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205-187
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:Lau, Jack J (OGC) To:Freeborn, Dusty Cc:Pogany, Mandy W; Livingston, Erica J Subject:Re: 2T-208 (PTD 205-187) Packerless ESP production flow period to reduce SBHP pre-RWO Date:Friday, September 26, 2025 4:55:28 PM Attachments:image001.png Dusty - Your plan detailed below to reduce BHP by flowing for 21 days is approved. Jack From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Friday, September 26, 2025 4:00 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Pogany, Mandy W <Mandy.W.Pogany@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: 2T-208 (PTD 205-187) Packerless ESP production flow period to reduce SBHP pre- RWO Jack- As per our discussion, Kuparuk Tabasco ESP producer 2T-208 (PTD 205-187) has a failed ESP pump/motor. The ESP pump was removed for an upcoming RWO and a SBHP was harvested at ~1597 psi. The RWO is slated to be executed in mid-October, so CPAI intends to bring the well online without the ESP pump installed and produce the well naturally for up to 21 days to reduce the bottom hole pressure for the upcoming RWO. Off set injection in the two supporting injectors has been minimized to reduce SBHP as well. DHD recently monitored the well and found TIO pressures at 563/583/4 with an IA FL at surface. The well passed an MIT-OA to 1800 psi on 12 September 2025 proving integrity of the surface casing (attached 10-426). Due to the packer-less completion style, the production casing integrity is assumed based on TIO trends and IA pressure stabilization (attached 90-day TIO plot). CPAI intends to monitor the well daily and will respond to any abnormal pressure observances as needed for the duration of the flow period. If at any point in time, the well indicates any mechanical failure, the well will be shut in and diagnosed to investigate the issue. Please feel free to give me a call with any questions or concerns. Appreciate your time to discuss today. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 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: Replace Tubing/ESP 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Tabasco Oil Pool N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7654' 3144'1344 None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 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 KRU 2T-208 5043-5126' 5379-5420' 5423-6419' 6466-6508' 6511-7507' 7509-7551' 6018' 4-1/2" 3044-3062' 3109-3115' 3115-3134' 3134-3134' 3134-3140' 3140-3140' 10/10/2025 7620'1901' 4-1/2" 3142' Baker SC-1R 1579' 5426' Perforation Depth MD (ft): 3116'7-5/8" 16" 10-3/4" 77'109' 1579' 109' 1689' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025569, ADL0025548 205-187 P.O. Box 100360, Anchorage, AK 99510 50-103-20518-00-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 4944'MD/3016'TVD Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 4647' 2861'4509'36', 1289', 1429' Kuparuk River Field Adam Klem adam.klem@conocophillips.com TVD BurstMD m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:41 pm, Sep 09, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.09.09 12:19:06-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-549 10-404 A.Dewhurst 24SEP25 X AOGCC witnessed BOP and Annular test to 2500 psi. JJL 9/23/25 DSR-9/10/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.24 15:36:51 -08'00'09/24/25 RBDMS JSB 092625 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 9, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2T-208 (PTD# 205-187). 2T-208 is a producer drilled in 2005 completed with 4.5" tubing and 7 5/8" casing. It currently is completed with an ESP that has failed. A rotary workover is required to pull the tubing and ESP and replace the ESP. If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.09.09 12:19:27-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 2T-208 RWO Procedure Tabasco Producer PTD #205-187 Page 1 of 2 Remaining Pre-Rig Work 1. MITOA, IC POT & PPPOT, TBG POT &PPPOT 2. Prep well for rig. Rig Work MIRU 1. MIRU Nabors 7ES on 2T-208. Pull BPV 2. Circulate in filtered seawater. a. KWF weight will be determined based on observed pressures once on well. 3. Shut the well in and perform no flow test for 30 min to verify KW. 4. Set BPV, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4.5” Completion 5. Pull BPV, MU landing joint and BOLDS. 6. Pull 4-1/2” tubing laying down tubing and ESP Cleanout and Test packer Run 7. Make up cleanout BHA. Run cleanout BHA down to below planned packer set depth (~4450’ MD) 8. Make up test packer or plug and RIH to just below planned packer set depth. 9. Set test packer or plug at ~4500’ MD. Test casing from packer/plug to surface to 1500psi 10. POOH LD DP Install 4-½” Tubing Completion 11. MU 4 ½” completion with ESP, packer, nipple, and GLMs. RIH to planned setting depth 12. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 13. Pressure test tubing to 2,500 psig for 5 minutes. 14. Pressure test inner annulus to 1,500 psig for 30 minutes on chart. ND BOP, NU Tree 15. Confirm pressure tests, then shear out SOV with pressure differential. 16. Install BPV. 17. ND BOPE. NU tree. PT tree. 18. Pull BPV, freeze protect well, and set BPV if necessary. 19. RDMO. Post-Rig Work 20. Pull BPV 21. Install DV 22. Pull B&R, RHC plug General Well info: Wellhead type/pressure rating: FMC Tabasco Gen 2, 5M psi top flange Production Engineer: Natalie Dye Estimated Start Date: 10/10/25 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently shut in. 2T-208 RWO Procedure Tabasco Producer PTD #205-187 Page 2 of 2 Well Type: Producer Scope of Work: Pull the existing 4.5”completion and replace the ESP BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross/ Pipe Ram / Mud Cross MIT results: x MIT-OA: planned pre rig x IC POT & PPPOT: planned pre rig x TBG POT &PPPOT: planned pre rig MPSP: 1344 psi using 0.1 psi/ft gradient Static BHP: 1634 psi / 2895’ TVD measured on 8/26/25 Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:4,509.0 2T-208 12/27/2008 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced SOV 2T-208 1/16/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.012/28/2008 ninam General Notes: Last 3 entries Com Date Last Mod By IA & TBG freeze protected, shut in and secured.11/25/2022 nskrwocm 11/12/22 - pulled sheared SOV in mandrel @4425'. left open. 11/15/22 - reservoir pressure of 1384 psi logged at 4602' = 9.1 kwf. second SBHP to be gathered on 11/19/22 to verify for rig. Offset injection currently SI BPV installed in wellhead 11/18/2022 nberrym 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 31.0108.0108.062.50 H-40 WELDED SURFACE 10 3/49.9531.31,689.4 1,579.3 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.4 5,425.7 3,115.7 29.70 L-80 BTCM LINER w/Screens 4 1/2 3.96 4,943.8 7,620.0 3,142.2 12.60 L-80 13 CR Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.1 Set Depth … 4,647.2 Set Depth… 2,912.6 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 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) 24.124.10.00 Hanger 10.750 FMC 11" x 4.5" ESP Hanger 2/5" RH Acme Lift Threads Vault Gen 23.900 2,106.11,853.8 53.34 Mandrel – GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-10 Camco KBMG3.865 4,413.4 2,826.5 68.66 Mandrel – GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-06 Camco KBMG3.833 4,481.4 2,851.268.61 Nipple - DB 5.190 3.812" DB nipple SN: 3654-14 Camco DB Nipple 3.813 4,499.9 2,858.0 68.52 Sensor - Discharge Gauge 5.620 4.5" Vigilant Discharge Pressure Tubing Sub Summit Vigilant 3.958 4,602.2 2,895.8 68.18 Annular Connection Port (ACP) 5.380 Receiving base and Adapter/TCC Perforated Intake, SN:45TTC203420 Summit TCC 3.958 4,613.0 2,899.8 68.17 Seal - Protector 5.130 Upper 513 Series Tandem Seal Section, SN:13356463 Summit 513 Series 4,630.9 2,906.5 68.13 Motor 5.620 562, KMS2, 180HP/2290V/48A Motor, SN:13817621 Summit Gauge 4,644.4 2,911.5 68.11 Motor - Adapter Adapter from gauge to 562 Motor, SN:5SDHV091 Summit 562, 180 HP 4,644.7 2,911.6 68.11 Sensor - Discharge Gauge Vigilant, Sensor, High Temp, 150C w/Discharge Pressure 5000 Psi, SS Summit Vigilant 4,646.6 2,912.3 68.11 Centralizer 6.000 Centralizer/Anode Summit 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) 4,583.02,888.7 68.22 SLIP STOP Set slip stop on packoff.12/5/2022 0.000 4,585.02,889.4 68.22 PACKOFF Set D&D packoff on ESP (OAL 58") 12/5/2022 0.000 4,590.02,891.368.21 ESP Set TTC-ESP (40.95')12/5/2022 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) 2,106.1 1,853.8 53.34 1 DMY BK-5 1 11/24/2022 Schlumb erger BK 4,413.4 2,826.5 68.66 2 ESP SOVBK 1 1/16/2023 2000# STS Schlumb erger BK 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) 4,943.83,016.4 70.93 PACKER 6.690 LINER TOP PACKER SC-1R4.000 4,948.03,017.7 71.20 MILLOUT EXT 4.500 MILLOUT EXTENSION 3.958 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 2T-208, 1/17/2023 8:41:02 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,646.5 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Tubing - XO; 4,506.8 Sensor - Discharge Gauge; 4,499.9 Tubing - XO; 4,492.7 Mandrel – GAS LIFT; 4,413.4 Annular Fluid - CI Brine; 2,000.0 -4,647.0; 11/25/2022 Mandrel – GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD KB-Grd (ft) 35.60 RR Date 1/21/2006 Other Elev… 2T-208 ... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE Annotation Last WO: End Date 11/25/2022 H2S (ppm) 20 Date 12/6/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.0 3,140.2 3,140.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 2T-208, 1/17/2023 8:41:05 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,646.5 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Tubing - XO; 4,506.8 Sensor - Discharge Gauge; 4,499.9 Tubing - XO; 4,492.7 Mandrel – GAS LIFT; 4,413.4 Annular Fluid - CI Brine; 2,000.0 -4,647.0; 11/25/2022 Mandrel – GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD 2T-208 ... WELLNAME WELLBORE 2T-208 Proposed RWO Completion PROPOSED COMPLETION 4-1/2" 12.6# L-80 Hyd563 Tubing to surface 4-1/2" GLMs @ TBD HES Tbg/IA sensing DHG Viking Feedthrough packer Summit Pump and Motor Motor Centralizer REMAINING COMPLETION LEFT IN HOLE Packer and Perfs with Screens from 4943' RKB to 7620' RKB (3.25" ID) Surface Casing Production Liner w/ slots Conductor Perfs for Tabasco ESP Production Casing DHG @ ~4450’ MD - JJL 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,654'N/A Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5,043' - 7,551' 5,398' 4 1/2" 3,044' - 3,140' 7/26/2025 7,620'2,676' 4 1/2" 3,142' SSSV: None 7 5/8" 16" 10 3/4" 77' 1,658' 5,426' 108' 1,579' 108' 1,689' 3,116' Length Size Proposed Pools: L-80 TVD Burst 4,647' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 / ADL0025569 205-187 P.O. Box 100630, Anchorage, Ak. 99510 50-103-20518-00-00 ConocoPhillips Alaska, Inc. AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: Conductor Ext KUPARUK RIV U TABS 2T-208 KUPARUK RIVER N/ATABASCO OIL 3,144'N/A SSSV: None Packer: 4,944' MD / 3,016' TVD Well Integrity Field Supervisor Brennen Green / Roger Mouser N1927@conocophillips.com 907-659-7506 Packer: LINER TOP PACKER SC-1R m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-388 By Gavin Gluyas at 8:21 am, Jun 27, 2025 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.26 16:01:49-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green DSR-6/30/25JJL 6/30/25 10-404 A.Dewhurst 17JUL25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.17 14:25:36 -08'00' 07/17/25 RBDMS JSB 071825 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 6/26/2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 application for Sundry Approval from ConocoPhillips Alaska, Inc. for well KRU 2T-208 (PTD 205-187) to extend the conductor. Summary: Conductor has subsided or well has grown ~7” or more. With AOGCC approval we would like to add conductor material to cover the surface casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.26 16:01:12-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Kuparuk Well 2T-208 (PTD 205-187) SUNDRY NOTICE 10-403 APPROVAL REQUEST 6/26/2025 This application for Sundry approval for Kuparuk Well 2T-208 is to extend the conductor to original height to stabilize tree and prevent corrosion to the surface casing. At some point during normal operations the conductor subsided or the well has grown ~7”. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair with photo documentation. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:4,509.0 2T-208 12/27/2008 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced SOV 2T-208 1/16/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.012/28/2008 ninam General Notes: Last 3 entries Com Date Last Mod By IA & TBG freeze protected, shut in and secured.11/25/2022 nskrwocm 11/12/22 - pulled sheared SOV in mandrel @4425'. left open. 11/15/22 - reservoir pressure of 1384 psi logged at 4602' = 9.1 kwf. second SBHP to be gathered on 11/19/22 to verify for rig. Offset injection currently SI BPV installed in wellhead 11/18/2022 nberrym Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.2531.0 108.0 108.062.50 H-40 WELDED SURFACE 10 3/4 9.95 31.3 1,689.4 1,579.3 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.4 5,425.7 3,115.7 29.70 L-80 BTCM LINER w/Screens 4 1/2 3.96 4,943.8 7,620.0 3,142.2 12.60 L-80 13 CR Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.1 Set Depth… 4,647.2 Set Depth… 2,912.6 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 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) 24.1 24.1 0.00 Hanger 10.750 FMC 11" x 4.5" ESP Hanger 2/5" RH Acme Lift Threads Vault Gen 2 3.900 2,106.1 1,853.8 53.34 Mandrel – GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-10 Camco KBMG3.865 4,413.4 2,826.5 68.66 Mandrel – GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-06 Camco KBMG3.833 4,481.4 2,851.2 68.61 Nipple - DB 5.190 3.812" DB nipple SN: 3654-14 Camco DB Nipple 3.813 4,499.9 2,858.0 68.52 Sensor - Discharge Gauge 5.620 4.5" Vigilant Discharge Pressure Tubing Sub Summit Vigilant 3.958 4,602.2 2,895.8 68.18 Annular Connection Port (ACP) 5.380 Receiving base and Adapter/TCC Perforated Intake, SN:45TTC203420 Summit TCC 3.958 4,613.0 2,899.8 68.17 Seal - Protector 5.130 Upper 513 Series Tandem Seal Section, SN:13356463 Summit 513 Series 4,630.9 2,906.5 68.13 Motor 5.620 562, KMS2, 180HP/2290V/48A Motor, SN:13817621 Summit Gauge 4,644.4 2,911.5 68.11 Motor - Adapter Adapter from gauge to 562 Motor, SN:5SDHV091 Summit 562, 180 HP 4,644.7 2,911.6 68.11 Sensor - Discharge Gauge Vigilant, Sensor, High Temp, 150C w/Discharge Pressure 5000 Psi, SS Summit Vigilant 4,646.6 2,912.3 68.11 Centralizer 6.000 Centralizer/Anode Summit 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) 4,583.0 2,888.7 68.22 SLIP STOP Set slip stop on packoff. 12/5/2022 0.000 4,585.0 2,889.4 68.22 PACKOFF Set D&D packoff on ESP (OAL 58") 12/5/2022 0.000 4,590.0 2,891.3 68.21 ESP Set TTC-ESP (40.95') 12/5/2022 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) 2,106.1 1,853.8 53.34 1 DMY BK-5 111/24/2022 Schlumb erger BK 4,413.4 2,826.5 68.66 2 ESP SOVBK 1 1/16/2023 2000# STS Schlumb erger BK 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) 4,943.8 3,016.4 70.93 PACKER 6.690 LINER TOP PACKER SC-1R 4.000 4,948.03,017.7 71.20 MILLOUT EXT 4.500 MILLOUT EXTENSION 3.958 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 2T-208, 1/17/2023 8:41:02 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,646.5 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Tubing - XO; 4,506.8 Sensor - Discharge Gauge; 4,499.9 Tubing - XO; 4,492.7 Mandrel – GAS LIFT; 4,413.4 Annular Fluid - CI Brine; 2,000.0 -4,647.0; 11/25/2022 Mandrel – GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD KB-Grd (ft) 35.60 RR Date 1/21/2006 Other Elev… 2T-208 ... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE Annotation Last WO: End Date 11/25/2022 H2S (ppm) 20 Date 12/6/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.03,140.23,140.0 TABASCO, 2T- 208 1/16/2006 99.0SLOTS Alternating screens/solid pipe 2T-208, 1/17/2023 8:41:05 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,646.5 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Tubing - XO; 4,506.8 Sensor - Discharge Gauge; 4,499.9 Tubing - XO; 4,492.7 Mandrel – GAS LIFT; 4,413.4 Annular Fluid - CI Brine; 2,000.0 -4,647.0; 11/25/2022 Mandrel – GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 Annular Fluid - Diesel; 0.0- 2,000.0; 11/25/2022 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD 2T-208 ... WELLNAME WELLBORE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing/ ESP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7654'feet None feet true vertical 3144'feet None feet Effective Depth measured 7654'feet 4944' feet true vertical 3144'feet 3016'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4647' MD 2913' TVD Packers and SSSV (type, measured and true vertical depth) 4944' MD N/A 3016' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 1689' 1579' Burst Collapse Production Liner 5397' 2676' Casing 3116' 4-1/2" 5426' 7620' 3142' 1658' 108'Conductor Surface Intermediate 16" 10-3/4" 77' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-187 50-103-20518-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025548, ADL0025569 Kuparuk River Field/ Tabasco Oil Pool KRU 2T-208 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 500 Gas-Mcf MD 1200 Size 108' 2900 70050 120 245700 260 322-626 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 10 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Liner Top Packer SC-1R SSSV: None Adam Klem adam.klem@conocophillips.com (907) 263-4529Senior RWO/CTD Engineer Screens alt. solid pipe: 5043-5126', 5379-5420', 5423-6419', 64666-6508', 6511-7507', 7509-7551' feet Screens alt. solid pipe: 3044-3062', 3108-3115', 3115-3134', 3134-3134', 3134-3140', 3140-3140' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 9:20 am, Dec 21, 2022 Page 1/4 2T-208 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2022 16:00 11/20/2022 19:30 3.50 MIRU, MOVE MOB P Pull pits away from sub. Load shop and office. 11/20/2022 19:30 11/20/2022 22:00 2.50 MIRU, MOVE MOB P Move pits, Taylor camp and shop to 2T pad. spot truck shop and Taylor camp. Build rig mat layout around wellhead for Sub base spread pit liner and stage wellhead equipment behind 2T-208. Stage DSA's for BOP stack. Lower derrick on sub-base. Clean up 1G-13 location. Notified AOGCC intent to test BOP at 9PM on 11/21/22. Notice sent at 6:30PM 11/20/22. 11/20/2022 22:00 11/21/2022 00:00 2.00 MIRU, MOVE MOB P Transport sub T/ 2T. 11/21/2022 00:00 11/21/2022 05:00 5.00 MIRU, MOVE MOB P Transport sub T/ CPF 2 11/21/2022 05:00 11/21/2022 07:00 2.00 MIRU, MOVE MOB P Field change out. 11/21/2022 07:00 11/21/2022 12:00 5.00 MIRU, MOVE MOB P Transport sub T/ 2T. 11/21/2022 12:00 11/21/2022 16:00 4.00 MIRU, MOVE MOB P Spot sub over well, lay mats and herculite. Spot pits to sub, lay mats and herculite. 11/21/2022 16:00 11/21/2022 18:30 2.50 MIRU, MOVE MOB P Berm in rig. Hook up inter connect. Turn steam and air on to pits. Spot cuttings tank. R/U tiger tank line. Spot filter pod. 11/21/2022 18:30 11/22/2022 00:00 5.50 MIRU, MOVE MOB P Raise derrick. Bridal down. Rig accept at midnight. 11/22/2022 00:00 11/22/2022 03:30 3.50 MIRU, MOVE RURD P Bring lubricator to rig floor. Rig up tiger tank and choke skid. Heat 9.0 brine to 140deg. Rig Accept @ 0:00 Hrs. 0.0 0.0 11/22/2022 03:30 11/22/2022 04:30 1.00 MIRU, MOVE COND P Rig up 9.0 hauler to filter skid. Offload heated 9.0 ppg brine into pits. Rig up lubricator to wellhead. Pull BPV. 0.0 0.0 11/22/2022 04:30 11/22/2022 05:00 0.50 MIRU, MOVE RURD P Rig up lubricator to wellhead. 0.0 11/22/2022 05:00 11/22/2022 05:15 0.25 MIRU, MOVE PRTS P PT lubricator T/ 2500 PSI. 11/22/2022 05:15 11/22/2022 05:45 0.50 MIRU, MOVE MPSP P Pull BPV. 11/22/2022 05:45 11/22/2022 06:15 0.50 MIRU, MOVE RURD P R/D lubricator. 11/22/2022 06:15 11/22/2022 06:30 0.25 MIRU, MOVE RURD P RU to kill well 11/22/2022 06:30 11/22/2022 09:00 2.50 MIRU, WELCTL KLWL P Initial T/IA=400/350. Bleed gas off tubing and IA Circulate at 4BPM=350 PSI down tubing up IA till 9# NaCl recovered in returns 11/22/2022 09:00 11/22/2022 09:30 0.50 MIRU, WELCTL OWFF P OWFF for 30 minutes No flow observed 11/22/2022 09:30 11/22/2022 10:00 0.50 MIRU, WELCTL SVRG P Service rig/blow down circulation manifold 11/22/2022 10:00 11/22/2022 10:30 0.50 MIRU, WELCTL MPSP P Set BPV attempt to pressure test under BPV to 1000 PSI rolling test for 10 minutes. 250 PSI attained 11/22/2022 10:30 11/22/2022 14:30 4.00 MIRU, WHDBOP NUND P ND tree and adapter. Install HP BPV dart. NU DSA and BOP stack. Install choke and kill lines after BWM. Install Flow Riser Rig: NABORS 7ES RIG RELEASE DATE 11/26/2022 Page 2/4 2T-208 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2022 14:30 11/22/2022 15:30 1.00 MIRU, WHDBOP PULD P PU 4.5" Donut Test Joint, mark bag / UPRS. FIll BOP Stack and function all Ram's and HCR. 11/22/2022 15:30 11/22/2022 16:00 0.50 MIRU, WHDBOP SVRG P Rig Service. 11/22/2022 16:00 11/22/2022 17:00 1.00 MIRU, WHDBOP PRTS P Perform Shell Test. Re-Tighten Doors on Double Gate. 11/22/2022 17:00 11/22/2022 22:00 5.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 4 1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV, and IBOP, Test 4 ½ EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1625 PSI, 200 PSI attained =19 sec, full recovery attained = 95 sec. UVBR's= sec, Annular= 26 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1960 PSI. Test gas detectors, PVT and flow show.Test Witness Waived by AOGCC rep Adam Earl. 11/22/2022 22:00 11/22/2022 22:30 0.50 MIRU, WHDBOP RURD P RD Testing Equipment. 11/22/2022 22:30 11/22/2022 23:30 1.00 MIRU, WHDBOP MPSP P Check for Pressure and Pull BPV and fill BOP Stack 11/22/2022 23:30 11/23/2022 00:00 0.50 COMPZN, RPCOMP RURD P PU Landing Joint. 11/23/2022 00:00 11/23/2022 00:30 0.50 COMPZN, RPCOMP PULL P MU Landing Joint to Hanger. BOLDS and Pull Hanger to Rig Floor. 4,606.0 4,550.0 11/23/2022 00:30 11/23/2022 00:45 0.25 COMPZN, RPCOMP PULD P Hang Sheave in Derrick while working on LDS. 4,550.0 4,550.0 11/23/2022 00:45 11/23/2022 04:45 4.00 COMPZN, RPCOMP PULL T All of the Lock down screws were seized up. Unseated Hanger @ 80k, Pull Hanger to the Rig floor and L/D same. 4,550.0 4,550.0 11/23/2022 04:45 11/23/2022 06:15 1.50 COMPZN, RPCOMP CIRC P Circulate BUS 4,550.0 4,550.0 11/23/2022 06:15 11/23/2022 06:45 0.50 COMPZN, RPCOMP OWFF P Observe well for flow. Blow down top drive. Establish loss rate. 8 BBL's/hour 4,550.0 4,550.0 11/23/2022 06:45 11/23/2022 07:15 0.50 COMPZN, RPCOMP PULL P Pull ESP cable over sheave and attach same to ESP spooler. 4,550.0 4,470.0 11/23/2022 07:15 11/23/2022 16:00 8.75 COMPZN, RPCOMP PULL P Start POOH laying down 4.5" ESP completion F/4470' T/0 Recovered 80 cannon clamps, 22 stainless steel bands 4 flat gaurds 3 "Protectolizer" 4,470.0 0.0 11/23/2022 16:00 11/23/2022 16:30 0.50 COMPZN, RPCOMP RURD P Run ESP cable and chem lines over sheave 0.0 0.0 11/23/2022 16:30 11/23/2022 17:00 0.50 COMPZN, RPCOMP SVRG P Service blocks top drive and crown 0.0 0.0 11/23/2022 17:00 11/23/2022 17:30 0.50 COMPZN, RPCOMP CLEN P Clean and Clear Rig Floor. 0.0 0.0 11/23/2022 17:30 11/23/2022 21:30 4.00 COMPZN, RPCOMP PULD P Waiting on Bigger Loader to install ESP Spool in Spooler. Load Summit ESP Equipment in pipe shed. Load Rig Floor w/ Cannon Clamps & 3rd Party Tools. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/26/2022 Page 3/4 2T-208 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2022 21:30 11/24/2022 00:00 2.50 COMPZN, RPCOMP PULD P PU & MU Lower ESP Section. Centralizer, sensor, gauge, motor, Upper & Lower Tandem Seal Section and TCC Perforated Intake. Install ESP Spool into Spooler and feed cable over sheave. 0.0 154.0 11/24/2022 00:00 11/24/2022 02:00 2.00 COMPZN, RPCOMP RCST P Install Cable and secure with Protectorlizer. Install Discharge gauge unit. 154.0 175.0 11/24/2022 02:00 11/24/2022 05:30 3.50 COMPZN, RPCOMP RURD P Make Cable Splice to Lead Cable. 175.0 175.0 11/24/2022 05:30 11/24/2022 13:30 8.00 COMPZN, RPCOMP RCST P Continue to RIH with 4.5" ESP Completion performing electrical test on the ESP power cable every 1000' ft. 175.0 4,590.0 11/24/2022 13:30 11/24/2022 14:30 1.00 COMPZN, RPCOMP THGR P MU tubing hanger with timed collars to orient hanger with Well-head. 4,590.0 4,590.0 11/24/2022 14:30 11/24/2022 15:00 0.50 COMPZN, RPCOMP RURD P RD GBR casing tongs and set up floor to terminate ESP cable and install dummy penetrators 4,614.0 4,614.0 11/24/2022 15:00 11/24/2022 17:00 2.00 COMPZN, RPCOMP THGR P Install penetrators, terminate ESP cable at tubing hanger. 4,614.0 4,614.0 11/24/2022 17:00 11/24/2022 17:45 0.75 COMPZN, RPCOMP PULD P MU Landing Joint and Land 4.5" ESP Completion. Checked ESP Cable & Motor for electrical integrity. Good Test. 4,614.0 4,647.6 11/24/2022 17:45 11/24/2022 18:15 0.50 COMPZN, WHDBOP MPSP P RILDS and Back out Landing Joint. Install 'HP' BPV. 4,647.6 4,647.6 11/24/2022 18:15 11/24/2022 18:30 0.25 COMPZN, WHDBOP PRTS P Perform rolling PT on BPV for 10 mins. 0.0 0.0 11/24/2022 18:30 11/24/2022 20:00 1.50 COMPZN, WHDBOP RURD P RD GBR Pipe Tongs. RD Sheave and spool up excess ESP cable. Clear full of unused cannon clamps. Clean and Clear Rig Floor. 0.0 0.0 11/24/2022 20:00 11/25/2022 00:00 4.00 COMPZN, WHDBOP NUND P ND BOP Stack & DSA. NU Tubing Head and New 4-1/16" Tree. 0.0 0.0 11/25/2022 00:00 11/25/2022 02:00 2.00 COMPZN, WHDBOP PRTS P RU Testing Equipment and PT Packoffs void to 5K for 5 Min's. Pressure test Tree to 250/5000 psi for 15 Min's. Pressure Test on Tree failed after several attempts. 0.0 0.0 11/25/2022 02:00 11/25/2022 16:00 14.00 COMPZN, WHDBOP WWSP T SBMS (Smooth Bore Metal Seal) failed on Tree. ND Tree to C/O Seals. Adapter failed to test SBMS failed second time. Replaced adapter and SBMS. Attemtped to test adpater void test failed. Pulled adapter and tree. Redressed SBMS with new O-ring installed adapter from de-completion. Tested void to 5000 PSI for 15 minutes. Tested tree to 5000 PSI for 10 minutes. good test. 0.0 0.0 11/25/2022 16:00 11/25/2022 16:30 0.50 COMPZN, WHDBOP MPSP P Pull HP dart and BPV. 0.0 0.0 11/25/2022 16:30 11/25/2022 18:30 2.00 COMPZN, WHDBOP CIRC P RU circulating equipment to IA. Bullhead 200 bbls of 9# NaCl corrosion inhibited brine down IA @ 4 BPM, 160 PSI. Swap over to Diesel and Pump 61 bbls down IA to freeze protect at 2 bpm, 450 psi. Swap over to the TBG side and pump 30 bbls of Diesel down TBG @ 2 bpm, 250 psi. 0.0 0.0 11/25/2022 18:30 11/25/2022 19:30 1.00 COMPZN, WHDBOP RURD P RDMO LRS from Location. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/26/2022 Page 4/4 2T-208 Report Printed: 12/20/2022 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2022 19:30 11/26/2022 00:00 4.50 DEMOB, MOVE DMOB P RDMO. Cleanup wellsite. Release Rig at Midnight. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 11/26/2022 DTTMSTART JOBTYP SUMMARYOPS 11/11/2022 SUPPORT OTHER OPERATIONS ATTEMPT TO DRIFT W/ 2.77" GAUGE RING & ENCOUNTER THICK FLUID @ 3300' RKB (UNABLE TO PASS), PUMP DISPLACEMENT OF HOT FLUID & ABLE TO GET DOWN & TAG SLIP STOP @ 4512' RKB; PULLED SLIP STOP, 3.5" D&D PACKOFF, & 43' ESP @ 4531' RKB. IN PROGRESS. 11/12/2022 SUPPORT OTHER OPERATIONS PULLED SHEARED SOV @ 4425' RKB; RETURN IN 2 DAYS FOR BHP. 11/15/2022 SUPPORT OTHER OPERATIONS MEASURED BHP @ 4570' RKB (1384 PSI). JOB COMPLETE. 11/19/2022 SUPPORT OTHER OPERATIONS MEASURED BHP (1324 PSI) @ 4570' RKB. JOB COMPLETE. 11/20/2022 RECOMPLETION Pull pits away from sub. Load shop and office. Transport pits, office and shop to 2T. Set shop and office. Stage pits on pad. Bridal up. Lay derrick over. Pull sub off of 1G-13. Clean up around well. Transport sub to 2T. 11/21/2022 RECOMPLETION Transport sub to 2T. Spot sub over well. Spot pits to sub. Berm in rig. Hook up interconnect and electrical to pits. Turn on steam and air. Spot cuttings tank. Raise derrick. Bridal down. Get measurements for riser height from tubing spool height. Take initial pressures T/IA/OA. Rig up circ manifold in cellar. Complete acceptance checklist. 11/22/2022 RECOMPLETION Rig Accept. Offload 9.0 PPG NaCl into pits. PT circ manifold & tiger tank T/ 3500 PSI. Bleed free gas off TBG/IA. R/U Lubricator. Pressure test lubricator. Pull BPV. Rig down lubricator. Test BOPE as per sundry. Pull dart and BPV. 11/23/2022 RECOMPLETION Make up landing joint. BOLDS. Pull hanger to rig floor. Circulate well. Lay Down Hanger. Hang and Pull ESP line over Sheave. POOH L/D ESP Completion while spooling ESP Cable. Swap ESP Spools and Prep to run new ESP Completion. 11/24/2022 RECOMPLETION Run 4.5" Summit ESP Completion Pre-Tally and Land Same. ND BOPE, NU Tubing head and Tree. 11/25/2022 RECOMPLETION PT Tree and Hanger to 250/5000 psi. C/O Tubing Head x3, Finally got PT on Hanger and Wellhead. Circulate in CI brine and Freeze protect well with Diesel. RDMO. Transport Equipment to 3H-Pad. 12/3/2022 SUPPORT OTHER OPERATIONS MEASURE SBHP @ 4602' RKB (1197 PSI) REPLACED ST#2 DMY @ 4413'RKB W/1''(#2000TBG SHEAR)SOV BK LATCH. IN PROGESS 12/4/2022 SUPPORT OTHER OPERATIONS HOT FLUSH TBG WITH 100 BBLS DSL @ 110*F TO CLEAN OUT ESP MOTOR & DH ASSEMBLY. READY FOR SLICKLINE. 12/5/2022 SUPPORT OTHER OPERATIONS SET 4.5' TTC 'ESP (OAL40.95') @ 4631 'RKB. SET 4.5'' PACK-OFF(OAL58'' )@ 4590' RKB. GOOD PT TO 1000 PSI ON THE TBG. SET 4.5'' SLIP STOP (OAL21'' ) @ 4586' RKB. JOB COMPLETE 2T-208 ESP RWO Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: 4,509.0 2T-208 12/27/2008 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set SOV & ESP equip.2T-208 12/5/2022 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/28/2008 ninam General Notes: Last 3 entries Com Date Last Mod By IA & TBG freeze protected, shut in and secured.11/25/2022 nskrwocm 11/12/22 - pulled sheared SOV in mandrel @4425'. left open. 11/15/22 - reservoir pressure of 1384 psi logged at 4602' = 9.1 kwf. second SBHP to be gathered on 11/19/22 to verify for rig. Offset injection currently SI BPV installed in wellhead 11/18/2022 nberrym 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 31.0 108.0 108.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 31.3 1,689.4 1,579.3 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 28.4 5,425.7 3,115.7 29.70 L-80 BTCM LINER w/Screens 4 1/2 3.96 4,943.8 7,620.0 3,142.2 12.60 L-80 13 CR Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.1 Set Depth 4,647.2 Set Depth 2,912.6 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 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) 24.1 24.1 0.00 Hanger 10.750 FMC 11" x 4.5" ESP Hanger 2/5" RH Acme Lift Threads Vault Gen 2 2.992 2,106.1 1,853.8 53.34 Mandrel GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-10 Camco KBMG 3.865 4,413.4 2,826.5 68.66 Mandrel GAS LIFT 4.500 GLM, Camco, KBMG, 4-/2" x 1" with DV & BK-5 Latch, SN: 23061-06 Camco KBMG 3.833 4,481.4 2,851.2 68.61 Nipple - DB 5.190 3.812" DB nipple SN: 3654-14 Camco DB Nipple 3.813 4,499.9 2,858.0 68.52 Sensor - Discharge Gauge 5.620 4.5" Vigilant Discharge Pressure Tubing Sub Summit Vigilant 3.958 4,602.2 2,895.8 68.18 Annular Connection Port (ACP) 5.380 Receiving base and Adapter/TCC Perforated Intake, SN:45TTC203420 Summit TCC 3.958 4,613.0 2,899.8 68.17 Seal - Protector 5.130 Upper 513 Series Tandem Seal Section, SN:13356463 Summit 513 Series 4,630.9 2,906.5 68.13 Motor 5.620 562, KMS2, 180HP/2290V/48A Motor, SN:13817621 Summit Gauge 4,644.4 2,911.5 68.11 Motor - Adapter Adapter from gauge to 562 Motor, SN:5SDHV091 Summit 562, 180 HP 4,644.7 2,911.6 68.11 Sensor - Discharge Gauge Vigilant, Sensor, High Temp, 150C w/Discharge Pressure 5000 Psi, SS Summit Vigilant 4,646.6 2,912.3 68.11 Centralizer 6.000 Centralizer/Anode Summit 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) 4,583.0 2,888.7 68.22 SLIP STOP Set slip stop on packoff.12/5/2022 0.000 4,585.0 2,889.4 68.22 PACKOFF Set D&D packoff on ESP (OAL 58") 12/5/2022 0.000 4,590.0 2,891.3 68.21 ESP Set TTC-ESP (40.95') 12/5/2022 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) 2,106.1 1,853.8 53.34 1 DMY BK-5 1 11/24/2022 Schlumb erger BK 4,413.4 2,826.5 68.66 2 ESP SOV BK-5 1 0.0 12/3/2022 #2000 TBG shear Schlumb erger BK 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) 4,943.8 3,016.4 70.93 PACKER 6.690 LINER TOP PACKER SC-1R 4.000 4,948.0 3,017.7 71.20 MILLOUT EXT 4.500 MILLOUT EXTENSION 3.958 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 2T-208, 12/20/2022 3:28:29 PM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Nipple - DB; 4,481.4 Mandrel GAS LIFT; 4,413.4 Mandrel GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD KB-Grd (ft) 35.60 RR Date 1/21/2006 Other Elev 2T-208 ... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE Annotation Last WO: End Date 4/27/2009 H2S (ppm) 20 Date 12/6/2016 Comment SSSV: NONE Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.0 3,140.2 3,140.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 2T-208, 12/20/2022 3:28:32 PM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Motor; 4,630.9 Seal - Protector; 4,613.0 ESP; 4,590.0 Annular Connection Port (ACP); 4,602.2 PACKOFF; 4,585.0 SLIP STOP; 4,583.0 Nipple - DB; 4,481.4 Mandrel GAS LIFT; 4,413.4 Mandrel GAS LIFT; 2,106.0 SURFACE; 31.3-1,689.4 CONDUCTOR; 31.0-108.0 Hanger; 24.1 KUP PROD 2T-208 ... WELLNAME WELLBORE 1 Regg, James B (OGC) From:Cozby, Kelly <Kelly.Cozby@nabors.com> Sent:Thursday, November 24, 2022 4:07 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); NSK RWO CM Cc:White, Bradley; Morales, Tony; Yearout, Paul; Hobbs, Greg S; Kneale, Michael L Subject:Nabors 7ES BOP Test 11/22/22 Attachments:Nabors 7ES 11-22-22 .xlsx Thanks, Kelly Cozby Nabors Alaska Drilling Rig 7ES Rig Manager Office 907‐670‐ 6132 Cell 907‐715‐9055 ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. 