Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-065
Originated: Delivered to:20-Nov-25Alaska Oil & Gas Conservation Commiss20Nov25-NRATTN: Meredith Guhl333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539Anchorage, AK 99518(907) 273-1700 main (907)273-4760 faxWELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTIONDATA TYPE DATE LOGGED2P-A 50-103-20475-01-00 204-009 Kuparuk River WL SCMT FINAL FIELD 6-Nov-252P-406 50-103-20484-00-00 204-022 Kuparuk River WL IBC-CBL FINAL FIELD 9-Nov-25CD4-209 50-103-20532-00-00 206-065 Colville River WL Patch Setting FINAL FIELD 11-Nov-251Y-22 50-029-22369-00-00 193-070 Kuparuk River WL LDL FINAL FIELD 14-Nov-251G-12 50-029-21009-00-00 183-132 Kuparuk River WL LDL FINAL FIELD 15-Nov-25Transmittal Receipt________________________________X__________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.Nraasch@slb.comSLB Auditor - TRANSMITTAL DATETRANSMITTAL #A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media.# Schlumberger-PrivateT41163T41164T41165T41166T41167CD4-209 50-103-20532-00-00206-065Colville RiverWLPatch SettingFINAL FIELD11-Nov-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.21 09:11:58 -09'00' Originated: Delivered to:8-Oct-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 CD1-47 50-103-20659-00 910153881 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 29-Jul-25 0 12 CD4-209 50-103-20532-00 910213378 Colville RiverLeak Detect Log with IntelliscopeField & Processed 30-Jul-25 0 1345PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40982212-083206-065T40983Leak Detect Log withCD4-20950-103-20532-00910213378Colville RiverIntelliscopeField & Processed30-Jul-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:04:54 -08'00' 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: Tubing Patch 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): 13215'None Casing Collapse Structural Conductor Surface Intermediate Production Slotted Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3782 Senior Well Interventions Engineer CRU CD4-209 6195' 6503' 6054' 6503' N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6446' MD and 6025' TVD N/A Mark Shulman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380077, ADL0384209, ADL0384211, ADL0388903 206-065 P.O. Box 100360, Anchorage, AK 99510 50-103-20532-00-00 Colville River Field Nanuq Oil Pool ConocoPhillips Alaska, Inc. Length Proposed Pools: PRESENT WELL CONDITION SUMMARY Nanuq Oil Pool TVD Burst 6847' MD 119' 2381' 6202' 119' 2394' 16" 9-5/8" 77' 7"6957' 2352' 6994' Alternating Slotted Liner: 6991-13163' 4-1/2" Alternating Slotted Liner: 6202-6198' Perforation Depth TVD (ft): 10/5/2025 13205'6365' 4-1/2" 6196' Packer: Baker Premier Packer SSSV: None Perforation Depth MD (ft): L-80 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 12:01 pm, Sep 19, 2025 Mark Shulman Digitally signed by Mark Shulman Date: 2025.09.19 09:31:06 -08'00' 325-570 DSR=9/24/25SFD 9/23/2025 10-404X X VTL 9/25/25JLC 9/25/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.25 14:21:37 -08'00'09/25/25 RBDMS JSB 092625 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 25, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. CRU well CD4-209 (PTD 206-065). On June 17, 2025 the AOGCC was notified of a failed MIT. Subsequent diagnostics have identified a Tubing to IA leak at 3,900’MD. This request is for approval to install a tubing patch for repair of tubing by inner annulus communication. Please contact me at: 263-3782 if you have any questions. Sincerely, Mark Shulman Senior Well Integrity Engineer ConocoPhillips Alaska, Inc. Mark Shulman Digitally signed by Mark Shulman Date: 2025.09.19 09:32:09 -08'00' CD4-209 Tubing Patch Running Procedure 1. Pull plug from PXN nipple at 6,503’. 2. Brush and flush patch set area of ~3,920' – 3,880'. 3. Set lower PIIP mid-element at ~3,910'. 4. Set PIIP test tool and sting into lower packer. 5. Perform CMIT TxIA to 3000 psi. 6. Pull test tool. 7. Set anchor latch, spacer pipe and upper PIIP mid element at ~3,890'. 8. Perform MIT-IA to confirm patch and tubing integrity. 9. Submit 10-404 post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD4-209 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Schematic Clean up CD4-209 9/16/2025 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: INSTALLED SLEEVE FROM 8" BELOW HANGER TO 18'3". 10/6/2014 lehallf NOTE: SLEEVE MADE WITH 12".500 WALL x 65 PIPE. 10/6/2014 lehallf NOTE: TOTAL REPAIR LENGTH IS 17'7' FROM TOP OF A BAND TO BOTTOM OF B BAND. 10/6/2014 lehallf NOTE: SHUT-IN INJECTOR 6/7/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 41.4 118.8 118.8 65.00 H-40 Welded SURFACE 9 5/8 8.83 41.4 2,393.8 2,380.9 40.00 L-80 BTC INTERMEDIATE 7 6.28 37.4 6,994.4 6,202.3 26.00 L-80 BTCM LINER Slotted 4 1/2 3.96 6,839.8 13,205.0 6,195.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.9 Set Depth … 6,847.0 Set Depth … 6,174.6 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) 28.9 28.9 0.00 HANGER 10.850 Tubing Hanger w/ 2.28' pup FMC 3.958 2,001.0 1,996.0 9.79 NIPPLE 5.620 Nipple Camco DB 3.812 6,338.7 5,968.0 55.62 GAS LIFT 5.984 Camco KBG-2 3.920 6,445.9 6,025.4 59.53 PACKER 5.970 PREMIER PACKER Baker 3.875 6,503.4 6,053.7 61.28 NIPPLE 5.000 HES XN Nipple 3.725 6,827.2 6,169.9 75.95 WLEG 5.000 Fluted WLEG w/ LOCATOR SUB Baker 3.958 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) 3,900.0 3,838.2 20.57 LEAK LEAK FOUND WITH ACX LDL 7/30/2025 0.000 6,503.0 6,053.5 61.26 PLUG PXN Plug with 4-1/2" GS Bait Catcher and Prong. 6/17/2025 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,338.7 5,968.0 55.62 1 GAS LIFT DMY 1 0.0 9/6/2014 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,839.8 6,172.9 76.48 SLEEVE 5.790 'HR' LINER SETTING SLEEVE Baker 4.420 6,852.8 6,175.9 77.03 NIPPLE 5.600 "RS Packoff Seal Nipple Baker 4.250 6,866.5 6,178.9 77.60 XO 5.570 CROSSOVER 5x4.5" 3.910 13,162.6 6,198.2 93.16 BUSHING 4.500 BAKER Packoff Bushing 2.380 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,991.0 13,163.0 6,201.7 6,198.2 NANLB3, NANLB2, NANLB3, CD4- 209 6/9/2006 32.0 SLOTS Alternating slotted/blank pipe Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,150.0 6,995.0 5,849.9 6,202.4 Production Casing Cement 6/2/2006 Horizontal, CD4-209, 9/17/2025 9:26:08 AM Vertical schematic (actual) LINER Slotted; 6,839.8-13,205.0 SLOTS; 6,991.0-13,163.0 INTERMEDIATE; 37.4-6,994.4 Production Casing Cement; 6,150.0 ftKB PLUG; 6,503.0 PACKER; 6,445.9 GAS LIFT; 6,338.7 LEAK; 3,900.0 SURFACE; 41.4-2,393.8 CONDUCTOR; 41.4-118.8 WNS INJ KB-Grd (ft) 44.13 RR Date 6/11/2006 Other Elev… CD4-209 ... TD Act Btm (ftKB) 13,215.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053200 Wellbore Status INJ Max Angle & MD Incl (°) 94.28 MD (ftKB) 7,791.77 WELLNAME WELLBORECD4-209 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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: AOGCC Notification CRU CD4-209 (PTD# 206-065) Date:Monday, June 16, 2025 1:43:51 PM Attachments:image001.png AnnComm Surveillance TIO for CD4-209.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, June 16, 2025 1:41 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: AOGCC Notification CRU CD4-209 (PTD# 206-065) Well Name: CD4-209 Facility: WNS PTD: 206-065 Well Type: Injector AA Number (if applicable): AIO 28.003 Internal Waiver (Yes/No if applicable): Yes Type of Issue: Failed MIT-IA Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): 6/15/25 Chris, CRU CD4-209 (PTD# 206-065) failed a diagnostic MIT-IA to 3,300 psi on 6/15/2025. Please note this well is a waivered WAG injector (AIO 28.003) with IAxOA communication. The MIT-IA did not show IA to OA communication. The well has been shut-in since 4/19/25 and it will be secured with a plug. After securing the well, we will begin initial diagnostics. 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, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD4-209 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-209 2025-03-21 1000.0 450 -550.0 OA CD4-209 2025-05-12 492.0 491 -1.0 IA CD4-209 2025-05-17 26.0 1 -25.0 IA CD4-209 2025-05-17 154.0 70 -84.0 OA CD4-209 2025-05-18 74.0 2 -72.0 OA CD4-209 2025-05-18 8.0 0 -8.0 IA CD4-209 2025-05-23 10.0 403 393.0 IA CD4-209 2025-05-23 30.0 315 285.0 OA CD4-209 2025-06-15 178.0 0 -178.0 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-209 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Set A1 CD4-209 2/20/2025 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: INSTALLED SLEEVE FROM 8" BELOW HANGER TO 18'3".10/6/2014lehallf NOTE: TOTAL REPAIR LENGTH IS 17'7' FROM TOP OF A BAND TO BOTTOM OF B BAND. 10/6/2014 lehallf NOTE: SLEEVE MADE WITH 12".500 WALL x 65 PIPE. 10/6/2014 lehallf NOTE: VIEW SCHEMATIC w/Alaska Schematic9.09/3/2008 lmosbor NOTE: SHUT-IN INJECTOR 6/7/2008 lmosbor NOTE: TREE: FMC 4-1/16" 5,000 PSI - TREE CAP CONNECTION: 7" OTIS 7/6/2006 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 CONDUCTOR1615.25 41.4 118.8 118.865.00 H-40 Welded SURFACE 9 5/8 8.83 41.4 2,393.8 2,380.9 40.00 L-80 BTC INTERMEDIATE 7 6.28 37.4 6,994.4 6,202.3 26.00 L-80 BTCM LINER Slotted 4 1/2 3.96 6,839.8 13,205.0 6,195.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.9 Set Depth… 6,847.0 Set Depth… 6,174.6 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) 28.928.90.00 HANGER 10.850 FMC Tubing Hanger w/ 2.28' pup 3.958 2,001.0 1,996.0 9.79 NIPPLE 5.620 Camco DB nipple 3.812 6,338.7 5,968.0 55.62 GAS LIFT 5.984 CAMCO KBG-2 3.920 6,445.9 6,025.4 59.53 PACKER 5.970 BAKER PREMIER PACKER Baker 3.875 6,503.4 6,053.7 61.28 NIPPLE 5.000 HES XN Nipple 3.725 6,827.2 6,169.9 75.95 WLEG 5.000 Baker fluted WLEG w/ LOCATOR SUB 3.958 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) 2,001.0 1,996.0 9.79 INJ VALVE 4.5" Injection Valve on 3.812" DB Lock (40" OAL) Camco A1 HSS- 165 2/20/2025 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) 6,338.7 5,968.0 55.62 1 GAS LIFT DMY 1 0.09/6/2014 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,839.8 6,172.9 76.48 SLEEVE 5.790 BAKER 'HR' LINER SETTING SLEEVE 4.420 6,852.8 6,175.9 77.03 NIPPLE 5.600 BAKER "RS Packoff Seal Nipple 4.250 6,866.5 6,178.9 77.60 XO 5.570 CROSSOVER 5x4.5" 3.910 13,162.6 6,198.2 93.16 BUSHING 4.500 BAKER Packoff Bushing 2.380 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,991.0 13,163.0 6,201.7 6,198.2 NANLB3, NANLB2, NANLB3, CD4- 209 6/9/2006 32.0 SLOTS Alternating slotted/blank pipe Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,150.06,995.0 5,849.96,202.4 Production Casing Cement 6/2/2006 Horizontal, CD4-209, 2/21/2025 5:31:48 AM Vertical schematic (actual) LINER Slotted; 6,839.8-13,205.0 SHOE; 13,203.0-13,205.0 SLOTS; 6,991.0-13,163.0 INTERMEDIATE; 37.4-6,994.4 Float Shoe; 6,992.4-6,994.4 Float Collar; 6,904.1-6,905.4 XO; 6,866.5-6,868.4 HANGER; 6,856.6-6,866.5 NIPPLE; 6,852.8-6,856.6 SLEEVE; 6,839.8-6,852.8 WLEG; 6,827.2 Production Casing Cement; 6,150.0 ftKB NIPPLE; 6,503.4 Tubing pup; 6,454.0 PACKER; 6,445.9 GAS LIFT; 6,338.7 SURFACE; 41.4-2,393.8 Float Shoe; 2,391.3-2,393.8 Float Collar; 2,311.5-2,312.9 INJ VALVE; 2,001.0 NIPPLE; 2,001.0 CONDUCTOR; 41.4-118.8 Casing Hanger; 41.4-43.6 HANGER; 28.9 WNS INJ KB-Grd (ft) 44.13 RR Date 6/11/2006 Other Elev… CD4-209 ... TD Act Btm (ftKB) 13,215.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053200 Wellbore Status INJ Max Angle & MD Incl (°) 94.28 MD (ftKB) 7,791.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE 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: CRU CD4-209 (PTD 206-065) Date:Tuesday, March 25, 2025 8:56:58 AM Attachments:image001.png AnnComm Surveillance TIO for CD4-209.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, March 24, 2025 4:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-209 (PTD 206-065) Chris, CRU CD4-209 (PTD 206-065) is a waivered injector (AIO 28.003). On 3/21/25, the well’s OA exceed the allowable operating pressure of 1000 psi as the wells brought on sea water injection. The max pressure was 1020 psi, the OA was bled down to 500 psi and stable. CD4-209 passed an MIT-IA to 3,335 psi on 6/25/2023. DHD will complete initial diagnostics. Depending on results, proper notifications will be made as needed. The 90 day TIO is attached. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD4-209 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-209 2025-03-21 1000 450 -550 OA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-209 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Set A1 CD4-209 2/20/2025 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: INSTALLED SLEEVE FROM 8" BELOW HANGER TO 18'3".10/6/2014lehallf NOTE: TOTAL REPAIR LENGTH IS 17'7' FROM TOP OF A BAND TO BOTTOM OF B BAND. 10/6/2014 lehallf NOTE: SLEEVE MADE WITH 12".500 WALL x 65 PIPE. 10/6/2014 lehallf NOTE: VIEW SCHEMATIC w/Alaska Schematic9.09/3/2008 lmosbor NOTE: SHUT-IN INJECTOR 6/7/2008 lmosbor NOTE: TREE: FMC 4-1/16" 5,000 PSI - TREE CAP CONNECTION: 7" OTIS 7/6/2006 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 CONDUCTOR1615.25 41.4 118.8 118.865.00 H-40 Welded SURFACE 9 5/8 8.83 41.4 2,393.8 2,380.9 40.00 L-80 BTC INTERMEDIATE 7 6.28 37.4 6,994.4 6,202.3 26.00 L-80 BTCM LINER Slotted 4 1/2 3.96 6,839.8 13,205.0 6,195.8 12.60 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.9 Set Depth… 6,847.0 Set Depth… 6,174.6 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) 28.928.90.00 HANGER 10.850 FMC Tubing Hanger w/ 2.28' pup 3.958 2,001.0 1,996.0 9.79 NIPPLE 5.620 Camco DB nipple 3.812 6,338.7 5,968.0 55.62 GAS LIFT 5.984 CAMCO KBG-2 3.920 6,445.9 6,025.4 59.53 PACKER 5.970 BAKER PREMIER PACKER Baker 3.875 6,503.4 6,053.7 61.28 NIPPLE 5.000 HES XN Nipple 3.725 6,827.2 6,169.9 75.95 WLEG 5.000 Baker fluted WLEG w/ LOCATOR SUB 3.958 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) 2,001.0 1,996.0 9.79 INJ VALVE 4.5" Injection Valve on 3.812" DB Lock (40" OAL) Camco A1 HSS- 165 2/20/2025 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) 6,338.7 5,968.0 55.62 1 GAS LIFT DMY 1 0.09/6/2014 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,839.8 6,172.9 76.48 SLEEVE 5.790 BAKER 'HR' LINER SETTING SLEEVE 4.420 6,852.8 6,175.9 77.03 NIPPLE 5.600 BAKER "RS Packoff Seal Nipple 4.250 6,866.5 6,178.9 77.60 XO 5.570 CROSSOVER 5x4.5" 3.910 13,162.6 6,198.2 93.16 BUSHING 4.500 BAKER Packoff Bushing 2.380 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,991.0 13,163.0 6,201.7 6,198.2 NANLB3, NANLB2, NANLB3, CD4- 209 6/9/2006 32.0 SLOTS Alternating slotted/blank pipe Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 6,150.06,995.0 5,849.96,202.4 Production Casing Cement 6/2/2006 Horizontal, CD4-209, 2/21/2025 5:31:48 AM Vertical schematic (actual) LINER Slotted; 6,839.8-13,205.0 SHOE; 13,203.0-13,205.0 SLOTS; 6,991.0-13,163.0 INTERMEDIATE; 37.4-6,994.4 Float Shoe; 6,992.4-6,994.4 Float Collar; 6,904.1-6,905.4 XO; 6,866.5-6,868.4 HANGER; 6,856.6-6,866.5 NIPPLE; 6,852.8-6,856.6 SLEEVE; 6,839.8-6,852.8 WLEG; 6,827.2 Production Casing Cement; 6,150.0 ftKB NIPPLE; 6,503.4 Tubing pup; 6,454.0 PACKER; 6,445.9 GAS LIFT; 6,338.7 SURFACE; 41.4-2,393.8 Float Shoe; 2,391.3-2,393.8 Float Collar; 2,311.5-2,312.9 INJ VALVE; 2,001.0 NIPPLE; 2,001.0 CONDUCTOR; 41.4-118.8 Casing Hanger; 41.4-43.6 HANGER; 28.9 WNS INJ KB-Grd (ft) 44.13 RR Date 6/11/2006 Other Elev… CD4-209 ... TD Act Btm (ftKB) 13,215.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053200 Wellbore Status INJ Max Angle & MD Incl (°) 94.28 MD (ftKB) 7,791.77 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-209 COLVILLE RIV NAN-N CD4-209 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-209 50-103-20532-00-00 206-065-0 W SPT 6025 2060650 3000 2040 2040 2040 2040 340 650 610 580 REQVAR P Bob Noble 6/25/2023 MITIA to max anticipated injection p[ressure as per AIO 28.003. 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 NAN-N CD4-209 Inspection Date: Tubing OA Packer Depth 350 3320 3260 3220IA 2040 570 45 Min 3220 60 Min Rel Insp Num: Insp Num:mitRCN230629121544 BBL Pumped:1.4 BBL Returned:1.5 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-209 COLVILLE RIV NAN-N CD4-209 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-209 50-103-20532-00-00 206-065-0 W SPT 6025 2060650 1800 2045 2020 2010 2005 340 2030 2010 2000 REQVAR P Bob Noble 6/25/2023 CMIT IA x OA to 1800 as per AIO 28.003 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 NAN-N CD4-209 Inspection Date: Tubing OA Packer Depth 540 2060 2030 2030IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230629123757 BBL Pumped:0.8 BBL Returned:1.4 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 999 9 9 9 9 CMIT IA x OA to 1800 James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 15:50:43 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -209 COLVILLE RIV NAN-N CD4 -209 Src: Inspector Reviewed By: P.I. Supry Comm Well Name COLVILLE RIV NAN-N CD4 -209 API Well Number 50-103-20532-00-00 Permit Number: 206-065-0 Insp Num: mitLOL210611111034 Rel Insp Num: Inspector Name: Lou Laubenstein Inspection Date: 6/11/2021 , Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 -209 (Type Ips W TVD 6025 Tubing 2058 - 2060 - 2060 ' 2060 - PTD 2060650 ' Type Test SPT Test psi! 3000 IA 816 3330 3260 - 3250 ' BBL Pumped: ! 1.2 BBL Returned: 1.2 OA 886 1128 1126 1131 _ Interval] REQVAR P/F P Notes: MIT -IA to 1.2x maximum anticipated injection pressue per AID 28.003, Amended Docket AIO-17-009 MIT -IA to Maximum anticipated injection pressure. Thursday, June 17, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -209 COLVILLE RIV NAN-N CD4 -209 Sre:. Inspector Reviewed By: P.I. Supry TJ >ELl Comm Well Name COLVILLE RIV NAN-N CD4 -209 API Well Number 50-103-20532-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-065-0 Inspection Date: 6/11/2021 - Insp Num: mitLOL210611110640 Rel Insp Num: Packer Well CD4 -209 Type Inj W "TVD PTD 2060650 Type Test SPT Test psi BBL Pumped: 0.5 ' BBL Returned: Interval REQVAR P/F Notes: MIT -OA to 1800 psi per AIO 28.003 Depth 6025 1800 0.5 F Pretest Initial Tubing 2057 2057 - IA 785 885 OA 770 2020 _, 15 Min 2057 - 880 - 1960 - 30 Min 2057 - 880 _ 1840 45 Min 2057 - 885 - 1820 - 60 Min 2057 890 . 1805 Thursday, June 17, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, .lune 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -209 COLVILLE RIV NAN-N CD4 -209 Sre: Inspector Reviewed By: P.I. Supry J Comm Well Name COLVILLE RIV NAN-N CD4 -209 API Well Number 50-103-20532-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-065-0 Inspection Date: 6/11/2021 Insp Num: mitLOL210611122711 Rel Insp Num: Packer Depth Well CD4 -209 Type Inj w- TVD 6025 Tubing - - - - PTD 2060650 Type Test, SPT -Test psi 1800 IA BBL Pumped: 04 - BBL Returned: 0.4 OA Interval REQVAR P/F P Notes: Retest MIT -OA to 1800 psi per AIO 28.003 Pretest Initial 15 Min 30 Min 45 Min 60 Min 2063 2063. 2063 2063 775 865 _ 865 - 873 - 905 2010 - 1895 - 1875 Thursday, .lune 17, 2021 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor ���1 / �9 FROM: Adam Earl Petroleum Inspector State of Alaska .Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -209 COLVILLE RIV NAN-N CD4 -209 Ste: Inspector Reviewed By: P.I. Supry 3fx NON -CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4 -209 API Well Number 50-103-20532-00-00 Inspector Name: Adam Earl Permit Number: 206-065-0 Inspection Date: 6/202019 IUSp Num: mitAGE190623144323 Rel Insp Num: Packer Depth Well CD4 -209 Type Inj w -TVD 6025 - Tubing PTD 2060650 Type Test Sar Test psi 2900 IA BBL Pumped: _ 1.5 ',BBL Returned: 1.1 OA Interval L REQVAR P/17 1 - — Notes: MITIA tested as per AIO 28.003 to MAIP Pretest Initial 15 Min 30 Min 45 Min 60 Min 2042 2042 - 2035 - 2037 600 3250 - 3220 - 3205 585 -- 770- 730 - 730 - Tuesday, July 2, 2019 Page I of I MEMORANDUM State of Alaska Tubing '01' Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, July 2, 2019 P.I. Supervisor 2��1 7l SUBJECT: Mechanical Integrity Tests 627 - ConocoPhillips Alaska, Inc. CD4 -209 FROM: Adam Earl COLVILLE RIV NAN-N CD4 -209 Petroleum Inspector OA 620 Sre: Inspector 1950 - Reviewed By: P.I. Supry J5F-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4 -209 API Well Number 50-103-20532-00-00 Inspector Name: Adam Earl Permit Number: 206-065-0 Inspection Date: 6/20/2019 — IBsp Num: mitAGE190623144814 Rel Insp Num: Packer Well C134-209 . IType Inj w 1,TVD PTD 2060650 - Type Test SPT Test ps BBL Pumped: 0.6 BBL Returned: Interval REQVAR P/F Notes: MIT -OA tested as per AIO 28.003 to I800psi Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6025 - Tubing '01' 40-1' 1041_ 2042 1800 - IA 500. 612 -, 620 - 627 - 0.6 OA 620 2030 1970 - 1950 - P Tuesday, July 2, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 19,2017 Jim Regg P.I.Supervisor rQ g0.11,7 SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC CD4-209 FROM: Bob Noble COLVILLE RIV NAN-N CD4-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-209 API Well Number 50-103-20532-00-00 Inspector Name: Bob Noble Permit Number: 206-065-0 Inspection Date: 6/9/2017 Insp Num: mitRCN170612055517 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-209 - Type Inj W' TVD 6025 Tubing 2060 2063 • 2061 . 2061 • PTD 2060650 - Type Test SPT Test psi 3000 ' IA 570 3300 - 3250• 3240 , BBL Pumped: 1.4 - BBL Returned: 1.4 - OA 568 804 801 • 808. Interval REQVAR P/F P ✓ Notes: MITIA per AIO 28.003 to max anticapated injection pressure of 3000. SCANNED AUG 2 ri, Monday,June 19,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg P.I.Supervisor I( Wz4(i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-209 FROM: Bob Noble COLVILLE RIV NAN-N CD4-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .1g2.-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-209 API Well Number 50-103-20532-00-00 Inspector Name: Bob Noble Permit Number: 206-065-0 Inspection Date: 6/9/2017 Insp Num: mitRCN170612073431 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-209 - iType Inj W 'TVD 6025 ' Tubing 2060 - 2060 • 2061 - 2061 - PTD 2060650 " Type Test SPT Test psi 1800 - IA 607 701 - 708 - 715 , BBL Pumped: 0.6 ' BBL Returned: 0.6 - OA 580 2000 . 1835 - 1815 Interval REQVAR P/F P ✓ Notes: MITOA to 1800 psi as per AIO 28.003 t/ • SCANNED AUG 2 2 2017, Monday,June 19,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim DATE: Friday,November 20,2015 Regg `I ee a 11I I P.I.Supervisor ( , SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-209 FROM: Guy Cook COLVILLE RIV NAN-N CD4-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry'TEC-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-209 API Well Number 50-103-20532-00-00 Inspector Name: Guy Cook Permit Number: 206-065-0 Inspection Date: 11/11/2015 Insp Num: mitGDC151119154326 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We❑ CD4-209 • Type Inj W TVD 6025 • Tubing 2025 • 2024 2025 7 PTD 2060650 1Type Test SPT Test psi 1800 - IA 314 416 - 423 Interval 'REQVAR P/F F ✓ OA 360 2050 ' 1880 ' Notes: AIO 28.003 MITOA.Operator requested to stop test and start again. SCANNED SEP 1 6 2016; Friday,November 20,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,November 19,2015 TO: Jim Regg P.I.Supervisor /ifr' '((c-71jj SUBJECT: Mechanical Integrity Tests ` CONOCOPHILLIPS ALASKA INC CD4-209 FROM: Guy Cook COLVILLE RIV NAN-N CD4-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-209 API Well Number 50-103-20532-00-00 Inspector Name: Guy Cook Permit Number: 206-065-0 Inspection Date: 11/11/2015 Insp Num: mitGDC151112I42801 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-209 Type Inj W'TVD 6025 ' Tubing 2025 _ 2025 -n 2025 - 2025- PTD 2060650 - Type Test SPT Test psi j 1800 IA 423 437 - 448 - 458 - Interval REQVAR P/F P OA 1880 - 2030 - 1980 - 1960 - Notes: AIO 28.003 MITOA to 1800 psi. SCANNED SEP 1 8 2096 Thursday,November 19,2015 Page 1 of 1 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,November 12,2015 TO: Jim Regg P.I.SupervisorPe "t/I741‹ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-209 FROM: Guy Cook COLVILLE RIV NAN-N CD4-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvIT3P= NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-209 API Well Number 50-103-20532-00-00 Inspector Name: Guy Cook Permit Number: 206-065-0 Inspection Date: 11/11/2015 Insp Num: mitGDC151112141209 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 209 Type Inj W' TVD_ 6025 —-Tubing 2025 2025 202s 2024 r PTD 2060650 ' Type Test SPT Test psi I 2573 - IA 348 3750 - 3680 - 3670 - Interval;REQVAR PAF P ✓ OA I 348 , 567 - 555 563 ---- ----- – ---- Notes: AIO 28.003 MITIA to 1.2 times. Max anticipated injection pressure since August of 2015 is 2144 psi. SCANNED SEP 1 6 HIS, Thursday,November 12,2015 Page 1 of 1 20 0`es RECEIVED ConocoPhillips APR 2 7 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SCANNED tv'N" 0 4 2015 April 23, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, gl? 7:2// MJ oveland ConocoPhillips Well Integrity Projects Supervisor Co ocoPhillip Alaska Inc. • Surface C s rig by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 4/23/2015 CD4 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD4-96 50103206730000 21405600 33" N/A 33" N/A 12.3 4/20/2015 . CD4-209 50103205320000 20606500 19' 1.24 20" 4/3/2015 7.6 4/20/2015 CD4-213 50103205400200 21200500 15" N/A 15" N/A 4.5 3/24/2015 • Image Project V11ell 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. p~ Q !~ - ~ ~Q Jr Well History File Identifier Organizing (aone> RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: aria ~- Project Proofing BY: Maria ~: Scanning Preparation BY: Maria Production Scanning P P + ~3 =TOTAL PAGES l l 3 (Count does not include cover sheet) ~ /~~ ©g /s/ Stage 1 Page Count from Scanned File: ~ ! L,T (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES _ BY: Maria Date: 7~a ~ O 8 Stage 7 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~ NO 1 viiiiimuuRUii ReScanned III IIII'I VIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III o..o.ced iuumiuiiiuiu DIGITAL DATA Diskettes, No. I ^ Other, No/Type: Date: Date: „iuumimiiiiil _x30= Date: ~/o o Re,~a~~e~e, iiuuiiiAUOUu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '7 DATE: Wednesday, November 09, 2011 P.I. Supervisor ( 1 f ( 1 ('( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: Jo17 Crisp COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J7I - NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -N CD4 -209 API Well Number: 50- 103 - 20532 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr111031124002 Permit Number: 206 -065 -0 Inspection Date: 10/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 CD4 -209 - Type In j. W . TVD 6025 ' IA 1166 1837 - 1820 1816 - P.T.D 2060650 TypeTest SPT Test psi 1800 ' OA 1769 1837 - 1830 - 1826 - Interval RE P/F P / Tubing 1916 1918 , 1915 1916 - Notes: CMIT IA x OA as per AIO 28.003. Supervisor review for pass /fail determination. .4 bbls pumped for test. .113R- pass — iv • Wednesday, November 09, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 09, 2011 TO: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: John Crisp COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN - N CD4 - 209 API Well Number: 50 103 - 20532 - 00 - 00 Inspector Name: John Crisp Insp Num: mitiCr111031122747 Permit Number: 206 - 065 - Inspection Date: 10/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I CD4 -209 Type Inj. W TVD 6025 IA 1027 1124 1131 P.T.D 2060650 TypeTest SPT Test psi 1800 OA 237 1845 1690 Interval REQVAR P/F F Tubing 1916 1912 1914 Notes: AIO 28.003 MIT OA. f e e C C - ( Z ) 4/1,1:t � C r M O 3 Z ;1 v\ Wednesday, November 09, 2011 Page 1 of 1 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 09, 2011 TO: Jim Regg P.I. Supervisor 1t 1 j 6 11/( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: John Crisp COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry jI� NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN - N CD4 - 209 API Well Number: 50 103 - 20532 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr111031123542 Permit Number: 206 - 065 - Inspection Date: 10/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -209 T ype Inj. W ' TVD 6025 ' IA 1142 1149 - 1151 1155 1158 1163 P.T.Di 2060650 TypeTest SPT Test psi 1800 - OA 1754 ' 1856 ' 1824 - 1805 - 1789 - 1775 - Interval REQVAR p, P - Tubing 1 1914 1912 - 1914 1917 1917 1916 - Notes: Retest MITOA as per AIO 28.003..1 bbl pumped. Supervisors review for pass /fail status. .113R- pass Wednesday, November 09, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg rr DATE: Wednesday, November 09, 2011 ��� l� l( SUBJECT: Mechanical Inte rit Tests P.I. Supervisor � 1 4 g Y CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: John Crisp COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry �60ie--- NON - CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN - N CD4 - 209 API Well Number: 50 103 - 20532 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr111031123101 Permit Number: 206 - 065 - Inspection Date: 10/30/2011 Rel Insp Num: • Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -209 Type Inj. W' TVD 6025 - IA 1131 . 1143 - 1146 . 1147- 1142 P.T.D 2060650 'TypeTest SPT Test psi 1800 - OA 1690 1859 . 1805 -- 1782 • 1754 Interval REQVAR p/F P " Tubing 1914 1915 - 1917 1912 1914 - Notes: Retest MITOA as per AIO 28.003..1 bbl pumped. JBR- pass — c'I t (- t t • 1 11" Wednesday, November 09, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ( DATE: Tuesday, November 01, 2011 / P.I. Supervisor JC' 1 f . 1( SUBJECT: Mechanical Integrity Tests f CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: John Crisp COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv.T.ge- --- NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN - N CD4 - 209 API Well Number: 50 103 - 20532 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr111031122029 Permit Number: 206 - 065 - Inspection Date: 10/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -209 ,' Type Inj. W TVD 6025 ' IA 1225 3867 - 3802 3784 - P.T.D 2060650 I SPT Test psi I _ 3600 - OA 270 532 514 511 , Interval RE p/F P Tubing 1917 1912 , 1915 1915 Notes: AIO 28.003. 1.9 bbls pumped for test. MIT IA. Tuesday, November 01, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 'DATE: Friday, July 15, 2011 TO: Jim Regg fVfr 7//511( P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -209 FROM: Matt Herrera COLVILLE RIV NAN -N CD4 -209 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry j NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN - CD4 - 209 API Well Number: 50 103 - 20532 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110701084051 Permit Number: 206 - 065 - Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -209 Type Inj• W TVD r 6025 IA 850 3150 ' 3080 3050 ' P.T.D 2060650 TypeTest 1 SPT Test psi 3100 - OA 146 167 167 167 Interval REQVAR — P/F P Tubing 2296 2276 2296 2295 Notes: IA tested to 3100 psi 1.6 BBL's. AIO 28.003 ' Friday, July 15, 2011 Page 1 of 1 i S • ConocoPhilii s p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 Commissioner Dan Seamount a:06- 0 (Ls Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 : � a 4 - a°7 Anchorage, AK 99501 * Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD4 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft gal CD4 -07 50103205530000 2071180 6" n/a 16" n/a 3.8 3/13/2011 CD4 -12 50103204140100 2100910 13" n/a 36" n/a 11.9 3/13/2011 CD4 -23 50103206210000 2100670 28" n/a 28" n/a 8.5 3/13/2011 CD4 -24 50103206020000 2090970 16" n/a 16" n/a 4.3 3/13/2011 C04 -26 50103206000000 2090490 26" n/a 26" n/a 8.5 3/13/2011 x4»209. 