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207-155
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: OA Cementing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A COLVILLE RIV UNIT CD4-05 Yes No 9. Property Designation (Lease Number): 10. Field: ADL0380075 / ADL0380077 / ADL0387208 Colville River Alpine Pool N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:SSSV: TRMAXX-5E SAFETY VALVE Packers and SSSV MD (ft) and TVD (ft):SSSV-2075' MD / 1983' TVD PACKER: BAKER PREMIER; BAKER HRD ZXP LINER TOP Premier Packer-13023' MD / 6961' TVD; HRD ZXP-14974' MD / 7541' TVD 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:Mark Shulman Contact Email:mark.shulman@conocophilllips.com Contact Phone: 907-263-3782 Authorized Title:Senior Well Intervention Engineer 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 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 207-155 PO Box 1000360, Anchorage, Alaska 99510 5010320558-00 ConocoPhillips Alaska Inc. Length Size Proposed Pools: L-80 TVD Burst 15020' MD 114' 2388' 7553' 114' 2674' 7491'4 1/2" 16" 9 5/8" 77' 7"15106' 2637' 21132' Perforation Depth MD (ft): 15140' 14350-21092' 6159' 7439'-7491' FEB-10-2025 3 1/2" m n P 2 66 t t gggg N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-075 By Gavin Gluyas at 10:01 am, Feb 12, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.02.06 10:06:43 -09'00' 7,491' SFD DSR-2/18/25 Feb 12, 2025 50-103-20558-00-00 SFD 21,142' SFD 2/12/2025 FEB-10-2025 10-404 sc leak repair VTL 2/25/2024*&: 2/25/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.25 13:53:39 -09'00' RBDMS JSB 022625 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 6, 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- 05 (PTD 207-155). 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. CD4-05 Cement Shoe Page 1 Date: Feb. 4, 2025 Subject: CD4-05 OA Cement Shoe Procedure: Prepared By: Mark Shulman, 263-3782 Objective Downsqueeze 9-5/8”x7” OA to cement surface casing shoe to surface. x Injectivity test 9/24/2023 showed a maximum injectivity of 2.33 bpm at approximately 730 psi. Cement Volume Calculations: x Volume in 9 5/8”x7” annulus: (2,674 ft) x (0.02814 bbl/ft) = 76 bbl x Excess: 34 bbl x Total volume: 76 + 34.0 = 105 bbl CRU CD4-05 (PTD#207-155) is a producer that was originally drilled and completed in 2007. The well is currently shut-in for a surface casing leak. CD4-05 needs a surface casing repair. CD4-05’s OA maintains a pressure of +400 psi and surfaced liquids when we completed the injectivity test. 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. CD4-05 Cement Shoe Page 2 9. PT lines and surface equipment to 3,000 psi. 10. Pump the OA shoe. a. Injectivity test September 24, 2023 showed a maximum injectivity of 2.33 bpm at approximately 730 psi. 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. When cement gets to the shoe (75.3 bbls pump total after starting on cement), slow pumps to a maximum of 1 BPM or 500 psi. With 10 bbls of cement past the shoe (85.3 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. d. Use cement composition on page #3. e. Pump Schedule: i. 10 bbls hot diesel per Wells Supv. ii. 65 bbls 90oF hot seawater 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. 90 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. 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. CD4-05 Cement Shoe Page 3 Cement Composition: Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,802.0 CD4-05 3/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Schemaic update, OV & XX plug CD4-05 8/25/2023 oberr Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 16 15.25 36.6 114.0 114.0 65.00 H-40 Welded SURFACE 9 5/8 8.83 36.5 2,674.0 2,388.0 40.00 L-80 MBTC PRODUCTION 7 6.28 34.3 15,140.5 7,553.0 26.00 L-80 MBTC LINER 4 1/2 3.96 14,973.9 21,132.0 7,490.7 12.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.9 Set Depth … 15,020.0 Set Depth … 7,545.4 String Ma… 3 1/2 Tubing Description TUBING 4.5"x3.5" @149' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 31.9 31.9 0.00 HANGER 10.000 FMC TUBING HANGER 4.500 150.2 150.2 0.94 XO Reducing 4.500 CROSSOVER 4.5" x 3.5" 3.500 2,075.4 1,983.3 38.05 SAFETY VLV 5.176 TRMAXX-5E SAFETY VALVE 2.812 4,947.9 3,401.6 64.01 GAS LIFT 5.390 CAMCO KBMG 2.920 9,952.0 5,603.8 64.19 GAS LIFT 5.390 CAMCO KBMG 2.920 12,933.6 6,921.6 63.68 GAS LIFT 5.390 CAMCO KBMG 2.920 13,023.1 6,961.5 63.56 PACKER 5.970 BAKER PREMIER PACKER 2.870 13,102.2 6,996.6 63.83 NIPPLE 3.875 HES X NIPPLE 2.813 14,364.5 7,443.0 75.73 SLEEVE-O 4.490 BAKER CMD w2.81" 'X' PROFILE (OPEN 3/13/2013) 2.810 14,408.8 7,454.0 75.62 NIPPLE 3.960 HES XN 2.813" NIPPLE w/ 2.75" NO GO 2.750 14,980.8 7,541.6 83.80 SEAL ASSY 3.980 BAKER LOCATOR (OAL 1.24') SEAL ASSEMBLY Baker 80-40 3.010 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) 13,102.2 6,996.6 63.83 PLUG 2.81" XX plug w/ fill ext., set and tested Hal XX 5/31/2023 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) 4,947.9 3,401.6 64.01 1 GAS LIFT GLV BK 1 2,008.0 2/10/2013 0.188 9,952.0 5,603.8 64.19 2 GAS LIFT GLV BK 1 1,986.0 2/10/2013 0.188 12,933.6 6,921.6 63.68 3 GAS LIFT OV BK 1 0.0 5/31/2023 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) 14,973.9 7,540.8 83.60 PACKER 6.000 BAKER HRD ZXP LINER TOP PACKER 4.430 14,993.5 7,542.9 84.17 NIPPLE 4.500 RS NIPPLE 4.250 15,026.7 7,546.0 85.15 XO BUSHING 5.000 XO BUSHING 5" BTC x 4/5 IBT 4.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,350.0 14,370.0 7,439.4 7,444.3 4/18/2008 6.0 APERF 2 7/8" PJ OMEGA GUNS 15,325.0 21,092.0 7,557.6 7,491.1 4/3/2008 1.0 PERFP ALTERNATING SOLID PIPE (AVG 204') w/PERF PUPS (AVG 4.9') w/ SIX 1/2" HOLES/ PERF PUP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,325.0 21,092.0 1 A-Sand FRAC 4/23/2008 0.0 0.00 0.00 14,350.0 14,370.0 1 C-Sand FRAC 4/28/2008 0.0 0.00 0.00 15,325.0 21,092.0 1 A-Sand RE- FRAC 2/3/2013 0.0 0.00 0.00 HORIZONTAL, CD4-05, 8/25/2023 5:58:11 PM Vertical schematic (actual) LINER; 14,973.9-21,132.0 SHOE; 21,131.2-21,132.0 A-Sand RE-FRAC; 15,325.0 A-Sand FRAC; 15,325.0 PERFP; 15,325.0-21,092.0 PRODUCTION; 34.3-15,140.5 CASING Float Shoe - Ray Oil Tools Silver bullet; 15,138.4- 15,140.5 CASINGFloat Collar - Halliburton w/ by-pass baffle; 15,052.8-15,053.8 XO BUSHING; 15,026.7- 15,028.3 SBE; 15,007.2-15,026.7 CASING Halliburton Shut-off baffle; 15,010.8-15,011.8 HANGER; 14,997.3-15,007.2 SEAL ASSY; 14,980.8 NIPPLE; 14,993.5-14,997.3 PACKER; 14,973.9-14,993.5 NIPPLE; 14,408.8 SLEEVE-O; 14,364.5 APERF; 14,350.0-14,370.0 C-Sand FRAC; 14,350.0 PLUG; 13,102.2 NIPPLE; 13,102.2 PACKER; 13,023.1 GAS LIFT; 12,933.6 GAS LIFT; 9,952.0 CSG Stage Collar - Halliburton HES; 7,025.4-7,027.8 GAS LIFT; 4,947.9 SURFACE; 36.5-2,674.0 Float Shoe ( Ray Oil Tools SB); 2,671.8-2,674.0 Float Collar (Halliburton); 2,594.9-2,596.1 SAFETY VLV; 2,075.4 CONDUCTOR Insulated 34"; 36.6-114.0 Casing Hanger; 36.5-38.7 Casing Hanger; 34.3-37.7 HANGER; 31.9 WNS PROD KB-Grd (ft) 36.91 RR Date 12/8/2007 Other Elev… CD4-05 ... TD Act Btm (ftKB) 21,142.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032055800 Wellbore Status PROD Max Angle & MD Incl (°) 92.43 MD (ftKB) 16,637.95 WELLNAME WELLBORECD4-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 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: Cement OA SC Repair 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 21142'feet None feet true vertical 7491' feet None feet Effective Depth measured 21142'feet 13023', 14974'feet true vertical 7491' feet 6962', 7541' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2"x 4-1/2" L-80 15020' MD 7545' TVD Packers and SSSV (type, measured and true vertical depth) 13023' MD 14974' MD 2075' MD 6962' TVD 7541' TVD 1983' TVD Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 2674' 2388' Burst Collapse Production Liner 15106' 6158' Casing 7553' 4-1/2" 15140' 21132' 7491' 2638' 114'Conductor Surface Intermediate 16" 9-5/8" 77' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-155 50-103-20558-00-00 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: ADL0380075, ADL0380077, ADL0387208 Colville River Field/ Alpine Oil Pool CRU CD4-05 Plugs Junk measured Length 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) 600 Gas-Mcf MD 481 Size 114' 761 13042536 0 2750 303 325-075 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. 36'-2674' MD Packer: Baker Premier Packer Packer: Baker HRD ZXP LT Packer SSSV: TRMAXX-5E Safty Vlv Mark Shulman Mark.Shulman@conocophillips.com 263-3782Senior Well integrity Engineer 14350-14370', Alternating Perf Pups w/ Solid Pipe @15325-21092' 7439-7444', Alternating Perf Pups w/ Solid Pipe @ 7558-7491' 12. Stimulation or cement squeeze summary:Cement down squeeze 9-5/8"x 7" casing. Filling OA from Casing Shoe @2674' MD to surface with 15.8 ppg Class G cement 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 2:09 pm, Apr 15, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.04.15 11:07:30 -08'00' VTL 4/22/2025 DSR-4/17/25 DTTMSTART JOBTYP SUMMARYOPS 1/9/2025 ACQUIRE DATA (AC-EVAL) IC-POT (PASSED) IC-PPPOT (PASSED) 1/11/2025 ACQUIRE DATA (AC-EVAL) T-DDT & IA DDT (IN-PROGRESS) 1/12/2025 ACQUIRE DATA (AC-EVAL) T & IA DDT (IN-PROGRESS) 1/13/2025 ACQUIRE DATA (AC-EVAL) T-DDT (PASSED) IA-DDT (PASSED) 3/26/2025 ACQUIRE DATA PUMP OA CEMENT DOWN SQUEEZE 9-5/8" X 7", FILLING OA FROM CASING SHOE 2674' TO SURFACE WITH 15.8 PPG CLASS G CEMENT W/ CEMNET AND GAS BLOCKER. PUMPED 110 BBLS OF CEMENT WITH TWO 15 MINUTE HESITATIONS BEFORE PRESSURE LOCK UP. SQUEEZE IN 0.25 BBL DIESEL AFTER CEMENT TO CLEAR VALVES AND OA LEFT SHUT IN WITH 600 PSI. 3/30/2025 DATA ACQUISITION (MISC) OA DDT TO 0 PSI (PASSED), TOC IN SURFACE CASING - OA (ESTABLISHED TOC @ 6' 10") 4/3/2025 ACQUIRE DATA EQUALIZED AND PULLED 2.81'' XX PLUG W/ FILL EXT @ 13102' RKB. MEASURED BHP @ 13102' RKB (2157 PSI / 152*). JOB COMPLETE. 4/8/2025 MAINTAIN WELL HOT FLUSH PUMPED 50 BBLS 190* CRD DWN TBG PUMPED 10 BBLS HOT CRD DWN FL 4/10/2025 DATA ACQUISITION (AC-EVAL) SI-TIFL (PASSED) CD4-05 OA Cement Shoe SC Repair Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,802.0 CD4-05 3/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled XX Plug CD4-05 4/3/2025 RMOORE2 2 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 16 15.25 36.6 114.0 114.0 65.00 H-40 Welded SURFACE 9 5/8 8.83 36.5 2,674.0 2,388.0 40.00 L-80 MBTC PRODUCTION 7 6.28 34.3 15,140.5 7,553.0 26.00 L-80 MBTC LINER 4 1/2 3.96 14,973.9 21,132.0 7,490.7 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.9 Set Depth … 15,020.0 Set Depth … 7,545.4 String Max No… 3 1/2 Tubing Description TUBING 4.5"x3.5" @149' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 31.9 31.9 0.00 HANGER 10.000 FMC TUBING HANGER 4.500 150.2 150.2 0.94 XO Reducing 4.500 CROSSOVER 4.5" x 3.5" 3.500 2,075.4 1,983.3 38.05 SAFETY VLV 5.176 TRMAXX-5E SAFETY VALVE 2.812 4,947.9 3,401.6 64.01 GAS LIFT 5.390 CAMCO KBMG 2.920 9,952.0 5,603.8 64.19 GAS LIFT 5.390 CAMCO KBMG 2.920 12,933.6 6,921.6 63.68 GAS LIFT 5.390 CAMCO KBMG 2.920 13,023.1 6,961.5 63.56 PACKER 5.970 BAKER PREMIER PACKER 2.870 13,102.2 6,996.6 63.83 NIPPLE 3.875 HES X NIPPLE 2.813 14,364.5 7,443.0 75.73 SLEEVE-O 4.490 BAKER CMD w2.81" 'X' PROFILE (OPEN 3/13/2013) 2.810 14,408.8 7,454.0 75.62 NIPPLE 3.960 HES XN 2.813" NIPPLE w/ 2.75" NO GO 2.750 14,980.8 7,541.6 83.80 SEAL ASSY 3.980 BAKER LOCATOR (OAL 1.24') SEAL ASSEMBLY Baker 80-40 3.010 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) 4,947.9 3,401.6 64.01 1 GAS LIFT GLV BK 1 2,008.0 2/10/2013 0.188 9,952.0 5,603.8 64.19 2 GAS LIFT GLV BK 1 1,986.0 2/10/2013 0.188 12,933.6 6,921.6 63.68 3 GAS LIFT OV BK 1 0.0 5/31/2023 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) 14,973.9 7,540.8 83.60 PACKER 6.000 BAKER HRD ZXP LINER TOP PACKER 4.430 14,993.5 7,542.9 84.17 NIPPLE 4.500 RS NIPPLE 4.250 15,026.7 7,546.0 85.15 XO BUSHING 5.000 XO BUSHING 5" BTC x 4/5 IBT 4.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,350.0 14,370.0 7,439.4 7,444.3 4/18/2008 6.0 APERF 2 7/8" PJ OMEGA GUNS 15,325.0 21,092.0 7,557.6 7,491.1 4/3/2008 1.0 PERFP ALTERNATING SOLID PIPE (AVG 204') w/PERF PUPS (AVG 4.9') w/ SIX 1/2" HOLES/ PERF PUP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,325.0 21,092.0 1 A-Sand FRAC 4/23/2008 0.0 0.00 0.00 14,350.0 14,370.0 1 C-Sand FRAC 4/28/2008 0.0 0.00 0.00 15,325.0 21,092.0 1 A-Sand RE- FRAC 2/3/2013 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 36.5 2,674.0 36.5 2,388.0 Cement Squeeze CEMENT DOWN SQUEEZE 9-5/8" X 7", FILLING OA FROM CASING SHOE 2674' TO SURFACE WITH 15.8 PPG CLASS G CEMENT 3/26/2025 HORIZONTAL, CD4-05, 4/14/2025 5:21:20 PM Vertical schematic (actual) LINER; 14,973.9-21,132.0 PERFP; 15,325.0-21,092.0 A-Sand FRAC; 15,325.0 A-Sand RE-FRAC; 15,325.0 PRODUCTION; 34.3-15,140.5 APERF; 14,350.0-14,370.0 C-Sand FRAC; 14,350.0 PACKER; 13,023.1 GAS LIFT; 12,933.6 GAS LIFT; 9,952.0 GAS LIFT; 4,947.9 SURFACE; 36.5-2,674.0 SAFETY VLV; 2,075.4 Cement Squeeze; 36.5 ftKB CONDUCTOR Insulated 34"; 36.6-114.0 WNS PROD KB-Grd (ft) 36.91 RR Date 12/8/2007 Other Elev… CD4-05 ... TD Act Btm (ftKB) 21,142.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032055800 Wellbore Status PROD Max Angle & MD Incl (°) 92.43 MD (ftKB) 16,637.95 WELLNAME WELLBORECD4-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Alpine Pool N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21142'13102' Casing Collapse Conductor Surface 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 Jan-16 2024 21132'6159' 3 1/2" 7491' Brennen Green/Roger Mouser 77' 2637' 15140' Perforation Depth MD (ft): 14350'-21092' 15106' 4 1/2" 7439'-7491' 114' 2388' 114' 2674' 7553'7" 16" 9 5/ 8" Size Proposed Pools: L-80 TVD Burst 15020' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380075 / ADL0380077 / ADL0387208 Colville River 207-155 PO Box 1000360, Anchorage, Alaska 99510 501032055800-00 Conoco Phillips Alaska Inc. AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): W.I. Field Supvisor 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 writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY n1927@conocophillips.com 907-659-7506 Other: SC Repair 7491' COLVILLE RIV UNIT CD4-05 SSSV: TRMAXX-5E SAFETY VALVE PACKER: BAKER PREMIER; BAKER HRD ZXP LINER TOP SSSV-2075' MD / 1983' TVD Premier Packer-13023' MD / 6961' TVD; HRD ZXP-14974' MD / 7541' TVD Length m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2023.11.16 15:53:55-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green By Grace Christianson at 8:26 am, Nov 27, 2023 323-642 DSR-11/29/23SFD 11/27/2023 50-103-20558-00-00 SFD VTL 01/04/2024 10-404X Photo documentation of all steps of the repair required. *&:JLC 1/4/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.04 13:58:25 -09'00'01/04/24 RBDMS JSB 010924 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 16, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well, ALP CD4-05 (PTD 207-155), to repair the Surface Casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.11.16 15:53:17-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. ALPINE WELL CD4-05 (PTD 207-155) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 16, 2023 This application for Sundry approval for Alpine well CD4-05 is for the inspection and repair of a leak in the Surface Casing. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the suspected Surface Casing leak. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in the tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate well. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 13,802.0 CD4-05 3/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Schemaic update, OV & XX plug CD4-05 8/25/2023 oberr Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 16 15.25 36.6 114.0 114.0 65.00 H-40 Welded SURFACE 9 5/8 8.83 36.5 2,674.0 2,388.0 40.00 L-80 MBTC PRODUCTION 7 6.28 34.3 15,140.5 7,553.0 26.00 L-80 MBTC LINER 4 1/2 3.96 14,973.9 21,132.0 7,490.7 12.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.9 Set Depth … 15,020.0 Set Depth … 7,545.4 String Ma… 3 1/2 Tubing Description TUBING 4.5"x3.5" @149' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 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) 31.9 31.9 0.00 HANGER 10.000 FMC TUBING HANGER 4.500 150.2 150.2 0.94 XO Reducing 4.500 CROSSOVER 4.5" x 3.5" 3.500 2,075.4 1,983.3 38.05 SAFETY VLV 5.176 TRMAXX-5E SAFETY VALVE 2.812 4,947.9 3,401.6 64.01 GAS LIFT 5.390 CAMCO KBMG 2.920 9,952.0 5,603.8 64.19 GAS LIFT 5.390 CAMCO KBMG 2.920 12,933.6 6,921.6 63.68 GAS LIFT 5.390 CAMCO KBMG 2.920 13,023.1 6,961.5 63.56 PACKER 5.970 BAKER PREMIER PACKER 2.870 13,102.2 6,996.6 63.83 NIPPLE 3.875 HES X NIPPLE 2.813 14,364.5 7,443.0 75.73 SLEEVE-O 4.490 BAKER CMD w2.81" 'X' PROFILE (OPEN 3/13/2013) 2.810 14,408.8 7,454.0 75.62 NIPPLE 3.960 HES XN 2.813" NIPPLE w/ 2.75" NO GO 2.750 14,980.8 7,541.6 83.80 SEAL ASSY 3.980 BAKER LOCATOR (OAL 1.24') SEAL ASSEMBLY Baker 80-40 3.010 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) 13,102.2 6,996.6 63.83 PLUG 2.81" XX plug w/ fill ext., set and tested Hal XX 5/31/2023 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) 4,947.9 3,401.6 64.01 1 GAS LIFT GLV BK 1 2,008.0 2/10/2013 0.188 9,952.0 5,603.8 64.19 2 GAS LIFT GLV BK 1 1,986.0 2/10/2013 0.188 12,933.6 6,921.6 63.68 3 GAS LIFT OV BK 1 0.0 5/31/2023 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) 14,973.9 7,540.8 83.60 PACKER 6.000 BAKER HRD ZXP LINER TOP PACKER 4.430 14,993.5 7,542.9 84.17 NIPPLE 4.500 RS NIPPLE 4.250 15,026.7 7,546.0 85.15 XO BUSHING 5.000 XO BUSHING 5" BTC x 4/5 IBT 4.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,350.0 14,370.0 7,439.4 7,444.3 4/18/2008 6.0 APERF 2 7/8" PJ OMEGA GUNS 15,325.0 21,092.0 7,557.6 7,491.1 4/3/2008 1.0 PERFP ALTERNATING SOLID PIPE (AVG 204') w/PERF PUPS (AVG 4.9') w/ SIX 1/2" HOLES/ PERF PUP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,325.0 21,092.0 1 A-Sand FRAC 4/23/2008 0.0 0.00 0.00 14,350.0 14,370.0 1 C-Sand FRAC 4/28/2008 0.0 0.00 0.00 15,325.0 21,092.0 1 A-Sand RE- FRAC 2/3/2013 0.0 0.00 0.00 HORIZONTAL, CD4-05, 8/25/2023 5:58:11 PM Vertical schematic (actual) LINER; 14,973.9-21,132.0 SHOE; 21,131.2-21,132.0 A-Sand RE-FRAC; 15,325.0 A-Sand FRAC; 15,325.0 PERFP; 15,325.0-21,092.0 PRODUCTION; 34.3-15,140.5 CASING Float Shoe - Ray Oil Tools Silver bullet; 15,138.4- 15,140.5 CASINGFloat Collar - Halliburton w/ by-pass baffle; 15,052.8-15,053.8 XO BUSHING; 15,026.7- 15,028.3 SBE; 15,007.2-15,026.7 CASING Halliburton Shut-off baffle; 15,010.8-15,011.8 HANGER; 14,997.3-15,007.2 SEAL ASSY; 14,980.8 NIPPLE; 14,993.5-14,997.3 PACKER; 14,973.9-14,993.5 NIPPLE; 14,408.8 SLEEVE-O; 14,364.5 APERF; 14,350.0-14,370.0 C-Sand FRAC; 14,350.0 PLUG; 13,102.2 NIPPLE; 13,102.2 PACKER; 13,023.1 GAS LIFT; 12,933.6 GAS LIFT; 9,952.0 CSG Stage Collar - Halliburton HES; 7,025.4-7,027.8 GAS LIFT; 4,947.9 SURFACE; 36.5-2,674.0 Float Shoe ( Ray Oil Tools SB); 2,671.8-2,674.0 Float Collar (Halliburton); 2,594.9-2,596.1 SAFETY VLV; 2,075.4 CONDUCTOR Insulated 34"; 36.6-114.0 Casing Hanger; 36.5-38.7 Casing Hanger; 34.3-37.7 HANGER; 31.9 WNS PROD KB-Grd (ft) 36.91 RR Date 12/8/2007 Other Elev… CD4-05 ... TD Act Btm (ftKB) 21,142.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032055800 Wellbore Status PROD Max Angle & MD Incl (°) 92.43 MD (ftKB) 16,637.95 WELLNAME WELLBORECD4-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP • • WELL LOG TRANSMITTAL Z0"7- 155 141'1.3b G� To: Alaska Oil and Gas Conservation Comm. November 9, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: CD4-05 Run Date: 10/30/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4-05 PPROF Data in LAS format, Digital Log file, Interp. report 1 CD Rom 50-103-20558-00 Production Profile(Field Print) 1 Color Log 50-103-20558-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 SCANNED [BAR 1 3 2013 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 17-AA‘ Signed: L1 6044 i ~ Image F'rQj~ct V1l~ll I~i~tO~r~ F'il~e GOV~r 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 scanner.! during a special rescan activity or are viewable by direct inspection of the file. ~~' ~ - ~~~~ Well History File Identifier Organizing (done> ^ Two-sided III II'III I) III II III ^ Rescan Needed III II~III II II III II RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. r ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Project Proofing III II~III IIIII II III BY: Maria Date: /s/ ~' ~;~ Scanning Preparation _~ x 30 = Gam' + ~ =TOTAL PAGES / (Count does not include cover sheet) BY: Maria ~~, Date: ! ~~ ~ 9 /s/ ~~, Production Scanning III 111111 IIIII II III Stage 1 Page Count from Scanned File: _~ (count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: ~~~~~Q~ /sl ~~ Stage 1 If NO in stage 1, page(s) discrepancies wlJJlere found: YES NO 111 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II (IIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III II'I III 10!6/2005 Well History File Cover Page.doc STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell (°° Plug Perforations [ Perforate - Other E Alter Casing I- Rill Tubing r Stimulate - Frac I Waiver E Time Extension ("- Change Approved Program EOperat. Shutdow n r Stimulate - Other - Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fie Exploratory f 207 -155 3. Address: 6. API Number: Stratigraphic j° `" Service P. O. Box 100360, Anchorage, Alaska 99510 ` 50 - 103 - 20558 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 387208, 380077, 380075 P CD4 - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): " none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 21142 feet Plugs (measured) none true vertical 7491 feet Junk (measured) none Effective Depth measured 21132 feet Packer (measured) 13023, 14974 true vertical 7491 feet (true vertical) 6961, 7541 Casing Length Size MD TVD Burst Collapse CONDUCTOR I 77 16 114 114 SURFACE 2637 9.625 2674 2388 PRODUCTION 15106 7 15140 7553 LINER 6158 4.5 21132 7491 RECEIVED SCANNED APR 17 2013 MAR 0 4 2013 Perforation depth: Measured depth: 14350'- 14370', 15325- 21092' True Vertical Depth: 7440'- 7444', 7557-7491' AOGCC Tubing (size, grade, MD, and TVD) 3.5, L -80, 15020 MD, 7542 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 13023 MD and 6961 TVD PACKER - BAKER HRD ZXP PACKER @ 14974 MD and 7541 TVD SSSV - CAMCRO TRMAXX -5E @ 2075 MD and 1983 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15325' - 21092' MD Treatment descriptions including volumes used and final pressure: pumped total 530,554# proppant 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 863 2282 1 -- 323 Subsequent to operation 313 2084 76 -- 314 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I- Development 5, Service V Stratigraphic E 16. Well Status after work: „ Oil I i Gas E WDSPL F Daily Report of Well Operations XXX GSTOR l WINJ r WAG E GINJ E SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -012 Contact Robert Blakney a 26 -6417 Email Robert. G.Blakneyaconocophillips.com Printed Name R•A•, -rt BI.,,,,- � Title Completions Engineer Signature p . 3 /ct , Phone: 265 -6471 Date 0 � RBDMS MAR 0 5 1013 .� , ) v -F Form 10-404 Revised 12/2012 4///13 Submit Original Only WNS • CD4 -05 C &We - Well Attributes Max Angle & MD TD a Inc, Wellbore API/UWI Reid Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) "st,aeP,^ 501032055800 ALPINE PROD 92.43 16,637.95 21,142.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 36.91 12/8/2007 Well Conga: HORIZONTAL - CD4 -05, 2/25/2013 2 4582 PM Schematic - Actual - Annotation Depth (ftKB) End Date Annotation Last Mod ...End Date Last Tag: Rev Reason. FRAC, GLV 0 /0, Close CMD osborl 1 2/25/2013 HANGER. 32 - - III , Casing Strings Casin Description String 0... String ID ... Top (ftKB) Set Depth ( ( 9 1 . .... Depth (TVD) ... String Wt... Str ng .. String Top Thrd CONDUCTOR 16 15.250 36.6 114.0 114.0 65.00 H-40 Welded a Insulated 34" CONDUCTOR p, C uing Desc String 0... String ID ... Top (ftKB) Set Depth (9... Set Depth (ND) ... Stri Wt... String ... String Top Thrd Insulated 34", ';. SURFACE 95/8 8.835 36.5 2,674.0 2,388.0 40.00 L - 80 MBTC 37 -114 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.3 15,140.5 7,552.5 26.00 L - 80 MBTC Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd SAFETY VLV, { � . I LINER 41/2 3.958 14,973.9 21,132.0 7,490.7 12.60 L - 80 IBTM 2,075 Liner D etail s Top Depth (ND) Topincl Noml. SURFACE. Top ( ftKB ) (ft (1 Rem Description Comment ID (in) 37 - 2.674 1 7, 540 . 8 84.98 PACKER BAKER HRD ZXP LINER TOP PACKER 4.430 GAS LIFT, 14,993.5 7,542.9 85.27 NIPPLE RS NIPPLE 4.250 4,948 14,997.3 7,543.3 85.32 HANGER BAKER 5" x 7" FLEXLOCK LINER HANGER 4.420 15,007.2 7,544.3 85.47 SBE SEAL BORE EXTENSION 4.000 15,026.7 7,546.0 85.75 XO BUSHING XO BUSHING 5" BTC x 4/5 IBT 4.500 GAS LIFT, t Tubing Strings 9,952 " ..: .. Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd TUBING 4.5 "x3.5" 31/2 2.992 31.9 15,020.0 7,545.4 9.30 L -80 EUE IF @149' GAS LIFT, Completion Details AK 12,934 - Top Depth 41* (TVD) Top Inc! Nomi... III Top (ftKB) MKS) ( °) Item Description Comment ID (!n) 31.9 31.9 - 0.08 HANGER FMC TUBING HANGER 4.500 13,023 ID NIPPLE, 73,102 150.2 150.2 1.12 XO Reducing CROSSOVER 4.5" x 3.5" 3.500 APERF, t 2,075.4 1,983.3 38.05 SAFETY VLV TRMA)0(-5E SAFETY VALVE 2.812 14,350-14,370 c -Sand FRAC. I 1 13,023.1 6,961.4 63.56 PACKER BAKER PREMIER PACKER 2.870 14,350 , SLEEVE - C, 1 13,102.2 6,996.3 63.62 NIPPLE HES X NIPPLE 2.813 14,355 it 14,364.5 7,443.1 75.73 SLEEVE -C BAKER CMD w2.81" 'X PROFILE (CLOSED 1/27/2013) 2.810 illit 14,408.8 7,452.8 76.04 NIPPLE HES XN 2.813" NIPPLE w/ 2.75" NO GO 2.750 NIPPLE. 14,409 14,980.8 7,541.6 85.08 SEAL ASSY BAKER LOCATOR (OAL 1.24') SEAL ASSEMBLY 3.010 i. ∎ __ Perforations & Slots SEAL ASSY, Shot 14,981 ti 1- Top (ND) Btm (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Dens Date (ah••• Type Comment WA Y"�! 14,350.0 14,370.0 7,439.5 7,444.4 ALPC, CD4 -05 4/18/2008 6.0 APERF 2 7/8" PJ OMEGA JUNGS 15,325.0 21,092.0 7,557.0 7,491.1 ALPA, CD4-05 4/3/2008 1.0 PERFP ALTERNATING SOLID PIPE (AVG 204') w/PERF PUPS (AVG 4.9') w/ SIX 1/2' HOLES / PERF PUP Stimulations & Treatments Bottom PRODUCTION, & Min Top Max Btm Top Depth Depth 34-15,140 Depth Depth (TVD) (ND) t (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment _ 14,350.0 14,370.0 7,439.5 7,444.4 C-Sand FRAC 4/28/2008 PUMPED A TOTAL OF 192,6308 OF 16/20 M CARBOLITE PLACING 159,8198 INTO THE - FORMATION. FRAC SCREENED OUT WITH 161 BBLS OF 8 PPA SLURRY IN FORMATION. IMEN APPROX. 32,800# OF PROPPANT IN TUBING. it IMON 15,325.0 21,092.0 7,557.0 7,491.1 A -Sand 2/3/2013 Pumped Alpine A -sand re-frac consisting of six main !p >: RE -FRAC stages: 2 -7 ppa 16/20 Carbolite and 308 crosslink gel MIll at 20 -bpm. Pumped total of 530,554# proppant with 18" estimated 527,2128 behind pipe (106% design) in M I 4850.0 -bbl total slurry volume. MN 15,325.0 21,092.0 7,557.0 7,491.1 A -Sand FRAC 4/23/2008 PUMPED A TOTAL OF 252,430# OF 16/20 5 ' 1 CARBOLITE, PLACING 252,416# INTO 1111111 1 FORMATION. dal Notes: General & Safety MINN se End Date Annotation 9/2/2008 NOTE: View Schematic w/ Alaska Schematic9.0 En IR PERFP, 15,325- 21,092 111.1 A -Sand FRAC, la 15,325 MI ASand R RE -FRAC, _ 15,325 *: IIIIIII 9 MIMI MIN MIll 5 Mandrel Details Top Depth Top Port 5 S (TVD) Inc! OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) C) Make Model (!n) Sery Type Type (in) (psi) Run Date Com... B 1 4,947.9 3,401.5 63.82 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,008.0 2/10/2013 ili 2 9,952.0 5,603.8 64.19 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,986.0 2/10/2013 b 3 12,933.6 6,921.5 63.31 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2110/2013 M 5/ 5 It MN R ^ MB 5, Mill LINER. i 14.974-21.132 TD,21.142 • CD4 -05 Frac Summary DATE SUMMARY • • 1/26/2013 CUT HARD /DRY PARAFFIN f/ 130' - 320' SLM. GAUGE TBG TO 2.78" TO 14409' RKB. ATTEMPT TO CLOSE CMD @ 14364' RKB. IN PROGRESS. 1/27/2013 SET 2.81" STANDING VLV @ 14409' RKB. VERIFY CMD CLOSED @ 14364' RKB. PULLED OV @ 12933' RKB. WELL READY TO LOAD, IN PROGRESS. 1/28/2013 PUMP 290 BBLS OF IHIBITED SEAWATER DOWN TBG, TAKING RETURNS OFF IA TO CD4 -04 FLOW LINE. CHASED SEAWATER WITH 110 BBLS OF CRUDE DOWN TBG. PRESSURE UP TBG /IA TO 2500 PSI, WATCH FOR 10 MINUTES. HOOK UP JUMPER LINE AND U TUBE CRUDE FOR FREEZE PROTECT. WELL READY FOR SLICKLINE. 1/29/2013 ATTEMPT TO SET SPG @ 12933' RKB. IN PROGRESS. 1/30/2013 ATTEMPT TO SET DV @ 12933' RKB. RAN LIB TO SAME. PIC OF FILL & SMILY FACE IN CENTER OF 1.25" LIB. IN PROGRESS. 1/31/2013 RAN POCKET BRUSH TO 12933' RKB. SET DV © 12,933' RKB. IN PROGRESS. LRS TO MITT AND MITIA 2/1/2013 PULLED CAT SV @ 14,409' RKB. SET FRAC SLV @ 2075' RKB. BRUSH & FLUSHED TREE. COMPLETE. 2/3/2013 Pumped Alpine A -sand re -frac consisting of six main stages; 2 -7 ppa 16/20 Carbolite and 30# crosslink gel at 20 -bpm. Pumped total of 530,554# proppant with estimated 527,212# behind pipe (106% design) in 4850.0-bbl total slurry volume. 2/9/2013 PULLED FRAC SLEEVE @ 2075' RKB, ATTEMPTED TO SET CAT SV, DRIFTED TBG. w/ BRUSH & 2.71" G- RING TO 14,320' SLM, WELL PRESSURES UP WHEN TRYING TO PUMP. IN PROGRESS. 2/10/2013 DROPPED 2.79" CATCHER, PULLED DV'S f/ STA #1, STA #2, & STA #3, SET .25" OV IN STA # 3, SET GLV (TRO 1986) IN STA #2, SET GLV (TRO 2008) IN STA #1. IN PROGRESS. 2/11/2013 ATTEMPT TO PULL CATCHER, BAILED FRAC SAND OFF CATCHER. IN PROGRESS. 2/12/2013 BAIL FRAC SAND OFF THE CATCHER, PULLED CATCHER, SET FRAC SLEEVE. 2/17/2013 PULLED FRAC SLEEVE @ 2075' RKB. READY FOR COIL. vtit 0,1",\ %% s?, THE STATE Alaska 011 and Gas °A LASKA Conservation Commission GOVERNOR SEAN PARNELL . 