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Home My WebLink About204-072MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-57 COLVILLE RIV UNIT CD2-57 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 CD2-57 50-103-20492-00-00 204-072-0 W SPT 7000 2040720 3000 1868 1869 1868 1871 0 0 0 0 REQVAR P Austin McLeod 12/28/2025 Two year to MAIP. AIO 18E.005. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-57 Inspection Date: Tubing OA Packer Depth 720 3480 3406 3394IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251229102343 BBL Pumped:3.3 BBL Returned:3.3 Friday, January 16, 2026 Page 1 of 1             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 Cement Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16433'None Casing Collapse Structural Conductor Surface Intermediate Production Open Hole 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 6/5/2025 16432'3790' 4-1/2" 7296' Packer: Baker S-3 Packer SSSV: None Perforation Depth MD (ft): L-80 3355' Open Hole 12642-16432' 12608' 6-1/8" Open Hole: 7448-7296' 7" Perforation Depth TVD (ft): 114' 3391' 7248'12642' 16" 9-5/8" 76' 11996' MD 114' 2378' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Alpine Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380075 204-072 P.O. Box 100360, Anchorage, AK 99510 50-103-20492-00-00 Colville River Field Alpine Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 11932' MD and 7001' TVD N/A Mark Shulman Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Mark.Shulman@conocophillips.com (907) 263-3782 Senior Interventions Engineer CRU CD2-57 7296' 16433' 7296' None N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:41 am, May 16, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.05.15 14:42:45 -08'00' 325-308 DSR-6/3/25A.Dewhurst 28MAY25 VTL 6/4/2025 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.05 08:07:24 -08'00'06/05/25 RBDMS JSB 060525 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 13, 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 CD2- 57 (PTD 204-072) this is a waivered well AIO 18E.005. 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. Mark Shulman Digitally signed by Mark Shulman Date: 2025.05.15 14:41:24 -08'00' CD4-05 Cement Shoe Page 1 Date: May 8, 2025 Subject: CD2-57 OA Cement Shoe Procedure: Prepared By: Mark Shulman, 263-3782 Objective Down squeeze 9-5/8”x 7” OA to cement surface casing shoe to surface. Cement Volume Calculations: x Volume in 9-5/8”x 7” annulus: (3,392’ MD/2,379’ TVD) x (0.0297 bbl/ft) = 101 bbl x Volumes: 126 bbl mixed and 100 bbl dry (ready for on-the-fly use): 226 bbls CRU CD2-57 (PTD#204-072) is a waivered injector (AIO 18E.005) that was originally drilled and completed in 2004. The well is currently shut-in for a surface casing leak. CD2-57 needs a surface casing repair. CD2-57’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. The surface casing FIT calculated the EMW to be 17.9 ppg (5/19/2004). 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. (see setup picture #1 below) 5. Ensure Valve crew services OA valves and any additional hardline valves installed for cementing job. 6. Install containment into cellar to contain any returns from surface casing leak. Ensure vac truck on location with cement containment to take returns from surface casing leak from pumping operations. 7. MIRU cement pumping equipment and rig up 2” hardline to the circulation skid. Stage equipment to minimize pumping stop time between stages. 8. Be sure to monitor around wellhead, wellhouse, and conductor top during OA pumping. There is a known surface casing leaks near the surface. During the OA injectivity testing returns were observed at the conductor. 9. PT lines and surface equipment to 3,000 psi. 10. Pumping the OA shoe recommendation. a. Complete an Injectivity test up to 1500 psi. and ensure OA will take injection. CD2-57 Cement Shoe Page 2 i. Lead with methanol and swap to diesel for injection test. ii. Record injection pressures and rates for cementing. b. At the beginning of the job, increase the pump pressure as necessary to break over on injection. i. 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. d. When cement gets to the shoe (101 bbls pump total after starting on cement), slow pumps to a maximum of 1 BPM or 500 psi. e. With 25 bbls of cement past the shoe (126 bbls after starting cement), shut- down pumps and watch pressure. f. Perform a 15-minute hesitation, then attempt to slowly squeeze another 10 bbls at minimum rate. i. If OA does not catch pressure after 110 bbls are pumped in OA, stop pumping cement and swap to pump 90 bbls of diesel in OA to FP and keep the shoe open and contact production engineer and WI engineer. g. Use cement composition on page #4. 11. Pump Schedule: a. Complete injectivity test with methanol and swap to diesel. b. 10 bbls hot diesel per Wells Supv. c. 65 bbls 90oF hot freshwater for flush of the OA. d. 20 bbls CW100 surfactant wash e. 10 bbls freshwater spacer f. 15 bbls 15.8# Class G cement (neat) g. 111 bbls 11# Class G cement with 2 lbs/bbl of CemNet and gas blocker. i. Perform 15-minute hesitation. h. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. i. Repeat 15-minute hesitation step i. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. i. Repeat 15-minute hesitation step j. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. i. Repeat 15-minute hesitation step k. If well locks up while pumping cement, go to next step. CD2-57 Cement Shoe Page 3 12. Close annulus, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. Top off OA with diesel for freeze protection. 13. Do not bleed the OA. Monitor the conductor top and downspout and vac out fluids if needed. 14. Wash up cementing equipment, RDMO. 15. Send OA cement shoe field blend UCA results to mark.shulman@conocophillips.com 16. After the cement cures for 72 hours, perform OA drawdown test. 17. If DDT passes DHD to drop string line and verify top of cement. 18. Report well work to AOGCC on 10-404 form. Volume (bbl):Fluid: Details: Step 1 Methanol and diesel Complete injectivity test with methanol and swap to diesel. Step 2 10 Hot diesel 10 bbls hot diesel per Wells Supv. Step 3 65 Hot Fresh water 65 bbls 90F hot freshwater for flush of the OA. Step 4 20 CW100 Surfactant 20 bbls CW100 surfactant wash. Step 5 10 Freshwater 10 bbls freshwater spacer. Step 6 15 15.8# Cement Neat 15 bbls 15.8# Class G cement (neat). Step 7 111 11# Cement gas blocker/CemNet 111 bbls 11# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. Step 8 Perform 15-minute hesitation. Step 9 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. Step 10 Repeat 15-minute hesitation step Step 11 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker. Step 12 Repeat 15-minute hesitation step Step 13 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker. Step 14 Repeat 15-minute hesitation step Pump Schedule: CD2-57 Cement Shoe Page 4 Equipment Setup (Picture#1): May 7, 20256 Needed on locaƟon: LRS: •Pump truck w/25 bbls diesel NES: •Transport w/cement mix water •must be clean with funcƟonal paddles •With 72 bbls of 90-degree freshwater from Deadhorse Hot Water Plant mixed with chemicals from SLB bulk plant in Deadhorse-SLB East camp. •Transport with 75 bbls of PowerVis to be located at K-pad Mud plant. Alpine Well Support: •Dirty vac truck to suck out cellar during job •Transport with 80 bbls KWF to be loaded at K-pad Mud plant. •Transport with 290 bbls 90-degree freshwater to be loaded at K- pad Mud Plant SLB: •CemenƟng crew, cement and associated equipment. CD2-57 Cement Shoe Page 5 Cement Composition: Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-57 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Set A1 CD2-57 5/18/2024 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.011/3/2010 hipshkf NOTE: TREE: FMC 4-1/16 5K - TREE CAP CONNECTION: 7" OTIS 6/4/2004 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1614.69 38.0 114.0 114.0 109.00 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,391.2 2,378.4 36.00 J-55 BTC PRODUCTION 7 6.28 34.5 12,642.4 7,248.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 12,642.4 16,432.0 7,295.9 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth… 11,995.9 Set Depth… 7,033.9 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.532.50.00 HANGER 10.800 FMC TUBING HANGER 4.500 2,666.0 1,997.4 58.42 NIPPLE 5.620 CAMCO 'DB' NIPPLE 3.812 11,817.66,939.1 57.01 GAS LIFT 5.984 CAMCO KBG-23.938 11,932.0 7,000.5 58.13 PACKER 5.970 BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 11,983.5 7,027.5 58.83 NIPPLE 5.000 HES 'XN' NIPPLE 3.725 11,994.5 7,033.1 58.98 WLEG 5.000 BAKER WLEG 3.875 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) 2,666.01,997.4 58.42 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock (OAL-= 41") Camco A1 HWS- 210 5/16/2024 1.250 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) 11,817.6 6,939.1 57.01 1GAS LIFT DMY BK 1 0.0 6/22/2004 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,642.4 7,248.0 83.79 OPEN HOLE 6.125 CD2-57, 5/15/2025 1:47:46 PM Vertical schematic (actual) OPEN HOLE; 12,642.4-16,432.0 PRODUCTION; 34.5-12,642.4 PACKER; 11,932.0 GAS LIFT; 11,817.6 SURFACE; 36.7-3,391.2 INJ VALVE; 2,666.0 NIPPLE; 2,666.0 CONDUCTOR; 38.0-114.0 WNS INJ KB-Grd (ft) 44.30 RR Date 6/5/2004 Other Elev… CD2-57 ... TD Act Btm (ftKB) 16,432.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032049200 Wellbore Status INJ Max Angle & MD Incl (°) 91.25 MD (ftKB) 15,215.09 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Regg, James B (OGC); Wallace, Chris D (OGC) Subject:FW: [EXTERNAL]RE: 10-426 Form CD2-57 and CD4-213B Date:Wednesday, September 4, 2024 4:31:34 PM Attachments:CD4-213B 10-426 March 2024.xlsx CD2-57 state MIT test form 10-426 July 2024.xlsx Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, September 4, 2024 4:20 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL]RE: 10-426 Form CD2-57 and CD4-213B See attached. Sorry about that! Kate From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Wednesday, September 4, 2024 4:19 PM To: WNS Integrity <WNSIntegrity@conocophillips.com> Subject: [EXTERNAL]RE: 10-426 Form CD2-57 and CD4-213B CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Kate, Will you send these in an Excel format so they can be imported into our database? Thank you, Phoebe CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from wnsintegrity@conocophillips.com. Learn why this is important Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, September 4, 2024 3:34 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Dodson, Kate <Kate.Dodson@conocophillips.com>; Shulman, Mark <Mark.Shulman@conocophillips.com> Subject: 10-426 Form CD2-57 and CD4-213B Hello, See attached for diagnostic MIT-IA on CD2-57 and CD4-213B. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040720 Type Inj W Tubing 790 1060 1060 1060 Type Test P Packer TVD 7001 BBL Pump 4.1 IA 765 2500 2440 2420 Interval O Test psi 1750 BBL Return 3.8 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Van Camp 07/03/24 Notes:Diagnostic MIT-IA Notes: Notes: Notes: CD2-57 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2024-0703_MIT_CRU_CD2-57 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CD2-57 PTD 204-072 Date:Tuesday, July 2, 2024 3:06:30 PM Attachments:AnnComm Surveillance TIO for CD2-57.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, July 2, 2024 1:17 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CD2-57 PTD 204-072 Chris, CD2-57 PTD 204-072 failed a Surface Casing Leak Detect. The well has been SI and additional diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-57 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Set A1CD2-57 5/18/2024oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.011/3/2010 hipshkf NOTE: TREE: FMC 4-1/16 5K - TREE CAP CONNECTION: 7" OTIS6/4/2004WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1614.69 38.0 114.0 114.0 109.00 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,391.2 2,378.4 36.00 J-55 BTC PRODUCTION 7 6.28 34.5 12,642.4 7,248.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 12,642.4 16,432.0 7,295.9 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth … 11,995.9 Set Depth … 7,033.9 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.532.50.00 HANGER 10.800 FMC TUBING HANGER 4.500 2,666.01,997.4 58.42 NIPPLE 5.620 CAMCO 'DB' NIPPLE 3.812 11,817.66,939.1 57.01 GAS LIFT 5.984 CAMCO KBG-23.938 11,932.0 7,000.5 58.13 PACKER 5.970 BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 11,983.5 7,027.5 58.83 NIPPLE 5.000 HES 'XN' NIPPLE 3.725 11,994.5 7,033.1 58.98 WLEG 5.000 BAKER WLEG3.875 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) 2,666.0 1,997.4 58.42 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock (OAL-= 41") Camco A1 HWS- 210 5/16/2024 1.250 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) 11,817.6 6,939.1 57.01 1 GAS LIFT DMY BK 1 0.0 6/22/2004 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,642.4 7,248.0 83.79 OPEN HOLE 6.125 CD2-57, 5/18/2024 10:07:11 AM Vertical schematic (actual) OPEN HOLE; 12,642.4-16,432.0 OPEN HOLE; 12,642.4-16,432.0 PRODUCTION; 34.5-12,642.4 FLOAT SHOE; 12,640.2- 12,642.4 FLOAT COLLAR; 12,552.0- 12,553.3 WLEG; 11,994.5 NIPPLE; 11,983.5 PACKER; 11,932.0 GAS LIFT; 11,817.6 SURFACE; 36.7-3,391.2 FLOAT SHOE; 3,388.9-3,391.2 FLOAT COLLAR; 3,301.3- 3,302.8 INJ VALVE; 2,666.0 NIPPLE; 2,666.0 CONDUCTOR; 38.0-114.0 HANGER; 36.7-38.9 HANGER; 34.5-36.3 HANGER; 32.5 WNS INJ KB-Grd (ft) 44.30 RR Date 6/5/2004 Other Elev… CD2-57 ... TD Act Btm (ftKB) 16,432.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032049200 Wellbore Status INJ Max Angle & MD Incl (°) 91.25 MD (ftKB) 15,215.09 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP 5HJJ-DPHV%2*& )URP6PLWK7UDYLV77UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW7XHVGD\-XQH30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&58)RUPV $WWDFKPHQWV0,7&58&' 6,7(676[OV[0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚǇŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041500 Type Inj N Tubing 1310 1600 1600 1600 Type Test P Packer TVD 6998 BBL Pump 3.6 IA 50 2200 2160 2160 Interval 4 Test psi 1750 BBL Return 2.5 OA 110 130 130 130 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040720 Type Inj N Tubing 1350 1350 1350 1350 Type Test P Packer TVD 7001 BBL Pump 3.6 IA 50 2000 1950 1940 Interval 4 Test psi 1750 BBL Return 2.3 OA 0 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2091150 Type Inj N Tubing 1000 1275 1275 1275 Type Test P Packer TVD 6978 BBL Pump 3.8 IA 60 2000 1950 1940 Interval 4 Test psi 1745 BBL Return 3.7 OA 380 400 400 400 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD2-56 CD2-57 Notes: CD2-60A Notes:Tubing plug set at 13,201' MD Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/12/22 Form 10-426 (Revised 01/2017)2022-0612_MIT_CRU_CD2-pad_3wells 9 9 9 9 9 9 9 - 5HJJ CD2-57 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-57 COLVILLE RIV UNIT CD2-57 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-57 50-103-20492-00-00 204-072-0 G SPT 7000 2040720 1750 3994 3992 3994 3992 80 100 100 100 4YRTST P Matt Herrera 6/28/2022 MIT-IA Performed to 2200 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-57 Inspection Date: Tubing OA Packer Depth 950 2200 2160 2150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629151055 BBL Pumped:1.5 BBL Returned:1.5 Thursday, July 21, 2022 Page 1 of 1         MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor 1\4Gj q/Sit SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-57 FROM: Brian Bixby COLVILLE RIV UNIT CD2-57 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-57 API Well Number 50-103-20492-00-00 Inspector Name: Brian Bixby Permit Number: 204-072-0 Inspection Date: 6/6/2018 Insp Num: mitBDB180611053559 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-57 Type Inj W-TVD 7000 ' Tubing 2220 - 2240 - 2240 2240 . PTD 2040720 -Type Test SPT Test psi 1750 - IA 980 3000 - 2960 2960 - BBL Pumped: 1.9 IBBL Returned: 1 1.9 - OA 590 - 800 ' 800 . 800 - R Interval 4YRTST !P/F P V - -J Notes: SCAIN JUN 2 l,J1G Monday,June 11,2018 Page 1 of 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 Y-- - 0 ~ ;L Well History File Identifier µ0'WO-Sided 1111111111111111111 Organizing (done) D Rescan Needed 1111111111111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA ~kettes. No. :;L D Other, Norrype: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: CMaria) Date ~ /JJ 0 (P D Other:: /5/ VV\P Date g ~ D(P 5 x30= ISO+ D~ 1111111111111111111 Project Proofing Scanning Preparation BY: I VV\f = TOTAL PAGES /5/ (Count does not include cover sheet) /5/ /5/ BY: ~ Date: 11111111111111 "III BY: Production Scanning Stage 1 Page Count from Scanned File: J 5 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES ~ Date:<?;/I/D(P If NO in stage 1, page(s) discrepancies were found: NO Stage 1 YES /5/ VV\ r NO BY: Maria Date: /5/ 11111111/1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: /5/ Comments about this file: Quality Checked 11111111111I1111111 10/6/2005 Well History File Cover Page.doc Wallace, Chris D (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, October 18, 2013 5:20 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C Subject: RE: Report of suspected TxIA communication of Alpine injector CD2-57(PTD 204-072) 10-14-13 Attachments: MIT CRU CD2-57 Diagnostic MITIA 10-16-13.xls Chris, Initial diagnostics were completed with DHD on 10/16/13 that included a passing MITIA, passing tubing and inner casing packoff tests, however the IA drawdown test showed a pressure build up. The well was shut in at 8:26 PM on 10/16/13. A plan forward will be decided upon and the appropriate paperwork will be submitted prior to any further injection. Attached is a copy of the MITIA form. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons SCANNED kl r'; ..4 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, October 15, 2013 2:19 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Jolin, Approved to keep CD2-57 on injection during additional monitoring and diagnostics. As soon as diagnostics confirm the leak, well is to be shut in. Maximum 30 days injection approved—shut in 11/14/2013 unless extension applied for with supporting documentation up to or including an application for Administrative Approval. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, October 14, 2013 6:47 PM To: Wallace, Chris D (DOA) Subject: RE: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Chris— 1 I just wanted to clarify slightly with the note below. CPAI requests permission to keep the well on injection during the initial diagnostic testing, which will be conducted as soon as possible. Then the well will be shut in as soon as possible if TxIA communication is still suspected. The appropriate paperwork and action plan will be submitted as needed. Thanks, Jolin Oksness Well Integrity Engineer ConocoPhillips, Alaska 907 659-7224 (c) 907 230-7493 From: NSK Problem Well Supv Sent: Monday, October 14, 2013 5:10 PM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Proj; Dethlefs, Jerry C Subject: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Chris— Alpine Injector CD2-57(PTD#204-072) is demonstrating suspected TxIA communication based on a recent spike in IA pressure over the last few days. The well will be SI as soon as possible and initial diagnostics will be performed including an MIT-IA, IA-DDT, and T-POTs. Pending the outcome of the initial diagnostics,the appropriate paperwork will be submitted to continue injection or repair as need. The well has been added to the monthly report. Attached are 90 day and 30 TIO plots. Let me know if you have any questions. Regards, Jolin Oksness Well Integrity Engineer ConocoPhillips,Alaska 907 659-7224 (c) 907 230-7493 2 Wallace, Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Tuesday, October 15, 2013 2:19 PM To: 'NSK Problem Well Supv' Subject: RE: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Jolin, Approved to keep CD2-57 on injection during additional monitoring and diagnostics. As soon as diagnostics confirm the leak,well is to be shut in. Maximum 30 days injection approved—shut in 11/14/2013 unless extension applied for with supporting documentation up to or including an application for Administrative Approval. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 — .:; `'4;' (907)793-1250(phone) SCANNED ` (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617Cc)conocophillips.com] Sent: Monday, October 14, 2013 6:47 PM To: Wallace, Chris D (DOA) Subject: RE: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Chris— I just wanted to clarify slightly with the note below. CPAI requests permission to keep the well on injection during the initial diagnostic testing,which will be conducted as soon as possible.Then the well will be shut in as soon as possible if TxIA communication is still suspected. The appropriate paperwork and action plan will be submitted as needed. Thanks, Jolin Oksness Well Integrity Engineer ConocoPhillips,Alaska 907 659-7224 (c) 907 230-7493 From: NSK Problem Well Supv Sent: Monday, October 14, 2013 5:10 PM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Proj; Dethlefs,Jerry C Subject: Report of suspected TxIA communication of Alpine injector CD2-57 (PTD 204-072) 10-14-13 Chris— 1 Alpine Injector CD2-57(PTD#204-072) is demonstrating suspected TxIA communication based on a recent spike in IA pressure over the last few days. The well will be SI as soon as possible and initial diagnostics will be performed including an MIT-IA, IA-DDT,and T-POTs. Pending the outcome of the initial diagnostics,the appropriate paperwork will be submitted to continue injection or repair as need. The well has been added to the monthly report. Attached are 90 day and 30 TIO plots. Let me know if you have any questions. Regards, Jolin Oksness Well Integrity Engineer ConocoPhillips,Alaska 907 659-7224 (c)907 230-7493 2 WNS CD2-57 Conoco'Phillips #41116 Max An,le&MD , D Wellborn API1UWI Field Name Well Statue Ind(°) MD((1KB) Act Btm(ftKB) rb,omitrwps 501032049200 ALPINE INJ 91.25 15215.09 16,432.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(K) Rig Release Date SSSV:WRDP Last WO: 44.30 6/42004 Well Confq:-CD2.57,12/7..'0125 I •-' - Schemalk-ACwal _ - Annotation Depth(ftKB) End Data Annotation Last Mod...End Date Last Tag: Rev Reason:RESET INJ VALVE ninam 12/72012 Casing Description String 0... String ID...Top(fIKB) Set Depth If...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 14.688 38.0 114.0 114.0 109.00 H-40 WELDED Casing Description String 0... String ID...Top(NKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 36.7 3,391.2 2,378.4 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Sot Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 34.5 12,642.4 7,249.7 26.00 L-80 BTCM MANGER.32 RI • Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Sot Depth(ND)...String Wt...String...String Top Thrd p OPEN HOLE 6 1/8 12,642.4 16,432.0 7,295.9 Tubing Strin s - Tubing Description String 0... String ID...Top MKS) Set Depth(/...Set Depth(ND)...String Wt...String.••String Top Thrd TUBING 41/2 3.958 , 32.5 11.995.9 7.033.7 12.60 L-80 IBTM Completion Details Top Depth (ND) Top Intl Nomi... i , _.1p Top(ftKB) (ftKB) 11 Item Description Comment ID(in) 32.5 32.5 -0.15 HANGER FMC TUBING HANGER 4.500 2,666.0 1,997.4 58.42 NIPPLE CAMCO'DB'NIPPLE - 3.812 11,932.0 7,000.5 58.12 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 11,983.5 7,027.2 58.83 NIPPLE HES'XIJ'NIPPLE 3.725 CONDUCTOR. 11,994.5 7,033.0 58.98 WLEG BAKER WLEG - 3.875 38-114 .-._._.._. --..-.."...._.. __ — Other in Wote treline retrievable plugs,valves,pumps,fish.etc.) (ND) Top Intl - Top Depth VALVE.2.666 i 2 Top(NKB) (NKB) (•) Deacripton Comment Run Data ID(in) NIPPLE.zstab - 2.6661 1.997 4' 50 42 VALVE 3.813"A-1 INJECTION VALVE(HYS-444)--- 7/29/2011 1.250 MI e-e eneral&Safet End Date Annotation 6/42004 NOTE:TREE:FMC4-1/16 5K-TREE CAP CONNECTION: 7"OTIS 11/3/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 • SURFACE. - - ' ' 37-3,391 4 GAS LIFT 818 4 PACKER 11.932 NIPPLE.11.984—-- i WLEG,11,995 • Mandrel Details Top Depth Top Port (NO) Ind OD Volvo Latch Size TRO Run' Stn Top MKS), (fK8) P) Make Model lint Sery Type TYpe On) (Psi) Run Date Cont... 1 11,817.6 6,939.1 57.01 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 6/22/2004 PRODUCTION.35.12,042 v, — OPEN HOLE, • — 12,842-16,432 TD,18,432 — • MEMORANDUM TO: Jim Regg ~ldc9 ~ 7(27~/~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-57 COLVILLE RIV UNIT CD2-57 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~;e- Comm Well Name: COLVILLE RIV UNIT CD2-57 Insp Num: mitJJ100719133219 Rel Insp Num: API Well Number: 50-103-20492-00-00 Permit Number: 204-072-0 Inspector Name: Jeff Jones Inspection Date: 6/12/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-57' Type Inj. ~' ~ TVD 700o IA 1350 2950 2890 2870 ' P.T.D zoao7zo TypeTest sPT Test psi I7so ~ pA so so 55 so Interval aYRTST p~F P ~ Tubing zlso use use use NOtes: 1.7 BBLS diesel pumped. 1 well inspected; no exceptions noted. ~.i1':F ,.. Monday, July 26, 2010 Page 1 of 1 • • _~_ . -~- MICROFILMED 03/01 /2008 DO NOT PLACE ..x~.. ~.: ~_ ANY NE1N MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Mitcrofilm Marker.doc ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 2 7 2007 ~O~-D1~ Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~!:~--_/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-1 09 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 318/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CÐ2,.51 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska £\p P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ''''I ,:~' 'w_> March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: à0Lf-- °7J- Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, St:ANNED APR 0 9 2007 ~~C "" Jerry Dethlefs . ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/812007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 CD2-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . WELL LOG TRANSMITTAL ~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 29,2006 RE: MWD Formation Evaluation Logs CD2-56_Ll, CD2-57, CD2-59_PBl, CD2-60_PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 u~ CD2-56 Ll: ;)ð4- 15""6 Digital Log Images: 50-103-20498-00,60 CD2-57: V:r:c..- QO'-/ -Ü-=t-d 'Ii 1'"/31--:f- Digital Log Images: 50-103-20492-00 u;rc... ~ 1L/376- I ÐD4 -IS-I it }'-137fc 1 CD Rom 1 CD Rom .. CD2-59 _PBl: gìc...-- ~l..( __:;;;'-I~ -It Ji..f31-'ff Digital Log Images: 50-103-20505-00, 70 1 CD Rom CD2-60_PBl: U:r...C-.Q.cS- -o~~ # IL(3l-'1 Digital Log Images: 50-103-20511-00,70 1 CD Rom SCANHED JAN 302007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic 0 Service 0 6. Permit to Drill Number: 204-072 ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 7. Well Name: CO2-57 2. Address: 4b. Well Status: Oil 0 Gas 0 WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ 0 WINJ 0 WDSPL 0 50-103-20492-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal Oor Continuation o or Final 0 305-238 8/17/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 0 0 392* 392 0 totals (bbls): 2005 / 3rd 18689 100 0 18789 20 8/22/2005 9/11/2005 C02-01 2005 / 4th 0 0 0 0 0 2006/1st 0 0 0 0 0 2006 / 2nd 0 0 0 0 0 2006 / 3rd 0 0 0 0 0 Total Ending Report is due on the 20th Volume 18689 100 392 19181 20 (bbls): of the month following the final month of the quarter. Ex: 0 0 April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time Step Rate Test October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth auarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: K~~ -.."-=--- Date: to(~/Þ6 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 "'M~ in_A")'" Cð" ")¡")nnA 1"'~T6, ".. .- '~,:...~;,;" . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIOn TO: ~~~S~;;~isor~7t- S/~)J¿)G DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CO2-57 COLVILLE RIV UNIT CO2-57 ó-1A-01'r FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,Jf3/Z-- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-57 API Well Number 50-103-20492-00-00 Inspector Name: Chuck Scheve Insp Num: mítCS060828 I 50240 Permit Number: 204-072-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CO2-57 Type Inj. w TVD 7000 IA 1050 2460 2430 2430 P.T. 2040720 TypeTest SPT Test psi 1750 OA 700 850 850 850 Interval 4YRTST P/F P /' Tubing 1950 1950 1950 1950 Notes Pretest pressure observed and found stable SCANNED SEP 0 82006 Wednesday, August 30, 2006 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic 0 Service D 6. Permit to Drill Number: 204-072 ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 7. Well Name: CO2-57 2. Address: 4b. Well Status: Oil 0 Gas 0 WAGD 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ 0 WINJ 0 WDSPL 0 50-103-20492-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal o or Continuation D or Final 0 305-238 8/17/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occu rred fluids, formation fluids and any necessary water added .' Previous 0 0 392* 392 0 totals (bbls): 2005 / 3rd 18689 100 0 18789 20 8/22/2005 9/11/2005 C02-01 2005 /4th 0 0 0 0 0 2006/1st 0 0 0 0 0 2006 / 2nd 0 0 0 0 0 j Total Ending Report is due on the 20th Volume 18689 100 392 19181 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes , I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~-«- ~'-'v- .- ... Date: 7/ro 186 1 . Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Permit to Drill 2040720 MD 16433 REQUIRED INFORMATION L1J~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. COLVILLE RIV UNIT CD2-57 Operator CONOCOPHILLlPS ALASKA INC TVD 7296 Completion Status WAGIN Current Status WAGIN API No. 50-103-20492-00-00 Directional Survey Yes Rpt C Lis 13652 Induction/Resistivity 114 16433 Open 2/22/2006 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Completion Date 6/4/2004 Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens/Neutron, SCMT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ~12541 I:~ D Rpt ~ D (data taken from Logs Portion of Master Well Data Maint Name Induction/Resistivity Log Log Run Scale Media No Interval OH/ Start Stop CH 3367 16366 Open 3367 16366 Open 0 16433 0 16433 0 16433 0 16433 11752 12472 LIS Verification Directional Survey Directional Survey Directional Survey Directional Survey Cement Evaluation Blu Interval Start Stop Sample Set Number Comments Sent Received Daily History Received? Y/N Formation Tops Y/N Comments: r "'- F, I I-L- . Received Comments 7/9/2004 EWR4 GR ABI ROP PWD I 7/9/2004 DSN 12541 EWR4 GR ABI ' ROP PWD 7/16/2004 MWD 7/16/2004 7/16/2004 7/16/2004 1 0/15/2004 MWD IIFR IIFR CEMENT BOND LOG SCMT -CNPRESSITEMP ROP DGR EWR plus Graphics . lÝo '-I'D? DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040720 Well Name/No. COLVILLE RIV UNIT CD2-57 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20492-00-00 MD 16433 TVD 7296 Compliance Reviewed By: Completion Date 6/4/2004 Completion Status WAGIN Current Status WAGIN UIC Y ~ Date: .1q J~~ . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic D Service 0 6. Permit to Drill Number: 204-072 ConocoPhillips Alaska, Inc. Development D Exploratory D 7. Well Name: CD2-57 2. Address: 4b. Well Status: Oil D Gas D WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ D WINJ D WDSPL D 50-103-20492-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal D or Continuation o or Final D 305-238 8/17/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 0 0 392* 392 0 totals (bbls): 2005 / 3rd 18689 100 0 18789 20 8/22/2005 9/11/2005 CD2-01 2005 / 4th 0 0 0 0 0 2006/1st 0 0 0 0 0 2006 / 2nd .. Total Ending Report is due on the 20th Volume 18689 100 392 19181 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure VS. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoin is true and correct to the best of my knowledge. \ . \ ". i.{h(è> 6 Signature: ~..... Date: ! Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate . . WELL LOG TRANSMITTAL t)IC/ d()t ~l ð' To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 13(j)5~ RE: MWD Fonnation Evaluation Logs CD2-57, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-57: LAS Data & Digital Log Images: 50-103-20492-00 1 CD Rom (¡imytt ~f{}fjf6Zo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 0 392* 392 0 18689 100 0 18789 20 8/22/2005 9/11/2005 CD2-01 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG 0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 305-238 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/17/2005 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2005 / 3rd 2005 / 4th 2006/1st 2006 / 2nd Total Ending Volume 18689 100 (bbls): 392 19181 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ . -=-".i. ,~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: ·····204.;.072 CD2-57 50-103-20492-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 20 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. lflOZ(06 Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic D Service 0 6. Permit to Drill Number: 204-072 ConocoPhillips Alaska, Inc. Development D Exploratory D 7. Well Name: CO2-57 2. Address: 4b. Well Status: Oil D Gas D WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ D WINJ D WDSPL D 50-103-20492-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 00r Continuation D or Final D 305-238 8/17/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 0 0 392* 392 0 totals (bbls): 2005 / 3rd 18689 100 0 18789 20 8/22/2005 9/11/2005 C02-01 2005 / 4th 2006/1st 2006 / 2nd Total Ending Report is due on the 20th Volume 18689 100 392 19181 20 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~-\~ Date: l 0 ( ZP./z, ) \ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 , ' Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE RBDMS BFL (Je! 2 7665 Submit in Duplicate ~lF ru.. ) ~L 9"f .[6 ULb . rmr ¡n ;, "'U".·..f.'.. n:.,.. lhU U-- . Il . ¡ ~ L::::! ~ ¡ ,,-,;...¡ , '. ,;~\'\ ,~ IT\ ¡LJ\ U.,nì u FRANK H. MURKOWSKI, GOVERNOR A.,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska 700 G Street Anchorage, Alaska 99501 ;;20C+ - ö7V Re: Alpine CD2-57 Sundry Number: 305-238 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer than one year. 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 decisi t Superior Court unless rehearing has been requested. BY ORDER O..F THE COMMISSION DATED thisK day of August, 2005 Encl. ConocoPhillips Alaska, Inc. c__ PoS't Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ,-/ ~ ConocoPhillips RECEIVED AUG 1 6 2005 Anchorage, Alaska 99501-3539 Alaska Oil &GU;j Cons. Commission Re: ADDlication for Sundry A'PDroval for Annular DisDosal of Drillin2: Wast~l,,(fhO#M CD2-57 August 10,2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Dear Sir or Madam: ConocoPhiIlips Alaska, Inc. hereby requests that CD2-57 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 CD2-57 approximately August 25, 2005 or as soon as a permit is available.. Please find attached form 10-403AD and other pertinent infonnation 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 CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within ~ mile radius, not already on file at AOGCC: CD2-60 Further details regarding wells on CD2 pad within ~ mile radius should be on file at the AOGCC. The initial annular LOT (16.8 ppg) and subsequent annular LOT (15.9 ppg 8/6/05) occurred at a lower equivalent mud weight than the casing shoe test (17.9 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT /LOT. If you have any questions or require further information, please contact Vem Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. ~'7 e:~- Drilling Engineer c¡11 ( /oS- cc: CD2-57 Well File Chip Alvord Anadarko Sharon Allsup-Drake ATO-1700 ATO-1530 ø i/-:C:¡7!17 () STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~$ßJ9N ""...~!~ F ! .~, ANNULAR DISPOSAL APPLICATION'·' oj:; 20 MC 25.080 C4'r V -( I~(;l:> qUe ~j\~ 1. Operator Name: ConocoPhillips Alaska 3. Permit to Drill Number: 204-072 4. API Number: 50-103-20492-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska C02-57 6. Field: Colville River Field 7. Publicly recorded wells a) All wells within one-quarter mile: C02-38, C02-37, C02-51 C02-58, C02-27, C02-53 C02-50 8. Stratigraphic description: a) Interval exposed to open annulus: Torok and Seabee formation, shale, siltstone and sandstone b) water wells within one mile: b) Waste receiving zone: Sand layers in the Colville group C-30 in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier 9. Depth to base of permafrost: approximately 1900' MD / 1600' TVD 10. Hydrocarbon zones above waste receiving zone: None 11. Previous volume disposed in annulus and date: None 14. Estimated volume to be disposed with this request: 12. Estimated slurry density: densities range from diesel to 12#/gal 15. Fluids to be disposed: 13. Maximum anticipated pressure at shoe: 2213 PSI 35,000 bbls. 16. Estimated start date: Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and an other fluids associated with drilling a well. 25-Aug-05 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) D FIT Records w/LOT Graph 0 Surf. Casing Cementing Data o Other D 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2-:ò-V~ Signature: 2~f-G:.f79 Title: Printed Name: .f-- Chip Alvord 265-6120 Date: rjJ J10) Phone Number: Commission Use Onl Conditions of approval: 'C; ~..I".~ \, C: (é ~ , ()CJ ~ ~ C- ð- $" . 0 ~. 0 LOT review and approval: 1:{i..7Jv1 9:(, t") Approval number: 30~- d 3~ Approve COMMISSIONER BY ORDER OF THE COMMISSION Date: Form 10-403AD Rev. 9/2003 ORIGINAL INSTRUCTIONS ON REVERSE Submit in Duplicate AnnuluslJisposal Transmittal Form - Wèn"'CD2-57 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD2-57 2 The depth to the base of freshwater aquifers and pennafrost, if There are no USD\V aquifers in the Colville River Unit. present. Estimated base ofPelmafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff fonnation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Lower Cretaceous Torok commission fmding that the waste will be confmed and will FOlmation provide a lower ban-ier. Calculated water salinities not come to the surface or contam.jn.ate freshwater. of the Cretaceous and older stratigraphic sections range £Tom 15000 to 18000 mgiL (Ref. AOGCC Conservation Order No. 443, IvIarch 15, 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within I í4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, dril1ing cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated \vith the act of drilling a well, dril1 rig wash fluids, domestic waste \vater, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a wen. Densities range from diesel to 12#ígal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate waste under (h)(3) of this section. 