production Liner 7693' 6826' Casing 6213' 3-1/2" 7727' 14374' 6217' 2507' 114'Conductor Surface Intermediate 16" 9-5/8" 78' 2542' 2391' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:23 am, Jul 17, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.07.16 17:29:47 -08'00' RBDMS JSB 072525 VTL 7/30/2025 DSR-7/21/25 DTTMSTART JOBTYP SUMMARYOPS 3/13/2025 DATA ACQUISITION (AC-EVAL) SCLD (FAILED, LEAK IDENTIFIED @ 7') OA-DDT (PASSED) 4/11/2025 REPAIR WELL BRUSH n' FLUSH TBG W/ 2.75" GAUGE RING IN THE RBP SETTING AREA @ 6895' RKB. SET 2.72" P2P RBP @ 6895' RKB {ALPP35035, ALEQ35006} & TESTED TBG TO 1500 PSI. ATTEMPT TO SET CATCHER & RBP FELL DOWN HOLE TO 6998' RKB. PULLED CATCHER & ATTEMPT TO EQUALIZE RBP W/ EQ. PRONG, PLUG FELL THRU THE MILLED 2.80" XN NIPPLE @ 7005' RKB. RECOVERED THE RBP @ 7539' RKB. JOB IN PROGRESS. 4/12/2025 REPAIR WELL SET 2.72" P2P RBP @ 6873.5' RKB (M.E. @ 6876' RKB) & TESTED TBG TO 1500 PSI. SET CATCHER ON TOP OF RBP & PULLED OV @ 6775' RKB. PERFORM 233 BBL DIESEL CIRCOUT PUMPING DOWN TBG & TAKING RETURNS UP THE IA. JOB IN PROGRESS. 4/12/2025 REPAIR WELL CIRC OUT PUMPED 233 BBLS DSL DWN TBG TAKING RETURNS OFF IA TO CD2- 211 FL FREEZE PROTECT PUMPED 5 BBLS DSL DWN FL 4/13/2025 REPAIR WELL SET DV @ 6775' RKB & ACHIEVED A PASSING MIT-IA TO 3000 PSI. PULLED CATCHER & 2.72" P2P RBP @ 6873' RKB. JOB COMPLETE 4/24/2025 MAINTAIN WELL HOT FLUSH PUMPED 50 BBLS 190* CRD DWN TBG PUMPED 10 BBLS HOT CRD DWN FL 4/26/2025 MAINTAIN WELL FREEZE PROTECT TBG/FL PUMPED 35 BBLS CRUDE DOWN TBG PUMPED 5 BBLS CRUDE DOWN FL (JOB COMPLETE) 6/14/2025 REPAIR WELL PUMP OA CEMENT DOWN SQUEEZE 9-5/8" X 7", FILL OA FROM CASING SHOE AT 2542' TO SURFACE WITH 15.8 PPG CLASS G CEMENT W/ CEMNET AND GAS BLOCKER. PUMPED 108 BBLS OF CEMENT WITH MULTIPLE 15 MINUTE HESITATIONS PRIOR TO PRESSURE LOCK UP, PLACING 36 BBLS OF CEMENT BEYOND CASING. SQUEEZE IN 0.1 BBL DIESEL AFTER CEMENT TO CLEAR VALVES AND OA LEFT SHUT IN WITH 600 PSI. 6/18/2025 DATA ACQUISITION (MISC) OA DDT PASSED, TOC IN SC +/-3", IC POT PASSED 6/25/2025 REPAIR WELL GAUGED TBG W/ 2.79'' TO 7200' RKB. SET 3.5'' SLIP STOP CATCHER @ 7045' RKB. PULLED DMY FROM GLM#2 @ 6774' RKB & SET OV. PULLED DMY FROM GLM#1 @ 4044' RKB & SET GLV. DDT 375 ON TBG / 0 ON IA. PULLED EMPTY CATCHER @ 7045' RKB. JOB COMPLETE. 7/6/2025 MAINTAIN WELL HOTFLUSH. PUMPED 50 BBLS CRD @190 DEG DOWN THE TUBING FOLLOWED BY 10 BBLS CRD @ 190 DEG DOWN THE FLOWLINE JOB COMPLETE 7/12/2025 MAINTAIN WELL HOTFLUSH: PUMPED 50 BBLS CRD @190 DEG DOWN THE TUBING FOLLOWED BY 10 BBLS CRD @ 190 DEG DOWN THE FLOWLINE, JOB COMPLETE, TURN WELL OVER TO OPS. CD4-211 OA Cement Squeeze Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD4-211 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Gas Lift Re-design CD4-211 6/25/2025 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/9.0 7/16/2008 lmosbor 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 16 15.25 36.0 114.0 114.0 65.00 H-40 Welded SURFACE 9 5/8 8.83 35.4 2,542.0 2,391.2 40.00 L-80 BTC INTERMEDIATE 7 6.28 34.8 7,727.4 6,213.3 26.00 L-80 BTCM LINER 3 1/2 2.99 7,548.4 14,374.0 6,217.4 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 16.8 Set Depth … 3,999.1 Set Depth … 3,708.2 String Max No… 4 1/2 Tubing Description TUBING - VIT Wt (lb/ft) 12.60 Grade L-80 Top Connection VIT/IBT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 16.8 16.8 0.00 HANGER 10.850 FMC TUBING HANGER 4.500 30.4 30.4 0.00 XO Reducing 4.500 XO 4-1/2" IBTM to 3-1/2" IBT 3.500 2,148.5 2,044.3 29.70 SAFETY VLV 5.180 CAMCO SSSV TRMAXX-5E 2.812 2,152.8 2,048.1 29.60 XO Increasing 4.500 XO 3-1/2" EUE to 3-1/2" IBT 3.500 Top (ftKB) 3,999.1 Set Depth … 7,565.1 Set Depth … 6,199.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEMOD ID (in) 2.99 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) 3,999.1 3,708.2 22.73 XO Reducing 4.500 3.500 4,044.5 3,750.1 22.52 GAS LIFT 5.290 CAMCO KBMG 2.920 6,774.7 5,904.5 55.80 GAS LIFT 5.390 CAMCO KBMG 2.920 6,863.7 5,953.5 57.41 PACKER 5.890 BAKER PREMIER PACKER 2.875 7,004.9 6,026.7 60.80 NIPPLE 5.000 HES XN NIPPLE (MILLED 1/17/2018 to 2.80") 2.800 7,544.6 6,196.8 82.07 SOS 6.030 SHEAR OUT SUB 3.000 7,564.1 6,199.4 82.63 WLEG 4.130 MULE SHOE WIRELINE ENTRY GUIDE 3.000 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) 7,782.0 6,214.1 89.68 WHIPSTOCK - MONOBORE 3.5" XL Monobore with open hole anchor 4/9/2018 7,799.0 6,214.3 89.45 WHIPSTOCK - MONOBORE 3.5" XL-Monobore 4/8/2018 7,805.0 6,214.3 89.37 FISH String mill has parted below pin leaving fish in hole. 2.80 Window mill & 2.79 string reamer 4/9/2018 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) 4,044.5 3,750.1 22.52 1 GAS LIFT GLV BK 1 1,935.0 6/25/2025 0.188 6,774.7 5,904.5 55.80 2 GAS LIFT OV BK 1 0.0 6/25/2025 0.250 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) 7,548.4 6,197.3 82.18 SLEEVE 5.790 HR LINER SETTING SLEEVE 4.420 7,561.4 6,199.0 82.55 NIPPLE 5.600 "RS" Packoff Seal Nipple 5.60 OD x 4.25 4.250 7,590.2 6,202.6 83.37 XO 4.5x3.5" 4.500 XO - 4 1/2" SLHT x 3 1/2" SLHT 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,719.0 14,372.0 6,213.0 6,217.6 11/30/2006 40.0 PERFP Alternating solid/perforated pup joints Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 37.0 2,542.0 37.0 2,391.2 Surface Casing Cement 11/17/2006 3,913.0 7,727.0 3,629.0 6,213.3 Intermediate Casing Cement 11/23/2006 37.0 2,542.0 37.0 2,391.2 Squeeze – Behind Casing Squeeze 15.8 PPG class G cement with cement & gas blocker, 108 BBLS 6/14/2025 CD4-211, 7/16/2025 5:04:30 PM Vertical schematic (actual) LINER; 7,548.4-14,374.0 PERFP; 7,719.0-14,372.0 L1 LINER; 8,244.5-10,700.0 FISH; 7,805.0 WHIPSTOCK - MONOBORE; 7,799.0 INTERMEDIATE; 34.8-7,727.4 PACKER; 6,863.7 GAS LIFT; 6,774.7 Intermediate Casing Cement; 3,913.0 ftKB GAS LIFT; 4,044.5 SURFACE; 35.3-2,542.0 SAFETY VLV; 2,148.5 Surface Casing Cement; 37.0 ftKB Squeeze – Behind Casing Squeeze; 37.0 ftKB CONDUCTOR; 36.0-114.0 HANGER; 16.8 WNS PROD KB-Grd (ft) 43.93 RR Date 12/5/2006 Other Elev… CD4-211 ... TD Act Btm (ftKB) 14,379.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053800 Wellbore Status PROD Max Angle & MD Incl (°) 94.94 MD (ftKB) 14,341.16 WELLNAME WELLBORECD4-211 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD4-211L1 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SIDETRACK CD4- 211L1 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 LINER 2 3/8 1.99 8,244.5 10,700.0 4.60 L-80 STL 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) 8,244.5 Aluminum Billet 2.630 Aluminum Liner Top Billet BOT Billet 1.920 CD4-211L1, 7/16/2025 5:04:31 PM Vertical schematic (actual) L1 LINER; 8,244.5-10,700.0 LINER; 7,548.4-14,374.0 PERFP; 7,719.0-14,372.0 FISH; 7,805.0 WHIPSTOCK - MONOBORE; 7,799.0 INTERMEDIATE; 34.8-7,727.4 PACKER; 6,863.7 GAS LIFT; 6,774.7 Intermediate Casing Cement; 3,913.0 ftKB GAS LIFT; 4,044.5 SURFACE; 35.3-2,542.0 SAFETY VLV; 2,148.5 Surface Casing Cement; 37.0 ftKB Squeeze – Behind Casing Squeeze; 37.0 ftKB CONDUCTOR; 36.0-114.0 HANGER; 16.8 WNS PROD KB-Grd (ft) 43.93 RR Date 12/5/2006 Other Elev… CD4-211L1 ... TD Act Btm (ftKB) 10,700.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053860 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORECD4-211 Annotation Last WO: End DateH2S (ppm) DateComment Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD4-211L1 -01 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SIDETRACK CD4- 211L1-01 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 LINER 2 3/8 1.99 7,739.7 10,989.0 4.60 L-80 STL 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) 7,739.7 Aluminum Billet 2.630 Shorty Deployment Sleeve BOT Billet 1.920 9,563.9 Aluminum Billet 2.630 Shorty Deployment Sleeve BOT Billet 1.920 CD4-211L1-01, 7/16/2025 5:04:31 PM Vertical schematic (actual) L1-01 LINER; 7,739.7-10,989.0 LINER; 7,548.4-14,374.0 PERFP; 7,719.0-14,372.0 INTERMEDIATE; 34.8-7,727.4 PACKER; 6,863.7 GAS LIFT; 6,774.7 Intermediate Casing Cement; 3,913.0 ftKB GAS LIFT; 4,044.5 SURFACE; 35.3-2,542.0 SAFETY VLV; 2,148.5 Surface Casing Cement; 37.0 ftKB Squeeze – Behind Casing Squeeze; 37.0 ftKB CONDUCTOR; 36.0-114.0 HANGER; 16.8 WNS PROD KB-Grd (ft) 43.93 RR Date 12/5/2006 Other Elev… CD4-211L1-01 ... TD Act Btm (ftKB) 10,989.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053861 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORECD4-211 Annotation Last WO: End DateH2S (ppm) DateComment 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 Other:SC Leak Repair /OA Cement 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14379'7805' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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 5/15/2025 14374'6826' 3-1/2" 6217' Packer: Baker Premier Packer SSSV: Camco TRMAXX-5E Perforation Depth MD (ft): L-80 7693' 2507' 7727' Alternating perforated pup joints @ 7719-14372' 3-1/2" Alternating perforated pup joints @ 6213-6218' Perforation Depth TVD (ft): 114' 2542' 16" 9-5/8" 78' 7" 7565' MD 114' 2391' 6213' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Nanuq Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380077, ADL0384209, ADL0384211, ADL0388903 206-153 P.O. Box 100360, Anchorage, AK 99510 50-103-20538-00-00 Colville River Field Nanuq Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6864' MD and 5954' TVD 2148' MD and 2044' TVD Mark Shulman 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: Mark.Shulman@conocophillips.com (907) 263-3782 Senior Well Interventions Engineer CRU CD4-211 6218' 14739' 6218' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:54 am, Apr 23, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.04.23 09:15:20 -08'00' 325-249 SFD 5/5/2025 DSR-4/25/25 10-404 OA double valved during cementing ops. Include OA TOC tag depth in 10-404. JJL 5/8/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.12 08:03:41 -08'00'05/12/25 RBDMS JSB 051225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 21, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-403 from ConocoPhillips Alaska, Inc. for OA cementing CRU CD4- 211 (PTD 206-153). The goal of the OA cementing is to mitigate the pressure source and potentially repair the surface casing leak. Please contact me at (907) 263-3782 if you have any questions. Sincerely, Mark Shulman Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. CD4-211 Cement Shoe Page 1 Date: April 21, 2025 Subject: CD4-211 OA Cement Shoe Procedure: Prepared By: Mark Shulman, 263-3782 Objective Down squeeze 9 5/8” x 7” OA to cement surface casing shoe to surface. Cement Volume Calculations: x Volume in 9-5/8”x 7” annulus: (2,542 ft) x (0.0282 bbl/ft) = 72 bbl x Excess: 216 bbl x Total volume: 72 + 216 = 288 bbl CRU CD4-211 (PTD#206-153) is a producer that was originally drilled and completed in 2006. The well is currently shut-in for a surface casing leak. CD4-211 has a surface casing repair. CD4-211’s OA has maintained a pressure of +400 psi. The goal of the OA cementing is to control the OA pressure by pumping an OA cement shoe to surface. Procedure 1. Verify 10-403 Sundry form has been approved for OA cement job. 2. Contact Cement Pumping Services to schedule the OA cement job and allow time for pilot testing. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. Install 1502 union and valves on the OA. Rig up hardline to the OA with an option to divert to open top tank for wash up. 5. Ensure Valve crew services OA valves and any additional hardline valves installed for cementing job. 6. Install containment into cellar to contain any returns from surface casing leak. Ensure vac truck on location with cement containment to take returns from surface casing leak from pumping operations. 7. MIRU cement pumping equipment and rig up 2” hardline to the circulation skid. Stage equipment to minimize pumping stop time between stages. 8. Be sure to monitor around wellhead, wellhouse, and conductor top during OA pumping. There is a known surface casing leaks near the surface. During the OA injectivity testing returns were observed at the conductor. 9. PT lines and surface equipment to 3,000 psi. 10. Pump the OA shoe. a. Complete an Injectivity test up to 1500 psi. and ensure OA will take injection. Ensure OA double valved during cementing ops - JJL CD4-211 Cement Shoe Page 2 i. Record injection pressures and rates for cementing. b. At the beginning of the job, increase the pump pressure as necessary to break over on injection. Do not exceed 1,000 psi. c. Once the OA breaks over, pump at maximum possible rate without exceeding maximum pressure of 1,000 psi. i. When cement gets to the shoe (72 bbls pump total after starting on cement), slow pumps to a maximum of 1 BPM or 500 psi. ii. With 10 bbls of cement past the shoe (82 bbls after starting cement), shut-down pumps and watch pressure. Perform a 15-minute hesitation, then attempt to slowly squeeze another 10 bbls at minimum rate. iii. If OA does not catch pressure after 100 bbls are pumped in OA, stop pumping cement and swap to pump 75 bbls of diesel in OA to FP and keep the shoe open and contact production engineer and WI engineer. d. Use cement composition on page #3. e. Pump Schedule: i. 10 bbls hot diesel per Wells Supv. ii. 65 bbls 90oF hot freshwater for flush of the OA. iii. 20 bbls CW100 surfactant wash iv. 10 bbls freshwater spacer v. 15 bbls 15.8# Class G cement (neat) vi. 273 bbls 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker. 1. if well locks up while pumping cement, go to next step. 11. Close annulus, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. Top off OA with diesel for freeze protection. 12. Do not bleed the OA. Monitor the conductor top and downspout and vac out fluids if needed. 13. Wash up cementing equipment, RDMO. 14. Send OA cement shoe field blend UCA results to mark.shulman@conocophillips.com 15. After the cement cures for 72 hours, perform OA drawdown test. 16. If DDT passes DHD to drop string line and verify top of cement. 17. Report well work to AOGCC on 10-404 form. CD4-211 Cement Shoe Page 3 Cement Composition: Originated: Delivered to:7-May-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 CD2-21 50-103-20504-00 909953586 Colville River Leak Detect Log Field- Final 22-Apr-25 0 12 CD2-21 50-103-20504-00 909953586 Colville RiverPlug Setting RecordField- Final 21-Apr-25 0 13 CD2-40 50-103-20464-00 909953481 Colville RiverMulti Finger CaliperField & Processed 10-Apr-25 0 14 CD2-40 50-103-20464-00 909953481 Colville RiverPacker Setting RecordField- Final 14-Apr-25 0 15 CD4-24 50-103-20602-00 909953393 Colville RiverLeak Detect LogField- Final 16-Apr-25 0 16 CD4-24 50-103-20602-00 909953479 Colville RiverPacker Setting RecordField- Final 6-Apr-25 0 17 CD4-24 50-103-20602-00 909953393 Colville RiverPacker Setting RecordField- Final 19-Apr-25 0 18 CD4-211 50-103-20538-00 909953392 Colville RiverPlug Setting RecordField- Final 11-Apr-25 0 19 CD4-211 50-103-20538-00 909953392 Colville RiverPlug Setting RecordField- Final 12-Apr-25 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:204-245203-126209-097206-153T40368T40368T40369T40369T40370T40370T40370T40371T403715/8/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 10:16:03 -08'00'8 CD4-21150-103-20538-00 909953392Colville RiverPlug Setting RecordField- Final11-Apr-25019 CD4-21150-103-20538-00 909953392Colville RiverPlug Setting RecordField- Final12-Apr-250106-153 • Image Project Well History File Couer 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 fife. ~~ ~~ - 1 ~ ~ Well History File Identifier Organizing (done> RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o,wosa~d iuimimiuuii DIGI AL DATA iskettes, No. I ^ Other, No/Type: a.,~a„~eaaae uumiiuiuuui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Marian Date: L ~ ~~ ~ (~ CJ /s/ ~ Project Proofing BY: Maria - Date: ~ ~ /s/ ~; , Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES~~, { / I (Count does not include cover sheet) , ^ n r BY: Maria ~ Date: .~ f In/ /~ ~ Isl t/ h I I` Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: l ~p~'~ ~ /s/ ~~~ Stage 1 If NO in stage 1, page(s) discrepancies ////were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'II) I II II II III Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'll) III III III 10/6/2005 Well History File Cover Page.doc _.,, ~, ~: : - °* _ '~ Y _ ,. ~ .,.. i ~`a ~~ ~ ~ ` ~ x ~* ~ ~ ~ ". MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~ ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 ~-~~-~. • 'y ~~~~ % ~: ~~1 ~~r~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: aG~~ ~ 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 corrosion inhibitor/sealant was pumped March 18~', 2009. 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. Sinc Perry 111G1i1 ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 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 CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18!2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 S~"J~ ~a~q DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061530 Well Name/No. COLVILLE RIV NAN-N CD4-211 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20538-00-00 MD 14379 TVD 6218 Completion Date 12/5/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/Neutron Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name D D Asc Directional Survey ICI ~ C Lis 15007 Induction/Resistivity 15017 LIS Verification E~ C Lis 15017 Induction/Resistivity ':frD C 15670 i InductionlResistivity (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments 0 14379 Open 1/28/2007 2518 14379 Open 4/13/2007 LIS Veri, GR, ROP, FET 2518 14379 Open 4/17/2007 LIS Veri, GR, FET, ROP "'New Info to replace previous*" 2518 14379 Open 4/17/2007 LIS Veri, GR, FET, ROP *"New Info to replace previous"" 2518 14379 11/12/2007 EMF in PDF and EMF graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? Chips Received? ~N, Formation Tops Y / N Analysis Y~'IV' Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061530 Well Name/No. COLVILLE RIV NAN-N CD4-211 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20538-00-00 MD 14379 TVD 6218 Completion Date 12/5/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: _~_ Date: ~6y ~©~~ CJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-153 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD4-211 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20538-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 306-392 12/29/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 373* 373 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 24428 100 0 24528 24 6/4/2007 6/30/2007 CD4-302, CD4-16 2007 / 3rd 6936 100 0 7036 8 7/2/2007 7/11/2007 CD4-16 2007 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th volume 31364 200 373 31937 32 (bbls): of the month following the final month of the quarter. Ex: July 20 for the second quarter Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Itl~@CtlVlt test, freeze rotect I hereby certify that the foregoin true and correct to the best of my knowledge. Signature: ~ ~-----_ Date: t ~~I ~d $ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-211 October 29, 2007 AK-MW-4726255 CD4-211: Digital Log Images: 50-103-20538-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date ~ Signed: r5 3 X15-~~d ~b~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-153 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD4-211 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20538-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-392 12/29/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 373* 373 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 24428 100 0 24528 24 6/4/2007 6/30/2007 CD4-302, CD4-16 2007 / 3rd 6936 100 0 7036 8 7/2/2007 7/11/2007 CD4-16 2007 / 4th Total Ending Report is due on the 20th volume 31364 200 373 31937 32 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *In~ectlVl test, freeze protect I hereby certify that the foregoing is true and correct to the best of my knowledge. Si t ~~ a ~°~~ gna ure: ~ Date: < Z Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 206-153 ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 7. Well Name: CD4-211 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20538-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 306-392 12/29/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 373* 373 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 24428 100 0 24528 24 6/4/2007 6/30/2007 CD4-302, CD4-16 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 24428 100 373 24901 24 (bbls): of the month following the final month of the quarter. Ex: July 20 for the second quarter April 20 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *In~ectlVlt test, freeze rotect I hereby certify that the foregoing is true and correct to the est of m y knowledge. b ~ - ~ ~-" °` ~ --°- ` -`"e't' 1 ~J ~° ~ Signature: --- 1 \ ~ Date: ~- Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate WELL LOG TRANSI~TITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-21 1, April 16, 2007 AK-MW-4726255 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 5 0-103 -205 3 8 -00. ~z.. F Note: This data replaces any previous data for well CD4-211. L.G~ i~ ~ ~ ~~n~. ~ 6' ~ =v ~o~ - ~s3 `'ELL LOG TRatiS~'IITTaL To: State of Alaska April 5, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-211, AK-MW-4726255 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-2053 8-00. ~~ ~~ ~ ~ ~ ~ ~, o ,- m~:~ ~ ~~ ~~ ~. Z~U ~~ ~.~~ ~. ~ , . ~ ~~'° 3(310-t53 ~ ~5ao~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. ~~-153 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD4-211 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WiNJ ^ WDSPL ^ 50-103-20538-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 306-392 12/29/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 373* 373 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume (bbls>: 0 0 373 373 0 of the month following the final month of the quarter. Ex: July 20 for the second quarter Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *in~ectivit test, freeze protect nd correct to the b tr a e st of my knowledge. I hereby certify that the foregoing~is ue ~ ` ' me ~ r Signature: ~ ~_ "`-'~`~'1 l Date: L7~'3 fa Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SIGN ~/ WELL COMPLETION OR RECOMPLETION REPORT~-~IO~~ 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well C~Y'V~ o L~Q I Development / Exploratory n^ G~CO(1SSt~C1~1'i~IPMIISS~i~I--~ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 5, 2006 12. Permit to r~ I u e ,:c ~~i ye 206-153 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 15, 2006 13. API Number: 50-103-20538-00 4a. Location of Well (Governmental Section): Surface: 2932' FNL, 264' FEL, Sec. 24, T11N, R4E, UM 7. Date TD Reached: December 1, 2006 14. Well Name and Number: CD4-211 At Top Productive Horizon: 853' FSL, 2320' FEL, Sec. 24, T11 N, R4E, UM 8. KB Elevation (ft): 56' RKB MSL 15. Field/Pool(s): Colville River Field Total Depth: 32' FNL, 856' FWL, Sec. 31, T11 N, R5E, UM 9. Plug Back Depth (MD + TVD): 14379' MD ! 