333 West Seventh Avenue rq � ` _ • � .:�.��- ��""�� Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney Completions Engineer 2 2013 ConocoPhillips Alaska, Inc. HEa P.O. Box 100360 a07 -155- 0 7 1� j 5- Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4 -05 Sundry Number: 313 -012 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this Z day of January, 2013. Encl. • • STATE OF ALASKA ; ALASKA OIL AND GAS CONSERVATION COMMISSION o7f APPLICATION FOR SUNDRY APPROVALS JAN 1, 4 2013 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r. Perforate New Pool r Repair well r Char teem m r Suspend r Rug Perforations r Perforate r FUII Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stinulate r Alter casing IT Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development 7. Exploratory E. 207 - 155 3. A ddress: Stratigraphic r` Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20558 - 00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD4 - - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 387208, 3130077, 380075 Colville River Field / Alpine Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (e): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 21142 7491 • 21132' 7491' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2637 9.625 2674' 2388' PRODUCTION 15106 7 15140' 7553' LINER 6158 4.5 21132' 7491' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): •14350' 14370', 15325' 21092' • 7440' 7444', 7557' - 7491' 3.5 L - 80 15020 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER - MD= 13023 TVD= 6962 PACKER - HRD ZXP LINER TOP PACKER • MD =14974 TVD =7541 SSSV - CAMCO TRMAXX -5E • MD =2075 7VD =1983 12. Attachments: . Description Summary of Proposal T : • 13. Well Class after proposed work: Detailed Operations Program J- BOP Sketch r Exploratory r Stratigraphic r Development F • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/25/2013 Oil Gas r WDSPL Fr Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney © 265 -6417 Email: Robert.G.Biaknev5conocophillips.com Printed Name Robert BI e Title: Completions Engineer / �6 Signature Phone: 265 -6471 Date 6 ef Commission Use Only Sundry Number: '5111„ Conditions of approval: Notify Commission so that a representative may witness („ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS JAN 2 8 2013 eb/ Spacing Exception Required? . Yes ❑ No Subsequent Form Required: / _, 0 APPROVED BY ��^^ Approved by: P L- COMMISSIONER THE COMMISSION Date: / - - (� -- l 3 ® 1 , A r ove application is valla tor 1z montns from the Gate or approval. `,, Form 10-403 (Revised 0/2012) Submit Form and Attachments In Duplicate V �� � ORIGINAL ,4 t • • CD4 — 05 Sundry Application CD4 - 05 was completed in December of 2007 as horizontal producer in the Alpine A & C formations. The well was completed with 3.5" tubing with a selective completion across the Alpine C formation and a 4.5" liner in the Alpine A formation. Initially both the Alpine C & A were hydraulically fractured. We will re- stimulate the Alpine A with a 6 stage fracture treatment using bioballs to obtain diversion during the treatment. We expect the increased production to be 148 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 9 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 4000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 200 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7500 psi. Stage 1 • 240 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Bioball diversion Stage 2 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite RB • • • • Bioball diversion Stage 3 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Bioball diversion Stage 4 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite Stage 5 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite Stage 6 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Flush with 147 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 500,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal well until they are clean enough for production.) Cement Evaluation of CD4 -05 and wells within 1 /4 mile of CD4-05 CD4 -05: 7" casing cement pump report on 11/27/2007 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 2470 psi and checked floats and no pipe movement. RB • CD4 -318: 7" casing cement pump report on 8/30/2006 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 1100 psi and checked floats and no pipe movement. CD4 -322: 7" casing cement pump report on 8/12/2007 (1 stage) shows job was pumped to completion with returns up the annulus, indicating competent cementing operations. Bumped plug and checked floats. Tested casing to 3500 psi for 30 min. Pump report 8/13/2007 for 2 stage pumped as designed. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a ' mile radius or any other nearby well. RB • • WellSchematic: "; INNS CTD4 -05 ConocoPhil6 ( ; Well Attributes Max Angle & MD TD '•A ARM Reld Name 'A'ellbbre Stat.Iil hcl ( °) M0(ttK6) At Into MK t n'a'b' tl` 501032055800 ALPINE PROD 92.43 18,637.' 21,142.1 Comment ,, KS(ppm) Cate Annotation ISMOste KEGrd(tt) Rig Release ,,( "' SSSV: TRDP Last WO: 36.91 12/8/201 000e00000um;; ira *ar.immiom000n Anno.,. on Dip .1( KB) Bid rim , no• on Lai Mod I3,; Bid Ca : gm _.. _ _ Last Tag: Rev Reason: WELL REVIEW osborl 11/30/21 NANQER, _ - , ; , Casing Strings Cuing De scription String GEL siring ID... Top (018 B) Set Depth (1.. Set Cepti (TVD)... String Al.. String ... Siring Top 11 i CONDUCTOR 16 15.250 36.6 114.0 114.0 65.00 H-40 Welde. Insulated 34" CONDUCTOR Casing Deaeripton String 00.. Siring ID... Top (ttK6) Set Depth (T... Set Depth (WO)... Sting At.. Sting ... Sting Top 111 rcaa i. SURFACE 95/8 8.835 36.5 2,674.0 2,388.0 40.00 L -80 MBTC �a Caging De acripton String OD.. Sting ID... Top (1tK6) Set Depth (T... Set Capin (TVD)... Siring Wt.. Siring ... Sting Top 111 7111 PRODUCTION 7 6276 34.3 15,140.5 7,552.5 26.00 L-80 MBTC Ca sing De icripton String 00.. String 10... Top (ttK6) Set Depth (t... set Depth (TVD)... String Al.. Siring ... Sting Top T1 8AF ETY zpi Ili LINER 41.2 3.958 14,973.9 21,132.0 7,490.7 12.60 1.80 Liner Details I Top Depth i Top (TVD) Top hcl Nom I... ESN RFAC E, L. MK B) MKS) ( °) Item De acrlpton Comment loon) 37z 14,973.9 7,540.8 84.98 PACKER BAKER HRD ZXP LINER TOP PACKER 4.430 ae8 LIFT, --b 14,993.5 7,542.9 85.27 NIPPLE RS NIPPLE 4.250 14,997.3 7,543.3 85.32 HANGER BAKER 5Th 7" FLEXLOCK LINER HANGER 4.420 15,0072 7,544.3 85.47 513E SEAL BORE EXTENSION 4.000 15,026.7 7,546.0 85.75 XO BUSHING XO BUSHING 5 "BTCx4151BT 4.500 aAS LIFr T ubing Strings 9 Tubing Deacipton Sting OD.. Sting ID... Top (ttK6) Set Depth (t... Set Depth (NO)... Siring Vet.. String... String Top 111 TUBING 4.5'43.5" 3 1/2 2.992 31.9 15,020.0 7,545.4 9.30 L-80 1 EUE @149' ...... { i1 OA8 LIFT, Completion Details ,a�n. • Top Depth Top (ND) Top hcl Soml... (0186) (01861 ( °) Item De ecrtpton Comment ID (In) PACKER, 31.9 31.9 -0.08 HANGER FMC TUBING HANGER 4.500 13AIZa N 5 NIPPLE, 150.2 1502 1.12 XO Reducing CROSSOVER 4.5 "x3.5" 3.500 1 APE@ 11111 2,075.4 1,983.3 38.05 SAFETYVLV TR MAYME SAF ETY VALVE 1.1.,370 C-Eaa FRAC, 13,023.1 6,961.4 63.56 PACKER BAKER PREMIER PACKER 2.870 sLESS17, • 13,102.2 6,896.3 63.62 NIPPLE HESXNIPPLE 2.813 ,. 14,364.5 7,443.1 75.73 SLEEVE -0 BAKER CMDw2.81 "'X PROFILE (OPENED 8/2/2012) 2.810 NIPPLE, m . 14,408.8 7,452.8 76.04 NIPPLE HES XN NIPPLE w/ 2.875" NO GO 2.813 su 1.,1iH 14,980.8 7,541.6 85.08 SEALASSY BAKER LOCATOR SEALASSEMBLY 3.010 4 q 1 ti Perforations & Slots 73 Ee.1 "05-e, .11111' Elll . Till 1.,S21 Top(ND) IntN(NO) Dena TN TtK6 Zone Date ih.. Comment Iff. - 14,350.0 14,370.0 7,439.5 7,444.4 ALPC, CD4-05 4/18/2008 6.0 APERF 27/8 "PJ OMEGAJUNGS 15,325.0 21,092.0 7,557.0 7,491.1 ALPA. CD4-05 4/3/2008 1.0 PERFP ' TERNATING SOLID PIPE (AVG 204') w /PERF PUPS (AVG 4.9') w/ SIX 12 " HOLES/ PERF PUP Stimulations & Treatments 1 Bo ' PRADNCTgN, II, ten Top MMI Top Depth Depth 3/15,1.0 �` Deptt Dept! (ND) (ND) _ - Fiir (11KB) (7tK6) (ttKB) MK 5) 'rive Cate Comment 1 14,350.0 14,370.0 7,439.5 7,444.4 C -Sand FRAC 4/28/2008 PUMPED ATOTAL OF 192,6300 OF 16/20 as s CARBOLITE PLACING 159,8190 INTO THE , FORMATION. FRAC SCREENED OUT WITH 161 ■. ` BBLSOF8PPASLURRYINFORMATION. _ 'ii APPROX. 32,8000 OF PROPPANT IN TUBING. M 15,325.0 21,092.0 7,557.0 7,491.1 A-Sand FRAC 4/23/2008 PUMPED ATOTAL OF 252,4300 OF 1620 is I CARBOLITE, PLACING 252,4160 INTO ' FORMATION. EMI Notes: General & Safety I ■ NI End Date Annotation SEW 922008 NOTE: Mew Schematic w/ Ataska Schematic9.0 T) I Stimulation Surface Rig -Up Bleed % Tattle , / Tale Tank 00111 �� :� ' ' _ • Minimum pressure rating on all surface treating lines 10,000 psi N / / • Main treating line PRV is set to 95% of max g Rs treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV 110111 • Tree saver used on all fracs rated for 15,000 psi. o, G 0► 4 m s 1pi►' m m F r- it 000 I■ d L 4xul &Jed 0 I _:= ;IIT:iw Fop Ott Tank 1 F n n Trur ^- N 1"2 �T hff. F J t V C C i Frac Pump � l—t :r 1 r F; f F Jr !F Fret:Pump ti n. I ... %y . ry !� �. a; * I ,.I f ',: T) • • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR 70 MANDREL INSERTION) (MANDREL INSERTED) E FRAC IRON fl t �^ CONNECTION f� 1 .. TT.. • / REMOTE OPERATED ,TT. i l : 4 V ( MASTER VALVE f � I I S i 0. I #103. i I �AN • t f / MANUAL OPERATED 4 * � 0 • I MASTER VALVE -_ ■ 1 1 Stinger AIIIIWIIIII e 11111 L•11 NI: V, r I 'I ®I#-- VALVE E I = I • \� 1 OPEN • I% ytul I 1 I .! \` 1� . � I FLOW TEE AND • / VENT VALVE WELLHEAD k1t�' AINI VALVES WdeS 0 OPEN NY i WELL HEAD t VALVES �,�* `: r CLOSED d''»�4 r C a :, t ' �= �e g�, 1� [d �. 1 ii '-'. QUAD PACKOEF `~� 1 5 . * -.�a ASSEMBLY IN ' PLACE IN TUBING •> k. TUBING A\ \ • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1 /2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB 1 • • eD2 -41 • • . RP D2 470 • l NEVE 1 '• 1 ` '•CD2 467 _._• D2 4B `'•• t Y. j: \.... CD2 -56 CD2-47 s' Ci2 -55 ' 44 CD2 -60PB1 • CD2' J 1 • T ` +. CD2-43 • CD2 -56L1 0 ` +• CD4 -16 CD4 -304 • '' _'. CD2 -36P61 • • CD4 -17 CD4 -210 • CD4 -30 CD4- A., .. D2 -37 T. •• • CD4- 304PB1 C D2 -36 • l- • Legend •CD4 -322 Well A........... l P + A � Suspe nded ...... ...... T + Service 0 Producer A ♦ Observation Injection: SW • Injection: SAPW Injection: PW A Injection: MWAG 1 ACTIVE, INJ, MG • • ACTIVE, INJ, IWAG • ACTIVE, INJ, GAS CD4 -24 CD4 -213E • • ACTIVE, INJ, DG CD4 - :: • ACTIVE, INJ, <Null> CD4 -25 t Disposal CD4 -25L1 11111 1/4 Mile Radius :110. CD4 - 321 • • • • • ConocoPhilhhps CD4 -318 PB•T' • 4- 318' CD4 -05 Fracture Radius +'''••..•, C O N F I D E N T I A L ....... •. •�� ' • 0 0.25 0.5 •• A I E M iles ..,..•• FracProgram2013.mcd CSR 1 -10 -2012 • CD4 Alpine A Frac Model • Frac Design 1 stage Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bblfmin) (gal) (lb/mgall (PPA) Pad 40.0 YF125ST 21840 25.0 0.00 2.0 PPA 40.0 YF125ST 9269 25,0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 17157 25.0 CarboLite 16/20 4.00 4.0 PPA 40.0 YF125ST 14297 25.0 Carbolite 16/20 4.00 7.0 PM 40,0 YF125ST 27650 25.0 CarboLite 16/20 7.00 Flush 40,0 WF125 6722 25.0 0.00 • Totals (6 stages) YF 125 FX-D - 3700 bbls WF 125 256 bbls 16/20 Carbolite - 500,000 lbs 'II M odel Initial Fracture Top Tv[ _ - _...._.. - - - - -- 7545.4 ft Initial Fracture Bottom Tvl 7570.0 ft • Propped Fracture Helf- Length ..._.._._.._.... 315.5 ft ECU Hyd Height at Well .....---- ._.._.... ft Average Propped width ._ _.. --------- - - - - -- 0.151 in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. • • Well Schematic: I ----`, WNS CD4 -05 ConocoPhillips & ) Well Attributes Max Angle & MD TD h 8: •s, r),. 'Ole ARM Arl Field Name •AoIlbore StatullEdt I ( °) MD(1156) (t At Btm Mitt Cc x isp, r 501032055800 ALPINE PROD 92,43 16,637.8a 21,142 """ Comment I =11;1 H25 (ppm) Cate I` dit Annotation Bid Cate IEdt KB -Ord (tt) Rig Release Edt "' SSSV: TRDP ' Last WO: 36.91 12420 Annotaton Depti (ttK6) End Cat(i:.. i;< Annotation Last Mod E' Bid Cate lE Last Tag: Rev Reason: WELL REVIEW osborl 111302 I p - C as i ng Str Caring De cnpbon Sting Of. Sting ID... Top (1tK6) set Deptn (t... Sot Copth (ND)... Sting "Art_ Sting ... string Top 11)o] i +!I'" ,, � CONDUCTOR 16 15250 36.6 114.0 114.0 65.00 H-40 Welded 34" CONDUCTOR cuing Description String OD... String ID... Top (ttK 6) set Depth (t.. Set Depth (ND)... String Wt.. Siring... String Top lii) d 3 tcUatN 30, 37-114 SURFACE 95/8 8.835 36.5 2,674.0 2,388.0 40.00 L-80 MBTC Casing Cescri ton Strip OD... Strip .. ID. Top CUB) Da Set th 1... Set re th (ND)... Siring Alt.. Strip String Top 111 sa PRODUCTION ' Cuing n 6.276 34.3 15,140.5 7,552 5 26.00 L-80 MBTC BC ig Ce cripton Siring 4 1 �OD.. Sting g ID... T 14 973 9 S " Cepti )t... Set Dep t)( 7 T G)... Stri 2 0 't 8 0 .. Sting�.. sting Top TljEd t BAFETY VW, 22,07.5 L `'' Liner Details [Edit Top Depth Top (ND) Top lacl Plural... SU MAC E, _ L MK 6) (MKS) ( °) Item DeH:Option Comment ID(In) 3i -2,67, 14,973.9 7,540.8 84.98 PACKER BAKER HRD ZXP LINER TOP PACKER 4.430 ISM OAS LIFT, 14,993.5 7,542.9 85.27 NIPPLE RS NIPPLE 4.250 e .9 s 14,997.3 7,543.3 85.32 HANGER BAKER 5"H 7" FLEXLOCK LINER HANGER 4.420 15,007.2 7,544.3 85.47 SBE SEAL BORE EXTENSION 4.000 15,026.7 7,546.0 85.75XOBUSHING XO BUSHING 5"ETCo4+516T 4500 O LIFT, Tubing Strings 9,962 , Tubing Dcripton String Oct .. sting ID... Top (MK 6) set Eopt i (1... Sot Depth (TVD)... Sting A.1... String... sting Top TijEdt TUBING 4.5' 312 2.992 31.9 15,020.0 7,545.4 9.30 lII L-00 EUE @149' OAS LIFT, Completion Details (Edit rz93e 1 Top Ceptir tom''. Top (ND) Top 510 Noml... MI6 :, MKS) (ftI6) ( °) Item Cercripton Comment ID(In) PACKER, 31.9 31.9 -0.08 HANGER F MC TUBING HANGER 4.500 13,13=1 31.9 NIPPLE, 150.2 150.2 1.12 XO Reducing CROSSOVER 4.5 "x3.5" 3.500 13,102 OW APENF, 2,075.4 1,983.3 38.05 SAFETY VLV TRMAX -5E SAFETY VALVE 141.,310 c.. F - 13,023.1 6,961.4 63.56 PACKER BAKER PREMIER PACKER 2.870 SLEEVE-0, 13,102.2 6,996.3 63.62 NIPPLE HESXNIPPLE 2.813 1065 , - 14,364.5 7,443.1 75.73 SLEEVE -0 BAKER CMDw2.81"'X PROFILE (OPENED 8/2/2012) 2.810 NIPPLE, *MN 14,408.8 7,452 76.04 NIPPLE HES XN NIPPLE w12.875" NO GO 2.813 14,980.8 7,541.6 85.08 SEALASSY BAKER LOCATOR SEAL ASSEMBLY 3.010 F IN1111111 " Perforations & Slots 'Edit SERI ABBY, 1 14,981 iiill silo Tap (ND) erl (ND) Dahl ftK6 MK Zone Cite nt... Comment ' 14,350.0 14,370.0 7,439.5 7,444.4 ALPO, CD4-05 4/182008 6.0 APERF 274 "PJ OMEGAJUNGS 15,325.0 21,092.0 7,557.0 7,491,1 ALP?, CD4-05 43+2008 1.0 PERFP ALTERNATING SOLID PIPE (AVG 204') w /PE R F PUPS (AVG 4.9') w/ SIX 12 " HOLES/ PERF PUP Stimulations & Treatments I: r.11. Bottom PNADNCTOIN, A Min Top MaI Mtn Top Depth Depth 3v16,14) Dppti Depth (ND) (ND) (MKS) (ilI6) (ft);6) (IMO) Tye Cate Comment 14,350.0 14,370.0 7,439.5 7,444.4 C -Sand FRAC 4 PUMPED A TOTAL OF 192,63014 OF 1620 is I .. - CARBOLITE PLACING 159,8194 INTO THE FORMATION. FRAC SCREENED OUTWITH 161 I ® BBLS OF 8 PPA SLURRY IN FORMATION. -4 C C APPROX. 32,8004 OF PRO PPANT IN TUBING. 15,325.0 21,092.0 7,557.0 7,491.1 A-Sand FRAC 4232008 PUMPED ATOTAL OF 252,4300 OF 1620 ClEtr CARBOLITE, PLACING 252,41614 INTO r _ I _ FORMATION. Notes: General & Safety i` r)a End Cate Annotation __ 922088 NOTE: View Schematic w /Alaska Schematic9.0 SUPERSEDED RIi • CD4 05 Sundry Application CD4 - 05 was completed in December of 2007 as horizontal producer in the Alpine A & C formations. The well was completed with 3.5" tubing with a selective completion across the Alpine C formation and a 4.5" liner in the Alpine A formation. Initially both the Alpine C & A were hydraulically fractured. We will re- stimulate the Alpine A with a 6 stage fracture treatment using bioballs to obtain diversion during the treatment. We expect the increased production to be 148 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 9 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 4000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 200 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7500 psi. Stage 1 • 240 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Bioball diversion Stage 2 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite RB • • • Bioball diversion Stage 3 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Bioball diversion Stage 4 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite Stage 5 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite Stage 6 • 190 bbls YF125FX -D Pad • 60 bbls YF125FX -D w/ 2 ppa 16/20 Carbolite • 140 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 60 bbls YF125FX -D w/ 4 ppa 16/20 Carbolite • 220 bbls YF125FX -D w/ 7 ppa 16/20 Carbolite • Flush with 147 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 500,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. Production Cement Report: 11/27/2007 MU Cement head and lines Stage pumps up to 6.5 bpm - circulate and condition mud for cementing - Attempted to reciprocate pipe W/ 425K - unable. FCP =670 psi - Held PJSM with Dowell and rig crew Cement 1st stage 7" casing as follows: Pumped 2 bbls CW -100 - Dropped Halliburton Bypass Plug - Load closing plug - Test lines to 4000 psi - Pumped 38 bbls CW -100 @ 4.5 bbls /min @ 400 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.4 bbl /min @ 390 psi - Mixed & Pumped 152 bbls Lead Slurry Class G w/ additives @ 11.0 ppg @ 470 psi - Mixed and pumped 24 bbls of 15.8 ppg Tail Slurry Class G w /additives @ 4.6 bpm / 225 psi RB • • - Dropped top plug and pumped 20 Bbls water behind. Switched to rig pumps & displaced w/ 554 bbls 10.0 ppg LSND mud @ 7 bbl /min @ 570 to 840 psi - slowed rate to 4 bbl /min @ 640 psi for last 10 bbls of displacement - Bump plug with 1150 psi. Floats held. Full returns throughout. - CIP @ 0500 hrs. Check floats, holding - Loaded 2nd stage closing plug in cement head and opened stage collar with 3,200 psi. CBU @ 7 bpm / 370 psi Cement 2nd Stage 7" casing as follows: - Pumped 20 bbls CW -100 @ 4.7 bbls /min @ 144 psi - Mixed & pumped 30 bbls MudPush XL @ 10.5 ppg @ 4 bbl /min @ 148 psi - Mixed & Pumped 37 bbls Tail Slurry Class G w/ additives @ 15.8 ppg @ 4.6 BPM / 116 psi - Dropped Closing plug and pumped 20 Bbls water behind. Switched to rig pumps and displaced with 10.0 LSND mud @ 7.5 bpm / 180 -410 psi - Slowed to 3 BPM / 190 psi for last 6 Bbls and bumped plug with 2470 psi closing Stage collar total of 249 bbls of mud. CIP @ 0650 Hrs. Checked floats OK. Full returns throughout. RD cement head and lines - LD landing joint and RD casing elevators RB • • Ferguson, Victoria L (DOA) From: Blakney, Robert G [ Robert.G.Blakney @conocophillips.com] Sent: Tuesday, January 22, 2013 4:27 PM To: Ferguson, Victoria L (DOA) Cc: Blakney, Robert G Subject: RE: CD4- 05(PTD 207 -155, Sundry 313 -012) Fracture Stimulation Attachments: CD4 - 05 sundry attachment.doc Afternoon Victoria, 1st off, sorry I wasn't able to call you to discuss these items in more detail. I've been trapped on the slope dealing with weather. But I did have a chance to talk to Ty and Randy about your meeting, and I believe the attachment should address all the concerns you have. Assuming you like addresses your concerns, I will send similar updates for the CD3 -109 and CD3- 199 sundry applications shortly. And then we can use this as the template going forward. Please let me know if you have any questions. Thanks, - Robbie Robert Blakney ConocoPhillips Completions Engineer 907- 265 - 6417 (office) 713 - 367 -8504 (cell) ATO 1508, 700 G st. Anchorage, AK From: Ferguson, Victoria L (DOA) [mailto :victoria.ferguson @alaska.govl Sent: Friday, January 18, 2013 10:23 AM To: Blakney, Robert G Subject: [EXTERNAL]CD4- 05(PTD 207 -155, Sundry 313 -012) Fracture Stimulation Robert, Several items on this procedure: 1. Provide schematics(wellhead /BOP /surface) and /or engineering statement that wellbore and surface is appropriately constructed to handle treatment pressures. 2. Engineering review and assessment of cementing in subject well and wellbores within the % mile radius. 3. Where will frac flowback be taken? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria. ferguson(ctAlaska. gov 1 • • ~p~ ~. .~ a. ~ ~ ~ n ~~ .3:y+ ..~ .~ y.: ~ ,. :. '` ~- 4 +_ aj3 ~,. k~`. MICROFILMED 6/30/201 0 D4 NO~T~ PLACE ANY NEW MATERIAL UNDERTHIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • y 1 ! ~' SARAH PALlN, GOVERNOR r 3 ~~ ' ALAS7~ OIL ~ V[tsia ~'~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COh'II~iIS5IOI~T ;~ ANCHORAGE, ALASKA 99501-3539 r° PHONE (907) 279-1433 t FAX (907) 276-7542 Chip Alvord ~ `~f ~,U~ Alpine Drilling Manager ~,,,~~~~ ;a ConocoPhillips Alaska -~ ,` ;~,,~~' ' „~~ PO Box 100360 Anchorage, AK 99507 ~) ~ ~ ' Re: Colville River Field, Alpine Oil Pool, CD4-05 Sundry Number: 309-154 Dear Mr. Alvord: Your Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well is DENIED. While the construction of CD4-05 was determined satisfactory, an uncemented wellbore section lies within about 140' of the surface casing shoe of CD4- 05. If communication were to develop between the wellbores, this uncemented section could allow waste to move to shallower depths. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr Chair DATED this? day of May, 2009 Encl. ~6q ~ I~~ t ~ ~~ ~ 6 STATE OF ALASKA b k,F>{;~ ~ ~~q~ , ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ANNULAR DISPOSAL APPLICATION~s~~ ll ~ has ~°ns. ~arln~missian 20 AAC 25.080 ,4nchore 1. Operator 3. Permit to Drill Name: Number: 207-155 ConocoPhillips Alaska a. API Number. ~- 50-103-20558 0 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD 5 6. Field: Coly~ a River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulu Torok and ee for ion, shale, siltstone and sandstone CD4-07, CD4-16, CD4-17, CD4-208, CD4-209, CD4-210, CD4-211, CD4-213, CD4-214, CD4-215, CD4-304, CD4-306, C D4-320 ` c-~~WQ~~\ ~~0~\0~~~~\`E. RSe~'l~vF ~~\ b) Waste recei IOg ko b) water wells within one mile: ~~~ San Jaye el ~~~JJJ a C30 marker in the Seabee formation sc ~O None c) onfi me The e u ormation provides an upper barrier and marine shales and claystones f the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1519' MD / 1500' ND None 11. Previous volume disposed in annulus and date: 12. Esti to u sit : 13. Maximum anticipated pressure at shoe: None a sties ge from esel to 12#/gal 2260 14. Estimated volume to be disposed with this r uest: 1 FI ds to dis sed: 1 35,000 bbls. ~ pe o wa to may be drilling mud, drilling cuttings, reserve pit fluids, cement- cont drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act ing a well, drill rig wash fluids, cement rinsate, domestic waste water, any 8-Sep-07 adde water needed to facilitate pumping of drilling mud or drilling cuttings, and other sub ances that the commissioner determines on application are wastes associated with the act of drillin a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD an TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Dat ~ Other ^~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoi is true and correct to the best of my knowledge. Signature: Title: ~~ ~-ws.r Printed Phone Name: Chip Alvord Number: 265-6120 Date: 4/22/2009 Commission Use Onl Conditions of proval: LOT review and approvaL 2 S b f i d l vD / ~ ' J~' A b u seque orm requ re : pprova er: c~ num ~. ~'IR~' ~ ~? 2ODy APPROVED BY Ap oved by: COMMISSIONER THE COMMISSION Date: Form 10-403RD Rev. 6/2004 t ~ N TRUCTIONS ON REVERSE s%~~%~~~~ubmit in Duplicate k~~~~~ ~ ConocoPhillips Alaska, Inc. • Post Office Box 100360 ~, ~ Anchorage, Alaska 99510-0360 ~~~~~~~'' I' ~C' Telephone 907-276-1215 •7 Apri122, 2009 Alaska Oil and Gas Conservation Commission 333 West 7'i' Avenue, Suite 100 ~~a~~c~ ~~ ~~~ ~0"° 0~-~m9~~~4r Anchorage, Alaska 99501-3539 Anctr~t~ge Re: Application for Sundrv Approval for Annular Disposal of Drilling Waste on well CD4-OS Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-OS 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-OS approximately May 3, 2009. Please find attached form 10-403AD 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 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within'/4 mile radius not at AOGCC: CD4-304, CD4-07 12. Well within 1/4 mile radius at the AOGCC (13 Wells): CD4-07, CD4-16, CD4-17, CD4-208, CD4-209, CD4- 210, CD4-211, CD4-213, CD4-214, CD4-215, CD4-304, CD4-306, CD4-320 13. 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 The initial annular LOT (16.5 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.2 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. It should also be noted that Nanuq 3 was plugged and abandoned in April of 2007. Therefore, it is not counted as a well within the quarter mile radius. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Ga ~ a Drilling ngineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 cc: CD4-OS Well File Chip Alvord Anadarko Sharon Allsup-Drake ConocoPhillips ATO-1577 ATO-1530 ulus Disposal Transmittal Form - We~CD4-05 AOGCC Reeulations, 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD4-OS 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 = 1500' TVD 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/1. (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 2260 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 CD4-24, CD4-25, CD4-26 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Well CD4-05 Date 4/22/2009 '''''/ ~ ~ d v 00 a .~ U 0 0 0 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 lift) 1,000 psi an eai:i: ' Us:: V. '. N I -- 2,388 TVD TOC Est. @ 11,200' MD 6,155' TVD 4.s "Tubing 7,554 TVD Pburst85% - PHydrostatic +PApplied - PFormation Version 1.0 -Jan'OS 4,888 = ( 2,388 * 0.052 * MWm~ ) + 1500 - (0.4337 * 2,388 ) MWmax = 35.6 PPg Surface Casing String Size 9.625 in Weight 40 ppf Grade L 80 rbnrstloo°i° 5,750 psi Pburst85% 4,888 psi Depth of Shoe 2,388 $ FIT/I,OT @ Shoe 18.2 ppg or 2,260 psi FIT/I,OT for Annulus 16.5 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied' PGasGradient - PHeader 4,599 =( 6,155 * 0.052 * MWm~ )+ 1,500 - (0.0700 * 6,155) - 1,000 MWmax = 14.2 PPP 2nd Casing String Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 pSl Pcollapse85% 4,599 psi Top of Cement 6,155 $ Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = (2,388 * .052 * 18.2 ) Pmax allowable - 2,260 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD4-05 CD4-05 x v Surtace Casing Shoe ASP 4 Coordinates NAD 27: 377233.39 5957348.01 ells Details ~ AOGCC" Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date Distance from Object well` Surtace csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surt LOT (ppg) Surtace casing TVD (ft) Annular LOT (ppg) omments CD4A7 InGuded 883 376700.4 5958052.5 16.7 2396 15.4 CD4-16 y 679 376571.7 5957499.3 18.1 2388.5 17.90 Not for annular disposal, due to proximity to Nanuq 3 CD4-17 y 827 376416.3 5957221.0 18.1 2386.93 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4-208 y 306-183 5/3012006 CD4-318a, CD4-320, CD4-214, CD4-321,CD4-211 61839 7/3/2006 1/4/2007 1058 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit#306-266 CD4-209 y 702 377935.02 5957333.89 14.7 2376.79 17.5 Not for annular disposal CD4-210 y 497 377547.47 5956963.14 18.0 2385.97 17.3 CD4-211 y 306-392 12/29/2006 CD4-302, CD4-16 31937 6/20/2007 7111/2007 189 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test@18.4 ppg CD4-213 y 798 377441.38 5956577.89 18.1 2400.5 21.40 Not for annular disposal. High Ann test Probably ice plug, will retest if needed CD4-214 CD4-215 CD4-302 CD4-304 CD4-305 y y y InGuded y 307-257 307-258 9/6/2007 9/6/2007 -"- CD4-304, CD4-OS CD4-304, CD4-07 32000 28330 10/21/2007 9/11/2007 1216/2007 10/21/2007 454 641 2015 531 746 377016.49 376762.06 379247.67 377304.4 377262.19 5956949.56 5956914.11 5957393.4 5957874.3 5958093.22 17.3 17.6 18.1 16.8 18.0 2400.8 2400.4 2390.43 2391 2376.29 17.6 17.50 17.10 17.8 14.90 Not for annular disposal Not for annular disposal Not for Annular Disposal CD4-318 y 306-181 5/26/2006 CD4209, CD4-320 942 5/3112006 812/2006 1510 376138.31 5956308.17 18.2 2375.32 17.1 Unable to pump- SD pumping CD4-319 CD4-320 y y 305-373 12/9/2005 CD4-208, CD4-318, CD4-209, CD4-320 32010 12/14/2005 7/212006 1559 1022 377174.72 377915.36 5955790.44 5958108.91 18.4 17.1 2396.47 2387.33 16.1 17.8 Not for annular disposal CD4-321 y 306-393 1/212007 CD4-306, CD4-322 31117 7/14/2007 8/20/2007 1493 375795.28 5956945.38 18.0 2385.47 16.3 CD4-322 y 307-293 10/25/2007 CD4-301, CD4-OS 30832 12/8/2007 1110/2008 1605 375674.64 5957731.19 18.0 2385.44 16.8 Nanuk 1 n Exploration P&A'd Nanuk 2 Nanu 3 n 222 377015.63 5957391.42 11.8 1774.97 Exploration P&A'd Ex /oration P8A'd in A ril 2007 Nanu 5 1555 378326.61 5956241.68 14.9 2393.75 15.1 Not for annulardis osal CD4-301 n 2330 379541.0 5957028.4 14.8 2387 13.5 CD4A5 n D 377233.4 5957348.0 18.2 2388 16.5 Nanu 3 2400' TVD 735 376499.3 5957380.8 Inter olated for 2400' TVD ` Lateral distance in feet, between surface casing shoes, in the X-Y plane " As of April 21, 2008 Note that this sheet is not the definitive record for annular disposal volumes \ I r~ SURFACE CASING SHOE SEPARATION FROM CD4-05 CD4-05 x v Surface Casin Shoe ASP 4 Coordinates NAD 27: 377233.39 5957348.01 ells Details ~ AOGCC"' Ann. isp. Per 't # 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 (ftj Annular LOT (ppg) omments CD4-07 Included 883 376700.4 5958052.5 16.7 2396 15.4 CD4-16 679 376571.7 5957499.3 18.1 2388.5 17.90 for annular disposal, due to proximity to Nanuq 3 CD4-17 y 827 376416.3 5957221.0 18.1 2366.93 .2 Not for annular disposal, due to proximity to Nanuq 3 CD4-208 CD4-209 y y 306-183 5/30!2006 -318a, CD4-320, CD4-214, CD4- 1,CD4-211 61839 7/3/2006 1/412007 1058 702 378134.12 377935.02 5956792.58 5957333.89 16.3 14.7 2440.26 2376 14.4 17.5 volume extension to 70000 bbl, permit #306-266 Not for annular disposal CD4-210 y 497 377547.47 5956963.14 18.0 2 .97 17.3 CD4-211 y 306-392 12l2912D06 CD4-302, CD4-1 31937 6/20/2007 7/11/2007 189 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test@18.4 ppg CD4-213 y 798 377441.38 5956577.89 1 2400.5 21.40 Not for annular disposal. High Ann test Probably ice plug, will retest if needed CD4-214 y 454 377016.49 5956949.56 17.3 2400.8 17.6 Not for annular disposal CD4-215 y -"' 641 376762.06 5956914.11 17.6 2400.4 17.50 Not for annular disposal CD4-302 CD4-304 y Included 307-257 9/6/2007 CD4-304, CD4-05 3 0 10/21/2007 12/6/2007 2015 531 379247.67 377304.4 5957393 5957 4.3 18.1 16.6 2390.43 2391 17.10 17.8 Not for Annular Disposal CD4-306 y 307-258 9/6/2007 CD4-304, CD4-07 28330 11/2007 10/21/20D7 746 377262.19 59 93.22 18.0 2376.29 14.90 CD4-318 y 306-181 5/26J2D06 CD4-209, CD4-320 942 5/ 006 612!2006 1510 376138.31 56308.17 18.2 2375.32 17.1 Unable to pump- SD pumping CD4-319 y 305-373 12/9120D5 CD4-208, D4-318, CD4-209, CD4-320 32010 12/14/2005 7!2!2006 1559 37717 5955790.44 18.4 2396.47 16.1 CD4-320 y 1022 377 5.36 5958108.91 17.1 2387.33 17.8 Not for annular disposal CD4-321 y 306-393 1!2/2007 CD4-306, CD4-322 31117 7/14/2007 8!2 DD7 1493 5795.28 5956945.38 18.0 2385.47 16.3 CD4-322 Nanuk 1 Nanuk 2 Nanu 3 Nanu 5 y n n 307-293 1D/2512DD7 CD4-301, CD4-05 30832 12/8/2007 111012 1605 555 375674.64 78326.61 5957731.19 956241.68 18.0 4.9 2385.44 r.