50103205320000 2060650 SF n/a 16" n/a 4.2 3/13/2011 �/ / CD4 -213 50103205400000 2061730 13" n/a 18" n/a 4.3 3/13/2011 CD4 -322 50103205510000 _ 2071010 SF n/a 16" n/a 4.7 3/13/2011 • • _ SEAN PARNELL, GOVERNOR B ALASKA OIL AATD GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AIO 28.003 Mr. Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. NOV (t P.O. Box 100360 Anchorage, AK 99510 -0360 RE: CRU CD4 -209 (PTD 2060650) Request for Administrative Approval Dear Mr. Walters: An application to continue water injection in CRU well CD4 -209 with a known communication was received on October 19, 2010. The injection order and rule citation are incorrect. Injection into the Nanuq Oil Pool is governed by Area Injection Order (AIO) 28, rather than AIO 18 which applies to the Alpine Oil Pool. In accordance with Rule 11 of AIO 28.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Colville River Unit (CRU) CD4 -209 exhibits pressure communication between the production and surface casings (outer annulus or OA). The Commission was notified of the communication in November 2009. Positive pressure tests performed on the well's inner annulus (IA), OA, have identified a leak at 36' below pad level. Although the flow rate through the leak is small, the IA and OA pressures tend to equalize over time. The Commission finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that CRU CD4 -209 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in CRU CD4 -209 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; AIO 28.003 • • November 1, 2010 Page 2 of 2 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall perform an MIT -OA or IA x OA CMIT every 2 years to 1800 psi; 5. CPAI shall limit IA pressure to 2000 psi and OA pressure to 1000 psi; 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical 'condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and ; ;tMl 8. The MIT anniversary date is November 28, 2009. DOaAnho laska and dated November 1, 2010. O v L an Cathy . Foerster o a, Commissioner om is 'oner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m, on the next day that does not fall on a weekend or state holiday. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 nr 1 9 2010 October 15, 2010 ftsk% 00 &an GODS, Cgmf ; sion ��ttera�a Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per Ajs'1'8, R , to apply for Administrative Approval allowing well CD4 -209 (PTD 206 -065) to be online in water only injection service with IAxOA communication. If you need additional information, please contact myself or Brent Rogers at 659 -7224, or MJ Loveland / Perry Klein at 659 -7043. Sincerely, Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File ConocoPhillips Alaska, Inc. Colville River Unit CD4 -209 (PTD# 206 -065) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 18, Rule 9, to continue injection with known annular communication for Alpine injection well CD4 -209. Well History and Status Colville River Unit well CD4 -209 (PTD 206 -065) was drilled and completed in 2006 as a service well. C134 -209 was reported to the Commission on November 11, 2009 as showing signs of IAxOA communication. The following pertinent operations have been completed to date: Date Operation Result Comment 8/24/10 MITOA Passed 8/16/10 Cement NA Pumped OA cement shoe 4/13/10 LDL NA Identified production casing leak at 36' 11/28/09 MITIA Passed 11/15/09 IC POTS Passed 10/19/09 MITIA Inconclusive Witnessed by Bob Noble (passed AOGCC criteria) 9/28/09 T &IC POTs Passed 7/14/09 MITIA Passed Repair of the production casing leak would require a rig workover and cannot be justified at this time but will be considered should a workover be necessary in the future. ConocoPhillips requests Administrative Approval which will allow the OA to equalize with the IA in water only injection service at a pressure not to exceed 1000 psi. NSK Problem Well Supervisor 10/16/2010 1 • • Barrier and Hazard Evaluation Tubing: The 4 -1/2 ", 12.6 ppf, L -80 tubing has integrity to the packer @ 6446' MD, based on the passing MITIA as outlined above. Production casing: The 7 ", 26 ppf, L -80 production casing has an internal yield pressure rating of 7240 psi and but does not have integrity to the packer @ 6446' MD (6025' TVD) based upon the leak detect log results and pressure trend that illustrate IAxOA equalization in a relatively short period of time.. Surface casing: The 9 -5/8 ", 40 ppf, L -80 surface casing with an internal yield pressure rating of 5750 psi set at 2394' MD (2381' TVD) has integrity based upon the passing MITOA outlined above. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production tubing. Second barrier: The secondary barrier to prevent a release from the well and provide zonal isolation is the surface casing should the production tubing fail. Monitoring Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or surface casing above the conductor shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /I /O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. SVS: Due to the surface casing yield pressure rating of 5750 psi and the maximum anticipated injection pressure of 2600 psi, ConocoPhillips does not intend to install automatic shut -in equipment on the well's outer annulus. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), OA pressure may equalize with IA pressure not to exceed 1000 psi; 2. Perform a passing MITIA or MITT with tubing plug below uppermost packer every 2 -years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum). 3. Perform a passing MITOA or IAxOA CMIT to 1800 psi every 2 years; 4. IA pressure not to exceed 2000 psi & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 10/16/2010 2 y r VVNS Max Ang & MD Wellbore AP`uWl ConocoPhillips Well Attrib Fielq Well Status Inc/ MD ( IR K Inc. 1 °I 1 ) (ftKB) 501032053200 NANU INJ 94.28 7,791.76 ,215.0 A' ,•• Comment 112S (ppm) Date Annotation End Date KB-Grd (tt) Rig Release Date well n .tt ontal 209 a1 01 4: :3 M SSSV: WRDP Last WO: 44.13 6111/2006 emetic -ACWaI Annotation Depth (ftKB) Annotation Last Mod... End Date Last Tag: End Date Rev Reason: RESET INJ VLV Imosbor 4/16/2010 HANG C.aSln Strip S . _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String WL.. String ... String Top Thrtl CONDUCTOR 16 15.250 41,5 118.8 118.8 65.00 H40 Welded Casing Description String o... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String WL.. String_ String Top Third -- - - - - - - - - - - - - - - - - - - - - - SURFACE 9518 8.835 41.4 2,393.8 2,380.9 40.00 L-80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String WL.. String ... String Top Third INTERMEDIATE 7 6.276 37.4 6,994.4 1 6,201.3 26.00 L -80 BTCM Casing Description String C... String ID ... Top (ftKB) Set Depth if Set Depth (ND) ... String WL.. String ... String Top Third CONDUCTOR, LINER Slotted 41/2 3.958 6,839.8 13,205.0 6195.8 12.60 L -80 SLHT 41 -119 Liner Details Top Depth (TVD) Top Intl No L.. Top (ftKB) (ftKB) (') Item Description Comment ID (in) VALVE, 2,001 6,839.8 6,172.4 76.48 SLEEVE BAKER'HR' LINER SETTING SLEEVE 4.420 NIPPLE, 2,001 6,852.8 6,175.2 77.03 NIPPLE BAKER "RS Packoff Seat Nipple 4.250 6,856.6 6,176.2 77.19 HANGER BAKER "DG" Flex Lock Hanger 4.400 - 6,866.5 6,178.6 77.60 XO CROSSOVER 5x4.5" 3.910 13,162.6 1 6,198.2 93.26 BUSHING BAKER Packoff Bushing 2.380 Tubing Strings SURFACE, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (N WL.. D) ... String String ... String Top Thrtl 41 -2,394 TUBING 4112 3.958 28.9 6,847.0 6,173.8 12.60 L -80 ISTM Com tion Details Top Depth (ND) Top Intl Nomi... Top (ftKB) (ftKB) (•) IMm Description Comment ID (in) GAS LIFT, 28.9 28.9 -0.04 HANGER FMC Tubi Hanger w/ 2.28' u 8,339 9 9 .28'p up 3.958 2,001.0 1,996.1 1 10.96 NIPPLE Camco DB nipple 3.812 I 6,445.91 6,025.2 59.53 PACKER jt3AKFR PREMIER PACKER 3.875 6,503.41 6,053.71 61.28 NIPPLE HESXNNipple 3.725 PACKER, 6,446 6,827.2 6,169.6 75195 WLEG Baker Fluted WLEG w/ LOCATOR SUB 3.958 Tubing pup, Other In Hole Wiretine retrievable plugs valves PUMPS, fish etc. 8,454 i Top Depth (ND) Top Intl NIPPLE, 6,503 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 2,001 1,996.1 10.96 VALVE A -1 INJECTION VALVE (HRS -45) w/1.25" ORIFICE 4/15/2010 1 1.250 Perforations B Slots WLEG, 6,827 Shot Top (ND) Stm (ND) Dens Top (ftKB) Btm (fa(B) (ftKB) (ftKB) Zone Date (sh - -- Type Comment 6,991 13,163 6,200.6 6,198.2 NANLB3, NANLB2, 6/9/2006 32 m .0 SLOTS Alteatingslotted/blankpipe NANLB3, CD4 -209 Notes: General & Saf End Date Annotation 7/6/2006 NOTE: TREE: FMC 4 -1/16" 5,000 PSI -TREE CAP CONNECTION: 7" OTIS 61712008 NOTE: SHUT -IN INJECTOR 913/2008 NOTE: VIEW SCHEMATIC wl klaska Schematic9.0 NTERMEDIATE, 37 -6,994 I I , I I : SLOTS. I ' 6,991-13,163 ii Mandrel Details • Top Depth �CAMCO Port OD Valve Latch Size TRO Run Iin) Sery Type Type (inl (psi) Run D 5,966.9 5 1 INJ DMY BK 0.000 0.0 7/17/2009 11 LINER Slotted, 6,840. 13,205 TO, 13,215 Well Name CD4 -209 Notes: Administrative Approval Application Start Date 5/1/2010 Days 180 End Date 10/28/2010 Annular Communication Surveillance 3000 WHP 160 _ IAP OAP 140 WHT 2500 120 2000 i ,00 LL .Q 1500 80 60 1000 40 500 20 0 0 May -10 Jun -10 Jul -10 Aug -10 Sep -10 Oct -10 7000 �DGI 6000 �MGI 5000 �PWI CI m 4000 SWI ° 0000 BLPD U f 2000 1000 0 May -10 Jun -10 Jul -10 Aug -10 Sep -10 Oct -10 Date Y- 9 ~.` STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~. operations Pertormed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other ~, Pump OA shoe Alter Casing ~ Pull Tubing ~ F~rforate New Fbol r Waiver r Time Extension r Change Approved Program (- Operat. Shutdown (- Perforate r` Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 206-065 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~ 50-103-20532-00 7. Property Designation: 8. Well Name and Number. 80077, 384209, 384211, 388903 ALK 3: °° CD4-209 9. Field/Pool(s): Colville River Feild / Nanuq Oil Pool 10. Present Well Condition Summary: Total Depth measured 13215 feet Plugs (measured) None true vertical 6195 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 2001, 6446 true vertical 0 feet (true vertucal) 1996, 6025 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 119 119' 0 0 SURFACE 2352 9.625 2394 2381' 0 0 INTERMEDIATE 6957 7 6994 6201' 0 0 LINER SLOTTED 6365 5.92 13205 6196 0 0 0 0 0 0 0 0 ' ' Perforation depth: Measured depth: Slotted liner from 6991 to 13,163 True vertical Depth: Slotted liner from 6201' to 6198' ~35 ' ~ 1q ~"' w" l 3~ ~`i~a ~''.1't111SS4Dn Tubing (size, grade, MD, and TVD) 4.5, L-80, 6827 MD, 6170 TVD ~~a~~!~" ~.~+ z~ ., ~~t°,ie ~r 't! Packers & SSSV (type, MD, and TVD) VALVE - A-1 INJECTION VALVE (HRS-45) W/1.25" OR @ 2001 MD and 1996 TVD IF IC E ~~ -- -- ~~ PACKER -BAKER PREMIER PACKER @ 6446 MD ana~L;ii~D NONE -Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): ; .r ~ : ~ ~ ~ ~ ~ f`s Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run E~loratory r Development r Service 15. Well Status after work: Oil ~ Gas r WDSPL ~ Daily Report of Well Operations ~' _ GSTOR [` WAG r GASINJ (- WINJ r SPLUG ('"', 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 310-240 Contact Brent Ro ers/Marf Walters Printed Name Br t Ro s Title Problem Well Supervisor Signature Phone: 659-7224 Date ~ ~ ~t9 ¢/~S ~' For 10-404 Revised 7/2009 0_ ~- 3/-:~ S~ubfmit Ofig~l Only ~,~: CD4-209 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/16/10 PUMPED 25 BBL OA CEMENT SHOE DISPLACED WITH 45 BBLS OF DIESEL. PUMPED JOB TO COMPLETION. DESIGNED TOC = ~ 1500' 08/23/10 08/24/10 Summary: Pumped job at ~ 2.0 BPM as follows: 20 bbls. diesel, 20 bbls. CW100 chemical wash, 20 bbls 12 ppg Mudpush, 5 bbls neat 15.7 ppg Arctic Set 1, 15 bbls 15.7 ppg Arctic Set 1 with 2.0 ppb CemNet, and 5 bbls neat 15.7 Arctic Set 1. Job was displaced with 45 bbls diesel and rate was slowed to 1.0 BPM at 35 bbls away, and 0.5 BPM at 40 bbls away MITOA- passed; Initial T/I/0= 640/425/0; LRS pressured up OA T/I/0= 640/500/1800; 15min. reading T/I/0= 640/500/1690; Re-pressured T/I/0= 640/510/1800; 15min. reading T/I/0= 640/510/1760; 30min. reading T/I/0= 640/510/1690; Re-pressured T/I/0= 640/510/1850; 15min. reading T/I/0= 640/510/1850; 30min. reading T/I/0= 640/510/1850 MITOA- passed; Initial T/I/0= 640/425/100; LRS pressured up OA to 1800psi. with .5bbls. of diesel. Start T/I/0= 640/505/1800; 15min. reading T/I/0= 640/490/1780; 30min. reading T/I/0= 640/490/1780 • • Brent Rogers Problem Well Supervisor O ~~ _ ConocoPhillips Alaska, Inc. ~~6 "~ " P.O .Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4-209 , Sundry Number: 310-240 Dear Mr. Rogers: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ~~~ ~ Cathy/P. Foerster Commissioner DATED this ~. day of August, 2010. Encl. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2010 • AU G (~ Z i; Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~ka ~! & Gas Cam. Cammi. ~r~ci~~ar~ve ~~ ~~ Dear Mr. Seamount: ConocoPhillips Alaska, Inc. presents the attached 10-403 Application for Sundry Approval to pump an OA shoe on CD4-209. The request for the OA shoe is in order to apply for a subsequent AA for water injection only with IAxOA communication. If you need additional information, please contact me or Martin Walters at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, Brent Rogers. Problem Well Supervisor ConocoPhillips Alaska Inc. Attachments ., ..~-i~ • RBDMIS AUG 0 9 ~0 STATE OF ALASKA `~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~ 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill j'"• Perforate New Pbol (- Repair wep r Change Approved Program r " Suspend r' Plug Perforations r F~rforate ~"' FUII Tubing r' Time Extension ~ Operational Shutdown r• Re-enter Susp. Well r Stimulate r Alter casing r" Other. Pump OA shoe ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Inc ConocoPhillips Alaska Development (" Exploratory ~ 206-065 , . 3. Address: Stratigraphic r" Service ~ . 6. API Number. ' P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 7. If pertorating, Gosest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number. where ownership or landownership changes: Spacing Exception Required? Yes (`~ No ~ CD4-209 9. Property Designation: , 10. Field/Pool(s): ADL 380077, 384209, 384211, 388903 ALK 380077 Colville River Feild / Nanuq Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13215 6195 ' Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 119' 119' SURFACE 2352 9.625 2394' 2381' INTERMEDIATE 6957 7 6994' 6201' LINER SLOTTED 6365 5.92 13205' 6196' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted liner from 6991' to 13,163' Slotted liner from 6201' to 6198' 4.5 L-80 6827 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) VALVE - A-1 INJECTION VALVE (HRS-45) W/1.25" ORIFICE MD= 2001 TVD=1996 PACKER -BAKER PREMIER PACKER MD= 6446 TVD= 6025 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: ' " Exploratory r Developme ' nt r Service ~ BOP Sketch r Detailed Operations Program ( 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/5/2010 Oil ~ Gas ~ WDSPL ~ Suspended ~ 16. Verbal A royal: Date: Pp WINJ t`" GINJ r WAG ' ~ Abandoned ~ GSTOR r SPLUG r Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers/Martin Walters Printed Name Brent Ro erS Title: Problem Well Supervisor Signature / Phone: 659-7224 Date 07/30/10 C mmi ion U Onl +-~ Sundry Number. ?J" 1 ~ ~ _ 1 ~f G'~ V Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~° BOP Test ~'" Mechanical Integrity Test ~'" Location Clearance ~'-' ~~~U ~ ~ L.~~li Other: ±~laska ~ ~ Gas C~'~, Ctalrtmiss ~ ;ILA Jf~3QP. Subsequent Form Required: /O ._ `7/ GY ~o~~ // / ~ ~ t A APPROVED BY / ~.....,.sa ti.,• ~ 9. ~ 0/ % l~ ~ /~ nC~9I~I~~J~1 I\ ~ THE COMMISSION Date: ~'- ~-` / ~~' n f=nrm 1r1~n3 Ravicp 1/~(11n ,~`r ubmit in DutS~icate • • ConocoPhillips Alaska, Inc. Alpine Well CD4-209 (PTD 206-065) SUNDRY NOTICE 10-403 REQUEST 07/30/10 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine wag injection well CD4-209. A surface casing cement shoe was not pumped at the time of original completion in 2006. CD4-209 was originally reported to the AOGCC for suspected IAxOA communication on 11/25/09. The cement shoe is required in order to verify integrity of the surface casing in order to send in an AA application for continued water injection with IAxOA communication. The well's primary barrier is the 4.5" tubing. If the cement shoe remediation is successful (resulting in a passing MIT-OA to 1800 psi), there will be confirmation of the integrity of the surface casing. Surface casing integrity was confirmed to 1200 psi during an infectivity test that was performed on 05/28/10 in preparation for pumping the shoe. If the cement shoe remediation is unsuccessful (resulting in a failing MIT-OA), further diagnostics will be undertaken to identify the location and severity of the leak. Pending results, an administrative relief request will be submitted for approval to return the well to water only injection. With approval, the OA cement shoe will require the following general steps: 1. Pump 25 bbls of cement into the OA. y~~/~ 2. Displace cement with 45 bbls of diesel freeze protection for a calculated cement topp at . 1511' MD. , ozt~R ~"~tf~ x ~ s" _ `(3 BESL 3. Wait 48 hrs on cement 4. MITOA to 1800 psi. 5. Submit 10-404 to AOGCC. ~ ~~ ~~ w~r,1J6~~ ~~(~ ~~~ NSK Problem Well Supervisor ~ 8/32010 w,.~ ~}" 7 s~ << eus-~ Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 23, 2010 12:23 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 fPTD 206-065) Report of suspected IAxOA communication Thanks much. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, June 23, 2010 12:21 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication We will submit a 10-403 once the design is finalized. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, June 23, 2010 12:18 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Martin, Do you have a sundry for that operation? k ~ , a~:> _ ~ `~ ~~"~ Tom Maunder, PE ~'~~°~'"~"`~ "~''~`" ~~ ~ ~ ~~ AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, June 23, 2010 12:16 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Tom, CPAI performed a step rate injection test on the CD4-209 ou#er annulus on 05/29/10. According to the test, we are capable of achieving sufficient injection rate which allows us to proceed with pumping an OA cement shoe. We will plan to execute the job when the design and resources are available and plan to continue water only injection until that time. Martin From: NSK Problem Well Supv 7/1/2010 Page 2 of 3 Sent: Wednesday, May 05, 2010 9:31 AM To: 'Maunder, Thomas E (DOA)' Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David ]; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Perry Klein is our resident cementing expert who is off the Slope and will not return until 05-12-10. Once he returns we should be able to make an informed decision within his two week hitch and proceed towards implementation. Martin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov} Sent: Wednesday, May 05, 2010 9:27 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Thanks much. What sort of timing do you foresee regarding the resolution options you mentioned? Tom From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, May 05, 2010 9:16 AM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Tom, The welt is and has always been a water injector. The leak rate is relatively low and was estimated to be 0.15 gpm at 2000 to 2500 psi during the LDL. Martin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 05, 2010 9:05 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Walker, Jack A; Neville, David J; Reed, Scott; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Martin, Some questions ... 1. What is being injected into the well? 2. You have identified a leak. What sort of leak rate was identified? Thanks in advance, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com} Sent: Wednesday, May O5, 2010 8:44 AM 7/1/2010 Page 3 of 3 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; Walker, Jack A; Neville, David J; Reed, Scott Subject: RE: CD4-209 (PTD 206-065) Report of suspected IAxOA communication Tom/Jim/Guy, On 04-13-2010 CPAI performed an ultrasonic leak detection log on the CD4-209 while pumping down the IA and taking returns up the OA. The survey identified a production casing leak at 36' MD. ConocoPhillips intends to continue injection while a repair plan is evaluated. Options we are currently considering are: AA status quo, AA post OA cement shoe, Seal-Tite, and Brinker Platelets/Plasma. The appropriate paperwork will be submitted as necessary. Please contact me at your convenience if you have questions or comments. Attached is a 90 day TIO plot and schematic. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 i Well Supv November 25, 2009 7:48 PM nas E (DOA)'; Regg, James S (DOA); Schwartz, Guy L (DOA) dell Supv; NSK Well Integrity Proj 19 (PTD 206-065) Report of suspected IAxOA communication Tom, Jim, Guy Alpine injector CD4-209 (PTD 206-065) was reported to have suspect IAxOA communication and has been added to the monthly report. The current TIO is 1682/540/540. The well passed a witnessed MITIA on 10/19/09 after being converted to injection. Diagnostics will be done in order to identify the source of communication if possible. It is ConocoPhillips intention to continue injection while diagnostics are performed. Pending the results of the diagnostics, the appropriate paperwork will be submitted to continue injection. Please let me know if you have any questions. Attached is a schematic and a 90 day TIO plot. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 « File: CD4-209 90 day TIO plot.jpg » « File: CD4-209 schematic.pdf» 7f 1/2010 • • ~: ~~` ~~ ~~ Vt r ~ 4 ~~ ~~ ~. ,- t a. , 4~ « ~.~ , s .~ ... MICROFILMED 6/30!2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~ WELL LOG S TRANSM/TTAL PeoAcrive Dincnosric SeevicES, Inc. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection - WLD 13 Aprv10 CD4-209 2) v~~ a~ -oc~5 i9~5 5. BL / EDE 50-103-20532-00 ~;r~ar; Vii'- ~ ~ e, ~,,~ _ C:\Documents and Settings\Diane Willisms\Desktop\Tiansmit_Conoco.docx MEMORANDUM TO: Jim Re ~ ~G~' ~ gg ~~(?ei<~ L- r~ P.I. Supervisor FROM: RCN CiJebi~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November O5, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-209 COLVILLE RIV NAN-N CD4-209 Src: h~spector NON-CONFIDENTIAL Reviewed By~ P.I. Suprv ~°'' Comm Well Name: COLVILLE RIV NAN-N CD4-209 API Well Number: 50-103-20532-00-00 Inspector Name: RCN Insp Num: mitRCN091105102011 Permit Number: 206-065-0 Inspection Date: 10/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---- ' r 6026 - IA ~ 529 CD4-209 T~ Well ~ 650 ,yTYPe InJ• rs T-' -- p -~ --- - - ----- -f- -- ~ D TypeTest I TCSt Sl 2493 OA 400 P T ~ -- ~-2493 / 2468 i 2454 ~ 2444 / -- - -~--- -+--- - 402 ~ 402 402 ~ 402 ~ . . ----~ ------- --~------- ~ - --- Interval IMTAL p~F P / --- - - - Tubing 1628 - -E-- ---~ --~----- 1628 1628 ~ 1628 i 1628 _~-_ Notes: ~~~~ n ~ 'I~s~ f~s~~~- , ~ ~~~ ~ ~~~.~~~~~~ d1~-~ ~ ~D~C; Thursday, November O5, 2009 Page I of 1 • • STATE OF ALASKA ALASKA OIL AND GAS COMSERVATION COMMfSSION Mechanical tnte+grity Test Email to:jim.regg~alaska.gov; tom.maunder~,lalaska.garv;bob_ftecicerutein~afaslca.gaAe;doa.aogcc.prudhce.bay~alaska.gov OPERATOR: CanacoPhi~Eip~ Al~ka ~nc.. FIELD / UNIT / PAQ: A(pine / CRU / GD4-20~ DATE: 101'19/09 OPERATOR REP: Co~ee/~'h~i~s AOGCC REP: Bob ~ot~ie Racker Pretest In~i 15 Min_ 30 Min. WeII CD4209 T In'. W 'NL3 6,426" T" 1,628 't,628 1,628 1,628 Ir~terval I P.T.D. 2060650 T te.st R Tesk ` '~5~k7 C~i 52~ 2,493 2,468 2,454 PIF P Notes: Initial MITIA post injec~~ OA 4(3a ' 402 -002 402 45 minute = 1628/2444l402 Well T In'_ TVD T" Interval P.T.D. 7 test 7es~ ' Gasi P/F Notes: OA Well T In'. TVD T~ Interval P.T.D. T te~ Test ' Casi P/F Notes: OA Well T In'. 7'1lD Tvtri Interval P.T.D. T test Test " Casi P/F Notes: OA Well T In"~ TVD Tubi Interval P.T.D. T test Test ~ P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Artnule~ AAoni~ring P = S1ar~ard Pr~su~e T~t R= lr~teGt~eal Radioactiv~ Traeer Sucvey A - Ternperaa,re nnort~iy sur,~er D= - ' T T~ ~;~~,~~~~ F,~ r~ ;~ ;~ ~' ~t1C~~ ~~Ca ~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Otfier (describe i~ notes) MIT Report Form BFL 11/27/07 MIT CRU CD4-20910-19-09.x1s ~,~CEIV~D • STATE OF ALASKA • OCT 1 ~ 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~laskaQil&GasCons.Commission Anrhnrsnra 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other Q convert to injector Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter S spended Well ^ 2. Operator Name: COnOCOPhillips AIBSka, InC. 4. Well Class Before Work: Development ^ Exploratory ~ Permit to Drill Number: 206-065 / 3. Address: Stratigraphic ^ Service ^~ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 7. KB Elevation (ft): ~ Well Name and Number: RKB 56' CD4-209 8. Pre~erty Desigt~ation: r, ~ 0. Field/Pool(s): ADL 384209, 384211, 388903, 380077 Colville River Field / Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured `~ 13215' feet true vertical ~ 6195' feet Plugs (measured) Effective Depth measured 13215' feet Junk (measured) true vertical 6195' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2334' 9-5/8" 2390' 2377' PRODUCTION 6939' 7" 6995' 6202' SLOTTED LINER 6365' 4.5" 13205' 6196' Perforation depth: Measured depth: slotted liner from 6840'-1 3215' MD true vertical depth: 6172'-6195' ,,-; Tubing (size, grade, and measured depth) 4.5" , L-80 , 6849.5 Packers & SSSV (type & measured depth) Baker premier pkr @ 6448' Camco DB nipple @ 2003. 5' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daify Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation not applicable -- Subsequent to operation 3419 -- 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X . Well Status after work: C)il^ Gas ^ WAG ^~ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-241 Contact Jack Walker @ 265-6268 Printed Name Jack Walker Titie WNS Production Engineer Signature ~~ Phone: 265-6268 Date ~ ,~ ~7 ~ ~ / Pre r haro All ake 63-46 2 V Form 10-404 Revised 04/2006 ~ ~~~~'hS ~~~~~~~ ~i. /o~/G• ay Submit Original Only ` CanotoPhiilips Ai.:s~-s. hx; _ ••• Wel C.mRg; Hmi2arrtel.:_..D42~ .. _ _ __..._ _-' _.. SU~ern.euc =Ac HANGER.3t - ~ _._,.!:::1~.^4 CONDUCTOR,_ 41-119 'u~in9 VuP. 121 - VALVE.2.OOM1 SURFACE, 41-2.394 GAS LIFT, 6,3a1 'Aq(ER, 6,d48 TW in9 P~P. s.as~ NIPRE,fi.506 WLEG.6,830 35-6.99a SLOTS. fi.991-13.163 LINER Slonetl. 6,653~13.205 ` T0.13215 WNS ~ CD4-209 ell Attributes j Max A ngle u MD _: 1 U IboreAPVUWI ~FieldName WaIlStatus 'Incl(°) MD(ftKB) ActBbn~ftKB) 501032053200 NANUQ iSHUT-IN '~ 9428 I 7,791J6 13215.0 ent ~H2S(ppn~ ~Date ~Mnotation '~.EntlDate 'HB-Grd(fl) ~RigReleaseDat~ SV: WRDP ~ Las~ WO: ~~. ~ 44.13 6l11/2006 iotation ~'~,Depth (NKB) End Date ~Mnofation , Last Motl By ,End Date Casin Descn 9 Ptp^ Strin 0... Strin ID ... 9 9 I To (HKB) P Set De th t... P ( Set De th ND P ( I-. String WI.... String ... String Top Th~d CONDUCTOR I 76 I 15.250 41.5 118.8 178 8 I 65.00 H-00 Weltled Casing Description 'IString 0... ~;String ID ... Top (HKB) Se~ Dapth (1... Set Depth (ND) ... Ii String WI._ String ._ String Top ThN SURFACE I 95/8 ' 8.835 41.4 2,393.8 2.380.9 ~~~ 40.00 L-80 BTC Casing Descnption String 0... String ID._ Top (HKB) Se~ Depth ((... Se~ Depth (ND) ... I String WI... String ... String TopThid ~INIERMEDIATE ~ 7 6276 34.9 6,994.4 l 6,2013 26.00 L80 ~ ~ BTCM ~Casin Descri g ption String 0... String ID ._ Top (ftKB~ Set Depth (f... Set Dapth (ND) .. String Wt._ ~ Str g... String Top Thrd '~,LINERSIOttetl 41/2 3.958 6,8528 13,205.0 6,195.8 12.60 L-80 SLHT Liner Details ~ 'iTOpDepih ' I (ND) Top Incl I P( , To HKB (ftKg) (°) Item Dascription ~ Comment ID (in~_ _. .__. _" - . _ _ ~ 6,852.8 6, 7752 77.03 4250 NIPPLE "RS Packoff Seal Nipple 6,856.6 6,17fi2 77.19 HANGER ~"DG' Flez Lock Hanger 4.400 6,86&5 6.178.6 77.60 XO ~XO ~--- ~ ' 3910 i 13.162.6 6,7982 9326 BUSHING '~packoHBushing ~, 2.380 Tubing Strings Tubing Description String 0 Set Depth (ND) . Siring Wt... IStr g IString Top ThM TOp (ftKe) Set Dapth (f... ._ String ID ... TUBING I 412 I I I I l 3.958 314 6,849.5 6.1744 1260 j L80 IBTM Completion De ,ToPOePm I tails _ _ _ .._.__.. . - ~ (ND~ Top Incl I Top (HKB~ (kKe) I (°) Itam Dascriptio~ ~ Comment ID (in) ~~ 31 A, 31 A' ~ -0.03 3.958 HANGER ~FMC 7ubing Hanger w/ 228' pup 2,003.S I 1,998_6 10.96 NIPPLE iCamco DB nipple 3.812 6,448.4I 6,026A 59.60 PACKER ~IBAKER PREMIER PACKER 3.875 6,505.91 6,054.9 ~ 61.35 . _.. _. . _- - _- - _ 3J25 NIPPLE ~HES XN Nlpple 6,829-7~ 6.1702 76_06 . ; ..-_. . ____.. W~EG ~Baker Outetl WLEG w/ LOCATOR SUB 3.958 Other in Hole ireline retrievableplu s, valves um s fish etc. Top Dapt~ (TVD) Top Incl ~, Top(HKB) (ftKg) I (°) Description ~i Comment RunOate ID(in) I 2,004 . 1,998.6~ ~ 10.9GVAWE iq-1 INJECTIONVAWE(HRS-53)w/125"ORIFICE 7/17/2009 1250 ~ I ..__ . ...._.._- - ___ .'_._ Perfora tions & Slots i sha Top (ND~ Btm (iVD) ~^s Top (flK6) BM (kKBj . (kKB) (flK8) Zona Date (sh-~ Type Commeirt 6,991 13.163 I 6,200.6 6,1982 NANL83, 6/9/2006 32.0 SLOTS ANemating slotted/blank pipe NANL82, I I NANL83, ~~Notes: General CD4-209 l8 Safet ~ I ' End Date ' Annotation 7/6l2006 ~NOTE~. TREE: FMC 4-1/16" 5,000 PSI - TREE CAP CONNECTIOM 7" OTIS 6(7l2008 ~~,NOTE: SHUT-ININJECTOR 9/3/2008 INOTEVIEWSCHEMATICw/AlaskaSchematic9A . _. Mandrel Details ITOpOapth ToP j .... __... ~ Por~ I ~ (ND) Incl ~ OD Valve Latch ~~ Size TRO Run SN Top(ftK6) (ftK6) (°) Maka ~. Modal (in) Serv Typa Type (~~) (psi) RunDate Can... 1 6,3412 5,968.4 56.34 CAMCOIKBG2 1 INJ DMY BK i0.000 _.0.0 7J17/2009 CD4-209 (permit 209-065) Conversion Sundry Maund~r, Thomas E (Df,~A} Frs~m: M~und~r, Th+~mas E (DOA) Sent: Monday, Jaly 2'~, 2QQ9 3:22 RM To; 'Walk~r, Jack A' Cc: 'Altsup-Qrake, Sl~aron K' ~~ubJec#: R~; CD4-2Q9 (permit ~f~ 65) ConversiQn Sundr~ - AGA1N Js~~c ~r~d ~h~rc~ra, ~~~~~~ r~~~, ~r~ ~~`~ n~!~r~~ i~ ~~ 5, ~~t ~~9 ~. ~"~rr~ .