6218' TVD Nanuq Nanuq Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377980 y- 5957479 Zone- 4 10. Total Depth (MD + TVD): 14379' MD / 6218' TVD 16. Properly Designation: ADL 380077, 384209, 384211, 388903 TPI: x- 375901 y- 5956018 Zone- 4 Total Depth: x- 378976 - 5949804 Zone- 4 11. Depth where SSSV set: 2149' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1720' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE Wt. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 56' 114' 56' 114' 36" pre-installed 9.625" 40# L-80 56' 2543' 56' 2391' 12.25" 308 sx ArcticSet Lite, 235 sx Class G 7" 26# L-80 56' 7727' 56' 6213' 8.75" 135 sx LiteCRETE, 287 sx Class G 3.5" 9.3# L-80 7549' 14374' 6197' 6217' 6.125" slotted liner (refer to attachment) 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 7565' 6864' slotted liner from 7549'-14374' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Producer -waiting for facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA 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". 4 ..,.. .__ .~.i _~. T~yy r Y~rV NONE ,'~"""~f 's~i~I} Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL ~ ConocoPhillips January 19, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-211 (APD 206-153) Dear Commissioner: i'.+1LYr Ui':au45 ConocoPhillips Alaska, Inc. submits the WeII Completion Report for the recent drilling operations on the Alpine well CD4-211. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~~,~ V-~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~~-lS3 ~~~1~~~~ ~~~ ~ ,~. STATE OF ALASKA ~ ._J.~'~+~ ~ ,~~ P ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOf~i~-°~C~,~~,QP'~~ ~:~mmiss°~ 1a. Well Status: Oil O Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other 1b. Well Class: Development Q Exploratory ^ ^ Stratigra hic Test1_J Service ~1 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 5, 2006 ' 12. Permit to Drill Number: 206-153 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 15, 2006 ~ 13. API Numb 50-103-20538-00 - 4a. Location of Well (Governmental Section): Surtace: 2932' FNL, 264' FEL, Sec. 24, T11N, R4E, UM " 7. Date TD Reached: December 1, 2006 14. ell Name and Number: CD4-211 At Top Productive Horizon: 853' FSL, 2320' FEL, Sec. 24, T11 N, R4E, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Colville River Field Total Depth: 32' FNL, 856' FWL, Sec. 31, T11N, R5E, UM 9. Plug Back Depth (MD + TVD): 14379' MD / 6 ' TVD Nanuq Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377980 ~ y- 5957479 ~ Zone- 4 10. Total Depth (MD + ): .. 14379' / 6218' TVD - 16. Property Designation: , ADL 380077, 384209, 384211, 388903 TPI: x- 375901 y- 5956018 Zone- 4 Total Depth: x- 378976 ~ - 5949804 Zone- 4 11. Depth wher SSV set: 2149' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^/ No ^ 19. Wat Depth, if Offshore: /A feet MSL 20. Thickness of Permafrost: 1720' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, L ER AND CEMENTING RECORD SETTING DEPTH M SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BO OM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 37' 114' 37' 114' 36" pre-installed 9.625" 40# L-80 37' 2543' 37' 2391' 12.25" 308 sx ArcticSet Lite, 235 sx Class G 7" 26# L-80 37' 7727' 37' 6213' 8.75" 135 sx LiteCRETE, 287 sx Class G 3.5" 9.3# L-80 7549' 14374' 6197' 6217' 6.125" slotted liner (refer to attachment) 23. Pertorations open to Production (MD + TVD of Top a Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 7565' 6864' ~ slotted liner ^ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. p DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~(y 0 n/a ~ tT ~ ~ 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Producer -waiting for facility hook-up Date of Test Hours T sled Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Ca g Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief descriptio 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". NONE - - e „~ ~. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ~, L,/.~ ~~~~EAL f~~~r/=f~~ ~~ 2s. 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". CD4-211 Nanuq sand 7422' - 6172' N/A 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: Vern Johnson @ 265-6081 Printed Name C. Alvord Title: Alpine Drillino Team Leader / ~ Signature Phone ~5 ~.~~~ Date l ~~I Q7 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 i Cona-c Phillips Time Log Summary tNelNiecv Web Reportrnq Weii Name: CD4-211 Job Type: DRILLING ORIGINAL ! Time Logs ~~ _ _ Date From To Dur S. De th E De th Phase Code Subcode T COM 11/15/2006 00:00 02:30 2.50 0 0 MIRU MOVE MOB P Move in Pits and Motor Complexes - S of Ball Mill 02:30 06:00 3.50 0 0 MIRU MOVE RURD P Rig up mud, water, air and steam lines -take on mud in pits -troubleshoot Ri Hi hline ower roblem 06:00 09:30 3.50 0 0 MIRU MOVE RURD P Accepted rig at 0600 hours - Operating on rig generators - PU an standback two 8" flex collars and drillin 'ars -MU BHA #1 09:30 09:45 0.25 0 0 MIRU MOVE SFTY P Held Pre-Spud meeting with rig team 09:45 11:00 1.25 0 0 MIRU MOVE RURD P Fill riser -repaired leak on flange in cellar -pressure test mud lines to 3500 si 11:00 12:00 1.00 114 160 SURFA DRILL DDRL P Spud well @ 1100 hours Drill 12 1/4" hole from 114' to 160'. M D/TVD ADT 0.23 hrs -ART 0.23 hrs -AST 0 hrs. WOB 15 K, RPM 40 -GPM 500gpm / 850 psi. PU Wt 95K SOW 92K ROT 93K Torq ON/ Off Btm 4000 / 3500 Ft Lbs. Ran G ro suroe 12:00 00:00 12.00 160 1,077 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 160' to 1077 MD 1072' TVD ADT - 6.13 hrs =ART - 4.31 hrs. AST - 1.82 hrs WOB 20/25 k RPM 50 GPM 500 @ 1230 psi String wt. PU 122 SO 122 Rot 122 Torque on/off btm. - 6500/4500 fUlbs Note -Last ro sunre 797' 11/16/2006 00:00 12:00 12.00 1,077 2,155 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 1077' to 2155' MD 2050' TVD ADT - 7.75 hrs =ART - 5.05 hrs. AST - 2.68 hrs WOB 20/25 k RPM 50 GPM 650 @ 2000 psi String wt. PU 134 SO 130 Rot 135 Tor ue on/off btm. - 7000/6000 ft/Ibs ~~~ ~ ~ Pay `t s~f 13 i Time Logs _._ - - --- Date From To Dur S Depth E. De th Phase Code Subcode T COM _ 11/16/2006 12:00 18:30 6.50 2,155 2,552 SURFA DRILL DDRL P Drill 12 1/4" hole w/ motor f/ 2155' to 2552' MD 2400' TVD ADT - 5.57 hrs. =ART 4.68 hrs AST .89 hrs WOB 24/30 k RPM 60 GPM 650 @ 2120 psi String wt - PU 144 SO 137 Rot 142 Tor ue on/off btm.- 75000/6000 ft/Ibs 18:30 19:00 0.50 2,552 2,552 SURFA DRILL CIRC P Circulate hole clean for wiper trip - 650 m 1900 si w/ 60 m 19:00 22:00 3.00 2,552 891 SURFA DRILL WPRT P Flow ck (static) -Wiper trip f/ 2552' to 891' w/pump @ 550 gpm @ 1450 psi w/ 60 rpm to 1700' slow pump to 450 to 891' - Hole in ood condition 22:00 23:00 1.00 891 2,506 SURFA DRILL TRIP P Flow ck (static) - RIH f/ 891' to 2506' - No roblem oin in hole 23:00 00:00 1.00 2,506 2,552 SURFA DRILL CIRC P Wash down f/ 2506' to 2552' - Circ hole clean for trip out - 650 gpm @ 1900 si w/ 60 r m 11/17/2006 00:00 02:00 2.00 2,552 166 SURFA DRILL TRIP P POOH on TT from 2552' to 891' -flow check well, static -stand back HWDP 02:00 05:00 3.00 166 0 SURFA DRILL PULD P Stand back NMflex collars and jars - Download MWD -lay down remainder of bha -clear tools from floor 05:00 07:00 2.00 0 0 SURFA CASINC RURD P Rig up to run casing: LD drilling elevators and bails -pull pollution flange from riser - MU fill-up tool - install casing bails, elevators and slips - RU casin ton sand work lafform 07:00 07:15 0.25 0 0 SURFA CASIN( SFTY P Held safety and Opts meeting with crew 07:15 11:30 4.25 0 2,542 SURFA CASIN( RNCS P Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Howco) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) Ran 61jts of csg to 2500' (65 jts total ran) - MU FMC csg hanger & landing jt. -Land csg w/ fluted mandrel hanger on landing ring w/float shoe @ 2542' & float collar @ 2463' 11:30 12:15 0.75 2,542 2,542 SURFA CEME~ PULD P Lay down fill-up tool -blow down top drive - MU cement head 12:15 14:30 2.25 2,542 2,542 SURFA DRILL CIRC P Establish circulation @ 2 bpm / 320 psi -PUW 170K SOW 133K -stage pumps up to 8 bpm -circulate and condition mud for cementing - FCP @ 8 bpm / 390 psi -reciprocated pipe with full returns throughout -PUW 150K SOW 142K ~~~ m F'~e 2 of 13 Time Logs ___ Date From To Dur S. De th E. De th Ph se Code Subcode T COM _ 11/17/2006 14:30 15:00 0.50 2,542 2,542 SURFA CEME~ DISP P Cement 9 5/8" csg as follows Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 10 bbls CW100 w/ Dowell -Tested lines to 3000 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 5.5 b m / 255 si 15:00 15:15 0.25 2,542 2,542 SURFA CEME~ WOOR NP An announcement was made over the rig PA system of a fire in the Boiler room. Rig personnel responding to the alarm located an air compressor that had over heated and was billowing out smoke but no flames were observed. The compressor was locked and the module quickly cleared of smoke. Alpine Security and Fire were notified. Alpine Fire responded to the rig to confirm no further threat was resent. 15:15 16:30 1.25 2,542 2,542 SURFA CEME~ DISP P Continued with cement operations: Mixed & pumped 245 bbls lead slurry (ASL) @ 10.7 ppg (* Observed nut plug marker @ shakers w/ 220 bbls lead pumped -pumped down surge can) Pumped 49 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell - Switched over to rig pumps & displaced cmt w/ 167 bbls 9.8 ppg water base mud -Displaced @ 8.0 bbls/min for first 157 bbls -slowed to 4.0 bbls/min for last 10 bbls -Bumped plug w/ 1120 psi (prep bump pressure 580 psi) Check float (held OK) CIP @ 1627 hrs. -Full circulation throughout job w/ 68 bbls of 10.7 ppg cmt returns to surface -reciprocated pipe until last 77 bbls of dis lacement. 16:30 17:15 0.75 2,542 2,542 SURFA CASIN( DHEO P Test casing to 2500 psi for 30 minutes - bleed off pressure and blow down lines 17:15 18:45 1.50 0 0 SURFA CEME~ RURD P Rig down cmt head & lines - LD landin 't. 18:45 19:30 0.75 0 SURFA DRILL RURD P ND surface riser & starting head 19:30 20:30 1.00 SURFA DRILL OTHR P Install FMC Unibore Horizontal well head -Test to 1000 si 20:30 22:00 1.50 SURFA WELCT NUND P Nipple up BOPE 22:00 00:00 2.00 SURFA WELCT BOPE P RU & Begin testing BOPE - Hydril to 250 & 3500 psi -Top pipe rams - choke maniflod valves to 250 & 5000 si P~e~e esf 13~ Time Logs __ _ __ _ Date From To Dur S. De th E. De th Pha se Code Subcode T COM 11/18/2006 00:00 05:00 5.00 0 0 _ SURFA WELCT BOPE P _ Continue testing BOPE: Tested Blind and lower pipe rams, choke, kill, remaining manifold valves, and surface safety valves to 250 / 5000 psi. Chuck Scheve waived witnessing tests. Pull test plug and install wear bushing - blow down lines 05:00 05:30 0.50 0 0 SURFA DRILL OTHR P PU drilling bails and elevators -ready ton s 05:30 09:00 3.50 0 713 SURFA DRILL PULD P MU BHA #2 - 8 3/4" bit , 7600 GeoPilot - DM flex - MWD/LWD tools - Initialize tools - R!H with flex drill collars and hwdp to 713' -pressure test Geo-Skid to 3500 psi -shallow test tools 09:00 09:45 0.75 713 1,869 SURFA DRILL TRIP P PU drilling jars - RIH with 5"drill pipe t o 1869' 09:45 10:30 0.75 1,869 2,340 SURFA DRILL TRIP P Change elevators and RIH with 4"drill i e to 2340' 10:30 12:15 1.75 2,340 2,340 SURFA RIGMN SVRG P Slip and cut drilling line -service Top Drive and Drawworks 12:15 16:30 4.25 2,340 2,552 SURFA CEME~ DRLG P Wash down from 2340' -clean out cement from 2438' to 2461' -drill wiper plugs, FC, cement, FS and clean out rathole to 2552' - 500 gpm / 1440 psi - WOB 6-10K -RPM 70 PUW 130K SOW 130K 16:30 16:45 0.25 2,552 2,572 SURFA DRILL DDRL P Drill 20' of new hole from 2552' to 2572' MD 2417' TVD 16:45 17:15 0.50 2,572 2,572 SURFA CEME~ FIT P Circ hole clean for FIT - 500 gpm / 1440 si - 70 r m 17:15 18:00 0.75 2,572 2,572 SURFA CEME~ FIT P RU and perform PIT to 18.0 ppg EMW - RD /blow down lines 18:00 00:00 6.00 2,572 3,102 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 2572' to 3102' MD 2892' TVD ADT - 3.58 hrs ECD - 10.6 ppg WOB 10/15 RPM 100 GPM 550 1380 psi String wt. PU 150 SO 127 Rot 140 Torque on/off btm. - 8000/7500 ft/Ibs Note -Changed over to 9.6 ppg LSND mud while drillin 1st std after FIT 11/19/2006 00:00 12:00 12.00 3,102 4,355 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3102' to 4355' MD 4020' TVD ADT - 7.82 hrs ECD - 10.6 - 10.8 ppg WOB 10/20 RPM 130/150 GPM 450/550 @ 1390 / 2050 psi String wt. PU 180 SO 135 Rot 152 Tor ue on/off btm. - 10000/8500 ft/Ibs _~~~ r'~~ce~ .~ e~f ~3 _! _Time LoOs__ _ Da_t_e__ _From To Dur S, D~th E. D~th Phase Code Subcode T COM 11/19/2006 12:00 21:30 9.50 _ 4,355 5,523 INTRM1 DRILL DDRL P __ Drill 8 3/4" hole w/GP f/ 4355' to 5523' MD 5009' TVD ADT - 5.99 hrs ECD- 10.55 ppg WOB 20 RPM 150 GPM 650 @ 2290 psi String wt. PU 205 SO 145 Rot 165 Torque on/off btm. - 11,500/9.500 ft/Ibs Note -Began losing pump pressure f/ 2890 si to 1850 si over last 125' 21:30 22:15 0.75 5,523 5,523 INTRM1 DRILL OTHR T Ck. surface equipment -Pressure test surface system All OK - Circ to send home command to GP -Blow down TD - Flow ck well -static 22:15 00:00 1.75 5,523 4,342 INTRM1 DRILL TRIP T POOH on TT f/ 5523' to 4342' - Lookin for wash out 11/20/2006 00:00 00:30 0.50 4,342 4,187 INTRM1 DRILL TRIP T POOH from 4342' -located washout in the tube of a joint of drill pipe -bit depth 4187 -changed out joint -flow check well, static 00:30 01:15 0.75 4,187 5,523 INTRMI DRILL TRIP T RIH from 4187' to 5493' -stage pumps up to 650 gpm / 2850 psi / 150 rpm - Precautionary wash down from 5493' to 5523' 01:15 08:45 7.50 5,523 6,343 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 5523' to 6343' MD 5639' TVD ADT - 4.14 hrs ECD 10.5 - 10.6 ppg WOB 20 RPM 150 GPM 550 @ 2040 psi String wt. PU 220 SO 145 Rot 175 Torque on/off btm. - 12,000/10.500 fUlbs '" Unable to obtain Dogleg rate from GeoPilot re uired to land out well. 08:45 09:30 0.75 6,343 6,343 INTRM1 DRILL CIRC T Circulate hole clean - 650 gpm / 2650 psi / 150 rpm final ECD= 10.2 ppg - flow check well, static 09:30 11:30 2.00 6,343 5,295 INTRM1 DRILL TRIP T POOH on trip tank from 6343' to 5295' - hole taking proper fill -Pump dry job - blow down to drive 11:30 14:00 2.50 5,295 2,436 INTRM1 DRILL TRIP T Pooh on TT from 5295' to 2436' -wiped through tight spot @ 3710' -flow check well 2436', static 14:00 15:30 1.50 2,436 711 INTRM1 DRILL TRIP T POOH from 2436' to 1865', change running tools to 5" -POOH from 1865' to 711' -laid down both ghost reamers -flow check well static 15:30 17:00 1.50 711 0 INTRM1 DRILL PULD T POOH from 711' to 72' -set back HWDP and NM Flex DC's -Plug into MWD to down load -Pull up & break bit & service GP - LD GP &MWD 17:00 19:45 2.75 0 89 INTRM1 DRILL PULD T MU BHA #3 -Motor -MWD -adjust bend in motor & orient w/ MWD - Up load MWD - MU bit 19:45 21:15 1.50 89 421 INTRM1 DRILL TRIP T RIH f/ 89' to 421' -shallow test MWD - Blow down TD Page ~ e~f 1 ~ i Time Logs Date From To __ Dur _ S. DeptFi E. De th Phase Code Subcode T COM 11/20/2006 21:15 00:00 2.75 421 5,194 INTRM1 DRILL TRIP T Continue RIH f/ 421' to 5194' (fill pipe eve 20 stds. 11/21/2006 00:00 00:45 0.75 5,194 6,343 INTRM1 DRILL TRIP T RIH from 5194' -precautionary ream last stand to 6343' - 550 gpm / 2300 si/70r m 00:45 12:00 11.25 6,343 6,940 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f/ 6343' to 6940' MD 5994' TVD ADT - 7.36 hrs ECD 10.1 - 10.3 ppg WOB 10/12 RPM 70 GPM 550 @ 2120 psi String wt. PU 200 SO 150 Rot 175 Tor ue on/off btm. - 10,000/8.500 ft/Ibs 12:00 00:00 12.00 6,940 7,640 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f/ 6,940' to 7,640' MD 6,025' TVD ADT - 8.01 hrs ECD 10.1 - 10.3 ppg WOB 10/15 RPM 70 GPM 650 @ 3,340 psi String wt. PU 195 SO 155 Rot 175 Tor ue on/off btm. - 9,500/8.000 ft/Ibs 11/22/2006 00:00 01:45 1.75 7,640 7,737 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/motor f/ 7,640' to 7,737' MD 6,214' TVD ADT - 1.3 ART 0.76 AST 0.54 hrs ECD 10.4 ppg WOB 12/15 RPM 70 GPM 650 @ 3,280 psi String wt. PU 195 SO 152 Rot 175 Tor ue on/off btm. - 10,500/9.500 fUlbs 01:45 03:45 2.00 7,737 7,381 INTRM1 DRILL CIRC P Pumped 40 bbls high vis sweep - circulate hole clean 650 gpm / 3300 psi / 70 rpm Stood back one stand / 30 minutes to 7381' 03:45 05:30 1.75 7,381 6,333 INTRM1 DRILL TRIP P Perform wiper trip from 7,381' to 6,333' - 550 gpm / 2350 psi / 60 rpm - no problems -flow check well, static - Blow down to drive 05:30 06:15 0.75 6,333 7,737 INTRM1 DRILL TRIP P RIH from 6,333' to 7,666' - recautiona wash and ream to 7,737' 06:15 07:45 1.50 7,737 7,737 INTRM1 DRILL CIRC P Circulate and condition mud -increase mud wt. from 9.8 to 10.0 ppg - 650 gpm / 3400 psi / 70 rpm -flow check well, static -Spot WBS and Lube pills to bit 07:45 09:45 2.00 7,737 6,333 INTRM1 DRILL TRIP P Pump out of hole spotting pills from 7,737' to 6,333' - 2.5 /3.0 bpm / 300 / 400 si 09:45 12:15 2.50 6,333 4,427 INTRMI DRILL TRIP P POOH on TT from 6,330' to 4,427' hole appears in good condition -flow check well, static -pump dry job -blow down to drive 12:15 13:45 1.50 4,427 1,857 INTRMI DRILL TRIP P POOH on TT from 4,427' to 1,857' - no problems -flow check well, static - chan a runnin tools to 5". 13:45 15:30 1.75 1,857 77 INTRM1 DRILL TRIP P POOH from 1,857' to 77' -stood back nm flex collars 15:30 17:15 1.75 77 0 INTRM1 DRILL PULD P Plug in and download LWD - LD bit - lay down remainder of BHA #3. Clear tools from floor. iT~~~ ~ of 1 i Time Logs __ _ _ _~ Date From To _ Dur _ S. Degtt~_ E._Depth Phase Code Subcode T COM ___ __ 11/23/2006 12:30 13:15 0.75 7,727 7,727 INTRMI CASIN( DHEQ P Pressure test 7" casing to 3500 psi for 30 minutes -bleed off and blow down lines 13:15 14:00 0.75 0 0 INTRM1 CASIN( RURD P Ld casing elevators and landing joint - ull thin wall wear bushin 14:00 14:30 0.50 0 0 INTRM1 CASIN( DHEQ P Install and test packoff to 5000 psi - 10 minutes 14:30 17:00 2.50 0 0 INTRM1 WELCT OTHR P Changed top pipe rams to 3 1/2" X 6" VBR's -install test plug -test top rams to 250/5000 psi - LD test plug - installwear bushing in wellhead - LD casing bails and PU drilling bails while than in i e rams 17:00 21:15 4.25 0 375 INTRM1 DRILL PULD P Picked up components and made up GeoPilot BHA. 21:15 22:00 0.75 375 375 INTRM1 DRILL DHEQ P Tested Geo Span and shallow tested MWD. Pulse weak, MWD suggested retest - 2000'. 22:00 00:00 2.00 375 1,805 INTRM1 DRILL PULD P RIH with BHA picking up DP to 1,805'. 11/24/2006 00:00 00:30 0.50. 1,805 2,277 INTRM1 DRILL TRIP P RIH picking up 4"drill pipe from 1805' to 2277' 00:30 01:15 0.75 2,277 2,277 INTRM1 DRILL OTHR P Shallow test tools -blow down top drive 01:15 03:45 2.50 2,277 5,518 INTRM1 DRILL TRIP P Continue to RIH picking up 4"drill pipe from 2277' to 5518' 03:45 04:45 1.00 5,518 7,423 INTRM1 DRILL TRIP P RIH from 5518' to 7423' 04:45 05:30 0.75 7,423 7,423 INTRM1 RIGMN SVRG P Service Rig: Top Drive , Drawworks, crown - ad'usts brakes 05:30 07:15 1.75 7,423 7,641 INTRM1 DRILL REAM P Wash and ream from 7423' to 7557' - drill out cement from 7557' to 7641' 07:15 12:00 4.75 7,641 7,644 INTRM1 CEME~ DRLG P Drill wiper plugs and float collar from 7641' to 7644' - 220 gpm / 1040 psi - WOB 4-12K - 40-70 r m 12:00 15:00 3.00 7,644 7,757 INTRM1 CEME~ DRLG P Continue drilling shoe track to 7,727'. Cleaned out rat hole to 7,737'. Drilled 20' of new hole to 7,757'. 15:00 15:45 0.75 7,757 7,757 INTRM1 CEME~ CIRC P CBU. 15:45 16:30 0.75 7,757 7,757 INTRMI CEME~ FIT P Rigged up and did FIT to 12.5 PPG EMW. 16:30 00:00 7.50 7,757 8,130 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 7,757' to 8,130' MD 6,224' TVD ADT - 5.7 hrs ECD - 10.3 ppg WOB 10/12 RPM 130 GPM 220 1420 psi String wt. PU 180 SO 140 Rot 165 Torque on/off btm. - 9000/8000 ft/Ibs Note -Changed over to 9.2 ppg Flow Pro mud while drillin 1st std after FIT. ~ ~ F'~g~ esff 13 • Time Logs ~ I Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/25/2006 00:00 12:00 12.00 8,130 8,854 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 8,130' to 8,854' MD 6,252' ND ADT - 9.56 hrs ECD - 10.4 ppg WOB 10/12 RPM 130 GPM 220 1530 psi String wt. PU 190 SO 140 Rot 164 Tor ue on/off btm. - 10,000/8,500 ft/Ibs 12:00 00:00 12.00 8,854 9,530 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 8,854' to 9,530' MD 6,230' ND ADT - 9.57 hrs ECD - 10.4 ppg WOB 10/12 RPM 120 GPM 220 1530 psi String wt. PU 190 SO 135 Rot 165 Tor ue on/off btm. - 10,500/8,500 ft/Ibs 11/26/2006 00:00 12:00 12.00 9,530 10,385 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 9,530' to 10,385' MD 6,211' ND ADT - 9.32 hrs ECD - 10.6 ppg WOB 10/12 RPM 120 GPM 220 1630 psi String wt. PU 197 SO 127 Rot 162 Torque on/off btm. - 11,500/10,000 ft/Ibs 12:00 00:00 12.00 10,385 11,200 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 10,385' to 11,200' MD 6,250' ND ADT - 9.39 hrs ECD - 10.7 ppg WOB 10!12 RPM 120 GPM 220 1650 psi String wt. PU 200 SO 125 Rot 165 Tor ue on/off btm. - 11,000/9,500 ft/Ibs 11/27/2006 00:00 12:00 12.00 11,200 11,869 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,200' to 11,869' MD 6,212' ND ADT - 9.54 hrs ECD - 10.7 ppg WOB 10/12 RPM 120 GPM 220 1760 psi String wt. PU 207 SO 123 Rot 162 Torque on/off btm. - 12,000/11,000 ft/Ibs 12:00 13:30 1.50 11,869 11,952 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,869' to 11,952' MD 6,206' ND ADT - 1.16 hrs ECD - 10.7 ppg WOB 10/12 RPM 120 GPM 220 1760 psi String wt. PU 205 SO 115 Rot 165 Torque on/off btm. - 12,000/10,500 ft/Ibs 13:30 15:15 1.75 11,952 11,806 PROD1 DRILL CIRC T Circulated and trouble shoot Geo-Pilot. 220 GPM 120 RPM 1760 PSI. Stood back 1 stand every 20 min. Geo-Pilot not res ondin correct! . 15:15 00:00 8.75 11,806 7,042 PROD1 DRILL TRIP T POOH with pump from 11,806' to 7,042'. 220 GPM 1710 PSI 80 RPM. Flow checked well. Static. Blew down To Drive. 11/28/2006 00:00 06:45 6.75 7,042 190 PROD1 DRILL TRIP T POOH on trip tank from 7,042' to 190'. 06:45 07:45 1.00 190 0 PROD1 DRILL TRIP T Stood back Flex collars and downloaded MWD. --- Page 9 of 13 ~ ~~ Time Logs __ Date From To Dur S De th E De th Pha e Code Subcode T COM _~_ 12/01/2006 00:00 12:00 12.00 14,148 14,327 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 14,148 to 14,327' MD 6218' ND. ADT - 9.74 hrs ECD - 11.01 ppg WOB 10/12 RPM 120 GPM 220 @ 2280 psi String wt. PU 218 SO 114 Rot 160 Torque on/off btm. - 11,500/10,000 ft/Ibs 12:00 13:00 1.00 14,327 14,379 PROD1 DRILL DDRL P Dril16 1/8" hole w/GP f/ 14,327' to 14, 379' M D. 6218' ND. ECD - 11.05 WOB 10/12 RPM 120 GPM 220 @ 2260 si 13:00 16:15 3.25 14,379 14,379 PROD1 DRILL CIRC P Rotate pipe & backream, Circulate 3 BU's. Wt up mud to 9.6 ppg. Observe well -static. 16:15 00:00 7.75 14,379 10,092 PROD1 DRILL TRIP P Pump out of hole f/ 14,379' to 10,092'. 47 SPM @ 1940 psi. RPM 80. 20 K over ull on stands 4 & 5. 