-- 2393.75 16.8 5.1 Exploration P8A'd Exploration P&A'd Ex /oration P&A'd in A ril 2007 Not for annular dis osal CD4-301 n 2330 9541.0 5957028.4 14.8 2387 13.5 CD4.05 n 0 37 3 4 5957348.0 18.2 2388 16 5 ' * Lateral distance in feet, between surface casing shoes, in the X-Y plane "As of April 21, 2008 \ Note that this sheet is not the definitive record for annular disposal volumes ~~.~ ~ " ~° • i CcanocoPhil ' lips Casing Detail 9 5/8" Surface Casing Well: CD4-05 Date: 11 /16/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.58 FMC Gen V Hanger 2.17 36.58 Jts 3 to 6° 66 Jts 9-5/8" 40# L-80 BTC Csg 2556.16 38.75 Halliburton Float Collar 1.20 2594.91 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 75.68 2596.11 Ray Oil Tools "Silver Bullet" Float Shoe 2.25 2671.79 9 5/8" Shoe @ 2674.04 TD 12 114" Surface Hole 2684.04 12 114" hale 2,684' MD 2,393' T1tD 9 518° csg shoe 2,674' MD - 2,388' T~1U TOTAL BOWSPRING CENTRALIZERS - 40 1 per jt on Jt #1 - #14 (stop ring on Jt #1 & 3 } and over collars on jts# 16,18,20 ,22,24,26,28,30, 32,34,36,38,40,42,44,46,48,50, 52,54, 56, 58,60,62,64,66 75 joints in the pipe shed. 68 jts to run -Last 7 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque ~ 9000 ft/Ibs Remarks: Up Wt - 180 k DnWt-150k Block Wt - 75k Supervisor: D.Burley / D. Mickey Security Level: Development - ~ - Daily Drilling Report -,~ -~..; CD4-05 Report Number: 4 Rig: DOYON 19 Report Date: 11/16/2007 AFE Type NetworWlO"#' Total AFE+Sup 10200411 10,044,998.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-05 Development ALPINE 3.00 4.0 0.00 2,684.0 2,684.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,199.45 68,115.48 485,855.45 1,133,908.48 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 11 /13/2007 11/14/2007 31.36 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,674.OftKB Ops and Depth ~ Morning Report 24hr Forecast Picking up 5" DP Finish PU 5" DP -Test BOPE -MU BHA - RIH w/ 54 jt Dp Last 24hr Summary Finish LD BHA -Clean & clear rig floor - RU & Run 9 5/8" csg w/ shoe to 2674' - FC @ 2595' - RU to cmt - Circ -Cmt w/ 296 bbls lead & 49 bbls tail -full returns w/ 112 bbls cmt returns to surface - RD from cmt job - ND riser -Install & test wellhead - NU BOPE - PU 45 jts %" DP f/ pipe shed General Remarks Weather Head Count 10 / -12 we / NE @ 21/ Vis. 3 miles 46.0 Supervisor - Title Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Time Lo Start Time - End Tame Dur (hrs) Phase - -- Op.Gode Activity Cade - Time P-T-X - Trbl Code Trbl Class. Depth Start (ftKB) Depth End (ftKB) -'' Operation 00:00 00:45 0.75 SURFAC DRILL PULD P 50.0 0.0 Finish laying down BHA - DM HOC - XO sub -stab -float sub - & motor 00:45 03:45 3.00 SURFAC DRILL OTHR P 0.0 0.0 Clean & clear rig floor of BHA componets - RU to run 9 5!8" csg 03:45 04:00 0.25 SURFAC DRILL SFTY P 0.0 0.0 Held PJSM on running 9 5/8" csg 04:00 07:00 3.00 SURFAC CASING RNGS P 0.0 1,517.0 Ran 9 5/8" 40# L-80 MBTC csg as follows: FS(Ray Oil Tool Ssilver bullet) 2 jts csg - FC( Halliburton Super seal) 2 jts csg - 4 jts total (made up w/ BakerLoc - fill pipe 8r check floats OK) Ran 35 joints to 1517' (39 jts total) 07:00 07:30 0.50 SURFAC CASING CIRC P 1,517.0 1,517.0 Stage pumps up to 5 bpm - CBU -FCP= 350 psi 07:30 09:15 1.75 SURFAC CASING RNCS P 1,517.0 2,674.0 Continue running 9 5/8" csg f/ 1,517' to 2635' (68 jts total) - PU FMC csg hanger & landing jt. -Land casing w/ FMC fluted hanger on landing ring w/ FS @ 2,674.04' - FC @ 2,594.91' 09:15 09:45 0.50 SURFAC CEMENT PULD P 2,674.0 2,674.0 RD fill up tool -Blow down top drive - RU cement head and lines 09:45 11:15 1.50 SURFAC CEMENT CIRC P 2,674.0 2,674.0 Stage pumps up to 7 bpm -circulate and condition mud for cementing -FCP=260 psi -Reciprocated pipe with full returns throughout -PJSM w/ Dowell, MI, AES and rig crew Latest BOP Test Data Date Comment Page 1/3 Report Printed: 4/22/2009 Security Level: Development. `~ , ~, -~-,~ Daily Drilling Report ~ ~ `~- ,~ CD4-05 Report Number: 4 Rig: DOYON 19 Report Date: 11/16/2007 lime Lo Start Emd Dur Time Depth-Start Depth End Time Time (hrs) phase Op Cade' Activity Code P-T-X Trbl Code TrblClass. (TtKB) (ftKB) Operation 11:15 13:30 2.25 SURFAC CEMENT DISP P 2,674.0 2,674.0 ~',®rrterrt 9 518" casing as follows: Pumped 40 bbls Biozan water w/nut lu for marker w/ rig pump - umped 3 bbis water w/ Dowell -Pressure test lines to 3700 psi -Dropped btm plug -Mixed & pumped 50 bbis - 10.5 MudPush. @ 5.5 BPM @ 160 psi - Ixe ~ pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.6 BPM @ 240 psi -Observed nut plug marker @ shakers w/ 280 bbls lead slurry pumped -pumped down surge can - 296 bbis total lead slur um ed - umpe sal slu (Class G w/ D65) @ 15.8 ppg @ 5.5 BPM @ 175 psi - Dropped top' plug w/ 20 bbis water - Switched to rig pump & dis laced w/ 177 bbls 9.9 mud 7.5 BPM @ 400 to 640 psi -Slowed pump to 4 BPM for last 8 bbis @ 540 psi -Bumped plug t/ 1200 psi -Checked floats OK - CIP @ 1330 hrs. - Reci ocated ipe during job -full returns throughout - s ppg cm re urns o su ace 13:30 14:30 1.00 SURFAC CASING DH Q P 2,674.0 0.0 RU and test casing to 3500 psi for 30 minutes -bleed off and blow down lines 14:30 18:30 4.00 SURFAC DRILL RURD P 0.0 0.0 RD cement head and casing equipment - LD landing joint - ND riser and speedhead -install FMC wellhead & test seals to 1000 psi for 10 mins. 18:30 20:00 1.50 SURFAC WELCTL NUND P 0.0 0.0 NU BOPE -Install bell nipple & flow line - Make up turnbuckles -set mouse hole 20:00 21:30 1.50 SURFAC DRILL OTHR P 0.0 0.0 Install drilling bails & DP elevators - PU & Spot GeoSpan unit -Bring BHA componets(ghost reamers & bit) to rig floor -Install long wear bushing 21:30 21:45 0.25 SURFAC DRILL SFTY P 0.0 0.0 PJSM on picking up DP 21:45 00:00 2.25 SURFAC DRILL PULD P 0.0 1,465.0 PU 5" DP f/ pipe shed & RIH to 1465' (45 jts of 399 to pick up) Mud Check Data Type Depth (ftKB) Dens (Ib/gal) Vis (slat) PV Calc(cp) YP Calc (Ibf/100ft') Gel (10s) (Ibf/100ft') Gef (10m) (IbfltOQft') Gel (30m) (Ibf/100ft')- MBT (Ib/bbl) HTHP Filt (mL/30min): pH. Density Temp (°F) Solids, Con. (%) Spud Mud 2,684.0 9.80 56 31.0 13.0 4.0 5.0 5.000 8.8 8.8 8.0 In`ection Fluid Fluid Source F(omLease (bbp Destination Vendor Manifest.Number Note Diesel 10.0 CD4-302 periodic freeze protect Diesel 5.0 CD4-302 infectivity test Fresh Water 10.0 CD4-302 spacer Other CD4-05 565.0 CD4-302 Cmt comtam. mud Water Based Mud CD4-05 1290.0 CD4-302 Drill Strin s: BHA No. 1 - 8" 4/5 5.3 motor / Bit Run No. 1 - 12 1L4ia, Hu hes Christensen ', MXL-1 , 5122871 Depth In (ftKB) Depth Otrt (ftKB) TFA (incl Noz) (in=) Nozzles (/32") IADC Bit Dull String Wt (10001bf) 114.0 2,684.0 3-5-WT-A-E-1-HC-TD 44 Drill Strin Com onents Jts Item Description OD (in) ID (in) : Top Conn Sr(in) TbpThread :Cum Len (ft) Mud Motor 8 5.000 6 5/8 H 90 31.87 Page 2/3 Report Printed: 4/22/2009 Security Level: Development ~- `: -~, - ,~~ ~ Daily Drilling. Report CD4-05 Report Number: 4 Rig: DOYON 19 Report Date: 11/16/2007 DriII Strin Com onents Jts Item Description OD (in) ID-(in) Top:ConrnSz'(in) Top-ihread Cum Len (ft) Float Sub 8 2.750 6 5/8 H 90 33.66 Integral Blade Stabilizer 8.11 2.813 6 5/8 H 90 39.54 XO Sub 8.05 3.000 6 5/8 H 90 41.19 MWD (Directional) 8 1.920 6 5/8 Reg 50.27 MWD HCIM 7.98 1.920 6 5/8 Reg 58.65 MWD TM 8 1.920 6 5/8 H 90 68.10 Non Mag UBHO Sub 7.88 2.750 6 5/8 H 90 70.63 NMDC 7.67 2.813 6 5/8 H 90 101.60 NMDC 8.11 3.313 6 5/8 H 90 132.56 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 167.88 24 HWDP 5 3.000 4 1/2 IF 893.70 1Nellbores Wellbore Name Wellbore APWWI CD4-05 501032055800 Section Size (in) AcC "rop (ftKB) AcPBtm (ftK8) Start.Date End Date COND1 18 36.0 114.0 11 /1 /2007 11 /2/2007 SURFAC 121/4 114.0 ~ 2 ,684.0 11/14/2007 11/15/2007 INTRMI 8 3/4 2,684.0 15 ,155.0 11/18/2007 11/23/2007 PROD1 6 1 /8 15,155.0 21 ,142.0 11/29/2007 12/3/2007 Cement Surface Casin Cement -Started 11/16/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-05 SURFACE, 2,674.OftK6 Stg No. Description Top (fi:KB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Surface Casing Cement 36.0 2,674.0 8 586.0 Fluid Glass mount (sacks) V(pbp Density(IWgap Yeld(fNlsack): Est T op(ftK6) EstBtm.(ftK8) Lead Cement G 374 296.0 10.70 4.45 0.0 2,174.0 Tail Cement G 239 49.0 15.80 1.16 2,174.0 2,674.0 Page 3/3 Report Printed: 4/22/2009 • • ~~ ~ ~ - Cement Detail Re ort '-~ P -~ . ~ CD4-05 .~ ° String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/16/2007 11:30 11/16/2007 13:26 CD4-05 Comment Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug for marker w/ rig pump -Pumped 3 bbls water w/ Dowell -Pressure test lines to 3700 psi -Dropped btm plug -Mixed & pumped 50 bbls - 10.5 ppg MudPush @ 5.5 BPM @ 160 psi -Mixed & pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.6 BPM @ 240 psi -Observed nut plug marker @ shakers w/ 280 bbls lead slurry pumped -pumped down surge can - 296 bbls total lead slurry pumped - Pumped 49.6 bbls tail slurry (Class G w/ .2% D046 + 1 % S2 + .2% D46 = .35 D65) @ 15.8 ppg @ 5.5 BPM @ 175 psi -Dropped top plug w/ 20 bbls water - Switched to rig pump & displaced w/ 177 bbls 9.9 ppg mud @ 7.5 BPM @ 400 to 640 psi -Slowed pump to 4 BPM for last 8 bbls @ 540 psi -Bumped plug t/ 1200 psi -Checked floats OK - CIP @ 1330 hrs. - Recipocated pipe during job -full retums throughout - 112 bbls 10.7 ppg cmt returns to surface Cement Sta es Sta e # <Sta a Number2> Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surtace Casing Cement 36.0 2,674.0 Yes 112.0 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) 6 8 8 586.0 1,272.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment :Cement Fluids & Additives -Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 2,174.0 374 G 296.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.20 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) Tail Cement 2,174.0 2,674.0 239 G 49.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprSV 1 (psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/22/200 9 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 00 _ N W 0 O 0' W 0 N 0 0 0 _ 0 O 0 O 0 O 0 O 0 ao 0 M 0 M 0 ao 0 CO 0 I~ 0 ti 0 ~ 0 ~r 00 0 Y r r r r ~ r r d ~ y N d1 ~ : ! 4 F + 3 m ~ ~ ~ ~ O In In r Ln N Ln M Ln ~ Ln Ln Ln (O tL3 I~ LL~ 00 In ~ L n O ~ 'a ~, •L ~ O O r N M ~ Ln (a f~ a0 O r ~ m 3 ~ _ __ d ~+ a _ ° ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ ' co v u~ co r co N 0 ~ o o o ~n 0 ~ oo m L m r N M d" ~ fp co r o co O O O O O ~ ~ N •~ ~ ~ m 3 i ~ M ~ ~ 47 O r N ~ t,f) (p I M 0 0 r N M T t0 C0 O 7 Q. Q. L r r r r > a Y (n O Y ~ N ` ~ _ 0 M 0 ao 0 ao 0 ti 0 ti 0 r 0 ti 0 ~ 0 0 0 O 0 O O O 0 ~[> 0 ~' 0 ~' Y M d ~ ^ O ~ ~ L () ~ ~ ~ ~ ~ t [) i f 7 ~ ~ ~ t o ~ ~ d V ~ m - •~ M M M M M M M M M M M M M M M ~ R m 7 O 0 r+ ~ C O r N M ~ 1n C4 1~ 00 0 0 to O H O -a 0 ~ ~ r r N N M ; y ~ ~ m O ~.+ . ~ O O O O 0 0 0 0 '. 0 0 4 O 0 0 0 0 0 0 h 7 tZ ' y ~ _ N r r M ~' ~ oO I~ ~ 0 N r O M 00 ~t 00 GO (3') 00 ~ r (p M 0 CO ~' M r Cfl M O O d ~ ~ C (,~ ~_ r r r r c- N N N N M M M ~ 41 m ~ ~' ~'' E y O N ~ CO GO O N V 0 00 0 N d• CO OO O N ~ 3; Y d ~ _ r r r r r N N N N N M M M ; a d' M ~ ~ ~ , ' N ~ _ . N ~ ~O ~ ~ y ~ ~ O }, N ~ CD a ~ LL LL ° O 3 N ~ Y r CL C L ~ O ~ O O ~ N N ~ m ~ L .l ~ C ~ r j ~ d i N CA ~ N fA ~ •~ ~ L O ul ~ N d ? Q .fl .Q ~ Q to ~ ~ r' a? ~ Q .o d ~ QJ J J Q u , N ~ c 0 N C O O O O Lp ~" ~ c~ E ~ E W N a d N! ~ ~ m O ~ ', H ai n r O O ° O cci r ~ ~ C. `'' S ~~ °- a~ ~ ~ a° C H o 't7 N N O) ~ LLLL Q Q A C W L t o Q ~ ~ N ~ ~ ~ ~ ~ • w ~ ~ Z ~ 3 d O ~ 7 C •~ fA W ~' a a a Cr. o~~, + ~ ~ ~ V o I ~ p o• £ o00oN a ' ~~ M 0 ~ Y ~ N N~ O r U O W~ ° ~ ~ ~ m p O D o K II O ~' O O M 0°0 o ~ ~ ^ ~ LL " O ~ N J O O ~ ~ Xk ~ Q U of ~~ N ~ i R LL W ~ O o ~ .N L ~ N ~ T 7 t0 L 0 M + r~ V d' p II ~N.r W ~ u_ ~ Q O~ y N y ~ t ~ N (~ d ~ ~ N O.~ N~.Q~ Cf ~ L ~ p Q.J QJ J Q '~ ~ ~ ~ ~ ~ 0 0 0 0 0 1 ~ ~ m ~ ~ O ' 0 O O O N ' N O ~ a+ ~ tS~ 0 0 a ~ ~ ~ ~ . ~ O M ~ t~ ~ CO ~ t4 cLi~ ~ O N ~ c ~ am ~ ~ t N ~L t (p' ~ ~ L ~ R Z LO U ~ (} C ~(~ J ~ N 7 ~ ~ ~ ~ V > ~ ~ > i K ~ U "J c ~; H ~ N N O m o d m> y d ~ W t n N N • p ' ~ O ~ I- ' w ~ ~ ~ ~ ~ , O G ~ LL ~ ~ o O O 2 C ~ O ~ ~ ~ Y t0 j ~ G1 m V v ~ J 0 ~ ° ° ° ° ° ° ° ° N ~ ~ gy / i W a n o ~ n 0 o ~ n o ~ o ~ V C~ M N N ~ ~ Z ~ _ N vI ~, ~ m ~~ ~ aanss3bd ~ _ N ~ 'L O ~ O i D = W U • ~,, Casing Detail well: CD4-05 ConocoPhillips 7" casrna Date: 11}25/07 .Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.33 FMC Gent/ Hanger 3.34 34.33 Jts 192 to 355 164 Jts 7" 26# L-80 BTCM Csg 6987.71 37.67 Halliburton HES Stage collar 2.47 7025.38 Jts 4 to 191 188 Jts 7" 26# L-80 BTCM Csg 7982.99 7027.85 Halliburton Shut-off baffle 1.00 15010.84 Jts 3 to 3 1 Jts 7" 26# L-80 BTCM Csg 40.95 15011.84 Halliburton Float Collar w/ By-pass baffel 1.02 15052.79 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.54 15053.81 Ray Oil Tools "Silver Bullet "Float Shoe 2.12 15138.35 7" Shoe @ 15140.47 8 314" hole @ 15155.00 8-314" Hole TD @ 15,155' MD / 7553.75' TVD 7 "Shoe @ 15,140.47' MD / 7553' TVD Total Centralizers: 70 Straight blade centralizer one per jt on jts # 1-14 Straight blade cent. one per jt on jts. #'S 191 thru 214 Straight blade cent. one per jt. on joint #'s 294, 295, 296 Straight blade cent.one on every other jts. # 298 thru 354 365 joints in shed - 355 total jts. to run Last 10 jts. Out Use Run & Seal i e do e Average make up torque 6800 ft/Ibs Drifted 6.151" SOW 145K PUW -Unable to move pipe with 425K Blocks Wt. 75K Supervisor.' Burley /Hill Page 1 Security Level: Development ' ~ ` ~ ; _ Daily Drilling Report °~ ~_ CD4-05 ,. ,• Report Number: 14 Rig; DOYON 19 Report Date: 11/26/2007 AFE Type Neiwork/ID# Total AFE+Sup 10200411 10,044,998.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4-05 Development ALPINE 13.00 14.0 0.00 15,155.0 15,155.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,487.27 453,416.37 545,772.27 3, 808,142.37 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 11 /13/2007 1 1 /14/2007 31.36 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) PRODUCTION, 15,140.5ftKB Ops and Depth @ Morning Report 24hr Forecast RIH with Cleanout BHA. RIH and clean out casing. Test casing. POOH and PU Drilling BHA. Last 24hr Summary Circulated and conditioned mud. Cemented 2 stage job on 7" casing. Set and tested packoff. Changed rams to VBR. Tested rams. Laid down 5" DP in mousehole. General Remarks Weather Head Count Clear 45.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor Time. Lo Start End Dur Time Depth Start Depth End Tme Trne (hrs) -.. Phase -- Op Cade Activity Code '. p T-X 'Trhl Code _ Trbl Class. (~~) - (ftKB) 'Operation 00:00 00:15 0.25 INTRM1 CEMENT RURD P 15,140.0 15,140.0 MU Cement head and lines 00:15 02:30 2.25 INTRM1 CEMENT CIRC P 15,140.0 15,140.0 Stage pumps up to 6.5 bpm -circulate and condition mud for cementing - Attempted to reciprocate pipe W/ 425K - unable. FCP=670 psi -Held PJSM with . Dowell and rig crew 02:30 05:00 2.50 INTRM1 CEMENT DISP P 15,140.0 15,140.0 Cement 1st stage'7"' casing as follows: Pumped 2 bbls CW-100 -Dropped Halliburton Bypass Plug -Load closing plug -Test lines to 4000 psi -Pumped 38 bbls CW-100 @ 4.5 bbls/min @ 400 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.4 bbUmin @ 390 psi - Mixed & Pumped 152 bbls Lead Slurry Class G w/ additives @ 11.0 ppg @ 470 psi -Muted strut 24 bbls of 15.8 ppg Tail Slurry Class G w/additives @ 4.6 bpm / 225 psi -Dropped top plug and pumped 20 Bbls water behind. Switched to rig pumps & displaced w/ 554 bbls 10.0 ppg LSND mud @ 7 bbl/min @ 570 to 840 psi -slowed rate to 4 bbllmin @ 640 psi for last 10 bbls of displacement - Bump plug with 1150 psi. Floats held. Full returns throughout. - CIP @ 0500 hrs. 05:00 05:15 0.25 INTRM1 CEMENT OTHR P 15,140.0 15,140.0 Check floats, holding -Loaded 2nd stage closing plug in cement head and opened stage collar with 3,200 psi. 05:15 05:45 0.50 INTRMI CEMENT CIRC P 15,140.0 15,140.0 CBU @ 7 bpm / 370 psi Latest BOP Test Data Date Comment 11/17/2007 Tested h dril to 250 & 2500 si -all other tom onets to 250 & 3500 si - AOGCC waived witnessin of test Page 1/3 Report Printed: 4/22/2009 Security Level: Development • Daily Drilling Report _,~ y S ~ CD4-05 '~ V Report Number: 14 ., . .• Rig: DOYON 19 Report Date: 11/26/2007 Time Lo Start Time End Time Dur (hrs) Phase Op Code Activity Code Time P-T-X Trbl Code Trbf.Glass. Depth Start (ftKB) DepthEnd (ftK6) Operation 05:45 07:00 1.25 INTRM1 CEMENT DISP P 15,140.0 15,140.0 Cement 2nd Stage 7" casing as follows: - Pumped 20 bbls CW-100 @ 4.7 bbls/min @ 144 psi -Mixed & pumped 30 bbls MudPush XL @ 10.5 ppg @ 4 bbl/min @ 148 psi -Mixed & Pumped 37 bbls Tail Slurry Class G w/ additives @ 15.8 ppg @ 4.6 BPM / 116 psi -Dropped Closing plug and pumped 20 Bbls water behind. Switched to rig pumps and displaced with 10.0 LSND mud @ 7.5 bpm / 180-410 psi -Slowed to 3 BPM / 190 psi for last 6 Bbls and bumped plug with 2470 psi closing Stage collar total of 249 bbls of mud. CIP @ 0650 Hrs. Checked floats OK. Full returns throughout. 07:00 08:15 1.25 INTRM1 CEMENT RURD P 0.0 0.0 RD cement head and lines - LD landing joint and RD casing elevators 08:15 09:30 1.25 INTRMI CASING DHEQ P 0.0 0.0 Putl wear bushing -Install and test packoff to 5000 psi for 10 minutes 09:30 11:30 2.00 INTRM1 WELCTL BOPE P 0.0 0.0 Set upper test plug -Change top pipe rams to 3 112" x 6" VBR's -test rams 250/3500 psi. -pull test plug and install wear bushing 11:30 12:00 0.50 INTRMI GASING RURD P 0.0 0.0 Changed out long bales and picked up 5" elevators. 12:00 00:00 12.00 INTRM1 DRILL PULD P 0.0 0.0 Laid down 5" DP from derrick in mousehole. .Mud Check Data Type Depth (ftK6) Dens (Iblgal) Vis (s(qt) PV Calc (cp) YP Calc ' (Ibf/100ft') GeP(tos) (Ibf1100ft') Gel (10m) (Ibfl100ft?} Gel (3om) (Ib_f/100ft') M6T (Ib/bbl) HTHP Filt (m_ L/30min) pH Density Temp ('F) Solids, Corr. (~) LSNDw/ 15,155.0 10.00 38 10.0 15.0 7.0 8.0 10.000 10.5 7.3 9.2 10.5 Inhibycol XT 1n~ectiori Fluid Fluid Source Ecom Lease (bbl) Destination Vendor Manifest Number Note Diesel CD4-05 59.0 CD4-05 Water CD4-05 300.0 CD4-05 Water Based Mud CD4-05 1960.0 CD1-19 Water Based Mud CD4-05 14.0 CD4-05 Wetl6ores Wellbore Name Wellbore APIIUWI CD4-05 501032055800 Section Ste(in) ActTOp(ftKB) Ad.Btm(ftKB) Start-Date - End'Date COND1 18 36.0 114.0 11 /1 /2007 11 /2/2007 SURFAC 12 1 /4 114.0 2,684.0 11 /14/2007 11 /15/2007 INTRMI 8 3/4 2,684.0 15,155.0 11/18/2007 11/23/2007 PROD1 6 1 /8 15,155.0 21,142.0 11 /29!2007 12/3/2007 Dement 7" casin 2 Sta a -Started 11/26/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD4-05 PRODUCTION, 15,140.5ftK6 Stg No. Description Top (ftKBj Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 7" casing 2 Stage 11,200.0 15,140.0 4 600.0 Fluid Class € ;Amount(sabks) V (bbl) DensityQ_blgal) Yield;(ft'/sack). Est T op (ftKB) Est Btm;(ftl(B) Lead Cement G 250 150.0 11.00 3.35 11,200.0 14,640.0 Tail Cement G 115 24.0 15.80 1.17 14,640.0 15,140.0 Page 213 Report Printed: 4/22/2009 Security Level: Development Daily Drilling Report :_~a-~- ,~ ~. , f '_' ~ CD4-05 ... Report Number: 14 Rig: DOYON 19 Report Date: 11/26/2007 Stg No. Description Top (ftKB) Bottom (ftKB) 4 (end) (bbl/... P (final) (psi) 2 6,046.0 7,025.0 3 190.0 Fluiii Class Amount (sacks} V(bbp ~ensity(Ib[gaq Yield(f~/sack) Est T op(ftK6) EstBtrrt(ftKB) Tail Cement G 176 37.0 15.80 1.17 6,025.0 7,025.0 Page 3/3 Report Printed; 4/22/2009 i • - Cement Detail Report : 5 ~_ ..• String: 7" casing 2 Stage Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7" casing 2 Stage 11/26/2007 03:04 11/26/2007 06:50 CD4-05 Comment CementSta es Sta a#1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 7" casing 2 Stage Cover sands 11,200.0 15,140.0 Yes Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 600.0 1,150.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement 1st stage 7" casing as follows: Pumped 2 bbls CW-100 -Dropped Halliburton Bypass Plug -Load closing plug -Test lines to 4000 psi -Pumped 38 bbls CW-100 @ 4.5 bbls/min @ 400 psi -Mixed & pumped 40 bbis MudPush XL @ 10.5 ppg @ 4.4 bbl/min @ 390 psi -Mixed & Pumped 152 bbis Lead Slurry Class G w/ additives @ 11.0 ppg @ 470 psi -Mixed and pumped 24 bbls of 15.8 ppg Tail Sluny Class G w/additives @ 4.6 bpm / 225 psi -Dropped top plug and pumped 20 Bbls water behind. Switched to rig pumps & displaced w/ 554 bbls 10.0 ppg LSND mud @ 7 bbl/min @ 570 to 840 psi -slowed rate to 4 bbl/min @ 640 psi for last 10 bbls of displacement -Bump plug with 1150 psi. Floats held. Full returns throughout. -CIP @ 0500 hrs. CementF)uids & Additives Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement. 11,200.0 14,640.0 250 G 150.0 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 14,640.0 15,140.0 115 G 24.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... 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 Sta a#2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? K-2 6,046.0 7,025.0 Yes Yes No 4 (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 3 6 190.0 2,470.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement 2nd Stage 7" casing as follows: -Pumped 20 bbls CW-100 @ 4.7 bbls/min @ 144 psi -Mixed & pumped 30 bbls MudPush XL @ 10.5 ppg @ 4 bbl/min @ 148 psi -Mixed & Pumped 37 bbls Tail Slurry Class G w/ additives @ 15.8 ppg @ 4.6 BPM / 116 psi -Dropped Closing plug and pumped 20 Bbls water behind. Switched to rig pumps and displaced with 10.0 LSND mud @ 7.5 bpm / 180-410 psi -Slowed to 3 BPM / 190 psi for last 6 Bbls and bumped plug with 2470 psi closing Stage collar total of 249 bbls of mud. CIP @ 0650 Hrs. Checked floats OK. Full returns throughout. Cement Flu)ds 8~ Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) .Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 6,025.0 7,025.0 176 G 37.0 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 Unk label Page 1l1 Report Printed: 4/22/200 9 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: ~D4-05 Rig: Doyort 19 Date: 1112612007 Volume In ut Pum Rate: Drilling Supervisor: l~. Bt.~rley I Im. I-lill N~ur~np used: cement unit ~ Barrels ~ 0.1000 gbls/Strk ~ 0•$i Bbl/min ~ T f T t ~ P i d ~ ~ ype o es : Annulus Leak Off Test for Disposal Adequacy ump ng own annulus. Casin Test Pressure Ira te ri Test Hole Size: $-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 3433.0 Ft 2.674 Ft-MD 2 388 Ft-TVD 6 025 Ft-MD 3.87.7 Ft-TVD Bbls si Min si Bbls si Min si Casing Size and Descriution: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 ' `0 0 545 Chan es for Annula r Ade ua c Test Pressure Irat e ri Tes t 1 0.5 51 0.25 530 outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 1 111 0.5 510 Description references outer casing string. Inner casing OD: 7.0 In. 3 - 1.5 ' 167 1 485 ize is that drilled below outer casing. 4 2 ' 227 1.5 timated TOC for Hole Depth. 5 2.5 293 2 4 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 344 2.5 455 Estimates for Test: 745 si 0.5 bbls 7 3.5 ...396 3 450 ~ ~ 8 4 '.450 3.5 450 EMW =Leak-off Pressure + Mud Weight = 813 ~~~~, PIT 15 Second 9 4.5 500 4 450 0.052 x TVD 0.052 2388 T ~~~ Shut-in Pressure si 10 5 545 4.5 444 EMW at 2674 Ft-MD 2388 Ft-TVD 16.5 530 15 5.5 58s 5 444 ~oo0 ~ 20 a 641 5.5 444 25 6.5 677 6 444 30 7 727 6.5 439 '~~ 7 767 7 439 _ 8 813 7.5 439 8.5 833 8 439 w 9 848 8.5 439 ~ 9.5 858 9 39 5 0 10 853 9.5 439 0 N w 10.5 ':828 10 4 ,, o 11 803 . 11.5 753 12 .692 12.5 641 13 13 5 06 . 14 591' 0 0 2 4 6 8 1 0 1 2 14 1 6 0 5 1 0 1 5 2 0 2 5 30 Cdr-' CASING TEST Barrel s ~ ~ LEAK-O FF TEST Shut-I O P n tim IT Poin e, M t inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back 0.0 Bbls Bbls 14.0 Bbls Bbls Comments: 9 5l8" Surface casing FiT mm 18.2 F71~0 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: x,07_ f.~s C.`P 4" °S 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 18th, 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 1~1G111 t'°'"` ~ MAC? :z ~` ~bC!~ 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 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # .cement um ed cement date 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 C 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 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071550 Well Name/No. COLVILLE RIV UNIT CD4-05 Operator CONOCOPHILLIPS ALASKA INC MD 21142 TVD 7491 Completion Date 12!7/2007 REQUIRED INFORMATION Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Data Digital Electr Dataset Med/Frmt Number Name D D Asc - - -- __ Directional Survey pt Directional Survey pt LIS Verification i~ C Lis 16004 Induction/Resistivity p'Log Induction/Resistivity ", Log Induction/Resistivity C 16052 /Induction/Resistivity Well Cores/Sampl es Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? 1~~ Analysis aL,L.PI/ Received? Log Log Run Interval OH / Scale -------- - Media No Start Stop CH Received Comments -- - ----- -------- 36 21142 Open - 1/16/2008 36 21142 Open 1/16/2008 2644 21094 Open 3/7/2008 Lis Veri, GR, ROP, FET, RPD, RPM, RPS, RPX 2644 21094 Open 3/7/2008 Lis Veri, GR, ROP, FET, RPD, RPM, RPS, RPX 25 Col 114 7490 Open 3/28/2008 TVD, ROP, DGR, EWR, ADR 3-Dec-2007 25 Col 114 21142 Open 3/28/2008 MD, ROP, DGR, E!^.~R, ADR 3-Dec-2007 114 21142 Open 3/24/7200 MD and TVD logs in CGM, EMF, PDF graphics Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Su (data taken from Logs Portion of Master Well Data Maint Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~~~N~~ Formation Tops L'~^~ API No. 50-103-20558-00-00 Comments: DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071550 Well Name/No. COLVILLE RIV UNIT CD4-05 Operator CONOCOPHILLIPS ALASKA INC MD 21142 TVD 7491 Completion Date 12/7/2007 Compliance Reviewed By: __ _ ______ __ __ ______________ _ Completion Status 1-OIL Current Status 1-OIL Date: API No. 50-103-20558-00-00 UIC N RECEI~/EC~ • MAY 9 2008 STATE OF ALASKA 1 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~'ska Oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Ptug Perforations ^ Stimulate Q Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development 0 ~ Exploratory ^ 207-155 • 3. Address: Stretigrephic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20558-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD4-05 . 8. Property Designation: 10. Field/Pool(s): ADL 387208, 380077, 380075 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 21142' feet true vertical 7491' feet Plugs (measured] Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2618' 9-5/8" 2674' PRODUCTION 15084' 7" 15140' LINER W/PERF f 6158' 4-1/2" 21132' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth} 3-1/2" , L-80, 1501T MD. Packers &SSSV (type & measured depth) Baker Premier Packers Packer- 13022' SSSV= TRMAXXSE SSSV= 2075' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~~ ~Q~ ~ ZQQQ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1445 779 1 952 270 Subsequent to operation 3360 2287 98 1488 298 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-145 Contact Tim Schneider Printed Name .Tim Sc~neide~ Title Production Engineer Signature ~,_~~ ~ Phone 265-6859 Date ~~~~ --~1~ '~ `~~-t' Pre red b Jeanne Haas 263-4470 ~IGI~iAL ~r~ g ~~~9~ Form 10-404 Revised 04/2006 Submit Ori final Onl .. ~~~r. 5/r5~.~~ CD4-05 Stimulation Results Summary of stimulation job: 4-24-08: Pump frac in 7 stages in the Alpine °A" sand dropping 16 and 21 bio balls between each stage: The frac ramped from 2-7 ppa; Frac: AIR-27 BPM, AIP-4142 psi, ISIP-647 psi, 436,587# 16/20 Carbolite sand in open hole. 4817 bbls slurry, 50 bbls diesel for freeze protect and 136 bbls SW flush. 4-28-08: Pump frac in 4 stages in the Alpine "C" sand. The frac ramped from 2-8 ppa; Frac: AIR-20 BPM, AIP-4919 psi, 192,630# Carbolite sand in perfs and 32,800# left in tubing. Screened out. 2036 bbls slurry, 103 bbls diesel for freeze protect and 1893 bbls SW flush. Well test: 5/14/08: 3360 bopd, 98 bwpd, 2.29 mmcfpd, 298 WHP RE: Producer CD4-OS (PTD 207-155) TxIA communication Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, May 14, 2008 1:21 PM ~ To: NSK Well Integrity Proj; Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: RE: Producer CD4-05 (,PTD 207-155) TxIA communication ~ro~uCer - Zotc. ~ Tom and Jim, ~~ Page 1 of 2 ~~~~~ Slickline was able to set the OV on 05/13108. If you have any questions or need any more information, please let me know. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: NSK Well Integrity Proj Sent: Thursday, May 08, 2008 4:53 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Producer CD4-05 (PTD 207-155) TxIA communication « File: CD04-04 1 Mon TIO.png » With the attachment this time From: NSK Well Integrity Proj Sent: Thursday, May 08, 2008 4:51 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Producer CD4-05 (PTD 207-155) TxIA communication Tom and Jim, Due to the 4 days of down time caused by the current NS weather and the necessi#y of finishing up work required by the ice road at CD3, it is unlikely that the OV will be replaced within the one week time frame stated be{ow. hiowever, slickine will get on the Weil as soon as possible (mostly likely Monday May 12th}. Attached is the recent TIO for a 1 month time frame showing the current production period. Please let me know if you would like more information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. 5/20/2008 RE: Producer CD4-OS (PTD 207-155) TxIA communication Page 2 of 2 • Office (907) 659-7043 Cell (907) 943-1687 From: NSK Well Integrity Proj Sent: Saturday, May 03, 2008 1:02 PM To: Regg, James B (DOA); 'Maunder, Thomas E (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Producer CD4-05 (PTD 207-155) TxIA communication Tom/Jim, CD4-05 (PTD 207-155) had a successful hydraulic fracture simulation on 4/28/08 followed by a coil tubing unit fill clean out (CTU FCO) on 4/30/08. Before the frac a side pocket pressure gage was install in the GLM (gas lift mandrel) @ 12933' for frac surveillance. After the frac and FCO on 5/2/08 the gage was removed however, slickline has been unsuccessful re installing an OV in the GLM 12933' due to frac sand fall out in the belly of the GLM. To clean the sand from the GLM ConocoPhillips intends to flow the well on aaslift service with an omen GLM pocket at 12933' for a few days (no longer than 1 week). After which slickline will attempt to reinstall the OV. If the insta a Ion o e OV Is not successful after the flow back, another CTU FCO will be completed before slickline repeats the OV installation process. Sustained casing pressure is not present and the well will be online with TxIA communication for no longer than one week. A schematic and 3 month TIO are attached. « File: CD4-05 TIO.jpg » « File: CD4-05.pdf » ~ Please let me know if you have any questions or need more details. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 5/20/2008 CRU CD4-OS PTD 207-155 7!la~ PIQt - G1~4-0~ 1200 1000 800 600 400 200 0 - ~~~ _'~ 03-Feb-08 16-Feb-08 29-Feb-08 13-Mar-08 26-Mar-08 08-Apr-08 21-Apr-08 C1~t9 2ao 150 100 r 50 0 • • CRU CD4-OS PTD 207-155 5/8/2008 7!110 Plot -CD4-0~ 1400 1200 1000 800 600 400 200 0 07-Apr-08 12-Apr- 0 8 17-Apr-08 22-Apr-08 Dale 27-Apr-O$ 02-May-08 200 150 100 50 ~~ 0 07-May-08 • • C+~n~caP~ill~p~,~la~ka, Ins, TUBING , (114-15017, OD:3.500, `-` Casino String -ALL STRINGS Descri lion Size To -- Bottom TVD Wt Grade -_ Thread CONDUCTOR 16.000 0 114 114 65.20 H-40 WELDED SURFACE 9.625 0 2674 2388 40.00 L-80 MBTC ~- PRODUCTION 7.000 0 15140 7553 26.00 L-80 MBTC LINER wIPERF PUPS 4.500 14974 21132 7491 12.6(1 L-80 IBTM Tubing String TUBING -- -- - - - Size - -> S~ ~~) _ Top _- 2ottom TVD Wt Grade Thread _ - 0 114 11 d 12.60 L-80 IBTM - -- - _ 3 SUU ParfnratinnG ~u I 111 15017 ;~45 9.30 L-80 E!_!E mmarv 'RODUCTION (o-151ao, OD:7.000, Wt:26:00) Perf ;14350-14370) SLEEVE ;14353-14354, OD:3.675) NIP ;14409-14410, OD:4.490) PACKER 14974-14975, OD:5.960) LOCATOR ;14980-14981, OD:3.500) ALPINE CD4-OS CD4-05 _ - - -- API: 501032055800 Well T e: PROD An le TS: de SSSV Type: T RDP Orig Completion: 12/8/2007 Angle @ TD: 91 deg @ 21142 Annular Fluid: Last W/O: Rev Reason: PERF Reference Lo Ref Lo Date: Last U date: 1/4/2008 Last Ta TD: 21142 ftK6 Last Ta Date: Max Hole An le: 92 de 16638 Interval TVD Zone Status Ft SPF Date T e Comment 14350 - 14370 7440 - 7444 20 6 12/6/2007 IPERFS 2 7/8" PJ OMEGA GUNS 15325 - 21092 7557 - 7491 5767 6 12/4/2007 Perf Alternating solid pipe (avg Pups 209') w/4.79' pert pup (27 _ -- _ .._ - - joints of part pope) _ Gas Lift Mandreis/Valves I St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt i 4947 3401 CAMCO KBMG GLV 1.0 BK-5 0.188 1879 12/14/200 2 9951 5603 CAMCO KBMG GLV 1.0 BK-5 0.188 1806 12/14/200 3 12933 692.1 CAMCO KBMG nV 1.0 BEK-5 0.000 0 12!14/200 Uther (plugs, equ~p.,_etc.) - CUMNLf= I IUN De th TVD T e Descri lion ID 31 31 HANGER FMC TUBING HANGER 3.900 2075 1983 SSSV CAMCO TRMAXX-5E SSSV w/PROFILE 2.812 13022 6961 PACKER BAKER PREMIER PACKER 2.870 13101 6996 NIP HALLIBURTON 'X' NIPPLE 2.813 14353 7440 SLEEVE BAKER CMD SLIDING SLEEVE w/2.81' X PROFILE 2.813 i 14409 7454 NIP HALLIBURTON 'XN' 2.75" NO GO NIPPLE 2.813 ' 14980 7541 LOCATOR BAKER LOCATOR W/4' SPACE OUT ABOVE LANDING RING 2.992 14981 7541 SEAL BAKER SEAL ASSEMBLY 2.992 1F017 Other De th 7545 plugs, TVD WLEG -equip., etc T e BAKER WIRELINE ENTRY GUIDE .) -LINER DETAIL _ _- _ --_ - -_ Descri lion 2.992 ', ID 14974 7541 PACKER LINER BAKER'HRD' ZXP LINER TOP PACKER 4.430 14993 7542 NIP LINER RS PACKOFF SEAL NIPPLE 4.250 14997 7543 HANGER LINER BAKER FLEXLOCK LINER HANGER 4.420 15007 7544 SBE LINER 190-47 SEAL BORE EXTENSION 4.000 15027 7545 XO Bushin LINER CR05SOVER BUSHING 5" TO 4.5" 3.950 21131 7491 SHOE LINER BAKER BULL NOSE SHOE 4.500 R Q ~ ~ 4 ~ ~ ~ ~ ~ ~ ~ A~ d ~ 4~~ ~ I ~~~ ALASSA OIL AI~TD GAS COI~TSERQA7'IOZ•T COl-I1~IISSIOIQ Tim Schneider Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4-05 Sundry Number: 308-145 Dear Mr. Schneider: SARAH PAL/N, 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 the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court .unless rehearing has been requested. DATED this Z~day of April, 2008 Encl. Sincerely, f^ ,..~~yy ~1~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR ~ ~ LOOS APPLICATION FOR SUNDRY APPROVA~.~~a Oil & Gas C~;ns. Commission 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 207-155 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20558-00 w 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ^ NO ~ CD4-05 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 387208, 380077, 380075 ~ RKB 36' Colville River Field !Alpine Oil Pool ' 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 21142' • 7491' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2618' 9-5/8" 2674' PRODUCTION 15084' 7" 15140' _INER W/PERF PUP 6158' 4-1/2" 21132' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1 /2" L-80 15017' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packers Packer= 13022' SSSV= TRMAXX-SE SSSV= 2075' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory [] Development (] Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 22, 2008 ~ Oil ^~ ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tim S Id Title: Production Engineer Signature Phone 265-6859 /'~ Date '~ ~~=(~d" Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness (' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. `gg` ~~ ~ y ry gY 8 R-. F`9 ; y ~ / ~fi ~ i V V U Subsequent Form Required: ~~~ APPROVED BY Approved by: C M ISSIONER THE COMMISSION Date: ~` ~ ~. Form 10-403 Revised 06/2006 ~ --, Submit~rDuplicate •2. ''~~ Y(~~ a$ .+ ~ • Overview: CD4-05: A hydraulic fracture treatment will be performed in the Alpine "C" and- Alpine "A" intervals. :Procedure: 1. MIRU 10 clean insulated frac tanks. Load tanks with seawater from the injection system. 2. Rig up Service company equipment and stab Tree Saver. 3. Pressure test surface tines to 9500 psi 4. `Pump 350,000 lbs. of 16/20 carbolite proppant ramping. from 2-7 ppa into the Alpine "A" sand. 5. RD Service company tree saver. 6. RU slickline and set PXN plug is nipple @ 14,409' RKB above Alpine "A". 7. RIH with CMD shifting tool and open the sliding sleeve @ 14,353' RKB. RD slickline $. 'PU tree saver and stab .into tree. 9. Pressure test surface lines to 9500 psi. 10. Pump 250,000 bls. 16/20 carbolite proppant ramping from 2-7 ppa into the Alpine "C" sand. 11. RDMO service company equipment. 12. RU CT and perform FCO to PXN plug @ 14,409' RKB. POOH. RD 13. RU slickline and pull PX prong in XN plug body. RIH and pull XN plug body. 14. RDMO. 15. Put well to production. Page 1 of 2 Maunder, Thomas E (DOA) From: Schneider, Tim S. [Tim.S.Schneider@conocophillips.com) Sent: Friday, April 18, 2008 1:30 PM To: Maunder, Thomas E (DOA) Subject: RE: CD4-05 (207-155) Stimulation Sundry -Again Tom, I talked with Vance Yoakum, our stimulation authority for CPAI, and he said he's not seen any issues in the past 10+ years fracture stimulating through a frac sleeve causing damage to the sleeve or the casing. He didn't ~ state how many that had been done, just no issues. He also mentioned that he had pumped some fracs through 3-1/2" gaslift mandrels (1" pocket) and not damaged the pocket or casing. I'll forward your request for an updated 407 and have it sent over early next week unless you need it today in order to approve our proposed stimulation. Thanks for reviewing this so quickly. Tim Schneider Prod. Engineer CPAI WNS From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 18, 2008 1:08 PM To: Schneider, Tim S. Subject: RE: CD4-OS (207-155) Stimulation Sundry -Again Tim, Will pumping 250,000 # of proppant through the sliding sleeve potentially be damaging to the sleeve or casing? Thanks for the, updated wellbore drawing. As we discussed, I had checked further on the drawing in our file and the 407 that was submitted and there is no mention of the Alpine C perforations. The operations summary does record that those perforations were shot. I believe that a revised 407 with the drawing should be submitted. With regard to holding IA pressure, I expected you were doing it but needed it confirmed. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Friday, April 18, 2008 12:43 PM To: Maunder, Thomas E (DOA) Subject: RE: CD4-05 (207-155) Stimulation Sundry Tom, Here's the wellbore schematic you had requested. Also, regarding your question on IA pressure. We have Baker model the expected tubing movement during the frac stimulation job. From this we have been maintaining between 3000-3500 psi IA pressure during the frac job We have a pump truck RU to the IA and have them maintain this pressure range. If you need additional information, please let me know. thanks 4/18/2008 Page 2 of 2 Tim S. Schneider Subsurface Development Staff Production Engineer WNS-Alpine '~ Phone: 907-265-6859 ~ Fax: 907-2656472 ~ Mobile: 907-632-8136 rte-' Email: um.s.schneider@conocophilhps com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 18, 2008 12:35 PM To: Schneider, Tim S. Subject: CD4-05 (207-155) Stimulation Sundry Tim, I am reviewing the sundry to stimulate this well. Nothing is mentioned regarding holding pressure on the IA. Since you plan to test your surface lines to 9500 psi, it would seem appropriate that some annulus pressure is needed. 1 look forward to your response. Tom Maunder, PE AOGCC 4/18/2008 -~-~ `~ . '~ C+~no~coPhillips Al~~ka, iin~~. ruaiNG - - - - ' d4-05 API: ' t11a-15an oD 3500, ~ ~ _ .__ SSSV Type: ID2 992) ~ II 114 jai - Man r ALPINE BK-5 BK-5 'RODUCTION - (0.15140, OD 7.000, Wt26.00) I Perf 14350-14370) SLEEVE - ;14353-14354, OD:3.875) NIP - ;14409-14410, OD:4.490) PACKER - ;14974-14975, OD:5.960) LOCATOR - ;14980-14981, OD:3 500) X WIRFI INF CD4-05 @T ~~ - @ TD 91 deg @ 21142 eason: ~ PERF I ate: 1/4/2008 - --- Perf Alternatin Pups 209') w/4. Other _DePth 4974 plugs, TVD j ~ 7541 equip., et Type - PACKER c.) - LINER ~:; .~,~,;'' I~` Description -- i LINER BAKER 'HRD' ZXP LINER T_OP PACKER _ -- -- , ,, ID 4.430 ,_ 14993 _ 7542 - NIP LINER RS PACKOFF SEAL NIPPLE ~ -_4.250 14997 _ 7543 HANGER i LINER BAKER FLEXLOCK LINER HANGER _ I _4.420 ~ 15007 7544 SBE 'LINER 190-47 SEAL BORE EXTENSION 4.000 15027 7545 XO Bushin LINER CROSSOVER BUSHING 5" TO 4.5" _ 3.950 21131 7491 SHOE LINER BAKER BULL NOSE SHOE 4.500 ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-OS March 10, 2008 AK-MW-5474256 CD4-O5: 2" x 5" MD ADR Logs: 1 Color Logs 50-103-20558-00 2" x 5" TVD ADR Logs: 1 Color Logs 50-103-20558-00 Digital Log Images: 1 CD Rom 50-103-20558-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,~ ~~. Date: ~„~ ~ ~: ~ ~;,n,5 ? Si 4~ ..- ~,~ Signed: c~o~-~5~ ~ t ~~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 L ~ March 6, 2008 RE: MWD Formation Evaluation Logs: CD4-OS AK-MW-547425 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 5 8-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995:1.$_ ..~ Date: Signed: ~D`~'~s `5 ~~lvCJ~~/ a `+ ConocoPhillips February 20, 2008 G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~G~~~ id Commissioner FEB 2 2 ~ppg State of Alaska Alaska Oil ~ Gas Cons. Commission Alaska Oil & Gas Conservation Commission Anchorage 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Corrected Well Completion Report for CD4-05 (APD 207-155) Dear Commissioner: J ConocoPhillips Alaska, Inc. submits the corrected Well Completion Report for the Alpine well CD4-05. A perforation interval was inadvertently left off of the initial report. ~1 p ~~ ~ ~ry ~ r ~~ If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~- G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ~ •1..V V~ r a..w FEB 2 2 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOA{aska Oil & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT A~1~~~0G 1a. Well Status: Oil O Gas Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ` 1b. Well Class: Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 7, 2007 12. Permit to Drill Number: 207-155 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 14, 2007 13. API Number: 50-103-20558-00 4a. Location of Well (Governmental Section): Surface: 2903' FNL, 148' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: December 3, 2007 14. Well Name and Number: CD4-05 Top of Productive Horizon: 627' FSL, 4107' FWL, Sec. 22, T11 N, R4E, UM 8. KB (ft above MSL): 56' AMSL Ground (ft MSL): 19.5' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 679' FSL, 1168' FWL, Sec. 15, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 21132' MD / 7491' ND Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378097 y- 5957507 Zone- 4 10. Total Depth (MD + ND): 21142' MD / 7491' TVD 16. Property Designation: ADL 3s72os, 3aoo77, 380075 TPI: x- 366486 y- 5955954 Zone- 4 Total Depth: x- 363634 - 5961337 Zone- 4 11. SSSV Depth (MD + ND): SSSV @ 2075' MD / 1983' TVD 17. Land Use Permit: 380077 1 S. Directional Survey: Yes ^~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (lVD): 1400' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G C AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE ORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" Portland Type III 9-5/8" 40# L-80 37' 2674' 37' 2388' 12.25" 374 sx AS Lite 3, 239 sx Class G 7" 26# L-80 37' 15140' 37' 7553' 8.75" 250 sx LiteCRETE, 115 sx CI G, 176 sx CI G 4.5" 12.6# L-80 14961' 21132' 7539' 7491' 6.75" blank liner w/pert. Pup joints 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 15020' 13022' alternating blank liner with pert pups from 15325'-21092' MD 14350'-14370' MD 7440'-7444' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 19, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 12/25/2007 Hours Tested 4 hours Production for Test Period --> OIL-BBL 455 GAS-MCF 368 WATER-BBL 1 CHOKE SIZE 100% GAS-OIL RATIO 951 Flow Tubing press. 283 psi Casing Pressure 1694 Calculated 24-Hour Rate -> OIL-BBL 2628 GAS-MCF 2501 WATER-BBL 8 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~ j (,'P1 `"~~ 1 ~' ~• 07" NONE '~!_~ 41-l.} i Form 10-407 Revised 2!2007 IIy~IE~AN REV ~ E SI ~ ~Q ~ e Iv` `/!q ~' X7.00 ~~~ ~~ ~2~8' ~ 28. GEOLOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes Q No If yes, list intervals and formations tested, Permafrost -Top Surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1412' 1400' needed, and submit detailed test information per 20 AAC 25.071. C-20 3609' 2813' K-3 5969' 3853' K-2 6545' 4104' ALB 97 10289' 5753' Top HRZ 13259' 7064' Kuparuk D 13492' 7161' Kuparuk C 13580' 7196' Alpine D 14247' 7414' Alpine C 14318' 7432' Alpine A 15043' 7547' N/A Formation at total depth: Alpine 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 h ia Alvord Title: WNS Drilling Team Lead / ~ Signature ~~~ °Ls` Phone ~,S-,~ ~ 2' Date ~Z-L- ~' INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 - /~ ~~~toct~Ph~11~P~ A~a~k~, Inc. C D4-05 ' TUBING API: 5010320558 {11415017, oD:3.5o0, SSSV Type: TRDP ID:2.992) ALPINE CD4-05 a7 TS: de a) - @ TD: 91 deg @ 21142 Last Tag Date:_I I Max Hole Angle• 192 deg n 1 gg3g I I I - - __ _ Casing String -ALL. STRINGS T _ - ~ROOUCnoN (0-15140, 00:7.000, wt:zs.ao) Pert :14350-14370) SLEEVE ;14353-14354, OD:3.875) NIP 14409-14410, OD:4.490) PACKER '14974-14975, OD:5.960) LOCATOR ;14980-14981, OD:3.500) LINER w/PERF PUPS. I__ 4.500 I _ 14974 -_ _ I 21132 I 7491 I 1260 I !._g0 I IBTM I Tubing String -TUBING _ - Size To Bottom TVD Wt Grade Thread __ 4.500 0 114 114 12.60 L-80 16TM 3.500 114 15017 7545 9.30 L-80 E U E _ - Perforations Summary __ Interval TVD Zone Status Ft SPF Date T e Comment 14350 - 14370 7440 - 7444 20 6 12/6/2007 IPERFS 2 7/8" PJ OMEGA GUNS 15325 - 21092 7557 - 7491 5767 6 12/4/2007 Perf Alternating solid pipe (avg Pups 209 w/4.79' pert pup (27 ioints of pert pups). __ ,__ Gas Lift Mandrels/Valve s ~ _~ __ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4947 3401 CAMCO KBMG GLV 1.0 BK-5 0.188 1879 12/14/200 2 9951 5603 CAMCO KBMG GLV 1.0 BK-5 0.188 1806 12/14/200 3 12933 6921 CAMCO KBMG OV 1.0 BEK-5 0.000_ _ 0 12/14!200 _ Other (plugs, equip., etc.) -COMPLETION _ _ __.. I nnnfh i TVn i Tvw i nn¢rrirNinn i In ~ 31 31 HANGER FMC TUBING HANGER 3.900 2075 1983 SSSV CAMCO TRMAXX-5E SSSV w/PROFILE 2.812 13022 6961 PACKER BAKER PREMIER PACKER 2.870 13101 6996 NIP HALLIBURTON'X'NIPPLE 2.813 14353 7440 SLEEVE BAKER CMD SLIDING SLEEVE w/2.81' X PROFILE 2.813 14409 7454 NIP HALLIBURTON'XN' 2.75" NO GO NIPPLE 2.813 14980 7541 LOCATOR BAKER LOCATOR W/4' SPACE OUT ABOVE LANDING RING 2.992 14981 7541 SEAL BAKER SEAL ASSEMBLY 2.992 i iJUl/ I /p4J I WLtCi ItiAKtK WIKtLINt-tNIKY LiUIUt I Z.L~`~L I _....... Other (plugs, equip., etc.) -LINER DETAIL -_ __ _-_ 4.420 4.000 3.950 4.500 ConocoPhillips January 23, 2008 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner State of Alaska ~~~ ~ 2008 Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 ~~ask~ Oil ~ ~~ Ct~ns. Commission Anchorage, Alaska 99501 _ Ar~choroge Subject: Well Completion Report for CD4-05 (APD 207-155) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-05. If you have any questions regarding this matter, please contact me at 265-6120 Sincerely, ~~ ~ ~, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ~ 3 ~~~~ WELL COMPLETION OR RECOMPLETION F~,~~,~~1;~on 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. VYell~ DevetAliof~plment ~/ . Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: December 7, 2007 12. Permit to Drill Number: 207-155 ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 14, 2007 ~ 13. API Number: 50-103-20558-00 4a. Location of Well (Governmental Section): Surface: 2903' FNL, 148' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: December 3, 2007 14. Well Name and Number: CD4-05 Top of Productive Horizon: 627' FSL, 4107' FWL, Sec. 22, T11 N, R4E, UM 8. KB (ff above MSL): 56' AMSL Ground (ft MSL): 19.5' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 679' FSL, 1168' FWL, Sec. 15, T11 N, R4E, UM 9. Plug Back Depth (MD + TVD): 21132' MD / 7491' TVD Alpine Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378097 y- 5957507 Zone- 4 10. Total Depth (MD + TVD): 21142' MD / 7491' TVD 16. Property Designation: ADL 3a72o8, 380077, 380075 TPI: x- 366486 y- 5955954 Zone- 4 Total Depth: x- 363634 - 5961337 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 2075' MD ! 1983' TVD 17. Land Use Permit: 380077 18. Directional Survey: Yes ^/ No^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1400' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE COR AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RE D PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" Portland Type III 9-5/8" 40# L-80 37' 2674' 37' 2388' 12.25" 374 sx AS Lite 3, 239 sx Class G 7" 26# L-80 37' 15140' 37' 7553' 8.75" 250 sx LiteCRETE, 115 sx CI G, 176 sx CI G 4.5" 12.6# L-80 14961' 21132' 7539' 7491' 6.75" blank liner w/pert. Pup joints 23. Open to production or injection? Yes / . No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET p `~ ~ 3.5" 15020' 13022' altern~ting blank liner with pert pups from 15325'-21092' MD ~ yil ~t Z ~° -~~ t~-lril 25. ACID, FRACTURE, CEMENTS EEZE, ETC. ~~ ~~~. '~~~ C \ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~ ~ n/a 1 ~35~ ~- ~ ~-13'l.C~ ~.~.~ 26. PRODUCTION TEST Date First Production December 19, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 12/25/2007 Hours Tested 4 hours Production for Test Period -> OIL-BBL 455 GAS-MCF 368 WATER-BBL 1 CHOKE SIZE 100% GAS-OIL RATIO 951 Flow Tubing press. 283 psi Casing Pressure 1694 Calculated 24-Hour Rate -> OIL-BBL 2628 GAS-MCF 2501 WATER-BBL 8 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / ~ Sidewall Cores Acquired? Yes No ^/ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~T~ NONE !2' ?• v -- ) a-~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~,~ /. 2 g'. Os/ '~'~..fs`itti ~'~. ~ ~;; ~~ :~ 2008 ,~ ~~~®~ a• r 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1412' 1400' ~ needed, and submit detailed test information per 20 AAC 25.071. C-20 3609' 2813' K-3 5969' 3853' K-2 6545' 4104' ALB 97 10289' 5753' Top HRZ 13259' 7064' Kuparuk D 13492' 7161' Kuparuk C 13580' 7196' Alpine D 14247 7414' Alpine C 14318' 7432' Alpine A 15043' 7547' N/A Formation at total depth: Alpine 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 i Ivord Title: WNS Drilling Team Lead l ~L; l ' ~ q Phone ~~+~ Signature ~e, ~ ~ ~, ZO Date 7 INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~orto+~oPhiilps Time Log Summary Wetwlew VJeb ReAOrtieg Well Name: CD4-05 Job Type: DRILLING ORIGINAL Time Lomas ___ __ Date From_To Dur _S. Depth E. Depth Phase Code_ Subcode T_COM _ _ _ _ 11/13/2007 03:00 04:30 1.50 0 0 MIRU MOVE RURD P Prepare rig for move 04:30 04:45 0.25 0 0 MIRU MOVE SFTY P PJSM for move 04:45 06:30 1.75 0 0 MIRU MOVE PSIT P Move out pits and motor complexes - skid rig -hoist feet -move subbase off of well 06:30 09:00 2.50 0 0 MIRU MOVE OTHR P Prep of CD4-05 cellar area a result of late change in drill schedule -Set matting boards -spot wellhead equipment -remove ladder and handrails from ad'acent wellhouse 09:00 12:00 3.00 0 0 MIRU MOVE PSIT P Move subbase onto well CD4-05 -skid rig over well -spot up pit and motor complexes Accept Rlg @ 1130 hrs. -move accept time back to cover time to prep location 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Rig up air water and steam lines - weldin re airs to monke board. 14:00 17:30 3.50 0 0 SURFA DRILL RURD P NU starting head & test - NU surface riser -set mouse hole 17;30 19:00 1.50 0 0 SURFA DRILL PULD P PU & std back 9 jts. HWDP -Run 1 std to ck for fill in conductor - No fill 19:00 20:00 1.00 0 0 SURFA RIGMN RGRP T Repair pipe skate 20:00 22:30 2.50 0 0 SURFA DRILL PULD P MU 12 1/4" BHA -bit motor & MWD - lu into MWD to u load 22:30 22:45 0.25 0 0 SURFA DRILL SFTY P Held pre spud meeting with crew & service hands 22:45 23:30 0.75 0 0 SURFA DRILL OTHR P Fill conductor & check for leaks OK - Pressure test mud lines to 3500 si 23:30 00:00 0.50 0 0 SURFA DRILL PULD P PU & MU NM DC's & jars 11/14/2007 00:00 12:00 12.00 114 889 SURFA DRILL DDRL P S ud well 0005 hrs Drill 12 1/4" hole w/ motor f/ 114' to 889' MD 88T TVD ADT 5.43 hrs =ART 2.5 hrs AST 2.93 hrs WOB - 10/25 k RPM 60 GPM 500 @ 1090 psi String wt. PU 112 SO 112 Rot 112 Torque on/off btm. - 6000/4500 ft/Ibs Run ros eve stand j ~'~ge 1 ztf ~~ I Date Frnm Tn DYir S Danth F rlanth Phaco hnriP Si ihcnria T ('CIA ! 11/16/2007 09:45 11:15 1.50 2,674 2,674 SURFA CEME~ CIRC P Stage pumps up to 7 bpm -circulate and condition mud for cementing - FCP=260 psi -Reciprocated pipe with full returns throu hout -PJSM w/ Dowell, MI, AES and ri crew 11:15 13:30 2.25 2,674 2,674 SURFA CEME~ DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/nut plug for marker w/ rig pump -Pumped 3 bbls water w/ Dowell -Pressure test lines to 3700 psi -Dropped btm plug - Mixed & pumped 50 bbls -10.5 ppg MudPush @ 5.5 BPM @ 160 psi - Mixed & pump Lead slurry (ArcticSet Lite 3) 10.7 ppg @ 7.6 BPM @ 240 psi -Observed nut plug marker @ shakers w/ 280 bbls lead slurry pumped -pumped down surge can - 296 bbls total lead slurry pumped - Pumped 49.6 bbls tail slurry (Class G w/.2%D046+1%S2+.2%D46= .35D65)@15.8 ppg@5.5BPM@ 175 psi -Dropped top plug w/ 20 bbls water -Switched to rig pump & displaced w/ 177 bbls 9.9 ppg mud @ 7.5 BPM @ 400 to 640 psi -Slowed pump to 4 BPM for last 8 bbls @ 540 psi -Bumped plug t/ 1200 psi - Checked floats OK - CIP @ 1330 hrs. `~~innratc?d ni~durlnq Iqb -full returns throughout -112 bbls 10.7 ppg cmt returns to surface 13:30 14:30 1.00 2,674 0 SURFA CASINC DHEO P RU and test casing to 3500 psi for 30 minutes -bleed off and blow down lines 14:30 18:30 4.00 0 0 SURFA DRILL RURD P RD cement head and casing equipment - LD landing joint - ND riser and speedhead -install FMC wellhead & test seals to 1000 si for 10 mins. 18:30 20:00 1.50 0 0 SURFA WELC NUND P NU ROPE -Install bell nipple & flow line -Make up turnbuckles -set mouse hole 20:00 21:30 1.50 0 0 SURFA DRILL OTHR P Install drilling bails & DP elevators - PU & Spot GeoSpan unit -Bring BHA componets(ghost reamers & bit) to rig floor -Install Ion wear bushin 21:30 21:45 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up DP 21:45 00:00 2.25 0 1,465 SURFA DRILL PULD P PU 5" DP f/ pipe shed & RIH to 1465' 45 ~ts of 399 to ick u 11/17/2007 00:00 01:15 1.25 1,465 0 SURFA DRILL PULD P Pick up 5"drill pipe from shed and RIH from 1465' to 2194' - POH stand back drill i e 69'tstotal 01:15 04:15 3.00 0 0 SURFA DRILL PULD P RIH picking up 5"drill pipe from shed to 2190' (69 jts.) POOH -stand back drill i e 04:15 05:00 0.75 0 630 SURFA DRILL PULD P RIH picking up 5"drill pipe from shed to -630' 20 'ts. ~ r Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/17/2007 05:00 05:30 _ 0.50 630 630 SURFA RIGMN' SVRG P Service Top Drive, Drawworks & Iron Rou hneck 05:30 08:15 2.75 630 0 SURFA DRILL PULD P Continue to RIH picking up 5"drill pipe from shed to 2190' (69 jts.total) POOH -stand back drill i e 08:15 11:00 2.75 0 0 SURFA DRILL PULD P RIH picking up 5"drill pipe from shed to -2190' (69 jts.) POOH -stand back drill i e 11:00 13:30 2.50 0 0 SURFA DRILL PULD P RIH picking up 5"drill pipe from shed to 2190' (69 jts.) POOH -stand back drill i e 13:30 14:00 0.50 0 0 SURFA DRILL OTHR P Pull wear ring and set test plug in wellhead 14:00 18:45 4.75 0 0 SURFA WELCT BOPE P Test BOPE - Annular to 250 & 2500 psi -Pipe rams -choke & kill line vavles, Choke manifold valves -Floor safety valve -Dart valve - TD IBOP valves -Blind rams to 250 & 3500 psi - perform accumulator closure test - AOGCC waived witnessing of test - RD & ull test lu 18:45 19:15 0.50 0 SURFA DRILL OTHR P Install wear bushing -Blow down choke & kill lines 19:15 00:00 4.75 0 723 SURFA DRILL PULD P MU BHA # 2 -Bit - GeoPilot - DM flex - DGR/PWD -Stab - EWR/HCIM - TM HOC -Float sub -Stab -Plug in & up load MWD - PU NM flex DC's - PT Geo-Span -Pulse test & down link MWD & GP - MU 1 std HWDP & Jars to 723' 11/18/2007 00:00 01:30 1.50 723 2,445 SURFA DRILL TRIP P RIH picking up 5" drill pipe from 723' to 2445' -placed ghost reamers 758' & 1812' above bit 01:30 02:00 0.50 2,445 2,445 SURFA DRILL DHEQ P Fill pipe -pulse test tools -blow down to drive 02:00 03:30 1.50 2,445 2,445 SURFA RIGMN SVRG P Slip and cut drilling line -Service top drive and drawworks 03:30 08:00 4.50 2,445 2,684 SURFA CEME DRLG P Wash down f/ 2445' -clean out cement from 2485' to 2593' -drill wiper plugs / FC /cement / FS /and clean out rathole to 2684' - 600 gpm / 1900 si / 60 m 08:00 08:15 0.25 2,684 2,704 SURFA DRILL DDRL P Drill 8 3/4" hole from 2684' to 2704' - ADT 0.16 hrs 08:15 08:45 0.50 2,704 2,704 SURFA CEME CIRC P CBU for FIT - 600 gpm ! 1900 psi / 60 rpm - MWT @ 9.5ppg -Flow check well, static 08:45 09:30 0.75 2,704 2,704 SURFA CEMEC` FIT P Blow down top drive - RU and perform FIT to 18.2 EMW - 1080 psi applied surface pressure - RD & blow down lines F'~ga ~ raf ~5 l J ~ Time Logs __ Date From To Dur 5. De th E De th Phase Code Subcode T COM 11/18/2007 09:30 12:00 2.50 2,704 2,921 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f! 2704' to 2921' MD 2512' TVD ADT - 1.26 hrs. ECD - 10.44 ppg WOB 10/15 RPM 130 GPM 650 @ 1500 psi String wt. PU 150 SO 120 Rot 130 Torque on/off btm. - 9000/8000 ft/Ibs Changed over to 9.6 ppg LSND mud while drillin ahead from 2730'. 