---- ~ronn: Maunder, Thc~mas E (UQA) Senk: Monday, .7uly 27, 2409 ~.i.8 PM To: 'Wall~r, ]a~k A' =- ~,~ , ; . , ~ ~~~~. ~~~,~~ ~~ i,l f; 1~ ~ ~D~° GG: Alisup-~rake, Sharon K Suaje+ct: RE; cL?4-2n9 (pern,it 2E? ~) ~onversian sunary J~~ ~rsd ~~~r~n, ~c~rrr~ ! wv~~ d~l~~r~ r~piyin~.. ~"h~n~~ in ~9~~n~, ~`~rr~- ~~~~~~r, ~~ ~C?~~~ J~~t ~h~k 1M~~ ~-~ #~~ 4~4 ~~d ir-~lud~ ~ ~py ~~ ~i~ ~~ ~~r ~t.. Fr~m; 1Afali~er, .7ack A [mailto:.~ack.A.Walker~a eonocophillips,eom] 5~nt; Wednesday, 7~uly z2, 2t)09 8;22 AM To: Maunder, Thamas ~ (~AA) Cc: AI{su~-Qrake, Sharon I~ Subject: Cf}4-2f}~ (pe~rmit 2f~ S} Gonver~ion Sur~dry Page 1 of 1 Torn, 1 noticed on a 10-4~J3 form submitted to convert CQ4-2fl9 from d~v~lopment to nrice class, we incorr~ctiy checkeci WINJ in box 16. A~fier the prQ~os~ad wQck 4n GG4~2Q9 (peemit 5)> we nEed ~ 1lVAG w~tl ~tatus. Ptease let m~ k~ow if t n~d to foliow up with anythinr~ els~ to irnple t thi~ rsquest, and please ~ccept our apol~gy fpr any confusion thi~ may cause. Jaek W~Iker CanocaPhitlips Alaska, lnc. Western I~ortl~ ~lope ~evelopm~:n# 265~268 ~f2'~/2Q09 • ~ ~ s°r:` `'t ~` e'; ~ ~'° ;""; ~ ~ ~°. % -F` ~ i n ~ ~ :~ ~f ~ ~ ~ ~ ~ - 4 C ,~ 5 ~ ~~ ~~~ ~ ~ ~ ~ ' f C ~ ~ ~ {! i i f ~ e 8 ~ ~ '' ~ ~ y . ~ +. a ~ ~' ~ ~. ~k ~ ~at a c~ 4, ~` e~ r , ~ ~ ~` . _ -. ~ ~~."° € $ <m_ ~_ ~. ~<S ~~ ¢.,,,~~ \ ~' f g A,~" ~ p ~~ ~ ~ i~ ~ ~ ~~ 1l~iA-SBA Du A1~D G~ CO1~T5ERQATIOI~T COMI~II5SI011T Mr. Jack Walker Production Engineer ConocoPhillips P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Rool, CD4-209 Sundry Number: 309-241 • i d~, SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 t_.. ~ (o~ ~~ V ' ~~;`' A~ ~~ ~ ;~ 2D~~ ~~ f~~a~ .~.~ Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, conta.ct the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commiss:on 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 af this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~~ day of July, 2009 Encl. C/1'~ ~O 1 STATE OF ALASKA • ~~C~~~ ~~x ~~ A~ SKA OIL AND GAS CONSERVATION COMMISSION ~. ~u~ ~~;.;; ,} APPLICATION FOR SUNDRY APPROVAL ~~~~ 2o,~c 25zso :~iaska Oii ~ ~as C~ > ~, ~;~.~r~ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~~~a`w ~' Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ ~nvert to injector Change approved program ^ Puli Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhiliips Alaska, Inc. Development ~. Expioratory ^ 206-065 ' 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ CD4-209 ' 9. Property Designation: J~ ~ ~T~ 3 ~ %~ ~ 10. KB Elevation (ft): 11. Field/Pool(s): L ~- - D~-. ~7 iG~ ADL 384209, 384211~ 388903 , RKB 56' Colville River Field / Nanuq Oil Pool . 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth nno (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13215' • 6195' • 13215' • 6195' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 2334' 9-5/8" 2390' 2377' PRODUCTION 6939' 7" 6995' 6202' SLOTTED LINER 6365' 4.5" 13205' 6196' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 6840'-13215' MD 6172'-6195' 4.5~~ L-80 6849.5' Packers and SSSV Type: Packers and SSSV MD (ft) Baker premier pkr @ 6448' Camco DB nipple @ 2003.5' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service 0~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 7, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ~~ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ftyan Shirtliffe @ 265-6371 Printed Name R hlrt ~ff Title: WNS Production Engineer Signature Phone 265-6371 Date ~4 /,d p Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _a~~ . Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~O ~ APPROVED BY ~ / 7~~ I Approved by: O MISSIONER THE COMMISSION Date: ~~}~~ r Form 10-40~Revised 06/2006 ~}-~ ~~~ j~ [~ ~ ~ub it in Du licate 1 ~ /1 ~~'~ .l"~ ~ /~•~ .. CorlocoPhillips :ll„~,~_~, hx: HANGER,31~ F.~.~~:~.~~aucas~ coNOUCroa. <1.119 fuDng qq. ~ 1~ VALVE, 2,M3 SURFACE. a~.z.3sa GAS L IFT 1. 6.3a1 PACKER, 6.N8 TuDn9 WP. 6 05] NIPPLE,6.508 WLEG.6.830 SLOTS. fi,991-13.163 ID (in) pipe OD ~I (in) Cortvn... WNS • CD4-209 weu Am~aUCeS Well~oreAPIIUWIIFieltlName WeIISta~uslProtl/InjWellType Ilncl(°) MD(ftK6~ TD(max~(fl... 501032053200 NANUQ SHUT - IN 94 28 7,191 J6 ~~i 13,215.0 Gomment M25 (pqn) ~ Da~e ''.Annotation Entl Date KB-Grtl (fl) Rig Ralease Data SSSV~ WRDP I Last WO: _ 44.13 6l11/2006 Annofation IDep~h (ftKB) EnA Date Mno~a~ion "Entl Data Last Tag~ ~ I Rev Reason: RESET INJ VAWE I 7118/2008 Casin $t(ifl S __' __ Casing Description String 0... String ID ... Top (itK6) Set Depih (t... Set Deplh (ND) ... String Wt... String ... Stting TopThrd CONDUCfOR i6 15250 41_5 118.8 118.8 65,00 H-40 Weltled ,Gasing Description Shing 0... String ID ... Top (ttKB) Set Depih (t... Set DepM (ND~ ... String Wt... String ... String Top T~rd SURFACE I 95/8 8.835 41A 2,393.8 2,380-9 4000 L-80 B1C i Gasing Description String 0... String ID ... Top (1tKB) Sat Depth (t... Set Depth (ND) ... String Wt... Strin9 ... String Top ThN l INiERMEDIATE J 6276 34.9 6,994.4 6201.3 26.00 L-80 BTCM ' Casing Description SVing 0... String ID ... Top (HKB) Set Dep[h (i... Set Dep[h (ND) ... String Wt... String ._ String Top ThrA LWERSIOned 41/2 3.958 6,852.8 13,205A 6.7958 12.60 L-80 SLHT Liner Details I TopDep~~~ T- - i ~~ Top (ftNB) (TVD) ' (NKe) ~ Top ' ~~~~ (°) nem Description Comment ID (in) ' 6,852.8 6,1752I 77.03 NIPPLE "RS Packoff Seal Nipple 4250 6,856.6 I 6,1762 77.19~HANGER "DG" Rex Lock Hanger 4.400I I 6.866.S 6.178.6 77.60~X0 ~Xp .. .- -~ ~ 3.910~ Depth (NO) ... ~ Top (ftK6) I ~'~^6~ '~~~~ (°1 ~ Mem Description I Lomment 31.4~ 31.4 -0.03IHANGER FMC Tubinq Hangerw! 228' pup 2,003.5 1,998.6 10.96~NIPPLE CamcoDBnipple ~PACKER BAKER PREMIER PACKER 6,445.4 6,026.4 59.60 6,505.9 6,054.9 61.35INIPPLE HESXNNipple ~ ~~ PoA Valve '~, Lafch Size TRO Run S~ Type . Type (n) (psi) Run Date 1 INJ ~'~~IOV iBEK-2 1/4 0.0 7/152006 LINER Slotted. fi,653-13.205 ~ ~ ~ TD. 13.115 ~ ~ Maunder, Th~ma~ E D4A From: Waiker, Jack A [Jack.A.Walker~conocophillips.com] Sent: Thursday, July 16, 2009 5:13 PM To: Maun OA) Subject: RE: CD4-209 (206-065 and CD4-214 (206-145) Attachments: ~ CD4-209 SCMt 09June2006 Print.PDS ~ ~Y., GD4-209 SCMt Q9June2QQf F'rint.... Tom, CD4-209 (permit to drill 206-065) had a Schlumberger Memory Cement Bond Log ~un Q9- Jun-2006 (PDS file enclosed) with good bond that demonstrates isolation of injection fluids to the approved interval, i.e, Nanuq Oil Pool. 'The mechanical condition of the well is good based on a preliminary (non-witnessed) mechanical integrity test. I'11 review the CD4-214 BAT log, sundry application and provic~e a response soon. Jack Walker GonocoPhil.lips Alaska, Inc, Western North Slope Development ~~~~t~',~j~q~~~, ~~~ ~~ ~Y .~ ~ 265-6268 "` ~~~~ -----Original Message----- Fzom: £~Iaunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Thursday, July 16, 2009 3.00 PM To: Walker, Jack A Subject; FW; CD4-209 (206-065) and CD4-214 (206-145) «CD4-26 Convert to Injector 9 7 2009 (2),doC» Hi Jack, Here is the message I got back when I sent a message to Ryan. Can you help me here? All that was sent was the sundries and wellbore drawings. Can you provide some sort of "statement" document that assesses t~e cement isolation and coneludes it is effective or in question. Thanks, Tom Maunder, PE AOGCC I will be on holidays fram July 17-July 26th, then relocating ta Calqary. Pl~ase call me on cell at 907-575-7839 for anything urgent. Scale associated items call Tim Schneider, CD4 items piease call Jack YJalker. Thanks, Ryan -~----Oriqinal Message----- From: Maunder, Thomas E (DOA) Sent: Thursday, July 16, 2009 2:53 PM Ta: 'Shirt~iffe, Ryan` Subject; CD4-209 (206-065) and CD4-214 (206-145) Ryan, I have received the sundries incTuding a wellbore drawinq, but that is all, I need a document for each similar to what you sent for CD4-26, We had earlier exchanged emails regarding GD4-214 where you indicated that a water flow log would be run due to the p~ssimistic BAT sonic. Email is fine, I look forward to your reply. 1 _~ ' ' ~ I~C~3ANICAt ~~~~'X R~ORT ~ ~, ~ ~p "' ~ ~ ~ . ~ ~ ~~~~v~~ =~v~ ~~ ~~ : : ~ ~a~'0 ~ op~ ~ F~ c'~ [~'~ C~~ : sG ~5?~~~ ~~ : ~ ~~,~ ' ~ Ca ~r`iZL NUMBER , ~ ~.~ ~` ~~' ~1,~ ;~-~~. ~~~~ sia: ~~~i~.~~ ~ t~s~ • =~sn : t~ s?-~ ~ ~i,5 rsm _....._.. ~ . _""'""""" ~ • Casir,g : ~ ~ Shoe: ~~i.~1~ MD ~O ~O~ TVD s ~Y : ~ '~Q ~ •';'V"D ~ -~-----~- .~.~ :.,~.;~er : ~t~- Shoe : .MD ..,,,, ~ ; '~G~' : ~ ~ ~ ..,...,.....__ z~ ._____""' ` Co ~`1.~ _ uo:.:: g:~~`~,~,~ ackez ~I~ _,,,_____~_1'~ s S e t~~ . ,_iole S#~e ~3 ~~„_,_ aad t Perfs ~~ tc ~~ ' ~ ~` ~L"?~1+lIC~S iNTEGRITY - ?ART # ? . ' . ~anuius S rass T~st: ~..'~~s ~5 ~~,.~.._.~ ~~ ~. Com~aae~sts : ` ~~zK _~ , . ~tc.~d~ ~Q v0'"~ ~ ~----~- ~~~b~,s . ~ ~c~~ca~. zxrrECRt~ - p~~ # 2 Ce~enz Va3vm~g : ~imt. Lirser ~l~ _ : Csg ~~~,,.,-~ DV ~ ~ . Cmt ~aol to cove_ ~ ~ ~ c~~~ ~~ ~ ^~ ~ ~ ~ ~~~~ ~~--h~~~, ~... - - _ _ _ -- . . x Q~ T_heQretical TflC ~°-'~~~Z~,1~, S"~' S~S~~ .~ C~~C. ~~ ».r_.__-~_. _..r~ J5-O~ C~menr Hond Log tyes oY No)~~~,~-~,-t In At~GCC File C8L :.valuation, ~one above p~r~s c,~~~~r~'«`r~~,,.~,. `? c~ ~= -~ .~ ,., t C1 Froducation 7rag: Type~ ~s Evalu~tioa CONCLUSip~iS : ?'srt ~ 1 ' ?,a.r ~ ¢ ? ::.:: ,, 4,,< A ConocoPhillips ~~~ ~~~~ ~~~ Alaska ~ ~~ ~~~~~ ~®~ P.O. BOX 100360 ~~®~ ~~ ANCHORAGE, ALASKA 99510-0360 ~ ~ ' ~~®~~~~~ March 19, 2008 ~~"~~ ~`~~~ °' "~~~` Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 ~ ~ ~ Q Anchorage, AK 99501 ~,~ ~. - . q Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry ~G~~~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18!2009 CD4-30fi 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214` 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-209 July 17, 2008 AK-MW-4406583 CD4-209 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20532-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20532-00 Digital Log Images: 50-103-20532-00 ~,;~~~~~~ AU ~ ~ °; ZOU$ i.q~ 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: v z ~ ~U~- o~S /(~~15 ~~ ,w DATA SUBMITTAL CO PLIANCE REPORT 6/25/2008 Permit to Drill 2060650 Well Name/No. COLVILLE RIV NAN-N CD4-209 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20532-00-00 MD 13215 TVD 6195 Completion Date 6/11/2006 Completion Status 1WINJ Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D D Asc Directional Survey 37 13215 Open 7/19/2006 ~ D C Asc 13987 Induction/Resistivity 0 0 Open 7/19/2006 Text // yED C Lis 13987 Induction/Resistivity 0 0 Open 7/19/2006 LIS , Rp~~t 13987 InductionlResistivity loo Cement Evaluation 0 0 Open 7/19/2006 5 Col 1 5700 6856 Open 7/25/2006 Mem CBL, MEM GR, CCL, CBL, VDL 09-Jun-2006 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~-1•P!/ Analysis ~`}d'- Received? Interval Start Stop Sent Received Sample Set Number Comments Daily History Received? Formation Tops ~Y N f'~41! N Comments: Compliance Reviewed By: Date: . ~ Page 1 of i Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.comj Sent: Wednesday, July 25, 2007 11:23 AM To: Maunder, Thomas E (DOA) Subject: RE: CD4-319 (205-148) an CD4-209 (206-065 ~1 Tom, CD4-319 started injecting on December 2, 2006. It's production test period ended in March 16, 2006. CD4-319 was shut in during the interim, waiting on drill site facilities. CD4-209 acid treatment was pumped on April 12, 2007. The following is a more complete CD4-209 treatment report from 4/12!07 than the original 10-404: Lay in 12% HCl acid from 13,155' to 6,991' CTMD with coiled tubing. Pump acid at 1.7 bpm while taking returns to tanks. CTP pressure = 3100 psi, with average WHP ~ 280 psi. Freeze protect well to 2000' MD with diesel. Please let me know if there is any other info needed. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Wednesday, July 25, 2007 10:55 AM To: Walker, Jack A Subject: CD4-319 (205-148) and D4-209 (206-065) Jack, You recently submitted 404 reports of sundry operations for these wells. A little further information is needed. CD4-319 -would you provide the date that the well was converted from a producer to injector. CD4-209 -- would you provide the date when the welt was stimulated. Thanks in advance. Tam Maunder, PE AOGCC 7/25/2007 STATE OF ALASKA ~U~ O J 2Q0~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION"~ska OiI & Gas Cons. Commission 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^/ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 206-065 ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 ` 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD4-209 ' 8. Property Designation: 10. Field/Pool(s): ADL 384209, 384211, 388903 Colvile River Field/Nanuq Oil Pool ? 11. Present Well Condition Summary: Total Depth measured 13215' ~ feet true vertical 6195' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2334' 9-5/8" 2390' PRODUCTION 6939' 7" 6995' SLOTTED LINER 6365' 4-1/2" 13205' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6847' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at 6446' SSSV = 2100' MD 12. Stimulation or cement squeeze summary: Pump 193 Bbts. 12% HCI acid from 13,155' to 6,991' CTMD w/coiled tbg. Intervals treated (measured): 6,991' to 13,155' ~S~IIAS BFL ,1UL ~ ~ 2QQ? Treatment descriptions including volumes used and final pressure : CTP pressure = 3100 psi, with average WHP = 280 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.o. Exempt: 307-110 contact Jack Walker Printed Name Ja k alker Title Production Engineer c , W Si nature f` I 9 Phone 265-6268 Date , ~ 3 a7 ~=~.-- U Pre ared b Jeanne Haas 263-4470 Form 10-404 Revised 04/2006 ORIGINAL ~~r~S i~~'~~'~ Submit Original Only t~'~t~7 ~ ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,1UL 0 5 2007 AlasiCa 0i! & Gas Cons. Commission Anchora n 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 206-065 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD4-209 8. Property Designation: 10. Field/Pool(s): ADL 384209, 384211, 388903 Colvile River Field/Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured 13215' feet true vertical 6195' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2334' 9-5/8" 2390' PRODUCTION 6939' 7" 6995' SLOTTED LINER 6365' 4-1/2" 13205' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6847' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at sacs' SSSV= NIP SSSV= 2001' 12. Stimulation or cement squeeze summary: ~u~ 2 3 200, Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _X Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OiIO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-356 contact Jack Walker Printed Name Jack Walker Signature fi ~/~, ~ Title Phone 265-6268 Production Engineer Date f ~ ~ ~ ~ ~ V v Pre ared J a as 26 70 n `~J Form 10-404 Revised 04!2006 ORIGINAL ~~(~~ ~T~o,~, ~D ?' ig~sl Submit Original Only CD4-209 Operations Sequence of Events June `06 Completed as second horizontal well in Nanuq Sand. ~ Aug '06 Initial 24 hr flowback. Shut in. Dec '06 Extended flowback via CD4 facilities. Similar response to initial flowback. Shut-in. Jan '06 CT diesel washed upper 56% of drilled interval. Jan '06 Production test. Performance unchanged. Shut in. ~ Apr ' 07 CT tractor acid wash 100% of drilled interval Apr ' 07 Production test. Performance unchanged. • • U ~~ .T V O N 0 U O r O M .-. L `/ O ~ O M O N (!sd '8 ad081S) dH8 '8 a~e~ I!O O O O O O O O O O ~ C'7 N ~ Greater flow period did not improve performance. Proceeded to CT diesel wash to clean up MOBM. 4000 0 ~ 3000 m ~, 2000 .~ 0 °~ 1000 a~ ca O 0 0 20 40 60 80 100 120 140 Time (hr) CD4-209 Coil Tubing Diesel Wash Horizontal Section - 6219 Feet Nanuq 5 GR Deep Res Lobe 4 - - Lobe 3 Lobe 2 _ - ~ __ `I Y~`~~ MAf~IfuM,'~yN~ O N d' U i 7" Casing Pt-6996' Log Display by Knock Maximum CT depth Job Summary: Jet liner with 120°F diesel from top of slotted liner to 10,394'MD at 1.7 bpm. 290 bbl diesel injected, 326 bbl returns. Trace solids in returns. • CT diesel wash had no effect on well performance. Proceeded to tractor-conveyed CT acid treatment. 4000 0 O m 0 U O ^L L.L 3000 2000 1000 0 0 20 40 60 80 100 120 140 Time (hr) Remedial operations had no effect CD4-209 performance. CD4-209 Allocated Well Tests 2000 4000 1500 a O m H ~ 1000 ~a 0 500 0 ^ • --- -_ ! - ----- extended FB 12/1 /06 12/31 /06 1 /30/07 3/2/07 t CT Diesel Wash • Oil Rate • GLR • FGOR ^ ^ Tractor CT Aci~ 100% 4/1 /07 •I U .~ 2000 ~ t~ 0 u~. 0 Jim Ennis Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Unit, Nanuq Oil Pool, CD4-209 Sundry Number: 307-110 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this? day of April, 2007 Encl. ao~-o~s- Chairman STATE OF ALASKA ~~~ ~ .2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~'R APPLICATION FOR SUNDRY APPROVA~~~k~ 0~1 & Gate Cons. Commission 20 AAC 25.280 „__~_._..., 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate /^ ~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ ' Exploratory ^ 206-065 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^~ - CD4-209 9. Property Designation: ~ a 10. KB Elevation (ft): 11. Field/Pool(s): ADL 384209, 384211, 388903 RKB 56' Colville River Unit / Nanuq Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13215' - 6195' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 114' 114' SURFACE 2334' 9-5/8" 2390' 2377' PRODUCTION 6939' 7" 6995' 6202' SLOTTED LINER 6365' 4-1/2" 13205' 6196' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted from 6991'-13163' 4-1 /2" L-80 6847' Packers and SSSV Type: Packers and SSSV MD (ft) Baker pkr @ 6446' Camco DB nipple @ 2001' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 77, 2007 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam Ennis Title: Wells Group Engi eer Signature c ` .~,.'`"" Phone -°~~ Date `~ 3 G Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness • Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~b OO ~S ~ Mt ~ ~F~, ~i'~ ~ ~ 200% Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ Form 10-403 Revised O6/200~~ I ~~ ~~/~/ Submit in Duplicate C~7 ' ' v , ~~_ v~ ~ D y, ~. • CD 4-209 CT Acidize Nanuq Lateral Network#: 10168926 ...Procedure:. 1. MIRU 1.75" CTU w/ pipe straightener. Nipple up BOP & test as per SOP. 2. .Utilizing 6% KCL seawater drift 3/" ball through CT string, note the minimum rate required to get the ball around the reel and over the gooseneck. 3. Make up BHA consisting of: ^ Connector for 1-3/4" CT (1.4 ft) ^ 3-1/8" MHA with 3/" circulation valve ball seat (2.75 ft) ^ X-Over to 4.7" Short SA (-1 ft) ^ Single 3-1/8" WeIITec Tractor (--23 ft) ^ X-Over to 1.7" Short SA (~1 ft) ^ Jetting nozzle (~ 0.5 ft) 4. RIH to end of liner @ 13,205 ft. - Predicted lockup depth without tractoring is between --11,600 ft - Start pumping 6% KCL seawater at 1.5 bpm to begin tractoring once lockup ~s reached - - Tractor is predicted to provide sufficient force to reach the end of liner - Minimum rate for tractor operation is 0.4 bpm. 5. -Drop 3/" ball to activate the circulation valve. Pump the ball around the reef and over gooseneck while holding the CT in place. 6. Pressure up to shift open circ port and pump 6% KCI seawater max rate at 3800 psi until clean returns are seen at surface while keeping the CT stationary. 7. Switch to 12% HCI (226 bbls/ 9492 gals) w/additives as follows: ^ HCI Acid H036 - 2539. gals ^ Miscible Solvent U067 - 949 gals ^ Surfactant F103 - 17 gals ^ Corrosion Inhibitor A261 - 42 r~als ^ Corrosion.Inhibitor Aid A201 --47 gals ^ ..Non-emulsifying Agent W054- 42 gals ^ Anti-sludge Agent W060 - 42 gals ^ Iron Stabilizer L058 - 170 Ibs 8. When the acid reaches the circ ports (reel volume = 35.5. bbls) POOH at 50 fpm and lay in acid at 3800 psi pump pressure (estimated @ 1.8 bpm) until reaching the top of slotted liner @ 6,991 ft - .Depending on maximum rate achieved at 3800 psi, it may be required to adjust the -POOH speed to ensure all the acid is placed in the slotted liner 9. Displace acid w/diesel and freeze protect tubing to 2000' MD while POOH. RD CTU. 10. RU PWS flowback equipment & tanks. Flow well to tanks until acceptable PH for plant is achieved. May need to kick well off with nitrogen gas lift. RD flowback equipment. Jim Ennis Page 1 4/3/2007 - - ~ k 1 Ct3r~lc~ct~~'t~tiliips Alaska, ~C1C« TUBING .CD4-209 (46847, API: OD:4.500, SSSV Type: ID:3.958) SURFACE Annular Fluid: (0-2390, OD:9.625, Reference L Wt:40.00) I aaT Tan• PRODUCTION (assss, OD:7.000, Wt:26.00) PACKER (6446-6447, OD:5.970) NIP (6503-6504, OD:5.000) SLEEVE (sBao-sa53, OD:5.790) NIP (6853-6856, OD:5.600) SLOTTED LINER (6840-13205, OD:4.500, Wt:12.60) Perf (6991-13163) ALPINE CD4-209 I Well T e: INJ An le TS: d Orig 6/11/2006 Angle @ TD: 93 deg @ 13215 Com letion: Last W/O: Rev Reason: GLV C/O, Pull RHC. Ball. Rod Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD VYt Grade Thread SURFACE 9.625 0 2390 2377 40.00 L-80 BTC PRODUCTION 7.000 0 6995 6202 26.00 L-80 BTCM CONDUCTOR 16.000 0 114 114 68.00 H-40 WELD SL_ O_ TIED LINER 4.500 6840 13205 6196 12.60 L-80 SLHT ~`„ Tubin Strin -TUBING ~ Size To Bottom TVD Wt Grade Thread 4.500 0 6847 6174 12.60 L-80 IBTM Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 6991 -13163 6202 - 6198 6172 32 6/9/2006 SLOTS Alternating slotted/blank ie Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 6339 5968 CAMCO KBG-2 OV 1.0 BEK-2 0.250 0 7/15/2006 DCK2 Other 'Iu s, a ui ., et c. -COMPLETION JEWELRY De th ND T e Descri ion ID 29 29 HANGER FMC TUBINGHANGER 4.500 2001 1996 NIP CAMCO DB NIPPLE 3.812 6446 6025 PACKER BAKER PREMIER PACKER 3.875 6503 6053 NIP HES'XN' NIPPLE 3.725 6827 6169 WLEG w/Locator BAKER FLUTED SHEAR INDICATING WLEG ASSEMBLY w/LOCATOR SUB 3.958 Other 1u s, a ui ., et c. -LINER JEWELRY De th TVD T e Descri tion ID 6840 6172 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 6853 6175 NIP BAKER'RS' PACKOFF SEAL NIPPLE 4.250 6856 6176 HANGER BAKER 'DG' FLEX LOCK HANGER 4.400 13163 6198 BUSHING BAKER PACK-OFF BUSHING 2.380 13203 6196 SHOE BAKER 'V' SET FLOAT SHOE 0.000 General Notes Date Note 7/6/2006 TREE: FMC 4-1/16" 5,000 PSI TREE CAP CONNECTION: 7" OTIS BUSHING (13163-13164, OD:4.970) • Conoc Philli S Casing Detail 9 5/8" Surface Casin_g ~ aa6-~6S" Well: CD4 - 209 Date: 5/10/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 37.20 FMC Gen V Hanger 2.19 37.20 Jts 3 to 61 59 Jts 9 5/8" 40# L-80 MBTC Csg 2267.90 39.39 Weatherford Float Collar 1.41 2307.29 Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg 78.39 2308.70 Ray Oil tools (Silver Bullet) 2.50 2387.09 2389.59 TD 12 1/4" Surface Hole 2400.00 12 1/4" Hole @2400 ' MD / 2386' TVD 9 5/8" Shoe @ 2390' MD /2377 ' TVD RUN TOTAL 36 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8 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, 59 ~i.} ~ A ~ 65 joints in the pipe shed. Run 61 joints Last 4 joints stay out Use Best-o-Life 2000 i e do e MU torque _ ft/Ibs Remarks: Up Wt - 170k Dn Wt - 135k Block Wt - 75k Supervisor.• D. Mickey Cement Detail Report C D4-209 Surtace Casing Cement Primary Job Type Job Category AFE I RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10136182 5/24/2006 5/25/2006 6/11/2006 - - Cement Details - - -- --- I _ - -- Description ~ --- - -- - Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/27/2006 18:45 5/27/2006 20:36 CD4-209 Comment ',Cement Stages - -- - - Sta e # 1 - -- -- -- _' Description Objective Top (ftKB) Bottom (ftKB) Full Retum? Cmnt Rtrn {... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,390.0 Yes 89.0 Yes Yes Q (start) (bbl/min) Q (end) (bbllmin) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 570.0 1,100.0 Yes 2 0.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives _ iFluid -- - - - - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) 'Glass Volume Pumped (bbl) Lead Cement 0.0 1,890.0 302 240.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.15 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,890.0 2,390.0 232 G 50.0 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Fluid - -- Fluid Type Fluid Description -- Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 1, 890.0 1,890.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) Additives Additive Type Concentration Conc Unit label Page 1/5 Report Printed: 10/10/2006 Daily Drilling Report CD4-209 ~,,:.~ Report Date: 5/27/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 4 2.17 2,400.0 2,400.0 0.00 CD4-209 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 5/25/2006 DOYON 19 NANUQ Development AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10136182 4,742,126.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,390.OflKB Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Testing BOPE 276,395.02 829,058.40 24hr Forecast Daily Mud Cost Cummulative Mud Cost PU 4" DP - MU BHA #2 - C/O shoe track -FIT -Drill 8 3/4" hole 9,819.02 34,784.40 Last 24hr Summary Wiper trip f/ 2400' to 893' -RIH to TD - Circ hole clean -POOH on TT- LD BHA General Remarks Weather Head Count 34/28 WC/ E @ 7 mph 46.0 -- -- Supervise: Title --- - -- Dave Burley Rig Supervisor Time Log_ Start rn~f C_u '. Tm~~ it D,Fir R~art Depth End ~ Tame I,n~a I r° . Phase Op Code OAS.: i., P-tJ T Tiol C .; z Tit I Clan= itF H'. (ftKB) t, r i 'O~~ i .li,n _ 1 _.. _ --------~ - - ------ 00:00 03:45 3.75 SURFAC DRILL WPRT P 2,400.0 890.0 Wiper trip f/ 240U' to 1154' w/ pump @ 550 gpm wi 70 rpm -Continue wiper trip f/ 1154' to 890' w/ pump @ 450 gpm w/ 70 rpm 03:45 04:30 0.75 SURFAC DRILL TRIP P 890.0 2,400.0 Flow check well (static) RIH f/ 890' to 2400' -hole in good condition -wash last 80' to btm. 04:30 05:30 1.00 SURFAC DRILL CIRC P 2,400.0 2,400.0 Circulate hole clean - 650 gpm @ 2100 psi @ 70 rpm 05:30 07:00 1.50 SURFAC DRILL TRIP P 2,400.0 890.0 Flow check (static) POOH on TT f/ 2400' to 890' -hole took proper fill -hole in good condition 07:00 08:30 1.50 SURFAC DRILL TRIP P 890.0 73.0 Flow check well @ BHA (static) Std back HWDP & NM flex DC' & jars f/ 890' to73' 08:30 10:15 1.75 SURFAC DRILL PULD P 73.0 0.0 LD BHA -down load MWD - LD UBHO, MWD, motor & bit (' bit look in very good shape) Clean up rig floor 10:15 12:00 1.75 SURFAC CASING RURD P 0.0 0.0 PJSM - RU to run 9 5/8" casing 12:00 12:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held perjob ops & safety meeting w/ crew 12:15 15:00 2.75 SURFAC CASING RNCS P 0.0 1,650.0 Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) 39 jts csg to 1650' 15:00 15:30 0.50 SURFAC CASING CIRC P 1,650.0 1,650.0 Break circulation -Circulate btms up @ 5 bbls/min -ICP 340 psi -FCP 320 psi 15:30 17:00 1.50 SURFAC CASING RNCS P 1,650.0 2,390.0 Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1650' to 2350' - 18 jts (61 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/fluted mandle hanger on landing ring w/ float shoe @ 2390' & float collar @ 2307' - LD Frank's fill up tool -Blow down TD - MU cmt head & lines 17:00 18:30 1.50 SURFAC CEMENT CIRC P 2,390.0 2,390.0 Establish circulation -Stage pump up to 6.5 bbl/min - Circulate & condition hole & mud for cmt job -ICP 430 psi FCP 320 psi (circulated 440 bbls) 18:30 18:45 0.25 SURFAC CEMENT SFTY P Held pre op & safety meeting w/ crew Latest BOP Test Data Page 1/2 Report Printed: 11/15/2006 Daily Drilling Report CD4-209 Report Date: 5/27/2006 Time Loy err I r r r ~c I [~ ; Y_~ F' nsc- ~ ~F Cede OpSub-Co.. i Trrr ~' N T - -- -- Trbl CcJe ~. ~ - -- T t Class D ath Start ~ RK6j Depth End (ftKE1 ~, randvNGi etion 18:45 20:30 1.75 SURFAC CEMENT DISP P 2,390.0 2,390.0 Dement 9 5/8" csg as follows :Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 3000 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 240 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 220 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top ', plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 155 bbls 9.6 ppg water base mud -Displaced @ 6.5 bbls/min for first 135 bbls - slowed pump to 3.5 bbls/min for last 20 bbls -Bumped plug w/ 1150 psi (prep bump pressure 570 psi) Check float (held OK) CIP @ 20:36 hrs. -Full circulation throughout job w/ 89 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 30 bbls of displacement 20:30 21:30 1.00 SURFAC CEMENT OTHR P 2,390.0 2,390.0 Rig up & test 9 5/8" casing to 2500 psi for 30 mins. - Blow down lines - RD 21:30 22:30 1.00 SURFAC CEMENT PULD P 2,390.0 2,390.0 RD cement lines & head - LD landing jt. 22:30 00:00 1.50 SURFAC DRILL RURD P 2,390.0 2,390.0 ND surface riser -__ _ - - 'Mud Check Data ~ E ~s3c Gel (10s) 1 n~ra rnl H I Hr F c CJ_n_iry l emp Solids, Corr --... .-____ _- ~~,,,,~cLSt'i MBl - ~ ~ ~~ ~ ~ ~~ Type Depth (ftKB) Dens (Ib/gal) Vis (slgq i-V Lan; Qcpj ~ I JGft') (Ibf1100ft') h~ 1 C )ff i ~ U,U~,j ~ i ~ WI f F; (~ l Water 2,400.0 9.65 71 22A 19.000 12.000 26.000 30.000 27.5 8.8' 8.5 Based Mud ~Ilnjection Fluid -- - Fluid ource l - ---------From Lease (bbp - - -- Destination N ?e~ Dlesel 15.0 CD4-319 ;freeze protect Water Based Mud ~~~ ~ 560.0 CD4-319 f! CD4-209 Wellbores _ _ Wellbore Name Wellbore APIIUWI CD4-209 50103205200 Section S¢e {~rY Act np {ftKR)' Act Btm (ttKB. Start D-~b~ ~ Er , Darn - - --- INTRM2 --- -_ - COND 1 36 36.7 114.0 1 /24/2006 1 /26/2006 SURFAC 12 1/4 114.0 2,400.0 5/25/2006 5/26/2006 INTRMI 8 3/4 2,400.0 7,005.0 5/29/2006 5/31/2006 PROD1 6 1/8 7,005.0 13,215.0 6/8/2006 ___ - - - Cement Surface Casing Cement -Started 5/27/2006 Type Wellbore String Cement Evaluation Results casing CD4-209 Surface, 2,390.OftKB Stg No. Description Top (ftK6) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 0.0 2,390.0 4 570.0 Ffufd c~~~"-- i a~,o~~,tf;~ ,, oers,ry0 ~ X ~ Eststm t< ~ estr~:~~,rrrce) ~rlefdtn°rs ~ 70 10 302~ - 240.0 LeatlCement 4 45 1,890.0 0.0 Tail Cement G 232 50.0 15.80 1.17 1,890.0 2,390.0 1,890.0 1,890.0 Page 2/2 Report Printed: 11/15/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-209 Rig: Doyon 19 Date: 5/29/2006 Volume Input Volume/Stroke Pum a Rate: Drilling Supervisor: D. Mickey Pump used: I #z Mud Pump ~ ~ --- -- - - Strokes I, ~ 0.1000 Bbls/Strk ~ 8.0, Strk/min ~ Type of Test: Casing Shoe Test LOT/FrT ~ Pumping down USE LIST ~ Casin Test Pressure Inte rit Test Hole Size: ' 1z-1/4" ' ~ Casin Shoe Depth Hole De th Pum in Shut-in Pumpin Shut-in RKB-CHF: 37.2 Ft 2,390 Ft-MD 2,377 Ft-TVD - _-- 2,420 Ft-MD 2,406 Ft-TVD - Strks si Min si Strks si Min psi Casing Size and Description: 10-3/4" 45.5#/Ft L-8o BTC I ~ 0 0 0 2540 0 40 0 780 Casin Test Pressure Int e rit Test 2 180 1 2540 1 100 0.25 620 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 4 480 2 2540 2 200 0.5 580 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 18.0 Lb/100 Ft2 6 680 3 2540 3 340 1 570 Test Pressure: 2,500 psi Rotating Weight: 150 Lbs 8 1000 4 2540 4 470 1.5 Rotating Weight: 0 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1180 5 2540 5 630 2 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1400 6 2540 6 700 2.5 5 Estimates for Test: 2.5 bbls Estimates for Test: 1038 psi 1 bbls 14 1600 7 2540 7 750 3 560 ~ ~ 16 1840 8 2540 8 780 3.5 555 EMW =Leak-off Pressure + Mud Weight = 630 + 9 6 PIT 15 Second 18 2100 9 2540 9 790 4 550 . 