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KRU 2T-208PTD 2051870 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:11/22/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2051870 Sundry #322-626 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:991 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"NT H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1625 P Check Valve 0 NA 200 psi Attained (sec)19 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)95 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1958 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 26 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 0 NT #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/20/22 05:40PM Waived By Test Start Date/Time:11/22/2022 17:00 (date)(time)Witness Test Finish Date/Time:11/22/2022 22:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Tested with 41/2" Test jnt. Kelly Cozby/Paul Yearout ConocoPhillips Mark Adams/Dale Rowell KRU 2T-208 Test Pressure (psi): kelly,cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1122_BOP_Nabors7ES_KRU_2T-208 J. Regg; 12/27/2022 From:Brooks, James S (OGC) on behalf of AOGCC Reporting (CED sponsored) To:AOGCC Records (CED sponsored) Subject:FW: BOP - Nabors 7ES (11-22-2022) Date:Wednesday, December 28, 2022 9:30:30 AM Attachments:2022-1122_BOP_Nabors7ES_KRU_2T-208.pdf James Brooks research analyst II | alaska oIl and Gas conservatIon commIssIon department of commerce, communIty and economIc development 907-793-1241|James.Brooks@alaska.Gov From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, December 27, 2022 4:20 PM To: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov> Subject: BOP - Nabors 7ES (11-22-2022) KRU 2T-208 (PTD 2051870) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 ! " # $! % " &' ( $ )" " * +$ ', +# - # ./$ 0/ 1 $ $ " # # ! 2 ,2 3 $ 4+ 56 $ 7 8 " + 9+5 7 + :+5 7 ' #+ 9+ ' #+ :+ 9 5 7 59+7 ; <59+7 0.*)=$ " / 6 < : < :9+5 7:+5 7 ( - " !< + > < ', +# # )' + * !< " /6 /$; + 6 .:# + ? ? ? 6@? ?"" #?/$; ! 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"##$ % & '()'(' )) " ( )'*"+,-'( )'* +,-.& ) ) ' ' ' ./ ' )' )''' 0 !' ( ) ! (.(( ! '(' ) (' 1 )) 23 3 +( ) '4( ./ '(' ( ( ) '( ( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5( 7 ! 48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"# $#$%& '( #)*+,*+" "( "' "- +. +/ + ($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,- !& &%&!-#- &- &%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,- !& &%&!(- &- &%&!!."!!*$%%&'&---)%%&%(!)('$&-*,- !& &%&!$!- &- &%&!&/"-!-$%!%-&%&))%%!'*&!'0 &!,# &* &%!'*- &# &%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,) -! &%&%&- &# &%&!& "&%*$%!%-&%$!*%%&%$!*))(,%$!&,- &- &%&!*!- &- &%&!& "-)$%!%-&%&&)%%!'$!%!-%,%&%&(,- &- &%&!')- &- &%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2 #*, - &# &%&! !% - &# &%&! 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well SC Repair ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary:Repaired Total Depth measured 7654'feet NA feet true vertical 3144'feet NA feet Effective Depth measured 4506'feet NA feet true vertical 2861'feet NA feet Perforation depth Measured depth 5043' - 7551' feet True Vertical depth 3043' - 3140' feet Tubing (size, grade, measured and true vertical depth)4.5" x 3.5" L-80 4606' 2897' Packers and SSSV (type, measured and true vertical depth)NA 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 11/24/2020 Contact Phone: 320-272 Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor NA NA NA NA NA NA NA NA NA NA N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Liner Production 5397'7 5/8"5425'3115' Conductor 77'16"108'108' Intermediate NA Surface 1658'10 3/5"1689'1579' Packer measured true vertical Casing Length Size MD TVD N/A Kuparik River Field/Tabasco Oil Pool Plugs measured Junk measured Burst Collapse 205-187 50-103-20518-00-00 ADL0025548/ADL0025569 KRU 2T-208 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: ntt e Fra O g g g l g y e 6. A y G L PG AAC 25 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:52 am, Nov 24, 2020 or of t r Wint Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-11-24 06:07:07 Foxit PhantomPDF Version: 10.0.0 Roger Winter DSR-11/24/2020 RBDMS HEW 11/25/2020 SFD 11/24/2020VTL 2/17/21 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 24th day of November, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for surface casing repair KRU 2T-208 (PTD 205-187). Please contact Roger Mouser or myself at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-11-24 06:05:37 Foxit PhantomPDF Version: 10.0.0 Roger Winter Date Event Summary Executive Summary SC Repair 08/01/20 Cut & remove 16" landing ring and 24" of conductor. 11/10/20 Pump brine in T/I/O. 11/20/20 Install 20" sleeve made with X65 .500 wall pipe over damaged 10 3/4" SC. 11/21/20 MITOA to 1800 psi passed. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: 4,509.0 12/27/2008 2T-208 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced SOV5/9/2020 2T-208 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.3 Set Depth (ftKB) 1,689.4 Set Depth (TVD)… 1,579.3 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.4 Set Depth (ftKB) 5,425.7 Set Depth (TVD)… 3,115.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER w/Screens OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,943.8 Set Depth (ftKB) 7,620.0 Set Depth (TVD)… 3,142.2 Wt/Len (l… 12.60 Grade L-80 Top Thread 13 CR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,943.8 3,016.4 70.93 PACKER LINER TOP PACKER SC-1R 4.000 4,948.0 3,017.7 71.20 MILLOUT EXT MILLOUT EXTENSION 3.958 4,954.3 3,019.7 71.60 SBE LINER HAS ALTERNATING SBE/SCREEN/LINER THROUGHOUT 3.250 Tubing Strings Tubing Description TUBING 4.5"x3.5" String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 25.7 Set Depth (ft… 4,606.5 Set Depth (TVD) (… 2,897.4 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 25.7 25.7 0.00 HANGER FMC 11" x 4.5" ESP Hanger w/ 5" RH Acme Lift Threads 3.958 4,482.12,851.5 68.61 SLEEVE-C Baker 4.5" CMU-Sliding Sleeve w/ 3.813" 'DB' Nipple Profile (RUN CLOSED) 3.813 4,496.5 2,856.8 68.54 DISCHARGE 4.5" Well Lift Discharge Pressure Tubing Sub 4.000 4,499.6 2,857.9 68.52 XO - Reducing 4.5" 8rd Box x 3.5" 8rd Pin X-Over 2.992 4,574.1 2,885.4 68.24 ESP Intake TCC Crossover / Coupling / Intake 4,578.8 2,887.1 68.23 SEAL Lower 513 Series Tandem Seal Section 4,592.5 2,892.2 68.20 Gear Box 538 Series Gear Reducer 4,594.4 2,892.9 68.20 ESP MOTOR 562 Series ESP 76 HP Motor 4,602.7 2,896.068.18 GAUGEWell Lift Pressure Sensor 4,604.5 2,896.7 68.18 Centralizer 5.85" OD Motor Centralizer w/ 0.375" Capilary Tubing Port 4.500 Tubing Description ESP PUMP String Ma… 2.79 ID (in)Top (ftKB) 4,531.0 Set Depth (ft… 4,574.0 Set Depth (TVD) (… 2,885.3 Wt (lb/ft)Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 4,531.02,869.4 68.38 TTC PCP PUMP 3.5" 350T 1800 PCESP W/ TEST PROFILE (43.6 OAL)0.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 4,522.0 2,866.1 68.42 PACKOFF 3.5" D&D PACKOFF ASSEMBLY (OAL=92" W/ STINGER SEALS @ 2.31" OD) SET ON TOP OF ESP 4/5/2019 1.600 4,522.02,866.168.42SLIP STOP Set Slip Stop 3/27/2020 1.600 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.0 3,140.2 3,140.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,136.9 1,872.1 Camco KBG-2- 1R 1 ESP DMY BK-5 0.000 0.0 4/27/2009 2 4,425.0 2,830.7 Camco KBG-2- 1R 1 ESP SOV BK 0.000 2,000.0 5/9/2020 2000# STS Notes: General & Safety End Date Annotation 12/28/2008 NOTE: View Schematic w/ Alaska Schematic9.0 2T-208, 5/10/2020 4:37:40 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,604.5 GAUGE; 4,602.7 ESP MOTOR; 4,594.4 Gear Box; 4,592.5 SEAL; 4,578.8 ESP Intake; 4,574.1 TTC PCP PUMP; 4,531.0 PACKOFF; 4,522.0 SLIP STOP; 4,522.0 DISCHARGE; 4,496.5 SLEEVE-C; 4,482.1 ESP MANDREL; 4,425.0 ESP MANDREL; 2,136.9 SURFACE; 31.3-1,689.4 CONDUCTOR; 31.0-108.0 HANGER; 25.7 KUP PROD KB-Grd (ft) 35.60 Rig Release Date 1/21/2006 2T-208 ... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE Annotation Last WO: End Date 4/27/2009 H2S (ppm) 20 Date 12/6/2016 Comment SSSV: NONE 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: SC Repair 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: Stratigraphic Service 6.API Number: 7.If perforating:8.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7654' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:6/22/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7506 NA NA NA NA Size Authorized Signature: 7/22/2020 4.5" x 3.5" Perforation Depth MD (ft): L-80 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3043' - 3140' Perforation Depth TVD (ft):Tubing Size: 5043' - 7551' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 \ ADL0025569 205-187 P.O. Box 100630, Anchorage, Alaska 99508 50103205800 ConocoPhillips Alaska, Inc. KRU 2T-208 Kuparuk River Field / Tabasco Oil Pool 3144'4509' PRESENT WELL CONDITION SUMMARY 2861' Length TVD Burst 4606' MD 1579' 3115' 1689' 5397' 108'108' 5425' 77'16" 10 3/4" 7 5/8" 1658' Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com m n P s 66 t y t ir rr c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:45 am, Jun 22, 2020 320-272 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: F206 Date: 2020-06-22 04:30:05 Foxit PhantomPDF Version: 9.7.0 Roger Winter 10-404 50-103-20518-00-00 X DSR-6/22/2020 SFD 6/22/2020 Photo document all steps including cutting windows,SC before and after patch SFD 6/22/2020VTL 6/29/20 Comm 6/29/2020 dts 6/29/2020 RBDMS HEW 7/1/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 22 June 2020 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. well KRU 2T-208 (PTD 205-187) to repair the Surface Casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: F206 Date: 2020-06-22 04:29:37 Foxit PhantomPDF Version: 9.7.0 Roger Winter P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2T- 208 (PTD 205-187) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 22, 2020 This application for Sundry approval for Kuparuk well 2T-37 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~20’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: 4,509.0 12/27/2008 2T-208 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced SOV5/9/2020 2T-208 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.3 Set Depth (ftKB) 1,689.4 Set Depth (TVD)… 1,579.3 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.4 Set Depth (ftKB) 5,425.7 Set Depth (TVD)… 3,115.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER w/Screens OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,943.8 Set Depth (ftKB) 7,620.0 Set Depth (TVD)… 3,142.2 Wt/Len (l… 12.60 Grade L-80 Top Thread 13 CR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,943.8 3,016.4 70.93 PACKER LINER TOP PACKER SC-1R 4.000 4,948.0 3,017.7 71.20 MILLOUT EXT MILLOUT EXTENSION 3.958 4,954.3 3,019.7 71.60 SBE LINER HAS ALTERNATING SBE/SCREEN/LINER THROUGHOUT 3.250 Tubing Strings Tubing Description TUBING 4.5"x3.5" String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 25.7 Set Depth (ft… 4,606.5 Set Depth (TVD) (… 2,897.4 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 25.7 25.7 0.00 HANGER FMC 11" x 4.5" ESP Hanger w/ 5" RH Acme Lift Threads 3.958 4,482.12,851.5 68.61 SLEEVE-C Baker 4.5" CMU-Sliding Sleeve w/ 3.813" 'DB' Nipple Profile (RUN CLOSED) 3.813 4,496.5 2,856.8 68.54 DISCHARGE 4.5" Well Lift Discharge Pressure Tubing Sub 4.000 4,499.6 2,857.9 68.52 XO - Reducing 4.5" 8rd Box x 3.5" 8rd Pin X-Over 2.992 4,574.1 2,885.4 68.24 ESP Intake TCC Crossover / Coupling / Intake 4,578.8 2,887.1 68.23 SEAL Lower 513 Series Tandem Seal Section 4,592.5 2,892.2 68.20 Gear Box 538 Series Gear Reducer 4,594.4 2,892.9 68.20 ESP MOTOR 562 Series ESP 76 HP Motor 4,602.7 2,896.068.18 GAUGEWell Lift Pressure Sensor 4,604.5 2,896.7 68.18 Centralizer 5.85" OD Motor Centralizer w/ 0.375" Capilary Tubing Port 4.500 Tubing Description ESP PUMP String Ma… 2.79 ID (in)Top (ftKB) 4,531.0 Set Depth (ft… 4,574.0 Set Depth (TVD) (… 2,885.3 Wt (lb/ft)Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 4,531.02,869.4 68.38 TTC PCP PUMP 3.5" 350T 1800 PCESP W/ TEST PROFILE (43.6 OAL)0.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 4,522.0 2,866.1 68.42 PACKOFF 3.5" D&D PACKOFF ASSEMBLY (OAL=92" W/ STINGER SEALS @ 2.31" OD) SET ON TOP OF ESP 4/5/2019 1.600 4,522.02,866.168.42SLIP STOP Set Slip Stop 3/27/2020 1.600 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.0 3,140.2 3,140.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Ty pe Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,136.9 1,872.1 Camco KBG-2- 1R 1 ESP DMY BK-50.000 0.0 4/27/2009 2 4,425.0 2,830.7 Camco KBG-2- 1R 1 ESP SOV BK 0.000 2,000.0 5/9/2020 2000# STS Notes: General & Safety End Date Annotation 12/28/2008 NOTE: View Schematic w/ Alaska Schematic9.0 2T-208, 5/10/2020 4:37:40 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,604.5 GAUGE; 4,602.7 ESP MOTOR; 4,594.4 Gear Box; 4,592.5 SEAL; 4,578.8 ESP Intake; 4,574.1 TTC PCP PUMP; 4,531.0 PACKOFF; 4,522.0 SLIP STOP; 4,522.0 DISCHARGE; 4,496.5 SLEEVE-C; 4,482.1 ESP MANDREL; 4,425.0 ESP MANDREL; 2,136.9 SURFACE; 31.3-1,689.4 CONDUCTOR; 31.0-108.0 HANGER; 25.7 KUP PROD KB-Grd (ft) 35.60 Rig Release Date 1/21/2006 2T-208 ... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE Annotation Last WO: End Date 4/27/2009 H2S (ppm) 20 Date 12/6/2016 Comment SSSV: NONE By Samantha Carlisle at 9:08 am, May 26, 2020 Digitally signed by Matt Miller DN: C=US, OU=Wells, O=ConocoPhillips, CN=Matt Miller, E=Matthew.Miller@contractor.conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-05-23 14:54:04 Foxit PhantomPDF Version: 9.7.0 Matt Miller VTL 5/26/20 DSR-5/26/2020 RBDMS HEW 5/26/2020 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: OA Cement Shoe 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?NA Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Kuparuk River Field / Tabasco Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7654' 7620' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email: Contact Phone: 907-659-7224 Date: 5/2/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 5/11/2020 7620'2676' 4.5", 3.5" 3142' NA, packerless ESP Jan Byrne 5426' Perforation Depth MD (ft): 5043' - 7551' 5397' 4.5" 3116'7.625" 16" 10.75" 77' 1658' 108' 1579' 108' 1689' L-80 TVD Burst 4574 MD ConocoPhillips Alaska, Inc. Length Size KRU 2T-208 3144'3142' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 \ ADL0025569 205-187 P. O. Box 100360, Anchorage, Alaska 99510 501032051800 Tubing Grade:Tubing MD (ft): 3043' - 3140' NA, packerless ESP Perforation Depth TVD (ft):Tubing Size: Well Integrity Compliance Specialist N1617@conocophillips.com COMMISSION USE ONLY Authorized Name: Authorized Title: m n P 66 t e Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Working remotely from home Date: 2020-05-02 10:10:03 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conoco phillips.com By Samantha Carlisle at 1:21 pm, May 03, 2020 320-190 X 10-404 5/4/20 NA DLB DLB 05/04/2020 DSR-5/4/2020 X -00 DLB VTLComm. 5/5/2020 dts 5/4/2020 JLC 5/4/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 2 May 2020 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. well KRU 2T-208 (PTD 205-187) to pump an outer annulus (OA) cement shoe. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Working remotely from home Date: 2020-05-02 10:11:56 Foxit PhantomPDF Version: 9.7.0 jan.byrne@con ocophillips.com P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CPAI Well Integrity & Compliance Specialist PROCEDURE FOR OUTER ANNULUS CEMENT SHOE 2T-208 (PTD 205-187) ConocoPhillips Alaska, Inc., (CPAI) intends to pump a cement shoe in the outer annulus (OA) of Kuparuk producer 2T-208 (PTD 205-187). The OA in this well is the annular void between 7- 5/8” casing and 10-3/4” casing. The annulus does not contain a cement shoe. CPAI is requesting to install a cement shoe to isolate the OA from shallow formation pressure. This isolation will allow the OA to be bled to 0 psi, which is required to progress surface casing diagnostics. With approval, the OA cement shoe will require the following general steps: 1. Pump cement design to place ~700 ft linear shoe in the OA. 2. Displace cement with freeze protection fluids. 3. Wait on cement to cure. 4. OA drawdown test. 5. Submit 10-404 to AOGCC. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: 4,509.0 12/27/2008 2T-208 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replaced ESP equipment & SOV4/5/2019 2T-208 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 31.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 31.3 Set Depth (ftKB) 1,689.4 Set Depth (TVD)… 1,579.3 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.4 Set Depth (ftKB) 5,425.7 Set Depth (TVD)… 3,115.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER w/Screens OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 4,943.8 Set Depth (ftKB) 7,620.0 Set Depth (TVD)… 3,142.2 Wt/Len (l… 12.60 Grade L-80 Top Thread 13 CR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 4,943.8 3,016.4 70.93 PACKER LINER TOP PACKER SC-1R 4.000 4,948.0 3,017.7 71.20 MILLOUT EXT MILLOUT EXTENSION 3.958 4,954.3 3,019.7 71.60 SBE LINER HAS ALTERNATING SBE/SCREEN/LINER THROUGHOUT 3.250 Tubing Strings Tubing Description TUBING 4.5"x3.5" String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 25.7 Set Depth (ft… 4,606.5 Set Depth (TVD) (… 2,897.4 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 25.7 25.7 0.00 HANGER FMC 11" x 4.5" ESP Hanger w/ 5" RH Acme Lift Threads 3.958 4,482.12,851.5 68.61 SLEEVE-C Baker 4.5" CMU-Sliding Sleeve w/ 3.813" 'DB' Nipple Profile (RUN CLOSED) 3.813 4,496.5 2,856.8 68.54 DISCHARGE 4.5" Well Lift Discharge Pressure Tubing Sub 4.000 4,499.6 2,857.9 68.52 XO - Reducing 4.5" 8rd Box x 3.5" 8rd Pin X-Over 2.992 4,574.1 2,885.4 68.24 ESP Intake TCC Crossover / Coupling / Intake 4,578.8 2,887.1 68.23 SEAL Lower 513 Series Tandem Seal Section 4,592.5 2,892.2 68.20 Gear Box 538 Series Gear Reducer 4,594.4 2,892.9 68.20 ESP MOTOR 562 Series ESP 76 HP Motor 4,602.7 2,896.068.18 GAUGEWell Lift Pressure Sensor 4,604.5 2,896.7 68.18 Centralizer 5.85" OD Motor Centralizer w/ 0.375" Capilary Tubing Port 4.500 Tubing Description ESP PUMP String Ma… 2.79 ID (in)Top (ftKB) 4,531.0 Set Depth (ft… 4,574.0 Set Depth (TVD) (… 2,885.3 Wt (lb/ft)Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 4,531.02,869.4 68.38 TTC PCP PUMP 3.5" 350T 1800 PCESP W/ TEST PROFILE (43.6 OAL)0.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 4,522.0 2,866.1 68.42 SLIPSTOP 3 1/2" SLIPSTOP 4/5/2019 1.430 4,522.02,866.168.42 PACKOFF 3.5" D&D PACKOFF ASSEMBLY (OAL=92" W/ STINGER SEALS @ 2.31" OD) SET ON TOP OF ESP 4/5/2019 1.600 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,043.0 5,126.0 3,043.7 3,062.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,379.0 5,420.0 3,108.5 3,115.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 5,423.0 6,419.0 3,115.3 3,133.9 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,466.0 6,508.0 3,133.9 3,134.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 6,511.0 7,507.0 3,134.0 3,140.2 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe 7,509.0 7,551.0 3,140.2 3,140.0 TABASCO, 2T- 208 1/16/2006 99.0 SLOTS Alternating screens/solid pipe Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Ty pe Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 2,136.9 1,872.1 Camco KBG-2- 1R 1 ESP DMY BK-50.000 0.0 4/27/2009 2 4,425.0 2,830.7 Camco KBG-2- 1R 1 ESP SOV BK 0.000 2,000.0 4/3/2018 200# STS Notes: General & Safety End Date Annotation 12/28/2008 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NONE 2T-208, 4/6/2019 8:17:38 AM Vertical schematic (actual) LINER w/Screens; 4,943.8- 7,620.0 SLOTS; 7,509.0-7,551.0 SLOTS; 6,511.0-7,507.0 SLOTS; 6,466.0-6,508.0 SLOTS; 5,423.0-6,419.0 PRODUCTION; 28.4-5,425.7 SLOTS; 5,379.0-5,420.0 SLOTS; 5,043.0-5,126.0 Centralizer; 4,604.5 GAUGE; 4,602.7 ESP MOTOR; 4,594.4 Gear Box; 4,592.5 SEAL; 4,578.8 ESP Intake; 4,574.1 TTC PCP PUMP; 4,531.0 PACKOFF; 4,522.0 SLIPSTOP; 4,522.0 DISCHARGE; 4,496.5 SLEEVE-C; 4,482.1 ESP MANDREL; 4,425.0 ESP MANDREL; 2,136.9 SURFACE; 31.3-1,689.4 CONDUCTOR; 31.0-108.0 HANGER; 25.7 KUP PROD KB-Grd (ft) 35.60 Rig Release Date 1/21/2006 Annotation Last WO: End Date 4/27/2009 2T-208 H2S (ppm) 20 Date 12/6/2016... TD Act Btm (ftKB) 7,654.0 Well Attributes Field Name TABASCO Wellbore API/UWI 501032051800 Wellbore Status PROD Max Angle & MD Incl (°) 91.88 MD (ftKB) 7,287.04 WELLNAME WELLBORE • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o2Q Sj - 1 9 ~ Well History File Identifier Organizing (done) Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ~ 1 O S ^ Other:: /s/ ~' Project Proofing II I II ~) I I I I III I I III BY: Maria Date: ~ / ~ /s! Scanning Preparation ~ x 30 = d + ~ ~ =TOTAL PAGES~~ BY: Maria Date: ~/ ~ ~ ~ (Count does not i ~ dude cover sheet) 1/~/) Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ /' ~~ ~ /s/ /// /// Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII Illll BY: Maria Date: !s! Comments about this file: Quality Checked III IIIIII III () II III 10!6!2005 Well History File Cover Page.doc • ConocoPhillps aa~ka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~CEaVED ~,~~~• ~ C 7.01Q ~~aska OA & Gas Cam. C~tt~t~ssion Anchar~Qa a -a Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these-wells was found to have a void in the conductor. These voids were filled with 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 July 1 lth, 12th, 13th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ~ + Report of Sundry Operations (10-404) Kuparuk Field Date 7116110 2T_ 3H POr) Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2T-22 50103202240000 1950860 8" Na 8" n/a 3.8 7/12/2010 2T-23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010 2T-27A 50103202170100 2090900 7" n/a 7" Na 1.7 7/12/2010 2T-32 50103202180000 1950490 36" Na 36" n/a 11.9 7/12/2010 2T 37 50103202270000 1951010 22" Na 22" n/a 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" n/a 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T 208 50103205180000 2051870 13" Na 15" n/a 2.5 7/13/2010 2T-210 50103202730000 1982030 18" Na 18" n/a 5.1 7/12!2010 2T-217A 50103203340100 2000740 8" Na 8" n/a 1.7 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 4 ~~ ~ ~~ .~ r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc • Vi'i' ~ 1~.~ ~ °~ STATE OF ALASKA ~A,~ `~ ~ ZdO9 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~~,~a ~$a ~ ~~~ ~~~~. ~~,~,~,~~;~, 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. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillipsAlaska, Inc. CJs~re.Io~rr,car,4 ^~ Exploratory ^ 205-187/ . 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20518-00 7. KB Elevation (ft): 9. Well Pdame and Number: RKB 30' - 2T-208 8. Property Designation: • 10. Fieldr'Pool{s}: ADL 25569, 25548 Kuparuk River Field /Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 7654' feet true vertical 3144' feet Plugs (measured; Effective Depth measured 7620` feet Junk (measured) true vertical 3142' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 1659' 10-3{4" 1689' 1579' PRODUCTION 5396` 7-5f8" 5425' 3116' LINER 2676` 4.5" 7620' 3142' Perforation depth: Measured depth: 5043'-5126', 5379'-5420', 5423'-6419', 6466'-6508', 6511'-7507', 7509'-7551' true vertical depth: 3044'-3062', 3108'-3115', 3115'-3134', 3133'-3134', 3134'-3142', 314 3'-3140' Tubin size, rade, and measured de th 4.5", 3.5", L-80, 4500`, 4607 MD -;~cy~ rt Packers &SSSV (type & measured depth) Liner top pkr ~ 4944' no SSSV 12. Stimulation or cement squeeze summary: w~\l ~~ i~ ra_®~ I Intervals treated (measured) not applicable 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 SI Subsequent to operation 291 11 10 -- 233 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ .Service ^ Daily Report of Well Operations _X 16. Well Status after work : Oil ^d 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: none contact J' nnis ~ 265-1544 Printed Name Ennis ~ Title Wells Engineer 5~ ~~~ ~ 1 Signature Phone: 265-1544 Date Pre aced b Karon llsu -Ora a 2634612 ~~ ~. ,.;~~ ~~?~o~ ~ ~ ~ I ~A L Form 10-40 evised 04/2006 '~, ,, ~ ~_ - I S Submit Origins yg~ /~ ~' - KUP ~. ~ ConOCOPhillips ~ Well Attributes ' Alittih~i IlT, Wellbore APllUWI FieltlN ~ '. 501032051800 TABA commem ... - - 3 rv 6 r ono ' ' SSSV_ NONE o, , went 2T~2 6. a a .t n 9 Schemaily A rt„ I Annotation Depth (ftK6) Last Tag: 4,509.0 Casing Strings MANGER, 26 Casing Description String CONDUCTOR 16 Casing Description i5tring SURFACE 103 Casing Description String CONDUCTOR. PRODUCTION 7 5/ ~ 0106 I Casing Des iption 'String SURFACE. LINER w; SCreenS 41/ 31-1,659 Liner Details --- - Top Depth ESP (TVDI Top Intl MANDREL, 2.137 Top (kKB) (kKB) .., ..,„ ~~.~~ (°) -.~~.. ESP MANDREL. 4.azs SLEEVE-C, 4,602 DISCHARGE, a <s7 ESP Imake. __ 6,574 SEAL. x,579 -- Gear Box, 6,593 ESP MOTOR, _ 4,696 GAUGE, 6.603 -- Centralizer, _ a.sos Description 5 1/1/'2009 ~La ate ~Annotaron '12008 I Rev Reason: ESP - 2T-208 Max Angle & MD II Status Intl (°) MD (ftKe) I;TD Ac[ BM (kK81 OD 91.88 7,287.04 7,654.0 i IEnd Date 'KB-Grd (k) ~~, Rig Raleasa Dat - 1 2/3 012 0 06 ~ 1121/2006 Last Mod By End Date ( KOVER Imosbor I 4/286'2009 .. Set Depth (TV D) .. !. String -_ String Wt... String Top Thrd 108 0 62 5Q 1140 WELDED .. Set De th VD p (T )... Strin yry g String _.. String Top Thrd 1,581.0 'I 45.50 '~ L-80 BTC f... Set Depth (TVD) ... String Wt... ii String ... String Top Thrd 3,115.0 29 70 L 80 BTCM f... Set Depth (rVD) .. St ng W[... ~Stnng ... String Top Thrd 3,142.2 1260 , L80 13 CR _ _-. Comment -- ~ _ ID (il -- SC-1R 4.0( f... Set Depth (TVDI ... String Wt... IString ... String TOp Thrd 2.897.4 ~ 12.60 ~ L-80 i IBTM ' (ND) ' Top Intl t) it (kK6) ~ (°) Rem Description _ Comment 7 25.71 -0.01 HANGER FMC 11' x 4.5' ESP Hanger w/ 5' RH Acme LiR Threads 1 ~ 2,851.5 68.40 SLEEVE-C Baker 4.5" CMU-Sliding Sleeve w! 3.813"D8' Nipple Profit CLOSED) -_. 5 2,856.7 68.37 DISCHARGE - 4.5' Well LiR Discharge Pressure Tubing Sub 7 2,857.9 68.37 XO -Reducing 4.5' 8rd Box x 3.5' Srd Pin X-Over 1 2,885.4 68.24 ESP Intake TCC Crossover 1 Coupling I Intake 8 2,887.1 68.23 SEAL I LOwer 513 Series Tantlem Seal Section 5 2,892.2 68.20 Gear Box 1 _.. 538 Series Gear Reducer 4 2,892.9 68.20 ESP MOTOR _ __ 562 Series ESP 76 HP Motor 7 2,896.0 68 18' GAUGE Well Lift Pressure Sensor 2,°96.7 6fl 18 Centralizer - 5.85' OD Motor Centralizer w/ 0.375" Capllary Tubing Port ations 8 Slots ' Shot Top (TV D) Btm (TVD) Dens tl~Btm lftK81 IflKe) (ftK6) Zone Date iah... Tvoe C 6,419 3,114.81 3, screens/solid pipe screens/solid pipe screens/solid pipe 1/16/2006 Sveen. 5,063-5.126 Screen, 5,379-6,620 PRODUCTION, 28-5.426 - - Saeen, 6,623-6.419 Screen. 6,466-6.505 sueen. ss11 zso7 screen. 7,609-7,551 LINER ~.._._~ ~- -i r I w/SaeenS 1,9H-7.620 J L TD (2T~206). 7,656 ___. _ __ ToP --__ j Port Intl OD Valve Latch i S¢e TRO Run I (") ' Make Motlel (inl Sarv TYPe TYPe I (~n) (PSr) ~ Run Data Com... iZ22 Camco KBG-2-1R 1 ESP SOV IBK-5 0.000 0.04/27/2009 '~, I I I 18.67 Camco KBG-2-1R 1 ESP DMY '~,BK-5 0.000 O.OI4l27I2009 I n • Cono~t~Phi~~ips Time Log & Summary tVe1N?ew 4Veb Reporting Re ~~ Well Name: 2T-208 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/23/2009 11:00:00 PM Rig Release: 4/27/2009 1:30:00 PM Time Logs _ _ _ _ _ _ _ _ _ Date From To Dur __8 Depth_ E Depth _Phase Code Subcode T_ _ Comment _ _ _ 4/23/2009 24 hr Summary Moved rig from 1C Pad to 2T Pad, spotted rig mats and pulled rig over well. 07:30 17:00 9.50 COMPZ MOVE TRNS P Moving rig from 1C-178 to 2T-208 17:00 19:00 2.00 COMPZ MOVE TRNS P Rig on standby with crews on 26 Pad for feildwide crew than e. 19:00 22:00 3.00 COMPZ MOVE TRNS P Cont moving rig from 26 Pad to 2T ad. 22:00 00:00 2.00 COMPZ RPCOM PSIT P Spot rig mats at well site, pull rig over well, level and berm up cellar. Acce ted Nordic Ri 3 at 23:00 hrs. 4/24/2009 Pulled BPV, flushed tubing and IA with hot filtered sea-water, installed BPV, ND tree, installed blanking plug, NU BOP, tested BOPE, remove blankin lu and BPV, MU landin 'nt and circ hose. 00:00 01:00 1.00 COMPZ RPCOM RURD P Cont berm up cellar, spot tanks and mudshack, MU hardline to kill tank, RU circ hoses in cellar, 400 psi on tubin 400 si on IA 0 si on IA. 01:00 06:30 5.50 COMPZ RPCOM RURD T PU lubricator, had no hoses or pulling tool, wait on FMC to retrieve hardware for lubricator. RU hardware, attempted to pull BPV but rod length too short, wait on FMC to retrieve extension rod and backup lubricator, MU extension rod but lubricator too Ion for tree, CO lubricators. 06:30 07:30 1.00 0 0 COMPZ RPCOM RURD P RU new lubricator, pull BPV. RD lubricator. 07:30 08:30 1.00 0 0 COMPZ RPCOM PRTS P PJSM. Pressure test line to kill tank 2500 psi. blow down line. RU heated SW Vac Truck. 08:30 11:00 2.50 0 0 COMPZ RPCOM CIRC P Open well tbg pres = 160 psi, IA press = 220 psi. Bleed off pressure. Pump 70 bbl down the tubing and 200 bbl down the IA, 140 deg SW at 5 b m 60 si, no returns to tank. 11:00 18:00 7.00 0 0 COMPZ RPCOM NUND P Install BPV. ND tree, install blanking lu . NU BOPE 18:00 23:00 5.00 0 0 COMPZ RPCOM BOPE P Test all BOPE at 250 / 2,500 psi, good tests, RD test equipment, pull blanking plug. Gave AOGCC 24 hour notice of up-coming BOP test at 16:00 hrs on 4/23/09. Witness of BOP test was waived by AOGCC Rep Jeff Jones at 16:30 hrs on 4/23/09. ~~..~ .~..~ ~g~ 1 of 4 Time Logs Date From To Dur S. Depth.. _E._D~th Phase Code Subcod_e_ T Comment __ _ _ 23:00 23:30 0.50 0 0 COMPZ RPCOM RURD P Load capilary tube spooler, RU sheaves while re airin BPV T-Bar. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Pull BPV MU landing jnt and circ hose. /25/2009 BOLD's, pull hanger to rig floor, LD landing jnt, drop 3.833" drift with wire, POOH 1 stand and string ESP cable and capilary tubing through sheaves, POOH standing back 4 1/2" completion, LD jewelry and ESP pump assembly, MU new ESP pump assembly, RU slickliine, installed pump, packoff and test tool, tested assembly to 500 psi, pulled test tool, set slip stop, RD slickline, MU discharge sub and CMU sliding sleeve, s lived tec wire and tested. 00:00 01:00 1.00 4,622 4,595 COMPZ RPCOM PULL P BOLD's, unseat hanger at 85K, pull han er to ri floor dd 50 bbls to hole. 01:00 02:30 1.50 4,595 4,500 COMPZ RPCOM RURD P RD circ hose, LD landing jnt and hanger, RU and drop 3.833" drift with wire, POOH 1 stand, string ESP cable and capilary tubing through sheaves and secure on s oolers. 02:30 08:30 6.00 4,500 135 COMPZ RPCOM PULL P POOH standin back 4 1/2" tubin , LD 'ewel 08:30 10:00 1.50 135 0 COMPZ RPCOM PULD P Break down and lay down ESP assembly. **Motor lead ulled out of the pot head, cable was burnt where it ulled out of the of head.** 10:00 13:00 3.00 0 0 COMPZ RPCOM RURD P Clean floors. PJSM. Crane on location, remove pulled ESP cable spool and load new ESP cable s ool. 13:00 14:30 1.50 0 0 COMPZ RPCOM SVRG P PJSM. Slip and cut drill line. 14:30 15:30 1.00 0 0 COMPZ RPCOM RURD P Set up ESP cable spooler and arran a ESP com letion. 15:30 20:00 4.50 0 103 COMPZ RPCOM PULD P PU and MU ESP um /motor asembl ,RIH 2 'nts 3 1/2" tb . 20:00 22:00 2.00 103 103 COMPZ RPCOM SLKL P RU slickline, RIH 3" GS and 3 1/2" TTC PCP, sat down, set and sheared GS, POOH, RIH with 3" GS and 3 1/2" packoff assembly, sat down, set and sheared GS, POOH, RIH with 3" GS and packoff test tool, sat down, set and sheared GS, POOH, RU and testpackoff assembly to 500 psi, good test, RIH with 3" GS, latched in and POOH with test tool, RIH with 3" GS and slip stop, sat down set and sheared GS, POOH, RD slickline. 22:00 00:00 2.00 103 134 COMPZ RPCOM PULD P MU discharge sub and "CMU" sliding sleeve with pups, spliced in Tec Wire, tested and clamped cable and tubin . 4/26/2009 Cont RIH with 4 1/2" ESP completion from derrick checking ESP cable every 1,000', cable showing ground at 1,878', POOR, motor tested good, found bad spot in ESP cable, cut and splice new MLE, MU and RIH to 1,880', retrieve wiper rubber from flow riser, cont RIH to 4,580', MU hanger and landing jnt, start ESP cable s lice to enetrator. ~.-~ ®® ~ page 2 of ~ ~1 • Time Logs __ -- ---- ----- ------ - -. ___ Date From To Dur S De th E. Depth Phase Code _ Subcode T Comment _ _ 00:00 02:00 2.00 134 1,878 COMPZ RPCOM RCST P Cont RIH from 134' to 1,878' checkin cable inte ri eve 1,000'. 02:00 02:30 0.50 1,878 1,878 COMPZ RPCOM OTHR T ESP cable not testing, double checked surface a ui ment. 02:30 03:00 0.50 1,878 1,372 COMPZ RPCOM PULL T POOH from 1,878' to 1,372' visually ins ectin ESP cable for dams e. 03:00 03:30 0.50 1,372 1,372 COMPZ RPCOM EQRP T Repair ESP spooler. 03:30 05:30 2.00 1,372 0 COMPZ RPCOM PULL T Cont POOH visually inspecting ESP cable for damage, from 1,372' to cable connection on motor assembly. Disconnected cable from motor, tested motor (good), tested cable, found bad spot in cable where cable laid across 4 1/2" to 3 1/2" XO. Cut off cable and prep for splice of new MLE. 05:30 10:30 5.00 0 0 COMPZ RPCOM EQRP T Splice cable and new motor lead. 10:30 18:30 8.00 0 1,880 COMPZ RPCOM RCST T MU motor lead to motor and RIH with 4-1/2" completion to 1,880', found stripping rubber had been pulled into BOP stack, POOH in attempt to pull wiper back up into drip pan, wiper rubber lodged in flow riser, had to cut wiper rubber in half and remove from flow riser. 18:30 23:00 4.50 1,880 4,580 COMPZ RPCOM RCST P Continue running completion from 1,880' to 4,580', up weight 75K, down weight 55K, MU hanger and landing nt. 23:00 00:00 1.00 4,580 4,580 COMPZ RPCOM SEOP P Prep and splice ESP cable. 4/27/2009 Completed ESP cable splice to penetrator, MU capilary tubing to hanger, tested ESP cable, flushed IA with 95 bbls diesel for freeze protect, landed hanger, RILD's, flushed tbg with 15 bbls diesel for freeze protect, LD landing jnt, installed 2 way check, ND ROPE, NU and tested tree, pulled 2 way check, installed BPV, blew down all circ liines, prepped cellar for rig move, RDMO well, cleaned cellar box. Nordic Ri 3 released from 2T-208 on 4/27/2009 13:30 00:00 03:00 3.00 4,580 4,580 COMPZ RPCOM SEQP P Cont splice ESP cable to penetrator, MU ca ila tb to han er. 03:00 03:30 0.50 4,580 4,606 COMPZ RPCOM HOSO P Land hanger, up weight 75K, down weight 53K, bottom of ESP pump assembl at 4,606' MD. Installed : 68 (4.5") Cannon clamps, 2 (3.5") Cannon clamps, 22 SS bands, 3 Protectolizers, 4 flat aurds. 03:30 04:00 0.50 4,606 0 COMPZ RPCOM OTHR P RILD's. 04:00 06:30 2.50 0 0 COMPZ RPCOM FRZP P PJSM with LRS, RU and flush 15 bbls diesel into tbg with fill up hose, LD landing jnt, install 2 way check, RU in cellar and flush 95 bbls diesel down IA. Page 3 asf ~ r~ Time Logs _ _ __ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 06:30 08:00 1.50 0 0 COMPZ RPCOM NUND P ND BOPE check ESP cable thru penetrator OK. NU tree, check ESP cable thru bonnet OK. 08:00 10:30 2.50 0 0 COMPZ RPCOM NUND P NU tree Test tubing pack off to 5000 si, test tree to 5000 si, ood test. 10:30 13:30 3.00 0 0 COMPZ RPCOM RURD P Cfean cellar, dress tree, RDMO. Nordic Ri 3 released from 2T-208 on 4/27/2009 13:30 - - ~-- #~a~e ~ ~f 4 2T-208 Post Rig Well Work DATE SUMMARY 5/14/09 PULLED 3 1/2" TBG STOP FR 4506' SLM. ATTEMPT TO PULL PACK ASSY GOT BLOWN UPHOLE. PACKOFF ASSY ATTATCHED TO PCPESP WITH 32' TOOLSTRING APPROX 18' WIRE ATTATCHED."*TOOLSTRING IN HOLE ATTATCHED TO PACKOFF ASSY AND ESP"" IN PROGRESS. 5/15/09 ATTEMPT TO FISH 32' TOOLSTRING LATCHED TO PACKOFF ASSY ATTATCHED TO PCPESP FROM TOP OF FISH @ 4479' SLM. ATTEMPT TO LATCH TOOL STRING, NO SUCCESS. RUN BLIND BOX TO KNOCK OFF WIRE FROM TOOL STRING. ATTEMPT TO DISPLACE THICK FLUID, IN PROGRESS. 