12:00 00:00 12.00 2,921 4,404 INTRMI DRILL DDRL P Drill 8 3/4" hole w! GP f/ 2921' to 4404' MD 3161' TVD ADT - 7.3 hrs. ECD - 11.22 ppg WOB 8/15 k RPM 150 GPM 650 @ 2040 psi String wt. PU 145 SO 126 ROT 138 Tor ue on/off btm. - 9000/7500 ft/Ibs 11/19/2007 00:00 12:00 12.00 4,404 5,704 INTRMI DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 4404' to 5704' MD 3736' TVD ADT - 8.04 hrs. ECD - 11.19 ppg WOB 8/15 k RPM 150 GPM 650 @ 1890 psi String wt. PU 160 SO 130 ROT 145 Tor ue on/off btm. - 10500/900 ft/Ibs 12:00 00:00 12.00 5,704 7,296 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 5704' to 7296' MD 4437' TVD ECD - 10.77 ppg ADT - 7.97 hrs. WOB 12/18 k RPM 160 GPM 650 @ 2210 psi String wt. PU 183 SO 143 Rot 163 Tor ue on/off btm. 12,000/12,000 ft/Ibs 11/20/2007 00:00 12:00 12.00 7,296 8,819 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 7296' to 8819' MD 4437' TVD ECD - 10.69 ppg ADT - 7.71 hrs. WOB 15/22 k RPM 160 GPM 650 @ 2060 psi String wt. PU 235 SO 135 Rot 173 Tor ue on/off btm. 17,000/16,000 ft/Ibs 12:00 00:00 12.00 8,819 10,414 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f! 8,819' to 10,414' MD 5,809' TVD ECD - 10.79 ppg ADT - 8.11 hrs. WOB 18/25 k RPM 160 GPM 650 @ 2,400 psi String wt. PU 240 SO 145 Rot 185 Tor ue on/off btm. 18,000/17,500 fUlbs 11/21/2007 00:00 12:00 12.00 10,414 11,750 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 10,414' to 11,750' MD 6,399' TVD ECD - 11.14 ppg ADT - 7.98 hrs. WOB 20/28 k RPM 160 GPM 650 @ 2,460 psi String wt. PU 287 SO 147 Rot 192 Tor ue on/off btm. 20,000/19,000 ft/Ibs P<~~ 5 of 15 ~~ ' _. Time Logs __ Date From To D ur S. De th E. De th Phase Code Subcode T COM 11/21/2007 12:00 14:45 _ 2.75 11,750 12,128 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 11,750' to 12,128' MD 6,566' ND ECD - 11.14 ppg ADT - 2.37 hrs. WOB 20/28 k RPM 160 GPM 650 @ 2,480 psi String wt. PU 287 SO 147 Rot 192 Tor ue on/off btm. 20,000/19,000 fUlbs 14:45 15:45 1.00 12,128 12,128 INTRM1 DRILL CIRC T Lost 540 psi pump pressure. Checked surface lines, valves, and pumps. Pressure loss 940 si. 15:45 20:15 4.50 12,128 9,043 INTRM1 DRILL TRIP T POOH looking for hole in drill pipe from 12,128' to 10,150'. Found hole in slip area of 32 stands and a double out. Laid down washed 'oint of 5" DP. 20:15 20:45 0.50 9,043 9,043 INTRM1 DRILL CIRC T Circulated @ 650 gpm to check ressure. 20:45 22:15 1.50 9,043 12,053 INTRM1 DRILL TRIP T RIH from 9,043' to 12,053'. 22:15 22:45 0.50 12,053 12,128 INTRM1 DRILL REAM T Washed from 12,053' to 12,128'. 22:45 00:00 1.25 12,128 12,242 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 12,128' to 12,242' MD 6,615' TVD ECD - 11.14 ppg ADT - 0.67 hrs. WOB 18/25 k RPM 160 GPM 650 @ 2,570 psi String wt. PU 265 SO 155 Rot 200 Tor ue on/off btm. 21,500/21000 ft/Ibs 11/22/2007 00:00 12:00 12.00 12,242 13,384 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 12,242' to 13,384' MD 7,116' TVD ECD - 11.14 ppg ADT - 7.83 hrs. WOB 18/25 k RPM 150 GPM 650 @ 2,840 psi String wt. PU 280 SO 160 Rot 205 Tor ue on/off btm. 20,000119,000 ft/Ibs 12:00 00:00 12.00 13,384 14,241 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 13,384' to 14,241' MD 7,412' TVD ECD -10.65 ppg ADT - 8.85 hrs. WOB 20/25 k RPM 150 GPM 650 @ 2,830 psi String wt. PU 285 SO 160 Rot 210 Tor ue on/off btm. 21,000/20,000 ft/Ibs 11/23/2007 00:00 10:15 10.25 14,241 15,155 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 14,241'to 15,155' MD 7,554' ND ECD -10.70 ppg ADT - 6.87 hrs. WOB 20!25 k RPM 150 GPM 650 @ 2,880 psi String wt. PU 290 SO 155 Rot 210 Tor ue on/off btm. 23,000/21,000 fUlbs 10:15 13:30 3.25 15,155 14,906 INTRM1 DRILL CIRC P Circulate and condition mud -Pumped 35 bbls high vis sweep - 650 gpm / 2850 psi / 150 rpm - CBU X 3 -Set back three stands to 14,906' -Flow check well, static 13:30 17:15 3.75 14,906 12,750 INTRM1 DRILL WPRT P Wiper trip from 14,906' to 12,750' - 550 gpm / ICP=2210 psi - FCP=2090 psi / 110 r m -flow check well, static ~- ~~ ~ ~ P~sJ~ ~i a f 1 Time Logs _ _ ___ Date__ From To Dur S Depth E. De th PhaSe Code Subcode T COM _ 11/23/2007 17:15 18:30 1.25 12,750 15,096 INTRM1 DRILL WPRT P RIH to 15,096'. 18:30 20:45 2.25 15,096 15,155 INTRM1 DRILL CIRC P Broke circulation and washed to 15,155'. Circulated hole clean raising MW to 10 PPG. 650 GPM 3,020 psi 150 RPM. 20:45 21:15 0.50 15,155 15,155 INTRM1 DRILL CIRC P Spotted casing running pill to bit. 21:15 00:00 2.75 15,155 13,575 INTRM1 DRILL TRIP P POOH with pump @ 2.5 BPM displacing casing pill from 15,155' to 13,575'. 11/24/2007 00:00 01:00 1.00 13,575 12,718 INTRM1 DRILL TRIP P POOH with pump from 13,575' to 12,718' displacing WBS & tube pill into open hole - 2.5 bpm / 250 psi / tri seed 1800 h 01:00 02:45 1.75 12,718 11,767 INTRM1 DRILL TRIP P Flow check well, static- Blow down top drive -POOH on trip tank from 12,718' to 11,767' -flow check well, static -pump dry job -Blow down top drive 02:45 06:00 3.25 11,767 8,819 INTRM1 DRILL TRIP P POOH on trip from 11,767' to 8819' - hole appears in good condition and takin ro er fill. 06:00 10:15 4.25 8,819 7,010 INTRM1 DRILL TRIP P POOH from 8819' -attempt to work through tight spot @ 8749' w/ 75K over - no go - Backream from 8819' to 8724' - 400 gpm / 1140 psi / 100 rpm -Blow down top drive -Flow check well, static -POOH on trip tank from 8724' to 7010' -wiped through tight spots @ 8522' 10:15 12:30 2.25 7,010 6,059 INTRM1 DRILL TRIP P No reduction in PUW observed for last 5 stands pulled -wiped through several tight spots from 7000' to 6960'- Backream 10 stands from 7010' to 6059' - to clean up hole - 650 gpm / 2220 psi / 150 rpm -Observed moderate amout of fine cuttings across shakers -Flow check well, static -Blow down to drive 12:30 15:45 3.25 6,059 4,300 INTRM1 DRILL TRIP P Continue POOH working through tight spots from 6,059' to 4,300' reaming with 650 GPM 150 RPM when re uired.Ti ht 5,577' . 15:45 18:45 3.00 4,300 723 INTRM1 DRILL TRIP P Continue POOH on trip tank from 4,300' to 723'. Flowcheck well static. 18:45 19:15 0.50 723 207 INTRM1 DRILL TRIP P Stood back HWDP and laid down jars with 2 'ts HWDP. 19:15 21:45 2.50 207 0 INTRM1 DRILL PULD P Download MWD and laid down BHA. 21:45 22:15 0.50 0 0 INTRM1 DRILL PULD P Pulled wear bushing. 22:15 00:00 1.75 0 0 INTRMI CASIN NUND P PJSM chan ed to rams to 7" and tested 250 / 3500 si. 11/25/2007 00:00 00:30 0.50 0 0 INTRM1 CASIN OTHR P Pull long wear bushing -set thin wall wear bushin ~'~ge~~tla l ~J , Time Logs _ _ Date From To Dur S De th E De tp h Phase Code Subcode T COM 11/25/2007 00:30 01:45 125 0 0 INTRM1 CASIN( RURD P Rig up to run 7" Casing 01:45 02:00 0.25 0 0 INTRM1 CASIN SFTY P Held pre-Job Safety and Opts meeting with crew 02:00 05:15 3.25 0 2,534 INTRM1 CASINC RNCS P Ran 7" 26# L-80 MBTC csg as follows: FS (Ray Oil Tool Silver bullet) 2 jts csg - FC (Halliburtonw/ by-pass baffle!) 1 jt csg - Halliburton Shut-Off Baffle - 1 jnt. csg - 4 jts total (made up w/ BakerLoc -fill pipe & check floats OK) Ran 56 joints to 2534' (60 'ts total 05:15 05:45 0.50 2,534 2,534 INTRM1 CASINC CIRC P Stage pumps up to 6 bpm and condition mud -FCP= 370 psi -PUW 125K SOW 120K 05:45 09:30 3.75 2,534 6,362 INTRM1 CASIN RNCS P Run 7", 26#, L-80 MBTC casing from 2,534' to 6362' - 150 'ts total 09:30 10:30 1.00 6,362 6,362 INTRM1 CASIN( CIRC P Stage pumps up to 6 bpm -circulate and condition mud - MWT. out 10.6 - 10.1 ppg - MWT. in 10 ppg -FCP=480 si PUW 185K SOW 135K 10:30 14:15 3.75 6,362 9,770 INTRM1 CASIN RNCS P Run 7", 26#, L-80 MBTC casing from 6,362' to 9,770' - 230 'ts total 14:15 15:45 1.50 9,770 9,770 INTRM1 CASINC CIRC P Stage pumps up to 5.5 bpm -circulate and condition mud - MWT. out 10.45 - 10.05 ppg - MWT. in 10 ppg - FCP=540 si PUW 245K SOW 145K 15:45 18:45 3.00 9,770 12,711 INTRM1 CASIN< RNCS P Run 7", 26#, L-80 MBTC casing from 9,770' to 12,711'. 299 'ts total run. 18:45 20:45 2.00 12,711 12,711 INTRM1 CASINC CIRC P Stage pumps up to 5 bpm -circulate and condition mud - MWT. out 10.35 - 10.05 ppg - MWT. in 10 ppg - FCP=510 si PUW 295K SOW 150K 20:45 23:45 3.00 12,711 15,140 INTRM1 CASINC RNCS P Run 7", 26#, L-80 MBTC casing from 12,711' to 15,140'. 355 jts total run. Landed casin . 23:45 00:00 0.25 15,140 15,140 INTRM1 CASIN RURD P Rigged down Franks tool. Made up cement head. 11!2612007 00:00 00:15 0.25 15,140 15,140 INTRM1 CEME~ RURD P MU Cement head and lines 00:15 02:30 2.25 15,140 15,140 INTRM1 CEME~ CIRC P Stage pumps up to 6.5 bpm -circulate and condition mud for cementing - Attem ted to reciprocate pipe W/ CP=670 psi -Held PJSM with Dowell and ri crew ~ac~e 3 of 15 L ~~ Time Logs _ Date From To Dur S. Depth E. De th Phase Code Subcode T COM 11/26/2007 02:30 05:00 2.50 15,140 15,140 INTRM1 CEME~ DISP P Cement 1st stage 7" casing as follows: Pumped 2 bbls CW-100 - Dropped Halliburton Bypass Plug - Load closing plug -Test lines to 4000 psi -Pumped 38 bbls CW-100 @ 4.5 bbls/min @ 400 psi -Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.4 bbl/min @ 390 psi -Mixed & Pumped 152 bbls Lead Slurry Class G w/ additives @ 11.0 ppg @ 470 psi - Mixed and pumped 24 bbls of 15.8 ppg Tail Slurry Class G w/additives @ 4.6 bpm / 225 psi -Dropped top plug and pumped 20 Bbls water behind. Switched to rig pumps & displaced w/ 554 bbls 10.0 ppg LSND mud @ 7 bbl/min @ 570 to 840 psi -slowed rate to 4 bbl/min @640 psi for last 10 bbls of displacement -Bump plug with 1150 psi. Floats held. Full returns , throu hout. - IP 0500 hrs. 05:00 05:15 0.25 15,140 15,140 INTRMI CEME~ OTHR P Check floats, holding -Loaded 2nd stage closing plug in cement head and o ened sta a collar with 3,200 si. 05:15 05:45 0.50 15,140 15,140 INTRM1 CEME~ CIRC P CBU @ 7 bpm / 370 psi 05:45 07:00 1.25 15,140 15,140 INTRM1 CEME~ DISP P Cement 2nd Sta a 7" casing as„__ follows: -Pumped 20 bbls CW-100 @ 4.7 bbls/min @ 144 psi -Mixed & pumped 30 bbls MudPush XL @ 10.5 ppg @ 4 bbl/min @ 148 psi -Mixed & Pumped 37 bbls Tail Slurry Class G w/ additives @ 15.8 ppg @ 4.6 BPM / 116 psi -Dropped Closing plug and pumped 20 Bbls water behind. Switched to rig pumps and displaced with 10.0 LSND mud @ 7.5 bpm / 180-410 psi -Slowed to 3 BPM / 190 psi for last 6 Bbls and bumped plug with 2470 psi closing Stage collar total of 249 bbls of mud. CIP @ 0650 Hrs. Checked floats OK. Full returns throu hout. 07:00 08:15 1.25 0 0 INTRM1 CEME~ RURD P RD cement head and lines - LD landin 'oint and RD casin elevators 08:15 09:30 1.25 0 0 INTRM1 CASIN( DHEO P Pull wear bushing -Install and test ackoff to 5000 si for 10 minutes 09:30 11:30 2.00 0 0 INTRM1 WELCT BOPE P Set u er test plug -Change to~pipe _ rams to 3 1/2" x 6" VBR's -test rams 250/3500 psi. -pull test plug and install wear bushin 11:30 12:00 0.50 0 0 INTRM1 CASINC RURD P Changed out long bales and picked up 5" elevators. 12:00 00:00 12.00 0 0 INTRM1 DRILL PULD P Laid down 5" DP from derrick in mousehole. 11/27/2007 00:00 03:00 3.00 0 0 INTRM1 DRILL PULD P Laid down 5" DP from derrick to i eshed via mousehole. Faye 9 of 1~ ~~ Time Logs _ Date From To Dur 5 D th E. De th Phase Code Subcode T COM 11/27/2007 03:00 03:30 0.50 0 0 INTRM1 DRILL RURD P Rigged up to handle 4" DP. 03:30 05:30 2.00 0 289 INTRM1 CEME PULD P Made up Cleanout BHA. 05:30 11:00 5.50 289 5,995 INTRM1 CEME TRIP P RIH singling in 4" DP from pipeshed to 5995'. 11:00 12:30 1.50 5,995 5,995 INTRM1 RIGMN' SVRG P Slipped and cut drill line. Serviced top drive. 12:30 13:30 1.00 5,995 6,910 INTRM1 CEME TRIP P RIH singling in 4" DP from pipeshed to 6910'. 13:30 14:15 0.75 6,910 6,910 INTRM1 CEME CIRC P CBU @ 400 gpm 2100 psi 90 rpm. Tested casin 3500 si for 10 min. 14:15 17:45 3.50 6,910 7,423 INTRM1 CEME COCF P Drilled out stringers and stage collar from 6910' to 7423'. Found stage collar @ 7025'. Tested casing 3500 psi for 10 min OK. 17:45 18:00 0.25 7,423 6,948 INTRM1 CEME TRIP P POOH to 6948' to replace stands in derrick.. 18:00 00:00 6.00 6,948 14,850 INTRM1 CEME TRIP P RIH singling in 4" DP from pipeshed to 14,755'. RIH with stands to 14,850'. 11/28/2007 00:00 01:15 1.25 14,850 14,995 INTRM1 CEME COCF P Washed and reamed from 14,850' to 14, 995'. 01:15 02:15 1.00 14,995 14,995 INTRM1 CASIN( DHEQ P Rigged up and tested casing to 3500 si for 30 min. 02:15 04:15 2.00 14,995 15,130 INTRM1 CEME DRLG P Cleaned out shoe track from 14,995' to 15,130'. Drilled plugs, baffle, float collar, and cement. 04:15 05:45 1.50 15,130 15,130 INTRM1 CEME CIRC P CBU 7 BPM 2260 psi 100 rpm and blew down to drive. 05:45 12:00 6.25 15,130 9,805 INTRM1 CEME TRIP P POOH on trip tank from 15,130' to 9,805'. 12:00 14:45 2.75 9,805 289 INTRM1 CEME TRIP P Continue POOH on trip tank from 9,805' to 289'. 14:45 15:30 0.75 289 0 INTRM1 CEMER PULD P Laid down Cleanout BHA. 15:30 21:30 6.00 0 0 INTRM1 WELC BOPE P Pulled wear bushing and set test plug. Tested BOP, Choke manifold and floor valves to 250/3500 psi. Tested Hydril to 250/2500 psi. Tested Closing unit. Tested with 3.5", 4", and 4.5" test jts. Witiness of test waived by Jeff Jones AOGCC. Pulled test plug and set wear bushin . 21:30 00:00 2.50 0 210 INTRM1 DRILL PULD P PU 6 1/8" Drilling BHA. RIH flex collars and tested Geospan to 3500 si. 11/29/2007 00:00 00:30 0.50 210 398 INTRM1 DRILL DHEQ P Install corrosion ring in top of NMFC's. MU 1 std HWDP. Shallow test Sperry tools. RIH w/ HWDP and 'ars to 398'. 00:30 03:15 2.75 398 3,346 INTRM1 DRILL TRIP P PU and RIH with 93 jts 4" DP from 398' to 3346'. 03:15 08:45 5.50 3,346 15,057 INTRM1 DRILL TRIP P RIH with stands to 15,057'. 08:45 10:15 1.50 15,057 15,155 INTRM1 CEME DRLG P Washed to 15,130'. Drilled out shoe track and cleaned out rathole to 15,155'. Page i D ref ' l~ Time Logs Date From To Dur S Depth E. De tp h Pha e Code Subcode T COM 11/29/2007 10:15 10:30 0.25 15,155 15,175 INTRM1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 15,155' to 15,175' MD 7,554' TVD ECD - 10.1 ppg ADT - .25 hrs. WOB 5/10 k RPM 100 GPM 252 @ 2,000 psi String wt. PU 210 SO 140 Rot 170 Tor ue on/off btm. 12,000/10,000 ft/Ibs 10:30 12:00 1.50 15,175 15,175 INTRM1 DRILL CIRC P Flowchecked well. CBU 200 gpm 1790 si 90 r m. 12:00 12:45 0.75 15,175 15,175 INTRM1 CEME~ FIT P Ri ed u and erformed FIT to 12.5 PPG EMW. 12:45 15:15 2.50 15,175 15,175 PROD1 DRILL CIRC P Circulated and changed mu to 9.6 PPG FlowPro. 220 gpm FCP 1990 psi 50 r m. 15:15 00:00 8.75 15,175 15,724 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 15,175'to 15,724' MD 7,549' TVD ECD - 11.1 ppg ADT - 6.71 hrs. WOB 10/12 k RPM 120 GPM 252 @ 2,090 psi String wt. PU 220 SO 145 Rot 180 Tor ue on/off btm. 13,000/11,500 fUlbs 11/30/2007 00:00 12:00 12.00 15,724 16,586 PROD1 DRILL DDRL P Dritl 6 1/8" hole w/GP f/ 15,724' to 16,586' MD 7,534' TVD ECD - 11.29 ppg ADT - 9.13 hrs. WOB 10/12 k RPM 120 GPM 252 @ 2,120 psi String wt. PU 224 SO 138 Rot 179 Tor ue on/off btm. 13,000/11,500 ft/Ibs 12:00 00:00 12.00 16,586 17,450 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 16,586' to 17,450' MD 7,521' TVD ECD - 11.46 ppg ADT - 9.4 hrs. WOB 8/10 k RPM 120 GPM 207 @ 2,240 psi String wt. PU 225 SO 135 Rot 177 Tor ue on/off btm. 13,000/11,500 ft/Ibs 12/01/2007 00:00 12:00 12.00 17,450 18,217 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 17,450' to 18,217' MD 7,517' TVD ECD - 11.35 ppg ADT - 9.32 hrs. WOB 8/12 k RPM 120 GPM 200 @ 2,180 psi String wt. PU 225 SO 132 Rot 175 Tor ue on/off btm. 14,000/12,000 ft/Ibs 12:00 00:00 12.00 18,217 1.9,065 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 18,217' to 19,065' MD 7,509' ND ECD - 11.5 ppg ADT - 9.62 hrs. WOB 10/12 k RPM 120 GPM 200 @ 2,350 psi String wt. PU 228 SO 127 Rot 175 Tor ue on/off btm. 14,000!12,000 ft/Ibs 12/02/2007 00:00 12:00 12.00 19,065 19,865 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 19,065' to 19,864' MD 7,506' TVD ECD - 11.68 ppg ADT - 9.35 hrs. WOB 10/14 k RPM 120 GPM 200 @ 2,470 psi String wt. PU 227 SO 127 Rot 176 Tor ue on/off btm. 15,000/12,000 ft/Ibs ~ ~ Page 1~ as 15 ~~ i Time Logs __ ~ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 12/02/2007 12:00 00:00 12.00 19,865 20,680 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 19,864' to 20,680' MD 7,496' TVD ECD - 11.83 ppg ADT - 9.39 hrs. WOB 10/12 k RPM 120 GPM 200 @ 2,580 psi String wt. PU 232 SO 115 Rot 173 Torque on/off btm. 14,500/12,500 ft/Ibs Mud loss - 10 BPH. Last 24 hrs. 225 Bbls. 12/03/2007 00:00 06:30 6.50 20,680 21,142 PROD1 DRILL DDRL P Drill 6 1/8" hole w/GP f/ 20,680' to 21,142' MD 7,491' TVD ECD - 11.82 ppg ADT - 5.5 hrs. WOB 8/12 k RPM 120 GPM 200 @ 2,580 psi String wt. PU 237 SO 111 Rot 174 Torque on/off btm. 15,000/13,500 ft/Ibs Mud loss _ 10 BPH. Last 24 hrs. 225 Bbls. 06:30 10:00 3.50 21,142 21,142 PROD1 DRILL CIRC P CBU x 2 200 gpm 2950 psi 50 rpm FCP 2880 si. 10:00 12:00 2.00 21,142 20,197 PROD1 DRILL TRIP P POOH from 21,142' to 20,197' Pum in 2.5 b m. 12:00 18:00 6.00 20,197 15,057 PROD1 DRILL TRIP P Continue POOH from 20,197' to 15,057' Pumping 2.5 bpm. Dropped rabbit 4 stands below shoe. 18:00 20:00 2.00 15,057 15,057 PROD1 DRILL CIRC P Circulate and raised MW to 10 PPG 200 m 30 m FCP 2200 si. 20:00 22:30 2.50 15,057 13,153 PROD1 DRILL TRIP P POOH from 15,057' to 13,153' Pum in 2.5 b m. 22:30 00:00 1.50 13,153 12,486 PROD1 DRILL TRIP P Flow checked well static. POOH on Trip Tank from 13,153' to 12,486'. Hole fill ood. 12/04/2007 00:00 10:30 10.50 12,486 398 PROD1 DRILL TRIP P Continue POOH f/ 12,486' to 398' - retrieve rabbit -Flow check well - Static 10:30 12:00 1.50 398 109 PROD1 DRILL PULD P Std back HWDP & Jars - LD xo, NM flex DC's, Stab, float sub - MU lifter into TM tool & plug into MWD & down load 12:00 13:30 1.50 109 0 PROD1 DRILL PULD P LD MDW (TM, PWD, Stab,GM flex,DM, Stab) & GeoPilot & bit - Clean up & clear rig floor - LD Geo S an 13:30 15:00 1.50 0 0 COMPZ RPCOh PULD P Bring pert pups to rig floor - PU liner hanger & MU 3 1/2" lift sub - LD liner han er 15:00 15:15 0.25 0 0 COMPZ RPCO SFTY P Held PJSM w/crew on running liner 15:15 22:15 7.00 0 6,172 COMPZ RPCOb RCST P Run 4.5" liner as follows: Baker Bull Nose shoe - 1 jt 4 1/2" 12.6# L-80 IBT liner - 1 pert pup - Continue w/ 5 its 4 1/2" 12.6# L-80 IBT liner w/ 1 pert pup , / eve 5 'ts. ran 143 jts total 4 1 /2" 12.6# L-80 IBT liner w/ 28 perF pups) to 6172'.P/U 124, S/O 105. Make up liner han er & ZX acker assembl 22:15 23:30 1.25 6,172 7,120 COMPZ RPCOh RCST P Run in hole with 4.5" liner on 4 drill i e to 7120'. ~~ ~ ~ Page 12 e~f s5 Tirne Logs I Date From To Dur S. Depth E. De th Phase Code Subcode T GOM 12/04/2007 23:30 00:00 0.50 7,120 7,120 COMPZ RIGMN SFTY P PJSM -Cut and slip drill line 12/05/2007 00:00 01:00 1.00 7,120 7,120 COMPZ RIGMN SVRG P Finish cut & slip drill line 01:00 06:15 5.25 7,120 15 COMPZ RPCOb RCST P Continue RIH w/ 4 1/2" liner on 4" DP f/ 7120' to 15,117' PO wt. 220 SO wt. 143 06:15 07:00 0.75 15,117 15,117 COMPZ RPCOh CIRC P Establish circ -Pump DP volume + 10 bbls @ 3.5 bbls/min @ 740 psi -Blow down TD 07:00 10:30 3.50 15,117 21,132 COMPZ RPCO RCST P Continue RIH w/4 1/2" liner on 4" DP f/ 15,117' -tag btm @ 21,142' -Drop liner setting ball -Pull up to setting depth -Shoe @ 21,132' & top @ 14,974' - PU wt. 265 SO wt. 140 10:30 12:00 1.50 15,044 14,949 COMPZ RPCO CIRC P Pump down liner setting ball @ 3 bbls/min @ 950 psi - Pressure up to set liner hanger -Slack off to 90 K to confirm hanger set -Pressure up to set ZX packer -Pressure up to release running tool.- Std back 1 std DP - Blow down TD 12:00 12:45 0.75 14,949 14,949 COMPZ RPCOh OTHR P RU -Pressure up 7" x 4" DP to 3500 psi & test ZX packer for 30 mins. - Blow down kill & choke lines 12:45 13:00 0.25 14,949 14,895 COMPZ RPCO TRIP P Pull up to clear running tool from liner to to 14,895' 13:00 15:00 2.00 14,895 14,895 COMPZ RPCOh CIRC P PJSM -Displace well f/ 10.0 ppg FloPro to 10.0 brine 6 bbls/min 15:00 00:00 9.00 14,895 1,470 COMPZ RPCO TRIP P POOH 4" DP F/ 14895' - 1470' 12/06/2007 00:00 00:45 0.75 1,470 0 COMPZ RPCO TRIP P Finish POOH w/ DP & liner running toot 00:45 01:15 0.50 0 0 COMPZ RPCOti PULD P Break down running tool & LD same - Monitorwell (observed slight static loss less than 1 bbl/hr 01:15 01:30 0.25 0 0 COMPZ RPCO SFTY P PJSM w/ rig crew & Schlumberger on ri in u & handlin erf un 01:30 03:45 2.25 0 0 COMPZ RPCO RURD P Spot Schlumberger unit -Close blind rams & RU shooting flange -Close top VBR's on 5 1/2" riser - RU sheaves - MU erf un assembl (sinker bars w/ rollers - CCL/Gr & perf gun (2 7/8") - Open blind rams & run perf gun assmebly in hole - MU pack-off & pump in sub -Est. circ across mud cross to as buster & monitor well 03:45 05:30 1.75 0 0 COMPZ RPCOti PERF P RIH w/ perf gun assembly - to 14,500' - Run correlation log (GR & CCL) -set guns on depth -Fire guns -shot 6 holes /ft f/ 14350' to 14370' in AI ine C 05:30 06:30 1.00 0 0 COMPZ RPCO PERF P POOH w/ perf gun assembly r ~~~~ '13 cif 1 ~ C~ ~~ Time Logs ~ Date From To Dur S. De th E. De th Phase Code Subcode T _ COM 12/06/2007 06:30 07:45 1.25 0 0 COMPZ RPCOh PULD P Open bleeder & check for pessure - RD pack-off & pump in sub -Pull guns(all shots fired) LD perf gun assmebly - RU sheaves - LD shooting flange -Blow down choke & kill lines - Monitorwell (static lose less than 1 bbls/hr. 07:45 08:00 0.25 0 0 COMPZ RPCO OTHR P Pull wear bushing 08:00 08:30 0.50 0 0 COMPZ RPCOb RURD P RU to run 3 1/2" completion -monitor well on TT - no losses 08:30 08:45 0.25 0 0 COMPZ RPCOh SFTY P PJSM on running 3 1/2" completion w/ ri crew 08:45 23:00 14.25 0 12,908 COMPZ RPCOh RCST P Run 3 1/2" completion (all tbg & pups are 3 1/2" 9.3# L-80 EUE) as follows: Baker seal assembly & locator - 18 jts. tbg -HES "XN" nipple - 1 jt. tbg - pup jt. -Baker CMD sliding sleeve - pup jt.- 40 jts tbg -HES "X" nipple w/ RHC plug installed - 2 jts tbg - pup jt. - Baker Premier Packer - pup jt - 2 jts tbg -pup jt. -Camco GLM w/shear valve - pup jt - 96 jts tbg -pup jt- Camco GLM w/dummy valve -pup jt. - 161 jts tbg - pup jt -Camco GLM w/dummy valve - pup jt- 93 jts tbg - pup jt -Camco TRMAXX-5E SSSV - u 't. 23:00 00:00 1.00 12,908 12,908 COMPZ RPCOh RCST P R/U SSSV control line, tested good to 5000 si for 10 min. 12/07/2007 00:00 03:00 3.00 12,908 14,869 COMPZ RPCOh RCST P Continue running 3 1/2" completion f/ 12, 908' to 14, 869' - 62 jts 3 1 /2" 9.3# L-80 EUE tbg -banding control line to tb 03:00 04:00 1.00 14,869 14,985 COMPZ RPCOfi RCST P Change elevators - MU xo to tbg - RIH w/ 4" DP to land oput locator sub into top of liner -pumping @ 1.5 bbls/min -- Observed pressure increase when seals entered into seal bore -Pick up to set locator 3' off land out - POOH w/ DP -Blow down TD 04:00 05:30 1.50 14,983 14,983 COMPZ RPCO6 RCST P Change elevators - MU XO 3 1/2" EUE x 4 1/2" IBT - PU space out pups 4 1/2" 12.6# L-80 IBT- PU 2 jts. 4 1/2" 12.6# L-80 IBT tbg - MU XO on landing jt w/ 4 " XT391ift sub - MU landing jt to tb han er - MU tb han er to stirn 05:30 06:00 0.50 14,983 14,983 COMPZ RPCOh RCST P Terminate control line through hanger & test connection to 5000 psi - Pressure up on control line to open SSSV PacJ~ 1~ cat 15~ Time Logs _ _ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 12/07/2007 06:00 07:30 1.50 14,974 14,974 COMPZ RPC©h CIRC P MU TD to landing jt. - PU string to place tbg tail @ top of liner - 14974' - Establish circ w/brine -Pumped 70 bbls 10.0 ppg inhibited brine followed by 112 bbls 10.0 ppg reg. brine to spot inhibited brine f/ liner top to btm GLM in annulus & f/ tbg tail to GLM inside tb -shut down um s 07:30 07:45 0.25 14,974 15,018 COMPZ RPCO RCST P Drain stack -Land tbg in well head w/ tail 15,018' - 07:45 09:00 1.25 15,018 15,018 COMPZ RPCO OTHR P RILDS - LD landing jt. A - Set TWC - Install landing jt. B -Test hanger seals to 5000 si OK - LD landin 't. B 09:00 10:30 1.50 15,018 15,018 COMPZ RPCOh NUND P LD mouse hole - LD riser - ND BOP stack - chba a saver sub in TD 10:30 11:00 0.50 15,018 15,018 COMPZ RPCOh OTHR P Terminate control line through wellhead 11:00 12:00 1.00 15,018 15,018 COMPZ RPCO NUND P NU tree & test to 5000 psi 12:00 18:00 6.00 15,018 15,018 COMPZ RPCO OTHR P Pull TWC - MU lubricator -Open SSSV -Drop packer setting ball/rod assembl ,test tbg to 4000 psi for 30 min. test annulus to 3500 psi for 30 .min. Sheered valve at 3400 PSI, displaced 10 ppg brine with 300 bbls 8.6 inhibited brine followed by 153 bbls diesel. 18:00 19:30 1.50 15,018 COMPZ RPCOti DHEQ P R/U and set BP valve. tbg 850 psi, IA 200 si, OA 350 si. 19:30 00:00 4.50 COMPZ RPCO OTHR P PJSM, lay down 4" DP 12/08/2007 00:00 14:00 14.00 COMPZ RPCO PULD P LD excess 4" DP f/ derrick via mouse hole for rig move -Pull mouse hole Release ri 1400 hrs Page. 1~ raf ~5 TUBING (11415017, OD:3.500, ID:2.992) Cc~t~a+c~aPhliips Alaska, inc~ - _-- cna..n ALPINE CD4-05 API: 501032055800 Well T e: PROD An le TS: de SSSV Type: TRDP Orig Completion: Angle @ TD: deg @ Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo Ref Lo Date: Last U ate: 12/9/2007 Last Ta TD: 21132 ftKB Last Taa Date: Max Hole Anale~ 0 deg r~ Casino String -ALL STRINGS Descri lion Size To Bottom TVD 1M Grade Thread CONDUCTOR 16.000 0 114 114 65.20 H-40 WELDED ~ SURFACE 9.625 0 2674 2674 40.00 L-80 MBTC I ~ PRODUCTION 7.000 0 15140 15140 26.00 L-80 MBTC LINER w/PERF PUPS 4.500 14974 21132 21132 12.60 L-80 IBTM ~Tubmg String -TUBING __ ___ Size To Bottom TVD VtR Gratle Threatl 4.500 0 114 114 12.60 L-80 IBTM 3.500 114 15017 15017 - 9.30 L-80 EUE - - Perforations Summary •- Interval TVO Zone Status Ft SPF Date T e Comment 15325 - 21092 15325 - 21092 5767 6 12/4/2007 Perf Alternating solid pipe (avg Pups 209 w/4.79' pert pup (27 joints of pert pups)___ Gas Lift Mandrels/Valves ' St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vh! Cmnt 1 4947 4947 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/4/2007 2 9951 9951 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/4/2007 3 12933 12933 CAMCO KBMG SOV 1.0 BEK-5 0.000 0 12/4/2007 Other (plugs, equip.., etc .) -COMPLETION De h TVD T e Descri lion ID 31 31 HANGER FMC TUBING HANGER 3.900 ~ 2075 2075 SSSV CAMCO TRMAXX-5E SSSV w/PROFILE 2.812 -~~~ 13022 13022 PACKER BAKER PREMIER PACKER 2.870 j 13101 13101 NIP HALLIBURTON'X' NIPPLE w/RHC PLUG, BALUROD 2.813 14353 14353 SLEEVE BAKER CMD SLIDING SLEEVE w/2.81' X PROFILE 2.813 14409 14409 NIP HALLIBURTON'XN' 2.75" NO GO NIPPLE 2.813 14974 14974 SEAL BAKER LOCATOR/SEAL ASSEMBLY w/4' SPACE OUT 0.000 15017 15017 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 Other plugs, equip., etc .7 -LINER DETAIL De h TVD T Desch lion ID 14974 14974 PACKER LINER BAKER'HRD' ZXP LINER TOP PACKER 4.430 I 14993 14993 NIP LINER RS PACKOFF SEAL NIPPLE 4.250 4.500 LINER w/PERF PUPS 14974-21132, OD:4.500, Wt:12.60) Halliburton Company Survey Report Compam~: ConocoPhillips Alaska Inc . [>:~tr. 12!20/2007 I imc: 08:18:47 Pa:;c: I Field: Colville River Unit C~o -ordin;ate(\F:) kc(crence: Well: CD4-05. True North - Sitc Nanuq CD4 ~c rtiail ("I'b'I)1 Re ference CD405 (19:5+ 36.58) 56.1 ~~ell: CD4-05 Section 115) Refer ence Well (O.OON O.O OE,293.96Azi) \Vellp.