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 2213 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT í 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 summalY sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal qperations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing 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 NíA annular space of the well and, if s6, a summary of the dates of the disposal operations, the voluml~s of waste disposed of, and the wells where the drilling waste was generated. 14 The welle s) where the drilling waste to be disposed of was or CD2-01, CD2-11, CD2-04, CD2-34a, CD2-17a, CD2-43a will be generated. 15 If the operator proposes not to comply with a limitation NíA established in (d) of this section, an explanation of why compliance would be Î1nPrudent. 16 Any additional data required by the commission to confirm NiA containment of drilling waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas/Fluid Gradient in tubing/casing annulus Header Pressure (for wells on gas lift) Well Date CD2-57 8/1 012005 10,345' MD 6,13S' TVD 4.5 "Tubing 1,500 12.0 0.434 0.1 o Version LO - Jan '05 psi ppg psi/ft psi/ft pSI Maximum Fluid Density to avoid Burst of Surface Casin2 Pburst85% = PHydrostatic + P Applied - PFormarion 2,992 = ( 2,378 * 0.052 * MWmax MW max ppg ) + 1500 - ( 0.4337 * 2,378) 20.4 Surface Casin2 Strin2 9.625 36 Size Weight Grade l\urstIOO% Pburst85% ppf J 55 3,S20 2,992 2,378 17.9 16.8 I,SOO m psi pSI ft ppg ppg psi or 2,213 psi Maximum Fluid Densitv avoid Collapse of 2nd Casin2 Strin2 P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure 4,599 = ( 6,135 * 0.052 '" M W max 11.6 )+ 1,500 - (0.1000 * 6,135) - 0 MW max ppg pSI pSI ft psi/ft psi pSI 2nd Casin2 Strin2 7 26 Size Weight Grade l' collapselOO% P collapse85% m ppf L 80 5,410 4,599 6,135 0.1 1,500 o Top of Cement Gas Gradient Max Surf. Pressure Header Press Maximum Anticipated Pressure at Surface Casin2 Shoe P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = 2,378 * .OS2 * 17.9 ) P max allowable = 2,213 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ~. Conoc6Phillips Casing Detail 95/8" Surface Casino Well: Date: C02-57 5/18/2004 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.70 FMC Gen V Hanger 2.21 36.70 Jts 3 to 81 79 Jts 9-5/8" 36# J-55 BTC Csg 3262.37 38.91 Davis Lynch Float Collar 1.48 3301.28 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 86.09 3302.76 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 3388.85 3391.15 TD 12 1/4" Surface Hole 3401.00 RUN TOTAl 45 BOWSPRING CENTRALIZERS - 1 per jt on :Jt #1 - #12 (One stop ring on Jt #2) and over collars on jts# 14, 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, 64, 66, .68,70,72,74,76,78 90 joints in the pipe shed. Run 81 joints-9 joints stay out Use Best-a-Life 2000 pipe dope Remarks: Up Wt - ??? k On Wt - ??? k Block Wt - 75k Supervisor: D. Burley / L.. Hill ConocoPhillips Alaska Casing Report Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING 1 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/19/2004 End: 6/4/2004 -_._,."----- -",_._-----,-,--------_. String Type: Surface Casing Hole TVD: 2,384.0 (ft) Ground Level: 15.90 (ft) Circ Hours: 2.00 (hr) Report #: Start: -------- ----.---,--.----- General Information -----,.__._------------------,---- Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Kelly Bushing 15.90 (ft) , (ft) 150.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff:. 12.250 (in) (ft) (ft) 36.70 (ft) Hole TMD: Str Wt on Slips: Max Hole Angie: Days From Spud: ---...---.,.----.------..-.----,------.-----...'.- ------..--,-.--------------------.---'---------.-.- --,---_.,---_.- Manufacturer: Hanger Model: Casing Flange I Wellhead -,.,--..------..--.,--- ----,-..-.-------.------ 3,401.0 (ft) 125,000 (Ibs) 61'~'16 n' 3.70 (days) Page 1 of 1 . -"....,.--...--.-,----.-----.-..". -------..---.--- ---.--..--------...--...,.-.-..,.,---.---.---..,-,. -----,------,--_._.._---- --.-.-.-....,."'....--,-..--.--.-,------".--- Top Hub/Flange: (in) / (psi) BTM Hub/Flange: (in) / (psi) --_...,--'-'-_.'-- Model: Packoff Model: -----,--- ------------.,-.--".--.-------- ----,---,----_._------- Actual TMD Set: 3,391.15 (ft) Item Size (in.) Casing Hanger 7.000 Casing 7.000 Float Collar 7.000 Casing 7.000 Float Shoe 7.000 -,------.---.----.- Integral Casing Detail .- ight Grade Drift Threads JTS Length Top MU Torq. THO Manufacturer Model Condo Itt) (in) (ft) (ft) (ft-Ibf) 2.21 36.70 FMC L-80 6.151 BTC 79 3,262.37 38.91 1.48 3,301.28 WEATHERFORD L-80 6.151 BTC 2 86.09 3,302.76 2.30 3,388.85 RAY OIL TOOLS -- ----. --.--".--- We (Ib Max 00 Min 10 Compo Name (in) (in) Casing Hanger 6.276 7" 26# L-80 Ca Float Collar 6.276 7" 26# L-80 Ca Float Shoe --.---,..-----,---"--- Printed: 8/12/2005 2:28:27 PM I -- " ~/ ConocoPhillipsAtaska Cementi ng ~Rep()rt Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING PrimaIV Hole Size: 12.250 (in) TMD Set: 3,391 (ft) Date Set: 5/19/2004 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 139.80 Meas. From: 150 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 294 (gpm) Mud Circ Press: (psi) Report #: Start: 1 5/14/2004 Cement Job Type: Primary ~ Saueeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Saueeze Casino Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Page 1 of 3 Spud Date: 5/16/2004 Report Date: 5/19/2004 End: 6/4/2004 ~ ~ ~ ~ Pluo Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 10f 1 Start Mix Cmt: 07:31 Start Slurry Displ: 08:36 Start Displ: 08:36 End Pumping: 09:17 End Pump Date: 5/19/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbl/min) Y 618 (psi) 1,000 (psi) 1,000 (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 100 Total Mud Lost: (bbl) Gmt Vol to Surf: 150.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: Spud Mud Density: 9.6 (ppg) Visc: 80 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVIYP: 29 (cp)/29 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 237.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry<No: 1 of4 Description: Biozan water w/nut plug Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (fP/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: Wash Mix Water: (gal) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 8/12/2005 2:12:12 PM Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Slurry Data Fluid Type: LEAD Slurry Interval: 2,891.00 (ft)To: (ft) Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) ConocoPhillips Alaska Cementing Report Page 2 of 3 Report #: Start: 1 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/19/2004 End: 6/4/2004 Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: ("F) Temperature: ("F) Temperature: ("F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 4 Description: ASLite Cmt Vol: 415.0 (bbl) Slurry Vol544 (sk) Class: Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Vol: 251.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 3,391.00 (ft)To: 2,891.00 (ft) Cmt Vol: 47.5 (bbl) Water Source: lake water Slurry Vol230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: ("F) Temperature: (OF) Density: 15.80 (ppg) Water Vol: 29.0 (bbl) Class: G Yield: 1.16 (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp ("F) ("F) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 19.40 (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 5.10 (gal) Foam Job: N Pressure (psi) (psi) Printed: 8/12/2005 2:12:12 PM -- -... / ConocoPhillipsAlaska Cementi-ng..Report Page 3 of 3 . - Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING Report #: Start: 1 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/19/2004 End: 6/4/2004 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: LoglSurvey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Pump 40 bbls biozan/nutplug spacer and 5 bbls H20. Test lines to 2500 psi. Drop bottom plug. Pump 50 bbls 12.5 ppg mud push spacer, 415 bbls 10.7 ppg lead cement and 49 bbls 15.8 ppg tail cement. Drop top plug. Dowell pumped 20 bbls H20. Displace with rig pumps with 9.6 ppg mud. Bumped plug. Printed: 8/12/2005 2:12:12 PM Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE \24 HRS PROG iTMD ITVD I DFS I REPT ~o. DATE : I CO2-57 ¡ ODR i 3,401.0 ¡ 2,384.0 3.70 · 5/19/2004 SUPERVISOR ¡ RIG NAME & NO. FIELD NAME / OCS NO. i AUTH MD iDAJLYTAN~ ¡CUM. TANGO D. Lutrick I L. Hill Doyon Drilling Inc 19 ALPINE ¡ 17,259.0 CURRENT STATUS ¡ACCIDENTS LAST 24 HRS.? DAJL Y INT w/o MUD CUM INTANG WI MUD Pickinq UP 4" DP. I 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAJL Y TOTAL CUM COST W/ MUD PU DP & BHA. RIH. Drill ST. Drill to 3421'. FIT. Drill. 5/10/2004 456,771 1,052,753 LITHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE IAUTH. CLAYSTONE ¡ I 10033832 I LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 5/18/2004 3,354.00 57.220 157.250 9.625 (in) @ 3,391.1 (ft) 7.000 (in) (cù 12,631.0 eft) 5/19/2004 DENSITY(ppg) 9.60 . r PP I IECDI IMUD DATAl DAILY COST 0 I CUM COST I 0 FV PVIYP I GELS WUHTHP FCfT.SOL I OIL/WAT I %Sand/MBT I Ph/pM I Pf/Mf T CI T Ca 1 H2S I LIME I ES 57 28/17 1 5/6 8.2/ I 21 I I I 0.5/25.0 i 9.01 I 0.01/0 I I 20 I I ; i OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:001 02:00 2.00 CASE Np IDH CIRC SURFAC Reciprocate pipe from 2453' to 2411'. Had full returns at 5 bpm at 360 psi. I I Pump low vis sweep with 15 ppb nut plug wi DO soap. I I I I 02:00 05:00 3.00 CASE Np I DH RUNC SURFAC Circ csg down from 2453' to 3352'. MU landing jt. Land csg at 3391'. 05:00 05:30 0.50 CASE P RURD !SURFAC LD Franks fill-up tool. Blow down top drive. RU cement head and lines. 05:30 06:45 1.25 CEMENT 1 ICIRC ISURFAC Pump la-vis sweep with nut plug and soap. Circ and condition mud for cement I job at 7 bpm at 400 psi. No losses to formation. 06:45 i 07:00 0.25 CEMENT Po ISFTY I SURFAC PJSM on cement job. 07:00 09:00 2.00 ! CEMENT P¡ ¡PUMP I SURFAC Pump 40 bbls biozan/nutplug spacer and 5 bbls H20. Test lines to 2500 psi. I I I I I I Drop bottom plug. Pump 50 bbls 12.5 ppg mud push spacer, 415 bbls 10.7 I I I I ppg lead cement and 49 bbls 15.8 ppg tail cement. Drop top plug. I 09:00 09:30 I 0.50 I CEMENT R /DISP SURFAC Dowell pumped 20 bbls H20. Displace with rig pumps with 9.6 ppg mud. I ! ¡ Bumped plug. 09:30 10:15 0.75 CASE P !DEQT SURFAC Test csg to 2500 psi fro 30 min. 10:15 11 :15 i 1.00 CASE P IRURD SURFAC RD cement head, bales and elevators. 11 :15 13:30 I 2.25 I CASE P I !NUND SURFAC ND surface riser, flowline, turn-buckles and mousehole. 13:30 14:30 T 1.00 ¡ CAS E P !NUND SURFAC Installed and tested FMC wellhead. 14:30 17:00 2.50 I WELCTL F NUND SURFAC Nippled up BOP. 17:00 21 :30 T 4.50 ¡WELCTL F ¡BOPE ISURFAC Tested Annular to 250/3500 PSI. Tested rams,choke lines, kill lines, choke I ¡ i and kill valves and floor valves to 250/5000 PSI. Tested IBOP to 250/5000 I i I I PSI. Test witiness waived by John Crisp State inspecter. i 21:30 22:00 0.50 DRILL P PULD I SURFAC Pulled tesr plug and installed wear bushing. 22:00 00:00 2.00 DRILL P IPULD SURFAC PJSM. Picked up and stood back 4" drill pipe from the pipe shed. 70 Jts I picked up. 24 HR SUMMARY: Ran and cemented 95/8" casing @ 3391'. Tested casing. Nippled down riser and nippled up BOP. Tested BOP. Picked up 4" DP and stand back in derrick. PERSONNEL DATA COMPANY ! SERVICE NO. HOURS I COMPANY I SERVICE T NO. HOURS i ConocoPhillips Company i 1 I Halliburton - Sperry-Sun I I 21 Fairweather E&P Service I 1 M-I Drilling Fluids I I 31 Doyon Drilling Inc I 25 Swaco I T 4 ! Dowell I 2 Arctic Catering Inc. I 5 Halliburton - Sperry-Sun I 21 FMC Corporation Wellhe I Halliburton - Sperry-Sun I T I Printed: 8/12/2005 2:11 :37 PM - ....... ~ Page 2 of 2 ConocoPhilli psAlaska,lnc. Daily Drilling Report . WELL NAME I JOB NUMBER I EVE~OC~DE 124 HRS PROG TMD rvD DFS I REPT N6O. ¡DATE CO2-57 3,401.0 2,384.0 3.70 5/19/2004 MATERIALS J CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel gals 1,185 6,387 Fuel, Camp gals 2,080 Water, Drilling bbls 980 1,015 Water, Potable bbls 120 1,040 RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE I COMMENTS C02-12 I CO2-57 1 2065 1 11300 Printed: 8/12/2005 2:11 :37 PM PRESSURE It.. _ ..,¿GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I C02-57 I Rig: Doyon 19 Dat!:~_~~Èku",-e Input Volul11e/S.!r_oke Pump Rate: Drilling Supervisor: _1_" _"__"_.. "~utri~':I~ __""_ TPump used: 1 #~ M~UI11-"---"-I':' Strokes ...... 0.1000 BbIS/Str1<...... 6.0 Strk,lmin .... Type of T~: J~~~~~ LOT/FIT 1...1 Pumping down 1 annulus and DP.... Casin Test Pressure Integrity T;;st Hole Size: 18-1/2" r ... Casing Shoe Depth I I Hole Depth PumpinQ Shut-in Pumping Shut-in RKB-CHF:I 36.7 Ft 3,391IJJ9-_fsJ/'-:8-~~-3D6#-/FtJ2_-S,3S7BT8JFcF:!::IVD I ~AºJlf!~MP J ~!.~ªj Ft-IV& Strkso psi 0 Min psi Strks psi Min psi Casinq Size and Description: 1"'1 0 2500 0 0 0 1050 Casino Test Pressure IntearitvTest 2 150 1 2500 2..,{) 80 0.25 1000 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 4 300 2 2500 4 '~;, 180 0.5 950 Mud 10 min Gel: 13.0 Lb/100 Ft2 Mud 10 min Gel: 13.0 Lb/100 Ft2 6 475 3 2500 6 y~- 370 1 800 Test Pressure: 2,500 psi Rotating Weight: 115,000 Lbs 8 650 4 2500 8 '''l>~ 550 1.5 720 - Rotating Weight: 75,000 Lbs Blocksrrop Drive Weight: 75,000 Lbs 10 850 5 2500 10 \: l"'720 2 Blocksrrop Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1025 6 2500 12 ~~'"'820 2.5 __~~~~U~~~~~__~~fu~~~~_~ ~~: ~:: ~:;: ~ EMW '= --Leak-off Pressure + Mud Weight = 1025. _ 96 PIT 15 Second 18 1475 9 2500 18 "~1025 4 0.052 x TVD 0.052 x,//2378 ~ Shut-in Pressure, psi 20 1625 10 2500 20 ~P1050 4.5 EMW at 3391 Ft-MD (2378 Ft-TV[!l..;;(17.9 PPd 1000 22 1800 15 2500 5 -.. :7 3000 ==~===-==-=::==~~~~===_-=::~' =~~:~s~~~~:~r:gtest.held 100% = ;: ;~~~ ;~ ;;~~ 5.~ : ~;i~~~~~~fJ~ ~~~~~ ;~ ;;~~ 30 2500 :.~ w .'u..._..__~._.__._·__ ------. .....-.--..------ ------ 8.5 i 1~ ~~~rij/f~~~i;-~~~~~ ~~~~~~ 91~ ': a~j-!f!f~ ;~~2lili o o 1 2 3 Barrels 4 o 5 10 15 20 25 Shut-In time, Minutes o PIT Point Volume Pumped 3.0 Bbls Volume Bled Back Bbls Volume Pumped 2.0 Bbls 30 ""'-CASING TEST ___LEAK-OFF TEST Comments: Tested 9 5/8" casing after bumping plugs on cement job. \.IvV 640 640 635 625 620 615 615 610 605 602 600 600 600 600 r .... Volume Bled Back Bbls ---- .~ CònocoPhillips Casing Detail 7" Casina Well: C02-57 Date: 5/26/2004 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 34.50 FMC Gen V Hanger 1.82 34.50 Jts 3 to 297 295 Jts 7" 26# L-80 BTCM Csg 12515.70 36.32 Davis Lynch Float Collar 1.32 12552.02 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.89 12553.34 Ray Oil Tools "Silver Bullet" Float Shoe 2.16 12640.23 12642.39 TO 8 1/2" Hole 12652.00 ; Total Centralizers: 53 Straight blade centralizer one per jt em jts # 1-12 Straight bi}de centraHzer one per jt em jts. # 217,218,219 Straight. blade centralizer one per jt on every other jûint Starting @ # 221 to # 295 305 joints in shed - 297 total jts. to run Last 8 jts. out Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 350 + k Dn Wt - 145 k Block Wt - 75k Supervisor: D.Mickey ConocoPhillips Alaska Casing Report Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING --,--_.._-- Report #: S ta rt: 2 5/14/2004 . . .----..,.. --.-,..-...----------------.--,-----,--. General Information String Type: Hole TVD: Ground Level: Circ Hours: 7,249.0 (ft) 15.90 (ft) 2.00 (hr) .----------,-.-.- Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Kelly Bushing 15.90 (ft) (ft) 30.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 8.500 (in) (ft) (ft) 34.50 (ft) Page 1 of 2 Spud Date: 5/16/2004 Report Date: 5/25/2004 End: 6/4/2004 - -- - -. Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 12,652.0 (ft) (Ibs) 81.19 n 9.70 (days) Casing Flange I Wellhead --_._.,----------_..,------_._---_.,---~--,------_. Model: Unihead Packoff Model: ..---------------.. - -------.,---.---- ----_..,._---------------,------------,-_._-,_...,._----------- -.',------- -.,.-,..-,..,..-- ...-_._-,,-_._------- Integral Casing Detail Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer (Ib/ft) (in) (ft) (ft) (ft-Ibf) 1.82 34.50 26.00 L-80 6.151 BTC-MOD 295 12,515.70 36.32 26.00 L-80 BTC-MOD 1.32 12,552.02 Y WEATHERFORD 26.00 L-80 6.151 BTC-MOD 2 86.89 12,553.34 Y L-80 2.16 12,640.23 Y RAY OIL TOOLS ------ ---- '"--. Non-Integral Casing Accessories Manufacturer Number Spacing (ft) -----------------.----.,.-..-,..-.,.---..-.-,---------.,----.,. ___,__..,_____,_._______________________.ø_,_ø,_._,_________,______.________.____,_"'___.ø_.__,ø__._.._.,_,ø__._____,_..__,______..__.______,___________·_·_,·_·_________ Manufacturer: FMC Hanger Model: ..__ø. ,-- Actual TMD Set: 12,642.39 (ft) Item Size (in.) 7.000 7.000 7.000 7.000 7.000 Casing Hanger Casing Float Collar Casing Float Shoe -,-- -- Accessory Centralizer Centralizer Centralizer --...- RAY OIL TOOLS RAY OIL TOOLS RAY OIL TOOLS 12 3 38 Top Hub/Flange: (in) 1 5,000 (psi) BTM Hub/Flange: (in) / 5,000 (psi) - ___ ~__Ø_'M__.____ Remarks Model Cond, Max OD Min ID Compo Name (in) (in) Casing Hanger 6.276 7" 26# L-80 Cas 6.276 Float Collar 6.276 7" 26# L-80 Cas 6.276 Float Shoe ,--.---.--- ---'--........--.......-.-.-..-... 1-- Interval -- How Fixed Top (ft) 12,136.0 3,353.0 121.0 Bottom (ft) 12,640.0 Floating 3,437.0 Floating 3,267.0 Floating _ø____._ ________.._,_.__ Ran 7" 267# L-80 MBTC casing as follows: FS ( Ray Oil Tools Sliver bullet) 2 jts. .. FC (Weathertord) 2 jts. ( SakerLoc first 4 cnnections - fill pipe & check floats) 76 jts. to 3376' (80 jts. total) .___ø____________·________ Circulate casing volume @ 4 BPM @ 300 psi - PU wt. 135 SO wt. 113 Printed: 8/12/2005 2:28:34 PM ConocoPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING Report #: Start: 2 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/25/2004 End: 6/4/2004 Remarks Continue running 7" 26# L-80 MBTC casing f/ 3376' to 7206' ( 170 jts. total) Circulate bottoms up + 4 BPM @ 520 psi FCP - PU wt. 215 SO wt. 135 Continue running 7" 26# L-80 MBTC casing fl 7206' to 11,240' (265 jts. total) Circulate bottoms up + @ 4 BPM @ 680 psi FCP - PU wt 355 SO wt. 140 Continue running 7" 26# L-80 MBTC casing fl 11,240' to 12,606' (297 jts. total) - PU hanger & landing jt. - land casing w/ FS @ 12,642' FC @ 12,552' - string took excess wt. @ 11,370' 15 to 20 k - worked through tight spot w/ 35 k down - ran 2 jts. wI no returns - stab in & attempt to circulate - work pipe - had slight returns @ 3.5 BPM @ 490 psi - Ran in hole w/ remaining 27 jts w/ no returns - SO wt. 160 to 135 ~ - Printed: 8/12/2005 2:28:34 PM Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 12,642 (ft) Date Set: 5/25/2004 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 40.00 Meas. From: N/A Time Circ Prior To Cementing: Mud Circ Rate: (gpm) Mud Circ Press: (psi) ConocoPhillips Alaska Cementing Report Report #: Start: Cement Job Type: Primary I Saueeze Open Hole Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Cmtd. Csg: RPM: SPM: 2 5/14/2004 I Saueeze Casino I Hole Size: I I TMD Set: ¡ Date Set: I I Csg Type: SQ TMD: II SQ Date: Cmtd. Csg: Cementer: Steve Daughten Pipe Movement Init Torque: Stroke Length: (ft-Ibf) (ft) Stage No: 1 of 1 I Start Mix Cmt: 01 :20 'I Start Slurry Displ: 01 :20 Start Displ: 01 :39 I End Pumping: 03:00 III End Pump Date: 5/26/2004 Top Plug: Y ! Bottom Plug: Y Type: LSND 1 Glydril Density: 9.8 (ppg) Visc: 39 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Disp Avg Rate: Disp Max Rate: Bump Plug: . Press Prior: Press Bumped: Press Held: Float Held: Mud Data Pipe Movement: Avg Torque: (ft-Ibf) Drag Up: (lbs) 6.00 (bbl/min) 6.00 (bbl/min) Y 6,200 (psi) 1,100 (psi) 5 (min) Y Page 1 of 3 Spud Date: 5/16/2004 Report Date: 5/26/2004 End: 6/4/2004 Plug I Hole Size: I Top Set: (ft) I BTM set: (ft) Plug Date: I Plug Type: i¡ Drilled Out: Cmtd. Csg: Max Torque: (ft-Ibf) Drag Down: (Ibs) I Returns: 10 Total Mud Lost: Cmt Vol to Surf: 600.00 (bbl) (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer PV/yP: 9 (cp)/17 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.8 (ppg) Volume: 456.00 (bbl) Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: CW100 Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Density: 8.30 (ppg) Water Vol: (bbl) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Class: Yield: (ft3/sk) Other Vol: 0 Purpose: Chemical was Mix Water: (gal) Foam Job: N Temp ("F) (OF) Pressure (psi) (psi) Printed: 8/12/2005 2:12:20 PM ~ ConocoPhillips Alaska Cementing Report Legal Well Name: C02-57. Common Well Name: C02-57 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) . Page 2 of 3 Report #: Start: 2 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/26/2004 End: 6/4/2004 Stage No: 1 SlurryN(): 2 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 40.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Tempnrature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Stage No: 1 Slurry No: 3014 Temperature: (OF) Temperature: (OF) Temperature: (OF) Slurry Data Fluid Type: LEAD Description: LiteCRETE Slurry Interval: 11,270.00 (fIþ: 10,345.00 (ftçmt Vol: 43.0 (bbl) Water Source: lake water Slurry Vol:72 (sk) Trade Name D167 B155 D-65 D-46 Class: Density: 11.00 (ppg) Yield: 3.30 (fP/sk) Water Vol: 18.9 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 Slurry No: 30f 4 -Additives Tvee fluid loss retarder DISPERSANT DEFOAMER Liquid Conc. Concentration Units 0.2e %BWOC 0.01 %BWOC 1.0C %BWOC O.4C %BWOC Stage No: 1 Slurry No: 40f4 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 12,642.00 (ff):>: 11,900.00 (ftÇmt Vol: 31.0 (bbl) Water Source: lake water Slurry Vol:148 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: CF) Temperature: (OF) Tempørature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.16 (fP/sk) Water Vol: 17.9 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 11.06 (gal) Foam Job: N Pressure (psi) (psi) Units Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Pressure (psi) (psi) Printed: 8/12/2005 2:12:20 PM ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: C02-57 l Common Well Name: C02-57, Event Name: ROT - DHILLlNG Report #: Start: 2 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/26/2004 End: 6/4/2004 Stage No: 1 Slurry No: 4 of 4 - Additives Trade Name Type , . DISPERSANT retarder DEFOAMER Fluid loss Concentration Units I 0.3C %BWOC 0.07 %BWOC 0.2C %BWOC OAC %BWOC Liauid Conc. Units D-65 B-155 D-46 D-1 67 Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: Ilf Unsuccessful Detection Indicator: ¡Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Cement 7" casing as follows: Pumped 1J bbls CW-100 @ 4BPM @ 400 psi - Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 psi - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug wi 20 bbls water fl Dowell - Switch over to rig pumps & displace wi 456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug w/11 00 psi - Check floats - floats held - CIP @ 0300 hrs. Observed slight flow @ flow line during job wi flow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bur1ped Printed: 8/12/2005 2:12:20 PM - "--" Page 1 of 2 ConocoPhillips Alaska, Inc. Daily DrilUngReport . WELL NAME JOB NUMBER I EVENT CODE 124 HRS PROG TMD ITVD I DFS I REÞT NO. DATE CO2-57 ODR 12,652.0 7,249.0 10.70 13 5/26/2004 SUPERVISOR I RIG NAME & NO. I FIELD NAME / OCS NO. AUTH MD IDAlLYTAN~ CUM. TANGO D. Mickey Doyon DrillinQ Inc 19 ALPINE 17,259.0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/ MUD Rig maintenance 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Rig maintenance 5/10/2004 221,105 2,477,388 LITHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE AUTH. FINE SAND 17.67 10033832 lAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 5/24/2004 12,583.37 81 . 190 152.760 7.000 (in) @ 12,642.0 (ft) 4.500 (in) @ 12,012.0 (ft) 5/26/2004 DENSITY(ppg) I 9.80 I PP I ECDI I MUD DATAl DAILY COST I 0 I CUM COST I 0 FV PVIYP I GELS WUHTHP I FCrr.SOl I OILlWAT I %SandIMBT I Ph/pM I PflMf I CI I Ca I H2S I LIME I ES 39 9/17 I 7/9 4.6/9.4 I 11 I 1 I 0.2/15.0 I 8.51 I 0.05/1 I I 20 I I I OPERATIONS SUMMARY . FROM TO HOURS CODE TROUBLE SUB PHASE . DESCRIPTION 00:00 00:45 0.75 CEMENTF CIRC INTRM1 Attempt to regain circulation @ 2 to 4 BPM @ 520 psi - Observed slight ftow @ flow line - PJSM on cmt procedures 00:45 03:15 2.50 CEMENTF PUMP INTRM1 Cement 7" casing as follows: Pumped 10 bbls CW-100 @ 4BPM @ 400 psi- Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 ps - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug w/ 20 bbls water fl Dowell - Switch over to rig pumps & displace wI 456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug wI 1100 psi - Check floats - floats held - CIP @ 0300 hrs. Observed slight flow @ flow line during jOb wI ftow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bumped 03:15 04:00 0.75 CEMENT F OTHR INTRM1 Test 7" casing to 3500 psi for 30 mins. 04:00 04:45 0.75 CEMENT F RURD INTRM1 RD cement lines, cmt head, casing elevators, & landing jt. 04:45 05:45 1.00 WELCTL F OTHR INTRM1 Pull thin wall wear bushing - Install 7 x 9 5/8" pack off & test to 5000 psi 05:45 06:45 1.00 WELCTL F EQRP INTRM1 PJSM - Change top pipe rams fl 7" back to 31/2" x 6" VBR 06:45 11 :00 4.25 WELCTL F BOPE INTRM1 RU & test BOPE - Hydril to 250 & 3500 psi - Pipe rams, blind rams, kills & choke line valves, choke manifold valves, TO IBOP's, Floor & dart valves to 250 & 5000 psi - performed accumulator closure test - witnessing of test was waived by Jeff Jones 11:00 11 :30 0.50 WELCTL F OTHR INTRM1 Pull test plug - install wear bushing - LD test jt. 11 :30 12:00 0.50 DRILL P OTHR INTRM1 PU drill bails & 4" elevators 12:00 16:00 4.00 DRILL P PULD INTRM1 PU & RIH wI 159 jts. 4" drill pipe f/ pipe shed (to drill 6 1/8" section) 16:00 17:00 1.00 RIGMNT P RSRV INTRM1 PJSM - Slip & cut 90' drill line 17:00 19:30 2.50 DRILL P TRIP INTRM1 POOH w 4" drill pipe & stand back in derrick (SLM) 19:30 00:00 4.50 RIGMNT N:) OTHR INTRM1 Due to rising water from break up & possibility of road being washed out between CD1 &CD2 - decision was made to suspend drilling operations & perform rig maintenance while monitoring water conditions Prep mud pits for some repairs - clean & service euqipment 24 HR SUMMARY: Attempt to circ for cement job - no returns - Cement 7" casing - Test casing to 3500 psi - set & test pack-off - Test BOPE - PU 4" DP - Slip & cut drilllline - POOH & Std. back DP - Rig maintenance Printed: 8/12/2005 2:11 :52 PM Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME ! JOB NUMBER I EVENT CODE 124 HRS PROG ITMD TVD IDFS I REPT NO. DATE CO2-57 I I ODR 12,652.0 7,249.0 I 10.70 13 5/26/2004 PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS Fairweather E&P Service 1 ! i M-I Drilling Fluids 3 Doyon Drilling Inc 26 ! ¡ Swaco i 4 Dowell 2 ¡ Arctic Catering Inc. 5 Halliburton - Sperry-Sun i 2 I ASRC Energy Services ( 2 Halliburton - Sperry-Sun 2, I Epoch Well Services Inc 21 MATERIALS I CONSUMPTION ITEM UNITS I USAGE I ON HAND ! ITEM UNITS USAGE ON HAND Fuel gals I 1,840 I 7,430 ! Fuel, Camp gals 2,130 i Water, Drilling bbls I 1,190 I -305 ¡ Water, Potable bbls 120 640 I RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE I COMMENTS CD2-12 I CO2-57 i 766 3.9 11250 Printed: 8/1212005 2:11 :52 PM PRESSURE IN I ':GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I C02 -57 I Rig: Doyon 19 Date: 5/26/2004 Volume Input Pump Rate: Drilling Supervisor: Don Mickey IPump used: I Cement Unit I~ Barrels .. Bbls/Strk .. 0.8 Bbl/min . Type of Test: \ Annulus Leak Off Test for Disposal Adequacy ... I Pumping down I annulus. \... Casin I Test Pressure Integritv Test Hole Size: IS-1/2" \. Casing Shoe Depth I Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 34.7 Ft 3.391 -Ft-MD 2,378Ft-TVD 10.345 Ft-MD 6,135IFt-TVD Bbls psi Min psi Bbls psi Min psi Casino Size and DescriDtion: \9-5/8" 36#/Ft J-55 BTC 1·[ 0 0.5 240 0 727 Chanoes for Annular Adeauacv Test Pressure IntearitvTest 1 1 250 0.25 487 outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1.5 275 0.5 446 Description references outer casing string. Inner casing 00: 7.0 In. 3 2 315 1 425 f)ize is that drilled below outer casing. 4 2.5 370 1.5 f titimated TOC for Hole Depth. 5 3 411 2 3~"'1' Enter inner casing 00 at right Desired PIT EMW: 15.5 ppg 6 3.5 455 2.5 386 Estimates for Test: 705 psi 0.7 bbls 7 4 497 3 380 1·1 . 8 4.5 540 3.5 374 EMW = Leak-off Pressure + Mud Weight = 864___ 9 8 PIT 15 Second 9 5 582 4 370 0.052 x TVD 0.052~ã) . Shut-in Pressure, psi 10 5.5 621 4.5 366 EMW at 3391 Ft-MD (2378 Ft-,vpt; 16.'8 487 15 6 662 5 363 / ----........ 20 6.5 1000 tf - 698 5.5 360 25 7 737 6 357 -'iL 30 7.5 776 6.5 356 I~- -- ...... -- 8 810 7 353 / ~. 8.5 842 7.5 351 9 864 8 349 JI r ~~ w ~~ 9.5 842 8.5 346 D:: V 10 838 9 346 :J ~--- tJ) 500 10.5 835 9.5 ~.A' tJ) / ." 'I. W '11~~1l 11 830 10 \ D:: 11.5 764 - Q. I~ ""!IIIIIII!lllml:1 ¡'IIIIIIII'!IIIIIII!I:IIII!IIIIIII ~ V f- r 12 727 .... h. rc.~' IJ/P" '( 0 0 2 4 6 8 10 12 14 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ~CASING TEST ___LEAK-OFF TEST 0 PIT Point PumDed Bled Back Pumped Bled Back 0.0 Bbls IBbls 12.0 Bbls IBblS Comments: 95/8 LOT = 17.9 PPG EMW PRESSURE INTt::GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I C02-57 Rig: Doyon 19 Date: _1_~~~/2~~5 ~_olume Input Pump Rate: Drilling T:::e;~:;J~~~þ-;-~:~;~~~;U:~----1 T II ::::i::e:~W~ I:::~~~~ ----- T~ Barrels :;ng Test ~ls/~Uk I-:ressur:;:t::i~~ J ... Hole Size: 18-1/2" I'" Casing Shoe Depth I I Hole Depth Pumping Shut-in Pumping Shut-in RKc':~~:~ize an:~:'::~iPtion: 3,3911~iiï;:;~;~7~-J-1Q,345 Ft-MD J -E>,1}ti[F:t:!VÄ Bbls psi Min 0 psi BblSO P~71 Min 0 ~~90 Chanaes for Annular Adeauacv Test Pressure IntearitvTest 1 0.4 621 0.25 1020 þuter casing shoe test results in comments Mud Weight: 6.8 ppg 2 0.8 649 0.5 973 Description references outer casing string. Inner casing 00: 7.0 In. 3 1.2 690 1 970 I>ize is that drilled below outer casing. 4 1.6 730 1.5 qSO ~timated TOC for Hole Depth. 5 2 780 2 Enter inner casing 00 at right Desired PIT EMW: 17.0 ppg 6 2.4 830 2.5 I .---.,..".-.--.-. '1-;-'1 _.___..___É~!.~~.~te.~_!~.~_!~~!.: J~_t.e.~i_ ..t~·~þ·T~ ~ ~:~ ~~~ 3.~ ~Ñlw = Leak-off Pressure + Mud Weight = 1120 _:)68 .- PIT 15 Second 9 3.6 1060 4 0.052 x TVD 0.052 x '-~378' Shut-in Pressure, psi 10 4 1120 4.5 EMW at 3391 Ft-MD (2378 Ft-TVDl ~.,4~5.9 1020 15 4.5 1129 5 . -~- . _____H__ --- -~ ---6L-- f- 20 5 1129 5.5 :--------'---- "Ji3;=~= _~~=~~_=H=_=~ F =t u-' --~ - --: -:-~::::-:= ~g ::~ m~ ::~ 1000 ===--- ~Y-~ -___~_ ___~_______ . -=-t - 7.5 1090 8 ~ ___"" _ .. _ m__ ____ ~~U_ H -----:iZil¡\Y\: 8 1090 8.5 ~ --..--~_-..'_..-_-.._,._..£_.,._~-..._'...,....-,._.-"...._.-.- ..,.-.. .m__ ----. _.._~._'_._<:'\.-V:~Ì -'1- 91';0 en ~___ __ ____.___ ___._________ _.___.___._ _______ __. ___.~ ~~,-.\..m- ______+______ ~ I~' -.--- ... .-.--.-.. ~.. __._""..__m._m._._ _____m._ - 1500 500- on.._. __._._.................. I..· --. . ... .. ....... --.....---...-- -..·--..--·..---·1··........··· .-. ..... ._-----,- - . -.-.".-- --.- f--.---..--- -.- .----- --.---".---. ---.-.-.--.- --.- ---------- -' . --_.-.--- --"'"-.---..... ~._..- .-.-..-..-... - --...---.- -,_..,- --." -. '" .-.... _.n _.,,,.,,,,._,~..___".,,, . ....,... _~....."._ _ _ . ,,,____. ,,_. ,._._ ". .'_,__'.. ,,_ --"" ..,-----"._- _,,__..._._.,...._.__._ . _.wn _,.,_,.....~ ,_____ -,,-,._..._._,- -....-.-.. ..-- --.------.-",... ..., -,-- -- - .-- - _.'-.-.'",-,,- .....-.- ..------- --- _..-.. .... ...- ..- -., ---.-.-...".---. --.---...-..... . --. - -- "....".--... ~._... "-,--,,-- -.-.--.......-- -"- .-..--- .,----.-,,-."-...- ---. -.. -"-"-"'-"" .. - --."'. --",-,-- - ..' -.--.....--.--.,-..,. -.-..,- --,_._-- '_"'_."_"..__h'" _...,__._ ..___ _...._.._ n_", _'_.n_ __ o o 1 2 3 6 7 8 4 Barrels 5 9 o 5 10 15 20 25 Shut-In time, Minutes o PIT Point 30 Volume Pumped 0.0 Bbls Volume Bled Back IBbls Volume Pumped 8.0 Bbls Volume Bled Back IBbls .....CASING TEST -II- LEAK-OFF TEST Comments: Used Ball Mill Injection pump for job ~MÕ 920 919 910 910 910 900 900 890 880 870 860 860 850 850 pr:'f) I - - CIIIouIoIIon _ Mlnmum CUIwUo Enar II)<otom: ISCWSA Sc:on _ T..... CyIIndor Nof1h ~~~~Ic GoodoIIo DoUn: /W) t927 ¡NADCON COIf.JS M..,.& _ 9OO'ØI04 ""'''''-'''..·........'·;;;:;öïiãÄL9''''·'·",··"'',..,,,,·,,''''''',·,,''''''''''''',,·,,'''""..,,,,,,,,,"'''',,,,...,,,,''','''.,,.''',,.,.,.,,,,,,,,''',,,,.,,,,,,''',,,..''',,,...''',,.,"'"".".""',"'.""......."..""'""."",."."""..,,,,,.,...,,,,,,.....,,,,"'.."'·1 ! I . I I I I ! fi I i I ï ! .~ - ( I ! 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ConocoPhillips Alaska I HALLIBURTON Speny Drilling Services i I I I I i I I I I i i I I I ~ I ! , ¡ i : .111111I11I11I11I1111111111111111I11I11I11I11I11I11I11I11I111I11I1111I11I111111I11I1111111111I11I11I11I11111111I111111111I1111I1111I11111111111111I11I1111I1111I1111I11I1111I111I111111I111I111111I11I1111I11I11111111I11I111111I1111I11I1111I111I11111111I111111I11I11I111111111111I111I11I1111I11I1111I111I111111I11I111111I11I11I11I11I1111I1111I1111111111I1111I11I11I11I1111I11111111I11I11I1111I11I11I1111I11I1111I11I11111111111111I11I111111I11111111I111111I11I111111I1111I111111111111I11I11I1111I111111I11111111I1111I11I1111I11111111I11I11I11111111I1111I111I11I"11I1111I11I11111111I1111I111I1111I11I111111111111I11I111111I1111I11I1111111I11I1111I11111111I11IIIIlIlIUlllllllllllllltllllllllUlIlIIlIUllllllllllllllUlllIIlIlIlIlIlIIlIlIIlIlIlIlIlIlIlIIlIUif ê ~ o In .... :::: -1 &10 + € o ~ 'Î' :c ....E::J o UJ Project: Colville River Unit Site: Alpine CO2 Well: CD2..s7 Well bore: CD2-57 No 1\'1) MD Non-. _ , Z3B3.IIIIZ 3«II.IJOO IIW' ~ r;rour:d :"'n~'Çt¡: !J coo RKB CO2-57: ~ 52.B¡:,;t~ ¡CD2·,';"1 ) N,,,til,n¡¡'Asr '/: 5')1~;>2-t2\iOO (a'lI1PE:¡\SP x: 37,740.5':~~ CD2...57 o ( -7fIJ -22fIJ -3000 ... ......... .................................. -37fIJ -3000 -1&10 o West(-)/East(+) (750 ftlin) I ¡ ! ï ! I ~ ¡ ! c I ~ ¡ I I ! ! ¡ I I ~ ¡ I I ~ I I i I ~ ..- I ~ ê ¡ ~ ¡ ~ I ª ~ ~ ! ~ ! ~ ¡ -19JO 1CXXJ ¡ i West(-)/East(+) (500 ftljn) i ! ¡: - - :: E - - - - - - - - - - illlllllllllllllllllllllllllllllllllllllllll"'''IIIIIIIIIIII'"1111'11I111111111"11I1111111111'111111111111111111111111111111111'"111111111111I1111111111111111111111111111111111111111111'11111111111'1'1'11111111111111111111'11111111111111111111111111111111111111111111111111111111111111111111111111111111,"11"'1111"111111111111111111111111111111111111111111'11I1111111111111111111111111111111'111111111111111111111111111111111'11111'11111111'''''1111111111111111111111111'1111111111'1111111111111111111111111111'11111111111111111111I11111111111'1'111111111111111'111111'111111111111111'11111111111"11I'1111111111111111111'11'11111111111111IIIIIIIIII'UIIIIIIIIIIIIIIIIIIII'IIIIII'II'IIII'"III"IIIIII'Il'II""I"I'III"IIIIIIIIII'I"""III'I",i ··......................·.."..·..,....CÄšiNÕïiËT;;;L.š""..."·.."""',,·,,"""',,...,""",,..·,,·"....""..,.....".."..,......."..,..",,,,,..,,,,,,,,,,,,..,,..,....,...........................""",...","'.."""....."".."..,..,.."........""........"",..."...".........,.........."................".."..............·.......1 No 1VD MD N..... sm, ~ 1 2383.002 3«I1.1D1 9 511'" _ . ~ ~ ~ i 5 ª jj I 5 I ! I ~ ~ ~ o o ~ +' € o ~ -2000 :E '5 o en -1500 -1 CXXJ Project: Colville River Unit Site: Alpine CD2 Well: CD2-57 Well bore: CD2-57 :11111I...111.............'1.'11.."''''''11111'...11111..''.1..111.11''....''.11'10'"11'''11''''''''''_'''''11'111I1'''11''''''''''''1''11''11I''11''''''"1111II1II""II''''I''''I''''''IOI.....,,'''llltlIIIIII''"II'''IIIII'''I'''''I''I''''"..,Il'."''''..I...I..'iillllll....II..I.ttU.U.I.UU1WUW'....''I.''IIIIII''.llil...111...111.. I .'\11I". f . Calculation Method: Minimum CU_ i ConocoPhilllps ~~~E I Alac,ka GooœIIo~~~CCWS) ¡ ~ I HALLIBURTON I Sperry Drilling Services ! î I I ~ I ~ I -500 CD2-57 ~---" SURFACE CASING SHOE SEPARATION FROM CD2-57 CD2·57 x y Suñace Casing Shoe ASP 4 Coordinates: 372537.05 5972324.37 LlIStanCe Details from Surface csg. Surface csg. @ Ann. Object Shoe X Shoe Y Wells AOGCC Permit # Permit Date Source well Vol.