5/16/09 OPENED 3.81"CMU @ 4482' RKB TO DISPLACE THICK FLUID. FISHED 32' TOOLSTRING FROM 4797' RKB; SEPARATING PACKOFF FROM PCPESP. PULLED 40.56' PCPESP FROM 4574' RKB. ALL WIRE RECOVERED. CLOSED 3.81" CMU @ 4482' RKB.IN PROGRESS 5/17/09 SET 3 1/2" 40.75' PCPESP @ 4574' RKB. SET PACK OFF (OAL=7.66' MIN ID=1.6,NO CHECK) @ 4533' RKB. TEST TBG TO 1000 PSI. SET 3 1/2" TBG STOP ON PACKOFF @ 4526' RKB, JOB COMPLETE. Ti~d41~-/T7a4L ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) fi59-5102 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. ti Attn: Robert A. Richey 130 West International Airport Road Suite C >'t~ ~ i~~~t.~~ ' ~~~ ~I ~ ~h ~~~G Anchorage, AK 99518 Fax. (907j 245-8952 1) Caliper Report 28-Deo~08 2K 14 1 Report / E~ 50-1 03-201 1 2-00 2) Caliper Report 28-Dec~08 2T,2O8 1 Report / EDE 50.103-20518.00 1~9 -o~~ ~ ~-3~5~ ~a5 -l~s~ ~ !~-3~so. Signed Print Name: ~> ~-~~ Y ~ ~ ~ {~ -~ s8j~3 Date ~. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~cl~an~$aoragec(3~eenorYl®a.car~ WEBSITE:~mnr~v.rresa?o~4f~aa.~~~ _~ ~~ C:\Docianerts and Settings\OwnetU>esktop\T~at~smit_Conoco.doc~c • • Memory Mutt'-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-208 Log Date: December 28, 2008 Field: Kuparuk Log No.: 8728 State: Alaska Run No.: 1 API No.: 50-103-20518-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 Top Log Intvl: 43 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl: 4,513 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ' This caliper data is tied into fhe Well Lift Discharge Sub at 4,491' (Drfller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage prior ' to rig operations to replace a burnt ESP. The caliper recordings indicate the tutnng'is in good condition, with no significant wall pene#rations, areas of cross-sectional waft loss or 1.D. restrictions recorded throughout the interval logged. ~~;~~~~:~~ J~al~ .~ ~ HOC MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 11°ib) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant LD, restrictions are recorded throughout the tubing logged. Field Engineer: K. Miller Analyst: M. Lawrence Witness: S. Ferguson PraActive Diagnostic Services, Inc. J P.~, Box 1.169, Stafford, TX 77497 Phone: (281j ar {888) 565-9085 Fax: (281} 565-1369 E-maiL PDS;a'7memorylag.cam Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-231.4 ads ~~~ ~ ! ~-3~`~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (43.7' -4499.8') Well: 2T--208 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: December 28, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 44 292 602 913 1223 1534 1846 2151 p 2461 ,i c GLM 1 2794 ~ D 3105 3416 3725 4034 4343 GLM 2 143.4 4500 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 143.4 10 - 20 30 40 SO 60 70 iv ~ 80 Z ~ 90 ' ~ o 100 110 120 130 140 • • PDS Report Overview S, Body Region Analysis Well: 2T--208 Survey Date: December 28, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fngers: 40 Anal st: M. Lawrence Tubing: Norn.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°Ao wall) ~ penetration body metal loss body 1 SO 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 to 40 ro over 40% 85% 85% Number of ~oints anal se d total = 150 pene loss . 1 147 2 89 61 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ~~;t; metal loss body 0 50 100 GLM 1 ~ GLM 2 Bottom of Survey = 143.4 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • i LATI O N SHEET 2T-208 Kuparuk ConocoPhillips Alaska, Inc USA December 28, 2008 Joint No. Jt. Depth (Ft.) I'~°n. I ll,tirt Iln..) Pen. Body (Ins.) Pen. %> Metal I uss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 44 (1 0.00 1 I 3.97 2 47 t ~ 0.01 3 I 3.94 3 78 t~ 0.01 =1 1 3.95 4 109 t l 0.02 i, 3.93 5 138 t I 0.02 (~ ~ 3.9 6 169 tl 0.02 ~ 3.94 7 199 U 0.02 7 I 3.94 8 230 l) 0.01 5 Z 3.91 9 261 i) 0.02 7 ~) 3.96 10 292 t) 0.02 ~ t3 3.95 1 323 U 0.01 ~; 1 3.94 12 355 t ~ 0.01 i I 3.96 13 386 t? 0.01 5 I 3.95 14 418 U 0.02 ~ I 3.9 15 449 n 0.01 i 3.94 16 481 tl 0.0 ~ I 3.95 17 509 t~ 0.01 -3 t3 3.94 18 540 t ~ 0.01 4 1 3.94 19 571 t~ 0.01 5 a 3.92 20 602 U 0.02 ~ 1 3.91 21 633 t? 0.02 t, I 3.96 22 664 t~ 0.02 ' .95 23 695 tl 0.01 ~ I 3.94 24 727 t1 0.01 4 1 3.95 25 758 a 0.01 i 1 .94 26 789 t t 0.01 -1 ~' 3.93 27 820 11 0.01 6 7 3.91 28 851 U 0.02 7 ~' 3.93 29 882 tl 0.01 4 1 .93 30 913 t3 0.01 ~ is 3.92 3 945 t~ 0.01 3 3. 4 32 976 t ~ 0.01 4 1 3.95 33 1007 tt 0.01 3 1 3. 6 34 1038 tl 0.02 i I 3.95 35 1069 U 0.02 7 1 3.95 36 1100 U 0.02 7 I 3.95 37 1130 t~ 0.01 ~ I 3.94 38 1162 t 1 0.02 ti 3.94 39 1193 t ~ 0.02 (, I .95 40 1223 t~ 0.01 z 3.91 41 1 55 t ~ 0.02 r3 _' 3.96 42 1286 t~ 0.01 I 3.93 43 1318 U 0.01 3 1 3.9 44 1348 t ~ 0.02 8 I 3.90 5 1379 t~ 0.02 7 I 3.93 46 1410 t ~ 0.01 -1 3.94 47 1441 ~ ~ 0.01 > I 3.95 48 1472 t ~ 0.02 ~~ I 3.95 49 1503 ~? 0.02 t3 3.94 50 1534 0.01 _' I 3.95 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • iLATION SHEET 2T-208 Kuparuk ConocoPhillips Alaska, Inc. USA December 28, 2008 Joint No. Jt. Depth (Ft) I'c•n. U)~s~~t (Ins.) Pen. Body (Ins.) Pen. % ~~letal Loss °-i> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1566 O 0.02 fi ~) 3.94 52 1597 l) 0.01 I 3.96 3 1628 t) 0.02 7 1 3.95 54 1659 (~ 0.01 s I 3.95 55 1690 (~ 0.01 3.91 56 17 2 (i 0.01 ~ I 3.95 57 1753 O 0.02 ti I 3.94 58 1784 ll 0.03 Il) 3.95 59 1815 O 0.01 ; I 3.92 60 1846 O 0.01 ~ ! ~ 3.90 61 1875 t) 0.01 i <' 3. 62 1906 i) 0.01 4 1 3.95 63 1937 (~ 0.01 ; 2 3.92 64 1968 (~ 0.02 tf 3. 9 65 1996 ~ i 0.01 ~ 97 66 2027 I1 0.01 '> I 3.93 67 057 O 0.01 } I 3.96 68 2088 a 0.01 _' I 3.92 69 2119 c) 0.01 4 I 3.9 70 2151 ~) 0.02 ~) I 3.95 71 2182 ~~ 0.01 s I 3.8 72 2212 ~ ~ 0.03 1 1 3.91 73 2243 O 0.02 ~) _' 3.91 74 2274 O 0.02 (, 9 3.94 75 306 O 0.01 ~ 3.94 76 2337 ~) 0.02 t) 1 3.94 77 2368 (~ 0.01 ~ _' 3.95 78 2399 l) 0.02 ~) 3.94 79 2430 U 0.01 ~t r 3.94 80 2461 a 0.01 ~ ~ 3.89 81 2493 U .01 4 1 3.94 82 2523 a 0.01 3 1 3.92 83 2554 ~) 0.01 -1 I 3.94 84 2585 U 0.01 ~ 1 3.94 85 2616 U 0.02 (3 I 3.94 86 2647 O 0.01 ~ 3.88 87 2678 O 0.01 ~ _' 3.94 88 2709 t) 0.01 4 I 3.93 88.1 2740 ~~ 0.0 t9 1 3.95 PUP 88.2 2748 O 0 t) U N A GLM 1 Latch ~ 1:00 88.3 2755 (! 0.03 ~) 1 3.93 PUP 89 2763 a 0.03 ~) 1 3.94 90 2 794 a 0.01 3 ? 3.94 91 2825 O 0.01 4 I 3.94 92 2856 a 0.01 3 .93 93 2887 t) 0.01 5 I 3.89 94 2918 U 0.01 ~ I 3.91 95 2950 i) 0.01 3 I 3.93 96 2981 l~ 0.01 ~ I 3.94 97 3012 ~ ~ 0.02 tf ~ 3.95 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI Pipe: 4.5 in 12.6 ppf 1.-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: Page 3 i ILATION SHEEP 2 f-208 Kuparuk ConocoPhillips Alaska, Inc USA December 28, 2008 _ Penetration Body Metal Loss Body PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ELATION SHEET 2T-208 Kuparuk ConocoPhillips Alaska, Inc. USA December 28, 2008 Joint No. )t. Depth (Ft.) I'E~n. UE~S~~i (Ins.) Pen. Body (Ins.) I'c~n. `%, Mci.~l I oss °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 43.2 4491 ~~ 0 l) ~~ 3.90 Well Lift Discha e Sub 143.3 4494 ~~ 0.02 !~ I 3.94 PUP 143.4 4500 ! ~ 0.01 ! 391 PUP _ Penetration Body Metal Loss Body Page 4 ConocoPhillips Alaska, Inc. KRU 2T-208 2T-208 API: 501032051800 Well T : PROD An le TS: d TUBING (o-as2a, oD:a soo SSSV Type: NONE Orig Com letion: 1/21/2006 Angle @ TD: 87 deg @ 7654 . , ID:3.992) ~ Annular Fluid: Last W/O: 12!30/2006 Rev Reason: SHOW PUMP Reference L : 30' RKB Ref Lo Date: Last U ate: 10/13/2007 Last Ta TD: 7654 ftK6 Last Ta Date: Max Hole An le: 92 d 7287 asin Strin -ALL STRI NGS Descri lion Size To Bottom TV Wt Grede Thread CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED SURFACE 10.750 0 1689 1578 45.50 L-80 BTC PRODUCTION 7.625 0 5425 3114 29.70 L-80 BTCM LINER w/SCREENS 4.500 4944 7620 3142 12.60 L-80 13 CR Tubi Strin -TUBING Size To Bottom NO Wt Grade Thread 4.500 0 4624 2904 12.60 L-80 ESP EOT Perforations Summa Interval TVD Zone Status Ft 3PF Date T e Comment 5043 - 5126 3044 - 3062 83 99 1/16/2006 Screen Altemating screens/solid i INTAKE 5379 - 5420 3109 - 3114 41 99 1/16/2006 Screen Altemating screertslsolid 1 e (as~o-asa1, OD:5.130) 5423 - 6419 3114 - 3134 996 99 1/162006 Screen Alternating screens/solid 1 sEaL 6466 - 6508 3134 - 3134 42 99 1 /162006 Screen Altemating sixeens/solid (asst-arse, OD:5.130) 6511 - 7507 3134 - 3141 996 99 1/162006 Screen Alternating screens/solid j 7509 - 7551 3141 - 3140 42 99 1/162006 Screen Alternating screens/solid I e MOTOR (a5s5-aezo, Gas Lift Mendr els/Yalves oD:5.e2o) 3t MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2750 2145 CAMCO KBG-2-1R DMY 1.0 BK-5 0.000 0 2!30120 SENSOR 2 4440 2836 CAMCO KBG-2-1R SOV 1.0 BK-5 0.000 2000 1/13/2007 (~~~i Other u s ui .etc. -COMPLETION -POST W/O De th TVD T e De~ri lion ID 26 26 HANGER FMC HORIZONTAL TUBING HANGER 3.958 4491 2855 Discharge Sub WELL LIFT D-SCHARGE SUB 3.950 4500 2858 PUMP 4.5" ESP w/PACKOFF ASSEMBLY set 12282006 0.000 4570 2884 INTAKE PERFORATED CROSSOVER INTAKE 0.000 Pert 4581 2888 SEAL UPPER 8 LOWER TANDEM SEAL SECTION 0.000 (5oaa-st2s) 4595 2893 MOTOR CENTRILIFT 304 HP KMH 2290V/91A 0.000 4620 2902 SENSOR WELL LIFT SENSOR 0.000 4622 2903 Centralizer CENTRILIFT MOTOR CENTRALIZER 0.000 Other lu ui .etc. -LINER De th TVD T Deecri lion ID 4944 3016 PACKER BAKER SC-1 R 76A-40 LINER TOP PACKER 4.000 5332 3101 SEAL SEALBORE wNAM TOP SEALBORE 3.250 5377 3108 SEAL SEALBORE wNAM TOP SEALBORE 3.250 5421 3114 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6120 3136 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6464 3134 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6507 3134 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7506 3141 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7553 3140 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7593 3141 SEAL SEALBORE wNAM TOP SEALBORE 3.250 Pert (~`~8) SEAL (6507-6508, OD:4.960) 2T-208 (PTD# 205-187) Report Of Failed ESP Page 1 of 1 • Maunder, Thomas E (DOA) From: _ NSK Problem Welt Supv [n1617@conocophillips.com] Sent: Monday, December 15, 2008 9:25 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Welt Integrity Proj; CPF2 Prod Engrs Subject: 2T-208 (PTD# 205-187) Report Of Failed ESP Jim/Tom, Tabasco ESP producer 2T-208 (PTD# 205-187) went down on a high current alarm on 12/01/08 and subsequent testing indicated that the pump has an electrical short downhole. The well is tentatively scheduled to undergo a rig workover in the first quarter of 2009 and will remain shut in until that time. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Ofhce 907-659-7724 Cell 907-943-1720 Pager 907-659-7000 #909 12/15/2008 • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: ZT-208+PB l+PB2+PB3 July 7, 2008 AK-MW-4111438 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2T-208+PBl+PB2+PB3 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 5 0-103 -20518 -00, 70, 71, 72 2" x 5" TVD RESISTNITY & GAMMA RAY Logs: 1 Color Log 5 0-103 -20518 -00, 7 0, 71, 72 Digital Log Images 1 CD Rom 50-103-20518-00,70,71,72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~IG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~G/ii~t~~~ JllL 2 ~ 2D08 .~ Signed: ~ ~C.e ~~- • WELL. L®G TI8ANSIVIITTAL To: State of Alaska July 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2T-208 AK-MW-411143 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20518-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Axtch~~'age; Al`aska-99518 _{. Date; ~~A~NE~ JUL ~ ~ 2008 I Signed: ~b~' ~ ~~- ~l ~~~ ~1LL L®G TRANSMITT~. • To: State of Alaska July 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2T-208 PB1 AK-MW-411143 1 LDWG formatted CD Rom with verification listing. API#: 50-103 -20518-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish ~~N •~~~ ~ ~ ~~~~ 6900 Arctic Blvd. Anchor~e; Alaska 9951.8 Date: Signed: X05=1~~- 1~2r • WELL LOG TRANSMITTAL To: State of Alaska July 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2T-208 PB2 AK-MW-411143 1 LDWG formatted CD Rom with verification listing. API#: 5 0-103 -20518-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _. ~~~dN~o JUL 2 ~ 2008 Signed: ~bs"~~~ ~ / ~~ • WELL. L®G TRANSMITTAL, CJ To: State of Alaska July 3, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite I00 Anchorage, Alaska RE: MWD Formation Evaluation Data 2T-208 PB3 AK-MW-411143 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20518-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish ~~~, JI1L ~ ~ ~~~$ 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: -- - Signed: Okland, Howard D (DOA) From: Okland, Howard D (DOA) Sent: Tuesday, April 29, 2008 3:32 PM To: 'Sandra.D.Lemke@conocophillips.com' Subject: Digital Open Hole data for KRU 2T-208 Sandy, Our records show that no open hole logging data was submitted for KRU 2T-208 (API 50 103 20518 00 00) The Completion Report indicates the GR/Res, Dens/Neu OH logging was done. Please send over the digital OH logging data. Please also send over Blue line copies of the OH data. Please send over digital graphics files of the OH logs in the agreed upon .TIFF format. Directional surveys for the final hole and the 3 plugbacks have been submitted. Thank you for your attention in getting the missing data to us. Howard 793 1235 1 ~i~~b DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051870 Well NamelNo. KUPARUK RIV U TABS 2T-208 Operator CONOCOPHILLIPS ALASKA INC MD 7654 TVD 3144 Completion Date 1/21/2006 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GrlRes, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc Directional Survey /,~D D Asc Directional Survey ~ ED D Asc Directional Survey ED D Asc Directional Survey Well Cores/Samples Information: Samples No Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 30 7654 Open 4/17/2006 30 7594 Open 4/17/2006 PB 3 30 5642 Open 4/17/2006 PB 2 30 6732 Open 4/17/2006 PB 1 Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y I~ Daily History Received? ~ N Chips Received? 'ti'~~ Formation Tops ~ N Analysis STN Received? M -- - - - --- --- ---- --- - - Comments: l ~,~) I ~ .~ ~ ~r ~~ 1<`~'~.1u1`~. • ~ ~ ~' ~> '~'~ ~~ Compliance Reviewed. By: Date: API No. 50-103-20518-00-00 UIC N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'i1,~ REPORT OF SUNDRY WELL OPERATIC~~a 0~~ ~ Gas G©ns. Cofrarniss~an 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Othe~`,f~?'`,:°"~? Alter Casing ^ Pull Tubing Q 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 ^ 205-187 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20518-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' 2T-208 8. Property Designation: 10. Field/Pool(s): ADL 25569,25548 Kuparuk River Field /Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 7654' feet true vertical 3144' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 1659' 10-3/4" 1689' 1579' PRODUCTION 5395' 7-5/8" 5425' 3116' LINER W/SCREE 2676' 4-1/2" 7620' 3142' Perforation depth: Measured depth: 5043'-5126', 5379'-5420', 5423'-6419', 6466'-6508', 6511'-7507', 7509'-7551' true vertical depth: 3044'-3062', 3109'-3114', 3114'-3134', 3134'-3134', 3134'-3141', 3141'-3140' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4624' MD. Packers &SSSV (type & measured depth) Baker SC-1 R liner top packer @ 4944' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 4944'-7560' Treatment descriptions including volumes used and final pressure: 166 bblS 10% HCI 13. Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 239 12 214 -- 277 Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO 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: contact Jim nnis .Printed Name nnis Title Wells Group Engineer ~ ~ ~~' Signature a Phone rC~ D ~, ~r ~~,~~~/ Date / ~ `` 0 1 Pre ared aron All -Drake 263-4612 f/~ !t ~ 11 /A- tt ~F~. ~t=~ ~'~ ~ 2Q07 ,fib i• ~~ • a7 Form 10-404 Revised 04/2004 ~ ~ ~ t -'t E ~ \1 f_{ 1 p`~ Submit gin~IfJmy KRU 2T-208 ~c~~~+aPhlEips Ataska, (nC, "27-208 TUBING ~ API: 501032051800 _ Well T e: PROD _ An le TS: de (0-4624, ~, SSSV Type: NONE Orig Completion: 1/21/2006 Angle @ TD: 87 deg @ 7654 OD:4.500, ~ ID:3.992) ? Annular Fluid: Last W/O: 1213012006 Rev Reason: WORKOVER Reference Lo : 30' RKB Ref Lo Date: Last U date: 1/1/2007 Last Ta TD: 7654 ftKB Last Tap Date: Max Hole Angle: 92 deg @ 7287 Casing String -ALL STR INGS Descri tion Size To Bottom TVD VYt Grade Thread CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED SURFACE 10.750 0 1689 1578 45.50 L-80 BTC PRODUCTION 7.625 0 5425 3114 29.70 L-80 BTCM LINER w/SCREENS 4.500 4944 7620 3142 12.60 L-80 13 CR -- Tubing String -TUBING _ __ _ I, Size Top Bottom TVD Wt Grade Thread 4 500 p -162.1 290-1 12.60 L -30 ESP ~_i EOT @t`fOratltJnS SUn1fTt2ry INTAKE (as~aa5at OD:5.130) SEAL (4581-4595, OD:5.130) MOTOR (4595-4620, OD:5.620) SENSOR (as2aas22, OD:4.500) Perf (5043-5126) interval TVD Zone Status Ft SPF Date T e Comment 5043 - 5126 3044 - 3062 83 99 1/16/2006 Screen Alternating screenslsolid ie 5379 -5420 3109 - 3114 41 99 1/16/2006 Screen Alternating screens/solid ie 5423 - 6419 3114 - 3134 996 99 1/16/2006 Screen Alternating screens/solid ie 6466 - 6508 3134 - 3134 42 99 1/16/2006 Screen Alternating screens/solid i 6511 - 7507 3134 - 3141 996 99 1/16/2006 Screen Alternating screens/solid ie 7509 - 7551 3141 - 3140 42 99 1/16/2006 Screen Alternating screens/solid Pipe t `' "' Gas Lift Mandre~sJValves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2750 2145 CAMCO KBG-2-1 R DMY 1.0 BK-5 0.000 0 12/30/200 2 4440 2836 CAMCO KBG-2-1R DMY t0 BK-5 nnno 0 12/30/200 ,Other (plugs, eguip., etc.) -LINER DETAIL 5377 3108 SEAL SEALBORE wNAM TOP SEALBORE 3.250 5421 3114 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6120 3136 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6464 3134 SEAL SEALBORE wNAM TOP SEALBORE 3.250 6507 3134 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7506 3141 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7553 3140 SEAL SEALBORE wNAM TOP SEALBORE 3.250 7593 3141 SEAL SEALBORE wNAM TOP SEALB(~RE 3.250 Other (plugs, equip., etc.) - COMPLETION -POST W/O 3.950 0.000 Perf (6466-6508) ConocQPhillips Time Log Summary tNeJtview tNeb ReporTrng Wel{ Name: 2T-208 Job Type: RECOMPLETION __ Time Logs Date Fro~~i To Dur S. De th E, D~th Phase Code Subcodz T COM _ _ 12/15/2006 16:30 17:30 1.00 MIRU MOVE MOB P Move rig from 2T-203 to 2T-208. Spot ri over 2T-208 and level u . 17:30 18:30 1.00 MIRU MOVE RURD P Berm up cellar. 18:30 20:00 1.50 COMPZ WELCT OTHR P Rig-up lubricator and pull BPV - 20:00 00:00 4.00 COMPZ WELCT OTHR P Rig-up flowback tank, hammer up hardline. Make up well kill lines and pressure test to 2500 psi. Load pits with 200 bbls of 100 degree filtered seawater, re for well kill. 12/16/2006 00:00 01:30 1.50 COMPZ WELCT CIRC P Shut-in tubing pressure 70 psi. Shut-in casing pressure 110 psi. Pump 200 bbls of 100 degree filtered seawater on casing @ 5 BPM @ 60 psi. Shut-in and monitor well, welt on a vac. 01:30 02:00 0.50 COMPZ WELCT OTHR P Set BPV 02:00 06:00 4.00 COMPZ WELCT NUND P ND tree. NU BOPE. 06:00 10:00 4.00 COMPZ WELCT BOPE P Function and PT BOP rams, annular and choke manifold to 250/2500 psi. Pull TWC, RD test equip. BOP test waived by AOGCC (Lou Grimaldi) @ 1700 hrs on 12/15/06. 10:00 11:30 1.50 COMPZ RPCOA PULD P PJSM, flow check annulus, BOLDS, MU Idg jt, pull hgr to floor. No up drag with h r. U 90K. LD h r. Clear floor. 11:30 13:30 2.00 COMPZ RPCOh RURD P PJSM, Place line spoolers on rig floor, RU for tb ull. 13:30 20:30 7.00 4,612 0 COMPZ RPCOh PULD P PJSM, flow check, fluid column do approx 900 ft. 50 bbls to fill well. Commence POH 4 1/2 tbg ESP comp. Standing back 4.5" tubing in derrick. 20:30 00:00 3.50 COMPZ RPCOA PULD P Lay down pump assembly. All clamps and bands recovered. I-Wire damaged in two laces. 12/17/2006 00:00 02:30 2.50 COMPZ RPCOA PULD P Make up Baker seal assembly. RIH w/ seal assembly on 4.5" tubing from derrick. At 1100'MD found crushed tubing above make up collar. Inspect remaining tubing in derrick, found several more in same condition, decide to lay down all tubing originally ulled from well. 02:30 04:00 1.50 COMPZ RPCOR PULD T Lay down tubing in hole. - _ ~ _ e _ ~e -~~~ _ ~r ~ ~sf 2~ ~. - _ _ _~ r~ Time Logs - Date From To Dur _ S. De th E. De th Phase Code ' Subcode T COP/1 _ _ _ 12/17/2006 04:00 05:30 1.50 COMPZ RPCOh PULD T RIH w/ 4.5" tubing from derrick. 05:30 09:30 4.00 COMPZ RPC04 PULD T POOH laying down damaged 4.5" tubin . 09:30 15:30 6.00 COMPZ RPC06 PULD T Flow check, PJSM, load pipe shed with new 4 1/2 tbg, prepare same for RIH. 15:30 16:00 0.50 COMPZ RPCOh PULD T MU seal assy. Test /confirm tbg tongs accurate torque gauge, jaws not bindin . OK. 16:00 17:00 1.00 0 1,100 COMPZ RPCOt1 PULD T Flow check, PJSM, follow seal assy with sin les 4 1/2 tb to 1100 ft. 17:00 23:00 6.00 1,100 4,925 COMPZ RPCOh PULD P Cont RIH 4 1/2 tbg to 4925'MD. 23:00 00:00 1.00 4,925 4,948 COMPZ RPC06 PULD P Locate top of packer, continue in hole, locate NO-GO @ 4948'MD. Calculate s ace-out len th. 12/18/2006 00:00 00:30 0.50 4,948 COMPZ RPCOh PULD P Continue space-out. Up weight 85K Down 65K. 00:30 01:30 1.00 COMPZ RPCOti RCST P Pick-up landing joint, hanger with single joint. Make dummy run to verify space-out measurement. Need 30.43' of spacing for 10K compression, found sin le 'oint of that len th. 01:30 03:00 1.50 COMPZ RPCOh CIRC P Rig-up ASRC pump truck on casing, PT lines to 2500 psi. PJSM. Pump 70 bbls diesel down casing to fill void @ 3 BPM @ 80 psi. Land hanger, RILDS. Pumped another 12 bbls before seeing pressure, PT to 1500 psi. Monitor ressure 30 mins. Good test. 03:00 04:00 1.00 COMPZ RPCOR RURD P Set BPV 04:00 09:30 5.50 COMPZ RPCOh NUND P ND ROPE. NU tree and test to 5000 psi. Test successful.. Flow check, Set BPV. 09:30 10:00 0.50 COMPZ RPCOh RURD P PJSM, set crane, remove ESP spooler from ri floor. 10:00 14:00 4.00 COMPZ RPCOh RURD P Clean pits, prepare rig for move. Secure well. Release Nordic rig #3, 1400 hrs this date 12/18/2006 _. 2T-208 Well Events Summary • DATE Summary 12/21/06 JETTED SCREENS WITH SCALEBLASTER TOOL FROM 7560' TO 4944' WITH 166 BBLS 10% HCL. TWO PASSES WITH 240 BBLS FILTERED SSW. FP WELL WITH 30 BBLS DIESEL. ADDITIONAL 480 BBLS FILTERED SSW AND 50 BBLS DIESEL WILL BE PUMPED DOWN HOLE BY WELLS SUPPORT. r~ ~onoc Phitiips Time Log Summary WeIN?ew Web Re.7arting Well Name: 2T-208 Job Type: RECOMPLETION - 'I ~ Time Logs Date From To Dur S. De~th E. De th Phase Code Subcode T COM - - _ _ __ _- 12/27/2006 18:00 20:00 2.00 COMPZ MOVE MOB P Move rig from 2T-203 to 2T-208 20:00 22:00 2.00 COMPZ MOVE RURD P Accept rig at 20:00 hrs. Level Rig and continue to s of a ui ment 22:00 00:00 2.00 COMPZ WELCT NUND P Check well for pressure. IA has 0 psi, tubin is on a vac. ND Tree 12/28/2006 00:00 03:00 3.00 COMPZ WELCT NUND P PJSM. NU ROPE. 03:00 04:00 1.00 COMPZ WELCT BOPE P RU lines. Test BOPE. State witness waived by Chuck Scheve with AOGCC. Attempting to test blinds, leakin -off, no a arent surface leaks. 04:00 05:00 1.00 COMPZ WELCT BOPE T Trouble shoot leak. No surface leaks. Leak appears to be blanking plug, ma be enetrators in han er. 05:00 06:30 1.50 COMPZ WELCT BOPE P Test choke manifold and valves to 250 si & 3000 si while trouble shootin . 06:30 08:30 2.00 COMPZ WELCT BOPE T Test blinds with "running test", maintaining 1500 psi to 3000 psi with test pump. No surface leaks and blinds holding. Visually verify no leak thru penetrators or hanger body seals. Blanking plug leaking down hole, thru BPV. Remove blanking plug, appears not to have been fully made-up into landing thread for O-ring to seal. MU landing joint into hanger to continue testin . 08:30 10:30 2.00 COMPZ WELCT BOPE P Refill stack. Continue testing. Test upper pipe rams to 250 psi & 3000 psi. Test bag to 250 psi & 2500 psi, OK. Accumulator capacity test, OK. RD lines. Alerted Chuck Scheve, AOGCC Field Inspector, of testing problems with blanking plug, he OK'd continuing operations and testing blinds when out of hole. 10:30 11:00 0.50 COMPZ WELCT OTHR P Pull BPV. MU landing joint. BOLDS. 11:00 12:00 1.00 COMPZ RPCOR PULD P PJSM. Pull FMC hanger to floor, 85K# PU Wt. LDLJ. LD tubing hanger and joint below. RU to circulate. a• Time Logs _ _ Date From To Dur S De th E. De th Phase Cole Subcode T COM _ _ 12/28/2006 12.00 13:00 1.00 COMPZ RPCOh CIRC P .Pump 130 Bbls filtered 8.5 ppg Seawater down annulus, no returns up tubing. Pump 75 Bbls SW down tubing, no returns out annulus. Hole on vacuum. Plan to overfill hole while tripping tubing to assure no flow. RD lines. 13:00 13:30 0.50 COMPZ RPCOh RURD P Bring in Centrilift boxes and tools. 13:30 14:00 0.50 COMPZ RPCOh TRIP P POOH LD 11 joints of 4-1/2" tubing. 14:00 15:30 1.50 COMPZ RPCOh RURD P PJSM. RU crane. Remove empty ESP cable spool from spooler and rig. Remove 3/8" chemical injection tubing spool (near empty) from rig. Bring in new 3!8" SS tubing spool and set in spooler. Set new spool of ESP cable ins ooler on ri floor. 15:30 18:30 3.00 COMPZ RPCOti TRIP P Continue POOH standing back 4-1/2" tubing, 49 stands. Strap out. LD seal assembly. Filled hole with double pipe displacement plus 10 Bbls extra er hour. 18:30 21:00 2.50 COMPZ WELCT BOPE P Clear floor. RU to set test plug and test blind rams to 250/3000 si. 21:00 22:30 1.50 COMPZ RPCOh RCST P MU Perforated intake + 2 joints and pressure sub. MU TTC ESP and lower into erforated intake assembl . 22:30 00:00 1.50 COMPZ RPCOh SLKL P PJSM. RU slickline and set TTC ESP. 12/29/2006 00:00 02:30 2.50 COMPZ RPCOh SLKL P Set pack-off on top of Pump. Run test tool and test pack-off to 500 psi. Pull test tool and set slip stop. RD slickline 02:30 03:00 0.50 COMPZ RPCOA RCST P Stand pump assembly back in derrick. 03:00 07:00 4.00 COMPZ RPCOh RCST P MU motor assembly. Test motor for free spin and fill with oil. Terminate 3/8" capillary tubing at bottom of motor centrilizer for chemical in~ection. 07:00 09:00 2.00 COMPZ RPCOh RCST P RIH w/ tbg to 1800' MD. 60K down, 80K u .MEG each 1000'. 09:00 12:00 3.00 COMPZ RPCOh RCST P Cont RIH w/ 4.5" ESP completion from 1800' MD - 2064" MD (GLM #2 on stand #18. 12:00 17:00 5.00 COMPZ RPCOh RCST T MEG showed short toground - no apparent problem on surface. Start to POOH lookin for short. 17:00 20:00 3.00 COMPZ RPCOR RCST P Meter was hooked up backwards/polarity wrong - No problem w/ ESP cable. Repair armor that was peeled back at 2064' MD. Resume RIH 20:00 23:00 3.00 COMPZ RPCOM1 RCST P PU hanger and run in penetrators. S lice ESP cable. _ _-.-.- -°-._ . ~. _ .~ ~ _ _m®___ _._.__.__._~ I F:~~~ saf 3 i. ~.. __.__ _ __ ______~ _ _ _.. .~_._......._._ _._~_... _ ~_ ._.___.~__~ i r~ Time Logs Date From To Dur, S Depth E. Depth Phase Gode Subcode T COM __ 12/30/2006 00:00 01:00 1.00 COMPZ RPCO6 RCST P Finish splicing ESP cable to penetrator in hanger. Test ESP s lice. 01:00 02:30 1.50 COMPZ RPCOh DHEO P Test 3/8" chemical injection line at surface. Leaking just below penetrator on hanger. Change out fittings and re-test to 2500 si. 02:30 03:00 0.50 COMPZ RPCOh HOSO P Land Tubing hanger. Down wt 68K, Up wt 105k, blocks 39K. RILDS. LDLJ. Set BPV 03:00 04:00 1.00 COMPZ RPCOR OTHR P Breakdown 2 stands in derrick. Clean out its. 04:00 07:00 3.00 COMPZ RPCOh NUND P ND BOPE 07:00 07:30 0.50 COMPZ RPCOh DHEQ P Test ESP cable. Good test. 07:30 09:30 2.00 COMPZ RPCOh NUND P NU tree 09:30 10:30 1.00 COMPZ RPCOh OTHR P Test chemical injection line to 2500 psi for 10 min. Test Pack-off void 5000 si for 10 min. 10:30 12:30 2.00 COMPZ RPCOh NUND P Pull BPV, set TWC. Test tree 5000 si/10 min 12:30 13:00 0.50 COMPZ RPCOA OTHR P Pull TWC 13:00 14:30 1.50 COMPZ RPCOR FRZP P PJSM. RU LRS. Freeze protect w/ 70 bbls diesel down tubing and 75 bbls down IA. RD LRS 14:30 15:00 0.50 COMPZ RPCOA OTHR P Set BPV and dress tree. Release Rig ._ ...._.. -~ ~ _ ~-~ ~____ ~ ~ _ _ _ ~ _r-~d _. . , FW: 2t-208 PTD # 205-187 temporary gas lift of failed ESP producer Subject: FW: 2t-208 PTD # 205-187 temporary gas lift of failed ESP producer From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sat, 09 Sep 2006 07:18:04 -0800 `To: ASK ['r~~blem Wcll ~uin~ ~~_n1617~u.conocophillips.co~n=,, ~T~homas l~~laui~dcr ~~--toini~~aunder~a'aJmin.state.ak_uti=~, James Re<~~~ ~~=jimi~e~r~T<<<:ad«~in.stal~..ak.us: Tom, The gas lift test of 2T-208 failed ESP producer is complete. The well was SI on 9/7106. Initially the well made about 200 BOPD of flush production for the first few days of the gas lift test, but then dropped off rapidly with only gas lift gas returning to surface, confirming that a RWO is needed. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Sunday, August 27, 2006 6:49 PM To: 'Thomas Maunder'; James Regg Subject: 2t-208 PTD # 205-187 temporary gas lift of failed ESP producer Tom, and Jim CPAI began producing 2T-208 failed ESP producer with gas lift Aug 27th @ 14:24. We will produce the well temporarily for not more than 30 days. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 1 of 1 9/11/2006 8:04 AM 2t-208 PTD # 205-187 temporary gas lift of failed ESP producer Subject: 2t-208 PTD # 245-187 temporary gas lift of failed ESP producer From: NSK Problem Vi~ell Supv <n1617@conocophillips.com> Date: Sun, 27 Aug 2006 18:48:37 -0800 To: Thomas iVla~ir~citr ~=tommaunderr,~I';a~lmi~~.stat~.ak.us%. Jailles Rc~~~ ~jin~_rct~~~(iadmin.state.ak.us.. Tom, and Jim CPAI began producing 2T-208 failed ESP producer with gas lift Aug 27th @ 14:24. We will produce the well temporarily for not more than 30 days. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Ine. Office 907-659-7224 Cell 907-943-1244 1 of 1 9/11/2006 8:04 AM Re: 2T-208 (PTD 205-187) ESP failure -Request for temporary GL Subject: Re: ~"I~-208 (PTD 205-187) ESP failure -Request for temporary GL From: Tflonlas I~1ar:nder <tom matulder~u>admin.state.ak:us% Date: Thu, 10 Au~~ ?UU6 14:11:52 -0800 To: NSK Problc~l~ ~Vcll Supv <n1617(a)conocophillii~s.com~> CC: jim_re~~~(ua~~7~in.statc.ak.us Marie, Temporarily gas lifting 2T-208 for a maximum of 30 days is acceptable. Please keep us advised. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 8/10/2006 12:15 PM: Tom, Permission to temporarily gas lift 2T-208 for less than 30 days is requested for RWO diagnostic planning. A RWO is planned to repair the well as production performance has been considerably less than expected. A production test on gas lift is needed to evaluate if the ESP should be replaced or a gas lift completion should be installed. It is expected that the test on gas lift will be completed within 7 days, but might be extended a few days depending on how the test progresses. CPAI will notify AOGCC when gas lift production has started and again when the test has been completed. Previous emails reported that the ESP had failed; however after additional clarification, the ESP has not mechanically failed yet. The ESP will no longer be used to produce the well due to continual high temperature shut downs as the inflow from the reservoir is too low to cool the pump. It appears the formation was damaged somehow when the ESP was installed, but the cause of low inflow is uncertain until the ESP is removed. An attempt to slip stream water injection water down the IA to prime the ESP pump was partially successful. The well produced oil at about 300 BOPD, but still much lower than the AFE'd oil rate. Slip stream operations were conducted for only 1 week as temporary facilities were required. Due to the large capital expense required to install permanent slip stream facilities, engineering has decided to pursue a RWO instead to clean up the perfs or stimulate the well as needed to increase the production rate. Gas lift operations will commence once AOGCC approval is received. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Monday, August 07, 2006 2:15 PM To: 'Thomas Maunder' Subject: RE: 2T-208 (PTD 205-187) ESP failure I don't think they got the bugs ironed out of the slip stream before the pump quit. It worked while 1 of 3 8/10/2006 2:12 PM Re: 2T-208 (PTD 205-187) ESP failure -Request for temporary GL • they were doing it, however didn't get a longer term system in place in time - at least that is the word I hear from CPF2.... MJ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, August 07, 2006 1:49 PM To: NSK Problem Well Supv Subject: Re: 2T-208 (PTD 205-187) ESP failure That seems to have been the problem with 2T-208 from the earlier messages. Did you all ever get the water going down the annulus to helps the pump? Tom NSK Problem Well Supv wrote, On 8/7/2006 1:46 PM: Tom, I think the pumps were oversized and just didn't have the fluid to keep them going.,. but that is just an opinion and may not be fact... Have a good week. MJ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, August 07, 2006 12:08 PM To: NSK Problem Well Supv Subject: Re: 2T-208 (PTD 205-187) ESP failure MJ, Thanks. Unfortunately, looks like some pump problems on 2T. Tom NSK Problem Well Supv wrote, On 8/5/2006 1:50 PM: Tom, The ESP failed on 2T-208 {PTD 205-187) and will require a rig workover to repair. The well is now currently Sl. In the near future, ConocoPhillips intends to pursue 10-403 approval for gas lift for up to 2 years while waiting for workover rig. The well will remain SI until approval for gas lift is obtained. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043 Cel {907) 448-3114 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, June 01, 2006 9:01 AM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: Jim Regg 2 of 3 8/10/2006 2:12 PM Re: 2T-208 (PTD 205-187) ESP failure -Request for temporary GL Subject: Re: Concept question • MJ, BP has employed this technique on at least one well at Milne for a couple of years. I don't remember that there was any identified issue with the technique or that it was felt that there was a need for "formal" approval. In their case there was the added benefit of providing heat to the well. Call or message with any questions. Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 6/112006 8:55 AM: Tom, We have a recently drilled Tabasco well 2T-208 (PTD 205-187) that currently has an over sized ESP which continually to goes down as it pumps off. As part of our diagnostics we slip streamed produced water down the IA to keep fluid going through the pump. This option worked as long as we kept the slip stream going which confirmed that it was a pump size problem. We are now working on a concept to long term (until water break through in the reservoir ~ 6 mo to ~ 1 yr) slip stream PW down the IA to keep the pump on line. The slip stream would be analogous to the power fluid on a surface powered jet pump well using similar metering and tracking mechanisms. Before starting any conceptual work on facility modifications, we thought it would be prudent to review the slip stream concept with the AOGCC. Please let me know if a longer term slip stream of PW into the IA would be acceptable to the AOGCC. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 3 of 3 8/10/2006 2:12 PM • Conoco~illips April 7, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Report for 2T-208 (APD 205-187 / 305-397) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2T-208. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 263-6481. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4-'~E~%~ ~/ ~V WELL COMPLETION OR RECOMPLETION REPOF,~iTsi~-~+1®C~SQ~. Commission 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: ~n4iiflt~r~~L~ Development o Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: January 21, 2006 y 12. Permit to Drill Number: 205-187 / 305-397 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 19, 2005 ~ 13. API Number: 50-103-20518-00 4a. Location of Well (Governmental Section): Surface: 642' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ~ 7. Date TD Reached: January 12, 2006 / 14. Wel{ Name and Number: 2T-208 At Top Productive Horizon: 1144' FNL, 1560' FWL, Sec. 1, T11N, R8E, UM 8. KB Elevation (ft): 30' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 273' FSL, 1953' FEL, Sec. 36, T12N, R8E, UM 9. Plug Back Depth (MD + TVD): 7620' MD / 3142' TVD Tabasco Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498945 " y- 5970623 ' Zone- 4 10. Total Depth (MD + TVD): ~ 7654' MD / 3144' TVD 16. Property Designation: ADL 25569 & 25548 TPI: x- 499947 y- 5974116 Zone- 4 Total Depth: x- 501713 ~ - 5975533 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 2667/2662 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1566' MD 21. Logs Run: GR/Res, Dens/Neu 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" 62.58# H-40 30' 108' 30' 108' 24" 9 cu yds High Early 10.75" 45.5# L-80 30' 1689' 30' 1579' 13.5" 380 sx ASLite, 380 sx AS I 7-5/8" 29.7# L-80 30' 5426' 30' 3116' 9-7/8" 379 sx Class G 4.5" 12.6# 13Cr 4944' 7620' 3016' 3142' 6.75" screens 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 screens from: 4.5" 4614' 4944' 5043'-5126' and ' 5379'-5420' and 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5423'-6419' and DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6466'-6508' and abandonment plug 1:6282'-6732' and 277 sx Class G 6511'-7507' and abandonment plug 2: 5832'-6282' and 274 sx Class G 7509'-7551' and abandonment plug 3: 4000'-4592' and 369 sx Class G abandonment plug 4: 3400'-4000' and 396 sx Class G 26. PRODUCTION TEST Date First Production March 16, 2006 ~ Method of Operation (Flowing, gas lift, etc.) Oil producer Date of Test 3/29/2006 Hours Tested 15 hours Production for Test Period --> OIL-BBL 347 GAS-MCF 27 WATER-BBL 33 CHOKE SIZE 176 Bean GAS-OIL RATIO 112 Flow Tubing press. 301 psi Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 528 ~ GAS-MCF 59 WATER-BBL 51 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". - ,, ~ ~, ( P~~I~~ ~`~. ~,~~ ~ 2006 ! .z1- NONE '~~ °'~ ' _.~:.w Form 10-407 Revised 12/2003 (~ ~ ~ ~ ~ ~ A ~ CONTINUED ON REVERSE ~~ `C ~~d~n~ lJ /K, ~o V rr~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and brieFly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2T-208 Tabasco 5380' 3109' 2T-208PB1 TD 6732' 3542' N/A 2T-208PB2 TD 5640' 3119' 2T-208PB3 TD 7594' 3151' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 263-6481 Printed Napae__,,, Rand Thoma Title: Greater Kuoaruk Area Drilling Team Leader ~~ f, ~~ 6 ' > Zr,y ~-.~5 ~ Date ~~-~ Signature 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 ConocoPhillips Alaska Opera#ions Summary. Rep©rt Legal Well Name: 2T-208 Common Well Name: 2T-208 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillps.com Rig Name: Nordic 3 Date From - To 12/17/2005 06:00 -19:30 19:30 - 22:30 Hours Code 'Code Phase 13.50 3.00 22:30 - 00:00 ' 1.50 12/18/2005 ! 00:00 - 04:30 4.50 04:30 - 08:00 3.50 08:00 - 12:30 4.50 12:30 - 17:30 5.00 j 17:30 - 18:30 i 1.00 18:30-21:00 i 2.50 i 21:00 - 23:00 2.00 23:00 - 00:00 1.00 12/19/2005 00:00 - 00:30 I 0.50 00:30 - 01:00 i 0.50 1 i 01:00 - 12:00 I 11.00 ~ i 12:00 - 13:00 1.00 ~ 13:00 - 16:00 3.00 16:00 - 20:00 4.00 20:00 - 20:30 0.50 20:30 - 22:30 2.00 i i 22:30 - 00:00 ; 1.50 12/20/2005 100:00 - 01:30 I 1.50 01:30 - 02:00 , 0.50 02:00 - 04:30 ~ 2.50 04:30 - 06:00 1.50 06:00 - 12:00 6.00 12:00 - 18:30. 6.50 Page 1 of 15 Spud Date: 12/20/2005 End: 1 /21 /2006 Group: Description of ©perations MOVE i MOVE MOVE ~ Moved rig & camps 17 miles from 3J-101 to 2T-208. MOVE POSN SURFAC !Moved rig over well and level same, spot tanks, bermed up, Accepted rig at 22:00 hrs 12-17-05. WELCT NUND ; SURFAC Begin NU diverter and gun barrel. WELCT NUND ~ SURFAC Continue to nipple up diverter. DRILL ~ PULD SURFAC Rack & tally 5" drill pipe-HWDP & jars. DRILL '! PULD SURFAC 'Pick up & stand back 5" dp & hwdp. DRILL PULD SURFAC !Load 10 3/4" csg. in pipe shed, tally & drift same. Rig up 3" valves on ~ conductor. Rig up wire line sheave & weld down wire line unit. DRILL SFTY SURFAC Pre Spud meeting w/ crew & service hands. (While waiting on truck to bring sperry tools from deadhorse=truck broke down on way to I Deadhorse) DRILL PULD SURFAC ! Cont load 10 3/4" csg and float equipment, service rig and top drive. Total of 42 juts 10 3/4" casing loaded and strapped. Rig on highline at 20:30 hrs. DRILL PULD SURFAC Rack and Tally BHA #1 in pipeshed. DRILL PULD ~ SURFAC MU 13 1/2" bit #1 on 8" motor with 1.83 deg bend, flt sub and UBHO sub. " DRILL i PULD IF. SURFAC Cont MU UBHO sub and x/o to 4 1/2 DRILL ~ CIRC SURFAC ,Flood stack check for leaks, RIH from 40' and tagged cement inside ~ conductor at 102', cleaned out to btm of conductor at 108'. DRILL DRLG ~ SURFAC Spudded well at 01:00 hrs drilling 13 1/2" hole from 108' to 679' (571') ADT 5.37 hrs, AST 2.85 hrs, ART 2.52 hrs, 5-10K wob, 40 rpm's, 133 spm at 400 gpm and 350 psi, ROP 100' fph. Took Gyro surveys every I connection due to close approach of other wells. 400 gpm=104 rpm mtr. Up wt 48K, dwn wt 48K, rot wt 48K, torque on bolt 1,350 ft/Ibs, off bolt torque 1,000 ft/Ibs, 72.37 hrs on jars. DRILL TRIP SURFAC POOH from 679' for directional BHA. DRILL PULD SURFAC Fin MU BHA #1, PU MU MWD, oriented MWD and uploaded, PU ' 3-NMFDC s. DRILL DRLG SURFAC ~ Directionally drilled 13 1/2" hole from 679' to 858' MD. DRILL OTHR SURFAC Auger plugged due to large amounts of clay. Circ and recip while unplugging auger. DRILL DRLG SURFAC .Directionally drilled 13 1/2" hole from 858' to 990' MD/ 980' TVD. ADT ~ ! 3.3 hrs, AST 2.69 hrs, ART .61 hrs, 5-25K wob, 40 rpm's, 140 spm at 417 gpm and 960 psi, up wt 65K, dwn wt 65K, rot wt 65K, on bott torque 1,825 ft/Ibs, off bolt torque 900 ft/Ibs, 75.67 hrs on jars. DRILL OTHR SURFAC Stopped drilling and checked with Sperry Directional Coordinator and ( Well Planner on close approach at 1,500', while circ and recip. ' ' " ' DRILL DRLG MD/1,079 hole from 990 to 1,096 SURFAC Cont to directionally drilling 13 1/2 TVD, ART -0-hrs, AST 1.02 hrs, could not get desired build rate with ~ 1.83 deg bend motor. DRILL CIRC SURFAC Circ btms up DRILL TRIP SURFAC POOH from 1,096' and change motor angle from 1.83 deg to 2.38 deg. DRILL TRIP i SURFAC RIH washing last std to btm at 1,096' with no problems and no fill. DRILL DRLG ~ SURFAC :Directionally drilled 13 1/2" hole from 1,096' to 1,400' MD/1,351' TVD (304') ART .49 hrs, AST 3.04 hrs, 15-30K wob, 40 rpm's, 145 spm, 420 ~ gpm, off btm pressure 900 psi, on btm 1,150 psi, off btm torque 1800 ft-Ibs, on btm 3,200 ft-Ibs, rot wt 71 K, up wt 75K, do wt 65K. DRILL DRLG (SURFAC Directionally drilled 13 1/2" hole from 1,400' to 1,700' MD/1,585' TVD (300') ART .64 hrs, AST 4.1 hrs, 15-30K wob, 40 rpm's, 160 spm, 477 gpm, off btm pressure 1,260 psi, off btm torque 2,800ft-Ibs, on btm ~ j 3,750 ft-Ibs, rot wt 75K, up wt 85K, do wt 72K. Pumped weighted hi vis Start: 12/17/2005 Rig Release: 1/21/2006 Rig Number: 3 Printed: 3/31/2006 10:50:01 AM ConocoPhillips Alaska Page 2 of 15 Operations Summary Report Legal Well Name: 2T-208 Common Well Name: 2T-208 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillps.com Rig Name: Nordic 3 Date 'From - To Hours 'Code Sub j phase Code Start: 12/17/2005 Rig Release: 1/21!2006 Rig Number: 3 Spud Date: 12/20/2005 End: 1 /21 /2006 Group: Description of Operations 12/20/2005 12:00 - 18:30 6.50 ~ DRILL ' DRLG 'SURFAC sweep at TD (2# over MW) 18:30 - 19:45 I 1.25 DRILL CIRC SURFAC ~ Circ out weighted hi vis sweep, had 25% increase in cuttings back from 19:45 - 21:30 21:30 - 23:45 i 23:45 - 00:00 12/21!2005 , 00:00 - 00:45 1.751 DRILL iTRIP 2.251 DRILL (TRIP 0.251 DRILL i CIRC 0.75 ~, DRILL CIRC 00:45 - 01:30 I 0.75 I DRILL I TRIP 01:30 - 02:30 1.00 I DRILL (TRIP .RIH to 10' 07:15 - 08:30 1.25 DRILL ~ TRIP SURFAC RIH with cleanout BHA #3 from 10' with HWDP, jars and 5" DP, set I down 20K wt at 1,625', PU to 1,600' 08:30 - 09:00 0.50 DRILL CIRC SURFAC Est circ and washed down from 1,600' to TD at 1,700', did not see I anything at 1,625', circ at 400 gpm at 350 psi and 30 rpm's, after j I ~ tagging btm increased pump rate to 500 gpm at 530 psi and 40 rpm's, ~ i 'st wt up 65K, do wt 60K 09:00 - 10:00 ~ 1.00 DRILL CIRC ~ SURFAC Pumped 30 bbl weighted hi vis sweep and circ hole clean, had 10% increase in cuttings back from sweep, circ an add. btms up and was clean at shakers, circ at 167 spm, 500 gpm at 530 psi and 60 rpm's j sweep, Circ a total of 3X btms up and was clean at shakers, circ hole at 180 spm, 550 gpm, 1,450 psi and 40 rpm's SURFAC BROOH from 1,700' to 1,510'. Cont POOH wet on elevators to 613' with no problems. SURFAC ,RIH from 613' to 1,510'., tight at 1,510, kelly'd up and washed/reamed through tight spots at 1,510', 1,589' and 1,630'. Pumped 35 bbl weighted hi vis sweep. SURFAC Circ out weighted hi vis sweep, circ hole at 160 spm, 447 gpm, 1,260 psi and 40 rpm's. SURFAC ~ Cont circ out weighted hi vis sweep, had 25% increase in cuttings back from sweep, circ a total of 2X btms up and was clean at shakers, circ hole at 182 spm, 539 gpm, 1,530 psi and 40 rpm's SURFAC BROOH through tight spots at 1,630', 1,589', 1,510' and cunt to BROOH to 1,367' and blow down top drive. SURFAC POOH wet on elevators from 1,367' to 160', POOH to 160' standing back HWDP and Jars with no problem, at NMFDC's: 02:30 - 06:00 3.50 ~ DRILL i PULD I SURFAC LD XO and NMFDC's, downloaded MWD and fin LD 13 1/2" BHA #2, ~ 1 ' cleared rig floor 06:00 - 07:15 1.25 DRILL PULD SURFAC MU 9" Bull Nose Hole opener on 13 1/2" ghost reamer with float sub and did not see spot at 1,686 . 11:15 - 12:30 1.25 DRILL ( CIRC SURFAC Pumped 30 bbl hi vis sweep only and circ out of hole with no increase in cuttings back from sweep, circ a total of 2.5X btms up and was clean at shakers, circ at 500 gpm, 530 psi and 60 rpm's, rot wt 75K, up wt 75K, do wt 62K, 10.0 ppg MW in and 10.05 ppg MW out 12:30 - 14:30 2.00 DRILL TRIP SURFAC POOH wet on elevators from 1,700', stood back HWDP and jars POOH to ghost reamer, no problems POOH 14:30 - 15:30 1.00 DRILL PULD I SURFAC POOH LD 13 1/2" ghost reamer and 9" bull nose hole opener and ~ cleared rig floor 15:30 - 16:30 1 ~ 1.00 ~ CASE CA OTHR RD SURFAC FAC Made dummy run with FMC hanger and landing jt f ll l BR' 1 / " i t ith F k t 6:30 -19:00 2.501 i SE RU SUR ' w s i up 4 csg equ pmen ran oo RU G s 0 3 " 19:00 - 19:15 0.25 CASE j SFTY SURFAC Held PJSM on running order of 10 3/4 csg 19:15 - 21:00 I 1.75 CASE RUNC SURFAC MU 10 3/4" Shoe track and ck float equip, RIH with 20 jnts 10 3/4" csg ~ to 804'. 21:00 - 21:30 ~ 0.50 CASE CIRC SURFAC Est circ through Franks tool at 64 spm, 220 psi, staged pump up to 84 I i spm and 275 psi and CBU at 804'. 21:30 - 22:30 1.00 j CASE i RUNC SURFAC - Cont PU and RIH with 10 3/4" csg from 804' to 1,630' and set down 20K 22:30 - 00:00 % 1.501 CASE I CIRC f " SURFAC wt at 1,630'. Est circ staging pump to 80 spm 275 psi and washed dwn through tight 10:00 - 10:30 0.50 DRILL i WIPR SURFAC 'POOH wet 6 stds from 1,700' to 1,124' with no problems 10:30 - 11:00 i 0.50 DRILL WIPR .SURFAC RIH from 1,124', set 20K wt down at 1,686', PU to 1,600' 11:00 - 11:15 0.251 DRILL REAM SURFAC Est circ and washed down from 1,600' to btm at 1,700' with no rotation Printed: 3!31/2006 10:50:01 AM ConocoPhillips Alaska Page 3 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To Operations Summary Report 2T-208 2T-208 ROT -DRILLING n 1433@conocophillps.com Nordic 3 Hours I Code I, Sub Phase 12/21 /2005 ~ 22:30 - 00:00 12/22/2005 100:00 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:45 05:45 - 06:15 06:15 - 08:30 08:30 - 14:00 14:00 - 18:00 18:00 - 00:00 12/23/2005 (00:00 - 01:30 01:30 - 05:00 05:00 - 14:00 14:00 - 21:00 21:00 - 21:30 21:30 - 23:00 23:00 - 00:00 ;Code 1.50 ~ CASE CIRC SURFAC 2.50': CEMENTCIRC SURFAC i I 0.50 ~ CEMEN RURD SURFAC 1.OO CEMENl~CIRC SURFAC ~ ~ I 1.75! CEMENT PUMP (SURFAC 0.50 DISP I SURFAC 2.25 CEMENT RURD SURFAC 5.50 WELCTL NUND SURFAC 4.00 ~ WELCT(. NUND SURFAC i 6.00 WELCT NUND SURFAC 1.50 WELCT NUND SURFAC 3.50 DRILL OTHR SURFAC 9.00 DRILL PULD SURFAC 7.00 WELCT BOPE SURFAC i I ~ i 0.50' DRILL ~ OTHR SURFAC 1.50 i DRILL PULD SURFAC 1.00 DRILL OTHR SURFAC Spud Date: 12/20/2005 Start: 12/17/2005 End: 1/21/2006 Rig Release: 1/21/2006 Group: Rig Number: 3 ~ Description-of Operations spot at 1,630, MU hanger and washed down to btm at 1,689', landed hanger with float shoe at 1,689', ran total of 41 jnts (1,650) of 45.5# L-80, BTC csg, total csg float equip and hanger, 1,658', ran 16 bow spring centralizers and 3 stop rings as per well plan, st up wt 110K, do wt 65K Began circ and conditioning mud for cementing thru Franks fill up tool, ;staged pump rate up to 6.5 bpm at 300 psi., st wt up 110K, do wt 65K, j reciprocated pipe with full returns. RD Franks fill up tool, blew down top drive and MU Dowell's cement 'head. Fin circ and conditioning mud for cementing, conditioned mud in to 9.85 ppg, 50 vis, PV 23 and YP of 16, mud out at 9.8 ppg, 52 vis, 22 PV and 15 YP, circ at 6 bpm at 250 psi, st wt up 110K do wt 65K, held PJSM with Dowell, ASRC vac truck drivers, MI mud eng. and rig crew on cementing operations while circ. i Turned over to Dowell and cemented 10 3/4" csg, pumped 10 bbls of '~ CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an ~ additional 40 bbls of CW 100 (50 bbls total), then pumped 45 bbls of ~ 10.5 ppg mudpush, ave 4 bpm at 120 psi, dropped btm plug, began mixing and pumping Arcticset lite lead slurry, pumped 303 bbls (380 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.5 bpm at 140 psi, followed with 61.5 bbls (380 sxs) of Arcticset 1 tail cmt at 15.7 ppg and .93 yield with add., ave 6.8 bpm at 170 psi, reciprocated csg and had full returns, shut down and dropped top plug. Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 134 bbls of 9.85 ppg mud, displaced cmt at 7 bpm, initial circ pressure 275 psi, max pressure 445 psi, slowed rate to 4 bpm and bumped plug on calc displacement, pressured up to 1,050 psi, checked floats and held, CIP @ 06:10 hrs, had full returns during job and had 42 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 05:30 hrs, 40 bbls into tail cement when red dye in mud push was at surface, stopped reciprocating pipe and landed hanger with csg shoe at 1,689'. RD cement head and elevators, backed out and LD landing jt. Flushed out diverter and ND same, ND knife valve and 16" diverter line. Oriented and MU FMC 11" x 5K Unihead Csg Head, tested seals to 1,000 psi for 15 min and ck ok. PU and set 11" 5M BOP stack on wellhead and begin to NU same. Fin NU 11" 5M BOP stack, riser and turnbuckles, installed 7 5/8" csg rams in lower ram body Loaded pipe shed with 153 jts of 5" Dp and strapped same, serviced top drive PU, torqued up and stood back 51 stand of 5" DP I RU and tested BOPE, tested valves, choke manifold and rams including 7 5/8" csg rams to 250 psi low and 3,000 psi high then performed Koomey test, RD test equip and blew down top drive. Note: John Crisp W/AOGCC waived witnessing of test Installed wear bushing PU and MU 7" mtr with 1.5 deg bend and 9 7/8" bit #2, oriented same and RIH, could not get through the 10.880" x 10.380" x 50" long wear bushing with bit. POOH with mtr and pulled wear bushing. (bushing would not drift to 9.875") Printed: 3/31/2006 10:50:01 AM ConocoPhiNips Alaska Operations Summary Report. Legal Well Name: 2T-208 Common Well Name: 2T-208 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillps.com Rig Name: Nordic 3 Date ;From- To Hours Code '' Code Phase 12/24/2005 00:00 - 03:30 .03:30 - 05:00 3.501 DRILL ', PULD I SURFAC 1.50! DRILL (TRIP !SURFAC 05:00 - 06:00 06:00 - 07:15 07:15 - 08:30 .08:30 - 09:00 09:00 - 12:00 ~I 12:00 - 13:30 i 13:30 - 15:00 15:00 - 00:00 12/25/2005 00:00 - 12:00 i 12:00 - 23:00 1.00 I DRILL ;CIRC I SURFAC 1.25 CASE DEOT ~ SURFAC 1.25 DRILL i SFTY ~ SURFAC 0.50 DRILL TRIP i SURFAC 3.00 I CEMEN DSHO I SURFAC 1.501 DRILL !CIRC SURFAC 1.501 DRILL I LOT I SURFAC 9.001 DRILL !DRLG I INTRM1 12.00! DRILL !DRLG INTRM1 11.001 DRILL i DRLG I INTRMI 23:00 - 00:00 '. 1.001 RIGMNTI RGRP I INTRMI 12/26/2005 100:00 - 06:30 ' 6.501 RIGMNTI RGRP ! INTRM1 06:30 - 09:00 2.50'1 DRILL ! WIPR INTRM1 Page 4 of 15 Spud Date: 12/20/2005 Start: 12/17/2005 End: 1/21/2006 Rig Release: 1/21/2006 Group: Rig Number: 3 Description of Operations Fin MU BHA #4 and RIH to 204', oriented and uploaded MWD, held PJSM and loaded radioactive sources, PU 3-6 1/2" NMFDC's RIH to 204' RIH with HWDP and jars, MU 9 7/8" ghost reamer, installed wear bushing above reamer RIH setting same, cunt to RIH with BHA #4 to 1,132' Circ hole evening MW in and out for csg test at 9.6 ppg, circ at 83 spm, 247 gpm at 400 psi, st wt up 70K, do wt 65K RU and tested 10 3/4" csg to 3,000 psi for 30 min, good test Held stripping drill with rig crew RIH from 1,132' and tagged plugs at 1,603' (float collar at 1,604') Drilled out cmt plugs, float collar at 1,604', shoe track, float shoe at 1,689', cleaned out to 1,700' then drilled 20' of new hole to 1,720' MD/1 ,602' TVD, drilled out at 30 rpm's, 5-10K wob, 150 spm, 450 gpm at 1,050 psi, rot wt 70K, up wt 75K, do wt 65K Circ hole clean then displaced out 9.8 ppg spud mud with 8.8 ppg re-conditioned LSND mud, circ at 450 gpm at 850 psi, blew down top drive RU and performed a LOT to 11.2 ppg EMW with 200 psi at 1,579' TVD and 8.8 ppg MW Directionally drilled 9 7/8" hole from 1,720' to 2,296' MD/1,954' TVD (576'), ART 1.27 hrs, AST 3.78 hrs, ADT 5.05 hrs, 2-10K wob, 75 rpm's, 160 spur's, 477 gpm, on btm press 990 psi, on btm torque 4,830 ft-Ibs, off btm torque 4,100 ft-Ibs, up wt 90K, do wt 63K, rot wt 75K, with 9.0 ppg MW ECD ave 9.5 ppg, prior to drilling ahead, est clean hole ECD's, at 440 gpm clean hole was 9.0 ppg and at 550 gpm clean hole was 9.2 PP9, Directionally drilled 9 7/8" hole from 2,296' to 3,180' MD/ 2,321' TVD (884'), ART 4.5 hrs, AST 3.47 hrs, ADT 7.97 hrs, 5-10K wob, 75 rpm's, ave 165 spm, 490 gpm, off blur pressure 1,050 psi, on btm 1,150 psi, off blur torque 4,200 ft-Ibs, on blur torque 5,000 ft-ibs, rot wt 75K, up wt 90K, do wt 60K, 9.0 ppg MW, ave ECD 9.7 ppg, pumped 30 bbl hi vis sweep only at 3,000' with no increase in cuttings Directionally drilled 9 7/8" hole from 3,180' to 3,887' MD/ 2,588' TVD (707'), ART 2.86 hrs, AST 3.52 hrs, ADT 6.38 hrs, 5-20K wob, 55 - 75 rpm's, ave 165 spm, 490 gpm, off blur pressure 1,050 psi, on blur 1,150 psi, while rotating at times would bring pump rate up to 520 gpm at 1,350 psi, using lower rates to maintain angle, off blur torque 5,000 ft-Ibs, on blur torque 5,725 ft-Ibs, rot wt 78K, up wt 85K, do wt 75K, 9.1 ppg MW, ave ECD 9.9 ppg, pumped 30 bbl wt'd hi vis sweep (1# over MW) at 3,430' with 25% increase in cuttings. Top drive would not rotate, trouble shoot top drive while circ and recip at 150 spm, 447 gpm, 1,000 psi, st up wt 85K, do wt 75K. Cont trouble shooting top drive problem. Lower hydraulic pump on power pack locked up and stripped spline shaft. Locked out/tagged out power pack, removed bad pump and spline sleeve. Replaced sleeve and hydraulic pump, top drive working again at 06:30 hrs, circ hole at a reduced rate POOH slow to 3,715'. Wiped hole 15 stds from 3,715' to 2,365' with ghost reamer to 1,610' (10 3/4"Shoe @ 1,689'), POOH on elevators from 3,715' to 3,300' (5 stds) and hole swabbing slightly and not taking proper fill, BROOH fro 3,300' to 3,211' at 275 gpm, at 180 psi and 40 rpm's w/no problems, POOH wet on elevators from 3,211' to 2,365' with no problems, saw Printed: 3/31/2006 10:50:01 AM Con©coPhillips Alaska Opera#ions Summary Report Legal Well Name: 2T-208 Common Well Name: 2T-208 Event Name: ROT -DRILLING Contractor Name: n1433@conoco phillps.com Rig Name: Nordic 3 Date !From - To Hours Code 'Sub ' Phase 'Code 12/26/2005 06:30 - 09:00 i 2.50 DRILL WIPR INTRM1 09:00 - 10:00 1.00 DRILL ~ WIPR INTRM1 10:00 - 11:00 1.00 DRILL I I CIRC INTRM1 i j 111 00 00 00 13 00 DRILL I DRLG INTRMI : - : ~ . ~ 4 j ~ 12/27/2005 00:00 - 12:00 12.00 DRILL DRLG INTRMI I ~ 12:00 - 00:00 12.00 i DRILL I i I 'DRLG INTRM1 ~ 12/28/2005 00:00 - 12:00 12.00 DRILL DRLG INTRMI 12:00 - 12:45 12:45 - 14:45 14:45 - 15:30 15:30 - 22:45 22:45 - 00:00 12/29/2005 ~ 00:00 -04:30 I i 104:30 - 06:30 0.751 I DRILL CIRC INTRMI i 2.00 DRILL REAM INTRM1 0.75 DRILL CIRC INTRM1 7.25 DRILL i j TRIP ~ INTRM1 I 1.25 DRILL OTHR i ;INTRMI 4.50 ~ i DRILL PULD ~ INTRMI 2.00' CEMEN1t RURD INTRM1 Page 5 of 15 Spud Date: 12/20/2005 Start: 12/17/2005 End: 1/21/2006 Rig Release: 1/21/2006 Group: Rig Number: 3 Description of Operations slight swabbing effect as ghost reamer went thru shoe and ave 10-15K drag POOH, no other problems POOH to 2,365' RIH from 2,365' to 3,778' with no problems Washed down from 3,778' to 3,860' and pumped a 30 bbl weighted hi vis sweep (1# over MW) and circ out of hole, had a 25% increase in cuttings back from sweep, circ hole at 173 spm, 515 gpm, 1,250 psi, 70 rpm's with 5,000 ft-Ibs off btm torque, rot wt 75K, ECD after sweep was out of hole had 9.0 ppg mw in and 9.1 ppg mw out with an ECD of 9.65 ppg, then washed down from 3,860' to 3,887' with no problems Directionally drilled 9 7/8" hole from 3,887' to 4,999' MD/ 2,842' TVD (1,112'), ART 5.22 hrs, AST 3.08 hrs, ADT 8.3 hrs, 5-10K wob, 55 - 75 rpm's, ave 165 spm, 500 gpm, off btm pressure 1,400 psi, on btm 1,550 psi, off btm torque 7,500ft-Ibs, on btm torque 8,000 ft-Ibs, rot wt 76K, up wt 105K, do wt 62K, 9.1 ppg MW, ave ECD 10.1 ppg, pumped 30 bbl wt'd hi vis sweep (1# over MW) at 4,650' with 25% increase in cuttings. Directionally drilled 9 7/8" hole from 4,999' to 5,913' MD/ 3,067' TVD (914'), ART 6.51 hrs, AST 1.38 hrs, ADT 7.89 hrs, 5-12K wob, 75 rpm's, 180 spm, 540 gpm, off btm pressure 1,500 psi, on btm 1,650 psi, off btm torque 6,000ft-Ibs, on btm torque 8,500 ft-Ibs, rot wt 80K, up wt 110K, do wt 65K, 9.2 ppg MW, ave ECD 10.3 ppg, pumped 30 bbl wt'd hi vis sweep (1# over MW) at 5,800' with no increase in cuttings. Directionally drilled 9 7/8" hole from 5,913' to 6,358' MD/ 3,289' TVD (445'), ART 3.21 hrs, AST 5.20 hrs, ADT 8.41 hrs, 5-12K wob, 75 rpm's, 180 spm, 540 gpm, off btm pressure 1,500 psi, on btm 1,690 psi, off btm torque 10,000ft-Ibs, on btm torque 12,000 ft-Ibs, rot wt 89K, up wt 155K, do wt 65K, 9.1 ppg MW, ave ECD 10.2 ppg, drilling thru hard spots and torque increasing while dropping angle Directionally drilled 9 7/8" hole 6,358' to 6,732' MD/ 3,542' TVD (374'), (Pilot Hole TD) ART 7.16 hrs, AST 2.2 hrs, ADT 9.36 hrs, 10-20K wob, 75 rpm's, 186 spm, 550 gpm, off btm pressure 1,550 psi, on btm 1,700 psi, off btm torque 12,000ft-Ibs, on btm torque 13,500 ft-Ibs, rot wt 95K, up wt 190K, do wt 65K, 9.0 ppg MW, ave ECD 10.0 ppg, had no trouble sliding, cont to drill thru hard spots and torque increased while dropping angle, pumped 30 bbl hi vis sweep Fin circ hi vis sweep out of hole, saw no increase in cuttings from sweep, circ out at 550 gpm, 1,550 psi and 75 rpm's Precautionary backreamed out of hole 9 stds thru the Tabasco sand from 6,732' to 5,944' with no problems, BROOH at 75 rpm's, 550 gpm at 1,600 psi Circ 1 1/2 X btms up at 5,944' and was clean at the shakers, circ at 550 gpm at 1,700 psi, 9.0 ppg mw in & out, rot wt 85K, up wt 155K do wt 52K Monitored well-static, POOH wet 5 stds from 5,944' to 5472' and blew down top drive, POOH wet 10 more stds to 4530 and hole took talc fill, pumped dry job and cont POOH to BHA and LD ghost reamer and stood back HWDP & jars to 265' RIH with wear bushing puller in DP string, drained stack and pulled wear bushing. POOH from 265', stood back NMFDC's, held PJSM and removed radioactive sources, downloaded MWD and LD remaining BHA, cleared rig floor Changed out handling tools on rig floor to 3 1/2" tbg and installed wear bushing Printed: 3/31/2006 10:50:01 AM ConocoPhiiiips Alaska Page 6 of 15 Operations Summary Report Legal Well Name: 2T-208 Common Well Name: 2T-208 Spud Date: 12/20/2005 Event Name: ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 Contractor Name: n1433@conocophillps.com Rig Release: 1/21/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date ~ From - To Hours Code 'Code -_ 12/29/2005 j _ 06:30 - 07:45 ~ 1.25 ~ CEMEN1 _- r PULD 07:45 - 08:15 0.50 CEMEN RURD 08:15 - 11:00 2.75 . CEMEN TRIP 11:00 - 13:15 2.25 CEMEN CIRC 13:15 - 13:45 ' 0.50 CEMEN7RURD 13:45 - 14:30 0.75 CEMEN'If PUMP ' 14:30 - 15:15 15:15 - 18:30 18:30 - 19:00 119:00 - 20:30 20:30 - 21:30 21:30 - 21:45 21:45 - 22:30 22:30 - 23:30 23:30 - 00:00 12/30/2005 i 00:00 - 01:00 01:00 - 01:30 01:30 - 03:15 Phase INTRM1 INTRM1 I NTRM 1 INTRM1 INTRM1 INTRMI 0.75 CEMENT~TRIP INTRM1 3.25 CEMEN CIRC INTRM1 i i 0.50. CEMEN PUMP INTRM1 I I I 1.50 CEMEN TRIP INTRM1 1.00 CEMEN CIRC INTRM1 i I 0.25 CEMEN TRIP INTRM1 0.75 CEMEN PUMP i INTRMI i 'i 1.00 CEMEN TRIP INTRM1 0.50 j CEMEN CIRC INTRM1 1.00 CEMENTPUMP ; INTRM1 0.50 CEMENTIITRIP ;INTRMI 1.75 CEMENlf CIRC INTRM1 Description of Operations Held PJSM then PU and RIH with 35 jts of 3 1/2", 9.3#, L-80 EUE-8rd tbg to 1,100' Changed handling tools back to 5" DP RIH with 3 1/2" cmt stinger from 1,100' to 6,638' Washed down from 6,638' to btm at 6,732' with no problems, cont to circ hole and cond. mud for setting cement plug, circ at 430 gpm at 550 psi, st wt up 120K, do wt 55K, circ hole evening MW in and out at 9.3 ppg, held PJSM with rig crew and Dowell on setting of cement plugs while cond. mud MU pump in sub and Dowell's cement line, blew down top drive Turned over to Dowell and pumped 5 bbls water, pressure tested lines to 3,500 psi, cont to pump 5 add. bbls of water, mixed and pumped 57.8 bbls (277 sxs) of 15.8 ppg, 1.17 yield cement with additives, ave 4.5 bpm, ave 200 psi, followed with 2.5 bbls of water, turned over to rig and pumped 100 bbls of 9.3 ppg mud to balance plug, ave 6 bpm at 600 psi, CIP at 14:25 hrs, est TOG at 6,282', had full returns during job and reciprocated pipe throughout job. POOH from 6,732' and stood back 5 stds of 5" Dp, RIH with 1 single of DP to 6,282' Circ btms up at 6,282', at btms up had approx 80 bbls of cmt contaminated mud back to surface, circ hole and cond. mud for next cement plug, circ hole at 420 gpm at 1,000 psi, st wt up 110K, do wt 52K, circ hole evening MW in and out at 9.2 ppg. DoweN and pumped 10 bbls water, then mixed and pumped 57 bbls (274 sxs) of 15.8 ppg, 1.17 yield cement with additives, ave 4.5 bpm, ave 145 psi, followed with 2.5 bbls of water, turned over to rig and pumped 91 bbls of 9.2 ppg mud to balance plug, ave 9 bpm at 1,100 psi, CIP at 19:00 hrs, est TOC at 5,832', had full returns during job. Cement volumes talc. on 9 7/8" hole with 35% excess POOH 15 stds from 6,282' to 4,875' Circ btms up at 4,875', 420 gpm, 970 psi. spot 35 bbl. hi-vis sweep F/ 4875' to 4592' had app 50 bbl. cement contaminated mud back to surface, POOH F/ 4875' to 4592' Dowell and pumped 10 bbls water, then mixed and pumped 77 bbls (369 sxs) of 15.8 ppg, 1.17 yield cement with additives, ave 4.5 bpm, ave 145 psi, followed with 2.5 bbls of water, turned over to rig and pumped 60 bbls of 9.2 ppg mud to balance plug, ave 8 bpm at 1,000 psi, CIP at 22:30 hrs, est TOC at 3997', had full returns during job. Cement volumes talc. on 9 7/8" hole with 35% excess POOH F/4592' to 3997' Circ btms up at 3997', 420 gpm, 970 psi. had app. 40 bbl. cmt contaminated mud to surface Dowell and pumped 10 bbls water, then mixed and pumped 76 bbls (369 sxs) of 15.8 ppg, 1.17 yield cement with additives, ave 4.5 bpm, ave 100 psi, followed with 2.5 bbls of water, turned over to rig and pumped 50 bbls of 9.2 ppg mud to balance plug, ave 9 bpm at 1,100 psi, CIP at 00:45 hrs, est TOC at 3400', had full returns during job. Cement volumes talc. on 9 7/8" hole with 35% excess. NOTE: Jeff Jones with AOGCC waived witnessing of plug placement and tagging of plug for sidetracking. POOH from 3,997' to 3,400', POOH 6 stds and a double Dropped DP wiper dart and circ 2X btms up to circ hole clean, at btms Printed: 3/31/2006 10:50:01 AM ConocoPhillips Alaska Page 7 of 15 Opelrations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/30!2005 ~ 01:30 - 03:15 2T-208 2T-208 Spud Date: 12/20/2005 ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 n1433@conocophillps.com Rig Release: 1/21/2006 Group: Nordic 3 Rig Number: 3 Hours I Code Code 1.75 ~ CEMENl~ CIRC 03:15 - 05:00 1.75 ~ CEMENl ~TRIP i 05:00 - 05:45 05:45 - 07:30 07:30 - 08:30 '~ 0.75 1.751 1.00 ~ CEMEN~ CEMENTI CEMENl RURD PULD f RURD 08:30 - 10:30 2.00 DRILL II PULD 10:30 - 13:30 3.00 , RIGMNT! RSRV 13:30 - 14:15 0.75 14:15 - 14:30 0.25 14:30 - 18:30 4.00 ;18:30-19:15! 0.75 19:15 - 19:30 0.25 19:30 - 23:00 3.50 23:00 - 23:30 0.50 23:30 - 00:00 0.50 12/31 /2005 i 00:00 - 02:00 i 2.00 02:00 - 03:00 I 1.00 03:00 - 12:00 1 9.00 12:00 - 00:00 I 12.00 1 /1 /2006 ~ 00:00 - 08:30 ' 8.50 08:30 - 09:15 ~ 0.75 09:15 - 12:00 I 2.75 DRILL PULD DRILL SFTY DRILL ~ PULD DRILL j OTHR DRILL ~ DEOT DRILL I TRIP Phase INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRMI DRILL CIRC INTRM1 DRILL DRLG INTRMI DRILL I DRLG I INTRM1 DRILL CIRC INTRM1 DRILL I DRLG I INTRM1 DRILL i DRLG I INTRM1 DRILL I DRLG INTRM1 DRILL CIRC INTRM1 DRILL I DRLG .INTRM1 Description of Operations up had approx 40 bbls of cement contaminated mud, circ hole at 460 gpm at 1,000 psi. POOH from 3,400' to 3 1/2" stinger at 1,100', cleaned off excess clay on 5" tool jts RD 5" DP handling tools and PU 3 1/2" tools POOH LD 35 jts of 3 1 /2" cement stinger RD 3 1/2" handling tools and RU 5" tools RIH with 16 stds of excess DP from derrick and POOH LD same Slip and cut 42' of drlg line, changed out top drive saver sub, serviced top drive, blocks and drawworks Pulled wear bushing Held PJSM on MU BHA #5 M/U Bha # 5 M/U wear ring installing tool in string and set same & rilds M/U topdrive and test mud motor @ 500 gpm, 900 psi. RIH with BHA #5 ,tag bridge @ 2590', M/U top drive and orient mud motor and work through and continue to RIH to 3,385' and tagged cmt. Setting down 20K st wt. Circ bottoms up at 3,386 357 gpm, 800 psi, 98k up, 65k do Drilled out cement plug from 3,385' to 3,400' with 5K WOB, 45 rpm's, 357 gpm at 800 psi Cont to drill out cement from 3,400' to 3,450', 3-5K wob, 45 rpm's, 357 gpm, 650 psi, rot wt 75K, up wt 98K, do wt 65K Trenched low side of hole from 3,420' to 3,450' Time drilled to sidetrack well from 3,450' to 3,465' (15' in 6 hrs) displaced hole over to recond. mud while time drlg, directionally drilled 9 7/8" hole from 3,465' to 3,555' MD/ 2,483' TVD (90'), AST 7.33 hrs, ART .45 hrs, 5-10K wob, 35 rpm's, 147 spm, 440 gpm, off btm pressure 950 psi, on btm pressure 1,100 psi, off btm torque 3,900 ft-Ibs, on btm 4,900 ft-Ibs, rot wt 75K, up wt 105K, do wt 65K, 8.9 ppg MW, ave ECD 9.5 ppg Directionally drilled 9 7/8" hole from 3,555' MD, 2483' TVD to 4309' MD, 2788 TVD, (754') ART 4.82 hrs AST 3.12 hrs. TQ on bottom 7100 Ft-Ib, TO off bottom 7400 Ft-Ib, rot wt 81 k, up wt 115k, do wt 65k, 9.0 ppg mw, ECD Avg 9.6 ppg. 10.15 k wt on bit, 70 rpms, 180 spm, 530 gpm, 1650 psi Pumped 40 bbl. Hi-vis sweep weighted 1 ppg over mw @ 4415' seen small increase in cutting in return . Directionally drilled 9 7/8" hole from 4,309' to 4,881' MD/2,989' TVD (572'), ART 3.66 hrs, AST 2.6 hrs„ pumped weighted hi vis sweep at 4,430' with very little increase in cuttings back, 9.0 ppg MW ave ECD 10.25 ppg Pumped weighted hi vis sweep at 4,881' (1# over MW) with 2 drums lubetex and nut plug and circ out of hole, had 100% increase in cuttings back from sweep, mostly clay, circ hole at 555 gpm at 1,800 psi and 75 rpm's, ECD before sweep was 10.4 ppg, ECD after sweep was 10.0 ppg, saw 1 K to 1,500 ft-Ib reduction in torque after sweep. Directionally drilled 9 7/8" hole from 4,881' to 5,002' MD/ 3,021' TVD (121') ART .65 hrs AST 1.27 hrs. 10-15K wob, 70 rpm's, while sliding ave 450 gpm at 1,100 psi, rotated at 180 spm, 550 gpm, off btm pressure, 1,600 psi, on btm 1,750 psi, off btm torque 7,000 ft-Ibs, on btm 8,500 ft-Ibs, rot wt 83k, up wt 115k, do wt 65k, ave mw 9.0 ppg Printed: 3/31/2006 10:50:01 AM ConocoPhitlips Alaska Page 8 of ~5 Operations .Summary Rep©rt Legal Well Name: 2T-208 Common Well Name: 2T-208 Event Name: ROT -DRILLING Contractor Name: n1433@conocophillps.com Rig Name: Nordic 3 Spud Date: 12/20/2005 Start: 12/17/2005 End: 1/21/2006 Rig Release: 1/21/2006 Group: Rig Number: 3 Date -From - To !Hours Code Sub r'j Phase Code - 1/1/2006 ~ 09:15 - 12:00 ' 2.75 ~ -- _ _ ' DRILL _ DRLG ~ INTRM1 12:00 - 00:00 i 12.00 DRILL !DRLG i INTRM1 1/2/2006 ~ 00:00 - 01:00 ~ I'~ 1.00 ~ DRILL DRLG I INTRMI ~I 01:00 - 02:00 1.00 ~ DRILL CIRC ~ i , INTRM1 02:00 - 03:15 I 1.25 ~ DRILL TRIP ~ INTRMI 03:15 - 05:15 2.00 ~ DRILL CIRC INTRM1 05:15 - 12:00 ! 