~th: CD4-05 Su i~ey ('akula[ionMethod: Minimum curvature llh: Oracle 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 (C larke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD4-05 Slot Name: 50-103-20558-00 Well Position: +N/-S -20.08 ft Northing: 5957507.28 ft Latitude: 70 17 32.768 N +E/-W -77.62 ft Easting : 378096.77 ft Longitude: 150 59 13.025 W Position Uncertainty: 0.00 ft Wellpath: CD4-05 Drilled From: Well Ref. Point 50-103-20 558-00 Tie-on Depth: 36.58 ft ' Current Datum: CD4-05 (19.5+36.58) Height 56.08 ft Above System Datum: Mean Sea Level Magnetic Data: 11/12/2007 Declination: 22.36 deg Field Strength: 57565 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.58 0.00 0.00 283.96 Survey Program for Definitive Wellpath Date: 12!3/2007 Validated: Yes Version: 11 Actual From To Survey Toolcode Tool Name ft ft 81.00 904.00 CD4-05 Gyro (81.00-904.00) C&GYRO-SS Camera based gyro si ngle shot 937.79 21103.37 CD4-05 IIFR+MS+SAG (937.79-211 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1l) Inc! Azim T~~1) SysTt~n \/S E/W ~i:~pA MapE Fool ft deg deg ft ft ft ft ft ft 36.58 0.00 0.00 36.58 -19.50 0.00 0.00 5957507.28 378096.77 TIE LINE 81.00 0.75 110.00 81.00 24.92 -0.10 0.27 5957507.18 378097.04 CB-GYRO-SS 172.00 1.00 117.00 171.99 115.91 -0.66 1.54 5957506.59 378098.30 CB-GYRO-SS 262.00 0.50 101.00 261.98 205.90 -1.10 2.63 5957506.14 378099.38 CB-GYRO-SS 351.00 1.00 328.50 350.98 294.90 -0.51 2.60 5957506.73 378099.36 CB-GYRO-SS ~ 442.00 1.75 272.00 441.95 385.87 0.22 0.80 5957507.49 378097.57 CB-GYRO-SS 535.00 3.25 238.00 534.87 478.79 -1.13 -2.86 5957506.20 378093.89 CB-GYRO-SS 626.00 5.48 239.00 625.60 569.52 -4.73 -8.77 5957502.69 378087.92 CB-GYRO-SS 716.00 5.65 248.00 715.17 659.09 -8.61 -16.56 5957498.94 378080.07 CB-GYRO-SS 807.00 6.10 262.00 805.70 749.62 -10.96 -25.50 5957496.74 378071.09 CB-GYRO-SS ~ 904.00 6.60 263.00 902.11 846.03 -12.36 -36.14 5957495.51 378060.44 CB-GYRO-SS 937.79 6.65 254.11 935.67 879.59 -13.13 -39.95 5957494.80 378056.62 MWD+IFR-AK-CAZ-SC 1033.35 7.77 273.06 1030.49 974.41 -14.30 -51.72 5957493.82 378044.83 MWD+IFR-AK-CAZ-SC 1128.90 8.65 275.52 1125.06 1068.98 -13.26 -65.33 5957495.08 378031.24 MWD+IFR-AK-CAZ-SC 1224.02 12.20 259.02 1218.61 1162.53 -14.49 -82.32 5957494.13 378014.23 MWD+IFR-AK-CAZ-SC 1318.90 16.03 255.74 1310.61 1254.53 -19.63 -104.87 5957489.36 377991.61 MWD+IFR-AK-CAZ-SC 1413.81 19.73 275.12 1401.00 1344.92 -21.43 -133.56 5957488.02 377962.89 MWD+IFR-AK-CAZ-SC 1509.17 20.25 269.31 1490.63 1434.55 -20.19 -166.10 5957489.79 377930.38 MWD+IFR-AK-CAZ-SC 1604.33 23.16 256.31 1579.08 1523.00 -24.82 -200.77 5957485.72 377895.64 MWD+IFR-AK-CAZ-SC 1699.80 26.52 257.97 1665.71 1609.63 -33.71 -239.87 5957477.47 377856.40 MWD+IFR-AK-CAZ-SC 1794.60 29.19 259.25 1749.52 1693.44 -42.43 -283.29 5957469.45 377812.85 MWD+IFR-AK-CAZ-SC 1890.17 31.39 260.03 1832.03 1775.95 -51.09 -330.71 5957461.56 377765.30 MWD+IFR-AK-CAZ-SC 1985.31 35.76 259.26 1911.28 1855.20 -60.57 -382.45 5957452.93 377713.42 MWD+IFR-AK-CAZ-SC 2080.77 38.19 257.92 1987.54 1931.46 -71.94 -438.72 5957442.47 377656.98 MWD+IFR-AK-CAZ-SC 2175.58 40.41 259.27 2060.91 2004.83 -83.80 -497.58 5957431.57 377597.94 MWD+IFR-AK-CAZ-SC 2270.74 44.65 258.73 2131.02 2074.94 -96.08 -560.71 5957420.31 377534.62 MWD+IFR-AK-CAZ-SC 2365.94 46.17 256.16 2197.85 2141.77 -110.84 -626.87 5957406.63 377468.24 MWD+IFR-AK-CAZ-SC 2460.78 49.28 256.01 2261.64 2205.56 -127.71 -694.97 5957390.87 377399.88 MWD+IFR-AK-CAZ-SC 2555.93 52.58 255.21 2321.60 2265.52 -146.08 -766.51 5957373.66 377328.05 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: Conoco Phillips Alaska Inc. Date: 12!20/2007 "Time: 08.18:47 Pace: 2 Field: Colville River Unit Co-ordinate(~'F;) Reference: Well: CD4-05, True North Site: Nanuq CD4 Vertical (TVI)> Reference: CD4-05 (19.5+36.58) 56.1 WeII: CD4-05 Section (VS) Kefereucr. Well (O.OON.O.OOE,283.96Azi) «'eilpath: CD4-05 Sure}~ Cirkula[ion Method: Minnnum Curvature Db: Oracle tiunc~ SID Intl ~iim f~'D SysTVD t\/S FJ~V MapN }1apE fool ~~, ft dey deg ft ft ft ft ft ft 2636.48 57.19 253.53 2367.93 2311.85 -163.85 -829.94 5957356.92 377264.35 MWD+IFR-AK-CAZ-SC 2701.22 58.84 254.47 2402.22 2346.14 -178.98 -882.72 5957342.65 377211.34 MWD+IFR-AK-CAZ-SC i 2796.21 59.74 255.50 2450.73 2394.65 -200.14 -961.60 5957322.78 377132.13 MWD+IFR-AK-CAZ-SC 2891.19 61.39 255.03 2497.41 2441.33 -221.18 -1041.59 5957303.04 377051.81 MWD+IFR-AK-CAZ-SC 2986.64 62.60 259.11 2542.24 2486.16 -240.01 -1123.71 5957285.54 376969.41 MWD+IFR-AK-CAZ-SC 3081.42 63.81 258.56 2584.97 2528.89 -256.40 -1206.71 5957270.51 376886.16 MWD+IFR-AK-CAZ-SC 3176.44 63.75 258.70 2626.95 2570.87 -273.20 -1290.28 5957255.06 376802.34 MWD+IFR-AK-CAZ-SC 3271.04 64.65 260.63 2668.12 2612.04 -288.47 -1374.06 5957241.15 376718.33 MWD+IFR-AK-CAZ-SC 3366.45 64.99 258.85 2708.72 2652.64 -303.85 -1459.02 5957227.15 376633.14 MWD+IFR-AK-CAZ-SC 3461.89 64.45 255.91 2749.48 2693.40 -322.70 -1543.22 5957209.67 376548.65 MWD+IFR-AK-CAZ-SC 3557.11 64.24 254.10 2790.71 2734.63 -344.91 -1626.13 5957188.81 376465.40 MWD+IFR-AK-CAZ-SC 3652.30 64.02 255.18 2832.25 2776.17 -367.60 -1708.72 5957167.47 376382.46 MWD+IFR-AK-CAZ-SC 3747.43 64.03 253.66 2873.91 2817.83 -390.56 -1791.09 5957145.84 376299.73 MWD+IFR-AK-CAZ-SC 3842.76 64.18 254.78 2915.55 2859.47 -413.88 -1873.62 5957123.87 376216.84 MWD+IFR-AK-CAZ-SC 3937.72 63.96 256.24 2957.07 2900.99 -435.25 -1956.30 5957103.84 376133.84 MWD+IFR-AK-CAZ-SC 4033.24 63.83 256.68 2999.10 2943.02 ~t55.34 -2039.69 5957085.12 376050.14 MWD+IFR-AK-CAZ-SC 4127.86 64.44 258.32 3040.38 2984.30 -473.76 -2122.81 5957068.04 375966.74 MWD+IFR-AK-CAZ-SC 4223.16 64.44 259.81 3081.50 3025.42 -490.07 -2207.22 5957053.11 375882.08 MWD+IFR-AK-CAZ-SC 4318.62 63.96 260.00 3123.05 3066.97 -505.13 -2291.83 5957039.42 375797.24 MWD+IFR-AK-CAZ-SC 4414.17 63.84 258.66 3165.09 3109.01 -521.02 -2376.15 5957024.90 375712.68 MWD+IFR-AK-CAZ-SC 4509.52 63.33 258.54 3207.51 3151.43 -537.90 -2459.86 5957009.39 375628.71 MWD+IFR-AK-CAZ-SC 4603.87 63.01 257.59 3250.09 3194.01 -555.31 -2542.23 5956993.31 375546.08 MWD+IFR-AK-CAZ-SC ~ 4699.01 63.78 258.40 3292.70 3236.62 -573.00 -2625.44 5956976.98 375462.60 MWD+IFR-AK-CAZ-SC 4794.26 64.11 255.12 3334.54 3278.46 -592.60 -2708.72 5956958.73 375379.03 MWD+IFR-AK-CAZ-SC 4888.81 64.1.8 254.55 3375.78 3319.70 -614.85 -2790.84 5956937.81 375296.56 MWD+IFR-AK-CAZ-SC 4983.86 63.90 253.27 3417.39 3361.31 -638.54 -2872.95 5956915.46 375214.08 MWD+IFR-AK-CAZ-SC 5078.10 64.10 251.81 3458.70 3402.62 -663.95 -2953.74 5956891.37 375132.89 MWD+IFR-AK-CAZ-SC 5172.67 64.72 252.16 3499.55 3443.47 -690.33 -3034.86 5956866.31 375051.37 MWD+IFR-AK-CAZ-SC 5267.34 63.48 252.52 3540.90 3484.82 -716.16 -3116.00 5956841.80 374969.82 MWD+IFR-AK-CAZ-SC 5363.09 63.55 253.00 3583.60 3527.52 -741.56 -3197.85 5956817.73 374887.58 MWD+IFR-AK-CAZ-SC 5458.29 63.68 253.69 3625.91 3569.83 -766.01 -3279.56 5956794.62 374805.50 MWD+IFR-AK-CAZ-SC 5553.21 63.42 253.61 3668.19 3612.11 -789.93 -3361.10 5956772.02 374723.58 MWD+IFR-AK-CAZ-SC 5648.45 63.55 254.01 3710.70 3654.62 -813.69 -3442.95 5956749.59 374641.37 MWD+IFR-AK-CAZ-SC 5743.33 63.55 255.08 3752.97 3696.89 -836.33 -3524.82 5956728.29 374559.14 MWD+IFR-AK-CAZ-SC 5838.72 63.70 256.11 3795.34 3739.26 -857.59 -3607.59 5956708.37 374476.04 MWD+IFR-AK-CAZ-SC 5933.78 63.91 255.63 3837.31 3781.23 -878.41 -3690.31 5956688.90 374393.01 MWD+IFR-AK-CAZ-SC 6028.92 63.89 256.12 3879.16 3823.08 -899.26 -3773.16 5956669.39 374309.83 MWD+IFR-AK-CAZ-SC 6123.99 64.65 257.23 3920.44 3864.36 -919.00 -3856.50 5956651.01 374226.20 MWD+IFR-AK-CAZ-SC 6220.23 63.83 257.52 3962.26 3906.18 -937.94 -3941.08 5956633.44 374141.33 MWD+IFR-AK-CAZ-SC 6315.23 64.10 258.31 4003.96 3947.88 -955.81 -4024.55 5956616.93 374057.59 MWD+IFR-AK-CAZ-SC 6410.07 63.69 259.07 4045.69 3989.61 -972.52 -4108.06 5956601.59 373973.83 MWD+IFR-AK-CAZ-SC 6504.95 64.38 258.36 4087.23 4031.15 -989.21 -4191.71 5956586.25 373889.92 MWD+IFR-AK-CAZ-SC 6599.64 64.99 258.67 4127.72 4071.64 -1006.25 -4275.59 5956570.57 373805.78 MWD+IFR-AK-CAZ-SC 6694.85 64.79 258.13 4168.12 4112.04 -1023.59 -4360.04 5956554.61 373721.07 MWD+IFR-AK-CAZ-SC 6790.32 64.03 258.04 4209.36 4153.28 -1041.36 -4444.29 5956538.20 373636.55 MWD+IFR-AK-CAZ-SC 6885.76 64.18 257.23 4251.04 4194.96 -1059.75 -4528.16 5956521.18 373552.40 MWD+IFR-AK-CAZ-SC 6981.01 62.73 256.66 4293.61 4237.53 -1078.99 -4611.16 5956503.29 373469.10 MWD+IFR-AK-CAZ-SC 7076.18 62.71 256.23 4337.23 4281.15 -1098.82 -4693.39 5956484.80 373386.57 MWD+IFR-AK-CAZ-SC 7171.86 62.93 256.36 4380.93 4324.85 -1118.98 -4776.08 5956465.98 373303.57 MWD+IFR-AK-CAZ-SC 7266.98 63.55 255.96 4423.76 4367.68 -1139.30 -4858.55 5956447.00 373220.79 MWD+IFR-AK-CAZ-SC 7362.41 63.91 255.67 4466.00 4409.92 -1160.27 -4941.51 5956427.38 373137.50 MWD+IFR-AK-CAZ-SC 7458.80 63.77 255.68 4508.50 4452.42 -1181.68 -5025.34 5956407.34 373053.35 MWD+IFR-AK-CAZ-SC i i Halliburton Company Survey Report CamQan~: ConocoPhillips Alaska Inc. Date 12/20!2007 Timr. 08:18.47 Nape: 3 Field: Colville Rlver Unit Cb-ordinatelNE}Reference: Well: CG4-05, True North Sitr. Nanuq CD4 vertical (T~~D}Reference: CD4-05 (19.5+36.50 56.1 ~~cll: CD4-05 tiectiun ID'S)Reference: Well (O.OON.O.OOE,233.96Azi) Wellpath: CD4-05 Sunk} Calculation Method: Minimum Curvature Db: Oracle __ __ Survey MD Tncl ~zim I'U'D Sys"F~'D V%S F./~~ ~]apA J1apE: I'uul ft deg deg ft ft ft ft ft ft 7554.66 64.45 256.54 4550.35 4494.27 -1202.38 -5109.05 5956388.00 372969.32 MWD+IFR-AK-CAZ-SC 7647.60 65.00 256.94 4590.03 4533.95 -1221.65 -5190.86 5956370.06 372887.22 MWD+IFR-AK-CAZ-SC 7742.67 64.03 257.79 4630.94 4574.86 -1240.43 -5274.59 5956352.65 372803.19 MWD+IFR-AK-CAZ-SC 7837.75 63.22 257.29 4673.18 4617.10 -1258.81 -5357.77 5956335.62 372719.74 MWD+IFR-AK-CAZ-SC 7933.18 63.85 257.39 4715.71 4659.63 -1277.53 -5441.12 5956318.25 372636.10 MWD+IFR-AK-CAZ-SC 8028.74 63.88 256.92 4757.80 4701.72 -1296.60 -5524.77 5956300.54 372552.17 MWD+IFR-AK-CAZ-SC I 8123.91 64.24 255.73 4799.43 4743.35 -1316.83 -5607.92 5956281.66 372468.70 MWD+IFR-AK-CAZ-SC 8218.84 64.12 255.88 4840.78 4784.70 -1337.79 -5690.76 5956262.05 372385.54 MWD+IFR-AK-CAZ-SC 8314.14 63.89 254.71 4882.55 4826.47 -1359.53 -5773.61 5956241.66 372302.35 MWD+IFR-AK-CAZ-SC I 8409.39 63.75 255.66 4924.57 4868.49 -1381.39 -5856.25 5956221.15 372219.38 MWD+IFR-AK-CAZ-SC 8504.51 63.88 257.28 4966.55 4910.47 -1401.36 -5939.23 5956202.53 372136.09 MWD+IFR-AK-CAZ-SC ~ 8599.64 64.18 257.13 5008.21 4952.13 -1420.30 -6022.63 5956184.94 372052.40 MWD+IFR-AK-CAZ-SC 8695.04 63.56 257.52 5050.22 4994.14 -1439.09 -6106.20 5956167.51 371968.55 MWD+IFR-AK-CAZ-SC 8790.13 63.81 257.28 5092.38 5036.30 -1457.69 -6189.38 5956150.27 371885.08 MWD+IFR-AK-CAZ-SC 8884.89 64.19 257.03 5133.92 5077.84 -1476.62 -6272.42 5956132.68 371801.76 MWD+IFR-AK-CAZ-SC 8979.99 64.24 256.70 5175.28 5119.20 -1496.08 -6355.81 5956114.58 371718.07 MWD+IFR-AK-CAZ-SC 9075.29 64.18 255.93 5216.75 5160.67 -1516.38 -6439.18 5956095.64 371634.39 MWD+IFR-AK-CAZ-SC 9170.05 63.97 254.39 5258.18 5202.10 -1538.21 -6521.56 5956075.15 371551.67 MWD+IFR-AK-CAZ-SC 9265.09 63.28 253.94 5300.40 5244.32 -1561.44 -6603.47 5956053.25 371469.40 MWD+IFR-AK-CAZ-SC 9360.51 63.36 254.19 5343.24 5287.16 -1584.85 -6685.46 5956031.18 371387.05 MWD+IFR-AK-CAZ-SC 9455.63 63.55 255.50 5385.75 5329.67 -1607.09 -6767.59 5956010.27 371304.58 MWD+IFR-AK-CAZ-SC 9550.73 63.35 256.96 5428.26 5372.18 -1627.34 -6850.21 5955991.37 371221.64 MWD+IFR-AK-CAZ-SC 9643.93 63.97 257.50 5469.62 5413.54 -1645.80 -6931.67 5955974.23 371139.90 MWD+IFR-AK-CAZ-SC 9740.89 64.11 257.21 5512.06 5455.98 -1664.88 -7016.73 5955956.53 371054.55 MWD+IFR-AK-CAZ-SC 9836.19 64.31 256.66 5553.52 5497.44 -1684.28 -7100.32 5955938.49 370970.67 MWD+IFR-AK-CAZ-SC 9931.15 64.25 256.31 5594.73 5538.65 -1704.28 -7183.50 5955919.85 370887.18 MWD+IFR-AK-CAZ-SC 10025.62 63.96 256.89 5635.99 5579.91 -1723.97 -7266.17 5955901.50 370804.21 MWD+IFR-AK-CAZ-SC 10120.98 63.76 258.20 5678.00 5621.92 -1742.43 -7349.76 5955884.40 370720.34 MWD+IFR-AK-CAZ-SC 10215.41 63.07 258.45 5720.26 5664.18 -1759.52 -7432.46 5955868.65 370637.38 MWD+IFR-AK-CAZ-SC 10310.49 63.49 257.61 5763.01 5706.93 -1777.14 -7515.53 5955852.39 370554.03 MWD+IFR-AK-CAZ-SC 10405.77 63.55 255.71 5805.50 5749.42 -1796.81 -7598.51 5955834.06 370470.75 MWD+IFR-AK-CAZ-SC 10500.55 63.20 254.24 5847.98 5791.90 -1818.78 -7680.34 5955813.43 370388.58 MWD+IFR-AK-CAZ-SC 10595.80 63.29 254.01 5890.86 5834.78 -1842.04 -7762.15 5955791.50 370306.42 MWD+IFR-AK-CAZ-SC 10690.97 64.31 254.49 5932.88 5876.80 -1865.22 -7844.34 5955769.66 370223.87 MWD+IFR-AK-CAZ-SC 10786.23 63.75 255.25 5974.59 5918.51 -1887.57 -7927.01 5955748.65 370140.86 MWD+IFR-AK-CAZ-SC 10881.25 63.76 255.85 6016.61 5960.53 -1908.84 -8009.53 5955728.72 370058.00 MWD+IFR-AK-CAZ-SC 10976.25 64.24 257.28 6058.26 6002.18 -1928.68 -8092.58 5955710.24 369974.65 MWD+IFR-AK-CAZ-SC 11071.47 63.84 258.02 6099.94 6043.86 -1946.99 -8176.21 5955693.29 369890.74 MWD+IFR-AK-CAZ-SC 11166.70 64.39 257.32 6141.51 6085.43 -1965.28 -8259.91 5955676.35 369806.77 MWD+IFR-AK-CAZ-SC 11261.85 64.09 256.97 6182.87 6126.79 -1984.35 -8343.46 5955658.65 369722.93 MWD+IFR-AK-CAZ-SC 11357.19 63.40 256.45 6225.04 6168.96 -2004.00 -8426.67 5955640.35 369639.41 MWD+IFR-AK-CAZ-SC 11452.40 63.28 256.23 6267.76 6211.68 -2024.10 -8509.35 5955621.60 369556.43 MWD+IFR-AK-CAZ-SC 11547.49 64.11 255.90 6309.90 6253.82 -2044.63 -8592.08 5955602.41 369473.38 MWD+IFR-AK-CAZ-SC 11642.43 63.62 255.82 6351.72 6295.64 -2065.45 -8674.73 5955582.94 369390.41 MWD+IFR-AK-CAZ-SC 11737.61 63.96 256.58 6393.76 6337.68 -2085.82 -8757.66 5955563.92 369307.17 MWD+IFR-AK-CAZ-SC 11832.74 64.24 256.70 6435.31 6379.23 -2105.59 -8840.92 5955545.50 369223.60 MWD+IFR-AK-CAZ-SC 11927.48 63.62 256.66 6476.95 6420.87 -2125.20 -8923.73 5955527.24 369140.49 MWD+IFR-AK-CAZ-SC 12022.97 63.69 256.41 6519.32 6463.24 -2145.12 -9006.95 5955508.67 369056.97 MWD+IFR-AK-CAZ-SC 12117.85 64.30 257.18 6560.92 6504.84 -2164.60 -9089.97 5955490.54 368973.65 MWD+IFR-AK-CAZ-SC 12213.05 64.15 257.01 6602.32 6546.24 -2183.75 -9173.53 5955472.75 368889.80 MWD+IFR-AK-CAZ-SC 12307.88 63.91 257.03 6643.85 6587.77 -2202.89 -9256.61 5955454.95 368806.43 MWD+IFR-AK-CAZ-SC 12403.21 64.52 256.98 6685.31 6629.23 -2222.20 -9340.25 5955437.01 368722.49 MWD+IFR-AK-CAZ-SC 12498.40 64.72 257.13 6726.11 6670.03 -2241.46 -9424.07 5955419.11 368638.38 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/20/2007 "Time: 08:18:47 Pa~~e: 4 field: Colville River Unit Co-ordinate(NEjRefcrence: Weft CD4-05. True North Site Nanuq CD4 ~crtical(TVD)Refcrencc: CD4-OS (19.5+3G.58) 56.1 Nell: CD4-05 Section (VS)Refereuce: Well (O.OON,O.OOE,283.96P,zi) lYellpath: CD4-05 Sur~~eq Calculation 1lcthod: Minimum Cwvai~ire llh: Oracle Sung ~~Ill Incl ~zim l~~ U Sys "h~~D \/S I:/W ~~lapA ~~1apIC fool ft deg deg ft ft ft ft ft ft 12593.39 63.29 256.63 6767.75 6711.67 -2260.84 -9507.21 5955401.08 368554.94 MWD+IFR-AK-CAZ-SC 12688.35 62.59 255.72 6810.95 6754.87 -2281.05 -9589.33 5955382.22 368472.51 MWD+IFR-AK-CAZ-SC ~ 12783.88 62.67 255.76 6854.86 6798.78 -2301.94 -9671.55 5955362.66 368389.97 MWD+IFR-AK-CAZ-SC ~ 12878.95 64.03 255.04 6897.51 6841.43 -2323.36 -9753.77 5955342.57 368307.42 MWD+IFR-AK-CAZ-SC 12974.22 63.42 256.43 6939.68 6883.60 -2344.41 -9836.56 5955322.87 368224.30 MWD+IFR-AK-CAZ-SC 13069.59 63.69 258.48 6982.16 6926.08 -2362.96 -9919.91 5955305.68 368140.68 MWD+IFR-AK-CAZ-SC 13164.72 64.11 262.44 7024.02 6967.94 -2377.11 -10004.13 5955292.90 368056.24 MWD+IFR-AK-CAZ-SC 13259.56 64.86 263.87 7064.88 7008.80 -2387.31 -10089.11 5955284.08 367971.11 MWD+IFR-AK-CAZ-SC 13354.91 64.81 264.81 7105.42 7049.34 -2395.82 -10174.99 5955276.96 367885.12 MWD+IFR-AK-CAZ-SC 13450.52 66.29 267.07 7145.00 7088.92 -2401.97 -10261.80 5955272.22 367798.23 MWD+IFR-AK-CAZ-SC 13545.52 67.42 270.64 7182.35 7126.27 -2403.70 -10349.11 5955271.90 367710.90 MWD+IFR-AK-CAZ-SC 13640.27 67.22 274.75 7218.90 7162.82 -2399.60 -10436.42 5955277.43 367623.68 MWD+IFR-AK-CAZ-SC 13735.74 68.42 278.84 7254.95 7198.87 -2389.12 -10524.17 5955289.32 367536.12 MWD+IFR-AK-CAZ-SC 13831.32 70.41 282.15 7288.56 7232.48 -2372.81 -10612.13 5955307.05 367448.44 MWD+IFR-AK-CAZ-SC 13926.47 70.72 286.47 7320.24 7264.16 -2350.64 -10699.05 5955330.63 367361.90 MWD+IFR-AK-CAZ-SC 14022.11 72.29 289.80 7350.58 7294.50 -2322.40 -10785.22 5955360.26 367276.20 MWD+IFR-AK-CAZ-SC 14117.27 73.45 292.96 7378.62 7322.54 -2289.25 -10869.89 5955394.78 367192.10 MWD+IFR-AK-CAZ-SC 14211.43 74.35 297.41 7404.74 7348.66 -2250.76 -10951.73 5955434.59 367110.90 MWD+IFR-AK-CAZ-SC I 14306.21 76.20 299.47 7428.83 7372.75 -2207.10 -11032.32 5955479.54 367031.03 MWD+IFR-AK-CAZ-SC 14401.67 75.43 302.80 7452.23 7396.15 -2159.26 -11111.53 5955528.66 366952.62 MWD+IFR-AK-CAZ-SC i 14496.57 78.03 305.60 7474.02 7417.94 -2107.34 -11187.90 5955581.80 366877.10 MWD+IFR-AK-CAZ-SC 14591.58 80.18 308.01 7491.98 7435.90 -2051.45 -11262.58 5955638.90 366803.34 MWD+IFR-AK-CAZ-SC 14686.20 82.36 310.07 7506.34 7450.26 -1992.54 -11335.21 5955698.96 366731.68 MWD+IFR-AK-CAZ-SC 14781.53 83.23 312.33 7518.30 7462.22 -1930.25 -11406.37 5955762.40 366661.55 MWD+IFR-AK-CAZ-SC 14876.66 83.17 315.91 7529.56 7473.48 -1864.50 -11474.17 5955829.23 366594.83 MWD+IFR-AK-CAZ-SC 14971.87 83.54 318.29 7540.58 7484.50 -1795.23 -11538.54 5955899.53 366531.60 MWD+IFR-AK-CAZ-SC 15066.75 86.33 320.44 7548.96 7492.88 -1723.52 -11600.08 5955972.23 366471.24 MWD+IFR-AK-CAZ-SC 15121.93 87.13 322.69 7552.11 7496.03 -1680.37 -11634.32 5956015.92 366437.70 MWD+IFR-AK-CAZ-SC 15210.66 88.30 324.70 7555.64 7499.56 -1608.92 -11686.81 5956088.20 366386.38 MWD+IFR-AK-CAZ-SC 15307.10 89.47 327.47 7557.52 7501.44 -1528.91 -11740.60 5956169.07 366333.90 MWD+IFR-AK-CAZ-SC 15402.15 91.01 329.22 7557.12 7501.04 -1448.01 -11790.48 5956250.76 366285.34 MWD+IFR-AK-CAZ-SC 15497.43 92.37 330.41 7554.31 7498.23 -1365.69 -11838.36 5956333.84 366238.80 MWD+IFR-AK-CAZ-SC 15592.10 91.75 331.26 7550.91 7494.83 -1283.08 -11884.47 5956417.18 366194.05 MWD+IFR-AK-CAZ-SC 15687.48 90.15 333.02 7549.33 7493.25 -1198.77 -11929.03 5956502.20 366150.86 MWD+IFR-AK-CAZ-SC 15782.80 90.89 335.45 7548.46 7492.38 -1112.94 -11970.46 5956588.68 366110.83 MWD+IFR-AK-CAZ-SC 15877.51 92.25 334.58 7545.87 7489.79 -1027.13 -12010.45 5956675.12 366072.25 MWD+IFR-AK-CAZ-SC I 15972.73 90.33 329.40 7543.72 7487.64 -943.11 -12055.14 5956759.84 366028.93 MWD+IFR-AK-CAZ-SC ~ 16067.43 89.72 329.35 7543.68 7487.60 -861.62 -12103.38 5956842.10 365982.02 MWD+IFR-AK-CAZ-SC 16162.76 90.64 332.49 7543.38 7487.30 -778.32 -12149.71 5956926.13 365937.05 MWD+IFR-AK-CAZ-SC 16257.63 91.69 334.29 7541.45 7485.37 -693.52 -12192.19 5957011.60 365895.95 MWD+IFR-AK-CAZ-SC 16352.46 91.69 334.17 7538.66 7482.58 -608.16 -12233.40 5957097.61 365856.14 MWD+IFR-AK-CAZ-SC 16447.35 90.70 333.00 7536.68 7480.60 -523.20 -12275.60 5957183.24 365815.32 MWD+IFR-AK-CAZ-SC 16542.72 90.95 335.07 7535.30 7479.22 -437.47 -12317.35 5957269.63 365774.97 MWD+IFR-AK-CAZ-SC 16637.95 92.43 335.24 7532.50 7476.42 -351.09 -12357.34 5957356.64 365736.38 MWD+IFR-AK-CAZ-SC 16733.13 90.64 333.79 7529.95 7473.87 -265.21 -12398.28 5957443.16 365696.85 MWD+IFR-AK-CAZ-SC 16827.93 91.32 333.21 7528.33 7472.25 -180.39 -12440.57 5957528.66 365655.94 MWD+IFR-AK-CAZ-SC 16923.21 90.95 332.13 7526.44 7470.36 -95.76 -12484.31 5957613.98 365613.59 MWD+IFR-AK-CAZ-SC 17018.53 90.40 330.88 7525.32 7469.24 -11.99 -12529.78 5957698.46 365569.48 MWD+IFR-AK-CAZ-SC , 17113.95 90.27 330.72 7524.76 7468.68 71.30 -12576.33 5957782.49 365524.29 MWD+IFR-AK-CAZ-SC 17209.02 90.89 331.36 7523.79 7467.71 154.48 -12622.36 5957866.39 365479.62 MWD+IFR-AK-CAZ-SC 17304.32 90.70 332.74 7522.47 7466.39 238.65 -12667.02 5957951.27 365436.34 MWD+IFR-AK-CAZ-SC i t 17399.80 90.21 331.96 7521.71 7465.63 323.22 -12711.33 5958036.55 365393.41 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. U>rtc 12!20/2007 Timr. 08:18:47 Pa;;c 5 Pitld: Colville River Unit Co-ordin;ite(NE}Referencc Weil CD4-05. True North... tine: Nanuq CD4 ~crtical (l'~"D)Referencc: CD4-C5 (19.5+36.55) 56.1 ~~ell: CD4-05 Sectionl~S)Referencc Vdell(O.OON.O.OOE,283.96Azi) We[kpath: CDd-05 tiun~ey Calculation McUwd: Minimum Curvature lib: Oracle Survev MD Lrcl Aim TVD Sy.l'~'D V/S E/W ~1ap`i ~tapE Tool ft deg deg ft ft ft ft ft ft 17495.02 88.54 328.98 7522.75 7466.67 406.06 -12758.25 5958120.12 365347.84 MWD+IFR-AK-CAZ-SC 17590.27 88.73 328.81 7525.02 7468,94 487.59 -12807.44 5958202.44 365299.98 MWD+IFR-AK-CAZ-SC 17685.82 91.20 330.49 7525.08 7469.00 570.03 -12855.72 5958285.65 365253.05 MWD+IFR-AK-CAZ-SC 17781.27 90.27 328.35 7523.86 7467.78 652.20 -12904.27 5958368.58 365205.84 MWD+IFR-AK-CAZ-SC 17876.42 92.00 332.37 7521.97 7465.89 734.86 -12951.31 5958451.99 365160.16 MWD+IFR-AK-CAZ-SC 17971.31 91.63 332.94 7518.97 7462.89 819.10 -12994.87 5958536.92 365117.97 MWD+IFR-AK-CAZ-SC 18066.73 89.90 333.04 7517.69 7461.61 904.10 -13038.20 5958622.61 365076.03 MWD+IFR-AK-CAZ-SC 18161.32 90.46 332.62 7517.39 7461.31 988.26 -13081.39 5958707.44 365034.21 MWD+IFR-AK-CAZ-SC 18256.52 90.15 331.79 7516.89 7460.81 1072.47 -13125.79 5958792.35 364991.19 MWD+IFR-AK-CAZ-SC j 18352.25 90.52 331.91 7516.33 7460.25 1156.88 -13170.95 5958877.47 364947.41 MWD+IFR-AK-CAZ-SC 18447.58 90.46 331.34 7515.51 7459.43 1240.75 -13216.25 5958962.06 364903.47 MWD+IFR-AK-CAZ-SC 18542.55 90.15 330.16 7515.01 7458.93 1323.61 -13262.65 5959045.66 364858.42 MWD+IFR-AK-CAZ-SC 18638.28 90.40 330.11 7514.55 7458.47 1406.62 -13310.32 5959129.43 364812.11 MWD+IFR-AK-CAZ-SC 18733.37 90.77 330.58 7513.58 7457.50 1489.25 -13357.37 5959212.80 364766.42 MWD+IFR-AK-CAZ-SC 18828.84 90.46 331.15 7512.55 7456.47 1572.64 -13403.85 5959296.92 364721.30 MWD+IFR-AK-CAZ-SC 18923.90 90.40 332.14 7511.84 7455.76 1656.29 -13448.99 5959381.29 364677.52 MWD+IFR-AK-CAZ-SC 19019.00 90.95 332.00 7510.72 7454.64 1740.31 -13493.53 5959466.01 364634.35 MWD+IFR-AK-CAZ-SC 19113.97 90.64 331.27 7509.40 7453.32 1823.87 -13538.65 5959550.28 364590.60 MWD+IFR-AK-CAZ-SC 19208.92 90.70 331.50 7508.29 7452.21 1907.21 -13584.12 5959634.35 364546.49 MWD+IFR-AK-CAZ-SC 19303.59 89.90 332.26 7507.79 7451.71 1990.77 -13628.74 5959718.55 364503.24 MWD+IFR-AK-CAZ-SC 19398.85 90.58 330.71 7507.40 7451.32 2074.41 -13674.21 5959802.97 364459.13 MWD+IFR-AK-CAZ-SC 19493.71 90.46 329.80 7506.53 7450.45 2156.76 -13721.27 5959886.07 364413.41 MWD+IFR-AK-CAZ-SC 19587.19 89.72 330.03 7506.39 7450.31 2237.65 -13768.13 5959967.70 364367.88 MWD+IFR-AK-CAZ-SC i 19684.28 89.90 331.21 7506.71 7450.63 2322.25 -13815.76 5960053.05 364321.63 MWD+IFR-AK-CAZ-SC 19779.37 90.21 332.40 7506.62 7450.54 2406.06 -13860.69 5960137.57 364278.07 MWD+IFR-AK-CAZ-SC 19874.49 90.95 333.28 7505.66 7449.58 2490.68 -13904.11 5960222.88 364236.03 MWD+IFR-AK-CAZ-SC 19969.91 91.14 332.67 7503.91 7447.83 2575.67 -13947.46 5960308.55 364194.07 MWD+IFR-AK-CAZ-SC 20064.92 91.01 330.09 7502.13 7446.05 2659.05 -13992.95 5960392.65 364149.94 MWD+IFR-AK-CAZ-SC 20160.33 90.52 329.51 7500.86 7444.78 2741.50 -14040.94 5960475.87 364103.29 MWD+IFR-AK-CAZ-SC 20255.05 90.52 328.82 7500.00 7443.92 2822.83 -14089.49 5960557.96 364056.08 MWD+IFR-AK-CAZ-SC 20350.40 89.41 329.83 7500.06 7443.98 2904.83 -14138.13 5960640.74 364008.77 MWD+IFR-AK-CAZ-SC 20445.80 90.95 330.43 7499.76 7443.68 2987.56 -14185.64 5960724.22 363962.61 MWD+IFR-AK-CAZ-SC 20540.99 90.52 331.79 7498.54 7442.46 3070.89 -14231.63 5960808.28 363917.99 MWD+IFR-AK-CAZ-SC 20636.45 90.77 332.06 7497.46 7441.38 3155.11 -14276.55 5960893.21 363874.44 MWD+IFR-AK-CAZ-SC 20731.55 91.51 332.87 7495.57 7439.49 3239.42 -14320.51 5960978.21 363831.86 MWD+IFR-AK-CAZ-SC 20826.41 91.26 330.46 7493.28 7437.20 3322.89 -14365.51 5961062.39 363788.22 MWD+IFR-AK-CAZ-SC ~ j 20921.64 90.33 329.09 7491.95 7435.87 3405.16 -14413.45 5961145.42 363741.63 MWD+IFR-AK-CAZ-SC j 21016.66 90.09 329.17 7491.61 7435.53 3486.72 -14462.20 5961227.75 363694.21 MWD+IFR-AK-CAZ-SC 21103.37 90.70 330.68 7491.01 7434.93 3561.75 -14505.65 5961303.47 363651.99 MWD+IFR-AK-CAZ-SC I I` ` 21142.00 90.70 330.68 7490.54. 7434.46 3595.43 -14524.56 5961337.45 ~ 363633.62 .PROJECTED to TD Casing Detail Report CD4-05 Liner Casing Casing Description Liner Depth (ftKB) Run Date 21,132.0 Tension (kips) Casing Components Nem ~~ascn pho^. OD iinl VJt Ilos,fft) Grade lop Thread Jts Len (ft) Top ift KBD 6tin iftY.E3) (R-Ibsj Class Ma~:OD ~inV ID yin; tsaker riKU cxr nner top packer a vz ~ ~ ly.b4 i4,yi3.a ~4,ays.ol I RS Nipple 4 1/2 1 3.85 14,993.5 14,997.3 Baker 5" x 7" Flexlock liner hanger 4 1/2 1 9.921 14,997.3 15,007.2 Seal Bore Extension 4 1!2 1 19.43 15,007.2 15,026.7 X O Bushing 5" BTC Ix 41/2 IBT 4 1/2 1 1.64 15,026.7 15,028.3 Liner Pup Joint 4 1l2~ 12.60 L-80 1 3.81 15,028.3 15,032.1 3.980 Casing Jts 4 1/2 12.60; L-80 7 292.68 15,032.1 15,324.8 3.958 Perforated Pup Joint 4 1/2 12.60' L-80 1 4.80 15,324.8 15,329.6 3.958 Casing Jts 4 1/2 12.60 L-80 5 208.21 15,329.6 15,537.8 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.80 15,537.8 15,542.6 3.958 Casing Jts 4 1/2 12.60 L-80 5 215.34 15,542.6 15,757.9 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.80 15,757.9 15,762.7 3.958 Casing Jts 4 1/2 12.60 L-80 5 208.27 15,762.7 15,971.0 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.78 15,971.0 15,975.8 3.958 Casing Jts 4 1/2 12.60 L-80 5 209.71 15,975.8 16,185.5 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.81 16,185.5 16,190.3 3.958 Casing Jts 4 1/2 12.60 L-80 5 200.16 16,190.3 16,390.5 3.958 Perforated Pup Joint 4 1!2 12.60 L-80 1 4.79 16,390.5 16,395.3 3.958 Casing Jts 4 1/2 12.60 L-80 i 5 208.27 16,395.3 16,603.5 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.75 16,603.5 16,608.3 3.958 Casing Jts 4 1/2 12.60 L-80 5 217.43 16,608.3 16,825.7 3.958 Perforated Pup Joint 4 1/2 12.60~ L-80 1 4.78 16,825.7 16,830.5 3.958 Casing Jts 4 1/2 12.60 L-80 5 211.34 16,830.5 17,041.8 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.76: 17,041.8 17,046.6 3.958 Casing Jts 4 1/2 12.60 L-80 5 214.80 17,046.6 17,261.4 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.79 17,261.4 17,266.2 3.958 Casing Jts 4 1/2 12.60 L-80 ~ , 5 216.01 17,266.2 17,482.2 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.79 17,482.2 17,487.0 3.958; Casing Jts 4 1/2 12.60. E-80 ~ 5~ 215.08 17,487.0 17,702.1 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 i 4.79 17,702.1 17,706.8 3.958 Casing Jts 4 1/2 12.60 L-80 5 213.53 17,706.8 17,920.4 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.79 17,920.4 17,925.2 3.958 Casing Jts 4 1/2 12.60 L-80 i 5 215.07 17,925.2 18,140.2 ; 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.79 18,140.2 18,145.0 3.958 Casing Jts 4 1/2 12.60 L-80 5 203.02 18,145.0 18,348.0 3.958 Perforated Pup Joint 4 1!2 12.60' L-80 ~ 1 4.79; 18,348.0 18,352.8 3.958 Casing Jts 4 1/2 12.60 L-80 5 201.83 18,352.8 18,554.7 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.80 18,554.7 18,559.5 3.958 Casing Jts 4 1/2 12.60 L-80 5 202.33 18,559.5 18,761.8 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.81 18,761.8 18,766.6 3.958 Casing Jts 4 1/2 12.60 L-80 5 201.26 18,766.6 18,967.9 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.78 18,967.9 18,972.6 3.958 Casing Jts 4 1/2 12.60 L-80 5 2 0 9.88 18,972.6 19,182.5 3.958 )Perforated Pup Joint 4 1/2 12.60 L-80 1 _ __ . 4.79 19,182.5 19,187.3 ! 3.958 I Casing Jts 4 1 /2 ~ 12.60 L-80 5 204.62 19,187.3 19,391.9 3.958 Perforated Pup Joint 4 1/2j 12.60 L-80 1 4.80 19,391.9 19,396.7 3.958 Casing Jts 4 1/2 12.60 L-80 5 202.14 19,396.7 19,598.9 3.958 Perforated Pup Joint ~ 4 1/2 12.60 L-80 i 1 4.80 19,598.9 19,603.7 ! 3.958 Casing Jts 4 1/2 12.60 L-80 5 i 200.03 _ 1 19,603.7 19,803.7 3.958 Perforated Pup Joint 4 1/2 12.60 L-80 1 4.79 19,803.7 19,808.5 3.958 Casing Jts 4 1/2 12.60 L-80 5 207.13 19,808.5 20,015.6 3.958 i Page 1/2 Report Printed: 12/19/20071 Casing Detail Report CD4-05 Liner Casing Components MF:-up Ty I,em Deoaphcn OD I~n1 W1 Jt~~,Y~i Grade Top Thread Js Len lrt~ lop !RY.BI Ptm !~~KBi l<<-Ibsl Class Ma~O~fini ID !in) 28-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-05 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 36.58' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 21,142.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date o ~~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~,~~~_ c~''liL~''~L' ~~J~I II ~J!;-ui11!~~ COI~TSER~A ATIO CO1~II II SIp1~ C. Alvord WNS Drilling Team Lead Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 i SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD4-05 Conoco Phillips Alaska, Inc. Permit No: 207-155 Surface Location: 2903' FNL, 148' FEL, Sec. 24, T11N, R4E Bottomhole Location: 4591' FNL 4096' FEL, Sec. 15, T11N, R4E 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 any required test, contact the Commission's petroleum field inspector at (9059-3607 (pager). DATED this day of November, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 5 2007 PERMIT TO DRILLY~p~aska Oil & Gas Cons. Commission 20 AAC 25.005 Anchors e 1 a. Type of Work: Drill ^/ ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^/ i Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone Q 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single WeII Bond No. 59-52-180 11. Well Name and Number: CD4-05 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 21120' ~ TVD: 7515' ' 12. Field/Pool(s): Colville River Field 4a. Location of Well {Governmental Section): Surface: 2903' FNL, 148' FEL, Sec 24 T11 N R4E 7. Property Designation: ADL 387208, 38077, 380075 Alpine Oil Pool Top of Productive Horizon: 4424' FNL 1266' FEL, Sec. 22 T11N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 11/12/2007 Total Depth: 4591' FNL 4096' FEL, Sec. 15 T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property:>2mi common ownership 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378097 ' y- 5957507 ~ Zone- 4 10. KB Elevation 56' abov a MSL (Height above GL): 37' RKB feet 15. Distance to Nearest WeII within Pool: CD4-07 , 613' 16. Deviated wells: Kickoff depth: 400 - ft. Maximum Hole Angle: 91° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 3416 psig ~ Surface: 2661 psig ~ 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24"' 16" 62.5# H-40 Welded 77 37 37 114 ~ 114' pre-installed 12.25" 9-5l8" 40# L-80 BTC 2664 37 37 2701 ~ 2400 463 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 15235 37 37 15272 7551 482sx 15.8G, 2nd stage 184 sx 15.8G 3.5" 9.3# L-80 EUEM 15083 32 32 15115 7548 tubing 6-1/8" 4.5" 12.6# L-80 IBTM 6007 15103 7548 21110 7515 Liner with perforated subs 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth 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 r BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 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 . Alvord Title WNS Drilling Team Lead Signature ~, ~ f~/~ Phone ue'~ ~o~~l~ Date (1C~~2.s~ ~'' \ Commission Use Only Permit to Drill Number: `~~~'~~,~ API Number: 50- ~~3~ ~55~' Permit Approval Date: ~r • ~ ° ! ~ See cover letter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Ye~ No[r]' Other: ?J S~iO ~ 5 ~ ~~ ~~ ~V ~ H2S measures: Yes N D rectional svy req'd: Yes Q~ No ^ ~~ ~ ~ES~ APPROVED BY THE COMMISSION DATE: ~' ~' ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate ~Y~oJ~ /(• 7.07 ConocoPhillips Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 5, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-05 Dear Sir or Madam: r ConocoPhilli s p ~~~ V L~ Nt~V ~ ~ 2~~7 Alaska Ql ~ ~ Cans, ~ttl~lttilissian Anch~raga 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 11/12/07. It is intended that Doyon Rig 19 be used to drill the well. CD4-05 will be drilled to penetrate the Alpine reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as pre- perforated liner producer. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. The well will then be closed in awaiting completion of well work that will allow the well to begin production fourth quarter 2007. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage too an 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. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 19 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas by rates. - -' 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. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. 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. oaiciNa~ • r If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Sincer ~;~« ,~~~~ r Vern Johnson Drilling Engineer Attachments cc: CD4-05 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Tim Scheinder ATO 1768 Lanston Chin Kuukpik Corporation ORIGINAL CD4-05 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" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro 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 well bore. 