12/02/2006 00:00 04:15 4.25 10,092 7,710 PROD1 DRILL TRIP P Continue POOH from 10,092' to the shoe at 7710' with pump - 200 GPM - 80 RPM. Drop Rabbit for drift. Proper displacement -Monitor well 15 min - static. 04:15 05:45 1.50 7,710 7,710 PROD1 DRILL CIRC P Circulate 35 BBLS spacer and displace with 9.6 ppg Brine - 220 GPM @ 1120 psi. Brine to surface -Monitor well -static. 05:45 10:00 4.25 7,710 375 PROD1 DRILL TRIP P Blow do TD. Continue POOH on trip tank from 7,710' to BHA. 10:00 12:00 2.00 375 0 PROD1 DRILL PULD P Std back 2 stands HWDP, UD Flex collars -Download MWD - Service GP and break off bit - LD GP &MWD. 12:00 12:30 0.50 0 0 COMPZ WELCT OTHR P Pull Wear Ring, RU to test BOPE. 12:30 21:00 8.50 0 0 COMPZ WELCT BOPE P Tested annular 250/3500 psi. Test choke manifold vlvs, top, btm, and blind rams, HCR-kill & choke, man. kill, choke, floor safety vlv, dart vlv. Auto IBP & man. tested to 250/5000 psi. Tested pipe rams w/ 3 1/2" - 4" - 4 1/2" Pipe. Install Wearbushin . 21:00 21:30 0.50 0 0 COMPZ CASINC RURD P RU to run 3 1/2" liner. Held PJSM with crew. 21:30 00:00 2.50 0 1,988 COMPZ CASIN( RUNL P RIH w/ 3 1/2" 9.3# L-80 SLHT Blank and Slotted liner to 1,988'. Spirolizer centralizers on blank 'ts Jts 2 &3 . 12/03/2006 00:00 04:00 4.00 1,988 6,782 COMPZ CASIN( RNCS P Continue running 3 1/2" blank/slotted liner from 1,988' to 6,782'. 04:00 05:30 1.50 6,782 6,782 COMPZ CASIN( RUNL P Made up liner hanger. Mix and spot al mix in settin tool. 05:30 10:30 5.00 6,782 14,375 COMPZ CASIN( RUNL P RIH with liner on 4" DP from 6782' to 14,379'. Establish circulation, pump DPV of 30 bbls. Tagged bottom and set liner on de th 14,375'. ~a~ 1 °! of 13 i Time Logs _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 12/03/2006 10:30 ~ 11:00 0.50 14,375 7,549 COMPZ CASIN( _ RUNL _ P Dropped ball and pumped down. Set liner with 4,000 psi. Slacked off to 80,000 Lbs to check set - OK. Pulled out of liner. TOL 7,549'. 11:00 12:00 1.00 7,549 7,549 COMPZ CASIN( CIRC P CBU @ 50 SPM, 500 psi. Flow check well -static. 12:00 16:30 4.50 7,549 0 COMPZ CASIN( OTHR P POOH with liner running tool and lay down Baker runnin tool. 16:30 18:00 1.50 0 0 COMPZ RPCOh RURD P Pull wear ring. RU to run upper completion -bring VlTequip onto rig floor. 18:00 18:30 0.50 0 0 COMPZ RPCOR SFTY P PJSM to run completion - VIT tbg and hardware. 18:30 00:00 5.50 0 3,472 COMPZ RPCOC` RCST P Run upper completion as follows: Baker fluted shear indicating WLEG assembly, pup w/fluted No-GO - 17 jts 3 1/2" 9.3# EUE tbg - XN Npl - 4 jts 3 1/2" tbg -Baker Premier Packer assembly - 2 jts 3 1/2" tbg -Camco KBMG 3 1/2" GLM w/Dummy - 87 jts 4 1/2" tbg -Camco KBMG 3 1/2"GLM w/Dummy. (111 jts total of 3 1/2" EUE. 12/04/2006 00:00 07:00 7.00 3,472 5,407 COMPZ RPCOh RCST P Continue RIH with upper completion: 59 jts of 3 1/2" x 4 1/2" VI Tbg (w/ red clamps) - XO -Camco TRMAXX-5E SSSV. PU Camco completion tools, MU CL t/SSSV. Test & hold for 6000 psi, Band line w/tb . 07:00 16:00 9.00 5,407 7,565 COMPZ RPCOR RCST P Continue RIH with: XO - 67 jts of 3 1/2" x 4 1/2" VT Tbg (w/green clamps) -One 5.8' space out pup - XO - 9.83' 4 1/2" Tbg -FMC tbg hanger Spaced out 3.36' above liner top - Landed tbg on hanger w/ tbg tail @ 7565' - XN Npl @ 7005' - PKR @ 6864' -GLM#2@4045'-GLM#1 @2148'- SSSV @ 2148'. (126 jts total of VIT.) MU CL test U5000 si. 16:00 18:00 2.00 7,565 7,565 COMPZ RPCOA RURD P LD Tbg Equip. Clear Floor. CO Landing jts. FMC installed 2-way check; Test Tbg hanger seals t/ 5000 si. 18:00 19:30 1.50 COMPZ RPCOh OTHR P ND BOPE - CO SVR Sub t/5" 19:30 22:00 2.50 COMPZ RPCOA OTHR P NU Tree & Test t/ 5000 psi. Pull TWC. 22:00 00:00 2.00 COMPZ RPCOh SFTY P RU for displacement. PJSM to review um in schedule. 12/05/2006 00:00 01:30 1.50 COMPZ RPCOh CIRC P Dowell pumped 3 bbls of water and PT lines and equipment to 2000 psi. Circulate 128 BBLS of inhibited brine followed by 106 BBLS of diesel. Maintained 1:1 on the choke. Final ressure was - 800 si. s ~ Page 1 ~ ~f 13 Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T __ COM _ 12/05/2006 01:30 02:30 1.00 COMPZ RPCOh PACK RU Lubricator and drop packer setting rod/ball assembly. Pressure test lines to 5000 psi. Pressure up on tbg to 4800 si to set acker. Good set. 02:30 04:00 1.50 COMPZ RPCOR Bleed tubing pressure to 3500 psi & monitor for 30 minutes. Good test. Bleed tbg pressure to 1300 psi. PU IA to 3500 psi. Intial T/I = 1500/3600 psi. 30 min test = 1700/3555 psi. Good test. Bleed IA to 0 psi. Final Tbg = 800 psi. SI well. Blow down hardline & manifold. RD. 04:00 06:00 2.00 COMPZ RPCOh RU FMC Lubricator and set BPV - RD & Secure well. Pre ri for move. 06:00 14:30 8.50 COMPZ RPCOh Lay down excess 4" DP for rig move. 14:30 14:30 0.00 COMPZ RPCOh Rig Released to CD4-315 at 14:30 hours. ~az~ 13 of 13 • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. ______ Date: 1 212 1 /2 006 'Time: 08:34:26 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Wekl: CD4-211; True North - Site: Alpine CD4 V"ertical (TVD) Reference: CD4-211: 56.4' Well: CD4-211 Section (VS) Reference: Well (O.OON,O.OOE,171.21Azi) Wellpath: CD4-211 Survey Calculation ilethod: ____ Minimum Curvature ~ Db: Oracle _ ___ __ i Field: Colville 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 System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD4-211 Slot Name: Alpine CD4 Well Position: +N/-S -49.46 ft Northing: 5957479.79 ft Latitude: 70 17 32.479 N +E/-W -193.70 ft Easting : 377980.24 ft Longitude: 150 59 16.408 W Position Uncertainty: 0.00 ft Wellpath: CD4-211 Drilled From: Well Ref. Point ~ 501032053800 Tie-on Depth: 36.40 ft Current Datum: CD4-211: Height 56.40 ft Above System Datum: Mean Sea Level '~ Magnetic Data: 11/10/2006 Declination: 22.99 deg Field Strength: 57552 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.40 0.00 0.00 171.21 Survey Program for Definitive Wellpath Date: 12/21/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 74.00 622.00 CD4-211 gyro (74.00-622.00) CB-GYRO-SS Camera based gyro single shot 746.59 14341.16 CD4-211 (746.59-14341.16) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey '•tD ft - ---- 36.40 74.00 ~ 168.00 it 256.00 350.00 ~I 442.00 533.00 622.00 746.59 839.60 ', 934.69 1029.82 1125.03 1220.36 1315.53 1411.10 1505.97 1601.21 1696.47 1791.31 1886.68 1981.94 2077.30 2173.16 2268.61 2364.26 2459.88 2502.94 2600.84 [ncl Azim TVD Sys TVD deg deg ft ft 0.00 0.00 36.40 -20.00 0.40 316.00 74.00 17.60 0.60 300.00 168.00 111.60 1.00 324.00 255.99 199.59 1.70 352.00 349.96 293.56 2.25 10.00 441.91 385.51 3.10 0.00 532.81 476.41 4.25 2.00 621.62 565.22 5.92 353.69 745.72 689.32 6.38 352.94 838.20 781.80 8.64 340.08 932.47 876.07 10.68 327.56 1026.26 969.86 11.77 311.99 1119.67 1063.27 16.06 296.26 1212.21 1155.81 18.90 284.95 1303.00 1246.60 19.91 269.01 1393.20 1336.80 22.52 261.15 1481.66 1425.26 24.94 259.95 1568.84 1512.44 27.92 259.67 1654.13 1597.73 30.05 260.18 1737.09 1680.69 30.93 259.79 1819.27 1762.87 30.54 259.34 1901.15 1844.75 31.30 260.01 1982.96 1926.56 29.14 256.00 2065.79 2009.39 30.14 257.30 2148.75 2092.35 26.94 256.68 2232.77 2176.37 26.50 257.48 2318.18 2261.78 27.31 258.01 2356.58 2300.18 28.30 259.51 2443.17 2386.77 N/S E!W MapN ft ft ft 0 .00 0 .00 ___-- 5957479. 79 0 .09 -0 .09 5957479. 89 0 .58 -0 .75 5957480. 38 1 .43 -1 .60 5957481. 24 3 .47 -2 .27 5957483. 30 6 .60 -2 .15 5957486. 43 10 .82 -1 .84 5957490. 64 16 .52 -1 .72 5957496. 34 27 .53 -2 .27 5957507. 35 37 .42 -3 .43 5957517. 26 49 .38 -6 .51 5957529. 27 63 .54 -13 .68 5957543. 54 77 .49 -25 .63 5957557. 68 89 .84 -44 .70 5957570. 33 99 .64 -71 .41 5957580. 57 103 .36 -102 .66 5957584. 79 100 .28 -136 .77 5957582. 27 93 .97 -174 .57 5957576. 57 86 .47 -216 .30 5957569. 75 78 .43 -261 .55 5957562. 45 70 .02 -309 .20 5957554. 81 61 .20 -357 .08 5957546. 77 52 .42 -405 .28 5957538. 78 42 .45 -452 .46 5957529. 58 31 .56 -498 .39 5957519. 43 21 .29 -542 .91 5957509. 88 11 .67 -584 .82 5957500. 95 7 .54 -603 .86 5957497. 13 -1 .35 -648 .65 5957488. 97 YIapF. Tool ft 377980.24 TIE LINE 377980.15 CB-GYRO-SS 377979.50 CB-GYRO-SS 377978.67 CB-GYRO-SS 377978.02 CB-GYRO-SS 377978.20 CB-GYRO-SS 377978.58 CB-GYRO-SS 377978.79 CB-GYRO-SS 377978.42 MWD+IFR-AK-CAZ-SC 377977.42 MWD+IFR-AK-CAZ-SC 377974.53 MWD+IFR-AK-CAZ-SC 377967.60 MWD+IFR-AK-CAZ-SC 377955.87 MWD+IFR-AK-CAZ-SC 377937.01 MWD+IFR-AK-CAZ-SC 377910.46 MWD+IFR-AK-CAZ-SC 377879.28 MWD+IFR-AK-CAZ-SC 377845.12 MWD+IFR-AK-CAZ-SC 377807.23 MWD+IFR-AK-CAZ-SC 377765.39 MWD+IFR-AK-CAZ-SC 377720.02 MWD+IFR-AK-CAZ-SC 377672.25 MWD+IFR-AK-CAZ-SC 377624.23 MWD+IFR-AK-CAZ-SC 377575.90 MWD+IFR-AK-CAZ-SC 377528.56 MWD+IFR-AK-CAZ-SC 377482.47 MWD+IFR-AK-CAZ-SC 377437.79 MWD+IFR-AK-CAZ-SC 377395.74 MWD+IFR-AK-CAZ-SC 377376.64 MWD+IFR-AK-CAZ-SC 377331.71 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConacoPhillips Alaska Inc. llate: 12/21/2006 Time: 08:34:26 Page: 2 Field: Colville River Unit Co-ordinaCe(NF.) Reference: Well: CD4-211, True North Site: Alpine CD4 Vertical (1'VD) Reference: CD4-211: 56.4 Well: CD4-211 Section (VS) Reference: Well (O.OON,O.OOE,171.21Azi) Wellpath: CD4-211 Survey Calculation Method: Minimum Curvature Db: Oracfe Survey SID Incl Azim TVD Svs T~'D N/S ElW Map~i h1apE Teul ft deg deg ft ~ ft ft ft ft ft 2695.37 27.11 258.59 2526.86 2470.46 -9.69 -691.79 5957481.33 377288.44 MWD+IFR-AK-CAZ-SC 2789.76 26.03 258.55 2611.28 2554.88 -18.06 -733.18 5957473.63 377246.93 MWD+IFR-AK-CAZ-SC 2884.99 25.91 260.59 2696.90 2640.50 -25.61 -774.18 5957466.75 377205.81 MWD+IFR-AK-CAZ-SC 2978.87 26.11 262.83 2781.27 2724.87 -31.54 -814.91 5957461.48 377164.99 MWD+IFR-AK-CAZ-SC 3075.10 25.72 265.05 2867.83 2811.43 -35.99 -856.73 5957457.72 377123.11 MWD+IFR-AK-CAZ-SC 3171.56 26.43 268.33 2954.48 2898.08 -38.42 -899.04 5957455.97 377080.77 MWD+IFR-AK-CAZ-SC ~ 3266.84 25.77 267.89 3040.04 2983.64 -39.80 -940.94 5957455.27 377038.86 MWD+IFR-AK-CAZ-SC 3362.38 25.17 268.22 3126.29 3069.89 -41.20 -982.00 5957454.54 376997.79 MWD+IFR-AK-CAZ-SC 3457.41 24.65 267.90 3212.48 3156.08 -42.55 -1022.00 5957453.84 376957.77 MWD+IFR-AK-CAZ-SC 3552.89 24.12 267.25 3299.44 3243.04 -44.21 -1061.38 5957452.81 376918.37 MWD+IFR-AK-CAZ-SC 3648.05 23.92 267.85 3386.36 3329.96 -45.87 -1100.08 5957451.78 376879.65 MWD+IFR-AK-CAZ-SC 3743.46 23.37 267.53 3473.76 3417.36 -47.41 -1138.32 5957450.86 376841.40 MWD+IFR-AK-CAZ-SC 3839.10 23.92 269.71 3561.38 3504.98 -48.33 -1176.66 5957450.57 376803.05 MWD+IFR-AK-CAZ-SC 3934.38 23.42 270.47 3648.64 3592.24 -48.27 -1214.91 5957451.25 376764.81 MWD+IFR-AK-CAZ-SC 4029.67 22.41 271.02 3736.41 3680.01 -47.79 -1252.01 5957452.33 376727.72 MWD+IFR-AK-CAZ-SC 4124.40 23.14 270.53 3823.75 3767.35 -47.30 -1288.68 5957453.42 376691.07 MWD+IFR-AK-CAZ-SC 4219.98 25.01 268.83 3911.02 3854.62 -47.54 -1327.66 5957453.81 376652.09 MWD+IFR-AK-CAZ-SC ~ 4314.88 26.43 264.88 3996.52 3940.12 -49.83 -1368.76 5957452.18 376610.97 MWD+IFR-AK-CAZ-SC 4409.94 28.04 262.46 4081.04 4024.64 -54.65 -1411.98 5957448.07 376567.67 MWD+IFR-AK-CAZ-SC 4504.95 30.21 262.52 4164.03 4107.63 -60.69 -1457.83 5957442.77 376521.74 MWD+IFR-AK-CAZ-SC j 4599.88 31.16 261.68 4245.67 4189.27 -67.36 -1505.81 5957436.89 376473.66 MWD+IFR-AK-CAZ-SC ~~ 4695.11 32.07 259.49 4326.77 4270.37 -75.54 -1555.05 5957429.51 376424.30 MWD+IFR-AK-CAZ-SC 4790.71 33.41 261.62 4407.18 4350.78 -84.00 -1606.04 5957421.87 376373.18 MWD+IFR-AK-CAZ-SC 4885.79 33.47 259.57 4486.52 4430.12 -92.56 -1657.73 5957414.15 376321.37 MWD+IFR-AK-CAZ-SC 4982.29 34.56 257.83 4566.51 4510.11 -103.15 -1710.66 5957404.43 376268.28 MWD+IFR-AK-CAZ-SC 5077.47 34.38 254.77 4644.99 4588.59 -115.90 -1762.98 5957392.53 376215.76 MWD+IFR-AK-CAZ-SC 5172.77 34.56 249.45 4723.57 4667.17 -132.46 -1814.26 5957376.80 376164.22 MWD+IFR-AK-CAZ-SC 5267.79 34.66 245.81 4801.79 4745.39 -153.00 -1864.15 5957357.08 376114.00 MWD+IFR-AK-CAZ-SC 5362.82 35.48 241.79 4879.57 4823.17 -177.11 -1913.11 5957333.77 376064.66 MWD+IFR-AK-CAZ-SC 5457.99 35.86 236.54 4956.91 4900.51 -205.54 -1960.72 5957306.12 376016.61 MWD+IFR-AK-CAZ-SC 5554.35 36.64 234.02 5034.62 4978.22 -238.00 -2007.54 5957274.43 375969.27 MWD+IFR-AK-CAZ-SC 5649.84 37.07 230.13 5111.04 5054.64 -273.19 -2052.69 5957239.97 375923.56 MWD+IFR-AK-CAZ-SC 5744.75 37.34 225.86 5186.64 5130.24 -311.58 -2095.31 5957202.28 375880.33 MWD+IFR-AK-CAZ-SC 5840.26 37.82 222.42 5262.34 5205.94 -353.38 -2135.85 5957161.16 375839.11 MWD+IFR-AK-CAZ-SC 5935.45 39.15 217.96 5336.87 5280.47 -398.62 -2174.03 5957116.54 375800.21 MWD+IFR-AK-CAZ-SC 6030.77 40.69 213.87 5409.98 5353.58 -448.16 -2209.86 5957067.59 375763.58 MWD+IFR-AK-CAZ-SC 6125.65 41.75 209.16 5481.37 5424.97 -501.44 -2242.50 5957014.85 375730.08 MWD+IFR-AK-CAZ-SC 6221.18 43.21 204.45 5551.84 5495.44 -559.00 -2271.55 5956957.77 375700.11 MWD+IFR-AK-CAZ-SC 6316.12 45.13 201.42 5619.94 5563.54 -619.92 -2297.29 5956897.29 375673.38 MWD+IFR-AK-CAZ-SC ~ 6394.84 49.16 193.46 5673.52 5617.12 -674.92 -2314.43 5956842.58 375655.35 .MWD+IFR-AK-CAZ-SC 6490.04 51.01 186.74 5734.64 5678.24 -746.74 -2327.16 5956770.98 375641.46 MWD+IFR-AK-CAZ-SC 6585.49 52.33 179.97 5793.88 5737.48 -821.41 -2331.50 5956696.40 375635.91 MWD+IFR-AK-CAZ-SC Ili 6680.74 54.43 173.58 5850.73 5794.33 -897.66 -2327.15 5956620.09 375639.02 MWD+IFR-AK-CAZ-SC 6776.05 55.82 167.02 5905.27 5848.87 -974.66 -2313.95 5956542.90 375650.97 MWD+IFR-AK-CAZ-SC 6871.13 57.55 160.85 5957.52 5901.12 -1050.94 -2291.94 5956466.28 375671.74 MWD+IFR-AK-CAZ-SC 6966.71 59.29 155.06 6007.61 5951.21 -1126.34 -2261.36 5956390.39 375701.08 MWD+IFR-AK-CAZ-SC 7061.92 63.06 151.18 6053.52 5997.12 -1200.68 -2223.62 5956315.45 375737.61 MWD+IFR-AK-CAZ-SC 7156.87 67.68 149.92 6093.08 6036.68 -1275.81 -2181.18 5956239.65 375778.82 MWD+IFR-AK-CAZ-SC 7252.25 71.05 150.06 6126.69 6070.29 -1353.10 -2136.54 5956161.66 375822.19 MWD+IFR-AK-CAZ-SC 7347.30 74.99 150.43 6154.44 6098.04 -1432.00 -2091.44 5956082.04 375866.01 MWD+IFR-AK-CAZ-SC 7442.61 76.44 150.68 6177.95 6121.55 -1512.43 -2046.04 5956000.89 375910.10 MWD+IFR-AK-CAZ-SC 7537.51 81.87 151.27 6195.80 6139.40 -1593.90 -2000.83 5955918.70 375953.97 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 12/21/2006 Time: 08:34:26 Page: 3 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD4-211, True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-211: 56.4 Nell: CD4-211 Section (VS) Reference: Well (O.OON,O.OOE,171.21Azi} Wellpath: CD4-211 Survey Cakulation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD NIS E/~V MapN MapE Tool ft deg deg ft ft ft ft ft ft 7632.93 84.58 146.93 6207.06 6150.66 -1675.18 -1952.18 5955836.66 376001.29 MWD+IFR-AK-CAZ-SC ', 7702.33 86.91 147.06 6212.21 6155.81 -1733.21 -1914.49 5955778.02 376038.03 MWD+IFR-AK-CAZ-SC 7768.48 89.87 144.34 6214.07 6157.67 -1787.83 -1877.23 5955722.82 376074.40 MWD+IFR-AK-CAZ-SC 7853.29 88.70 144.57 6215.13 6158.73 -1856.82 -1827.93 5955653.03 376122.56 MWD+IFR-AK-CAZ-SC 7959.11 88.82 144.76 6217.42 6161.02 -1943.13 -1766.74 5955565.75 376182.34 MWD+IFR-AK-CAZ-SC 8054.32 87.40 146.82 6220.56 6164.16 -2021.82 -1713.25 5955486.21 376234.55 MWD+IFR-AK-CAZ-SC 8149.31 88.08 148.84 6224.31 6167.91 -2102.16 -1662.71 5955405.07 376283.76 MWD+IFR-AK-CAZ-SC ~~ 8244.57 88.76 150.74 6226.93 6170.53 -2184.44 -1614.80 5955322.02 376330.33 MWD+IFR-AK-CAZ-SC i 8340.09 87.47 149.74 6230.08 6173.68 -2267.32 -1567.42 5955238.40 376376.36 MWD+IFR-AK-CAZ-SC 8435.32 88.27 147.59 6233.62 6177.22 -2348.60 -1517.93 5955156.33 376424.52 MWD+IFR-AK-CAZ-SC 8530.50 87.09 146.35 6237.47 6181.07 -2428.33 -1466.10 5955075.78 376475.05 MWD+IFR-AK-CAZ-SC 8625.93 87.84 144.78 6241.69 6185.29 -2506.95 -1412.19 5954996.29 376527.67 MWD+IFR-AK-CAZ-SC 8721.21 87.28 145.94 6245.75 6189.35 -2585.27 -1358.08 5954917.12 376580.49 MWD+IFR-AK-CAZ-SC ': 8814.44 88.52 145.25 6249.16 6192.76 -2662.14 -1305.44 5954839.41 376631.88 MWD+IFR-AK-CAZ-SC 8912.40 89.69 146.32 6250.69 6194.29 -2743.13 -1250.36 5954757.54 376685.62 MWD+IFR-AK-CAZ-SC 9007.66 90.31 149.67 6250.69 6194.29 -2823.90 -1199.88 5954675.97 376734.78 MWD+IFR-AK-CAZ-SC 9103.36 92.71 155.00 6248.17 6191.77 -2908.59 -1155.48 5954590.58 376777.80 MWD+IFR-AK-CAZ-SC 9197.88 92.45 159.51 6243.91 6187.51 -2995.65 -1118.98 5954502.94 376812.88 MWD+IFR-AK-CAZ-SC 9291.61 91.91 159.78 6240.35 6183.95 -3083.47 -1086.41 5954414.62 376844.02 MWD+IFR-AK-CAZ-SC 9388.46 92.96 158.07 6236.23 6179.83 -3173.75 -1051.61 5954323.79 376877.34 MWD+IFR-AK-CAZ-SC 9483.96 92.04 154.26 6232.06 6175.66 -3261.01 -1013.06 5954235.93 376914.47 MWD+tFR-AK-CAZ-SC 9575.07 92.16 153.88 6228.73 6172.33 -3342.89 -973.25 5954153.42 376952.94 MWD+IFR-AK-CAZ-SC 9674.47 92.53 153.24 6224.66 6168.26 -3431.82 -929.03 5954063.79 376995.71 MWD+IFR-AK-CAZ-SC 9765.64 92.34 152.49 6220.79 6164.39 -3512.88 -887.49 5953982.07 377035.93 MWD+IFR-AK-CAZ-SC I 9864.99 91.79 154.04 6217.21 6160.81 -3601.55 -842.82 5953892.70 377079.14 MWD+IFR-AK-CAZ-SC 9959.96 92.65 151.55 6213.53 6157.13 -3685.94 -799.44 5953807.62 377121.15 MWD+IFR-AK-CAZ-SC 10055.50 92.22 151.56 6209.47 6153.07 -3769.87 -753.98 5953722.97 377165.24 MWD+IFR-AK-CAZ-SC 10150.85 91.05 152.18 6206.75 6150.35 -3853.92 -709.04 5953638.21 377208.80 MWD+IFR-AK-CAZ-SC 10246.37 88.82 154.46 6206.85 6150.45 -3939.26 -666.16 5953552.19 377250.29 MWD+IFR-AK-CAZ-SC 10341.69 87.96 156.61 6209.53 6153.13 -4025.98 -626.70 5953464.85 377288.33- MWD+IFR-AK-CAZ-SC 10437.29 86.85 156.75 6213.86 6157.46 -4113.68 -588.89 5953376.55 377324.71 MWD+IFR-AK-CAZ-SC 10532.50 85.55 156.25 6220.17 6163.77 -4200.80 -551.01 5953288.84 377361.16 MWD+IFR-AK-CAZ-SC 10627.81 86.60 156.57 6226.70 6170.30 -4287.94 -512.96 5953201.10 377397.79 MWD+IFR-AK-CAZ-SC 10723.02 87.46 154.93 6231.63 6175.23 -4374.63 -473.91 5953113.80 377435.43 MWD+IFR-AK-CAZ-SC 10818.27 86.29 152.42 6236.82 6180.42 -4459.86 -431.74 5953027.89 377476.21 MWD+IFR-AK-CAZ-SC 10913.41 85.74 151.71 6243.43 6187.03 -4543.71 -387.28 5952943.34 377519.30 MWD+IFR-AK-CAZ-SC 11008.56 86.60 153.09 6249.79 6193.39 -4627.84 -343.29 5952858.51 377561.91 MWD+IFR-AK-CAZ-SC 11103.75 90.12 156.17 6252.51 6196.11 -4713.80 -302.54 5952771.92 377601.26 MWD+IFR-AK-CAZ-SC 11198.64 93.95 156.60 6249.15 6192.75 -4800.67 -264.56 5952684.45 377637.82 MWD+IFR-AK-CAZ-SC i 11293.78 94.01 156.18 6242.54 6186.14 -4887.63 -226.55 5952596.88 377674.41 MWD+IFR-AK-CAZ-SC 11388.93 93.83 154.16 6236.04 6179.64 -4973.78 -186.69 5952510.11 377712.87 MWD+IFR-AK-CAZ-SC 11484.03 93.95 153.50 6229.58 6173.18 -5058.94 -144.84 5952424.29 377753.32 MWD+IFR-AK-CAZ-SC 11579.14 93.15 152.67 6223.70 6167.30 -5143.58 -101.87 5952338.97 377794.91 MWD+IFR-AK-CAZ-SC 11673.27 91.97 150.99 6219.49 6163.09 -5226.47 -57.48 5952255.37 377837.95 MWD+IFR-AK-CAZ-SC 11769.29 92.09 151.39 6216.09 6159.69 -5310.55 -11.23 5952170.56 377882.82 MWD+IFR-AK-CAZ-SC 11862.87 92.65 152.09 6212.22 6155.82 -5392.91 33.04 5952087.50 377925.74 MWD+IFR-AK-CAZ-SC 11960.28 92.90 153.26 6207.50 6151.10 -5479.35 77.70 5952000.36 377968.99 MWD+IFR-AK-CAZ-SC 12055.87 88.14 152.95 6206.64 6150.24 -5564.57 120.92 5951914.45 378010.82 MWD+IFR-AK-CAZ-SC 12151.04 87.10 153.81 6210.59 6154.19 -5649.58 163.53 5951828.77 378052.04 MWD+IFR-AK-CAZ-SC 12245.92 88.21 155.94 6214.47 6158.07 -5735.40 203.78 5951742.31 378090.89 MWD+IFR-AK-CAZ-SC 12340.66 88.70 154.15 6217.03 6160.63 -5821.26 243.73 5951655.82 378129.44 MWD+IFR-AK-CAZ-SC j 12436.33 87.84 153.42 6219.91 6163.51 -5907.05 285.97 5951569.37 378170.28 MWD+IFR-AK-CAZ-SC 12531.47 87.65 155.05 6223.66 6167.26 -5992.66 327.30 5951483.10 378210.20 MWD+IFR-AK-CAZ-SC N • Halliburton Company Survey Report r~ ~J Company: ConocoPhillips Alaska Inc. ' Field: Colville River Unit Site: Alpine CD4 Well: CD4-211 ' Wellpath: CD4-211 Survey __ Uate: 12!21/2006 Cime: 08:34:26 Page: -! Co-ordinate(NE) Reference: Well: CD4-211, True North ertical (TVD) Rcfcrcncr. CD4-211: 56.4 Section (VS)Keference: Well (O.OON,O.OOE,171.21Azi) Survey Calculation Method: Minimum Curvature Db: .Oracle MD 1nc1 - Azim _- TVD - Sys'FVD N/S E/yV MapN ft deg deg ft ft ft ft ft 12626. 67 88. 27 154.57 6227 .05 6170 .65 -6078 .75 367 .79 5951396. 37 12722. 03 88. 02 154.11 6230 .13 6173 .73 -6164 .66 409 .06 5951309. 81 12815. 75 88. 02 152.63 6233 .37 6176 .97 -6248 .39 451 .04 5951225. 42 12911. 33 87. 84 154.48 6236 .82 6180 .42 -6333 .91 493 .58 5951139. 23 13006. 32 88. 15 157.99 6240 .15 6183 .75 -6420 .78 531 .83 5951051. 76 13102. 73 88. 76 157.14 6242 .75 6186 .35 -6509 .86 568 .61 5950962. 10 13198. 14 87. 53 153.21 6245 .84 6189 .44 -6596 .39 608 .64 5950874. 94 13293. 55 87. 53 153.04 6249 .95 6193 .55 -6681 .41 651 .72 5950789. 24 13388. 93 90. 74 151.67 6251 .39 6194 .99 -6765 .88 695 .97 5950704. 07 13484. 26 92. 84 153.15 6248 .41 6192 .01 -6850 .32 740. 10 5950618. 93 13579. 57 92. 03 153.34 6244 .36 6187 .96 -6935 .35 782. 96 5950533. 22 13674. 56 91. 45 154.59 6241 .48 6185 .08 -7020 .66 824 .64 5950447. 25 13770. 08 91. 54 155.09 6238 .99 6182 .59 -7107 .09 865. 23 5950360. 19 ' 13866. 16 91. 29 154.56 6236 .61 6180 .21 -7194 .01 906 .09 5950272. 62 13962. 32 91. 35 156.11 6234 .40 6178 .00 -7281 .37 946 .21 5950184. 62 14056. 84 92. 04 153.94 6231 .60 6175 .20 -7367 .01 986 .09 5950098. 35 14152. 10 90. 98 154.18 6229 .09 6172 .69 -7452 .65 1027 .75 5950012. 07 14247. 31 92. 41 156.15 6226 .28 6169 .88 -7539 .01 1067 .72 5949925. 07 14341. 16 94. 94 156.64 6220 .26 6163 .86 -7624 .82 1105 .22 5949838. 67 14379. 00 94. 94 156.64 6217 .00 . 6160 .60 -7659 .43 1120 .17 5949803. 