6.75 i DRILL I DRLG I INTRMI 12:00 - 21:00 I 9.00 i DRILL I DRLG I INTRM1 21:00 - 21:30 I 0.501 DRILL !:CIRC I INTRM1 21:30 - 00:00 2.501 DRILL j DRLG I INTRMI 1/3/2006 i 00:00 - 01:00 I 1.00 i DRILL I DRLG I INTRM1 01:00 - 03:00 I 2.001 DRILL I CIRC I INTRM1 03:00 - 05:45 2.751 DRILL .WIPR INTRM1 05:45 - 07:30 1.751 DRILL WIPR INTRM1 07:30 - 08:00 ~ 0.50 RIGMNT RSRV INTRM1 08:00 - 10:30 2.50 DRILL ~ CIRC INTRMI 10:30 - 11:30 1.00 DRILL ~ TRIP I INTRM1 11:30 - 16:00 4.50 DRILL TRIP i INTRM1 16:00 - 16:30 0.50 DRILL OTHR !INTRMI Description of Operations mw, ECD avg 10.2 ppg. Directionally drilled 9 7/8" hole from 5,002' to 5,608' MD/3,115' TVD (606'), ART 3.09 hrs, AST 4.11 hrs, 20k wob, 75 rpm's, while sliding avg 450 gpm, at 1,125 psi, drilling @ 180 spm, 550 gpm at 1,800 psi, off bottom torque 7100 ft/Ib, on btm, 9,000 ft/Ib, rot wt 80k, up wt 120k, do wt 60k ,ECD avg 10.19 ppg. Pumped weighted hi vis sweep at 5,235' with 50% increase in cuttings back from sweep. Directionally drilled 9 7/8" hole 5,608' to 5,641' MD/3,118' TVD (33'), ART .8 hrs, AST -0- hrs, 20k wob, 75 rpm's, while sliding avg 450 gpm, at 1,125 psi, drilling @ 180 spm, 550 gpm at 1,800 psi, off bottom torque 7100 ft/Ib, on btm, 9,000 ft/Ib, rot wt 80k, up wt 120k, do wt 60k , ECD avg 10.2 ppg. Circ hole evaluating logs for geology, decis'son was made to POOH to 4,812' and do a open hole sidetrack POOH from 5,641' to 4,750' with no problems Trenched low side of hole from 4,750' to 4,812' in preparation for open hole sidetrack Time drilled to sidetrack well from 4,812' to 4,820' (4 hrs), then directionally drilled 9 7/8" hole from 4,820' to 4,860' MD/ 2,989' TVD, AST 6.52 hrs, ART -0- hrs, 20K wob, -0- rpm's, 143 spm, 426 gpm, off btm pressure 900 psi, on btm 1,000 psi, st wt up 115K, do wt 70K, 8.9 ppg mw ave ECD 9.3 ppg Directionally drilled 9 7/8" hole from 4,860' to 5264' MD/ 3088' TVD, 180 spm, 536 gpm, 75 rpm, 1700 psi. TQ on bottom 8500 ft/Ib, TQ off bottom 7800, WOB 20-25k, Up wt 120k, Dn wt 65k, Rot 85k, ECD Avg 9.9 ppg. ART .2 hrs AST 4.98 hrs Circ 1 ppg over original mw sweep around had approximately 75 increase in cuttings returns, Circ rate 566 gpm, pump pressure psi at start 1740 psi. sweep out of hole pp 1700 psi. Directionally drilled 9 7/8" hole F/5264' MD, 3088' TVD, to 5355' MD 3104' TVD, 180 spm, 536 gpm, 75 rpm, 1700 psi. TO on bottom 8500 ft/Ib, TO off bottom 7800, WOB 20-25k, Up wt 120k, Dn wt 65k, Rot 85k, AST .4 hrs ART .8 hrs Directionally drilled 9 7/8" hole F/5355' MD, 3104' TVD, to 5436' MD 3118' TVD, 180 spm, 536 gpm, 75 rpm, 1700 psi. TO on bottom 8500 fUlb, TQ off bottom 7800, WOB 20-25k, Up wt 120k, Dn wt 65k, Rot 85k, ART .3hrs AST .7 hrs Circ 40 bbl. Weighted Hi-Vis sweep around and 2X bottoms up, 180 spm 536 gpm, 90 rpm, 1500 psi. reciprocate throughout circulation Wiper TOH to 2900' seen normal overdrag, pulled on elevators did not use topdrive. Wiper TIH to 5436' (No problems, no noticeable fill on bottom) Service Rig Circ Hi-Vis sweep aroung and 2X bottoms up @ 507 gpm, 170 spm, 1400 psi, 75 rpm, reciprocate pipe throughout circulation Pooh 5 stds ,Normal drag, pump dry job POOH to 726' and stand back 5 stds of HWDP Pull wear bushing Printed: 3/31/2006 10:50:01 AM ConocoPhiilips Alaska Page 9 of 15 Operations Summary Report Legal Well Name: 2 T-208 Common W ell Name: 2 T-208 Spud Date: 12/20/2005 Event Nam e: ROT -D RILLING Start: 12/17/2005 End: 1/21/2006 Contractor Name: n 1433@ conocop hillps.c om Rig Release: 1/21/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date -From - To I, Hours Code Cod ehase Description of Operations 1/3/2006 ~ 16:30 - 19:30 3.00 DRILL PULD ~ INTRM1 ~ Lay down Bha #4 ,and down load MWD data 19:30 - 20:00 0.50 CASE DEQT INTRMI P/U hanger on landing jt and RIH and drift to landing ring in wellhead 20:00 - 20:30 0.50 CASE ; SFTY INTRM1 PJSM with all employees involved in 7 5/8" csg running operation 20:30 - 22:30 ' 2.00 ~ CASE RURD INTRM1 , Rig up GB&R and Rigs csg running equipment. 22:30 - 23:00 i 0.501 CASE RUNC ~ INTRM1 I p/U and make up Jts # 1 through #3 and circulate through float i ' equipment and check same (ok) 23:00 - 00:00 1.00 CASE RUNC INTRM1 Run 7 5!8" 29.7# L80 BTC csg. 21 jts. in hole @ 00:00 hrs 900' 1/4/2006 00:00 - 01:30 i 1.50 CASE ~ RUNC INTRM1 RIH w/ 7 5/8" csg. 01:30 - 02:00 0.50 ~ CASE ~ CIRC INTRMI CBU @ 10 3/4" shoe 33 spm 250#. i 02:00 - 07:30 ' 5.50 i CASE I RUNC ~, INTRM1 Fiish running 126 jts. 7 5/8" csg. 29.7 Ib/ft L80 BTC set @ 5425' MD, 3116' TVD 07:30 - 08:15 0.75 CASE I RURD ~ INTRM1 Rig down Franks circ. tool-slips & Rig top drive. 08:15 - 10:15 I , 2.00 CASE ; CIRC INTRM1 Circ. condition mud for cementing @ 6 bpm. 10:15 - 12:00. 1.75 ~ CEMENIT PUMP INTRM1 R/U BJ pump 10.2 H2O, @ 4 bpm, Test liines to 3588 psi, pump 30 j ~ ; bbl. CW 100 @ 4.4 bpm, +50 bbl. ' MP11 10.5 ppg, 150 bbl. Class "G" (379 sxs) mixed at 12.5 ppg. Displaced with 20 bbl. H2O +225 bbl. mud with rig pump @ 6 bpm, slowed to 3 bpm 600 psi ,bumped plug correct displacement to 1200 psi. ~ I ~ held 1-min, released and floats held.. CIP 1200 hrs 1/4/2006. ~ 12:00 - 16:00 4.00 CEMEN PULD ~ INTRMI I R!D Cement equipment & Back out landing jt, Remove all casing equipment from rig, P/O Stack and rinse same 16:00 - 17:00 1.00 i CASE I DEQT INTRMI Set 7 5/8" packoff with FMC techs and test to 5000 psi for 10 min. , 17:00 - 18:30 ! 1.50 ~ DRILL ~ LOT INTRMI R/U and perform LOT on 7/5/8" X 10 3/4 surface csg. (9.0 ppg fluid ~ ~ 200 psi applied pressure @ ' TVD Broke at 200 psi pumped a total of 4.3 bbl EMW 11.39 and 1579 Freeze protect 7 5/8" X 10 3/4" annulus with 100 bbl. diesel. 18:30 - 19:00 0.50 CASE ~ OTHR INTRM1 Run and set wear bushing 19:00 - 20:00 1.00 CASE RURD INTRMI Rig up equipment to lay down 5" drill pipe ~ 20:00 - 00:00 4.00 DRILL PULD ~ INTRMI ~ RIH 5 stds 5" per interval and UD same. 1/5/2006 00:00 - 02:30 2.50 DRILL PULD INTRM1 Continue to lay down 5" drill pipe 02:30 - 03:15 0.75 WELCT BOPE INTRM1 Bring in test equipment and pull wear bushing and set test plug 03:15 - 10:15 7.00 ~ , WELCT NUND INTRM1 Open doors on BOP stack and clean out cavities ,and change out 5" to 4" pipe rams 10:15 - 18:00 7.75 WELCT BOPE INTRMI R/ U Test equipment and test stack and all related well control equipment to 300 psi low! 3000 psi high R/D test equipment and pull test plug. (Witness of Test waived by Chuck'Sheve with AOGC) 18:00 - 19:00 ; 1.00 DRILL OTHR INTRM1 ; Finish drifting and strapping 4" DP and 4" HWDP. 19:00 - 20:00 ~ 1.00 RIGMNT RSRV % INTRM1 Service Top drive, Drawworks, Crown and blocks, CIO wash pipe ~ 20:00 - 20:30 0.50 WELCT OTHR INTRM1 Set wear bushing 20:30 - 00:00 3.50 DRILL ; PULD INTRM1 Pick up and M/U Bha # 6 3/4" for drilling production hole. 1/6/2006 00:00 - 02:30 2.50 DRILL i PULD INTRMI M!U Bha # 6 (Load data in MWD and load sources) 02:30 - 07:00 4.50 DRILL PULD INTRM1 RIH Picking up singles of 4" dp from pipe shed 07:00 - 09:00 '~ 2.00 1 DRILL TRIP i INTRM1 ~ POOH ,Std back in derrick , 22 stds of4 " dp,. 7- stds HWDP, 6- stds 4" Dp , (To be used to drill horizontal production hole j 09:00 - 16:00 7.00 DRILL ~ PULD INTRMI I RIH picking up Single drill pipe from pipe shed to 5251' 16:00 - 17:00 1.00! DRILL CIRC i INTRMI , Circ bottoms up @ 5251' 17:00 - 18:00 1 1.00 ~ i CASE 1 DEQT ~ INTRM1 Rig up and Pressure test 7 5/8" csg to 3000 psi. for 30 min. good test 18:00 - 19:00 ~ 1.00 RIGMNT RSRV INTRM1 Service rig 19:00 - 22:30 ~ 3.50 CEMENl~ DSHO INTRMI RIH ,Clean out cement stringer @ 5268' and 5296' ,Drill out shoe ~, ', tract, and clean out rat hole Printed: 3/31/2006 10:50:01 AM ConocoPhillips Alaska Page 10 of 15 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2T-208 2T-208 Spud Date: 12/20/2005 ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 n1433@conocophillps.com Rig Release: 1/21/2006 Group: Nordic 3 Rig Number: 3 ' Sub Date From - To Nours ' i Code 'Code Phase 1/6/2006 19:00 - 22:30 3.50 ; CEMENIj DSHO ' I ' INTRM1 i 22:30 - 00:00 1.50= DRILL ~ CIRC INTRM1 1/7/2006 00:00 - 01:30 1.50 ; DRILL i CIRC ~ INTRM1 j i 01:30 - 03:30 ~ 2.00 DRILL ~ OTHR ~ INTRM1 ~ 03:30 - 04:30 1.00 !, DRILL FIT INTRM1 04:30 -06:00 1.50' 1 DRILL `CIRC INTRM1 06:00 - 06:30 0.50 ~, DRILL i FIT INTRMI 06:30 - 00:00 I 17.501 DRILL I DRLG I PROD 1/8/2006 100:00 - 20:30. 20.50 DRILt DRLG I PROD 20:30 - 21:30 j 1.00'1 DRILL CIRC ;PROD 21:30 - 23:00 I 1.50 DRILL i TRIP I PROD 23:00 - 00:00 ! 1.00 I DRILL I TRIP i PROD 1/9/2006 00:00-01:30 1.50'DRILL (TRIP PROD 01:30 - 08:30 7.00 DRILL I DRLH PROD 08:30 - 09:00 ~ 0.50 DRILL OTHR !PROD 09:00 - 15:00 6.00 DRILL TRIP PROD 15:00 - 18:30 3.50 DRILL PULD PROD 18:30 - 20:30 2.00 RIGMNT~ RSRV PROD 20:30 - 00:00 3.50 DRILL PULD PROD 1/10/2006 00:00 - 07:30 7.50, DRILL TRIP PROD 07:30 - 12:00 I 4.50 i DRILL .DRLG I PROD 12:00 - 00:00 12.00 i DRILL 'DRLG I PROD 1/11/2006 00:00 - 03:00 ' 3.00 DRILL ' DRLG ' PROD 03:00 - 04:30 1.50 DRILL I OTHR PROD j 04:30 - 05:00 0.50 DRILL TRIP; PROD `i 05:00 - 07:30 2.50; DRILL CIRC ; PROD Description of Operations below csg shoe and drill 5' of new hole F/5436' to 5441' (ART .15 hrs) NOTE=Drilled 5' of new hole rather than 20' due to MWD not working & we need to get turn immediatly out of shoe. Drilled 5' to get dynamic test. Circ wellbore clean of cmt before changing over to new Flo-Pro Mud. Pump 30 bbl. Hi-Vis sweep and follow with 9.1 ppg Flo-Pro mud to displace wellbore. Clean pits, shaker, flow line and take on 200 bbls Flo-Pro mud Attempt to perform Dynamic formation integrity test ,unable to get max rate due to mud) Circ and condition mud through bit to shear Perform Dynamic formation test to max flow rate of 275 gpm ECD 11.0 ppg. no fluid loss during this test was detected. Drill ahead directionally 6 3/4" hole F/5441' MD 3117' TVD, to 6370' MD, 3137'TVD, ART 4.54hrs AST 5.55 hrs. RPM 70, BW 2-5k , 110 spm, 273 gpm, Up wt. 110k, Dn wt.38k, Rot wt.67k. TO on bottom 5400 ft/Ib, TO of bottom 5200 ft/Ib. Drill ahead directionally 6 3/4" hole F/6370' MD 3134' TVD' To 7173' MD, 3133'TVD, ART 4.58 hrs AST 9.41 hrs. RPM 70, BW 2-5k , 90 spm, 269 gpm, Up wt. 125k, Dn wt.27k, Rot wt.63k. TO on bottom 5600 ft/Ib, TQ of bottom 5300 ft/Ib. Circ bottoms up at 275 gpm 1400psi, rotate @ 70 rpm and reciprocate pipe POOH to 5436' Normal hole drag, (POOH to place HWDP at top of hole for more effective weight . RIH, to 6699, Down drag to zero while pushing out in to lateral section although it kept moving with out rotation and pump. RIH after moving HWDP up hole. (Hole in good condition) Drill F/ 7103' to 7203' MD,3133' TVD,Attempting to drill sliding=need to build 2 deg. & turn to right. (Problems trying to slide.)AST=2.23 hrs. ART= .81 up wt 125k, do wt 25k , RT wt 67k 223 gpm, TO on 5600, TO off 5300 Blow down top drive-shuffle pipe in derrick. POH to bha UD Bha # 6 and download all directional equipment. Slip and cut drilling line, adjust brakes M/U Bha # 7 and load and scribe mwd etc. R/U and performed shallow pulse test, PJSM and loaded nuke sources, cont RIH with BHA #8 to 7,203' with no problems. Cont directional drilling 6 3/4" hole from 7,203' MD to 7,231' MD (28') ART .11 hrs, AST 3.09 hrs, 2K wob, 35 rpm's, drilled at 215 gpm, 1,800 psi, torque off btm 4,600 ft/Ibs, on btm 4,900 ft/Ibs, rot wt 67K, up wt 125K, dwn wt 25K. Cont directional drilling 6 3/4" hole from 7,231' MD to 7,483' MD/ 3,131' TVD (252'), ART 1.64 hrs, AST 6.31 hrs, ADT 7.95 hrs, 2-15K wob, 35 rpm's, drilled at 252 gpm, 2,050 psi, torque off btm 4,250 ftllbs, on btm 4,870, rot wt 70K, up wt 125K, dwn wt 57K, jar hrs 37.80, 9.0 Flo-Pro MW, ECD at 10.2. Cont directional drilling 6 3/4" hole from 7,483' MD to 7,594' MD (111'). Circ and Recip as per Geologist, prep to POOH. POOH 7 stnds, wet on elevators from 7,594' to 6,930' MD. Break Circ, orient mtr, start trenching. Printed: 3/31/2006 10:50:01 AM GonocoPhillips Alaska Operations Summary Report Legal Well Name: 2 T-208 Common W ell Name: 2 T-208 Event Nam e: ROT -D RILLING Contractor Name: n 1433@ conocop hillps.i Rig Name: Nordic 3 Date From - To ~ Hours Code ~ Code 1/11/2006 07:30 - 09:00 ~ 1.50 1 DRILL DRLG I 09:00 - 12:00 j 3.00 ~ DRILL ~ DRLG 12:00 - 00:00 ~ ~ 12.00 , ~ DRILL ~ ~ DRLG i 1/12/2006 00:00 - 12:00 i 12.00 DRILL DRLG 12:00 - 15:00 3.00 I i DRILL i DRLG i I 15:00 - 17:00 17 00 18 30 2.00 1 50 i DRILL DRILL CIRC WIPR ~ : - : ~ . i 18:30 - 20:00 1.50 FRMTST! TRIP 20:00 - 21:00 21:00 - 22:00 1.00 ~ 1.00 ~ DRILL RIGMNTi WIPR RSRV 22:00 - 00:00 2.00 DRILL ' WIPR 1/13/2006 00:00 - 03:00 I 3.00 ~ DRILL WIPR 03:00 - 05:00 2.00 DRILL I CIRC 05:00 - 07:30 2.501 DRILL CIRC 07:30 - 08:30 1.00 DRILL OBSV 08:30 - 09:00 0.50 i DRILL CIRC 09:00 - 11:30 2.50 DRILL i TRIP 11:30 -12:00 0.50 DRILL ' OBSV 12:00 - 14:00 2.00 DRILL CIRC 14:00 - 14:30 0.50 ~~ DRILL OBSV i 14:30 - 17:30 3.00 DRILL j TRIP 17:30 - 22:00 4.50 DRILL ~ I PULD 22:00 - 00:00 i i 2.00' I DRILL ; OTHR 1!14/2006 ~ i 00:00 - 01:00 1.00 CMPLTN '~ PULD Page 1.t of 15 Spud Date: 12/20/2005 Start: 12/17/2005 End: 1!21/2006 :om Rig Release: 1/21/2006 Group: Rig Number: 3 Phase Description of Operations PROD ~ Time drill side track at 1" per minute. PROD ', Cont directional drilling 6 3/4" hole from 6,935' MD to 6,953' MD (18'), jART 0 hrs, AST 4.89 hrs, ADT 4.89 hrs, 5K wob, 35 rpm's, drilled at 240 gpm, 1,700 psi, torque off btm 5,600 ft/Ibs, on btm 5,900, rot wt 65K, up wt 125K, dwn wt 30K, jar hrs 42.69, 9.0 Flo-Pro MW, ECD at ;10.12. PROD ~I Cont directional drilling 6 314" hole from 6,953' MD to 7,380' MD/ 3,138' TVD (42T), ART 2.75 hrs, AST 5.23 hrs, ADT 7.98 hrs, 2-5K wob, 65 ~i rpm's, drilled at 247 gpm, 1,790 psi, torque off btm 5,240 ft/Ibs, on btm 6,130, rot wt 65K, up wt 130K, dwn wt 30K, jar hrs 50.67, 9.0 Flo-Pro !, MW, ECD at 10.37. PROD ~, Cont directional drilling 6 3/4" hole from 7,380' MD to 7,560' MD (180'), ART 2.47 hrs, AST 7.45 hrs, ADT 9.92 hrs, 2-5K wob, 65 rpm's, drilled at 240 gpm, 1,800 psi, torque off btm 5,500 ft/Ibs, on btm 6,300, rot wt 70K, up wt 135K, dwn wt 30K, jar hrs 60.59, 9.0 Flo-Pro MW, ECD at 10.16. PROD Cont directional drilling 6 3/4" hole from 7,560' MD to TD at 7,654' MD/ 3,144' TVD (94'), ART 1.07 hrs, AST 1.42 hrs, ADT 2.49 hrs, 2-5K wob, 50 rpm's, drilled at 252 gpm, 1,820 psi, torque off btm 5,200 ft/Ibs, on btm 6,370, rot wt 68K, up wt 85K, dwn wt 60K while pumping, jar hrs 163.08, 9.0 Flo-Pro MW, EGD at 10.56. PROD ~ CBU 3x while rotate and recip. Blow dwn Top Drive and flow check. PROD ;POOH., wet on elevators from 7,654' to 6,613' with no problem, up wt ~ 150K, dwn wt 20K. PROD MADD PASS from 6,592' MD to 6,492' MD, rot 35 rpm's, 102 spm at 1,760 psi, < 120 fpm. PROD Cont POOH for wiper trip from 6,483' to 5,346'. PROD Change out Saver Sub and service Top Drive, monitor well. PROD RIH on elevators from 5,346' to 6,641', PU 2 jnts 5" DC's and stage in j string with 4" HWDP. PROD .RIH on elevators from 6,641' to 7,654' with no problems, up wt 145K, dwn wt 25K, PU 11 jnts 5" DC's and stage in string with 4" HWDP. PROD Pump 30 bbl Hi-Vis sweep and CBU 3x at 6 bpm, 1,800 psi, rot and ,recip 70 rpm, PJSM on brine displacement. PROD ~ Pump 30 bbl Push Pill, displace well with 580 bbls 9.1 ppg filtered brine from tank farm at 6 bpm, 1,800 psi, rot and recip 70 rpm, off btm torque 7,478 ft/Ibs, offload mud, clean trip tank. PROD i Monitor well, fluid loss at 20 bph with 9.1 brine in hole. PROD 'Circ and spot 200 bbls Hi-Vis brine at 6 bpm, 1,550 psi, rot and recip 70 rpm. PROD POOH from 7,654' to 5,410', wet on elevators, up wt 143K, dwn wt 25K. PROD Monitor well. PROD ;Circ 280 bbls 9.1 filtered brine, 110 spm, 1,750 psi, flush all surface lines. PROD Blow dwn Top Drive and monitor well. Well static. PROD POOH to BHA #8, up wt 110K, dwn wt 30K. PROD LD BHA #8, PJSM and remove nuke sources, dwn load MWD, LD mtr 'and pull jets from bit. PROD MU stack washing tool on Top Drive , on-load 100 bbls clean brine, function BOP, flush stack-kill-choke lines. 1,330 bbls of clean filtered brine on location. CMPLTN !PJSM, PU 1st Magnet/Scraper/Brush assembly and re-run 6 314" PDC j bit with no jets. Printed: 3/31/2006 10:50:01 AM COnocoPhillips Alaska Page 12 of 15 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 2T-208 2T-208 Spud Date: 12/20/2005 ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 n1433@conocophillps.com Rig Release: 1/21/2006 Group: Nordic 3 Rig Number: 3 Date From - To Hours Code Lode i Phase'' 1 /14/2006 j 01:00 - 02:30 02:30 - 03:00 03:00 - 05:30 105:30 - 07:30 ~~ 07:30 - 08:30 08:30 - 10:30 ~! 10:30 -.12:00 ~I 12:00 - 17:00 ~I 17:00 - 20:00 i 20:00 - 20:30 20:30 - 22:45 I I I 22:45 - 00:00 1 /15/2006 00:00 - 01:30 01:30 - 02:00 02:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 13:15 13:15 - 14:15 14:15 - 16:00 16:00 - 16:15 16:15 - 20:45 20:45 - 00:00 1/16/2006 100:00 - 00:30 1.25 CMPL 1.00 CMPL 1.75 CMPL 0.25 CMPL 4.50 CMPL 3.25 CMPL 0.501 CMPL CIRC CMPLTN CIRC CMPLTN CIRC CMPLTN OBSV CMPLTN TRIP CMPLTN RURD CMPLTN SFTY 1 CMPLTN 00:30 - 08:00 7.501 CMPLTN SCRN CMPLTN 08:00 - 09:30 ' 1.50 I CMPLTN RURD i CMPLTN 09:30 - 10:30 1.00 CMPLTN RUNT CMPLTN 10:30 - 12:30 I 2.00 CMPLTN OTHR CMPLTN 12:30 - 19:30 ~ 7.00 CMPLTN RUNT CMPLTN 19:30 - 20:30 I 1.001 CMPLTNI RURD , CMPLTN 1.50 CMPLTN TRIP CMPLTN 0.50 CMPLTN PULD i~ CMPLTN 2.50 i CMPLTNI TRIP ;CMPLTN 2.00 CMPLTN OTHR 'CMPLTN 1.00 ~ CMPLTN CIRC CMPLTN 2.00 i CMPLTN TRIP 'CMPLTN 1.50 CMPLTN TRIP CMPLTN 5.00 ~ CMPLTNI OTHR CMPLTN 3.00' CMPLTN OTHR CMPLTN 0.50 CMPLTN SFTY ~ CMPLTN 2.25 ~ CMPLTNI CIRC CMPLTN 1.251 CMPLTNI OTHR CMPLTN 1:50 CMPLTNI OTHR I CMPLTN 0.50? CMPLTN! SFTY CMPLTN 4.001 CMPLTNIAWSH (CMPLTN 1.00 I CMPLTNI CIRC I CMPLTN 0.50 CMPLTN'OTHR (CMPLTN 4.50 CMPLTN OTHR ~ CMPLTN Description of Operations RIH 28 studs 4" DP from derrick. PU 2nd MagneUScraper/Brush assembly. Cont RIH with 8 studs 4" DP, 14 studs DC/HWDP and 6xx studs to 5,423'. Clean flowline, shakers, pits and cuttings box for brine. Circ 200 bbls clean 9.1 ppg brine at 7 bpm, 750 psi, 70 rpm, up wt 110K, dwn wt 65K. POOH from 5,423' to 2,734'. Inspect and clean upper magnet. RIH from 2,734' to 5,423', up wt 110K, dwn wt 65K. Clean pits and cuttings box, service Top Drive.. Wait on Caustic wash delivery. PJSM with CPA( reps, Swaco reps, Rig crew, truck drivers on caustic wash, suit up personell. Pump 75 bbls Caustic Wash from tanker at 5 bpm, 500 psi, followed with clean 9.1 brine for 1 hole volume, start rotate/recip as caustic cleared bit at 1000 strokes, diverted returns to rockwasher at 2,813 strokes (within 50 bbls prior to caustic at surface) stop rotatelrecip and divert a total of 200 bbls to rock washer, with PH at 10 diverted returns back to pits, circulated 1 hole volume while rotate/recip monitoring NTU's, 63 NTU's at circ shut dwn. Load dirty vac with Caustic Wash, notify 1 R pad, transported shower unit with truck to 1 R pad, RU to transfer dirty brine to tank farm, Spot and RU Dowell pump unit and hardline to rig floor. Load 300 bbls 9.1 brine in pits, check all circ lines, stage soda ash, stage shower unit at returns tank, MU Dowell hardline on rig floor. PJSM with CPAI reps, Swaco reps, Rig crew, Dowell, truck drivers on acid pickle, suit up personell. Dowell pumped 5 bbls water, tested circ lines to 3,000 psi, pumped 10 bbl Flovis high vis pill, 6.3 bbls Super Pickle, 12 bbls 15% HCI, 35 bbls 9.1 clean brine, and 5 bbls water at 112 bpm to within 1 /2 bbl from end of workstring. Line up and reverse circ 2 work string volumes at 2 bpm, 80 psi, then 1 more string volume at 3 bpm, 150 psi, blow down circ lines. R/D Dowell equipment and clear rig floor. Off-load dirty brine, clean out acid returns tank, on-load 300 bbls clean 9.1 brine. Line up and circ dwn DP at 6 bpm, 560 psi. Transfer line from rig to tank farm froze. Stop circ and blow dwn Top Drive. Attempted to thaw transfer line, C/O frozen hardline section. Cont circ long way at 6 bpm, 560 psi, up wt 85K, dwn wt 70K, rot wt 82K, 17 NTU's in, 34 NTU's out. Blow dwn Top Drive, monitor well. POOH from 5,423', LD BHA #9. Clear rig floor, RD spinners, RU ECKEL tubing tongs, RU Doyon torque monitor system and handling equip, C/O bales, prep stabbing board. PJSM with Baker, Nordic, CPA(, Doyon reps on screen PU, handling and running. PU and run 4.5" chrome screens to 2,687. Swap out bails and RU to run 2 7/8" inner string. PU RIH with 2 7/8" tubing. LD broken KOIV and wait on delivery of new one. MU new KOIV cunt PU RIH with 2 7/8" tubing to 2,687'. C/O handling equipment to run 4" DP. Printed: 3/31/2006 10:50:01 AM ConocoPhillips Alaska Page ~ 3 of 15 Operations Summary"Report Legal Well. Name: Common Well Name Event Name: Contractor Name: Rig Name: 2T-208 2T-208 Spud Date: 12/20/2005 ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 n1433@conocophillps.com Rig Release: 1/21/2006 Group: Nordic 3 Rig Number: 3 Sub Phase ' Description of Operations Code, CIRC ~ CMPLTN I Break circ at 1 bpm, torque 2,000 ft/Ibs at 25 rpm, up wt 73K, dwn wt Date ,From - To ,Hours Code 1 /16/2006 ~ 20:30 - 21:15 ~ 0.75 ~ CMPLT ~ 21:15 - 00:00 I 1 /17/2006 00:00 - 01:00 01:00 - 05:00 i 05:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 12:00 12:00 - 13:45 13:45 - 14:15 14:15 - 15:30 15:30 - 15:45 15:45 - 16:45 .16:45 - 17:00 17:00 - 19:30 '~ 19:30 - 20:00 i 20:00 - 20:45 20:45 - 22:15 22:15 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 1 /18/2006 ~ 00:00 - 01:00 2.75 j CMPLTNI TRIP 1.001 CMPLTNITRIP 4.001 CMPLTNITRIP CMPLTN CMPLTN CMPLTN 1.50 I CMPLTNI CIRC I CMPLTN 0.501 CMPLTNI OBSV i CMPLTN 1.00, CMPLTN; PCKR ;CMPLTN 4.00 CMPLTNI RURD CMPLTN i 1.75 i CMPLTNI RURD I CMPLTN 0.50 CMPLTNI SFTY CMPLTN 1.25 CMPLTNI CIRC ';CMPLTN 0.25 CMPLTN OBSV CMPLTN 1.00 CMPLTN TRIP CMPLTN 0.25 CMPLTN OBSV ~ CMPLTN 2.50 CMPLTNI OTHR .CMPLTN 0.50'. CMPLTNI TRIP I CMPLTN 0.751 CMPLTNI CIRC I CMPLTN 1.50 CMPLTN TRIP CMPLTN 0.25 CMPLTN OTHR CMPLTN 0.50 CMPLTNjTRIP CMPLTN 0.50 CMPLTN CIRC CMPLTN 0.501 CMPLTN TRIP CMPLTN 1.00 CMPLTN OBSV ,,CMPLTN 60K, blow dwn Top Drive. RIH with 4" DP from derrick at 90 seconds per stand from 2,687 to 5,062' filling DP every 5 stnds, up wt 97K, dwn wt 55K. Cont RIH with 4" DP from derrick at 90 seconds per stand from 5,062' Ito 5,425' (shoe depth) filling DP every 5 stnds, Kelly up and break circ I at 1 bpm at 60 psi, up wt 102K, dwn wt 55K while pumping. Cont RIH from 5,425' to 7,620' pumping each stand at 1 bpm, 60 psi, ',with no problem, went to 7,634' to ensure we are in proper open hole !section, pulled back up to 7,620', up wt 144K, dwn wt 20-25K with no j pump. !I CBU 1 1/2x at 4 bpm, 520 psi to displace Hi-Vis brine from open hole section. Monitor well and drop 1 7/16" ball. Pump ball down and seat at 1 bpm, pressure to 1,300 - 1,800 - 2,200 psi and verified slips are anchored, lined up and tested packer down backside to 1,500 psi (test good), released service tools, up wt 120K, dwn wt 50K after packer set with no pump. RU Dowell circ line on rig floor, RU crane and set in Centrilift's spools Ion rig floor with ESP spooler. RU Dowell for pumping MudSOLV and transfered fluid from tank farm to mud pits ~ Held PJSM with Dowell, Baker Reps, rig crew and ASRC vac truck drivers on pumping of MudSOLV PU on string to 7,605' and opened inner string seals to shoe and ;annulus, est circ with rig pump at 2 bpm at 160 psi, took approx 25 bbls i to est circ, turned over to Dowell and pumped 3 bbls water, pressure tested lines to 3,500 psi, then pumped 108 bbls of 9.34 ppg MudSoly, ave 6.1 bpm at 1,250 psi, displaced with 62 bbls of 9.1 ppg brine, pumped a total of 174 bbls with 141 recovered in mud pits, talc I MudSoIV volume on 2 7/8" x 6 3/4" annulus to 200' above 7 5/8" csg 'shoe with 25% excess, st wt up 95K, do wt 55K Monitored well for 15 min, ave 12 bph losses to formation POOH from 7,605' to 6,471' Monitored well and ave 60 bph losses to formation PU and set seals in safe position to allow MudSOLV to soak on ',formation, annulus stayed static on trip tank, DP was shut in. Lower string and Locate into mid circ position at 6,515', losses at 120 bph. Line up on Dowell pump unit, pump 1 bbl fresh water, test circ lines to 3,500 psi, pumped 100 bbls of 9.34 ppg MudSoly at 6.5 bpm at 1,080 psi with 21 % return flow, displaced with 47 bbls 9.1 brine at 6.5 bpm, `1,030 psi, pumped a total of 150 bbls, RD Dowell hardline and head pin. POOH from 6,515' to 4,998', up wt 95K. Install TIW and close, close annular and srtip OOH from 4,998' to 4,962' through KOIV, indication KOIV did not close. 1 POOH from 4,962' to 4,893. Kelly up and circ at 6 bpm, 600 psi and attempt to close KOIV, indication KOIV did not close. RIH from 4,893' to 5,048' ("B" seal) to monitor fluid loss. Monitored well while in safe position at 5,048' and well annulus was !static Printed: 3/31/2006 10:50:01 AM ConocoPhillips Alaska " Page ~ 4 of ~ 5 Operations Summary Report Legal Well Name: 2T-208 Common Well Name: 2T-208 Spud Date: 12/20/2005 Event Name: ROT -DRILLING Start: 12/17/2005 End: 1/21/2006 Contractor Name: n1433@conocophillps.com Rig Release: 1/21/2006 Group: Rig Name: Nordic 3 Rig Number: 3 Date 1 /18/2006 1!19/2006 From - To ~` Hours Code , Code ~ Phase _- _ _.__ 01:00 - 02:00 ~ 1.00 ~ CMPLTNI OBSV ~ CMPLTN 02:00 - 04:45 ; 2.75 I CMPLTNI OTHR 04:45 - 05:45 ! 1.001 CMPLTNI CIRC 05:45 - 07:45 1 2.001 CMPLTNI OBSV 07:45 - 08:30 I 0.75 I CMPLTNI CIRC 08:30 - 10:00 I 1.50 I CMPLTNI OBSV 10:00 - 14:00 ' 4.00 CMPLTN PULD 14:00 - 19:30 5.50 CMPLTN PULD 19:30 - 20:00 0.50 CMPLTN OTHR 20:00 - 21:45 1.75 , CMPLTN PULD 21:45 - 23:45 2.00 CMPLTNI TRIP 23:45 - 00:00 0.25 i CMPLTN PULD 00:00 - 00:30 I 0.50' CMPLTN PULD 00:30 - 01:00. 0.50 CMPLTN TRIP 01:00 - 06:00 5.00 CMPLTN OTHR CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN 06:00 - 09:30 I 3.50 I CMPLTNI PULD I CMPLTN 09:30 - 10:30 1.00 ~ CMPLTNI OTHR i CMPLTN 10:30 - 11:30 1.00 CMPLTNI RURD CMPLTN 11:30 - 19:30 8.00 CMPLTN PULD CMPLTN 1 19:30 - 23:00 3.50 CMPLTN TRIP ! CMPLTN 23:00 - 23:15 ' 0.25 CMPLTN~i OTHR CMPLTN 23:15 - 00:00 0.75 CMPLTN RURD CMPLTN 1/20/2006 1 00:00 - 01:00 I 1.00 ~ CMPLTN RUNT CMPLTN 01:00 - 01:30 0.50 CMPLTN SFTY CMPLTN 01:30 - 04:00 2.50 CMPLTN PULD CMPLTN 04:00 - 05:00 1.00 CMPLTN PULD CMPLTN 05:00 - 07:00 2.00 CMPLTN PULD CMPLTN 07:00 - 15:30 8.50 ~ CMPLTN RUNT i CMPLTN Description of Operations PU from 5,048' to 5,042' and monitored well for losses, ave 163 bph loss rate, set back down to safe position at 5,048' I~ Mixed up a 40 bbl, 100 ppb (4.5 ppb SafeCarb 20 + 50.8 ppb SafeCarb 40 + 44.6 ppb SafeCarb 250), 9.9 ppg LCM pill, (sized calcium carbonate screen pill) POOH from 5,048' to 4,931', (to above top of packer at 4,944') began to est circ at 2-3 bpm, after pumping 55 bbls still had not gained circ, filled hole from trip tank, took 30 bbls to fill hole, then pumped 35 bbl, 100 ppb, 9.9 ppg LCM pill and spotted out end of inner string I Picked up from 4,931' to 4,857 and monitored well, initial losses ave 60 BPH, final rate after 2 hrs was 58 BPH, lost approx 114 bbls in 2 hrs RIH from 4,857 to 4,931' and spotted 20 additional bbls of 10.0 ppg, 100 ppb LCM pill and spotted out of 2 7/8" inner string, blew down top drive POOH from 4,931' to 4,857' and monitored well, initial losses ave 60 ;BPH after 45 min's losses decreased to an ave 48 BPH, decision was ;made to POOH LD 4" DP and 2 7/8" inner string POOH LD 4" DP from 4,857' to 2,661' (2 7/8" inner string). ~ RU and POOH LD 2 7/8" inner string and setting tool. I Unload pipeshed and off load BOT handling equipment. ;RIH with 8 studs 4" DP from derrick to make pushpipe more accessible, POOH LD 24 juts DP. RIH with 14 studs pushpipe and 4" DP to 4,215'. POOH LD 4" DP from 4,215' to 3,733'. Hole losses ave. 50 BPH ~ POOH LD 4' DP from 3,733' to 3,258' RIH with remaining 4" DP in derrick from 3,258' to 4,215' Unloaded 4" DP from pipe shed and fin loading pipe shed with completion tools and 4 1/2", 12.6# L-80 completion tbg and strapped same, monitoring well, losses ave 55-60 BPH POOH from 4,215' LD 31 stds of 4" XT-39 DP and 14 stds of Hybrid ,push pipe (2-HWDP & 1-4 3/4" DC) Unloaded 4" DP, HWDP and Dc's from pipe shed Rigged up to run 4 1!2" tbg PU RIH with 138 juts 4 1/2", 12.6# L-80 comp tubing to 4,260'. "Rig off Highline at 14:00 hrs" POOH rack back 46 studs 4 1/2" tubing, CIO seal rings, Pulled wear bushing. String ESP cable and hang sheave, RU handling equipment, spot Centrilift equip and RU to run completion, fluid losses ave. 65 bph. I Cont RU Centrilift equipment. PJSM with CPAI reps, Centrilift rep and rig crew, on running of ESP. PU MU motor, intake and pump with discharge head and RIH to 70' Install ESP power cable on pump assembly, Meger test ESP cable (test ok), install Cannon Clamps. Install Guardian Gauge and splice TEC wire and tested same RIH with ESP completion on 4 1/2" tbg to 4,522', RIH with 143 jts (4,410') of 4 1/2", 12.6 ppf, L-80 IBTM tbg with CMU sliding sleeve, (closed) with 2-GLM's, 1 with dummy valve and upper GLM with DCK-2 shear valve set at 2,000 psi per well plan, Total tubing and completion equip. RIH 4,588.63'. Used 77 6.75" Cannon clamps, 4-5.875" Protectolizer clamps, 2-5.625" Flat guards and 4-Flat stainless steel bands., ave tbg MU was 3,500 ft-Ibs Printed: 3f31/2006 10:50:01 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1/20/2006 i 15:30 - 16:00 16:00 - 19:15 19:15 - 20:00 20:00 - 21:45 21:45 - 00:00 1 /21 /2006 00:00 - 03:00 I ~ 03:00 - 09:30 09:30 - 12:00 12:00 - 13:30 13:30 - 15:00 ConocoPhillips Alaska Operations Summary Report 2T-208 2T-208 ROT -DRILLING n 1433@conocophillps.com Nordic 3 Hours ~ Code Code ~ Phase _ -- 0.50 CMPLTNI PULD ~ CMPLTN 3.251 CMPLTNI OTHR 0.75 CMPLTNI RUNT 1.75 I CMPLTNI SEOT 2.25 WELCT~ NUND 3.00 WELCT NUND CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN 6.501 WELCTLI NUND 2.50 I CMPLTNI FRZP 1.50; WELCTL~ EQRP 1.50 ~ CMPLTNI OTHR CMPLTN Page 15 of 15 Spud Date: 12/20/2005 Start: 12/17/2005 End: 1/21/2006 Rig Release: 1/21/2006 Group: Rig Number: 3 Description of ©perations MU FMC Uni-Head / horizontal tbg hanger and RIH to 4,522', st wt up 82K, do wt 46K, fluid losses to hole ave 55-60 BPH while RIH with completion assembly, last 150 bbls in hole contained ConCor 404 corrosion inhibitor. Installed penetrators to tbg head, cut ESP and TEC wires and spliced wires to penetrators and checked continuity and ck ok NOTE: Lower connector for ESP cable maybe out of spec -too long - and may have been damaged on 7 5/8" pack-off. See subsequent problems on 2T-203 - P. Hayden 2/23/2006) RIH with FMC tbg hanger and landed 4 1/2" ESP completion at 4,614', RILDS, landed ESP completion string with the motor at 4,578', pump intake at 4,564', ESP pump at 4,540', CMU sliding sleeve (closed) with 3.813" DB profile at 4,451', KBMG 4 1/2" x 1" GLM #1with dummy valve at 4,400' and KBMG 4 1/2" x 1" GLM #2 with DCK-2 Shear valve set at 2,000 psi at 2,896', st wt up 82K, do wt 46K, blk wt 20K, ran a total of 93 cannon Clamps, 4 Protectotizer Guards, 2 Flat guards and 4 Flat stainless steel bands, 11" x 4 1/2" Horizontal Hanger with 5" Right Hand Acme Top Connection. RU and test upper/lower hanger seals at 250 psi low and 3,000 psi high. Test OK, RD test equipment and LD landing jnt. PJSM, N/D 11" BOP riser. Cont ND 11" BOP stack and rack for move. Load Sperry tools. Continuity test Ok on ESP cables. Loaded FMC 11" x 5M Unihead/Horizontal System tree and components into cellar and NU same. Check ESP continuity and ck ok, Final guardian guage readings were 679 psi at 61 degrees with 1.8 OHMS and 1 GIG, Tested void and tree to 5,000 psi each for 10 min and ck ok, pulled TWC i NOTE: Lower connector for ESP cable maybe out of spec -too long - and may have been damaged on 7 5!8" pack-off. See subsequent problems on 2T-203 - P. Hayden 2/23/2006) CMPLTN RU little red and freeze protected well by pumping 32 bbls diesel down the tbg, then pumping 53 bbls diesel down 4 1/2" x 7 5/8" anhulus, talc !volume is 2,000', pumped at 1 bpm with no pressure, well was on slight vaccum, RD Little Red CMPLTN RU & installed BPV and secured well. - CMPLTN Fin cleaning out mud pits, trip tank and cellar area. RELEASED RIG 15:00 Hrs 1/21/06 Printed: 3!31/2006 10:50:01 AM Halliburton Company Global Report Company: GonoroPhillips Alaska Inc. Ua€e: 2/9/2006 lime: 15:2823 1'a~c: 1 Field: Kupanik River Unit Co-ordinate(NE) Itcfercncc: Well: 2T-208, True North Site: Kuparuk 2T Pad Vertical (TVII) Reference: 2T-208: 910.8 ~~ ell: 2T-208 Section (VS) Kcference: Well (O.OON,O.OOE,49.25Azi) ~~ellpath: 2T-208 Survey Calculation IVlethod: Miiiimum Curvature Db: Oracle Survey: Start Date: ~ I Company: Engineer: i Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 2T Pad Site Position: Northing: 5970382.43 ft Latitude: 70 19 49.129 N From: Map Easting: 498944.93 ft Longitude: 150 0 30.807 W Position Uncertainty: 0.00 ft North Reference: True I round Level: 0.00 ft Grid Convergence: -0.01 deg ~WeII: 2T-208 Slot Name: Well Position: +N/-S 240.28 ft Northing: 5970622.69 ft Latitude: 70 19 51.492 N +E/-W -0.09 ft Easting : 498944.87 ft Longitude: 150 0 30.810 W Position Uncertainty: 0.00 ft Wellpath: 2T-208 Drilled From: 2T-208PB3 501032051800 Tie-on Depth: 6895.23 ft Current Datum: 2T-208: Height 110.79 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 12/18/2005 Declination: 24.02 deg Field Strength: 57546 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.39 0.00 0.00 49.25 Survey Program for Definitive Wellpath i Date: 2/9/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 78.00 627.00 2T-208PB1 gyro (78.00-627.00) CB-GYRO-SS Camera based gyro single shot 694.55 3358.04 2T-208PB1 (694.55-6693.07) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i 3452.09 4745.26 2T-208PB2 (3452.09-5600.12) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i 4812.00 6895.23 2T-208P63 (4812.00-7553.53) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6930.00 7613.59 2T-208 (6930.00-7613.59) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~~~ ~ 11D Incl A2im Tell tiffs "t`l'D V4 Li~1 ~lap_A ~lapt; ~luul ', ft deg deg _._ ft _ _ _._ ft ft ft ft ft 30.39 0.00 0.00 30.39 -80.40 0.00 0.00 5970622.69 498944.87 TIE LINE 78.00 0.06 323.82 78.00 -32.79 0.02 -0.01 5970622.71 498944.86 CB-GYRO-SS 170.00 0.37 315.50 170.00 59.21 0.27 -0.25 5970622.96 498944.62 CB-GYRO-SS 259.00 3.73 335.43 258.93 148.14 3.11 -1.66 5970625.80 498943.21 CB-GYRO-SS 289.00 4.66 330.13 288.85 178.06 5.05 -2.67 5970627.74 498942.20 CB-GYRO-SS 348.00 5.39 318.49 347.62 236.83 9.21 -5.70 5970631.90 498939.17 CB-GYRO-SS ~ 442.00 7.43 313.86 441.03 330.24 16.73 -13.01 5970639.42 498931.86 CB-GYRO-SS 532.00 7.09 318.58 530.31 419.52 24.92 -20.88 5970647.61 498924.00 CB-GYRO-SS 627.00 5.99 322.12 624.69 513.90 33.23 -27.80 5970655.92 498917.08 CB-GYRO-SS 694.55 7.33 326.79 691.78 580.99 39.62 -32.33 5970662.31 498912.55 MWD+IFR-AK-CAZ-SC 748.45 7.86 329.01 745.21 634.42 45.66 -36.11 5970668.35 498908.77 MWD+IFR-AK-CAZ-SC 845.34 12.86 330.64 840.49 729.70 60.74 -44.81 5970683.43 498900.07 MWD+IFR-AK-CAZ-SC 939.39 16.15 327.87 931.53 820.74 80.95 -56.90 5970703.64 498887.98 MWD+IFR-AK-CAZ-SC 1030.00 18.48 333.44 1018.04 907.25 104.47 -70.03 5970727.16 498874.86 MWD+IFR-AK-CAZ-SC 1062.51 19.30 334.21 1048.80 938.01 113.91 -74.67 5970736.60 498870.22 MWD+IFR-AK-CAZ-SC , I I Halliburton Company Global Report i Comp;~m~: ConocoPhillips Alaska Inc. Field: Kaparuk River Unit Date: 2/9/2006 Time: 1528?_8 Cn-ordinate(NEj Reference: Well: 2T-208, True Pale: 2 North Site: Kuparuk 2T Pa d Ve rtical (TVn) Refi rcncc: 2T- 208- 1 10.8 Well: 2T- 208 tie ction (VS} Refere nce: Well (O.OON.O-OOE,49.25Azi) ~~'ellpath:' 2T- 208 tiu n~ec Calculation 3[ethod: Minimum Curv ature Db: Oracle Sur~ev __ _ ~1D incl -- Azim l~'U S_~~tll'U \/ti E/1~~ ~IapN 11aPh~, 'foul ft deg deg ft ft ft ft ft ft ' __ j 1094.15 __ 20.73 335. 71 1078 .52 967 .73 123. 73 -79.25 5970746 .42 498865. 65 MWD+IFR-AK-CAZ-SC ' 1124.94 21.28 337. 49 1107 .27 996. 48 133. 86 -83.63 5970756 .54 498861. 27 MWD+IFR-AK-CAZ-SC 1159.12 21.60 338. 46 1139 .08 1028. 29 145. 44 -88.31 5970768 .13 498856. 59 MWD+IFR-AK-CAZ-SC 1189.98 23.49 339. 08 1167 .58 1056. 79 156. 47 -92.60 5970779 .15 498852. 31 MWD+IFR-AK-CAZ-SC 1220.25 25.70 340. 78 1195 .11 1084. 32 168. 30 -96.91 5970790 .99 498847. 