0.052 x TVD 0.052 x 2377 Shut-in Pressure, si 20 2340 10 2540 10 790 4.5 550 EMW at 2390 Ft-MD (2377 Ft-ND) = 14.7 620 21 2540 15 2540 11 780 5 550 3000 Lost 0 psi during test, held 1 00% - 20 2540 12 5.5 550 - - - _ - of te st pre ssure. 25 2540 13 6 545 30 2540 14 6 5 540 zsoo - - . 15 7 540 - _ _ _ _ - -- _ 16 7.5 540 8 535 2000 - 8 5 530 w . ~ - - 9 530 1500 - - - 9.5 530 y --- - w -- - 10 53 ~ - _ - - a _ 1000 - -- - - ~, -- - - __ - - -- t - - 500 - - - - _ - 0 o , z 3 o s , o , s Z o i s ~ ~~CASING TEST Barrels --L EAK-OFF TEST S hut-I O PI n tim T Poin e, M t inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back s s s s Comments: Tested casing after bumping plugs on cement job. • ConocoPhilli s p Casing Detail 7" Casin_g • Well: CD4209 Date: 6/2/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.95 FMC Gen V Hanger 2.61 34.95 Jts 3 to 163 161 Jts 7 " 26# L-80 BTCM Csg 6866.74 37.56 Weatherford Float Collar 1.31 6904.30 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.92 6905.61 Ray Oil Tools Float Shoe 2.06 6992.53 6995.14 TD 8 3/4" Hole 7005.00 8 3/4" Hole TD @7005' MD /6204' TVD 7" Shoe @6995' MD / 6202' TVD Total Centralizers: 43 Straight blade centralizer one perjt on jts # 1-14 Straight blade centralizer one perjt jts. # 107,108, 109, Straight blade centralizer one per jt on every other joint Starting @ # 111 to # 161 Top Nanuq - 6790 ' MD - 6160' TVD 179 joints in shed -163 total jts. to run Last 16 jts. out Use Run & Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 220 k Dn Wt - 145k Block Wt - 75k Supervisor.• D, Mickey / L. Hill Cement Detail Report CD4-209 Production Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10136182 5/24/2006 5/25/2006 6/11/2006 Cement Details - - - Description Cementing Start Date Cementing End Date -- - Wellbore Name Production Casing Cement 6/2/2006 04:30 6/2/2006 05:50 CD4-209 Comment Cement Stages _ __ Sta e # <Sta a Number?> Description Objective _ _ -Top (ftKB) Bottom (ftKB) Full Retum? _ Cmnt Rtrn (... Top Plug? Btm Plug? Production Casing 6,150.0 6,995.0 Yes Yes Yes Cement Q (start) (bbl/min) O (end) (bbl/min) O (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 526.0 1,029.0 Yes 2 5.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8~ Additives -- - - - - -- - - Fluid _ -- - _- - Fluid Type Fluid Description Estimated Top (ftKB) Est 8trn (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Production Cement 6,150.0 6,995.0 175 G 37.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (°~) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 Additives Additive Type Concentration Conc Unit label Retarder 6155 0.05 %BWOC Additive Type Concentration Conc Unit Zabel Antifoam DO 46 0.2 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Page 1/5 Report Printed: 10/10/2006 Daily Drilling Report CD4-209 Report Date: 6/2/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 10 8.17 7,005.0 7,005.0 0.00 CD4-209 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 5/25/2006 DOYON 19 NANUQ Development AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10136182 4,742,126.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 6,994.9ftKB Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost Making MADD pass. 493,817.58 2,237,922.21 24hr Forecast Daily Mud Cost Cummulative Mud Cost Drill shoe track. MADD pass TOC. Drill 20'. CBU. FIT. Change to MOBM. Drill ahead. 4,100.58 125,350.21 Last 24hr Summary Cont. Running 7" csg .Land w/ shoe @ 6995' -Circ & Cmt 7" -Test csg to 3500 psi -Set & test pack-off - PU DP & BHA to 4,694'. General Remarks Weather Head Count 28 Deg Wind SW @ 18 MPH 51.0 - - S,pervisor - - - Title Dave Burley Rig Supervisor Larry Hill P.iq Supervisor (Time Loa Sta ~ ~ n t Tv Time Dui (hrs) phase Op Code OpSub-Co-.. Time p-N-T Trb4Code '~3 th End ~~, D ;.tn Start '~. ep - - --.._.__... TrblCda;~ it1KG1 (ftKB) 'i CorimlOp~rahc~n 00:00 00:15 0.25 INTRMI CASING RNCS P 4,694.0 5,121.0 Cont. running 7" 26# L-80 MBTC csg f/ 4694' to 5121' - 10 jts.( 120 jts. total) 00:15 00:45 0.50 INTRMI CASING CIRC P 5,121.0 5,121.0 Break circ -stage pumps up to 6 bbls/min ICP 510 psi FCP 430 psi 00:45 02:30 1.75 INTRM1 CASING RNCS P 5,121.0 6,995.0 Cont. running 7" 26# L-80 MBTC csg f/ 5121' to 6956.83' - 43 jts (163 jts. total) PU FMC fluted hanger & landing jt. -Land csg w/ shoe @ 6995' & FC @ 6904' 02:30 03:15 0.75 INTRM1 CEMENT PULD P 6,995.0 6,995.0 RD csg equipment - RU cmt. head & lines 03:15 04:15 1.00 INTRMI CEMENT CIRC P 6,995.0 6,995.0 Break circ -stage pumps up f/ 2 bblJmin to 6.5 bbls/min - Circ & condition for cmt job -ICP 600 psi FCP 520 psi 04:15 04:30 0.25 INTRM1 CEMENT SFTY P 6,995.0 6,995.0 Held PJSM w/ crew 04:30 06:00 1.50 INTRM1 CEMENT DISP P 6,995.0 6,995.0 Cement 7" 26# L-80 MBTC as follows: Pumped 5 bbls water -Test lines to 2500 psi -Pumped 30 bbls CW-100 -Dropped btm plug -Mixed & pumped 37 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 243 bbls 9.6 ppg LSND mud @ 6.9 bbl/min -slowed pumps to 4 bbls/min @ bumped plug w/ 1000 psi - CIP @ 0550 hrs. -Checked floats OK - Full circulation throughout job 06:00 06:30 0.50 INTRM1 CEMENT OTHR P 6,995.0 6,995.0 Test 7 "csg to 3500 psi for 30 mins. 06:30 08:30 2.00 INTRMI CEMENT PULD P 6,995.0 6,995.0 RD cmt. head - LD landing jt. -Pull thin wall wear bushing -set & test pack off to 5000 psi 08:30 10:30 2.00 INTRMI WELCTL EORP P 6,995.0 6,995.0 PJSm -Change top pipe rams f/ 7" to 3 1/2" X 6" VBR - Test to 250 & 5000 psi -pull test plug -set wear bushing 10:30 13:00 2.50 INTRMI DRILL PULD P 0.0 1,700.0 PU & RIH w/ 57 jts. 4" drill pipe f/ pipe shed 13:00 14:00 1.00 INTRMI DRILL TRIP P 1,700.0 0.0 POOH & std back pipe in derrick -19 stds 14:00 14:30 0.50 INTRMI DRILL PULD P 0.0 0.0 PU BHA components to rig floor 14:30 17:00 2.50 INTRM1 DRILL PULD P 0.0 300.0 PU 6 1/8" BHA - 17:00 18:00 1.00 INTRM1 DRILL PULD P 300.0 399.0 PU and RIH HWDP. Shallow tested MWD. 18:00 00:00 6.00 INTRM1 DRILL PULD P 399.0 5,921.0 -- RIH picking up DP from pipe shed to 5,921'. - - - Mud Check Data ~ YP Calc Gs ~. ~ I 1 r; Get (3f ~; HTHP Filt li~,^ ~ Temp ~a>, Corr. ~ Type Deptn ~'~h6~ Jens tiwyelj '/is (s/qt) PV Calc {ep) (Jbfl100IP} , {Ibf. .,.,.,) ~ .. , ..,:, : j QbN10C 1', MCiT (IblGb,) (mLf30min) pJ i F' t Water 7,005.0 9.80 37 12.0 18.000 11.000 17.000 18.000 20.0 9.2 9.5 Based Mud Latest BOP Test Data Comrrrc ! ~ Page 1/2 Report Printed: 11/15/2006 Daily Drilling Report CD4-209 Report Date: 6/2/20061 - I~ection Fluid - -- - Fluid Source R~_,nLease{W.:^ ~ Destination - Nola- - - ----- --- ~-- ------- . Diesel 58.0 Freeze protect CD4-209 Recycled mud 1400.0 CD1-19 From CD4-209 Recycled mud 9.0 Annunal LOT CD4-209 Water 300.0 Annular flush CD4-209 - _ `-- Drill Strin s: BHA No. 4 - Steerable 1 Bit Run No. 3 - 6 1/bin, Halliburton Securi DBS , FSF2553Z, 10835487 Depth In (ftKB) 7,005.0 Depth Out (ftKB) 7,005.0 TFA (incl Noz) (ins) 0.45 Noules (l32") 14/14/14 IADC Bit Dull 0-0-NO-A-X-I-NO-DTF String Wt (10001bt) 10 WOB (max) (100... 0 WOB (min) (1000... 0 Drill String Components Jls I~u;~ U~ ~ oven ~~ OD (in) IL! hr~; ~ 1bo Cann Sz (in) fop Thread Cam Len ,`!/ 1 Geo Pilot 4 314 1.500 3 1/2 NC 38 17.28 1 Drill Collar -Flex Non Mag 4 314 1.500 3 1/2 NC 38 28.82 1 Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 32.41 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 40.97 1 MWD GR/RES 4.73 1.500 3 1/2 NC 38 65.15 1 MWD (Dir & Logging) 4.7 1.500 3 1/2 NC 38 76.01 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 87.14 1 Float Sub 4.66 2.313 3 1/2 NC 38 89.48 1 Stabilizer (Non Mag) 4 3/4 2.250 3 1/2 NC 38 95.01 1 MWD Batt Sonic 4.7 1.250 3 1/2 NC 38 123.88 1 NMDC 4.68 2.250 3 1/2 NC 38 148.97 1 NMDC 4.56 2.250 3 1/2 NC 38 179.97 1 NMDC 4.52 2.250 3 1/2 NC 38 210.85 1 XO Sub 4.8 2.563 4 XT 39 213.50 3 HWDP 4 2.563 4 XT 39 305.53 1 Drilling Jars - DNT 4 3/4 2.000 4 XT 39 337.53 2 HWDP 4 2.563 4 XT 39 398.90 _ - _ _ __ Drilling Parameters _ - __ - __-- Ui dli q T~me ~ a'uom c H' I r' .: i5 Uo,v) T- Dr I ~rt Y. F'i Fn i F 6~ ~ r~; (mir ~ft C.,rr DrF U~ frrc Int I _uC_i ill -~'r') WON II[~t ~ f F't~t i'p SFP I,.'; Drill J ~ I,u(~5.0 r 005.0 0.00 0.00 0 ~~ 0 ~_~ 0.0~ ~ Wellbores - - - -_ Wellbore Name Wellbore API/UWI CD4-209 501032053200 --- __ Bestir ~ 'Size (ini As' Top ,ftKB) Act Btm (ftKB) - i a ~ D-pia Erid Date INTRM2 COND 1 36 36.7 114.0 1 /24/2006 1 /26/2006 SURFAC 12 1/4 114.0 2,400.0 5/25/2006 5/26/2006 INTRMI 8 3/4 2,400.0 7,005.0 5/29/2006 5/31/2006 PROD1 6 1/8 7,005.0 13,215.0 6/8/2006 Cement Production Casin Cement -Started 6/2/2006 Type Wellbore casing CD4-209 String Intermediate, 6,994.9ftK6 Cement Evaluation Results Stg No. Description Production Casing Cement Top (ftKB) 6,150.0 Bottom (ftKB) 6,995.0 Q (end) (bbl/... 4 P (final) (psi) 526.0 Fluid Class Amount (sacks) V (bbp Density {IWga[} Yel d (ft /sack) '~.£st T op (ftKB) Est Btm (ftK63 Production Cement G 175 37.0 15.80 _ 1.16 6,150.0 6,995.0 Page 2/2 Report Printed: 11/15/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-209 Rig: Doyon 19 Date: 6/2/2006 Volume Input Pump Rate: Drilling Supervisor: - - Mickey/Hill Pump used: Cement Unit ~ Barrels I' ~ Bbls/strk ~ 0.80 Bbl/min ~ Type of Test: Annulus Leak off Test for disposal Adequacy ~ Pumping down 'annulus. ~ Casin Test Pressure Inte rit Test --- Hole Size: a-3/4" ~ Casin Shoe Depth Hole De th Pumpin Shut-in Pumpin Shut-in RKB-CHF: 37.2 Ft 2390.0 Ft-MD 2377.0 Ft-TVD -- 6150.0 Ft-MD 5851.0 Ft-TVD -- Bbls psi Min si Bbls psi Min si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0.00 723 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 14 0.25 712 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 19 0.50 655 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 23 1.00 602 Hole Size is that drilled below outer casing. 4 2 67 1.50 ~ Use estimated TOC for Hole Depth. 5 2.5 206 2.00 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 353 2.50 Estimates for Test: 643 psi 0.4 bbls_ 7 3.5 527 3.00 ~, ~ 8 4 659 3.50 551 EMW =Leak-off P ressu re + Mu d Wei ght = 951 + 9 8 PIT 15 Second 9 4.5 822 4.00 552 0.05 2 x TV D 0.05 2 x 2 377 Shut-in Pressure, p si 10 5 924 4.50 544 EMW at 239 0 Ft- MD (2 377 Ft -ND) = 17 .5 712 15 5.5 951 5.00 544 toao - - - - - 20 6 873 5.50 537 25 6.5 803 6.00 534 - - ~ - - - 30 7 798 6.50 530 _ - 7.5 815 7.00 526 - 8 809 7.50 522 - - - - 8 5 839 8 00 518 ~ . . w 8.50 513 ~ ~ - -- 9.00 510 soo _ ---- 9.50 5U9 N ~ - - - -- -- - _ - ~ - ~ 10.00 '~ a P ~ vt 0 o , z s a s s ~ a s o s ,o ,s zo 2s s o ~~ CASIN G TEST Bar rels tL EAK-OFF TEST Shut-In time, Minutes O PIT Point Volume PUm ed Volume Bled Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: 9 5/8" shoe LOT @ 14.7 ppg ~,v~+-cv~ ru a wiai w ~ Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-210 Rig: Doyon 19 Date: 11 /25/2006 Drilling Supervisor: D. Burley / L. Hill Pump used: Cement Unit ~ Volume Input Pump Rate: garrets ~ Bbls/Strk ~ 0.5~ Bbl/min ~ ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ asin Test Pressure In te ri Test Hole Size: s-3/4" ~ Casin Shoe Depth Hole De th Pum pin Shu t-in Pumpin Shut-in 7 Ft RKB-CHF: 34 2,540 Ft-MD 2,386 Ft-TV 6,480 Ft-MD 5,857 Ft-TVD Bbls psi Min psi Bbls psi Min psi . Casing Size and Description: 9-5/s" 4o#/Ft L-so gTC ~ 0 0 500 0 1206 Chan es for Annula r Ade u ac Tes Pressure Int e ri Tes 1 1 1 510 0.25 1095 outer casing shoe test result. in comments Mud Weight: 7.0 ppg 2 2 530 0.5 1040 Description references oute casing string Inner casing OD 7.0 In. 3 3 550 1 1030 ize is that drilled below oute casing. 4 4 581 1.5 ~`~`t timated TOC for Hole Depth 5 5 611 2 974 Enter inner casing OD at righ Desired PIT EMW: 16.0 ppg 6 6 641 2.5 954 Estimates for Test: 1117 psi 0.8 bbls 7 7 671 3 936 . j • 8 8 702 3.5 914 EMW =Leak-off Pressure + Mud Weight = '- 1287 PIT 15 Second 9 9 742 4 904 + 7 052 x TVD 0.052 x 2386 0 Shut-in Pressure, psi 10 10 803 4.5 893 . EMW at 2540 Ft-MD (2386 Ft-TVD) = 17.4 1095 15 11 873 5 1378 __ ~ 500 - - - 20 12 949 5.5 868 25 13 1015 6 858 30 14 1075 6.5 848 ~ ~ I 15 1136 7 843 - 16 1211 7.5 833 r\ _ ~ 17 1262 8 823 ~ooo - ~ ~ - - - 17.5 1287 8.5 818 w ~ ~, _ - ~ --- - - 18 1242 9 813 ~ - _ ~ _ - M1 N ~~ - 18.5 1227 9.5 803 ~n ' _- - - 19 1227 10 798 ~ _ _ _ _ _ _ -- 19.5 1227 a 500 - ~- - - - - 20 1222 _ _ 20.5 1216 21 1216 ~. 1 - - ~ ~~ ~ _ ' ~I ' 0 2 5 3 0 0 5 10 15 20 25 0 5 10 15 20 Barrels Shut-In time, Minutes i PIT P t Vol Pum ume ed Vol Bled ume Back Vo Pu lume m ed Vo Bled lume Back n o ~~CASING TEST BLEAK-OFF TEST O s s s s omments: 9 5/8" shoe test = ppg 7 ppg mud weitght includes a weighted average to account for freshwater and diesel fluid column RE: CD4-209 (PTD 206-065) THANX! eom • • Subject: RE: CD4-209 (PTD 206-065) THANX! eom From: "Walker, Jack A" •=;.!acl:.A.Walker@cono~ophillips.eom=% Date: Fri, 08 Dec 2006 1 _S:l 5:25 -0900 To: Thomas Maunder ~-ton1 nlaunder(1~%admin.state.ak.u5> From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, December 08, 2006 2:57 PM To: Walker, lack A Subject: Re: CD4-209 (PTD 206-065) Sundry 306-356 Jack, From our conversation, I understand that the attempt to naturally flow the well has not adequately removed the filter cake. Employing the CT and diesel as you plan should help clean out the solids. Thanks for the notice. Nothing fiu ther is needed. Please insure the BOP is tested to a minimum of 3500 psi. Call or message with any questions. Tom Maunder, PE AOGCC Walker, Jack A wrote, On 12/8/2006 2:33 PM: Tom, A coiled tubing diesel wash is proposed for CD4-209 as part of sundry no. 306-356. The purpose of the CT wash is to assist removal of residual filter cake left over from the mineral oil based mud. Jack Walker ConocoPhillips Alaska, Inc. North Slope Operations and Development 907-265-6268 907-250-1749 1 of 1 12/8/2006 3:31 PM AC•~ " ~ ~~ ~ ~ fj ~- t `~ `~ ~ ~: FRANK H. MURKOWSKI GOVERNOR ~~~~ ~~~~++ *~ ~t~~ ~ ~~+ F tut[~-7I~A OaL tusL GAS ~ 333 W. 7"' AVENUE, SUITE 100 C01~5ER'QA~'IOi1T CODII~iISSIOH /'~ ANCHORAGE, ALASKA 99501-3539 f PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker North Slope Operations and Development ConocoPhillips Alaska, Inc. 700 G Street ~.~ ~ .~~ Anchorage, Alaska 99501 v~ ~ (p Re: Colville River Field, Nanuq Oil Pool, Well Name CD4-209 Sundry Number: 306-356 Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this 06 of November, 2006 Encl. Qir-~narn~~~ r1 ConocoPhillips • Jack Walker North Slope Operations and Development ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 r ~ ~. ~~~~ October 31, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Re: Temporary Production of Well CD4-209 Nanuq Oil Pool Colville River Field Dear Chairman Norman: ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Field submits the attached 10-403 for well CD4-209 completed in the Nanuq Oil Pool. This well was originally permitted and completed as a service well. Producing CD4-209 via a temporary flowline connected to permanent facilities is needed to improve completion clean up and to help understand horizontal well performance of the Nanuq Oil Pool. The proposed flow period is 14 days. Performance during the 1-day, post-completion flowback indicated that a large fraction of the horizontal production hole may not have been contributing to flow. Additional flowing time may increase mud cake lift off and enable injection into more of the production hole. Please call me 265-6268 if you have questions. Very truly yours, l/~ Jack Walker North Slope Operations and Development ConocoPhillips Alaska, Inc. Attachment f ~~ ~ ~ T ~. , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION N I~ APPLICATION FOR SUNDRY APPROVAL ~`~~~ '~ 20 AAC 25.280 A~I~ska C~ii s'~°:: 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ _ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^/ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-065 • 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20532-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^~ CD4-209 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ,I~c. ~QilZaP, 3s{~y/, 38~j3 ,.l19 i~ r •aG RKB 56' Nanuq Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13215' 6195' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2334' 9-5/8" 2390' PRDO-UCTION 6939' 7" 6995' `V SLOTTED LINER 6365' 4-1/2" 13205' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 6847' Packers and. SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 2001' 13. Attachments: Description Summary of Proposal Q 14. Well Class after propo sed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ ~,,J Development [~o" Service'' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 15, 2006 ~ Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name Jack Walker Title: Production Engineer Signature Phone 265-6268 Date la~31~o(,, Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 3 ©~_ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other. ~~.. I,,C~~= t~ 200 Subsequent Form Required: ~® APPROVED BY ~ Approved by: I I THE COMMISSION ~ Date: Form 10-403 Revised 06/2006 "' ~~ U ~ 0 1 d'F - ~ ~ ' ""' Submi n Duplicate /!-Z •ab t~~c~ L_J ConocoPhillips September 12, 2006 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner ~EGE~U~ State of Alaska Alaska Oil & Gas Conservation Commission SEP 1 3 2(105 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Report for CD4-209 (APD 206-065) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine wells CD4-209. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ,- ~• ~~- G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~EIVEv SEP 1 3 2006 WELL COMPLETION OR RECOMPLETION REPOt~~aAtP~l~ ~ orrxr,ission .~~~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 G1NJ ^ WINJ ~ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory I^ Service ~ Stratigraphic Testl_1 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., orAband.: June 11, 2006 12. Permit to Drill Number: 206-065 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 25, 2006 - 13. API Number: 50-103-20532-00 4a. Location of Well (Governmental Section): Surface: 2923' FNL, 226' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: June 8, 2006 14. Well Name and Number: CD4-209 ' At Top Productive Horizon: 351' FSL, 329' FEL, Sec. 24, T11 N, R4E, UM 6. KB Elevation (ft): 32' RKB 15. Field/Pool(s): Colville River Field Total Depth: 76' FNL, 2546' FEL, Sec. 31, T11 N, R5E, UM 9. Plug Back Depth (MD + TVD): 13215' MD / 6195' TVD Nanuq Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378019 y- 5957489 ` Zone- 4 10. Total Depth (MD + TVD): 13215' MD / 6195' TVD 16. Property Designation: ADL 380077, 384209, 384211, 388903 TPI: x- 377882 y- 5955484 Zone- 4 Total Depth: x- 380567 - 5949735 Zone- 4 11. Depth where SSSV set: Landing Nipple @ 2100' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 781' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 68# H-40 32' 114' 32' 114' 42" Portland Type III 9.625" 40# L-80 32' 2390' 32' 2377' 12.25" 302 sx AS Lite, 232 sx Class G 7" 26# L-80 32' 6995' 32' 6202' 8.75" 175 sx Class G 4.5" 12.6# L-80 6840' 13205' 6172' 6196' 6.125" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6847' 6446' slotted liner from 6840'-13215' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production August 23, 2006 Method of Operation (Flowing, gas lift, etc.) Flowback Date of Test 8/23/2006 Hours Tested not available Production for Test Period --> OIL-BBL 1480 GAS-MCF WATER-BBL CHOKE SIZE not available GAS-OIL RATIO 1080 Flow Tubing press. psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ait~ Q(~ 8l %% b ~~~ ~~~ ~ ~ 200 f~ F,~~~ NONE ,/,~ Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ~ ~.~g.o6 2s. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-209 K-3 3896' 3834' K-2 4161' 4081' Nanuq Sand 6859' 6176' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name ////~~~~ ~ Nod Title: Alpine Drilling Team Leader ~ ~l ~' ~ G Signature ~J. Phone ~ ~'_ ~ ~ ~ J Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips FIELD/ UNIT/ PAD: Alpine/CD4 DATE: 6/11/2006 IIti1=~~tIUI~'I"..... ', >::>::>::>: ::: ~Tl~i MI ,; .;:.;;: >::; .:: :> TBG:: TYPE PAC I~E~t::;: ':>: TIC:. ;:::::::[~E ' TlM TtIVIE ,,< ' >::>::>::>::; ;;>::>::>:::: -, > INJ TEST tI~~VN. TVQ CASING ' TBG TEBT >~ ~5~3 >:T~: TB~3 TBG .;! ST#T > P' P 'W~L~...... ! F1.UIp TYP FLUID M;[3 SIZE / WT/GRADE St2E'i RRf~S PRESS: '! ~.. tt5~~ 'CSCx...: : TIIVIE.. >.:.... >P :: SS <>::> ::>::>: PTD: 206-065 6,025 500 2,200 2,200 2,200 2240 X Well #: CD4-209 N P MOBM 6, 446 7" / 26# / L-80 4.5 3500 1, 200 3, 520 3, 500 3, 500 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: TBG. INJ. FLUID CODES F =FRESH WATER INJ. G =GAS INJ. S =SALT WATER INJ. N = NOT I NJECTI NG Distribution: orig -Well File c -Operator c -Database c -Trip Rpt File c -Inspector TEST TYPE: ANNULAR FLUID: P.P.G. Grad. WELL TEST: M =ANNULUS MONITORING DIESEL 6.8 0.35 Initial X P =STD ANNULUS PRESSURE TEST GLYCOL 0.00 4 -Year R =INTERNAL RAD. TRACER SURVEY SALT WATER Workover A =TEMPERATURE ANOMALY TEST DRILLING MUD 9.2 0.48 Other D =DIFFERENTIAL TEMPERATURE TEST OTHER 0.00 OPERATOR REP SIGNATURE: L. Hill , AOGCC REP SIGNATURE: CD4-209 MIT .xls (Rev 9/23199) ~onoc PPhiili{p-~~s ~ Time Lo Summa Wcllview INeU Xeparting L _ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/24/2006 07:00 00:00 17.00 MIRU MOVE MOB P Blow down steam & water lines - Disconnect electrical lines -move motor ~ pit modules away from sub - Jack floor -Move ball mill -motor & pit modules & pipe shed f/ CD2 to CD4 - Sub base in route 05/25/2006 00:00 04:30 4.50 MIRU MOVE MOB P Move sub to CD4 -Spot sub over well - level rig lower feet & cellar walls - unpin rig floor & Jack floor into drilling position -Spot pit & motor complexes & ball mill 04:30 05:30 1.00 MIRU MOVE RURD P Hook up service lines (electrical,water, steam,water, & air 05:30 07:30 2.00 SURFA DRILL RURD P NU surface riser - turnbuckels -mouse hole & flow line -Accept rig @ 0530 hrs. 07:30 09:30 2.00 SURFA DRILL RURD P Spot pipe shed - laod 5" Dp & 5" HWDP in shed 09:30 13:30 4.00 SURFA DRILL PULD P PU 5" DP (57 jts) & stand back in derrick - PU 5" HWDP (24 jts) & stand back in derrick 13:30 14:00 0.50 SURFA DRILL PULD P Bring BHA components to rig floor 14:00 16:30 2.50 SURFA DRILL OTHR P Mix spud mud -fill hole & check for leaks -pressure test mud lines to 3500 si 16:30 19:30 3.00 SURFA DRILL PULD P PU & Stand back NM flex DC's & jars -MU BHA #1 -adjust bend in motor to 1.5 -Orient UBHO sub -Down load MWD -Held Pre -spud meeting with crew 19:30 20:00 0.50 SURFA DRILL OTHR P PU MN flex DC & jars -Clean out conductor f/ 78' to 114' 20:00 00:00 4.00 SURFA DRILL DRLG P Spud in & Drill 12 1/4" hole f/ 114' to 346' MD 346' TVD ADT - 1.56 hrs =ART 1.56 hrs AST - 0 hrs. WOB 8/10 RPM 50 GPM 450 @ 880 psi String wt. PU 97 SO 97 Rot 97 Torque on/off tm. - 4500/4000 ft/Ibs. Take ro surve s 05/26/2006 00:00 12:00 12.00 346 1,458 SURFA DRILL DRLG P Drill 12 1/4" hole f/ 346' to 1458' MD 1457' TVD ADT - 8.51 hrs =ART - 6.97 hrs AST - 1.54 hrs WOB 15/25 RPM 70 GPM 620 @ 1890 psi String wt. PU 128 SO 128 Rot 128 Tor ue on/off btm. - 6000/4000 ft/Ibs ~ age 1 oaf 1~ ...... ~ .. . . .~ .~.. ~...~. . .. ~ Time Logs Date From To Dur ~ th E. De th Phase Code Subcode T CM 05/26/2006 12:00 23:30 11.50 1,458 2,400 SURFA DRILL DRLG P Drill 12 1/4" hole f/ 1458' to 2400' MD - 2387' TVD WOB 15/25 RPM 70 GPM 650 @ 2200 psi String wt. PU 143 SO 137 Rot 140 Tor ue on/off btm. - 7000/5000 ft/Ibs 23:30 00:00 0.50 2,400 2,400 SURFA DRILL CIRC P Circ hole clean for wiper trip 650 gpm 2000 si w/ 70 r m 05/27/2006 00:00 03:45 3.75 2,400 890 SURFA DRILL WPRT P Wiper trip f/ 2400' to 1154' w/ pump @ 550 gpm w/ 70 rpm -Continue wiper trip f/ 1154' to 890' w/ pump @ 450 mw/70r m 03:45 04:30 0.75 890 2,400 SURFA DRILL TRIP P Flow check well (static) RIH f/ 890' to 2400' -hole in good condition -wash last 80' to btm. 04:30 05:30 1.00 2,400 2,400 SURFA DRILL CIRC P Circulate hole clean - 650 gpm @ 2100 si 70 r m 05:30 07:00 1.50 2,400 890 SURFA DRILL TRIP P Flow check (static) POOH on TT f/ 2400' to 890' -hole took proper fill - hole in ood condition 07:00 08:30 1.50 890 73 SURFA DRILL TRIP P Flow check well @ BHA (static) Std back HWDP & NM flex DC' & jars f/ 890' to73' 08:30 10:15 1.75 73 0 SURFA DRILL PULD P LD BHA -down load MWD - LD UBHO, MWD, motor & bit (* bit look in ve ood sha a Clean u ri floor 10:15 12:00 1.75 0 0 SURFA CASIN( RURD P PJSM - RU to run 9 5/8" casing 12:00 12:15 0.25 0 0 SURFA CASIN( SFTY P Held per job ops & safety meeting w/ crew 12:15 15:00 2.75 0 1,650 SURFA CASIN( RNCS P Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc - filled pipe & checked floats) 39 jts csg to 1650' 15:00 15:30 0.50 1,650 1,650 SURFA CASIN( CIRC P Break circulation -Circulate btms up @ 5 bbls/min -ICP 340 psi -FCP 320 si 15:30 17:00 1.50 1,650 2,390 SURFA CASIN( RNCS P Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1650' to 2350' - 18 jts (61 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/fluted mandle hanger on landing ring w/ float shoe @ 2390' & float collar @ 2307' - LD Frank's fill up tool -Blow down TD - MU cmt head & lines 17:00 18:30 1.50 2,390 2,390 SURFA CEMEf~ CIRC P Establish circulation -Stage pump up to 6.5 bbl/min -Circulate & condition hole & mud for cmt job -ICP 430 psi FCP 320 si circulated 440 bbls 18:30 18:45 0.25 SURFA CEMEf~ SFTY P Held pre op & safety meeting w/ crew fi~~r~e 2 of 11 ®~ _..,,. Time Lo s Date From To Dur e th E De th Phase Code Subcode T OM 05/27/2006 18:45 20:30 1.75 2,390 2,390 SURFA CEME~ DISP P Cement 9 5/8" csg as follows Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 3000 psi - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 240 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 220 bbls lead pumped - pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 155 bbls 9.6 ppg water base mud -Displaced @ 6.5 bbls/min for first 135 bbls -slowed pump to 3.5 bbls/min for last 20 bbls - Bumped plug w/ 1150 psi (prep bump pressure 570 psi) Check float (held OK) CIP @ 20:36 hrs. -Full circulation throughout job w/ 89 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 30 bbls of dis lacement 20:30 21:30 1.00 2,390 2,390 SURFA CEME~ OTHR P Rig up & test 9 5/8" casing to 2500 si for 30 mins. -Blow down lines - RD 21:30 22:30 1.00 2,390 2,390 SURFA CEME~ PULD P RD cement lines & head - LD landing 't. 22:30 00:00 1.50 2,390 2,390 SURFA DRILL RURD P ND surface riser 05/28/2006 00:00 02:30 2.50 2,390 2,390 SURFA WELCT NUND P ND starting head -Install wellhead & test seals to 1000 si - NU BOPE 02:30 04:00 1.50 2,390 2,390 SURFA WELCT OTHR P RU to test BOPE 04:00 08:30 4.50 2,390 2,390 SURFA WELCT BOPE P PJSM -Test BOPE - Hydrill to 250 & 3500 psi -Test pipe rams, kill & choke lines, choke manifold valves, to 250 & 5000 psi -Auto IBOP leaking - Attempt to test blind rams found leak on wellhead 08:30 11:00 2.50 2,390 2,390 SURFA WELCT EQRP T RD test equipment - LD mouse hole - Split wellhead @ csg flange -inspect & replace API ring -Reassemble wellhead - ser riser, mouse hole & test lu 11:00 12:00 1.00 2,390 2,390 SURFA WELCT BOPE P Fill BOP -Test blind rams to 250 & 5000 si 12:00 21:00 9.00 2,390 2,390 SURFA WELCT EQRP T PJSM -Change out auto IBOP - Rebuild & test to 250 & 5000 psi - RD test a ui ment 21:00 21:30 0.50 2,390 2,390 SURFA WELCT OTHR P Pull test plug -set wear bushing 21:30 22:00 0.50 2,390 2,390 SURFA DRILL PULD P PU drilling bails & 4" elevators - PU Geo-S an tori floor 22:00 00:00 2.00 2,390 SURFA DRILL PULD P PJSM - PU 4" DP f/ shed & RIH to 1500' Time Logs _ Date From To Dur th E. De th Phase Code Subcode T OM 05/29!2006 00:00 01:00 1.00 SURFA DRILL PULD P Continue PU 4" DP f/ shed &RIH f/ 1500' to 1900' 60 'ts. 01:00 02:00 1.00 SURFA DRILL TRIP P POOH & std back DP in derrick (20 stds 02:00 04:00 2.00 SURFA DRILL PULD P PU &RIH w/ 4" DP f/ shed to 1900' (60 'ts. 04:00 04:30 0.50 SURFA DRILL TRIP P POOH w/ 4" DP & std back in derrick 20 stds 04:30 06:00 1.50 SURFA DRILL PULD P PU & RIH w/ 4" DP f/ shed to 1450' (45 'ts. 06:00 06:45 0.75 SURFA DRILL TRIP P POOH w/ 4" DP & std back in derrick 15 stds 06:45 07:30 0.75 SURFA DRILL OTHR P Clean up rig floor -Change to 5" handlin a ui ment 07:30 11:15 3.75 0 250 SURFA DRILL PULD P MU 8 3/4" BHA -Bit -GeoPilot - MWD- PU NM flex DC's - Up load MWD -RIH to 250' -Shallow test tools & pressure test Geo Span skid to 3000 si 11:15 12:30 1.25 250 1,970 SURFA DRILL TRIP P RIH w/ HWDP & 5" DP f/ 250' to 1970' PU 8 3/4" host reamers 12:30 13:00 0.50 1,970 2,156 SURFA DRILL TRIP P Change over to 4" handling equipment - RIH w/ 2 stds 4" DP f/ 1970' to 2156' 13:00 14:30 1.50 2,156 2,156 SURFA RIGMN SVRG P PJSM -Cut & slip 60' drill line -service TD 14:30 15:00 0.50 2,156 2,290 SURFA DRILL REAM P Wash down from 2156' to 2290' (tag to of cmt 15:00 16:45 1.75 2,290 2,400 SURFA CEMEf~ DRLG P Clean out cmt f/ 2290/ to 2305' -drill wiper plugs to FC @ 2307' -Drill FC, cmt & FS @ 2387' to 2390' -Clean out rat hole to 2400' 16:45 17:00 0.25 2,400 2,420 SURFA DRILL DRLG P Drill 20' new hole f/ 2400' to 2420' 17:00 18:00 1.00 2,420 2,420 SURFA DRILL LOT P Circ hole clean for FIT/LOT - RU - Attempt for FIT to 18.0 ppg -Went to LOT w/ 15.9 EMW - RD 18:00 18:30 0.50 2,420 2,420 INTRM1 DRILL CIRC P Displace well to 9.6 ppg LSND mud - Flow check static 18:30 22:30 4.00 2,420 2,920 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 2420' to 2920' MD 2895' TVD ADT= 2.86 hrs - ECD - 10.2 ppg WOB 14 RPM 80 GPM 500 @ 1240 psi String wt. PU 145 SO 135 Rot. 140 Torque on/off btm - 7000/5000 ft/Ibs. GeoPilot failure 22:30 23:00 0.50 2,920 2,920 INTRM1 DRILL CIRC P Circ btms up for trip 500 gpm @ 1160 si-80r m 23:00 00:00 1.00 2,920 2,824 INTRMI DRILL TRIP T Flow check (static) POOH on TT f/ 2920' to2583' -improper fill - RIH f/ 2583' to 2824 05/30/2006 00:00 00:30 0.50 2,834 2,920 INTRMI DRILL REAM T Wash down f/ 2834' to 2920' -Circulate btms up @ 500 gpm @ 1200 psi w/ 70 rpm - no gas or increased flow rate @ btms u Time Logs _ Da e From To Dur .. th E. De th Phase Code Subcode T DM 05/30/2006 00:30 02:00 1.50 2,920 1,970 INTRM1 DRILL TRIP T POOH w/ pump f/ 2920' to 1970' @ 400 m 780 si w! 60 m 02:00 02:30 0.50 1,970 1,970 INTRM1 DRILL OTHR T Change to 5" handling equipment 02:30 05:45 3.25 1,970 75 INTRMI DRILL TRIP T POOH on TT f/ 1970' to 75' -Hole taking proper fill -had to pull slow to avoid swabbin -Flow check static 05:45 08:15 2.50 75 75 INTRM1 DRILL PULD T Down load MWD -Break bit - LD GeoPilot - PU new GeoPilot - MU bit - Up load MWD -Reran bit # 2 -Found all three housing stabs(cutters) packed with clay -not allowing cutters into extend 08:15 09:00 0.75 75 260 INTRM1 DRILL OTHR T RIH f/ 75' to 260' -shallow test tools 09:00 10:00 1.00 260 1,973 INTRM1 DRILL TRIP T RIH f/ 260' to 1973' 10:00 10:45 0.75 1,973 2,827 INTRM1 DRILL TRIP T Change to 4" handling tools -RIH f/ 1973' to 2827' 10:45 11:30 0.75 2,827 2,920 INTRM1 DRILL REAM T Wash down f/ 2827' to 2920' 11:30 12:00 0.50 2,920 2,935 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/GP f/ 2920' to 2935' MD 2908' TVD ADT - .25 hrs WOB 10/14 RPM 80 GPM 650 @ 1910 psi String wt. PU 145 SO 130 Rot 140 Tor ue on/off btm. - 7000/6000 ft/Ibs 12:00 00:00 12.00 2,935 4,544 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 2935' to 4544' MD 4439' TVD ADT - 8.33 hrs WOB 17/22 RPM 130 GPM 650 @ 2670 psi String wt. PU 165 SO 145 Rot 155 Tor ue on/off btm. - 8500/6000 ft/Ibs 05/31/2006 00:00 12:00 12.00 4,544 5,820 INTRM1 DRILL DRLG P Driil 8 3/4" hole w/GP f/ 4544' to 5820' MD 5591' TVD ADT - 8.32 hrs. ECD - 10.4 ppg WOB 17/22 RPM 130 GPM 500 @ 1920 psi String wt. PU 190 SO 160 Rot 175 Tor ue on/off btm. - 9500/7000 ft/Ibs. 12:00 22:30 10.50 5,820 7,005 INTRM1 DRILL DRLG P . Drill 8 3/4" hole w/ GP f/ 5820' to 7005' MD 6204' TVD ADT - 7.99 hrs. ECD - 10.4 ppg WOB 17/22 RPM 130 GPM 550 @ 2550 psi String wt. PU 192 SO 157 Rot 176 Tor ue on/off btm. - 11000/7500 ft/Ibs. 22:30 00:00 1.50 7,005 7,005 INTRM1 DRILL CIRC P CBU X 2. 