83 D1apE - - - - Tool ft __ 378249.29 _ MWD+IFR-AK-CAZ-SC 378289.16 MWD+IFR-AK-CAZ-SC 378329.77 MWD+IFR-AK-CAZ-SC 378370.91 MWD+IFR-AK-CAZ-SC 378407.74 MWD+IFR-AK-CAZ-SC 378443.07 MWD+IFR-AK-CAZ-SC 378481.68 MWD+IFR-AK-CAZ-SC 378523.38 MWD+IFR-AK-CAZ-SC 378566.25 MWD+IFR-AK-CAZ-SC 378608.99 MWD+IFR-AK-CAZ-SC 378650.47 MWD+IFR-AK-CAZ-SC 378690.75 MWD+IFR-AK-CAZ-SC 378729.93 MWD+IFR-AK-CAZ-SC 378769.37 MWD+IFR-AK-CAZ-SC 378808.06 MWD+IFR-AK-CAZ-SC 378846.55 MWD+IFR-AK-CAZ-SC 378886.81 MWD+IFR-AK-CAZ-SC 378925.37 MWD+IFR-AK-CAZ-SC 378961.47 MWD+IFR-AK-CAZ-SC 378975.85 ~ PROJECTED to TD ~onoco~'hi!!i~-~ Liner Detail 31/2" Slotted and Blank Line Well: CD4-211 Date: 11/30/2006 ~1FPTN Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Top of Liner Hanger @ 7548.43 Baker "HR" Liner Setting Sleeve 5.79 OD x 4.42 ID 13.00 7548.43 Baker "RS" Packoff Seal Nipple 5.60 OD x 4.25 ID 3.80 7561.43 Baker "DG" 5" x 7" Flex Lock Hanger 5.92 OD x 4.40 ID 9.53 7565.23 XO - 5" L-80 BTC x 4 1/2" L-80 SLHT 5.57 OD x 4.00 ID 1.95 7574.76 Pup - 41 /2", 12.6#, L-80, SLHT BLANK PIPE 3.76 7576.71 Pup - 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 9.74 7580.47 XO - 4 1/2" SLHT x 3 1/2"SLHT 1.74 7590.21 Jts 217 to 220 4 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 126.60 7591.95 Jts 207 to 216 10 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 298.35 7718.55 Jts 203 to 206 4 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 127.20 8016.90 Jts 202 to 202 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.85 8144.10 Jts 196 to 201 6 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 189.13 8174.95 Jts 193 to 195 3 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 90.45 8364.08 Jts 190 to 192 3 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 95.47 8454.53 Jts 188 to 189 2 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 60.72 8550.00 Jts 184 to 187 4 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 127.44 8610.72 Jts 179 to 183 5 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 151.68 8738.16 Jts 172 to 178 7 Jts 3-1 /2'°, 9.3#, L-80, SLHT BLANK PIPE 221.38 8889.84 Jts 169 to 171 3 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 91.04 9111.22 Jts 166 to 168 3 Jts 3-1/2", 9.3#, L-8o, SLHT BLANK PIPE 94.23 9202.26 Jts 163 to 165 3 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 88.70 9296.49 Jts 155 to 162 8 Jts 3-1/2", 9.3#, L-8o, SLHT-BLANK PIPE 249.48 9385.19 Jts 154 to 154 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.93 9634.67 Jts 151 to 153 3 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 94.09 9665.60 Jts 150 to 150 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 29.50 9759.69 Jts 146 to 149 4 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 125.16 9789.19 Jts 133 to 145 13 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 393.37 9914.35 Jts 129 to 132 4 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 127.40 10307.72 Jts 128 to 128 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.15 10435.12 Jts 120 to 127 8 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 249.85 10465.27 Jts 119 to 119 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.32 10715.12 Jts 116 to 118 3 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 95.65 10745.44 Jts 115 to 115 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.59 10841.09 Jts 109 to 114 6 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 186.96 10871.68 Jts 104 to 108 5 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 150.48 . 11058.64 Jts 98 to 103 6 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 187.78 41209.12 Jts 91 to 97 7 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 208.85 11396.90 Jts 82 to 90 9 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 279.24 11605.75 Jts 81 to 81 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 30.82 11884.99 Jts 60 to 80 21 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 659.57 11915.81 Jts 52 to 59 8 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 239.79 12575.38 Jts 50 to 51 2 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 61.76 12815.17 Jts 21 to 49 29 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 876.49 12876.93 Jts 14 to 20 7 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 215.00 13753.42 Jts 12 to 13 2 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 61.14 13968.42 Jts 2 to 11 10 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 312.97 14029.56 Jts 1 to 1 1 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 29.66 14342.53 Baker V set float shoe 5.05" OD 1.81 14372.19 4 1/2" liner shoe @ 14374.00 14374.00 TD of 6 1/8" hole = 14379.76 Run-NSeal pipe dope e R marks ; gip:V~.:::: K.; :::::.::..:::::.;:.:;.;:.;:.:;;.::.;;:;«<;;.;;;;:.;;;:.;:;.;:;<::<:::.:<.;;:;.:<.;:.:;;;.;;:.;:.;:.:.;:.;:.;:.;:.;:.;;:.;;:.;:.:;:.:; 51t ~rutsot's E,.:I~k111. E~,. V1tt~4~t5..:...: • LJ 29-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-211 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.40' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 14,379.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.AllenCHALLIBURTON.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 Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • ®~ ~~ Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99503 Re: Colville River Field, Nanuq Oil Pool, CD4-211 Sundry Number: 306-392 Dear Mr. Alvord: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to perior Court unless rehearing has been requested. ,., Orman DATED this day of December, 2006. Encl. ~~- X53 ,Z~ ~ ~ ~ ~~ TS J~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION iRE~~IVED Q ~ C 1 4 2006 ANNULAR DISPOSAL APPLICATION Alaska Oil & Gas Cans. Commission 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: Number: 206-153 ConocoPhillips Alaska 4. API Number: 50-103-20538-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-211 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: Nanuk 3, CD4-208, CD4-209, CD4-210, CD4-320, Torok and Seabee formation, shale, siltstone and sandstone - CD4-17, CD4-214 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation . None ~ c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier ° 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1636' MD / 1 600' TVD ~ None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2250 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- formation fluids associated with the completion fluids diesel contaminated drilling mud 16. Estimated start date: , , , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 1-Jan-07 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and an other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph 0 Surf. Casing Cementing Data ^~ Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the forego in and correct to the best of my knowledge. g is true j / ' Signature: - c--- °\ / \ Title: ,*~l+V ~J~1r ~~'~° ~~~-~' Printed Phone Name: Chip Alvord Number: 265-6120 Date: j L~(f (G Commi .ion Use Only Conditions of approval: yu~ ( LOT review and approval: ' ~'C t ~aR-® C Subsequent form required: i~ '- ~~ Approval number. <~~ APPROVED BY Approved by: MMISSIONER THE COMMISSION Date: /9 ~~ r (~ l~ BCD ti~ Z~ 06 Form 10-403RD Rev. 6/20 ~ I STRUCTIONS ON REVER ` ~~ ~ Submit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 11, 2006 ~ ~ ConocoPhillips Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 Alaska Oit ~ Gas Cans. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-211 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-211 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-211 approximately January 1, 2007 or whenever a permit is available. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form ~ 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job ~ 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells - I0. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: no new wells 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations Two annular leak off tests were performed. The initial annular LOT (11/23/06) was 18.4 ppg, and a subsequent annular LOT (11/25/06) was 15.0 ppg. The initial LOT pressure dropped more quickly than normal for this formation in this area, so a second test was performed indicating a much lower equivalent mud weight. An explanation for this is there could have been cement stringers as high as the surface casing shoe, due to the larger than normal cement volume pumped. A larger than normal intermediate cement volume was used to isolate the shallow Qannik (K2) formation. The second test occurred at a lower equivalent mud weight than the casing shoe test (18.1 ppg LOT). Therefore, we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Sin~re~fy, ~` ~ r z l~ ~-~/~ ~,~ Vern Johnson Drilling Engineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 cc: CD4-321 Well File Chip Alvord Anadarko Sharon Allsup-Drake ~ ConocoPhilli s P ATO-1700 ATO-1530 s Annulus Disaosal T AnGCC Reeulations_ 20 AAC 25.ORO (hl 211 1 Desi ation of the well or wells to receive drillin wastes: CD4-211 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = +/-1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from. 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 220 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-16, CD4-215, CD4-207, CD4-205, CD4-213, CD4-212, will be enerated. CD4-203 CD4-204 CD4-223, CD4-224, CD4-222 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm NIA containment of drillin waste. • • Well CD4-211 Date 12/8/2006 ./ Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas Litt) 1,000 psi ao e .y R U v, N a 2,391 TVD Version 1.0 - lan'05 Pburst85% -PHydrostatic +PApplied - PFormation 4,888 = ( 2,391 * 0.052 *MWmax ) + 1500 - ( 0.4337 * 2,391 ) MWmax = 35.6 ppg Surface Casing Strin Size 9.625 in Weight 40 ppf Grade L 80 rburst100% 5,750 Pst Pburst85% 4,888 Pst Depth of Shoe 2,391 ft FIT/LOT @ Shoe 18.1 ppg or 2,250 psi FIT/LOT for Annulus I S ppg Max Surf. Pressure 1,500 psi •~, TOC Est. @ 3,913' Ml U 3,629' TV 0 °o r Maximum Fluid Density avoid Collapse of 2nd CasinS String Pcollapse85% -PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 3,629 * 0.052 *MWmax ) + 1,500 - (0.0700 * 3,629) - 1,000 4.5 "Tubing ,6,213 TVD MWmax = 23.1 PPg 2nd Casing Strin Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 pst Pcollapse85% 4,599 pst Top of Cement 3,629 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 ps] Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax avowable = ( 2,391 * .052 * 18.1 ) Pmax allowable - 2,250 psi This is the va]ue for the Injection Permit "Maximum Anticipated Pressure at Shoe". • • ConocoPhilli 5 Casing Detail 9 5/8"Surface Casing Well: CD4-211 Date: 11 /17/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 37.00 FMC Gen V Hanger 2.35 37.00 Jts 3 to 65 63 Jts 9-5/8" 40# L-80 BTC Csg 2423.65 39.35 Halliburton Float Collar 1.12 2463.00 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 76.25 2464.12 Ray Oil Tools "Silver Bullet" Float Shoe 2.24 2540.37 2542.61 TD 12 1/4" Surface Hole 2552.00 12 1/4" hole 2552' MD - 2400 'TVD 9 5/8" csg shoe 2542.61 ' MD - 2391.33 'TVD TOTAL BOWSPRING CENTRALIZERS - 38 1 per jt on Jt #1 - #13 (stop ring on Jt #1 8~ 3 ) Every other jt. f/ # 15 to # 63 Joints in the pipe shed 75: 65 jts to run -Last 10 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.815" MU torque ^- 8600 ft/Ibs Remarks: Up Wt - 150k Dn Wt - 142k Block Wt - 75k Supervisor: D. Burley / D. Mickey .i Cement Detail Report CD4-211 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10149020 11/15/2006 11/15/2006 Cemertt Details - Description - _ _ ~ -- Cementing Start Date Cementing End Date Weiibore Name Surtace Casing Cement 11/17!2006 15:15 11/17/2006 16:27 CD4-211 Comment 'Cement Stages _- - - -- - - _ _ _ _ - -- - Sta e # <Sta a Number?> _- - ---- Description Objective Top (ftKB) Bottom (ftK6) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Primary 37.0 2,542.0 Yes 68.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 8 580.0 1,120.0 Yes 20.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8~ Additives Fluid _ Fluid Type Fluid Description _ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Lead Cement 37.0 2,042.0 308 G 245.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.72 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description _ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tait Cement 2,042.0 2,042.0 235 G 49.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/8/2006 .rld i ~ Security Level: Development Daily Drilling Report CD4-211 ,.;. Report Number: 3 Report Date: 11/17/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 3 2.54 2,552.0 2,552.0 0.00 CD4-211 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 11/15/2006 DOYON 19 NANUO Development 14,392.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10149020 7,300,000.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,542.OftK6 3 1/2 14,374.00 Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost MU BHA 300,517.99 895,278.93 24hr Forecast Daily Mud Cost Cummulative Mud Cost RIH - CO shoe trk. -FIT -Drill 8 314" hole 9,386.99 42,178.93 Last 24hr Summary POOH - LD BHA -Run & Cmt 9 5/8" csg - RD riser -Install wellhead & NU BOPE -Begin testing BOPE General Remarks Weather Head Count -16 /Clam 46.0 -- supen~s __ -----..-T..__ -- _ -.. Tai, _.. ----- _ Dave Burley Rig Supervisor Don Mickey Rig Supervisor (Time Loa 'Start End Dui art 'i Depth Cr.~ I T~m~ I, r ~ ~~ Time Tlme (hrsj phas¢ O Code P tik[ i ~~;~.,, i P-N-T .~ ~ Trrl Code TrblGlass. j ~ (ftKL, '. GommlOperal~on 00:00 02:00 2.00 SURFAC DRILL TRIP P 2,552.0 166.0 POOH on TT from 2552' to 891' -flow check well, static - stand back HWDP 02:00 05:00 3.00 SURFAC DRILL PULD P 166.0 0.0 Stand back NMflex collars and jars -Download MWD - lay down remainder of bha -clear tools from floor 05:00 07:00 2.00 SURFAC CASING RURD P 0.0 0.0 Rig up to run casing: LD drilling elevators and bails -pull pollution flange from riser - MU fill-up tool -install casing bails, elevators and slips - RU casing tongs and work platform 07:00 07:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held safety and Opts meeting with crew 07:15 11:30 4.25 SURFAC CASING RNCS P 0.0 2,542.0 Run 9 518" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Howco) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) Ran 61jts of csg to 2500' (65 jts total ran) - MU FMC csg hanger ~ landing jt. -Land csg w/fluted mandrel hanger on landing ring w/ float shoe @ 2542' & float collar @ 2463' 11:30 12:15 0.75 SURFAC CEMENT PULD P 2,542.0 2,542.0 Lay down fill-up tool -blow down top drive - MU cement head 12:15 14:30 2.25 SURFAC DRILL CIRC P 2,542.0 2,542.0 Establish circulation @ 2 bpm / 320 psi -PUW 170K SOW 133K -stage pumps up to 8 bpm -circulate and condition mud for cementing - FCP @ 8 bpm / 390 psi - reciprocated pipe with full returns throughout -PUW 150K SOW 142K 14:30 15:00 0.50 SURFAC CEMENT DISP P 2,542.0 2,542.0 Cement 9 5/8" csg as follows :Pumped 40 bbls Bioian water w/ nut plug as marker -Pumped 10 bbls CW100 w/ Dowell -Tested lines to 3000 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg 5.5 bpm / 255 psi 15:00 15:15 0.25 SURFAC CEMENT WOOR NP 2,542.0 2,542.0 An announcement was made over the rig PA system of afire in the Boiler room. Rig personnel responding to the alarm located an air compressor that had over heated and was billowing out smoke but no flames were observed. The compressor was locked and the module quickly cleared of smoke. Alpine Security and Fire were notified. Alpine Fire responded to the rig to confirm no further threat was present. Latest BOP Test Data -- - - _ - - - Date Comment Page 1/2 Report Printed: 12/8/2006 ~- Security Level: Development Daily Drilling Report CD4-211 , ; Report Number: 3 .. Report Date: 1111712006 Tsme Lofna ~ -- - - 1 ~ uric 7~crvr Time hi ~ Phase Ur. " 1~ rIFS _;_i F-N-I I TrblGoae ~ J - _ _ -- -- - - D I i=.d Depth E~ Trt,iCiea~. ~ ~ ,EI {ft~) ~ _ ~ ~'~., ~;n 25 SURFAC CEMENT DISP P 15:15 16:30 1 2,542.0 2,542.0 Continued with cement operations: Mixed & pumped . 245 bbls lead slurry (ASL) @ 10.7 ppg (' Observed nut plug marker @ shakers w/ 220 bbls lead pumped - pumped down surge can) Pumped 49 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 167 bbls 9.8 ppg water base mud - Displaced @ 8.0 bbls/min for first 157 bbls -slowed to 4.0 bbls/min for last 10 bbls -Bumped plug w/ 1120 psi (prep bump pressure 580 psi) Check float (held OK) CIP @ 1627 hrs. -Full circulation throughout job w! 68 bbls of 10.7 ppg cmt returns to surface -reciprocated pipe until tact 77 bbls of d'ssptacement. 16:30 17:15 0.75 SURFAC CASING DHEQ P 2,542.0 2,542.0 Test casing to 2500 psi for 30 minutes -bleed off pressure and blow down lines 17:15 18:45 1.50 SURFAC CEMENT RURD P 0.0 0.0 Rig down cmt head & lines - LD landing jt. 18:45 19:30 0.75 SURFAC DRILL RURD P 0.0 ND surface riser & starting head 19:30 20:30 1.00 SURFAC DRILL OTHR P Install FMC Unibore Horizontal well head -Test to 1000 psi 20:30 22:00 1.50 SURFAC WELCTL NUND P Nipple up BOPE 00 SURFAC WELCTL ROPE P 22:00 00:00 2 RU & Begin testing BOPE - Hydril to 250 & 3500 psi - . Top pipe rams -choke maniflod valves to 250 & 5000 psi Mud Check Data ~- T- - ~ ~ ~ ~ ~.i ~ . FV Cak (cPl t ;_ o ~'h ~Ke Den, I 3` ~~ 'u - -- 000 "0 HIHI'F~~~ n) ~ P~ _._ _. ~i- i ro7 h~, S OOO- (ibt35 000 bt50a~001 MBT(1 3010 iL _)mi Densii r n:,' :, ii .; 9.8 - . 19.0 S ud 2,552.0 9.80 60 p - - _ __ - - - _ I- -- Injection Fluid _ - _ __~ - Fluid :~aurce - ___ _.- Diesel Water -- - _ - -- - - - r rom Lesse (bbl) _ I t zn ioc _ _ ,,~ ___ 5.0 CD4-208 infectivity test 5.0 CD4-208 Annular flush Water Based Mud 810.0 CD1-19 f/ CD4-211 Water Based Mud 277.0 CD4-208 f/ CD4-211 Wellbores - -- - - Wellbore Name CD4-211 Wellbore API/UWI 501032053860 I - - - _ -- --- _ _ Se~~r•n Size{m) _ -- Act Top(ft COND1 ~ 36~ I FndDate - K6) _- I .4; E ~ rKN)) S3artDate . 0.0 ~ 114.0 11/4/2006 11/5/2006 SURFAC 12 1 /4 114.0 2, 552.0 11 /15/2006 11 /16/2006 INTRMI 8 3/4 2,552.0 7,737.0 11/18/2006 11/22/2006 PROD1 6 118 -- _ - _ 7,737.0 14,379.0 11 /24/200 12/1 /2006 Cement _ ___ __ __ _ __ - _ - -- _ _ Surface Casin Cement -Started 11/17/2006 Type Wellbore String Cement Evaluation Results casing CD4-211 Surface, 2,542.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbll... P (final) (psi) Surface Casing Cement 580.0 37.0 2,542.0 4 _ _ - F 1^~d Class Amount (sacks) ,-_, Top {ftKa~ _ _ V (bbl) Density{dblgal) Yield (ft'lsack} ~°` CstBlm {ftKB) 0 042 0 2 37 Lead Cement G 308 , . . 245.0 10.70 4.45 Tail Cement G 235 49.0 15.80 1.17 2,042.0 2,042.0 Page 2/2 Report Printed: 12/8/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-211 Rig: Doyon 19 Date: 11/17/2006 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Burley / D. Mickey Pump used: ~ #2 Mud Pump ~ strokes ~ 0.1000 Bbls/Strk ~ 8.0 Strk/min ~ Type of Test: openholeTest LOT/Frr ~ Pumping down annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: s-3/4" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pum pin Shut-in RKB-CHF: 34.8 Ft 2,542 Ft-MD 2,391 Ft-TVD 2,572 Ft-MD 2,418 Ft-TVD Strks psi Min psi Strks si Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 2520 1 80 0 1070 Casin Test Pressure Int e rit Test 2 220 1 2520 2 180 0.25 1060 Mud Weight: 9.8 ppg Mud Weight: 9.5 ppg 4 480 2 2510 3 "~ 280 0.5 1060 Mud 10 min Gel: 30.0 Lb/100 Ft2 Mud 10 min Gel: 65.0 Lb/100 Ft2 6 760 3 2510 4 °' 400 1 1060 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 960 4 2510 5 510 1.5 1050 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1130 5 2510 6 600 2 1 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1330 6 2510 7 .. 700 2.5 1 Estimates for Test: 1.8 bbls Estimates for Test: 1057 psi 0.7 bbls 14 1540 7 2510 8 790 3 1040 ~ ~ 16 1730 8 2500 9 , , 890 3.5 1040 EMW =Leak-off Pressure + Mud Weight = 1070 PIT 15 Second 18 1960 9 2500 10 960 0.052 x TVD + 9 5 0.052 x 2391 ~ Shut-in Pressure, psi 20 2200 10 2500 11 1020 EMW at 2542 Ft-MD (2391 Ft-ND) = 18.1 ppg_ loco _ _ 22 2420 15 2490 12 1070 3000 Lost 40 psi during test, held ~ 23 2520 20 2490 98.4% of test pressure. 25 2480 30 2480 zsoo a 2000 - - w ~ __ ~ 1500 -- w o: a . loo0 4 i' , _ ~ 500 - - 0 0 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Vol ume tCASING TEST -LEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed s s s Comments: Casing tested after bumping plugs on cement job. 5 1030 I 5.5 1030 9.51 1 ~ • 7" Csg Detail ConocoPhillips Alaska, Inc. Well: CD4-211 Date: 11/23/2006 Subsidiary of PHILLIPS PETROLEUM Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.75 FMC Gen V Hanger 2.65 34.75 Jts 3 to 180 178 Jts 7" 26# L-80 BTCM Csg 7605.94 37.40 Halliburton Float Collar .95 7643.34 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 81.06 7644.29 Ray Oil Tools "Silver Bullet" Float Shoe 2.08 7725.35 7" Shoe @ 7727.43 8 3/4" hole TD @ 7737.00 8 314" hole TD @ 7737' MD / 6214 TVD 7" Shoe @ 7727' MD / 6213' TVD Total Centralizers: 56 Straight blade centralizers one per jt. on jts. # 1-15 Straight blade cent. one per jt. on jts. # 73 - 83 Straight blade cent. One per jt # 122,123,124 Straight blade cent. One every other jts # 126 - 178 193 jts in shed - 180 total jts. to run Last 13 jts. Out Used Jet Lube Run-N-Seal i e do e Remarks: Up wt - 250k Dn wt - 168k Blocks - 75k Make up torque - -8000 ft/Ibs Supervisor.•D. Burley/L. Hill 4 Cement Detail Report CD4-211 ... Intelrmediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date 10149020 11/15!2006 11/15/2006 DRILLING ORIGINAL DRILLING Cemen#Detaiis _ _ __ ___ ---- - - _ __ _ _ __ - -- -- -- -- - - - - -- Cementing Start Date Cementing End Date Wellbore Name Description Intermediate Casing Cement 11/23/2006 10:48 11/23/2006 12:22 CD4-211 Comment Cement Stares _ - -_ - - - -- -- --~ - ---- - - a Sta e # 1 _ - - - -- Description Objective ___ _ --- - - - - --- Bottom (ftKB -~ - -Full Return? Gmnt Rtm (... Top Ptug? Btm Plug? Top (ftKB) ) Yes Y Intermediate Casing es 3,913.0 7,727.0 Yes 0.0 Cement O (start) (bbllmin) O (end) (bbllmin) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No 8 q g 770.0 1,300.0 Yes 20.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives - - --- - -- - - Fluid - _ -_ _ __ _ - Fluid Type Fluid Description -- - -- - _ - - - - r - - Volume Pumped (bbl Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class G 80.5 ) Lead Cement Yield (fP/sack) Mix H2O Ratio (gal/sa... 3,913.0 ~ 6,227.0 i35 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.22 11.00 Additives Concentration Conc Unit label Type Additive Fluid _ _ _ _ Fluid Type Fluid Description - - Volume Pum ed bbY Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class 59 0 ( ) Tail Cement Yield (fNlsack) Mix H2O Ratio (gallsa... G 6,227.0 7,727'0 287 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 Additives Concentration Conc Unit label Type Additive Page 1/1 Report Printed: 12/8/2006 Security bevel: Development Daily Drilling Report CD4-211 Report Number: 9 . ,~ Report Date: 11/23/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 9 8.54 7,737.0 7,737.0 0.00 CD4-211 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 11/15!2006 DOYON 19 NANUQ Development 14,392.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10149020 7,300,000.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 7,727.4ftKB 3 1/2 14,374.00 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Drilling Shoe track. 516,021.49 2,479,413.61 24hr Forecast Daily Mud Cost Cummulative Mud Cost Drill Shoe track and FIT. Change out mud to FlowPro and drill. 