**** Start Date End Date well· Coarct Coord. C02-35** ----- ---- --- ---- --- 1708 372312.31 5974017.68 C02-24, C02-33, C02-33A, C02-42 v 301-140 6/1/2001 C02-15 33992 6/1/2001 10110/2001 2203 371098.46 5973992.48 C02-33 (+A&B), C02-39. C02-24 v 301-186 7/13/2001 C02-14. C02-15 33999 7/16/2001 10/9/2001 3063 370630.11 5974721.81 C02-33 BU. ---- ----- --- ---- ~ 2848 370155.64 5973886.23 C02-39 v 301-281 10/9/2001 C02-15. C02-47, C02-44 29945 10/10/2001 9/16/2002 1322 372350.61 5973633.17 C02-14 v 301-288 10/9/2001 C02-45. C02-47, C02-32 31073 11/13/2001 315/2002 2658 372202.47 5974960.87 C02-15 v 301-308 11/612001 C02-50. C02-25, C02-44 31652 3/6/2002 9/21/2002 3159 370832.00 5974984.02 C02-47 v 301-322 12/3/2001 C02-34. C02-26 27349 12/17/2001 1/20/2002 1626 371231.72 5973294.19 C02-45 v 301-345 12/13/2001 C02-49. C02-17 22991 1/20/2002 2/19/2002 1546 372765.13 5973853.74 C02-34 v 302-069 3/4/2002 C02-13. C02-37 22842 10/17/2002 11/28/2002 2239 371803.06 5974439.79 C02-26 v 302-068 3/4/2002 C02-44, C02-29, C02-13 29626 9/7/2002 10/17/2002 2349 371798.52 5974554.55 C02-49 v 302-070 3/4/2002 C02-50. C02-46, C02-22 27960 4/22/2002 5/28/2002 2164 371252.38 5974065.93 C02-17 v 302-122 4/10/2002 C0-48, C02-o8 18181 5/29/2002 217/2003 2443 371774.00 5974645.00 C02-32 v 302-119 4/30/2002 C02-19. C02-41. C02-23 31113 6/14/2002 7/23/2002 2335 371295.61 5974302.38 C02-41, C02-19. C02-16, CO2-50 v 302-121 4/30/2002 C02-38 32000 7/24/2002 9/7/2002 2093 371665.21 5974227.65 C02-25 v NA 2352 371594.00 5974479.00 C02-46 v 302-273 9/20/2002 C02-51, C02-12 31864 4/15/2003 5/19/2003 2158 371694.80 5974310.85 C02-22 v 302-274 9/20/2002 C02-08. C02-36. CO2-51 31253 21712003 3/16/2003 2397 371678.61 5974562.30 C02-28. C02-35a. C02-48 v 302-275 9/20/2002 C02-45, C02-o8 32000 12/10/2002 2/4/2003 1677 371631.74 5973736.14 C02-19 v 303-083 4/28/2003 C02-58. CO2-52 31337 5/19/2003 6/27/2003 2370 372284.88 5974681.33 C02-41 v 303-081 4/28/2003 C02-20. C02-55,C02-43 32000 6/27/2003 7/28/2003 1576 371990.58 5973802.52 C02-23 v 303-080 4/28/2003 C02-18, C02-55. C02-o6 32000 9/4/2003 1/1/2004 3141 371013.17 5975070.46 C02-16 v --- ---- ---- ---- ---- 2467 372460.34 5974790.01 C02-38 v 303-082 4/28/2003 C02-40. C02-30 30011 7/28/2003 9/4/2003 1304 372033.86 5973527.13 C02-44 v --- ---- ---- --- --- 2066 372034.57 5974328.53 C02-29 v 303-249 8/25/2003 C02-o6. C02-3D. C02-27 29036 10/8/2003 11119/2003 2574 372652.44 5974896.02 :;02-13 v ---- ---- --- --- ---- 3463 372658.78 5975785.31 C02-37 v --- ---- ---- --- --- 1113 371569.79 5972874.47 C02-28 v ---- ---- ---- ---- ---- 2437 372139.80 5974728.95 C02-o8 v --- ---- --- ---- ---- 3282 372655.88 5975603.76 C02-36 v 303-365 12/12/2003 C02-43, C02-31, CO2-57 32000 12/31/2003 7/9/2004 1393 371848.22 5973535.38 CO2-51 v 303-312 10/28/2003 C02-o7. C02-10 31769 11/19/2003 12/24/2003 1231 373114.02 5973411.81 C02-12 v 303-365 12/12/2003 C02-57. C02-31 32000 5/15/2004 6/14/2004 3448 371071.29 5975445.60 CO2-58 v NA 548 372102.03 5972657.80 CO2-52 v NA 1341 372637.61 5973661.63 C02-20 v 304-288 7/30/2004 452 3391 371366.14 5975507.11 CO2-55 v --- --- ---- --- ---- 1665 371118.23 5973194.84 C02-40 v NA 0 2364 370691.67 5973801.44 C02-30 NA 0 2432 370473.52 5973610.96 C02-18 --- ---- ---- ---- ---- 3615 369825.76 5974716.05 C02-o6 v NA 0 3808 371610.81 5976018.45 C02-27 v 304-226 6/23/2004 C02-53, C02-o5. C02-o9 32000 71912004 8/27/2004 904 373046.07 5973071.83 C02-10 v 304-289 7/30/2004 C02-09, CO2-56 30703 8/27/2004 10/15/2004 3755 371800.58 5976006.36 C02-o7 v NA 0 3976 372218.06 5976287.95 C02-43 --- ---- ---- --- --- 2498 370344.04 5973520.68 CO2-57 v NA 0 0 372537.05 5972324.37 C02-31 NA 0 3447 369824.37 5974451.30 CO2-53 v 304-361 9/30/2004 C02-56. CO2-54 20350 10/3/2005 10/22/2005 404 372896.67 5972509.19 C02-o5 NA 0 2680 370258.60 5973735.40 C02-09 v 304-362 9/30/2004 NA 382 4500 370318.00 5976239.00 CO2-56 NA 0 2759 369875.93 5973053.08 CO2-54 NA 0 2750 369991.09 5973363.59 C02-21 3700 370286.77 5975261.48 CO2-59 3363 369650.94 5974049.86 C02-60 1268 371269.33 5972336.05 C02-o3 4431 371040.60 5976495.42 C02-o2 4885 369463.97 5976121.87 C02-o1 C02-11 C02-D4 * Lateral distance in feet, between suñace casing shoes. in the X-V plane - C02-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been pennitted for annular disposal. -*C02-33 8 was a delineation well with a window milled out of 9-5/8" casing at 3840' MO (3062' TVO), shoe depth shown indicates window depth. It has not been pennitted for annular disposal. **** As of 07-29-05 Note that this sheet is not the definitive record Conoc~hillips Casing Detail 9 5/8" Surface Casina Well: Date: CD2-60 6/10/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.37 FMC Gen V Hanger 2.22 36.37 Jts 3 to 78 76 Jts 9-5/8" 36# ·J-55 BTC Csg 3149.96 38.59 Weatherford Float Collar 1.50 3188.55 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 84.05 3190.05 Ray Oil Tools "Silver Bullet" Float Shoe 2.27 3274.10 3276.37 TO 12 1 í4" Surface Hole 3286.37 TOTAL BOWSPRING CENTRALlZERS-44 1 per jt on 'Jt #1 - #12 (stop ring on Jt #1 & 2 ) and over collars on jts# 14,16,18,20,22,24,26,28,30, 32,34,36,38,40,42,44,46,48,50,52,54,56,58,60,62 64,66,68,70,72,74,76 84 joints in the pipe shed. Run 78 joints - 6 joints stay out Use Best-o-Life 2000 pipe dope MU torgue, - 8600 ftllbs Remarks: Up Wt - k Dn Wt - k Block Wt - 75k Supervísor: Míckey / Hí/I ConocoPhillips Alaska Page 1 of 2 Casing Report Legal Well Name: CD2-60 Spud Date: 6/8/2005 Common Well Name: CD2-60 Report #: 1 Report Date: 6/10/2005 Event Name: ROT - DRILLING Start: 6/7/2005 End: 7/10/2005 General Information String Type: Surface Casing Permanent Datum: Rotary Table Hole Size: 8.500 (in) Hole TMD: 3,286.0 (ft) Hole TVD: 2,377.0 (ft) KB-Datum: 15.90 (ft) Water TMD: (ft) Str Wt on Slips: (Ibs) CFEle'vation: '17.87 (ft) .. . ... ~. ¡'- Ground Level: 15.87 (ft) Liner Overlap: (ft) Max Hole Angle: 62.00 (0) Circ Hours: 1.25 (hr) Mud Lost: (bbl) KB to Cutoff: 36.4 7 (ft) Days From Spud: 2.75 (days) Casing Flange I Wellhead Manufacturer: FMC Model: Alpine Unihe Top Hub/Flange: (in) / 5,000 (psi) Hanger Model: Packoff Model: BTM Hub/Flange: (in) 1 (psi) Actual TMD Set: 3,276.47 (ft) Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Condo Max OD Min ID Compo Name (in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf) (in) (in) Casing Hanger 2.22 36.47 Casing Hanger Casing 9.625 36.00 J-55 8.765 BTC 76 3,149.96 38.69 8.921 9 5/8" 36# J-55 Float Collar 9.625 J-55 BTC 1.50 3,188.65 Y WEATHERFORD Float Collar Casing 9.625 36.00 J-55 8.765 BTC 2 84.05 3,190.15 Y 8.921 9 5/8" 36# J-55 Float Shoe 9.625 J-55 BTC 2.27 3,274.20 Y RAY OIL TOOLS Float Shoe ( Non~lntegral Casing Accessories , Accessory Manufacturer Number Spacing Interval How Fixed (ft) Top (ft) Bottom (ft) Bowspring Centralizer WEATHERFORD 1 3,266.0 3,266.0 Clamped Bowspring Centralizer WEATHERFORD 1 3,230.0 3,230.0 OverCollar Bowspring Centralizer WEATHERFORD 1 3,215.0 3,215.0 Clamped Bowspring Centralizer WEATHERFORD 10 2,768.0 3,145.0 OverCollar Bowspring Centralizer WEATHERFORD 31 121.0 2,685.0 OverCollar Remarks Run 9 5/8" 36# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats - first 4 connections made up w/ BakerLoc) 41 jts. csg. for 45 total to Printed: 8/12/2005 2:09:29 PM ConocoPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 1 6/7/2005 Spud Date: 6/8/2005 Report Date: 6/10/2005 End: 7/10/2005 _._--,-- ---'--------_._-------------._,_.__._--.---,---,._---~--.---..- Remarks ---.---'-- - _.".,-"-----_.".._".._._~,-,_._"-,---~---_._----_._-.~-,_..__.."-"..."-,.."-,,_.._-". --.-.-------------.--,-------.----,.----,-------- 1885' Break circulation - circulate btms up + Continue running 9 5/8" 36# BTC csg. f/1885' to 3,276'. Total jts. run 78 - Landed casing @ 1800 Hrs wi shoe @ 3276' & FC @ 3188' Printed: 8/12/2005 2:09:29 PM -- ConocoPhillips. Alaska Cementing ;Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 3,276 (ft) Date Set: 6/10/2005 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 300.00 Meas. From: 200 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 440 (psi) . Report #: Start: 1 6/7/2005 Cement Job Type: Primary Squeeze ODen Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Crntd. Csg: Cementer: Steve SqueezeCasinQ Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Page 1 of 3 . . . Spud Date: 6/8/2005 Report Date: 6/11/2005 End: 7/10/2005 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 10f 1 Start Mix Cmt: 22:37 Start Slurry Displ: 22:40 Start Displ: 00:00 End Pumping: 00:40 En9 Pump Date: 6/11/2005 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.50 (bbl/min) 7.00 (bbl/min) Y 600 (psi) 1,150 (psi) 2 (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 200.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: Spud Mud Density: 9.6 (ppg) Vise: 58 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVNP: 21 (cp)/20 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 15 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.6 (ppg) Volume: 226.00 (bbl) Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1of3 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 8/12/2005 2:09:06 PM ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 1 6/7/2005 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: LEAD Slurry Interval: 2,776.00 (ftJTo: 36.50 (ft) Water Source: Lake Description: ASLite Cmt Vol: 435.0 (bbl) Slurry Vol:550 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temp~rature: (OF) Temperature: (OF) Temperature: (OF) Page 2 of 3 Spud Date: 6/8/2005 Report Date: 6/11/2005 End: 7/10/2005 Class: G Density: 10.70 (ppg) Yield: 4.45 (ft3/sk) Water Vol: 272.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 20.77 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Trade Name Stage No: 1 Slurry No: 2 of 3 - Additives 0-53 0-46 0-79 S1 0-124 0-44 0-65 I TVDe I II GYPSUM IDEFOAMER I EXTENDER ACCELERATOR I FILLlTE ! ACCELERATOR I DISPERSANT Concentration I Units 30.09% 0.60% 1.59% 1.5~% 43.00 % 9.09 %BWOW 0.50¡% Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 3,276.00 (ftJTo: 2,776.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: Lake Slurry Vol:241 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temp,srature: CF) Temp (OF) (OF) Pressure (psi) (psi) I LiquidConc. Units i I Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 29.3 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.10 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Trade Name Stage No: 1 Slurry No: 3 of 3 - Additives Units 0-46 0-65 S1 I Type I !DEFOAMER i I DISPERSANT I ACCELERATOR Concentration I 0.2d% 0.3~% 2.0q% Temp (OF) (OF) Pressure (psi) (psi) I Liquid Conc. I I I Units Printed: 8/12/2005 2:09:06 PM '~ ConocoPhillips Alaska Cementing Report Page 3 of 3 . Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 1 6/7/2005 Spud Date: 6/8/2005 Report Date: 6/11/2005 End: 7/10/2005 Casing Test Shoe Test Liner Top Test Test Press: 2,600 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.30 (ppge) Tool: N Open Hole: 30 (ft) I Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: 37 (ft) How Determined: TOC Sufficient: Y Job Rating: Good If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water wI nut plug - 6 bpm @ 240 psi wI rig pump - Switch to Dowell - Pumped 3 bbls water - test cement lines to 2500 psi - Dropped btm plug - Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.0 bpm @ 175 psi- Mixed & pumped 435 bbls of lead slurry ( ASL "G" wI 30% 0-53, 0.6% 0046, 1.5% 0079, 1.5% S001, 43.1 % 0124, 9% BWOW 044, 0.5% 0-65) @ 10.7 ppg - 6.5 bpm @ 50 - 350 psi - switched to tail slurry 50 Bbls ("G" wI 0.2% D46, 0.3% 065, 2% S001) @ 15.8 ppg - 5.2 bpm @ 325 - 400 psi Dropped top plug & pumped 20 bbls water wI Dowell - Switch to rig pumps - Displaced wI 9.6 ppg mud @ 7 bpm 370 to 600 psi for first 220 bbls - slowed to 4 bpm @ 660 psi for last 6 bbls. - Bumped plug tJ 1050 psi - CIP @ 0040 hrs, floats helds. Full returns during job wI 200 bbls cement retums to surface - recripcated pipe until 360 Bbls of lead slurry away, landed hanger on landing ring. Good returns. Printed: 8/12/2005 2:09:06 PM Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME ¡ JOB NUMBER I EVENT CODE 124 HRS PROG TMD I rvD I DFS I REPT :0. JDATE CD2-60 I ODR 3,286.0 2,377.0 2.75 ! 6/1 0/2005 SUPERVISOR i RIG NAME & NO. FIELD NAME / OCS NO. AUTH MD I DAlL Y TAN~ I CUM. TANGO Don MickeylLarry Hill I dovon1 @ppco.com 19 Aloine 18,279.0 CURRENT STATUS ¡ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/ MUD Nippling up BOP. I 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING OAILYTOTAL CUM COST W/ MUO Test BOP. Pick UP DP. MU BHA. RIH. Drill ST. FIT. Drill. 346,717 694,065 LITHOLOGY JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. CLAYSTONE 10069544 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 6/9/2005 3,213.21 62.170 193.220 9.625 (in) @ 3,276.0 (ft) 7.000 (in) @ 14,155.0 (ft) DENSITY{ppg) I 9.70 I PP 1 IECD IMUD DATAl DAILY COST 1 0 1 CUM COST 1 0 FV PVNP I GELS WUHTHP FC/T.SOL I OIUWAT I %Sand/MBT I Ph/pM 1 Pf/Mf 1 CI ¡ Ca I H2S 1 LIME 1 ES 300 36/76 I 32/82 10.41 I 31 1 I I 0.3/30.0 1 9.01 I 0.031 I i I I I BHA NO. 1 1 I BHA I HOLE CONDITIONS 1 BIT NO. I 1 BHA WT. BELOW JARS I STRING WT. UP I STRING WT. DN I STRING WT. ROT 1 TORQUE 1 UNITS I BHA LENGTH I I I I ft-Ibf I 884.27 ITEM DESCRIPTION NO JTS LENGTH 1 O.D. 1 I.D. CONN SIZE CONN TYPE Bit 1 1.50 12.250 ¡ 4.500 Mud Motor 1 28.98 8.000 I 5.000 ! Sub - Float 1 2.21 8.000 ! 2.870 i Stabilizer 1 5.95 I 8.000 I 3.000 I Crossover - NonMag 1 1.70 i 8.050 I 2.875 I MWD 1 8.82 I 7.920 1 3.500 MWD 1 8.59 8.020 I 1.920 MWD ; 1 9.96 8.090 I 1.900 Sub - Bottom Hole Orienting 1 3.30 8.000 I 2.875 Drill Collar - Non Mag 1 31.01 2.812 I 2.875 Drill Collar - NonMag 1 31.00 8.062 I 2.880 Jars 1 34.30 7.500 I 2.750 I Drill Pipe - Heavy Wgt 24 716.95 5.000 I 3.000 BITS BIT 1 RUN I SIZE I MANUF. I TYPE 1 SERIAL NO. 1 JETS OR TFA 1 DEPTH IN DATE IN I I-O-D-L·B-G·O-R 1 I 1 I 12.250 I HUGHES-CHR I MX-1 15075090 1 16/16/18/12/1 T 114.0 6/8/20051 1-3-WT -A-E-I-EC- TD BIT OPERATIONS BIT / RUN I WOB I RPM I GPM I PRESS 1 PBIT 1 HRS 1 24Hr DIST I 24Hr ROP 1 CUM HRS 1 CUM DEPTH I CUM ROP 1 I 1 I 25 I 35 I 60 I 60 I 656 I 2,300 1 673 I 1 I 171.60 I 17.61 1 3,172.0 I 180.12 OPERATIONS SUMMARY FROM TO HOURS CODE ¡TROUBLE SUB PHASE DESCRIPTION 00:00 01:30 1.50 DRILL P Î !WIPR I SURFAC Continue POOH wI pump fl 2021' to 884' - 500 gpm @ 1300 psi wI 50 rpm I 01:30 02:45 1.25 DRILL P I ¡TRIP SURFAC Flow check (static) RIH fl 884' to 3286' - Hole in good condiüon I 02:45 I 04:00 I 1.25 DRILL P Î iCIRC I SURFAc! Break circulation - Pump nut plug sweep & circulate hole clean 600 gpm @ i I I I . i I 2200 pSI wI 60 rpm I 04:00 I 06:451 2.75 DRILL P ¡TRIP SURFAC Flwo check (static) POOH on TT fl 3,286' to 1,926' (hole took good fill) POOH I I fl 1926' to 1640' - improper fill - Monitor well (static) 06:451 08:30 1.75 DRILL P TRIP SURFAC RIH fl 1640' to 1926' - Monitor well (static) POOH fl 1926' to 167' - hole took i I i proper fill 08:30 110:30 2.00 DRILL P !PULD I SURFAC¡ Handle BHA - Std back NM flex DC"s - Down load MWD - LD MWD - motor & I ¡¡bit 10:30 ¡ 12:30 I 2.00 CAS E P ¡ OTHR SURFACÎ LD Iron roughneck spinners - RU to run 95/8" casing - Pre job safety meeting Printed: 8/12/2005 2:30:23 PM .~ Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER I EVE;TDc~DE 124 HRS PROG TMD ITVD DFS I REPT ~o. I DATE CD2-60 3,286.0 2,377.0 2.75 6/10/2005 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 12:30 15:45 3.25 CASE P RUNC SURFAC Run 9 5/8" 36# BTC csg as follows: FS(Silver bullet) 2 jts. csg - FC (Weatherford) 2 jts. csg (fill pipe & check floats - first 4 connections made up wi BakerLoc) 41 jts. csg. for 45 total to 1885' 15:45 16:15 0.50 CASE P CIRC SURFAC Break circulation - circulate btms up + 16:15 18:00 1.75 CASE P RUNC SURFAC Continue running 9 5/8" 36# BTC csg. f/1885' to 3,276'. Total jtS. run 78- Landed casing @ 1800 Hrs wI shoe @ 3276' & FC @ 3188' 18:00 18:30 0.50 CASE P RURD SURFAC Made up cement head and laid down Franks fillup tool. 18:30 22:15 3.75 CASE P CIRC SURFAC Circulated working rate up to 7 BPM. Checked out stroke counter for count total. PJSM for Cementing. 22:15 00:00 1.75 CEMENTF PUMP SURFAC Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water wI nut plug - 6 bpm @ 240 psi wi rig pump - Switch to Dowell - Pumped 3 bbls water - test cement lines to 2500 psi - Dropped btm plug - Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.0 bpm @ 175 psi - Mixed & pumped 435 bbls of lead slurry ( ASL "G" wi 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 6.5 bpm @ 50 - 350 psi - switched to tail slurry 50 Bbls ( "G" wi 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 5.2 bpm @ 325 - 400 psi 24 HR SUMMARY: POOH and laid down BHA. Rigged up and ran 78 Jts 95/8" casing to 3276'. Circulated and cemented casing. PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company M-I Drilling Fluids 3 Fairweather E&P Service 2 ACI - Arctic Catering 5 Doyon Drilling Inc 25 Dowell 2 Halliburton - Sperry-Sun 2 Swaco 4 Halliburton - Sperry-Sun 3 FMC Corporation Wellhe 1 MATERIALS I CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel Rig gals 1,210 2,100 Water, Potable bbls 120 600 Water, Drilling bbls 800 1,110 Fuel Camp gals 1,120 RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE 1 TOP BASE 1 COMMENTS CD2-19 I CD2-60 I 1120 01 '-' Printed: 8/12/2005 2:30:23 PM Page 1 of 1 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG ITMD TVD I DFS I REPT ~O. ¡DATE CD2-60 I ODR i 3,286.0 2,377.0 3.75 i 6/11/2005 SUPERVISOR i RIG NAME & NO. FIELD NAME / OCS NO. i AUTH MD I DAILY TAN~ CUM. TANG Don Mickev/Larry Hill ¡ doyon1@ppco.com 19 AIDine I 18,279.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD I CUM INT ANG ~I MUD RIH to drill shoe track. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL I CUM COST W/ MUD Drill out + 20'. CBU. FIT. Chanae over & drill 6/6/2005 96,814 I 790,879 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP 1 LEAKOFF AFE IAUTH. CLAYSTONE 10069544 LAST SURVEY: DATE TMD INC AZIM i LAST CASING I NEXT CASING I LAST BOP PRES TEST 6/9/2005 3,213.21 62.170 193.220 ¡ 9.625 (in) @ 3,276.0 (ft) 7.000 (in) @ 14,155.0 (ft) I 6/11/2005 DENSITY(ppg) I 9.60 ¡ PP I I ECD 19.60 I MUD DATAl DAILY COST I 0 I CUM COST 0 FV PVIYP I GELS WUHTHP I Fcrr.SOL OIUWAT I %Sand/MBT I Ph/pM I Pf/Mf I CI I Ca I H2S I LIME I ES 56 20/18 I 5/12 ¡ 11.21 ! 31 I Î 0.3/29.0 i 9.01 I 0.031 I I I ! ¡ I I OPERATIONS SUMMARY FROM TO HOURS I CODE ITROUBLE SUB PHASE DESCRIPTION 00:00 00:45 0.75 CEMENTF DISP I SURFAC Dropped top plug & pumped 20 bbls water wi Dowell - Switch to rig pumps - I I Displaced wi 9.6 ppg mud @ 7 bpm 370 to 600 psi for first 220 bbls - slowed I !to 4 bpm @ 660 psi for last 6 bbls. - Bumped plug U 1050 psi - CIP @ 0040 hrs, floats helds. Full returns during job wi 200 bbls cement returns to surface - recripcated pipe until 360 Bbls of lead slurry away, landed hanger on landing ring. 00:45 01:30 0.75 CEMENTF OTHR I SURFACITest casing to 2600 psi for 30 mins. 01:30 03:45 2.25 CEMENT F OTHR . SURFAC' RD cmt lines & head - flush riser & landing jt. 03:45 07:00 3.25 WELCTL F ¡NUND SURFAC ND riser - Install wellhead & test to 5000 psi - NU BOPE 07:00 08:00 I 1.00 WELCTL ~ IOTHR SURFAC Set test plug & rig up to test BOPE 08:00 113:00 I 5.00 WELCTL A IBOPE SURFAC Test BOPE to 250 psi & 5000 psi - Annular to 3500 psi - perform accumulator i closure test - Witnessing of test waived by Chuck Scheve AOGCC ! I 13:00 13:30 0.50 WELCTL ~ IOTHR SURFAC RD test equipment - pull test plug - Set wear bushing 13:30 14:00 0.50 DRI LL P Î IOTHR SURFAC RU to pick up 5" drill pipe 14:00 00:00,10.00 DRILL P I PULD 1 SURFAC PU 5" drill pipe fl pipe shed & stand back in derrick 24 HR SUMMARY: Finished cementing casing. Tested casing. Nippled down riser and nippled up BOP. Tested BOP. Picked up 5 " DP from pipe shed and stood back in derrick. PERSONNEL DATA COMP ANY I SERVICE NO. HOURS COMPANY 1 SERVICE NO. I HOURS ConocoPhillips Company i ! M-I Drilling Fluids I 31 i Fairweather E&P Service I 2 ACI - Arctic Catering 1 5. Doyon Drilling Inc I 25 Dowell I 2, Halliburton - Sperry-Sun i I 2 Swaco I 4, Halliburton - Sperry-Sun i I 3 I T I ! i MATERIALS I CONSUMPTION ITEM I UNITS I USAGE I ON HAND ITEM UNITS I USAGE ON HAND Fuel Rig I gals ¡ 1,155 I 9,245 i Water, Potable bbls I 120 750 i Water, Drilling I bbls 1,050 I 960 I Fuel Camp gals ¡ I 1,120 RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE T COMMENTS CD2-19 I CD2-60 ! 2625 01 I Printed: 8/12/2005 2:08:33 PM PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD2-60 I Rig: Doyon 19 Date: 6/12/2005 I Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Mickey / Hill I Pump used: I #1 Mud Pump \. Strokes ... 0.1005 Bbls/Strk ... 8.0 Strk/min I'" Type of Test: I Casing Shoe Test LOT/FIT 1..-1 Pumping down I annulus and DP. \..- Casin Test Pressure Integrity Test Hole Size: 18-1/2" I~ Casing Shoe Depth I I Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: I 36.5 Ft 3,276 I Ft-MD 2,3731 Ft-TVD I 3,306 Ft-MD 2,387Ft-TVD Strks psi Min psi S trks psi Min psi CasinQ Size and Description: \9-5/8" 36#/Ft J-55 BTC I~I 0 0 0 2600 0 0 0 830 Casino Test Pressure InteQritvTest 2 75 1 2600 2 20 0.25 700 Mud Weight: 9.6 ppg Mud Weight: 9.3 ppg 4 250 2 2600 4 40 0.5 650 Mud 10 min Gel: 80.0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 6 460 3 2600 6 120 1 630 .- ... -- .. f"" ~ Test Pressure: 2,600 psi Rotating Weight: 125,000 Lbs 8 660 4 2600 8 280 1.5 Rotating Weight: 74,000 Lbs Blocksrrop Drive Weight: 72,000 Lbs 10 820 5 2600 10 460 2 6,..- Blocksrrop Drive Weight: 74,000 Lbs Desired PIT EMW: 18.0 ppg 12 1000 6 2600 12 600 2.5 605 Estimates for Test: 2.5 bbls Estimates for Test: 1074 psi 1 bbls 14 1120 7 2600 14 720 3 600 1~1 I~ 16 1250 8 2600 16 800 3.5 600 EMW = Leak-off Pressure + Mud Weight = 720 2373 + 9.3 PIT 15 Second 18 1400 9 2600 18 840 4 600 0.052 x TVD 0.052 x Shut-in Pressure, psi 20 1600 10 2600 20 860 4.5 595 EMW at 3276 Ft-MD (2373 Ft-TVD) = 15.1 ppg 700 22 1750 15 2600 22 860 5 590 3000 ~ Lost 0 psi during test, held 1 00% ~ 24 1870 20 2600 24 860 5.5 590 _ of test pressure. 26 2120 25 2600 26 860 6 580 " I I I ¡--¡-- 28 2300 30 2600 28 860 6.5 580 ,. .7...·.·...'...:.:.,¡,,¡:1,·~...~4;----:;.,;----"· 2500 ~ 30 2490 30 860 7 580 , --- -- ". 31 2600 32 860 7.5 '. 580 , 34 850 8 570 ,- 2000 .I 36 850 8.5 570 w ~ 0:: .Æ 38 850 9 570 :J " tJ) ~~ .'. 40 850 9.5 570 1500 tJ) , 42 850 10 { w """ 0:: .Æ 44 850 c.. ~ 1000 .". 46 850 ". ,.~ .'. 48 850 - " r."... 50 85Q & ~ i.""'" 500 .I ~ - 4 n ". .I J .4 J111J ." ." 0 0 1 2 3 4 5 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ---CASING TEST -II- LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 3.1 Bbls Bbls 5.0 Bbls IBbls Comments: Casing tested after bumping plug on surface cmt job. Conoc~hillips Casing Detail 7" Casina Well: Date: CD2-6U 6/30/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.50 FMC Gen V Hanger 2.84 34.50 Jts 3 to 336 334 Jts 7" 26# L-80 BTCM Csg 14204.72 37.34 Weatherford Float Collar 1.31 14242.06 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.32 14243.37 Ray Oil Tools "Silver Bullet" Float Shoe 2.09 14328.69 ~ 14330.78 TD 8 1/2" Hole 14341.00 8-1/2" Hole TO @ 14,341' MO /1 TVO 73791 7" Shoe @ 14,331' MD /1 TVD 73781 Total Centralizers: 54 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts # 257,258,259 Straight blade centralizer one every other joint Starting @ # 261 thru # 333 Top Alpine C -14,215' MD - 7366' TVD : 336 joints in shed - 336 total jts. to run Use Run & Seal pipe dope Average make up torque 8000 ft/lbs Remarks: Up Wt - 410 k Dn Wt - 120k Block Wt - 75k Supervisor: D. Burley / D. Mickey ConocoPhillips Alaska Page 1 of 2 Casing Report Legal Well Name: CD2-60 Spud Date: 6/8/2005 Common Well Name: CD2-60 Report #: 2 Report Date: 6/30/2005 Event Name: ROT - DRILLING Start: 6/7/2005 End: 7/10/2005 General Information String Type: Production Casing Permanent Datum: Rotary Table Hole Size: 8.500 (in) Hole TMD: 14,341.0 (ft) Hole TVD: 6,891.0 (ft) KB-Datum: 15.90 (ft) Water TMD: (ft) Str Wt on Slips: (Ibs) Ground Level: 15.87 (ft) CF Elevation: 17.87 (ft) Liner Overlap: (ft) Max Hole Angle: 85.37 n Circ Hours: 5.00 (hr) Mud Lost: 40.0 (bbl) KB to Cutoff: 34.50 (ft) Days From Spud: 22.75 (days) Casing Flange I Wellhead Manufacturer: FMC Model: Alpine Unibo Top Hub/Flange: (in) 15,000 (psi) Hanger Model: A-75 Fluted Packoff Model: A-75 BTM Hub/Flange: (in) I 5,000 (psi) Actual TMD Set: 14,330.78 (ft) Integral Casing Detail Item Size Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer Model Cond; Max OD Min ID Compo Name (in,) (Iblft) (in) (ft) (ft) (ft-Ibf) (in) (in) Casing Hanger 7.000 L-80 2.84 34.50 N FMC A-75 Fluted NEW Casing Hanger Casing 7.000 26.00 L-80 6.151 BTC-MOD 334 14,204.72 37.34 N NEW 6.276 7 " 26# L-80 Ca~ Float Collar 7.000 26.00 L-80 BTC-MOD 1.31 14,242.06 Y WEATHERFORD NEW Float Collar Casing 7.000 26.00 L-80 6.151 BTC-MOD 2 85.32 14,243.37 Y NEW 6.276 7 " 26# L-80 Cas Float Shoe 7.000 26.00 L-80 BTC-MOD 2.09 14,328.69 Y RAY OIL TOOLS NEW Float Shoe ( 14,330.78 Non-Integral· Casing Accessories ... . Accesspry Manufacturer Number Spacing Interval How Fixed (ft) Top(ft) Bottom (ft) Centralizer RAY OIL TOOLS 14 13,732.0 14,286.0 Floating Centralizer RAY OIL TOOLS 3 3,315.0 3,399.0 Floating Centralizer RAY OIL TOOLS 38 166.0 3,230.0 Floating Remarks Held safety and Opts meeting with crew Printed: 8/12/2005 2:09:39 PM ConocoPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 2 6/7/2005 Spud Date: 6/8/2005 Report Date: 6/30/2005 End: 7/10/2005 --.--------,-----,---.,-.---- -- Remarks ------.---...---.,---. .-----.-------- -.- Run 7" 26# L-80 BTCM as follows: FS - 2 jts. - FC - 74 jts. to 3236' - (Baker Loc 1st four connections - pump through string on jt. #4 to check floats) install straight blade centralizers on first 14 jts. Staged pumps up to 6.0 bpm /410 psi - reciprocated pipe - circulated one pipe volume (124 bbls) Pumps off - PUW 138K SOW 119K Run casing from 3236' to 6803' - 160 jts total Stage pumps up 3.5 bpm @ 420 psi initial /4.6 bpm @ 380 psi final Total of 296 blls pumped - reciprocated pipe throughout. Pumps off - PUW 205K SOW 135K Run 7" casing from 6803' to 9784' - 230 jts. total Stage pumps up to 3.8 bpm @ 450 psi initial I 4.5 bpm @ 490 psi final Pumped 350 bbls total - reciprocated pipe throught Pumps off - PU 260 K SO 140 Run 7" casing f/ 9784' to 12,208' - 287 jts total Stage pumps up to 4.0 bpm @ 660 psi initial /4.0 bpm @ 540 psi final -reciprocated pipe throught Run 7" casing f/12,208' to 13,185' - 310 jts. total Run casing: Lost SOW @ 13,190', attempted to circ, hole packing off - regained circ - worked pipe from 13,185' to 13,210' - hole packing off. Laid down one joint - regain circ and wash from 13,185' to 13,140'. Continue to work pipe pumping 4 bpm / 570 psi fighting tight hole and packing off to 13,227'. Worked pipe down from 13,227' to 13,245' with out pump hole conditions improved. Continue to run casing from 13,245' to 14,298' SOW from 140K to 75K (block wt.) MU FMC fluted hanger and landed in wellhead with FS @ 14,330.78' and FC @ 14,242.06' Printed: 8/12/2005 2:09:39 PM - "'--" ConocoPh illipsAlaska Cementing Report Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 14,331 (ft) Date Set: 6/30/2005 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 40.00 Meas. From: N/A Time Circ Prior To Cementing: 3.50 Mud Circ Rate: 147 (gpm) Mud Circ Press: 730 (psi) Report #: Start: 2 6/7/2005 Cement Job Type: Primary Squeeze aDen Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casino Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Page 1 of 3 Spud Date: 6/8/2005 Report Date: 6/30/2005 End: 7/10/2005 Pluo Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement: No movement RPM: SPM: Init Torque: Stroke Length: Pipe Movement (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 10f 1 Start Mix Cmt: 17:17 Start Slurry Displ: 17:17 Start Displ: 17:40 End Pumping: 19:40 End Pump Date: 6/30/2005 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 5.00 (bbl/min) Y 1,060 (psi) 1,550 (psi) 5 (min) N Max Torque: (ft-Ibf) Drag Down: (Ibs) Retums: 100 Total Mud Lost: Cmt Vol to Surf: 10.00 (bbl) (bbl) Mud·Data Ann Flow After: N Mixing Method: Density Meas By: denseomete Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 35 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVIYP: 9 (cp)/17 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 523.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 11,094.00 (11):.>: 1 0,209.00 (ft~mt Vol: 20.0 (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: CF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Flush Mix Water: (gal) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 8/12/2005 2:09:17 PM ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 2 6/7/2005 Spud Date: 6/8/2005 Report Date: 6/30/2005 End: 7/10/2005 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Spacer Description: MUDPUSH II Class: Slurry Interval: 12,422.00 (ffþ: 11,094.00 (ft~mt Vol: 30.0 (bbl) Density: 11.50 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 14,331.00 (ffþ: 12,422.00 (ft~mt Vol: 65.0 (bbl) Water Source: lake Slurry Vol:315 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 38.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.08 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Temperature: (OF) Temperature: (OF) Temperature: (0 F) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.50 (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: I I Cement Top: (ft) I How Determined: I TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Stage pumps up slowly initial rate 1 bbls I min @ 430 psi - final 3.5 bbl I min @ 730 psi - No pipe movement - PJSM on cmt job Cement 7" 26# L-80 csg as follows: Pumped 5 bbls CW-100 - Tested lines to 3700 psi - Pumped 15 bbs CW-100 @ 4.1 bbls/min @ 690 psi - Pumped 30 bbls 11.5 ppg Mudpush II @ 4.1 bbls/min @ 680 psi - Dropped btm plug - Pumped 64.9 bbls 15.8 ppg tail slurry Class Printed: 8/12/2005 2:09:17 PM '--' ---- ConocoPhillipsAlaska Cementing Report Page 3 of 3 Legal Well Name: CD2-60 Common Well Name: CD2-60 Event Name: ROT - DRILLING Report #: Start: 2 6/7/2005 Spud Date: 6/8/2005 Report Date: 6/30/2005 End: 7/10/2005 Remarks G wI 0.2% 0046, 0.3% 0065, 0.4% 0167, 0.1% 8155 @ 4 bbls/min @ 400 psi - Dropped top plug wi 20 bbls water - switched to rig pumps Displaced cmt wi 9.6 ppg LSND mud as follows: 150 bbls @ 4.4 bbls/min @ 480 psi - 30 bbl @ 4.6 bbls/min @ 300 psi (* observed 200 psi drop in pressure @ 179 bbls - no losses & pumps OK) 30 bbls @ 4.8 bbls/min @ 310 psi - 270 bbls @ 5 bbls/min @ 330 psi to 750 psi (* Observed pressure increasing as Mudpush & cmt tumed the comer) slowed pumps to 3.3 bbls/min wi 480 bbls of displacment pumped wi pressure fl 440 psi to 580 psi - @ 500 bbls of displacement gone pressure began rising fl 580 to 1790 psi - slowed pump to 1.6 bbls/min (hole packing off -lost reutrns with 510 bbls of displacment gone) finished displacing @ 1.6 bbls/min final pressure before bumping plug 1060 psi - bumped plug w/ 523 bbl @ 1550 psi - CIP @ 1940 hrs. - Checked floats OK - Lost 10 bbls mud during displacement - no flow fl annulus after shutting down pump Printed: 8/12/2005 2:09:17 PM Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME ! JOB NUMBER I EVENT CODE 124 HRS PROG !TMD iTVD IDFS I REPT NO. I DATE , I 14,341.0 I 7,378.0 22~75 24 ! 6/30/2005 CD2-50 ¡ ODR I SUPERVISOR I RIG NAME & NO. I FIELD NAME / OCS NO. AUTH MD IDAJLYTAN~ ¡CUM. TANGO D. Burley/D. Mickey I doyon1 @pPco.com 19 I Alpine 18,279.0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAJL Y INT W/O MUD CUM INTANG W/ MUD Layinq down 5" DP 0 0 24 HR FORECAST I DATE OF LAST SAFETY MEETING DAJLYTOTAL CUM COST w/ MUD Finish LD 5" DP - MU 6 1/8" BHA - RIH - PU 4" DP I 6/27/2005 351,714 5,594,001 LITHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP ! LEAKOFF AFE AUTH. I I I I 16.28 10069544 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 6/27/2005 14,300.06 85.370 149.170 7.000 (in) @ 14,331.0 (ft) 7.000 (in) @ 14,331.0 (ft) 6/24/2005 DENSITY(ppg) I 9.80 I PP-' ecDI IMUD DATAl DAILY COST I 0 i CUM COST I 0 FV PVNP I GELS WUHTHP FCrr.SOL I OIUWAT I %Sand/MBT I Ph/pM I PflMf I CI I Ca 1 H2S I LIME I ES I 11/20 T I r I ! I 8.81 I 0.031 I I I I I 42 9/10 4.4/9.0 I 11 I 120.0 I OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE! SUB PHASE DESCRIPTION 00:00 01 :00 ¡ 1.00 CAS E P jCIRC IINTRM1 I Stage pumps up to 4.0 bpm @ 660 psi initial 14.0 bpm @ 540 psi final I I-reciprocated pipe throught I I I I 01:00 02:00 1.00 CASE P ¡RUNC ' INTRM1 Run 7" casing fl 12,208' to 13,185' - 310 jts. total 02:00 10:45 8.75 CASE Np CIRC INTRM1 Run casing: Lost SOW @ 13,190', attempted to circ, hole packing off - regained cire - worked pipe from 13,185' to 13,210' - hole packing off.Laid down one joint - regain circ and wash from 13,185' to 13,140'. I Continue to work pipe pumping 4 bpm I 570 psi fighting tight hole and packing off to 13,227'. Worked pipe down from 13,227' to 13,245' with out pump hole conditions improved. 10:45 13:00 2.25 CASE P RUNC INTRM1 Continue to run casing from 13,245' to 14,298' SOW from 140K to 75K (block ! I J wt.) MU FMC fluted hanger and landed in wellhead with FS @ 14,330.78' and FC @ 14,242.06' 13:00 13:30 0.50 I CEMENT R IRURD INTRM1 Lay down fill-up, blow down Top Drive - MU Dowell 2 plug cement head 13:30 17:00 3.50 I CEMENT F CIRC INTRM1 Stage pumps up slowly initial rate 1 bbls I min @ 430 psi - final 3.5 bbl I min r ! @ 730 psi - No pipe movement - PJSM on emt job r ! 17:00 17:45 0.75 CEMENT F PUMP INTRM1 Cement 7" 26# L-80 csg as follows: Pumped 5 bbls CW -100 - Tested lines to 3700 psi - Pumped 15 bbs CW-100 @ 4.1 bbls/min @ 690 psi - Pumped 30 bbls 11.5 ppg Mudpush II @ 4.1 bbls/min @ 680 psi - Dropped btm plug - Pumped 64.9 bbls 15.8 ppg tail slurry Class G wi 0.2% D046, 0.3% D065, 0.4% D167, 0.1% B155 @ 4 bbls/min @ 400 psi - Dropped top plug w/20 bbls water - switched to rig pumps 17:45 20:00 2.25 CEMENTF DISP INTRM1 Displaced cmt wi 9.6 ppg LSND mud as follows: 150 bbls @ 4.4 bbls/min @ 480 psi - 30 bbl @ 4.6 bbls/min @ 300 psi (* observed 200 psi drop in pressure @ 179 bbls - no losses & pumps OK) 30 bbls @ 4.8 bbls/min @ 310 psi - 270 bbls @ 5 bbls/min @ 330 psi to 750 psi (* Observed pressure ! increasing as Mudpush & cmt turned the corner) slowed pumps to 3.3 I bbls/min wi 480 bbls of displacment pumped wi pressure f/440 psi to 580 psi - @ 500 bbls of displacement gone pressure began rising fl 580 to 1790 psi - slowed pump to 1.6 bbls/min (hole packing off - lost reutms with 510 bbls of displacment gone) finished displacing @ 1.6 bbls/min final pressure before bumping plug 1060 psi - bumped plug wi 523 bbl @ 1550 psi - CIP @ 1940 hrs. - Checked floats OK - Lost 10 bbls mud during displacement - no flow fl ! annulus after shutting down pump 20:00 20:30 ! 0.50 DRILL P ! ¡DEQT i INTRM1 Tested 7" casing to 3500 psi for 30 mins. Printed: 8/12/2005 2:08:47 PM , "--" \~ 6 Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME I JOB NUMBER I EVE~TDc~DE 124 HRS PROG TMD rvD I DFS I REPT NO. DATE CD2-60 14,341.0 7,378.0 22.75 24 6/30/2005 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 20:30 21:15 0.75 CEMENT F PULD INTRM1 RD cmt lines & cmt head - csg elevators & landing jt. 21:15 00:00 2.75 DRI LL P OTHR I NTRM 1 Pull wear bushing - set & test pack to 5000 psi for 10 mins. - Pull pack-off running tool - set upper test plug - Change top pipe rams fn" to 3 1/2" X 6' VBR - test rams & body to 5000 psi. 24 HR SUMMARY: Circ csg @ 12,208' - RIH to 13,190' - Work casing down to 13,245' - Run csg to 14,331' - Circ for cmtjob - cement 7" casing - test csg to 3500 psi - set & test pack-off - Change pipe rams PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company 1 ACI - Arctic Catering 5 Fairweather E&P Service 1 Dowell 2 Doyon Drilling Inc 26 Swaco 4 Halliburton - Sperry-Sun 2 FMC Corporation Wellhe 1 Halliburton - Sperry-Sun 2 Epoch Well Services Inc 1 M-I Drilling Fluids 3 MATERIALS I CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel Rig gals 939 5,565 Water, Potable bbls 120 -510 Water, Drilling bbls 600 -3,330 Fuel Camp gals 1,680 RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE I COMMENTS CD1-19A I CD2-60 I 560 01 Printed: 8/12/2005 2:08:47 PM PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. I C02-50 I Rig: Doyon 19 Dat~:. __J___!~~!~_?_~ .Lyo!!!l!!e Input Drilling T::e:~::~: ~~L~~~;-~:~~~~~~~-- \ ~ II :~::i~:e:~W~ Cle::~~n~~ -- ~ Banels ,.. I ~ Casing Test Hole Size: 1-'8~lï-2;' -·--·.....--·.-----.-1... Casing Shoe Depth I Hole Depth PumpinQ Shut-in RK~~~:~ìze an:~::C~iPtion: 3,27î~~;F;~!s7!t=-1YD--LJ.2~<42~E!--MD~1YR Bbls psi MinO psi Chanaes for Annular Adeauacv Test Pressure IntearitvTest 1 :>uter casing shoe test results in comments Mud Weight: 9.7 ppg 2 Description references outer casing string. Inner casing 00: 7.0 In. 3 )ize is that drilled below outer caSing.. J... . 4 timated TOe for Hole Depth. 5 Enter inner casing 00 at right Desired PIT EMW: 14.5 ppg 6 d_____ _ ___[... :. Estimates f()r.! ""t.: _ . _._ ~!l2~__021:>F- ; EMW=·-Leak-':off PressÙre+Miid Weight = ..-..- ·-q520-·-·-----~----·----PIT-15 Second 9 0.052 x TVD 0.052 x 2373 + . Shut-in Pressure, psi 10 EMW at 3?I~_~t-MD (2373 Ft-TVD) = 13.9 _... ....._._~~.. 15 .-...........-----.. - .- 20 25 30 Pump Rate: . B::;~l ,.. 0.8 Bbl/min Pressure Integrity Test Well Name: -,-- - .'"----.-,-.--.,---- 1000 - ,.._,-,,--,,- ---,-,--_._,"-,~ -.,.------,---..,- ._...~,...~.,--_..__._- -,.,_..,-,_.~.._-- ---.. ,.,......--.---.."." -,,,_. .--_.. ---........----.. -....--.-...-. ---.-.----- -....---...---- .-.----,,-. -----".~. ...."._,-,- ----- .... . .",- -,,_....,,~_."- -.. ~_._...,_.,..- -,-.....-"..-.-.- ----.,--.--,,- ---...--. . --,,, ....-...--.- -..... .. -.-..--..-..........................--..."".......-,......... -.............. ..... ._._-_.~ .,..",..--.-,.".. ....-----. .-- -... ........,.-...,.".,-..- ..._---... _n._.. ~,......_.__ _._..~"_ ._,_moo·.,_ .,. .,.,,~.,,_,...... ._, __. _ ". .. _ _._ _.._..,___.".~..~' -,~~~ -.-.-...,.---."'-,... -..--., .-'''''--..-.- ..,- .-.-- .'-'--"~ -,~~..."., ,- ." "-.,,..-. _...,-,-."._,,-. .,--, ,..--.. --,_........,-_._~,~ ..~.."'~."....- "..,..,. --. ._-" .-..,--.-.-,.. .-..---, - .... w ~ :::::> en 500 en w ~ D.. -.--..."'...-,."..-- ....---... _.,--~ -.,--,,-.....-.- ..._...._ _____",,___". ..~ "....,...._.._.. __."... .__.. ...."n_. ._,."_,_,,. ._.,,_." ". -,_._..,~._,....._- -------~._.._- _.._~.._..- -_._~- ..-.".-.-- - -------,- '-~'.._'. ". --_.,,----- """"- - --- ----.----=::¿;:¡?,- - - -----:=-:= ~L 72 ----- ----- ---~==- o ....---"..-...-- ~......- --. -....-...".-...''''.-. -"".,.--.-.-." --...,,-. . ~,-,._,-_.- ~ ..._.:......:.} ..-:.:. --.-..-.... ......---------...-----. .. _'.'.'_".'.~'n'_. _.-..".---,.~".- ..-,-."..-.-- --..-- -.'-"-.~."'--".. ~..,,-_., ,--- .--..-.. ,,- ----.._-- --"~-,,...__._--- -.-.,,-"'., ..- .---.---,-.. -." ,---_... .._-~".~.__.,. -_._~.~....- ..--.".-.....-.. .-...,,-..-.-...... ..,-..-.-.-,...-. .-.."....--.. o 2 6 8 10 Barrels 12 16 20 5 10 15 20 25 Shut-In time, Minutes o PIT Point 30 Volume Pumped 0.0 Bbls 18 o 14 4 .....CASING TEST ___ LEAK-OFF TEST Comments: 9 5/8" Surface casing shoe LOT = 15.3 ppg Volume Bled Back Bbls I,.. PumpinQ Shut-in Bbls psi Min psi 0 0 0 454 1 56 0.25 450 2 106 0.5 450 3 157 1 444 4 197 1.5 .1~4 5 247 2 6 288 2.5 419 7 333 3 419 8 374 3.5 414 9 409 4 414 10 444 4.5 409 11 464 5 409 12 485 5.5 404 13 500 6 404 14 515 6.5 399 15 520 7 399 16 520 7.5 394 17 520 8 389 18 520 8.5 384 9 379 9.5 379 10 ,,-. 