600 GPM 2890 psi. 130 RPM. 06/01/2006 00:00 02:00 2.00 6,830 5,590 INTRM1 DRILL WPRT P POOH w/ pump f/ 6830' to 5590' - 550 gpm @ 2450 psi w/ 60 rpm -Flow check well static 02:00 02:45 0.75 5,590 6,925 INTRM1 DRILL TRIP P RIH f/5590' to 6925' -flow check static fi~~ge ~t ~1 ~ .~ ..~ ~ ® ~ Time Logs Date From To Dur pth E. De th Phase Code Subcode T COM 06/01/2006 02:45 04:00 1.25 6,925 7,005 INTRM1 DRILL CIRC P Wash down f/ 6025' to 7005' -Circ & wt. up to 9.8 ppg @ 600 gpm @ 3100 si w/ 100 m 04:00 04:30 0.50 7,005 7,005 INTRM1 DRILL CIRC P Pump well strengthening pill & tube pill to bit 04:30 06:00 1.50 7,005 6,070 INTRMI DRILL TRIP P POOH spotting pills f/ 7005' to 6070' - w/ 3 BPM @ 270 psi -flow check static 06:00 11:00 5.00 6,070 1,974 INTRM1 DRILL TRIP P POOH on TT f/ 6070' to 1974' -hole in good condition & took proper fill -Flow check static 11:00 13;00 2.00 1,974 718 INTRM1 DRILL TRIP P Change over to 5" handling equipment - Continue POOH on TT f/ 1974' to 718'. 13:00 15:30 2.50 718 0 INTRM1 DRILL PULD P Laid down BHA and cleared rig floor. 15:30 17:00 1.50 0 0 INTRM1 WELCT BOPE P Changed rams to 7" and tested to 250/5000 si. 17:00 18:00 1.00 0 0 INTRM1 CASIN( RURD P Set thin wear bushing and rigged up to run casin . 18:00 21:00 3.00 0 2,355 INTRM1 CASIN( RNCS P PJSM and ran 7" 26# L 80 BTCM casin to 2,355'. 21:00 21:30 0.50 2,355 2,355 INTRM1 CASIN( CIRC P Circulated 1 casing volume + 10 Bbls. 6 BPM 290 si FCP. 21:30 00:00 2.50 2,355 4,694 INTRM1 CASIN( RNCS P Ran 7" 26# L 80 BTCM casing from 2,355' to 4,694'. 06/02/2006 00:00 00:15 0.25 4,694 5,121 INTRM1 CASIN( RNCS P Cont. running 7" 26# L-80 MBTC csg f/ 4694' to 5121' - 10 'ts. 120 'ts. total 00:15 00:45 0.50 5,121 5,121 INTRMI CASIN( CIRC P Break Circ -stage pumps up to 6 bbls/min ICP 510 si FCP 430 si 00:45 02:30 1.75 5,121 6,995 INTRM1 CASIN( RNCS P Cont. running 7" 26# L-80 MBTC csg f/ 5121' to 6956.83' - 43 jts (163 jts. total) PU FMC fluted hanger & landing jt. -Land csg w/ shoe @ 6995' & FC 6904' 02:30 03:15 0.75 6,995 6,995 INTRM1 CEME~ PULD P RD csg equipment - RU cmt. head & lines 03:15 04:15 1.00 6,995 6,995 INTRM1 CEMEI~ CIRC P Break circ -stage pumps up f/ 2 bbl/min to 6.5 bbls/min -Circ & condition for cmt job -ICP 600 psi FCP 520 si 04:15 04:30 0.25 6,995 6,995 INTRM1 CEMEI~ SFTY P Held PJSM w/ crew 04:30 06:00 1.50 6,995 6,995 INTRMI CEME~ DISP P Cement 7" 26# L-80 MBTC as follows: Pumped 5 bbls water -Test lines to 2500 psi -Pumped 30 bbls CW-100 - Dropped btm plug -Mixed & pumped 37 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced cmt w/ 243 bbls 9.6 ppg LSND mud @ 6.9 bbl/min -slowed pumps to 4 bbls/min @ bumped plug w/ 1000 psi - CIP @ 0550 hrs. -Checked floats OK - Full circulation throu hout 'ob - - - ~qe ~ Qf 1~ Time Logs Date From To Dur th E. De th Phase Code Subcode T COM 06/02/2006 06:00 06:30 0.50 6,995 6,995 INTRM1 CEME~ OTHR P Test 7 " csg to 3500 psi for 30 mins. 06:30 08:30 2.00 6,995 6,995 INTRM1 CEME~ PULD P RD cmt. head - LD landing jt. -Pull thin wall wear bushing -set & test ack off to 5000 si 08:30 10:30 2.00 6,995 6,995 INTRM1 WELCT EQRP P PJSm -Change top pipe rams f/ 7" to 3 1/2" X 6" VBR -Test to 250 & 5000 si - ull test lu -set wear bushin 10:30 13:00 2.50 0 1,700 INTRM1 DRILL PULD P PU & RIH w/ 57 jts. 4" drill pipe f/ pipe shed 13:00 14:00 1.00 1,700 0 INTRM1 DRILL TRIP P POOH & std back pipe in derrick -19 stds 14:00 14:30 0.50 0 0 INTRM1 DRILL PULD P PU BHA components to rig floor 14:30 17:00 2.50 0 300 INTRM1 DRILL PULD P PU 6 1/8" BHA - 17:00 18:00 1.00 300 399 INTRM1 DRILL PULD P PU and RIH HWDP. Shallow tested MWD. 18:00 00:00 6.00 399 5,921 INTRM1 DRILL PULD P RIH picking up DP from pipe shed to 5,921'. 06/03/2006 00:00 01:00 1.00 5,921 6,684 INTRM1 DRILL PULD P Cont. RIH w/ BHA & PU 4" drill pipe f/ shed to 6684' - 66 stds total - 01:00 02:30 1.50 6,684 6,684 INTRM1 RIGMN SVRG P PJSM -Cut & slip drill line 02:30 03:00 0.50 6,684 6,820 INTRM1 DRILL REAM P Wash down f/ 6684' to 6820' (top of cmt. 03:00 04:15 1.25 6,820 6,904 INTRM1 CEME~ COCF P Drill cmt f/ 6820' to 6902' -drill wiper lu s f/ 6902' to 6904' to of FC 04:15 04:30 0.25 6,904 6,779 INTRM1 EVALV~ DLOG P POOH w/ pump (/6904' to 6779' @ 220 m 1480 si 04:30 05:00 0.50 6,779 6,017 INTRMI EVALV~ TRIP P POOH on TT f/ 6779' to 6017' 05:00 10:00 5.00 6,017 6,904 INTRM1 EVALVI~ DLOG P MADD pass w/ Bat sonic tool f/ 6017' to 6904' 210'/hr. 10:00 12:30 2.50 6,904 6,970 INTRM1 CEMEI~ DRLG P Drill FC @ 6904' & clean out cmt to 6970' *MWD failure 12:30 13:00 0.50 6,970 6,970 INTRM1 DRILL CIRC T CBU trying to get uplink. 13:00 16:00 3.00 6,970 123 INTRM1 DRILL TRIP T POOH to 123' on trip tank. 16:00 19:45 3.75 123 399 INTRM1 DRILL PULD T Down loaded tool and changed out PWD. Uploaded tool and Made up BHA. Shallow tested tools. 19:45 22:30 2.75 399 6,970 INTRM1 DRILL TRIP T RIH to 6,970'. 22:30 00:00 1.50 6,970 7,005 INTRMI CEME~ DRLG P Drilled out shoe track from 6,970' to 6,995'. Cleaned out rat hole to 7,005'. 06/04/2006 00:00 00:15 0.25 7,005 7,025 INTRMI DRILL DRLG P Drill 6 1/8" hole w/ GP f/ 7005' to 7025' MD 6206' TVD ADT - .35 hrs. WOB 10 k RPM 90 GPM 210 @ 1480 si 00:15 00:30 0.25 7,025 7,025 INTRM1 DRILL CIRC P Circ hole clean for FIT Time Logs ~ __ Date From To Dur th E. de th Phase Code Subcode T COM 06/04!2006 00:30 01:00 0.50 7,025 7,025 INTRM1 DRILL FIT P RU & perform FIT to 12.5 ppg EMW - (.8 ppg mud w/ 875 psi @ 6202' TVD - RD 01:00 01:45 0.75 7,025 7,025 PROD1 DRILL CIRC P Held job meeting -Displace well f/ 9.8 ppg LSND mud to 9.2 ppg OBM -Flow check static 01:45 12:00 10.25 7,025 7,740 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/GP f/ 7025' to 7740' MD 6243' TVD ADT - 6.92 hrs. ECD - 10.5 to 10.6 PP9 WOB 12/15 k RPM 130 GPM 210 @ 2220 psi String wt. PU 180 SO 137 Rot 163 Tor ue on/off btm. - 9500/7500 ft/Ibs. 12:00 00:00 12.00 7,740 8,543 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/GP f/ 7,740' to 8,543' MD 6201' TVD ADT - 8.25 hrs. ECD - 10.5 to 10.6 PP9 WOB 8/15 k RPM 120 GPM 220 @ 2230 psi String wt. PU 185 SO 130 Rot 160 Tor ue on/off btm. - 10000/8000 ft/Ibs. 06/05/2006 00:00 12:00 12.00 8,543 9,340 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 8,543' to 9340' MD 6240' TVD ADT - 9.28 hrs. ECD - 10.7 ppg WOB 9/12 k RPM 120 GPM 210 @ 2270 psi String wt. PU 180 SO 135 Rot 160 Tor ue on/off btm. - 9000/8000 ft. lbs. 12:00 00:00 12.00 9,340 10,189 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/GP f/ 9340' to 10,189' MD 6230' TVD ADT - 8.38 hrs. ECD - 10.7 ppg WOB 9/12 k RPM 120 GPM 210 @ 2280 psi String wt. PU 185 SO 126 Rot 158 Tor ue on/off btm. - 10500/9000 ft. lbs. 06/06/2006 00:00 12:00 12.00 10,189 10,795 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 10,189' to 10,795' MD 6204' TVD ADT - 7.92 hrs. WOB 9/11 k RPM 120 GPM 220 @ 2520 psi String wt. PU 195 SO 115 Rot 155 Torque on/off btm. - 10,000/8,500 ft. I bs. ECD - 10.7-10.9 12:00 00:00 12.00 10,795 11,436 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 10,795' to 11,436' MD 6223' TVD ADT - 8.12 hrs. WOB 9/11 k RPM 120 GPM 220 @ 2500 psi String wt. PU 198 SO 105 Rot 157 Torque on/off btm. - 10,500/9,500 ft. lbs. ECD - 10.7-10.9 Time Logs Date From To Dur e th E. De th Phase Code Subcode T COM 06/07/2006 00:00 12:00 12.00 11,436 12,243 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 11,436' to 12,243' MD 6233' TVD ADT - 7.78 hrs. WOB 8/11 k RPM 120 GPM 220 2700 psi String wt. PU 185 SO 115 Rot 157 Torque on/off btm. - 11,000/10,000 ft. lbs. ECD - 10.9-11.2 12:00 00:00 12.00 12,243 12,986 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 12,443' to 12,986' MD 6202' TVD ADT - 9.17 hrs. WOB 8/11 k RPM 150 GPM 220 2700 psi String wt. PU 200 SO 100 Rot 157 Torque on/off btm. - 12,500/10,500 ft. lbs. ECD - 10.9-11.3 06/08/2006 00:00 03:15 3.25 12,986 13,215 PROD1 DRILL DDRL P Drill 6 1/8" horiz. hole w/ GP f/ 12,986 to 13,215' MD 6195' TVD ADT - 2.98 hrs. WOB 8/11 k RPM 150 GPM 220 2830 psi String wt. PU 195 SO 100 Rot 157 Torque on/off btm. - 12,000/11,500 ft. lbs. ECD - 11.2-11.45 03:15 05:30 2.25 13,215 12,881 PROD1 DRILL CIRC P Circ hole clean - 220 gpm / 2750 psi / 150 rpm Stood back 1 stand every 30 minutes to 12881' -flow check well, static 05:30 14:30 9.00 12,881 7,256 PROD1 DRILL TRIP P POOH from 12.881' to 7,256' - 168 gpm / 1700 psi / 80 rpm -hole appears in ood condition 14:30 16:00 1.50 7,256 6,970 PROD1 DRILL CIRC P Circ and cond mud -increased mud wt. to 9.6 ppg - 225 gpm / 2200 psi / 80 rpm stood back 3 stands to 6,970' - flow check well, static 16:00 18:45 2.75 6,970 4,684 PROD1 DRILL TRIP P POOH f/ 6970' to 6,017' - 3.5 bpm / 1000 psi -attempt to POOH without pump -well swabbing -flow check well, static. Continue POOH to 4,684' with um .. 18:45 21:30 2.75 4,684 399 PROD1 DRILL TRIP P POOH on Trip tank from 4,684' to 399'. 21:30 00:00 2.50 399 30 PROD1 DRILL PULD P POOH and lay down BHA. 06/09/2006 00:00 01:45 1.75 30 0 PROD1 DRILL PULD P Lay down pony flex, stab, bit, GeoPilot and flex drill collars -clear tools from floor 01:45 02:15 0.50 0 0 COMPZ RPCOh RURD P Rig up to run 4 1/2" liner 02:15 02:30 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with crew 02:30 07:15 4.75 0 6,333 COMPZ RPCOh PULD P Pick up 159 jts of 4 1/2", 12.6 ppf, L-80 Blank and slotted liner oa=6333' ~ ~~ ~. ~.~.~ ~ _ P~~ 9 ~t 11 Time Logs - Date From To Dur th E. De th Phase Code Subcode T OM 06!09/2006 07:15 08:45 1.50 6,333 6,371 COMPZ RPCOh PULD P PU Baker Liner hanger assembly - MU schlumberger CET tools - MU hanger assembly -fill tie back with Pal mix and let set u 08:45 12:45 4.00 6,371 13,205 COMPZ RPCOh RCST P RIH w/liner from 6371', tagged bottom at 13,215' , icked u to settin de th. 12:45 13:45 1.00 13,205 13,205 COMPZ RPCOh OTHR P Establish circ @ 2 bpm / 570 psi - drop setting ball and pump down to seat -Set liner hanger and anchor test with 50K SOW -pressure up to 3500 psi -bled off and released running tool from hanger assembly with shoe @ 13,205', Top of Tie back @ 6,840'- flow check well, static. 13:45 15:30 1.75 13,205 5,686 COMPZ RPCOh OTHR P POOH @ 30 fpm from 6873' to 5686' for cement bond l0 1.5 b m / 180 si 15:30 18:00 2.50 5,686 3,527 COMPZ RPCOti TRIP P Flow check well, static -attempted to pull pipe without pump, hole swabbing - POOH from 5,686' to 3,527 2.5 bpm / 270 si 18:00 20:30 2.50 3,527 75 COMPZ RPCOR TRIP P POOH on Trip tank from 3,527' to 75'. 20:30 21:00 0.50 75 0 COMPZ RPCOh PULD P Laid down schlumberger memory tool and liner runnin tool. 21:00 22:45 1.75 0 0 COMPZ RPCOh RURD P Pulled wear bushing. Laid down Geospan. Rigged up to run Tubing. PJSM. 22:45 00:00 1.25 0 600 COMPZ RPCOh RCST P Ran 4.5" completion string to 600'. 06/10/2006 00:00 07:00 7.00 600 6,840 COMPZ RPCOh RCST P RIH picking up 4 1/2", 12.6 ppf, L-80 IBTM production tubing from 600' to 6849' -observed locator pins sheer at liner to w/10 k 07:00 08:45 1.75 6,840 0 COMPZ RPCOh RCST P MU space out pup joints - MU FMC tubing hanger and LJa -land hanger in well head -locator sub spaced out 2' above TOL. WLEG @ 6,847' Tops of XN nipple @ 6,503' /Packer @ 6,445' / GLM @ 6,339' / DB nipple @ 2,001' {total of 169 jts of tubing ran) PUW 142K SOW 132K 08:45 10:15 1.50 0 0 COMPZ RPCOR DHEQ P RILDS - LD LJa -Install TWC in hanger - MU LJb -test M/M hanger seals to 5000 si - LD LJb 10:15 11:15 1.00 0 0 COMPZ RPCOh OTHR P Blow down choke, kill and hole fill lines - PU stack washer sub and flush out BOP stack - LD stack washer 11:15 14:30 3.25 0 0 COMPZ RPCOh OTHR P Clean Rig Floor, iron roughneck, pollution pan below rotary table, floor drains and drill pipe drip pans of MOBM 14:30 15:30 1.00 0 0 COMPZ RPCOh NUND P Nd flowline, riser and BOP stack 15:30 18:00 2.50 0 0 COMPZ RPCOti NUND P Nippled up Xmas Tree and tested to 5000 si. Pulled TWC. ~~ ® P 1~ f ~ ~ ~~ Time Logs Date From To Dur .~. . b th E. De th Phase Code Subcode T OM _ 06/10/2006 18:00 21:00 3.00 0 0 COMPZ RPCOh FRZP P Rigged up Squeeze Manifold and Dowell pumped 5 bbls Mineral oil. Tested lines to 2500 psi. Pumped with Dowell 15 bbls MO followed by 232 bbls diesel to freeze protect well @ 3 BPM. 21:00 00:00 3.00 0 0 COMPZ RPCOb PACK P Pressue tested line to 5000PS1. Pressured up tubing to 4500 PSI and set packer. Bled pressure to 3500 PSI and tested tubing 30 Min. Bled tubing to 2200 PSI and Pressured annulus to 3500 PSI for 30 Min. Bled annulus to 0. Bled tubin to 500 PSI. 06/11/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh FRZP P RD circulating lines to wellhead 00:15 01:15 1.00 0 0 COMPZ RPCOh OTHR P Install BPV w/ FMC lubricator -secure wellhead 01:15 07:15 6.00 0 0 COMPZ RPCOh OTHR P Lay down excess drill pipe from derrick - clear tools from floor 07:15 08:00 0.75 0 0 COMPZ RPCOh OTHR P Finish MOBM clean up on rig floor - Released rig to CD4-210 @ 0800 hours e~ s- _ ~ ~ '~e 11 flf 11~ . Halliburton Company Survey Report Company:.-ConocoPhillipsAlaska Inc. Date: 6/27/2006 Time: 10:53:58 Pade: 1 Field: ColvifleRiver Unit Co-ordinate(NE) Rcfercncr. Well: CD4-209, True North . Sife: Alpine CD4 Vertical (TVD) Re ference: CD4-209: 56.4 Well: CD4-209 Section (VS) Refer ence: Well (O.OON,QO OE,160:90Azi) Wellpath: C04-209 Survey Calculation Method: Minimum Curva _ _-- __- ture , Db: Oracle Field: Colville River Unit _ North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD4-209 Slot Name: Alpine CD4 WeII Position: +N/-S -40.03 ft Northing: 5957488.60 ft . Latitude: 70 17 32.572 N +E/-W -155.43 Position Uncertainty: 0.00 ft Easting : 378018.65 ft ft Longitude: 150 59 15.293 W Wellpath: CD4-209 Drilled From: Well Ref. Point 501032053200 Tie-on Depth: 37.40 ft j Current Datum: CD4-209: Height 56.40 ft Above System Datum: Mean Sea Level Magnetic Data: 5/22/2005 Declination: 23.69 deg i Field Strength: 57493 nT Mag Dip Angle: 80.61 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction i ft ft ft deg ~~ 37.40 ` 0.00 0.00 160.90 Survey Program for Definitive Wellpath ' ~i Date: 6/29/2005 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 85.00 533.00 CD4-209 gyro (85.00-533.00) CB-GYRO-SS Camera based gyro single shot ~I 658.43 13175.30 CD4-209 (658.43-13 175.30) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C I, Survey D]ll Incl Azim fVD Sys TVD N/S E/W MapN MapE Tool ' ft deg deg ft ft ft ft ft ft I 37.40 0.00 0.00 37.40 -19.00 0.00 0.00 5957488.60 378018.65 TIE LINE I ~i 85.00 0.25 202.00 85.00 28.60 -0.10 -0.04 5957488.50 378018.61 CB-GYRO-SS 172.00 0.70 247.00 172.00 115.60 -0.48 -0.60 5957488.13 378018.04 CB-GYRO-SS '' ~~ 261.00 1.10 247.00 260.99 204.59 -1.03 -1.89 5957487.60 378016.75 CB-GYRO-SS '~~ 350.00 1.15 199.00 I 349.97 293.57 -2.20 -2.96 5957486.44 378015.65 CB-GYRO-SS ~I 442.00 1.50 198.00 441.95 385.55 -4.22 -3.64 5957484.44 378014.95 CB-GYRO-SS ' i 533.00 1.00 173.00 532.92 476.52 -6.14 -3.91 5957482.52 378014.64 CB-GYRO-SS 658.43 1.45 167.32 658.33 601.93 -8.78 -3.43 5957479.88 378015.08 MWD+IFR-AK 750.40 1.13 159.92 750.27 693.87 -10.77 -2.86 5957477.88 378015.62 MWD+IFR-AK ', 839.98 1.00 118.20 839.84 783.44 -11.96 -1.87 5957476.67 378016.59 MWD+IFR-AK I'i 934.60 0.90 95.54 934.45 878.05 -12.43 -0.40 5957476.18 378018.05 MWD+IFR-AK ', I 1029.89 0.91 105.20 1029.72 973.32 -12.70 1.08 5957475.89 378019.52 MWD+IFR-AK ~, 1124.69 2.14 175.42 1124.49 1068.09 -14.66 1.94 5957473.91 378020.36 MWD+IFR-AK 1219.39 4.37 196.27 1219.04 1162.64 -19.89 1.07 5957468.70 378019.40 MWD+IFR-AK 1314.69 4.94 203.52 1314.02 1257.62 -27.13 -1.58 5957461.50 378016.63 MWD+IFR-AK 1409.58 4.16 201.12 1408.61 1352.21 -34.09 -4.45 5957454.59 378013.65 MWD+IFR-AK 1504.99 4.22 212.73 1503.77 1447.37 -40.27 -7.60 5957448.46 378010.40 I MWD+IFR-AK !~ 1600.74 5.90 208.48 1599.15 1542.75 -47.56 -11.85 5957441.24 378006.03 MWD+IFR-AK ~' 'I 1695.78 6.54 209.97 1693.63 1637.23 -56.54 -16.88 5957432.34 378000.86 MWD+IFR-AK 1790.85 6.94 208.52 ~ 1788.04 1731.64 -66.28 -22.33 5957422.70 377995.25 MWD+IFR-AK i i ~ 1886.00 8.09 218.78 1882.37 1825.97 -76.55 -29.27 5957412.54 377988.15 MWD+IFR-AK 1980.96 9.45 218.63 1976.22 1919.82 -87.85 -38.32 5957401.39 377978.91 MWD+IFR-AK 2075.90 11.05 211.55 2069.65 2013.25 -101.69 -47.95 5957387.71 377969.06 MWD+IFR-AK 2170.77 11.17 212.98 2162.74 2106.34 -117.15 -57.71 5957372.41 377959.06 MWD+IFR-AK ', 2266.41 11.76 210.06 2256.47 2200.07 -133.36 -67.63 5957356.37 377948.87 MWD+IFR-AK !, 2351.09 12.70 210.90 2339.23 2282.83 -148.81 -76.73 5957341.06 377939.52 MWD+IFR-AK li 2430.50 12.70 212.00 2416.70 2360.30 -163.71 -85.84 5957326.32 377930.17 MWD+IFR-AK 2510.67 12.73 212.98 2494.90 2438.50 -178.59 -95.32 5957311.60 377920.45 MWD+IFR-AK 2605.91 12.79 214.22 2587.79 2531.39 -196.11 -106.96 5957294.27 377908.53 MWD+IFR-AK • Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. llate: 6/27/2006 Time: 10:53:58 Page: 2 Rield: Colville Rive r Unit Co-or dinatc (NE) Reference: Well: CD4-209, True North Site: Alpine CD4 i'ertical (TVD) Reference: Cd4-209: 56.4 Well: CD4-209 Sectio n (VS) Reference: Well (O.OON,O.O OE,160~90Azi) Wellpath: CD4-209 Survey Calc ulation Method: Minimum C urva ture Db: Oracle Survcv ____ ~~1D Incl Azim TVD Sys'I'V D \'/S F,IW Map1 MapE Tool ft deg deg ft ft ft ft ft ft ii 2699.53 12.28 214 .77 2679. 18 2622. 78 -212 .86 -118. 47 5957277 .71 377896 .76 MWD+IFR-AK 2796.56 11.47 215 .40 2774. 13 2717. 73 -229 .20 -129. 94 5957261 .56 377885 .02 MWD+IFR-AK 2891.39 10.86 216 .73 2867. 16 2810. 76 -244 .04 -140. 74 5957246 .89 377873 .98 MWD+IFR-AK 2988.65 11.71 212 .82 2962 .54 2906. 14 -259 .68 -151. 57 5957231 .43 377862 .90 MWD+IFR-AK 3084.16 12.45 212 .21 3055 .94 2999. 54 -276 .54 -162. 31 5957214 .76 377851 .88 MWD+IFR-AK 3179.47 12.56 211 .79 3148. 99 3092. 59 -294 .04 -173. 25 5957197 .44 377840 .67 MWD+IFR-AK 3274.91 13.34 211 .02 3242. 00 3185. 60 -312 .29 -184. 39 5957179 .36 377829 .23 MWD+IFR-AK 3370.37 15.00 209 .96 3334. 55 3278. 15 -332 .44 -196. 24 5957159. 42 377817. 06 MWD+IFR-AK 3465.40 15.22 209 .21 3426. 30 3369. 90 -353 .98 -208. 47 5957138 .08 377804. 49 MWD+IFR-AK 3560.36 17.44 207 .79 3517. 42 3461. 02 -377 .45 -221. 18 5957114 .82 377791 .39 MWD+IFR-AK 3657.02 19.06 206 .66 3609. 21 3552. 81 -404 .37 -235. 02 5957088 .13 377777 .12 MWD+IFR-AK 3752.40 19.63 205 .63 3699. 21 3642. 81 -432 .73 -248. 94 5957060 .00 377762 .74 MWD+IFR-AK ~ 3847.87 19.39 205 .49 3789. 20 3732. 80 -461 .50 -262. 69 5957031 .46 377748 .52 MWD+IFR-AK ~~ 3943.29 21.55 200 .07 3878. 60 3822. 20 -492 .26 -275. 53 5957000 .91 377735 .19 MWD+IFR-AK I 4038.99 21.78 196 .56 3967. 54 3911. 14 -525 .79 -286. 62 5956967 .57 377723 .56 MWD+IFR-AK ' 4134.69 20.99 193 .97 4056. 65 4000. 25 -559 .44 -295. 82 5956934 .08 377713 .82 MWD+IFR-AK ' 4230.25 20.56 193 .08 4146. 00 4089. 60 -592 .40 -303. 75 5956901 .26 377705 .36 MWD+IFR-AK 4323.39 20.26 191 .07 4233. 29 4176. 89 -624 .15 -310. 55 5956869 .62 377698 .04 MWD+IFR-AK 4418.95 20.66 188 .95 4322. 82 4266. 42 -657 .04 -316. 35 5956836 .83 377691 .71 MWD+IFR-AK 4514.31 19.98 186 .92 4412. 25 4355. 85 -689 .84 -320. 93 5956804 .12 377686 .60 MWD+IFR-AK 4610.05 19.53 188 .20 4502 .36 4445. 96 -721 .91 -325. 18 5956772 .12 377681 .83 MWD+IFR-AK ', 4705.49 19.66 189 .51 4592 .27 4535. 87 -753 .54 -330. 11 5956740 .58 377676 .39 MWD+IFR-AK ~ 4800.89 20.22 191 .22 4681. 95 4625. 55 -785 .54 -335. 97 5956708 .68 377670 .01 MWD+IFR-AK 4896.51 20.92 191 .31 4771 .47 4715. 07 -818 .48 -342. 53 5956675 .85 377662 .91 MWD+IFR-AK 4991.82 21.73 191 .58 4860 .26 4803. 86 -852 .46 -349. 41 5956642 .00 377655 .49 MWD+IFR-AK 5087.01 23.10 191 .42 4948 .25 4891. 85 -888 .02 -356. 64 5956606 .55 377647 .67 MWD+IFR-AK 5182.65 23.82 190 .18 5035 .99 4979. 59 -925 .42 -363. 77 5956569 .28 377639 .94 MWD+IFR-AK 5277.88 23.49 187 .64 5123 .22 5066. 82 -963 .16 -369. 69 5956531 .64 377633 .41 MWD+IFR-AK ! 5373.00 24.86 185 .63 5210 .00 5153. 60 -1001 .85 -374. 18 5956493 .04 377628 .30 ~ MWD+IFR-AK ~ 5468.34 26.74 183 .25 5295 .83 5239. 43 -1043 .21 -377. 36 5956451 .73 377624 .45 MWD+IFR-AK ~ 5563.34 29.23 181 .07 5379 .72 5323. 32 -1087 .75 -379. 00 5956407 .23 377622 .08 MWD+IFR-AK j 5658.60 32.29 177 .63 5461 .57 5405. 17 -1136 .44 -378. 39 5956358 .54 377621 .91 MWD+IFR-AK 5753.65 33.17 171 .17 5541 .56 5485. 16 -1187 .52 -373. 34 5956307 .39 377626 .12 MWD+IFR-AK 5848.88 34.99 168 .48 5620. 43 5564. 03 -1240 .02 -363. 89 5956254 .75 377634 .72 MWD+IFR-AK 5944.06 38.25 167 .42 5696. 81 5640. 41 -1295 .53 -352. 02 5956199 .06 377645 .69 MWD+IFR-AK 6039.18 41.40 166 .89 5769. 86 5713. 46 -1354 .92 -338. 47 5956139 .46 377658 .27 MWD+IFR-AK 6134.41 45.40 166 .49 5839. 04 5782. 64 -1418 .58 -323. 40 5956075 .57 377672 .30 i MWD+IFR-AK 'i 6229.55 50.70 166 .33 5902. 61 5846. 21 -1487 .33 -306. 78 5956006 .57 377687 .81 MWD+IFR-AK !, 6324.70 55.08 164 .81 5960. 01 5903. 61 -1560 .79 -287. 84 5955932 .82 377705 .54 MWD+IFR-AK ~ ~i 6419.78 58.73 161 .67 6011. 93 5955. 53 -1637 .02 -264. 84 5955856 .23 377727 .31 MWD+IFR-AK 6515.03 61.63 158 .23 6059. 30 6002. 90 -1714 .61 -236. 48 5955778 .20 377754 .40 MWD+IFR-AK 6610.16 66.32 157 .42 6101 .03 6044. 63 -1793 .74 -204. 22 5955698 .56 377785 .37 MWD+IFR-AK 6705.04 71.27 154 .99 6135 .34 6078. 94 -1874 .63 -168. 51 5955617 .10 377819 .76 MWD+IFR-AK 6800.44 74.83 152 .86 6163 .15 6106. 75 -1956 .58 -128. 40 5955534 .53 377858 .53 MWD+IFR-AK 6895.43 78.82 152 .74 6184 .80 6128. 40 -2038 .82 -86. 13 5955451 .61 377899 .46 MWD+IFR-AK i 6973.31 80.45 153 .25 6198 .81 6142. 41 -2107 .07 -51. 34 5955382 .81 377933 .13 MWD+IFR-AK ', 7029.00 81.07 151 .06 6207 .75 6151. 35 -2155 .67 -25. 67 5955333 .81 377958 .01 MWD+IFR-AK 7069.39 83.14 151 .64 6213 .30 6156. 90 -2190 .78 -6. 49 5955298 .40 377976 .61 MWD+IFR-AK ~ ; 7124.44 84.19 152 .11 6219 .37 6162. 97 -2239 .03 19. 30 5955249 .73 378001 .62 MWD+IFR-AK i 7164.97 84.38 152 .35 6223 .41 6167. 01 -2274 .72 38. 09 5955213 .75 378019 .82 MWD+IFR-AK 7220.17 84.25 151 .22 6228 .88 6172. 48 -2323 .12 64. 06 5955164 .94 378045 .00 MWD+IFR-AK 7259.68 86.05 152 .56 6232 .22 6175. 82 -2357 .84 82. 61 5955129 .93 378062 .98 MWD+IFR-AK Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc: Dater 6/27/20D6 Tame: 10:53:58 Page: 3 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD4-209, True Norfh Site: Alpine CD4 Vertical (TVD) Reference: CD4-209: 56.4 Well: CD4-209 Section (VS) Reference: Well (O:OON,O.OOE,160.90Azi) Wellpath: CD4-2D9 Survey Calculation Method: Minimum Curvature Db: Oracle Sur~'eti ` ___ ___ - __ 1vID lnc1 Azim TVll Sys "T~'D NlS E/Vb' MapN MapE Toul ft deg deg ft ft ft ft ft ft 7314.85 85.14 152.41 6236.45 6180.05 -2406.63 108.02 5955080.74 378087.60 MWD+IFR-AK 7365.14 84.89 153.57 6240.82 6184.42 -2451.26 130.77 5955035.74 378109.62 MWD+IFR-AK ~' 7411.03 86.07 154.32 6244.44 6188.04 -2492.36 150.86 5954994.33 378129.04 MWD+IFR-AK 7457.39 87.62 155.65 6246.99 6190.59 -2534.30 170.44 5954952.08 378147.93 MWD+IFR-AK j 7506.34 89.10 155.91 6248.39 6191.99 -2578.92 190.51 5954907.14 378167.27 MWD+IFR-AK 7551.60 89.78 156.01 6248.84 6192.44 -2620.26 208.95 5954865.52 378185.04 MWD+IFR-AK 7601.62 91.20 154.80 6248.41 6192.01 -2665.73 229.76 5954819.71 378205.11 MWD+IFR-AK it 7645.01 91.69 154.78 6247.31 6190.91 -2704.98 248.24 5954780.17 378222.95 MWD+IFR-AK 7696.78 91.87 154.86 6245.71 6189.31 -2751.81 270.25 5954733.00 378244.20 MWD+IFR-AK ~ 7742.08 93.85 155.78 6243.45 6187.05 -2792.92 289.14 5954691.59 378262.42 MWD+IFR-AK 7791.75 94.28 155.24 6239.92 6183.52 -2838.00 309.68 5954646.18 378282.22 MWD+IFR-AK 7837.88 93.81 154.61 6236.67 6180.27 -2879.68 329.18 5954604.20 378301.04 MWD+IFR-AK ' 7886.79 93.32 154.41 6233.63 6177.23 -2923.74 350.19 5954559.80 378321.33 MWD+IFR-AK 7927.95 93.57 153.70 6231.16 6174.76 -2960.69 368.17 5954522.57 378338.70 MWD+IFR-AK 7981.95 92.58 153.53 6228.26 6171.86 -3008.99 392.13 5954473.89 378361.87 MWD+IFR-AK i 8027.97 92.27 154.56 6226.31 6169.91 -3050.33 412.25 5954432.23 378381.32 MWD+IFR-AK j i, 8078.93 92.39 155.21 6224.24 6167.84 -3096.44 433.86 5954385.79 378402.18 MWD+IFR-AK ~ 8122.59 92.76 155.50 6222.28 6165.88 -3136.08 452.05 5954345.86 378419.72 MWD+IFR-AK ii 8173.94 93.81 156.99 6219.34 6162.94 -3183.00 472.70 5954298.61 378439.60 MWD+IFR-AK ~! 8222.51 94.06 156.24 6216.00 6159.60 -3227.48 491.93 5954253.84 378458.11 MWD+IFR-AK ~~ 8268.96 93.19 156.48 6213.07 6156.67 -3269.94 510.52 5954211.08 378476.01 MWD+IFR-AK 8317.08 91.96 155.53 6210.90 6154.50 -3313.86 530.07 5954166.85 378494.84 MWD+IFR-AK 8364.21 92.76 155.29 6208.96 6152.56 -3356.68 549.67 5954123.73 378513.73 MWD+IFR-AK 8408.68 92.76 155.30 6206.82 6150.42 -3397.03 568.23 5954083.08 378531.64 MWD+IFR-AK 8459.49 92.51 153.85 6204.49 6148.09 -3442.87 590.02 5954036.90 378552.68. MWD+IFR-AK ~, '~ 8507.01 91.40 152.15 6202.87 6146.47 -3485.18 611.58 5953994.24 378573.55 MWD+IFR-AK ~ 8555.44 89.67 152.27 6202.41 6146.01 -3528.02 634.16 5953951.05 378595.43 MWD+IFR-AK ', 8602.09 89.49 152.74 6202.75 6146.35 -3569.40 655.69 5953909.33 378616.29 MWD+IFR-AK 8650.18 89.74 152.62 6203.08 6146.68 -3612.13 677.77 5953866.25 378637.66 MWD+IFR-AK ' 8696.14 88.64 153.79 6203.73 6147.33 -3653.15 698.48 5953824.90 378657.71 MWD+IFR-AK 8746.50 86.96 152.91 6205.66 6149.26 -3698.12 721.05 5953779.57 378679.54 MWD+IFR-AK ~~ 8790.69 86.71 153.09 6208.10 6151.70 -3737.44 741.08 5953739.94 378698.93 MWD+IFR-AK '~ 8840.83 86.28 153.59 6211.17 6154.77 -3782.16 763.54 5953694.86 378720.66 MWD+IFR-AK 8885.94 86.03 155.12 6214.19 6157.79 -3822.73 783.02 5953653.98 378739.47 MWD+IFR-AK 8936.25 86,71 155.98 6217.38 6160.98 -3868.44 803.80 5953607.95 378759.51 MWD+IFR-AK 8980.55 87.45 156.91 6219.63 6163.23 -3909.00 821.48 5953567.12 378776.53 MWD+IFR-AK 9031.88 87.33 156.62 6221.97 6165.57 -3956.11 841.71 5953519.68 378795.99 MWD+IFR-AK 9074.66 86.46 155.91 6224.29 6167.89 -3995.22 858.90 5953480.31 378812.54 MWD+IFR-AK 9127.41 86.34 155.10 6227.60 6171.20 -4043.12 880.73 5953432.05 378833.59 MWD+IFR-AK i 9171.19 86.22 154.35 6230.44 6174.04 -4082.63 899.38 5953392.25 378851.60 MWD+IFR-AK 9222.53 86.59 154.27 6233.66 6177.26 -4128.80 921.59 5953345.73 378873.05 MWD+IFR-AK 9265.30 86.53 153.64 6236.23 6179.83 -4167.16 940.34 5953307.08 378891.17 MWD+IFR-AK ~ ~' 9317.33 86.53 152.64 6239.38 6182.98 -4213.49 963.80 5953260.38 378913.88 MWD+IFR-AK 9371.41 86.15 153.30 6242.83 6186.43 -4261.57 988.33 5953211.91 378937.62 MWD+IFR-AK ~, 9413.25 86.40 153.70 6245.55 6189.15 -4298.93 1006.96 5953174.25 378955.64 MWD+IFR-AK 9457.62 87.39 154.09 6247.95 6191.55 -4338.72 1026.45 5953134.16 378974.49 MWD+IFR-AK 9508.67 88.81 154.41 6249.64 6193.24 -4384.67 1048.62 5953087.86 378995.90 MWD+IFR-AK 9554.10 89.06 154.08 6250.49 6194.09 -4425.58 1068.36 5953046.64 379014.97 MWD+IFR-AK i 9603.90 90.05 154.88 6250.87 6194.47 -4470.52 1089.81 5953001.36 379035.69 MWD+IFR-AK 9647.76 91.03 156.47 6250.46 6194.06 -4510.48 1107.88 5952961.11 379053.10 MWD+IFR-AK II 9698.95 91.71 156.42 6249.24 6192.84 -4557.39 1128.33 5952913.88 379072.79 MWD+IFR-AK ~ 9742.76 92.82 156.62 6247.50 6191.10 -4597.54 1145.77 5952873.45 379089.58 MWD+IFR-AK 9795.14 92.70 155.35 6244.98 6188.58 -4645.33 1167.06 5952825.33 379110.09 MWD+IFR-AK --- - - -- Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc Field: Colville River Unit Site: Alpine CD4 I ' Wetl: CD4-209 ~~'cllpath: CD4-209 Survev MD 1 ncI Azim 'I ft deg deg --- I i 9838.87 92.02 154.66 9889.94 92.02 155.13 9931.97 -92.45 154.60 9986.43 92.64 152.84 10026.86 91.90 152.38 10081.51 92.70 151.50 10116.43 92.14 151.65 10176.99 91.90 151.36 10210.38 92.14 151.18 10272.03 91.65 153.33 10320.56 91.53 155.39 10367.31 93.20 155.23 10416.14 93.50 154.29 10462.48 92.45 153.09 10511.28 91.52 153.01 10557.31 91.96 152.67 ', 10604.73 92.51 152.88 10653.74 93.88 153.36 10700.56 92.88 153.20 10749.21 91.90 153.23 10798.16 91.65 154.22 ~~ 10844.30 91.59 155.46 10887.72 91.09 155.73 ~ 10939.15 90.23 155.57 ~, 10988.43 89.37 155.44 ii 11033.74 88.19 155.65 ~~ 11081.82 86.65 155.43 ~~ 11130.07 86.77 155.41 11174.45 86.83 154.61 11225.03 87.33 154.76 11272.64 87.45 154.08 11319.89 87.21 153.65 11369.33 86.96 153.51 11415.46 86.84 153.25 11461.90 85.66 152.68 11510.84 85.91 154.33 ii 11559.68 87.58 154.46 11605.78 89.00 155.22 11653.86 90.48 155.23 11702.46 90.91 154.70 11748.17 90.48 153.74 ~ 11798.04 89.37 151.91 11845.19 88.81 151.57 11892.04 89.86 151.77 11940.37 90.48 153.34 ', 11988.53 89.80 154.91 Date: 6/27/2006 Time: 10:53:58 Page: 4 Co-ordinate(NE) Reference: Welt CD4=209, True North Vertical (TVD) Reference: CD4-209: 56.4 Section (VS) Reference: Well (O.OON,O.OOE,160.90Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 'I`U'D - - tit's "FVD _N/S E/W ft ft ft ft 6243. 18 6186 .78 -4684 .93 1185. 52 6241. 38 6184 .98 -4731. 15 1207. 18 6239. 74 6183 .34 -4769. 17 1225. 02 6237. 32 6180 .92 -4817. 95 1249. 10 6235. 72 6179 .32 -4853. 82 1267. 69 6233. 53 6177 .13 -4902. 01 1293. 37 6232. 05 6175 .65 -4932. 69 1309. 98 6229. 92 6173 .52 -4985 .88 1338. 86 6228. 74 6172 .34 -5015. 14 1354. 90 6226. 70 6170 .30 -5069 .67 1383. 58 6225. 36 6168 .96 -5113 .40 1404. 57 6223. 43 6167 .03 -5155 .84 1424. 08 6220. 57 6164 .17 -5199 .93 1444. 86 6218. 17 6161 .77 -5241 .41 1465. 38 6216. 48 6160 .08 -5284. 89 1487. 48 6215. 08 6158 .68 -5325. 82 1508. 48 6213. 23 6156 .83 -5367. 96 1530. 16 6210. 50 6154 .10 -5411. 60 1552. 28 6207. 74 6151 .34 -5453. 35 1573. 30 6205. 71 6149 .31 -5496 .74 1595. 20 6204. 20 6147 .80 -5540. 61 1616. 86 6202. 89 6146 .49 -5582 .36 1636. 47 6201. 88 6145 .48 -5621 .89 1654. 40 6201. 28 6144 .88 -5668 .74 1675. 61 6201. 46 6145 .06 -5713 .58 1696. 04 6202. 42 6146 .02 -5754 .82 1714. 79 6204. 58 6148 .18 -5798. 54 1734. 68 6207. 35 6150 .95 -5842. 34 1754. 72 6209. 83 6153 .43 -5882. 50 1773. 43 6212. 41 6156 .01 -5928. 17 1795. 03 6214. 58 6158 .18 -5971. 07 1815. 57 6216. 78 6160 .38 -6013. 44 1836. 36 6219. 29 6162 .89 -6057. 66 1858. 33 6221. 79 6165 .39 -6098. 84 1878. 97 6224. 82 6168 .42 -6140. 11 1900. 03 6228. 42 6172 .02 -6183 .79 1921. 80 6231. 19 6174 .79 -6227 .77 1942. 