7,899.49 174,028.61 Last 24hr Summary Ran and cemented 7" casing. Changed rams to VBR. Made up BHA and RIH picking up DP. General Remarks Weather Head Count -1 S @ 3 mph 48.0 -- --- - -- Supervisor Tula - -- - _ __ Dave Burley ,Rig Supervisor Larry Hill Rig Supervisor Time Lv _ Start End G~ ~r fim~ Depth Start Depth F~x~ Time Time (hrs '~ F~has--_ ~. Op Code OpSut~-C., P-N-T TrblCode TfiIClass (ftK6) (ftKE~,i '~. Com~rJ4n~iat~r,^. - - INTRM1 CASING RNCS P 1,064.0 2,553.0 Continue running 7" 26# L-80 BTCM csg f/ 1064' to 00:00 01:00 1.00 -- - -- 2553' (60 jts total) 01:00 01:30 0.50 INTRM1 CASING CIRC P 2,553.0 2,553.0 Stage pumps up to 5 bpm - CBU -FCP 190 psi - PUW 130K SOW 120K 01:30 04:30 3.00 INTRMI CASING RNCS P 2,553.0 5,550.0 Continue running 7" 26# L-80 BTCM csg f/ 2553' to 5550' (130 jts total) 04:30 05:30 1.00 INTRM1 CASING CIRC P 5,550.0 5,550.0 Establish circulation with 2.5 bpm / 400 psi -staged pumps up to 7.0 bpm and condition mud -FCP 610 psi - PUW 205K SOW 157K 05:30 08:00 2.50 INTRM1 CASING RNCS P 5,550.0 7,727.0 Continue running 7" 26# L-80 BTCM csg f/ 5550' to 7685' (180 jts total) - PU FMC fluted hanger & landing jt. -Land 7" csg w/ FS @ 7727' FC @ 7643' 08:00 08:45 0.75 INTRM1 CEMENT RURD P 7,727.0 7,727.0 Lay down fill up tool -blow down top drive - MU cement head and lines 08:45 10:45 2.00 INTRMI CEMENT CIRC P 7,727.0 7,727.0 Establish circulation - 2.0 bpm / 420 psi -stage pump up to 7 bbls/min -circulate & condition for cement job - FCP 510 psi -Reciprocated pipe -full returns while. circulating -Final mud properties - Wt. 9.8 ppg Vis 41 PV 7 YP 14 Gels 5/6/6 10:45 12:30 1.75 INTRMI CEMENT DISP P 7,727.0 7,727.0 Cement 7" csg as follows: Pumped 10 bbls 8.3 ppg CW-100 -Test lines to 3900 psi -Pumped 10 bbls 8.3 ppg CW-100 - 3.3 bbls/min @ 240 psi -Pumped 30 bbls 10.5 ppg MudPush 4.5 bbls/min @ 295 psi -Dropped bottom plug -Mixed & pumped 80 bbls 11.0 ppg Lead slurry (LiteCrete) 5.7 bbls/min @ 375 psi -Mixed & pumped 59 bbls 15.8 ppg Tail slurry (Class G w/ additives) 4.6 bbls/min @ 195 psi -Drop top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps ~ displaced w/ 271.8 bbls 9.8 ppg LSND mud - 7.5 bbls/min @ 910 psi for first 260 bbls -slowed pumps to 4.2 bbls/min @ 770 psi for last 11.8 bbls -Bumped plug w/ 1300 psi - Checked floats OK - CIP @ 12:22 hrs. -Full returns throughout job - reciprcated pipe until last 62 bbls of displacement 12:30 13:15 0.75 INTRM1 CASING DHEQ P 7,727.0 7,727.0 Pressure test 7" casing to 3500 psi for 30 minutes - bleed off and blow down lines Latest BOP Test Data _.-_. Date -...._...- --... --- t rr-ne~.t 11/22/2006 Function test. Page 1/3 Report Printed: 12/8/2006 Security Level: Development Daily Drilling Report CD4-211 ,..,,• Report Number: 9 Report Date: 11/23/2006 me Lo - -- I -- _ -- SY -, End { ~~ ''irr e- Time (h~si Yt~a~e _ 3p Co _ VP~uu-l.o -13:15 14:00 0.75 INTRM1 CASING RURD T~r ~~ ~ I i Ali SL~ar3 fl. ..r~ End flR6 F-N Ti 1 r.~d Co~~ ~ Trol Glass. - ,J:Fij ~~,,,u:.p~ a,~~ ~- -- P 0.0 0.0 Ld casing elevators and landing joint -pull thin wall wear bushing 14:00 14:30 0.50 INTRM1 CASING DHEQ P 0.0 0.0 Install and test packoff to 5000 psi - 10 minutes 14:30 17:00 2.50 INTRM1 WELCTL OTHR P 0.0 0.0 Changed top pipe rams to 3 1/2" X 6" VBR's -install test plug -test top rams to 250/5000 psi - LD test plug - install wear bushing in wellhead - LD casing bails and PU drilling bails while changing pipe rams 17:00 21:15 4.25 INTRM1 DRILL PULD P 0.0 375.0 Picked up components and made up GeoPilot BHA. 21:15 22:00 0.75 INTRM1 DRILL DHEQ P 375.0 375.0 Tested Geo Span and shallow tested MWD. Pulse weak, MWD suggested retest @ - 2000'. 22:00 00:00 2.00 INTRM1 DRILL PULD P 375.0 1,805.0 RIH with BHA picking up DP to 1,805'. Mud Check Data -- ~~ ' - - - - - __ ~ ensity Fral, i J5, ~ ~ el (30m) ~ h ~ I~ F i! ~ Corr_ i Ge3 t ~ ~~ ~I Y Type DeptYt (ftKB) Dens Qblg, Wfs js/qt) PV Cal LSND 7,737.0 41 9.80 -- 1 ~ ~ ~, L f~107ft~~ MBT (IbPobh ~i rL _ r~r pH ~ ~ ~~ cp i Ibfl100ft') IhU1ODft? I 1 fi° _ - 3, 6.000 20.0 a4~ 5 '~ 9.0 14000 5.000 r 0 ~~ 001_.. -- Injection Fluid _ - - - Flu~c Source Diesel ___ _ __ 1 I From Lease (bbt) Deshnatie~~ Nola 60.0 To CD4-211 Recycled mud 1680.0 CD1-19 From CD4-211 Recycled mud 6.5 From 211 to 211 Water 300.0 From CD4-211 to Same 'Driii Stria s: BHA No. 3 - Motor / Bit Run No. 3 - 8 3/4in, Hu hes Christensen , HCM605 , 7110224 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (maxj (100... WOB (min) (1000... 6,343.0 7,737.0 1.04 15/15/15/15/15/15 1-1-NO-A-X-I-NO-TD 64 0 0 Drill Str i n Com onents _ _ Jts Item Description OD (In) ~ I[ ~ ,~n; Top Conn Sz (in) ~Tc F Thi =_, C:un. I on (ff) _- 1 _- 7" Mud Motor 7 -- 4.680 4 1/2 NC 50 26.35 1 Float Sub NM 6 1/2 3.500 4 1/2 NC 50 28.73 1 DM HOC (pony collar) 6 3/4 1.920 4 1/2 NC 50 37.95' 1 Stabilizer (Non Mag) ILS 6 3/4 1.900 4 V2 NC 50 40.16 1 MWD (Dir & Logging) 6 3/4 1.900 4 1/2 NC 50 61.05 1 Stabilizer (Non Mag) 6 3/4 1.900 4 1!2 NC 50 62.95 1 MWD (Dir & Logging) H-Cim 6 3/4 1.900 4 1/2 NC 50 69.93 1 MWD (Directional) T-M 6 3/4 1.900 4 1/2 NC 50 79.85 3 NMDC 6 3/4 2.813 4 1/2 NC 50 171.82 3 HWDP 5 3.000 4 1/2 NC 50 261.66 1 Drilling Jars -Hydraulic 6 1/4 2.250 4 1/2 NC 50 293.98 14 HWDP 5 3.000 4 1/2 NC 50 715.83 36 Drill Pipe 5 4.276 4 1/2 NC 50 1,857.33 XO Sub 6 1/2 2.500 4 XT 39 1,858.69 'Drilling Parameters _ C i r p ~ ri >hcr 1 Its (~.urr Dull L fl Nj ;,c-nt (ftKB) Er7 ttKBi -~ (n~i tL lur Depth if. Tir- - I-it DeGth at~~ ~Fm ~~H ~Jtd~RPM , r: i' SF F'i;,~i1 ---Uiill la 7,737.0 7.737.0 _. --~~- 1,394.00 _ 16.6' -- 0.00- 650y - 20.01 - 70 '_230.0 _ - 10.500.0 Wellbores -j Wellbore Name Wellbore APIIUWI CD4-21 1 501032053800 ~ - - , _ Act Top;(EtK$} - - P,ci Btm (ftiC81 Sfart DatF ET~ Daro COND1 y 36 0.0 114.011/4/2006 11/5/2006 SURFAC 12 1 /4 114.0 2,552.0 11 /15/2006 11 /16/2006 INTRM1 8 3/4 2,552.0 7,737.0 11/18/2006 11/22/2006 PROD1 6 1 /8 7,737.0 14, 379.0 11 /24/2006 12/1 /2006 - - Cement Intermediate Casin Cement -Started 11/23/2006 Type Wellbore CD4-211 String Intermediate, 7,727.4ftKB Cement Evaluation Results Page 2/3 Report Printed: 12/8/2006 \ Daily Drilling Report Security Levei: Development CD4-211 :,, Report Number: 9 Report Date: 11/23/2006 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 3,913.0 7,727.0 4 770.0 Fduld ~inount (sacsl U (bh- ~, Density (Ib/gal; Yield (ft'lsack) Est Tap (ftK6~ Est Bfr~a (ftKB` Lead Cement G 135 80.5 11.00 3.35 3,913.0 6,227.0 Tail Cement G 287 59.0 15.80 1.16 6,227.0 7,727.0 Page 3/3 Report Printed: 12/8/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-211 Rig: Doyon 19 Date: 11/23/2006 Volume Input Pump Rate: -` i Drilling Supervisor: D. Burley / L. Hill Pump used: Cement Unit ~ ! P i d ~ Barrels ~ 0.1000 Bbls/Strk ~ 0.8 Bbl/min ~ ump ng own annulus. Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ ~ Casin Shoe Depth Hole De th Pumpin Shut-in Pumping Shut-in RKB-CHF: 34.8 Ft 2,542 Ft-MD 2,391 Ft-TVD 3,913 Ft-MD 3,629 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 4o#/Ft L-so BTC ~ 0 0 0 0 0 0 580 Chan es for Annular Ade ua c Test Pressure Int e rit Test 1 0.5 160 0.25 500 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 320 0.5 488 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 525 1 488 ize is that drilled below outer casing. 4 2 716 1.5 `~8 timated TOC for Hole Depth. 5 2.5 885 2 4 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 1073 2.5 4 Estimates for Test: 771 psi 0.3 bbls 7 3.5 700 3 487 _ ~ ~ 8 4 520 3.5 487 __ _ _ _ EMW =Leak-off Pressure + Mud Weight 1073 _ PIT 15 Second 9 4.5 560 4 487 + 9 8 0.052 x TVD 0.052 x 2391 Shut-in Pressure, psi 10 5 560 4.5 487 EMW at 2542 Ft-MD (2391 Ft-ND) = 18.4 500 15 5.5 575 5 489 1soo, ~ ~ ~ ~ ~ ~ 20 6 580 5.5 487 7 1000 W 0' w a 500 0^ 0 9 1 2 3 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume •~CASING TEST tLEAK-OFF TEST O PIT Point Pum ed Bled Back Pum ed Bled Back s s s s Tested 9 5/5" shoe to 18.1 ppg PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-211 Rig: Doyon 19 Date: 11/25/2006 Volume Input Pum Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: Cement Unit ~ Barrels ~ Bbls/Strk ~ ' 0.5 Bbl/min ~ P i d Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annulus. ~ Casin Test Pressure In te rit Test Hole Size: 1z-1/4" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 34.8 Ft 2,542 Ft-MD 2,391 Ft-TVD 3,913 Ft-MD 3,629 Ft-TVD Bbls psi Min psi Bbls p si Min si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 439 0 803 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.2 540 0.25 772 uter casing shoe test results in comments Mud Weight: 7.0 ppg 2 0.4 656 0.5 757 Description references outer casing string. Inner casing OD: 7.0 In. 3 0.6 752 1 742 ize is that drilled below outer casing. 4 0.8 848 1.5 timated TOC for Hole Depth. 5 1 924 2 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 1.2 999 2.5 Estimates for Test: 1119 psi 0.9 bb_Is 7 1.4 878 3 717 ~ 8 1.5 838 3.5 712 _ _ EMW =Leak-off Pressure + Mud Weight = 999 _ PIT 15 Second 9 2 848 4 707 0.052 x TVD 0.052 x + 7 2391 Shut-in Pressure, psi 10 2.5 914 4.5 707 EMW at 2542 Ft-MD (2391 Ft-ND) = 15.0 ~ 772 15 3 954 5 707 lsoo 20 3.5 939 5.5 707 25 4 899 6 702 30 4. 7 6 5 8 4 7 702 1000 W W a 500 0 0 1 2 3 4 5 6 Barrels CASING TEST -FLEAK-OFF TEST s: 9 5/8" PIT= 18.1 ppg EMW Mud weight for calculation -weighted average of c Second annular LOT, suspect cement stringer or i N ~~ ~, ~a - ~ ; r - - 7 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point id on ume SURFACE CASING SHOE SEPARATION FROM CD4-211 CD4-211 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 377358.34 5957494.04 ells Details @ AOGCC'"` Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ante from Object well' Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Nanuk 1 n Exploration P&A'd Nanuk 2 n Exploration P&A'd Nanu 3 '~ 866 376499.5 5957382.0 11.8 1781 Exploration, X-Y location calculated at 2400' TVD, NOT the surface shoe depth Nanu 5 1583 378326.6 5956241.7 14.9 2393 15.1 Not for annular dis oral CD2-319 305-373 121912005 CD4-208, CD4-318, CD4-209, CD4-320 32000 12/14/2005 7/2/2006 1713 377174.7 5955790.4 18.4 2400 16.1 CD4-208 306-183 5/30/2006 CD4-318a, CD4-320, CD4-214, CD4-321,CD4-211 60672 7/3/2006 12/6/2006 '^"h 1046 378134.2 5956792.7 16.3 2439 14.4 volume extension to 70000 bbl, permit #306- 266 CD4-318 306-181 5/26/2006 CD4-209, CD4-320 457 5/3112006 7/2/2006 1701 376138.4 5956308.2 18.2 2375 17.1 Unable to ump- SD pumpin CD4-209 598 377934.9 5957333.9 14.7 2377 17.5 Not for annular disposal CD4-210 .564 377547.4 5956963.2 18.0 2386 17.3 E CD4-320 •--# 826 377914.2 5958105.0 17.1 2378 17.8 Not for annular disposal CD4-17 --a 981 376416.3 5957221.0 18.1 2387 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4-321 1656 375795.6 5956945.4 18.0 2385 16.3 CD4-214 •--~ 619 377040.9 5956962.8 18.2 2365 17.6 Not for annular disposal 4~ CD4-211 n 0 377358.3 5957494.0 18.1 2391 15.0 2nd annular LOT, 1st ann test 18.4 * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Nov. Dec. 8, 2006 Note that this sheet is not the definitive record for annular disposal volumes Y C • ConocoPhilli s p Alaska MALLIBURTON ,~.. t>,..~..,...~, 0 s 0 1156 57 WELLPATIi DETAILS Rig: CD4-21 I Rig. Doyon 19 Ref. Datum: Plan: CD4-211 56.30ft Quarter Mile VSection Origin Origin Starting Angle +N/-S +E/-W From'I'VD (1320 feet) 171.21° 0.00 0.00 36.30 radius plot i CD4-208 CD4-208 - - -~ - i ~'' \~~. Ri :CD4-211 -2890 -2312 -1734 -1156 -578 0 578 1156 1734 West(-)/East(+) [ft] :CD4-214 Ri :CD4-214 CD4-318 CD4-318A - CD4-209 CD4-209 Nanu 5 ~Nanu 5 ~- CD4-17 CD4-17 ~ -578 - _ Ri :CD4-215 Ri :CD4-215 - °' --~ ~ ~ CD4-321 CD4-321 ~~~~ CD4-320 (CD4-320) ,; CD4-208 CD4-208 CD4-319 CD4-319 CD4-318 CD4-318 ~ 115 - -- • • ~'O:tS and Shannon, "~'ou have rcc~=fisted to dispo .e of "rieiv-prt~ducC" c'! can up fluids from the' zatitiue mixinc} of ~tu8 ~d semen; ~t 1pirc~ ~~ well as the- clea.~ up fluids resulti,zYg fra~ri cleaning shut the kanks at the mud p1~iit `in prerse.ration fc~r using oil base mud e, T~"ie Coo,snissio:~ has prav~.ous3:y approucd dispasinc( of the 'rev: procuct" clan up flu~.ds vi.a ar:nular disposal at GD 1 pad. ~i:e to the ~zeological seetinc. at alpine, Mass 1 ~ndClass 2 disposer optio7~s are 1ir;:ited. Ph,1li.ps' predecessor, S.~Ct}, had esrabis~ed the limitat~.on of czi 5posa 1 options. tc~ the Com<nissior.'s s~7ta:sacriar. arr1 ahr.~~lar dispersal vlas approved a the practical and environm@ntal a1'ternatv~'.. In these requests tiaev~aste fluids are zoo d~ ferent ti~a~ previouslyappr~a~+ed- ard are the result o` the ongoing develor~icien~ activtzes at r'~lpr,~- Tt2e-Commissioners'have authorized me ~v send yvu this message. Hy copy of t~tiS email;. Phillips is auLh~a_2ed tc~ ciisp+~se of c~.ean up fluids as descxikd in your ca^,a i 1 Please call with .any q:aestiar;s . 'Com ~aundc~r , PE Sr. Petroleu~« Enc~inee~ ~CGCC ~'+~P Env Caord ~,~rate: ':~ ~eaY Mr'. Maunder, -. , y ~ noted in the aL-tac3~ed email, 'Iom M<ansan prcvfously requested 7 <ut~©rization to dispose of near-product clean up fluids such as cement > rinsate, a.-~d irturx and ~rre pit rises from mixing pperatons t~ia annular > in:eCton ir, permttsa t,,ells at the ~.lpine CD2 Dri11 Site. .~s noted belotia. ~ ~QGCG a~protred ~uchdisposal at the eD1'Dri11 Side i~r 199., ba ed on th@ 3 integral reiaCionsiip of the in~.td mzxi-nq La~zli~.y and the on-site drillinn =°~ operation. y Phillips ~.*c~uld 1i~e to continui:rag purs~~iner this req~iest. Signifidant clean. > out of tanks at the mud mixing faei?it~ must occur in prepax'aton foreth~ > te;nporary use'~of oil k~ased mud praducrs at Rlpine rz~ the cAming months. >^he~a~ailability ofannular disposal as an option for tank rinses fluids~arld > sirt az` vrastes ~.~rauld greatly facilitate this process: t~~ically, routine > rinses are bcrfe£iciall}r reused however, there is a concexn ab©ut the, > po~ential quantity of fluid that could be generated. duping thin large sca3e >clean up process,) s ~Fanks at the s~:~d mixing faoility mater cc~r~~~i~ either n+~w and used mud > products. Zhcug~rinses in cox~cact with used products-znay bo injeGtedin. ~- the percr~itted class 21 disposal trill (CI319n~ , rinses of neT~r products kould I~o;:er,t-ially be r4lzt~d to the class. l d~st~osa3 erell (vim-~2} , w*here Lh~rs > a`difficulty manar3ing spuds cor_tent_ 'The class Lwell is a critical } lifeline fQr facility infYastructu~e, }wing the disposal l:aaatic~n f~rall domestic effluent, and if, is a prorir.y t-o pxevent an~r compromise to this > disposal facility. Annular disposal prE~sents a preferred waste management } alternative in t~is case. ~- ~ A Thank yciz veer `much for your' co~siclerat:~~n of this request. 'P7.sase tab nab }:esztate to contact me o ~ °alternate va° wail, or phaas at t907} 57.0=42C?0 if yc~u have questi,ars or deed :addit::ona~, r~fozmati~n. a Skt~nr_an Zlon*relly ° alpine = e'ci ~avirc~xlme~tal. Coora~naLCir t9~'7} 6'70_4~t}0 y __~_~, Fox~.varde~d b~ ,ALA Env CaozdlPFGd az 13~G2~t?I 1~ 5p :T~!"l~ ~-~~°~- ISLE Frio' ~C3T~ > A~~t3~:~Q~. ~2:~~ Pis Tt?e t,o,~.;inaunderCr-admin.st~re.a'~c.us;` ~'~ ~_;_ ~ Sub~~t `Rf~~1tC#est t~ 1x~je~t :~emer_t. €ta;r~s,~t~ .a Q2 Dear i~ir. i~launder,- Infection o.f cement .r%~sate anc3 clean-uD flxzd:~ Frain mini., and brine miXinc~ operations at the 7slpine mud plant Facility into appxoved arinulaY di~posa7~ ~ operations ,atas granted by the r~las'~a oil. And Gas Conservation Com~ssiarl a (~f)GCC~ in 'the T~arch 1'~, 1999 letter Pram ~OCCC to 17oug ChQStex of ~.k~C~ Alaska. ~~nc. , nrna P7iillps Alaska. Inc. {PAl) . The approval v:as granted: to'.' a P~',~ spe~i~ically Eor Algine Drill `Site ~D1 and aati~orized xxs~lumes up tU 35, A00 barrels- t7irough the a~--nular 'space. - ., ~~T request tY~at this aaprozral be extended to drillang operations a4 Al'~r4c~.; } Br_11 Site C~2. Cement mixinu operations fc~r setting Surface conductors > will be tasking place at the Gzind and 1r:ject facility which. is currently s attacheca-.to the drillirig rig at.CD2. .Upon completor of the cementinq`in; of the candue~ars, the lanes and mwxing tank :ill have 'to be' rinsed .and the-: xinsa~~e dsposed',of_ AAI request approval to ityjeCt tbi$ rinsate, anti other clean-up. zro-; the mud -and brine mixing aperatioas. into trc art~ua~-: space o£ ;apprgved ~e11s located at Drill, Site CT~2. "f y'ott I~'a~e'any q,~e~'t,~.dnS pease contact me ~~ 67Q=~2UQ: •-: , Tcmt t~T3St3T1 ~- plpi,~-e E"ield Environmental ~o~a~liance t!vix-~tt~u~d~rvcf Note to File CD4-211 (206-153...306-392) Colville River Unit (Nanuq-Nanuq) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 68 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 59% XS of the calculated hole volume. --On the initial leak off test, the pressure slope rises with some inflections to the determined FIT point at 18.1 EMW. Minimal fluid was pumped into the formations. During the observation period, the pressure declined to about 17.6 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An injectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 18.4 EMW. The pressure declined with additional pumping to 14.5 EMW. During the observation period, the pressure declined to 13.7 EMW. A 2"d injectivity test was conducted a few days later. The pressure rises smoothly to 15.0 EMW with final pump in at 13.8 EMW. The pressure declined to 12.6 EMW. The lower EMWs of the pump in tests indicate that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD4-211. The nearest well is 564' distant with 3 other wells about 600' distant. Nanuq 3 is 860' distant at 5 o'clock from the surface shoe. 2 other wells are about 1000' distant. An examination of the cementing information for all wells did not reveal any problem that would preclude granting CPA's request for CD4-211. Nanuq 3 is sufficiently distant that ii~s uncemented annulus should not be of concern Based on examination of the submitted ConocoPhillips' request for the subject well. Tom Maunder, PE Sr. Petroleum Engineer December 27, 2006 information, I recommend approval of G:\common\tommaunder\Well Information\By Subject\Annular Disposal\061227--CD4-211.doc • • Note to File CRU CD4-211 (PTD 2061530) December 27, 2006 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD4-211 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of CD4-211. Recommendation Approve ConocoPhillips' request. Discussion CPAI's application was reviewed along with records from nearby wells Nanuk No. 1 ("Nanuk 1"), Nanuq No. 3 ("Nanuq 3"- the spelling of Nanuq is indeed different), and Nanuq No. 5 ("Nanuq 5"). The proposed injection interval in CRU CD4-211 lies in the Seabee formation approximately 2,925' from the north line and 900' from the east line of Section 24, T11N, R4E, UM and slightly more than 2 miles from the current boundary of the Colville River Unit. The surface casing shoe of CD4-211 lies at the base of a siltstone and claystone interval that is about 300' thick and appears to be continuous throughout this area (see attached schematic cross- section). This interval will .provide upper confinement. The annulus proposed for disposal of drilling wastes extends downward from the 9-5/8" surface casing shoe at about 2,350' true vertical feet subsea ("TVDSS") to the top of cement for the 7" casing string, which is estimated to be at about 3,590' TVDSS. The disposal injection zone in CD4-211 consists of a 700-foot thick sequence of siltstone, silty sandstone and sandstone with scattered interbeds of claystone. Beneath the injection zone are several layers of clay, claystone and shale will provide lower confinement. These layers range in thickness from 10' to 20', appear to be continuous throughout the area, and have an aggregate thickness of approximately 80'. The operator's application reports the base of permafrost occurs at about 1550' TVDSS in this area. My inspection of the well logs indicates that precise determination of the base of permafrost is difficult here. The geologic section is frozen through the West Sak Sands at about 1,050' TVDSS, and possibly as deep as 1,300' TVDSS. Depending on the correlation used, the base of permafrost lies between 800' and 1,300' above the top of the proposed injection interval. The shallow geologic section in the area surrounding CD4-211 commonly contains methane gas. Records from Nanuk 1, Nanuq 3 and Nanuq 5 indicate that surface hole was drilled in each of these wells using about the same weight of drilling mud (between 9.5 and 10 pounds per gallon). Traces of methane were first measured in Nanuk 1, Nanuq 3 and Nanuq 5 at 460', 380' and 50', respectively. The shallowest occurrence of more significant amounts of methane encountered in these three wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,890', 1,700' and CRU CD4-211 ~ • December 27, 2006 Note to File Page 2 of 2 2,235' TVDSS, respectively. So, the entire proposed disposal zone currently contains methane gas. Supporting documentation to ConocoPhillips' annular disposal application states "...There are no USDW aquifers in the Colville River Unit." This is correct. Area Injection Orders No. 18, 18A, and 18B all conclude that there are no USDWs beneath the permafrost in the Colville River Unit area. Shallow aquifers within the area affected by this proposed disposal injection program occur in an area of abundant surface water, contain methane gas, and are situated beneath about 1,000' of permafrost. Even if the shallow aquifers contained freshwater, these characteristics combine to ensure that it would never be economically possible to develop them as sources of drinking water. The shallowest oil shows in Nanuq 3 and Nanuq 5 occur at 3,940' and 3,770' TVDSS. Correlative intervals within CD4-211 are separated from the disposal intervals by several layers of clay, claystone and shale, and are sealed with cement placed around the 7-inch casing. This cement extends upward to about 3,590' TVDSS. The shallowest oil show in Nanuk 1 lies at 6,110' TVDSS, well below the disposal and lower confining intervals. Conclusions 1. The 9-5/8" surface casing shoe is set near the base of a 300-foot thick claystone and shale interval that persists throughout the area and will provide upper confinement to prevent migration of injected waste into freshwater or to the surface. 2. There appears to be a sufficient volume of siltstone, silty sandstone and sandstone open to the annulus of CRU CD4-211 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick (about 80' aggregate thickness) and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. The disposal injection operations will not affect potential oil reservoirs. 6. Correlative rights will be protected. I recommend approval of the proposed program to inject drilling waste into the annulus of CRU CD4-21 . Steve Davies Senior Petroleum Geologist A WEST CRU CD4-211 Annular Disposal Intervals Schematic Permafrost West Sak Sands -- - - ~ ,~.. ~ . A_..,o~ A~_ No nNy; Nanuk 1 - \ Nanuy c .~ ~ '~° . CD4-211 ~~ 6010]30%600 ]00P 60101]WII00 11ggN 6010J3030gW LONOLOpNIWPg AlAgl( LONOLOpMILllp9 •1A91( MCO NANUO J 1l 1 IUNW S NANUI(1 t26g igL 6]~FEL C,l/~- 211 TVN:11 N?Renga:6 E~4~c.L ,YIP:I~N~Ren006 EnSx. 10 iMT: It N ~ PangO: ~ E ~ Sac. b First occurtence of 20 units gas in mud Upper Confining Intervals A' EAST i ,~, ~~', i ~~ ~ ;.F~ d ~ +~ ~ "~ ".7 roan% Nenuk I First oil show ~~ 6,150' bID, 6,110' TVDSS ro-slu r • • SFD 12!27/2006 „'STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:~ €-e~,,;~)asimin.state.ak.us Uogcc p€.€d~oe b~:v~ad:~=n.stae.ak.€s bol ~ eckenstein~yadr~:i:~.state.a>~.