11 12 -....,,- 369 13 354 14 359 15 359 Volume Pumped 18.0 Bbls Volume Bled Back Bbls _c '-- Note to File C02-57 (204-072...305-238) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 150 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 650/0 XS of the calculated hole volume. --On the initial leak off test, the pressure slope changed at 15.8 EMW with continued pumping giving a determined LOT point at 17.9 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 14.4 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented, although minimal returns were noted. The 7" could not be reciprocated. Slight returns were noted after the lead slurry rounded the shoe. --An injectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 16.8 EMW. The pressure declined with additional pumping to 15.7 EMW. Steady pump in was not observed. During the observation period, the pressure declined to 12.6 EMW. CPAI recently conducted an additional pump in test to verify the injectivity. On this second test, steady pump in occurred at 15.9 EMW with the pressure declining to 13.7 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within % mile of C02-57. There are a total of 9 wells within % mile of the surface shoe. There are 2 wells between 400' - 550' distant with the remainder lying between 900' - 1400' distant. The surface casing cementing records have been evaluated for all wells and the pump in tests evaluated for 6 of the 9 wells. An examination of this information did not reveal any problem that would preclude granting CPA's request for C02-57. . Based on examination of the submitted information, I recommend approval of ZOCOPhilliPS' request for the subject well. ;::=u:::J~ Sr. Petroleum Engineer August 17,2005 G: \common \tommaunder\ Well Information \By Subj ect\Annular Disposal\050817 --CD2-57 .doc Scbl:umbepger Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth ) Well CD2-57 ) Job# 10802887 SCMT Log Description Date 06/21/04 SIG w:~. NO. 3226 Ó<ð~~·¿)72 09/28/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine BL Color Prints 1 DATE: /~Þf Please sign and retu 0 e copy ofthis transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. CD - -- Transmittal Form r&i. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West th Ave, Suite 100 Anchorage, Alaska 99501 Attention: R6 b;11 Deasun- Reference: IE-II2Ll Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 693594 ~ent By: Glen Horel . i Recelv~f ¡¿ yØ~ Date: Oct. 18, 2004 Date: IcI<tff PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 '--'" I ¡-~---------_.___.m_--'1 I ¡ ~triJt·UiHIIIðl&11:.1U ,. i' , : ,~"_,, I r~'. ~ _~;.n_:"':.1 ¡;-;;;~::""'~~.,;-.~j .... .. n. .=.~~-~~=~-~_.... ! ¡ i I I I I I j I i I ¡ ! I I -- ,- . i~~~:~f~;~1 ~~;r<- i .- -----------.- ....t!I:.1!L k:-;:m bI fT'" r~'i. .'. j.~__:_ _ L:_:~;____..::.~.~__: :-:-~- - ~--- - -: ¡ -::-:~-:-i:--____:_::_:-: -:-:-:-:--- ;., . I·· ; ~~~~:J~-_u- ~:~:J¿~_-~~~:~_~ ¡-~~~¡~ !>~:~.- -..:.t. i-;: _;: - i ¡:~_~; . : _ - U~- 1--)-:. . , [t~f I 1:.j~}}Z~J: ~ in::. . ¡m"~' ¡ ::-';. - ! ~~~¡!..-.-- i ...... : rh~:'~~_- j i '·'1- I i r'~ j MEMORANDUM ~~ State of Alaska --I Alaska Oil and Gas Conservation Commission TO: Jim Regg ")~ØMl' llz~':?)ck P.I. Supervisor n DATE: Wednesday, July 14,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHllLIPS ALASKA INC cm-57 COLVILLE RIV UNIT CD2-57 :J..ð 't - 07)- FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ;'<;-?n P .1. Suprv :·Jt)'L.- Comm . NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-57 API Well Number: 50-103-20492-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS040712195136 Permit Number: 204-072-0 Inspection Date: 7/12/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cm-57 Type Inj. S TVD 7296 IA I 450 2125 2050 2050 I P.T. 2040720 TypeTest SPT Test psi 1750.25 OA 500 600 600 600 I Tubing I I Interval INIT AL PIF P 1100 1100 1100 1100 I . Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, July 14, 2004 Page I of 1 e e G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Conoc6Phillips July 6, 2004 Commissioner State of Alaska Alaska Oil & Gas ConselVation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-57 (APD 204-072) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-57. If you have any questions regarding this matter, please contact me at. 265-6120. Sincerely, þ( CßZ .. G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended D WAGE] 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory I GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test I 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: June 4, 2004 204-072 I 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 100360, Anchorage, AK 99510-0360 May 16, 2004 50-103-20492-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2133'FNL, 1494'FEL, Sec. 2, T11N,R4E,UM June 2, 2004 CD2-57 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: ~1FNL,~'FEL,Sec.13,T11N,R4E,UM 37' RKB 153' AMSL Colville River Field Total Depth: 3"{0' 2-3rK'¡::1µ~ 9. Plug Back Depth (MD + TVD): Alpine Oil Pool 1328' FSL, 993' FEL, Sec. 13, T11 N, R4E, UM 16433' MD 17296' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 371741 y- 5974224 Zone-4 16433' MD 17296' TVD ADL 380075 TPI: x- 375498 y- 5965326 Zone- 4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 377321 y- 5961751 Zone- 4 Landing Nipple @ 2666' ALK 18. Directional Survey: Yes 0 NoU 19. Water Depth, If Offshore: 20. Thickness of N/A feet MSL Permafrost: 1910' M[ 21. Logs Run: GRlRes/Dens/Neutron, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 42" pre-installed 9.625" 36# J-55 37' 3391' 37' 2378' 12.25" 544 sx AS Lite, 230 sx Class G 7" 26# L-80 37' 12642' 37' 7248' 8.5" 72 sx LiteCrete, 148 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SE 4.5" 11996' 11932' open hole completion from 12642'-16432' MD 7248'-7296' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection Method of Operation (Flowing, gas Jift, etc.) June 23, 2004 Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATII N/A Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none'. NONE Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-57 Seabee Form. Nanushuk Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TO 3447' 6097' 11475' 11842' 11907' 11993' 12319' 12392' 16260' 16433' 2409' 3845' 6753' 6952' 6987' 7032' 7174' 7198' 7290' 7296' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 p~nted Name..4.vt C~d Signature 1.... l ~ Title: Phone Alpine Drilling Team Leader Date 1 rC '.0+ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none·, Item 29: List all test information. If none, state ·None·. Form 10-407 Revised 2/2003 · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/14/2004 21 :00 - 00:00 3.00 MOVE RURD MOVE Rig down to move. Moved Ball Mill and pipe shed to CD2-57. 5/15/2004 00:00 - 15:30 15.50 MOVE MOVE MOVE Moved to CD2-57 and rigged up on well. 15:30 - 19:00 3.50 DRILL RIRD RIGUP Nippled up riser and connected flowline. Picked up tools. Loaded pipe shed with 26 Jts HWDp. Rig accepted @ 1530 Hrs. 5/15/04. 19:00 - 20:00 1.00 DRILL REAM RIGUP Picked up 3 Jts. Hwdp. Made up bit and RIH to 42' tagged ice plug. Cleaned out to 93'. Checked for leaks and tested lines to 3500 PSI. POOH and stood back HWDP. 20:00 - 22:30 2.50 DRILL PULD RIGUP Picked up and stood back 23 Jts HWDP and jars. 22:30 - 00:00 1.50 DRILL PULD RIGUP Picked up and stood back 24 Jts. 5" drill pipe. 5/16/2004 00:00 - 01 :45 1.75 DRILL PULD RIGUP P/U and stand back 54 jts of 5" drill pipe and (3) - 8" nmdc's. 01 :45 - 02:15 0.50 DRILL SFTY RIG UP Held pre-spud meeting with rig team. 02:15 - 03:45 1.50 RIGMNT RSRV RIGUP Cut and slip drilling line - Service Top Drive and Drawworks. 03:45 - 06:00 2.25 DRILL PULD SURFAC MU BHA #1: Bit / Motor / FS / Stab 1 XO 1 MWD I UBHO 1- set AKO @ 1.5 degrees - scribe tools and initialize MWD. MU 1 stand 8" collars. 06:00 - 06:15 0.25 DRILL DEQT SURFAC Clean out Conductor from 93' to 108' (ice) - MWD pulses inconsistant. 06:15 - 06:30 0.25 DRILL DEQT SURFAC Varied pump rate from 400 - 600 gpm - no improvement. 06:30 - 08:30 2.00 DRILL TRIP SURFAC Stand back DC's, Ud UBHO - change out pulser - shallow test tools. MU 8" dc's and cleanout from 108' to 114' (5 min.) 08:30 - 12:00 3.50 DRILL DRLG SURFAC Spud well @ 0830 hrs. - Drill 12 1/4" hole from 114' to 348' - ran gyro surveys @ 82', 167' and 260'. ADT - 1.52 hrs. = ART - 0.9 hrs. AST - 0.62 hrs. WOB - 10/20 k RPM - 0/60 GPM 400 - 425 @ 680 psi String wt. PU 95 SO 95 Rot 90 Torque on/off btm. - 4500/4000 ft. Ibs. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole from 348' to 1258' - ran gyro surveys @ 437',526', 616',703',794' and 883'. ADT - 5.46 hrs. = ART - 1.65 hrs. AST - 3.81 hrs. WOB - 20/35 k RPM - 0/60 GPM 504 @ 1150 psi String wt. PU 120 SO 120 Rot 120 Torq offlon Btm 5000/7500. Torque on/off btm. - 4500 /4000 ft. Ibs. 5/17/2004 00:00 - 11 :30 11.50 DRILL DRLG SURFAC Drill 12 1/4" hole from 1258' to 2628'. ADT - 8.14 hrs. = ART - 5.87 hrs. AST - 2.27 hrs. WOB - 25/30 k RPM - 0/80 GPM 651 @ 2230 psi String wt. PU 130 SO 115 Rot 125 Torq off/on Btm 7500/9000. 11 :30 - 12:15 0.75 DRILL CIRC SURFAC Bit balled up could not un ball. No ROP. Filled trip tank. 12:15 - 16:00 3.75 DRILL TRIP SURFAC POOH. 16:00 - 17:30 1.50 DRILL PULD SURFAC Changed out bit and Mud Motor. 17:30 - 19:00 1.50 DRILL TRIP SURFAC RIH to 2496'. 19:00 - 19:30 0.50 DRILL REAM SURFAC Wash and reamed from 2496' to 2628'. 19:30 - 20:30 1.00 DRILL CIRC SURFAC Lost Highline power. Started Cats and circulated working pipe until power restored. 20:30 - 00:00 3.50 DRILL DRLG SURFAC Drill 12 1/4" hole from 2628' to 2900'.2124' TVD. ADT - 2.29 hrs. = ART - 1.75 hrs. AST - .54 hrs. WOB - 10/20 k RPM - 0/80 GPM 651 @ 2650 psi String wt. PU 130 SO 115 Rot 125 T orq offlon Btm 7500/8000. 5/18/2004 00:00 - 06:45 6.75 DRILL DRLG SURFAC Drill 12 1/4" hole from 2900' to 3401'. 2384' TVD. ADT - 5.44 hrs. = ART - 4.7 hrs. AST - .74 hrs. WOB - 10/25 k RPM - 0/80 GPM 651 @ 2680 psi String wt. PU 140 SO 118 Rot 130 T orq off/on Btm 8000/8500. Printed: 6/25/2004 2:18:51 PM · .' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/18/2004 00:00 - 06:45 6.75 DRILL DRLG SURFAC 06:45 - 08:15 1.50 DRILL CIRC SURFAC Pumped sweep and circulated hole clean. 08:15 - 10:00 1.75 DRILL WIPR SURFAC POOH to 2586' Wiped tight spots. Overpull 50 K also took weight going down. 10:00 - 10:30 0.50 DRILL WIPR SURFAC RIH to 3348'. Wiped tight spots. 10:30 - 10:45 0.25 DRILL REAM SURFAC Washed to 3401' (Precaution). 10:45 - 12:00 1.25 DRILL CIRC SURFAC Circulated hole clean. 12:00 - 14:30 2.50 DRILL TRIP SURFAC Observed well and POOH to BHA. 14:30 - 16:30 2.00 DRILL PULD SURFAC Laid down BHA. 16:30 - 18:00 1.50 CASE RURD SURFAC Cleaned floor and rigged up to run casing. 18:00 - 22:00 4.00 CASE RUNC SURFAC PJSM and ran 9 5/8" casing to 1950'. Had to wash down several times from 520' to 1950'. 22:00 - 22:30 0.50 CASE CIRC SURFAC CBU @ 5 BPM. 22:30 - 23:15 0.75 CASE RUNC SURFAC Ran 9 5/8" casing to 2400' had to work pipe and wash down. 23:15 - 00:00 0.75 CASE CIRC SURFAC Partial returns while washing. Circulated and worked pipe to regain full returns. Returns 50% of normal. 5/19/2004 00:00 - 02:00 2.00 CASE CIRC SURFAC Reciprocate pipe from 2453' to 2411 '. Had full returns at 5 bpm at 360 psi. Pump low vis sweep with 15 ppb nut plug w/ DD soap. 02:00 - 05:00 3.00 CASE RUNC SURFAC Circ csg down from 2453' to 3352'. MU landing jt. Land csg at 3391'. 05:00 - 05:30 0.50 CASE RURD SURFAC LD Franks fill-up tool. Blow down top drive. RU cement head and lines. 05:30 - 06:45 1.25 CEMEN CIRC SURFAC Pump lo-vis sweep with nut plug and soap. Circ and condition mud for cement job at 7 bpm at 400 psi. No losses to formation. 06:45 - 07:00 0.25 CEMEN SFTY SURFAC PJSM on cement job. 07:00 - 09:00 2.00 CEMEN PUMP SURFAC Pump 40 bbls biozan/nutplug spacer and 5 bbls H20. Test lines to 2500 psi. Drop bottom plug. Pump 50 bbls 12.5 ppg mud push spacer, 415 bbls 10.7 ppg lead cement and 49 bbls 15.8 ppg tail cement. Drop top plug. 09:00 - 09:30 0.50 CEMEN DISP SURFAC Dowell pumped 20 bbls H20. Displace with rig pumps with 9.6 ppg mud. Bumped plug. 09:30 - 10:15 0.75 CASE DEQT SURFAC Test csg to 2500 psi fro 30 min. 10:15 -11:15 1.00 CASE RURD SURFAC RD cement head, bales and elevators. 11 :15 - 13:30 2.25 CASE NUND SURFAC ND surface riser, flowline, tum-buckles and mousehole. 13:30 - 14:30 1.00 CASE NUND SURFAC Installed and tested FMC wellhead. 14:30 - 17:00 2.50 WELCT NUND SURFAC Nippled up BOP. 17:00-21:30 4.50 WELCT BOPE SURFAC Tested Annular to 250/3500 PSI. Tested rams,choke lines, kill lines, choke and kill valves and floor valves to 250/5000 PSI. Tested IBOP to 250/5000 PSI. Test witiness waived by John Crisp State inspecter. 21 :30 - 22:00 0.50 DRILL PULD SURFAC Pulled tesr plug and installed wear bushing. 22:00 - 00:00 2.00 DRILL PULD SURFAC PJSM. Picked up and stood back 4" drill pipe from the pipe shed. 70 Jts picked up. 5/20/2004 00:00 - 00:30 0.50 RIGMNT RSRV SURFAC Serviced top drive. 00:30 - 05:15 4.75 RIGMNT RGRP SURFAC Repaired Iron Roughnek. 05:15 - 09:45 4.50 DRILL PULD SURFAC Continue picking up 4" drill pipe from pipe shed. 09:45 - 10:30 0.75 DRILL CIRC SURFAC Circulated mud to break gels before standing back pipe. 10:30 - 16:15 5.75 DRILL PULD SURFAC Continued picking up drill pipe into hole and standing back. 16:15 - 20:00 3.75 DRILL PULD SURFAC Picked up Geopilot BHA. 20:00 - 20:30 0.50 DRILL CIRC SURFAC Shallow tested tools. 20:30 - 22:45 2.25 DRILL PULD SURFAC RIH picking up drill pipe to 3050'. 22:45 - 23:30 0.75 DRILL REAM SURFAC Washed down to 3298'. 23:30 - 00:00 0.50 CEMEN DSHO SURFAC Drilled shoe track to 3301'. 5/21/2004 00:00 - 01 :30 1.50 CEMEN DSHO SURFAC Cleaned out shoetrack and rathole to 3401', 01 :30 - 01 :45 0.25 DRILL DRLG SURFAC Drilled from 3401' to 3421'. ADT .25 Hrs. 01:45 - 02:15 0.50 DRILL CIRC SURFAC CBU. Printed: 6/25/2004 2:18:51 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/21/2004 02:15 - 03:00 0.75 DRILL FIT SURFAC Did FIT. 17.7 EMW. 03:00 - 12:00 9.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 3421' to 4557'.3074' TVD. ADT - 6.2 hrs. = ART - 6.2 hrs. AST - 0 hrs. WOB - 5/13 k RPM.. 140 GPM 600 @ 2790 psi String wt. PU 165 SO 130 Rot 130 Torq offlon Btm 9300/10500. Displaced mud system on the fly. 12:00.. 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 4557' to 6000'. 3798' TVD. ADT - 7.3 hrs. = ART - 7.3 hrs. AST - 0 hrs. WOB - 15/22 k RPM - 140 GPM 600 @ 3260 psi String wt. PU 165 SO 110 Rot 130 Torq offlon Btm 9500/10500. 5/22/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 6000' to 7677'. 4700' TVD. ADT - 7.8 hrs. = ART - 7.8 hrs. AST - 0 hrs. WOB - 5/20 k RPM - 140 GPM 600 @ 2730 psi String wt. PU 195 SO 125 Rot 150 Torq off/on Btm 12500/13500. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 7677' to 9236'. 5543' TVD. ADT - 7 hrs. = ART - 7 hrs. AST - 0 hrs. WOB - 15/22 k RPM -140 GPM 600 @ 3000 psi String wt. PU 210 SO 130 Rot 160 Torq off/on Btm 13000/14500. 5/23/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2' hole from 9236' to 10797'. 6382' TVD. ADT - 8.1hrs. = ART - 8.1 hrs. AST - 0 hrs. WOB - 15/22 k RPM -140 GPM 600 @ 3420 psi String wt. PU 225 SO 140 Rot 175 Torq off/on Btm 16500/17500. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole from 10787' to 12004'. 7040' TVD. ADT - 8.05 hrs. = ART.. 8.05 hrs. AST- 0 hrs. WOB - 15/22 k RPM - 140 GPM 600 @ 3860 psi String wt. PU 235 SO 140 Rot 180 Torq off/on Btm 13500/14500. 5/24/2004 00:00 - 06:30 6.50 DRILL DRLG INTRM1 Drill 8 1/2" hole from 12004' to 12652'. 7249' TVD. ADT - 4.45 hrs. = ART - 4.45 hrs. AST - 0 hrs. WOB.. 13/22 k RPM - 130 GPM 575 @ 3670 psi String wt. PU 250 SO 140 Rot 185 Torq off/on Btm 1000/13000. 06:30 - 08:45 2.25 DRILL CIRC INTRM1 Pumped sweep and circulated hole clean. 08:45 - 12:00 3.25 DRILL WIPR INTRM1 POOH with pump to 10,893'. Max overpull 20 K. 12:00 . 12:30 0.50 DRILL WIPR INTRM1 RIH to 12,570' no problem. 12:30 - 14:30 2.00 DRILL CIRC INTRM1 Washed to 12.652'. Pumped sweep and circulated hole clean. 14:30 - 15:30 1.00 DRILL TRIP INTRM1 POOH with pump spotting pill from 12652' to 11620'. 15:30 - 22:00 6.50 DRILL TRIP INTRM1 POOH on trip tank to BHA. 22:00 - 00:00 2.00 DRILL PULD INTRM1 POOH and lay down BHA. 5/25/2004 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 Handle BHA - LD NM flex DC's - pull pulser f/ MWD - LD MWD - GeoPilot - remove GeoPilot skid fl rig floor 01 :00 - 01 :45 0.75 CASE OTHR INTRM1 MU stack washer & flush BOP stack - Pull wear bushing 01 :45 - 03:30 1.75 CASE OTHR INTRM1 PJSM - Close blind rams.. change top VBR to 7" - Set test plug & test to 5000 psi - Pull test plug - Set thin wall wear bushing 03:30 .. 04:30 1.00 CASE OTHR INTRM1 RU to run 7' casing - PJSM 04:30 - 07:45 3.25 CASE RUNC INTRM1 Ran 7" 267# L-80 MBTC casing as follows: FS ( Ray Oil Tools Sliver bullet) 2 jts. - FC (Weatherford) 2 jts. ( BakerLoc first 4 cnnections - fill pipe & check floats) 76 jts. to 3376' (80 jts. total) 07.:45 - 08:15 0.50 CASE CIRC INTRM1 Circulate casing volume @ 4 BPM @ 300 psi.. PU wt. 135 SO wt. 113 Printed: 6/25/2004 2: 18:51 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 . Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/25/2004 08:15 - 12:30 4.25 CASE RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/3376' to 7206' ( 170 jts. total) 12:30 - 13:30 1.00 CASE CIRC INTRM1 Circulate bottoms up + 4 BPM @ 520 psi FCP - PU wt. 215 SO wt. 135 13:30 - 18:30 5.00 CASE RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing fl 7206' to 11,240' (265 jts. total) 18:30 - 20:00 1.50 CASE CIRC INTRM1 Circulate bottoms up + @ 4 BPM @ 680 psi FCP - PU wt 355 SO wt. 140 20:00 - 23:00 3.00 CASE RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/11 ,240' to 12,606' (297 jts. total) - PU hanger & landing jt. - land casing w/ FS @ 12,642' FC @ 12,552' - string took excess wt. @ 11,370' 15 to 20 k - worked through tight spot wI 35 k down - ran 2 jts. wI no returns - stab in & attempt to circulate - work pipe - had slight returns @ 3.5 BPM @ 490 psi - Ran in hole wI remaining 27 jts w/ no retums - SO wt. 160 to 135 23:00 - 00:00 1.00 CASE RURD INTRM1 RD casing equipment - & Frank's fill up tool - blow down TD - MU cement head & cement lines 5/26/2004 00:00 - 00:45 0.75 CEMEN CIRC INTRM1 Attempt to regain circulation @ 2 to 4 BPM @ 520 psi - Observed slight flow @ flow line - PJSM on cmt procedures 00:45 - 03:15 2.50 CEMEN PUMP INTRM1 Cement 7" casing as follows: Pumped 10 bbls CW-100 @ 4BPM @ 400 psi - Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 psi - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switch over to rig pumps & displace w/456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug w/11 00 psi - Check floats - floats held - CIP @ 0300 hrs. Observed slight flow @ flow line during job wi flow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bumped 03:15 - 04:00 0.75 CEMEN OTHR INTRM1 Test 7" casing to 3500 psi for 30 mins. 04:00 - 04:45 0.75 CEMEN RURD INTRM1 RD cement lines, cmt head, casing elevators, & landing jt. 04:45 - 05:45 1.00 WELCT OTHR INTRM1 Pull thin wall wear bushing - Install 7 x 9 5/8" pack off & test to 5000 psi 05:45 - 06:45 1.00 WELCT EaRP INTRM1 PJSM - Change top pipe rams f/7" back to 3 1/2" x 6" VBR 06:45 - 11 :00 4.25 WELCT BOPE INTRM1 RU & test BOPE - Hydril to 250 & 3500 psi - Pipe rams, blind rams, kills & choke line valves, choke manifold valves, TD IBOP's, Floor & dart valves to 250 & 5000 psi - performed accumulator closure test - witnessing of test was waived by Jeff Jones 11 :00 - 11 :30 0.50 WELCT OTHR INTRM1 Pull test plug - install wear bushing - LD test jt. 11 :30 - 12:00 0.50 DRILL OTHR INTRM1 PU drill bails & 4" elevators 12:00 - 16:00 4.00 DRILL PULD INTRM1 PU & RIH w/159 jts. 4" drill pipe fl pipe shed (to drill 6 1/8" section) 16:00 - 17:00 1.00 RIGMNT RSRV INTRM1 PJSM - Slip & cut 90' drill line 17:00 - 19:30 2.50 DRILL TRIP INTRM1 POOH w 4" drill pipe & stand back in derrick (SLM) 19:30 - 00:00 4.50 RIGMNT OTHR INTRM1 Due to rising water from break up & possibility of road being washed out between CD1 &CD2 - decision was made to suspend drilling operations & perform rig maintenance while monitoring water conditions Prep mud pits for some repairs - clean & service euqipment 5/27/2004 00:00 - 00:00 24.00 RIGMNT OTHR INTRM1 Rig maintenance while monitoring break up water for possible lose of road between CD1 &CD2 Cleaning wind walls inside derrick & cellar - Clean mud pits in prep for some welding work on suction valves - work on drag chain - Inspect & change oil in chain case on mud pumps - Work on Top Drive replace Printed: 6/25/2004 2:18:51 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/27/2004 00:00 - 00:00 24.00 RIGMNT OTHR INTRM1 block f/ air soleniods to grabs & link tilt - clean traction motors & replace brushes in draw works Service pipe handler in pipe shed - Change out bulk material hose to pits 5/28/2004 00:00 - 00:00 24.00 RIGMNT OTHR INTRM1 Continue rig maintenance waiting on high water from break up to recede Cleaning wind walls - Change disc brakes on draw works - Working on suction valves in pits - clean pump room - Change oil in centrifugal pumps - Clean drip pan under draw works - load, drift,& strap 4 1/2" tubing 5/29/2004 00:00 - 09:00 9.00 RIGMNT OTHR INTRM1 C~ntinue rig maintenance - Replace water line in pits - Finish cleaning wind walls 09:00 - 12:00 3.00 DRILL PULD INTRM1 MU BHA #4 - 6 1/8"bit - 5" motor w/1.22 bend & ABI - MWD - Upload MWD - PU NM flex Dc's, HWDP & jars - shallow test MWD 200 gpm @ 670 psi 12:00 - 18:00 6.00 DRILL TRIP INTRM1 RIH w/ BHA # 4 f/375' to 12,400' - fill pipe every 20 std. - Circ btms up @ 4,000' & 8,000' 18:00 - 18:30 0.50 DRILL REAM INTRM1 Establish circ - wash & ream f/12,400' to 12,518' - Tag top of cmt. 18:30 - 20:45 2.25 CEMEN DSHO INTRM1 Clean out shoe track - cmt - wiper plugs - FC @ 12,552 - cmt - FS @ 12,640' - Clean out rat hole to 12,652' 20:45 - 21 :00 0.25 DRILL DRLG INTRM1 Drill 20' new hole f/12,652' to 12,672' - 7251' TVD RPM 50 WOB 10/15 200 GPM @ 1800 psi String wt. PU 230 So 120 Rot 175 Torque on/off btm - 18,000/18,000 ft. Ibs. ATD - .25 21 :00 - 22:30 1.50 DRILL CIRC INTRM1 Change well over to 8.8 ppg FloPro - Pumped 40 bbls spacer SafeServo - 45 bbls Hi Vis FloPro & FloPro - shut down & monitor well - static 22:30 - 23:30 1.00 DRILL FIT INTRM1 RU & perform FIT to 12.5 ppg EMW wI 1400 psi wI 8.8 ppg mud & 7249' TVD - RD 23:30 - 00:00 0.50 DRILL OTHR PROD Blow down lines - Obtain SPR 5/30/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal section f/12,672' to 13,499' MD -7256' TVD ADT - 8.22 hrs. = ART- 4.94 hrs. AST- 3.28 hrs. WOB - 8 -14 k RPM 0 -90GPM 214 @ 2600 psi String wt. PU 220 SO 135 Rot 173 Torque on/off btm. - 16,500/16,000 ft. Ibs. ECD -10.3 to 10.7 Average ROP - 100.6 ftIhr 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal section f/13,499' to 14,319' MD -7257' TVD ADT - 7.1 hrs. = ART - 5.03 hrs AST - 2.07 hrs. WOB -10 -13 k RPM 90 GPM 220 @ 2740 psi String wt. PU 220 SO 130 Rot 170 Torque onloff btm - 14,400/11,600 ft. Ibs. ECD - 10.6 to 10.9 Average ROP - 115.5 ftIhr Overall ROP - 107.5 ftIhr 5/31/2004 00:00 - 02:30 2.50 DRILL DRLH PROD Drill 6 1/8" horizontal section f/14,319' to 14,555' MD 7258' TVD WOB 8/12 k RPM 90 GPM 217 @ 2800 psi- Hit drilling break @ 14,545 - flow dropped off f/22% to 4% 02:30 - 04:30 2.00 DRILL CIRC PROD Slow pump rate to 3 BPM - Circ - monitor hole for losses & mix LCM pill (losses 240 to 24 BPH) Circulate btms up - No gas Printed: 6125/2004 2:18:51 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 5/31/2004 04:30 - 05:15 0.75 DRILL CIRG PROD Spot 40 bbls LCM pill @ 30 #/ bbl (Mix II Fine, med. & course) 05:15 - 08:00 2.75 DRILL DRLH PROD Drill 6 1/8" horizontal section fl 14,555' to 14,690' wI losses @ 60 to 100 bbl/hr WOB 4/10 k RPM 90 GPM 172 @ 2060 psi Well breathing on connections 0.75 DRILL CIRG PROD Girc & Spot 40 bbls LCM pill 30 #/bbl (Mixll fine, med. & course) 2.75 DRILL DRLH PROD Drill 61/8" horizontal section f/14,690' to 14,786' MD 7264' TVD wi losses @ 60 bbl/hr WOB 4/10 k RPM 90 GPM 172 @ 2060 psi String wt. PU 215 SO 135 Rot 175 Torque on/off btm - 16,500/16,000 ftIIbs Total ADT 5.37 hrs = ART - 4.64 hrs AST - .73 hrs Well breathing on connections Lost 676 bbls to formation 1.00 WELCT OTHR PROD Perform Exhale test - Shut in well monitor pressure - stabilized in 10 mins. DP 90 psi Csg 170 psi - Bleed off through choke for 5 mins - casing pressure went to 0 when choke was opened - Shut in well monitor pressure - stabilized in 10 mins. DP 100 Csg 100 psi - Bleed off & open well 4.00 DRILL DRLH PROD Drill 6 1/8" horizontal section fl 14,786' to 15,029' MD wI losses @ 35 bblsl hr WOB 6/8 k RPM 75 GPM 184 @ 2100 psi Well breathing on connections Hit drilling break @ 14,019' - flow dropped off fl 22% to 4% 1.50 DRILL CIRC PROD Slow pump rate to 3 bbl/min - Mixed & pumped 40 bbls LCM pill @ 30 #/bbl - same mix as above 6.00 DRILL DRLH PROD Drill 6 1/8" horizontal section f/15,029' to 15,358' MD 7262' TVD wi losses @ 80 to 120 bbls/hrs WOB 5/6 k RPM 75 GPM 184 @ 2180 psi String wt. PU 270 SO 130 Rot 175 Torque on/off btm - 17,100/12,900 ftllbs Total ADT f/1200 hrs to 0000 hrs - ADT - 5.70 hrs. = ART 4.14 hrs. AST 1.07 hrs Well breathing on connections Lost 947 bbls to formation 08:00 - 08:45 08:45 - 11 :30 11 :30 - 12:30 12:30 - 16:30 16:30 - 18:00 18:00 - 00:00 6/1/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Total losses fl 0000 to 0000 - 1,623 bbls 8.8 ppg FloPro Drill 6 1/8" horizontal section fl 15,358' to 15,957' MD 7282' TVD WOB 5/10 k RPM 75 GPM 176 @ 1960 psi String wt. PU 225 SO 135 Rot 175 Torque onloff btm - 16,500/15,000 ftllbs Total ADT 10.99 hrs = ART - 9.23 hrs AST - 1.76 hrs Losses ave. 60 BPH I Well breathing on connections Pumping 35 bbls LCM pills (30 ppb Mixll corse, medium, fine) every 3 hrs. Lost 720 bbls to formation Drill 6 1/8" horizontal section fl 15957' MD - 7298' TVD ADT - 6.95 hrs = ART - 3.95 AST -3.0 hrs WOB 10/15 k RPM 85 GPM 197 @ 2680 psi Stimg wt. PU 230 SO 135 Rot 175 Torque onloff btm. - 16,000/13,000 ftllbs. Losses ave. 60 BPH / well breathing on connections 12:00 - 00:00 12.00 DRILL DRLH PROD Printed: 6/25/2004 2:18:51 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 6/1/2004 12:00 - 00:00 6/212004 00:00 - 02:00 12.00 DRILL DRLH PROD 2.00 DRILL DRLH PROD 02:00 - 06:00 4.00 DRILL CIRC PROD 06:00 - 08:30 2.50 DRILL CIRC PROD 08:30 - 09:30 1.00 WELCT OBSV PROD 09:30- 10:30 10:30 - 11 :30 11 :30 - 20:00 20:00 - 22:30 6/3/2004 22:30 - 23:00 23:00 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 08:00 08:00 - 13:15 13:15 - 15:45 1.00 DRILL CIRC PROD 1.00 DRILL 8.50 DRILL TRIP PROD OTHR PROD 2.50 DRILL OTHR PROD 0.50 RIGMNT RSRV PROD 1.00 DRILL OTHR PROD 3.50 DRILL OTHR PROD 2.50 DRILL 2.00 DRILL TRIP CIRC PROD PROD 5.25 DRILL TRIP PROD 2.50 DRILL PULD PROD Pumping 20 bbls LCM pills ( 30ppb Mix II course,medium &fine) every 3 hrs. Lost 480 bbls to formation Total loses past 24 hrs. 1200 bbls - Cumulative 2823 bbls Drill 61/8" horizontal section f/16,399' to 16,433' MD -7295' TVD TD called by geologist WOB 4/12 RPM 0/90 GPM 197 @ 2490 psi ADT - 2.18 hrs. = ART - .13 AST - 2.05 hrs. String wt. PU 230 SO 135 Rot 175 Torque on/off btm - 16,500/15,000 ftllb Well still breathing on connections CBU - Pump 40 bbls high vis sweep and circ hole clean - 4.8 ppm / 2100 psi/ 85 rpm Losses ave. 30 bph. Prepare for change over to brine. Flow check well - well breathing. Pumped 40 bbls high vis spacer and change well over to 8.8 ppg brine. Flow check well, well breathing. Perform Exhale test - Shut in well monitor pressure - stabilized in 10 mins. DP 30 psi Csg 30 psi - Bleed off through choke for 5 mins - casing pressure went to 0 when choke was opened - Shut in well monitor pressure - stabilized in 10 mins. DP 20 Csg 0 psi - Bleed off & open well. Continue circulating wth brine untill returns look clean. Flow check well, slight breathing, static in 5 minutes. POOH on trip tank from 16432' to 15072', losing 7 bph. Attempted to pull stand #14 - pipe stuck. Work stuck pipe with slump and torque to 26K ftllbs. Jar down with 12 k ftllbs torque in pipe - Qar functional limit) Hit up jar with 31 OK pulled to 450K.Spot 40 bbls polymer pill across BHA, continue to work stuck pipe. Circ and reduce brine wt. from 8.8 to 8.5 ppg. Continue to work pipe with torque and down jar only. Pumped 122 bbls minerial oil & displace into annulus to lighten hydrastatic pressure on well to 2910 psi - Continue to work stuck pipe - Jarring down & work pipe with torque & slump starting w/15k to & working up to 30k torque Adjust brakes Continue working stuck pipe - Torque & slump & jarring down Jar on stuck pipe. Displace mineral oil out of annulas with 8.5 ppg brine - continue to torque, slump and jar down on pipe. Jarred pipe free @ 0145 hrs. Worked pipe up to 15002' and complete CBU @ 4.6 bpm 1940 psi 160 rpm. POOH on trip tank from 15002' to 12550'. Pump 40 bbls high vis sweep to circ casing clean @ 4.9 bpm 11260 psi / 60 rpm Inspect Derrick - post jarring opts. Monitor well, static losses @ 5 bph. POOH on trip tank from 12550' to 9250', pump dry job. Continue to POOH to BHA. LD 6 1/8" BHA - Found no signs of external damage to any componets of the BHA - Couldn't down load data fl MWD Printed: 6/25/2004 2:18:51 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-57 C02-57 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 5/14/2004 Rig Release: 6/4/2004 Rig Number: Spud Date: 5/16/2004 End: 6/4/2004 Group: 6/3/2004 15:45 - 16:45 16:45 - 00:00 1.00 CMPL TN RURD CMPL TN Pull wear bushing - RU to run 4 1/2" completion - PJSM 7.25 CMPL TN RUNT CMPL TN Ran 41/2" completion as follows: WLEG - 41/2" 12.6# L-BO IBTM pup jt - 41/2" XN nipple - 1 jt 41/2" 12.6# L-BO IBTM tbg - 41/2" 12.6# L-BO IBTM pup jt. - Baker S-3 packer wI mill out extension - 4 1/2" 12.6# L-BO IBTM pup jt. - 2 jt. 41/2" 12.6# L-BO IBTM tbg - 41/2" 12.6# L-BO IBTM pup jt. - Cameo GLM w/ dummy valve - 41/2" 12.6# L-BO IBTM pup jt. - 213 jts. 4 1/2" 12.6# L-BO IBTM tbg - Camco 41/2" DB nipple- 4 jts. 4 1/2" 12.6# L-BO IBTM tbg. to 9503' Ran total of 217 jts of 273 jts. total to run 6/4/2004 00:00 - 01 :30 Lost 290 bbls brine to formation past 24 hrs. 1.50 CMPL TN RUNT CMPL TN Continue running 41/2" completion - Ran 56 jts. 4 1/2" 12.6# L-80 IBTM tbg ( 273 jts. total) MU FMC tbg hanger & landing jt B. - Land tbg in wellhead wI tail @ 11,995.73' - XN nipple @ 119B3.54' - Packer @ 11,932' - GLM @ 11,817.63' & DB nipple @ 2666' 12:00 - 13:00 13:00 - 00:00 . Note - Ran hanger w/ TWC installed & landed w/landing jt. B RILS and test hanger seals to 5000 psi - LD landing jt. B N/D BOPE, Change out junk sub on top drive. N/U tree and test tubing hanger adapter to 5000 psi/10 min. Test tree to 5000 psi 10 min.-OK. Pull TWC - RU circulating manifold and hardline to tubing and annulus on tree. Held Safety and Opts meeting for change over with crew. Test lines to 4000 psi - Displace well wI 174 bbls 9.2 ppg KCL brine & 235 bbls of diesel (tbg volume plus 2000' tvd ann. vol.) for flowback and freeze protection. RU lubricator - drop ball and rod - RD lubricator Pressure test lines to 4000 psi - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 750 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off pressure - vaccume out lines - RD lines & squeeze maniflod 1.00 CMPL TN OTHR CMPL TN RU FMC lubricator and install BPV - RD lubricator and secure wellhead. 11.00 CMPL TN OTHR CMPL TN RU and lay down excess 4" drill pipe from derrick for rig move. 01 :30 - 02:30 1.00 CMPL T OTHR CMPL TN 02:30 - 05:00 2.50 CMPL TN NUND CMPL TN 05:00 - 06:00 1.00 CMPL TN OTHR CMPL TN 06:00 - 06:15 0.25 CMPL TN SFTY CMPL TN 06:15 - 09:00 2.75 CMPL TN FRZP CMPL TN 09:00 - 09:45 0.75 CMPL TN OTHR CMPL TN 09:45 - 12:00 2.25 CMPL T PCKR CMPL TN RELEASE RIG @ 2359 hrs. 6/4/2004 Move to CD2-31 Printed: 6/25/2004 2:18:51 PM e e ~/ ConocoPhillips Casing Detail 9518" Surface Casinø Well: Date: C02-57 5/18/2004 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.70 FMC Gen V Hanger 2.21 36.70 Jts 3 to 81 79 Jts 9-518" 36# J-55 BTC Csg 3262.37 38.91 Davis Lynch Float Collar 1.48 3301.28 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 86.09 3302.76 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 3388.85 3391.15 TO 12 1/4" Surface Hole 3401.00 RUN TOTAL 45 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (One stop ring on Jt #2) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32,34,36,38,40,42,44,46,48,50,52,54,56,58,60,62 64,64,66,68,70,72,74,76,78 90 joints in the pìpe shed. Run 81 joints-9 joints stay out ~ <.:... \ \. ~.. \\.Ctcl r. '" ......... \ 011 Jr\\. ........ r--. \ \ ~ Ç. ~d - ;)... "\ Ä\) " , , ,",-OV\, ;}O~·- .~~ Use Best-o-Life 2000 pipe dope Remarks: Up Wt - ??? k On Wt - ??? k . Block Wt - 75k Supervisor: D. Burley / L Hill legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRilLING Report #: Start: 1 5/14/2004 of 3 Spud Date: 5/16/2004 Report Date: 5/19/2004 End: 6/4/2004 Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 3,391 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/19/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) SQ TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co; Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: 139.80 Meas. From: 150 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 294 (gpm) Mud Circ Press: (psi) Start Mix Cmt: 07:31 Start Slurry Displ: 08:36 Start Displ: . 08:36 End Pumping: 09:17 End Pump Date: 5/19/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbllmin) 7.00 (bbl/min) Y 618 (psi) 1,000 (psi) 1,000 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 150.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: Biozan water w/nut plug Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: 1°F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: Wash Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/10/2004 2:19:42 PM Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 2,891.00 (ft)To: (ft) Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: AS Lite Cmt Vol: 415.0 (bbl) Slurry Vol:544 (sk) Class: Density: 10.70 (ppg) Yield: 4.28 (fP/sk) Water Vol: 251.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: 19.40 (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry Interval: 3,391.00 (ft)To: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: 2,891.00 (ft) Cmt Vol: 47.5 (bbl) Slu'ry Vol230 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ftS/sk) Water Vol: 29.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: 5.10 (gal) Foam Job: N Pressure (psi) (psi) Printed: 6/10/2004 2: 19:42 PM e e Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) I How Determined: TOC Sufficient: I Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Pump 40 bbls biozan/nutplug spacer and 5 bbls H20. Test lines to 2500 psi. Drop bottom plug. Pump 50 bbls 12.5 ppg mud push spacer, 415 bbls 10.7 ppg lead cement and 49 bbls 15.8 ppg tail cement. Drop top plug. Dowell pumped 20 bbls H20. Displace with rig pumps with 9.6 ppg mud. Bumped plug. Printed: 6/10/2004 2:19:42 PM ~ .... - ..:. - WELL NAME 1 JOB NUMBER EVENT CODE 124 HRS PROG TMD TVD DFS REPT NO. I DATE CD2-57 ODR 3,401.0 2,384.0 2.70 5 5/18/2004 SUPERVISOR I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG D. Lutrick / L. Hill dovon1 @PPco.co Dovon 19 Alpine 17,259.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Circulatino prior to cementino casino. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Cmt casina. ND Riser/NU and test BOP. PU DP & BHA. 5/10/2004 106,163 595,982 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. CLAYSTONE 10033832 LAST SURVEY: DATE TMD INC ' AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 5/18/2004 3,354.00 57.220 157.250 16.000 (in) @ 114.0 (ft) 9.625 (in) @ 3,370.0 (ft) ~9æ~cml 0 ~ 0 IP 1"\11 AAln I Ph/nM I PflMf ~. Ca I H2S I LIME I ES 240 38/61 27/76 I 6.41 I 2/ / 0.4/27.5 I 8.7/ I 0.01/0 I 20 I I I ~ 2 r~+ ~~ iWT.UP 27,000 140 " NUJI::õ 0.0. I 1.0. CONN TYPE Bit 1 1.00 12.250 4.500 Mud Motor 1 29.17 8.000 5.000 Sub - Float 1 2.47 8.000 2.870 Stabilizer 1 5.92 8.150 2.875 Crossover - NonMag 1 2.44 8.140 2.875 MWD 1 9.17 8.020 3.500 MWD 1 8.70 8.020 1.920 MWD 1 9.90 8.090 1.900 Drill Collar - Non Mag 1 31.03 2.812 2.875 Drill Collar - NonMag 1 31.03 8.062 2.880 Drill Collar - NonMag 1 30.80 8.062 2.880 Crossover 1 3.02 6.750 2.780 Drill Pipe - Heavy Wgt 3 89.85 5.000 3.000 Jars 1 32.70 6.130 2.500 Drill Pipe - Heavy Wgt 23 685.15 5.000 3.000 -- 2/ 2 12.250 HUGHES-CHR MX-C1 5044528 16/16/12/18/1 2,628.0 5/17/200 1-1-WT-A-E-I-NO-TD ~~æ~:-i :::~ ~~ ~ IN~I I II" 1,781.17 58.000 157.150 1,543.07 -624.86 279.55 684.41 2,635.28 58.230 156.380 1,981.31 -1,292.5 581.78 1,417.23 1,876.49 60.020 155.370 1,592.15 -699.65 312.45 766.08 2,730.48 58.810 157.640 2,031.02 -1,367.3 613.49 1,498.36 1,971.72 60.800 155.420 1,639.18 -7:'4.94 346.93 848.89 2,825.59 58.500 157.860 2,080.50 -1,442.4 644.24 1,579.47 2,067.23 61.160 155.840 1,685.51 -851.02 381.39 932.39 2,921.05 58.950 158.170 2,130.06 -1,518.1 674.79 1,660.93 2,162.46 58.920 155.640 1,733.06 -926.23 415.29 1,014.88 3,016.38 58.970 158.020 2,179.21 -1,593.9 705.26 1,742.47 2,257.46 58.290 155.680 1,782.55 -1,000.1 448.71 1,095.96 3,111.64 58.300 157.040 2,228.80 -1,669.0 736.34 1,823.71 2,352.96 58.600 154.830 1,832.53 -1,074.0 482.78 1,177.34 3,206.85 57.720 156.910 2,279.24 -1,743.4 767.93 1,904.40 2,448.26 58.390 155.480 1,882.33 -1,147.7 516.92 1,258.59 3,299.93 57.490 156.590 2,329.10 -1,815.6 798.95 1,982.94 2,543.27 57.780 155.820 1,932.56 -1,221.2 550.17 1,339.22 3,354.00 57.220 157.250 2,358.27 -1,857.5 816.80 2,028.44 e e Printed: 6/10/2004 2: 17:21 PM e e - - WELL NAME JOB NUMBER EVENT CODE 124 HRS PROG ITMD ITVD DFS REPT NO. DATE CD2-57 ODR 3,401.0 2,384.0 2.70 5 5/18/2004 ~~ ~:oIIp~æ;~Y1~~~ ~ E (in) LINER ( 1 Cotinental Emsco 12.000 6.000 79 334.18 2,850 668.36 2 I Continental Ensco 12.000 6.000 I 79 334.181 2,850 I 668.36 ==== 00:00 06:45 6.75 DRILL P DRLG SURFAC Drill 12 1/4" hole from 2900' to 3401'.2384' TVD. ADT - 5.44 hrs. = ART - 4.7 hrs. AST - .74 hrs. WOB - 10/25 k RPM - 0/80 GPM 651 @ 2680 psi String wt. PU 140 SO 118 Rot 130 Torq off/on Btm 8000/8500. 06:45 08:15 1.50 DRILL P CIRC SURFAC Pumped sweep and circulated hole clean. 08:15 10:00 1.75 DRILL P WIPR SURFAC POOH to 2586' Wiped tight spots. Overpull 50 K also took weight going down. 10:00 10:30 0.50 DRILL P WIPR SURFAC RIH to 3348'. Wiped tight spots. 10:30 10:45 0.25 DRILL P REAM SURFAC Washed to 3401' (Precaution). 