88 6232. 57 6176 .17 -6269 .47 1962. 47 6232. 79 6176 .39 -6313 .12 1982. 61 6232. 20 6175 .80 -6357. 16 2003. 18 6231. 64 6175 .24 -6398. 31 2023. 06 6231. 71 6175 .31 -6442. 67 2045. 83 6232. 46 6176 .06 -6484. 20 2068. 15 6233. 00 6176 .60 -6525. 43 2090. 38 6232. 86 6176 .46 -6568. 32 2112. 66 6232. 74 6176 .34 -6611. 65 2133. 67 (V1apN _ 11apE __ Fool ft ft 5952785 __- .44 379127 .90 __._. MWD+IFR-AK 5952738 .88 379148 .80 MWD+IFR-AK 5952700. 58 379166. 02 MWD+IFR-AK j 5952651. 42 379189. 31 MWD+IFR-AK I~ 5952615. 25 379207. 31 MWD+IFR-AK ~ 5952566. 66 379232. 21 MWD+IFR-AK 5952535. 72 379248 .32 MWD+IFR-AK 5952482. 07 379276. 32 MWD+IFR-AK 5952452. 55 379291 .88 MWD+IFR-AK 5952397. 57 379319 .67 MWD+IFR-AK 5952353. 51 379339 .95 MWD+IFR-AK 5952310. 76 379358 .77 MWD+IFR-AK ~I 5952266 .34 379378 .83 MWD+IFR-AK 5952224 .54 379398 .67 MWD+IFR-AK 5952180. 71 379420 .06 MWD+IFR-AK 5952139. 44 379440. 39 MWD+IFR-AK 5952096. 97 379461. 38 MWD+IFR-AK ~! 5952052. 97 379482. 79 MWD+IFR-AK 5952010. 89 379503. 13 MWD+IFR-AK ~ 5951967. 16 379524. 32 I MWD+IFR-AK 5951922. 94 379545 .26 I MWD+IFR-AK 5951880. 89 379564 .19 MWD+IFR-AK 5951841. 08 379581 .48 MWD+IFR-AK I~ 5951793. 89 379601 .92 MWD+IFR-AK 5951748. 73 379621 .62 MWD+IFR-AK 5951707 .19 379639 .70 MWD+IFR-AK 5951663. 16 379658 .87 MWD+IFR-AK 5951619. 04 379678. 19 MWD+IFR-AK 5951578. 58 379696. 26 MWD+IFR-AK 5951532. 58 379717. 11 MWD+IFR-AK 5951489. 36 379736. 95 MWD+IFR-AK 5951446. 66 379757. 05 MWD+IFR-AK 5951402. 09 379778. 29 MWD+IFR-AK 5951360. 58 379798. 26 MWD+IFR-AK 5951318. 98 379818. 65 MWD+IFR-AK 5951274. 95 379839 .71 MWD+IFR-AK 5951230. 65 379860 .06 MWD+IFR-AK ~I 5951188. 63 379878 .97 MWD+IFR-AK 5951144. 66 379898 .41 MWD+IFR-AK 5951100. 31 379918. 25 MWD+IFR-AK ~i 5951058. 84 379937. 46 MWD+IFR-AK 5951014. 11 379959. 51 MWD+IFR-AK 5950972. 24 379981. 15 MWD+IFR-AK 5950930. 65 380002. 71 MWD+IFR-AK 5950887. 41 380024. 28 MWD+IFR-AK I, 5950843. 75 380044. 59 MWD+IFR-AK I I 5950802. 10 380062. 85 MWD+IFR-AK 5950756. 36 380082. 28 MWD+IFR-AK 5950713. 94 380100 .21 MWD+IFR-AK 5950668. 53 380119 .08 MWD+IFR-AK 5950627. 27 380135 .83 MWD+IFR-AK 5950580. 69 380154. 68 MWD+IFR-AK 12034.01 89 .80 155. 89 6232. 90 6176 .50 -6653. 00 2152. 61 12083.71 90 .11 156. 21 6232. 94 6176 .54 -6698 .43 2172. 78 12129.77 88 .93 156. 12 6233. 32 6176 .92 -6740. 56 2191. 39 12178.95 89 .61 156. 87 6233. 95 6177 .55 -6785 .65 2211. 01 12223.49 90 .79 157. 08 6233. 79 6177 .39 -6826 .64 2228. 43 12273.76 92 .64 157. 01 6232. 29 6175 .89 -6872. 91 2248. 02 • Halliburton Company ' Survey Report Company: ConocoPhillips Alaska Inc. Field: Colville Rive r Unit Site: Alpine CD4 VVeIL• CD4-209 ~'fellpath: CD4-209 Survey MD lncl Azim ft deg deg 12318.81 92.70 154.40 12368.89 92.14 155.01 12413.17 92.89 154.66 12452.62 91.90 153.55 12508.12 91.53 153.33 12559.02 91.90 154.07 12602.37 92.08 154.35 12654.45 92.27 154.04 12701.50 92.95 153.60 ~ 12749.00 92.33 152.98 12792.56 91.40 152.04 12843.68 91.34 152.91 12887.74 92.89 152.27 12938.80 92.27 151.47 12984.38 91.71 151.65 13034.09 91.65 151.52 13079.60 92.45 151.99 i 13129.35 92.83 151.50 13159.25 93.13 151.91 ~~ 13175.30 93.26 152.28 13215.00 93.26 152.28 Date: 6/27/2006 Time: 10:53:58 Page: 5 Co-ordinate(NE) Reference: We)1: CD4-209, True North Vertical (Ti'D) Reference: CD4-209: 56.4 Section (VS) Reference: Well (0.OON,O:OOE,160.90Azij Survey Calculation IVlethod: Minimum Curvature llb: Oracle TVD Sys TVD N/S ft ft ft 6230.19 6173.79 -6913.92 6228.08 6171.68 -6959.16 6226.13 6169.73 -6999.20 6224.48 6168.08 -7034.65 6222.82 6166.42 -7084.27 6221.30 6164.90 -7129.88 6219.80 6163.40 -7168.89 6217.82 6161.42 -7215.74 6215.68 6159.28 -7257.92 6213.49 6157.09 -7300.31 6212.07 6155.67 -7338.93 6210.85 6154.45 -7384.25 6209.22 6152.82 -7423.34 6206.92 6150.52 -7468.32 6205.34 6148.94 -7508.37 6203.88 6147.48 -7552.08 6202.26 6145.86 -7592.14 6199.96 6143.56 -7635.92 6198.41 6142.01 -7662.21 6197.52 6141.12 -7676.37 6195.26 6138.86 -7711.46 ElW Ntapr MapE __ Tool ft ft ft 2266.54 5950539.39 _ 380172.52 __ __ MWD+IFR-AK 2287.92 5950493.82 380193.16 MWD+IFR-AK 2306.73 5950453.48 380211.32 MWD+IFR-AK 2323.94 5950417.75 380227.95 MWD+IFR-AK 2348.74 5950367.74 380251.95 MWD+IFR-AK 2371.29 5950321.77 380273.74 MWD+IFR-AK 2390.14 5950282.47 380291.95 MWD+IFR-AK 2412.79 5950235.26 380313.84 MWD+IFR-AK 2433.53 5950192.75 380333.89 MWD+IFR-AK 2454.85 5950150.03 380354.53 MWD+IFR-AK 2474.95 5950111.09 380373.99 MWD+IFR-AK 2498.57 5950065.40 380396.87 MWD+IFR-AK 2518.84 5950025.99 380416.50 MWD+IFR-AK 2542.88 5949980.63 380439.81 MWD+IFR-AK 2564.58 5949940.23 380460.85 MWD+IFR-AK 2588.22 5949896.15 380483.78 MWD+IFR-AK 2609.75 5949855.75 380504.65 MWD+IFR-AK 2633.27 5949811.60 380527.46 MWD+IFR-AK 2647.43 5949785.08 380541.19 MWD+IFR-AK 2654.93 5949770.80 380548.45 MWD+IFR-AK 2673.36 5949735.42 380566.32. PROJECTED ~- ~ ~ _ ~ ~~~- M~'C:~ANICAL INTEGRITY REPORT P UD u:. _ _ : ~ ~~j S _ ~ G, OPER ~ .FIELD Cp ~ ~.oi y`~`~c.~v~c ...c r ~~~~ ~~ . ~ ~/~ ~ - o ~ ~~LL NUMBER LOy-a©~ ~~~c-'~~~ n ~ LL DAT ~_ TD : ~3~OS?-ID.. ~ ~Ct(o TVD ; ?BTD : ?m TvD Casi_^.g ~ ~ Shoe. Co~st•ID ~o~d~ TVD; liV• '~.`~~- ?~ ~~ T4~i ..:~e_ . ~J ~ Shoe: '~ T`Tr,; :OP . ?•~D ""iD =:~oi~y-~ (~. Packer ~,`~ TVD; het et ~~4 S\o1~~~ 1~~c- ole S,ce ~~~~-~ ana Perfs c,a4,~_ to ~3~OS . . -~-oQ off- Z-oc~e. (c,~S"S~ ~L'r'..r~?~=C~..~, IYTEGR?'TY - PART # I rnnulus Press Test• _~ 15 min ~0 min Cor~ents '_~' CHA NIC~~, INTEGR2'r~ _ p~T # 2 ~----~ ~ ~ ~~`~ Cement Volumes :~ Amt . Liner Cs ~ ~155~ DV~_. Cmt -rot to cover oers C 3~Z6 ~,S 1Ll°ZS~~,~-~~~,~ Sy~~`~c~~' ~-o c©~c ,c- -~~ ~.. ~ ~ P ~i z « S-Oc1 F _ erore tical TOC C 3b~ ~S ~ Q ~, ~ S ~-o 047 Cement Bond Log (Yes or No)~_; In AOGCC File ~ j -~ C3L Evaluation, gone aoove perfs S- v,~, ~c~c ~S C ° Productiu« Log: Type Evaluation CONGLJSIOt~S ?art #1 • ?art i 2 : ~"`~ 1 S ~r~CC~~ • • 10-Jul-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD4-209 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 37.40' MD Window /Kickoff Survey: 13,175.30' MD (if applicable) Projected Survey: 13,215.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 O date r~- 2N Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ ~~~ Schlumberger-DCS N0.3891 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken Attn: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~; ~ ~~~ Field: Alpine Color Well Job # Log Description Date BL Prints CD CD4-209 11216201 SCMT 06/09/06 1 SIGNED: DATE: ~ 1.~~/~ t~ 07/24/06 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. • • WELL LOG TRANSMITTAL To: State of Alaska June 30, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-209, AK-MW-4406583 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103 -20532-00. ~-ca~~ ~ t39~r~ ~ STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: dim #-~'q.~e)admin.state.a>t.us~ uo~cc prud~oe b~:v~ad:~n.stae.ak.us b~:l : ~ecken~ts'n :~~aorr:~:~.state. a~. ~~ ~' Contractor: Doyon Rig No.: 19 DATE: 5/28/2006 Rig Rep.: Welsh/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey Field/Unit & Well No.: Colville Rv CD4-209 PTD # 206-065 Operation: Drlg: x Workover: Explor.: ~~ Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P ' Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P ', Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test R No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 2900 P Pressure After Closure 1500 P 200 psi Attained 27 sec P Full Pressure Attained 2 min 28 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ psi 2100 Number of Failures: 1 Test Time: 6 Hours Components tested 28 Repair or replacement of equipment will be made within Immediately days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: dim repp ~adn:i:~.state.a>i.us Remarks: Had to replace ring gasket between unihead and casing head-Also had to replace upper IBOP 24 HOUR NOTICE GIVEN YES X NO Waived By Jeff Jones Date 05/26/06 Time 6:OOpm Witness Grazulis / Mickev Test start 4:OOam Finish BOP Test (for rigs) BFL 11/09/04 Doyonl9 5-28-06 CD4-209.x1s CD4-209 permit to drill • Subject: CD4-?09 permit to drill From:-"Johnsen, ~%~rn" <~ crn.JohnsoncL,conocophillips.com> _. Date: Mon, ?~ ~~lay ?~JO6 i)~._5?:~6 -~"~~00 ~~ l~ .` ~ ~~ ~'I'o: tom maunderl~i:ad~tiin.state.ak.us Tom, We are currently several days ahead of schedule on CD2-404, which means we will be moving to CD4-209 earlier than expected. Anticipated spud date is now Wednesday. Please let me know if there is anything I can do to help expedite processing of the permit for CD4-209. Vern Johnson ~~ ~ / 1 of 1 5/22/2006 8:55 AM "'~ j ~ ~ ~ , FRANK H. MURKOWSKI, GOVERNOR '~ ~LAa7~ ®IL ~ Vr0-7 333 W. T" AVENUE, SUITE 100 COIQSERQA~I'IOIQ CO1~ihiISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq Nanuq Oil Pool, CD4-209 ConocoPhillips Alaska, Inc. Permit No: 206-065 Surface Location: 2923' FNL, 226' FEL, Sec. 24, T11N, R4E, UM Bottomhole Location: 138' FNL, 2527' FEL, Sec. 31, T11N, R5E, 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 an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the. permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster Commissioner DATED thisday of May, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r s~~ J..:-. STATE OF ALASKA ~+;~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill /^ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD4-209 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13304' ' TVD: 6205'• 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2923' FNL, 226' FEL, Sec. 24, T11 N, R4E, UM ' 7. Property Designation: ADL 380077. 384209, 384211, 388903 Nanuq Nanuq Oil pool , Top of Productive Horizon: 5041' FNL, 283' FEL, Sec. 24, T11 N, R4E, UM ~ 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 5/26/2005 Total Depth: 138' FNL, 2527' FEL, Sec. 31, T11 N, RSE, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 5100' FNL 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378019 y- 5957489 ' Zone- 4 10. KB Elevation (Height above GL): 36.7' RKB feet 15. Distance to Nearest Well within Pool: Nanuq 5 , 60' 16. Deviated wells: Kickoff depth: 1000' ~ ft. Maximum Hole Angle: gp° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.os5) Downhole: 280$ psig Surface: 2168 psig ' t 8. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Welded 75 37 37 112 112 pre-installed 12.25 9-518" 40# L-80 BTC 2377 37 37 2414 2400 481 sx AS Lite, 230 sx LiteCRETE 8.75 7" 26# L-80 BTCM 6967 37 37 7004 6206 170 sx Class G 6.125 4.5" 12.6# L-80 SLHT 6450 6854 6177 13304 6205 slotted liner in open hole 4.5" 12.6# L-80 BTCM 6832 32 32 6864 6177 Tubing completion 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements /^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact V. Johnson 265-6081 Printed Name Chip Alvord Title WNS Drilling Team Lead Signature ~~~ ~ rn ~+r2. Gt • I~LVC,e A Phone Date o s `i2 ~21~dfp ^' c V ohn on Commission Use Only Permit to Drill Number: ~~~~ API Number. 50-~~3~~532 ~ Percnit Approval Date: ~_~Z-D~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed~myethane, gas hydrates, or gas contained in shales: U'~V~.~~~ i+:~Cii~1C-~v` c~.7-~•C~j~`,~~V~ Samples req'd: Yes ^ No L`9 Mud log req'd: Yes ^ No d Other: ~ H2S measures: Yes [] No ~ Directional svy req'd: Yes [~ No ^ ~~~~ ~5• cv~'~~:+, My ~~C.1~ -~~;} ; ~'l'1~'~` ~.w•~E.!+~~ c.~v~~t~~~C~. APPROVED BY THE COMMISSION DATE: ~ ,COMMISSIONER Fo~n 10-401 Revised 12/2005 U ~1 ~ ~„~ ~ ~ ~ ~ ~,,,~ ~G'r~~/~~,~ Submit in plica/1 `~, ConocoPhillips Alaska, Inc: Post Office Box 100360 ~~ Anchorage, Alaska 99510-0360 ConoCOPhill~ps Telephone 907-276-1215 May 12, 2006 Alaska Oil and Gas Conservation Commission - ~ ',? 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~ `~;af; ~., Re: Application for Permit to Drill CD4-209 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 05/26/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner injector. At the end of the rig work program, the well will be flowed back for ~ 5 - 15 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 5 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- +/- 150 ft TVD above the Nanuq reservoir. This will place the completion at a maximum inclination less than 65° 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 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1 ). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. • If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, Vern Johnson at 265-6081, or Chip Alvord at 265-6120. Si~ Vern Johnson Drilling Engineer Attachments cc: CD4-209 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Liz Galiunas Jack Walker Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1704 ATO 1740 Kuukpik Corporation • • CD4-209 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate y Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure ~ Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL • Nanua : CD4-209 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 3) Drill 12?/" hole to the surface casing point as per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 5000 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Mineral oil based mud. 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, 17) Run 4-%, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel with DCK shear valve, packer and stinger assembly. Sting in, space out and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 4.7 @ 600' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nanuq reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-209 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-209 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 Nanuq reservoir and there will be 500' of cement fill above the top of the Nanuq as per regulations. Upon completion of CD4-209 form 10-403, Application for Sundry Operations,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg)'` (0.052) " (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) " (2600') + 1,500 psi = 3122 psi Pore Pressure = 1,105 psi Therefore Differential = 3122 - 1105 = 2017 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint- 12'/" Intermediate hole to 7" casing point - 8 3/4" Production Hole Section - 6 1 /8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg - 8.1-8.8 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 -30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) 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 Approx. 64/36 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a 64/36 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ORIGINAL • • CD4-209 Nanuq -Nanuq Injector Completion 16" Insulated Conductor to 114' Sperry Sun Directional Plan WPO7 05/12/06 4-'/2" 12.6 ppf L-80 IBT Mod Tubing 3.813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2414' MD / 2400' TVD Circulate diesel freeze protection and corrosion inhibited brine before setting packer after tubing is spaced out and landed. U~oe r Com leo lion: Too MD TVD Item 1) Tubing Hanger 32' 32' 2) 4-'/~' 12.6 #/ft IBT-Mod Tubing (2) 3) Camco DB nipple (3.813") 2005' 2000' 4) 4-''/2' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG-2 GLM (DRIFT ID 3.833") 6350' 5977' 6) 4-%' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 6450' 6029' 8) 4-'/i' 12.6 #/ft IBT-Mod Tubing (1) 9) HES "XN" (3.725 Min ID")- 63° inc 6515' 6060' 10) 4-'/~' 12.6 #/ft IBT-Mod Tubing 11) BOT Stinger with Fluted WLEG/ stinger 6851' 6177' Stung into tieback extension 10' bottom at 6864' Lower Com len lion: Tou MD TVD Item 12) Baker 5" x 7" Flexlock Liner Hanger and tieback extension 6854' 6177' 13) 4-'/~', 12.6 #/ft, SLHT Tubing +/- 5 jts 14) 4-''/z' 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 13294' 6205' Top of cement ` 6150' MD / 5856' TVD 6783' MD 16159' TVD 4 '/~' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 slots / ft, 2-'/<" x 1/8" slots 7" 26 ppf L-80 BTC Mod Production Casing +/-90° 7004' MD, 6206' TVD TD 6-1/8" hole 13304' MD / 6205' TVD C^!GINAL • CD4-209 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) • The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure psi ASP Drilling psi 16 114 / 114 10.9 52 53 9 5/8 2414 / 2400 14.5 1086 1598 7" 7004 / 6206 16.0 2808 2168 N/A 13304 / 6205 16.0 2808 - N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2808 - (0.1 x 6153') = 2192 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2808 - (0.1 x 6159') = 2192 psi ORIGINAL • Cementing Program: 9 5/8" Surface Casing run to 2414' MD / 2400' TVD. Cement from 2414' MD to 2100' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1914' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (1914'-1600') X 0.3132 ft3/ft X 1.5 (50% excess) = 147.5 ft3 below permafrost 1600' X 0.3132 ft3/ft X 4 (300% excess) = 2004.5 ft3 above permafrost Total volume = 147.5 + 2004.5 = 2152 ft3 => 481 Sx @ 4.48 ft3/sk System: 481 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7004' MD / 6206' TVD Cement from 7004' MD to 6150' MD (300' MD above the packer & minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (7004' -6150') X 0.1503 ft3/ft X 1.4 (40% excess) = 179.7 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 179.7 + 17.2 = 196.9 ft3 => 170 Sx @ 1.16 ft3/sk System: 170 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement o~~~~~L r~ u ~-'' . . ~onocoPh~llips Jt Number ~ Num of Jts Casing Detail 9 5/8"Surface Casin_g COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing F FMC Gen V Hanger Jts 3 to 61 59 Jts 9 5/8" 40# L-80 MBTC Csg Weatherford Float Collar Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg Ray Oil tools (Silver Bullet) TD 12,1/4" Surface Hole 121/4" Hole @2400' MD / 2386' ND 9 518" Shoe @ 2390' MD /2377 ' TVD RUN TOTAL 36 BOWSPRING CENTRALIZERS - 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, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 59 65 joints in the pipe shed. Run 61 joints Last 4 joints stay out Use Best-o-Life 2000 i e do e MU torque - ft/Ibs Remarks: Up Wt - 170k Dn Wt - 135k Block Wt - 75k ~0~ -o ~~ Well: CD4 - 209 Date: 5/10/2006 DEPTH LENGTH TOPS 37.20 2.19 37.20 2267.90 39.39 1.41 2307.29 78.39 2308.70 2.50 2387.09 2389.59 2400.00 L. - Cement Detail Report CD4-209 • ° •' Surface Casing Cement e Job Category AFE / RFE Start Date Spud Date End Date Job T P i yp mary r DRILLING ORIGINAL DRILLING 10136182 5/24/2006 5/25/2006 --- -- - -- - - - - __ i - ~ _ _ _ -- - 'Cement Detafis __ ___ _ __ _ -- cementing Start Date Cementing End Date Wellbore Name Description 5/27/2006 00:00 CD4-209 Surface Casing Cement Comment - __ -_ _ -- -- --- -------- ------ - Cement Stakes - -_ - ---- - Stake#1 _ - Full Return? Cmnt Rtrn (... Top Plug? Blm Plug? - - -- Objective -- Top (ftKB) - -- Bottom (ftKB) i ti Y on p Descr es 0 2,390.0 Yes 89.0 Yes 0 . Surface Casing Cement O start bbl/min O end bbl/min O av bbl/min P (final si P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) ( )( ) ( )( 1 ( s)( ) )(p ) No 6 q 6 570.0 1,100.0 Yes 20.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment -_ -- - - - _- _ I --- - Cement Flwds & Additives l -_- - - -- _ - _ _- - - _J __ Fluid' _ _ _ - - - Amount (sacks - -Class - - Volume Pumped (bbl) Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) ) 240 0 . Lead Cement 0.0 1,890.0 302 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.15 10.70 Additives Concentration Conc Unit label Type Additive -_- i - - __ - --- -- -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbQ G 50.0 1,890.0 2,390.0 232 ~ ement ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Y . e 1.17 5.10 15.80 Additives Concentration Conc Unit label Type Additive - - Fluid _ _ --- -- -- ----- -- Cfass Volume Pumped (bbl) _ - - -- - -- Amount (sacks) Fluid Type 'Fluid Descriptton Estimated Top (ftKB) Est Btm (ftKB) 1,890.0 1,890.0 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Concentration Conc Unit label Additive Type 7/1 Daily Drilling Report __ CD4-209 *~~ Report Date: 5127!2006 Depth Start (ftKB) Depth End (ftKB} Depth Progress (ft) Wellbore Report Number Days From Spud (days) 00 CD4-209 0 4 . 2,400.0 2.17 2,400.0 Target Depth (ftKB) Weft Type Spud Date Contractor Ri Name/No Field Name g Development 19 Alpine 5/25/2006 DOYON Total AFE Amount Average ROP (ft/h~ AFE 1 RFE I Maint# 742,126.00 4 10136182 , Nett Casing Set Depth (ftKB) Last Casing String Next Casing OD (in) 6,994.89 Surface, 2,390.OftKB Daily Cost Total Cummulative Cost 7 Ops and Depth ~ Morning Report 276,395.02 829,058.40 Testing BOPS Daily Mud Cost Cummulative Mud Cost 24hr Forecast PU 4" DP - MU BHA #2 - C/O sh 9,819.02 34,784.40 oe track -FIT -Drill 8 3/4" hole Last 24hr Summary Head Count Wiper trip f! 2400' to 893' -RIH to TD - Circ hole clean -POOH on TT- LD BHA W th General Remarks ea er 34/28 WC/ E @ 7 mph 46.0 _ T tlr - - --- -- -- -- - -- -- - Supervrsor - - - - - - - Rig Supervisor Don A~lickey __ --- - - -_ -- - j _ _ _ - - - - _Time toy ,art ~ End ~ Ph.a-e i Trne Tm ~J' (ham=j j _ - ~ - - -- TirrF ~ ~ o~-pth Sta-t~ G~pth End ~.mm'Op~ration - - -- - - -.. - - -~ O~ Code ~' O S.~t~,C:e iz f-. N-l ; TrLil Cod (Yh B, fns) ~ - -- _ - 1154' w/ pump @ 550 gpm w/ ~G rpm - 400' t .~ -- 00:00 03:45 3.75 SURFAC o 2,400.0 890.0 Wiper trip f/ 2 DRILL WPRT P Continue wiper trip f/ 1154' to 890' w/ pump @ 450 gpm w/ 70 rpm __ _..__ _ ,. ....... Tolo 0 890.0 2,400.0 Flow check well (static) RIH f/ 890' to 2400' -hole in good ~ Latest BO_P Test Data __ '- Date: i_- RUII J wu ~ Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) 39 jts csg to 1650' l.rVllunuc iulun.~y ., .,... 18 jts (61 jts total ran) - PU FMC csg hanger & landing jt. - Lan< csg w/ fluted mandle hanger on landing ring w/ float shoe @ 2390' & float collar @ 2307' - LD Frank's fill up tool -Blow down TD - MU cmt head & lines C,lGUIIDII VIl a.uruarair• - vwy~ r--~-r- _~ _. _. & condition hole & mud for cmt job - tCP 430 psi FCP 320 psi (circulated 440 bbls) Comment Page 1!2 Report Printed: 5/30!201 • • Daily Drilling Report CD4-209 . - ,. Report Date: 5/27/2006 me Log p ~ --- --- - --- - - -- --- - "- "- Deplh Stari ~ Dzplh Ertd i o Tin = I Tl,f~ Fnd ~..-. I ;, Coi -. ~'O}wrat- ~ - -- -- r ~ Time ~D~. (hr~)j Phas Op C~~ _O -u-Code P N T; Trb! Code (ftlCB} '- {8h8i --- _„ _-_ __ 18:45 20:30 1.75 SURFAC CEMENT DISP P 2,350.0 2,390.0 Cement 9 5/8" csg as fotlows .Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell - Tested lines to 3000 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 240 bbls lead slurry (ASL) @ 10.7 ppg (' Observed nut plug marker @ shakers w! 220 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 155 bbls 9.6 ppg water base mud -Displaced @ 6.5 bblslmin for first 135 bbls -slowed pump to 3.5 bbls/min for last 20 bbls -Bumped plug w/ 1150 psi (prep bump pressure 570 psi) Check float (held OK) CIP @ 20:36 hrs. -Full circulation throughout job wl 89'bbls fi0.7 ppg'cmt returns to surface -reciprocated pipe while circulating & through cement iob until last 30 bbls of displacement 1:30 1.00 SURFAC CEMENT OTHR P 2,390.0 2,390.0 Rig up 8~ test 9 5/8" casing to 2500 psi down lines - RD 21:30 22:30 1.00 SURFAC l;tnntrv i raw ~ -~----- 0 390 2 390.0 2 ND surface riser _ _ - _ _ - _ - __ 22:30 00:00 1.50 SURFAC DRILL - RURD - - P --- . , , - - - _ _ Mud Check Data - - -- ~ - i - ~ Vi Pres 1 -~YP Calc II C' Z7 Gsj G~~ (lGm~~, Gel {"~'Ti)- " ~ - H~ iiF~ ~d - ~ lrr Ll'.Or i i 1 _ j ~ GH Tr »~ ~~ i~=, I ~ . ~ or N i ('F1 ~ ~~~ ~ ~ 1 {p.,l ~ PV Cal rF-~ lhlga9l Ders ~ ftK8 De h llbf ~~YJ`t=) I ~ (i~ 190C+FPi i (1bH1 C,tFt) llb 1~Jfi 1 ~d RT {Iblbbl~ - _ J ~ 8 $ - - f5.5 . T~'p"'- Water ) { pz 2,400.0 , ~ 9.65 _ -._ Z2.0 .. 19.000 12.000 26.000 30.000 27.5 . Based Mud I I I ~ _- ~--__- ~- - - -- -- - -- - - -- - - II, ion Fluld _ _ - __ -.-- --- - F ~,~d -- -- L - -- s ~'<< - --- -- - - From Le. s_ tbUl) _ - - - - - - --- 15 OTCD4-319 _ _ - -- ---- _ _ -- - - - - freeze protect _- Diesel 563 0 CD4-319 ~ f/ CD4-209 _ _ -- - - ---- Water Based Mud - I - - - - -- . - - - -- -- - - - - - - - - - - Wellbores - - - - - --- - --- - ---- Wellbore APIIUWI - - Wellbore Name 50103205 32 CD4-209 - ~- AdTop _ ftKB~1 --_- - --- --- - ~Sar{~at= f+~i Dtm (ftk'PJ - ~.-- - --- - ~~ - -- ---- Ea~d Date - - --- -- - - --- osLon ~ S~rtut) - . --- - - .. PROD7 - - - _- 61/8 INTRM2 7 36 114.0 1 /24/2006 1/26/2006 COND1 36 . 114 0 400.0 5/25/2006 2 5/26/2006 SURFAC 12 114 8 314 . 2.400.0 , 5/29/2006 -- - - - - -- - - INTRMI -- -- - - - -- - -- - ----- _ _ _ _ _ - -- Gement -- _ __ _ Surface Casin Ce ment -Started 5/2712006 Cement Evaluation Results Tye Wellbore String Casing CD4-209 Surface, 2,390.OftK6 .Top (ttK6) Bottom (fiiC6) Q (end) (bbl/... P (final) (Psi) Stg No. Description 2,390.0 0 0 4 _ 570.0 1 Surface Casing Cement -- -T - ~ . ~~ v~e,d in sa~.~i- ~ ~ v ~:cni; -~ ~erts~ry.{It~y3.~ Top tlrKal - T - - =Esr °-m I~~>z>3~ - - _ - - --_ C~...5 Fluid 1- -`_ - - - -. -- ATil01?1ll (SdC1:5j { I - 302 _ _ 240.0 _ 10.70 -- 4.45 - 0.0 1,890.( Lead Cement I T 2321 50.OI 15.801 1.171 1,890.0 2,390.( Tail Cement G 1,890.0 1,890.( Page 212 Report Printed: 5/30/200 PRESSURE IN~i 1=GRITY TEST CONOCOPHILLIPS Alaska, Inc. 'elt Name: CD4-209 Rig: Doyon 19 Date: 5/29/2006 Volume Input VolumelStro ke Pum Rate: tilling Supervisor: D. Mickey Pump used: #2 Mud Pump ~ strokes ~- 0.1000 13b1s/strk • $•0 Strk/min Type of Test: Casing Shoe Test LOT/FIT ~ Pumping down Use LIST ~ Casin Test Pressure In te tit Test ole Size: 1z-1/4" ~ Casin Shoe De th Hole Depth Pum in i Shut Mi -in si Pum Strks in si Shut- Min in si RKB-CHF: 37.2 Ft 2,390 Ft-MD 2,377 Ft-TVD 2,420 Ft-MD 2,406 Ft-TVD Strks s n Carina Size and Descriotion: 10-3/4" 45.5#/Ft L-80 BTC ~ 0 _ 0 0 2540 0 e 40 inn 0 n']~ 780 F7n Casin Test Pressure Into Mud Weight: 9.6 ppg Mud Weight: Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: Test Pressure: 2,500 psi Rotating Weight: Rotating Weight: 0 Lbs Blocks/Top Drive Weight: Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: Estimates for Test: 2.5 bbls Estimates for Test: IW =Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 2390 Ft-MD (23' 9.6 ppg 18.0 Lb/100 Ft2 150 Lbs 000 Lbs 18.0 ppg 038 asi 1 bbls 630 + 9 6 PIT 15 Second 0.052 x 2377 Shut-in Pressure, si Ft-TVD) = 14.7 s2o 7 9 8 1000 4 2540 ~ 4~ 470~~ 1.5~ 570 14 16 18 1600 1840 2100 7 8 9 1b4U 2540 2540 20 2340 10 2540 21 2540 15 2540 20 2540 555 11 780 5 550 12 5.5 550 13 6 545 ~ 2 s o s io 15 zo is so Volume Volume Volume Voli Barrels Shut-In time, Minutes ~^CASING TEST ~-LEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed Bled s s s este Casin after bum in plu son cement 'ob. • • Conocophilli S Casing Detail Weu: CD4209 Date: 6/2/2006 7" Casin_q C] Cement Detail Report CD4-209 • -' Production Casing Cement Job Category AFE I RFE Start Date Spud Date End Date Primary Job Type DRILLING 10136182 5/24/2006 5/25/2006 DRILLING ORIGINAL -- Cement Deta(Is - -- - - ementing Start Date Cementing End Date _-- - - - --_ Wellbore Name Description 6/2/2006 04:30 6/2/2006 05:50 CD4-209 Production Casing Cement Comment - rCement Sta es _ - - - - - ---- - -- -- -- J - - _ Sta e # <Sta e-Nun3ber?> e j i _ - - _ _ _ - Full Retum? Top (ftKB) Bottom (ftKB) - -- - - - Cmnt Rtrn (... Top Pfug? Btm Plug? v ect Description Ob 150.0 6,995.0 Yes 6 Yes YeS Production Casing , Cement O (start) (bbllmin) Q (end) (bbltmin) ~ Rotated? Pipe RPM (rpm) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip. Stroke (ft) 00 No 4 7 526.0 1,029.0 Yes 25. 7 Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Depth tagged (ftKB) Comment -- - - --- -- - -- -- - - - - __ - - --- - - -- - Cement Fluids & Additives - - - -- _ _ __ 'Fluid _ _ -- -- Flwd Type Fluid Description _ - - - - - -Volume Pumped (bbl) -- - - Amount (sacks Glass Estimated Top (ftKB) Est Btm (ftK6) ) G 37.0 Production Cement 6,150.0 6,995.0 175 e Water (%) DensdY (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) F ll veld (ft'/sack) Mix H2O Ratio (ga re sa... 1.16 5.08 15.80 Additives Concentration Conc Unit label Additive TYPe 05 %BWOC 0 Retarder 6155 . Concentration Conc Unit label Ad~+~tive TYPe 2 %BWOC 0 / 3m DO 46 . Concentration Conc Unit label A~_.~ve TYPe 4 %BWOC p Fluid Loss Control D167 , Concentration Conc Unit label Additive Type 3 %BWOC 0 Dispersant D065 . Nage ' Daily Drilling Report , CD4-209 #}~ Report Date: 6/2/2006 Report Number Days From Spud (days) Depth Start (ttK6) Depth End (ftK6) Depth Progress (ft) Wellbore 00 CD4-209 0 10 . 8.17 7,005.0 7,005.0 Tar et Depth (ftK8) Well Type g Spud Date Contractor Rig Name/No 19 Field Name NANUO Development 5/25/2006 DOYON Total AFE Amount Average ROP (ft/hr) AFE I RFE I Maint.# 10136182 4,742,126.00 Next Casing OD (in) Next Casing Set Depth (ftKB) Last Casing String Intermediate, 6,994.9ftKB Daily Cost Total Cummulative Cost Ops and Depth @ Morning Report 493,817.58 2,237,922.21 Making MADD pass. Daily Mud Cost Cummulative Mud Cost 24hr Forecast Drill shoe track. MADD pass TOC . Drill 20'. CBU. FIT. Chang 4,100.58 125,350.21 e to MOBM. Drill ahead. Last 24hr Summary Running 7" csg .Land w/ shoe @ 6995' -Circ & Cmt 7" Cont athe off - PU DP ~ BHA to 4,694'. Head Count -Test csg to 3500 psi -Set & tesWe . General Remarks a 51.0 28 Deg Wind SW @ 18 MPH _- - - __ - - _i ' ~U~JeNisof - - itle ti __ ~ _- - - - - - -_ . Don Mickey -- - - - - - - - - - IFig Supervisor Larry Hill - -- - - - - - - -- -- -- Rig Sup~n~isor - - - - -- - - - - - - - - - -. -_ _- I Time Log- I ~t rt ~ Erd - - _ ~ ~_ -~ I T,ma- ;ub-God ~ F N-T ~~ ~ O d _ - _ - ~D pt~i Start ~DPplrCnd ~ - v~~ o,,~,ac,~r, 1 irk P~ l -;,~ Cu~iP ~"~~~ - ' Dur (1i- }. Phase i Time j Tim p e Op Cc P _ t0 5 - 0 JtS.( 121 1 _ MBTC CSg f/ 4694 121.0 Cont. tannin 7" 26# L-80 g 0 5 654 4 00:00 00:15 0.25 INTRMI CASING RNCS , . , 120 jts. total) P 121.0 Break circ-stage pumps up to 6 bbls/min ICP 510 psi FCP 430 0 5 121 5 00:15 00:45 0.50 INTRMI CASING CIRC , . , psi P 995.0 Cont. running 7" 26# L-80 MBTC csg f/ 5121' to 6956.83' - 43 0 6 121 5 00:45 02:30 1.75 INTRMI CASING RNCS , . , jts (163 jts. total) PU FMC fluted hanger & landing jt. -Land csg w/ shoe @ 6995' & FC @ 6904' 02:30 03:15 0.75 INTRMI CEMENT PULD P 6,995.0 6,995.0 RD csg equipment - RU cmt. head & lines umps up f/ 2 bbl/min to 6.5 bbls/min -Circ & e c -sta i k B 03:15 04:15 1.00 INTRMI CEMENT CIRC P p g c r rea 6,995.0 6,995.0 condition for cmt job -ICP 600 psi FCP 520 psi 04:15 04:30 0.25 INTRMI CEMENT SFTY P 6,995.0 6,995.0 Held PJSM w/ crew 0 Cement 7" 26# L-80 MBTC as follows: Pumped 5 bbls water - 995 6 04:30 06:00 1.50 INTRM1 CEMENT DISP P . , 6,995.0 Test lines to 2500 psi -Pumped 30 bbls CW-100 -Dropped btm plug -Mixed 8~ pumped 37 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 243 bbls 9.6 ppg LSND mud @ 6.9 bbl/min -slowed pumps to 4 bbls/min @ bumped plug w/ 1000 psi - CIP @ 0550 hrs. -Checked floats OK -Full circulation throughout job 06:00 06:30 0.50 INTRMI CEMENT OTHR P 6,995.0 6,995.0 Test 7 "csg to 3500 psi for 30 mins. head - LD landing jt. -Pull thin wall wear bushing -set 0 RD cmt 995 0 6 06:30 08:30 2.00 INTRMI CEMENT PULD P . . , 6,995. & test pack off to 5000 psi 08:30 10:30 2.00 INTRM1 WELCTL EORP, P 6,995.0 6,995.0 PJSm -Change top pipe rams f/ 7" to 3 112" X 6" VBR -Test to 250 8~ 5000 psi -pull test plug -set wear bushing 0 PU ~ RIH w/ 57 jts. 4" drill pipe f/ pipe shed 700 0 1 0 10:30 13:00 2.50 INTRMI DRILL PULD P . , . 