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 H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL • Fiord : CD4-05 Procedure 1. Move on Doyon 19. Dewater cellar as needed. y 2. Drill 12 '/" hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. 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. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Driil out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and pull out of hole. 14. Run lower completion with blank liner, perforated pups, and liner hanger. 15. Run 3 %2, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, X nipple, and seal assembly. Sting in, space out and land hanger. 16. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. Circulate tubing and annulus to completion brine and diesel freeze protect fluid. 19. Drop ball and rod and test tubing and annulus to 3500 psi / 30 mins, set packer 20. Shear valve in the gas lift mandrel. 21. Set BPV and secure well. Move rig off. ORIGINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-304 is the closest well. Well separation is 15.1' @ 475' MD. Drilling Area Risks: It is possible that pressures higher than modeled could be seen. To mitigate this event, weighting material will be available to increase the mud weight. Lost circulation: Faulting within the Alpine 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 CD4-05 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-05 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq, Kuparuk, and the Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq and Qannik /'~ reservoirs. Upon completion of CD4-05 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 i • 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 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - Z00 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. ORIGINAL Completion Schematic: • Updated 11 /01 /07 16" Conductor to 114' Sperry Directional Plan - 4-''/z' space out pups WPO1 -3 '/i' x 4-'/z' cross-over, 2 jts below 4-'/i' hanger 9-5/8" 40 ppf L-80 BTC-mod Surface Casing 2701' MD / 2400' TVD cemented to surtace Cement to +/-6044' MD / 3885' TVD Qannik interval top +/- tool +/- 7064' MD / 4335' TVD /' ~/ TOC (~ +/- 12700' MD / 6819' TVD Min. 500' Above Kuparvk C sand/ 300' above packer Top Kuparuk +/-13532 MD / 7176 TVZ Top Alpine A +/-15103 MD / 7548 TVD Packer Fluid mix: Diesel in tubing and annulus Inhibited Brine also in annulus Upper Completion MD TVD 1) Tubing Hanger 32' 32' 2) 4-''/i' 12.6 #/ft IBT-Mod Tubing (2) 3) 4'/:" 12.6 #/ft IBT-Mod PUPS 4) Crossover 5) 3-1/2", 9.3#/ft, EUE-Mod Tubing 6) Camco TRMAXX-5E SSSV w/ x profile 2100' 2000' 7) 3-1/2", 9.3#/ft, EUE-Mod Tubing 8) Camco KBMG GLM (2.867" ID) w/dummy 4943' 3400' 9) 3-1/2", 9.3#/ft, EUE-Mod Tubing 10) Camco KBMG GLM (2.867" ID) w/dummy 9803' 5600' 11) 3-1/2", 9.3#/ft, EUE-Mod Tubing 12) Camco KBMG GLM (2.867" ID) w/DCK2 shear 12950' 6929' 13) 3-%'9.3#/ft, EUE-M (1) 14) Baker Premier Packer 13000' 6951' 15) 3'/:"9.3#/ft, EUE-M (2) 16) HES "XN" (2.75" min ID) @ 64° 13100' 6995' 17) 3 '/~' 9.3#/ft, EUE-M 18) BOT Stinger with Fluted WLEG/pup/shear sub 15100' 7547' bottom, 3' spaceout @ 15115' 7548' Lower Completion: Top MD TVD 19) Baker 5"x7" Flexlock Liner Hanger w/setting sleeve 15103' 7548' 20) 4??/z" 12.6#!ft L-80 IBTM Tubing with 5' Perforated pups 21) Baker Shoe 21110' 7515' 6-1/8" Hole 21120' MD /^515' TVD " ~~ 20 4-''/i' 12.6#Ift L-80 IBTM liner, 7" 29 ppf L-80 BTC Mod 1 ea 5 ft perforated pup per 4 Production Casing @ joints 15272' MD ! 7551' TVD Alpine A ORIGINAL • • CD4-05 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 2701 / 2400 14.5 1086 1571 7" 15272 / 7551 16.0 3416 ~--- 2661 N/A 21120 / 7515 16.0 3400 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) ~. ~~~ ~a A~, ~.c~7 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 2) ASP =FPP - (0.1 x D) OR 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) = 3416 - (0.1 x 7551) = 2661 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3400 - (0.1 x 7515') = 2648psi ORIGINAL Cementing Program: • 9 5/8" Surface Casing run to 2701' MD / 2400' TVD. Cement from 2701' MD to 2201' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2201' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1412' MD). Lead slurry: (2201'-1412') X 0.3132 ft3/ft X 1.5 (50% excess) = 370.7 ft3 below permafrost 1412' X 0.3132 ft3/ft X 4 (300% excess) = 1768.9 ft3 above permafrost Total volume = 370.7 + 1768.9 = 2139.6 ft3 => 463 Sx @ 4.63 ft3/sk System: 463 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 44^63 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW1 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 15272' MD / 7551' TVD Cement from 15272' MD to 12700' MD (300 ft above the planned packer depth) with Class G + adds @ 15.8 PPG. Tail: (15272'-12700') X 0.1503 ft3/ft X 1.4 (40% excess) =541.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 541.2 + 17.2 = 558.4 ft3 => 482 Sx @ 1.16 ft3/sk System: 482 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 re ra der and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a hydraulic opening stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (7064'-6044') X 0.1503 ft3/ft X 1.4 (40% excess) = 214.6 ft3 annular vol. Total Volume = 214.6 ft3 => 184 Sk @ 1.17 ft3/sk System: 184 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator 15.8 PPG yielding 1.17 ft3/sk ~~ ' By Weight Of mix Water, all other additives are BWOCement ORIGINAL ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 11/1!2007 Time: 12:36:30 Page: T Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: CD4-05 (36.3+19:5) 55.8 Well: Plan: CD4-05 Section (VS) Reference: Well (O.OON,O.OOE,283.96Azi) Wellpath: Plan: CD4-05 Survey Calculation Method: Minimum Curvature Db: Orate Plan: CD4-05wp01 Date Composed: 9/27/2007 Alpine A Version: 6 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: bggm2007 Site: Nanuq 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: CD4-05 Slot Name: Well Position: +N/-S -20.08 ft Northing: 5957507.28 ft Latitude: 70 17 32.768 N +E/-W -77.62 ft Easting : 378096.77 ft Longitude: 150 59 13.025 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-05 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-05 (36.3+19.5) Height 55.80 ft Above System Datum: Mean Sea Level Magnetic Data: 6/28/2005 Declination: 23.52 deg Field Strength: 57536 nT Mag Dip Angle: 80.58 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 283.96 Survey Program for Definitive Wellpath Date: 9/27/2007 Validated: No Version: 3 Actual From To Survey Tootcode Tool Name ft ft Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/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 0.00 650.00 5.00 210.00 649.68 -9.44 -5.45 2.00 2.00 0.00 210.00 900.00 4.02 297.09 899.15 -14.89 -18.71 2.50 -0.39 34.84 140.00 2927.83 63.85 256.36 2511.89 -216.48 -1066.77 3.00 2.95 -2.01 -42.12 13088.43 63.85 256.36 6990.18 -2367.33 -9929.99 0.00 0.00 0.00 0.00 15272.86 90.34 331.06 7550.80 -1511.86 -11678.78 3.50 1.21 3.42 82.81 CD4-05wp01 Heel 21120.39 90.34 331.06 7515.80 3605.39 -14508.31 0.00 0.00 0.00 0.00 CD4-05wp01 Toe ORIGINAL Name +N/-S +E/-W Plan: CD4-OS -20.08 -77.62 WELL DETAILS Northing Easting 5957507.28 378096.77 Latitude Longitude Slot 70°1T32.768N 150°59'13.025W N/A WELLPATH DETAILS Plan: CD4-OS Rig: Doyon 19 Ref. Datum: Plan: CD4-OS (36.3+19.5) 55.80ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 283.96° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.52° Magnetic Field Strength: 57536nT Dip Angle: 80.58° Date: 6/28/2005 Model: bggm2007 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD4-OSwp01 V3 CB-GYRO-SS 1000.00 21120.39 Planned: CD4-OSwp01 V3 MWD+IFR-AK-CAZ-SC c A 2 [-- Vertical Sectlon a[ 283.96° [SOOOf7/in] 1000 500 CD4-OS O1 ~ 0 o w Q \ ~ ~ °o h 0 ~ ~ o 0 oo ° 0 -500 15000 -10000 -5000 0 West(-)/East(+) [SOOOft/in] HALLIBURTON Sperry Drilling Services ConacoPhillips Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD4-O5, True North Vertical (TVD) Reference: Plan: CD4-OS (36.3+19.5) 55.80 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: Plan: CD4-OS (36.3+19.5) 55.80 Calculation Method: Minimum Curvature ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 11/1/2007 Time: 12:36:30 Page: 2 Field: Colville River Unit Co-ordinate(NE) Reference: We IL F'I art: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: C D4-05 (36. 3+19.5) !55.8 We1L• Plan: CD4-0 5 Section (VS) Reference: We II (O. OON,O.OOE,283.96Azi) Wellpatb: Plan: CD4-05 Survey Caleulation Method: Minimum Curvature Dbd Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE 1)LS TFO Comme t ft deg deg ft ft ft ft ft ft deg/1 OOft `deg 36. 30 0 .00 0. 00 36. 30 -19 .50 0. 00 0. 00 5957507 .28 ~ 378096. 77 ~ 0.00 0.00 100. 00 0 .00 0. 00 100. 00 44 .20 0. 00 0. 00 5957507 .28 378096. 77 0.00 0.00 200. 00 0 .00 0. 00 200. 00 144 .20 0. 00 0. 00 5957507 .28 378096. 77 0.00 0.00 300. 00 0 .00 0. 00 300. 00 244 .20 0. 00 0. 00 5957507 .28 378096. 77 0.00 0.00 400. 00 0 .00 0. 00 400. 00 344 .20 0. 00 0. 00 5957507 .28 378096. 77 0.00 0.00 KOP ~ 500. 00 2 .00 210. 00 499. 98 444 .18 -1. 51 -0. 87 5957505 .78 378095. 87 2.00 0.00 600. 00 4 .00 210. 00 599. 84 544 .04 -6. 04 -3. 49 5957501 .29 378093. 18 2.00 0.00 650. 00 5 .00 210. 00 649. 68 593 .88 -9. 44 -5. 45 5957497 .93 378091. 17 2.00 0.00 700. 00 4 .12 221. 25 699. 53 643 .73 -12. 68 -7. 72 5957494 .73 378088. 84 2.50 140.00 800. 00 3 .21 258. 60 799. 33 743 .53 -15. 93 -12. 84 5957491 .56 378083. 67 2.50 128.78 900. 00 4 .02 297. 09 899. 15 843 .35 -14. 89 -18. 71 5957492 .69 378077. 82 2.50 91.50 1000. 00 6 .56 279. 19 998. 72 942 .92 -12. 38 -27. 47 5957495 .34 378069. 11 3.00 317.88 1100. 00 9 .37 271. 59 1097. 75 1041 .95 -11. 25 -41. 25 5957496 .71 378055. 35 3.00 335.70 1200. 00 12 .28 267. 52 1195. 96 1140 .16 -11. 48 -60. 02 5957496 .78 378036. 58 3.00 343.23 1300. 00 15 .22 265. 00 1293. 08 1237 .28 -13. 08 -83. 72 5957495 .56 378012. 86 3.00 347.23 1400. 00 18 .18 263. 27 1388. 86 1333 .06 -16. 06 -112. 29 5957493 .05 377984. 25 3.00 349.69 1500. 00 21 .15 262. 02 1483. 02 1427 .22 -20. 39 -145. 65 5957489 .26 377950. 82 3.00 351.33 1600. 00 24 .12 261. 07 1575. 30 1519 .50 -26. 06 -183. 71 5957484 .20 377912. 68 3.00 352.51 1700. 00 27 .11 260. 31 1665. 47 1609 .67 -33. 07 -226. 36 5957477 .88 377869. 92 3.00 353.40 1800. 00 30 .09 259. 69 1753. 26 1697 .46 -41. 40 -273. 50 5957470 .33 377822. 66 3.00 354.08 1900. 00 33 .08 259. 18 1838. 43 1782 .63 -51. 01 -324. 98 5957461 .55 377771. 03 3.00 354.62 2000. 00 36 .07 258. 74 1920. 76 1864 .96 -61. 88 -380. 67 5957451 .58 377715. 18 3.00 355.06 2100. 00 39 .06 258. 36 2000. 02 1944 .22 -73. 99 -440. 41 5957440 .45 377655. 25 3.00 355.42 2200. 00 42 .05 258. 03 2075. 99 2020 .19 -87. 30 -504. 05 5957428 .17 377591. 42 3.00 355.72 2300. 00 45 .05 257. 73 2148. 46 2092 .66 -101. 77 -571. 40 5957414 .79 377523. 84 3.00 355.98 2400. 00 48 .04 257. 46 2217. 23 2161 .43 -117. 37 -642. 28 5957400 .35 377452. 72 3.00 356.19 2500. 00 51 .03 257. 22 2282. 12 2226 .32 -134. 05 -716. 51 5957384 .88 377378. 24 3.00 356.38 2600. 00 54 .03 256. 99 2342. 95 2287 .15 -151. 76 -793. 86 5957368 .42 377300. 62 3.00 356.53 2700. 00 57 .02 256. 79 2399. 54 2343 .74 -170. 46 -874. 14 5957351 .03 377220. 05 3.00 356.67 2700. 84 57 .05 256. 78 2400. 00 2344 .20 -170. 62 -874. 83 5957350 .88 377219. 36 3.00 356.79 9 5/8" x 12 1/4" 2707. 84 57 .26 256. 77 2403. 80 2348 .00 -171. 97 -880. 56 5957349 .63 377213. 61 3.00 356.79 C-30 2800. 00 60 .02 256. 59 2451. 76 2395 .96 -190. 10 -957. 12 5957332 .74 377136. 77 3.00 356.80 2900. 00 63 .01 256. 41 2499. 44 2443 .64 -210. 62 -1042. 58 5957313 .61 377051. 00 3.00 356.89 2927. 83 63 .85 256. 36 2511. 89 2456 .09 -216. 48 -1066. 77 5957308 .15 377026. 72 3.00 356.98 3000. 00 63 .85 256. 36 2543. 70 2487 .90 -231. 75 -1129. 73 5957293 .89 376963. 53 0.00 0.00 3100. 00 63 .85 256. 36 2587. 77 2531 .97 -252. 92 -1216. 96 5957274 .15 376875. 97 0.00 0.00 3200. 00 63 .85 256. 36 2631. 85 2576 .05 -274. 09 -1304. 19 5957254 .40 376788. 42 0.00 0.00 3300. 00 63 .85 256. 36 2675. 92 2620 .12 -295. 26 -1391. 42 5957234 .65 376700. 86 0.00 0.00 3400. 00 63 .85 256. 36 2720. 00 2664 .20 -316. 43 -1478. 65 5957214 .90 376613. 30 0.00 0.00 3500. 00 63 .85 256. 36 2764. 07 2708 .27 -337. 60 -1565. 88 5957195 .15 376525. 75 0.00 0.00 3519. 80 63 .85 256. 36 2772. 80 2717 .00 -341. 79 -1583. 16 5957191 .24 376508. 41 0.00 0.00 C-20 3600. 00 63 .85 256. 36 2808. 15 2752 .35 -358. 76 -1653. 11 5957175 .40 376438. 19 0.00 0.00 3700. 00 63 .85 256. 36 2852. 22 2796 .42 -379. 93 -1740. 35 5957155 .65 376350. 64 0.00 0.00 3800. 00 63 .85 256. 36 2896. 30 2840 .50 -401. 10 -1827. 58 5957135 .90 376263. 08 0.00 0.00 3900. 00 63 .85 256. 36 2940. 37 2884 .57 -422. 27 -1914. 81 5957116 .15 376175. 53 0.00 0.00 4000. 00 63 .85 256. 36 2984. 45 2928 .65 -443. 44 -2002. 04 5957096 .40 376087. 97 0.00 0.00 4100. 00 63 .85 256. 36 3028. 52 2972 .72 -464. 61 -2089. 27 5957076 .65 376000. 41 0.00 0.00 4200. 00 63 .85 256. 36 3072. 60 3016 .80 -485. 78 -2176. 50 5957056 .90 375912. 86 0.00 0.00 4300. 00 63 .85 256. 36 3116. 67 3060 .87 -506. 94 -2263. 73 5957037 .15 375825. 30 0.00 0.00 4400. 00 63 .85 256. 36 3160. 75 3104 .95 -528. 11 -2350. 96 5957017 .40 375737. 75 0.00 0.00 4500. 00 63 .85 256. 36 3204. 82 3149 .02 -549. 28 -2438. 20 5956997 .65 375650. 19 0.00 0.00 4600. 00 63 .85 256. 36 3248. 90 3193 .10 -570. 45 -2525. 43 5956977 .90 375562. 64 0.00 0.00 4700. 00 63 .85 256. 36 3292. 97 3237 .17 -591. 62 -2612. 66 5956958 .15 375475. 08 0.00 0.00 ORIGINAL • ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 11/1/2007 Time: 12:36:30 Page: 3 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD4-0 5, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: C D4-05 (36. 3+t9.5) 55.8 Well: Plan: CD4-05 Section (VS) Reference: Well (O. OON,O.OOE,283,96Azi) Wellpatb: Plan: CD4-05 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc l Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comme t ft deg d eg ft ft ft ft ft ft degllOOft deg 4800. 00 63 .85 256 .36 3337 .05 3281 .25 -612 .79 -2699. 89 5956938 .40 375387 .52 0.00 0.00 4900. 00 63 .85 256 .36 3381 .12 3325 .32 -633 .96 -2787. 12 5956918 .65 375299 .97 0.00 0.00 5000. 00 63 .85 256 .36 3425 .20 3369 .40 -655 .12 -2874. 35 5956898 .90 375212 .41 0.00 0.00 5100. 00 63 .85 256 .36 3469 .27 3413 .47 -676 .29 -2961. 58 5956879 .15 375124 .86 0.00 0.00 5200. 00 63 .85 256 .36 3513 .35 3457 .55 -697 .46 -3048. 81 5956859 .40 375037 .30 0.00 0.00 5300. 00 63 .85 256 .36 3557 .42 3501 .62 -718 .63 -3136. 05 5956839 .65 374949 .75 0.00 0.00 5400. 00 63 .85 256 .36 3601 .50 3545 .70 -739 .80 -3223. 28 5956819 .91 374862 .19 0.00 0.00 5500. 00 63 .85 256 .36 3645 .57 3589 .77 -760 .97 -3310. 51 5956800 .16 374774 .63 0.00 0.00 5600. 00 63 .85 256 .36 3689 .65 3633 .85 -782 .14 -3397. 74 5956780 .41 374687 .08 0.00 0.00 5700. 00 63 .85 256 .36 3733 .72 3677 .92 -803 .30 -3484. 97 5956760 .66 374599 .52 0.00 0.00 5800. 00 63 .85 256 .36 3777 .80 3722 .00 -824 .47 -3572. 20 5956740 .91 374511 .97 0.00 0.00 5900. 00 63 .85 256 .36 3821 .87 3766 .07 -845 .64 -3659. 43 5956721 .16 374424 .41 0.00 0.00 5958. 82 63 .85 256 .36 3847 .80 3792 .00 -858 .09 -3710. 74 5956709 .54 374372 .91 0.00 0.00 K-3 6000. 00 63 .85 256 .36 3865 .95 3810 .15 -866 .81 -3746. 66 5956701 .41 374336 .86 0.00 0.00 6100. 00 63 .85 256 .36 3910 .02 3854 .22 -887 .98 -3833. 89 5956681 .66 374249 .30 0.00 0.00 6200. 00 63 .85 256 .36 3954 .10 3898 .30 -909 .15 -3921. 13 5956661 .91 374161 .74 0.00 0.00 6300. 00 63 .85 256 .36 3998 .17 3942 .37 -930 .32 -4008. 36 5956642 .16 374074 .19 0.00 0.00 6400. 00 63 .85 256 .36 4042 .25 3986 .45 -951 .48 -4095. 59 5956622 .41 373986 .63 0.00 0.00 6462. 51 63 .85 256 .36 4069 .80 4014 .00 -964 .72 -4150. 12 5956610 .06 373931 .90 0.00 0.00 K-3 Basal 6500. 00 63. 85 256 .36 4086 .32 4030. 52 -972 .65 -4182. 82 5956602 .66 373899 .08 0.00 0.00 6544. 19 63. 85 256 .36 4105 .80 4050. 00 -982 .01 -4221. 37 5956593 .93 373860 .39 0.00 0.00 K-2 6600. 00 63. 85 256 .36 4130 .40 4074. 60 -993 .82 -4270. 05 5956582 .91 373811 .52 0.00 0.00 6700. 00 63. 85 256 .36 4174 .47 4118. 67 -1014 .99 -4357. 28 5956563 .16 373723 .97 0.00 0.00 6786. 96 63. 85 256 .36 4212 .80 4157. 00 -1033 .40 -4433. 13 5956545 .99 373647 .83 0.00 0.00 K-2 Basal 6800. 00 63. 85 256 .36 4218 .55 4162. 75 -1036 .16 -4444. 51 5956543 .41 373636 .41 0.00 0.00 6900. 00 63. 85 256 .36 4262 .62 4206. 82 -1057 .33 -4531. 74 5956523 .66 373548 .85 0.00 0.00 7000. 00 63. 85 256 .36 4306 .70 4250. 90 -1078 .50 -4618. 98 5956503 .91 373461 .30 0.00 0.00 7100. 00 63. 85 256 .36 4350 .77 4294. 97 -1099 .66 -4706. 21 5956484 .16 373373 .74 0.00 0.00 7200. 00 63. 85 256 .36 4394 .85 4339. 05 -1120 .83 -4793. 44 5956464 .41 373286 .19 0.00 0.00 7300. 00 63. 85 256 .36 4438 .92 4383. 12 -1142 .00 -4880. 67 5956444 .66 373198 .63 0.00 0.00 7400. 00 63. 85 256 .36 4483 .00 4427. 20 -1163 .17 -4967. 90 5956424 .91 373111 .08 0.00 0.00 7500. 00 63. 85 256 .36 4527 .07 4471. 27 -1184 .34 -5055. 13 5956405 .16 373023 .52 0.00 0.00 7600. 00 63. 85 256 .36 4571 .15 4515. 35 -1205 .51 -5142. 36 5956385. 42 372935 .96 0.00 0.00 7700. 00 63. 85 256 .36 4615 .22 4559. 42 -1226 .68 -5229. 59 5956365. 67 372848 .41 0.00 0.00 7800. 00 63. 85 256 .36 4659 .30 4603. 50 -1247 .84 -5316. 83 5956345. 92 372760 .85 0.00 0.00 7900. 00 63. 85 256 .36 4703 .37 4647. 57 -1269 .01 -5404. 06 5956326. 17 372673 .30 0.00 0.00 8000. 00 63. 85 256 .36 4747 .45 4691. 65 -1290 .18 -5491. 29 5956306. 42 372585 .74 0.00 0.00 8100. 00 63. 85 256 .36 4791 .52 4735. 72 -1311 .35 -5578. 52 5956286. 67 372498 .19 0.00 0.00 8200. 00 63. 85 256 .36 4835 .60 4779. 80 -1332 .52 -5665. 75 5956266. 92 372410 .63 0.00 0.00 8300. 00 63. 85 256 .36 4879 .68 4823. 88 -1353 .69 -5752. 98 5956247. 17 372323 .07 0.00 0.00 8400. 00 63. 85 256 .36 4923 .75 4867. 95 -1374 .86 -5840. 21 5956227. 42 372235 .52 0.00 0.00 8500. 00 63. 85 256 .36 4967 .83 4912. 03 -1396 .02 -5927. 44 5956207. 67 372147 .96 0.00 0.00 8600. 00 63. 85 256 .36 5011 .90 4956. 10 -1417 .19 -6014. 67 5956187. 92 372060 .41 0.00 0.00 8700. 00 63. 85 256 .36 5055 .98 5000. 18 -1438 .36 -6101. 91 5956168. 17 371972 .85 0.00 0.00 8800. 00 63. 85 256 .36 5100 .05 5044. 25 -1459 .53 -6189. 14 5956148. 42 371885 .29 0.00 0.00 8900. 00 63. 85 256 .36 5144 .13 5088. 33 -1480 .70 -6276. 37 5956128. 67 371797 .74 0.00 0.00 9000. 00 63. 85 256 .36 5188 .20 5132. 40 -1501 .87 -6363. 60 5956108. 92 371710 .18 0.00 0.00 9100. 00 63. 85 256 .36 5232 .28 5176. 48 -1523 .04 -6450. 83 5956089. 17 371622 .63 0.00 0.00 9200. 00 63. 85 256 .36 5276 .35 5220. 55 -1544 .20 -6538. 06 5956069. 42 371535 .07 0.00 0.00 9300. 00 63. 85 256 .36 5320 .43 5264. 63 -1565 .37 -6625. 29 5956049. 67 371447 .52 0.00 0.00 9400. 00 63. 85 256 .36 5364 .50 5308. 70 -1586 .54 -6712. 52 5956029. 92 371359 .96 0.00 0.00 9500. 00 63. 85 256 .36 5408 .58 5352. 78 -1607 .71 -6799. 76 5956010. 17 371272 .40 0.00 0.00 ORIGINAL w ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 11!1/2007 Time: 12:36:30 Page: 4 Field: Colville River Un it Co-ordinate(NE) Reference: WeIC Plan: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan; CD4-05 {36 .3+19.5) 55.8 .Well: Plan: CD4-05 Section (VS) Reference: WeII (O OON,O;OOE,283.96Azi) Wellpath: Plan: CD4-05 Survey Calculation Method: Minimum Curvature Dbc Oracle Survey MD Iucl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comme t ft deg deg ft ft ft ft ft ft deg/100ft deg 9600. 00 63 .85 256 .36 5452 .65 5396 .85 -1628 .88 -6886. 99 5955990 .42 371184 .85 0.00 0.00 9700. 00 63 .85 256 .36 5496 .73 5440 .93 -1650 .05 -6974. 22 5955970 .67 371097 .29 0.00 0.00 9800. 00 63 .85 256 .36 5540 .80 5485 .00 -1671 .22 -7061. 45 5955950 .92 371009 .74 0.00 0.00 9900. 00 63 .85 256 .36 5584 .88 5529 .08 -1692 .38 -7148. 68 5955931 .18 370922 .18 0.00 0.00 10000. 00 63 .85 256 .36 5628 .95 5573 .15 -1713 .55 -7235. 91 5955911 .43 370834 .63 0.00 0.00 10100. 00 63 .85 256 .36 5673 .03 5617 .23 -1734 .72 -7323. 14 5955891 .68 370747 .07 0.00 0.00 10200. 00 63 .85 256 .36 5717 .10 5661 .30 -1755 .89 -7410. 37 5955871 .93 370659 .51 0.00 0.00 10287. 80 63 .85 256 .36 5755 .80 5700 .00 -1774 .48 -7486. 96 5955854 .59 370582 .64 0.00 0.00 Albian 97 10300. 00 63 .85 256 .36 5761 .18 5705 .38 -1777 .06 -7497. 61 5955852 .18 370571 .96 0.00 0.00 10400. 00 63 .85 256 .36 5805 .25 5749 .45 -1798 .23 -7584. 84 5955832 .43 370484 .40 0.00 0.00 10500. 00 63 .85 256 .36 5849 .33 5793 .53 -1819 .39 -7672. 07 5955812 .68 370396 .85 0.00 0.00 10600. 00 63 .85 256 .36 5893 .40 5837 .60 -1840 .56 -7759. 30 5955792 .93 370309 .29 0.00 0.00 10700. 00 63 .85 256 .36 5937 .48 5881 .68 -1861 .73 -7846. 53 5955773 .18 370221 .74 0.00 0.00 10800. 00 63 .85 256 .36 5981 .55 5925 .75 -1882 .90 -7933. 76 5955753 .43 370134 .18 0.00 0.00 10900. 00 63 .85 256 .36 6025 .63 5969 .83 -1904 .07 -8020. 99 5955733 .68 370046 .62 0.00 0.00 11000. 00 63 .85 256 .36 6069 .70 6013 .90 -1925 .24 -8108. 22 5955713 .93 369959 .07 0.00 0.00 11100. 00 63 .85 256 .36 6113 .78 6057 .98 -1946 .41 -8195. 45 5955694 .18 369871 .51 0.00 0.00 11188. 54 63. 85 256 .36 6152 .80 6097 .00 -1965 .15 -8272. 69 5955676 .69 369793 .99 0.00 0.00 Albian 96 11200. 00 63 .85 256 .36 6157 .85 6102 .05 -1967 .57 -8282. 69 5955674 .43 369783 .96 0.00 0.00 11300. 00 63. 85 256 .36 6201 .93 6146 .13 -1988 .74 -8369. 92 5955654 .68 369696 .40 0.00 0.00 11400. 00 63. 85 256 .36 6246 .00 6190 .20 -2009 .91 -8457. 15 5955634 .93 369608 .85 0.00 0.00 11500. 00 63. 85 256 .36 6290 .08 6234 .28 -2031 .08 -8544. 38 5955615 .18 369521 .29 0.00 0.00 11600. 00 63. 85 256 .36 6334 .15 6278 .35 -2052 .25 -8631. 61 5955595 .43 369433 .73 0.00 0.00 11700. 00 63. 85 256 .36 6378 .23 6322. 43 -2073 .42 -8718. 84 5955575 .68 369346 .18 0.00 0.00 11800. 00 63. 85 256 .36 6422 .30 6366. 50 -2094 .59 -8806. 07 5955555 .93 369258 .62 0.00 0.00 11900. 00 63. 85 256 .36 6466 .38 6410. 58 -2115 .75 -8893. 30 5955536 .18 369171 .07 0.00 0.00 12000. 00 63. 85 256 .36 6510 .45 6454. 65 -2136 .92 -8980. 54 5955516 .43 369083 .51 0.00 0.00 12100. 00 63. 85 256 .36 6554 .53 6498. 73 -2158 .09 -9067. 77 5955496 .69 368995 .96 0.00 0.00 12200. 00 63. 85 256 .36 6598 .60 6542. 80 -2179 .26 -9155. 00 5955476 .94 368908 .40 0.00 0.00 12300. 00 63. 85 256 .36 6642 .68 6586. 88 -2200 .43 -9242. 23 5955457 .19 368820 .84 0.00 0.00 12400. 00 63. 85 256 .36 6686 .75 6630. 95 -2221 .60 -9329. 46 5955437 .44 368733 .29 0.00 0.00 12500. 00 63. 85 256 .36 6730 .83 6675. 03 -2242 .77 -9416. 69 5955417 .69 368645 .73 0.00 0.00 12600. 00 63. 85 256 .36 6774 .90 6719. 10 -2263 .93 -9503. 92 5955397 .94 368558 .18 0.00 0.00 12700. 00 63. 85 256 .36 6818 .98 6763. 18 -2285 .10 -9591. 15 5955378 .19 368470 .62 0.00 0.00 12797. 16 63. 85 256 .36 6861 .80 6806. 00 -2305 .67 -9675. 91 5955359 .00 368385 .55 0.00 0.00 HRZ 12800. 00 63. 85 256 .36 6863 .05 6807. 25 -2306 .27 -9678. 39 5955358 .44 368383 .07 0.00 0.00 12900. 00 63. 85 256 .36 6907 .13 6851. 33 -2327 .44 -9765. 62 5955338 .69 368295 .51 0.00 0.00 13000. 00 63. 85 256 .36 6951 .20 6895. 40 -2348 .61 -9852. 85 5955318 .94 368207 .95 0.00 0.00 13088. 43 63. 85 256 .36 6990 .18 6934. 38 -2367 .33 -9929. 99 5955301 .47 368130 .53 0.00 0.00 13100. 00 63. 90 256 .81 6995 .27 6939. 47 -2369 .74 -9940. 09 5955299 .23 368120 .39 3.50 82.81 13200. 00 64. 40 260 .66 7038 .89 6983. 09 -2387 .31 -10028. 33 5955283 .09 368031 .88 3.50 82.61 13300. 00 65. 00 264 .47 7081 .63 7025. 83 -2399 .00 -10117. 95 5955272 .85 367942 .09 3.50 80.93 13314. 62 65. 10 265 .02 7087 .80 7032. 00 -2400 .22 -10131. 15 5955271 .85 367928 .88 3.50 79.30 HRZ Base 13400. 00 65. 70 268 .24 7123 .35 7067. 55 -2404 .77 -10208. 64 5955268 .56 367851 .33 3.50 79.07 13418. 14 65. 83 268 .92 7130. 80 7075. 00 -2405 .18 -10225. 17 5955268. 42 367834 .79 3.50 77.73 K-1 13500. 00 66. 49 271 .97 7163. 89 7108. 09 -2404 .59 -10300. 03 5955270. 22 367759 .96 3.50 77.45 13532. 54 66. 76 273 .18 7176. 80 7121. 00 -2403 .24 -10329. 87 5955272. 05 367730 .15 3.50 76.22 Kuparuk 13600. 00 67. 36 275 .66 7203. 09 7147. 29 -2398 .46 -10391. 81 5955277. 84 367668 .30 3.50 75.74 13633. 23 67. 67 276 .87 7215. 80 7160. 00 -2395 .11 -10422. 33 5955281. 69 367637 .84 3.50 74.77 LCU/Miluveach 13700. 00 68. 32 279 .29 7240. 82 7185. 02 -2386 .40 -10483. 61 5955291. 38 367576 .71 3.50 74.31 13800. 00 69. 36 282 .88 7276. 92 7221. 12 -2368 .47 -10575. 11 5955310. 80 367485. 52 3.50 73.40 13900. 00 70. 47 286 .41 7311. 26 7255. 46 -2344 .72 -10665. 96 5955336. 01 367395 .08 3.50 72.11 14000. 00 71. 65 289 .89 7343. 73 7287. 93 -2315 .25 -10755. 82 5955366. 93 367305 .72 3.50 70.89 ORIGINAL • ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska )nc. Date: 11/1/2007 Time: 12:36:30 Page:. 5 Field: Colville Rive r Unit Co-ordinate(NE) Reference: Well: Plan: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: CD4-05 (36 .3+19.5) 55.8 WeIL• Plan: C D4-05 Section ( VS) Referenc e: We ll. (O .OON,O.OOE,283;96Azi) Wellpath: Plan; C D4-05 Survey Calculation Method: Minimu m Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS TI'O Comme t ft deg deg ft ft ft ft ft ft deg/100ft deg 14100. 00 72. 89 293 .33 7374 .18 7318. 38 -2280 .16 -10844.35 5955403 .45 367217 .77 3.50 69. 76 14200. 00 74. 19 296 .72 7402 .52 7346. 72 -2239 .59 -10931.23 5955445 .42 367131 .57 3.50 68. 72 14215. 80 74. 40 297 .25 7406 .80 7351. 00 -2232 .69 -10944.79 5955452 .54 367118 .13 3.50 67. 76 Miluveach A 14300. 00 75. 54 300 .06 7428 .64 7372. 84 -2193 .69 -11016.13 5955492 .68 367047 .43 3.50 67. 61 14400. 00 76. 94 303 .37 7452 .43 7396. 63 -2142 .63 -11098.74 5955545 .07 366965 .67 3.50 66. 88 14465. 91 77. 88 305 .53 7466 .80 7411. 00 -2106 .25 -11151.78 5955582 .31 366913 .23 3.50 66. 10 Alpine D 14500. 00 78. 38 306 .64 7473 .81 7418. 01 -2086 .60 -11178.74 5955602 .39 366886 .60 3.50 65. 63 14561. 87 79. 28 308 .64 7485 .80 7430. 00 -2049 .53 -11226.80 5955640 .23 366839 .14 3.50 65. 40 UJU 14600. 00 79. 85 309 .87 7492 .70 7436. 90 -2025 .81 -11255.84 5955664 .42 366810 .50 3.50 65. 01 14700. 00 81. 36 313 .07 7509 .04 7453. 24 -1960 .48 -11329.75 5955730 .93 366737 .67 3.50 64. 79 14800. 00 82. 89 316 .25 7522 .75 7466. 95 -1890 .86 -11400.19 5955801. 68 366668 .37 3.50 64. 26 14900. 00 84. 44 319 .40 7533 .78 7477. 98 -1817 .21 -11466.90 5955876 .39 366602 .86 3.50 63. 83 15000. 00 86. 01 322 .54 7542 .11 7486. 31 -1739 .81 -11529.64 5955954. 80 366541 .39 3.50 63. 48 15100. 00 87. 59 325 .67 7547 .69 7491. 89 -1658 .94 -11588.17 5956036. 60 366484 .19 3.50 63. 22 15102. 74 87. 64 325 .75 7547 .80 7492. 00 -1656 .67 -11589.71 5956038. 89 366482 .68 3.50 63. 04 Alpine A Reserv it 15200. 00 89. 18 328 .79 7550 .50 7494. 70 -1574 .90 -11642.27 5956121. 50 366431 .46 3.50 63. 04 15272. 86 90. 34 331 .06 7550 .80 7495. 00 -1511 .86 -11678.78 5956185. 12 366395 .99 3.50 62. 96 CD4-05wp01 He I 15300. 00 90. 34 331 .06 7550 .64 7494. 84 -1488 .10 -11691.91 5956209. 08 366383 .24 0.00 180. 00 15400. 00 90. 34 331 .06 7550 .04 7494. 24 -1400 .59 -11740.30 5956297. 36 366336 .28 0.00 180. 00 15500. 00 90. 34 331 .06 7549 .44 7493. 64 -1313 .08 -11788.69 5956385. 63 366289 .32 0.00 180. 00 15600. 00 90. 34 331 .06 7548 .84 7493. 04 -1225 .57 -11837.07 5956473. 91 366242 .36 0.00 180. 00 15700. 00 90. 34 331 .06 7548 .24 7492. 44 -1138 .06 -11885.46 5956562. 19 366195 .40 0.00 180. 00 15800. 00 90. 34 331 .06 7547 .64 7491. 84 -1050 .55 -11933.85 5956650. 47 366148 .45 0.00 180. 00 15900. 00 90. 34 331 .06 7547 .05 7491. 25 -963 .04 -11982.24 5956738. 74 366101 .49 0.00 180. 00 16000. 00 90. 34 331 .06 7546 .45 7490. 65 -875 .52 -12030.63 5956827. 02 366054 .53 0.00 180. 00 16100. 00 90. 34 331 .06 7545 .85 7490. 05 -788 .01 -12079.02 5956915. 30 366007 .57 0.00 180. 00 16200. 00 90. 34 331 .06 7545 .25 7489. 45 -700 .50 -12127.40 5957003. 57 365960 .61 0.00 180. 00 16300. 00 90. 34 331 .06 7544 .65 7488. 85 -612 .99 -12175.79 5957091. 85 365913 .65 0.00 180. 00 16400. 00 90. 34 331 .06 7544 .05 7488. 25 -525 .48 -12224.18 5957180. 13 365866 .69 0.00 180. 00 16500. 00 90. 34 331 .06 7543 .46 7487. 66 -437 .97 -12272.57 5957268. 40 365819 .73 0.00 180. 00 16600. 00 90. 34 331 .06 7542 .86 7487. 06 -350 .46 -12320.96 5957356. 68 365772 .77 0.00 180. 00 16700. 00 90. 34 331 .06 7542 .26 7486. 46 -262 .95 -12369.35 5957444. 96 365725 .81 0.00 180. 00 16800. 00 90. 34 331 .06 7541 .66 7485. 86 -175 .44 -12417.74 5957533. 24 365678 .85 0.00 180. 00 16900. 00 90. 34 331 .06 7541 .06 7485. 26 -87 .92 -12466.12 5957621. 51 365631 .90 0.00 180. 00 17000. 00 90. 34 331 .06 7540 .46 7484. 66 -0 .41 -12514.51 5957709. 79 365584 .94 0.00 180. 00 17100. 00 90. 34 331 .06 7539 .86 7484. 06 87 .10 -12562.90 5957798. 07 365537 .98 0.00 180. 00 17200. 00 90. 34 331 .06 7539 .27 7483. 47 174 .61 -12611.29 5957886. 34 365491 .02 0.00 180. 00 17300. 00 90. 34 331 .06 7538 .67 7482. 87 262 .12 -12659.68 5957974. 62 365444 .06 0.00 180. 00 17400. 00 90. 34 331 .06 7538 .07 7482. 27 349 .63 -12708.07 5958062. 90 365397 .10 0.00 180. 00 17500. 00 90. 34 331 .06 7537 .47 7481. 67 437 .14 -12756.45 5958151. 17 365350 .14 0.00 180. 00 17600. 00 90. 34 331 .06 7536 .87 7481. 07 524 .65 -12804.84 5958239. 45 365303 .18 0.00 180. 00 17700. 00 90. 34 331 .06 7536 .27 7480. 47 612 .16 -12853.23 5958327. 73 365256 .22 0.00 180. 00 17800. 00 90. 34 331 .06 7535 .67 7479. 87 699 .68 -12901.62 5958416. 01 365209 .26 0.00 180. 00 17900. 00 90. 34 331 .06 7535 .08 7479. 28 787 .19 -12950.01 5958504. 28 365162 .31 0.00 180. 00 18000. 00 90. 