10:45 12:00 1.25 DRILL P CIRC SURFAC Circulated hole clean. 12:00 14:30 2.50 DRILL P TRIP SURFAC Observed well and POOH to BHA. 14:30 16:30 2.00 DRILL P PULD SURFAC Laid down BHA. 16:30 18:00 1.50 CASE P RURD SURFAC Cleaned floor and rigged up to run casing. 18:00 22:00 4.00 CASE P RUNC SURFAC PJSM and ran 9 5/8" casing to 1950'. Had to wash down several times from 520' to 1950'. 22:00 22:30 0.50 CASE P CIRC SURFAC CBU @ 5 BPM. 22:30 23:15 0.75 CASE P RUNC SURFAC Ran 9 5/8" casing to 2400' had to work pipe and wash down. 23:15 00:00 0.75 CASE Np DH CIRC SURFAC Partial returns while washing. Circulated and worked pipe to regain full returns. Returns 50% of normal. 24 HR SUMMARY: Drill 12 1/4" hole from 2900' to 3401'. Circulated. Wiper Tripped and Circulated. POOH and RU to run casing. Ran casing to 2400'. Circulated to regain full returns. PI NO. , ConocoPhillips Company 1 Halliburton - Sperry-Sun 2 Fairweather E&P Service 1 M-I Drilling Fluids 3 Doyon Drilling Inc 26 Swaco 4 Dowell 2 ACI - Arctic Catering 5 Halliburton - Sperry-Sun 2 FMC Corporation Well he 1 Halliburton - Sperry-Sun m; .~ ~7=F~~ ~. ~~~=~~ Fuel ITEM gals 1,382 ~.. "~.. w 7,572 Fuel Camp gals 2,080 Water, Drilling bbls I 1,020 795 Water, Potable bbls 120 1,160 Printed: 6/10/2004 2:17:21 PM I - - - - ...... WELL NAME I JOB NUMBER EVENT CODE 124 HRS PROG TMD TVD DFS I"'~""~ CD2-57 ODR 3,401.0 2,384.0 3.70 6 5/19/2004 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD I DAILY TANG CUM. TANG D. Lutrick / L. Hill doyon1 @PPco.co Dovon 19 Alpine 17,259.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Picking UP 4" DP. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD PU DP & BHA. RIH. Drill ST. Drill to 3421'. FIT. Drill. 5/10/2004 456,771 1 052,753 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE AUTH. CLAYSTONE 10033832 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 5/18/2004 3,354.00 57.220 157.250 9.625 (in) @ 3,391.1 (ft) 7.000 (in) @ 12,631.0 (ft) 5/19/2004 ~ ~ 0 ~ I 0.5125.0 9.01 0.01/0 2() ES 57 28/17 516 8.2/ 2/ I I -- 00:00 02:00 2.00 CASE Np DH CIRC SURFAC Reciprocate pipe from 2453' to 2411'. Had full returns at 5 bpm at 360 psi. Pump low vis sweep with 15 ppb nut plug w/ DD soap. 02:00 05:00 3.00 CASE Np DH RUNC SURFAC Circ csg down from 2453' to 3352'. MU landing jt. Land csg at 3391'. 05:00 05:30 0.50 CASE P RURD SURFAC LD Franks fill-up tool. Blow down top drive. RU cement head and lines. 05:30 06:45 1.25 CEMENTF CIRC SURFAC Pump lo-vis sweep with nut plug and soap. Circ and condition mud for cement job at 7 bpm at 400 psi. No losses to formation. 06:45 07:00 0.25 CEMENT F SFTY SURFAC PJSM on cement job. 07:00 09:00 2.00 CEMENT F PUMP SURFAC Pump 40 bbls biozanlnutplug spacer and 5 bbl&H20. Test lines to 2500 psi. Drop bottom plug. Pump 50 bbls 12.5 ppg mud push spacer, 415 bbls 10.7 ppg lead cement and 49 bbls 15.8 ppg tail cement. Drop top plug. 09:00 09:30 0.50 CEMENT F DISP SURFAC Dowell pumped 20 bbls H20. Displace with rig pumps with 9.6 ppg mud. Bumped plug. 09:30 10:15 0.75 CASE P DEQT SURFAC Test csg to 2500 psi fro 30 min. 10:15 11 :15 1.00 CASE P RURD SURFAC RD cement head, bales and elevators. 11 :15 13:30 2.25 CASE P NUND SURFAC ND surface riser, flowline, turn-buckles and mousehole. 13:30 14:30 1.00 CASE P NUND SURFAC Installed and tested FMC wellhead. 14:30 17:00 2.50 WELCTL F NUND SURFAC Nippled up BOP. 17:00 21:30 4.50 WELCTL F BOPE SURFAC Tested Annular to 250/3500 PSI. Tested rams,choke lines, kill lines, choke and kill valves and floor valves to 250/5000 PSI. Tested IBOP to 250/5000 PSI. Test witiness waived by John Crisp State inspecter. 21:30 22:00 0.50 DRILL P PULD SURFAC Pulled tesr plug and installed wear bushing. 22:00 00:00 2.00 DRILL P PULD SURFAC PJSM. Picked up and stood back 4" drill pipe from the pipe shed. 70 Jts picked up. 24 HR SUMMARY: Ran and cemented 9 5/8" casing @ 3391 '. Tested casing. Nippled down riser and nippled up BOP. Tested BOP. Picked up 4" DP and stand back in derrick. ConocoPhillips Company 1 Halliburton - Sperry-Sun 2 Fairweather E&P Service 1 M-I Drilling Fluids 3 Doyon Drilling Inc 25 Swaco 4 Dowell 2 ACI - Arctic Catering 5 Halliburton - Sperry-Sun 2 FMC Corporation Well he Halliburton - Sperry-Sun e e Printed: 6/10/2004 2:18:12 PM Printed: 6/10/2004 2:18:12 PM Pump Rate:_ Strk/min ..... S Volume Input Strokes..... Bbls/Strk ..... Casing Test P a·. - Pumpin Shut-in ~ Strks Min Ri9:T T T I Supervisor: T"" ... annulus and DP. Hole Ft-TVD ;-r 2. 00 Ft2 Lbs Drive Weight: Lbs Desired PIT EMW: ppg Estimates for Test: 1039 psi Drive Estimates for 3. 4 1 bbls I..... PIT 15 Shut-in Pressure, 1000 2378 + 9.6 1 ppg .....1 1025 0.052 x Ft-MD (2378 Ft- TVD) = = Test: = Leak-oft Pressure + Mud Weight 0.052 x TVD EMW 3391 EMW 5 6 7 7.5 8 8 Lost 0 psi during test, held 100% of test pressure. ~ 3000 2500 2000 1500 PRESSURE INTEGRITY TEST _ IOCOPHILUPS Alaska, Inc. I L Hole i - - t ;t - - 9-5/8" 36#/ft J-55 BTC Mud Mud 10 min Gel: 00 Ft2 Test Pressure: Lbs Lbs 2.5 bbls W 0:: :::I W W W 0:: Q. 000 500 0 - 0 1 2 3 4 0 10 15 20 25 30 Barrels :'Ie, Minutes r I ... e e ~/ ConocoPhillips Casing Detail 7" Casing Well: CD2-57 Date: 5/26/2004 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 34.50 FMC Gen V Hanger 1.82 34.50 Jts 3 to 297 295 Jts 7" 26# L-80 BTCM Csg 12515.70 36.32 Davis Lynch Float Collar 1.32 12552.02 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.89 12553.34 Ray Oil Tools "Silver Bullet" Float Shoe 2.16 12640.23 12642.39 TO 8 1/2" Hole 12652.00 Total Centralizers: 53 Straight blade centralizer one per jt on jts # 1-12 Straight blade centralizer one per jt on jts. # 217,218,219 Straight blade centralizer one per jt on every other joint Starting @ # 221 to # 295 .. .. 305 joints in shed - 297 total jts. to run Last 8 jts. out Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 350 + k DnWt-145k Block Wt - 75k Supervisor: D.Mickey Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 12,642 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/25/2004 SQ Date: Date Set: BTM set: (ft) Csg Type: Production Casing SQ Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Steve Daughten Pipe Movement: Type: Cement Casing Volume Excess %: 40.00 Meas. From: N/A Time Circ Prior To Cementing: Mud Circ Rate: (gpm) Mud Circ Press: (psi) Start Mix Cmt: 01 :20 Start Slurry Displ: 01 :20 Start Displ: 01 :39 End Pumping: 03:00 End Pump Date: 5/26/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 6,200 (psi) 1,100 (psi) 5 (min) Y Returns: 10 Total Mud Lost: Cmt Vol to Surf: 600.00 (bbl) (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) PVNP: 9 (cp)/17 (lb/100ft2) Gels 10 see: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 456.00 (bbl) To: (ft) Description: CW100 Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature::oF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Chemical was Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 6/10/2004 2: 19:57 PM e e Legal Well Name: C02-57 Common Well Name: C02-57 Event Name: ROT - DRILLING Report #: Start: 2 5/14/2004 Spud Date: 5/16/2004 Report Date: 5/26/2004 End: 6/4/2004 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: MUDPUSH XL Class: Cmt Vol: 40.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 11,270.00 (f1)o: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) De~cription: LiteCRETE 10,345.00 (ft~mt Vol: 43.0 (bbl) Slurry Vol:72 (sk) Class: Density: 11.00 (ppg) Yield: 3.30 (ft3/sk) Water Vol: 18.9 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: 11.06 (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry Interval: 12,642.00 (f1)o: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: 11 ,900.00 (ft~rnt Vol: 31.0 (bbl) Slurry Vol:148 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 17.9 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Pressure (psi) (psi) Printed: 6/10/2004 2: 19:57 PM e Trade Name D-65 B-155 D-46 D-167 retarder DEFOAMER Fluid loss Shoe Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (It) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (It) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Cement 7" casing as follows: Pumped 10 bbls CW-100 @ 4BPM @ 400 psi - Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 psi - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug wI 20 bbls water f/ Dowell - Switch over to rig pumps & displace w/ 456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug w/1100 psi - Check floats - floats held - CIP @ 0300 hrs Observed slight flow @ flow line during job w/ flow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bumped Printed: 6/10/2004 2:19:57 PM e e WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD 1 DFS I REPT NO. DATE CD2-57 ODR 12,652.0 7,249.0 9.70 12 5/25/2004 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD I DAILY TANG CUM. TANG D. Mickey doyon1 @PPco.co Doyon 19 Alpine 17,259.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD Prep to test BOPE 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Test BOP - MU 6 1/8" BHA - RIH LOT. Drill. 5/10/2004 352,744 2,256,283 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE AUTH. FINE SAND 17.67 10033832 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 5/24/2004 12,583.37 81.190 152.760 7.000 (in) @ 12,642.0 (ft) 4.500 (in) @ 12,012.0 (It) 5/19/2004 . ""..,,, I 9.80 I PP I ECD I 9.80 ~ ~ H2It I '~ME I ES FV PV/YP GELS .... ...-..- ",,..IT <>1"\, ¡ 44 9/25 11/14 3.6/8.2 1/ / 0.3/15.0 I 9.21 0.10/2 1 20 I I ~ r I CODE ----- 00:00 01:00 1.00 DRILL P TRIP INTRM1 Handle BHA - LD NM flex DC's - pull pulser f/ MWD - LD MWD - GeoPilot - remove GeoPilot skid f/ rig floor 01:00 01:45 0.75 CASE P OTHR INTRM1 MU stack washer & flush BOP stack - Pull wear bushing 01:45 03:30 1.75 CASE P OTHR INTRM1 PJSM - Close blind rams - change top VBR to 7" - Set test plug & test to 5000 psi - Pull test plug - Set thin wall wear bushing 03:30 04:30 1.00 CASE P OTHR INTRM1 RU to run 7" casing - PJSM 04:30 07:45 3.25 CASE P RUNC INTRM1 Ran 7" 267# L-80 MBTC casing as follows: FS ( Ray Oil Tools Sliver bullet) 2 jts. - FC (Weatherford) 2 jts. ( BakerLoc first 4 cnnections - fill pipe & check floats) 76 jts. to 3376' (80 jts. total) 07:45 08:15 0.50 CASE P c'iRC INTRM1 Circulate casing volume @ 4 BPM @ 300 psi - PU wt. 135 SO wt. 113 08:15 12:30 4.25 CASE P RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/3376' to 7206' ( 170 jts. total) 12:30 13:30 1.00 CASE P CIRC INTRM1 Circulate bottoms up + 4 BPM @ 520 psi FCP - PU wt. 215 SO wt. 135 13:30 18:30 5.00 CASE P RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/7206' to 11,240' (265 jts. total) 18:30 20:00 1.50 CASE P CIRC INTRM1 Circulate bottoms up + @ 4 BPM @ 680 psi FCP - PU wt 355 SO wt. 140 20:00 23:00 3.00 CASE P RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/11 ,240' to 12,606' (297 jts. total) - PU hanger & landing jt. - land casing wI FS @ 12,642' FC @ 12,552' - string took excess wt. @ 11,370' 15 to 20 k - worked through tight spot wI 35 k down - ran 2 jts. wI no returns - stab in & attempt to circulate - work pipe - had slight returns @ 3.5 BPM @ 490 psi - Ran in hole w/ remaining 27 jts w/ no returns - SO wt. 160 to 135 23:00 00:00 1.00 CASE P RURD INTRM1 RD casing equipment - & Frank's fill up tool - blow down TD - MU cement head & cement lines 24 HR SUMMARY: LD BHA - RU & Run 7" csg to 12,642' - RU to cement Fairweather E&P Service 1 M-I Drilling Fluids 3 Doyon Drilling Inc 26 Swaco 4 Dowell 2 ACI - Arctic Catering 5 Halliburton - Sperry-Sun 2 FMC Corporation Well he 1 Halliburton - Sperry-Sun 2 ~ -~ ON~ UNITS - Fuel gals 1,710 9,270 Fuel Camp gals 2,130 Water. Drilling bbls I 1,290 885 II Water, Potable bbls I 120 760 Printed: 6/10/2004 2: 18:40 PM Printed: 6/10/2004 2: 18:40 PM Ri maintenance TMD 12,652.0 AUTH MD 17,259.0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 5/10/2004 221 ,105 AFE CUM INTANG WI MUD o CUM COST WI MUD 2,477,388 SUPERVISOR D. Micke CURRENT STATUS 24 HR FORECAST Ri LITHOLOGY AUTH. 10033832 LAST BOP PRES TEST 5/26/2004 Attempt to regain circulation @ 2 to 4 BPM @ 520 psi - Observed slight flow @ flow line - PJSM on cmt procedures 00:45 03:15 2.50 CEMENT PUMP INTRM1 Cement 7" casing as follows: Pumped 10 bbls CW-100 @ 4BPM @ 400 psi- Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 ps' - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug w/20 bbls water f/ Dowell - Switch over to rig pumps & displace w/ 456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug w/11 00 psi - Check floats - floats held - CIP @ 0300 hrs. Observed slight flow @ flow line during job w/ flow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bumped 03:15 04:00 0.75 CEMENT OTHR INTRM1 Test 7" casing to 3500 psi for 30 mins. 04:00 04:45 0.75 CEMENT RURD INTRM1 RD cement lines, cmt head, casing elevators, & landing jt. 04:45 05:45 1.00 WELCTL OTHR INTRM1 Pull thin wall wear bushing - Install 7 x 9 5/8" pack off & test to 5000 psi 05:45 06:45 1.00 WELCTL EaRP INTRM1 PJSM - Change top pipe rams f/7" back to 3 1/2" x 6" VBR 06:45 11 :00 4.25 WELCTL BOPE INTRM1 RU & test BOPE - Hydril to 250 & 3500 psi - Pipe rams, blind rams, kills & choke line valves, choke manifold valves, TD IBOP's, Floor & dart valves to 250 & 5000 psi - performed accumulator closure test - witnessing of test was waived by Jeff Jones 11 :00 11 :30 0.50 WELCTL OTHR INTRM1 Pull test plug - install wear bushing - LD test jt. 11 :30 12:00 0.50 DRILL P OTHR INTRM1 PU drill bails & 4" elevators 12:00 16:00 4.00 DRILL P PULD INTRM1 PU & RIH w/159 jts. 4" drill pipe f/ pipe shed (to drill 6 1/8" section) 16:00 17:00 1.00 RIGMNT P RSRV INTRM1 PJSM - Slip & cut 90' drill line 17:00 19:30 2.50 DRILL P TRIP INTRM1 POOH w 4" drill pipe & stand back in derrick (SLM) 19:30 00:00 4.50 RIGMNT N OTHR INTRM1 Due to rising water from break up & possibility of road being washed out between CD1 &CD2 - decision was made to suspend drilling operations & perform rig maintenance while monitoring water conditions Prep mud pits for some repairs - clean & service euqipment 24 HR SUMMARY: Attempt to circ for cement job - no returns - Cement 7" casing - Test casing to 3500 psi - set & test pack-off - Test BOPE - PU 4" DP - Slip & cut drilllline - POOH & Std. back DP - Rig maintenance Printed: 6/10/2004 2:19:13 PM e CD2-57 Fairweather E&P Service Doyon Drilling Inc Dowell Halliburton - Sperry-Sun Halliburton - Sperry-Sun 1 26 2 2 2 M-I Drilling Fluids Swaco ACI - Arctic Catering ASRC Energy Services ( Epoch Well Services Inc 3 4 5 2 2 Printed: 6/10/2004 2:19:13 PM PRESSURE INTEGRITY TEST CONOCOPHILUPS Alaska, Inc. Wel! Name: I Rig: Doyon Date: I I Volume Input Pump Rate: Drilling Supervisor: Mickey Pump Cement Unit I... Barrels ... Bbls/Strk ... Bbl/min ... Type of Test: lAnnUIUs Leak Off Test for Disposal Adequacy ....1 Pumping down annulus. .... Test I P Test Hole Size: 8-1/2" I.... [:ïæ ;Ii Hole Depth Shut-in Pumpina II Shut-in RKB-CHF: I 34.71Ft 3.391 IF 2. 3781Ft-TVD 1(, ':¡.d&:;IFt-MD I 6.135IFt-TVD Min Dsi Min Dsi Casinq Size and Description: 19-5/8" 36#/Ft J-55 BTC ....1 0 0 727 p~ ~ 1 0.25 I buter casing shoo test results in comments Mud Weight: 2 0.5 Description references outer casing string. Inner casing OD: In. _3 1 ize is that drilled below outer casing. - '-- 1.5 timated TOe for Hole Depth. 2 Enter inner casing OD at right Desired PIT EMW: 15.5 ppg 2.5 386 Estimates for Test: 705 psi 0.7 bbls 3 380 ....1 I.... 3.5 374 EMW :::: leak-off Pressure + Mud Weight :::: 864 9.8 PIT 15 Second 9 4 370 0.052 x TVD 0.052 x 2378 + Shut-in Pressure, psi 10 4.5 EMWat 3391 Ft-MD (2378 Ft-TVD) = 16.8 487 1 5 1000 -t1iL 6. IV" -.... 7 / ~ 7.5 ._.~ e-- 8 ~ .;P" ~ w ¡:;''L..I " * I) 8.5 3461 IX L? lv_ ...... ,,~ 9 3461 :J 9.5 . (/'J 500 (/'J ./ 10 W ''I. 11 IX: Q. Irl' W/l_.¡. ---:...; W70t.1\\Z.J ....;;7 F ---- !--- .... 0 0 2 4 Ii> 8 10 12 14 0 5 10 15 20 25 Volume Shut",ln time, Minutes ~ .......",__.1 Pu Bled Back 11:;.:;;;1 .........LEAK-OFF TEST 0 PIT 9518 LOT:::: 17.9 PPG EMW ... Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2, Slot Plan: CD2-57 CD2-57 MWD . Job No. AKMW3066896, Surveyed: 2 June, 2004 Survey Report 15 June, 2004 y G ~ \ o ....J )J Your Ref: API 501032049200 Surface Coordinates: 5974224.26 N, 371740.55 E (70· 20'16.1276" N, 151· 02' 26.5802" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 974224.26 N, 128259.45 W (Grid) Surface Coordinates relative to Structure: 218.22 S, 26.80 E (True) Kelly Bushing Elevation: 52. 80ft above Mean Sea Level Kelly Bushing Elevation: 52. 80ft above Project V Reference Kelly Bushing Elevation: 52.80ft above Structure spa............y-sul! QFUL...L..ING· seRVices A Halliburton Company Survey Ref: svy410 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 0.00 0.000 0.000 -52.80 0.00 O.OON 0.00 E 5974224.26 N 371740.55 E 0.00 CB-SS-Gyro 81.00 0.000 0.000 28.20 81.00 O.OON 0.00 E 5974224.26 N 371740.55 E 0.000 0.00 161.00 0.250 215.000 108.20 161.00 0.14 S 0.10W 5974224.12 N 371740.45 E 0.313 0.09 260.00 2.150 166.000 207.17 259.97 2.12 S 0.23 E 5974222.13 N 371740.74 E 2.015 2.02 349.00 5.500 161.000 295.96 348.76 7.78 S 2.02 E 5974216.45 N 371742.43 E 3.779 7.89 . 438.00 7.500 165.000 384.39 437.19 17.42 S 4.91 E 5974206.76 N 371745.16 E 2.303 17.85 527.00 9.000 163.000 472.46 525.26 29.69 S 8.45 E 5974194.43 N 371748.49 E 1.716 30.46 615.00 12.900 161.000 558.85 611.65 45.57 S 13.66 E 5974178.47 N 371753.43 E 4.452 47.04 703.00 15.300 157.000 644.19 696.99 65.54 S 21.40 E 5974158.36 N 371760.82 E 2.942 68.41 796.00 16.000 153.000 733.74 786.54 88.26 S 32.01 E 5974135.47 N 371771.05 E 1.383 93.48 MWD Magnetic 833.29 17.190 153.960 769.48 822.28 97.79 S 36.76 E 5974125.86 N 371775.64 E 3.275 104.13 924.07 20.580 153.890 855.36 908.16 124.18S 49.68 E 5974099.25 N 371788.10 E 3.734 133.50 1020.20 26.300 147.410 943.54 996.34 157.33 S 68.60 E 5974065.78 N 371806.45 E 6.518 171.56 1113.72 31.840 148.570 1025.24 1078.04 195.86 S 92.65 E 5974026.84 N 371829.83 E 5.954 216.67 1210.73 36.940 151.820 1105.28 1158.08 243.43 S 119.77E 5973978.82 N 371856.14 E 5.586 271.26 1305.42 38.470 154.980 1180.20 1233.00 295.20 S 145.67 E 5973926.61 N 371881.15 E 2.603 329.14 1400.75 41.630 156.090 1253.16 1305.96 351.04 S 171.05E 5973870.35 N 371905.58 E 3.398 390.46 1496.15 48.490 158.870 1320.52 1373.32 413.40 S 196.81 E 5973807.55 N 371930.26 E 7.479 457.86 1591.21 52.290 160.550 1381.12 1433.92 482.09 S 222.17 E 5973738.44 N 371954.44 E 4.223 530.80 1685.92 56.470 158.500 1436.27 1489.07 554.18 S 249.13 E 5973665.90 N 371980.16 E 4.751 607.50 1781.17 58.280 157.460 1487.62 1540.42 628.54 S 279.21 E 5973591.04 N 372008.97 E 2.111 687.58 1876.49 60.300 155.540 1536.30 1589.10 703.68 S 311.90 E 5973515.35 N 372040.36 E 2.737 769.49 . 1971.72 61.090 155.570 1582.91 1635.71 779.28 S 346.26 E 5973439.17 N 372073.43 E 0.830 852.52 2067.23 61.440 155.990 1628.83 1681.63 855.65 S 380.62 E 5973362.22 N 372106.47 E 0.532 936.26 2162.46 59.200 155.870 1675.98 1728.78 931.19S 414.36 E 5973286.12 N 372138.92 E 2.355 1018.97 2257.46 58.570 156.230 1725.07 1777.87 1005.52 S 447.37 E 5973211.23 N 372170.66 E 0.738 1100.28 2352.96 58.870 155.250 1774.66 1827.46 1079.93 S 480.91 E 5973136.26 N 372202.92 E 0.932 1181.88 2448.26 58.670 155.980 1824.07 1876.87 1154.15 S 514.55 E 5973061.48 N 372235.29 E 0.688 1263.36 2543.27 58.060 155.520 1873.90 1926.70 1227.90 S 547.78 E 5972987.17 N 372267.24 E 0.763 1344.24 2635.28 58.510 156.610 1922.27 1975.07 1299.44 S 579.53 E 5972915.10 N 372297.77 E 1.120 1422.49 2730.48 59.100 157.840 1971.58 2024.38 1374.53 S 611.05 E 5972839.48 N 372328.00 E 1.267 1503.85 2825.59 58.790 157.890 2020.64 2073.44 1450.00 S 641.75E 5972763.50 N 372357.40 E 0.329 1585.20 2921.05 59.240 158.150 2069.79 2122.59 1525.89 S 672.38 E 5972687.09 N 372386.73 E 0.526 1666.91 3016.38 59.250 158.410 2118.54 2171.34 1602.00 S 702.70 E 5972610.48 N 372415.74 E 0.235 1748.67 3111.64 58.590 157.310 2167.71 2220.51 1677.56 S 733.44 E 5972534.40 N 372445.19 E 1.208 1830.13 15 June, 2004 - 16:06 Page 20f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (!t) (ft) (o/100ft) 3206.85 58.000 156.960 2217.75 2270.55 1752.20 S 764.91 E 5972459.23 N 372475.38 E 0.694 1911.06 3299.93 57.780 156.640 2267.23 2320.03 1824.67 S 795.97 E 5972386.25 N 372505.20 E 0.375 1989.85 3354.00 57.510 157.360 2296.16 2348.96 1866.71 S 813.82 E 5972343.90 N 372522.32 E 1.231 2035.49 3439.21 57.410 157.090 2342.00 2394.80 1932.94 S 841.63 E 5972277.21 N 372548.99 E 0.292 2107.26 3534.77 56.630 157.780 2394.02 2446.82 2006.96 S 872.39 E 5972202.67 N 372578.48 E 1.016 2187.33 . 3630.52 55.990 157.910 2447.13 2499.93 2080.75 S 902.43 E 5972128.38 N 372607.26 E 0.678 2266.88 3724.05 55.230 157.870 2499.96 2552.76 2152.26 S 931.48 E 5972056.39 N 372635.08 E 0.813 2343.95 3821.56 54.310 157.370 2556.21 2609.01 2225.91 S 961.81 E 5971982.23 N 372664.14 E 1.032 2423.50 3917.21 53.300 158.240 2612.69 2665.49 2297.38 S 990.97 E 5971910.27 N 372692.08 E 1.286 2500.57 4012.91 52.490 158.130 2670.42 2723.22 2368.23 S 1019.33E 5971838.94 N 372719.23 E 0.851 2576.76 4107.60 51.590 158.470 2728.67 2781.47 2437.60 S 1046.94 E 5971769.11 N 372745.64 E 0.992 2651.27 4202.86 51.150 157.400 2788.14 2840.94 2506.56 S 1074.89 E 5971699.68 N 372772.41 E 0.992 2725.57 4298.61 50.760 159.620 2848.46 2901.26 2575.75 S 1102.13 E 5971630.04 N 372798.46 E 1.846 2799.77 4394.49 51.420 159.680 2908.68 2961.48 2645.70 S 1128.08 E 5971559.65 N 372823.21 E 0.690 2874.10 4489.43 52.260 160.400 2967.34 3020.14 2715.86 S 1153.56E 5971489.06 N 372847.49 E 1.067 2948.43 4585.00 54.840 160.590 3024.12 3076.92 2788.32 S 1179.22 E 5971416.18 N 372871.91 E 2.704 3024.91 4680.65 57.000 158.480 3077. 71 3130.51 2862.53 S 1206.93 E 5971341.51 N 372898.34 E 2.905 3103.84 4776.23 57.460 158.440 3129.45 3182.25 2937.28 S 1236.44 E 5971266.26 N 372926.57 E 0.483 3184.04 4871.64 58.290 156.100 3180.19 3232.99 3011.80 S 1267.66 E 5971191.22 N 372956.51 E 2.252 3264.76 4967.37 58.770 152.970 3230.17 3282.97 3085.50 S 1302.77 E 5971116.93 N 372990.35 E 2.833 3346.39 5062.97 58.270 154.240 3280.10 3332.90 3158.52 S 1339.01 E 5971043.30 N 373025.34 E 1.248 3427.90 . 5158.63 58.150 154.470 3330.49 3383.29 3231.82 S 1374.20 E 5970969.40 N 373059.28 E 0.240 3509.21 5254.25 57.820 156.040 3381.19 3433.99 3305.45 S 1408.14 E 5970895.21 N 373091.95 E 1 .434 3590.28 5349.19 58.920 156.300 3430.97 3483.77 3379.40 S 1440.80 E 5970820.71 N 373123.34 E 1.182 3671.09 5444.72 64.420 153.660 3476.30 3529.10 3455.53 S 1476.39 E 5970743.98 N 373157.62 E 6.249 3755.13 5539.99 63.920 152.860 3517.81 3570.61 3532.11 S 1514.97 E 5970666.75 N 373194.89 E 0.920 3840.85 5635.29 63.100 152.310 3560.31 3613.11 3607.83 S 1554.24 E 5970590.37 N 373232.86 E 1.004 3926.09 5730.78 63.060 154.110 3603.55 3656.35 3683.83 S 1592.62 E 5970513.73 N 373269.92 E 1.681 4011.20 5826.31 62.320 153.750 3647.38 3700.18 3760.07 S 1629.92 E 5970436.86 N 373305.92 E 0.844 4096.07 5921.85 62.490 153.860 3691.64 3744.44 3836.05 S 1667.30 E 5970360.25 N 373341.99 E 0.205 4180.73 6017.27 60.720 152.480 3737.01 3789.81 3910.95 S 1705.17E 5970284.71 N 373378.58 E 2.249 4264.63 6112.78 59.650 146.500 3784.53 3837.33 3982.31 S 1747.19 E 5970212.65 N 373419.37 E 5.546 4347.10 6208.17 58.060 147.010 3833.87 3886.67 4050.58 S 1791.95E 5970143.62 N 373462.96 E 1.729 4427.94 6303.70 57.080 149.980 3885.10 3937.90 4119.31 S 1834.09 E 5970074.18 N 373503.91 E 2.817 4508.08 6399.34 56.600 156.130 3937.45 3990.25 4190.62 S 1870.35 E 5970002.26 N 373538.95 E 5.406 4588.05 15 June, 2004·16:06 Page 3 of7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6494.69 55.720 162.360 3990.59 4043.39 4264.61 S 1898.41 E 5969927.80 N 373565.74 E 5.504 4666.94 6590.27 56.110 162.140 4044.15 4096.95 4340.00 S 1922.55 E 5969852.01 N 373588.58 E 0.450 4745.42 6685.73 57.350 164.080 4096.52 4149.32 4416.37 S 1945.72 E 5969775.26 N 373610.45 E 2.139 4824.37 6781.56 60.040 164.530 4146.31 4199.11 4495.19 S 1967.87 E 5969696.07 N 373631.24 E 2.836 4905.10 6877.19 58.770 162.970 4194.98 4247.78 4574.21 S 1990.89 E 5969616.66 N 373652.91 E 1.933 4986.40 . 6972.86 57.940 160.860 4245.18 4297.98 4651.63 S 2016.17 E 5969538.82 N 373676.86 E 2.068 5067.20 7068.52 57.240 160.250 4296.45 4349.25 4727.78 S 2043.05 E 5969462.22 N 373702.44 E 0.908 5147.54 7163.00 56.940 159.250 4347.79 4400.59 4802.20 S 2070.50 E 5969387.35 N 373728.61 E 0.944 5226.55 7258.39 57.760 155.660 4399.26 4452.06 4876.35 S 2101.30 E 5969312.68 N 373758.14 E 3.283 5306.76 7353.86 57.670 154.800 4450.25 4503.05 4949.64 S 2135.11 E 5969238.83 N 373790.69 E 0.767 5387.47 7449.65 57.780 154.220 4501.41 4554.21 5022.74 S 2169.97 E 5969165.14 N 373824.29 E 0.525 5468.45 7544.99 57.350 155.160 4552.54 4605.34 5095.48 S 2204.37 E 5969091.82 N 373857.44 E 0.946 5548.92 7640.57 57.500 155.450 4604.00 4656.80 5168.66 S 2238.02 E 5969018.08 N 373889.84 E 0.300 5629.46 7736.28 56.980 155.400 4655.79 4708.59 5241.86 S 2271.49 E 5968944.32 N 373922.05 E 0.545 5709.94 7831.91 57.200 153.740 4707.75 4760.55 5314.36 S 2305.97 E 5968871.24 N 373955.28 E 1.475 5790.22 7927.37 57.210 154.590 4759.46 4812.26 5386.58 S 2340.94 E 5968798.43 N 373989.01 E 0.749 5870.46 8022.92 57.270 155.110 4811.16 4863.96 5459.32 S 2375.08 E 5968725.12 N 374021.91 E 0.462 5950.81 8118.28 57.460 154.270 4862.59 4915.39 5531.91 S 2409.42 E 5968651.95 N 374054.99 E 0.768 6031.11 8213.94 57.390 155.190 4914.09 4966.89 5604.81 S 2443.83 E 5968578.47 N 374088.15 E 0.814 6111.72 8308.82 57.410 153.910 4965.21 5018.01 5676.98 S 2478.18 E 5968505.72 N 374121.26 E 1.137 6191.65 8404.67 57.330 154.560 5016.90 5069.70 5749.68 S 2513.26 E 5968432.44 N 374155.10 E 0.577 6272.37 8500.13 57.300 156.160 5068.45 5121.25 5822.70 S 2546.76 E 5968358.85 N 374187.34 E 1.411 6352.71 . 8595.64 57.300 155.740 5120.05 5172.85 5896.10 S 2579.51 E 5968284.91 N 374218.84 E 0.370 6433.06 8690.54 57.510 155.040 5171.17 5223.97 5968.78 S 2612.81 E 5968211.66 N 374250.89 E 0.660 6513.01 8786.22 57.310 155.980 5222.71 5275.51 6042.15 S 2646.23 E 5968137.74 N 374283.04 E 0.854 6593.61 8881.65 57.130 155.890 5274.37 5327.17 6115.41 S 2678.94 E 5968063.93 N 374314.50 E 0.205 6673.83 8977.16 57.320 156.060 5326.08 5378.88 6188.75 S 2711.64 E 5967990.03 N 374345.94 E 0.249 6754.12 9072.85 57.640 155.690 5377.52 5430.32 6262.39 S 2744.62 E 5967915.84 N 374377.65 E 0.467 6834.79 9168.13 57.580 158.320 5428.57 5481.37 6336.44 S 2776.04 E 5967841.26 N 374407.81 E 2.332 6915.17 9263.89 57.090 157.630 5480.25 5533.05 6411.18 S 2806.27 E 5967766.02 N 374436.76 E 0.794 6995.65 9359.07 57.300 157.370 5531.82 5584.62 6485.09 S 2836.89 E 5967691.60 N 374466.10 E 0.318 7075.56 9454.84 57.400 159.120 5583.49 5636.29 6559.97 S 2866.77 E 5967616.21 N 374494.70 E 1.542 7156.04 9550.17 59.950 151.570 5633.10 5685.90 6633.87 S 2900.77 E 5967541.75 N 374527.43 E 7.273 7237.38 9645.42 59.550 153.220 5681.09 5733.89 6706.77 S 2938.90 E 5967468.20 N 374564.30 E 1.554 7319.58 9741.15 59.310 154.850 5729.78 5782.58 6780.87 S 2974.98 E 5967393.49 N 374599.12 E 1.487 7402.00 15 June, 2004 - 16:06 Page 40f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 9836.89 58.560 154.930 5779.18 5831.98 6855.13 S 3009.78 E 5967318.65 N 374632.64 E 0.787 7484.00 9932.49 58.100 155.480 5829.37 5882.17 6929.00 S 3043.91 E 5967244.21 N 374665.50 E 0.686 7565.37 10027.85 57.140 154.560 5880.44 5933.24 7001.99 S 3077.91 E 5967170.64 N 374698.25 E 1.295 7645.89 10123.47 57.020 157.320 5932.41 5985.21 7075.28 S 3110.63 E 5967096.81 N 374729.71 E 2.426 7726.13 10219.36 56.460 158.040 5985.00 6037.80 7149.45 8 3141.08E 5967022.13 N 374758.89 E 0.857 7806.21 . 10314.83 56.500 157.910 6037.72 6090.52 7223.23 8 3170.93 E 5966947.85 N 374787.47 E 0.121 7885.67 10410.34 57.480 156.990 6089.76 6142.56 7297.208 3201.65 E 5966873.37 N 374816.92 E 1.306 7965.67 10505.87 58.780 157.120 6140.19 6192.99 7371.91 S 3233.28 E 5966798.13 N 374847.26 E 1.366 8046.73 10601.42 57.540 158.990 6190.60 6243.40 7447.198 3263.62 E 5966722.34 N 374876.31 E 2.109 8127.76 10695.89 56.420 158.850 6242.08 6294.88 7521.10 S 3292.11 E 5966647.96 N 374903.53 E 1.192 8206.76 1 0791.41 56.210 159.330 6295.06 6347.86 7595.34 S 3320.47 E 5966573.23 N 374930.62 E 0.472 8286.02 1 0886.76 56.710 158.650 6347.74 6400.54 7669.53 S 3348.97 E 5966498.57 N 374957.85 E 0.793 8365.27 1 0982.11 56.750 157.250 6400.05 6452.85 7743.428 3378.90 E 5966424.18 N 374986.51 E 1.228 8444.86 11077.52 57.010 157.640 6452.18 6504.98 7817.22 S 3409.55 E 5966349.87 N 375015.89 E 0.438 8524.68 11172.92 57.160 156.640 6504.03 6556.83 7891.01 S 3440.66 E 5966275.55 N 375045.73 E 0.894 8604.70 11268.38 57.260 155.760 6555.72 6608.52 7964.43 S 3473.04 E 5966201.59 N 375076.86 E 0.782 8684.92 11363.90 57.240 154.260 6607.40 6660.20 8037.25 S 3506.98 E 5966128.21 N 375109.54 E 1.321 8765.25 11459.36 56.960 152.720 6659.25 6712.05 8108.97 S 3542.75 E 5966055.88 N 375144.08 E 1.386 8845.38 11554.86 57.480 154.360 6710.96 6763.76 8180.84 S 3578.52 E 5965983.40 N 375178.62 E 1.543 8925.65 11650.31 57.530 155.170 6762.24 6815.04 8253.67 S 3612.84 E 5965910.01 N 375211.69 E 0.718 9006.15 11744.64 56.760 155.070 6813.41 6866.21 8325.55 S 3646.18 E 5965837.56 N 375243.80 E 0.821 9085.39 11841.13 57.340 155.450 6865.90 6918.70 8399.09 S 3680.07 E 5965763.45 N 375276.42 E 0.686 9166.36 . 11935.58 58.360 155.800 6916.16 6968.96 8471.93 S 3713.07 E 5965690.06 N 375308.17 E 1.125 9246.31 12032.11 59.690 157.490 6965.84 7018.64 8547.91 S 3745.87 E 5965613.53 N 375339.66 E 2.037 9329.03 12127.49 63.300 156.820 7011.35 7064.15 8625.148 3778.41 E 5965535.76 N 375370.88 E 3.835 9412.75 12223.12 66.900 156.170 7051.61 7104.41 8704.66 8 3813.01 E 5965455.65 N 375404.11 E 3.815 9499.44 12318.66 70.010 154.750 7086.69 7139.49 8785.48 8 3849.92 E 5965374.21 N 375439.64 E 3.536 9588.28 12414.07 73.670 154.840 7116.42 7169.22 8867.508 3888.52 E 5965291.55 N 375476.83 E 3.837 9678.93 12509.43 78.690 151.270 7139.20 7192.00 8949.99 S 3930.49 E 5965208.35 N 375517.38 E 6.397 9771.44 12583.37 81.390 151.080 7151.99 7204.79 9013.78 S 3965.59 E 5965143.97 N 375551.39 E 3.660 9844.12 12640.74 83.880 152.770 7159.34 7212.14 9063.98 S 3992.37 E 5965093.32 N 375577.30 E 5.232 9900.94 12736.18 88.400 153.710 7165.76 7218.56 9148.988 4035.23 E 5965007.60 N 375618.70 E 4.837 9996.10 12831.73 89.570 153.550 7167.46 7220.26 9234.58 S 4077.66 E 5964921.29 N 375659.66 E 1.236 10091.62 12927.33 90.310 150.120 7167.56 7220.36 9318.84 S 4122.78 E 5964836.26 N 375703.33 E 3.670 10187.08 13022.86 89.510 150.380 7167.71 7220.51 9401.788 4170.18 E 5964752.53 N 375749.31 E 0.881 10282.32 15 June, 2004 - 16:06 Page 5 of7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 13117.75 90.990 153.060 7167.29 7220.09 9485.33 S 4215.13 E 5964668.22 N 375792.83 E 3.226 10377.06 13213.45 91.300 154.040 7165.38 7218.18 9571.00 5 4257.75 E 5964581.84 N 375833.97 E 1.074 10472.72 13308.96 90.490 153.050 7163.89 7216.69 9656.49 S 4300.29 E 5964495.62 N 375875.05 E 1.339 10568.20 13404.57 89.570 153.950 7163.84 7216.64 9742.06 S 4342.95 E 5964409.34 N 375916.24 E 1.346 10663.78 13500.07 88.760 153.170 7165.23 7218.03 9827.56 S 4385.47 E 5964323.13 N 375957.29 E 1.177 10759.25 . 13595.28 89.940 153.610 7166.31 7219.11 9912.68 S 4428.11 E 5964237.29 N 375998.47 E 1.323 10854.43 13691.11 90.250 152.970 7166.15 7218.95 9998.28 S 4471.18 E 5964150.97 N 376040.07 E 0.742 10950.22 13786.38 90.560 151.740 7165.48 7218.28 10082.67 5 4515.39 E 5964065.83 N 376082.82 E 1.331 11045.41 13881.02 89.630 152.630 7165.32 7218.12 10166.37 S 4559.55 E 5963981.39 N 376125.54 E 1.360 11139.95 13977.49 90.990 151.070 7164.80 7217.60 10251.43 S 4605.06 E 5963895.57 N 376169.59 E 2.145 11236.29 14073.05 90.680 149.710 7163.41 7216.21 10334.50 S 4652.27 E 5963811.70 N 376215.37 E 1.460 11331.56 14168.02 90.000 149.520 7162.84 7215.64 10416.42 S 4700.30 E 5963728.97 N 376262.00 E 0.743 11426.15 14263.68 89.140 149.830 7163.56 7216.36 10498.99 S 4748.60 E 5963645.59 N 376308.88 E 0.956 11521.43 14359.21 90.740 152.880 7163.66 7216.46 10582.81 5 4794.39 E 5963560.99 N 376353.22 E 3.605 11616.78 14454.00 90.000 152.820 7163.05 7215.85 10667.16 S 4837.64 E 5963475.92 N 376395.03 E 0.783 11711.52 14549.59 88.830 152.870 7164.03 7216.83 10752.20 S 4881.26 E 5963390.14 N 376437.19 E 1.225 11807.05 14645.10 87.840 151.610 7166.80 7219.60 10836.68 S 4925.73 E 5963304.91 N 376480.21 E 1.677 11902.43 14740.92 88.640 150.750 7169.74 7222.54 10920.59 S 4971.90 E 5963220.22 N 376524.93 E 1.225 11998.01 14836.16 90.060 151.770 7170.82 7223.62 11004.09 S 5017.69 E 5963135.95 N 376569.29 E 1.836 12093.07 14931.77 89.260 151.550 7171.39 7224.19 11088.24 S 5063.07 E 5963051.04 N 376613.23 E 0.868 12188.54 15027.22 90.060 151.520 7171.96 7224.76 11172.15 S 5108.57 E 5962966.37 N 376657.28 E 0.839 12283.84 . 15122.83 89.380 151.210 7172.42 7225.22 11256.06 S 5154.38 E 5962881.68 N 376701.65 E 0.782 12379.28 15215.19 91.420 151.360 7171.78 7224.58 11337.06 S 5198.76 E 5962799.94 N 376744.63 E 2.215 12471.46 15313.48 90.490 152.070 7170.14 7222.94 11423.60 S 5245.32 E 5962712.61 N 376789.71 E 1.190 12569.60 15408.92 89.940 152.480 7169.78 7222.58 11508.085 5289.72 E 5962627.39 N 376832.66 E 0.719 12664.95 15503.92 89.140 151.690 7170.55 7223.35 11592.02 S 5334.20 E 5962542.70 N 376875.69 E 1.183 12759.85 15599.40 88.090 152.490 7172.85 7225.65 11676.37 S 5378.88 E 5962457.60 N 376918.92 E 1.382 12855.19 15694.70 87.410 151.730 7176.60 7229.40 11760.54 S 5423.42 E 5962372.68 N 376962.02 E 1.070 12950.32 15790.30 88.950 153.190 7179.63 7232.43 11845.26 S 5467.60 E 5962287.22 N 377004.74 E 2.219 13045.79 15885.68 87.970 154.140 7182.20 7235.00 11930.705 5509.89 E 5962201.06 N 377045.57 E 1.431 13141.12 15980.94 89.320 152.740 7184.45 7237.25 12015.88 S 5552.47 E 5962115.16 N 377086.69 E 2.041 13236.32 16076.38 89.140 154.160 7185.73 7238.53 12101.25 S 5595.13 E 5962029.08 N 377127.88 E 1.500 13331.72 16172.04 88.150 151.330 7187.99 7240.79 12186.25 S 5638.92 E 5961943.34 N 377170.21 E 3.133 13427.29 16267.62 87.280 153.900 7191.80 7244.60 12271.05 5 5682.84 E 5961857.81 N 377212.68 E 2.837 13522.72 16363.13 88.770 153.070 7195.10 7247.90 12356.46 S 5725.46 E 5961771.68 N 377253.82 E 1.785 13618.15 15 June, 2004 - 16:06 Page 60f7 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 MWD Your Ref: API 501032049200 Job No. AKMW3066896, Surveyed: 2 June, 2004 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 16384.88 88.890 151.490 7195.54 7248.34 12375.71 S 5735.57 E 5961752.26 N 377263.60 E 16433.00 88.890 151.490 7196.47 7249.27 12417.98 S 5758.53 E 5961709.60 N 377285.84 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=52.80' above MSL. Northings and Eastings are relative to 2132'FNL & 1494'FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2132'FNL & 1494'FEL and calculated along an Azimuth of 154.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16433.00ft., The Bottom Hole Displacement is 13688.21ft., in the Direction of 155.122° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 16433.00 7249.27 12417.98 S 5758.53 E Projected Survey Survey too/prOgram for CD2-57 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 796.00 0.00 786.54 796.00 16433.00 786.54 CB-SS-Gyro 7249.27 MWD Magnetic North Slope, Alaska Dogleg Vertical Rate Section Comment (0/100ft) 7.284 13639.87 0.000 13687.90 Projected Survey . . 15 June, 2004·16:06 Page 70f7 Dri/lQuest 3.03.06.002 . . 16-Jun-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-57 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 16,433.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ,/ Æ j ~ S ~'\j '1 Signed ~l ð/JJ ( Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager )\G'{- ô7)-· Attachment(s) Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2, Slot Plan: CD2-57 CD2-57 Job No. AKZZ3066896, Surveyed: 2 June, 2004 Survey Report 15 June, 2004 ~ o ...L ( V .......J ,..., Your Ref: API 501032049200 Surface Coordinates: 5974224.26 N, 371740.55 E (70020'16.1276" N, 151002' 26.5802" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974224.26 N, 128259.45 W (Grid) Surface Coordinates relative to Structure: 218.22 S, 26.80 E (True) Kelly Bushing Elevation: 52. 80ft above Mean Sea Level Kelly Bushing Elevation: 52. 80ft above Project V Reference Kelly Bushing Elevation: 52. 80ft above Structure sper-'r-'Y-SUI! [)FULLING SERVICES A Halliburton Company DEFINITIVE . . Survey Ref: svy411 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 Your Ref: API 501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.80 0.00 0.00 N 0.00 E 5974224.26 N 371740.55 E 0.00 CB-SS-Gyro 81.00 0.000 0.000 28.20 81.00 0.00 N 0.00 E 5974224.26 N 371740.55 E 0.000 0.00 161.00 0.250 215.000 108.20 161.00 0.14 S 0.10W 5974224.12 N 371740.45 E 0.313 0.09 260.00 2.150 166.000 207.17 259.97 2.12 S 0.23 E 5974222.13 N 371740.74 E 2.015 2.02 349.00 5.500 161.000 295.96 348.76 7.78 S 2.02 E 5974216.45 N 371742.43 E 3.779 7.89 . 438.00 7.500 165.000 384.39 437.19 17.42 S 4.91 E 5974206.76 N 371745.16 E 2.303 17.85 527.00 9.000 163.000 472.46 525.26 29.69 S 8.45 E 5974194.43 N 371748.49 E 1.716 30.46 615.00 12.900 161.000 558.85 611.65 45.57 S 13.66 E 5974178.47 N 371753.43 E 4.452 47.04 703.00 15.300 157.000 644.19 696.99 65.54 S 21.40 E 5974158.36 N 371760.82 E 2.942 68.41 796.00 16.000 153.000 733.74 786.54 88.26 S 32.01 E 5974135.47 N 371771.05 E 1.383 93.48 MWD+IIFR+MS+SAG 833.29 16.970 153.660 769.50 822.30 97.72 S 36.76 E 5974125.93 N 371775.63 E 2.649 104.06 924.07 20.360 153.570 855.49 908.29 123.74 S 49.67 E 5974099.69 N 371788.10 E 3.734 133.10 1020.20 26.060 147.230 943.82 996.62 156.50 S 68.56 E 5974066.61 N 371806.42 E 6.466 170.79 1113.72 31.590 148.440 1025.72 1078.52 194.67 S 92.52 E 5974028.03 N 371829.73 E 5.946 215.54 1210.73 36.690 151.730 1106.00 1158.80 241.88 S 119.56 E 5973980.37 N 371855.96 E 5.589 269.78 1305.42 38.210 154.860 1181.17 1233.97 293.32 S 145.41 E 5973928.50 N 371880.92 E 2.572 327.32 1400.75 41.370 155.990 1254.42 1307.22 348.80 S 170.76 E 5973872.59 N 371905.32 E 3.400 388.31 1496.15 48.220 158.710 1322.08 1374.88 410.82 S 196.53 E 5973810.14 N 371930.03 E 7.455 455.40 1591.21 52.020 160.340 1383.02 1435.82 479.15 S 222.02 E 5973741.38 N 371954.34 E 4.208 528.08 1685.92 56.200 158.230 1438.54 1491.34 550.88 S 249.18 E 5973669.19 N 371980.28 E 4.768 604.54 1781.17 58.000 157.150 1490.27 1543.07 624.86 S 279.55 E 5973594.71 N 372009.37 E 2.116 684.41 1876.49 60.020 155.370 1539.35 1592.15 699.65 S 312.45 E 5973519.37 N 372040.99 E 2.656 766.08 . 