~~s~ Contractor: Doyon Rig No.: 19 DATE: 12/2/2006 Rig Rep.: Krupa / Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Hill /Woods Field/Unit & Well No.: Colville Rv CD4-211 PTD # 206-153 Operation: Drlg: x Test: Initial: Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 Workover: Weekly: Annular:250/3500 Explor.: Bi-Weekly x Valves: 250/5000 _ TE:iT DATA FLOOR SAFETY VALVES: Test Result Quantity Test R€ _ P Upper Kelly 1 P _ P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 FP Test Result P P P Blind Rams 1 blinds 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 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P r....a o......u.. CHOKE MANIFOLD: Quantity Test Re: No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 2925 P Pressure After Closure 1500 P 200 psi Attained 31 P Full Pressure Attained 2 min 53 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2000 psi Number of Failures: 1 Test Time: 6.5 Hours Components tested 30 ', Repair or replacement of equipment will be made within n/a days. Notify the North Slope ~ Inspector 659-3607, follow with written confirmation to Superviser at: aim €-G~g ;~ad€~:i:~.state.a>~.us~ Remarks: IBOP failed, changed out and retested ok. Had to pull and change the seal on the test plug because it began to leak. Tested VRB's to 4", 3-1/2", & 4-1/2". 24 HOUR NOTICE GIVEN YES X NO Date 12/01/06 Time 8:30am Test start Finish Waived By Witness Tim Jeff Jones / Larry Hill BOP Test (for rigs) BFL 11/09/04 Doyon19 12-02-06 CD4-211.x1s STATE OF ALASKA >>rosroa OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to:~ re~~~ya~r~~_5tute.ak.us~ aogcc pr;_4d~oe b:~ad:~in.state_ak.~s br_.I ~ eckenstAn:;~a~rr:in.state.a>~.us Contractor: Doyon Rig No.: 19 DATE: 11/18/2006 Rig Rep.: Welsh / Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley /Mickey /` Field/Unit & Well No.: Colville Rv CD4-211 PTD # 206-153 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds 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 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Workover: Weekly: Annular: 250/3500 TEST DATA Explor.: Bi-Weekly Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Re No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 2950 P Pressure After Closure 1500 P 200 psi Attained 30 P Full Pressure Attained 2 min 39 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 1900 psi Test Results Number of Failures: 0 Test Time: 6.5 Hours ComROnents tested 30 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re~~ ~)adrr:i:~.stUte.alt.u~~ Remarks: Good Test. No Problems. 24 HOUR NOTICE GIVEN YES X NO Date 11/16/06 Time 7:OOam est start 22:00 Finish Waived By Chuck Scheve Witness Dave Sena BOP Test (for rigs) BFL 11/09/04 Doyon19 11-18-06 CD4-211.x1s C. Alvord WNS Drilling Team Lead ConocoPhilips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq Oil Pool, CD4-211 ConocoPhillips Alaska, Inc. Permit No: 206-153 Surface Location: 2932' FNL, 264' FEL, Sec 24 TI1N R4E Bottomhole Location: 207' FNL, 4048' FEL, Sec. 31 T11N R5E Dear Mr. Alvord: 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 y required test, contact the Commission's petroleum field inspector at (9 ) 6~Q-3607 (pager). an DATED this~day of November, 2006 0 cc: Department of Fish & Game, Habitat Section ~v/o encl. Department of Environmental Conservation w/o encl. ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS N PERMIT TO DRILL y~ 20 AAC 25.005 Ai~ska Oi€ E~~ ~~tns. C..:it"TtlTtiSSPCli1 ~. _i 1a. Type of Work: Drill Q ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil 0 Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone O ~ 1c. 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: CD4-211 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: 4~' ,[~~ MD: 14392' TVD: ~@2'/~'~ 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2932' FNL, 264' FEL,. Sec 24 T11 N R4E 7. Property Designation: -~7Z/~ 3 ADL 3soo77, 3642os, Nanuq Nanuq OiI Pool Top of Productive Horizon: 4885` FNL, 2023' FEL, Sec. 24 711N R4E 8. Land Use Permit: ~ R' ALK 380077 ~`• 13. Approximate Spud Date: 11113!2006 Total Depth: 207' FNL; 404$' FEL, SeC. 31 T11 N R5E 9. Acres in Property: 2560 14. Distance to Nearest Property:5o73' Nanuq PA 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377980 ' y- 5957479 Zone- 4 10. KB Elevation (Height above GL): 37' RKB feet 15. Distance to Nearest Well within Pool: CD4-210 , 1212' 16. Deviated wells: Kickoff depth: 400 ft. Maximum Hole Angle: 91 ° deg 17. Maximum Anticipated Pressures in psig (see 20 aaC 25.os5) Downhole: 2806 psig Surface: 2193 psig ' 18. Casing Program ifl ti S Setting Depth Quantity of Cement Size peC ca 0ns Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62 6# H-40 '1Veided 77 37 37 114 114` pre-installed 12.25" 9-518" 40 L-80 BTC 2510 37 37 2547 2400 503 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 7756 37 37 7793 6221 2295x 15.8G, 2nd stage 384 sx 15.8G 6.125" 3.5" 9.3# L-80 SLHT 6749 7643 6211 14392 6201 Slotted Liner 3.5" 9.3 L-80 EUE-M 7621 32 32 7653 6217 tubing & vac. Insui tubing 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 TVD (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 ^ BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 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 V. Johnson Printed Name C. Alvord Title WNS Drilling Team Lead Signature by ' ;~ ~~ ~ Phone Date Commission Use Only Permit to Drill Number: ZQ~ --~~3 API Number: //~~~~ 50- /~}3 ' ~,0~3~ '6/C.~ Permit Approva Date: / ee cover etter 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: ~'' Samples req'd: Yes ^ No [~ Mud log req'd: Ye~ No[.~ Other: ~ 2S mea ures: Yes ^ No Q re tonal svy req'd: Yes No ^ ~~" ~"'~ ~ APPROVED BY THE COMMISSION DATE: , COMMISSIO R Fnrm 1n-4r11 Reviceri 19/9(1(15 ~d ~~' f`~~Submit in Duolicat ~f~7 V Ii l~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 30, 2006 • ConocoPhilli s p ~~*~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-211 Dear Sir or Madam: `: 3 ~ 2006 Alaska Oil ~ has Gins. C~~r!~ission A:c~it~a ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Nanuq (CD4) drilling pad. The intended spud date for this well is 11/13/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner producer. At the end of the rig work program, the well will be flowed back ~ for 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities onnection that will allow the well to begin productio It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. ' Hydraulic modeling indicates that it is not technically feasible to place cement from the 7" casing shoe up to 500' above the K2, due to the distance between the two points, so a variance under 20 AAC 25.030 ~5 (g) is necessary. It is planned to pump lead cement, then open a stage tool and pump a second cement . job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. ~~~ ~ t ~ ~QQ~`~v 4~ ~ C.p ~~ C It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 9 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. • • If you have any questions or require further information, please contact Vern Johnson, 265- 6081, or Chip Alvord at 265-6120. Sincer , Vern Johnson Drilling Engineer Attachments cc: CD4-211 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation CD4-211 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casino Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G o sin le shots, travelin c tinder dia rams Gas Hydrates Low ., Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight .. Surface Formations , >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations - Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL • Nanug : CD4-211 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. • 3) Drill 12-%" hole to the surface casing point per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 5000 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Mineral oil based mud. 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 17) Run 3-%2, 9.3#, L-80 tubing with Vacuum insulated tubing, TRMAXX SCSSSV, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. ^31GINAL Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 152 @ 500' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nanuq reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-211 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-211 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only potentially significant hydrocarbon zone is the K2 (Qannik). If it is determined to be significant, a second stage cement job will be used to isolate it. Upon completion of CD4-211 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg)'` (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • s DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12'/" Intermediate hole to 7" casing point - 8 3/" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-g.3 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 KCL 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. OR161NAL CD4-211 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2547 / 2400 14.5 1086 1570 7" 7793 / 6221 16.0 2815 2193 N/A 14392 / 6201 16.0 2806 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2815 - (0.1 x 6221') = 2193 psi , 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2806 - (0.1 x 6201') = 2185 psi ORIGINAL ~ • CD4 - 211 Nanuq Nauuq Producer Completion 16" Insulated Conductor to -114' 2) 4-''/2' x 3-'/i' Vacuum insulated tubing (VIT) 2.813" 'X' TRMAXX SCSSSV 9-5/8" 40 ppf L-80 BTCM Surface Casing 2547' MD / 2400' TVD 4) 4-'/i' x 3-'/i' Vacuum insulated tubing (VIT) to +/- 4000' MD Stage TOC <' +/-3986' MD / 3651' TVD cementing tool +/- 5009' MD / 4541' TVD Top K2/Qannik sand +J-4486' MD / 4086' TVD Planned top of cement 6613' MD / 5833' TVD Top Reservoir at +/- Nanuq 7426' MD / 6176' 3-'/i' 9.3#/ft L-80 SLHT Slotted liner Pattern: 7" 26 ppf L-80 BTC Mod Production Casing @ +/_gg~ 7793' MD, 6221' TVD ORIGINAL TD 6-1/8" hole 14392' MD / 6201' TVD " • Cementing Program: • 9-5/8" Surface Casing run to 2547' MD / 2400' TVD. Cement from 2547' MD to 2047' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2047' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (assume 1600' TVD). Lead slurry: (2047'-1626') X 0.3132 ft3/ft X 1.5 (50% excess) = 197.8 ft3 below permafrost 1626' X 0.3132 ft3/ft X 4 (300% excess) = 2037.0 ft3 above permafrost Total volume = 197.8 + 2037.0 = 2234.8 ft3 => 503 Sx @ 4.45 ft3/sk System: 503 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7793' MD / 6221' TVD: Cemented in two stages Cement from 7793' MD to 6613' MD (300' MD above the packer & minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage• Lead: (7793' -6613') X 0.1503 ft3/ft X 1.4 (40% excess) = 248.3 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 248.3+ 17.2 = 265.5 ft3 => 229 Sx @ 1.16 ft3/sk System: 229 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the KZ interval to +/- 500' above the K2 interval (3986' to 5009' MD) with Class G + Adds @ 15.8 PPG. Assume 40% excess annular volume Tail slurry: (5009' -3986') X 0.3132 ft3/ft X 1.4 (40% excess) = 448.6 ft3 annular volume Total volume = 448.6 ft3 => 384 Sx @ 1.17 ft3/sk System: 384 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement !?~!GINAL ~OnOCOPhllli s Alaska Inc P CPAI Report Company: ConocoPhillips Alaska lnc. Date: 10/10/2006 Time: 09:48:58 Page; 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan; CD4 211, True North" - Site: Alpine CD4 Ve rtical (TVD) Reference: Plan: CD4-241 56.3 Well: Plan: CD4-211 Section (VS) Reference: Well (O.OONO.OOE,171.21Azi) Wellpath: Plan: CD4-211wp05 Survey Calculation Method: Minimum Curvature' Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Buitd Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ftdeg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 - 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 7.50 10.00 699.14 19.31 3.40 2.50 2.50 0.00 10.00 1786.15 29.59 262.39 1737.95 54.55 -257.19 3.00 2.03 -9.91 -119.07 4938.71 29.59 262.39 4479.23 -151.64 -1800.41 0.00 0.00 0.00 0.00 7793.05 88.57 149.29 6221.30 -1952.98 -1759.60 3.50 2.07 -3.96 -111.02 CD4-211wp05 T1 7806.65 88.45 148.90 6221.65 -1964.65 -1752.62 3.00 -0.86 -2.88 -106.57 8814.75 88.45 148.90 6248.86 -2827.56 -1232.14 0.00 0.00 0.00 0.00 8995.13 90.00 154.09 6251.30 -2986.00 -1146.10 3.00 0.86 2.88 73.44 CD4-211wp05 T2 9071.71 92.30 154.09 6249.76 -3054.87 -1112.64 3.00 3.00 0.00 0.04 10117.60 92.30 154.09 6207.84 -3994.88 -656.01 0.00 0.00 0.00 0.00 10194.20 90.00 154.05 6206.30 -4063.75 -622.52 3.00 -3.00 -0.06 -178.91 CD4-211wp05 T3 10302.92 86.74 154.04 6209.39 -4161.45 -574.97 3.00 -3.00 0.00 -179.97 10985.11 86.74 154.04 6248.21 -4773.83 -276.88 0.00 0.00 0.00 0.00 11093.83 90.00 154.07 6251.30 -4871.55 -229.35 3.00 3.00 0.03 0.51 CD4-211wp05 T4 11216.65 93.68 154.07 6247.35 -4981.93 -175.69 3.00 3.00 0.00 0.01 11871.85 93.68 154.07 6205.25 -5569.97 110.18 0.00 0.00 0.00 0.00 11994.66 90.00 154.07 6201.30 -5680.35 163.84 3.00 -3.00 0.00 -179.92 CD4-211wp05 T5 12080.53 87.42 154.07 6203.23 -5757.55. 201.38 3.00 -3.00 0.00 -179.98 13107.18 87.42 154.07 6249.37 -6679.90 649.88 0.00 0.00 0.00 0.00 13193.05 90.00 154.09 6251.30 -6757.10 687.40 3.00 3.00 0.02 0.47 CD4-211wp05 T6 13275.53 92.47 154.09 6249.52 -6831.27 723.44 3.00 3.00 0.00 0.00 14392.31 92.47 154.09 6201.30 -7834.85 1210.98 0.00 0.00 0.00 0.00 CD4-211wp05 T7 Plan: CD4-211wp05 Date Composed: 10/9/2006 Version: 8 Principal: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-211 Slot Name: Alpine CD4 Well Position: +N/-S -49.46 ft Northing: 5957479.79 ft Latitude: 70 17 32.479 N +E/-W -193.70 ft Easting : 377980.24 ft ~ Longitude: 150 59 16.408 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-211wp05 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-211 Height 56.30 ft Above System Datum: Mean Sea Level Magnetic Data: 10/9/2006 Declination: 23.03 deg Field Strength: 57550 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 171.21 Survey Program for Definitive Wellpath Date: 9/18/2006 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft ORIGINAL ~~ •- a ' •- .~ o 3 o S z w ° \, a ~ o + , O F" o p ~-° .-.. N z ~ O z N O ~ t+~ q° ~, ~° + ~ i F ~~ ro a O O ~ d ~ o c N O N U ~ a F F3. 3 °0 ~O c°o ° G q o~ o O °^ O w d V' p~ ~qoq ~ " o ~ Q N O ~ °~~ ~~ . F- ~ ° Z W UU U E v ~ o ccd~c ~ a ~ z 3av~a ~ p o a z v w W ai di ti ai -c c c c c 3 O ` ~ ~ w w w w ~ ~ ~ m u: cL rx a o ,5 °o Q m Wq~ n.ro o 7 ° zH~o 'N ~ ,~ N '-' p -O i0 is A ... ~ U ~ ~ J o ~r~~ M J ~ Q O ~ ~ U ~ ~ °o °a, o 0 O N o C' I~!/1i000Z1 ~+)qu°Wl-)4~~°S o ~D O 00 N ~ q U 0 0 °o o 92° z s° ~o ° ~~- ~~ ?~ °.°~ooo ° O° 'C ~ z r, ON ~L w o U ~°~O~ G Nvi NO p°np G ~ Oz t°~AQ~ a~ ~ Q ~ - ° g °o ~o ,° ~ ~.Y ~ _a o ~ v> > c ~ ^ ~ U ° ¢~ ~¢ ~ 94 ~ I o .~ Z .~+ ~ A ~ ~ C ~' O ~ ~ '~ i N ° .a ~ F^ F U ~ °g I o o ', 10000 `~ A a ~ I 92° ~ V] C N m ° ~ = ~J W ~ ~ o ' W cn O 0: °o 00 > > ~ ~ q a ~- ~ ~n ~n $$ ! ° 8 o0 3 ~ '~ ~ q _~' ~ a3 ~~ N ~ M = O ~ N N i a, ~ U U °Oy ~ .a ~ Q ~ N ~ i ~ ~ ~ ~ p 3 ~ w ~ F' o ~ ~ o, v q oc'_n3 ~ ~ o ~ a aR. o - 0 0 + x N ~ q ~~ o ~ °+ r° s °M ° c~i cn ~ ' a U ~ qa. c~ o° °°' n ~ orn o~, ov z a, a w 3 a z o o+ e w o ~ N o s ~ q 0 o M ° ° ~o o ~ q G Q ~ ¢ r. °o v °~o v U ~ ~ I°!hi000ZI ~d°4 le°!uaA amy z a 0 ° i N q U 000 3000 ~ 4000 ~~ °o h~ o n c 1 k • ~0 0 oPhilli s A as a Inc. P CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/10/2006 Time: 09:48:58 Page: 2 Field: Colville River Un it Co-ordinate(NE) Re ference: Well: Plan: CD4-211, True North Site: Al pine CD4 Vertica l (TVD) Reference: Pl an; CD4-291 56.3 Well: Plan: C D4-211 Sec tion (VS) Reference: Well (O.OONO.OOE,171 .21Azi) Wellpatb: Plan: C D4-211wp05 Survey Calculation Metbod: M inimum Curvature -Db: Oracle Survey MD 3nci Azim TVD Sys TVD N/S E/W MapN MapF, DLS VS Comore t ft deg deg ft ft ft ft ft ft deg/100ft ft 36 .30 0. 00 0 .00 36 .30 -20. 00 0 .00 0 .00 5957479. 79. 377980. 24 ~ 0.00 0 .00 100 .00 0. 00 0 .00 100 .00 43. 70 0 .00 0 .00 5957479. 79 377980. 24 0.00 0. 00 200 .00 0. 00 0 .00 200. 00 143. 70 0 .00 0. 00 5957479. 79 377980. 24 0.00 0. 00 300 .00 0. 00 0 .00 300. 00 243. 70 0 .00 0. 00 5957479. 79 377980. 24 0.00 0. 00 ~ 400 .00 0. 00 0 .00 400. 00 343. 70 0 .00 0. 00 5957479. 79 377980. 24 0.00 0. 00 500 .00 2. 50 10 .00 499. 97 443. 67 2 .15 0. 38 5957481. 93 377980. 65 2.50 -2. 07 600 .00 5. 00 10 .00 599. 75 543. 45 8 .59 1. 51 5957488. 35 377981. 89 2.50 -8. 26 700 .00 7. 50 10 .00 699. 14 642. 84 19 .31 3. 40 5957499. 04 377983. 96 2.50 -18. 56 800 .00 6. 58 346 .49 798. 41 742. 11 31 .31 3. 20 5957511. 04 377983. 95 3.00 -30. 46 900 .00 6. 95 321 .02 897. 73 841. 43 41 .60 -1. 95 5957521. 41 377978. 96 3.00 -41. 41 1000 .00 8. 44 301 .39 996 .85 940. 55 50 .13 -12. 03 5957530. 10 377969. 03 3.00 -51. 38 1100 .00 10. 59 288 .61 1095 .48 1039. 18 56 .89 -27. 01 5957537. 11 377954. 16 3.00 -60. 35 1200 .00 13. 08 280 .36 1193 .35 1137. 05 61 .86 -46. 85 5957542. 39 377934. 40 3.00 -68. 29 1300 .00 15, 74 274 .77 1290 .20 1233. 90 65 .02 -71. 50 5957545. 96 377909. 81 3.00 -75. 18 1368 .69 17. 63 271 .91 1356 .00 1299. 70 66 .14 -91 .18 5957547. 40 377890. 15 3.00 -79. 30 Base Permafrost 1400 .00 18. 50 270 .80 1385. 76 1329. 46 66. 37 -100. 88 5957547. 78 377880. 45 3.00 -81. 00 1500 .00 21. 33 267 .83 1479. 78 1423. 48 65 .90 -134. 93 5957547. 87 377846. 41 3.00 -85. 74 1600 .00 24. 19 265 .53 1571. 98 1515. 68 63 .62 -173. 54 5957546. 21 377807. 77 3.00 -89. 38 1700 .00 27. 09 263 .70 1662. 13 1605. 83 59 .52 -216. 60 5957542. 82 377764. 65 3.00 -91. 91 1786 .15 29. 59 262 .39 1737. 95 1681. 65 54 .55 -257. 19 5957538. 51 377723. 99 3.00 -93. 20 1800 .00 29. 59 262 .39 1749. 99 1693. 69 53 .65 -263. 97 5957537. 71 377717. 20 0.00 -93. 34 1900 .00 29. 59 262 .39 1836. 95 1780. 65 47 .11 -312. 92 5957531. 97 377668. 15 0.00 -94. 36 2000 .00 29. 59 262 .39 1923. 90 1867. 60 40 .57 -361. 87 5957526. 22 377619. 10 0.00 -95. 37 2100 .00 29. 59 262 .39 2010. 85 1954. 55 34 .03 -410. 82 5957520. 48 377570. 06 0.00 -96. 38 2200 .00 29. 59 262 .39 2097. 81 2041. 51 27 .49 -459. 78 5957514. 73 377521. 01 0.00 -97. 40 2300 .00 29. 59 262 .39 2184. 76 2128. 46 20 .95 -508. 73 5957508. 99 377471. 96 0.00 -98. 41 2324 .43 29. 59 262. 39 2206. 00 2149. 70 19. 35 -520. 68 5957507. 59 377459. 98 0.00 -98. 66 C-40 2400 .00 29. 59 262. 39 2271. 72 2215. 42 14. 41 -557. 68 5957503. 24 377422. 92 0.00 -99. 43 2500 .00 29. 59 262. 39 2358. 67 2302. 37 7. 87 -606. 63 5957497. 50 377373. 87 0.00 -100. 44 2565 .93 29. 59 262 .39 2416. 00 2359. 70 3. 55 -638. 90 5957493. 71 377341. 53 0.00 -101. 11 C-30 2600 .00 29. 59 262 .39 2445. 62 2389. 32 1. 32 -655. 58 5957491. 75 377324. 82 0.00 -101. 45 2700 .00 29. 59 262 .39 2532. 58 2476. 28 -5. 22 -704. 53 5957486. 01 377275. 77 0.00 -102. 47 2800 .00 29. 59 262 .39 2619. 53 2563. 23 -11. 76 -753. 48 5957480. 27 377226. 73 0.00 -103. 48 2900 .00 29. 59 262 .39 2706. 49 2650. 19 -18. 30 -802. 43 5957474. 52 377177. 68 0.00 -104. 50 2968 .44 29. 59 262 .39 2766. 00 2709. 70 -22. 77 -835. 94 5957470. 59 377144. 11 0.00 -105. 19 C-20 3000 .00 29. 59 262 .39 2793. 44 2737. 14 -24 .84 -851. 39 5957468. 78 377128. 63 0.00 -105. 51 3100 .00 29. 59 262 .39 2880. 39 2824. 09 -31. 38 -900. 34 5957463. 03 377079. 59 0.00 -106. 53 3200 .00 29. 59 262 .39 2967. 35 2911. 05 -37 .92 -949. 29 5957457. 29 377030. 54 0.00 -107. 54 3300 .00 29. 59 262. 39 3054. 30 2998. 00 -44. 46 -998. 24 5957451. 54 376981. 49 0.00 -108. 55 3400 .00 29. 59 262. 39 3141. 25 3084. 95 -51. 00 -1047. 19 5957445. 80 376932. 45 0.00 -109. 57 3500 .00 29. 59 262. 39 3228. 21 3171. 91 -57. 54 -1096. 14 5957440. 05 376883. 40 0.00 -110. 58 3600 .00 29. 59 262. 39 3315. 16 3258. 86 -64. 08 -1145. 09 5957434. 31 376834. 35 0.00 -111. 60 3700 .00 29. 59 262. 39 3402. 12 3345. 82 -70. 62 -1194. 05 5957428. 57 376785. 30 0.00 -112. 61 3800 .00 29. 59 262 .39 3489. 07 3432. 77 -77. 16 -1243. 00 5957422. 82 376736. 26 0.00 -113. 62 3900 .00 29. 59 262 .39 3576. 02 3519. 72 -83. 70 -1291. 95 5957417. 08 376687. 21 0.00 -114. 64 4000 .00 29. 59 262 .39 3662. 98 3606. 68 -90. 24 -1340. 90 5957411. 33 376638. 16 0.00 -115. 65 4100 .00 29. 59 262 .39 3749. 93 3693. 63 -96 .78 -1389. 85 5957405. 59 376589. 12 0.00 -116. 67 4200 .00 29. 59 262 .39 3836. 89 3780. 59 -103 .32 -1438. 80 5957399. 84 376540. 07 0.00 -117 .68 4204 .73 29. 59 262 .39 3841. 00 3784. 70 -103 .63 -1441. 12 5957399. 57 376537. 75 0.00 -117. 73 K-3 4300 .00 29. 59 262 .39 3923. 84 3867. 54 -109 .86 -1487. 75 5957394. 10 376491. 02 0.00 -118. 69 4400 .00 29. 59 262. 39 4010. 79 3954. 49 -116. 40 -1536. 70 5957388. 35 376441. 98 0.00 -119. 71 4486 .49 29. 59 262. 39 4086. 00 4029. 70 -122. 06 -1579. 04 5957383. 39 376399. 56 0.00 -120. 59 K-2 4500 .00 29. 59 262. 39 4097. 75 4041. 45 -122. 94 -1585. 66 5957382. 61 376392. 93 0.00 -120. 72 oRiciNa~ ~OnOCOPhllll s Alaska Inc• P CPAI Report Company: ConocoPhillips Alaska inc. Date: 10/10/2006 Time: 09:48:58 Pager 3 :Field: Colville River Un it Go-ordnate(NE) Reference: Well: Ptan: CD4-211, True North Site: Al pine CD4 Vertical (TVD) Reference: Plan: CD4-211 56.3 We1L• Plan: C D4-211 Sec tion (VS) Refere nce: Well {O.OON,O.OOE,171 .21Azi) Wellpath: Plan: C D4-211wp05 Survey Calculation Metbod: M inimum Curvature Db: OraCle Survey MD Incl Azim TVD Sys TVl) N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft -degl100ft ft 4600 .00 29. 59 262 .39 4184. 70 4128. 40 -129. 48 -1634. 61 5957376 .87 376343. 88 0.00 -121. 74 4601 .49 29. 59 262. 39 4186. 00 4129. 70 -129. 58 -1635. 34 5957376 .78 376343. 15 0.00 -121. 75 K-2 Base 4700 .00 29. 59 262 .39 4271. 66 4215. 36 -136. 02 -1683. 56 5957371 .12 376294. 84 0.00 -122. 75 4800 .00 29. 59 262 .39 4358. 61 4302. 31 -142. 56 -1732. 51 5957365 .38 376245. 79 0.00 -123. 76 4900 .00 29. 59 262 .39 4445. 56 4389. 26 -149. 10 -1781. 46 5957359 .63 376196. 74 0.00 -124. 78 4938 .71 29. 59 262 .39 4479. 23 4422. 93 -151. 64 -1800. 41 5957357 .41 376177. 75 0.00 -125. 17 5000 .00 28. 89 258 .24 4532. 71 4476. 41 -156. 66 -1829. 91 5957352 .87 376148. 18 3.50 -124. 72 5100 .00 28. 02 251 .12 4620. 65 4564. 35 -169. 18 -1875. 80 5957341 .09 376102. 10 3.50 -119. 34 5200 .00 27. 55 243 .68 4709. 15 4652. 85 -187. 05 -1918. 77 5957323 .93 376058. 85 3.50 -108. 26 5300 .00 27. 47 236 .10 4797. 87 4741. 57 -210. 17 -1958. 65 5957301 .45 376018. 60 3.50 -91. 50 5400 .00 27. 81 228 .58 4886. 48 4830. 18 -238. 48 -1995. 30 5957273 .75 375981. 50 3.50 -69. 12 5500 .00 28. 54 221 .33 4974. 66 4918. 36 -271 .86 -2028. 58 5957240 .92 375947. 68 3.50 -41. 22 5600 .00 29. 64 214. 49 5062. 07 5005. 77 -310. 19 -2058. 37 5957203 .08 375917. 28 3.50 -7. 89 5700 .00 31. 06 208. 16 5148. 39 5092. 09 -353. 32 -2084. 55 5957160 .38 375890. 40 3.50 30. 74 5800 .00 32. 77 202. 37 5233. 29 5176. 99 -401. 11 -2107. 03 5957112 .97 375867. 15 3.50 74. 53 5900 .00 34. 71 197. 13 5316. 46 5260. 16 -453. 36 -2125. 73 5957061 .03 375847. 61 3.50 123. 31 6000 .00 36. 86 192. 41 5397. 59 5341. 29 -509. 88 -2140. 56 5957004 .76 375831. 86 3.50 176. 90 6100 .00 39. 18 188. 15 5476. 37 5420. 07 -570. 46 -2151. 49 5956944 .37 375819. 95 3.50 235. 11 6200 .00 41. 64 184. 30 5552. 52 5496. 22 -634. 88 -2158. 46 5956880 .08 375811. 