34 331 .06 7534 .48 7478. 68 874 .70 -12998.40 5958592. 56 365115 .35 0.00 180. 00 18100. 00 90. 34 331 .06 7533 .88 7478. 08 962 .21 -13046.78 5958680. 84 365068 .39 0.00 180. 00 18200. 00 90. 34 331 .06 7533. 28 7477. 48 1049 .72 -13095.17 5958769. 11 365021 .43 0.00 180. 00 18300. 00 90. 34 331 .06 7532. 68 7476. 88 1137 .23 -13143.56 5958857. 39 364974 .47 0.00 180. 00 18400. 00 90. 34 331 .06 7532. 08 7476. 28 1224 .74 -13191.95 5958945. 67 364927 .51 0.00 180. 00 18500. 00 90. 34 331 .06 7531. 48 7475. 68 1312 .25 -13240.34 5959033. 94 364880 .55 0.00 180. 00 18600. 00 90. 34 331 .06 7530. 89 7475. 09 1399 .77 -13288.73 5959122. 22 364833 .59 0.00 180. 00 18700. 00 90. 34 331 .06 7530. 29 7474. 49 1487 .28 -13337.12 5959210. 50 364786 .63 0.00 180. 00 ORIGINA!_ ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Ina Date: 11/1/2007 Timer . 32:36:30 Page: 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: CD4-05 (36. 3+19.5) 55.8 Well: Plan: CD4-05 Section ( VS) Referenc e: Well (O. OON,O.OOE,283:96Azi) Wellpath: Plan: CD4-05 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comme t ft deg deg ft ft ft ft ft ft deg/100ft deg' 18800.00 90.34 331.06 7529 .69 7473. 89 1574 .79 -13385.50 5959298 .78 364739 .67 0.00 180 .00 18900.00 90.34 331.06 7529 .09 7473. 29 1662 .30 -13433.89 5959387. 05 364692 .71 0.00 180. 00 19000.00 90.34 331.06 7528 .49 7472. 69 1749 .81 -13482.28 5959475. 33 364645 .76 0.00 180. 00 19100.00 90.34 331.06 7527 .89 7472. 09 1837 .32 -13530.67 5959563. 61 364598 .80 0.00 180. 00 19200.00 90.34 331.06 7527 .29 7471. 49 1924 .83 -13579.06 5959651. 88 364551 .84 0.00 180. 00 19300.00 90.34 331.06 7526 .70 7470 .90 2012 .34 -13627.45 5959740 .16 364504 .88 0.00 180. 00 19400.00 90.34 331.06 7526 .10 7470 .30 2099 .85 -13675.83 5959828 .44 364457 .92 0.00 180. 00 19500.00 90.34 331.06 7525 .50 7469 .70 2187 .37 -13724.22 5959916 .71 364410 .96 0.00 180. 00 19600.00 90.34 331.06 7524 .90 7469 .10 2274 .88 -13772.61 5960004 .99 364364 .00 0.00 180. 00 19700.00 90.34 331.06 7524 .30 7468 .50 2362 .39 -13821.00 5960093 .27 364317 .04 0.00 180. 00 19800.00 90.34 331.06 7523 .70 7467. 90 2449 .90 -13869.39 5960181 .55 364270 .08 0.00 180. 00 19900.00 90.34 331.06 7523 .10 7467. 30 2537 .41 -13917.78 5960269 .82 364223 .12 0.00 180. 00 20000.00 90.34 331.06 7522 .51 7466. 71 2624 .92 -13966.16 5960358 .10 364176 .17 0.00 180. 00 20100.00 90.34 331.06 7521 .91 7466. 11 2712 .43 -14014.55 5960446 .38 364129 .21 0.00 180. 00 20200.00 90.34 331.06 7521 .31 7465. 51 2799 .94 -14062.94 5960534. 65 364082 .25 0.00 180. 00 20300.00 90.34 331.06 7520 .71 7464. 91 2887 .45 -14111.33 5960622. 93 364035 .29 0.00 180. 00 20400.00 90.34 331.06 7520 .11 7464. 31 2974 .97 -14159.72 5960711. 21 363988 .33 0.00 180. 00 20500.00 90.34 331.06 7519 .51 7463. 71 3062 .48 -14208.11 5960799. 48 363941 .37 0.00 180. 00 20600.00 90.34 331.06 7518 .91 7463. 11 3149 .99 -14256.50 5960887. 76 363894 .41 0.00 180. 00 20700.00 90.34 331.06 7518 .32 7462. 52 3237 .50 -14304.88 5960976. 04 363847 .45 0.00 180. 00 20800.00 90.34 331.06 7517 .72 7461. 92 3325 .01 -14353.27 5961064. 32 363800 .49 0.00 180. 00 20900.00 90.34 331.06 7517 .12 7461. 32 3412 .52 -14401.66 5961152. 59 363753 .53 0.00 180. 00 21000.00 90.34 331.06 7516 .52 7460. 72 3500 .03 -14450.05 5961240. 87 363706 .57 0.00 180. 00 21100.00 90.34 331.06 7515 .92 7460. 12 3587 .54 -14498.44 5961329. 15 363659 .62 0.00 180. 00 21120.39 90.34 331.06 7515 .80 .7460. 00 3605 .39 -14508.31 5961347. 15 363650 .04 0.00 180. 00 CD4-05wp01 To Targets Map Map <____ Latitude __-> <__ Longitnde -> Name Description TVD +NI-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD4-05wp01 Toe 1/4 mile 7515.80 3605.39 -14508.31 5961347.15 363650.04 70 18 8.089 N 151 6 16.031 W -Circle (Radius: 1320) CD4-05wp01 Toe 7515.80 3605.39 -14508.31 5961347.15 363650.04 70 18 8.089 N 151 6 16.031 W CD4-05wp02 Hee l 7530.80 144.62 -12658.83 5957857.13 365443.00 70 17 34.086 N 151 5 21.938 W CD4-05wp01 Hee l 1/4 mile 7550.80 -1511.86 -11678.78 5956185.12 366395.99 70 17 17.810 N 151 4 53.302 W -Circle (Radius: 1320) CD4-05wp01 Hee l 7550.80 -1511.86 -11678.78 5956185.12 366395.99 70 17 17.810 N 151 4 53.302 W Annotation MD TVD ft ft 400.00 400.00 KOP Casing Points MD TVD Diameter Hole Size Name ft ft in in 2700.84 2400.00 9.625 12 .250 9 5/8" x 12 1 /4" 15272.86 7550.80 7.000 8 .750 7" x 8 3/4" 21120.39 7515.80 4.500 6 .125 4 1/2" x 6 1/8" ORIGINAL ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska InC. Date: 11/1!2007 Time: 12:36:30 Page: 7 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-05, True North Site: Nanuq CD4 Vertical (TVD) Reference: Plan: CD4-05 (36.3+19: 5) 55.8 Well: Plan: CD4-05 Section (VS) Reference: Well (O.OON,O.OOE,283.96Azi) Wellpatb: Plan: CD4-05 Survey Calculation Method: Minimum Curvature Db: OraGe Formations MD TVD Formations Litbology Dip Angle Dip Direction ft ft deg deg' 2707.84 2403.80 C-30 0.00 0.00 3519.80 2772.80 C-20 0.00 0.00 5958.82 3847.80 K-3 0.00 0.00 6462.51 4069.80 K-3 Basal 0.00 0.00 6544.19 4105.80 K-2 0.00 0.00 6786.96 4212.80 K-2 Basal 0.00 0.00 10287.80 5755.80 Albian 97 0.00 0.00 11188.54 6152.80 Albian 96 0.00 0.00 12797.16 6861.80 HRZ 0.00 0.00 13314.62 7087.80 HRZ Base 0.00 0.00 13418.14 7130.80 K-1 0.00 0.00 13532.54 7176.80 Kuparuk 0.00 0.00 13633.23 7215.80 LCU/Miluveach 0.00 0.00 14215.80 7406.80 Miluveach A 0.00 0.00 14465.91 7466.80 Alpine D 0.00 0.00 14561.87 7485.80 UJU 0.00 0.00 15102.74 7547.80 Alpine A Reservoir 0.00 0.00 ORIGINAL ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inca Date: 1 0/2 9120 07 Time: 11:52:13 Pagc: 1 ` Field: Colville River Unit I Reference Siteo Nanuq CD4 Co-ordinate(NE) Reference: Well: Pla n: CD4-05, True North Reference We1L Plan: GD4-05 Vertical (TVD) Refere nce: Plan: CD4-05 (36.3+ 19.5).55.8 Reference Wellpath Plan: CD4-05 Dbf > Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-05wp01 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 21120.39 ft Scan Method: Trav Cylinder No rth Maximum Radius: 2308.41 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2700.84 2400.00 10.750 13.500 10 3/4" x 13 1/2" 15272.86 7550.80 7.625 9.875 7 5/8" x 9 7/8" 21120.39 7515.80 4.500 6.750 4 1/2" x 6 3/4" Plan: CD4-05wp01 Date C omposed: 9/27/2007 Alpine A Version: 3 Principal: Yes Tied-to: From Well Ref. Point Summary <_________ew_____ Offset Wellpath ---------------> Reference -0ffset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Aistance Area De~~iation Warning ft ft ft ft ft --- Alpine CD2 •CD2-56 CD2-56L1 V10 Out of range Nanuq CD4 CD4-07 CD4-07 V1 349.75 350.00 41.44 6.60 34.84 Pass: Major Risk Nanuq CD4 CD4-16 CD4-16 V2 299.39 300.00 221.03 6.21 214.82 Pass: Major Risk Nanuq CD4 CD4-17 CD4-17 V13 5332.49 4950.00 202.83 139.65 63.19 Pass: Major Risk Nanuq CD4 CD4-208 CD4-208 V7 926.45 925.00 35.93 13.80 22.13 Pass: Major Risk Nanuq CD4 CD4-208 CD4-208P61 V6 926.45 925.00 35.93 13.80 22.13 Pass: Major Risk Nanuq CD4 CD4-209 CD4-209 V4 1256.15 1250.00 30.31 17.52 12.78 Pass: Major Risk Nanuq CD4 CD4-210 CD4-210 V3 854.12 850.00 87.51 12.76 74.75 Pass: Major Risk Nanuq CD4 CD4-211 CD4-211 V2 2391.23 2350.00 110.93 43.92 67.02 Pass: Major Risk Nanuq CD4 CD4-213 CD4-213 V4 832.34 825.00 154.60 12.81 141.79 Pass: Major Risk Nanuq CD4 CD4-214 CD4-214 V3 298.87 300.00 181.25 6.13 175.12 Pass: Major Risk Nanuq CD4 CD4-215 CD4-215 V4 349.23 350.00 203.29 7.43 195.86 Pass: Major Risk Nanuq CD4 CD4-302 CD4-302 V3 374.69 375.00 62.43 7.69 54.75 Pass: Major Risk Nanuq CD4 CD4-306 CD4-306 V1 549.74 550.00 15.74 8.55 7.19 Pass: Major Risk Nanuq CD4 CD4-318 CD4-318 V6 350.88 350.00 261.89 7.45 254.44 Pass: Major Risk Nanuq CD4 CD4-318 CD4-318A V5 14554.83 19125.00 270.57 156.60 113.96 Pass: Major Risk Nanuq CD4 CD4-318 CD4-318P61 V3 350.88 350.00 261.89 7.50 254.39 Pass: Major Risk Nanuq CD4 CD4-319 CD4-319 V5 300.25 300.00 281.79 6.11 275.68 Pass: Major Risk Nanuq CD4 CD4-320 CD4-320 V7 1451.54 1425.00 278.74 22.29 256.44 Pass: Major Risk Nanuq CD4 CD4-320 CD4-320P61 V4 1451.54 1425.00 278.74 22.29 256.44 Pass: Major Risk Nanuq CD4 CD4-321 CD4-321 V16 299.89 300.00 320.66 6.12 314.54 Pass: Major Risk Nanuq CD4 CD4-322 CD4-322 V8 275.06 275.00 341.17 5.17 335.99 Pass: Major Risk Nanuq CD4 Nanuq 3 Nanuq 3 V1 3916.75 3425.00 270.10 132.94 137.16 Pass: Major Risk Nanuq CD4 Nanuq 5 Nanuq 5 V1 880.81 875.00 117.13 13.91 103.22 Pass: Major Risk Nanuq CD4 Nanuq 5 Plan: CD4-212 VO Plan: 880.81 875.00 117.13 13.90 103.23 Pass: Major Risk Nanuq CD4 Plan: CD4-301 Plan: CD4-301 V4 Plan: 400.49 400.00 80.55 8.40 72.15 Pass: Major Risk Nanuq CD4 Plan: CD4-301 Plan: CD4-301 ST1 V1 PI 400.49 400.00 80.55 8.40 72.15 Pass: Major Risk Nanuq CD4 Plan: CD4-303 Plan: CD4-303 V3 Plan: 449.40 450.00 40.52 9.40 31.11 Pass: Major Risk Nanuq CD4 Plan: CD4-303 Plan: CD4-303ST1 V3 PI 449.40 450.00 40.52 9.40 31.11 Pass: Major Risk Nanuq CD4 Rig: CD4-304 Plan: CD4-304 V4 Plan: 474.59 475.00 20.71 9.79 10.92 Pass: Major Risk Nanuq CD4 Rig: CD4-304 Plan: CD4-304ST1 V6 PI 474.59 475.00 20.71 9.79 10.92 Pass: Major Risk Nanuq CD4 Rig: CD4-304 Rig: CD4-304 V13 474.57 475.00 15.10 8.71 6.38 Pass: Major Risk Nanuq CD4 Rig: CD4-304 Rig: CD4-304ST1 VO 474.57 475.00 15.10 8.60 6.49 Pass: Major Risk Plan: Alpine West CDPrelim: AW-4C Prelim: AW-4C VO Plan: Out of range SRAM ORIGINAL U Q -- U Y -- ~.fi ~ ~~ ~ ~~ c7 - _ae~ F u~ aR__ A oS$8=8m3 F- N°q°m v S~S 8 8 Nm T, 0 C7 ~ e_ 3 88oFFa~M. 0. » - : ~ ~~rm-`~ __ z C ~ 3 0o 8€S~ z r - A UU ~ T 99 j n+S.ao=b=aaw ~ ~ C C R R n~rr v, 'a 'a _ _ s~=_~ 0 F ° 000 __ ~ - M s oe n °o •+~~ . a o° r _ 8~~0 ° p o ~, ~€ ~ a. o o -o e~ s o - 6 M~ __N ~, .., n -.,m.., ,~~~x ~ O M '~ A c ~ U 3 ~ 000ooooov-c oooov,o~noooasv-c ,~ ov~o~noN~nro~nouesm-u O F"N3n [~^~^~--~NNM~7f~ ~ `_' (, M ~ O "N' A V I I I I I ~ ~ I ~~ N N ~L ~; ~~ ~ Z ~~ VOl O H O V) ~ 0 0 F .. v L N V'i [~O t~0~f',V~C F ~ C (z, ^~j^ ~--~ N N M Vl ~ y M Z ~ O d iW a ~" 0 D '? o M N , z a Q s .- - ~o ~~:: • ~ ooo~no~noc ~ O~nON~n t~O V ~. (~fV in l~ .--, .--, .--. ,--, N C Q L9. sS-~ ~ ~~ I I ~ I I ~ 0 . ~: .f U ~o ococ ~ N oA ~ ~n ~~ CJ ~ O aqN/~ ^i Q U ~ bA ~X ~~ Q: ~ @ ~~ Q \\~ U M O M ~ O Q M 0. U ~ A ~ U ooooa~oo ~ 0000000oooooV 0000ooooomoo O O O O O O N 7 ~D O~ V'i ~Oh000\~-~~ NN 5, I I C: o e o •'i ~ . ,•,; -. . ~ • ' n ~ ~ ; ~~~ - 4u ~r• . ; . , i p O _ -.r..~ - .. C ~ U ~/- ~.,~ M lalJdll N 7 a 7 c z 7 ~p ~/iii ~ ~ fi ' e ~ ~ o .r ~/i %h7 ~~. r l ~ i ~ _ ~ I/'~ I ~~ 1 A ~~f~~ •,-• ,.. M i~ U ~/ ,,, N N O a ~ 2s t` ° ~ ~ ~ '' A N U D a~BRm ~ 7 s ~ o =8g8~ M y( ~' ~' N ~1 . ( S~vsiuF ___._ 'y' s w=_`dfaf &"`~ _ 3 M O 10l1 O ~.<.. N N O ~ ~ _ N ~ ~r O ~ ~ O ~. ~ O M N N ?~€ 2 E~v~i eFa z 3 tat = 3i 3. t'' ' , U~ U ~ R 1 G I NA ~~~ .,.:;:: : . N ~ z z` n J ° + v < '` ~i ~'= _ ~` E3: ~ ~r~.Gx < - ?E~_? ~ - ~ ~~~ J J Ue~~3 Q O O O Ls~ O O ~ 0 z Y F U r a r w 33 a ~ ~, 00 ~ h~ m CO d 9 9 T C ~ C C ~ d d O a F $ e., t .o A °r E m e 0 0 0 0 0 0 0 ~ • 0 0 0 0 0 0 0 0 0 0 0 0 O OOOO~f~ V1000 00000000000000 O~O~OC`+1~171~0 V~O~O~OOOOOON~~O000 V~ H N ~ l~ .~ ~'Fh'~ti ~ N N M M 7 ~ ~ ~D I~ GO O~ ~-~+ ~ ~ .-~ ~ N N M ~-. L O w ~ M ~ l O ~ ~, r, A U U U ~~00000~0000000 00000000000 ~M~O ~Qdf~0~00000 00000000000 i, N ~~ ~~ O Vi0 Vi0 00000000000 ~~--~.-~NNMM~ ~~O[~OOC~ON~~0000 M ~ i 1 C G p~ G M (,~ ~ ~ N = V N N Q z F .. E^ ~ t Gz7 ~ 4 ~ i y a z ^sa p E- a J ,~ a ~ 0 M~ V O o ~`M°N z o Q ~~ ~o~ ~w o~~ R~~ a~~ ~ M N ~ ~ 0 ORIGINAL O N U ConocoPhillips Alaska MALLIBURTON PLAN DETAILS CD4-OSwp01 Alpine A Version 3 9/27/2007 Quarter Mile (1320 feet) radius plot w 0 0 0 (V 7O C O West(-)/Fast(+) [2000ft/in] -22000 -20000 -18000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 Op.M.r 9M W: Yhk rIY SM1pc. locex.n Comment 0 /V V I L_ `~ a y ~ U O 0) J N 7 0 T Con.coPFilip~ Aloaka Inc. Gdd Conection: GWNN. bv.r UnM MagnNic Declination: C DY.OSwp01 qp: YN/A DegMy px Original VS Plane: x: ne0,e.n Y: s131W).1l n View VS Plane: It POOL: CD4-05wp01 Plan: 7300' to 7494.08' TVDss CD417: 7300' to 7487.65' TVDss CD4-07: 7300' to 7429.04' TVDss CD2-56L1: 7300' to 7406.47' TVDss -0.93 lob No: NN/A ]].30 AEE NO: YN/A ° AM No: NN/A 100 11 SYN.nt 13VD1 I.f.nnc.: Mwn Sea LsvN 283.96 re<.nl w.E: %.n: cDN-os 283.96 Ece xNgbr. u.e0 n UNI SYN.m: A% b..d / iPi S.cxon IVSI IN.nnc.: YIELL Plan Vlew - CD2-S6L1 -~ -- ~~ - C D4-07 5972000 5971000 5970000 5969000 5968000 5967000 s966oo0 5965000 s96aooo 5963000 1962000 1961000 1960000 1959000 1958000 1957000 1956000 1955000 1954000 6800 7800 ch c7 M c7 th M M M (`~ M M N N M M M th 07 (7 ch M N N N N N N N N N N N N N N N N N N N N N O O O O O O O O O O O O O O O O O O O O O N c7 V h d n N P O N (7 V ~ ~ N P O N ~- ~ ~ '- ~- ~ N N N Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (C D4-05 toolbox.xls) 11/1/2007 3:20 PM • • Closest in POOL { /' Closest Approach: Reference Well: CD4-05wp01 Plan Offset Well: CD4-1 7 3-D ctr- Coords. - Coords. - ctr ASP ASP Distant - Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS -: Depth Angle Azi. TVD E(+)/W(_ (283.96°) Comments Depth Angle Azi. TVD E(+)/W(_ (283.96°) Comments POOL Min POOL Min Distance (1853.27 Distance (7853.27 ft) in POOL (7400 - ft) in POOL (7400 - 8537 TVDss) to 8537 TVDss) to CD4-17 (6800 - CD4-05wp01 Plan 18b3.2 1443 77.4 304.5 7404.2 595555 366935. 10284.2 8000 TVDss) 12761 79.62 317.5 7386.7 595678 368324. 9046. (6800-8000 Closest Approach: Reference Well: CD4-05wp01 Plan Offset Well: CD2-5 6L1 3-D ctr- Coords. - Coords. - ctr ASP ASP Distant r .... Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS - Depth Angle Azi. TVD E(+)/W(_ (283.96°) Comments Depth Angle Azi. TVD E(+)/W(_ (283.96°) Comments POOL Min POOL Min Distance (2077.53 Distance (2077.53 ft) in POOL (7400 - ft) in POOL (7400 - 8500 TVDss) to 8500 TVDss) to CD2-56L1 (7300 - CD4-OSwp01 Plan 2077.6 2112 90. 331 7459.3 596133 363644. 14949.5 7600 TVDss) 1955 84.22 151. 7406.46 596267 365226. 13768.2 (7300-7600 Closest Approach: Reference Well: CD4-05wp01 Plan Offset Well: CD4-07 3-D ctr- Coords.- Coords.- ctr ASP ASP Distance Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Depth Angle Azi. TVD E(+)/W(_ (283.96°) Comments Depth Angle Azi. TVD E(+)/W(- (283.96°) Comments POOL Min POOL Min Distance (612.87 ft Distance (612.87 ft in POOL (7400 - in POOL (7400 - 8537TVDss) to 5537 TVDss) to CD4-07 (7370 - CD4-OSwp01 Plan 612.8 ti0) 2112 90. 331 7459.3 596133 363644. 14949.5 7500 TVDss) 1742 76.61 291.1 7380.1 596190 363859. 14853.3 (7370-7500 PoolSummaryl.xls 11/1/2007 2:55 PM • L Pool Summary • Integrity: NoN: The Closest Approach, reported here, rs not necessanN The Closest Approach. The octual clo<esl approach might occur between survey stations. Create Chic report again with smaller interpolated inteval surveys for greater accuracy. eao o ,ao Imo mao ., so 6000 a ON v.t 00 5000 w30W 0 BO •e e 3000 !.5000 c -60 ~zaoo 6sooo 4 ^0 tmo 7000 ', -zo ., o eooa ~ B 3 R ~ s E= 3 v ¢ fi Q~ z 3 fZ SNp $ S Q~ _ _ _ rya w . ~ ~ yr~H Closed A .,, ~ , rr,e ~ ~~~ roach: _ Refere nee Well: C D4~OSw 1 Plon Off:cl Wnll: CD4~07 3-D c rvc r Honzon a - ~. r..,.., rvwx nc~ -.n., -:: .~: Mex. mot ~• - " ~- GetonCe. D51anCe "."-~ nn.ix ,],q. ~ '~ Commrrc. p.qn nnok -- ~ Cammrnrs -~ ~~ anel[lz errrlin POU Ir.00 ._rslro a0aorlrrro.rsao _ .celerz.er Rlnao001r.00 Caa05.pOr Plan l7]T0~ asst ra 612.87 607.73 zazino o..l Noh: The Closest Approach, reported here, s not necessarily The Closest approach. The oclual closest approach might occur between survey stations. Create this report again with interpolated interval surveys for greater accuracy. 2soa yyzoos r ~ itsoo o - tooa ~ 500 o 8 8 $ Q~ ~ ~ ~_ o o soo atooo E ~tsoa x1000 xoa : •F n _ s _ 7n so ao ~-30 '~-`~ -,o ~-a0 0, , t o I S ~ 'cam d E R° In the graahs above. the X-axe n t he Reference Well CDZASw •'. Plan and 1!re ^ lofletl Ilne'senes e the ~Hse' Well 'CJd~l7` Closest ach: Reference Well: C D6-OSw Ol Plan OMBN Well: CD<~ 17 -D C'r-C Drsta^ce. Han2rin a Grsiarice )!b:o~ D~"PrF r.-e Meas o.pn Mcl nrrPe .,_.,_ ~.., Meas. oapn ~ .~. 1953.27 Idb3.l9 75a w.w 0o 77as awx BY.~.58 ]669Y..91 n aeelevzl xlln Pea, 17.ao.e~i Tvo.groaw.n lceo0. soon TVasn ]z a7stoo 7962 sssc7n.80 xsJia>. ,. aroefflSJ_2rx1n P00. p.oo. esJ~*v~slromam..sl Pte, IBe00~w0orwssl Summary: Integrity: Nele: The Closest Approach, reported here, ¢ not necessarily the Closest Approach. the actual closest approach might occur between survey slaflons. Create thce report again with smaller interpolated interval surveys for greater accuracy. eooc a -too 70W ~ moo -so som ?zaoo ~~ ~sooc {. 70 F3000 60 %,4000 50 ,~a0:1 :, 000 ~ A °¢3000 ~¢ .._._ 1000 a"'~f.:Sz'X'.: ~. =.:::.}~ n. ~i+.'-.'.'a:+.S. ]000 . 0 o eooa o $ $ se ~ R` 8 ~ d ae _ ~ Y 8 8 N _ n :~ _ _ _ _ _ _ _ In the graehs above. the x-axe n the Reference well CD~-05w _ l Plan' ant I:^e -lotted Ime'xexes rs the Offset well CD2-56'7 Closest ach: Reference Well: C DO~OSw 1 Plan OMsef Well: CD7.56L7 .-U G'r-~t~ CiSta'+C<, HoriZanlal Disler re ) •b:~a Crrt-r-n pxrx Rr~gle ,,._ _~-~_ - .. - _ pqn ar~yi. ~. __ .. - .. 07753 076.% -_ -~ pooo :~ lnz ]e.a .+ awelzOnvx7nP0al t7.oo.B500 vpxlro Ca2~5[Ll li]00- OTVO.:1 ea •+. zs.e. c siMe9 se s maI$tn$]rtIn POOL pwe l00 rvasslw Wa05.p01Plat (hm-rwetvossl OR161NA ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~-"~u ~~ ~ ~ S PTD# ~~ ? ~`S~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- -_, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. 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 SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals 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 dame of well) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Com»any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13!2007 ~ ~ ^^ , ~ ~ ~ ~ ~ ~ ~ ~ o O) ~ ~ d N ~ ~ ~ ~ ~ ~ ~ ~ Q a; >, , N. 3 m O - : ~ Q ~ , N , , ~ g ~ 3. v, d N' ~ N' N n, p a. w N p J (6' f6' ~~ O , ~~ ~ Qi ~ ~ ~ ~ ~, Q ~. 0 O' ~ a~' a ~ y Y, Q ui' a~ d ~ E O ~, °O. o. ~, c. o o ~ ~ L ~ , 3 ~ p, a. ~ a o ~ a ~ ~ o' Q ~ ~, ~ ~ M' •3~ o' ~ ~~ ~ ~ ~ ~ ~ i, ~ ~ ~ ~ o N U. ~ ~ ~: ~ a. ~. ~ ~, ~ ~ , a~ I n ai m; .~~ ~~ N ~ : ~, an J' U. M. ~ Q. ~ 3, o. ~ ~ cv O ~ Q' 4, E SC, ~~ N. N. ~ ~ ~ ~ ~ ~ ~ ~ ~ a L• d ~ ~ N ~ ~ ~~ '~ N ~ ~ . ~~ m E. ~ w, U O. ~ ' ~ d N ~' a' rn ~ t ~ p Z a~ y o ~, ~ Q~ , ~ 4 ~, ~, ~, ~ a a 3, m ~ o , o c' a ~~ y~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ •Q c, ~~ w' ~ a~~ 4 ~ ~ -o' o' ~ ~, ~ o' a~' ~ ~ Z ~ .5, ao 00 a~~i ~ 3 ~, y i o. o. ~ o, o. c, ~ rn N. pp o. W. o ~ _~ ~ n . ~~ ~ o c. o ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~, a~~ °, ~ ~ 4 ~ ~ ~, J. C. ~~ N, w. '~, ~ ~ ~ ~ ~ O a. ~ Z, ~-'~ 4 , M~ ~ a ~ ~ ~ ~ E O I O ~ ~ y, W O: o, , ~ U N, O. Z o N ~, .c. .° ~ ~ ~ I C. _m. a a. Z. ° ~ ~ 4 N. a. y, ~ ~ N. a. , - C. U ~ I ~ U ~ ~ ~ N O E~ , ' ~ ~ O. c. N . ~ O ~ p. Q -~ N 'U, ~~ ~~ Q p ~ ~ ~ ~ ~ O: . ~ ins N o ~ ~ ~~ ,~~ ~ O N• ~ ~ ~ , ~ N ~ , pp . ~ . C' ~ C. X. ~ ~ ~ ~ ~ ~ ~ ~ w' ~ ~ ~ N m o. as ~ ~ ~ ~ o, 'a ?, o o i ~ Z ' ui o `~~ ~~ ~~ c o' aai' E' ~ ~ ~ ~ ~ Q ~ ~ ~ ~, ~ a ~ ~, ~~ ~ ~ ~~ ~ ~ ~~ ~, , o u°'i, ~ ~ o o W' a~' ~ O ~ g. ~, 'o a~ cx ~ c. ~, N N. ~ ~ ] ~ o. ~ o ~ a ~ N ~, ~. ~. a. t ~ ~, ~ 4 0 i a N~ Q N ~' z' N, N~ N N, N~ N~ N~ N N N N, N N N r; r; r' >- >-' ~' ~' N N~ N N r' ~' N N r' N N r N N r' ~ Q Q, Q z' z z' N, N~ N Q N O >-' z' r' z O, z N N, >- N~ N, r ~ N, N N~ Q N Q N N z' > ' ' ' ' N N, N, N N, N ' ' ~ O Q, ` N N, N. ~ N, Q, Q ' Q ' 4 ~ , . z r >- - r r r z z r >- z z z . ~ a i ; ~ 1 , ~' T , m ° ~ ~ ~ - C E o , ~, O `o ~" i o. a~ o ~ ~ 3. ~ ' ; 3. ii o '~ O. ~, co C ~ C• U - 'i ~, O (0, d ~ ~ ~ 7. ~ ~ ~~ ~ ~ ~~ O. fl. ~ ~~ ~.r C' ~ a, O. Q' ~ ~ ~, ~ ~ N~ ~ y. ~~ ~ ~ f0, ~ ~. ~ C~ ~ O~ .C~ ~ ~ ~ ~~ ~ 7 N N~ v N w 0 t/ ~ ~ U/ W ( ~ ~ Op 3~ •C ~ c O. ~ , 3 p. ~, ~ OM. ~ ~~ U, N. N: Q ~ . ~ ~~ O. Q. ~ 30~, ~. j a. N. ~ N. ~ ~ U i ' L ' ~- rn U1 ~, ~ N' T m ~, ~ o, 3~ ~ -o' °' c m o' =~ ,tf ~; N, ~, ~a` ~ M ~ ~' Q' y' N ~' ` i w z -a o c. .a o, ~ ,c a N: o. ~' a c. ~, m. O. o, rn ° ~ t. c. ~ ° c. oi o. .. J ~ ~ ~ E~ E~ a ~ .C, C ' E ' r ~~ _ N, O M' ~' C C N, 3' U. H y, c O ~tS ' C' ~, ~ C. N. ~.•; ~ N Q. N, L N' ' d C C ~ ~ O O a 7 . ~ O a, U• a O~ N C ' Q' O ~ O. , U• d N OQ U ~~ N ~ O _ O Qj~ d~ ~ Q 3: p N N >; ~ ~ ' ~ J ~ ~ ~ ~ C V p, p ' ; C, ~ ~ p N ' O O $' ~ ~ ~ C. o' ~ o' N• . (Q. C, N N. ' ' Q. N. f6' (6 y,~ a: > O, ~' O. O O, Y O, N N ,N O g °, , ~ °; ~ ~ ~; a ~ o ~, O' a •~ m a c' m ~ o, N .Y m, o c °- o ,~ ~ ~ 3 w o, ~ 3' ~' o' a~' ~ ~ m' 3 v o: .S ~ U ~ N. C. ~~ N~ y, f6. d {y r. ~, t Q a ~ N' . ~ m, a. ~~ . N. N' ~, ~~ C N' ~, M ~: N. U' ~ ~ N~ ~ y ~~ O~ N' ' N O' W O o d a -o. c ~ ~; ~' ~' "°' 3 3 ~ ~ ,~, .. o. :a ~, 'v, .. 03 0 ~ ~ oo' N. n 'a ~ m o, 3, (6 o r ~ ~.-, U O J a a, ~~ N N O O' N. ' ~~ ~, O~ V. d ~~ O, ~~ O (6~ ~~ O~ c' O U O' N~ O, O. C' Y ~ `O, O' i N• a~ ~~ ~' (6~ ~' L °~ p' l ~' O- 4-.' N _~ J N d : d . a N. ~ ~ d d ~ T ~ N T N d C' . • U ~ N O• d ~ ~ . - ~ ~ ~ N ~ ~ ~ C U ~3 N y . O ~ ~ ~ t , (0, ~ ~ ~ ' O~ O' . ~~ Or . ~ d N L' ~ , . C. N, . d D1 N (O _ N ~ ~ ~ , O O~ T . ~ - . a• 2 I . N , p . ~~ p . d a d a~ O ~ ~, ~ f6 C ~ c, d d m. $ ~'~ . m ar N . ~ ~, o ~3 ~, rn ~ ~ ~ 6 s a`r c. x; c '~ a: .~ ° o ~ ~ ~~ ~ a _ ° ° +- c• i ° ~ ~ ,_ a o ~ ~ _ o~ ii U ~ a~ ~ -, a. a. a~ v. ~ c' .o~ o' .Q~ ~ a. ~, ~ ~ C ~~ a~: a~~ •N' >~ ° .~ ~' ~ ~ ~ m 3~ N. o' .~ ~ ~ N~ ~ ~' m' c' ~' O ~, ~~ ~, 4?~ ~~ d~ N. -o' O. L. C. m C, m ~ E N. m 4 3. ~ °~~ ~ ~ (6, a a ~° ~° v o` °~ '~ °Y o ~ ~, O = = ° a O. '~ ~~ ~6~ ~~ ~. ~ c, m N. c. w m ~~ ~~ ~" z ~, ~a~ m. m, ~~ ~ 3' ~' ' . ' v ` ~' . a' >` , , , - a' : . ~, ~' ~' __ E' ~ ~ ' v` ' ` ~ ~ O c v v v o o, O o, o' a~~ ~~ o m ~ v a ~ o. c: I ~, a~, o, o v > >' - 3' rn i6, -o. m. r~ ui, rn a ~ 3 c o ~ N' m' „~ ~ v a. ~ .. U o, ~, -_ -_, -_ v. m; °~ ~ ; ~~ ~ d - ~ o v > ~ a m~ ~, ~, ~~ .c ° o. ° w, ~~ ~ ~~ ~' a w. a o Y` ~ ~ u E' ° ° o~ ; ~~ E m, °,i ~. Y >, a~~~ a`6i, a °r °r a~' ~' c ~, 'a a ~ ~; ~; ~; ~' U ~; O ~ a a~ a' O : a~ a m U ~, ~' ~ - '' o a' z' ' o ~~ ~' ~' ' ~' ' m' ' ~ ~6 a, ~ O; ~ w ' o O, ~, ~' o ~'' ~' a~, u i ~ o, af°i o; D U c , J, , , , ; ; , Q , , U; cn; U , U' U , U , Q, -, Q, -, p , m, m, U, , a p ~ U U W Q ~, _ ~ O r N M 'tt ~ CO I~ eD O) O r N M 'c}' t0 (O h a0 O _ O M M M O r N M V ~ CO I~ OO O __~ r r ___-___ r -._ r ._ r ___. r r r -___ r r N N _____ _____.____._.._ N .-_ N __ _ N _- N N N N N M M _ ___.__ M M_ M M M U ~ w ~ 0 N ~ 0 y ~ 0 +O+ N .. ~ U C ~~ w p C rn N p~ r ~ p~ r o •N ff~///~~, ~ ~ ` ' r ` O C ~ (~ ~ ~ N J ~k c \ / I ~ O O Q p ~ G. ~ ~" G p U ~~ a a n w a~ j ~ a~ Well History File APPENDIX Inforr7~ation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well 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. y s CD4-05.tapx Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 28 15:35:50 2008 Reel Header Service name .............LISTPE Date . ...................08/02/28 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/02/28 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 MWD/MAD LOGS WELL NAME: CD4-05 API NUMBER: 501032055800 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 28-FEB-08 ]OB DATA MWD RUN 2 MWD RUN 3 ]OB NUMBER: Mw-000547425 MW-000547425 LOGGING ENGINEER: J. BOBBITT E. QUAM OPERATOR WITNESS: D. BURLEY D. LUTRICK SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 04E FNL: 2903 FSL: FEL: 148 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 56.08 GROUND LEVEL: 19.50 WELL CASING RECORD Page 1 s 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: CD4-05.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 2674.0 6.125 7.000 15140.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), AT BIT GAMMA RAY (ABG), AND GEO-PILOT ROTARY STEERABLE (GP). 5. MWD RUN 300 WAS DIRECTIONAL WITH GAMMA MODULE (GM), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AZMUTHAL DEEP RESISTIVITY (ADR), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), AND GEO-PILOT ROTARY STEERABLE. 6. MWD DATA ARE CONSIDERED PDC PER THE DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT THE CONOCOPHILLIPS ALASKA, INC. VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1 - 3 REPRESENTS WELL CD4-05 WITH API #: 50-103-20558-00. THIS WELL REACHED A TOTAL DEPTH OF 21,142' MD, 7,490' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS AH1P = SMOOTHED COMPENSATED 2 MHZ PHASE RESISTIVITY (16 INCH SPACING). AH2P = SMOOTHED COMPENSATED 2 MHZ PHASE RESISTIVITY (32 INCH SPACING). AM3P = SMOOTHED COMPENSATED 500 kHZ PHASE RESISTIVITY (48 INCH SPACING). ADXT = ADR-REFERENCED FORMATION EXPOSURE TIME. Page 2 CD4-05.tapx ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX AM3P AH2P AH1P ADXT 1 clipped curves; all bit runs merged. .5000 START DEPTH 2644.0 2674.0 2675.0 2675.0 2675.0 2675.0 2675.0 15140.0 15140.0 15140.0 15140.0 STOP DEPTH 21094.5 21142.0 15101.5 15101.5 15101.5 15101.5 15101.5 21073.0 21073.0 21073.0 21073.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2644.0 15155.0 3 15155.0 21142.0 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 ......................-999.25 Page 3 CD4-05.tapx Depth Units. .. .. ..... Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 AH1P MWD OHMM 4 1 68 32 9 AH2P MWD OHMM 4 1 68 36 10 AM3P MWD OHMM 4 1 68 40 11 ADXT MWD HR 4 1 68 44 12 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2644 21142 11893 36997 2644 21142 ROP MWD FPH 0.15 308.31 150.669 36937 2674 21142 GR MWD API 36.58 410.23 97.8857 36902 2644 21094.5 RPX MWD OHMM 1.63 134.78 6.5935 24854 2675 15101.5 RPS MWD OHMM 0.9 148.95 6.64397 24854 2675 15101.5 RPM MWD OHMM 0.61 242.02 6.99532 24854 2675 15101.5 RPD MWD OHMM 0.68 2000 8.17423 24854 2675 15101.5 FET MWD HR 0.22 70.39 0.579004 24854 2675 15101.5 AH1P MWD OHMM 0.07 3809.63 19.2209 11867 15140 21073 AH2P MWD OHMM 0.26 5000 25.0692 11867 15140 21073 AM3P MWD OHMM 0.26 1821.6 21.7233 11867 15140 21073 ADXT MWD HR 0.57 149.88 1.45384 11867 15140 21073 First Reading For Entire File..........2644 Last Reading For Entire File...........21142 File Trailer Service name... .......sTSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/28 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.......08/02/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER Page 4 i 1 CD4-05.tapx 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 2644.0 15114.5 ROP 2674.0 15155.0 FET 2675.0 15101.5 RPD 2675.0 15101.5 RPM 2675.0 15101.5 RPS 2675.0 15101.5 RPX 2675.0 15101.5 LOG HEADER DATA DATE LOGGED: 23-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15155.0 TOP LOG INTERVAL (FT): 2644.0 BOTTOM LOG INTERVAL (FT): 15155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 58.8 MAXIMUM ANGLE: 87.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 9 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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: Page 5 8.750 2674.0 Polymer 9.60 45.0 9.7 350 .0 6.900 70.0 3.358 151.0 9.900 70.0 3.600 70.0 $ CD4-05.tapx 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 ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 C Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MwD020 API 4 1 68 8 3 RPx MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2644 15155 8899.5 25023 2644 15155 ROP MWD020 FPH 0.15 308.31 180.003 24963 2674 15155 GR MwD020 API 38.62 410.23 116.235 24942 2644 15114.5 RPx MWD020 OHMM 1.63 134.78 6.5935 24854 2675 15101.5 RPS MWD020 OHMM 0.9 148.95 6.64397 24854 2675 15101.5 RPM MWD020 OHMM 0.61 242.02 6.99532 24854 2675 15101.5 RPD MWD020 OHMM 0.68 2000 8.17423 24854 2675 15101.5 FET MWD020 HR 0.22 70.39 0.579004 24854 2675 15101.5 First Reading For Entire File..........2644 Last Reading For Entire File...........15155 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/28 Maximum Physical Record..65535 File Type ................L0 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.......08/02/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Page 6 CD4-05.tapx 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 GR 15115.0 21094.5 AM3P 15140.0 21073.0 AH2P 15140.0 21073.0 AH1P 15140.0 21073.0 ADXT 15140.0 21073.0 ROP 15155.5 21142.0 LOG HEADER DATA DATE LOGGED: 03-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 21142.0 TOP LOG INTERVAL (FT): 15155.0 BOTTOM LOG INTERVAL (FT): 21142.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.3 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 93091 GM DUAL GAMMA RAY 93091 $DR Azimuthal Deep Resis 10815496 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 15140.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Fresh water Gel 9.60 45.0 9.0 65000 .0 .100 70.0 .042 176.0 .170 70.0 .180 70.0 Page 7 i +~ CD4-05.tapx 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 ......................-999.25 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 AH1P MWD030 OHMM 4 1 68 12 4 AH2P MwD030 OHMM 4 1 68 16 5 AM3P MWD030 OHMM 4 1 68 20 6 ADxT MwD030 HR 4 1 68 24 7 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 15115 21142 18128.5 12055 15115 21142 ROP MwD030 FPH 7.99 207.61 89.5146 11974 15155.5 21142 GR MWD030 API 36.58 117.81 59.6189 11960 15115 21094.5 AH1P MwD030 OHMM 0.07 3809.63 19.2209 11867 15140 21073 AH2P MwD030 OHMM 0.26 5000 25.0692 11867 15140 21073 AM3P MWD030 OHMM 0.26 1821.6 21.7233 11867 15140 21073 ADXT MWD030 HR 0.57 149.88 1.45384 11867 15140 21073 First Reading For Entire File..........15115 Last Reading For Entire File...........21142 File Trailer service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/28 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/28 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Page 8 . ~ CD4-05.tapx Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................08/02/28 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 9