1971.72 60.800 155.420 1586.38 1639.18 774.94 S 346.93 E 5973443.50 N 372074.18 E 0.820 848.89 2067.23 61.160 155.840 1632.71 1685.51 851.02 S 381.39 E 5973366.84 N 372107.33 E 0.538 932.39 2162.46 58.920 155.640 1680.26 1733.06 926.23 S 415.29 E 5973291.06 N 372139.94 E 2.359 1014.88 2257.46 58.290 155.680 1729.75 1782.55 1000.11 S 448.71 E 5973216.62 N 372172.09 E 0.664 1095.96 2352.96 58.600 154.830 1779.73 1832.53 1074.02 S 482.78 E 5973142.14 N 372204.89 E 0.825 1177.34 2448.26 58.390 155.480 1829.53 1882.33 1147.75 S 516.92 E 5973067.83 N 372237.76 E 0.622 1258.59 2543.27 57.780 155.820 1879.76 1932.56 1221.22 S 550.17 E 5972993.80 N 372269.75 E 0.710 1339.22 2635.28 58.230 156.380 1928.51 1981.31 1292.57 S 581.78 E 5972921.93 N 372300.14 E 0.711 1417.23 2730.48 58.820 157.640 1978.22 2031.02 1367.31 S 613.49 E 5972846.66 N 372330.56 E 1.288 1498.36 2825.59 58.500 157.860 2027.69 2080.49 1442.49 S 644.25 E 5972770.96 N 372360.03 E 0.390 1579.48 2921.05 58.950 158.170 2077.24 2130.04 1518.15 S 674.79 E 5972694.79 N 372389.28 E 0.547 1660.94 3016.38 58.970 158.020 2126.40 2179.20 1593.93 S 705.26 E 5972618.50 N 372418.45 E 0.136 1742.47 3111.64 58.300 157.040 2175.98 2228.78 1669.09 S 736.35 E 5972542.82 N 372448.24 E 1.125 1823.72 15 June, 2004 - 15:58 Page 2 of7 DríffQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 Your Ref: API 501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3206.85 57.720 156.910 2226.42 2279.22 1743.41 S 767.93 E 5972467.97 N 372478.55 E 0.620 1904.41 3299.93 57.500 156.590 2276.28 2329.08 1815.63 S 798.96 E 5972395.23 N 372508.34 E 0.374 1982.96 3354.00 57.220 157.250 2305.45 2358.25 1857.51 S 816.81 E 5972353.05 N 372525.47 E 1.151 2028.45 3439.21 57.220 156.210 2351.58 2404.38 1923.33 S 845.11 E 5972286.76 N 372552.64 E 1.026 2100.05 3534.77 56.440 157.170 2403.86 2456.66 1996.78 S 876.76 E 5972212.77 N 372583.03 E 1.172 2179.99 . 3630.52 55.800 157.120 2457.24 2510.04 2070.03 S 907.64 E 5972139.01 N 372612.65 E 0.670 2259.41 3724.05 55.040 157.500 2510.32 2563.12 2141.088 937.34 E 5972067.46 N 372641.13 E 0.879 2336.34 3821.56 54.120 157.720 2566.84 2619.64 2214.55 S 967.61 E 5971993.48 N 372670.14 E 0.961 2415.70 3917.21 53.110 157.830 2623.58 2676.38 2285.83 S 996.74 E 5971921.71 N 372698.05 E 1.060 2492.60 4012.91 52.300 157.560 2681.56 2734.36 2356.27 S 1025.63 E 5971850.80 N 372725.73 E 0.876 2568.63 4107.60 51.400 158.580 2740.05 2792.85 2425.34 S 1053.45 E 5971781.26 N 372752.36 E 1.273 2642.96 4202.86 50.960 157.810 2799.77 2852.57 2494.25 S 1081.01 E 5971711.89 N 372778.74 E 0.781 2717.04 4298.61 50.570 159.370 2860.34 2913.14 2563.29 S 1108.09 E 5971642.39 N 372804.63 E 1.326 2791.04 4394.49 51.230 159.450 2920.80 2973.60 2632.94 S 1134.25 E 5971572.30 N 372829.60 E 0.691 2865.20 4489.43 52.070 160.370 2979.71 3032.51 2702.87 S 1159.82 E 5971501.95 N 372853.97 E 1.166 2939.35 4585.00 54.650 160.500 3036.74 3089.54 2775.12 S 1185.50 E 5971429.27 N 372878.41 E 2.702 3015.65 4680.65 56.810 158.940 3090.60 3143.40 2849.25 S 1212.91 E 5971354.68 N 372904.55 E 2.630 3094.39 4776.23 57.270 158.400 3142.60 3195.40 2923.95 S 1242.08 E 5971279.49 N 372932.44 E 0.676 3174.39 4871.64 58.090 156.080 3193.62 3246.42 2998.29 S 1273.28 E 5971204.63 N 372962.36 E 2.227 3254.94 4967.37 58.580 153.010 3243.88 3296.68 3071.84 S 1308.29 E 5971130.49 N 372996.11 E 2.777 3336.40 5062.97 58.080 153.750 3294.07 3346.87 3144.58 S 1344.75 E 5971057.14 N 373031.32 E 0.841 3417.74 5158.63 57.950 154.190 3344.74 3397.54 3217.49 S 1380.36 E 5970983.63 N 373065.67 E 0.413 3498.87 . 5254.25 57.630 155.450 3395.71 3448.51 3290.70 S 1414.78 E 5970909.84 N 373098.84 E 1.164 3579.77 5349.19 58.730 156.290 3445.77 3498.57 3364.32 S 1447.75 E 5970835.67 N 373130.55 E 1.381 3660.42 5444.72 64.220 153.490 3491.38 3544.18 3440.26 8 1483.40 E 5970759.13 N 373164.89 E 6.297 3744.31 5539.99 63.730 153.790 3533.18 3585.98 3516.97 S 1521.41 E 5970681.78 N 373201.59 E 0.587 3829.91 5635.29 62.910 153.020 3575.97 3628.77 3593.118 1559.53 E 5970605.00 N 373238.40 E 1.123 3915.03 5730.78 62.870 153.760 3619.48 3672.28 3669.118 1597.60 E 5970528.36 N 373275.16 E 0.691 4000.01 5826.31 62.120 153.880 3663.60 3716.40 3745.15 S 1634.99 E 5970451.70 N 373311.24 E 0.793 4084.73 5921.85 62.300 154.150 3708.15 3760.95 3821.128 1672.02 E 5970375.10 N 373346.97 E 0.313 4169.24 6017.27 60.520 151.900 3753.81 3806.61 3895.79 S 1710.01 E 5970299.79 N 373383.67 E 2.787 4252.98 6112.78 59.460 146.950 3801.60 3854.40 3966.97 8 1752.04 E 5970227.90 N 373424.48 E 4.623 4335.29 6208.17 57.870 146.590 3851.21 3904.01 4035.12 S 1796.69 E 5970159.00 N 373467.96 E 1.698 4415.98 6303.70 56.890 149.670 3902.71 3955.51 4103.43 S 1839.17 E 5970089.97 N 373509.27 E 2.903 4495.89 6399.34 56.410 154.710 3955.31 4008.11 4174.06 S 1876.43 E 5970018.72 N 373545.31 E 4.430 4575.66 15 June, 2004 - 15:58 Page 3 of7 DríllQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - CO2-57 Your Ref: API 501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6494.69 55.530 161.200 4008.71 4061.51 4247.23 S 1906.09 E 5969945.05 N 373573.71 E 5.715 4654.49 6590.27 55.920 161.360 4062.54 4115.34 4322.03 S 1931.44 E 5969869.83 N 373597.78 E 0.431 4732.95 6685.73 57.150 163.410 4115.18 4167.98 4397.93 S 1955.52 E 5969793.53 N 373620.56 E 2.207 4811.87 6781.56 59.850 163.960 4165.25 4218.05 4476.34 S 1978.47 E 5969714.74 N 373642.16 E 2.860 4892.58 6877. 19 58.580 162.650 4214.20 4267.00 4555.03 S 2002.06 E 5969635.66 N 373664.41 E 1.774 4973.81 . 6972.86 57.750 160.350 4264.66 4317.46 4632.10 S 2027.84 E 5969558.15 N 373688.87 E 2.219 5054.52 7068.52 57.050 159.620 4316.20 4369.00 4707.82 S 2055.42 E 5969481.97 N 373715.15 E 0.974 5134.77 7163.00 56.750 158.810 4367.80 4420.60 4781.82 S 2083.51 E 5969407.51 N 373741.96 E 0.785 5213.67 7258.39 57.570 156.070 4419.53 4472.33 4855.81 S 2114.26 E 5969332.99 N 373771.44 E 2.562 5293.71 7353.86 57.480 155.080 4470.80 4523.60 4929.15 S 2147.56 E 5969259.10 N 373803.49 E 0.880 5374.25 7449.65 57.590 154.290 4522.22 4575.02 5002.20 S 2182.12E 5969185.47 N 373836.79 E 0.705 5455.06 7544.99 57.160 154.850 4573.62 4626.42 5074.72 S 2216.60 E 5969112.37 N 373870.03 E 0.669 5535.36 7640.57 57.310 155.130 4625.34 4678.14 5147.56 S 2250.58 E 5969038.96 N 373902.76 E 0.292 5615.73 7736.28 56.790 155.080 4677.40 4730.20 5220.41 S 2284.39 E 5968965.54 N 373935.31 E 0.545 5696.05 7831.91 57.010 153.700 4729.63 4782.43 5292.64 S 2319.02 E 5968892.72 N 373968.70 E 1.231 5776.15 7927.37 57.020 154.550 4781.60 4834.40 5364.69 S 2353.96 E 5968820.09 N 374002.41 E 0.747 5856.22 8022.92 57.080 154.650 4833.57 4886.37 5437.12 S 2388.35 E 5968747.09 N 374035.56 E 0.108 5936.40 8118.28 57.260 154.130 4885.27 4938.07 5509.38 S 2422.99 E 5968674.25 N 374068.95 E 0.496 6016.53 8213.94 57.190 154.920 4937.05 4989.85 5581.99 S 2457.58 E 5968601.06 N 374102.30 E 0.698 6096.96 8308.82 57.220 154.320 4988.44 5041.24 5654.04 S 2491.77 E 5968528.42 N 374135.25 E 0.533 6176.71 8404.67 57.140 154.730 5040.39 5093.19 5726.76 S 2526.41 E 5968455.12 N 374168.64 E 0.369 6257.26 8500.13 57.110 155.820 5092.21 5145.01 5799.58 S 2559.95 E 5968381.74 N 374200.92 E 0.959 6337.43 . 8595.64 57.110 156.230 5144.08 5196.88 5872.87 S 2592.54 E 5968307.91 N 374232.25 E 0.360 6417.61 8690.54 57.320 156.420 5195.46 5248.26 5945.93 S 2624.57 E 5968234.30 N 374263.04 E 0.278 6497.36 8786.22 57.120 156.680 5247.27 5300.07 6019.73 S 2656.58 E 5968159.97 N 374293.78 E 0.310 6577.77 8881.65 56.940 156.270 5299.20 5352.00 6093.14 S 2688.54 E 5968086.03 N 374324.48 E 0.407 6657.79 8977.16 57.130 156.740 5351.17 5403.97 6166.63 S 2720.49 E 5968012.00 N 374355.16 E 0.458 6737.88 9072.85 57.450 156.320 5402.88 5455.68 6240.48 S 2752.55 E 5967937.61 N 374385.96 E 0.498 6818.36 9168.13 57.390 157.950 5454.19 5506.99 6314.46 S 2783.75 E 5967863.11 N 374415.89 E 1.443 6898.57 9263.89 56.900 157.400 5506.14 5558.94 6388.87 S 2814.30 E 5967788.19 N 374445.17 E 0.703 6978.91 9359.07 57.110 157.390 5557.97 5610.77 6462.57 S 2844.99 E 5967713.98 N 374474.59 E 0.221 7058.65 9454.84 57.200 157.640 5609.91 5662.71 6536.91 S 2875.76 E 5967639.12 N 374504.08 E 0.239 7139.02 9550.17 59.760 151.530 5659.78 5712.58 6610.23 S 2910.66 E 5967565.22 N 374537.72 E 6.086 7220.22 9645.42 59.360 152.770 5708.04 5760.84 6682.83 S 2949.03 E 5967491.97 N 374574.84 E 1.198 7302.25 9741.15 59.120 154.000 5757.00 5809.80 6756.37 S 2985.88 E 5967417.80 N 374610.43 E 1.132 7384.49 15 June, 2004 - 15:58 Page 4 of7 Oril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 Your Ref: API 501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9836.89 58.360 154.410 5806.68 5859.48 6830.06 S 3021.49 E 5967343.52 N 374644.78 E 0.874 7466.32 9932.49 57.900 154.990 5857.16 5909.96 6903.46 S 3056.19 E 5967269.54 N 374678.21 E 0.705 7547.51 10027.85 56.950 154.730 5908.50 5961.30 6976.20 S 3090.33 E 5967196.22 N 374711.10 E 1.022 7627.87 10123.47 56.820 155.680 5960.74 6013.54 7048.91 S 3123.91 E 5967122.95 N 374743.44 E 0.843 7707.95 10219.36 56.270 156.580 6013.60 6066.40 7122.07 S 3156.29 E 5967049.25 N 374774.56 E 0.971 7787.93 . 10314.83 56.310 156.810 6066.59 6119.39 7195.00 S 3187.71 E 5966975.79 N 374804.73 E 0.205 7867.30 10410.34 57.290 156.340 6118.89 6171.69 7268.33 S 3219.48 E 5966901.92 N 374835.24 E 1.106 7947.18 10505.87 58.590 156.390 6169.59 6222.39 7342.50 S 3251.94 E 5966827.21 N 374866.42 E 1.362 8028.11 10601.42 57.350 157.750 6220.27 6273.07 7417.10 S 3283.50 E 5966752.08 N 374896.71 E 1.772 8109.04 10695.89 56.230 158.640 6272.01 6324.81 7490.48 S 3312.86 E 5966678.21 N 374924.81 E 1 .424 8187.93 10791.41 56.020 159.550 6325.25 6378.05 7564.56 S 3341.16 E 5966603.65 N 374951.84 E 0.821 8267.01 10886.76 56.520 158.860 6378.20 6431.00 7638.70 S 3369.32 E 5966529.05 N 374978.72 E 0.798 8346.07 10982.11 56.560 158.020 6430.77 6483.57 7712.68 S 3398.55 E 5966454.58 N 375006.68 E 0.736 8425.45 11077.52 56.820 156.980 6483.17 6535.97 7786.34 S 3429.06 E 5966380.41 N 375035.93 E 0.951 8505.09 11172.92 56.970 156.820 6535.28 6588.08 7859.85 S 3460.42 E 5966306.37 N 375066.02 E 0.211 8584.95 11268.38 57.070 155.480 6587.24 6640.04 7933.08 S 3492.79 E 5966232.59 N 375097.14 E 1.182 8665.00 11363.90 57.050 154.170 6639.18 6691.98 8005.63 S 3526.89 E 5966159.47 N 375130.00 E 1.151 8745.16 11459.36 56.770 153.570 6691.30 6744.10 8077.44 S 3562.11 E 5966087.08 N 375163.99 E 0.603 8825.13 11554.86 57.290 154.620 6743.27 6796.07 8149.50 S 3597.11 E 5966014.42 N 375197.75 E 1.071 8905.24 11650.31 57.340 155.350 6794.82 6847.62 8222.30 S 3631.08 E 5965941.05 N 375230.47 E 0.646 8985.57 11744.64 56.570 155.790 6846.25 6899.05 8294.29 S 3663.79 E 5965868.51 N 375261.93 E 0.905 9064.63 11841.13 57.150 156.580 6899.00 6951.80 8368.21 S 3696.41 E 5965794.05 N 375293.29 E 0.912 9145.40 . 11935.58 58.170 156.170 6949.53 7002.33 8441.32 S 3728.39 E 5965720.41 N 375324.01 E 1.141 9225.17 12032.11 59.500 156.930 6999.48 7052.28 8517.09 S 3761.26 E 5965644.08 N 375355.58 E 1.534 9307.72 12127.49 63.110 156.520 7045.27 7098.07 8593.94 S 3794.32 E 5965566.68 N 375387.32 E 3.804 9391.33 12223.12 66.710 155.450 7085.82 7138.62 8673.03 S 3829.57 E 5965487.00 N 375421.21 E 3.898 9477.90 12318.66 69.810 153.510 7121.20 7174.00 8753.09 S 3867.81 E 5965406.29 N 375458.08 E 3.753 9566.62 12414.07 73.470 152.380 7151.25 7204.05 8833.72 S 3909.00 E 5965324.98 N 375497.88 E 3.997 9657.11 12509.43 78.500 152.570 7174.34 7227.14 8915.74 S 3951.74 E 5965242.23 N 375539.21 E 5.278 9749.53 12583.37 81.190 152.760 7187.37 7240.17 8980.39 S 3985.16 E 5965177.02 N 375571.52 E 3.647 9822.26 12640.74 83.710 152.770 7194.91 7247.71 9030.95 S 4011.18 E 5965126.02 N 375596.68 E 4.393 9879.10 12736.18 88.230 152.340 7201.62 7254.42 9115.42 S 4055.05 E 5965040.82 N 375639.09 E 4.757 9974.21 12831.73 89.400 150.870 7203.59 7256.39 9199.45 S 4100.48 E 5964956.02 N 375683.08 E 1.966 10069.59 12927.33 90.140 150.180 7203.98 7256.78 9282.68 S 4147.51 E 5964872.00 N 375728.68 E 1.058 10164.93 13022.86 89.360 150.200 7204.39 7257.19 9365.56 S 4195.00 E 5964788.31 N 375774.75 E 0.817 10260.15 15 June, 2004 -15:58 Page 50f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-57 Your Ref: AP/501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13117.75 90.830 152.760 7204.24 7257.04 9448.93 S 4240.31 E 5964704.19 N 375818.62 E 3.111 10354.88 13213.45 91.120 153.290 7202.61 7255.41 9534.20 S 4283.71 E 5964618.18 N 375860.56 E 0.631 10450.52 13308.96 90.320 152.570 7201.41 7254.21 9619.24 S 4327.17 E 5964532.41 N 375902.56 E 1.127 10545.98 13404.57 89.400 152.470 7201.64 7254.44 9704.06 S 4371.29 E 5964446.85 N 375945.22 E 0.968 10641.51 13500.07 88.590 152.410 7203.32 7256.12 9788.71 S 4415.47E 5964361.45 N 375987.94 E 0.850 10736.92 . 13595.28 89.790 153.060 7204.66 7257.46 9873.34 S 4459.08 E 5964276.10 N 376030.10 E 1 .433 10832.06 13691.11 90.090 152.850 7204.76 7257.56 9958.69 S 4502.65 E 5964190.02 N 376072.20 E 0.382 10927.84 13786.38 90.380 152.300 7204.37 7257.17 10043.25 S 4546.53 E 5964104.72 N 376114.63 E 0.653 11023.04 13881.02 89.460 153.030 7204.50 7257.30 10127.32 S 4589.99 E 5964019.91 N 376156.64 E 1.241 11117.62 13977.49 90.810 151.350 7204.28 7257.08 10212.64 S 4634.99 E 5963933.83 N 376200.18 E 2.234 11213.99 14073.05 90.510 150.590 7203.18 7255.98 10296.19 S 4681.36 E 5963849.51 N 376245.12 E 0.855 11309.34 14168.02 89.850 149.850 7202.88 7255.68 10378.62 S 4728.53 E 5963766.28 N 376290.87 E 1.044 11404.01 14263.68 88.970 150.000 7203.86 7256.66 10461.39 S 4776.46 E 5963682.70 N 376337.38 E 0.933 11499.32 14359.21 90.570 151.790 7204.25 7257.05 10544.85 S 4822.93 E 5963598.46 N 376382.41 E 2.513 11594.63 14454.00 89.830 151.800 7203.92 7256.72 10628.39 S 4867.73 E 5963514.17 N 376425.77 E 0.781 11689.30 14549.59 88.680 152.380 7205.16 7257.96 10712.85 S 4912.46 E 5963428.95 N 376469.06 E 1.347 11784.77 14645.10 87.690 151.790 7208.18 7260.98 10797.20 S 4957.16 E 5963343.85 N 376512.30 E 1.206 11880.13 14740.92 88.470 150.790 7211.39 7264.19 10881.19 S 5003.16 E 5963259.08 N 376556.86 E 1.323 11975.72 14836.16 89.890 152.050 7212.76 7265.56 10964.82 S 5048.71 E 5963174.69 N 376600.98 E 1.993 12070.79 14931.77 89.090 151.440 7213.61 7266.41 11049.03 S 5093.97 E 5963089.72 N 376644.79 E 1.052 12166.26 15027.22 89.890 152.480 7214.46 7267.26 11133.27 S 5138.84 E 5963004.72 N 376688.21 E 1.375 12261.59 15122.83 89.230 151.810 7215.19 7267.99 11217.80S 5183.51 E 5962919.44 N 376731.43 E 0.984 12357.10 . 15215.19 91.250 151.310 7214.80 7267.60 11299.01 S 5227.49 E 5962837.49 N 376774.02 E 2.253 12449.31 15313.48 90.330 151.090 7213.45 7266.25 11385.13 S 5274.84 E 5962750.57 N 376819.88 E 0.962 12547.41 15408.92 89.770 151.680 7213.37 7266.17 11468.91 S 5320.55 E 5962666.02 N 376864.15 E 0.852 12642.68 15503.92 88.960 151.670 7214.42 7267.22 11552.53 S 5365.62 E 5962581.64 N 376907.79 E 0.853 12737.54 15599.40 87.920 151.580 7217.02 7269.82 11636.51 S 5410.98 E 5962496.90 N 376951.70 E 1.093 12832.84 15694.70 87.230 151.710 7221.05 7273.85 11720.30 S 5456.20 E 5962412.35 N 376995.48 E 0.737 12927.92 15790.30 88.780 153.050 7224.38 7277.18 11804.95 S 5500.49 E 5962326.96 N 377038.32 E 2.143 13023.37 15885.68 87.810 153.680 7227.22 7280.02 11890.17 S 5543.23 E 5962241.02 N 377079.60 E 1.212 13118.68 15980.94 89.150 153.190 7229.74 7282.54 11975.34 S 5585.81 E 5962155.13 N 377120.72 E 1.498 13213.88 16076.38 88.980 153.150 7231.30 7284.10 12060.49 S 5628.88 E 5962069.25 N 377162.33 E 0.183 13309.27 16172.04 87.990 152.620 7233.83 7286.63 12145.61 S 5672.47 E 5961983.40 N 377204.45 E 1.174 13404.85 16267.62 87.110 153.340 7237.92 7290.72 12230.68 S 5715.85 E 5961897.61 N 377246.37 E 1.189 13500.29 16363.13 88.610 152.070 7241.48 7294.28 12315.49 S 5759.62 E 5961812.06 N 377288.68 E 2.057 13595.67 15 June, 2004 - 15:58 Page 60f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-57 Your Ref: AP/501032049200 Job No. AKZZ3066896, Surveyed: 2 June, 2004 Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 16384.88 88.720 151.320 7241.99 7294.79 12334.63 S 5769.93 E 5961792.74 N 377298.66 E 16433.00 88.720 151.320 7243.06 7295.86 12376.84 S 5793.01 E 5961750.15 N 377321.02 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=52.80' above MSL. Northings and Eastings are relative to 2132'FNL & 1494'FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2132'FNL & 1494'FEL and calculated along an Azimuth of 154.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16433.00ft., The Bottom Hole Displacement is 13665.47ft., in the Direction of 154.918° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 16433.00 7295.86 12376.84 S 5793.01 E Projected Survey Survey tool prOQram for CD2-57 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 796.00 0.00 796.00 786.54 16433.00 786.54 CB-SS-Gyro 7295.86 MWD+IIFR+MS+SAG North Slope, Alaska Dogleg Vertical Rate Section Comment (0/100ft) 3.484 13617.39 0.000 13665.41 Projected Survey . . 15 June, 2004 - 15:58 Page 70f7 OrillQuest 3.03.06.002 e . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 July 02, 2004 RE: MWD Fonnation Evaluation Logs: CD2-57, AK-MW-3066891i 'J. >- <...{ ( 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-Sun, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG fonnatted Disc with verification listing. ~I#: 50-103-20492-00. cl J~ À~~vt µo~w ) (J~( - ~ 7"~ e e ,dGY.-D~r~ MECHANICAL INTEGRITY REPORT' '.. :..IG RELEJ...S:::: OPER & FIELD -c. Ÿ' ~~ r .~ \ ~':\\~ WELL NUKBER c.\) ;}--s\ :: P UD D Þ. :: E: : 1"'""\ \,1.. Cas iDg : \ TD : .MD.. TVD; :?BTD: Shoe: \d<O~') HD ~\\C:\~<;1VD i DV: MD TVD ~~LL DATA ~ ~, MD \::;J ~ 'TVD '" ..." '" :..:':1e~ : \"J \-" Shoe: HD \.( \., :~bi:;g : l\ ~J P 2.cke~ \ \,,~") HI) ~ole Size ~\I) ana TVD j :CP: HD :'TD TVD i Set: ë. t - \ \ C;C\~ Perf :5 to o ~4-', \..G\L \)~ \c:,'~ ~\'C:..v€ ~\,(7Jc~ þ,.\'Y'¡~ \d-~Oa ~C?.Þ...NIc;-.L INTEGR ïTY - P .tŒT f 1 Annulus Press Test: 7~ 1 15 min ; 30 min C ommen t s : >,S'\)t;'r,\e'i\o.·\ CD "^f~\\a \,--, \~\~tX.'SstS'; \ \ \'\' ~'7-\-f'CL~fr~ ' '. . /' MEGHÞ..NICÞ.~ INTEGRITY - PART i 2 \ .,.~ ~ ~b\ .\a~ \ L 'í\d-~"i Cement: Volumes:' .P-..mt. Liner ~h esgT\~'ls'1-; DV ~b, . C&:üt -';01 to coveI perfs ~ "2..,((52£\ ''L "''';> \t)(;; C"i- t(.,~ -\..ò.,\ sv\.~.:\èlc~ +a I"N~·-.\a~fð~.f\\~\,",,-ç ~\,~'? SOD' \C«~ ~~ ,K,\- ~GtS-o Theoretical TOe ---~-~ -'.-'--"-.--- ----..- ---------.----.--- Ceme'!"'t Bond Log<t(CJy.~e'~'or No) ~L ...~ "" Ie ; In AOGCe File /¿H -t)'--\. CBL ~valuation. ::.one above perfs ¡('''f.<:£.\ \c~,-\- ~~,-\..,,~~~\\ ~~ ~k~ -\-0 ~\:;~~;~\\ Prociu~tion Log: Type ¡Evaluation . T~~ G..\'ê \'-0 \,<Z<"-\~\'\"e:;"'-s... 0-\-\"'-.(;: ~ \~\,,~ ~', \\"-, ~ \ I~M\ \0- CONCLUSIONS: O.-Ç. c.. \) d - S" t : . ? ar t if 1 : ?ar-= :2: V\~~ '-~-- ... \ . Ç\, l tco:..~~\ )/fJ'1 Z .. ~ ~ fi <O/:)-30l-\ Re: Request ot commence injection into CD2-57--(204-072) , e e Subject: Re: Request ot commence injection into CD2-57--(204-072) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 23 Jun 200413:57:44 -0800 To: "Crabtree, C L" <C.L.Crabtree@conocophillips.com> cc: "Alonzo, Chris" <Chris.Alonzo@conocophillips.com>, Vem Johnson <V em.J ohnson@conocophillips.com> Cliff, I have examined the information you have submitted for CD2-57. I concur that despite the difficulties encountered running and cementing the 7" casing that the bond log does indicates that in the intervals logged that good to excellent bend is evident. It is indicated that the casing is well cemented from below the top of the Alpine up to the tubing tail. It is likely that the cement quality is similar in the intervals shallower than the packer depth. This information satisfies the isolation requirements for an injection well and you have approval to initiate injection. Please make arrangements for the Inspector to witness an MIT after the well is placed in service. Tom Maunder, PE AOGCC Crabtree, C L wrote: Tom Attached you will find a tubing detail and bond log for Alpine Injection well CD2-57. This SCMT Log suggests good to excellent bond across the interval that was logged. Despite the lack of returns during the 7" cement job, it appears that a good cement coverage and bond was obtained across and above the 7" shoe. I've attached various files of use in evaluation of the attached log. We request AOGCC authorization to commence injection immediately. Time is of essence in this matter as we plan to utiize injection support from this well while drilling the upcomming producer CD2-53. API number 50-103-20492-00 Tubing Tail Alpine C Sand Top 7" Casing Shoe psi for 30 minutes 11,996' MD (6,982' ss) @ 59 deg 12,400' MD (7,148' ss) @ 74 deg 12,642' MD (7,196' ss) Completion MIT - OK (6-04-04) Tested to 3500 During the cement job on 5/26/04 mud returns were poor. The 7" Casing cement job summary is excerpted from daily drilling reports: Continue running 7" 26# L-80 MBTC casing f/ 11,240' to 12,606' (297 jts. total) - PU hanger & landing jt. - land casing w/ FS @ 12,642' FC @ 12,552' - string took excess wt. @ 11,370' 15 to 20 k - worked through tight spot w/ 35 k down - ran 2 jts. w/ no returns - stab in & attempt to circulate - work pipe - had slight returns @ 3.5 BPM @ 490 psi - Ran in hole w/ remaining 27 jts w/ no returns - SO wt. 160 to 135 RD casing equipment - & Frank's fill up tool - blow down TD - MU cement head & cement lines Attempt to regain circulation @ 2 to 4 BPM @ 520 psi - Observed slight flow @ flow line - PJSM on cmt procedures Cement 7" casing as follows: Pumped 10 bbls CW-100 @ 4BPM @ 400 psi - Test lines to 3800 psi - Pumped 40 bbls CW-100 @ 8.3ppg @ 4 BPM @ 450 psi - Mixed & pumped 40 bbls MudPush XL @ 10.5 ppg @ 4.7 BPM @ 480 psi - Dropped bottom plug - Mixed & pumped 43 bbls Lead slurry (LiteCRETE) @ 11.0 ppg @ 5.2 BPM @ 500 psi - Mixed & 10f2 6/23/2004 1 :58 PM Re: Request ot commence injection into CD2-57--(204-072) e e pumped 31 bbls Tail slurry(Classs G) @ 15.8 ppg @ 4.9 BPM @ 400 psi - Dropped top plug wi 20 bbls water fl Dowell - Switch over to rig pumps & displace wi 456.5 bbls 9.8 ppg LSND mud @ 6 BPM @ 420 to 850 psi - Slowed pumps to 3.5 BPM for last 6.5 bbls of displacement @ 590 to 620 psi - Bumped plug wi 1100 psi - Check floats - floats held - CIP @ 0300 hrs. Observed slight flow @ flow line during job wi flow increasing to 9 % flow as last 5 bbls of lead slurry was exiting casing and returns continued @ 9 % flow until plug was bumped Test 7" casing to 3500 psi for 30 mins. RD cement lines, cmt head, casing elevators, & landing jt. Regards, Cliff Crabtree Alpine Subsurface Development - ConocoPhillips Alaska, Inc. Office Telephone: (907) 265-6842 Mobile Telephone: (907) 223-7911 «CD2-57 1320 Plot.pdf» «CD2-57_SCMT.zip» «CD2-57 Tbg detail.xls» 2 of2 6/23/2004 1 :58 PM +' :c t o ~ , :c '5 o (f) -7000 -8000 -10000 CD2-57 (Toe) -13000 ,1'Jf'\) -14000 -15000 2000 3000 4000 5000 West(- )/East(+) 6000 7000 8000 e e dû4-Q'l") Tubing Detail Well: eD2~I)·t Date: 6f4f2t¡¡;}3 4. 112u Tba lJrrt,,?di .......................,..............., ConocoPhillips Alaska, Inc. Subsidiary of PHilLIPS PETROLEUM Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon -: ~1 RKB to LDS 32.46 FMC 4 H2" Tbg hang", 3.81 32.46 ,1:5 ;':: 14 to 273 fjO ..Jís 41i2" 126# l.·BO :8TM Tb~1 2629.74 36.27 Cameo 4 iì:.:-t DB n¡ppj~1 5.62" OD x 3.812" iD 1.53 2666.01 .Jt$ 4 to 213 ;,10.Jt:.:; 4 1 i2'" 126# l.··80 :8TM Tb,1 9140.70 2667.54 p'¡P- 4 1i2" 126# L..80 IBTM ,b,1 9.39 11808.24 Ca::1co 4 i!2' ~{ßC~·-2 GLJ'v1 \·vfd~;n-:my 5.98401 CJ[) x 3,9~'38" :0 7.36 11817.63 Pue - 4 H2" 126# L··80 IBTM :b,1 9.84 11824.99 ,jts 2 to ~-:,; 2 ,1:5 4 1i2" 12 F;# L-·80 :BTM Tbg 87.40 11834.83 Pue- 4 1 f2" 12.6# L··80 IBTM :bg 9.80 11922.23 4.5" X 7" 8!-'.Kr:.R ;:;··3 P.f.\CKr:.R wi MiHout "3)(1:. 5.~J7" OD X 3.8/5" 1[; 11.05 11932.03 P@ - 41fZ 12.6# L..80 IBTM ,b,1 9.80 11943.08 .Jts 1 to ~ 1 J:5 41i2" 12 6# l.-·80 iBTM Tbg 30.66 11952.88 4.5" "XN" NiPPLE S" (j[) ~< 3.725 ;!ID 1.21 11983.54 Pup··4 1/2" '12.6# 1..-80 18: M Tbg 9.77 11984.75 41/2" WU.::G 51; (jD 5" OD )( 3.875" ID 1.42 11994.52 4 1/2:" tÞg taH @ 11995.94 295 jts. tot.&! in pip<ô! shed 213 jt$. to nm ~ last 22 jt¡¡. Out Pa.Q!><ô!f@11,932' - 70Qú' TVD * 8"30 attõ:chr,;d draw:::g for p3cker & m,H out <:;<::"3nsion d3.ta T öp 01 Alpin/? "C" f2,4úO' MD 72Ua . TVD Used ,leT Lube Run··N..Sea! pipe dope Make up torque - 3'100 Aiijts. dnfted to 3.84:3" f~erne!f{$: Upwt-190 k Dn wt -',20 k 8i'Jcks .. -15k Supervisor: Bw1<:!j{ / Mfck<:!j{ · .' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alpine I CD2 06/04/04 David Burley N P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: Displaced tubing with diesel and tested against ball on seat in RHC plug I "XN" nipple. Bled down tubing to 750 psi and tested 7" X 4 1/2" annulus. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Mrr Report Form Revised: 06/19/02 CD2·57 Mrr Form.xls Re: FW: CD2-57 BOP test extension/waiver . . dD~ -0'\ d- Subject: Re: FW: CD2-57 BOP test extension/waiver From: James Regg <jimJegg@admin.state.ak.us> Date: Tue, 01 Jun 2004 17:20:07 -0800 To: "Kuenzler, Zane A" <Zane.A.Kuenzler@conocophillips.com> CC: Tom Maunder <tom_maunder@admin.state.ak.us>, Admin AOGCC Prudhoe Bay <aogcc -prudhoe _ bay@admin.state.ak.us> Your request for an extension until the 4th is granted. Jim Regg AOGCC 907-793-1236 Kuenzler, Zane A wrote: Mr. Regg, Tom Maunder left me a phone message asking me to forward this issue, as he was called away from the office. He had also asked when we would be on the bank after completing the horizontal section. The timing now looks like the Thursday the 3rd or Friday the 4th of June. Should any other questions come to mind feel free to contact me. Regards, Zane Kuenzler Alpine Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1308 Office 907-240-5499 Cell -----Original Message----- From: Kuenzler, Zane A Sent: Tuesday, June 01, 2004 2:29 PM To: 'Thomas Maunder' Cc: Johnson, Vern¡ Alvord, Chip¡ Doyon 19 Company Man Subject: CD2-57 BOP test extension/waiver Mr. Maunder, Doyon 19 is currently in the process of drilling the horizontal section of CD2-57, and is experiencing losses of 60-70 bph of the water-based drilling fluid. ConocoPhillips would like to request a waiver/extension of the required BOP test (scheduled for 6/2/2004), to be replaced with a function test, at the conclusion of tripping out of the hole for the horizontal section. This would alleviate some of the safety concerns with battling losses while testing the BOP. Should you have any questions or concerns please contact me at the numbers listed [Kuenzler, Zane A] below, or Vern Johnson at 265-6081. Best Regards, Zane Kuenzler Alpine Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1308 Office 907-240-5499 Cell 10f2 6/21/2004 2: 13 PM . rnn, '} i ¡ ! IU' '-~ n i! lb AI,ASIiA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Alpine Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage,AJ( 99510 . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field CD2-57 ConocoPhillips (Alaska), Inc. Permit No: 204-072 Surface Location: 2132' FNL, 1494' FEL, Sec, 2, T11N, R4E, UM Bottomhole Location: 560' FSL, 594' FEL, Sec. 13, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's North Slope petroleum field inspecto at -3607 (pager). BY ORDER OF THE COMMISSION DATED thiS-#- day of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Drilll::.J Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 1a. Type of Work: 3. Address: STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL Alaska Oil & G;u rAnc> "ft__' ExpIoratoryU Development Oil U A ~j!iple Žóne D '.. S Service 0 Development Gas 0 nCI~ijJt@,ne 0 5. Bond: L::J Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 CD2-57 6. Proposed Depth: 12. Reld/Pool(s): MD: 17259' .., TVD: 7257' Colville River Reid RedrillU 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 2132' FNL, 1494' FEL, Sec. 2, T11N, R4E, UM'" Top of Productive Horizon: 311' FNL, 2358' FWL, Sec. 13, T11N, R4E, UM Total Depth: 560' FSL, 594' FEL, Sec. 13, T11 N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): if Surface: x- 371740.55 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size Hole 42" 12.25" 8.5" f\VA Casing 16" 9.625" 7" 3.5" 19 Total Depth MD (ft): Casing Structural Conductor Detailed Operations Intermediate Production Uner Perforation Depth MD (ft): 20. Attachments: Rling Fee 0 Property Plat 0 y- / 5974224.3 Zone- ft. Waximum Hole Angle: 90° Weight 62.5# 36# 26# 9.3# Sœ ifica.tions Grade Coupling H-40 Weld J-55 BTC L-80 BTC-M L-80 1ST-mod 12594' 11980' Length 77' 3334' RECr=IVEDhzt,Sè) APR 2 9 20D4 ion 7. Property Designation: ADL 380075 ~ Alpine River Pool 8. Land Use Permit: 13. Approximate Spud Date: ALK N/ A 5115{~ ¿U'.4- S r LJ V 9. Acres in Property: 14. Distance to 1)560 - :.13'17 k Nearest Property: 311' FNL, Sec. 13 .-L r.¡'.'2,q<t. ., 10. KB Elevation 15. Distance to Nearest ./ 4 (Height above Gl): 52 feet Well within Pool: CO2-58, 1482 17. Anticipated Pressure (see 20 AAC J5.035) ~. Max. Downhole Pressure: 3284 psig / Max. Surface Pressure: 2558 psig Setting Depth Quantity of Cement Bottom c. 1. or sacks 1VD (including stage data) 114' 2390' 609 sx AS Ute & 230 sx UteCrete 7249' 248 total (101 sx @11ppg. 147 7055' sx@15.8ppg) MD 37' 37' 37' 32' Top 1VD 37' 37' 37' 32' MD 114' 3371' 12631' 12012' PRESENT WElL CONDmON SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth 1VD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth 1VD (ft): Junk (measured) Length Size BOP SketchD Diverter Sketch 0 Drilling program[Z) Seabed Report 0 21. Verbal ApprO\lal: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name C. Alvord Signature ~. c.... 0iA- Cement Volume MD lVD Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Ruid Program 0 Date: Shallow Hazard Analysis [J 20 AAC 25.050 requirements 0 Contact Vem Johnson @ 265-6081 Title Alpine Drilling Team Leader Phone 2&Ç- ~ 11.1:> Date i'{ U( O+- Þreoared bv Vem Johnson Commissíon Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ;2.(:;;> t.(.- 072- 50- /03 - 2ó l/ 9 2 -úû Date: for other requirements Conditions of approval: Samples required 0 Yes _g No Mud log required DYes g No _ H~en sulfide measures 0 Yes J3.No Directional survey required $rYes 0 No , Other~.:, ñ¿4^ '" ""- ~ ~'-- ~<::::J ~ ~~~ \-'\ \T ~ C£'""^L ~\ 0 \0ú \, \1- ,-?C~ t>,'J . ~ ~~:,t5.:[, óI~C) ~þ..c. d-S t~;~S,~ )\.d~ \>(¡<-\-tt'\ et~"'\~~ \>(,\dÖ_~(.¡;~~~ '-is[\) (~\ I Ij~ 'j_ BY ORDER OF r- hL 1/ Approv bv: ~ -1{ A./ COIv1MISSIONER THE COMMISSION Date: 0 / If" J ð"t'" VJ '--" I! f Form 10-401 Revised 3/2003, SUbmiÖ RJ'Gtf N A L CD2-57 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 1/411 H I /9 5/8" C I t - oe - aSlna n erva Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots as required Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increase mud weight Surface Formations >2000' TVD Lost Circulation Low Reduce pump rates, mud rheology, lost circulation material, use of low density cement slurries 8 1/2" HI/ 7" C I t - oe aSlna n erva Event Risk Level Mitigation Strategy Abnormal Pressure in low I BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations ._00,,/ Check for flow during connections and if needed, >2000' TVO increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheoloç¡y, 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 (ECO) monitoring, weighted sweeps. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low I H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low <, Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo , lost circulation material 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. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers OJl9~~At " -- .~ Alcine : CD2-57 Procedure Procedure 1. Move on Doyon 19. 2. Rig up on riser 3. Drill 12-1AII hole to the surface casing point as per the directional plan. 4. Run and cement 9-5/811 surface casing. 5. Pressure test casing to 2500 psi. 6. Install and test BOPE to 5000 psi. 7. Pick up and run in hole with 8-1/2" drilling BHA. 8. Drill out 20' of new hole. Perform leak off test. 9. Drill 8-%" hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) 10. Run and cement 711 casing as per program. Top of cement> 500 MD above Albian 96 formation. Carry out a leak off test down the 9-5/8" x 1" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. Pressure test casing to 3500 psi. 12. BOPE test to 5000 psi. 13. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. v 14. Drill 6-1/811 horizontal section to well TO (LWD Program: GR/RES/PWD). 15. Circulate the hole clean and pull out of hole, displacing the well to 9.2 ppg brine. 16. Run 4-%,12.6#, L-80 tubing with DB nipple, gas lift mandrel(s), and packer. Land hanger. 17. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 18. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 19. Circulate tubing to diesel and install freeze protection in the annulus. 20. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 1 30 mins. 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. C02-58 will be the closest well to C02-57. Well separation is 18.2' at 855' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 3.3' at 8551 MD. Drillina Area Risks: ,,' There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. 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 Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-57 will be injected into a permitted annulus on C02 pad or the class 2 disposal well on CD1 pad. The CD2-57 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. Upon completion of CD2-57 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 450-5001 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 TVO) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 - 1081 = 1910 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi O R ""'·1· ~~fjll f·~ J~.. ,,> !I ~l~l I ~Ìi'=- ~- .; '- ",-,- CD2-57 DRilliNG FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1/8" point - 12 %" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.6 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4-8 1 0-1 5 10 minute gels <18 12-20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 8.5-9.0 9.0 - 10.0 9.0-9.5 KCL 6% Oil/water ratio y~ Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline 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 Alpine 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 well bore stability. Production Hole Section : The horizontal production interval will be drilled with aM-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 Colville River Field CD2-57 Injection Well Completion Plan 16" Conductor to 114' Updated 4/28/04 4-1/2" Camco OS Nipple (3.812') at 1850' TVD = 2370' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 3371' MD / 2390' TVD cemented to surface Packer Fluid mix: 9 2 PPQ KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Tubina susoended with diesel Comoletion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DS6 nipple 2649' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM (3.909" 10) 11 800' 6890' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker S3 Packer w/ millout extension 11900' 6996' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (1) HES "XN" (3.725")-58.9° inc 12000' 7049' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 12012' 7055' TOC @ +/- 11540' MO 16801' TVO (>740' MD above top Alpine) Camco KBG-2 GLM (3.909" DRIFT 10) wi dummy Baker 83 Packer WI millout extension at +1- 11900' MOl 6996' TVO < 200' TVO from top of Alpine Well TD at 17259' MDI 72571 TVD 1c 7" 26 ppf L-80 STC Mod Production Casing @ 12631' / 7249' TVD @+/- 84.0º OR'IGlNAL ·~ CD2-57 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 Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. 1 (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 3371 12390 14.5 1081 1563 7" 12631 17249 16.0 3280 2558 / N/A 17259 1 7257 16.0 3284 :/ N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determ ined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2390) = 842 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 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3280 - (0.1 x 7249') = 2555 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3284 - (0.1 x 7257') = 2558 psi / ORIGINAL' 95/8" Surface Casine: run to 3371' MD 1 2390' TVD, Cement from 3371' MD to 2871' (500' of fill) with Class G + Adds @ 15,8 PPG, and from 2871' to surface with Arctic Set Lite 3, Assume 300 % excess annular volume in permafrost and 50 % excess below the permafrost (1602' MD), Lead slurry: System: Tail slurry: System: (2871'-1602') X 0.3132 ft3fft X 1.5 (50% excess) = 596.18 fe below permafrost 1602' X 0.3132 ft3fft X 4 (300% excess) = 2007.0 fë above permafrost Total volume = 596.2 + 2007.0 = 2603.2 ft3 => 609 Sx @ 4.28 ft3fsk 609 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.28 ft3fsk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOl accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 500' X 0.3132 felft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOl accelerator @ 15.8 PPG yielding 1.17 ft3 fsk 7" Intermediate Casin2 run to 12631' MD /7249' TVD Lead cement from 11780' MD to +1- 9881' MD (minimum 500' MD above top of Albian 96 Formation) with 11 PPG LiteCrete, Assume 40% excess annular volume, Tail cement from 12631' MD to +/- 11780' MD (minimum 500' MD above top of Alpine C Formation) with Class G + adds @ 15,8 PPG, Assume 40 % excess annular volume, Lead: Tail: System: (11780' -9881') X 0.1268 ft3fft X 1.4 (40% excess) = 337.1 fe annular vol Total volume = 337.lfe = 101 Sx @ 3.35 ft3fsk (12631' -11780') X 0.1268 fefft X 1.4 (40% excess) = 151.1 ft3 annular vol. 80' X 0.2148 fe fft = 17.2 ft3 shoe joint volume Total volume = 488.2 + 17.2 = 168.4ft3 => 147 Sx @ 1.15 fefsk 101 Sx LiteCrete (additives TBD) 147 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 fefsk 1 By Weight Of mix Water, all other additivesa~rr\f A L ORIGINAL A HALLI1l:UR1'QN COMPANY 5pe.-.l'""'y-sun DRIL-LINIS . SCERVlces 17 March, 2004 Standard Planning Report Plan: CD2-57 (wp02) ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-57 Plan: CD2-57 ,~ ·11- Conocurlll IPS \.