99 MWD+IFR-AK-CAZ-SC ' 1253.97 27.49 341. 22 1225 .26 1114 .47 182. 57 -101.82 5970805 .26 498843. 08 MWD+IFR-AK-CAZ-SC 1286.00 28.75 342. 57 1253 .51 1142 .72 196. 92 -106.51 5970819 .61 498838. 40 MWD+IFR-AK-CAZ-SC 1315.95 30.35 343. 47 1279 .56 1168. 77 211. 05 -110.82 5970833 .73 498834. 09 MWD+IFR-AK-CAZ-SC 1349.60 31.07 345. 47 1308 .49 1197. 70 227. 61 -115.42 5970850 .29 498829. 49 MWD+IFR-AK-CAZ-SC 1381.65 31.60 346. 18 1335 .87 1225. 08 243. 77 -119.50 5970866 .45 498825. 42 MWD+IFR-AK-CAZ-SC 1411.28 32.12 347. 16 1361. 03 1250. 24 258. 98 -123.10 5970881 .67 498821. 81 MWD+IFR-AK-CAZ-SC 1445.97 33.63 348. 50 1390 .17 1279 .38 277. 39 -127.07 5970900 .07 498817. 85 MWD+IFR-AK-CAZ-SC 1475.28 33.85 349. 02 1414 .54 1303. 75 293. 36 -130.24 5970916 .04 498814. 68 MWD+IFR-AK-CAZ-SC 1506.79 34.84 349. 23 1440 .56 1329. 77 310. 82 -133.60 5970933 .49 498811. 33 MWD+IFR-AK-CAZ-SC 1539.30 37.01 350. 38 1466 .88 1356. 09 329. 59 -136.97 5970952 .26 498807. 96 MWD+IFR-AK-CAZ-SC 1602.00 41.16 354. 32 1515 .55 1404. 76 368. 75 -142.17 5970991 .42 498802. 77 MWD+IFR-AK-CAZ-SC 1648.98 43.41 357. 70 1550. 30 1439. 51 400. 27 -144.34 5971022 .94. 498800. 60 MWD+IFR-AK-CAZ-SC 1759.07 47.63 2. 13 1627. 44 1516. 65 478. 76 -144.35 5971101 .43 498800. 60 MWD+IFR-AK-CAZ-SC 1849.75 47.01 2. 25 1688 .91 1578 .12 545. 38 -141.80 5971168 .03 498803. 16 MWD+IFR-AK-CAZ-SC 1944.62 48.64 5. 42 1752 .62 1641. 83 615. 51 -137.08 5971238 .16 498807. 89 MWD+IFR-AK-CAZ-SC 2040.37 51.80 9. 63 1813 .89 1703. 10 688. 41 -127.38 5971311 .05 498817. 59 MWD+IFR-AK-CAZ-SC 2134.01 53.99 11. 94 1870 .38 1759. 59 761. 76 -113.39 5971384 .39 498831. 60 MWD+IFR-AK-CAZ-SC 2232.20 59.84 13. 10 1923 .96 1813. 17 842. 03 -95.54 5971464 .64 498849. 46 MWD+IFR-AK-CAZ-SC 2324.25 62.37 15. 62 1968. 44 1857. 65 920. 08 -75.53 5971542 .69 498869. 47 MWD+IFR-AK-CAZ-SC 2420.16 65.69 19. 66 2010. 45 1899. 66 1002. 20 -49.37 5971624 .80 498895. 64 MWD+IFR-AK-CAZ-SC 2514.25 65.10 21. 83 2049 .63 1938. 84 1082. 19 -19.08 5971704 .78 498925. 95 MWD+IFR-AK-CAZ-SC I 2608.46 65.72 22. 89 2088 .83 1978. 04 1161. 42 13.51 5971783 .99 498958. 54 MWD+IFR-AK-CAZ-SC 2702.26 67.28 22. 50 2126 .23 2015. 44 1240. 78 46.70 5971863 .33 498991. 74 MWD+IFR-AK-CAZ-SC 2790.91 66.76 21. 70 2160. 84 2050. 05 1316. 39 77.40 5971938 .94 499022. 45 MWD+IFR-AK-CAZ-SC 2885.12 66.07 20. 87 2198. 54 2087. 75 1396. 84 108.75 5972019 .38 499053. 80 MWD+IFR-AK-CAZ-SC 2978.96 65.96 16. 99 2236. 70 2125. 91 1477. 92 136.56 5972100 .44 499081. 62 MWD+IFR-AK-CAZ-SC 3073.88 65.22 17. 43 2275 .92 2165. 13 1560. 48 162.13 5972183 .00 499107. 20 MWD+IFR-AK-CAZ-SC 3168.95 65.21 18. 50 2315 .78 2204. 99 1642. 59 188.75 5972265 .09 499133. 83 MWD+IFR-AK-CAZ-SC 3265.02 66.69 19. 26 2354 .93 2244. 14 1725. 59 217.14 5972348 .08 499162. 23 MWD+IFR-AK-CAZ-SC 3358.04 66.24 20. 39 2392 .07 2281. 28 1805. 82 246.06 5972428 .29 499191. 16 MWD+IFR-AK-CAZ-SC 3452.09 62.10 18. 59 2433. 05 2322. 26 1885. 59 274.32 5972508 .06 499219. 43 MWD+IFR-AK-CAZ-SC 3544.98 56.87 17. 38 2480. 20 2369. 41 1961. 67 299.04 5972584 .12 499244. 16 MWD+IFR-AK-CAZ-SC 3606.44 58.30 17. 04 2513. 14 2402. 35 2011. 23 314.39 5972633 .68 499259. 51 MWD+IFR-AK-CAZ-SC 3701.41 61.78 15. 24 2560. 56 2449. 77 2090. 26 337.24 5972712 .69 499282. 37 MWD+IFR-AK-CAZ-SC 3794.47 65.52 16. 80 2601 .86 2491. 07 2170. 39 360.26 5972792 .81 499305. 40 MWD+IFR-AK-CAZ-SC 3889.90 68.79 18. 06 2638 .91 2528. 12 2254. 28 386.61 5972876 .69 499331. 76 MWD+IFR-AK-CAZ-SC 3985.11 69.84 18. 54 2672. 54 2561. 75 2338. 84 414.58 5972961 .24 499359. 74 MWD+IFR-AK-CAZ-SC 4079.52 69.19 18. 10 2705. 58 2594. 79 2422. 80 442.38 5973045 .18 499387. 55 MWD+IFR-AK-CAZ-SC ~ 4173.39 68.06 18. 23 2739. 79 2629. 00 2505. 85 469.63 5973128 .23 499414. 81 MWD+IFR-AK-CAZ-SC 4269.52 69.39 18. 18 2774. 67 2663. 88 2590. 95 497.62 5973213 .31 499442. 80 MWD+IFR-AK-CAZ-SC 4364.75 68.61 18. 26 2808 .80 2698. 01 2675. 39 525.41 5973297 .74 499470. 61 MWD+IFR-AK-CAZ-SC 4459.50 68.71 17. 52 2843 .28 2732. 49 2759. 38 552.52 5973381 .72 499497. 73 MWD+IFR-AK-CAZ-SC 4554.61 68.27 17. 10 2878 .15 2767. 36 2843. 86 578.85 5973466 .18 499524. 06 MWD+IFR-AK-CAZ-SC 4649.69 68.10 18. 31 2913 .49 2802. 70 2927. 95 605.70 5973550 .26 499550. 92 MWD+IFR-AK-CAZ-SC i 4745.26 68.79 21. 86 2948. 61 2837. 82 3011. 41 636.22 5973633 .71 499581. 45 MWD+IFR-AK-CAZ-SC 4812.00 69.92 24. 54 2972. 14 2861. 35 3068. 80 660.82 5973691 .09 499606. 06 MWD+IFR-AK-CAZ-SC 4841.22 70.43 25. 70 2982. 05 2871. 26 3093. 69 672.49 5973715 .97 499617. 73 MWD+IFR-AK-CAZ-SC 4936.78 70.49 31. 29 3014 .04 2903. 25 3172. 80 715.44 5973795 .07 499660. 68 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Company: ConocoPhillipS AlaskalnC. I)atc 2/9/2006 1'imc: 15-28:28 Pagc: 3 Field: Ku paruk River Unit Co-ordinate(NE} Reference. Weli 2T-208; True North Site: Ku paruk 2T Pad Vertical(TVf1) Reference: 2T -208: 110,8 ~Vcll: 2T -208 Scctiuu (YSI Refere nce: Well (O.OON,O.OOE, 49.25AZi} ~~cllpath: 2T -208 Sunny (calculation Vtctho~: Mi nimum Curv ature Db: Oracle `urtec X11) locl Azim T1'D S.s ICU N/S E/~Y MahN M11apF,-- Tool ft deg deg ft ft ft ft ft ft 5030.82 76. _ 42 _ 34. 65 3040. 81 2930. 02 3248.36 764.50 5973870 .61 - 499709. 75 _--_ MWD+IFR-AK-CAZ-SC 5127.07 77. 64 39. 42 3062. 43 2951. 64 3323.20 820.98 5973945 .44 499766. 24 MWD+IFR-AK-CAZ-SC 5220.90 79. 13 46. 54 3081. 34 2970. 55 3390.38 883.61 5974012 .61 499828. 86 MWD+IFR-AK-CAZ-SC 5315.16 80. 63 49. 00 3097. 90 2987. 11 3452.74 952.31 5974074 .95 499897. 57 MWD+IFR-AK-CAZ-SC 5394.47 80. 26 52. 51 3111. 07 3000. 28 3502.21 1012.87 5974124 .40 499958. 13 MWD+IFR-AK-CAZ-SC 5492.21 87. 90 58. 39 3121. 16 3010. 37 3557.25 1092.87 5974179 .43 500038. 13 MWD+IFR-AK-CAZ-SC 5583.56 89. 32 58. 46 3123. 37 3012. 58 3605.07 1170.67 5974227 .23 500115. 93 MWD+IFR-AK-CAZ-SC 5674.88 88. 05 56. 55 3125. 47 3014. 68 3654.11 1247.66 5974276. 26 500192. 92 MWD+IFR-AK-CAZ-SC 5766.58 88. 90 53. 95 3127. 91 3017. 12 3706.35 1322.98 5974328 .49 500268. 23 MWD+IFR-AK-CAZ-SC 5859.61 88. 41 49. 01 3130. 09 3019. 30 3764.26 1395.72 5974386. 38 500340. 98 MWD+IFR-AK-CAZ-SC 5951.78 87. 98 47. 52 3133. 00 3022. 21 3825.58 1464.46 5974447. 68 500409. 72 MWD+IFR-AK-CAZ-SC 6043.54 89. 39 47. 74 3135. 10 3024. 31 3887.40 1532.24 5974509 .49 500477. 50 MWD+IFR-AK-CAZ-SC 6138.76 89. 82 48. 20 3135. 76 3024. 97 3951.15 1602.96 5974573 .22 500548. 23 MWD+IFR-AK-CAZ-SC 6232.39 90. 80 48. 74 3135. 25 3024. 46 4013.23 1673.05 5974635 .28 500618. 32 MWD+IFR-AK-CAZ-SC ~ 6327.31 90. 30 46. 54 3134. 34 3023. 55 4077.18 1743.18 5974699 .21 500688. 45 MWD+IFR-AK-CAZ-SC 6422.53 90. 19 46. 38 3133. 93 3023. 14 4142.77 1812.21 5974764 .79 500757. 48 MWD+IFR-AK-CAZ-SC 6517.64. 89. 69 47. 19 3134. 03 3023. 24 4207.89 1881.52 5974829 .90 500826. 80 MWD+IFR-AK-CAZ-SC 6612.50 90. 43 47. 65 3133. 93 3023. 14 4272.08 1951.37 5974894 .07 500896. 65 MWD+IFR-AK-CAZ-SC 6701.48 88. 54 45. 60 3134. 73 3023. 94 4333.18 2016.04 5974955 .15 500961. 32 MWD+IFR-AK-CAZ-SC 6800.24 89. 01 45. 27 3136. 84 3026. 05 4402.46 2086.38 5975024 .42 501031. 66 MWD+IFR-AK-CAZ-SC 6895.23 89. 82 42. 74 3137. 81 3027. 02 4470.78 2152.37 5975092 .72 501097. 65 MWD+IFR-AK-CAZ-SC 6930.00 89. 63 44. 99 3137. 98 3027. 19 4495.84 2176.46 5975117 .78 501121. 74 MWD+IFR-AK-CAZ-SC 7011.99 89. 39 49. 79 3138. 68 3027. 89 4551.33 2236.78 5975173 .25 501182. 07 MWD+IFR-AK-CAZ-SC 7101.85 86. 40 53. 70 3141. 98 3031. 19 4606.92 2307.27 5975228 .82 501252. 56 MWD+IFR-AK-CAZ-SC 7195.63 90. 49 56. 66 3144. 53 3033. 74 4660.43 2384.21 5975282 .32 501329. 50 MWD+IFR-AK-CAZ-SC 7287.03 91. 88 60. 00 3142. 64 3031. 85 4708.40 2461.97 5975330 .27 501407. 26 MWD+IFR-AK-CAZ-SC 7378.82 89. 31 58. 05 3141. 69 3030. 90 4755.63 2540.66 5975377 .49 501485. 94 MWD+IFR-AK-CAZ-SC 7471.04 91. 60 56. 84 3140. 95 3030. 16 4805.25 2618.38 5975427 .09 501563. 66 MWD+IFR-AK-CAZ-SC 7563.61 89. 42 53. 89 3140. 13 3029. 34 4857.85 2694.53 5975479 .68 501639. 81 MWD+IFR-AK-CAZ-SC 7613.59 86. 64 52. 33 3141. 85 3031. 06 4887.83 2734.47 5975509 .65 501679. 75 MWD+IFR-AK-CAZ-SC I 7654.00 86. 64 52. 33 3144. 22 , 3033. 43 4912.48 2766.40 5975534 .29 ' 501711. 69 - PROJECTED to TD Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. Dare: 2/9/2006 Time: 14.4027 P:~;;e: 3 Field: Kuparuk River Unit ! o-ordinatel\1:) Kcfc ecnce: Well: 2T-208, True North Site: Kuparuk 2TPad ~"crtical(T~~I)) ltcferc na•: 2T-208P61: 110.8 Nell: 2T-208 sectio^ f~~5~ Referenc e: Well (O.OON,O.OOE,49.25Azi) ~l'ellpath: 2T-2D8P61 Sur.cy (calculation M cthnd: PJlinimum Curdature Db: Oracle __ Survey: _- Start Date: _ -- Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 2T Pad Site Position: Northing: 5970382.43 ft Latitude: 70 19 49.129 N From: Map Easting: 498944.93 ft Longitude: 150 0 30.807 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg I ~ Well: 2T-208 Slot Name: Well Position: +N/-S 240.28 ft Northing: 5970622.69 ft Latitude: 70 19 51.492 N ' +E/-W -0.09 ft Position Uncertainty: 0.00 ft Easting : 498944.87 ft Longitude: 150 0 30.810 W Wellpath: 2T-208PB1 Drilled From: Well Ref. Point 501032051870 Tie-on Depth: 30.39 ft Current Datum: 2T-208P61: H eight 110.79 ft Above System Datum: Mean Sea Level Magnetic Data: 12/18/2005 Declination: 24.02 deg Field Strength: 57546 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction I ft ft ft deg ~ ~ 30.39 0.00 0.00 49.25 ~ Survey Program for Definitive Wellpath Date: 1/18/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 78.00 627.00 2T-208P61 gyro (78.00-627.00) CB-GYRO-SS Camera based gyro single shot 694.55 6693.07 2T-208PB1 (6 94.55-6693.07) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey Mll' 1nel Azim 7Vli Sys llU ~iS E/W NIapN t~1apE "foul ', ft deg deg ft ft ft ft ft ft - _ _ 30.39 0.00 0.00 30.39 -80.40 0.00 0.00 ___ 5970622.69 498944.87 _ TIE LINE 78.00 0.06 323.82 78.00 -32.79 0.02 -0.01 5970622.71 498944.86 CB-GYRO-SS 170.00 0.37 315.50 170.00 59.21 0.27 -0.25 5970622.96 498944.62 CB-GYRO-SS 259.00 3.73 335.43 258.93 148.14 3.11 -1.66 5970625.80 498943.21 CB-GYRO-SS I 289.00 4.66 330.13 288.85 178.06 5.05 -2.67 5970627.74 498942.20 CB-GYRO-SS ~ ~ ~ 348.00 5.39 318.49 347.62 236.83 9.21 -5.70 5970631.90 498939.17 CB-GYRO-SS 442.00 7.43 313.86 441.03 330.24 16.73 -13.01 5970639.42 498931.86 CB-GYRO-SS 532:00 7.09 318.58 530.31 419.52 24.92 -20.88 5970647.61 498924.00 CB-GYRO-SS 627.00 5.99 322.12 624.69 513.90 33.23 -27.80 5970655.92 498917.08 CB-GYRO-SS 694.55 7.33 326.79 691.78 580.99 39.62 -32.33 5970662.31 498912.55 MWD+IFR-AK-CAZ-SC 748.45 7.86 329.01 745.21 634.42 45.66 -36.11 5970668.35 498908.77 MWD+IFR-AK-CAZ-SC 845.34 12.86 330.64 840.49 729.70 60.74 -44.81 5970683.43 498900.07 MWD+IFR-AK-CAZ-SC 939.39 16.15 327.87 931.53 820.74 80.95 -56.90 5970703.64 498887.98 MWD+IFR-AK-CAZ-SC , 1030.00 18.48 333.44 1018.04 907.25 104.47 -70.03 5970727.16 498874.86 MWD+IFR-AK-CAZ-SC ~ i 1062.51 19.30 334.21 1048.80 938.01 113.91 -74.67 5970736.60 498870.22 MWD+IFR-AK-CAZ-SC 1094.15 20.73 335.71 1078.52 967.73 123.73 -79.25 5970746.42 498865.65 MWD+IFR-AK-CAZ-SC 1124.94 21.28 337.49 1107.27 996.48 133.86 -83.63 5970756.54 498861.27 MWD+IFR-AK-CAZ-SC 1159.12 21.60 338.46 1139.08 1028.29 145.44 -88.31 5970768.13 498856.59 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Company: ConocoPhilfipsAlaska Inc. Dare: 2/9/2006 Time: 14:40:27 Psi~c: Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2T-208, True'Norih tiitc: Kuparuk'2T Pad Vertical (T~'D) Reference: 2T'-208PB1: 110 R Well: 2T-208 ticction (VS) Reference: Well (0-OON,O-OOE,49 25Azi) Wellpatfi: 2T-208PB1 Survey Calculation Method: Minimum Curvafure llb: Oracle Survey ~lD [ncl .4zim T'VD tics fti'D Niti ElLV ~IapN M11apE Tool ft deg deg ft ft ft ft ft ft __ ---- 1189.98 23:49 339.08 1167.58 1056.79 156.47 -92.60 5970779.15 498852.31 MWD+IFR-AK-CAZ-SC ~ 1220.25 25.70 340.78 1195.11 1084.32 168.30 -96.91 5970790.99 498847.99 MWD+IFR-AK-CAZ-SC 1253.97 27.49 341.22 1225.26 1114.47 182.57 -101.82 5970805.26 498843.08 MWD+IFR-AK-CAZ-SC 1286.00 28.75 342.57 1253.51 1142.72 196.92 -106.51 5970819.61 498838.40 MWD+IFR-AK-CAZ-SC 1315.95 30.35 343.47 1279.56 1168.77 211.05 -110.82 5970833.73 498834.09 MWD+IFR-AK-CAZ-SC 1349.60 31.07 345.47 1308.49 1197.70 227.61 -115.42 5970850.29 498829.49 MWD+IFR-AK-CAZ-SC 1381.65 31.60 346.18 1335.87 1225.08 243.77 -119.50 5970866.45 498825.42 MWD+IFR-AK-CAZ-SC 1411.28 32.12 347.16 1361.03 1250.24 258.98 -123.10 5970881.67 498821.81 MWD+IFR-AK-CAZ-SC 1445.97 33.63 348.50 1390.17 1279.38 277.39 -127.07 5970900.07 498817.85 MWD+IFR-AK-CAZ-SC 1475.28 33.85 349.02 1414.54 1303.75 293.36 -130.24 5970916.04 498814.68 MWD+IFR-AK-CAZ-SC ~ 1506.79 34.84 349.23 1440.56 1329.77 310.82 -133.60 5970933.49 498811.33 MWD+IFR-AK-CAZ-SC 1539.30 37.01 350.38 1466.88 1356.09 329.59 -136.97 5970952.26 498807.96 MWD+IFR-AK-CAZ-SC 1602.00 41.16 354.32 1515.55 1404.76 368.75 -142.17 5970991.42 498802.77 MWD+IFR-AK-CAZ-SC 1648.98 43.41 357.70 1550.30 1439.51 400.27 -144.34 5971022.94 498800.60 MWD+IFR-AK-CAZ-SC 1759.07 47.63 2.13 1627.44 1516.65 478.76 -144.35 5971101.43 498800.60 MWD+IFR-AK-CAZ-SC ~ 1849.75 47.01 2.25 1688.91 1578.12 545.38 -141.80 5971168.03 498803.16 MWD+IFR-AK-CAZ-SC 1944.62 48.64 5.42 1752.62 1641.83 615.51 -137.08 5971238.16 498807.89 MWD+IFR-AK-CAZ-SC 2040.37 51.80 9.63 1813.89 1703.10 688.41 -127.38 5971311.05 498817.59 MWD+IFR-AK-CAZ-SC ~ 2134.01 53.99 11.94 1870.38 1759.59 761.76 -113.39 5971384.39 498831.60 MWD+IFR-AK-CAZ-SC i 2232.20 59.84 13.10 1923.96 1813.17 842.03 -95.54 5971464.64 498849.46 MWD+IFR-AK-CAZ-SC i 2324.25 62.37 15.62 1968.44 1857.65 920.08 -75.53 5971542.69 498869.47 MWD+IFR-AK-CAZ-SC 2420.16 65.69 19.66 2010.45 1899.66 1002.20 -49.37 5971624.80 498895.64 MWD+IFR-AK-CAZ-SC 2514.25 65.10 21.83 2049.63 1938.84 1082.19 -19.08 5971704.78 498925.95 MWD+IFR-AK-CAZ-SC 2608.46 65.72 22.89 2088.83 1978.04 1161.42 13.51 5971783.99 498958.54 MWD+IFR-AK-CAZ-SC 2702.26 67.28 22.50 2126.23 2015.44 1240.78 46.70 5971863.33 498991.74 MWD+IFR-AK-CAZ-SC i 2790.91 66.76 21.70 2160.84 2050.05 1316.39 77.40 5971938.94 499022.45 MWD+IFR-AK-CAZ-SC 2885.12 66.07 20.87 2198.54 2087.75 1396.84 108.75 5972019.38 499053.80 MWD+IFR-AK-CAZ-SC 2978.96 65.96 16.99 2236.70 2125.91 1477.92 136.56 5972100.44 499081.62 MWD+IFR-AK-CAZ-SC 3073.88 65.22 17.43 2275.92 2165.13 1560.48 162.13 5972183.00 499107.20 MWD+IFR-AK-CAZ-SC 3168.95 65.21 18.50 2315.78 2204.99 1642.59 188.75 5972265.09 499133.83 MWD+IFR-AK-CAZ-SC 3265.02 66.69 19.26 2354.93 2244.14 1725.59 217.14 5972348.08 499162.23 MWD+IFR-AK-CAZ-SC 3358.04 66.24 20.39 2392.07 2281.28 1805.82 246.06 5972428.29 499191.16 MWD+IFR-AK-CAZ-SC 3452.80 65.62 18.99 2430.72 2319.93 1887.28 275.21 5972509.74 499220.32 MWD+IFR-AK-CAZ-SC 3548.73 69.22 20.83 2467.55 2356.76 1970.54 305.39 5972592.99 499250.51 MWD+IFR-AK-CAZ-SC 3641.56 68.07 23.45 2501.36 2390.57 2050.61 337.96 5972673.05 499283.08 MWD+IFR-AK-CAZ-SC 3735.31 68.56 27.07 2536.01 2425.22 2129.38 375.13 5972751.80 499320.26 MWD+IFR-AK-CAZ-SC ~ 3829.30 70.27 32.68 2569.08 2458.29 2205.62 418.96 5972828.03 499364.09 MWD+IFR-AK-CAZ-SC i 3919.49 74.35 35.50 2596.49 2485.70 2276.74 467.12 5972899.14 499412.26 MWD+IFR-AK-CAZ-SC 4016.60 76.17 38.33 2621.20 2510.41 2351.81 523.53 5972974.19 499468.68 MWD+IFR-AK-CAZ-SC 4110.83 76.43 38.37 2643.52 2532.73 2423.61 580.33 5973045.97 499525.48 MWD+IFR-AK-CAZ-SC 4207.55 78.64 38.31 2664.39 2553.60 2497.68 638.91 5973120.03 499584.07 MWD+IFR-AK-CAZ-SC 4297.96 77.26 37.43 2683.27 2572.48 2567.47 693.19 5973189.81 499638.35 MWD+IFR-AK-CAZ-SC 4392.11 75.87 35.77 2705.14 2594.35 2640.98 747.79 5973263.30 499692.95 MWD+IFR-AK-CAZ-SC 4489.17 76.19 38.93 2728.58 2617.79 2715.84 804.92 5973338.15 499750.09 MWD+IFR-AK-CAZ-SC 4582.49 74.92 40.63 2751.86 2641.07 2785.29 862.74 5973407.58 499807.91 MWD+IFR-AK-CAZ-SC ~~ 4676.01 76.19 41.42 2775.19 2664.40 2853.61 922.18 5973475.89 499867.36 MWD+IFR-AK-CAZ-SC 4770.23 78.81 41.40 2795.58 2684.79 2922.60 983.02 5973544.86 499928.20 MWD+IFR-AK-CAZ-SC i ~ 4864.94 78.26 40.76 2814.40 2703.61 2992.56 1044.01 5973614.81 499989.20 MWD+IFR-AK-CAZ-SC 4958.38 78.93 38.65 2832.88 2722.09 3063.03 1102.52 5973685.25 500047.71 MWD+IFR-AK-CAZ-SC 5055.35 77.92 37.09 2852.34 2741.55 3138.01 1160.84 5973760.23 500106.03 MWD+IFR-AK-CAZ-SC 5148.92 76.20 37.15 2873.29 2762.50 3210.73 1215.87 5973832.92 500161.07. MWD+IFR-AK-CAZ-SC 5242.98 75.34 35.86 2896.42 2785.63 3284.01 1270.11 5973906.19 500215.31 MWD+IFR-AK-CAZ-SC ~, Halliburton Company Global Report Cnmpany: ConoCOPhillipsAlaska Inc. Datc: 2/9/2006 'lime: 14 :40'27 Pa;;c: 3 Field: Kuparuk River U nit Co-ordinatc(NE) Refcrencr. Well: 2T-208, True North Site: ''Kuparuk 2T Pad vertical (TVD) Refercncc: ZT-208PB1- 110.8 ~~'elL•'' 2T- 203 Se ction (~ SI Reference:. Well (O.OON.O OOE, 49.25Azi) Wellpath: 2T-208PB'1 Sun~c~ (~alcnlation McYhtxi: Minimum Curvatur e Ub: Oracle Survc~~ 1111 lncl ~cim l"I'll tit's ~I ~ I) N/S FaVV MapN NlapE "fool ft deg Jeg ft ft ft ft ft ft I 5338.10 75.68 35.51 2920.22 2809.43 3358. 81 1323.83 5973980. 98 500269. 04 MWD+IFR-AK-CAZ-SC 5431.49 74.15 34.76 2944.52 2833.73 3432. 55 1375.72 5974054. 70 500320. 94 MWD+IFR-AK-CAZ-SC 5526.42 76.22 38.20 2968.80 2858.01 3506. 32 1430.29 5974128. 46 500375. 51 MWD+IFR-AK-CAZ-SC 5619.44 76.19 39.45 2990.98 2880.19 3576. 69 1486.92 5974198. 82 500432. 14 MWD+IFR-AK-CAZ-SC 5714.77 75.33 38.19 3014.43 2903.64 3648. 68 1544.84 5974270. 79 500490. 07 MWD+IFR-AK-CAZ-SC ~ 5809.48 74.62 37.31 3038.98 2928.19 3721. 01 1600.84 5974343. 10 500546. 08 MWD+IFR-AK-CAZ-SC 5905.23 70.85 38.09 3067.40 2956.61 3793. 34 1656.74 5974415. 42 500601. 98 MWD+IFR-AK-CAZ-SC 5997.43 66.83 38.84 3100.67 2989.88 3860. 66 1710.21 5974482. 72 500655. 45 MWD+IFR-AK-CAZ-SC 6093.35 62.46 39.58 3141.74 3030.95 3927. 81 1764.99 5974549. 86 500710. 23 MWD+IFR-AK-CAZ-SC 6188.30 59.23 39.66 3187.99 3077.20 3991. 67 1817.86 5974613. 71 500763. 11 MWD+IFR-AK-CAZ-SC 6281.91 55.20 40.90 3238.67 3127.88 4051. 71 1868.71 5974673. 73 500813. 96 MWD+IFR-AK-CAZ-SC 6379.48 49.81 40.12 3298.04 3187.25 4110. 53 1918.99 5974732. 54 500864. 25 MWD+IFR-AK-CAZ-SC 6475.93 48.26 39.39 3361.27 3250.48 4166. 52 1965.57 5974788. 51 500910. 83 MWD+IFR-AK-CAZ-SC 6569.85 46.73 35.13 3424.74 3313.95 4221. 58 2007.49 5974843. 57 500952. 76 MWD+IFR-AK-CAZ-SC 6665.38 42.60 35.52 3492.67 3381.88 4276. 36 2046.31 5974898. 34 500991. 57 MWD+IFR-AK-CAZ-SC 6693.07 42.62 34.96 3513.05 3402.26 4291. 67 2057.12 5974913. 64 501002. 39 MWD+IFR-AK-CAZ-SC 6732.00 42.62 34.96 3541.70 3430.91 4313. 28 2072.23 5974935. 24 501017. 50 PROJECTED to TD S Halliburton Company Global Report (~ompanp: ConocoPhillips Alaska Inc. llate: 2/9/2006 '1'iroc: 15:15:45 Pale: 1 Ficld: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 2T-208, True Norfh Site: Kuparuk 2T Pad Vertical (1~~,`I?) Reference: 2T-208PB2: 110.8 Well: 2T-208 Section (VS) Referenc e: Well (O.OONQOOE,49.25Azi) ' Wellpath: 2T-208PB2 Survey Calculation M etBod: Minimum Curvatu€e Db: Oracle -__ Survey: _- Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ' Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 2T Pad Site Position: Northing: 5970382.43 ft Latitude: 70 19 49.129 N From: Map Easting: 498944.93 ft Longitude: 150 0 30.807 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg Well: 2T-208 Slot Name: Well Position: +N/-S 240.28 ft Northing: 5970622.69 ft Latitude: 70 19 51.492 N +E/-W -0.09 ft Easting : 498944.87 ft Longitude: 150 0 30.810 W Position Uncertainty: 0.00 ft Wellpath: 2T-208P62 Drilled From: 2T-208P61 501032051871 Tie-on Depth: 3358.04 ft Current Datum: 2T-208P62: Hei ght 110.79 ft Above System Da tum: Mean Sea Level Magnetic Data: 12/18/2005 Declination: 24.02 deg Field Strength: 57546 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.39 0.00 0.00 49.25 Survey Program for Definitive Wellpath Date: 2/9/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 78.00 627.00 2T-208PB1 gyro (78.00-627.00) CB-GYRO-SS Camera based gyro single shot 694.55 3358.04 2T-208PB1 (694.55-6693.0 7) (3) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC 3452.09 5600.12 2T-208P62 (3452.09-5600. 12) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey __ tilU Incl ~zim 'ICI) Scs"CVD N;S E/`~~~ MapN biapE - Tool ft deg deg ft ft ft ft ft ft 30.39 0.00 0.00 30.39 -80.40 0.00 0.00 5970622.69 498944.87 TIE LINE 78.00 0.06 323.82 78.00 -32.79 0.02 -0.01 5970622.71 498944.86 CB-GYRO-SS 170.00 0.37 315.50 170.00 59.21 0.27 -0.25 5970622.96 498944.62 CB-GYRO-SS 259.00 3.73 335.43 258.93 148.14 3.11 -1.66 5970625.80 498943.21 CB-GYRO-SS 289.00 4.66 330.13 288.85 178.06 5.05 -2.67 5970627.74 498942.20 CB-GYRO-SS 348.00 5.39 318.49 347.62 236.83 9.21 -5.70 5970631.90 498939.17 CB-GYRO-SS 442.00 7.43 313.86 441.03 330.24 16.73 -13.01 5970639.42 498931.86 CB-GYRO-SS 532.00 7.09 318.58 530.31 419.52 24.92 -20.88 5970647.61 498924.00 CB-GYRO-SS 627.00 5.99 322.12 624.69 513.90 33.23 -27.80 5970655.92 498917.08 CB-GYRO-SS 694.55 7.33 326.79 691.78 580.99 39.62 -32.33 5970662.31 498912.55 MWD+IFR-AK-CAZ-SC 748.45 7.86 329.01 745.21 634.42 45.66 -36.11 5970668.35 498908.77 MWD+IFR-AK-CAZ-SC 845.34 12.86 330.64 840.49 729.70 60.74 -44.81 5970683.43 498900.07 MWD+IFR-AK-CAZ-SC 939.39 16.15 327.87 931.53 820.74 80.95 -56.90 5970703.64 498887.98 MWD+IFR-AK-CAZ-SC 1030.00 18.48 333.44 1018.04 907.25 104.47 -70.03 5970727.16 498874.86 MWD+IFR-AK-CAZ-SC 1062.51 19.30 334.21 1048.80 938.01 113.91 -74.67 5970736.60 498870.22 MWD+IFR-AK-CAZ-SC 1094.15 20.73 335.71 1078.52 967.73 123.73 -79.25 5970746.42 498865.65 MWD+IFR-AK-CAZ-SC 1124.94 21.28 337.49 1107.27 996.48 133.86 -83.63 5970756.54 498861.27 MWD+IFR-AK-CAZ-SC ~ Halliburton Company ~, Global Report Cump:uq: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit tiitc: Kuparuk 2T P3d Well: 2T-208 Wellpath; 2T-208P$? Survey 11D L~cf ' ~zim TVD ft deg deg ft 1159 .12 21. 60 338. 46 1139.08 1189 .98 23. 49 339. 08 1167.58 ~ 1220 .25 25. 70 340. 78 1195.11 1253 .97 27. 49 341. 22 1225.26 1286 .00 28. 75 342. 57 1253.51 1315 .95 30. 35 343. 47 1279.56 1349 .60 31. 07 345. 47 1308.49 1381 .65 31. 60 346. 18 1335.87 1411. 28 32. 12 347. 16 1361.03 1445 .97 33. 63 348. 50 1390.17 1475 .28 33. 85 349. 02 1414.54 1506. 79 34. 84 349. 23 1440.56 1539 .30 37. 01 350. 38 1466.88 I 1602.00 41. 16 354. 32 1648.98 43. 41 357. 70 1759.07 47. 63 2. 13 1849.75 47. 01 2. 25 1944.62 48. 64 5. 42 2040.37 51. 80 9. 63 2134.01 53. 99 11. 94 2232.20 59. 84 13. 10 2324.25 62. 37 15. 62 j 2420.16 65. 69 19. 66 ~ 2514.25 65. 10 21. 83 2608.46 65. 72 22. 89 2702.26 67. 28 22. 50 2790.91 66. 76 21. 70 2885.12 66. 07 20. 87 2978.96 65. 96 16. 99 3073.88 65. 22 17. 43 i 3168.95 65. 21 18. 50 3265.02 66. 69 19. 26 3358.04 66. 24 20. 39 3452.09 62. 10 18. 59 3544.98 56. 87 17. 38 3606.44 58. 30 17. 04 3701.41 61. 78 15. 24 3794.47 65. 52 16. 80 I 3889.90 68. 79 18. 06 { 3985.11 69. 84 18. 54 4079.52 69. 19 18. 10 4173.39 68. 06 18. 23 4269.52 69. 39 18, 18 4364.75 68. 61 18, 26 4459.50 68. 71 17. 52 4554.61 68. 27 17. 10 4649.69 68. 10 18. 31 I 4745.26 68. 79 21. 86 4839.38 74. 06 26. 73 4935.84 75. 01 29. 86 5031.57 76. 56 36. 67 5126.49 77. 93 40. 39 5221.48 78. 15 44. 90 1515.55 1550.30 1627.44 1688.91 1752.62 1813.89 1870.38 1923.96 1968.44 2010.45 2049.63 2088.83 2126.23 2160.84 2198.54 2236.70 2275.92 2315.78 2354.93 2392.07 2433.05 2480.20 2513.14 2560.56 2601.86 Date: ?/9I2006 'Time: 15.15A5 Page: Z Co-ordinatcl]1') Reference: W~11; 2T-208, True North Vertical ("F~"D) Reference: 2T-208862: 110.8 Section (~~5~ Reference: Well (O.OON,O.OOE,4925Azi) Survey (';~Iculation Method: Minimum Curvature llb: Oracle Sys TVD \!S E,~~ _ _ MapN _ AlapE _ Tooi ft ft ft ft ft 1028.29 145. 44 -88.31 5970768.13 498856. 59 MWD+IFR-AK-CAZ-SC 1056.79 156. 47 -92.60 5970779.15 498852. 31 MWD+IFR-AK-CAZ-SC 1084.32 168. 30 -96.91 5970790.99 498847. 99 MWD+IFR-AK-CAZ-SC 1114.47 182. 57 -101.82 5970805.26 498843. 08 MWD+IFR-AK-CAZ-SC 1142.72 196. 92 -106.51 5970819.61 498838. 40 MWD+IFR-AK-CAZ-SC 1168.77 211. 05 -110.82 5970833.73 498834. 09 MWD+IFR-AK-CAZ-SC 1197.70 227. 61 -115.42 5970850.29 498829. 49 MWD+IFR-AK-CAZ-SC 1225.08 243. 77 -119.50 5970866.45 498825. 42 MWD+IFR-AK-CAZ-SC 1250.24 258. 98 -123.10 5970881.67 498821. 81 MWD+IFR-AK-CAZ-SC 1279.38 277. 39 -127.07 5970900.07 498817. 85 MWD+IFR-AK-CAZ-SC 1303.75 293. 36 -130.24 5970916.04 498814. 68 MWD+IFR-AK-CAZ-SC 1329.77 310. 82 -133.60 5970933.49 498811. 33 MWD+IFR-AK-CAZ-SC 1356.09 329. 59 -136.97 5970952.26 498807. 96 MWD+IFR-AK-CAZ-SC 1404.76 368. 75 -142.17 5970991.42 498802. 77 MWD+IFR-AK-CAZ-SC 1439.51 400. 27 -144.34 5971022.94 498800. 60 MWD+IFR-AK-CAZ-SC 1516.65 478. 76 -144.35 5971101.43 498800. 60 MWD+IFR-AK-CAZ-SC 1578.12 545. 38 -141.80 5971168.03 498803. 16 MWD+IFR-AK-CAZ-SC 1641.83 615. 51 -137.08 5971238.16 498807. 89 MWD+IFR-AK-CAZ-SC 1703.10 688. 41 -127.38 5971311.05 498817. 59 MWD+IFR-AK-CAZ-SC 1759.59 761. 76 -113.39 5971384.39 498831. 60 MWD+IFR-AK-CAZ-SC 1813.17 842. 03 -95.54 5971464.64 498849. 46 MWD+IFR-AK-CAZ-SC 1857.65 920. 08 -75.53 5971542.69 498869. 47 MWD+IFR-AK-CAZ-SC 1899.66 1002. 20 -49.37 5971624.80 498895. 64 MWD+IFR-AK-CAZ-SC 1938.84 1082. 19 -19.08 5971704.78 498925. 95 MWD+IFR-AK-CAZ-SC 1978.04 1161. 42 13.51 5971783.99 498958. 54 MWD+IFR-AK-CAZ-SC 2015.44 1240. 78 46.70 5971863.33 498991. 74 MWD+IFR-AK-CAZ-SC 2050.05 1316. 39 77.40 5971938.94 499022. 45 MWD+IFR-AK-CAZ-SC 2087.75 1396. 84 108.75 5972019.38 499053. 80 MWD+IFR-AK-CAZ-SC 2125.91 1477. 92 136.56 5972100.44 499081. 62 MWD+IFR-AK-CAZ-SC 2165.13 1560. 48 162.13 5972183.00 499107. 20 MWD+IFR-AK-CAZ-SC 2204.99 1642. 59 188.75 5972265.09 499133. 83 MWD+IFR-AK-CAZ-SC 2244.14 1725. 59 217.14 5972348.08 499162. 23 MWD+IFR-AK-CAZ-SC 2281.28 1805. 82 246.06 5972428.29 499191. 16 MWD+IFR-AK-CAZ-SC 2322.26 1885. 59 274.32 5972508.06 499219. 43 MWD+IFR-AK-CAZ-SC 2369.41 1961. 67 299.04 5972584.12 499244. 16 MWD+IFR-AK-CAZ-SC 2402.35 2011. 23 314.39 5972633.68 499259. 51 MWD+IFR-AK-CAZ-SC 2449.77 2090. 26 337.24 5972712.69 499282. 37 MWD+IFR-AK-CAZ-SC 2491.07 2170. 39 360.26 5972792.81 499305. 40 MWD+IFR-AK-CAZ-SC 2638. 91 2528.12 2254 .28 386.61 5972876 .69 499331. 76 MWD+IFR-AK-CAZ-SC 2672. 54 2561. 75 2338 .84 414.58 5972961 .24 499359. 74 MWD+IFR-AK-CAZ-SC 2705. 58 2594. 79 2422 .80 442.38 5973045 .18 499387. 55 MWD+IFR-AK-CAZ-SC 2739 .79 2629. 00 2505 .85 469.63 5973128 .23 499414. 81 MWD+IFR-AK-CAZ-SC 2774. 67 2663. 88 2590 .95 497.62 5973213 .31 499442. 80 MWD+IFR-AK-CAZ-SC 2808. 80 2698. 01 2675 .39 525.41 5973297 .74 499470. 61 MWD+IFR-AK-CAZ-SC 2843. 28 2732. 49 2759 .38 552.52 5973381 .72 499497. 73 MWD+IFR-AK-CAZ-SC 2878. 15 2767. 36 2843 .86 578.85 5973466 .18 499524. 06 MWD+IFR-AK-CAZ-SC 2913. 49 2802. 70 2927 .95 605,70 5973550 .26 499550. 92 MWD+IFR-AK-CAZ-SC 2948. 61 2837. 82 3011 .41 636,22 5973633 .71 499581. 45 MWD+IFR-AK-CAZ-SC 2978 .60 2867. 81 3092 .64 672.95 5973714 .93 499618. 19 MWD+IFR-AK-CAZ-SC 3004 .32 2893. 53 3174 .48 717.02 5973796 .76 499662. 26 MWD+IFR-AK-CAZ-SC 3027. 86 2917. 07 3252 .01 767.90 5973874 .27 499713. 15 MWD+IFR-AK-CAZ-SC 3048. 82 2938. 03 3324 .41 825.56 5973946 .66 499770. 82 MWD+IFR-AK-CAZ-SC 3068. 51 2957. 72 3392 .75 888.50 5974014 .97 499833. 76 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. Date: 2/9/2006 "rime: 15:15:45 Page: 3 Field: Kuparuk River U nit Co-ordinate(NE) Re ference: WeIL2T-208,T~ue North Site: Kuparuk 2T Pad Vertical (TVD) Refe rence: 2T-208P62: 110.8 ~~ ell: 2T-208 `ectiun (~ 11 Refere nce: Well (O.OON,O.OOE,49.25Azi) ~y~ellpath: 2T-208PB2 Sun~cr~ (~:~Iculatiun ~~lcthrrd: Minimum Curvature Db: Orade Survey ___ i'r1D Incf ~zim __ 7VD ' __ _ __ SysTVD N~ti E/W M:rpA MapF. "fool ft deg i deg _ ft _ ft ft ft -- ft ft ~ 5315.48 79.51 49.57 3086.73 2975.94 3455.34 956.19 5974077.55 499901.45 MWD+IFR-AK-CAZ-SC 5408.61 85.12 50.64 3099.18 2988.39 3514.51 1026.97 5974136.70 499972.23 MWD+IFR-AK-CAZ-SC 5504.13 85.24 49.32 3107.21 2996.42 3575.71 1099.86 5974197.89 500045.13 MWD+IFR-AK-CAZ-SC 5536.34 85.18 49.18 3109.90 2999.11 3596.66 1124.18 5974218.84 500069.44 MWD+IFR-AK-CAZ-SC 5568.04 85.24 49.17 3112.54 3001.75 3617.32 1148.08 5974239.48 500093.35 MWD+IFR-AK-CAZ-SC 5600.12 85.62 49.50 3115.10 3004.31 3638.15 1172.34 5974260.31 500117.60 MWD+IFR-AK-CAZ-SC 5642.00 85.62 49.50 3118.30 3007.51 3665.27 1204.09 5974287.43 500149.36 PROJECTED to TD i Halliburton Company! Global Report Company: ConacoPhillips Alaska Inc. Date: 2/9/2006 Time: 15:31:05 Pagc: Field: Kuparuk River Unit Co-ordinate(NE) Refe rence: Well: 2T-208, True North Site: Kuparuk'2T Pad Vertical (T~'D) Reference: 2T-208PB3: 110.8 Nell: 2T-208 Section I~~SI Referenc e: Well ("O.OON,O.OOE ;49.25Azi) Ncllpath: 2T-203~C3 SurveyC:~Icul3tiontl ethod: Minimum Curvature Db: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Kuparuk 2T Pad Site Position: Northing: 5970382.43 ft Latitude: 70 19 49.129 N From: Map Easting: 498944.93 ft Longitude: 150 0 30.807 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg Well: 2T-208 Slot Name: Well Position: +N/-S 240.28 ft Northing: 5970622.69 ft Latitude: 70 19 51.492 N +E/-W -0.09 ft Easting : 498944.87 ft Longitude: 150 0 30.810 W Position Uncertainty: 0.00 ft Wellpath: 2T-208P63 Drilled From: 2T-208P62 501032051872 ~ Current Datum: 2T-208PB3: Height 110.79 Tie-on Depth: ft Above System Da 4745.26 ft tum: Mean Sea Level Magnetic Data: 12/18/2005 Field Strength: 57546 nT ~ Vertical Section: Depth From (TVD) +N/-S Declination: Mag Dip Angle: +E/-W 24.02 deg 80.76 deg Direction ft -- ft ft deg ~- ~ 30.39 0.00 0.00 49.25 Survey Program for Definitive Wellpath Date: 2/9/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 78.00 627.00 2T-208PB1 gyro (78.00-627.00) CB-GYRO-SS Camera based gyro single shot 694.55 3358.04 2T-208P61 (694.55-6693.07) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3452.09 4745.26 2T-208PB2 (3452.09-5600. 12) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4812.00 7553.53 2T-208PB3 (4812.00-7553. 53) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey __ _. __ __ - J~1D Incl laim TVD Sic CVD N/S E/W A1apN tLlapE - "fool ft deg deg ft ft ft ft ft ft 30.39 0.00 0.00 30.39 -80.40 0.00 0.00 5970622.69 498944.87 TIE LINE ~ 78.00 0.06 323.82 78.00 -32.79 0.02 -0.01 5970622.71 498944.86 CB-GYRO-SS 170.00 0.37 315.50 170.00 59.21 0.27 -0.25 5970622.96 498944.62 CB-GYRO-SS ~ 259.00 3.73 335.43 258.93 148.14 3.11 -1.66 5970625.80 498943.21 CB-GYRO-SS I 289.00 4.66 330.13 288.85 178.06 5.05 -2.67 5970627.74 498942.20 CB-GYRO-SS 348.00 5.39 318.49 347.62 236.83 9.21 -5.70 5970631.90 498939.17 CB-GYRO-SS 442.00 7.43 313.86 441.03 330.24 16.73 -13.01 5970639.42 498931.86 CB-GYRO-SS 532.00 7.09 318.58 530.31 419.52 24.92 -20.88 5970647.61 498924.00 CB-GYRO-SS 627.00 5.99 322.12 624.69 513.90 33.23 -27.80 5970655.92 498917.08 CB-GYRO-SS 694.55 7.33 326.79 691.78 580.99 39.62 -32.33 5970662.31 498912.55 MWD+IFR-AK-CAZ-SC 748.45 7.86 329.01 745.21 634.42 45.66 -36.11 5970668.35 498908.77 MWD+IFR-AK-CAZ-SC 845.34 12.86 330.64 840.49 729.70 60.74 -44.81 5970683.43 498900.07 MWD+IFR-AK-CAZ-SC 939.39 16.15 327.87 931.53 820.74 80.95 -56.90 5970703.64 498887.98 MWD+IFR-AK-CAZ-SC 1030.00 18.48 333.44 1018.04 907.25 104.47 -70.03 5970727.16 498874.86 MWD+IFR-AK-CAZ-SC 1062.51 19.30 334.21 1048.80 938.01 113.91 -74.67 5970736.60 498870.22 MWD+IFR-AK-CAZ-SC 1094.15 20.73 335.71 1078.52 967.73 123.73 -79.25 5970746.42 498865.65 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. Uare: 2/9/2006 -lime: 15 :31:05 Pa:;c: 2 Field: Ku parukRiver Unit Caord inate(NE) Re ference. WeIG 2T--208, True North Site: Ku parak 2T Pa d Vertical(TVD) Reference: 2T-208P63: 110.8 Well: 2T -208 Section (VS) Refere nce: Well (O.OON,O.OOE-;4925Azi) ~l'ellpath: 2T-208P83 Survey Calculation 14ethoJ: Minimum Curvature Db: Oracle Survey NID Tncl Azim 'I'VD __ SysT'VD _ N/S F,/W 141apN _ _ _ N[apF. __ Tool ft deg deg ft ft ft ft ft ft i 1124 .94 21.28 337.49 1107 .27 996 .48 133. 86 -83.63 5970756.54 498861.27 MWD+IFR-AK-CAZ-SC 1159 .12 21.60 338.46 1139 .08 1028 .29 145. 44 -88.31 5970768.13 498856.59 MWD+IFR-AK-CAZ-SC 1189 .98 23.49 339.08 1167 .58 1056 .79 156. 47 -92.60 5970779.15 498852.31 MWD+IFR-AK-CAZ-SC 1220 .25 25.70 340.78 1195 .11 1084 .32 168. 30 -96.91 5970790.99 498847.99 MWD+IFR-AK-CAZ-SC I 1253 .97 27.49 341.22 1225 .26 1114 .47 182. 57 -101.82 5970805.26 498843.08 MWD+IFR-AK-CAZ-SC 1286 .00 28.75 342.57 1253 .51 1142 .72 196. 92 -106.51 5970819.61 498838.40 MWD+IFR-AK-CAZ-SC 1315 .95 30.35 343.47 1279 .56 1168 .77 211. 05 -110.82 5970833.73 498834.09 MWD+IFR-AK-CAZ-SC 1349 .60 31.07 345.47 1308 .49 1197 .70 227. 61 -115.42 5970850.29 498829.49 MWD+IFR-AK-CAZ-SC 1381 .65 31.60 346.18 1335 .87 1225 .08 243. 77 -119.50 5970866.45 498825.42 MWD+IFR-AK-CAZ-SC 1411 .28 32.12 347.16 1361 .03 1250 .24 258. 98 -123.10 5970881.67 498821.81 MWD+IFR-AK-CAZ-SC ~ 1445 .97 33.63 348.50 1390 .17 1279 .38 277. 39 -127.07 5970900.07 498817.85 MWD+IFR-AK-CAZ-SC 1475 .28 33.85 349.02 1414 .54 1303 .75 293. 36 -130.24 5970916.04 498814.68 MWD+IFR-AK-CAZ-SC 1506 .79 34.84 349.23 1440 .56 1329 .77 310. 82 -133.60 5970933.49 498811.33 MWD+IFR-AK-CAZ-SC 1539 .30 37.01 350.38 1466 .88 1356 .09 329. 59 -136.97 5970952.26 498807.96 MWD+IFR-AK-CAZ-SC i 1602 .00 41.16 354.32 1515 .55 1404 .76 368. 75 -142.17 5970991.42 498802.77 MWD+IFR-AK-CAZ-SC ~ 1648 .98 43.41 357.70 1550 .30 1439 .51 400. 27 -144.34 5971022.94 498800.60 MWD+IFR-AK-CAZ-SC 1759 .07 47.63 2.13 1627 .44 1516 .65 478. 76 -144.35 5971101.43 498800.60 MWD+IFR-AK-CAZ-SC 1849 .75 47.01 2.25 1688 .91 1578 .12 545. 38 -141.80 5971168.03 498803.16 MWD+IFR-AK-CAZ-SC 1944 .62 48.64 5.42 1752 .62 1641 .83 615. 51 -137.08 5971238.16 498807.89 MWD+IFR-AK-CAZ-SC j 2040 .37 51.80 9.63 1813 .89 1703 .10 688. 41 -127.38 5971311.05 498817.59 MWD+IFR-AK-CAZ-SC ~ 2134 .01 53.99 11.94 1870 .38 1759 .59 761. 76 -113.39 5971384.39 498831.60 MWD+IFR-AK-CAZ-SC 2232 .20 59.84 13.10 1923 .96 1813 .17 842. 03 -95.54 5971464.64 498849.46 MWD+IFR-AK-CAZ-SC 2324 .25 62.37 15.62 1968 .44 1857 .65 920. 08 -75.53 5971542.69 498869.47 MWD+IFR-AK-CAZ-SC 2420 .16 65.69 19.66 2010 .45 1899 .66 1002. 20 -49.37 5971624.80 498895.64 MWD+IFR-AK-CAZ-SC 2514 .25 65.10 21.83 2049 .63 1938 .84 1082. 19 -19.08 5971704.78 498925.95 MWD+IFR-AK-CAZ-SC 2608 .46 65.72 22.89 2088 .83 1978 .04 1161. 42 13.51 5971783.99 498958.54 MWD+IFR-AK-CAZ-SC 2702 .26 67.28 22.50 2126 .23 2015 .44 1240. 78 46.70 5971863.33 498991.74 MWD+IFR-AK-CAZ-SC 2790 .91 66.76 21.70 2160 .84 2050 .05 1316. 39 77.40 5971938.94 499022.45 MWD+IFR-AK-CAZ-SC ~ 2885 .12 66.07 20.87 2198 .54 2087 .75 1396. 84 108.75 5972019.38 499053.80 MWD+IFR-AK-CAZ-SC i 2978 .96 65.96 16.99 2236 .70 2125 .91 1477. 92 136.56 5972100.44 499081.62 MWD+IFR-AK-CAZ-SC j 3073 .88 65.22 17.43 2275 .92 2165 .13 1560. 48 162.13 5972183.00 499107.20 MWD+IFR-AK-CAZ-SC 3168 .95 65.21 18.50 2315 .78 2204 .99 1642. 