0 0.0 POOH 8~ std back pipe in derrick -19 stds 700 1 13:00 14:00 1.00 INTRMI DRILL TRIP P . , 0 PU BHA components to rig floor 0 0 0 14:00 14:30 0.50 INTRMI DRILL PULD P . . 0 PU 6 1/8" BHA- 0 300 0 14:30 17:00 2.50 INTRMI DRILL PULD P . . 0 PU and RIH HWDP. Shallow tested MWD. 0 399 300 17:00 18:00 1.00 INTRMI DRILL PULD P . . 0 RIH picking up DP from pipe shed to 5,921'. __ 921 0 5 399 18:00 00:00 6.00 INTRMI DRILL PULD P . , . --- ilAud Check Data -- - _ - :- -- t~P F,n ~ ~^ giro. o ds, c rr YP Calc Gel {70_i ( ) ( ) ~ ~~ ~ Te~ m S li o ~ ~~ to~~ (°F~ ~`°~ ~ °~°° ' 3 ~~ ~ ~ Dens ii D~ - ~Omirf nH ~=) r t mIJ bfl- 1i5r 000 rnaT;ier~i ( ~ - - ~ --- 1 {ihr; 0 9.2 9•' - - - 20 ~ FV Car 1t2a0 1~~ 18 01 v.5 i~~ 9 - 7,005.0 Water - 37 9 8 1 000 . . 17 000 18.000 Based Mud Latest BOP Test Data Page 1/2 Report Printed: s/4-zuu r-1 Daily Drilling Report CD4-209 ~1n~ecGon F3uid _ ___ - ---- 7 - Fr,m t-~ ~ ~ei Flwd _~ Source --- ---- -- ~ -_ 58.0 Diesel 1400.0 CD2-19 Recycled mud Recycled mud 9'0 300.0 Depth fn 7,0 Drill Stl ~t5 ~s: BHA No. 4 - Steerable / Bit Run lJv. _3 - 6 118in, Nalliburt ;B) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (!32") 0 ~ 7 005 - 0.45 ~ 14/14/14 Report Date: 6/212006 o~;:~~an~~~ _ - J r~„tc - CD4-209 to CD4-209 I From CD4-209 CD4-209 to CD4-209 CD4-209 to CD4-209 ---- ~ 10835487 Stony wt jtooolb~ woe (max) (100... wos ~minj (io0o... 10 ! 0 I 0 to ~ g Components - - - - - _ - - tem Descnpfion - ' - - ( - {1n 1 ' , if - - - - 4 3/4 500 1 0 1 Geo Pilot 3/4 4 1.50 1 Drill Collar -Flex Non Mag 1 Stabilizer (Non Mag) 4.76 1.500 4 3/4 1.500 1 MWD DM HOC 73 4 1.500 1 MWD GR/RES . 4 7 1.500 1 MWD (Dir & Logging) . 62 4 1.500 1 MWD TM HOC . 4.66 2.313 1 Float Sub 4 3/4 2.250 1 Stabilizer (Non Mag) 7 4 1.250 1 MWD Batt Sonic . 4.68 2.250 1 NMDC 4.56 2.250 1 NMDC 4.52 2.250 1 NMDC 4.8 2.563 1 XO Sub 4 2.563 3 HWDP 4 3/4 2.000 1 Drilling Jars - DNT 4 2.563 2 HWDP -. inn S~ {in) ~ o= 3 1/2 NC 38 3 1 /2 NC 38 3 1 /2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 3 1/2 NC 38 4 XT 39 4 XT 39 4 XT 39 4 XT 39 - c,um ixn{ft; - . 17.28 28.82 32.41 65.15 76.01 87.14 89.48 95.01 123.88 148.97 179.97 210.85 213.50 305.53 337.53 398.90 j Dnllin~Rarameters - -_ ~ - -- - _ Dril4i ig Timc ~ lidiro Hr Imi N`17 i Cvm Depth l h - - ~ G ~m Diill ~. t) ~ ~.nE It-rsj lit CI si h -- - - I i ~~ 4 c` ~~ ~pRi rry_ ~ !9Pm) ~ U'G5 tl .) ~ P.PM -pm) ~, - - -- - ~ Drill Ta SPP tPsl) ~ _ _ -- -. _ End (itKB) .art iftK2) __ 5 ' r) ~ ~ 0 00~ -~ I ~ L 0.00 0 0 0 O ~ -~ L ~ . . 0 0 O O --- - -- , 7,00 _ 7.005.0 - - 01 - _ - . - - - Wellbores - - - - ---- - --- -- - I Wellbore APl/UWI - _ - - - Wellbore Name 5010320532 --- - CD4 209 -- --- ,4ct Ta ' ft~) -. -' Siza Iin) ~ P{ 1 Act Etm (tU:E3 ~ _ - - -- ~ta¢Da e - - - - - _ --- - End D3tc -. ..Section--1 - - - INTRM2 7 36 114.0 1 /24/2006 1/26/2006 COND 1 36 12 1/4 . 114.0 2,400.0 5/25/2006 5/26/2006 SURFAC 8 3/4 2,400.0 7,005.0 5/29/2006 5/31/2006 INTRMI 6 1 /8 7,005.0 6/3/2006 PROD? - - -- 'Surve~ata ~ ~~ MD (ftKE) -~_ ~' (`i ~ VG fth E3 S jY,l _ - -~ Es;flj ;-- ~ T S 03 ~ 2 1 006 5 2 _ _ - Uts(~~Et~ ElJ ( ) _ J__- ~ 28 L 7.005_0 _ _ 80 80 ~ -153-25 6 203.961 ' , I - , _ _ ~Cement J - - -__ - - - - -- - - - - - - Production Casio Cement -Started 6/2/2006 Cement Evaluation Results Type Wellbore String casing CD4-209 Intermediate, 6,994.9ftKB Top (ftK6) Bottom (ftK6) Q (end) (bbl/... Stg No. Description Production Casing Cement 6 150.0 6,995.0 __ _ 4 _ Fluid C1a..~ -~Amo°dn1 {sa'4:~) V (bb9r - ~ry Ob(gal) Yeld (Y_'Isa~4:) ~- Fst Top (fl KB) _ - - _- Production Cement - ~G -~ - ~ - 175 - -~ 37.0 15.80 1.16 ~ 6,150.0 0-0-NO-A-X-I-NO-DTF 526.0 6,995.( Page 212 Report Printed: 6/4/200 PRESSURE IN i EGRITY ~ t5 I CONOCOPHILLIPS Alaska, Inc. CD4-209 Rig: Doyon 19 Date: 6/2/2006 Volume Input Pum Rate: ell Name: rilling Supervisor: Micke /Hill y Pump used: Cement Unit ~ Barrels '~ Bbls/Strk ~ 0.80 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure Int e rit Test ole Size: 8-3/4" ~ Casin Shoe De th Hole Depth 0 Ft-TVD 0 Ft-MD 5851 6150 Pum Bbls in psi Shut Min -in si Pum Bbls in si Shu Min t-in si RKB-CHF: 37.2 Ft 2390.0 Ft-MD 2377.0 Ft-TVD . . 0 0 00 723 Casina Size and Description: 9-5/8" 4o#/Ft L-8o BTC ~ 0 1 0.5 14 . 0.25 712 Chan es for Annular Ade uac Test Pressure Inte rit Tes t 2 1 19 0.50 655 Enter outer casing shoe test results in comments Mud Wei ht: g 9.8 ppg 3 1.5 23 1.00 602 Casing description references outer casing string. Inner casing OD: 7.0 In. 4 2 67 1.50 591 Hole Size is that drilled below outer casing. 5 2.5 206 2.00 576 Use estimated TOC for Hole Depth. 6 3 353 2.50 568 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 4 bbls i 0 7 3.5 527 3.00 561 Estimates for Test: . 643 s ~ $ 4 659 3.50 557 _ 4 5 822 00 4 552 951 PIT 15 Second 9 . . :MW =Leak-off Pressure + Mud Weight = + g,g si Shut-in Pressure 10 5 924 4.50 544 0.052 x TVD 0.052 x 2377 , 712 15 5.5 951 5.00 544 EMW at 2390 Ft-MD (2377 Ft-TVD) = 17.5 20 6 873 5.50 537 ~ooo ~ ~~ 6.5 803 6.00 534 1 w N 500 W a c ,com 7 8 9 0 5 10 15 20 25 30 0 1 2 3 Barrels s 6 Shut-In time, Minutes ~~CASING TEST --LEAK-OFF TEST O PIT Point Bled Summary 1.J ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-209 Plan: CD4-209 Plan: CD4-209wp07 Proposal Report 09 May, 2006 Sperry Drilling Services ORIGINAL C.OIl0001'I'11111p5 ScanMathod: Trav.CylinderNOrth Err« Surface: Elliptifal Conic Colville River Unit Alaska Warning Me[had: Rules Based Oeodagc Datum: NAD 1877 (NADCON CONUS) Alpine CD4 Magnetic Modal: BGGM2g05 Plan: CD4-209 HALLIiBURTON Ground Level: 19.70 Plan: CD4-209 SMrry DANMy NMcw RKB: Planned Doyon 19 @ 56.OOft (DOyon 19 (36.3 + 19.7)) NorthinglASP Y: 5957488.62 C D4-209wp07 Fasting/ASP X: 378018.64 9-5/8" Csg Pt; 2414' MD, 2400' ND / - 7" Csg Pt; 7004' MD, 6206' ND; 5041' FNL 8 283' FEL; Sec24-711 N-R04E -2500 - -5000 CD4-209wp07 SHL; 2923' FNL 8 226' FEL; Sec24-711 N-R04E Kick-off Point; 1°DLS, 210° TFO, 1000' MD, 1000' ND Begin Dir; 3° DLS, -118° TFO, 2900' MD, 2865' ND Start Sail; 17.5° INC, 3024' MD, 2983' ND Begin Dir; 4° DLS, -48° TFO, 5257' MD, 5112' ND Target (Heel); 7004' MD, 6206' ND Target (T2); 7547' MD, 6253' ND Target (T3); 8643' MD, 6196' ND Target (T4); 9639' MD, 6254' ND Target (T6); 11732' MD, 6246' ND -7500 -5000 -2500 0 ~niA~+r_v ~ ~ C 0 - O Base Permafrost O N - ~ 2500 r_en -- _ Q C-30 ~ C-20 I (B U_ K-3 ~ I K-2 Base > 5000 - a~ L _ Albian 97 Top Nanuq (Albian 96) -2500 4 1/2" Liner Target (T5); 11037' MD, 6196' ND Target (Toe); 13304' MD, 6205' ND, 138' FNL & 2527' FEL; Sec31-711 N-ROSE 2500 5000 7500 +l (2500 ft/inl - - ~ SHL; 2923' FNL & 226' FEL; Sec24-711 N-R04E Kick-off Point; 1°DLS, 210° TFO, 1000' MD, 1000' ND Kick-off Point; 1 °DLS, 210° TFO, 1000' MD, 1000' ND 9-5/8" Csg Pt; 2414' MD, 2400' ND Begin Dir; 3° DLS, -118° TFO, 2900' MD, 2865' ND Start Sail; 17.5° INC, 3024' MD, 2983' ND Begin Dir; 4° DLS, -48° TFO, 5257 MD, 5112' ND 7" Csg Pt; 7004' MD, 6206' ND; 5041' FNL & 283' FEL; Sec24-711 N-R04E Target (Toe); 13304' MD, 6205' ND, 138' FNL & 2527' FEL; Sec31-711 N-ROSE 20 n 3~ 4 1/2" Liner O t° t° c° (op _- h_~- -... ? W -- __ N G Target (Heel); 7004' MD, 6206' ND ° m o Target (T3); 8643' MD, 6196' T` Target (TS); 11037 MD, 6196' TVD ~ Target (T2); 7547 MD, 6253' TVD Target (T4); 9639' MD, 6254' ND Target (T6); 11732' MD, 6246' ND --r -- ---- 0 2500 5000 7500 10000 12500 nRiri~iol ConocoPhi~lips Alaska Database: EDM 2003:11 Single User Db Company: ConocoPhillips Alaska lnc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-209 Wellbore: Plan: CD4-209 Design: CD4-209wp07 Sperry Drilling Services Planning Report -Geographic NAL.L.IBURTON Sp~nry D~illin~ Sirvlcaas Local Co-ordinate Reference: Well Plan: CD4-209 TVD Reference: Planned Doyon 19 @ 56:OOft{Doyon 19{36 3 + 19.7)) MD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19.(36.3 + 19.7)) North Reference: True Survey Calculation Method: Minimum Curvature Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ---- - - -- Well Plans CD4-209 _ _ _ Wetl Position +N/-S 0.00 ft Northing: 5,957,488.62 ft Latitude: 70° 17' 32.572" N +E/-W 0.00 ft Easting: 378,018.64 ft Longitude: 150° 59' 15.293" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.70ft ~~_ Wellbore Plan: CD4-209 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 5/25/2006 23.32 80.63 57,500 ~I Design CD4-209wp07 Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (ft) I 36.30 PLAN Tie On Depth: +N/-S +E/-W Direction 0.00 0.00 161.00 36.30 5/9/2006 4:54:17PM Page 2 of 8 COMPASS 2003.11 Build 50 ORIGIN.^,L ConocoPhillps Alaska Database: EDM 2003:11 Single User Db Company: ConocoPhillips Alaska Inca Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-209 Wellbore: Plan: CD4-209 Design: CD4-209wp07 Sperry Drilling Services Planning Report -Geographic r-rac.~~jsu~~r+c~N Sp~-rry Drilling Services Local Co-ordinate Reference: Well Plan: CD4-209 TVD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19 {36.3 + 19.7)) MD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19 {36.3 + 1'9.7)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) {o) (e) ~{~) (~) {h) (°/100ft) (°I100ft) (°1100ft) (o) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 1,000.00 0.00 0.00 1,000.00 0.00 0.00 0.00 0.00 0.00 0.00 2,900.00 19.00 210.00 2,865.37 -270.33 -156.08 1.00 1.00 0.00 210.00 3,024.69 17.53 199.00 2,983.81 -305.69 -172.35 3.00 -1.18 -8.83 -118.18 5,257.27 17.53 199.00 5,112.65 -941.69 -391.29 0.00 0.00 0.00 0.00 7,004.07 82.00 154.12 6,206.00 -2,118.20 -56.88 4.00 3.69 -2.57 -48.09 7,020.26 82.32 154.15 6,208.21 -2,132.63 -49.89 2.00 1.98 0.22 6.22 7,163.21 82.32 154.15 6,227.31 -2,260.13 11.88 0.00 0.00 0.00 0.00 7,547.14 90.00 154.05 6,253.00 -2,604.47 179.06 2.00 2.00 -0.03 -0.73 7,725.02 93.56 154.05 6,247.48 -2,764.32 256.83 2.00 2.00 0.00 -0.04 8,465.70 93.56 154.05 6,201.52 -3,429.05 580.29 0.00 0.00 0.00 0.00 8,643.58 90.00 154.08 6,196.00 -3,588.91 658.03 2.00 -2.00 0.01 179.60 8,855.67 85.76 154.08 6,203.85 -3,779.50 750.67 2.00 -2.00 0.00 -179.99 9,427.60 85.76 154.08 6,246.15 -4,292.47 1,000.01 0.00 0.00 0.00 0.00 9,639.70 90.00 154.08 6,254.00 -4,483.05 1,092.63 2.00 2.00 0.00 0.11 9,770.88 92.62 154.09 6,251.00 -4,601.01 1,149.94 2.00 2.00 0.00 0.06 10,906.70 92.62 154.09 6,199.00 -5,621.57 1,645.77 0.00 0.00 0.00 0.00 11,037.92 90.00 154.03 6,196.00 -5,739.52 1,703.15 2.00 -2.00 -0.04 -178.76 11,340.50 82.68 154.02 6,215.31 -6,010.79 1,835.33 2.42 -2.42 -0.01 -179.88 11,429.79 82.68 154.02 6,226.69 -6,090.40 1,874.13 0.00 0.00 0.00 0.00 11,732.39 90.00 154.07 6,246.00 -6,361.73 2,006.21 2.42 2.42 0.02 0.44 11,808.99 91.53 154.07 6,244.98 -6,430.61 2,039.70 2.00 2.00 0.00 0.00 13,304.26 91.53 154.07 6,205.00 -7,774.89 2,693.29 0.00 0.00 0.00 0.00 5/9/2006 4:54:17PM Page 3 of 8 COMPASS 2003.11 Build 50 1~~,4~AL Y • Sperry Drilling Services • CCN'3000~I11~IIp5 Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc. TVD Reference: Project: Golville River Unit MD Reference: Site: Alpine CD4 North Reference: Well: Plan: CD4-209 Survey Calculation Method: Wellbore: Plan: CD4-209 Design: CD4-209wp07 NALi.18URT©N $psrry Dri11Mg $srviCes WeII Plan: CD4-209- Planned Doyon 19 @ 56.OOft (Doyon 19 (36.3 + 19.7)) Plannedboyon 19 @ 56.OOft (Doyon 19 (36.3 + 49,7)) True Minimum Curvature Planned Survey CD4-209wp07 MD Inclination Azimuth TVD SSTV~ (ft) (°) (°) (ft) (ft) 36.30 0.00 0.00 36.30 -19.70 SHL; 2923' FNL & 226' FEL; Sec24-T11N-R04E - 100.00 0.00 0.00 100.00 44.00 200.00 0.00 0.00 200.00 144.00 781.00 0.00 0.00 781.00 725.00 Base Permafrost 1,000.00 0.00 0.00 1,000.00 944.00 Kick-off Point; 1 °DLS, 210° TFO, 1000' MD, 1000' TVD r 1,100.00 1.00 210.00 1,099.99 1, 043.99 1,200.00 2.00 210.00 1,199.96 1,143.96 1,300.00 3.00 210.00 1,299.86 1,243.86 1,400.00 4.00 210.00 1,399.68 1,343.68 1,500.00 5.00 210.00 1,499.37 1,443.37 1,600.00 6.00 210.00 1,598.90 1,542.90 1,700.00 7.00 210.00 1,698.26 1,642.26 1,800.00 8.00 210.00 1,797.40 1,741.40 1,900.00 9.00 210.00 1,896.30 1,840.30 2,000.00 10.00 210.00 1,994.93 1,938.93 2,100.00 11.00 210.00 2,093.26 2,037.26 2,200.00 12.00 210.00 2,191.25 2,135.25 2,209.97 12.10 210.00 2,201.00 2,145.00 C-40 2,300.00 13.00 210.00 2,288.87 2,232.87 2,400.00 14.00 210.00 2,386.11 2,330.11 2,414.32 14.14 210.00 2,400.00 2,344.00 9-5/8" Csg Pt; 2414' MD, 2400' TV D - 9 5/8" 2,420.51 14.21 210.00 2,406.00 2,350.00 C-30 2,500.00 15.00 210.00 2,482.92 2,426.92 2,600.00 16.00 210.00 2,579.29 2,523.29 2,700.00 17.00 210.00 2,675.17 2,619.17 2,795.23 17.95 210.00 2,766.00 2,710.00 C-20 2,800.00 18.00 210.00 2,770.54 2,714.54 2,900.00 19.00 210.00 2,865.37 2,809.37 Begin Dir; 3° DLS, -11 8° TFO, 290 0' MD, 2865' TVD 3,000.00 17.77 201.31 2,960.28 2,904.28 3,024.69 17.53 199.00 2,983.81 2,927.81 Start Sail; 17.5° INC, 3024' MD, 2983' TVD 3,100.00 17.53 199.00 3,055.62 2,999.62 3,200.00 17.53 199.00 3,150.97 3,094.97 3,300.00 17.53 199.00 3,246.32 3,190.32 3,400.00 17.53 199.00 3,341.68 3,285.68 3,500.00 17.53 199.00 3,437.03 3,381.03 3,600.00 17.53 199.00 3,532.38 3,476.38 3,700.00 17.53 199.00 3,627.74 3,571.74 Map Map +N/-S +E/-W Northing Easting (ft) (ft) (ft) (ft) 0.00 0.00 5,957,488.62 378,018.64 ' DLSEV Vert Section (°/100ft) (ft) 0.00 0.00 0.00 0.00 5,957,488.62 378,018.64 0.00 0.00 0.00 0.00 5,957,488.62 378,018.64 0.00 0.00 0.00 0.00 5,957,488.62 378,018.64 0.00 0.00 0.00 0.00 5,957,488.62 378,018.64 0.00 0.00 -0.76 -0.44 5,957,487.87 378,018.19 1.00 0.57 -3.02 -1.75 5,957,485.63 378,016.85 1.00 2.29 -6.80 -3.93 5,957,481.88 378,014.60 1.00 5.15 -12.09 -6.98 5,957,476.65 378,011.47 1.00 9.16 -18.88 -10.90 5,957,469.92 378,007.43 1.00 14.30 -27.18 -15.69 5,957,461.70 378,002.51 1.00 20.59 -36.99 -21.35 5,957,451.99 377,996.69 1.00 28.02 -48.29 -27.88 5,957,440.79 377,989.98 1.00 36.58 -61.09 -35.27 5,957,428.12 377,982.39 1.00 46.28 -75.38 -43.52 5,957,413.96 377,973.90 1.00 57.11 -91.17 -52.63 5,957,398.33 377,964.54 1.00 69.06 -108.43 -62.60 5,957,381.23 377,954.29 1.00 82.14 -110.23 -63.64 5,957,379.44 377,953.22 1.00 83.51 -127.17 -73.42 5,957,362.66 377,943.17 1.00 96.34 -147.39 -85.10 5,957,342.64 377,931.17 1.00 111.66 -150.41 -86.84 5,957,339.65 377,929.38 1.00 113.94 -151.72 -87.59 5,957,338.36 377,928.60 1.00 114.93 -169.07 -97.62 5,957,321.17 377,918.30 1.00 128.08 -192.22 -110.98 5,957,298.24 377,904.57 1.00 145.62 -216.81 -125.18 5,957,273.88 377,889.97 1.00 164.25 -241.58 -139.48 5,957,249.35 377,875.27 1.00 183.01 -242.86 -140.21 5,957,248.09 377,874.52 1.00 183.98 -270.33 -156.08 5,957,220.88 377,858.21 1.00 204.79 -298.66 -169.77 5,957,192.78 377,844.06 3.00 227.12 -305.69 -172.35 5,957,185.80 377,841.37 3.00 232.92 -327. 14 -179 .73 5,957,164 .47 377,833 .64 0.00 250. 80 -355. 63 -189 .54 5,957,136 .14 377,823 .37 0.00 274. 54 -384. 12 -199 .35 5,957,107 .82 377,813 .10 0.00 298. 29 -412. 60 -209 .15 5,957,079 .50 377,802 .84 0.00 322. 03 -441. 09 -218 .96 5,957,051 .18 377,792 .57 0.00 345. 77 -469. 58 -228 .77 5,957,022 .85 377,782 .30 0.00 369. 52 -498. 07 -238 .57 5,956,994 .53 377,772 .04 0.00 393. 26 5/9/2006 4:54:17PM Page 4 of 8 COMPASS 2003.118ui1d 50 ORIGINAL ' • • ~• ' ' Sperry Drilling Services HIALf.~lB1.~1~3.1.~IV ~tJl 10CD ~ 1~~~IpS Planning Report -Geographic ---~ ~ --~ ~~~~~~~~ ~ --~~~ Alaska $petrry prflNttg Ssnrices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: GD4-209 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 56:OOft (Doyon 19 (36.3 + 19:7)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19:(36.3 + 19.7)) Site: Alpine CD4 North Reference: True Well: Plan: CD4-209 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-209 Design: CD4-209wp07 Planned Survey CD4-209wp07 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 3,800.00 17.53 199.00 3,723.09 3,667.09 -526.55 -248.38 5,956,966.21 377,761.77 0.00 417.00 3,899.53 17.53 199.00 3,818.00 3,762.00 -554.91 -258.14 5,956,938.02 377,751.55 0.00 440.63 K-3 3,900.00 17.53 199.00 3,818.45 3,762.45 -555.04 -258.19 5,956,937.89 377,751.50 0.00 440.74 4,000.00 17.53 199.00 3,913.80 3,857.80 -583.53 -267.99 5,956,909.57 377,741.24 0.00 464.49 4,100.00 17.53 199.00 4,009.15 3,953.15 -612.02 -277.80 5,956,881.24 377,730.97 0.00 488.23 4,166.96 17.53 199.00 4,073.00 4,017.00 -631.09 -284.37 5,956,862.28 377,724.09 0.00 504.13 K-2 4,200.00 17.53 199.00 4,104.51 4,048.51 -640.50 -287.61 5,956,852.92 377,720.70 0.00 511.97 4,276.03 17.53 199.00 4,177.00 4,121.00 -662.16 -295.06 5,956,831.39 377,712.90 0.00 530.02 K-2 Base 4,300.00 17.53 199.00 4,199.86 4,143.86 -668.99 -297.41 5,956,824.60 377,710.43 0.00 535.71 4,400.00 17.53 199.00 4,295.21 4,239.21 -697.48 -307.22 5,956,796.28 377,700.17 0.00 559.46 4,500.00 17.53 199.00 4,390.57 4,334.57 -725.97 -317.03 5,956,767.95 377,689.90 0.00 583.20 4,600.00 17.53 199.00 4,485.92 4,429.92 -754.45 -326.84 5,956,739.63 377,679.63 0.00 606.94 4,700.00 17.53 199.00 4,581.27 4,525.27 -782.94 -336.64 5,956,711.31 377,669.37 0.00 630.69 4,800.00 17.53 199.00 4,676.63 4,620.63 -811.43 -346.45 5,956,682.99 377,659.10 0.00 654.43 4,900.00 17.53 199.00 4,771.98 4,715.98 -839.92 -356.26 5,956,654.66 377,648.83 0.00 678.17 5,000.00 17.53 199.00 4,867.33 4,811.33 -868.40 -366.06 5,956,626.34 377,638.57 0.00 701.91 5,100.00 17.53 199.00 4,962.69 4,906.69 -896.89 -375.87 5,956,598.02 377,628.30 0.00 725.66 5,200.00 17.53 199.00 5,058.04 5,002.04 -925.38 -385.68 5,956,569.70 377,618.03 0.00 749.40 5,257.27 17.53 199.00 5,112.65 5,056.65 -941.69 -391.29 5,956,553,48 377,612.15 0.00 763.00 Begin Dir; 4° DLS, -48° TFO, 5257 ' MD, 5112' TVD 5,300.00 18.72 195.03 5,153.26 5,097.26 -954.40 -395.17 5,956,540.83 377,608.07 4.00 773.75 5,400.00 21.75 187.47 5,247.09 5,191.09 -988.29 -401.74 5,956,507.06 377,600.95 4.00 803.65 5,500.00 25.05 181.75 5,338.87 5,282.87 -1,027.84 -404.80 5,956,467.57 377,597.25 4.00 840.05 5,600.00 28.52 177.32 5,428.13 5,372.13 -1,072.86 -404.33 5,956,422.55 377,596.99 4.00 882.77 5,700.00 32.10 173.78 5,514.46 5,458.46 -1,123.14 -400.33 5,956,372.22 377,600.17 4.00 931.61 5,800.00 35.76 170.90 5,597.42 5,541.42 -1,178.43 -392.83 5,956,316.82 377,606.78 4.00 986.33 5,900.00 39.48 168.48 5,676.62 5,620.62 -1,238.45 -381.85 5,956,256.63 377,616.78 4.00 1,046.66 6,000.00 43.24 166.43 5,751.66 5,695.66 -1,302.93 -367.46 5,956,191.93 377,630.12 4.00 1,112.31 6,100.00 47.04 164.64 5,822.19 5,766.19 -1,371.54 -349.72 5,956,123.05 377,646.75 4.00 1,182.96 6,145.97 48.79 163.89 5,853.00 5,797.00 -1,404.37 -340.46 5,956,090.08 377,655.47 4.00 1,217.01 Albian 97 6,200.00 50.86 163.06 5,887.86 5,831.86 -1,443.94 -328.71 5,956,050.32 377,666.57 4.00 1,258.26 6,300.00 54.69 161.64 5,948.34 5,892.34 -1,519.80 -304.55 5,955,974.09 377,689.50 4.00 1,337.84 6,400.00 58.55 160.35 6,003.35 5,947.35 -1,598.73 -277.35 5,955,894.74 377,715.41 4.00 1,421.33 6,500.00 62.41 159.17 6,052.62 5,996.62 -1,680.35 -247.24 5,955,812.64 377,744.19 4.00 1,508.31 6,600.00 66.29 158.06 6,095.90 6,039.90 -1,764.26 -214.36 5,955,728.21 377,775.70 4.00 1,598.36 6,700.00 70.17 157.02 6,132.99 6,076.99 -1,850.07 -178.89 5,955,641.85 377,809.77 4.00 1,691.03 6,783.23 73.40 156.20 6,159.00 6,103.00 -1,922.62 -147.50 5,955,568.81 377,839.97 4.00 1,769.85 Top Nanuq (Albian 96) 6,800.00 74.05 156.03 6,163.70 6,107.70 -1,937.34 -140.99 5,955,553.99 377,846.25 3.99 1,785.89 6,900.00 77.95 155.08 6,187.88 6,131.88 -2,025.65 -100.84 5,955,465.04 377,884.96 4.00 1,882.46 7,000.00 81.84 154.15 6,205.43 6,149.43 -2,114.57 -58.64 5,955,375.45 377,925.70 4.00 1,980.28 7,004.07 82.00 154.12 6,206.00 6,150.00 -2,118.20 -56.88 5,955,371.80 377,927.40 4.00 1,984.28 7" Csg Pt; 7004' MD, 6206' TVD; 5041' FNL 8~ 283' FEL; Sec24-T11 N-R04E -Target (Heel); 7004' MD, 6206' TVD - 7" -CD4-209wp06 T1 5/9/2006 4:54:17PM Page 5 of 8 COMPASS 2003.11 Build 50 i ,. ,. ~ .~. r 4 ., f ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillipsAlaska Inc: Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-209 Wellbore: Pfan: CD4-209 Design: CD4-209wp07 Sperry Drilling Services HAL41BU1~TON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD4-209 TVD Reference: Planned Doyonl9 @ 56.OOft (Doyon 19 (36.3 + 19.7)) MD Reference: Planned. Doyon 19 @ 56:OOft (Doyon 19 (36.3 +.19.7}) North Reference: True ' Survey Calculation Method: Minimum Curvature ' Planned Survey CD4-209wp07 -__ ___ __ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 7,020.26 82.32 154.15 6,208.21 6,152.21 -2,132.63 -49.89 5,955,357.26 377,934.16 1.99 2,000.20 7,100.00 82.32 154.15 6,218.86 6,162.86 -2,203.75 -15.43 5,955,285.59 377,967.45 0.00 2,078.66 7,163.21 82.32 154.15 6,227.31 6,171.31 -2,260.13 11.88 5,955,228.79 377,993.84 0.00 2,140.86 7,200.00 83.06 154.14 6,231.99 6,175.99 -2,292.97 27.79 5,955,195.70 378,009.22 2.00 2,177.09 7,300.00 85.06 154.12 6,242.35 6,186.35 -2,382.46 71.19 5,955,105.52 378,051.15 2.00 2,275.83 7,400.00 87.06 154.09 6,249.22 6,193.22 -2,472.20 114.75 5,955,015.09 378,093.26 2.00 2,374.87 7,500.00 89.06 154.07 6,252.61 6,196.61 -2,562.08 158.44 5,954,924.52 378,135.47 2.00 2,474.08 7,547.14 90.00 154.05 6,253.00 6,197.00 -2,604.47 179.06 5,954,881.80 378,155.40 2.00 2,520.87 Target (T2); 7547' MD, 6253' TVD -CD4-209wp06 T2 7,600.00 91.06 154.05 6,252.51 6,196.51 -2,652.00 202.18 5,954,833.91 378,177.75 2.00 2,573.34 7,700.00 93.06 154.05 6,248.92 6,192.92 -2,741.86 245.90 5,954,743.36 378,220.00 2.00 2,672.54 7,725.02 93.56 154.05 6,247.48 6,191.48 -2,764.32 256.83 5,954,720.73 378,230.56 2.00 2,697.33 7,800.00 93.56 154.05 6,242.83 6,186.83 -2,831.61 289.58 5,954,652.92 378,262.21 0.00 2,771.62 7,900.00 93.56 154.05 6,236.62 6,180.62 -2,921.36 333.25 5,954,562.48 378,304.42 0.00 2,870.69 8,000.00 93.56 154.05 6,230.42 6,174.42 -3,011.10 376.92 5,954,472.05 378,346.62 0.00 2,969.77 8,100.00 93.56 154.05 6,224.21 6,168.21 -3,100.85 420.59 5,954,381.61 378,388.82 0.00 3,068.84 8,200.00 93.56 154.05 6,218.01 6,162.01 -3,190.60 464.26 5,954,291.17 378,431.03 0.00 3,167.92 8,300.00 93.56 154.05 6,211.80 6,155.80 -3,280.34 507.93 5,954,200.74 378,473.23 0.00 3,266.99 8,400.00 93.56 154.05 6,205.60 6,149.60 -3,370.09 551.60 5,954,110.30 378,515.44 0.00 3,366.07 8,465.70 93.56 154.05 6,201.52 6,145.52 -3,429.05 580.29 5,954,050.89 378,543.17 0.00 3,431.16 8,500.00 92.87 154.06 6,199.60 6,143.60 -3,459.85 595.27 5,954,019.86 378,557.65 2.00 3,465.15 8,600.00 90.87 154.07 6,196.33 6,140.33 -3,549.72 638.98 5,953,929.29 378,599.89 2.00 3,564.36 8,643.58 90.00 154.08 6,196.00 6,140.00 -3,588.91 658.03 5,953,889.80 378,618.30 2.00 3,607.62 Target (T3); 8643' MD, 6196' TVD - CD4209wp06 T3 8,700.00 88.87 154.08 6,196.56 6,140.56 -3,639.66 682.70 5,953,838.67 378,642.14 2.00 3,663.63 8,800.00 86.87 154.08 6,200.27 6,144.27 -3,729.53 726.38 5,953,748.11 378,684.35 2.00 3,762.83 8,855.67 85.76 154.08 6,203.85 6,147.85 -3,779.50 750.67 5,953,697.76 378,707.82 2.00 3,817.98 8,900.00 85.76 154.08 6,207.13 6,151.13 -3,819.25 769.99 5,953,657.69 378,726.50 0.00 3,861.86 9,000.00 85.76 154.08 6,214.52 6,158.52 -3,908.95 813.59 5,953,567.31 378,768.63 0.00 3,960.86 9,100.00 85.76 154.08 6,221.92 6,165.92 -3,998.64 857.19 5,953,476.93 378,810.76 0.00 4,059.86 9,200.00 85.76 154.08 6,229.32 6,173.32 -4,088.33 900.78 5,953,386.55 378,852.90 0.00 4,158.86 9,300.00 85.76 154.08 6,236.71 6,180.71 -4,178.02 944.38 5,953,296.17 378,895.03 0.00 4,257.86 9,400.00 85.76 154.08 6,244.11 6,188.11 -4,267.71 987.98 5,953,205.79 378,937.16 0.00 4,356.86 9,427.60 85.76 154.08 6,246.15 6,190.15 -4,292.47 1,000.01 5,953,180.85 378,948.79 0.00 4,384.18 9,500.00 87.21 154.08 6,250.59 6,194.59 -4,357.46 1,031.60 5,953,115.36 378,979.32 2.00 4,455.91 9,600.00 89.21 154.08 6,253.72 6,197.72 -4,447.35 1,075.28 5,953,024.78 379,021.53 2.00 4,555.13 9,639.70 90.00 154.08 6,254.00 6,198.00 -4,483.05 1,092.63 5,952,988.80 379,038.30 2.00 4,594.54 Target (T4); 9639' MD, 6254' TVD -CD4-209wp06 T4 9,700.00 91.21 154.09 6,253.37 6,197.37 -4,537.29 1,118.99 5,952,934.15 379,063.77 2.00 4,654.40 9,770.88 92.62 154.09 6,251.00 6,195.00 -4,601.01 1,149.94 5,952,869.94 379,093.68 2.00 4,724.72 9,800.00 92.62 154.09 6,249.66 6,193.66 -4,627.17 1,162.66 5,952,843.58 379,105.97 0.00 4,753.60 9,900.00 92.62 154.09 6,245.09 6,189.09 -4,717.02 1,206.31 5,952,753.04 379,148.15 0.00 4,852.77 10,000.00 92.62 154.09 6,240.51 6,184.51 -4,806.88 1,249.96 5,952,662.50 379,190.34 0.00 4,951.94 10,100.00 92.62 154.09 6,235.93 6,179.93 -4,896.73 1,293.62 5,952,571.95 379,232.53 0.00 5,051.11 10,200.00 92.62 154.09 6,231.35 6,175.35 -4,986.58 1,337.27 5,952,481.41 379,274.71 0.00 5,150.28 10,300.00 92.62 154.09 6,226.78 6,170.78 -5,076.43 1,380.92 5,952,390.87 379,316.90 0.00 5,249.45 10,400.00 92.62 154.09 6,222.20 6,166.20 -5,166.28 1,424.58 5,952,300.33 379,359.09 0.00 5,348.61 10,500.00 92.62 154.09 6,217.62 6,161.62 -5,256.14 1,468.23 5,952,209.79 379,401.27 0.00 5,447.78 10,600.00 92.62 154.09 6,213.04 6,157.04 -5,345.99 1,511.89 5,952,119.25 379,443.46 0.00 5,546.95 5/9/2006 4:54:17PM Page 6 of 8 COMPASS 2003.11 Build 50 n~!r,I~AL ~ ~ / Sperry Drilling Services ' . , Ph ll ~~ Ft i ID WALL u N Conoc i o ~ Planning Report -Geographic q~~ Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Pfan; CD4-209 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19 (36.3 + 19.7)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 56.OOft (Doyon 19 (36.3 + 19.7)) Site: Alpine CD4 North Reference: True- Well: Plan: CD4-209 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-209 Design: CD4-209wp07 - ___ _ ___ _ Planned Survey CD4 209wp07 _ I Map Map ~ MD Inclination Azimuth TVD SSTVD +NI-S +E/_yy Northing Easting DLSEV Vert Section i (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,700.00 92.62 154.09 6,208.47 6,152.47 -5,435.84 1,555.54 5,952,028.71 379,485.65 0.00 5,646.12 10,800.00 92.62 154.09 6,203.89 6,147.89 -5,525.69 1,599.19 5,951,938.17 379,527.83 0.00 5,745.29 10,900.00 92.62 154.09 6,199.31 6,143.31 -5,615.54 1,642.85 5,951,847.63 379,570.02 0.00 5,844.46 10,906.70 92.62 154.09 6,199.00 6,143.00 -5,621.57 1,645.77 5,951,841.56 379,572.85 0.00 5,851.11 11,000.00 90.76 154.05 6,196.25 6,140.25 -5,705.43 1,686.55 5,951,757.05 379,612.26 2.00 5,943.68 11,037.92 90.00 154.03 6,196.00 6,140.00 -5,739.52 1,703.15 5,951,722.70 379,628.30 2.00 5,981.31 Target (TS); 11037' MD, 6196' TVD -CD4-209wp 06 T5 11,100.00 88.50 154.03 6,196.81 6,140.81 -5,795.33 1,730.34 5,951,666.46 379,654.57 2.42 6,042.93 11,200.00 86.08 154.02 6,201.55 6,145.55 -5,885.12 1,774.08 5,951,575.98 379,696.85 2.42 6,142.07 11,300.00 83.66 154.02 6,210.49 6,154.49 -5,974.65 1,817.71 5,951,485.76 379,739.02 2.42 6,240.93 11,340.50 82.68 154.02 6,215.31 6,159.31 -6,010.79 1,835.33 5,951,449.34 379,756.05 2.42 6,280.84 11,400.00 82.68 154.02 6,222.89 6,166.89 -6,063.84 1,861.18 5,951,395.88 379,781.03 0.00 6,339.42 11,429.79 82.68 154.02 6,226.69 6,170.69 -6,090.40 1,874.13 5,951,369.11 379,793.55 0.00 6,368.75 11,500.00 84.38 154.03 6,234.60 6,178.60 -6,153.11 1,904.68 5,951,305.92 379,823.08 2.42 6,437.99 11,600.00 86.80 154.05 6,242.30 6,186.30 -6,242.75 1,948.33 5,951,215.60 379,865.26 2.42 6,536.95 11,700.00 89.22 154.07 6,245.78 6,189.78 -6,332.61 1,992.05 5,951,125.05 379,907.51 2.42 6,636.15 11,732.39 90.00 154.07 6,246.00 6,190.00 -6,361.73 2,006.21 5,951,095.70 379,921.20 2.42 6,668.30 Target (T6); 11732' MD, 6246' TVD -CD4-209wp06 T6 11,800.00 91.35 154.07 6,245.20 6,189.20 -6,422.54 2,035.77 5,951,034.43 379,949.77 2.00 6,735.41 11,808.99 91.53 154.07 6,244.98 6,188.98 -6,430.61 2,039.70 5,951,026.29 379,953.56 2.00 6,744.33 11,900.00 91.53 154.07 6,242.54 6,186.54 -6,512.44 2,079.48 5,950,943.84 379,992.01 0.00 6,834.64. 12,000.00 91.53 154.07 6,239.87 6,183.87 -6,602.34 2,123.19 5,950,853.25 380,034.25 0.00 6,933.88 12,100.00 91.53 154.07 6,237.20 6,181.20 -6,692.24 2,166.90 5,950,762.66 380,076.49 0.00 7,033.11 12,200.00 91.53 154.07 6,234.52 6,178.52 -6,782.14 2,210.61 5,950,672.07 380,118.74 0.00 7,132.35 12,300.00 91.53 154.07 6,231.85 6,175.85 -6,872.04 2,254.32 5,950,581.48 380,160.98 0.00 7,231.58 12,400.00 91.53 154.07 6,229.18 6,173.18 -6,961.94 2,298.03 5,950,490.88 380,203.22 0.00 7,330.81 12,500.00 91.53 154.07 6,226.50 6,170.50 -7,051.85 2,341.74 5,950,400.29 380,245.46 0.00 7,430.05 12,600.00 91.53 154.07 6,223.83 6,167.83 -7,141.75 2,385.45 5,950,309.70 380,287.70 0.00 7,529.28 12,700.00 91.53 154.07 6,221.15 6,165.15 -7,231.65 2,429.16 5,950,219.11 380,329.95 0.00 7,628.52 12,800.00 91.53 154.07 6,218.48 6,162.48 -7,321.55 2,472.87 5,950,128.52 380,372.19 0.00 7,727.75 12,900.00 91.53 154.07 6,215.81 6,159.81 -7,411.45 2,516.58 5,950,037.93 380,414.43 0.00 7,826.99 13,000.00 91.53 154.07 6,213.13 6,157.13 -7,501.35 2,560.29 5,949,947.34 380,456.67 0.00 7,926.22 13,100.00 91.53 154.07 6,210.46 6,154.46 -7,591.25 2,604.01 5,949,856.74 380,498.92 0.00 8,025.45 13,200.00 91.53 154.07 6,207.79 6,151.79 -7,681.16 2,647.72 5,949,766.15 380,541.16 0.00 8,124.69 13,300.00 91.53 154.07 6,205.11 6,149.11 -7,771.06 2,691.43 5,949,675.56 380,583.40 0.00 8,223.92 •13,304.26 91.53 154.07 6,205.00 ~ 6,149.00 -7,774.89 2,693.29 5,949,671.70 380,585.20 0.00 8,228.15 Target (Toe); 13304' MD, 6205' TVD, 138' FNL 8 2527' FEL; Sec31-T11N -R05E - 4112" Liner -CD4-209wp06 T7 5/9/2006 4:54:17PM Page 7 of 8 COMPASS 2003.11 Build 50 ~~~k~ ~ / Sperry Drilling Services " ' ' HALL1~3t.~RT C ~N ~©1 lOC0 ~11~~! 5 p Planning Report -Geographic ---- ~~ ~~°°~~° f#I~ka $petrRy D-itling Sorvia*s Database: EDM 2003.11. Single UserDb Local Co-ordinate Reference: Well Plan: CD4-209 Company: ConocoPhillips Alaska lnc: TVD Reference: Planned Doyon 19 @ 56:OOft (Doyon 19 (36.3 + 19.7)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 56OOft (Doyon 19 (36.3 + 19.7)) Site: Alpine CD4 North Reference: True. Well: Plan: CD4-209 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-209 Design: CD4-209wp07 Geologic Targets Plan: CD4-209 I TVD Target Name +N/-S +E/-W Northing Easting I' (ft) -Shape ft ft (ft) (ft) ', 6,206.00 CD4-209wp06 T1 -2,118.20 -56.88 5,955,371.80 377,927.40 - Point 6,196.00 CD4-209wpO6T5 -5,739.52 1,703.15 5,951,722.70 379,628.30 - Point 6,196.00 CD4-209wp06 T3 -3,588.91 658.03 5,953,889.80 378,618.30 - Point 6,253.00 CD4-209wp06 T2 -2,604.47 179.06 5,954,881.80 378,155.40 - Point 6,205.00 CD4-209wp06 T7 -7,774.89 2,693.29 5,949,671.70 380,585.20 - Point 6,246.00 CD4-209wp06 T6 -6,361.73 2,006.21 5,951,095.70 379,921.20 - Point 6,254.00 CD4-209wp06 T4 -4,483.05 1,092.63 5,952,988.80 379,038.30 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 2,414.32 2,400.00 9-5/8 12-1/4 7,004.07 6,206.00 7 8-3/4 13,304.25 6,205.00 4-1/2 6-1/8 Prognosed Format ion Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name 781.00 0.00 0.00 781.00 0.00 0.00 Base Permafrost 2,209.97 12.10 210.00 2,201.00 -110.23 -63.64 C-40 2,420.51 14.21 210.00 2,406.00 -151.72 -87.59 C-30 2,795.23 17.95 210.00 2,766.00 -241.58 -139.48 C-20 3,899.53 17.53 199.00 3,818.00 -554.91 -258.14 K-3 4,166.96 17.53 199.00 4,073.00 -631.09 -284.37 K-2 4,276.03 17.53 199.00 4,177.00 -662.16 -295.06 K-2_Base 6,145.97 48.79 163.89 5,853.00 -1,404.37 -340.46 Albian 97 6,783.23 73.40 156.20 6,159.00 -1,922.62 -147.50 Top Nanuq (Albian 96) 5/9/2006 4:54:17PM P age 8 of 8 COMPASS 2003.11 Build 50 (' ' ~ ~~ ~~ ?