-- ~- o o _ .§. -6000 \ ALBIAN 97 i ~ J "Ø' ALelAN 96 o -7000 -,,(\ÇJ . i\. I ¡ ~ ¡ TOP HRZ\/ K-' MAR~ER TSP K~::RUr en -8000 = Begin Oir@ 4.00; 11960.420'MD'7028..~03'TVD .......____.. .~~~~.~.~.....,.~{.~... ...... .. .:........ MILUVE.;CH A = - - - - r- - - - r - - - - T - - - - í : - -: í - - - - - - - - -'--f\ .'."'.'.' .A~.P.I.N'~P"h" '.. ALPINE ~ ;: He-ei: ~e~~cE~s~ee~;~;~9'=M~,=7~5~.~~ ~V~~~~F~~ ~2~1~'~EL,~~;f3~T'1-1'~~~;~.'!K··"·'·"'···' '-'. "'" '-7" Csg Pt @ ~2631' MD - I II . I I - I ~ I I CD2-57 (Heel) -1 ??oo = : ::- I \ - : : : : - I, I I -11000 1\ - : : ': : . - I I . I: -12000: __T~'=e: T~~ ~p~, H~'~ ~ 6~59'_M~'~~7toj~ ~+ (~5':~N: & ~2~'~E~, S~~J~'N;~~~~~_:: I I I I --1\ ..' -13000: - - - -" - - - - - -~: @ ~7~5:'~Dt J:6~2'T:D ~4~0~'FN~: :9:'FE:, ::U;':_:4~C~"-1 T 6-11~' Ope, Ho:e I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ConocóPhillips o ~---- ---- ---- -1000 ~---- ---- ---- ·2000 "'2 ~ -3000 - - - - -4000 - - - - -5000 - - - I I -3000 -2000 ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CO2 Well: Plan: CO2-57 WeI I bore: Plan: CO2-57 Plan: CO2-57 (wp02) Engineering Alpine Calculation Method: Minimum Curvature Error S%tem: ISCWSA Scan Method: Trav. Cylinder North Error Suriace: Elliptical Conic Waming Method: Rules Based Approved Plan J ~...... :':~S.~~(2132'~FNL & 149~' FEL, se~-T11N-R4~ .'."'....1... I I I __ __ \. B~91' Di, rO;300'M!'"OITTVD I I ~t'\ '~'~~·¿¡~,·si~rt Sail @ 57.316; 1732.904' MD, 1505.594' TVD I rz.ÇJI.t-' I I I C-40 ..:...... 9~518~.(jst Pt @ 3370'MD, 2390'TVO - - - - ¡ ~ -;. ~. .........---- C-30' "'r :' I 1...\ ÇJ i C-20 \':Jí§.J I . I .' . ,,(\ÇJ ¡ \I.~~.........::: ..' '" ...... I ~ ~o, K-3 MARKER BASAL K-3 SS .. I . K-2 MARKER I BASE K-2 SEQUENCE -' ~çÇj ~ I r:P: ~1 1".;1\<1 ør- .0 'C( \~'C\. CD2-57 (Toe) -1000 1000 2000 3000 4000 5000 6000 7000 8000 9000 1 0000 o West(-)/East(+) (2000 ftJjn) SECTION DETAILS See MD nc Azi TVD +NI-S +EI-W DLeg 1 36.100 0.000 0.000 36.100 0.000 0.000 0.00 2 300.000 0.000 0.000 300.000 0.000 0.000 0.00 3 1732.904 57.316156.193 1505.594 -602.831 265.967 4.00 411960.412 57.316 156.193 7028.499-8478.479 3740.680 0.00 512758.91989.000 151.904 7257.01&9155.702 4072.976 4.00 612783.998 90.003151.904 7257.233-9177.8244084.786 4.00 716758.87090.003 151.904 7257.01a2684.293 5956.758 0.00 817258.87090.003 151.904 7256.98;'13125.373 6192'n TFace VSec 0.00 0,000 0,00 0.000 0.00 658.685 0.00 9264.033 -8.130018.299 0,021 0043.346 0,00 4013.338 1 CO2-57 (Heel) CO2-57 (Toe) spar'r'v-sun ORtLt..fN"G ·S1:RvlC:eS - - - Target .\ IL\LUlIl1no:\ CO\lPAX\ Conocd'hillips ConocoPhillips Alaska Inc. Engineering Alpine Project: Colville River Unit Site: Alpine CO2 Well: Plan: CO2-57 Wellbore: Plan: CO2-57 Plan: CO2-57 (wp02) Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Waming Method: Rules Based Approved Plan J~ ..... .~HL(2132' ~L& 1491: FEL, J.T11N-R4E1 I = _ _ _ _ _ _ _ r- - -0P-.- ......... Begin Dir @ 4°; 300'MD. 300'TVD = 300 200 . I\. '\ ()\FJ I I 1000 659 4 · o~ &.'.... ~~~DI~, Start Sail @ S7 .316;1732.904' MD, 1 SOS.S94' TVO _ =-c~~~~--J - -~:3~- -!~ ~Æ!? . J9:~' cst~t @ 3370,JD, 23907Jo _,...,._1 ___L ___:_ ...._+_,..;... ì;S~:""~ 'I I... _·",C-30.. ·.,1. ,~., I;' i -···....11 ", ~ .. ,. 1-- C-20 I ¡I, ""'l <t: 1 I, - I I < I i -"""6 ... =,..~-3:r:.~,:~~...BASAL K-3 SS': ........... r 1:I,+:i "~!~. .,.. .,.~ .....:. . i. ...., Target~,o~;open HOl16759' Mr, 7257.015¡T~D,(425rFNL & 82j'FEL, seC1.r~.1.1 N~~4rl '" I .,),"'. . " ..J...'. I.. I ... ... .J:. . r .: I.:.··. T:. 1 ". ...1 "'. K-2 MARKER I. ,i I I I .... ,i 5r:'>,I"~.1 I I I I .... .. T I ¡I,.. Iii ........ Begin Dir @ 4.00; 11960.420'MD,7028.503'TVD ··.,.CD2-57 (Toe) BASE K-2 SEQUENCE .......... :: ,ilil:' ¡"i .... :....... It"\, 1 . /1 I .... AL~IAN 97 ': . .... ,i I: .... .....1 I 1 ~i c!~. ': I J .... .......... ,. ........... .... ... ,I··· ...,.\ ... .' I ,... , ,... ,.. '. ,;1', ..... .. 1 ... ~H ':.~ ! 7" Csg Pt @ 12631' MD : . 60001= A¿BIAN 96 I , !, , r I¡ " . " 's.>- ~; ..r I 6-118; Open Hole --------] ~i~L=_lL~L~.J--L~~~l~~-J~J _,1':'" ....",.." " 'I ' ',I". II I' I'r' ,', I, I,'" I, " . .' ''1 "'1" II. ",,, ":;;~;~:;.;~......,, . . .," ". '. '" ..t ',""",,,,' I I' .= .....-.-. - - ::-':~,~ ~_~ ~;R~:R - - + - - ï - - ~ ~ ... - - - t ~ ... - ... r - ... - ... r ~ ... ....- t - - - - t - - ... -1- - - -1-~<>V" ~ . I I I I . 1 I I ALPINE:D '. ....' "j"". I.·:: Target Heel: Begin GeoSteer; 12759' MD, 7257.014' TVD, (729'FNL & 2710'FEL, Sec13-T11N-R4E) I ...... TD @ 17259'MD, 7256.764'TVD (4700'FNL & 594'FEL, Sec13-T11N-R4E Roan . "., TOP KUPARUKii, ! I II I I i I I I I. : I I . I I· I : I ¡I. I I I . 1 . I I I' I I II I I', I , I I I I I I ALPINE C' '.. I .... I I I I I I I " I I I I I I I I I I I I I I I I I J I I I I I I I I I I I I I I I I I I I I I I I I I I I , I I I I I I I I I I I I I I I I r I I I I I I o .... I·· .... .... ..... . ... .. . MILUVEACH A JOI LCU 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 1700 SECTJONDETAlLS See MD Inc AzI TVD iW-S+E1-w DLeg 1 36.100 0.000 0.000 36.100 0.000 0.000 0;00 2 300.000 0.000 0;000 300.O!JQ .0,000 . O;(C)() 0;00 3 1732,904 57.316156.1931505,594-:1)02;831< 2.65.~7 4;00 4119!)0.412 57.316 156.1937028.499,8478.479 3740.~~ 0:00 512758.91989.000 151.904 7257.01S:9155.702 4072.976 4;00 612783.998 90.003 151.9047257.233'9177;8244084.7864.00 716758.870 90.003151.904 7257.01a2684~93 5956.758 0.00 817258.87090.003 151.904 725U~3125.373 6192.234 0.00 TFace VSec 0.00 0;000 0.00 0.000 lioo· 6æ685 0.00~~;033 -8.1300.18299 0;0.30043;346 0:oa4013.338 0.oa4512.725 CD2-57 (Heel) CD2-57 (Toe) 5pe........y-sun DRILL.ING SERVICES Target ^ IlAl,LIIM:R'lnNi (;()'j.ø>A.'I\" Conoc;p¡,illips SPERRY_SUN HES Planning Report spS..........\I-5un CRIL.L.ING SERVICES :0. HALU81'RTO.'< COI>IPAW ~} EDM 2003.5 Single User Db ~¡ ConocoPhillips Alaska Inc. (Alpine) ~~,l~~~' Colville River Unit Î!~~,f~~-:~~~~~~ -~Æ~_Ç2¡"iìle~R.Lv~ll.Jnitl_ Nor:tb~S!~ AI?sk~a~LLni~~d§t~t~~~_~_ ....6;:~ Well Plan: CD2-57 c,",'cc' 52' MSL @ 52.0000 (52' MSL) f£~52' MSL @ 52.0000 (52' MSL) .::;J~~True S~ Minimum Curvature US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor ...~ AIPin~9_~j i i Site Position: I From: Map I Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5974641.660 usft 371696.240 usft O.OOOin Latitude: Longitude: Grid Convergence: Well Position +N/-S +EJ-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5974224.260 usft 371740.550 usft ft Latitude: Longitude: Ground Level: ! 70020' 016" N: 151002' 026" W 0.000 ft 36.100 0.000 0.000 36.100 0.000 0.000 0.00 300.000 0.000 0.000 300.000 0.000 0.000 0.00 1732.904 57.316 156.193 1505.594 -602.831 265.967 0.00 11960.412 57.316 156.193 7028.499 -8478.479 3740.680 0.00 12758.919 89.000 151.904 7257.015 -9155.702 4072.976 -8.13 CD2-57 (Heel) 12783.998 90.003 151.904 7257.233 -9177.824 4084.786 0.02 16758.870 90.003 151.904 7257.015 -12684.293 5956.758 0.00 CD2-57 (Toe) 17258.870 90.003 151.904 7256.987 -13125.373 6192.234 0.00 3/17/2004 9:49:37AM Page 2 of 7 COMPASS 2003.5 ORHSINAL COMPASS 2003.5 ORfGfNAL' Page 3 of 7 3/17/2004 9:49:37AM -2404.444 2769.000 156.193 57.316 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000 0.000 0.00 0.000 0.000 0.00 0.000 0.000 0.00 1.408 3.488 4.00 5.627 13.935 4.00 12.635 31.291 4.00 22.398 55.471 4.00 34 .869 86.356 4.00 49.987 123.797 4.00 67.679 167.611 4.00 87.858 217.585 4.00 110.425 273.475 4.00 135.272 335.009 4.00 162.276 401.887 4.00 191.307 473.783 4.00 222.222 550.347 4.00 254.872 631.206 4.00 265.967 658.685 4.00 288.763 715.139 0.00 322.737 799.278 0.00 356.711 883.418 0.00 390.685 967.557 0.00 424.659 1051.696 0.00 458.634 1135.835 0.00 492.608 1219.975 0.00 526.582 1304.114 0.00 560.556 1388.253 0.00 594.530 1472.392 0.00 628.505 1556.532 0.00 662.479 1640.671 0.00 696.453 1724.810 0.00 701.591 1737.536 0.00 - ------. - - - -- 730.427 1808.949 764.401 1893.089 0.00 798.375 1977 .228 0.00 822.390 2036.703 0.00 -- 828.679 2052.276 0.00 - --- 832.350 2061.367 0.00 866.324 2145.506 0.00 900.298 2229.646 0.00 934.272 2313.785 0.00 968.246 2397.924 0.00 1002.221 2482.063 0.00 1036.195 2566.203 0.00 1060.834 2627.223 0.00 ~1ì~liii::~~ 36.100 0.000 0.000 36.100 SHL (2132' FNL & 1494' FEL, Sec2-T11N-R4E 100.000 0.000 0.000 100.000 200.000 0.000 0.000 200.000 300.000 0.000 0.000 300.000 Begin Dir @ 4°; 300'MD, 300'TVD 400.000 4.000 156.193 399.919 -3.192 500.000 8.000 156.193 499.351 -12.754 600.000 12.000 156.193 597.812 -28.638 700.000 16.000 156.193 694.821 -50.767 800.000 20.000 156.193 789.908 -79.033 900.000 24.000 156.193 882.607 -113.300 1000.000 28.000 156.193 972.469 -153.398 1100.000 32.000 156.193 1059.054 -199.135 1200.000 36.000 156.193 1141.941 -250.285 1300.000 40.000 156.193 1220.726 -306.601 1400.000 44.000 156.193 1295.025 -367.808 1500.000 48.000 156.193 1364.477 -433.608 1600.000 52.000 156.193 1428.743 -503.680 1700.000 56.000 156.193 1487.510 -577.683 1732.904 57.316 156.193 1505.594 -602.831 End Dir, Start Sail @ 57.316; 1732.904' MD,1505.594' TVD 1800.000 57.316 156.193 1541.827 -654.498 1900.000 57.316 156.193 1595.827 -731.503 2000.000 57.316 156.193 1649.828 -808.507 2100.000 57.316 156.193 1703.828 -885.512 2200.000 57.316 156.193 1757.829 -962.516 2300.000 57.316 156.193 1811.829 -1039.521 2400.000 57.316 156.193 1865.830 -1116.526 2500.000 57.316 156.193 1919.830 -1193.530 2600.000 57.316 156.193 1973.831 -1270.535 2700.000 57.316 156.193 2027.831 -1347.539 2800.000 57.316 156.193 2081.832 -1424.544 2900.000 57.316 156.193 2135.832 -1501.548 3000.000 57.316 156.193 2189.833 -1578.553 3015.125 57.316 156.193 2198.000 -1590.200 C-40 3100.000 57.316 156.193 2243.833 -1655.557 3200.000 57.316 156.193 2297.833 -1732.562 3300.000 57.316 156.193 2351.834 -1809.567 3370.686 57.316 156.193 2390.005 -1863.998 9-5/8" Cst Pt @ 3370'MD, 2390'TVD - 9 5/8" CsgPt @33I7'MD 3389.196 57.316 156.193 2400.000 -1878.251 C-30 3400.000 3500.000 3600.000 3700.000 3800.000 3900.000 4000.000 I L-__ 407?-,--523 -1886.571 -1963.576 -2040.580 -2117.585 -2194.589 -2271 .594 -2348.598 2405.834 2459.835 2513.835 2567.836 2621.836 2675.837 2729.837 57.316 57.316 57.316 57.316 57.316 57.316 57.316 156.193 156.193 156.193 156.193 156.193 156.193 156.193 0.000 0.000 0.000 .~~;1- .- _ ~- EDM 2003 5 Single User Db "." . ·?~Y:t:·~_· ¿ConocoPhilhps Alaska Inc. (Alpine) ëK'¡' .-~.¿:..;; Colville River Unit -f~l>~'i/f~;l~_-.·..; ~~~eC~~~57 ç'fÖ: c' - --, - . Plan CD2-57 ~l~::;~~~;'N~~'"c.C ~~~.~~5~ (w.p~~ ~/ ':~ ,""."0"_":. _;/ .\ IlALUBliRTON COMP~'W .,.___~.u_~.-_ ~~._.;,~_......--...~ ,,; -,~,......... ~ ..... _ - ," ">,,-,~ . '''-- <_-. I~ . ... . ~_.___"- - -'...~~;, .~;:,:",-,;--¿:\,-;¡__,--";:'_==",<~~_.~·=",::,~_r_","~~~~=.o.=="--_':y-=>'-=~~~""",_=~Z-~~=~..--=--~-:----~~-~----::::-:-~~3-~~-¡"'~.-"'?~~.::::"~~~~~~",~-~:::;:-~ spa""""y-sun DRILLING _SERViCeS '.---- SPERRY_SUN HES Planning Report Conoc~illips COMPASS 2003.5 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4837.962 4922.101 5006.241 5090.380 5174.519 5258.658 5342.798 5426.937 5511.076 5595.215 5679.354 5763.494 5847.633 5931.772 6015.911 6100.051 6184.190 6268.329 6352.468 6436.608 6520.747 6604.886 6689.025 4669.684 4753.823 4793.010 4632.523 4333.127 4417.266 4501.405 4585.544 4588.896 2650.342 2734.481 2818.620 2902.760 2986.899 3071.038 3155.177 3239.316 3323.456 3407.595 3491.734 3575.873 3660.013 3744.152 3828.291 3912.430 3996.570 4080.709 4164.848 4248.987 4283.504 o RfGfNß;l 1953.498 1987.472 2021 .446 2055.420 2089.394 2123.369 2157.343 2191.317 2225.291 2259.265 2293.240 2327.214 2361.188 2395.162 2429.136 2463.110 2497.085 2531.059 2565.033 2599,007 2632.981 2666,956 2700.930 1885.549 1919.524 1935.347 1870.544 1749.653 1783.627 1817.601 1851.575 1852.928 1070.169 1104.143 1138.117 1172.091 1206.066 1240.040 1274.014 1307.988 1341.962 1375.937 1409.911 1443.885 1477.859 1511.833 1545.807 1579.782 1613.756 1647.730 1681.704 1715.678 1729.616 Page 4 of 7 -4427.722 -4504.726 -4581.731 -4658.735 -4735.740 -4812.744 -4889.749 -4966.753 -5043.758 -5120.763 -5197.767 -5274.772 -5351.776 -5428.781 -5505.785 -5582.790 -5659.794 -5736.799 -5813.804 -5890.808 -5967.813 -6044.817 -6121.822 -4273.712 -4350.717 -4386.581 -4239.703 -3965.694 -4042.699 -4119.703 -4196.708 -4199.775 -2425.603 -2502,608 -2579,612 -2656.617 -2733.621 -2810.626 -2887.630 -2964.635 -3041 .640 -3118.644 -3195.649 -3272.653 -3349.658 -3426.662 -3503.667 -3580.671 -3657.676 -3734.681 -3811.685 -3888.690 -3920.280 4187.851 4241.851 4295.852 4349.852 4403.853 4457.853 4511.854 4565.854 4619.855 4673.855 4727.856 4781.856 4835.856 4889.857 4943.857 4997.858 5051.858 5105,859 5159.859 5213.860 5267.860 5321.861 5375.861 4079.850 4133.850 4159.000 4056.000 3863.848 3917.848 3971.849 4025.849 4028.000 2783.838 2837.838 2891.839 2945.839 2999.840 3053.840 3107.841 3161.841 3215.842 3269.842 3323.843 3377.843 3431.844 3485.844 3539.845 3593.845 3647.846 3701.846 3755.847 3809.847 3832.000 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156,193 156,193 156,193 156.193 156.193 156.193 156.193 156. 193 1 56. 193 156.193 156.193 - C-20 4100.000 4200.000 4300.000 4400.000 4500.000 4600.000 4700.000 4800.000 4900.000 5000.000 5100.000 5200.000 5300.000 5400.000 5500.000 5600.000 5700.000 5800.000 5900.000 6000.000 6041.024 K-3 MARKER 6100.000 6200.000 6300.000 6400.000 6403.983 BAsAL K-3 SS 6455.835 K-2 MARKER 6500.000 57.316 6600.000 57.316 6646.574 57.316 ~ASJ: K-2SEQUENCe 6700.000 57.316 6800.000 57.316 6900.000 57.316 7000.000 57.316 7100.000 57.316 7200.000 57.316 7300.000 57.316 7400.000 57.316 7500.000 57.316 7600.000 57.316 7700.000 57.316 7800.000 57.316 7900.000 57.316 8000.000 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 57.316 3/17/2004 9:49:37AM 8100,000 8200.000 8300.000 8400.000 8500.000 8600.000 8700.000 8800.000 8900.000 - - -- - - - - - - - - - ~~ÇåÌe~~jè~ifÎ(8-Dca.L? - ~ Well Plan: C02-57 ~--il:!iíf~2 ~t~~t ~;~:gg:¡;~: ~~ti =~=._ _--_-·-~_=c·- ~-~~~""'=---~--~- ~~~..~.~-=..~=-~-"~~;~c; Minimum Curvature tj;.l~?1 ~~~~~i'I~~i~:S~:~~~~AIPine) . -- - ~~~ Colville River Unit ~ Alpine C02 =~, Plan: C02-57 ~c= Plan: C02-57 Z~tóQ1 C02-57 (wp02) A HALU81'RTO:'\ COMl'A.~ì' spa""""y-5un DR I L. L.I N Ci--.p e...a VU: e 5 SPERRY_SUN HES Planning Report ConocJ'Phillips Conoc~illips "--' SPERRY_SUN HES ~- spel"T"Y-sun Planning Report DRILLING SERVICES .. H.U.UBt'RTO:>i COMPkW :"'=-:':-...a-~""""'-..r=-~_.:: ...<r;'-".... r---<.....--', ..- -:" '-1.-· - . - ~- - . - '.'==-"-"::==~~-=-=e::- _~"~""'-'=:'-~~T-~_~~=~~¿--=_~_:~=_CC==-=--~_-:-==~= ~._- ~:[fl~¡~~~¡~~~:~a~~~AIPine) '~_i~t~:~!~g~:·~~tJ 9000.000 57.316 156.193 5429.862 -6198.826 2734.904 6773.165 0.00 0.00 0.00 9100.000 57.316 156.193 5483.862 -6275.831 2768.878 6857.304 0.00 0.00 0.00 9200.000 57.316 156.193 5537.863 -6352.835 2802.852 6941.443 0.00 0.00 0.00 9300.000 57.316 156.193 5591.863 -6429.840 2836.826 7025.582 0.00 0.00 0.00 9400.000 57.316 156.193 5645.864 -6506.845 2870.801 7109.722 0.00 0.00 0.00 9455.807 57.316 156.193 5676.000 -6549.819 2889.761 7156.678 0.00 0.00 0.00 ALBIAN 97 9500.000 57.316 156.193 5699.864 -6583.849 2904.775 7193.861 0.00 0.00 0.00 9600.000 57.316 156.193 5753.865 -6660.854 2938.749 7278.000 0.00 0.00 0.00 9700.000 57.316 156.193 5807.865 -6737.858 2972.723 7362.139 0.00 0.00 0.00 9800.000 57.316 156.193 5861.866 -6814.863 3006.697 7446.279 0.00 0.00 0.00 9900.000 57.316 156.193 5915.866 -6891.867 3040.672 7530.418 0.00 0.00 0.00 10000.000 57.316 156.193 5969.867 -6968.872 3074.646 7614.557 0.00 0.00 0.00 10100.000 57.316 156.193 6023.867 -7045.877 3108.620 7698.696 0.00 0.00 0.00 10200.000 57.316 156.193 6077 .868 -7122.881 3142.594 7782.836 0.00 0.00 0.00 10300.000 57.316 156.193 6131.868 -7199.886 3176.568 7866.975 0.00 0.00 0.00 10381.725 57.316 156.193 6176.000 -7262.818 3204.334 7935.737 0.00 0.00 0.00 ALBIAN 96 10400.000 57.316 156.193 6185.869 -7276.890 3210.542 7951.114 0.00 0.00 0.00 10500.000 57.316 156.193 6239.869 -7353.895 3244.517 8035.253 0.00 0.00 0.00 10600.000 57.316 156.193 6293.870 -7430.899 3278.491 8119.392 0.00 0.00 0.00 10700.000 57.316 156.193 6347.870 -7507.904 3312.465 8203.532 0.00 0.00 0.00 10800.000 57.316 156.193 6401.871 -7584.908 3346.439 8287.671 0.00 0.00 0.00 10900.000 57.316 156.193 6455.871 -7661.913 3380.413 8371.810 0.00 0.00 0.00 11000.000 57.316 156.193 6509.872 -7738.918 3414.388 8455.949 0.00 0.00 0.00 11100.000 57.316 156.193 6563.872 -7815.922 3448.362 8540.089 0.00 0.00 0.00 11200.000 57.316 156.193 6617.873 -7892.927 3482.336 8624.228 0.00 0.00 0.00 11300.000 57.316 156.193 6671.873 -7969.931 3516.310 8708.367 0.00 0.00 0.00 11392.827 57.316 156.193 6722.000 -8041.412 3547.847 8786.471 0.00 0.00 0.00 TOP HRZ 11400.000 57.316 156.193 6725.874 -8046.936 3550.284 8792.506 0.00 0.00 0.00 11500.000 57.316 156.193 6779.874 -8123.940 3584.259 8876.646 0.00 0.00 0.00 11600.000 57.316 156.193 6833.875 -8200.945 3618.233 8960.785 0.00 0.00 0.00 11700.000 57.316 156.193 6887.875 -8277 .949 3652.207 9044.924 0.00 0.00 0.00 11700.232 57.316 156.193 6888.000 -8278.128 3652.286 9045.119 0.00 0.00 0.00 BASEHRZ 11783.564 57.316 156.193 6933.000 -8342.298 3680.597 K;.1 MARKER 11800.000 57.316 156.193 6941.876 -8354.954 3686.181 11846.526 57.316 156.193 6967.000 -8390.782 3701 .988 9168.210 0.00 0.00 0.00 TOP KUPARUK 11900.000 57.316 156.193 6995.876 -8431.959 3720.155 11922.452 57.316 156.193 7008.000 -8449.247 3727.783 9232.093 0.00 0.00 LCU 11960.412 57.316 156.193 7028.499 -8478.479 3740.680 9264.033 0.00 0.00 0.00 Begin Dir @ 4.00; 11960.420'MD,7028.503'TVD 12000.000 58.884 155.932 7049.418 -8509.196 3754.317 9297.632 4.00 3.96 -0.66 12100.000 62.847 155.307 7098.095 -8588.734 3790.374 9384.952 4.00 3.96 -0.62 12161.525 65.286 154.945 7125.000 -8638.926 3813.646 9440.275 4.00 3.96 -0.59 MILUVEACH A 12200.000 66.812 154.726 7140.619 -8670.750 3828.598 9475.436 4.00 3.97 -0.57 12219.039 67.567 154.619 7148.000 -8686.613 3836.106 9492.986 4.00 3.97 -0.56 ALPINE D 12279.805 69.978 154.286 7170.000 -8737.713 3860.532 9549.624 4.00 3.97 -0.55 ALPINE C 12300.000 70.779 154.178 7176.782 -8754.844 3868.802 9568.646 4.00 3.97 -0.54 ~ 12400.000 74.748 153.656 7206.408 -8840.607 3910.790 9664.125 4.00 3.97 -0.52 3/17/2004 9:49:37AM Page 5 of 7 COMPASS 2003.5 ORIGINAL COMPASS 2003.5 OR I Gi"ÑAL 3/17/2004 9:49:37AM -0.50 -0.49 -0.48 -0.48 -0.48 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12500.000 78.718 153.153 7229.352 -8927.620 3954.358 9761.410 4.00 3.97 12600.000 82.689 152.665 7245.504 -9015.460 3999.293 9860.026 4.00 3.97 12631.000 83.920 152.515 7249.118 -9042.792 4013.467 9890.792 4.00 3.97 7" Csg Pt, Continue Dir @ 40 ·7" Csg pt @ 12631' MD 12700.000 86.660 152.184 7254.784 -9103.699 4045.377 9959.492 4.00 3.97 12758.919 89.000 151.904 7257.015 -9155.702 4072.976 10018.299 4.00 3.97 Target Heel: Begin GeoSteer¡ 12759' MD, 7257.014' TVD, (729'FNL & 2710'FEL, Sec13-T11N-R4E) - CD2-57 (Heel) 12783.998 90.003 151.904 7257.233 -9177.824 4084.786 10043.346 4.00 4.00 12800.000 90.003 151.904 7257.232 -9191.940 4092.323 10059.329 0.00 0.00 12900.000 90.003 151.904 7257.226 -9280.156 4139.418 10159.206 0.00 0.00 13000.000 90.003 151.904 7257.221 -9368.372 4186.513 10259.083 0.00 0.00 13100.000 90.003 151.904 7257.215 -9456.588 4233.608 10358.960 0.00 0.00 13200.000 90.003 151.904 7257.210 -9544.804 4280.703 10458.838 0.00 0.00 13300.000 90.003 151.904 7257.204 -9633.020 4327.798 10558.715 0.00 0.00 13400.000 90.003 151.904 7257.199 -9721.236 4374.894 10658.592 0.00 0.00 13500.000 90.003 151.904 7257.193 -9809.452 4421.989 10758.469 0.00 0.00 13600.000 90.003 151.904 7257.188 -9897.668 4469.084 10858.347 0.00 0.00 13700.000 90.003 151.904 7257.182 -9985.884 4516.179 10958.224 0.00 0.00 13800.000 90.003 151.904 7257.177 -10074.100 4563.274 11058.101 0.00 0.00 13900.000 90.003 151.904 7257.171 -10162.315 4610.369 11157.978 0.00 0.00 14000.000 90.003 151.904 7257.166 -10250.531 4657.465 11257.856 0.00 0.00 14100.000 90.003 151.904 7257.160 -10338.747 4704.560 11357.733 0.00 0.00 14200.000 90.003 151.904 7257.155 -10426.963 4751.655 11457.610 0.00 0.00 14300.000 90.003 151.904 7257.149 -10515.179 4798.750 11557.487 0.00 0.00 14400.000 90.003 151.904 7257.144 -10603.395 4845.845 11657.364 0.00 0.00 14500.000 90.003 151.904 7257.138 -10691.611 4892.940 11757.242 0.00 0.00 14600.000 90.003 151.904 7257.133 -10779.827 4940.035 11857.119 0.00 0.00 14700.000 90.003 151.904 7257.128 -10868.043 4987.131 11956.996 0.00 0.00 14800.000 90.003 151.904 7257.122 -10956.259 5034.226 12056.873 0.00 0.00 14900.000 90.003 151.904 7257.117 -11044.475 5081.321 12156.751 0.00 0.00 15000.000 90.003 151.904 7257.111 -11132.690 5128.416 12256.628 0.00 0.00 15100.000 90.003 151.904 7257.106 -11220.906 5175.511 12356.505 0.00 0.00 15200.000 90.003 151.904 7257.100 -11309.122 5222.606 12456.382 0.00 0.00 15300.000 90.003 151.904 7257.095 -11397.338 5269.702 12556.260 0.00 0.00 15400.000 90.003 151.904 7257.089 -11485.554 5316.797 12656.137 0.00 0.00 15500.000 90.003 151.904 7257.084 -11573.770 5363.892 12756.014 0.00 0.00 15600.000 90.003 151.904 7257.078 -11661.986 5410.987 12855.891 0.00 0.00 15700.000 90.003 151.904 7257.073 -11750.202 5458.082 12955.769 0.00 0.00 15800.000 90.003 151.904 7257.067 -11838.418 5505.177 13055.646 0.00 0.00 15900.000 90.003 151.904 7257.062 -11926.634 5552.272 13155.523 0.00 0.00 16000.000 90.003 151.904 7257.056 -12014.850 5599.368 13255.400 0.00 0.00 16100.000 90.003 151.904 7257.051 -12103.065 5646.463 13355.278 0.00 0.00 16200.000 90.003 151.904 7257.045 -12191.281 5693.558 13455.155 0.00 0.00 16300.000 90.003 151.904 7257.040 -12279.497 5740.653 13555.032 0.00 0.00 16400.000 90.003 151.904 7257.034 -12367.713 5787.748 13654.909 0.00 0.00 16500.000 90.003 151.904 7257.029 -12455.929 5834.843 13754.787 0.00 0.00 16600.000 90.003 151.904 7257.023 -12544.145 5881.939 13854.664 0.00 0.00 16700.000 90.003 151.904 7257.018 -12632.361 5929.034 13954.541 0.00 0.00 16758.870 90.003 151.904 7257.015 -12684.293 5956.758 14013.338 0.00 0.00 Target Toe; Open Hole: 16759' MD, 7257.015' TVD,(4259'FNL & 829'fEL, Sec13-T11N-R4E) - CD2-57 (Toe) 16800.000 90.003 151.904 7257.012 -12720.577 5976.129 14054.418 0.00 0.00 16900.000 90.003 151.904 7257.007 -12808.793 6023.224 14154.296 0.00 0.00 17000.000 90.003 151.904 7257.001 -12897.009 6070.319 14254.173 0.00 0.00 17100.000 90.003 151.904 7256.996 -12985.225 6117.414 14354.050 0.00 0.00 17200.000 90.003 151.904 7256.990 -13073.440 6164.509 14453.927 0.00 0.00 17258.870 90.003 151.904 7256.987 -13125.373 6192.234 14512.725 0.00 0.00 TO @ 17259'MD, 7256,764'TVD (4700'FNL & 594'FEL, Sec13·T11N-R4E - 6·1/8" Open Hole _.~----- .!~£1~~_'~~:'~~~C~~~~~: ¡~~: ~~t~ -~~~~t;=-C-~Ál~~~f~ True ~- ~ - - ~ - --- . - --~~~~··:~c ¡Minimum Curvature A IlALUl!llHo.'1 çœ.¡P""W SPERRY_SUN HES Planning Report spe...,.....y-sun DR I L.J...U'IInG S e R v U:.E S ~~!~c~ EOM 2003.5 Single User Ob ~~?-t,,¡ConocoPhillips Alaska Inc. (Alpine) ~± Colville River Unit ~~î~Alpine C02 ':¿~£;: Plan: C02-57 ._~~ Plan: C02-57 ;':c'-;~_ C02-57 (wp02) ~.~ Conoc;p¡,illips Conoc;p.,illips -~ SPERRY_SUN HES Planning Report ,-,,' spe"""""v-sun DRILLING seRVIc:es A IlALLllIliRTON COMP,,"'W >".~'~" .-....-_- -, =C~'"'-""''''''''''7''~ ____..-7-:;......,._."'~-.. ~ "'__'"0'7 . ,._~_...... -__......"'" .-.'~,,",,-.~ ':7 .-.-' .~-~'_~--'--~.o.Y_.~,c:.~'?;;_.'-=-"~~,,"~~~~-'=o~~:='-~-~-,"=~~~~~~~~~~~~~-=--,,<-~~_~~_"-,",::'_,=~~~~~-=---=~~--,=",-~ :-:! :;;-..: :t:-,.'-7i>:,J-~'':;-;o....:z::-,'~ .:'.__':......j.'. EDM 2003.5 Single User Db ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine CD2 Plan: CD2-57 Plan: CD2-57 : CD2-57 (wp02) ~:;.: .:.~:: 7_~ _.'-~'-:",.-;_._~; ~~:, -:r~: ',~ D~·::~~:~T;_-':;-.-: ,! ~rõ- ({~? I--" Well Plan:CD2-57 52'MSL@-52,OOOft(52'MSL) !)2'MSL@c52;00Oft (52' MSL) True Minimum Curvature f _'"-. ':J~- ~ _ 1:.~:" _ ....,.:,- _ --:_-..~-;~.:.,,-- .".,;:-" > -'--i, ·1....-,. .-_.... ._: r- :,:-;......: ~ --. II:lr%~;*~f:£;8$1'~~~i~~fí:~(~2it;~*itr~~1~1t~~é~f'~i~~~0~4fJil~5~,- 3370.686 2390.005 9 5/8" Csg Pt @ 3377'MD 9.625 12.250 12631.025 7249.121 7" Csg Pt @ 12631' MD 7.000 8.500 17258.860 7256.987 6-1/8" Open Hole 6.125 6.125 ~..-;~£~~ ~ '.~~-'~~~~:~:i&\~:~::~~:;;'~:~-~~---'-~-Y<?)A':~<~~~t~-~;~ - ~f~"èi~~t'%;'1~f!~~iffi;;fl(~rh~r;~1:,j1'~~NàTr,,-p·é7i;~\l;~~~~{1Wtst;~~;~W£:~~Jÿf°r; 3015.125 2198.000 C-40 0.00 3389.196 2400.000 C-30 0.00 4072.523 2769.000 C-20 0.00 6041.024 3832.000 K-3 MARKER 0.00 6403.983 4028.000 BASAL K-3 SS 0.00 6455.835 4056.000 K-2 MARKER 0.00 6646.574 4159.000 BASE K-2 SEQUENCE 0.00 9455.807 5676.000 ALBIAN 97 0.00 {"úc,' AbOVIl. 10381.725 6176.000 ALBIAN 96 0.00 11392.827 6722.000 TOP HRZ 0.00 11700.232 6888.000 BASE HRZ 0.00 11783.564 6933.000 K-1 MARKER 0.00 11846.526 6967.000 TOP KUPARUK 0.00 11922.452 7008.000 LCU 0.00 12161.525 7125.000 MILUVEACH A 0.00 12219.039 7148.000 ALPINE D 0.00 12279.805 7170.000 ALPINE C 0.00 ~~~~~r.~E,¡:;'-' :,-, --:::'-1:" .- ::vEì~ìdl' ; D~ptii '(ft). 36.100 300.000 1505.594 2390.005 7028.503 7249.118 7257.014 7257.015 7256.987 ;-" OF _ _ I ¡ I I I I l__. c:c~t~:!!;;{Mí~~û."rð~ - ".~~~' -c ' '. _.&~~~~::h· 36.100 300.000 1732.904 3370.686 11960.420 12631.000 12758.919 16758.870 17258.860 >,~2~¡ç~' .... +N/:.s-')~lj;} C (fileS ---- 0.000 0.000 -602.831 -1863.998 -8478.485 -9042.792 -9155.702 -12684.293 -13125.364 0.000 0.000 265.967 822.390 3740.682 4013.467 4072.976 5956.758 6192.230 SHL (2132' FNL & 1494' FEL, Sec2-T11N-R4E Begin Dir @ 4°; 300'MD, 300'TVD End Dir, Start Sail @ 57.316; 1732.904' MD, 1505.594' TVD 9-5/8" Cst Pt @ 3370'MD, 2390'TVD Begin Dir @ 4.00; 11960.420'MD,7028.503'TVD 7" Csg Pt, Continue Dir @ 40 Target Heel: Begin GeoSteer; 12759' MD, 7257.014' TVD, (729'FNL &: Target Toe; Open Hole: 16759' MD, 7257.015' TVD, (4259'FNL & 829'F TD @ 17259'MD, 7256.764'TVD (4700'FNL & 594'FEL, Sec13-T11N-R 3/17/2004 9:49:37AM Page 7 of 7 COMPASS 2003.5 ORIGfNAL Nlln~ iN/·S l..ol¡p;iwk +¡:).\\' NOrUUJ!f\ EllilIÌlIJI, ."iI.J~ .c.('7,.~:!·!,2(,O 'nI7,10,."i~O 70":',0'1(0,12HN ],"iI"02'::!(,,:'õIWW NI,\ Interpolation Method:MD Depth Range From: 36. JO Maximum Range: 1922.27 SURVEY PROGRAM Depth Fm Depth To SurveyIPan Tool :16.10 lOOO.OO Planned: CD2-57 (wp02) V7 1000.00 17258.84 Planned: CD2-57 (wp02) V7 CB-GYRO-SS MWO+IFR-AK-CAZ-SC o CD2-51 (C02-51) CD2 -.52 (CD 2-52) 100 96 ···}2 G' '';1 3 u g e: \D -48 ";1 3 u ~ il: ····12 '96 100 ~~-'·-·----96-·-·--~""'~· 150 180 SEC..'IJON m,T AILS Sl~t: MD I lie Azj TVD +N/-S +E/-W DLcg TFace VSec Target 36.10 0.000 0.000 36.10 0.00 0.00 0.00 0.000 0.00 300.00 0.000 0.000 300.00 0.00 0.00 0.00 0.000 0.00 1732.90 57.316 156.193 1505.59 -602.83 265.97 4.00 0.000 658.68 11960.39 57.316 156.193 7028.49 -8478.44 3740.73 0.00 0.000 9264.02 12758.89 89.000 151.'X)4 7257.00 -9155.65 4073.03 4.00 -8.126 10018.28 CO2-57 (Heel) 12783.97 90.003 151.904 7257.22 -9171. 78 4084.84 4.00 0.000 10043.33 16758.84 90.003 151.904 7257.00 - 12684. 23 5956.84 0.00 0.000 t4û13.31 CD2-57 (Toe) 17258.84 90.003 151.904 7256. 97 -13125.30 6192.31 0.00 0.000 14512.70 'l'ravelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [ft] --- ANTI-COLLISION SETTINGS ConocoPfü&p!:. AlLdc.I Inc. En¡jncerin~ ~m COO-57 RÎ!:: Doyon 19 Rd Dobun: 52' MSL 52.001\ V.scclion ~~ .?FJ~ ~~ An~1c 154.743" 0.00 0.00 36.10 Interval: 50.00 To: 17258.84 Rctèrcnce: Plan: CD2-:57 (wp02) C.lcu..tion Mdhod: MìnØmrm Cwvalt.l:æ == ¥~;~crNorth w'=;=.f: ~~~L'~ Colour ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 II 000 12000 13000 Scanned from Surface to TD 0.7 '20.0 ToMD 3ar 4( 50--. 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 1??oo 10500 11000 12000 13000 Colour '-'15.0 10.0 90 Plan: C02-56 (PI : C02-56) 5.0 o 27 5.0 10.0 15.0 -'20.0 ZO.7 Travelling Cylinder Azinroth (TFO+AZI) [deg] vs Centre to Centre Separation [IOft/in] CD2-57 (wp02) Approved Plan '~Tlalliburton Sperry-SUD \.-- Anticollision Report ~ 4'"'\Y-SI...n D..ILLfNCS ....VIC.. <A. k\UlK.1{J'UI( ~.\.~ . ConocoPhillipsAlæka Inc. Colville River Unit Alpine CD2 Plan: C02~7 . CD2-57 - - - -- - - ------- - - -.- - -- --- -- - - -- -- ---- -- -- - --- - - ,- - - --- - - - - - - - - -- - --- WJâ,f¡lf¿.··~."é~~~t[~lI~i~~i1m.~¿;~~ê.i.·.b.f-.~.[.;.~.. ...... ...-- :-. . .-- - -.-- -- -- - -- --.-- - - - - - - - - - -- - - - - - - -- - ~--- - -- --- - - - - --- GLOBAL SCAN APPLIED: All well paths witlùn 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 36.10 to 17258.84 ft Maximum Radius: 1922.27 ft . - . . -- - - ~---- - - -~ -- - - - - - --- ~-- - - - - - --- - -- o:~ .·c-~~~~!m1ß'@l&ê1t~:j;·..·~~~W.ejl~'~JMl~,,~"1~~qrû~1J(tttF"~{~~~~i~.~~:c·~ -~4X[tflCítr~1~Rjiíè!..I~1~.:~·--º~;M§I3~Ä~~~~~:~:;F~~=J:-~:!it~~:i=~-' - - -_ - ~ _ ~ u_ -. ~--_-- =~ ~=~-- - .:::.::~~~ -=~~Æ~;~~~1-cc~~j!b:-=~ºrfÁÇf~:~fr~i Reference: Error Model: Scan Method: Error Surface: Plan: CD2-57 (wp02) & NOT PLANNED P ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD ft" ft 3370.68 2390.00 9 5/8" Csg Pt @ 3377'MO 12631.00 7249.11 7" Csg Pt @ 12631' MO 17258.84 7256.97 6-1/8" Open Hole Plan: C02-57 (wp02) Date Composed: 3/12/2004 Version: 7 Principal: Yes Tied-to: From Well Ref. Point Sununary .<- - - Offset WeUpath . Site· Well Alpine CO2 CD2-27 CD2-27 V6 424.66 450.00 292.94 8.32 284.61 Pass: Major Risk Alpine CD2 CD2-34 C02-34 V3 200.09 200.00 230.43 No Offset Errors Alpine CO2 CD2-34 CD2-34PB1 V2 250.07 250.00 231.37 5.10 226.28 Pass: Major Risk Alpine CD2 CD2-35 CD2-35 V1 311.62 300.00 218.83 5.48 213.35 Pass: Major Risk Alpine CD2 C02-35 C02-35A V1 342.99 350.00 219.25 5.71 213.54 Pass: Major Risk Alpine CD2 C02-36 CD2-36 Lat 1 V1 Plan: 387.47 400.00 209.09 6.60 202.50 Pass: Major Risk Alpine CD2 CD2-36 CD2-36 Lat 2 V1 Plan: 387.47 400.00 209.09 6.60 202.50 Pass: Major Risk Alpine CD2 CD2-36 CD2-36 Lat 3 V2 Plan: 387.47 400.00 209.09 6.60 202.50 Pass: Major Risk Alpine CD2 C02-36 C02-36 Lat 4 V1 Plan: 387.47 400.00 209.09 6.60 202.50 Pass: Major Risk Alpine CD2 CD2-36 CD2-36 PB1 V5 387.47 400.00 209.09 No Offset Errors Alpine CD2 CD2-36 CD2-36 V5 387.47 400.00 209.09 No Offset Errors Alpine CD2 C02-37 C02-37 Lat 1 V2 Plan: 299.42 300.00 199.42 5.81 193.61 Pass: Major Risk Alpine CD2 CD2-37 C02-37 Lat 2 V1 Plan: 299.42 300.00 199.42 5.81 193.61 Pass: Major Risk Alpine CD2 CD2-37 C02-37 Lat 3 V1 Plan: 299.42 300.00 199.42 5.81 193.61 Pass: Major Risk Alpine CD2 C02-37 C02-37 V16 299.42 300.00 199.42 No Offset Errors Alpine CD2 CD2-38 C02-38 (Sag) VO 343.93 350.00 189.61 5.64 183.97 Pass: Major Risk Alpine CD2 CD2-38 CD2-38 V5 343.93 350.00 189.61 5.90 183.71 Pass: Major Risk Alpine CD2 CD2-39 CD2-39 V1 389.33 400.00 176.83 No Offset Errors Alpine CD2 CD2-39 CD2-39PB1 VO 388.53 400.00 176.82 6.32 170.50 Pass: Major Risk Alpine CD2 CD2-4O CD2-40 V7 299.60 300.00 169.41 5.27 164.14 Pass: Major Risk Alpine CD2 CD2-40 CD2-4OPB1 V9 299.60 300.00 169.41 5.27 164.14 Pass: Major Risk Alpine CD2 CD2-41 CD2-41 V9 299.74 300.00 157.80 No Offset Errors Alpine CO2 CD2-42 CD2-42 VO 299.95 300.00 149.80 No Offset Errors Alpine CD2 CD2-42 CD2-42PB1 VO 345.39 350.00 150.31 5.60 144.72 Pass: Major Risk Alpine CD2 CD2-43 CD2-43 (Sag) VO 299.14 300.00 141.07 5.29 135.78 Pass: Major Risk Alpine CD2 CD2-43 CD2·43 V8 299.14 300.00 141.07 5.69 135.38 Pass: Major Risk Alpine CD2 CD2-43 CD2-43PB1 (Sag) VO 299.14 300.00 141 .07 5.29 135.78 Pass: Major Risk Alpine CD2 CD2-43 CD2-43PB1 V8 299.14 300.00 141 .07 5.69 135.38 Pass: Major Risk Alpine CD2 CD2-44 CD2-44 V15 299.50 300.00 130.00 5.61 124.39 Pass: Major Risk Alpine CD2 CD2-45 CD2-45 V5 345.59 350.00 121.55 No Offset Errors Alpine CD2 CD2-46 CD2-46 V2 299.39 300.00 109.53 5.10 104.44 Pass: Major Risk Alpine CD2 CD2-47 CD2-47 V2 346.25 350.00 99.76 5.81 93.95 Pass: Major Risk Alpine CD2 CD2-48 CD2-48 V1 299.75 300.00 90.02 No Offset Errors Alpine CD2 CD2-49 CD2-49 V1 346.78 350.00 77.78 5.72 72.06 Pass: Major Risk Alpine CO2 CD2-50 CD2-SO V2 299.57 300.00 70.69 No Offset Errors Alpine CD2 CD2-50 CD2-50PB1 V2 299.57 300.00 70.69 5.95 64.74 Pass: Major Risk Alpine CD2 CD2-51 C02-51 V8 299.96 300.00 61.81 6.21 55.60 Pass: Major Risk Alpine CD2 CD2-52 CD2-52 V6 396.48 400.00 46.59 7.54 39.05 Pass: Major Risk Alpine CO2 CD2-55 C02-55 V5 348.92 350.00 16.84 6.35 10.49 Pass: Major Risk Alpine CO2 CD2-58 C02-58 V10 854.55 850.00 18.18 14.90 3.28 Pass: Major Risk Alpine CD2 CO2-58 C02-58L 1 V4 854.55 850.00 18.18 14.79 3.39 Pass: Major Risk Alpine CD2 Plan: CD2-54 Plan: CD2-54 VO Plan: 348.73 350.00 29.47 6.15 23.32 Pass: Major Risk Alpine CD2 Plan: CD2-56 Plan: CD2-56 VO Plan: 299.92 300.00 9.13 5.50 3.63 Pass: Major Risk Alpine CD2 Prelim: CD2-53 C02-53 VO Plan: CO2-53 348.69 350.00 40.27 6.90 33.36 Pass: Major Risk Alpine Satellite Nan N-16 N-16 VO Plan: Prelim: Out of range Alpine Satellite Nan N-17 N-17 VO Plan: Prelim: 16924.57 10850.00 1132.59 177.99 954.60 Pass: Major Risk ORIGINAL Halliburton Sperry-Sun Anticollision Report sper"""y-SLr1 ~~I~~INm ....VIC.. .\. k\U.l"'1I:I1k'\. ,-~.,,"'\ €OIJl¡jifli:; . Ffe.I:a: ·Cc. 0 lW~er!~è·ª!te:. . ·Refe1".~eFe!: ~Rèfi!rence Wellpáth: ConOQ()EþHlipsj\laSkah1C. c..~ : CoIVilleRlyer UrHt AlpineCÖ2 -Plan: CD2-57 CD2-57 - - - . - --". - - . - - __ .'_ __.. - - - - 0- -- -. - --- . _. ..- - -- - -- - ..-- - - - ~~=:,.éº~"râínate(NEHtêfe¡,e~=-:;c- . Well: Plårt~Óº~"s7,,;rrYeNOI"tti~~ ·<Wetûcål[('l'yDJRerere~f '-~ ,52'~MSt.52.0- ~--- n c- TUìiet ~JO:OO;32~o - ···~·-(~ate:~< 3117/2004 , ..P11g~:_~~c._Z. - I!tif~~Qi~le-: OftšetWellpatll· -:'--~~.--"'~:'".;..:.:;...-> Wéll _u'~~llpath ~RefereÎlce: ()ffs~f 'Ctt--Qtt: N°-GO -@º~!!_ MD ;Mî>I)istan~eArea: "Ueviªtf¡tn'\Yåfitiilg -ft; ft__,,~~~ft-ft ft_~- - Alpine Satellite Nan Alpine Satellites NK-2 Nanuq 3 NK-2 VO Plan: Prelim: NQ-16 VO Plan: NQ-16 V Out of range Out of range o R I GI NAL Plan: CD2-57 (wp02) (Plan: CD2-57/CD2-57) 36. 34. 32. 30. 28. 26. 24. ~ ¡:: 22. .S ...... Q 20. ~ 18. --.!;;i. uS· 16. -... :2! 14. :J> r 12. 8. I I I I I ~----f----f--_·---i : i i i I I I I j : ---+----~---..·i---..·--I_--·-+_ I I I I I I I I! I I I I : I +--1 ! I I I i I I! i! '.....] I , I , I jJ==I~:1i-I-I--li---1 I I I I I I~-H-- I I I I I I I -1-"---+---'1-f---~--+- I I. .. I I I I I I I·! II II-I----¡--!-j----¡-¡-t . I +_.._+_._--~ . I I I I o. I I I I ··..1··· i -+ I I I i I +- I I I I +-t--~-11-- I I I I I I ··..1..·........-¡-····1·..........1·· I I I I i I-~·--+- -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 Measured Depth [ft] C02-27 (C02-27) C02-36 (C02-36 Lat 2) C02-37 (C02-37 Lat 2) C02-39 (C02-39PB 1) C02-43 (C02-43 (Sag» C02-46 (C02-46) CO2-51 (C02-51) Plan: CO2-56 (plan: C02-56) C02-34 (C02-34) C02-36 (C02-36 Lat 3) C02-37 (C02-37 Lat 3) C02-40 (C02-40) C02-43 (C02-43) C02-47 (C02-47) C02-52 (C02-52) Prelim: C02-53 (C02-53) C02-34 (C02-34PB 1) C02-36 (C02-36 Lat 4) C02-37 (C02-37) C02-40 (C02-40PB 1) C02-43 (C02-43PB 1 (Sag» C02-48 (C02-48) C02-55 (C02-55) N-16 (N-16) C02-35 (C02-35) C02-36 (C02-36 PBI) C02-38 (C02-38 (Sag» C02-41 (C02-41) C02-43 (C02-43PB 1) C02-49 (C02-49) C02-58 (C02-58) N-17 (N-17) C02-35 (C02-35A) C02-36 (C02-36) C02-38 (C02-38) C02-42 (C02-42) C02-44 (C02-44) C02-50 (C02-50) C02-58 (C02-58L1) NK-2 (NK-2) C02-36 (C02-36 Lat 1) C02-37 (C02-37 Lat 1) C02-39 (C02-39) C02-42 (C02-42PB 1) C02-45 (C02-45) C02-50 (C02-50PBl) Plan: C02-54 (Plan: CO2-54) Nanuq 3 (NQ-16) GEOLOGIC SUMMARY: CD2-57 arget 1 : Horizontal Well Resp: Steve Moothart - 6965 iii Complete prererrea Formatio Z Tar. n X Y (TVD.SS) Porosity Perm Net Pay Angle Within Alpine C Heel Targe 375,656 5,965,001 7,150' 0.18 6 75 Toe Target 377,707 5,960,996 7,200' 18.00 3 10 et Shape: Rectagular box 100' either side of wellbore in the Approx -14600 horizontal plane Ste 00 ut: Remarks: WP-02 l Geologic progno Responsible: Steve Moothart - 6965 iii Complete Formatio X Y Z MD Gross Net Pay Net to n (TVD.SS) Thicknes Gross s C-40 2,146' C-30 2,348' C-20 2,717' K-3 MARKER 3,780' BASAL K-3 SS 3,976' K-2 MARKER 4,004' BASE K-2 SEQUENCE 4,107' ALBIAN 97 5,624' ALBIAN 96 6,142' TOP HRZ I 6,670' BASE HRZ 6,836' K-1 MARKER 6,881' TOP KUPARUK 6,915' LCU I 6,956' MILUVEACH A 7,073' ALPINE D I 7,096' ALPINE C 7.118' Target Within Alpine C Interval 7,150' 95 75 Alpine C Above Target 7,125' I Base Alpine Below Target 7,220' Remarks:1 Geologic Discussion: Responsible: Steve Moothart· 6965 PI Complete CD2-57 is being drilled as the offset injector to the east of producer CD2-58. The most critical risk in the wellbore is reservoir quality. The Alpine C sands begin to thin and shale out to the south. This is evident in the offset wells C02-58 and C02-27. The wellbore does not cross any known mapped faults. but three areas are flagged as potential areas of faults. The first is at -13900' md which may have a small «10ft) down to the north fault. The second is at -14850' md, which may be a small «20 ft) down to the south fault. The third is at -15450' md which may be a small «10ft) down to the north fault. All three potential faults are at the limits of seismic detection. Care should be taken when approaching these areas as drilling fluid loses may occur in fault zones Shallow Intervals: K3/K2; Thin sands may be present in basal portion of the K3 and top of K2 intervals (3970'-4100' sstvd). Nanuq; The offset well C02-58 did not have reservoir quality sand in the Nanuq interval but sands do begin to develop to the east. Care should be taken when drilling into the top of this interval (Albian 96 need to be isolated by the 7" casing cement. The well will be landed by the geologist in town é wellsite geologists will steer the horizontal sectíon from the rig. iii ORIGINAL .Halliburton Sperry -Sun .~. GeoReport spe!I .'y-sun D"ILL.NO .B"Vlce. "'- Kuua.roo.