59 188.75 5972265.09 499133.83 MWD+IFR-AK-CAZ-SC 3265 .02 66.69 19.26 2354 .93 2244 .14 1725. 59 217.14 5972348.08 499162.23 MWD+IFR-AK-CAZ-SC 3358 .04 66.24 20.39 2392 .07 2281 .28 1805. 82 246.06 5972428.29 499191.16 MWD+IFR-AK-CAZ-SC I 3452 .09 62.10 18.59 2433 .05 2322 .26 1885. 59 274.32 5972508.06 499219.43 MWD+IFR-AK-CAZ-SC ~ 3544 .98 56.87 17.38 2480 .20 2369 .41 1961. 67 299.04 5972584.12 499244.16 MWD+IFR-AK-CAZ-SC 3606 .44 58.30 17.04 2513 .14 2402 .35 2011. 23 314.39 5972633.68 499259.51 MWD+IFR-AK-CAZ-SC 3701 .41 61.78 15.24 2560 .56 2449 .77 2090. 26 337.24 5972712.69 499282.37 MWD+IFR-AK-CAZ-SC 3794 .47 65.52 16.80 2601 .86 2491 .07 2170. 39 360.26 5972792.81 499305.40 MWD+IFR-AK-CAZ-SC 3889 .90 68.79 18.06 2638 .91 2528 .12 2254. 28 386.61 5972876.69 499331.76 MWD+IFR-AK-CAZ-SC 3985 .11 69.84 18.54 2672 .54 2561 .75 2338. 84 414.58 5972961.24 499359.74 MWD+IFR-AK-CAZ-SC 4079 .52 69.19 18.10 2705 .58 2594 .79 2422. 80 442.38 5973045.18 499387.55 MWD+IFR-AK-CAZ-SC 4173 .39 68.06 18.23 2739 .79 2629 .00 2505. 85 469.63 5973128.23 499414.81 MWD+IFR-AK-CAZ-SC 4269 .52 69.39 18.18 2774 .67 2663 .88 2590. 95 497.62 5973213.31 499442.80 MWD+IFR-AK-CAZ-SC 4364 .75 68.61 18.26 2808 .80 2698 .01 2675. 39 525.41 5973297.74 499470.61 MWD+IFR-AK-CAZ-SC 4459 .50 68.71 17.52 2843 .28 2732 .49 2759. 38 552.52 5973381.72 499497.73 MWD+IFR-AK-CAZ-SC 4554 .61 68.27 17.10 2878 .15 2767. 36 2843. 86 578.85 5973466.18 499524.06 MWD+IFR-AK-CAZ-SC 4649 .69 68.10 18.31 2913 .49 2802. 70 2927. 95 605.70 5973550.26 499550.92 MWD+IFR-AK-CAZ-SC 4745 .26 68.79 21.86 2948 .61 2837. 82 3011. 41 636.22 5973633.71 499581.45 MWD+IFR-AK-CAZ-SC 4812 .00 69.92 24.54 2972 .14 2861. 35 3068. 80 660.82 5973691.09 499606.06 MWD+IFR-AK-CAZ-SC 4841 .22 70.43 25.70 2982 .05 2871. 26 3093. 69 672.49 5973715.97 499617.73 MWD+IFR-AK-CAZ-SC 4936 .78 70.49 31.29 3014 .04 2903. 25 3172. 80 715.44 5973795.07 499660.68 MWD+IFR-AK-CAZ-SC 5030 .82 76.42 34.65 3040 .81 2930. 02 3248. 36 764.50 5973870.61 499709.75 MWD+IFR-AK-CAZ-SC - --- - ----- ----- Halliburton Company. Global Report ('unrpanu: ConocoPhillips Alaska Inc. Date: 2/9/2006 Timc: 15 :31:05 Na~c: 3 Rield: Kupa€uk River Unit Co-ord inate(NE) Re ference: Well: 2T-208; True North Site: Ku paruk 2T Pad Vertical (TVD) Refe rence: 2T-208P83:110 8 Weil: 2T -208= Section(VS)Reference: WeIII O.OON,O.OOE, 49.25Azi1 WeHpath: 2T -208P63 Survey Calcula tion Method: Minim um Curvature Db: Orac{e Survev MD fncl Azim lVD Sys TVD N/S - E/~~~ MapN MapE ____ __ Tonl '~ ft deg deg ft ft ft ft ft ft 5127.07 77.64 39. 42 3062. 43 2951. 64 3323.20 820. 98 5973945 .44 499766.24 MWD+IFR-AK-CAZ-SC 5220.90 79.13 46. 54 3081 .34 2970. 55 3390.38 883 .61 5974012 .61 499828.86 MWD+IFR-AK-CAZ-SC 5315.16 80.63 49. 00 3097. 90 2987. 11 3452.74 952 .31 5974074 .95 499897.57 MWD+IFR-AK-CAZ-SC 5394.47 80.26 52. 51 3111. 07 3000. 28 3502.21 1012 .87 5974124 .40 499958.13 MWD+IFR-AK-CAZ-SC 5492.21 87.90 58. 39 3121. 16 3010. 37 3557.25 1092. 87 5974179 .43 500038.13 MWD+IFR-AK-CAZ-SC 5583.56 89.32 58. 46 3123. 37 3012. 58 3605.07 1170. 67 5974227 .23 500115.93 MWD+IFR-AK-CAZ-SC 5674.88 88.05 56. 55 3125. 47 3014. 68 3654.11 1247. 66 5974276 .26 500192.92 MWD+IFR-AK-CAZ-SC ~ 5766.58 88.90 53. 95 3127. 91 3017. 12 3706.35 1322. 98 5974328 .49 500268.23 MWD+IFR-AK-CAZ-SC ~ 5859.61 88.41 49. 01 3130. 09 3019. 30 3764.26 1395. 72 5974386 .38 500340.98 MWD+IFR-AK-CAZ-SC 5951.78 87.98 47. 52 3133 .00 3022. 21 3825.58 1464 .46 5974447 .68 500409.72 MWD+IFR-AK-CAZ-SC 6043.54 89.39 47. 74 3135. 10 3024. 31 3887.40 1532 .24 5974509 .49 500477.50 MWD+IFR-AK-CAZ-SC ~ 6138.76 89.82 48. 20 3135. 76 3024. 97 3951.15 1602. 96 5974573 .22 500548.23 MWD+IFR-AK-CAZ-SC 6232.39 90.80 48. 74 3135. 25 3024. 46 4013.23 1673. 05 5974635 .28 500618.32 MWD+IFR-AK-CAZ-SC 6327.31 90.30 46. 54 3134. 34 3023. 55 4077.18 1743. 18 5974699 .21 500688.45 MWD+IFR-AK-CAZ-SC 6422.53 90.19 46. 38 3133. 93 3023. 14 4142.77 1812. 21 5974764 .79 500757.48 MWD+IFR-AK-CAZ-SC 6517.64 89.69 47. 19 3134. 03 3023. 24 4207.89 1881. 52 5974829 .90 500826.80 MWD+IFR-AK-CAZ-SC 6612.50 90.43 47. 65 3133. 93 3023. 14 4272.08 1951 .37 5974894 .07 500896.65 MWD+IFR-AK-CAZ-SC 6701.48 88.54 45. 60 3134. 73 3023. 94 4333.18 2016 .04 5974955 .15 500961.32 MWD+IFR-AK-CAZ-SC ~ 6800.24 89.01 45. 27 3136. 84 3026. 05 4402.46 2086. 38 5975024 .42 501031.66 MWD+IFR-AK-CAZ-SC 6895.23 89.82 42. 74 3137. 81 3027. 02 4470.78 2152. 37 5975092 .72 501097.65 MWD+IFR-AK-CAZ-SC 6992.92 92.79 43. 13 3135. 59 3024. 80 4542.27 2218. 88 5975164 .20 501164.17 MWD+IFR-AK-CAZ-SC j 7088.12 89.57 42. 68 3133. 63 3022. 84 4611.98 2283. 67 5975233 .89 501228.96 MWD+IFR-AK-CAZ-SC 7149.29 89.75 42. 43 3133. 99 3023. 20 4657.04 2325. 04 5975278 .94 501270.33 MWD+IFR-AK-CAZ-SC 7195.63 90.07 41. 06 3134. 07 3023. 28 4691.61 2355. 89 5975313 .50 501301.19 MWD+IFR-AK-CAZ-SC 7284.19 96.03 44. 75 3129. 35 3018. 56 4756.36 2416 .06 5975378 .23 501361.35 MWD+IFR-AK-CAZ-SC 7379.19 89.71 47. 71 3124. 60 3013. 81 4821.95 2484. 53 5975443 .80 501429.83 MWD+IFR-AK-CAZ-SC 7471.94 81.58 50. 15 3131. 64 3020. 85 4882.66 2554. 19 5975504 .50 501499.49 MWD+IFR-AK-CAZ-SC 7553.53 80.47 51. 13 3144. 37 3033. 58 4933.77 2616. 49 5975555 .60 501561.80 MWD+IFR-AK-CAZ-SC 7594.00 80.47 51. 13 3151. 07 3040. 28 4958.81 2647. 57 5975580 .64 501592.87 PROJECTED to TD • • 13-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-208 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,895.23' MD Window /Kickoff Survey: 7,613.59' MD (if applicable) Projected Survey: 7,654.00' 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 ~° a r date t1 ~ 4 Signed ~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) C7 ~ -- I ~ ? (~~ ` l~ C, • 13-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-208 PB3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,745.26' MD Window /Kickoff Survey: 7,553.53' MD (if applicable) Projected Survey: 7,594.00' 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 Date ~ 6 ®~ Si ned 2 ~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 13-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-208 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 3,358.04' MD Window /Kickoff Survey: 5,600.12' MD (if applicable) Projected Survey: 5,642.00' 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 Date A 0 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 13-Mar-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-208 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 30.39' MD Window /Kickoff Survey: 6,693.07' MD (if applicable) Projected Survey: 6,732.00' 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 Date Z ~~ J ~ (~= Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) C~ ~ -- l ~ ? f° i .~ Re: Tabasco 2T-208 Update--205-187 Subject: Re: T~hasc;c 2T-?f )5 t_lpelate--2U5-18? From: Thuii3as'~laancler ~~oizl_maunder~a~lniin.st~~te.ak.us Date: ~~~",:d, ll Jail ~~)(1(~11:Q1:35 -(?9~0 'I'o: "Ha~~~icn. Philii~" ~~Phili}~.H~iy~l~n~coi~ocophillips.com== Thanks Philip. Other than to note that the orphan is now a "PB" with some number attached to it, nothing further is needed. Good luck successfully finishing the well. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 1/11/2006 10:44 AM: Tom, We would expect the "orphan" to collapse with no support. The "orphan'° was ~11 ft T11D at most above the reservoir between the exit and entry points. Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, January li, 2006 9:58 AM To: Hayden, Philip Subject: Re: Tabasco 2T-208 Update Hi Philip, Is expected that this "orphan section" will collapse? I would suspect that there is not a lot of tvd difference between the exit and re-entry in the Tabasco and the "orphan" course. Look forward to your reply. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 1/11/2006 9:51 AM: Tom, Just wanted to let you know the latest on this well. We exited the top of the reservoir at 7228' MD due to an unexpected change in the structure (thinner and with a different dip). We dropped angle and tagged the sand again at 7493' MD before calling TD at 7594' MD. Due to missing several hundred feet of potential pay due to this exit we have pulled back and begun sidetracking at 6900'. MD to redrill this last section. The screens we are planning to run will be run in this latest sidetrack. If you have any questions please let me know. Regards Philip 1 of 1 1/11/2006 11:02 AM Re: 2T-208 -Well Status with 2 sidetracks • Subject: Re: 2T-208 - Well Status with 2 sidetracks From: ThomasMaunder <tom_maunder@admin.state.ak.us Date: Tue, 03 J an 2O0F~ 12 : U? : ~ 6 -0900 "['o: "~~1cKec~er. Stcvc" ~ -Sic~~c.~t'IrKeeverr~iconoc~~phillips.com~% ~S -~~~ Hi Steve, I have reviewed the information you submitted and concur that running and cementing the casing as you plan will effectively isolate 2T-208PB2. Good luck with the remaining operations. Tom Maunder, PE AOGCC ever, Steve wrote, On 1/3/2006 11:00 AM: Li ed below is a summary of o r operations over the past few days on 2 -208. And ttached are directional pl ts, showing the three well bores in 2 -208, and a schem ic, showing the proposed status of the well following the ce nt job on the 7- 8" intermediate hole. «2T-208' oposed Status w.Inter Csg.pdf» Please let e know that you are n agreement with our plan to run and cement the 7-5/8" casin past the abandonne 2T-208PB2 well bore. Thanks Steve McKeever Senior Drilling Engi eer ConocoPhillips Alaska, Inc. phone: 907.265.6826 pager: 907.275.0369 fax: 907.265.1535 Units of Conversion: \ 1 kilogram of falling figs: 1 f 2T-208 Operations Summaries: 12/29/05: Fin POOH & LD BH #4, C/O ~ dling Tools to 3 1f2" Tbg, PU Cmt Singer RIH to 1,100', Cont RIH W ame on 5" 0 6734', Circ Clean & Set 3 out of 4 Cmt Plugs Per Well prog m 12/30/05: Fin Pluggi Back Pilot Hole to 3, 00', POOH LD 3 1/2" Stinger & 16 Stds of 5" DP, Serv ced Rig, Slip & Cut Drlg ine & Changed Out Saver Sub, MU 9 7/8" BHA #5 & Set wear Bshg, Test Mud M r, RIH o cmt top @ 3385' Circ & Drill cmt F/3385' to 400' 3?465/0&•SDdetracdkedmWellfrDitrectionally~DrilledT9 8"1Hole from 3,465' to 4309'. 1/1/0 Directionally Drilled 9 7/8" Hole from 4,309' to 4881' ,Circ hi-vis swe Directionally driilled 9 7/8" hol Fj5002' to 560 and pump hi-vis sweep w le drilling. 1/2/06: Directionally Drilled 9 7/8" Hole F/ 5,608' to 5,641 (LWD logs confirm wellbore is in shales above the Tabasco fo mation) Circ Hole Geology & Decision was Made Open Hole Sidetrack, POO to 4,750, Trenched W 11 to 4,812', Time Drilled & Sidetracked Well @ 4,812' D 'lling 9 7/8" Hole to 355'. 1 of 2 1/3/2006 12:02 PM 2T-208 -Well Status with 2 sidetracks • • Subject: 2T-?U~ -Well Status with 2 sidetr<<cks From:"Meheever, Steve" <Steve:McKee~~cra)cc~i~oa~philliE~s.~oin=> Datc: I u~, t) ~ lun 2006 11:00:43 -0~>~i0 I'o: toi~i ~~~aunc~er!riadmin.slatc.ak.us Tom - Listed below is a summary of our operations over the past few days on 2T-208. And attached are directional plots, showing the three well bores in 2T-208, and a schematic, showing the proposed status of the well following the cement job on the 7-5/8" intermediate hole. «2T-208 Proposed Status w.lnter Csg.pdf» Please let me know that you are in agreement with our plan to run and cement the 7-5/8" casing past the abandonned 2T-208PB2 well bore. Thanks Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc phone: 907.265.6826 pager: 907.275.0369 fax: 907.265.1535 Units of Conversion: 1 kilogram of falling figs: ~ P 13 ~.. ~E Oc-i ~~ r.ca ~ ~ r~0~- ~ \E- ~CZ~'~,[~C~ ~~e~9ea-S.i~i wCy ~ P\~SS~ bc~.c~- Qco~r-ice , ~ ~'c ~.2~-~- acv. ~.~~~> cg `~ ~~.o~ pc~ru~cc~~ card ~~~~~s c M't' ~~ C i c~~CC~.~ ~~~~~ ~~~~l~fJ C_ f 1 fig Newton ' _ 2T-208 Operations Summaries: j ~~~~ `~ ~ ~~~~~ 12/29/05: Fin POOH & LD BHA #4, C/O Handling Tools to 3 1/2" Tbg, PU Cmt Singer RIH to 1,100' , Cont RIH W/Same on 5" DP,to 6734' , Circ Clean & Set 3 out of 4 Cmt Plugs Per Well program 12/30/05: Fin Plugging Back Pilot Hole to 3,400', POOH LD 3 1/2" Stinger & 16 Stds of 5" DP, Serviced Rig, Slip & Cut Drlg Line & Changed Out Saver Sub, MU 9 7/8" BHA #5 & Set wear Bshg, Test Mud Mtr, RIH to cmt top C~ 3385' Circ & Drill cmt F/3385' to 3400' 1 oft 1/3/2006 11:20 AM 2T-208 -Well Status with 2 sidetracks • • 12/31/05: Drilled cement from 3,400' to 3,450', Time Drilled from 3,450' to 3,465' & Sidetracked Well, Directionally Drilled 9 7/8" Hoie from 3,465' to 4309'. 1/1/06: Directionally Drilled 9 7/8" Hole from 4,309' to 4881' ,Circ hi-vis sweep, Directionally driilled 9 7/8" hole F/5002' to 5608' and pump hi-vis sweep while drilling. 1/2/06: Directionally Drilled 9 7/8" Hole F/ 5,608' to 5,641', (LWD logs confirm wellbore is in shales above the Tabasco formation) Circ Hole F/Geology & Decision was Made Open Hole Sidetrack, POOH to 4,750, Trenched Well to 4,812', Time Drilled & Sidetracked Well C~ 4,812' Drilling 9 7/8" Hole to 5,355'. 1/3/06: TD hole 9-7/8" hole at 5436'. Content-Description• 2T-208 Proposed Status w.Inter Csg.pdf 2T-208 Proposed Status w.Inter Csg.pdf Content-Type: application/octet-stream Content-Encoding: base64 2 of 2 1/3/2006 11:20 AM ConocoPhillips Ala.~ka 4500 3750 c 0 ~ 3000 t 0 2250 Z L 7 ~ 1500 T hlzimuths to True North Magnetic North: 24.00° 0 Magnetic Field Strength: 57545.5nT Dip Angle: 80.76° Date: 1/2/2006 0 Model: BGGM2005 • 2T-208 P62 2T-208 Rig. -~ • Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: Plan: 2T-208 Wellbore: Plan 2T-208 Design: 2T-208 Rig Y. 2T-208 P61 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 West(-)/East(+) (1500 iVn) c_ 0 M_ L Q N lII U N N 7 H 1925 2100 2275 2450 2625 2800 2975 3150 3315 35vu solo oo~v +~~~ +~~~ ~~•~ Vertical Section at 7.76° (350 ft/in) Surface Casing: 10-3/4", 45.5#, L-80, BTC 1688' MD / 1578' TVD ~- Proposed Top of Cement @ 2395' MD Top of West Sak @ 2908' MD, 2209' ND ~--- (Above sidetrack point, will be covered when casing is run in sidetrack hole) ~~~ Sidetrack Point from 2T-208PB1 @ 3450' \ ~ ~ , MD / 2432 ND 2T-208PB1 TD at 6732' `~~~ \~~~ MD/3542'ND ~~~ ~~~ Tabasco Formation Top ~' ~ ` @ 6062' MD / 3127' ND _ _ _ 2T-208PB2 TD @ 5641' -----_____ MD/3119'ND Sidetrack Point from - ' - - - _ 2T-208 PB2 @ 4812° _ - - MD/3069ND ---__ NOTES: The top Tabasco formation was expected at 5244' MD / 3086' TVD with a dip of +/- 1 degree. When the Tabasco had not been penetrated at a depth of 5641' in 2T-208P62, a decision was made to sidetrack the well, and drill vertically deeper. The actual top was found at 5382' MD / 3108' TVD in the sidetracked hole, with actual dip thought to be 2.5 degrees. l'No significant hydrocarbon bearing cones were penetrated in the abandoned 2T-208PB2 hole. The plan is to run and cement 7-5/8" casing at 5436' MD. Tabasco Formation Top @ 5382' MD / 3108 ND ~_ 2T-208 TD @5436' MD i 13118' ND Intermediate Casing: 7-5/8", 29.7#, L-80, BTCM 5436' MD 13118' ND Tabasco Well 2T-208 ~;~i~~~~~ Proposed Status of Wellbores upgon Cementing ~"(~ ' II Intermediate Casin prepared by Steve McKeever 2T-2081ntermediate Hole.vsd ~r~2oos a ~ ~ ~~~~ ~, ~ ~?,~ ~%' FRANK H. MURKOWSK/, GOVERNOR ~~~tr ~~~~++ ~~a~ ~t ~~+ ~-7~A OII! ~ ~ ~ 333 W. 7"' AVENUE, SUITE 100 C011TSI.'~RQA'TIO1Q COMDiI5SIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk Field Field 2T-208 305-397 Dear Mr. Thomas: 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. Please provide at least twenty-four (24) hours 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 r . Baring has been requested. / Sincerely, ~ DATED this~!r day of December, 2005 Encl. I L ~ S STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION «/~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ^/ Suspend ^ Operational shutdown ^ Perforate ^ ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^' Exploratory ^ 205-187 3. Address: Stratigraphic [] Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23260-70 7. KB Elevation (ft): 9. Well Name and Number: 30' AMSL 2T-208 8. Property Designation: 10. Field/Pools(s): ADL 25569 & 25548 / ALK 2667!2662 Ku aruk River Field /Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 6762' 3585' 6312' 3257' 6312', 5862', 4000', 3 Casing Length Size MD TVD rs Collapse Structural Conductor 80' 16" 108' 108' ~) ~ ,~ Surface 1658' 10.75" 1688' 1578' ~~ Cptps Intermediate 4r~~~ ~/o!r Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/28!2005 Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: ~~`` Date: i WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative:'+~ ~~~~ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve McKeever alb. 265-6826 Printed Name Thomas Title Greater Kuparuk Area Drilling Team Leader Signature Phone 265-6830 Date 12 ~ Q ~ . ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Nu~mjber:~j n ' J / // Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~ ~ ~~ Other: \s`~cC t~\.~5~-.~ ~Drc'~G~,C, ~?' a\L`LfO~~ 4-~7.+J'=C~ p\~~~~~~°~..~~t~'C.,+ ~ ~\~O~.t ~ ~. p ` ~~~~1~ ~'~, :-~~ ~ ~ Laos Subseque qu' ' d ~ ti ~~ ~~- ~~ft ~~ ` ~ APPROVED BY Appro COMMISSIONER THE COMMISSION Date: ~ ~ ~~ ~/ ~ Form 10-403 Revised 7/2005 ORIGINAL SUBMIT IN DUPLICATE • • McKeever, Steve From: McKeever, Steve Sent: Wednesday, December 28, 2005 10:26 AM To: tom maunder@admin.state.ak.us Subject: FW: P&A Procedure for 2T-208 Pilot hole Hi Tom- Based on actual tops in the hole, here is a revised P&A procedure for the 2T-208 Pilot hole. Based on your phone message this morning approving this plan, we will proceed wifih this procedure, and will submit a 403 application this afternoon. I have shown the top of the West Sak in this revised schematic. Note it is above our expected point of sidetrack from the pilot hole. These West Sak sands above-our kick off point will be cased off, with cement brought above the West Sak when the intermediate casing is run in the sidetrack hole. ..Again, please call with any questions or concerns. - - Steve McKeever 2T-208 Pilot ~A Plan.pdf (67 . -----Original Message----- From: McKeever, Steve Sent: Tuesday, December 27, 2005 3:56 PM To: tom_maunder@admin.state.ak.us; winton_aubert@admin.state.ak.us Subject: P8iA Procedure for 2T-208 Pilot hole Tom - Please find attached a schematic, with procedure embedded, of the proposed plugging operations for the pilot hole on well 2T-208, Permit to Drill # 205-187. Can you please provide approval of this procedure, with the understanding that an Application for Sundry Approval (403) will be submitted tomorrow? Only two significant hydrocarbon bearing zones are open in the pilot hole, the West Sak and the Tabasco. The Tabasco will be completely covered with cement, with the top of cement planned to be at least 200 feet above the top of the Tabasco. To cover the West Sak, a highly viscous pill will be spotted in open hole, with the top of this pill to be at least 100 feet below the base of the West Sak formation. Then a cement plug will be placed from this viscous pill to above- our sidetrack point, so that all West Sak sands in the pilot hole will be covered with cement. Please call should you have any questions or concerns about this proposed procedure. Thanks Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. phone: 907.265.6826 pager: 907.275.0369 fax: 907.265.1535 Units of Conversion: l kilogram of falling figs: 1 fig Newton 2 Conductor Casing Shoe @ 108', 16", 62.5#, API 5L Grade B Surface Casi 10-3/4", 45.5#, L-~ 1688' MD / 1578' ND Nordic Rig 3 Datum =Rig Floor = 0 feet Datum Elevation = 110 feet AMSL, 30 feet above pad. Top of West Sak @ 2908' MD, 2209' ND \ • (Above sidetrack point, will be covered when casing is run in sidetrack hole) \ ~ Top of Plug #4 at 3,400' MD, 2411' TVD, Inclination = 66 deg ~. Two plugs, each +/- 430 cubic ` \ feet 15.8 ppg Class "G"cement (370s~acsealgh)\`~E,~. ~ k ~\ v J a o e r l n ~ ~~ ~ O n to pump 4 plugs to abandon the pilot hole. All plugs to ~ 15.8 ppg Class "G" cement, with a yield of 1.16 cf per k. Assume hole diameter is 11-'/~' (35% excess volume Run in hole to TD with a 3-'/2' tubing stinger and lay in Plug #1, a 450' (finished length) plug from TD @ 6762' to +/- 6312' . POOH to 6312' and circulate pipe and hole clean. Lay in Plug #2, a 450' plug from 6312' to 5862'. POOH to +/- 5800' and circulate pipe and hole clean. POOH to 4875'. Lay in a 35 bbl hi-vis pill from the 4875' to +/- 4600' . Pick up to +/- 4600', and lay in Plug #3, a 600' plug from 4600' to 4000' . Pick up to +/- 4000', circulate pipe and hole clean. Lay in Plug #4, a 600' plug from 4000' to 3400'. POOH to 3400' and circulate pipe and hole clean. POOH, laying down drill pipe and tubing as needed. Make up drilling assembly and RIH, tagging top of top plug. Sidetrack Pomt @3490 MD,12450 ND, Inclination = 67 deg Top of Plug #3 at 4000' MD, 2619' ND, Inclination = 76 deg Base of West Sak Formation at 4325' MD, 2671 TVD, Inclination \ ~ = 78 deg ~\ x \ ~O O Bottom of Plug #3 at 4600' MD, 2758' TVD, Inclination = 75 deg 35 bbl Hi-vis pill, top at 4600' MD, 2758 TVD, Inclination = 75 deg. Bottom at 4875' MD, 2818' ND, Inclination = 78 deg ~-- 9.2 ppg Drilling Mud i Top of Plug #2 at 5862' ~' MD, 3055' TVD, Inclination = 73 deg Top of Tabasco Formation at 6061' MD, ~- 3129 ND, Inclination = \ 64 deg i Two plugs, each +/- 320 cf 15.8 Class "G"cement (275 sacks each) ~~...E s~~ <:~: ~ 1 Top of Plug #1 at 6312' MD, 3257' ND, Inclination = 54 deg TD 9-7/8" Open Hole @ 6762 MD, 3585 TVD, Inclination = 35 deg ~,/ Tabasco Well 2T-2~8 prepared by Steve McKeever • • gg • g 2T-208 Pilot P & A Plan and ~onocoPh~ I ~ p~ Pilot o e u In Schematic and Operations Sch12/28/2005 • r Calculeaon Method: MlMmum Curvature ` t c '*a+~~~ ~ •p+ 9mn Mehod Trev. CyNn~der^N°nh ~~ 7:}k3 Error 9urtau: ElllplblConk WamM9 Melhotl: Rules Based Geodetlc Dalum: NAD 19271NADCON CONU9) Magnalk Model: BGOM2005 HALLJBl1RTON eo.1o Sorry Oriltine Borv{oe>t "E,. ~. Nortlk 3~ 110.408 (Nordk 3 (80.N30q 597~~ o-+ 1 Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: PIan:2T-208 Wellbore: PIan:2T-208 Plan: 2T-208 wp05 AlMIOTATIONS TVD TVDss MD MMtotatlon 2181.45 2351.05 3490.00 Sldetrock Polnt; 4° DLS, 45° TFO, 3490' MD, 2481' TVD; 2704' FNL b 4438' FEL; See01•T11N4i08E 2805.43 2895.03 4315.71 Begin Pump Tangent Sedbn 4315.71' MD • HWd 85.38° WC, 18.71° Asm 2888.75 2778.35 4515.71 Contlnw Dir ~ 4°I1001L 4518R~, 28898 TVD 3091.59 2981.19 5295.00 7 Sl8" Cog Pl; 295' MD, 3091' TVD; 1191' FNL 6 3712' FEL; Sec01-T71N4M8E 3100 40 2990 Sd62.05 Target (Heel); 5462.05' MD, 3100.40' ND 3110.40 3000 6162.67 Target (Tt); 6162.6T MD, 3110.40' ND 3110.40 3000 6782.00 Target (`T2); 6762.00' MD. 3110.10' ND 3120.40 3010 7282.07 Target (T3); 7262.OT MD, 7120.40' TVD 3120.40 3010 7554.28 Target (foe); 7556' MD. 3120' TVD, 1993' FNL d 2031' FEL; Sac7fi-T72N-ROBE SECTION DETAILS See MD Inc Azi TVD TVDSS +NI•S +E/-W DLeg TFace VSec Target 1 3490.00 85.38 18.71 2461.45 2351.05 1933.56 286.83 0.00 0.00 1479.44 2 4515.71 65.38 18.71 2888.75 2778.35 2816.73 585.99 0.00 0.00 2282.57 3 5462.03 89.18 49.15 3100.40 2990 3560.82 1100.74 4.00 55.66 3158.24 :?r~208wp05 Herl 4 616265 89.18 49.17 3110.40 3000 4018.94 1630.73 0.00 67.26 3858.79 zL208wp06 T1 5 6192.95 90.06 49.40 3110.60 3000.2 4038.70 1653.69 3.00 14.90 3889.08 6 6721.37 90.06 49.40 3110.01 2999.61 4382.59 2054.91 0.00 0.00 4417.51 7 6761.98 88.85 49.29 3110.40 3000 4409.04 2085.72 3.00 -174.86 4458.11 T-208wp05 T2 8 7262.05 88.86 49.29 3120.40 3010 4735.13 2464.71 0.00 0.00 4958.08 2T-208wp05 T3 9 7303.31 90.09 49.44 3120.78 3010.38 4762.00 2496.02 3.00 7.09 4999.34 10 7554.29 90.09 49.44 3120.40 3010 4925.18 2686.71 0.00 0.00 5250.31 2T-208Mrp05 Tw C_ O O to t a G 1800 N V 0) m 3 H 2400 10 3/4" Csg - 13 1/2" Hole Base West Sak 3000 -- - Tabasco 3600 - y. ..... _.. ....... ; _. .. -- 0 600 Sidetrack Point; 4° DLS, 45° TFO, 3490' MD, 2461' TVD CA3WG DETAl3 FORIMTION TOP DETAa.S No ND MD Nama Sin No.TVDPNh TVD98 MDPaN Fomtapm 1 1576.89 1670.00 10 7l/" Ceg -17 112" (tole tOJ/4 i 10.1510 1315 1565.85 Permafrost 2 7081.59 5285.00 ] Sl8^ bg -9112" Hde 7-se ~ 162210 1512 t 781 AS Top U1plu C a 7t2o./o 7sse.oo ~ 1n• c.g - e v/° Nw. av2 3 221/.40 eta 2686.98 Top wea sek 0 4 2711.40 2601 10.99 Bsee West Sek 5 7099.10 2668 5120.27 Tebeaeo Continue Dir @ 4°/100ft, 4516ft MD, 2889ft ND Target (T3); 7262.07' MD, 3120.40' TVD Target (T2); 6762.00' MD, 3110.40' ND I Target (T1); 6162.67' MD, 3110.40' ND 41/2" Csg - 6 3/4" Plan: ~\ Target (Toe); 7554' MD, 3120' ~~ T 42100 4800 5400 Re: FW: P&A Procedure for 2T-208 Pilot hole • Sut~ject: Re: FW P&A Procedure for ZT-208 Pilot hole From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 28 Dec 20~» 11i:ti5:?7 -0900 rho: ";~~1cKc~e~er, Stc~~" ~~-Ste~~e.~~lcKce~cn~i~conocophillips.com-> C'C': ;~OC;CC ~'or~h Slo~c Ot~fic~ <aogccprudhoe ha~~~ri;aihnin.state.al~.us> Steve, Thanks for the additional information. Your plan is acceptable. There will not be a need to tag the deep plug, provided there are no difficulties encountered placing it. Your upper plug will be tagged when you kickoff and then the wS will be covered when the production casing is cemented. Good luck with the operations. Call or message with any questions. I will look for the sundry today. Tom Maunder, PE AOGCC McKeever, Steve wrote, On 12/28/2005 10:26 AM: Hi Tom- Based on actual tops in the hole, here is a revised P&A procedure for the 2T-208 Pilot hole. Based on your phone message this morning approving this plan, we will proceed with this procedure, and will submit a 403 application this afternoon. I have shown the top of the West Sak in this revised schematic. Note it is above our expected point of sidetrack from the pilot hole. These West Sak sands above our kick off point will be cased off, with cement brought above the West Sak when the intermediate casing is run in the sidetrack hole. Again, please call with any questions or concerns. Steve McKeever «2T-208 Pilot P&A Plan.pdf» -----Original Message----- *From: * McKeever, Steve *Sent: * Tuesday, December 27, 2005 3:56 PM *To: * ton: mazerder.~~adn.i_n.state.ak.i<.s; w.9.nton. aubertCaadmin.state.ak.la.s *Subject: * P&A Procedure for 2T-208 Pilot hole Tom - Please find attached a schematic, with procedure embedded, of the proposed plugging operations for the pilot hole on well 2T-208, Permit to Drill # 205-187. Can you please provide approval of this procedure, with the understanding that an Application for Sundry Approval (403) will be submitted tomorrow? Only two significant hydrocarbon bearing zones are open in the pilot hole, the West Sak and the Tabasco. The Tabasco will be completely covered with cement, with the top of cement planned to be at least 200 feet above the top of the Tabasco. To cover the west Sak, a highly viscous pill will be spotted in open hole, with the top of this pill to be at least 100 feet below the base of the West Sak formation. Then a cement plug will be placed from this viscous pill to above our sidetrack point, so that all West Sak sands in the pilot hole will be covered with cement. Please call should you have any questions or concerns about this proposed procedure. 1 of 2 12/29/2005 7:17 AM Re: FW: P&A Procedure for 2T-208 Pilot hole • Subject: Re.:FW: P&AProcedure~for 2T-208 Pilot hole From: Thomas Maunder <tom maunder@adnlin.state.ak.us> Date: Wed, 28 Dec ?005 10:55:27 -0900 To: "N1cK~e~cr. Stc~~" ~--Stet c.~l~Kee~cr~;uconoro~~hillix~s.c~~t~~ CC: ~~t)GC~C \orth Slope Ulfice -~ao~~c~ pru~lhoc ha~~~~~a~hnin.s<<ite.al..us- Steve, J ~ ~ ~ ~~~ Thanks for the additional information. Your plan is acceptable.. There will not be a need to tag the deep plug, provided there are no difficulties encountered placing it. Your upper plug will be tagged when you kickoff and then the WS will be covered when the production casing is cemented. Good luck with the operations. Call or message with any questions. I will look for the sundry today. Tom Maunder,. PE AOGCC McKeever, Steve wrote, On 12/28/2005 10:26 AM: Hi Tom- Based on actual tops in the hole, here is a revised P&A procedure for the 2T-208 Pilot hole. Based on your phone message this morning approving this plan, we will proceed with this procedure, and will submit a 403 application this afternoon. I have shown the top of the West Sak in this revised schematic. Note it is above our expected point of sidetrack from the pilot hole. These West Sak sands above our kick off point will be cased off, with cement brought above the West Sak when the intermediate casing is run in the sidetrack hole. Again, please call with any questions or concerns. Steve McKeever «2T-208 Pilot P&A Plan.pdf » -----Original Message----- *From: * McKeever, Steve *Sent: * Tuesday, December 27, 2005 3:56 PM *To: * tom maunder:~is.d?r:i.n.state.ak.t;.s; wi.nton a.ubertia?adm~.n.state.ak.us *Subject: * P&A Procedure for 2T-208 Pilot hole Tom - Please find attached a schematic, with procedure embedded, of the proposed plugging operations for the pilot hole on well 2T-208, Permit to Drill # 205-187. Can you please provide approval of this procedure, with the understanding that an Application for Sundry Approval (403) will be submitted tomorrow? Only two significant hydrocarbon bearing zones are open in the pilot hole, the West Sak and the Tabasco. The Tabasco will be completely covered with cement, with the top of cement planned to be at least 200 feet above the top of the Tabasco. To cover the West Sak, a highly viscous pill will be spotted in open hole, with the top of this pill to be at least 100 feet below the base of the West Sak formation. Then a cement plug will be placed from this viscous pill to above our sidetrack point, so that all West Sak sands in the pilot hole will be covered with cement. Please call should you have any questions or concerns about this proposed procedure. 1 of 2 12128!2005 11:18 AM Re: FW: P&A Procedure for 2T-208 Pilot hole • • Thanks Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. phone: 907.265.6826 pager: 907.275.0369 fax: 907.265.1535 Units of Conversion: 1 kilogram of falling figs: 1 fig Newton 2 of 2 12/28/2005 11:18 AM Re: Packer setting depth 2T-208 & 203 ~ • Subject: Re: Packersetting depth 2T-208 & 203 From: Thol7~asMaunder atom maunder@admin.state.ak.us-> Datc: E'~'cci, ~ i? Dcc ?(lfl5 07:05:4E -09(l~ To: "Hati~~icn. Philip" <Philip.Ha.ycl~n~cconocophilltps.co~»-> Philip, There is no specification regarding the packer depth on a production well. What likely applies is "good oilfield practice" and based on your comment, you are setting the packer where you are because of the requirements of the equipment you are using. Good luck with the operations. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 12/6/2005 3:19 PM: Tom, I just wanted to confirm that you are aware and approve that the packer with which we will be hanging off our production screens will be positioned approximately 500' inside the 7 5/8" casing. This is due to the space out required for circulating with the screens in place. Please let me know if you were not aware or if this presents a problem for the commission. Regards Philip ~~~ ~ NCO 1 of 1 1/12/2006 8:03 AM Re: 2T-208 Pilot hole Subject: Re: 2T-208 Pilot hole From: Thomas Nt~iunder - to~i~ maundcr~~r aaminatate.ak_u~-= Date: Fri, 02 D~~c 2005 U7:?7:~(, -U~)i)O ~~~- ~~ To: "Hayden, Philip" <Philip.Havdcn(a:conocophillips.com=~ Philip, This message is sufficient notification/information on your planned changes. I don't see a need for you to submit new anti collision paperwork. Key point is that it has been done. I really didn't have a concern that the new calculations had been done, just need to ask the question. Changing when you test the casing and the test pressure is also not a problem. I always preferred to have the drilling assembly in the hole as you are planning. 3500 psi is more the normal test pressure I see these days. The test pressure requirement of the regulations is a minimum value. You have more information as to what the actual operating conditions for the well will be and testing to the higher value based on that knowledge is valid. I will put a copy of this message in the well file. Good luck with the operations. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 12f 112005 5:02 PM: Tom, It turns out that the KOP will be at the same depth but the tangent angle has been dropped to a mare manageable 77 degrees. Therefore we will intersect the Tabasco about 200' short of the original pilot hole plan. We have carried out our anti collision analysis and things look OK. I can forward you the new well plan for the pilot hole if you would like to see the profiles, anti-collision etc? Also, in our permit package we stated that we wauld pressure test the casings before running in hole with our drilling assemblies. We would like to change this so that we plan on cleaning out to the float equipment before doing our casing tests. In addition we would like to potentially increase the 7 5/8°' pressure test from 2500 psi, as stated in our permit package, to 3500 psi. Please let me know if these modifications are acceptable to you. Regards Philip -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, November 30, 2005 10:37 AM To: Hayden, Philip Subject: Re: 2T-208 Pilot hole Philip, I don't believe that anything additional is necessary. How high are you raising the KOP? Moving the KOP could affect your proximitylanti-collision calculations, but I would presume that revising that information is standard when the planned profile of a well is changed. I look forward to your reply. Tom Maunder, PE AOGCC 1 of 2 12/2/2005 8:18 AM Re: 2T-208 Pilot hole Hayden, Philip wrote, On 11/30/2005 10:24 AM: Tom, We have been doing some last minute torque & drag work for the pilot hole to be drilled on 2T-208 and it looks like we will have to change the profile slightly in order to be able to get to TD. We will only be raising the planned KOP so as to give us a better tangent angle for weight transfer to the bit. The target of the pilot hole and the main well bore plan itself remain unchanged. Do you need any more formal communication for this change? Please let me know and I will happily oblige. Philip 2 of 2 12/2/2005 8:18 AM Re: 2T-208 • Subject: Re: 2T-208 From: Thomas Maunder <tom_maunder@,admin.sta~te.ak.us> Date: Wed; 23 Nov 2005 ~ ~ i :1 } : ~ ~ -0900 I'o: "Hav~icn. Philip" <=Philip.Nay-~len~ci~ca~locophillips.com~= Philip ,J v ~ ~ a ` Thanks for the reply. Equipping the BOP with the casing rams is acceptable. You might check with the WS guys as to how they are rigged up for testing. Call or message with any questions or comments. Tom Maunder, PE AOGCC Hayden, Philip wrote, On 11/22/2005 4:27 PM: Tom, With reference to your points below: 1. It is our plan to drill out the 7 5/8" casing with the intermediate mud and then monitor the well as we increase our rate to our planned drilling one before displacing to the Flo-Pro system. From your description below this would seem to qualify as a "drillout FIT" or a dynamic FIT as someone here called it. In future I will include this .in our applications if that is our plan. 2. We are going to wait on the logs before we decide on the exact P&A plan for the pilot hole. I'm thinking that we will try and cover the whole Tabasco with cement, in several stages if necessary, and then lay in a kick off plug higher up the hole. However, given the angles we are dealing with we are still going through our options. We will be sure to send in the 403 as required. 