94 3.50 297. 71 6300 .00 44. 22 180. 82 5625. 75 5569. 45 -702. 89 -2161. 46 5956812 .13 375807. 84 3.50 364. 46 6400 .00 46. 89 177. 65 5695. 78 5639. 48 -774. 25 -2160. 46 5956740 .77 375807. 67 3.50 435. 14 6500 .00 49. 64 174. 75 5762. 35 5706. 05 -848. 68 -2155. 48 5956666 .27 375811. 45 3.50 509. 45 6600 .00 52. 46 172. 08 5825. 22 5768. 92 -925. 91 -2146. 54 5956588 .92 375819. 14 3.50 587. 14 6642 .91 53. 68 171. 00 5851. 00 5794. 70 -959. 84 -2141. 49 5956554 .92 375823. 63 3.50 621. 44 Albian 97 6700 .00 55. 33 169. 61 5884. 15 5827. 85 -1005. 65 -2133. 65 5956508 .99 375830. 72 3.50 667. 92 6800 .00 58. 25 167. 30 5938. 92 5882. 62 -1087. 60 -2116. 89 5956426 .78 375846. 16 3.50 751. 47 6900 .00 61. 21 165. 14 5989. 32 5933. 02 -1171. 46 -2096. 30 5956342 .61 375865. 38 3.50 837. 49 7000 .00 64. 20 163. 09 6035. 18 5978. 88 -1256. 91 -2071. 96 5956256 .78 375888. 32 3.50 925. 65 7100 .00 67. 22 161. 15 6076. 31 6020. 01 -1343. 64 -2043. 97 5956169 .61 375914. 90 3.50 1015. 64 7200 .00 70. 26 159. 29 6112. 57 6056. 27 -1431. 32 -2012. 42 5956081 .44 375945. 02 3.50 1107. 10 7300 .00 73. 32 157. 50 6143. 81 6087. 51 -1519. 62 -1977. 45 5955992 .59 375978. 55 3.50 1199. 71 7400 .00 76. 40 155. 77 6169. 93 6113. 63 -1608. 22 -1939. 17 5955903 .39 376015. 39 3.50 1293. 12 7426 .61 77. 22 155. 32 6176. 00 6119. 70 -1631. 80 -1928. 44 5955879 .64 376025. 73 3.50 1318. 06 Top Nanuq (Albi 7500 .00 79. 48 154. 08 6190. 82 6134. 52 -1696. 78 -1897. 73 5955814 .18 376055. 38 3.50 1386. 97 7600 .00 82. 58 152. 43 6206. 41 6150. 11 -1784. 97 -1853. 28 5955725 .28 376098. 39 3.50 1480. 92 7700 .00 85. 68 150. 80 6216. 63 6160. 33 -1872. 47 -1806. 00 5955637 .03 376144. 24 3.50 1574. 62 7793 .05 88. 57 149. 29 6221. 30 6165. 00 -1952. 98 -1759. 60 5955555 .79 376189. 32 3.50 1661. 27 CD4-211wp05 T 7800 .00 88. 51 149. 09 6221. 48 6165. 18 -1958. 95 -1756. 04 5955549 .76 376192. 78 3.00 1667. 71 7806 .65 88. 45 148. 90 6221. 65 6165. 35 -1964. 65 -1752. 62 5955544 .01 376196. 11 3.00 1673. 87 7900 .00 88. 45 148. 90 6224. 17 6167. 87 -2044. 55 -1704. 42 5955463 .34 376243. 00 0.00 1760. 19 8000 .00 88. 45 148. 90 6226. 87 6170. 57 -2130. 15 -1652. 79 5955376 .92 376293. 23 0.00 1852. 67 8100 .00 88. 45 148. 90 6229. 57 6173. 27 -2215. 75 -1601. 16 5955290 .50 376343. 46 0.00 1945. 15 8200. 00 88. 45 148. 90 6232. 27 6175. 97 -2301. 35 -1549. 53 5955204 .09 376393. 69 0.00 2037. 64 8300. 00 88. 45 148. 90 6234. 97 6178. 67 -2386. 95 -1497. 90 5955117 .67 376443. 92 0.00 2130. 12 8400. 00 88. 45 148. 90 6237. 67 6181. 37 -2472. 54 -1446. 27 5955031 .25 376494. 15 0.00 2222. 60 8500. 00 88. 45 148. 90 6240. 37 6184. 07 -2558. 14 -1394. 64 5954944 .83 376544. 38 0.00 2315. 08 8600 .00 88. 45 148. 90 6243. 07 6186. 77 -2643. 74 -1343. 01 5954858 .41 376594. 61 0.00 2407. 56 8700. 00 88. 45 148. 90 6245. 77 6189. 47 -2729. 34 -1291. 38 5954772 .00 376644. 84 0.00 2500. 04 8800 .00 88. 45 148. 90 6248. 47 6192. 17 -2814. 94 -1239. 75 5954685 .58 376695. 07 0.00 2592. 52 8814 .75 88. 45 148. 90 6248. 86 6192. 56 -2827. 56 -1232. 14 5954672 .83 376702. 48 0.00 2606. 16 8900 .00 89. 18 151. 35 6250. 62 6194. 32 -2901. 47 -1189. 69 5954598 .26 376743. 71 3.00 2685. 68 8995 .13 90. 00 154. 09 6251. 30 6195. 00 -2986. 00 -1146. 10 5954513 .03 376785. 92 3.00 2775. 88 CD4-211wp05 T 96 ORIGINAL ~OnOCOPhllli s Alaska Inc! P CPAI Report Company: ConocoPhillips Alaska lnc. Date: 10110/2006 Tinxe: 09:48:58 Page:_ 4 Ftield: Colville River Unit Co-ordinate(NE) References Well: Plan: GD4-21:1, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-211 56.3 Well: Plan: CD4-2T1 Section(VS)Reference: Well (O.OON,O.OOE,171:21Azi) Wellpatb: Plan: CD4-211wp05 Survey Caleu[atiod Nletbod: Minimum. Curvature Db: Oracle Survey MD ft 9000.00 9071.71 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10100.00 10117.60 10194.20 10200.00 10300.00 10302.92 10400.00 10500.00 10600.00 10700.00 10800.00 10900.00 10985.11 11000.00 11093.83 11100.00 11200.00 11216.65 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11871.85 11900.00 11994.66 12000.00 12080.53 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13107.18 Iucl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 90.15 154.09 6251.29 6194.99 -2990.39 -1143.97 92.30 154.09 6249.76 6193.46 -3054.87 -1112.64 92.30 154.09 6248.63 6192.33 -3080.30 -1100.29 92.30 154.09 6244.62 6188.32 -3170.17 -1056.63 92.30 154.09 6240.61 6184.31 -3260.05 -1012.97 92.30 154.09 6236.60 6180.30 -3349.92 -969.31 92.30 154.09 6232.59 6176.29 -3439.80 -925.65 92.30 154.09 6228.59 6172.29 -3529.68 -881.99 92.30 154.09 6224.58 6168.28 -3619.55 -838.33 92.30 154.09 6220.57 6164.27 -3709.43 -794.67 92.30 154.09 6216.56 6160.26 -3799.31 -751.01 92.30 154.09 6212.55 6156.25 -3889.18 -707.35 92.30 154.09 6208.54 6152.24 -3979.06 -663.69 92.30 154.09 6207.84 6151.54 -3994.88 -656.01 90.00 154.05 6206.30 6150.00 -4063.75 -622.52 89.83 154.05 6206.31 6150.01 -4068.96 -619.98 86.83 154.05 6209.23 6152.93 -4158.83 -576.24 86.74 154.04 6209.39 6153.09 -4161.45 -574.97 86.74 154.04 6214.92 6158.62 -4248.60 -532.55 86.74 154.04 6220.61 6164.31 -4338.36 -488.85 86.74 154.04 6226.30 6170.00 -4428.13 -445.16 86.74 154.04 6231.99 6175.69 -4517.90 -401.46 86.74 154.04 6237.67 6181.37 -4607.67 -357.76 86.74 154.04 6243.36 6187.06 -4697.44 -314.07 86.74 154.04 6248.21 6191.91 -4773.83 -276.88 87.19 154.05 6249.00 6192.70 -4787.21 -270.37 90.00 154.07 6251.30 6195.00 -4871.55 -229.35 90.19 154.07 6251.29 6194.99 -4877.10 -226.65 93.19 154.07 6248.35 6192.05 -4966.99 -182.95 93.68 154.07 6247.35 6191.05 -4981.93 -175.69 93.68 154.07 6242.00 6185.70 -5056.74 -139.32 93.68 154.07 6235.57 6179.27 -5146.49 -95.69 93.68 154.07 6229.14 6172.84 -5236.24 -52.06 93.68 154.07 6222.72 6166.42 -5325.99 -8.43 93.68 154.07 6216.29 6159.99 -5415.74 35.20 93.68 154.07 6209.86 6153.56 -5505.49 78.83 93.68 154.07 6205.25 6148.95 -5569.97 110.18 92.84 154.07 6203.65 6147.35 -5595.25 122.47 90.00 154.07 6201.30 6145.00 -5680.35 163.84 89.84 154.07 6201.31 6145.01 -5685.15 166.18 87.42 154.07 6203.23 6146.93 -5757.55 201.38 87.42 154.07 6204.10 6147.80 -5775.04 209.89 87.42 154.07 6208.60 6152.30 -5864.88 253.57 87.42 154.07 6213.09 6156.79 -5954.72 297.26 87.42 154.07 6217.59 6161.29 -6044.56 340.94 87.42 154.07 6222.08 6165.78 -6134.40 384.63 87.42 154.07 6226.58 6170.28 -6224.24 428.31 87.42 154.07 6231.07 6174.77 -6314.08 472.00 87.42 154.07 6235.56 6179.26 -6403.92 515.69 87.42 154.07 6240.06 6183.76 -6493.77 559.37 87.42 154.07 6244.55 6188.25 -6583.61 603.06 87.42 154.07 6249.05 6192.75 -6673.45 646.74 87.42 154.07 6249.37 6193.07 -6679.90 649.88 MapN MapE DLS VS Comme 1 ft ft deg/100ft ft 5954508.61 376787.98 3.00 2780.54 5954443.63 376818.25 3.00 2849.05 5954418.01 376830.19 0.00 2876.07 5954327.45 376872.38 0.00 2971.56 5954236.88 376914.57 0.00 3067.05 5954146.32 376956.76 0.00 3162.54 5954055.75 376998.96 0.00 3258.03 5953965.19 377041.15 0.00 3353.52 5953874.62 377083.34 0.00 3449.01 5953784.05 377125.53 0.00 3544.50 5953693.49 377167.72 0.00 3639.99 5953602.92 377209.91 0.00 3735.48 5953512.36 377252.11 0.00 3830.97 5953496.42 377259.53 0.00 3847.78 5953427.02 377291.90 3.00 3920.96 CD4-211wp05 T 5953421.76 377294.35 3.00 3926.50 5953331.21 377336.62 3.00 4021.99 5953328.56 377337.86 3.00 4024.78 5953240.75 377378.85 0.00 4117.38 5953150.29 377421.08 0.00 4212.77 5953059.83 377463.31 0.00 4308.16 5952969.38 377505.54 0.00 4403.55 5952878.92 377547.77 0.00 4498.94 5952788.46 377590.00 0.00 4594.33 5952711.48 377625.94 0.00 4675.51 5952698.00 377632.23 3.00 4689.72 5952613.01 377671.87 3.00 4779.34 CD4-211wp05 T 5952607.42 377674.48 3.00 4785.24 5952516.84 377716.71 3.00 4880.75 5952501.78 377723.73 3.00 4896.62 5952426.40 377758.88 0.00 4976.11 5952335.96 377801.04 0.00 5071.47 5952245.52 377843.21 0.00 5166.83 5952155.08 377885.37 0.00 5262.20 5952064.64 377927.53 0.00 5357.56 5951974.20 377969.70 0.00 5452.92 5951909.22 377999.99 0.00 5521.43 5951883.75 378011.87 3.00 5548.29 5951798.00 378051.85 3.00 5638.71 CD4-211wp05 T 5951793.16 378054.11 3.00 5643.81 5951720.21 378088.13 3.00 5720.73 5951702.58 378096.35 0.00 5739.32 5951612.05 378138.57 0.00 5834.78 5951521.52 378180.79 0.00 5930.24 5951430.99 378223.00 0.00 6025.70 5951340.46 378265.22 0.00 6121.16 5951249.93 378307.44 0.00 6216.62 5951159.40 378349.66 0.00 6312.08 5951068.87 378391.88 0.00 6407.54 5950978.34 378434.10 0.00 6503.00 5950887.81 378476.31 0.00 6598.46 5950797.28 378518.53 0.00 6693.92 5950790.78 378521.56 0.00 6700.78 ,,~~~~ ~OnOCOPhllli s Alaska Inc• P CPAI Report Company: ConocoPhillips Alaska Inc. Dater 10/10/2006 Time: 09:48:58 Page: 5 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-211, True North .'Site: Alpine CD4 Vertical (TVD) Reference; Plan: CD4-211 56.3 Well: Plan: CD4-211 Section (VS) Reference; Well (O.OON,O.OOE,171.21Azi) Wellpath: Plan: CD4-211wp05 Survey Calculation Method: Minimum Curvature Db; Oracle Survey MD Inc/ Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 13193.05 90.00 154.09 6251.30 6195.00 -6757.10 687.40 5950712.98 378557.83 3.00 6782.80 CD4-211wp05 T 13200.00 90.21 154.09 6251.29 6194.99 -6763.35 690.44 5950706.68 378560.76 3.00 6789.45 13275.53 92.47 154.09 6249.52 6193.22 -6831.27 723.44 5950638.24 378592.65 3.00 6861.61 13300.00 92.47 154.09 6248.46 6192.16 -6853.26 734.12 5950616.09 378602.97 0.00 6884.97 13400.00 92.47 154.09 6244.14 6187.84 -6943.12 777.77 5950525.54 378645.16 0.00 6980.45 13500.00 92.47 154.09 6239.83 6183.53 -7032.99 821.43 5950434.98 378687.35 0.00 7075.92 13600.00 92.47 154.09 6235.51 6179.21 -7122.85 865.09 5950344.43 378729.53 0.00 7171.40 13700.00 92.47 154.09 6231.19 6174.89 -7212.71 908.74 5950253.88 378771,72 0.00 7266.88 13800.00 92.47 154.09 6226.87 6170.57 -7302.58 952.40 5950163.32 378813.91 0.00 7362.36 13900.00 92.47 154.09 6222.56 6166.26 -7392.44 996.06 5950072.77 378856.10 0.00 7457.83 14000.00 92.47 154.09 6218.24 6161.94 -7482.30 1039.71 5949982.22 378898.29 0.00 7553.31 14100.00 92.47 154.09 6213.92 6157.62 -7572.17 1083.37 5949891.67 378940.48 0.00 7648.79 14200.00 92.47 154.09 6209.60 6153.30 -7662.03 1127.03 5949801.11 378982.67 0.00 7744.27 14300.00 92.47 154.09 6205.29 6148.99 -7751.89 1170.68 5949710.56 379024.85 0.00 7839.75 X14392.31 92.47 154.09 6201.30 ~ 6145.00 -7834.85 1210.98 5949626.97 379063.80 0.00 7927.88 CD4-211wp05T Targets Map Map <---- Latitude ---> <--- Longitude --> `Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft' ft CD4-211wp05 T5 6201.30 -5680.35 163.84 5951798.00 378051.85 70 16 36.613 N 150 59 11,637 W CD4-211wp05 T7 6201.30 -7834.85 1210.98 5949626.97 379063.80 70 16 15.423 N 150 58 41.155 W CD4-211wp05 T3 6206.30 -4063.75 -622.52 5953427.02 377291.90 70 16 52.512 N 150 59 34.540 W CD4-211wp05 T1 6221.30 -1952.98 -1759.60 5955555.79 376189.32 70 17 13.270 N 151 0 7.673 W CD4-211wp05 T2 6251.30 -2986.00 -1146.10 5954513.03 376785.92 70 17 3.111 N 150 59 49.795 W CD4-211wp05 T6 6251.30 -6757.10 687.40 5950712.98 378557.83 70 16 26.023 N 150 58 56.394 W CD4-211wp05 T4 6251.30 -4871.55 -229.35 5952613.01 377671.87 70 16 44.568 N 150 59 23.088 W Annotation MD TVD ft ft 36.30 0.00 Surface Location 400.00 400.00 KOP; 2 .5 DLS, 400' MD 700.00 699.14 Build; 3 DLS, 700' MD 1786.15 1737.95 Sail 29. 59 Inc, 1786' MD for 3152' 2547.53 2400.00 9 5/8" csg pt, 2400' TVD 4938.71 4479.22 Build 3. 5 DLS, 4479' TVD 7793.05 6221.30 7" csg pt, 6221' TVD, 7793' MD 8995.13 6251.30 T2 10194.20 6206.30 T3 11093.83 6251.30 T4 11994.66 6201.30 T5 13193.05 6251.30 T6 14392.30 6201.30 TD, 14392' MD, CD4-211wp05 Casing Points MD TVD Diameter Hole Size Name ft ft in in 2547.53 2400.00 9.625 12.250 9 5/8" 7793.05 6221.30 7.000 8.750 7" 14392.31 6201.30 6.125 6.125 6 1/8" Open Hole ORIGINAL ~OnOCOPhllli s Alaska Inc• P CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/10/2006 Time: 09:48:58 Page: 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-211; True North Site: Alpine CD4 Vertical (TVD) Reference: Plan: CI?4-211 56.3 We1L• Plan: CD4-21.4 Section (VS) Reference: WeIF(O.OON,O.OOE,171.21Azi) Wellpath: Plan: CD4-211vrp05 Survey CaleulaHon Method: Minimum Curvature I)b: Oracle Formations MD TVD Formations Litbology Dip Angle .Dip Direction ft ft deg ' deg. 1368.69 1356.00 Base Permafrost 0.00 0.00 2324.43 2206.00 C-40 0.00 0.00 2565.93 2416.00 C-30 0.00 0.00 2968.44 2766.00 C-20 0.00 0.00 4204.73 3841.00 K-3 0.00 0.00 4486.49 4086.00 K-2 0.00 0.00 4601.49 4186.00 K-2 Base 0.00 0.00 6642.91 5851.00 Albian 97 0.00 0.00 7426.61 6176.00 Top Nanuq (Albian 96) 0.00 0.00 ORIGINAL ~OnOCOPhllli s Alaska, Inc• P Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 10/9/2006. Time: 16:15:07 Page:. 1 ' Field: Colville River tlnit Reference Site: Alpine CD4 Co-ordinate{NE) Reference: WeH:.Pla n: CD4-211, True North ; Reference Well: Plan: CD4-211 Vertical (T~ D) Reference: Plan: CD4-211 56.3 Reference Wellpath: Plan: CD4-211wp05 Dht Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of refe rence Reference: Plan: CD4-211wp05 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 14392 .31 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1635.60 ff Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft In _ in 2547.53 2400.00 9.625 12.250 9 5/8" 7793.05 6221.30 7.000 8.750 7" 14392.31 6201.30 6.125 6.125 6 1/8" Open Hole Plan: CD4-211wp05 Date Composed: 10/9/2006 Version : 6 PrincipaL• Yes Tied-to: From Well Ref. Point Summary 4__W__~-_~__ Offset Wellpath ------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation . ....Warning ff ft ft ft ft Alpine CD4 CD4-208 CD4-208 V7 677.32 675.00 55.72 11.44 44.28 Pass: Major Risk Alpine CD4 CD4-208 CD4-208PB1 V6 677.32 675.00 55.72 11.44 44.28 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 600.00 600.00 33.70 10.91 22.78 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 644.28 625.00 17.09 10.97 6.12 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 351.38 350.00 142.17 7.41 134.76 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 350.34 350.00 142.15 7.39 134.76 Pass: Major Risk Alpine CD4 CD4-318 CD4-318P61 V3 351.38 350.00 142.17 7.41 134.76 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 300.75 300.00 162.07 6.07 156.00 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 1385.19 1375.00 170.48 21.89 148.59 Pass: Major Risk Alpine CD4 CD4-320 CD4-320PB1 V4 1385.19 1375.00 170.48 21.89 148.59 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 503.14 500.00 14.99 8.59 6.40 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 503.14 500.00 14.99 8.59 6.40 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 375.49 375.00 100.70 7.91 92.78 Pass: Major Risk Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: 504.03 500.00 160.90 10.24 150.66 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 351.19 350.00 140.44 7.34 133.10 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 752.49 750.00 112.92 15.68 97.24 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 126.17 125.00 100.77 2.59 98.18 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V2 Plan: 751.51 750.00 73.81 15.88 57.93 Pass: Major Risk Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 351.19 350.00 40.54 7.09 33.44 Pass: Major Risk Alpine CD4 Plan: CD4-214 Plan: CD4-214wp04 V2 P 424.92 425.00 60.20 8.96 51.23 Pass: Major Risk Alpine CD4 Plan: CD4-215 Plan: CD4-215 V1 Plan: 326.20 325.00 80.25 6.57 73.68 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 VO Plan: 325.30 325.00 220.34 6.57 213.78 Pass: Major Risk Alpine CD4 Rig: CD4-17 Plan: CD4-17 V1 Plan: 400.49 400.00 120.23 8.37 111.86 Pass: Major Risk Alpine CD4 Rig: CD4-17 Prelim: CD4-17L1 V1 36.80 36.30 119.97 No Offset Stations Alpine CD4 Rig: CD4-17 Rig: CD4-17 V11 300.49 300.00 121.32 6.26 115.06 Pass: Major Risk Alpine CD4 Rig: CD4-321 Plan: CD4-321 V2 Plan: 376.00 375.00 200.43 7.88 192.55 Pass: Major Risk Alpine CD4 Rig: CD4-321 Rig: CD4-321 V4 300.99 300.00 200.93 6.09 194.84 Pass: Major Risk Alpine CD4 Slot 1 open for futu Slot 1 open for future 37.30 0.00 199.91 No Offset Stations Alpine CD4 Slot 2 open for futu Slot 2 open for future 37.30 0.00 179.92 No Offset Stations Alpine Nanuq EIS P a~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 56.30 0.00 169.98 No Offset Stations Alpine Nanuq EIS P a~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 56.30 0.00 169.98 No Offset Stations )GRAM ~ ~ ~ ~ ~ i WELL DF.TAII.S AMICOLLISION SFTTMli3 COMPANY UETAl1.5 ~N/-S +F/-W Nwlhing Earring I.alirvd< Longitude 51^1 Inlerryalation MelhodMD Ik h R F 36 30 Interval'. 25(N) ' 1439231 T Cun^coPh0lipa Aluka lnc. Engin<rnng CD/-211 -1944 -193.70 59574]9.79 3]7980.21 70°IJ'32479N 150°59'16.4UBW NA pl ange rom . Manlmlun Range 1435 GO o Reremnce Plan CDa-2113vpf15 Culcalalim Mahd. Minimum Curvarvr< I:rr^r Svsrvm ISCWSA Swn MclhoJ Trvv C~lindcr NoM h;rror Surfaw Elhpucal . C-umg W arcing MethoJ Rolex Bavnl From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 6750 6750 7000 7000 7250 T~sn ~snnn 75 0 0 I7 8 0 D4-204 (Plan'. CD4-204) 'D4-206 (Plan: CD4-206) 8 l7 CD4-203 (Plan: CD4-203) 25 $$~~~~ ~~~ Lip SNtvEV Mlrx:NAM DyN Fm Doak Ta 4n'gPlan Tad IOW W 14.9231 Mwrd r'Da.illop~115 J'4 MWM6R-AI({A] SL • t-209) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [2~fVin] 150 LEGEND CU4-2081CIYf-208). MelOr ILsk Plan CIN-207 (Plan C-D4-207). Myor Risk CP1-2Ug (CIN-208PB 1), Major Riak 09 IN 09 CD M R k ~ Plao.C'P1-217 (PIan:CD4-217), Major Rixk 04 ~ Pl CD4 214 Pl CIN 214 M R k (C -2 ). a1nr 4-3 1s CD4-21U (CD4-210). Major Risk ajor an - ( an - np ). u ~ Plmr CD4-215 (Plan: C'U4-215), Major Risk CD4-318 (CDd-318). Mayor Rut %u CD4-222 (Plan C-Dd-222). Mayor Rixk CD4-318 (CIN-318A). Major Rixk ~ Rig.CU4-1]IPlan CIN-171, MOjOr Rixk ~CrN-318 (CIN-318PB1).Mm^r klsk ~R1g CD4-1](Prclim CD4-I]I.I). Ma3or Rixk '-- CD4-J I9 (CD4-31.1). Major lLsk ~ Rig.CU4-1]IRiB'. CIN-IJ), Mnjor Risk CD4-320 (CD1-320). MyOr Rrxk Rig CD4-321 (Plan CD4-121). Major R1xk CD4-l2U ICU4-32oPB D. Major Ruk ~ Rig CIN-3211Rig'.CW-32n. Major Rixk Nuuq 5 Muuq 5). Mayor A1ak ~ SIo1 l ^pm1 for future well (SI^I 1 open (^r fuwrc well). Mm i Nonuq 5 (Plan: CIN-212). Major Ruk PIno CM-I6 (Plan.. CU4-16). Major Niak ~ SIo12 open (or future well (Slot 2 open for fuwrc well). Mai 1 ~ Plan Nuug4(Prclim: Nanug4ln A). Major Risk -~ Plan: CDd-2UJ IPlwa. ClN-2Ul). Mal^r Ruk Plan: Navug4 (Prelim. Nanuq 4 Lat e). Major Rixk Plu: t'D4-204 (Plan. 1-D4-2041. Mejnr Ruk Plan CIN-205 (Plvr 1W-2057. Mejnr Risk ~ Plan: C'Dd-211wp05 ~ CU4-211wp05 Rrak Riak SECTION DETAILS Sec MD Inc Av TVD xN/-S +FJ-W DL<g TFece VSec Target 1 ]6.30 0.00 0 00 36 JO 0.00 000 0.00 0.00 000 2 411000 000 000 JW.00 000 000 000 0110 000 3 70000 ].50 1000 699.14 19.11 140 2.50 1000 -18.56 4 1781515 29.59 2fi219 173793 Sd 55 -23719 100 -11907 -9120 5 493871 29.59 26239 447923 -151.64 -I M100.41 000 000 -12517 G 7797 OS BB 57 14929 622130 -195298 -175960 350 -11102 166127 CD4-211avpo5 Tl ] ]BUG GS 8845 14890 422145 -194445 -175262 300 -106.57 IG]38] 8 8814]3 88 d5 14890 624886 -262]56 -12]2.14 000 000 260616 9 8995.13 9000 15409 625130 -298400 -1146.10 3.00 73.44 27]5 Btl CDF211wp05 T2 10 90] 1 71 92 JO 154 09 6249 76 -3054 8] -1112 64 100 001 2849 05 II 1011760 92.30 ISa n9 420784 -3994.88 636.01 000 0.00 3847.78 12 1019420 9000 ISd 05 620610 x061]5 62252 300 -17891 192096 CD4-211wp05 T3 13 1030292 86.74 15404 420939 -016145 -574.97 1.00 -1]99] 4024 ]tl 14 109R5 11 84.74 154 04 624R 21 -0771 BJ -276.88 000 000 16]5 31 IS 1109363 9000 IS4 n] 4251.70 -087155 -229.35 100 0.51 47]9.34 CUJ-211wpn5 T4 16 1121665 91 b8 ISd 07 624].35 -098193 -17569 1.00 0.01 489662 I] 11871.85 9148 154117 420523 -554997 110.18 0.00 O.UO 5521.43 18 11994.66 90.00 15007 6201.30 -560.035 161.84 1.00 -179.92 561R.71 CD4-211wp05 T5 19 1208053 8702 1540] 62032) -575]55 20138 3n0 -179.98 572073 20 1310].IR 6142 ISIO] 624917 667990 649.88 0.00 0.00 6]00.]8 21 1119105 9(100 154 09 625110 6]57 10 68] JO 100 O d] fi]82 80 CIN-211wp03 T6 22 1127533 92.97 13109 6249.32 681127 727.44 3.00 000 686161 2J 1]39211 924] ISd 09 620130 -781485 1210.98 0.00 000 ]92788 CDL211wp05 T7 WFILPATN DETi11.5 Pkn. CIN-71I..p05 Rib. Dovm 19 Raf D.11n11. %.n:mszu w.:aR l'Sealxon Qum (kitm Branin!! Antk 1]171° ~TVS +E'-W" 000 O00 Frvm l'SD 3430 From Colour To MD 36 250 stn 500 750 1000 1250 6750 7000 7250 25000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] 200 -200 0 N u ,-, -400 0 ~~ -600 .S-i ~--+ 0 -000 -1000 8000 60 00 4000 20 00 0 2000 4000 60 00 80 00 We st(-)/East(+ ) [2000ft/in] CD4-210 CD4-210 D4-208 CD4-208PB1 Nanu 5 Plan: CD4-212 CD4-319 CD4-319 500 CD4-320 CD4-320PB1 ~~ Ri :CD4-17 Prelim: CD4-17L1 __~ Nanu 3 Nanu 3 7500 00 Ri :CD4-321 Ri :CD4-321 00 ~~ AO 50 2500 0 Ri :CD4-17 Ri :CD4-17 50 2500 5 0 250 500 Ri :CD4-32 1 Plan: CD4-321 • s 00 o0 5 0 50 0 CD4-318 C D4-318PB 1 CD4-320 CD4-320 CD4-318 CD4-318A ~~ CD4-21 ~ -209 CD 1w OS OS 4-209 Nanu 5 Nanu 5 0 0 0 0 O 0 0 ,yo4 ;~ 200 O l -200 S~ O O O -400 + 0 ~-, -600 O -800 -1000 -80 00 -60 00 -40 00 -20 00 0 20 00 40 00 60 00 80 00 We st(-)/East(+ ) [2000ft/in] ~~l \G 4 ~ti0 $ IGpA , :Lp ~~g~l oq~. ~ ICOA G~p OA ,~p4 . Cp4.21 \y'. 1 ~ C ~~UqS l4 ~ ~~,pIGQ GOp,L gl ?° Qp5 .fiA~~n~ R yo9l p9 ~C9 ~V pp,''L ~n ~'~~O ~ `,.. ~y~o45 ~~aruQ51 ~i~ ~ n ~ • 0 0 0 0 0 0 0 Closest in POOL . G~: s`y~ :~` ~...-~ Closest Approach: Reference Well: CD4-21 1wp05 Plan Offse t Well: CD4- 210 ' Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. ND E(+)/W(_ (171.21°) Comments Depth Angle Azi. TVD E(+)/W(_ (171.21°) Comments POOL Min POOL Min Distance (1211.88 Distance (1211.88 ft) in POOL (7436 - ft) in POOL (7436 - 14392 MD) to CD4 14392 MD) to CD4 210 (7468 -11710 211wp05 Plan (7 1211.8 743 77.52 155.1 6121.6 595586 376031. 1329.94 r"iD) 746 85. 335. 6196.92 595703 375701. 132.039 - 11710 MD) Closest Approach: Reference Well: CD4-21 1wp05 Plan Offse t Well: Nanuq 5 Coords.- Coords.- 3-D ctr- ASP ASP ctr Min. ' -- Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. : Depth Angle Azi. TVD E(+)M/(- (171.21°) Comments Depth Angle Azi. TVD E(+)/W(_ (171.21°) Comments POOL Min POOL Min Distance (1320.04 Distance (1320.04 ft) in POOL (7436 - ft) in POOL (7436 - 14392 MD) to 14392 MD) to CD4 Nanuq 5 (6120 - 211wp05 Plan (61 1320.0 1418 92.4 1 6153.98 594981 378985. 7732.0 6260 TVDss) 1020 58.0 161. 6253.94 595037 380175. 7338.32 - 6260 TVDss) Closest Approach: Reference Well: CD4-211 wp05 Plan Offset Well: CD4-2 09 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)!S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. ND E(+)/W(_ (171.21°) Comments Depth Angle Azi. TVD E(+)/W(- (171.21°) Comments POOL Min POOL Min Distance (1387.3 ft Distance (1387.3 ft in POOL (7436 - in POOL (7436 - 14392 MD) to CD4 14392 MD) to CD4 209 (7237 - 13215 211wp05 Plan (72 1387. 14161 92.4 1 6155.0 594983 378974. 7708.1 MD) 1243 92.2 153. 6168.2 595043 380226. 7288.39 -13215 MD) Closest Approach: Reference Well: CD4-211 wp05 Plan Offset Well: CD4-2 08 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. InG. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(_ (171.21°) Comments Depth Angle Azi. TVD E(+)/W(- (171.21°) Comments POOL Min POOL Min Distance (1739.97 Distance (1739.97 ft) in POOL (7436 - ft) in POOL (7436 - 14392 MD) to CD4 14392 MD) to CD4 208 (7361 - 12792 211wp05 Plan (7 1739.9 7 77.5 155.1 6121.6 595586 376031. 1329.9 MD) 7361 85.8 333.1 6112.71 595685 377465. 551. - 12792 MD) CD4-211wp05 PoolSummary.xis 10/10/2006 9:37 AM • • a SHARON K. ALLSUP-DRAKE 1161 CONOCOPHILLIPS ATO 1530 zi ~y ~ ~~~ ~ ' 700 G ST. DATE /y (•~ 56-1551/441 <i ANCHORAGE AK 99501 :1 I~ ORDEROFE - 5~I-I~L U~l~~S^-~I ~~~~~C~_ I ~~GCI.OIJ '~ ~/Oc~ ~ DOLLARS 8 ~,.,.,~,,.,a.., J PMorganChase ~ ~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. /~ ,~ Columbus, OH .v ~.~, 7 ~/ ~ MEMO -----~ -~-- ~~-~~--- -=~ ---- ~:044~~55~L~:528747190792711.1~6L ~J~S~1~~~~ ~>~~'~~~~f ~~~~~~~~' FELL NAME G~1~GC ~.~1/ 7 ~l~ PTD~ ZOC~ - /S3 V Development Sers~ice Exploratory Stratigraphic Vest Non-Conventional W"ell Circle Appropriate Letter /Paragraphs to be Included an Transmittal Letter CE{ECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES .VfL`LTI LATERAL ~ The permit is for a new we(lbore segment of existing we[I ,' ~ (If last taro digits in API number are Permtt No. . API No. ~0- - ,between 60-69) Production should continue to be reported as a function of the original API number Mated above. ~~ PLOT HOLE In accordance with 20 :~~C 25.005(f), all records, data and logs ~I acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number ~~0- - -_~ from records. data and logs ;acquired for well ' !SPACING !' The permit is approved subject to full compliance with 20 AAC EXCEPTION 2~.0». Approval to perforate and produce .' inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the 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 SAMPLE ~' no greater than 30' sample intervals from below the permafrost or j from where samples are first caught and 10' sample intervals I ' through target zones. ! 'Please note the following special condition of this permit. ~~ Non-Conventional production or production testing of coal bed methane is not allowed well 'for (name of welly until after (Company Name) has designed and ~, implemented a water well testing program to provide baseline data on water quality and quantity. ~Com~anv Name) must contact the ,' Commission to obtain advance approval of such water well testing Rev: l 135.06 C"jody`aransmittaf checklist i ~ ^^ N : : : m° ~a ;i : NN ~ t ~ , = , ~, _ o ~ i ~ ~~ ~~ '~ OOH ~ ~ ~ ~ ~ ~ ~ ~ ~ N' ~ ~ ~ ~ ~ ~ ~ . o ,° a ~ : O a. ' o 7' N f6 0 O 0. ~ m ~ ~ o' c ~, o: .a m. , a. w ~ O~ ~ rn: ~ v. o: ~ o ~ ~ a, ~ o. ~ ~ m rn N O o eo a~ o M ~ ~ ~ ~ >~ : ~: a ~ p , ~ ~ O. ~ ~o' ' O Q ~ E O ~ G U J O N ~ O 'Q ~ ~ ~ ~ ~ a, N ~ ~ ~ 4 ~ M O ~ w (6 a L M OS >s N ~ J' p. Q: V ~ : ~ N. ~ ~ ~ ~ ~ ~ ~ ~ ~ O, ~ ~ ~ ~ f0 N. ~ p. ~ ~ ~ ~~ ~ ~ N: , '~~ O, ~ ~~ O • ~` d O: -, .p' ~: ~, W U! C c Vl• ~ ~ ~ ~ ~ ~ ~ fl: ~ N• N ~ (': O. 7. a ~ ~ ~ O: ~, N pj: a ~. N' ~ c: 3. m, 0 0~ c' a~ co. -8: o. i M c: ~~ rn , ~ ~. Q. a m' ~ ~, ~ a c a 3, ~, .at ~ ~ p. •v •v c• a m: c: fl. N a ~ : m w: ~ ~ m ~ ~ ~, ~ ~ ; c, o ~ v a ~ ~ 3 ~ , c o N o ' ' ~ p• ~ C N y C• ~ ~ ~ C ~ N: ~ Z' N• ~ ~: ~ ~ 4 N• f0• N• N• N: ~ ~ 7. ~ C. ~ p. ~y, J ~ ~~ ~ ~ ~ N~ ~~ ~ N~ c9 ~ ~ M ~ ~ ~: o~ ~, O ~ : ~: : , , . ~ ~ ~ ~ O. ~ : a. ~ ~ L ~ a OD O .. p: v: ~: ~ ~ ~: - O: ~ -: ~ ~ ~ W~ ~ a a~ ~ a . ~ 4 7. Q a' y: o m ~ c. N• fl* : v U v i, o v O ~ Q O o; j i O, a ¢ ~, a m ; '~ o N ~ ~ r, p. ~: O: O. O. O: ~ ~ ~ ~ o ~ y. ~ a ~: a ~ O. ~ ~ ~: ' ~ N. U• ~ ~ ~ , ~ C. N. E O, O ~ ~ o. . c Z ~ O• O: O. O O. O• ~~ ~ ~ ~ ~ ~ ~ O. ~~ O. ~ m O: >~ gyp: ~ ¢: ~ ~ N• N• X' O~' : w ~ ~ ` M N V1: y, N~ N~ N, O, N, N, N, N~ Vl: N, N, N~ t/D y: y: N, N: N, N, y. N N, N ~ ¢~ ¢: ¢~ ¢~ N~ y. N, ¢: N, O, ~ O, f/N N~ N, N, ~ y. (A: ¢~ N, ¢~ N, N~ N~ N~ N, N, N, UA ~ N, O, ¢~ N~ fq: N, N, N~ N, ¢~ ¢. a }, z, } ~. } ~ } ~' }, ~', ~', ~", ~.. z. Z: z. z. r: z. }, z. z. }, }, z, }, Z: r, r, ~, }, ~' z, z, r ~'. } z, z, T ~ U i ~ in o ~~ c ': p ~ _ • ~ - I ~ ~ : : c ~ ~ ar : O. U. ~ ~ ~ ~ N. : ~: y^y ~ ~ a 3 ; : : rr ;~ ~ Z, N O ~ O: ~ y: N' Q: N. N• o, ~ N ~ ~ ~ ~ 'o' ~ ~~ ~ O. O. N~ ~ O. ~ 3: ~ ~ ~ ~ ~ O. • ~ v ~ ~~ y: ~ fC~ ~ O ~~ O~ , C ~ ~ ~ 7. ~" 3 C ~ f0 ~ M N ~ N C ~ ~~ ~ ~~ ~, 3 ~ >~ ~ N~ c : ~ ~ ~ _ ~ ~, 3 N. ~ .°c, ~ a o. ~ ~ (~. ~' $ N: o' . O ~. : ' a , ~' i . ° N. a ' (Ih ' i p a t xs ~ ~ .~ o; M i . O v ¢ ~ n ui ~ (Z -o' C• a ~ Z a' o m a 'c O. N: 4 ~ ~ ~ O: C. p~ a~~ m. O O. O ~ a rn o~ ~ ~: L. ~ c' N ~~ ~~ N ~ o J ~ ~ ~ ~~ - ~. - a. ~ C: C ' ~ r ' _ , d, O, M ( c c m, ' U• ~ ~ ~: ~ °~: • ~. ~ C. N. L-. a) ~ ' N. N, Q C O ~ i O O 'O 3 O : °: a m. ~ ` C~ ' 3 O o. ~ ., U 'fl Q U n. a~. ~ c ~ n o O s~ ~3 ~ O, N N ' >, .~ •w J cn ~: o ~ ~ a c. c. O ¢ N o o m c. ~ 'o , N ~o, c: o ia . .. 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N. ~ >: y N• a N• Q a • ca 3' L; a' O ~' O Or 6r • O. > C, C' ~ N• ~ ~, OQ ~: ~ O. ~: p' U• N• N• ~ >+ ~ ~' ii U O _ f0' .° -: a. a m ~ ~: ~ ~ o 3 m m a~ a. o ~: m. o ~ c' m ~ O. t: c. m a c. ° E a. _ o c' a, a 3' ~ ~~ ~ m N N v v c~ `o; ~ m' `°' o ~ ~: . ~ a; ~ 3: a~' ~ ~ ? = ~ N ~ o u~ a' ~~ `6~ o: ~ o m c ~ - c' c a~ m N o' o c m o m, c \~ ~ Z ~ : . . ~ `~- c U U : ~~ U . ~~ O O U U' . ~ U vi a , ~ : ~ N' w O: ~' : . : - N O U' N' . U ~ ~ '~, ~ ~ , ~ '>~ ~~ ~: '~~ '~, Q , N ' ' ' ~ ' ' C~ ' ~ ' ~ : ' ' ~ ~ ~ ~ J Y ~ ~ ~ ~ c o a~ ~ ~ ° a> as o: ~° 4 4 a~ c ai m ~ : ~ U 3, c - o ~ ~ (6 a c `t o ~ ~ o F ~ • ~ in m a ~ ~ j C, m a ~ a~ a YO O O L O Q V ~ ~ O a~ ~ N ~ a~ a~ C o Q >, c , : ~ a J ~ ~' ~; : ~' cn . ~-; O o. O a; v , ~ d n.; z , . , , ~ v v v , v , . ¢ v : 4; ¢ °_ - ~ . : m m c.~ ~' `~' ~; ~ : p a , : m ~ . v -~ U W a , : , , . , , , , , . : , , : : : : . , . : , , , "~ U O r N M cY In CO (~ O 00 O N M e- V ~ (O I~ _ W O O N N N N M I N N t0 f0 I~ W N _N N N _ O O N M M N M I M M M ~ M M M_ ~ O M M O M O N O N O N_ U= ~' ~ 0 p m ~ p ~ p~ o N y W d ~ N J *k R ~ Vl C r r a C d 'C C . ~ r ~ \ e ,c. I ~ 7+ p r r '' O / ~ ~ t^ o U ~ a a ~ ¢~ ~ w a ¢ , u t--~~r~k•:L o ~ Q ~ a v~ Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory 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. s Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 13 16:08:46 2007 Reel Header Service name .............LISTPE Date .....................07/04/13 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/04/13 Origin. ................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. • Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Nanuq MWD/MAD LOGS WELL NAME: CD4-211 API NUMBER: 501032053800 OPERATOR: ConocoPhillips Alaska Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 13-APR-07 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004726255 W-0004726255 W-0004726255 LOGGING ENGINEER: D. RICHARDSO D. RICHARDSO E. QUAM OPERATOR WITNESS: D. BURLEY D. BURLEY D. BURLEY MWD RUN 5 JOB NUMBER: W-0004726255 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: L. HILL SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N , ~ ~ ~ RANGE : 4E ~ ~yc,~ / FNL: 2932 ~ FSL: FEL: 264 a. FWL. ~~~~~ ~, ELEVATION (FT FROM MSL 0) KELLY BUSHING: p 1 ~ ZQ~~/ AP DERRICK FLOOR: 56.40 f\ GROUND LEVEL: 20.00 # ~8BIt80ii & Gas Cons, ;U~~ ~,~,~~a~~~r WELL CASING RECORD And10(~ OPEN HOLE CASING DRILLER S 8c~~ ~ (S3 ~15ot~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2539.0 2ND STRING 6.125 7.000 7727.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) GEOPILOT ROTARY-STEERABLE BHA (GP) WAS ALSO INCLUDED IN MWD RUNS 2,4,5. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-5 REPRESENT WELL CD4-211 WITH API#: 50-103-20538-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14379'MD/6217'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 (SEDP). SLIDE = ORIENTED DRILLING AT BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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; DEPTH INCREMENT: .5000 FILE SUMMARY all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 2518.0 14323.0 RPD 2530.0 14330.0 RPS 2530.0 14330.0 RPM 2530.0 14330.0 FET 2530.0 14330.0 RPX 2530.0 14330.0 ROP 2552.5 14379.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2518.0 6343.5 3 6343.5 7737.0 4 7737.0 11952.0 5 11952.0 14379.0 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 2518 14379 8448.5 23723 2518 14379 RPD MWD OHMM 0.23 2000 21.5902 23601 2530 14330 RPM MWD OHMM 0.23 2000 15.7493 23601 2530 14330 RPS MWD OHMM 0.19 2000 13.6727 23601 2530 14330 RPX MWD OHMM 0.17 2000 12.316 23601 2530 14330 FET MWD HOUR 0.15 160.22 1.59742 23601 2530 14330 GR MWD API 36.43 178.76 97.0462 23611 2518 14323 ROP MWD FT/H 0.57 425.11 120.239 23654 2552.5 14379 First Reading For Entire File..........2518 Last Reading For Entire File...........14379 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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.......07/04/13 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 BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 2518.0 RPD 2530.0 RPM 2530.0 RPX 2530.0 RPS 2530.0 FET 2530.0 ROP 2552.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6309.0 6301.0 6301.0 6301.0 6301.0 6301.0 6343.5 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): 20-NOV-06 Insite 66.37 Memory 6343.0. 2552.0 6343.0 27.3 45.1 TOOL NUMBER 97054 1050593.2 8.750 2539.0 Polymer 9.80 37.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 5.250 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.330 113.0 MUD FILTRATE AT MT: 5.050. 68.0 MUD CAKE AT MT: 2.600 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefine d Frame Spacing ................ .....60 .12N Max frames per record ........ .....Undefine d 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 2518 6343.5 4430.75 7652 2518 6343.5 RPD MWD020 OHMM 0.23 2000 7.5046 7543 2530 6301 RPM MWD020 OHMM 0.23 58.45 5.04457 7543 2530 6301 RPS MWD020 OHMM 0.19 2000 5.98867 7543 2530 6301 RPX MWD020 OHMM 0.17 2000 5.51163 7543 2530 6301 FET MWD020 HOUR 0.15 160.22 1.45308 7543 2530 6301 GR MWD020 API 52.38 178.76 105.146 7583 2518 6309 ROP MWD020 FT/H 0.57 425.11 193.176 7583 2552.5 6343.5 First Reading For Entire File..........2518 Last Reading For Entire File...........6343.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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.......07/04/13 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 6301.5 7687.0 FET 6301.5 7687.0 RPM 6301.5 7687.0 RPD 6301.5 7687.0 RPS 6301.5 7687.0 GR 6309.5 7695.0 ROP 6343.5 7737.0 LOG HEADER DATA DATE LOGGED: 22-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7737.0 TOP LOG INTERVAL (FT) 6343.0 BOTTOM LOG INTERVAL (FT) 7737.0, BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.2 MAXIMUM ANGLE: 86.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2539.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 38.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 135.0 MUD FILTRATE AT MT: 1.900 68.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: 2.200 68.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 6301.5 7737 7019.25 2872 6301.5 7737 RPD MWD030 OHMM 4.38 56.05 11.6391 2772 6301.5 7687 RPM MWD030 OHMM 4.31 65.24 11.6846 2772 6301.5 7687 RPS MWD030 OHMM 4.68 66.73 11.3025 2772 6301.5 7687 RPX MWD030 OHMM 4.83 67.26 10.8149 2772 6301.5 7687 FET MWD030 HOUR 0.35 16.9 1.3976 2772 6301.5 7687 GR MWD030 API 45.28 142.84 96.3271 27.72 6309.5 7695 ROP MWD030 FT/H 1.35 222.73 87.4071 2788 6343.5 7737 First Reading For Entire File..........6301.5 Last Reading For Entire File...........7737 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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.......07/04/13 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 RPS 7687.5 11902.5 FET 7687.5 11902.5 RPM 7687.5 11902.5 RPX 7687.5 11902.5 RPD 7687.5 11902.5 GR 7695.5 11895.5 ROP 7737.5 11952.0 LOG HEADER DATA DATE LOGGED: 27-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11952.0 TOP LOG INTERVAL (FT) 7737.0 BOTTOM LOG INTERVAL (FT) 11952.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7727.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 42.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .220 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .120 138.0 MUD FILTRATE AT MT: .200 70.0 MUD CAKE AT MT: .250 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value.... ................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel C~ 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 7687.5 11952 9819.75 8530 7687.5 11952 RPD MWD040 OHMM 0.78 2000 38.3611 8431 7687.5 11902.5 RPM MWD040 OHMM 3.34 2000 25.662 8431 7687.5 11902.5 RPS MWD040 OHMM 2.86 56.86 19.4473 8431 7687.5 11902.5 RPX MWD040 OHMM 1.87 51.53 17.4483 8431 7687.5 11902.5 FET MWD040 HOUR 0.33 63.7 1.57245 8431 7687.5 11902.5 GR MWD040 API 36.43 142.4 89.7028 8401 7695.5 11895.5 ROP MWD040 FT/H 1.97 1 79.09 89.8878 8430 7737.5 11952 First Reading For Entire File..........7687.5 Last Reading For Entire File...........11952 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 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.......07/04/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 • . Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11896.0 14323.0 RPM 11903.0 14330.0 RPX 11903.0 14330.0 RPS 11903.0 14330.0 RPD 11903.0 14330.0 FET 11903.0 14330.0 ROP 11952.5 14379.0 LOG HEADER DATA DATE LOGGED: O1-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14379.0 TOP LOG INTERVAL (FT) 11952.0 BOTTOM LOG INTERVAL (FT) 14379.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.1 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7727.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 41.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3) 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .220. 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .110 145.5 MUD FILTRATE AT MT: .190 71.0 MUD CAKE AT MT: .280 71.0 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11896 14379 13137.5 4967 11896 14379 RPD MWD050 OHMM 7.89 46.08 20.0325 4855 11903 14330 RPM MWD050 OHMM 6.51 35.97 17.4876 4855 11903 14330 RPS MWD050 OHMM 6.18 36.29 16.9362 4855 11903 14330 RPX MWD050 OHMM 4.46 31.33 14.8324 4855 11903 14330 FET MWD050 HOUR 0.4 35.42 1.97914 4855 11903 14330 GR MWD050 API 60.1 141.93 97.5119 4855 11896 14323 ROP MWD050 FT/H 0.87 171.08 77.8697 4854 11952.5 14379 First Reading For Entire File..........11896 Last Reading For Entire File...........14379 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/13 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date .....................07/04/13 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Library. Scientific Technical Services • 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 04 10:11:00 2007 Reel Header Service name .............LISTPE Date .....................07/04/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/04/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Nanuq MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004726255 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: D. BURLEY MWD RUN 5 JOB NUMBER: W-0004726255 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE Scientific Technical Services Scientific Technical Services CD4-211 501032053800 ConocoPhillips Alaska Inc Sperry Drilling Services 04-APR-07 MWD RUN 3 MWD RUN 4 W-0004726255 W-0004726255 D. RICHARDSO E. QUAM D. BURLEY D. BURLEY 24 11N 4E 2932 264 56.40 20.00 CASING DRILLERS 26~ -t 53 ~ ~5-ao'~- • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2539.0 2ND STRING 6.125 7.000 7727.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) GEOPILOT ROTARY-STEERABLE BHA (GP) WAS ALSO INCLUDED IN MWD RUNS 2,4,5. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-5 REPRESENT WELL CD4-211 WITH API#: 50-103-20538-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14379'MD/6217'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 (SEDP). SLIDE = ORIENTED DRILLING AT BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 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; DEPTH INCREMENT: .5000 FILE SUMMARY all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 2518.0 14323.0 RPD 2530.0 14330.0 RPS 2530.0 14330.0 RPM 2530.0 14330.0 FET 2530.0 14330.0 RPX 2530.0 14330.0 ROP 2552.5 14379.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2518.0 6343.5 3 6343.5 7737.0 4 7737.0 11952.0 5 11952.0 14379.0 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 2518 14379 8448.5 23723 2518 14379 RPD MWD OHMM 0.23 2000 21.5902 23601 2530 14330 RPM MWD OHMM 0.23 2000 15.7493 23601 2530 14330 RPS MWD OHMM 0.19 2000 13.6727 23601 2530 14330 RPX MWD OHMM 0.17 2000 12.316 23601 2530 14330 FET MWD HOUR 0.15 160.22 1.59742 23601 2530 14330 GR MWD API 34.8925 192.105 96.9291 23611 2518 14323 ROP MWD FT/H 0.57 425.11 120.239 23654 2552.5 14379 First Reading For Entire File..........2518 Last Reading For Entire File...........14379 File Trailer • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 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.......07/04/04 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 2518.0 6309.0 RPD 2530.0 6301.0 RPM 2530.0 6301.0 RPX 2530.0 6301.0 RPS 2530.0 6301.0 FET 2530.0 6301.0 ROP 2552.5 6343.5 LOG HEADER DATA DATE LOGGED: 20-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6343.0 TOP LOG INTERVAL (FT) 2552.0 BOTTOM LOG INTERVAL (FT) 6343.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.3 MAXIMUM ANGLE: 45.1 TOOL STRING {TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2539.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S) 37.0 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 Name Service Order DEPT RPD MWD020 RPM MWD020 RPS MWD020 RPX MWD020 FET MWD020 GR MWD020 ROP MWD020 Name Service Unit DEPT FT RPD MWD020 OHMM RPM MWD020 OHMM RPS MWD020 OHMM RPX MWD020 OHMM FET MWD020 HOUR GR MWD020 API ROP MWD020 FT/H 9.7 400 6.8 • 5.250 68.0 3.330 113.0 5.050 68.0 2.600 68.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 2518 6343.5 4430.75 7652 2518 6343.5 0.23 2000 7.5046 7543 2530 6301 0.23 58.45 5.04457 7543 2530 6301 0.19 2000 5.98867 7543 2530 6301 0.17 2000 5.51163 7543 2530 6301 0.15 160.22 1.45308 7543 2530 6301 50.7494 192.105 104.783 7583 2518 6309 0.57 425.11 193.176 75.83 2552.5 6343.5 First Reading For Entire File..........2518 Last Reading For Entire File...........6343.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 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.......07/04/04 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 6301.5 7687.0 FET 6301.5 7687.0 RPM 6301.5 7687.0 RPD 6301.5 7687.0 RPS 6301.5 7687.0 GR 6309.5 7695.0 ROP 6343.5 7737.0 LOG HEADER DATA DATE LOGGED: 22-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7737.0 TOP LOG INTERVAL (FT) 6343.0 BOTTOM LOG INTERVAL (FT) 7737.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.2 MAXIMUM ANGLE: 86.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2539.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.70 MUD VISCOSITY (S) 38.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 135.0 MUD FILTRATE AT MT: 1.900 68.0 • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 2.200 68.0 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 6301.5 7737 7019.25 2872 6301.5 7737 RPD MWD030 OHMM 4.38 56.05 11.6391 2772 6301.5 7687 RPM MWD030 OHMM 4.31 65.24 11.6846 2772 6301.5 7687 RPS MWD030 OHMM 4.68 66.73 11.3025 2772 6301.5 7687 RPX MWD030 OHMM 4.83 67.26 10.8149 2772 6301.5 7687 FET MWD030 HOUR 0.35 16.9 1.3976 2772 6301.5 7687 GR MWD030 API 43.0226 1 45.69 96.3041 2772 6309.5 7695 ROP MWD030 FT/H 1.35 2 22.73 87.4071 2788 6343.5 7737 First Reading For Entire File..........6301.5 Last Reading For Entire File...........7737 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 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.......07/04/04 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 RPS 7687.5 11902.5 FET 7687.5 11902.5 RPM 7687.5 11902.5 RPX 7687.5 11902.5 RPD 7687.5 11902.5 GR 7695.5 11895.5 ROP 7737.5 11952.0 LOG HEADER DATA DATE LOGGED: 27-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11952.0 TOP LOG INTERVAL (FT) 7737.0 BOTTOM LOG INTERVAL (FT) 11952.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7727.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 42.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .220 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .120- 138.0 MUD FILTRATE AT MT: .200 70.0 MUD CAKE AT MT: .250 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 7687.5 11952 9819.75 8530 7687.5 11952 RPD MWD040 OHMM 0.78 2000 38.3611 8431 7687.5 11902.5 RPM MWD040 OHMM 3.34 2000 25.662 8431 7687.5 11902.5 RPS MWD040 OHMM 2.86 56.86 19.4473 8431 7687.5 11902.5 RPX MWD040 OHMM 1.87 51.53 17.4483 8431 7687.5 11902.5 FET MWD040 HOUR 0.33 63.7 1.57245 8431 7687.5 11902.5 GR MWD040 API 34.8925 14 6.934 89.7029 8401 7695.5 11895.5 ROP MWD040 FT/H 1.97 1 79.09 89.8878 8430 7737.5 11952 First Reading For Entire File..........7687.5 Last Reading For Entire File...........11952 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 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.......07/04/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 • Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11896.0 14323.0 RPM 11903.0 14330.0 RPX 11903.0 14330.0 RPS 11903.0 14330.0 RPD 11903.0 14330.0 FET 11903.0 14330.0 ROP 11952.5 14379.0 LOG HEADER DATA DATE LOGGED: O1-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14379.0 TOP LOG INTERVAL (FT) 11952.0 BOTTOM LOG INTERVAL (FT) 14379.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.1 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 7727.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 41.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3) 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .220 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .110 145.5 MUD FILTRATE AT MT: .190 71.0 MUD CAKE AT MT: .280 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record n 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 r1 U DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11896 14379 13137.5 4967 11896 14379 RPD MWD050 OHMM 7.89 46.08 20.0325 4855 11903 14330 RPM MWD050 OHMM 6.51 35.97 17.4876 4855 11903 14330 RPS MWD050 OHMM 6.18 36.29 16.9362 4855 11903 14330 RPX MWD050 OHMM 4.46 31.33 14.8324 4855 11903 14330 FET MWD050 HOUR 0.4 35.42 1.97914 4855 11903 14330 GR MWD050 API 54.6367 149.783 97.5239 4855 11896 14323 ROP MWD050 FT/H 0.87 171.08 77.8697 4854 11952.5 14379 First Reading For Entire File..........11896 Last Reading For Entire File...........14379 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................07/04/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Scientific Technical Services l ! r Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