¡:~W ConocoPhillips Alaska Inc. Colville River Unit AlpjneC02 Plan: C02-57 C02-57 Cömpany: 'Field: Site: WeD: 'WeUpath: I S~'Y' Company: Tool: Survey MD ft 36.10 100.00 200.00 300.00 400.00 Incl deg 0.000 0.000 0.000 0.000 4.000 500.00 8.000 600.00 12.000 700.00 16.000 800.00 20.000 900.00 24.000 1000.00 28.000 1100.00 32.000 1200.00 36.000 1300.00 40.000 1400.00 44.000 1500.00 48.000 1600.00 52.000 1700.00 56.000 1732.90 57.316 1800.00 57.316 1900.00 57.316 2000.00 57.316 2100.00 57.316 2200.00 57.316 2300.00 57.316 2400.00 57.316 2500.00 57.316 2600.00 57.316 2700.00 57.316 2800.00 57.316 2900.00 57.316 3000.00 57.316 3015.13 57.316 3100.00 57.316 3200.00 57.316 3300.00 57.316 3370.68 57.316 3389.20 57.316 3400.00 57.316 3500.00 57.316 3600.00 57.316 3700.00 57.316 3800.00 57.316 3900.00 57.316 4000.00 57.316 4072.52 57.316 4100.00 57.316 4200.00 57.316 4300.00 57.316 Azim deg 0.000 0.000 0.000 0.000 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 TVD ft 36.10 100.00 200.00 300.00 399.92 499.35 597.81 694.82 789.91 882.61 972.47 1059.05 1141.94 1220.73 1295.02 1364.48 1428.74 1487.51 1505.59 1541.83 1595.83 1649.83 1703.83 1757.83 1811 .83 1865.83 1919.83 1973.83 2027.83 2081 .83 Sys TV» ft -15.90 48.00 148.00 248.00 347.92 447.35 545.81 642.82 737.91 830.61 920.47 1007.05 1089.94 1168.73 1243.02 1312.48 1376.74 1435.51 1453.59 1489.83 1543.83 1597.83 1651.83 1705.83 1759.83 1813.83 1867.83 1921 .83 1975.83 2029.83 2135.83 2083.83 2189.83 2137.83 2198.00 2146.00 2243.83 2191.83 2297.83 2245.83 2351.83 2390.00 2400.00 2405.83 2459.83 2513.83 2567.83 2621 .84 2675.84 2729.84 2769.00 2783.84 2837.84 2891 .84 2299.83 2338.00 2348.00 2353.83 2407.83 2461 .83 2515.83 2569.84 2623.84 2677 .84 2717.00 2731.84 2785.84 2839.84 0.00 0.00 0.00 0.00 -3.19 -12.75 -28.64 -50.77 -79.03 -113.30 -153.40 -199.13 -250.28 -306.60 -367.81 -433.61 -503.68 -577 .68 -602.83 -654.50 -731 .50 -808.51 -885.51 -962.51 -1039.52 -1116.52 -1193.53 -1270.53 -1347.54 -1424.54 -1501.54 -1578.55 -1590.20 -1655.55 -1732.56 -1809.56 -1863.99 -1878.25 -1886.57 -1963.57 -2040.57 -2117.58 -2194.58 -2271.59 -2348.59 -2404.44 -2425.60 -2502.60 -2579.60 Start Date: Engineer: Tied-to: 5.63 12.64 22.40 34.87 49.99 67.68 87.86 110.43 135.27 162.28 191.31 222.23 254.88 265.97 288.77 322.74 356.72 390.69 424.67 458.64 492.62 526.59 560.57 594.54 628.52 662.49 696.46 701.60 730.44 764.41 798.39 822.40 828.69 832.36 866.34 900.31 934.29 968.26 1002.24 1036.21 1060.85 1070.19 1104.16 1138.14 0.00 0.00 0.00 0.00 1.41 5974224.260 5974224.260 5974224.260 5974224.260 5974221.044 5974211.413 5974195.413 5974173.122 5974144.648 5974110.131 5974069.739 5974023.668 5973972.143 5973915.415 5973853.761 5973787.479 5973716.895 5973642.351 5973617.020 5973564.973 5973487.405 5973409.837 5973332.269 5973254.702 5973177.134 5973099.566 5973021.998 5972944.430 5972866.862 5972789.294 5972711.727 5972634.159 5972622.425 5972556.591 5972479.023 5972401.455 5972346.631 5972332.267 5972323.887 5972246.319 5972168.751 5972091.184 5972013.616 5971936.048 5971858.480 5971802.224 5971780.912 5971703.344 5971625.776 ORIGINAL 371740.550 SHL (2132' FNL & 1494'FEL, 371740.550 371740.550 371740.550 Begin Dir @ 4°; 300'MD, 30 371741.904 371745.958 371752.692 371762.075 371774.060 371788.589 371805.591 371824.983 371846.671 371870.549 371896.501 371924.400 371954.111 371985.488 371996.150 End Dir, Start Sail @ 57°; 372018.058 372050.708 372083.358 372116.008 372148.658 372181.308 372213.958 372246.608 372279.258 372311.908 372344.558 372377.208 372409.858 372414.797 C-40 372442.508 372475.158 372507.808 372530.885 9 5/8" Csg Pt @ 3377'MD 372536.931 C-30 372540.458 372573.108 372605.758 372638.408 372671.058 372703.708 372736.358 372760.037 C-20 372769.008 372801.658 372834.308 Halliburton Sperry-Sun GeoReport ···ç<iIi1ÞS!1y:CbrtóCoRliillipsAlaskðJno. ~Field: -COtvilleffiiVef Unit ~Sile: AIpinéCD2 -,-W@=-~ PIan:eD2-57 ~Weßpath: ··OD2-57 5pBI 'l'""'Y-su-1 DI'UL.L.INEI .....VIC.. A kU.ua.tu"'L ~.'"''\. - - Date:--:3Itil2.Q04- TiI1íè(-op:~.:ä4~?-~_- -. ..~_ -t~l'agef' c-L-'·2 -#9;-.Qrdina~)IRefér~nce:· ... - Wéll:P-L~J_ÇQ~57.:,::"'l'1iè North~~, _-~~~~ffi-~~cryµl-~e~er~:nçe: - ~ ~_9~~~M~µ-p~P:~~:--___-_ _O-~-~:~~- -~=--~--,---<~~:-~:_- -SeCtiQn(VS)Ret~ie-riCe: Well(O.QON¡p·cOOE.l54774Mr=-- ... n _ Sii!veyC8IcuJå1i(hlMethOd: MinimumClllVªhJre > -:~ Db:.-Ofacrè Survey MD - ·-.··ft::c- 4400.00 4500.00 57.316 4600.00 57.316 4700.00 57.316 4800.00 57.316 4900.00 57.316 5000.00 57.316 5100.00 57.316 5200.00 57.316 5300.00 57.316 5400.00 57.316 5500.00 57.316 5600.00 57.316 5700.00 57.316 5800.00 57.316 5900.00 57.316 6000.00 57.316 6041.03 57.316 6100.00 57.316 6200.00 57.316 6300.00 57.316 6400.00 57.316 6403.99 57.316 6455.84 57.316 6500.00 57.316 6600.00 57.316 6646.58 57.316 6700.00 57.316 6800.00 57.316 6900.00 57.316 7000.00 57.316 7100.00 57.316 7200.00 57.316 7300.00 57.316 7400.00 57.316 7500.00 57.316 7600.00 57.316 7700.00 57.316 7800.00 57.316 7900.00 57.316 8000.00 57.316 8100.00 57.316 8200.00 57.316 8300.00 57.316 8400.00 57.316 8500.00 57.316 8600.00 57.316 8700.00 57.316 8800.00 57.316 8900.00 57.316 9000.00 57.316 AZifu ~deQ 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 TVD SysTYD <>ff C ft 2945.84 2893.84 2999.84 2947.84 3053.84 3001 .84 3107.84 3055.84 3161.84 3109.84 3215.84 3163.84 3269.84 3323.84 3377 .84 3431.84 3485.84 3539.84 3593.84 3647.84 3701 .85 3755.85 3809.85 3832.00 3863.85 3917.85 3971 .85 4025.85 4028.00 4056.00 4079.85 4133.85 4159.00 4187.85 4241 .85 4295.85 4349.85 4403.85 4457.85 4511.85 4565.85 4619.85 4673.85 4727.85 4781.85 4835.86 4889.86 4943.86 4997.86 5051.86 5105.86 5159.86 5213.86 5267.86 5321 .86 5375.86 5429.86 3217.84 3271 .84 3325.84 3379.84 3433.84 3487.84 3541 .84 3595.84 3649.85 3703.85 3757.85 3780.00 3811.85 3865.85 3919.85 3973.85 3976.00 4004.00 4027.85 4081.85 4107.00 4135.85 4189.85 4243.85 4297.85 4351 .85 4405.85 4459.85 4513.85 4567.85 4621 .85 4675.85 4729.85 4783.86 4837.86 4891 .86 4945.86 4999.86 5053.86 5107.86 5161.86 5215.86 5269.86 5323.86 5377.86 NIS JC -2656.61 -2733.61 -2810.62 -2887.62 -2964.63 -3041 .63 -3118.64 -3195.64 -3272.64 -3349.65 -3426.65 -3503.66 -3580.66 -3657.67 -3734.67 -3811.67 -3888.68 -3920.27 -3965.68 -4042.69 -4119.69 -4196.70 -4199.76 -4239.69 -4273.70 -4350.70 -4386.57 -4427.71 -4504.71 -4581.72 -4658.72 -4735.73 -4812.73 -4889.73 -4966.74 -5043.74 -5120.75 -5197.75 -5274.76 -5351.76 -5428.76 -5505.77 -5582.77 -5659.78 -5736.78 -5813.79 -5890.79 -5967.79 -6044.80 -6121 .80 -6198.81 9100.00 57.316 156.193 5483.86 5431.86 -6275.81 F.JW ·c ft, 1172.11 1206.09 1240.06 1274.04 1308.01 1341.99 1375.96 1409.93 1443.91 1477.88 1511.86 1545.83 1579.81 1613.78 1647.76 1681.73 1715.71 1729.65 1749.68 1783.66 1817.63 1851.61 1852.96 1870.58 1885.58 1919.56 1935.38 1953.53 1987.51 2021.48 2055.45 2089.43 2123.40 2157.38 2191.35 2225.33 2259.30 2293.28 2327.25 2361 .23 2395.20 2429.18 2463.15 2497.13 2531 .1 0 2565.08 2599.05 2633.03 2667.00 2700.97 2734.95 2768.92 'MapN ·ft..c 5971548.209 5971470.641 5971393.073 5971315.505 5971237.937 5971160.369 5971082.801 5971005.234 5970927.666 5970850.098 5970772.530 5970694.962 5970617.394 5970539.826 5970462.259 5970384.691 5970307.123 5970275.300 5970229.555 5970151.987 5970074.419 5969996.851 5969993.760 5969953.540 5969919.283 5969841.716 5969805.588 5969764.148 5969686.580 5969609.012 5969531.444 5969453.876 5969376.308 5969298.741 5969221.173 5969143.605 5969066.037 5968988.469 5968910.901 5968833.333 5968755.766 5968678.198 5968600.630 5968523.062 5968445.494 5968367.926 5968290.358 5968212.791 5968135.223 5968057.655 5967980.087 5967902.519 ORIGINAL 372866.958 372899.608 372932.258 372964.908 372997.558 373030.208 373062.858 373095.508 373128.158 373160.808 373193.458 373226.108 373258.758 373291.408 373324.058 373356.708 373389.358 373402.753 K-3 MARKER 373422.008 373454.658 373487.308 373519.958 373521.259 BASAL K-3 SS 373538.189 K-2 MARKER 373552.608 373585.258 373600.465 BASE K-2 SEQUENCE 373617.908 373650.558 373683.208 373715.858 373748.508 373781.158 373813.808 373846.458 373879.108 373911.758 373944.408 373977.058 374009.708 374042.358 374075.008 374107.658 374140.308 374172.958 374205.608 374238.258 374270.908 374303.558 374336.208 374368.858 374401.508 lIalliburtoD Sperry-SUD '--' GeoReport spell "'Y-SLn aRILLINII .-."VIC.. "'Ku...ua.~~....'\' Company: ConocoPhllllps Alaska Inc. F1eld: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-57 weUpath: CD2-57 Survey MD ft 9200.00 9300.00 9400.00 9455.81 Incl deg 57.316 57.316 57.316 57.316 9500.00 57.316 9600.00 57.316 9700.00 57.316 9800.00 57.316 9900.00 57.316 1??oo.00 57.316 10100.00 57.316 10200.00 57.316 10300.00 57.316 10381.73 57.316 10400.00 57.316 10500.00 57.316 10600.00 57.316 10700.00 57.316 10800.00 57.316 10900.00 57.316 11000.00 57.316 11100.00 57.316 11200.00 57.316 11300.00 57.316 11392.83 57.316 11400.00 57.316 11500.00 57.316 11600.00 57.316 11700.00 57.316 11700.23 57.316 11783.57 57.316 11800.00 57.316 11846.53 57.316 11900.00 57.316 11922.45 57.316 11960.39 57.316 12000.00 58.885 12100.00 62.847 12161.53 65.287 12200.00 66.813 12219.05 67.568 12279.82 69.979 12300.00 70.780 12400.00 74.749 12500.00 78.719 12600.00 82.690 12631.00 83.921 12700.00 86.661 12758.89 89.000 12783.97 90.003 12800.00 90.003 12900.00 90.003 13000.00 90.003 Azim deg 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 156.193 155.931 155.307 154.945 154.726 154.619 154.286 154.178 153.656 153.153 152.664 152.515 152.184 151.904 151.904 151.904 151.904 151.904 -c-:,.·Datet.i~Æ3117)2004.-. : ~_ _.. ~.~ --- . - - - - - ----- - -- ----------. --- - ~ - -- - - - -- - - - ---- - ---- - - ----- .-:~la41i~! -··~·~1ý~~~n-~ètlio(JI~~~~ TVD ft 5537.86 5485.86 5591.86 5539.86 5645.86 5593.86 5676.00 5624.00 5699.86 5647.86 5753.86 5701.86 5807.86 5755.86 5861.86 5809.86 5915.86 5863.86 5969.87 5917.87 6023.87 5971.87 6077 .87 6025.87 6131.87 6079.87 6176.00 6124.00 6185.87 6133.87 6239.87 6187.87 6293.87 6241.87 6347.87 6295.87 6401.87 6349.87 6455.87 6403.87 6509.87 6457.87 6563.87 6511.87 6617.87 6565.87 6671.87 6619.87 6722.00 6670.00 6725.87 6673.87 6779.87 6727.87 6833.87 6781.87 6887.87 6835.87 6888.00 6836.00 6933.00 6881.00 6941.87 6889.87 6967.00 6915.00 6995.87 6943.87 7008.00 6956.00 7028.49 6976.49 7049.42 6997.42 7098.09 7046.09 7125.00 7073.00 7140.61 7088.61 7148.00 7096.00 7170.00 7118.00 7176.78 7124.78 7206.40 7154.40 7229.34 7177.34 7245.49 7193.49 7249.11 7197.11 7254.77 7202.77 7257.00 7205.00 7257.22 7205.22 7257.22 7205.22 7257.21 7205.21 7257.21 7205.21 -6352.82 -6429.82 -6506.82 -6549.80 -6583.83 -6660.83 -6737.84 -6814.84 -6891 .85 -6968.85 -7045.86 -7122.86 -7199.86 -7262.80 -7276.87 -7353.87 -7430.88 -7507.88 -7584.89 -7661.89 -7738.89 -7815.90 -7892.90 -7969.91 -8041.39 -8046.91 -8123.92 -8200.92 -8277.92 -8278.10 -8342.27 -8354.93 -8390.76 -8431.93 -8449.22 -8478.44 -8509.17 -8588.71 -8638.91 -8670.72 -8686.60 -8737.70 -8754.82 -8840.58 -8927.60 -9015.44 -9042.77 -9103.67 -9155.65 -9177 .78 -9191.92 -9280.13 -9368.35 2802.90 2836.87 2870.85 2889.81 2904.82 2938.80 2972.77 3006.75 3040.72 3074.70 3108.67 3142.65 3176.62 3204.39 3210.60 3244.57 3278.55 3312.52 3346.50 3380.47 3414.44 3448.42 3482.39 3516.37 3547.91 3550.34 3584.32 3618.29 3652.27 3652.35 3680.66 3686.24 3702.05 3720.22 3727.85 3740.73 3754.38 3790.44 3813.71 3828.66 3836.18 3860.60 3868.87 3910.86 3954.42 3999.36 4013.53 4045.44 4073.03 4084.84 4092.39 4139.49 4186.58 ORIGINAL 5967824.951 5967747.383 5967669.815 5967626.525 5967592.248 5967514.680 5967437.112 5967359.544 5967281.976 5967204.408 5967126.840 5967049.273 5966971.705 5966908.311 5966894.137 5966816.569 5966739.001 5966661 .433 5966583.865 5966506.298 5966428.730 5966351.162 5966273.594 5966196.026 5966124.020 5966118.458 5966040.890 5965963.323 5965885.755 5965885.573 5965820.934 5965808.187 5965772.095 5965730.619 5965713.202 5965683.776 5965652.815 5965572.678 5965522.091 5965490.027 5965474.028 5965422.517 5965405.264 5965318.802 5965231.063 5965142.475 5965114.907 5965053.467 5965001 .027 5964978.708 5964964.443 5964875.442 5964786.441 374434.158 374466.808 374499.458 374517.680 ALBIAN 97 374532.108 374564.758 374597.408 374630.058 374662.708 374695.358 374728.008 374760.658 374793.308 374819.992 ALBIAN 96 374825.958 374858.608 374891.258 374923.908 374956.558 374989.208 375021.858 375054.508 375087.158 375119.808 375150.117 TOP HRZ 375152.458 375185.108 375217.758 375250.408 375250.484 BASE HRZ 375277.692 K-1 MARKER 375283.058 375298.250 TOP KUPARUK 375315.708 375323.039 LCU 375335.425 Begin Dir @ 4°; 11960' MD 375348.541 375383.231 375405.644 MILUVEACH A 375420.045 375427.285 ALPINE D 375450.834 ALPINE C 375458.802 375499.314 375541.385 375584.808 375598.511 7" Csg Pt @ 12631' MD 375629.372 375656.064 CD2-57 (Heel) 375667.494 375674.799 375720.375 375765.951 Halliburton Sperry-Sun GeoReport ·COÏQPany:Q:OnQ2õPhilUl)s-Älasl<&lnc. F1eI~:,--CõlVilte RiVer Uriit~::- ... - ~ite:'-:~-cðlpiDe:CD2~ '.~ wen: ··c~·PIafi::CD2..5T ~wclïPåth~r <3,02:57 Date:c3lt7/2òQ4 · "''Ïiri1e:jÖ9i55:~4U1' ........ .c ../'j?age: . 4 .CŒo.J:"âinåte(NEIRéfe¡::eIlce:, -~Well~EIM;_ Cº2-5~J'T:rue NOOhc· Yertìc.ålQJ'¥D)RefereüCe:-·?52'~MSt..52.Œ~"~-, -.."c·'>~- - -~tiøÍl(VS)R~[etênclW é- ~Well~(Ö.(X)N.ŒOOE;1s;:tm~Azi}-, '. SUrv;eyCalctilatìönMethod: Minirnum¢urVature:c~> Db: -Orable Survey MD IncIAzbn'-- ft' - - .;c<deg~;,:- d~ 13100.00 90.003 151.904 13200.00 90.003 13300.00 90.003 13400.00 90.003 13500.00 90.003 13600.00 90.003 13700.00 90.003 13800.00 90.003 13900.00 90.003 14000.00 90.003 14100.00 90.003 14200.00 90.003 14300.00 90.003 14400.00 90.003 14500.00 90.003 14600.00 90.003 14700.00 90.003 14800.00 90.003 14900.00 90.003 15000.00 90.003 15100.00 90.003 15200.00 90.003 15300.00 90.003 15400.00 90.003 15500.00 90.003 15600.00 90.003 15700.00 90.003 15800.00 90.003 15900.00 90.003 16000.00 90.003 16100.00 90.003 16200.00 90.003 16300.00 90.003 16400.00 90.003 16500,00 90.003 16600.00 90.003 16700.00 90.003 16758.84 90.003 16800.00 90.003 16900.00 90.003 17000.00 90.003 17100.00 90.003 17200.00 90.003 .! 17258.84 90.003 Well path: C02·57 Current Datum: Magnetic Data: Field Strength: Vertical Section: 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 151.904 52' MSL 8/26/2002 57426 nT Depth From (TVD) ft 36.10 Tvn SysTVD ft· ---ft.- 7257.20 7205.20 7257.20 7257.19 7257.18 7257.18 7257.17 7257.17 7257.16 7257.16 7257.15 7257.15 7257.14 7257.13 7257.13 7257.12 7257.12 7257.11 7257.11 7257.10 7257.10 7257.09 7257.09 7257.08 7257.07 7257.07 7257.06 7257.06 7257.05 7257.05 7257.04 7257.04 7257.03 7257.03 7257.02 7257.01 7257.01 7257.00 7257.00 7257.00 7256.99 7256.99 7205.20 7205.19 7205.18 7205.18 7205.17 7205.17 7205.16 7205.16 7205.15 7205.15 7205.14 7205.13 7205.13 7205.12 7205.12 7205.11 7205.11 7205.10 7205.10 7205.09 7205.09 7205.08 7205.07 7205.07 7205.06 7205.06 7205.05 7205.05 7205.04 7205.04 7205.03 7205.03 7205.02 7205.01 7205.01 7205.00 7205.00 7205.00 7204.99 7204.99 7256.98 7204.98 7256.98 7204.98 7256.97 ..¡ 7204.97 sperT"y-SLr1 DflltlL..L..INCI ....VIC.. -A.Ku..J..Hil"I~(__~.....''\- NIS" E/W -·'ft~<~-ft - -9456.56 4233.68 -9544.78 -9632.99 -9721 .21 -9809.43 -9897.64 -9985.86 -10074.07 -10162.29 -10250.50 -10338.72 -10426.93 -10515.15 -10603.37 -10691 .58 -10779.80 -10868.01 -10956.23 -11044.44 -11132.66 -11220.87 -11309.09 -11397.31 -11485.52 -11573.74 -11661.95 -11750.17 -11838.38 -11926.60 -12014.81 -12103.03 -12191.25 -12279.46 -12367.68 -12455.89 -12544.11 -12632.32 -12684.23 -12720.54 -12808.75 -12896.97 -12985.19 -13073.40 -13125.30 Height 52.00 ft +N/-S ft 0.00 4280.77 4327.87 4374.97 4422.06 4469.16 4516.25 4563.35 4610.44 4657.54 4704.64 4751.73 4798.83 4845.92 4893.02 4940.11 4987.21 5034.31 5081.40 5128.50 5175.59 5222.69 5269.78 5316.88 5363.98 5411.07 5458.17 5505.26 5552.36 5599.46 5646.55 5693.65 5740.74 5787.84 5834.93 5882.03 5929.13 5956.84 5976.22 6023.32 6070.41 6117.51 6164.60 6192.31 5964697.440 5964608.439 5964519.438 5964430.437 5964341.436 5964252.435 5964163.435 5964074.434 5963985.433 5963896.432 5963807.431 5963718.430 5963629.429 5963540.428 5963451.427 5963362.426 5963273.425 5963184.424 5963095.423 5963006.422 5962917.421 5962828.420 5962739.419 5962650 .418 5962561 .417 5962472.416 5962383.415 5962294.414 5962205.413 5962116.412 5962027.411 5961938.410 5961849.409 5961760.408 5961671.407 5961582.406 5961493.405 5961441 .040 5961404.404 5961315.403 5961226.402 59611 37.401 5961048.400 5960996.035 Drilled From: Tie-on Depth: Aboye System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 ORIGINAL 375811.527 375857.104 375902.680 375948.256 375993.833 376039.409 376084.985 376130.561 376176.138 376221.714 376267.290 376312.867 376358.443 376404.019 376449.596 376495.172 376540.748 376586.324 376631.901 376677.477 376723.053 376768.630 376814.206 376859.782 376905.358 376950.935 376996.511 377042.087 377087.664 377133.240 377178.816 377224.392 377269.969 377315.545 377361.121 377406.698 377 452.27 4 377479.089 C02-57 (Toe) 377497.850 377543.426 377589.003 377634.579 377680.155 377706.971 6-1/8" Open Hole Well Ref. Point 36.10 ft Mean Sea Level 24.74 deg 80.59 deg Direction deg 154.743 ·."Italliburton Sperry-Suo'--'; GeoReport spE!I 4""'Y-Sl..n aRILLING .....Vlc::.. .... ..u.&.IIM-_1ON: ~w Description . Dip. Dir. .Çompany:. ConocoPhlllips Alaska Inc. cJìleld: CoIyille River Unit . Site: AlpineCD2 WeD: PIân: CD2-57 W'ellpatb: CD2-57 Targets CD2-57 (Heel) -12684.23 5956.84 5961441.040 377479.089 70 18 11.356 N 150 59 32.895 W 7257.00 -9155.65 4073.03 5965001.027375656.064 70 18 46.072 N 151 0 27.766 W Annotation 36.10 300.00 1732.90 3370.68 11960.39 12631.00 12758.89 16758.84 17258.83 TVD It 36.10 300.00 1505.59 2390.00 7028.49 7249.11 7257.00 7257.00 7256.97 SHL (2132' FNL & 1494'FEL, Sec2-T11N-R4E Begin Dir @ 4°; 300'MD, 300TVD End Dir, Start Sail @ 57°; 1733'MD 9-518" Cst Pt @ 3370'MD, 2390TVD Begin Dir @ 4°; 11960' MD 7" Csg Pt, Continue Dir @ 4° Target Heel 12759' (729'FN L&271 O'FEL, S 13- T11 N-R4E Target Toe 16759' (4259'FNL&829'FEL,(S13-T11 N-R4E) TD @ 17259' (47oo'FNL&594'FEL,S13-T11N-R4E) ORIGINAL DESCRIPTION DESCRIPTION PER A01004ACS 4 5/15/03 G.D. J.Z. C.A. PER K03074ACS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U.M. SEC.LlNE US PLAN WELL 'y' 'X' LA T.(N) LONG.(W) FNL EL GND PAD CD2-1 CD2-2 CD2-3 CD2-4 CD2-5 5.974741.17 371 685.60 70' 20' 21.202" 151' 02 28.443" 1617' 1558' 8.7 15.9 CD2-6 5.974731.13 371 686.73 70' 20' 21.103" 151" 02 28.406" 1627' 1556' 8.7 15.9 CD2-7 5974721.46 371 688.17 70' 20' 21.008" 151' 02 28.359" 1636' 1555' 8.7 15.9 CD2-8 5.974711.45 371 688.72 7(l' ?Ol ?O. Q1 (l" 151' 02' 28.337" 1646' 1554' 8.7 15.9 CD2-9 5,974701.48 371 690.14 70" 20' 20.812" 151' 02 28.291 1656' 1552 8.7 15.9 CD2-10 5.974691.64 371 691.07 70' ?O' 2(l.716" 151' 02 28.259" 1666' 1551 8.7 15.9 CD2-11 5974681.62 371 692.02 7(l' ?n' ?(lfì17" 151' 02 28.226" 1676' 1550' 8.7 15.9 CD2-12 5 974671 61 371 692,98 70' ·20' 20.519" 151' 02 28.193" 1686' 1549' 8.7 15.9 CD2-13 5974661.90 371 694.26 70' 20' 20.424" 151' 02 28.151" 1696' 1548 8.7 15.9 CD2-14 5974652.12 371 695.50 70' , 0' 20 328" 151' 02 28.110" 1706' 1546 8.7 15.9 CD2-15 5.974.641.66 371 696.24 70' , 0' 20.225" 151' 02 28.083" 1716 1545 8.7 15.9 CD2-16 5.974.631.95 371 697.39 70" , 0' 20130" 151" 02 28.044" 1726' 1544 8.7 15.9 CD2-17 5,974.622.10 371.698.48 70" D' 20.033" 151" 02 28.008" 1736' 1543 8.7 15.9 CD2-18 5974.612.15 371 699.38 7(l' (l' 1 Qç:nfi" 151" 02' 27.976" 1746' 1542 8.7 15.9 CD2-19 5 974.602.64 371.700.50 70' I' 0' 19.84?" 151" 02' 27.939" 1755' 1541' 8.7 15.9 CD2-20 5974.592.18 371.701.77 70' 2019.739" 151" 02 27.891" 1765' 1539 8.7 15.9 CD2-21 5 974.582.28 371.702.51 70' 20 19.642" 151" 02' 27.870" 1775' 1538 8.7 15.9 CD2-22 5 974.572.39 371.704.15 70' 20' 19.545" 151' 02-' 27.811" 1785' 1536' 8.7 15.9 * CD2-23 5 974.562.21 371.704.52 70" 20 19.445" 151" 02 27.801" 1795' 1536 8.7 15.9 CD2-24 5 974.552.30 371.705.92 70" 20 19.348" 151" 02-' 27.756" 1805 1534 8.7 15.9 CD2-25 5 974.542.33 371.706,81 70' 20' 19.250" 151' 02 27.725" 1815 1533 8.7 15.9 CD2-26 5.974.532.34 371.707.80 70' 20' 19.152" 151' 02 27.691 1825 1532 8.7 15.9 CD2-27 5.974.522,31 371.709.10 70" 20' 19.053" 151" 02 27.648 1835 1531 8.7 15.9 CD2-28 5.974.512.60 371.709.87 70' 20' 18.958" 151" 02 27.620" 1844 1530 8.8 15.9 CD2-29 5 974 502.63 371 711.26 70' 20' 18.860" 151' 02' 27.575" 1855' 1528' 8.8 15.9 CD2-30 5974492.75 371 712.00 70" 20' 18.763" 151' 02 27.548 1865 1527 8.8 15.9 CD2-31 5.974.482.74 371 713.04 70" 20' 18.665" 151' 02 27.513" 1875 1526 8.8 15.9 CD2-32 5 974.472.57 371.714.18 70" 20' 18.565" 151" 02 27.474" 1885' 1525 8.8 15.9 CD2-33 5 974.463.34 371.715.28 70' 20' 18.475" 151' 02 27.438" 1894 1523' 8.8 15.9 CD2-34 5 974452.65 371.716.13 70" 20' 18.370" 151' 02' 27.407" 1905 1522' 8.8 15.9 * CD2-35 5974442.90 371. 717.49 70' 20' 18.274" 151' 02 27.363" 1915 1521' 8.8 15.9 CD2-36 5.974433.20 371 718.42 70' 20' 18.179" 151' 02 27.331 1924 1520 8.7 15.9 CD2-37 5.974.423.05 371 719.40 70" 20' 18.079" 151' 02' 27.291" 1934' 1519' 8.7 15.9 CD2-38 5.974413.52 371 720.66 70' 20' 17.986" 151" 02' 27.256" 1944 1517' 8.7 15.9 * CD2-39 5.974403.28 371.721.83 70" 20' 17.885" 151' 02' 27.216" 1954 1516' 8,7 15.9 CD2-40 5.974393.27 371 722.68 7(l' ?(l' 17.1p.7" 151' 02' 27.187" 1964 1515' 8.7 15.9 CD2-41 5.974383.33 371 723.84 70' 20' 17.689" 151' 02' 27.148" 1974 1514' 8.7 15.9 CD2-42 5.974.373.69 371 724.77 70' 20' 17.595" 151' 02' 27.116" 1984 1513' 8.7 15.9 CD2-43 5,974363.45 371 725.60 70' 20' 17.494" 151' 02' 27.081" 1994 1512' 8.7 15.9 CD2-44 5.974353.42 371 726.94 70" 20' 17.396" 151" 02' 27.042" 2004 1510' 8.6 15.9 CD2-45 5.974344.11 371 728.07 70' 20'- 17.304-"- 151" 02' 27.005" 2013' 1509' 8.6 15.9 CD2-46 5.974333.52 371 729.06 70" 20' 17.200" 151' 02' 26.971" 2024 1508 8.6 15.9 CD2-47 5.974323.53 371.730.13 70' 20' 17.102" 151' 02' 26.934" 2034' 1506' 8.6 15.9 CD2-48 5.974313.77 371 731.19 70' 20' 17.006" 151' 02-'- 26.898" 2043' 1505' 8.6 15.9 CD2-49 5.974303.80 371.732.05 70' 20' 16.908" 151' 02-'- 26.868" 2053' 1504' 8.5 15.9 CD2-50 5.974293.84 371 733.00 70' 20' 16.811-"- 151' 02-'- 26.836" 2063' 1503' 8.5 15.9 CD2-51 5.974 283.88 371 734.28 70' 20 16.713" 151" 02-'- 26.793" 2073' 1502 8.5 15.9 CD2-52 5974274.18 371 735.18 70' 20' 16.618" 151' 02-'- 26.762" 2083 1501' 8.5 15.9 CD2-53 5.974264.07 371 736.31 70' 20 16.518" 151" 02 26.724 2093 1499 8.5 15.9 CD2-54 5974254.19 371 737.50 70' 20' 16.421 II 151" 02' 26.684 2103 1498 8.5 15.9 CD2-55 5.974244.05 371 738.44 70' 20 16.322" 151' 02' 26.652" 2113 1497 8.5 15.9 CD2-56 5 974.234.27 371 739.42 70' 20' 16.226" 151' 02' 26.618" 2123 1496' 8.5 15.9 CD2-57 5 974 224.26 371 740.55 70" 20' 16.128" 151" 02-'- 26.580" 2133' 1494 8.5 15.9 CD2-58 5974214.18 371 741.60 70' 20' 16.029" 151' 02 26.544 2143 1493 8.5 15.9 CD2-59 CD2-60 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) 3. * INDICATES DATA PER LOUNSBURY AS-BUILT. ConocðPhillips ALPINE MODULE: CD20 UNIT: CD ALPINE PROJECT CD-2 WELL CONDUCTORS Alaska, Inc. AS-BUlL T LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 01-02-05-1 05-27-01 20-121 2 OF 3 4 ConocoPhillips Alaska, Inc. '-' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 Con~c~illips April 28, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-57 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection .ç.,ell from the Alpine C02 drilling pad. The intended spud date for this well is May 15, 2004. It is intended that Doyon Rig 19 drill the well. The intermediate section of C02-57 will be drilled and landed in the Alpine sand horizontally; 7" casing will then be run and cemented in place. C02-57 will be completed as an open hole injector. .-' At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. /There have been 44 wells drilled on C02 pad with no significant indication of gas or shallow gas hydrates. It is also requested that the packer placement requirement be relaxed to place the packer 200 ft TVO above the Alpine formation. This will place the completion at a maximum inclination less than 65 degrees, and allow access to the completion with standard wireline tools for future intervention. 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 1 0-401 APPLICATION FOR Permit to Orill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup which replaces diverter RECEIVED APR 292004 Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~?~ Vern Johnson Drilling Engineer '-- Attachments cc: C02-57 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Cliff Crabtree Steve Moothart/Jeff Yeaton Nancy Lambert Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1768 ATO 1756/1752 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson@anadarko.com SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1051 e ~E or II¿ :5f;/f ~jred ..11III-" CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . , 200 WhIte Clay Center Dr., Newark, DE 19111 F I~;' ~ ~OO ~~~I: 2 ~8~? ~gO?g 2/1-~~~n¿:f~lk£ --- \ DATE 2cr !lp('¡ 12ê04- 62-14/311 f $;00.00 A S8<u,,¡yFealUfes DOLLARS ill ~~U:~;'ßac~ e e e TRANSMITAL LETTER CHECK LIST C~RCLE APPROPRIATE LETTERIP ARAGRAPHS TO I BE INCLUDED IN TRANSMITTAL LETTER I I I I i PTD# L7ætÆ (1])2 - $7 20(1- O~/Z- WELL NAME ~Development /' Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weUbore segment of LATERAL existing wen . Permit No, API No. . (If API Dumber Productionsbould continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. Pn..OT BOLE In accordance witb 20 AAC 25.005(f), an (PH) records, data and logs acquired for tbe piJot bole must be dearly differentiated 1n botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject -to fuD EXCEPTION compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jception. (Company Name) assumes the liability of any protest to tbe spacingeJception that may occur. DRY DITCH A)) dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample hiter:vals tbrougb target zones. Field & Pool COLVILLE RIVER, ALPINE OIL -120100 Well Name: COLVILLE RIV UNIT CD2-57 Program SER Well bore seg 0 PTD#: 2040720 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal 0 Administration 1 P~rmitfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ . _ _ 2 _Leas~.numberappropriale_ _ _ _ . _ . _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Y~$ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . . _ 3 .U_nique well_n.am~_aod oumb_er _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Y~$ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ 4 WeJUocat~d in_ad_efil'!ed_p.ool. _ . _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ Y~$ _ _ _ _ _ _ Conseryati.oo Ord.er 1\10. .443. AJpjn_eQilPo.oL _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ 5 WelUocaled prQper _distance_ from driJling ul'!ilb_oUl'!d.al)'_ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . Y~$ _ _ _ _ _ _ . More than 500' from exterior boundary of.are.a.est$lbltshed_by _CQ 44~ _ _ _ _ _ _ _ _ _ . . 6 WelUocat~d prQper _distance_ from other welJs _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Y~$ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . .. _ _ _ _ _ . _ _ _ _ _ _ . _ 7 _S_utfjciel'!tacreage_aYail<lble in_dri[liogunjt_ _ . _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _Y~s _ _ _ _ . _ . . _ _ _ _ _ _ .. . _ _ _ _ _ . _ _ _ . _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ _ _ 8 Jf.d~viated, js_ weJlbore platiocJuded _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ _ _ _ _ . .. _ _ _ Y~s _ _ _ .. _ _ _ _ _ _ . _ . _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ 9 _O-perator 01'!1}! affected party _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ . _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Y~s _ _ . . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _. . _ _ _ _ _. _ _ _ _ _ _ . 10 _O-Perator has_appr.opriate_bond inJorce _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ Y~s _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 11 P~rmit c.an be issued wjthout co.n$ervatioo order _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Appr Date 12 P~rmitcao be iS$ued without actmioistratil,le_apprpvaJ _ _ _ _ _ _ _ _ _ . _ . _ _ _ Y~s _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ _ ~ 4/29/2004 13 Can permit be approved before 15-day wait Yes . 14 WellJocat~d withil'! area and_strata authorized by.lojectipo Ord~r # (putlOtl in_cQrnm_eots).(For Y~s _ _ . . . _ _ .A.r~a Injection Qrder Np._ t8A _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . . . _ _ _ _ . _ _ . . _ _ _ _ _ . . _ 15 _AJlwelJs_witJ1inJI4.mile_area_ofreYiewid~otified(Fprservjc.ew_ellool}!). _ _ _ _ _.. _ _ _ _ _ _ _ _Y~s_ _ _ _ _ _ _CBUÇP2-;36_ _ _ _. _ _ _ _ _ _.. _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _... _ _ _ _ _. _ _ _ _ _ _ _ _ _ _. _ _. _ _ _ _ __ 16 Pre-prOduçec!injector; dur<ltionofpre--produGtiool~ssthan3months.(For_ser:viçewellonJy) _ No_ _ _ _. _ _W~lJwillnotbepre~prod.uçe.d, _ _ _ _ _. _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ __ 17 _ACMP_ FJndjng _of Con~lslency_h.as been issued_ for_ this proieçt _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _NA _ _ _ _ _ . . W~IJ drilled from exjstiog pa.d, _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . Engineering 18 _C.ooductor string_provided _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ . 19 _S_urfacecasil'!gprote~tsaILknown.USDWs .. _ _ _ _ _ _ _ _ _ _. _ _ . _ _NA _ _ _ _. _ .l\IoaqujferS,perAI0.18.A.conclusioo3._. _ _ _ _ _ _ _.. _. _ _ _ _ _ _.. _ _ _ _ _ _ _ _.. _ _ _ _ __ 20 _CMT vol adequ_ate.to circulate_o_ncond_uçtor. & SUJtcsg _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _Y~$ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ 21 _CMT v.ol adequ_ate.to tie-lnJongslring lo_surf çs.g. _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ No_ _ _ _ _ _ _ .A.on_ular disp_osal m_ay be requested._ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ 22CMTwiIJ coyer.aJl koow.n-pro_ductiye horizons_ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ . Open_h.ol~c.ompletlon plaooe_d, _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . 23Ca$iog de_signs ad_equa.te fpr C,_T~ B.&permafr_ost _ _ _ _ _ _ _ _ _ _ _ . _ . Y~$ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 .Ädequ<lletan.kage_oJ re_Serye pit _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ Y~s _ . _ _ _ _ _ Big isequippe_d.with st~elpjts. _ No. rese_rve_pjt-planoed, Wa_sle.to approved annulus or_djsposal well, 25 Jf.aJe-drilt hasa to:403 for $lbandonment be~o apPJoved _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ 26 _Ädequ<lle_wellbore separatjo_n-pro-posep. _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _Y~s _ _ _ _ _ _ _ I?rp~imit}! an$llysis pertorme_d, Jrayeling c}!lioder path calcuJate.d, ßyro$ Pos_siÞle, _ _ _ . . _ _ _ . _ _ _ . . . _ 27 Jf.djvecter required, does jt.meet reguJatioos_ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _NA _ _ _ _ _ ..A. diyerter waiveJ has_ beeo gr$loted tor CD2.20_AAC_ 25,0.35(J1)(2), _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ Appr Date 28 _Drilliogfluidprogramschematic&equipJistadequale _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _. _ _ _ Y~s_ _ _ _ _ _Maximumexpectedfprmationpressure_8,7EMW._ MWplanned9.0~9.6-ppg. _ _ _ _ _. IL~. 4/30/2004 29 BOPEs,_dp.they meelreguJatiol'! - - . . . . - - _ _ . _ . _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . . Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ . _ ~fr( 30 _BOPE_pressratiogap-propriate;.testlo_(pu.tpsigtn_comrneot5)_ _ _ _. _ _ _ _ _ _ _ _ _.. _ _ _ _ Y~$_ _ _ _. .W\Sl?calcuJate_d_at2558-psi, 3500_p~tapprQpriate_._CP.AJusuaIJYJes_tst.o.5000_ps[... _.. _ _ _ _. _. _ _ _ _ __ 31 _C_h.oke.manifold compJies w/APIRF'-53 (May 84) _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ Y~$ _ _ _ . _ _ _ _ . . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ 32 Work will .occur with.outoperatjonshutdown. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ . _ _ _ _ . _ . _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . 33 Jspresence_ofH2Sgas_prob.able_ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _.. _ _ _ _ _ _ No_ _. _. _ _ _Bigjs_e.quippe_d.withsensors_aodalarm~._ _ .. _ _ _ _ _ _ _ _. _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _. _ _ _ _ __ 34 Mecha_nicaLc.podjlloopt well$ withio .A.OB yerified (f.or.s_ervjce welJ onJy) _ . . . _ _ _ _ _ _ _ . . _ Y~$ _ _ There_ are 00 penetrati.oos.Îoto th~ Alpine_within _114_mile.of CD2-5'Z's pe_netra.tioo. _ _ _ _ _ . . . _ _ _ _ _ . . _ Geology 35 P~rmil cao be issued wto. hydrogen s_ulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ Ye$ _ . _ _ _ _ _ Vero Johnson, CI?AI, 4/29J2004:H2S_npt }!et seeo inJhi$ field. _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ . . . _ _ _ _ _ _ _ 36 .D_atapreSelJted on_ pote.ntial .oveJpres_sure _zooes _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Yes. . _ _ _ _ _ Expected r~5ervojr -pressure is _8,7.ppg EMW; wJlLbedrilled wjth 9.0 ~ 9.6 ppg mud. _ . _ . _ _ _ _ . . Appr Date 37 _S~lsrnic_analysjs_ of shaJlow gas_zpoes_ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ . .NA _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ _ _ . . SFD 4/29/2004 38 _S~abedcOl'!djtiolJ survey (if off-shore) _ . . _ . _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 39 _ Conta.ct namelpJ1oneJor.weekly pr.ogress_reports [explorato . _ _ _ _ _ NA _ _ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ ŒJij5 Date: f(r Engineering Commissioner: Date Geologic Commissioner: e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drtlting Services LIS Scan Utility e $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 23 15:01:14 2004 #IJf~/1-- )..() v\ - () 1 Reel Header Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/23 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/23 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments....... ......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-57 501032049200 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 23-JUN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0003066896 M. HANIK D. LUTRICK MWD RUN 4 MW0003066896 M. HANIK D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 llN 4E 2133 1494 MSL 0) 52.80 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 3391. 0 12642.0 # REMARKS: e e 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUNS 3 AND 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE. RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 3 AND 4 REPRESENT WELL CD2-57 WITH API#: 50-103-20492-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16433'MD/7296'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/23 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3359.5 3359.5 3359.5 3359.5 3359.5 3367.5 STOP DEPTH 16373.0 16373.0 16373.0 16373.0 16373.0 16366.0 ROP $ 3401._ 16432.5 e # 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 3 4 MERGE TOP 3359.5 12652.0 MERGE BASE 12652.0 16432.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type... ..0 Logging Direction.... ... ........ ..Down Optical log depth units.. ....... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record...... ..... ..Undefined Absent value................ ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 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 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3359.5 16432.5 9896 26147 3359.5 16432.5 ROP MWD FT/H 0.04 512.51 170.262 26063 3401. 5 16432.5 GR MWD API 33.08 431.27 97.9304 25998 3367.5 16366 RPX MWD OHMM 0.24 2000 7.55812 26028 3359.5 16373 RPS MWD OHMM 0.12 2000 7.83894 26028 3359.5 16373 RPM MWD OHMM 0.17 2000 8.9359 26028 3359.5 16373 RPD MWD OHMM 0.14 2000 16.678 26028 3359.5 16373 FET MWD HOUR 0.17 138.64 1.27224 26028 3359.5 16373 First Reading For Entire File......... .3359.5 Last Reading For Entire File.......... .16432.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/23 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 e Physical EOF File Header Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/23 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPS RPM GR ROP $ 2 e header data for each bit run in separate files. 3 .5000 START DEPTH 3359.5 3359.5 3359.5 3359.5 3359.5 3367.5 3401.5 STOP DEPTH 12609.5 12609.5 12609.5 12609.5 12609.5 12617.0 12652.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # 24-MAY-04 Insite 66.37 Memory 12652.0 3401.0 12652.0 50.6 81.2 TOOL NUMBER 124725 151812 8.500 3391. 0 LSND 9.60 36.0 9.0 250 3.9 4.500 2.600 5.200 4.000 80.0 143.6 80.0 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION e e (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............. ....Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.... ................ .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3359.5 12652 8005.75 18586 3359.5 12652 ROP MWD030 FT/H 4.81 512.51 197.636 18502 3401.5 12652 GR MWD030 API 41.5 431.27 113.749 18500 3367.5 12617 RPX MWD030 OHMM 0.27 2000 6.00796 18501 3359.5 12609.5 RPS MWD030 OHMM 0.12 2000 5.9294 18501 3359.5 12609.5 RPM MWD030 OHMM 0.17 2000 6.03501 18501 3359.5 12609.5 RPD MWD030 OHMM 0.14 2000 12.509 18501 3359.5 12609.5 FET MWD030 HOUR 0.17 68.68 0.663141 18501 3359.5 12609.5 First Reading For Entire File.... ..... .3359.5 Last Reading For Entire File..... ..... .12652 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/06/23 Maximum Physical Record..65535 File Type.............. ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... .4IÞ/06/23 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR Rap $ 3 e header data for each bit run in separate files. 4 .5000 START DEPTH 12610.0 12610.0 12610.0 12610.0 12610.0 12617.5 12652.5 STOP DEPTH 16373.0 16373.0 16373.0 16373.0 16373.0 16366.0 16432.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 02-JUN-04 Insite 66.37 Memory 16433.0 12652.0 16433.0 83.7 91.3 TOOL NUMBER 160788 57780 6.125 12642.0 Flo Pro 8.80 52.0 8.5 21000 4.0 .220 .110 .160 .240 68.0 140.0 68.0 68.0 # e e REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12610 16432.5 14521.3 7646 12610 16432.5 ROP MWD040 FT/H 0.04 282.86 103.274 7561 12652.5 16432.5 GR MWD040 API 33.08 90.15 58.9017 7498 12617.5 16366 RPX MWD040 OHMM 0.24 1301.32 11.3683 7527 12610 16373 RPS MWD040 OHMM 0.25 1302.61 12.5325 7527 12610 16373 RPM MWD040 OHMM 0.21 2000 16.0662 7527 12610 16373 RPD MWD040 OHMM 4.7 2000 26.9254 7527 12610 16373 FET MWD040 HOUR 0.35 138.64 2.76936 7527 12610 16373 First Reading For Entire File......... .12610 Last Reading For Entire File.. ........ .16432.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/06/23 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/06/23 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... ...... .LISTPE \ .. Date................... .~/06/23 ~ Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... ...... .UNKNOWN Continuation Number..... .01 Next Reel Name... ....... .UNKNOWN Comments.......... ...... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File