* t • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-209 Plan: CD4-209 CD4-209wp07 Anticollision Report 09 May, 2006 1-#AL..L1 ~3URTt~1'V Sperry Drilling Services ORIGINAL ConocoPhill~Xir~pA~s~ `Sel$W NALte101.IRTi7iV sn.mr omu.a s.r91w. CanomP~nips Nerlm inc RoBG C01aY Reef Vat SR Npne COJ Weil Pun CDI-x09 PoWeIINrc. n. - Nanuq 5 ~ 90 / 270 CD4-ibwp02 - - - CD4211wp04 - CD417wp01 CD4215wp03 To 13304.26 Muimum 0.anae Error Model: Sean McXwd: Ermr Surlau: Ima:2eo6-ASat9rna:ne:6X TalMal.d: rr, c<r:bn: DeplX Flom DegA TO Sulvey~Phn Tool 36)0 IOW.XX ('DJ-109m'p01 C'B1:1'R()-!i.9 IOW.W 1130)16 CUJ-109wp0] Nt\'M IFR-.IA-CV.SC CD4-214wp03 "r CD4213wp03 '~` CD4210wp05 -150 / No!e 180 / 1 BO CD4-212 (wp04) NDA Fr.m eWr• T. MO Critical Issues: Ewa: xesneen, ~nrv.IX Nanuq 5 Minor Risked to 1/200 al3aan ~- - Inter NaM - Coniv - aetl CD4207wp04 0 / 360 0 mrewr nnr1wo1 1.arresor ant-seor CD4-206wp05 CD4-204wp04 ~ \ cD4-zo6pel CD4208 NEGATIVE TFO+Aa values ham the Survey EdiEOr or Travellina CYlinder Report should he ploRed on fhe I•R aide of ale Travellina Cylinder. Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation 125 Nin] _ CD4-205wp04 -90 coN-xlawpl ~ CD4~203wp04 -180 / 1 BC TnvellleR C)lieder AJUnuM 1TF03A7J) I°t vX Centre to Ccelre 5<pantwe IS fl! I Src \R2 Ivc 1J1 T\'D +NI ,S +F/-\\' ULeR TFau VAcc TarRcl 1 Je.lO O.W II.W b.311 OW II.INI II INI OW O.pl 2 IWn,W O.W 0.00 IOW.W O.W O.W O.W O.W O.W ! 19011.1X1 IY.W 21U.W 2A6SJ] -1]UJ3 -IK.Utl 1.1X1 110.W 1U1.1Y J 503 J.69 I1.St 199.W 2983 M1 )05.69 -1]235 3.W -1IA.Ie 231.92 52511' I1.Si 19Y.W 51I1.fi5 -9)1.69 )91.29 O.IMI O.W ]63.W 6 ]WJ.111 tl1.W 151.12 M120fi.W -211R20 -56xA iW -JR09 19R1.2A t'D1209•P06 TI ] ]0211.16 X2.32 ISJ.IS M1EON.21 -1132.61 9X9 2.W 622 2aW.1A ]16).21 82.31 15).15 621].31 -1160.1) Il.tlB O.W O.W 21JU.Xfi 151].1) 911.Iq ISJ.IIf 6253.1X1 -2611))] 1]9.W 2.W A.]J 1510.X'! (1111U9x'pW T1 10 ]'25.112 93.56 IRJ.OS 63J].JX -1]6J.J2 LS6.M3 2.W -0.01 169).33 II RJRS]0 93.56 ISJ.OS 6201.51 -JJ29.05 580.29 O.W O.W 3Jll.lfi 12 R6JSSA 911.W 15J.IM fi196.IN1 -341X91 6SY.ID 2.011 1'1960 3611].62 ('Di2119wpIM T3 13 MX556] 8S]fi IG.Otl 110).X5 -3]'19.50 i50.h1 2.W -1]9.99 38]].9tl Ii YJ21M1 85.]6 IS1.nX 62)6.15 ~92.J] IIMNI.111 II.IMI 0.W 13Nl.Itl 15 wJ9.10 90.W 1VX9 n24.W JJA3.05 1092.63 2.00 0.11 J59J.51 <'DJ-20Arp06 T! I6 4']11X9 Y2.fi1 14UY fi2Y11N1 -MUL01 11lY.Y! 2.W D.IM )]31]2 tl IIWOfi]II 92.82 15tH n199.00 .5621.51 16)5.]] O.W O.W SA51.11 IM iY- 11031'12 -313M.Se 911.1x1 M3411- ISJID ISJAt fit Yfi.INI -611c 3t-- -5])9.52 '~oi0.:r 1]03.15 -~RiS33- E.Iq -i:e2 -1]R)6 ~r:+ev- SYAI.l1 <Tli2U9n'pW Ti _--61AB.E6 cl>t.xpe :a-zoepal • • 5/9/2006 2:52 PM \ir' ColnocoPhllips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville RiverUnit Reference Site: Alpine CD4 Site Error: O.OOft Reference Well: Plan: CD4-209" Well Error: O.OOft Reference Wellbore Plan: CD4-209. Reference Design: CD4-209wp07 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • NALi..rBUIaTON Sperry DrNiinS Services Well Plan: CD4-209 Planned Doypn 19 @ 56OOft (Doyon 19 (36.3 + 19.7)) Planned Doyon 19 @ 56.OOft (Doyon 19 (36.3 + 19.7)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference CD4-209wp07 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,526.80ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 5/9/2006 From To (ft) (ft) Survey (Wellbore) 36.30 1,000.00 CD4-209wp07 (Plan: CD4-209) 1,000.00 13,304.26 CD4-209wp07 (Plan: CD4-209) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Alpine CD4 CD4-208 -CD4-208 -CD4-208 650.83 650.00 19.85 12.87 6.98 Pass -Major Risk CD4-208 -CD4-208P61 -CD4-208PB1 650.83 650.00 19.85 12.87 6.98 Pass -Major Risk CD4-318 -CD4-318 -CD4-318 350.84 350.00 181.57 7.42 174.15 Pass -Major Risk CD4-318 -CD4-318PB1 -CD4-318PB1 350.84 350.00 181.57 7.42 174.15 Pass -Major Risk CD4-319 -CD4-319 -CD4-319 300.85 300.00 201.46 6.08 195.38 Pass -Major Risk Nanuq 5 /Plan: CD4-212 -Nanuq 5 -Nanuq 5 603.07 600.00 52.19 4.71 47.49 Pass -Minor 1/200 Nanuq 5 /Plan: CD4-212 -Plan: CD4-212 -CD4-~ 627.98 625.00 52.49 11.68 40.83 Pass -Major Risk Plan: CD4-16 -Plan: CD4-16 -CD4-16wp02 375.69 375.00 140.21 7.90 132.31 Pass -Major Risk Plan: CD4-17 -Plan: CD4-17 -CD4-17wp01 425.69 425.00 160.21 8.99 151.22 Pass -Major Risk Plan: CD4-203 -Plan: CD4-203 -CD4-203wp04 450.89 450.00 120.99 9.39 111.60 Pass -Major Risk Plan: CD4-204 -Plan: CD4-204 -CD4-204wp04 350.89 350.00 101.04 7.22 93.82 Pass -Major Risk Plan: CD4-205 -Plan: CD4-205 -CD4-205wp04 750.89 750.00 80.97 15.90 65.07 Pass -Major Risk Plan: CD4-206 -Plan: CD4-206 -CD4-206wp05 500.62 500.00 59.22 10.63 48.60 Pass -Major Risk Plan: CD4-207 -Plan: CD4-207 -CD4-207wp04 1,125.26 1,125.00 41.48 23.60 17.88 Pass -Major Risk Plan: CD4-210 -Plan: CD4-210 -CD4-210wp05 650.69 650.00 20.34 13.87 6.47 Pass -Major Risk Plan: CD4-211 -Plan: CD4-211 -CD4-211wp04 650.89 650.00 40.16 13.88 26.28 Pass -Major Risk Plan: CD4-213 -Plan: CD4-213 -CD4-213wp03 350.89 350.00 79.93 7.36 72.57 Pass -Major Risk Plan: CD4-214 -Plan: CD4-214 -CD4-214wp03 550.89 550.00 100.08 11.70 88.38 Pass -Major Risk Plan: CD4-215 -Plan: CD4-215 -CD4-215wp03 350.89 350.00 120.10 7.36 112.74 Pass -Major Risk Plan: CD4-320 -Plan: CD4-320 -CD4-320wp06 499.75 500.00 221.53 10.61 210.93 Pass -Major Risk Alpine Satellites Nanuq 5 -Nanuq 5 -Nanuq 5 56.00 56.00 59.42 1.17 58.26 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/9/2006 2:42:10PM Page 2 of 2 COMPASS 2003.11 Build 50 ~wrg N a u U Gn~~n O ~'.~~ O O 888 O ~~~ ~ ~~«~ O O O W ~ O ~ ~ O O ~ • ~ O O c_ 0 0 O N O .~. O }~ N N .+ W_ .C OO ~ .. ~~cc 3 3 ~ ~UU C d C C C N 'S?aa ~ o oa ~ U " ::mom V ~y~~ C ~O N ~ a` 3 a 0 0 0 N i g ~~ ~ o~ o ~~~ ~~~~ w..W.. ~ o E~~88O~ ~ _ ~m~af $ r'av`Oi n c3Q ~Y)it m~NN ~ t a i w ~p f4 '~Q z ~ >a Q ~ m ,~ o V ~ ~ ° Q o 0 0 0 0 o O o 0D ~ J~ 0 0 0 0 0 0 O Q o 0 0 0 0 0 N N ~ CO 00 O V =~ <Q 3 ~O a~J , a ~ ~ '. ~ ~ \ G~ - - -- ~o I I c; / ~V -} ~~ OJ I K 2 Nov I - - -- g bnueN ~~ d~ t7y ~ ~ O~ U ~ OJ ~ PO O J J i t • • • • c ca Z 0 N 0 U - ~ ~ _ c c~ Z 7 N N a O ~ ~ ~ ~v M mccc .oaaa N G _ ~ 7 C ~ O c~M d ~' V -m$ Z 3 uy~~ - ~ a 3 a N - >d maa _, Q z- U ~ c ca ~ M Z a Z I ~ ~ ~ jo ~ ~ V m o Q I V I • ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o S ~ ~ o ~ Q h ~O I~ W P 199LBE o R 19998E „ ~ ~ a ; a ~° e ~ ~ s ~ 199SBE g 19948E S 199E8E 199zeE 19918E 19908E 1996LE i 1998LE pp .~ s 199LLE E fr _ ~ *iE~ ~ $ < < ~ 6 ~ ~ 1999LE 199SLE 1996LE 199ECE f99ZCE 1991LE 199oLE ~ o °o, $ .p .p 19969E 8 ~ 19989E C D d 199L9£ ioooor I-1 4a~os / I+I 41~oN OC40Z OC461 VB O C I O LhLI 49 O L 1 - OL7Sl v 3 = 44 O 0 L 1 OL7£l OLVLI 4 O L ll 40 O L 1 _~ c 0 a 0L46 N OL48 O oLYL p u OCV9 ~ i ~ ii c o d `o ~_ ~ ~ 6 E ~ ~ j 3 ~~'~~os - s 8 _ - R -aa ~ OL4S ~~ OCh4 - - - OC6£ i i _ - OL4Z N Q -_ 1O OCV I - -_. I oLb I - ~- 0£S- ~, -- ~ o£sl- z o£sa- o£s£- 3 m o£sv- ~ co zoa c 0 o£ss- u $ N N S X ~ 0£S9- ~ g g ~ 41da4 ~~~ly~a~ anal walsAg § s p F U Closest in POOL Closest Approach: Reference Well: CD4-209wp07 Pla Offset Well: Nanuq 5 Coords. - Coords. - 3-D etr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (161°) Comments Depth Ind. Angle TRUE Azi. ND E(+)ryy(-) (161°) Comments POOL Min Distance POOL Min Distance (59.79 ft) in POOL (59.79 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304.26 MD) to Nanuq 5 (6100- to CD4-209wp07 Plan 59.79 12350 91.53 154.07 6174.55 5950536 380182.2 7281.054 6254 TVDss) 10025 57.49 162.98 6160.068 5950517 380127.2 7281.547 (6100 - 6254 TVDss) Closest Approach: Reference Well: CD4-209wp07 Pia Offset Well: CD4-208 Coords. - Coords. - 3-D ctr- ASP ASP clr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsee N(+)/S(-) View VS Diat. Depth Incl. Angle TRUE Azi. 7V0 E(+)NV(-) (161°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (161°) Comments POOL Min Distance POOL Min Distance (1443.44 ft) in POOL (1443.44 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304,26 MD) to CD4-208 (6100- to CD4-209wp07 Plan 1443.44 7004.07 82 154.12 6150.047 5955372 377927.4 1984.124 6254 TVDss) 7250 82.13 331.95 6101.046 5956754 377514.9 541.9988 (6100 - 6254 TVDss) Closest Approach: Reference Well: CD4-209wp07 Pla Offset Well: Nanuk Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. _. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dlst. Depth Incl. Angle TRUE Azi. TVD E(+)NV(-) (161°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (161°) Comments POOL Min Distance POOL Min Distance (2948.14 ft) in POOL (2948.14 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304.26 MD) to Nanuk 1 (6100- to CD4-209wp07 Plan 2948.14 7004.07 82 154.12 6150.047 5955372 377927.4 1984.124 6254 TVDss) fi175 0.49 13,32 6135,817 5958136 378951.1 -335.581 (6100-6254 TVDss) Closest Approach: Reference Well: CD4-209wp07 Pla Offset Well: Nanuk Coords. - Coords. - 3-D ctr- ASP ASP ctr Min ... ,_ Meas. Subsee N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist a Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (161°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (181°) Comments POOL Min Distance POOL Min Distance (3774.31 ft) In POOL (3774.31 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304.26 MD) to Nanuk 2 (6100 - to CD4-209wp07 Plan 3774.31 "a 7: 7004.07 62 154.12 6150.047 5955372 377927.4 1984.124 6254 TVDss) 7025 1.67 273.23 6114,267 5954429 374272.9 1783.854 (6100-6254 TVDss) • • CD4209wp07 PoolSummery.xls 5/9/2006 5:06 PM ConocoPhillips Alaska Company: ConocoPhillips Alaska Ina Project: Colville River Unit Reference Site: Alpine CD4 Site Error: O.OOft Reference Well: Plan: CD4-209 Well Error: O.OOft Reference Wellbore Plan: CD4-209 Reference Design: CD4-209wp07 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALILIE~UF~Tt~N Sperry Drilling Services Well Plan: CD4-209 Planned Doyon 19 @ 56.OOft (Doyon 19 (36.3 + 19.7)) Planned Doyon 19 @ 56.OOft (Doyon 19.(36.3 + 19.7)) True Minimum Curvature. 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference CD4-209wp07 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,526.80ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 5/9/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 36.30 1,000.00 CD4-209wp07 (Plan: CD4-209) CB-GYRO-SS Camera based gyro single shot 1,000.00 13,304.26 CD4-209wp07 (Plan: CD4-209) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Alpine CD4 CD4-208 -CD4-208 -CD4-208 650.83 650.00 19.85 12.87 6.98 Pass -Major Risk CD4-208 -CD4-208PB1 -CD4-208PB1 650.83 650.00 19.85 12.87 6.98 Pass -Major Risk CD4-318 -CD4-318 -CD4-318 350.84 350.00 181.57 7.42 174.15 Pass -Major Risk CD4-318 -CD4-318PB1 -CD4-318P61 350.84 350.00 181.57 7.42 174.15 Pass -Major Risk CD4-319 -CD4-319 -CD4-319 300.85 300.00 201.46 6.08 195.38 Pass -Major Risk Nanuq 5 /Plan: CD4-212 -Nanuq 5 -Nanuq 5 603.07 600.00 52.19 4.71 47.49 Pass -Minor 1/200 Nanuq 5 /Plan: CD4-212 -Plan: CD4-212 -CD4-~ 627.98 625.00 52.49 11.68 40.83 Pass -Major Risk Plan: CD4-16 -Plan: CD4-16 -CD4-16wp02 375.69 375.00 140.21 7.90 132,31 Pass -Major Risk Plan: CD4-17 -Plan: CD4-17 -CD4-17wp01 425.69 425.00 160.21 8.99 151.22 Pass -Major Risk Plan: CD4-203 -Plan: CD4-203 -CD4-203wp04 450.89 450.00 120.99 9.39 111.60 Pass -Major Risk Plan: CD4-204 -Plan: CD4-204 -CD4-204wp04 350.89 350.00 101.04 7.22 93.82 Pass -Major Risk Plan: CD4-205 -Plan: CD4-205 -CD4-205wp04 750.89 750.00 80.97 15.90 65.07 Pass -Major Risk Plan: CD4-206 -Plan: CD4-206 -CD4-206wp05 500.62 500.00 59.22 10.63 48.60 Pass -Major Risk Plan: CD4-207 -Plan: CD4-207 -CD4-207wp04 1,125.26 1,125.00 41.48 23.60 17.88 Pass -Major Risk Plan: CD4-210 -Plan: CD4-210 -CD4-210wp05 650.69 650.00 20.34 13.87 6.47 Pass -Major Risk Plan: CD4-211 -Plan: CD4-211 -CD4-211wp04 650.89 650.00 40.16 13.88 26.28 Pass -Major Risk Plan: CD4-213 -Plan: CD4-213 -CD4-213wp03 350.89 350.00 79.93 7.36 72.57 Pass -Major Risk Plan: CD4-214 -Plan: CD4-214 -CD4-214wp03 550.89 550.00 100.08 11.70 88.38 Pass -Major Risk Plan: CD4-215 -Plan: CD4-215 -CD4-215wp03 350.89 350.00 120.10 7.36 112.74 Pass -Major Risk Plan: CD4-320 -Plan: CD4-320 -CD4-320wp06 499.75 500.00 221.53 10.61 210.93 Pass -Major Risk Alpine Satellites Nanuq 5 -Nanuq 5 -Nanuq 5 56.00 56.00 59.42 1.17 58.26 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/9/2006 2:42:10PM Page 2 of 2 COMPASS 2003.118ui1d 50 CaloulaUon MaNod: Mf~num Curnlun ConotoPhillips ~ror~a~m:'~„ Snn Method: Trav. CyIIMar North Error Surfao: FAlipliml Conic 1.,, Warnln9 Method: RuW Barad Alaslta Daodetle Dalurrt NAD 1927 (Naocarl CDNUS( Magnetic Model: BOGM2005 HALLlBUFlTQN Ground Leval: 19.08 RKB: Planned Doyon 19 g~ 56.OOtt (Doyon 19 (38.3+ ...,~....,...,_._.._.>...,.,._.,......,..._......_..,..._.,_....~.._.._ NorthinyASP Y: 5957488.82 Spenry Drilling Services EestinglASP %: 378018.84 2000 - 0- -2000 - -4000 - -6000- -8000- -10000 -8000 Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4209 Wellbore: Plan: CD4209 Plan: CD4-209wp07 / ~A\ cASINC DEruLs No TVD MD Name 1 2400.00 2414.92 9 B8" 2 8208.00 7901.07 7" 3 8208.00 1391M2b 4112" Liner ~~g G GOA 60 G07- M ~ CD4-31 Z ~ ' d' 4 2 c~ N 9Q~1 ____ Ob,3 --~ G CDQ'318 - - - - ~g.NQ~1 a- Nor 5 a -6000 -4000 -2000 0 2000 4000 6000 8000 10000 West(-)/East(+) (2000 ftlin) • • • - ~ • L c ca Z ~ ~ ~ o ' N i ' ' d- ' U c~ Z c ~~ N N ~ h Q ~ r o ~ i i >oo0 ~UUU 3 Cf z 8 M ' mccc a m ca N ,~, ~ ~ - ~ -'- ~ - ' ~ ~ ~ oaaa ~ a ~ ~ p UY ~ ~ U om~ Z ~ p ` ~ d N a mYsX m~~~ d' Z ,~ N ,' U c ca ~ Z •°-'Q z a o a ~ ~ Q V m a ~ O Q V ~ ~ C Q F °_ i ex ~ E s ~ E L .. _ = E 3 = R c $ < . ~ r ~ 8 g o ~O ~O a w C a s ei o d • 0 o s s o 0 o s g s g o o s g o ~ R 99LBE 9998E 99SBE 9968E 99£8E 99Z8E 99ise 9908E 996LE 998LE ~~ 99LCE 999LE 99SLE ~' 996LE e Q 99eCe b N 99ZLE 991LE 990LE 9969E 99s9e 99L9E ~ ~ ~ S ~ ~ a OL40Z m 0 v OL 61 4 ~ O N OC481 'D OL4Ll OL49! OL4S! OL441 £ OL4 l OL4ZL OC4!! OC40! ~ N C 6 x ° tO OL46 0 > o N ~ rn l OL48 ~ o o a 6 p OL4L p ~ < N V O OL49 ~ N ~ ~ > ~ U `o 3 H . Z? i ~ ~- 8 $ c ; rn ~ $ ~` 80> $ i o ~ F s u 3 ^I9 g i~ N O M_ ~ f/1 ffJ U1 tl7 ~ 0 ~ ~ 0 ~ O ~~d'~t~ N N N N N _ ~ ~ ~ CO ~ R O Q ~ ~ 0 a .~ ~. ,, ..... ~ ° ° ° ° ° o o o o o ~ r ~ ~ ~ r ~ ~ t0 tD t0 t0 3 d! 00 r N M tf~ J N N Y Y ~~ ~ ~ 7 3 7 7 Q 0 ~ R l0 l6 R 0. C~C)ZZZZ € N s" E E o ~ ; ~' ~ U OL4S 0 d OL44 a OL4E OL4Z OL4l OL4 0£S- 0£Sl- o£sz- o£s£- 3 0/ 0£S4- 3 c ~' O a y;, OESS- ao V U 0£S9- y;dap loolua~ anil wa;sAg Closest in POOL Closest Approach: Reference Well: CD4-209wp07 Pla Offset Weli: Nanuq 5 Coords. - Coorda. - 3-D ctr- ASP ASP ctr Min. .~o. ... Mees. Subsea N(+)/S(•) View VS Meas. Subsea N(+pS(-) View VS Dlat. Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (161°) Comments Depth Incl. Angle TRUE AZi. ND E(+)NV(-) (161°) Comments POOL Min Distenca POOL Min Distance (59.79 ft) in POOL (59.79 ft) in POOL (7004 - 13304.28 MD) (7004 - 13304.26 MD) to Nanuq 5 (6100 - to CD4-209wp07 Plan 58.79 12350 91.53 154.07 6174.55 5950536 380182.2 7281.054 6254 TVDsa) 10025 57.49 162.98 6180.088 5950517 380127.2 7281.547 (8100-8254 NDsa) Closest Approach: Reference Weil: CD4 -209wp07 Pla Offset Well: CD4-208 Coords.- Coords.- 3-D ctr- ASP ASP dr Min. ._.., .. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+pS(-) View VS Diet Depth Incl. Angle TRUE Azi. TVD E(+)NV(-) (161°) Comments Depth Ind. Angle TRUE Azi. ND E(+)ryV(-) (161°) Comments POOL Min Distenca POOL Min Distance (1443.44 fl) in POOL (1443.44 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304.26 MD) to CD4-206 (6100 - to CD4-208wp07 Plen 1443.44 ~ i - 7004.07 82 154.12 8150.047 5955372 377927.4 1984.124 6254 NDsa) 7250 82.13 331.95 6101.048 5958754 377514.9 541.9988 (6100 -8254 TVDss) Closest Approach: Reference Weii: CD4-209wp07 Pla Offset Well: Nanuk Coords.- Coords.- 3-D ctr- ASP ASP ctr Mln. -.. ,, Meas. Subsea N(+)/5(-) View VS Meas. Subsea N(+)/S(-) View VS Dlst. Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (181°) Comments Depth Incl, Angle TRUE Azi. TVD E(+)/W(-) (161°) Comments POOL Min Distance POOL Min Distance (2948.14 fl) in POOL (2948.14 ft) in POOL (7004 - 13304.26 MD) (7004 - 13304.26 MD) to Nanuk 1 (6100 - to CD4-209wp07 Plan 2948.14 P I '~.._ ~ 7004.07 82 154.12 6150.047 5955372 377927.4 1984.124 6254 TVDss) 6175 0.49 13.32 8135.817 5958136 378951.1 -335.581 (6100 - 6254 TVDss) Closest Approach: Reference Well: CD4-209wp07 Pla Offset Well: Nanuk Coorda. - Coords. - 7-D etr- ASP ASP drMin. Meas. Subsea N(+)/S(-) View VS Mees. Subsea N(+yS(-) View VS Dfst. Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (161°) Comments Depth Incl. Angle TRUE AZI. TVD E(+)M/(-) (161°) Comments POOL Min Dislence POOL Min Distance (3774,31 fl) in POOL (3774.31 ft) in POOL (7004 - 13304.28 MD) (7004 -13304.26 MD) to Nanuk 2 (6100 • to CD4209wp07 Plan 3774.31 7004.07 82 154,12 8150.047 5955372 377927.4 1984.124 6254 TVDsa) 7025 1.87 273.23 8114.287 5954429 374272.9 1783.854 (8100-6254 TVDss) ~~ u CD4209wp07 PoolSummery.xl5 5/9/20017 5:06 PM • • Review of Permit to Drill Application 206-065 ConocoPhillips Alaska, Inc. Well CD4-209 In the cover letter for this application CPAI indicated that this injection well would be flowed back for 5 to 15 days after completion to mitigate reservoir damage. This duration seemed excessive, so I called Mr. Vern Johnson to discuss this flow back. He informed me that the purpose of the flow back is just to remove the filter cake from the formation and the typically this requires a volume of approximately 2 wellbores to complete. I informed him that flow back for the purpose of removing the filter cake was acceptable, but that if they intended to do any additional production testing beyond the volume required to clean up the well they would need additional authorization from the Com ~ ion. D.S. Roby May 17, 2006 • • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO1530 1146 700 G ST. ANCHORAGE AK 99501 / /j,L//J'~ ~"-t'C~J DATE C ~ ` PAY TO THE / 56-1551/441 ORDER OF ~~ ~ ~ f"` A~S~ ~~ C,~ ' I ry5 ~ ~`"~' JPMorganChase ~j L~aR 8 a,.~ JPMorgan Chase Bank, N.A. Valid Up To 5000 Dollars Columbus, OH 'f -MEMO T'07,~ ~:044L15511~:52874?190?927u~ _ i i46 • • TRANSMITT/A~L LETTER CH/E/CKLIST WELL NAME (.~ ~~ ~ `~ Z~ PTD# Z d ~ - ~~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Compan NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\jody\transmittal_checklist W L PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUO OIL -120175 Well Name: COLVILLE RIV UN NANUQ CD4-209 Program SER _____ Well bore seg ^ PTD#:2060650 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER ! PEND GeoArea 890 Unit 50360 On/Off Shore On _ Annular Disposal ^ Administration 1 Permit-fee attached- - - - - _ - _ . _ _ _ Yes _ . _ - -- - 2 Lease number appropriate- ------------------------- Yes _ - _ - --- -Surface location & topprod interval in ADL 380077, prod interval in ADL 384209_ &ADL 384211; 3 Uniquewell_nameandnumber----------------------------- ---------Yes_.._. -prod interval&TDin ADL 388903,__-__-___-----__--_---_-------._--_ ----------- 4 Well located in a_defnedpool_ Yes _ _ - _ _ _ Colville-River Field~Colville River Unit, Nanuq Oil Pool~governed_by_Conse_rvation_Order tJo, 562. 5 Well located proper distance-from drilling unitboundary_ - - - - - . - Yes _ - - . _ - -Conservation Order No. 562 contains no spacing restrictions with respe~ to drilling unit boundaries. _ - _ _ - - - 6 Well located proper distancefrom other wells_ _ - _ _ Yes Conservation Order No. 562 has no interwell_spacing-restr-ictions, _ _ - - - - . - - - 7 Sufficient acreage available in_drillingunit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - _ .Conservation Order No. 562 has no intenyell_spacing_restrictions, Wellbo[e will be more than 500' from _ - - _ - . 8 If deviated, is-wellbore plat-included - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - - -Yes - - - - - - -external property line_wh_ere_ ownership or fandownership_changes._ _ ------------------- 9 Oper_atoronlyaffectedparty------------------------------- ---------Yes------ ----------------- - - 10 Operator has appropriate.bondinforce ----------- -- --- ---- ----- -- Yes ----- ------ - --- --- ------------- -- --------- -- -- ----- ---- -.. 11 Permit_can be issued without co_nseruafion order. _ Yes --------- ------- Appr Date 12 Pe[miteanbeissuedwithoutadministrative_appr_oyal____------ --- - ---Yes-___-_ _--_------_--------.----_------__-__--__--__-__ ---------------------- SFD 511512006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_Injection Order # (put_1O# in_comments)_ (For. Yes - . - . - . - Coh[ille.River Field,Colville River Unit, Nanuq Oil Pool, governed_by Area_ Injection Order 28_ 15 All wells_within 114.mile area.of review identified (FO[serviee well only) . . . . . . . . . . . ... .Yes - - _ . _ . -Nanuq 5~Suspended well).. _ - - _ - - - _ - - 16 Pre-produced injector; duration of pre production Less than. 3 months_(For_seruice well only) _ .Yes - - _ _ - - -Well will be flowed back for 5 -15 days for clean-up. ---------------------- ACMP_Finding of Consistency_has been issued. for this project- NA_ ACMP determination_no_longer-affects AOGCC approval of permjt to drill.- - - - - - Engineering 18 Conductor string-provided________________________-______ __--__--_Yes___ _____-_____-.-- .--_--------. 19 Surface casing-protectsallknown USDWs__________ _________ ______ __ NA______- -Npaqujfers,_prA1O18AConclusion3.-__--_---_--__________ 20 CMTv_ol_adequate-toci[culate-onconductor&surf_csg_______________ _________Yes_--_-_ ______--__--__--__ - -- 21 CMT.vol-adequate-to tie-in long string to surf csg_ _ _ _ _ _ - _ No- - - . _ - - -All hydrocarbon zones to be covered. _ _ - - - 22 CMTwillcoyer_allknow_n_productivehorizon_s__________ __________ _________ No_______ _Slottedlinercompletionplanned._-----_--__-------------_------_-----_ 23 Casing designsadegcateforC,T,B&_permafrost------------------ --- - Yes------ ---.-- --------------------------- 24 Adequate tankage_or reserve pit Yes ----------------- --- -- Rig is_equipped with steel_pits. -No. reserve_pitplanned, All waste to approved annulus or disposal wel_Is. 25 If_are-drill, has_a_ 10-403 for abandonment been approved - - - . - _ , - _ - - _ _ - _ _ - - - - NA_ - -- -- - -- 26 Adequate wellbore separatjonproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ - _ _ _ -Proximity analysis performed: Traveling cylinder path calculated, Gyros planned.. - - _ - - _ - - _ - - - , - - - - - . 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ l)iyerter waiver requested. No shallow gasproblems-reported in any well at Nanu_ .- 20AAC-25,035 h 2_ - q (1 Appr Date 28 Drilling fluid. program schematic_& equip list adequate- - - - - - - - - - - - - - - - Yes Maximum expected formation pressure 8,7-EMW._ MW Planned up to 9,8-ppg in-8-314"-hole and 8.8 ppg in Nanuk, TEM 5122!2006 29 BO_PES,_dotheymeeiregulation---------------------------- ---------Yes__--_- ----_--__--__--__--__ _ _ _ "` ~ ~ ry~~ ` 30 BOPS- ress ratio a ro riate; test to_ _ut si m comments P- 9 -Pp- A (P P 9 ~ ) Yes MASP calculated at 2168 si, 3500. si a [o riate. CPAI usual! ies_ts to 5000_ _si. P p PPP Y P ~ - ~r 31 Choke-manifoldcomRliesw/APtRP-53GMay84)___________________ _________Yes__--__ ----.- 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - - - - - _ After flowback, well will be SI until ad start u later in 2006. p- P - - 33 Is presence ofH2Sgasprpbable---------------------------- --------- No---_-- _H2Shasnot_beenreportedinanyofthewellsatCD4.___-______-__--_-._--------------_- 34 Mechanical condition of wells within AOR verified (For_service well only) _ - Yes _ _ _ - - - - 7" cement jo_b on Nanuq_5 appears adequate. Geology 35 Permit_ean be issued wlo- hydrogen_sulfide measures _ _ . _ _ - - Yes - - - - - - t12S not encountered in offset wellss._ However, rig will be equipped with_operational_sensors.. - - . - 36 Data.presented on_ potential overpressure zones. Yes Expected rese_rvoirp_ressure is 8,7_ppg EMW; will be drilled with 8.8 ppg oil-based mud. Appr Date 37 Seismic analysis of shallow gas-zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - Multiple wells d[ill_ed from this pad.. Hydrates or shallow gas are_unlikely; mitigation measures discussed, - - . SFD 5115!2006 38 Seabed condjtion survey-(if off-shore) - - - _ _ NA -- - - -- 39 Contact name/phone for weekly_progress reports [exploratory only[ - - NA_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ~~~~~-~~ J~n~ ~ ~/a~ .~ ~, r~ • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. a~~ -06 S~'0~i3q~-~.. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 29 15:32:01 2006 Reel Header Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Nanuq MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 W-0004406583 M. HANIK D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 8.750 2ND STRING 6.125 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services CD4-209 501032053200 ConocoPhillips Alaska, Inc. Sperry Drilling Services 29-JUN-06 MWD RUN 3 MWD RUN 5 W-0004406583 W-0004406583 M. HANIK R. KRELL D. MICKEY D. MICKEY 24 11N 4E 2357 226 56.40 19.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 2390.0 7.000 6995.0 REMARKS: ~ • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY-STEERABLE BHA (GP) AND PRESSURE WHILE DRILLING (PWD) BIMODAL ACOUSTIC SONIC TOOL (BAT) WAS ALSO INCLUDED ON MWD RUN 5. THESE DATA ARE PRESENTED ELSEWHERE. NO PROGRESS WAS MADE ON MWD RUN 4. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-3,5 REPRESENT WELL CD4-209 WITH API#: 50-103-20532-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13215'MD/6195'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2367.0 13157.5 FET 2375.0 13164.5 . • RPD 2375 13164.5 RPS 2375.0 13164.5 RPM 2375.0 13164.5 RPX 2375.0 13164.5 ROP 2400.5 13215.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2367.0 2920.0 2920.0 7005.0 7005.0 13215.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2367 13215 7791 21697 2367 13215 RPD MWD OHMM 0.51 2000 19.2372 21580 2375 13164.5 RPM MWD OHMM 0.62 2000 16.2279 21580 2375 13164.5 RPS MWD OHMM 0.65 2000 14.2622 21580 2375 13164.5 RPX MWD OHMM 0.45 1105.5 14.6711 21580 2375 13164.5 FET MWD HOUR 0.17 75.88 1.16017 21580 2375 13164.5 GR MWD API 45.99 175.45 95.3056 21582 2367 13157.5 ROP MWD FT/H 0.89 311.78 129.662 21630 2400.5 13215 First Reading For Entire File..........2367 Last Reading For Entire File...........13215 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record.~535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2367.0 2886.0 FET 2375.0 2878.5 RPX 2375.0 2878.5 RPS 2375.0 2878.5 RPM 2375.0 2878.5 RPD 2375.0 2878.5 ROP 2400.5 2920.0 LOG HEADER DATA DATE LOGGED: 29-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2920.0 TOP LOG INTERVAL (FT) 2400.0 BOTTOM LOG INTERVAL (FT) 2920.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 10.9 MAXIMUM ANGLE: 12.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2390.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S): 36.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 9.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ~ ~ MUD AT MEASURED T RA TURE (MT): .280 0 MUD AT MAX CIRCULATING TERMPERATURE: .220 91.4 MUD FILTRATE AT MT: .400 72.0 MUD CAKE AT MT: 1.200 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2367 2920 2643.5 1107 2367 2920 RPD MWD020 OHMM 0.51 2000 65.6518 1008 2375 2878.5 RPM MWD020 OHMM 0.62 1045.52 7.37422 1008 2375 2878.5 RPS MWD020 OHMM 0.65 2000 8.99133 1008 2375 2878.5 RPX MWD020 OHMM 0.45 1105.5 5.28267 1008 2375 2878.5 FET MWD020 HOUR 0.19 67.56 3.91538 1008 2375 2878.5 GR MWD020 API 60.25 171.48 120.331 1039 2367 2886 ROP MWD020 FT/H 11.76 248.44 192.603 1040 2400.5 2920 First Reading For Entire File..........2367 Last Reading For Entire File...........2920 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF • File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH FET 2879.0 RPS 2879.0 RPX 2879.0 RPM 2879.0 RPD 2879.0 GR 2886.5 ROP 2920.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 31-MAY-06 Insite 66.37 Memory 7005.0 2920.0 7005.0 11.7 80.5 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 6960.0 6960.0 6960.0 6960.0 6960.0 6967.5 7005.0 8.750 2390.0 Fresh Water Gel 9.60 38.0 9.2 3100 7.2 .280 74.0 .180 122.0 .400 74.0 1.200 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: • HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2879 7005 4942 8253 2879 7005 RPD MWD030 OHMM 1.07 39.09 6.69724 8163 2879 6960 RPM MWD030 OHMM 0.94 36.71 6.1789 8163 2879 6960 RPS MWD030 OHMM 0.96 36.03 6.12286 8163 2879 6960 RPX MWD030 OHMM 0.97 35.02 6.03739 8163 2879 6960 FET MWD030 HOUR 0.17 13.27 0.522731 8163 2879 6960 GR MWD030 API 55.36 175.45 107.956 8163 2886.5 6967.5 ROP MWD030 FT/H 6.83 311.78 172.476 8170 2920.5 7005 First Reading For Entire File..........2879 Last Reading For Entire File...........7005 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type .............. Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 6960.5 13164.5 RPX 6960.5 13164.5 RPD 6960.5 13164.5 FET 6960.5 13164.5 RPS 6960.5 13164.5 GR 6968.0 13157.5 ROP 7005.5 13215.0 LOG HEADER DATA DATE LOGGED: 08-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13215.0 TOP LOG INTERVAL (FT) 7005.0 BOTTOM LOG INTERVAL (FT) 13215.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.1 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT) 6995.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 58.0 MUD PH: .0 MUD CHLORIDES (PPM): 100500 FLUID LOSS (C3) 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 158.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6960.5 13215 10087.8 12510 6960.5 13215 RPD MWDOSO OHMM 0.65 2000 23.716 12409 6960.5 13164.5 RPM MWD050 OHMM 1.41 2000 23.5577 12409 6960.5 13164.5 RPS MWD050 OHMM 2.64 1141.41 20.0446 12409 6960.5 13164.5 RPX MWD050 OHMM 1.7 767.62 21.1133 12409 6960.5 13164.5 FET MWD050 HOUR 0.37 75.88 1.35569 12409 6960.5 13164.5 GR MWD050 API 45.99 141.46 84.8642 12380 6968 13157.5 ROP MWD050 FT/H 0.89 196.28 96.2286 12420 7005.5 13215 First Reading For Entire File..........6960.5 Last Reading For Entire File...........13215 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ..............KNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF. Physical EOF End Of LIS File