3. We had not thought of using the West Sak BOP set-up until you mentioned it! If we can arrange to have the casing rams in the lower cavity and if this is acceptable to you we would like to do so. Regards Philip -----Original Message----- From: Thomas Maunder [mailto:tom maunder~~admir_.state.ak.us] Sent: Tuesday, November 22, 2005 9:10 AM To: Hayden, Philip Subject: 2T-208 Hi Philip, Three items on 2T-208. 1. After setting the 7-5/8" casing you state that a LOT is not planned. It may be more proper to state that you will actually conduct a "drillout FIT". This is possible since there is such a contrast between your formation pressure and the actual mud weight. I think BP has included such wording in their applications that I reviewed a few years back. There procedure was to drillout with the heavier mud they planned to replace and then observe the well from 10 minutes. The clean. mud they would be circulating in had a lower mud weight than what was used to drillout. 2. You will be plugging back quite a bit of hole on the pilot. How much of the "hole" do you plan to cement?? I noted on the drilling permit that you will need to submit a 403 with the plugging details. 3. Where you describe the BOP you refer to "the information on file". We do have BOP and pit diagrams for Nordic 3. Your MASP calculates pretty low and you 1 oft 11/23/2005 7:13 AM Re: 2T-208 • plan to do a 3000 psi BOP test. This is not a problem. Do you plan to have the BOP equipped "normally" or do you plan to have casing rams in the lower cavity like they have been doing for West Sak?? Thanks, Tom Maunder, PE AOGCC 2 of 2 11!23!2005 7:13 AM ~~ ~ ' ~ ~~ ~ ~:' ~,~ , s-~ ~ ~ )~ a~ ? Y ~~"g ~a FRANK H. MURKOWSKI, GOVERNOR I~ ~~ OuI ~ ~~a7 ~ ~' 333 W. 7"' AVENUE, SUITE 100 COI~TSERQAZ'IO1D1' COhil-iISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU/Tabasco 2T-208 ConocoPhillips Alaska, Inc. Permit No: 205-187 Surface Location: 4637' FNL, 4724' FEL, Sec. 1, T11N, R8E Bottomhole Location: 4993' FNL, 2034' FEL, Sec. 36, T12N, R8E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice far a representative of the Commission to witness any required test. Contact thf; Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this~ay of November, 2005 cc: Department of Fish & Game, Habitat Section wJ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~~~ ~Lf Alaska tai dt Gas Cons. Comrrnssiort~ Anchorage C 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Stratigraphic Test ^ Service^ Development Gas ^ Single Zone ^/ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 2T-208 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 7554' ~ TVD: 3120' 12. Field/Pool(s): Kuparuk River Field 4a. Location of We{I (Governmental Section): Surface: 4637' FNL, 4724' FEL, Sec.1, T11N, R8E 7. Property Designation: ADL 25569/25548 Tabasco Oil Pool Top of Productive Horizon: 1228' FNL, 3777 FEL, Sec.1, T11N, R8E ~ 8. Land Use Permit: ALK2667/2662 13. Approximate Spud Date: 12/15/2005 Total Depth: 4993' FNL, 2034' FEL, Sec.36, T12N, R8E ` 9. Acres in Property: 2560 14. Distance to ~Cf~ ~(~ ~rryf.C /~Le Nearest Property: 20 ~U~s ry 4b. Location of Well (State Base Plane Coordinates): d Surface: x- 498944.87 ~~ y- 5970622.7 Zone- 4 10. KB Elevation (Height above GL): 30 feet 15. Distance to Nearest r` zr~~z~7A- ,..7i~ . Well within Pool: 2T- 16. Deviated wells: Kickoff depth: 2g0 i ft. Maximum Hole Angle: g0° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1183 psig Surface: 789 psig '~ 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5 H-40 Welded 78 0 0 108 108 50 sx "High Early" - 9/4/1998. 13.1/2" 10 3/4" 45.5 L-80 BTCM 1670 0 0 1670 ~ 1537 380 sx ASLite, 380 sx DeepCRETE 9 7!8" 7 5/8" 29.7 L-80 BTCM 5295 0 0 5295 3092 360 sx DeepCRETE 6 3/4" 4 1/2" 12.6 13Cr VAM 2559 4995 3044 7554 3120 NA -Screens 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 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 Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Philip Hayden @ 265-6481 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ~C- ~ ""'~---1~- Phone LAS ~y ~ ~1 Date t i~t"~(p- ~. V -•}--`"''~ Pre ar Shar 11 -Dr ke Commission Use Only Permit to Drill Number. ~~a ~ - j~j ~ API. Number: 50- /~~'l~~~~ "~'~~ Permit Ap1proval Date: ~ ` p~ a,, • O~ See cover letter for other requirements Conditions of approval S ple required Yes ^ No ~ Mud log required Yes ^ No ,~ ydro n sulfide measures Yes ~ No ^ Directional survey required Yes ~ No ^ Other: ~ S~ S~"'G'-S`'Q~~+:c~~~ , pt~~~jCs-~~~`Gi1S ~-`~~ti'~C G ~~~ APPROVED BY App THE COMMISSION Date: ~ ZI (/~ Form 10-401 Revis 612004 Submit in Duplicate #~~. S i~ L/'c Y • ConocoPhillips Conoco/Phillips, Inc. Post Office Box 100360 Anchorage, Alaska 99510 November 18, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Surface Location: Top Productive Horizon: Bottom Hole Location: • ~. .~. ~ . ~.. ~~ska Uil ~ ~n~1ro~~4~ ~ ,E.;~ . . 2T-208 4637' FNL, 4724' FEL, Sec. 1, T11N, R8E, UM 1228' FNL, 3777' FEL, Sec. 1, T11 N, R8E, UM 4993' FNL, 2034' FEL, Sec. 36, T12N, R8E, UM Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies fora "Permit to Drill" for the producer well 2T-208. The well will be drilled and completed using Nordic Calista Rig #3. The planned spud date for 2T-208 is December 15, 2008. A pilot hole will be drilled for geologic control prior to drilling the production hole to TD. The pilot hole (2T-208PB1) will be plugged back to a suitable kick-off point. <° /` The following logs are to be run on this well: GR/Res/Density/Neutron and possibly Lateralog if it is available. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be hauled for treatment and injection in an approved Prudhoe or GKA disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25,070) 263-4612 6) Geologic Data and Logs Pat Perfetta, Geologist (20AAC 25.071) 263-4411 If you have any questions or require further information, please contact Phillip Hayden at (907) 265-6481. Sincerely, '"'~. ~~ Randy Thomas Kuparuk Drilling Superintendent A~tion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 Permit It -Tabasco Well #2T-208 Horizontal •'°d rn Application for Permit to Drill Document +'t • h~It~~cW~ll Mdxirriia~ Well ~fallt~e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c) (4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(1 D) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c){11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 2T--208 PERMIT iT.doc Page 1 of 7 Printed: 18-Nov-05 A~tion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plans - 2T--208 & 2T-208PB1 (25 pages) ..................................................... 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................ 7 Attachment 3 Cement Loads and CemCADE Summary (2 pages) ...................................................... 7 Attachment 4 Well Schematic (1 page) ................................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each we// must be identified by a unique name designated by the operator and a unique API number assigned 6y the commission under 20 AAC 25.040(6). For a we// with mu/tip/e we/I branches, each branch must similar/y be identified by a unique name and API number 6y adding a suffix to the name designated for the we// by the operator and to the number assigned to the wel/ by the Commission. The well for which this application is submitted will be designated as 2T-208. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must 6e accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed /ocation of the we// at the surface, at the tap of each objective formation, and at total depth, referenced to governmental section lines (B) the coordinates of the proposed /ocation of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Nat/anal Oceanic and Atmospheric Administration; (C) the proposed depth of the we/I at the top of each objective formation and at total depth, Location at Surface 4637' FNL 4724' FEL Sec 1 T11N R8E UM NGSCoordinates RKB Elevation 110.4AMSL Northings; 5970622.69 Eastings; 498944.87 Pad Elevation 80.4 AMSL Location at Top of Productive Interval Tabasco 1228 FNL, 3777' FEL, Section 1, T11N, R8E, UM '~ NGS Coordinates Measured De th, RKB; 5244 Northings; 5974031.97 Eastings; 499890.18 Total Vertical De th, RKB.• 3086 Total Vertical De th, SS.• 2976 Location at Total De th 4993 FNL, 2034' FEL, Section 36, T12N, R8E, UM NGS Coordinates Measured De th, RKB.• 7554 Northings; 5975547 Eastings; 501632 Total Vertical De th, RKB; 3120 Total Vertical De th, SS.• 3010 and (D) other information required 6y 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a we/f is to 6e intentionally deviated, the application for a Permit to Dri1/ (Farm 10-401) must (I) include a plat, drawn to a suitable scale, showing the path of the proposed welibore, including a/> adjacent wellbares within 200 feet ofany portion ofthe proposed wef/; 2T--208 PERMIT lT.doc Page 2 of 7 Printed: 18-Nov-05 • A~tion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 Please see Attachment 1: Directional Plan for both the pilot hole (2T-208PB1) and the well bore to be completed (2T-208). and (2) for ali wefts within 20(7 feet of the proposed wet/bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in pubiic records, and show that each named operator has been furnished a copy of the app/ication by certified mail; or (B) state that the applicant is the only affected owner. The .Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already an file with the commission and identified in the app/ication; (3) a diagram and description of the blowout prevention equipment (SC1PE) as required by 20 AA C 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; The BOPE will consist of an 11" x 5M BOP stack and 21 ~/a" 2M Diverter with 16" line. Please see information on the Nordic Calista Rig #3 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drit/ must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application; (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Tabasco sands in the 2T-208 area vary from 0.25 to 0.33 psi/ft, or 4.9 to 6.3 ppg EMW (equivalent mud weight). The pressure data was estimated using information from downhole gauges in the field. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Tabasco formation is 789 psi, calculated as follows: MPSP = (3585 ft)(0.33 - 0.11 psi/ft) = 789 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormaiiy geo pressured strata, lost circulation zones, and zones that have a propensity for differential sucking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to [?rill must be accompanied by each of the following items, except for an item already on file -with the commission and identified in the appGcation.~ (S) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); All Formation Integrity Tests (FIT) will be performed in accordance with the LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. An FIT will be pen`ormed after setting the 10 3/a" surface casing. Currently there is no plan to perform an FIT after drilling out the 7 5/8" casing. V ~c v et ~ ~~~ ~ o vJ ~t~E~e's~t+.~ ~t~~ ~ ~S Seim ~ n CYe ~`~ ~~~ ~ ~ Sh ~" ~V~ i ~ i i ~'~i~~ ~! w ~ it ~-- ~ ~ SN ~ ~,~ ~-'~ G~Ltj M \ ~ ~'~~~ ~ ~ ~ iV~~ ` l T-208 PERMIT IT.doc ~~ ~~.; '~ ~ `~ v~9`i t.~ ~ ~C ~ ~C- i ~~ ~ C, ~ ~ S ~'~i3 ~~ 1 ~ ~, S ~. ~~.5 V.1~ ~ Page 3 of 7 ~~~ ~ V1 ~ ~,~ ~~ ' ^ ~ ~ ~ ~ ~ ~ Printed: 18-Nov-05 • A~tion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 6. Casing and Cementing Program Requirements. of 20 AAC 25.005(c)(6) An app/icatian for a Permit to Dri// must be accompanied by each of the following items, except far an item already on file with the commission and identified in the application: (6) a complate proposed casing and cementing program as required by 20 AAC 25, 030, and a descriptioon of any slotted liner, pre- perfarated liner, or screen to be installed; Casin and Cementin Pro ram Hole Top etm Csg/Tbg Size Weight Length MD/TI/D (RKB) MD/1VD (RKB) OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 16 24 62.5 H-40 Welded 78 0 / 0 108 / 108 Cemented with 50 sx "Hi h Earl " 10 3/4 13 '/z 45.5 L-80 BTC, AB 1670 0 / 0 1670/1537 Cemented to Modified Surface with 380 sx ASLite Lead, 380 sx DeepCRETE Tail 7 5/8 9 7/8 29.7 L-80 BTC, AB 5295 0 J 0 5295/3092 360 sks Modified DeepCRETE 4 ~/z 6 3/a 12.6 13CR VAM 2559 4995 / 3044 7554 / 3120 NA /Screens & blank i e See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dr/Il must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a d/agram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21 ~/a", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2T-208. Please see diagrams of the Nordic Calista Rig #3 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application far a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (8) a dri!ling fluid program, inc/ud/ng a diagram and descrlpt/on of the drilling fluid system, as required by 20 AAC 25.033; Surface Drilling will be done with a bentonite based mud system, the intermediate hole with an LSND type mud system and the production hole with MI's Flo-Pro mud system. Drilling will be done having the following approximate properties over the listed intervals: S ud to Base of Permafrost Intermediate Ho% Section Production Interval Initial Value Final Value Density (ppg) 8.5 - 10.0 ~ 8.9 - 9.2 ~ 9.1 - 9.3 Funnel Viscosity seconds +150 +65 40-50 Plastic Viscosity c 8_12 Yield Point cP 30-50 15-30 24-30 26-30 pH 8.5-9 8.5-9 8.5-9 9-9.5 APl Filtrate(cc) g 5.5-8 4-6 4-6 2T--208 PERMIT lT.doc Page 4 of 7 Printed: 18-Nov-05 o~~~t~~~ • A~ion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 Chlorides (mg/l) <500 <500 <500 35000 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic Calista Rig #3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An applcation for a Permit to Drif! must be accompanied by each of the fallowing items, except for an item already on fi/e with the commission and identified in the app/ication; (9) for an exp/oratory or stratigraphic test well, atabu/atr`on setting out the depths of predicted abnormally geo pressured strata as required by 2D AAC25.033(fJ; Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Dril/ must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application; (10) for an explanatory or stratigraphic test we//, a seismic refraction or retTectian analysis as required by ZD AAC 25, D61(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application; (11) for a we// driA/ed from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an ana0ysis ofseabed conditions as required by 2D AAC 25. D61(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An appiieatian for a Permit to Drill must be accompanied by each of the fo/fowfng items, except for an item a/ready on file with the commission and identfied in the application; (12) evidence showing that the requirements of10AAC25.D25 {Banding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applcation for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application; The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Move In /Rig Up Nordic Calista Rig #3. 2. Provide 24 hour notice to AOGCC inspectors to witness diverter test and pending spud of well. Nipple up and function test the Diverter System. Prepare spud mud. 3. Spud and directionally drill surface hole to (1670' MD / 1537' ND (below base of the permafrost) as per the directional plan. Run MWD tool as required for directional monitoring. 4. Condition mud & hole for running casing. POOH. Run & cement 10 3/a" casing to surface. Displace cement with mud. Perform top job if required. ~, ~o ~+~ ~rr+~~r,~SS ~ O~ ORIGINAL 2T--208 PERMlT lT.doc Page 5 of 7 Printed: 18-Nov-05 • A~tion for Permit to Drill, Well 2T-208 Revision No.0 Saved: 18-Nov-05 6. Remove diverter system and install wellhead and test. Install and test li" x 5,000 psi BOP's and test to 3000 psi (Note that this test pressure is less than the working pressure of the BOP). Notify AOGCC 24 his before test. Pressure test casing to 2500 psi and record results. 7. Prepare LSND mud system for intermediate/pilot hole section. 8. PU 9 7/8" PDC bit & 6 3/a" drilling assembly with MWD/LWD (GR/RES/DENS/NEU). RIH, clean out casing to top of float equipment. 9. Drill out float equipment .and 20 ft of new hole. Perform LOT or FIT to 11 ppg EMW recording results. 10. Directionally drill pilot hole (2T-208 P61) to 6870 ft MD / 3585 ft TVD. POOH. 11. Review well logs and RIH with 600 ft tubing stinger on end of drill-pipe for plug back operations.` Plug back pilot hole w/ cement as per AOGCC requirements. Provide 24 hr notice to AOGCC :/ inspector for opportunity to witness plug placement & tag. 12. PU 9 7/8" PDC bit & 6 3/a" drilling assembly with MWD/LWD (GR/RES) &RIH. Kick off top of cement plug at approximately 3490' MD and drill intermediate hole section to 5295' MD / 3092' TVD (into top of Tabasco sand) as per the directional plan. 13: Condition mud & hole for running casing. POOH. 14. Run & cement 7 5/8" casing. Pressure test casing string to 2500 psi and record results. 15. PU 6 3/a" PDC bit, motor, MWD/LWD (GR/RES/DENS/NEU & LAT if available) and remaining BHA components, RIH. 16. Drill out float equipment. 17. Swap out LSND mud with Flo-Pro mud system. 18. Drill Horizontal production hole to 7,554` MD / 3120' TVD. 19. Condition mud & hole as required for running completion screens. Displace to brine. 20. POOH and LD excess drillpipe. 21. RIH with clean out assembly. Pump wash pills as necessary. Condition brine. POOH. J 22. RIH with 4 ~/z" screens, 2 7/8"inner string and liner hanger on drillpipe. 23. Set hanger and packer. Spot Wellzyme /Acid Flush across screen / wellbore annular space. POOH w/ DP and inner string. 24. Run ESP pump and GLM's on 4'/z"tubing. Land tubing. 25. ND BOPS/NU Tree, freeze protect, RD, Release rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication far a Permit to Drill must be accompanied by each of the fa/lowing items, except for an item already on fi/e with the commission and identified in the app/icationr ORIGINAL 2T--208 PERMIT IT.doc Page 6 of 7 Printed: 18-Nov-05 • A~ion for Permit to Drill, Well 2T-208 Revision No.O Saved: 18-Nov-05 (X4) a genera/ desorption ofhow the operatorplans to dispose ofdrr//rng ntud and cuttings and a statement of whether the operator intends to request author/zatron under ZO AAC 25. tJBII for an annular drsposa! operation rn the we/%; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage there and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2T-208 for annular disposal of fluids occurring as a result of future drilling operations on 2T pad 15. Attachments Attachment 1 Directional Plans - 2T--208 & 2T-208P81 (25 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 pages) Attachment 4 Well Schematic (1 page) oRicwa~ 2T--208 PERMIT lT.doc Page 7 of 7 Printed: 18-Nov-05 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River UniE Kuparuk 2T Pad Plan: 2T-208 Plan: 2T-208 Plan: 2T-208wp05 Proposal Report 09 November, 2005 • Sperry Dr~~ln~ Services ORIGINAL ~-' ~ Calculetlon Matlatl: Minimum Curveturo ~t]~tIOCCy~1~~~1~35 E„°,Sntam iscwsA Project: p Scan Method: Tmv. Cylinder North Error Budaca: Elllptlfal COnic Ku aruk River Unit WaMng Method: RUMS Based '~"'~'~ ~eotln1c ~~tl"Mm.i TeccMCO~N coNUSI Site: Kuparuk 2T Pad Plan: 2T-208 Well: plan: 2T-208 HALLIBURTON ,:r, ; .~ , __-__ - ~.~.i4~ASV V. 59'fx Sperry Drilling Services ~-;'s..~pnsax: a9B9aa SHL; 4637' FNL & 4724' FEL; Sec01-T11N-R08E 0 KOP @ 290ft MD, 290ft TVD -Build @ 3°/100ft Continue Dir @ 4°I100ft, 623ft MD, 622ft TVD 103/4" Csg -131/2" Hole 10314" Csg Pt; 1670' MD,1536' TVD Permafrost Top Ugnu C Sail @ 65.38°Inc & 18.71 °Azi : 2452ft MD, 2029ft TVD Top West Sak D Base West Sak Continue Dir @ 4°/100ft, 4516ft MD, 2889ft TVD Target (Tce); 7554' MD, 3120' TVD, 4993' FNL 8: 2034' FEL; Sec36-T12N-R08E Target (T3); 7262.07' MD, 3120.40' TVD Tabasco I I 7~~sg-•g-til"Tiole I / 7 518" Csg Pt; 5295' MD, 3091' TVD;1191' FNL & 3742' FEL; Sec01-T11 N-R08E / IX Target (T1); 6162.67' MD, 3110.40' TVD I Target (Heel); 5462.05' MD, 3100.40' TVD Target (T2); 6762.00' MD, 3110.40' TVD 0 700 1400 2100 2800 3500 4200 Vertical Section at 49.25° (700 ft/in) 41/2" Csg - 6 3/4" Hole 4900 5600 `,. CekuMllan Method. Mlnlnun CurvoW~e F eor Sy9xn: ISG1VSa1 CO~1CfCOPrt~l~tp-5 SanMeUgd. Tmr.L)AlrWerNaN Project: Kuparuk River Unit ~ 1 E^a5~~' EllptlralC°nk wem~Mem°a: wrseased Site: Kuparuk 2T Pad rti.~i_K~ ~oastonh,o: unnienlrloocwcouus, Well: Plan: 2T-208 MagwUC Model. BGGM3XG Wellbore: plan: 2T-208 HALLIBURTON "~~ ~; ~ ~~„~,imrrt,tn~~.asou-~,tl~~ Plan: 2T-208wp05 - ,,, I~ Sperry Drilling Services ~ °""'~"sF x ~"~ Target (Tce); 7554' MD, 3120' TVD, 4993' FNL 8 2034' FEL; Sec36-T12N-R08E '---~_ Target (T3); 7262.07 MD, 3120.40' ND j Target (T2); 6762.00' MD, 3110.40' TVD -~_ 4250 - _ Target (T1); 6162.67 MD, 3110.40' TVD '--._ -_---_ _. _ _.. __-_-, et (Heel); 5462.05' MD, 3100.40' TVD 7 5/8"Csg - 91/2" Hole ~0 7 5/8" Csg Pt; 5295' MD, 3091' ND; 1191' FNL & 3742' FEL; Sec01-711 N-R08E - ~ O CO Continue Dir @ 4°/100k, 4516ft MD, 2889k TVD O Z .••. ~ __ _... ~~~ i SHL; 4637 FNL 84724' FEL; Sec01-T11Na208E __ T -2550 -1700 -850 0 10314" Csg -131/2" Hole 103/4" Csg Pt;1670' MD,1536' ND KOP @ 290k MD, 290k TVD -Build @ 3°/100ft 4112" Csg - 6 3/4" Hole 850 1700 2550 3400 4250 5100 '-1/East(+1 (850 ft/inl ConocoPhittips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska{Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: Plan: 2T-208 Welfbore: Plan 2T-208 Design: 2T-208wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBCJRTON Sperry Drilling Services Well Plan: 2T-208 Nordic 3 @ 110AOft (Nordic 3 (80.4+30)) Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) True Minimum Curvature Project Kuparuk River Unit; North Slope Alaska, United States Map System: US State Plane 1927 (F~cact 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 II Well Plan: 2T-208 Well Position +NIS 0.00 ft Northing: 5,970,622.89 ft Latitude: 70° 19' 51.492" N +E!-W 0.00 ft Easting: 498,944.87 ft Longitude: 150° 00' 30.810" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 80.40 ft Wellbore Plan: 2T-208 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) i BGGM2005 12/31/2005 24.00 80.76 57,545 _I Design __ 2T-208wp05 I Audit Notes: Version: 2 Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (ft) (ft) (ft) (°) L_ 30.00 0.00 0.00 49.25. I Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (f{) (°/100ft) (°l100ft) (°1100ft) (~) 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 290.00 0.00 0.00 290.00 0.00 0.00 0.00 0.00 0.00 0.00 623.33 10.00 310.00 621.64 18.65 -22.23 3.00 3.00 0.00 310.00 1,316.68 36.00 340.00 1,255.95 253.43 -140.35 4.00 3.75 4.33 39.16 1,900.32 43.50 15.00 1,710.00 613.63 -147.12 4.00 1.29 6.00 85.68 2,452.33 65.38 18.71 2,029.15 1,040.09 -15.82 4.00 3.96 0.67 9.01 4,515.71 65.38 18.71 2,888.77 2,816.74 585.94 0.00 0.00 0.00 0.00 5,462.05 89.18 49.16 3,100.40 3,560.82 1,100.74 4.00 2.52 3.22 55.66 6,162.67 89.18 49.16 3,110.4D 4,018.94 1,630.73 0.00 0.00 0.00 0.00 6,193.11 90.06 49.40 3,110.60 4,038.80 1,653.80 3.00 2.89 0.79 15.27 6,721.54 90.06 49.40 3,110.02 4,382.68 2,055.02 0.00 0.00 0.00 0.00 6,762.00 88.85 49.29 3,110.40 4,409.04 2,085.72 3.00 -2.99 -0.27 -174.84 7,262.07 88.85 49.29 3,120.40 4,735.13 2,464.71 0.00 0.00 0.00 0.00 7,303.49 90.09 49.44 3,120.78 4,762.10 2,496.14 3.00 2.98 0.37 7.06 7,554.31 90.09 49.44 3,120.40 4,925.18 2,686.71 0.00 0.00 0.00 0.00 11/9/2005 3:28:07PM ORIGINAL COMPASS 2003.11 Build 50 ConocoPhi!lips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Wetl: PIan:2T-208 Wellbore: PIan:2T-208 Design: 2T-208wp05 Planned Survey 2T-208wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: MD Inclination Azimuth ND SSND +N/S (ft) (°) (°) (ft) (ft) (ft) 30.00 0.00 0.00 30.00 -80.40 0.00 SHL; 4637 FNL & 4724' FEL; Sec01•T11Nat0$E 100.00 0.00 0.00 100.00 -10.40 0.00 200.00 0.00 0.00 200.00 89.60 0.00 ~ 290.00 0.00 0.00 290.00 179.60 0.00 KOP @ 290ft MD, 290ft ND -Build @ 3°/t00ft ~ 300.00 0.30 310.00 300.00 189.60 0.02 400.00 3.30 310.00 399.94 289.54 2.04 500.00 6.30 310.00 499.58 389.18 7.41 600.00 9.30 310.00 598.64 488.24 16.14 623.33 10.00 310.00 621.64 511.24 18.65 Continue Dir ~ 4°HOOft, 623ft MD, 622ft ND 700.00 12.53 318.96 696.83 586.43 29.20 ~ 800.00 16.10 326.27 793.72 683.32 48.92 900.00 19.84 330.93 888.83 778.43 75.30 1,000.00 23.66 334.15 981.70 871.30 108.20 1,100.00 27.53 336.51 1,071.87 961.47 147.47 1,200.00 31.43 338.33 1,158.91 1,048.51 192.90 1,300.00 35.34 339.78 1,242.40 1,132.00 244.30 1, 316.68 36.00 340.00 1,255.95 1,145.55 253.43 1,400.00 36.38 345.60 1,323.21 1,212.81 300.39 1, 500.00 37.18 352.15 1,403.34 1,292.94 359.07 1,565.65 37.89 356.29 1,455.40 1,345.00 398.84 Permafrost 1,600.00 38.32 358.41 1,482.43 1,372.03 420.01 1,670.00 39.31 2.58 1,536.99 1,426.59 463.86 10 3/4" Csg Pt; 1670' MD, 1536' ND -10 314" Csg -13 112" Hole 1, 700.00 39.77 4.32 1, 560.12 1,449.72 482.93 1, 781.85 41.18 8.87 1,622.40 1;512.00 535.67 Top Ugnu C 1,800.00 41.51 9.85 1,636.03 1,525.63 547.50 1,900.00 43.49 14.98 1,709.77 1;599.37 613.42 1,900.32 43.50 15.00 1,710.00 1,599.60 613.63 2,000.00 47.44 15.85 1,779.89 1,669.49 682.11 2,100.00 51.40 16.59 1,844.93 1,734.53 755.02 2,200.00 55.36 17.26 1,904.56 1,794.16 831.79 2,300.00 59.33 17.87 1,958.51 1,848.11 912.04 2,400.00 63.30 18.43 2,006.49 1,896.09 995.38 2,452.33 65.38 18.71 2,029.15 1,918.75 1,040.09 Sail @ 65.38°Inc & 1$,71°Azi : 2452ft MD, 2029ft ND 2,500.00 65.38 18.71 2,049.01 1,938.61 1,081.14 2,600.00 65.38 18.71 2,090.67 1,980.27 1,167.24 2,700.00 65.38 18.71 2,132.33 2,021.93 1,253.34 2,800.00 65.38 18.71 2,173.99 2,063.59 1,339.45 2,896.99 65.38 18.71 2,214.40 2,104.00 1,422.96 Top West Sa k D +FJ-W (ft) 0.00 0.00 o.oo 0.00 -0.02 -2.43 -8.84 -19.23 -22.23 -32.79 -47.62 -63.57 -80.57 -98.54 -117.38 -137.01 -140.35 -154.87 -166.38 -170.39 -171.37 -170.98 -169.82 -163.70 -161.75 -147.18 -147.12 -128.21 -106.98 -83.60 -58.18 -30.85 -15.82 -1.92 27.24 56.41 85:57 113.86 HALLIBURTOIV Sperry Drilling S®rvices Well Plan: 2T-208 Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) Norde 3 @ 11 Q40ft (Nordic 3 (80 4+30)) True Minimum Curvature Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°/100ft) (ft) 5,970,622.69 - 498,944.87' 0.00 0.00 5,970,622.69 498,944.87 0.00 0.00 5,970,622.69 498,944.87 0.00 0.00 5,970,622.69 498,944.87 0.00 0.00 5,970,622.71 498,944.85 3.00 0.00 5,970,624.73 498,942.44 3.00 -0:51 5,970,630.10 498,936.04 3.00 -1.85 5,970,638.83 498,925.64 3.00 -4.04 5,970,641.34 498,922.65 3.00 -4.66 5,970,651.89 498,912.09 4.00 -5.78 5,970,671.62 498,897.27 4.00 -4.14 5,970,697.99 498,881.32 4.00 1.00 5,970,730.89 498,864.32 4.00 9.59 5,970,770.15 498,846.37 4.00 21.61 5,970,815.59 498,827.53 4.00 37.00 5,970,866.98 498,807.91 4.00 55.67 5,970,876.11 498,804.57 4.00 59.10 5,970,923,07 498,790.05 4.00 78.75 5,970,981.75 498,778.56 4.00 108.34 5,971,021.51 498,774.55 4.00 131.26 5,971,042.69 498,773.57 4.00 144.34 5,971,086.53 498,773.98 4.00 173.27 5,971,105.59 498,775.13 4.00 186.58 5,971,158.33 498,781.27 4.00 225.65 5,971,170.16 498, 783.22 3.99 234.85 5,971,236.07 498,797.80 4.00 288.92 5,971,236.28 498,797.85 4.00 289.10 5,971,304.75 498,816.77 4.00 348.13 5,971,377.65 498,838.01 4.00 411.80 5,971,454.41 498,861.39 4.00 479.62 5,971,534.64 498,886.82 4.00 551.26 5,971,617.97 498,914.17 4.00 626.38 5,971,662.68 498,929.20 4.00 666.94 5,971,703.72 498,943.10 0.00 704.27 5,971,789.81 498,972.28 0.00 782.57 5,971,875.90 499,001.45 0.00 860.86 5,971,961.99 499,030.62 0.00 939.16 5,972,045.49 499,058.92 0.00 1,015.10 11/9/2005 3:28:07PM ORIGINAL COMPASS 2003.11 Build 50 Conoco hillips Alaska Database: EDM 2003.11 Single UserDb Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit e Site: Kuparuk 2T Pad Well: PIan:2T-208 Wellbore: PIan:2T-208 Design: 2T-208wp05 Planned Survey 2T-208wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBtJRTGN Sperry Drilling Services Well Plan: 2T-208 Nordic 3 @ 110 40ft (Nordic 3 (80.4+30)) Nordic 3 @ 110 40ft (Nordic 3 (80.4+30)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N1S +E!-W Northing Fasting DLSEV Vert Section Ift) (°) (°) (ftl (ft) (ftj (ft) (ft) (ft) (°t100ft) (ft) 2,900.00 65.38 18.71 2,215.65 2,105.25 1,425.55 114.74 5,972,048.08 499,059.80 0.00 1,017.46 3,000.00 65.38 18.71 2,257.32 2,146.92 1,511.65 143.90 5,972,134.17 499,088.97 0.00 1,095.76 3,100.00 65.38 18.71 2,298.98 2,188.58 1,597.76 173.06 5,972,220.26 499,118.14 0.00 1,174.06 3,200.00 65.38 18.71 2,340.64 2,230.24 1,683.86 202.23 5,972,306.36 499,147.32 0.00 1,252.36 3,300.00 65.38 18.71 2,382.30 2,271.90 1,769.97 231.39 5,972,392.45 499,176.49 0.00 1,330.66 3,400.00 65.38 18.71 2,423.96 2,313.56 1,856.07 260:56 5,972,478.54 499,205.66 0.00 1,408.96 3,500.00 65.38 18.71 2,465.62 2,355.22 1,942.17 289.72 5,972,564.63 499,234.84 0.00 1,487.25 3,600.00 65.38 18.71 2,507.28 2,396.88 2,028.28 318.88 5,972,650.72 499,264.01 0.00 1,565.55 3,700.00 65.38 18.71 2,548.94 2,438.54 2,114.38 348.05 5,972,736.81 499,293.18 0.00 1,643.85 3,800.00 65.38 18.71 2,590.60 2,480.20 2,200.48 377.21 5,972,822.90 499,322.35 0.00 1,722.15 3,900.00 65.38 18.71 2,632.26 2;521.86 2,286.59 406.38 5,972,908.99 499,351.53 0.00 1,800.45 4,000.00 65.38 18.71 2,673.92 2,563.52 2,372.69 435:54 5,972,995.08 499,380.70 0.00 1,878.75 4,100.00 65.38 18.71 2,715.58 2,605.18 2,458.80 464.71 5,973,081.17 499,409.87 0.00 1,957.05 4,113.97 65.38 18.71 2,721.40 2,611.00 2,470.83 468.78 5,973,093.20 499,413.95 0.00 1,967.99 Base West Sak 4,200.00 65.38 18.71 2,757.24 2,646.84 2,544.90 493.87 5,973,167.27 499,439.05 0.00 2,035.35 4,300.00 65.38 18.71 2,798.90 2,688.50 2,631.00 523.03 5,973,253.36 499,468.22 0.00 2,113.65 4,400.00 65.38 18.71 2,840.56 2,730.16 2,717.11 552.20 5,973,339.45 499,497.39 0.00 2,191.94 4,500.00 65.38 18.71 2,882.22 2,771.82 2,803.21 581.36 5,973,425.54 499,526.57 0.00 2,270.24 4,515.71 65.38 18.71 2,888.77 2,778.37 2,816.74 585.94 5,973,439.06 499,531.15 0.00 2,282.54 Continue Dir @ 4°/100ft, 4516ft MD, 28 89k TVD 4,600.00 67.31 21.73 2,922.59 2,812.19 2,889.17 612.64 5,973,511.48 499,557.85 4.00 2,350.05 4,700.00 69.67 25.20 2,959.26 2,848.86 2,974.48 649.69 5,973,596.78 499,594.92 4.00 2,433.81 4,800.00 72.10 28.56 2,992.01 2,881.61 3,058.73 692.42 5,973,681.02 499,637.65 4.00 2,521.17 4,900.00 74.59 31.83 3,020.67 2,910.27 3,141.50 740.62 5,973,763.77 499,685.85 4.00 2,611.71 5,000.00 77.12 35.03 3,045.12 2,934.72 3,222.40 794.04 5,973,844.65 X499,739.28 4.00 2,704.99 5,100.00 79.69 38.16 3,065.22 2,954.82 3,301.02 852.44 5,973,923.26 499,797.68 4.00 2,800:55 5,200.00 82.29 41.24 3,080.89 2,970.49 3,376.99 915:52 5,973,999.22 499,860.77 4.00 2,897.93 5,244.37 83.45 42.59 3,086.40 2,976.00 3,409.75 944.92 5,974,031.97 499,890.18 4.00 2,941.59 Tabasco 5,295.00 84.78 44.13 3,091:59 2,981.19 3,446.37 979.50 5,974,068.58 499,924.76 4.00 2,991.69 7 5/8" Csg Pt; 5295' MD, 3091' TVD; 11 91' FNL & 3742' FEL; Sec01-T11N-R08E - 7 518" Csg - 9 112" Hole 5,300.00 84.91 44.28 3,092.04 2,981.64 3,449.94 982.97 5,974,072.14 499,928.23 3.98 2,996.65 5,400.00 87.54 47.29 3,098.63 2,988.23 3,519.50 1,054.48 5,974,141.69 499,999.74 4.00 3,096.23 5,462.05 89.18 49.16 3,100.40 2,990.00 3;560.82 1,100.74 5,974,183.00 €100,046.00 4.00 3,158.24 Target (Heel); 5462.05' MD, 3100.40' TVD - 2T-208wp05 Heel 5,500.00 89.18 49.16 3,100.94 2,990.54 3,585.63 1,129.44 5,974,207.81 ',100,074.70 0.00 3,196.18 5,600.00 89.18 49.16 3,102.37 2,991.97 3,651.02 1,205.09 5,974,273.18 ',100,150.35 0.00 3,296.17 5,700.00 89.18 49.16 3,103.80 2,993.40 3,716.41 1,280.74 5,974,338.55 ',100,226.00 0.00 3,396.16 5,800.00 89.18 49.16 3,105.22 2,994.82 3,781.80 1,356.38 5,974,403.92 500,301.65 0.00 3,496.15 5,900.00 89.18 49.16 3,106.65 2,99625 3,847.19 1,432.03 5,974,469.29 500,377.30 0.00 3,596.14 6,000.00 89.18 49.16 3,108.08 2,997.68 3,912.57 1,507.67 5,974,534.66 500,452.94 0.00 3,696.13 6,100.00 89.18 49.16 3,109.51 2,999.11 3,977.96 1,583.32 5,974,600.03 500,528.59 0.00 3,796.12 6,162.67 89.18 49.16 3,110.40 3,000.00 4,018.94 1,630.73 5,974,641.00 500,576.00 0.00 3,858.79 Target (71); 6162.67' MD, 3110.40' ND - 2T-208wp05 Tt 6,193.11 90.06 49.40 3,110.60 3,000.20 4,038.80 1,653.80 5,974,660.85 Ei00,599.07 3.00 3,889.23 6,200.00 90.06 49.40 3,110.59 3,000.19 4,043.28 1,659.03 5,974,665.33 ',100,604.30 0.00 3,896.11 _JI 11/9/2005 3:28:07PM Page 4 of 6 COMPASS 2003.11 Build 50 ~'R16INAL • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: KuparukRiverUnit Site: Kuparuk 2T Pad Well: Plan; 2T-208 Wellbore: PIan:2T-2p8 Design: 2T-208wp05 Planned Survey 2T-208wp05 Sperry Drilling Services HAt,LIBURTON Planning Report -Geographic Sperry Drilling ServFces Local Coordinate Reference: Well Plan: 2T-208 TVD Reference: Nordic 3 @ 110AOft (Nordic 3 (8Q4+30)) MD Reference: Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E!-W Northing Easting (ft) (`) (°) (ft) (ft) (ft) (ft) (ft) (ft) 6,300.00 90.06 49.40 3,110.48 3,000.08 4,108.36 1,734.96 5,974,730.39 500,680.23 6,400.00 90.06 49.40 3,110.37 2,999.97 4,173.44 1,810.88 5,974,795.45 500,756.16 6,500.00 90.06 49.40 3,110.26 2,999.86 4,238.51 1,886.81 5,974,860.51 500,832.09 6,600.00 90.06 49.40 3,110.15 2,999.75 4,303.59 1,962.74 5,974,925.57 500,908.02 6,700.00 90.06 49.40 3,110.04 2,999.64 4,368.67 2,038.67 5,974,990.63 500,983.95 6,721.54 90.06 49.40 3,110.02 2,999.62 4,382.68 2,055.02 5,975,004.65 501,000.30 6,762.00 88.85 49.29 3,110.40 3,000.00 4,409.04 2,085.72 5,975,031.00 501,031.00 Target (T2); 6762.00' MD, 3110.40' TVD - 2T-208wp05 T2 6,800.00 88.85 49.29 3,111.16 3,000.76 4,433.82 2,114.51 5,975,055.77 501,059.80 6,900.00 88.85 49.29 3,113.16 3,002.76 4,499.03 2,190.30 5,975,120.96 501,135.59 7,000.00 88.85 49.29 3,115.16 3,004.76 4,564.24 2,266.09 5,975,186.15 501,211.38 7,100.00 88.85 49.29 3,117.16 3,006.76 4,629.45 2,341.88 5,975,251.34 501,287.17 7,200.00 88.85 49.29 3,119.16 3,008.76 4,694.65 2,417.67 5,975,316.53 501,362.96 7,262.07 88.85 49.29 3,120.40 3,010.00 4,735.13 2,464.71 5,975,357.00 501,410.00 Target (T3); 7262.0T MD, 3120.40' TVD - 2T-208wp05 T3 7,300.00 89.98 49.43 3,120.78 3,010.38 4,759.83 2,493.49 5,975,381.69 !i01,438.78 7,303.49 90.09 49.44 3,120.78 3,010.38 4,762.10 2,496.14 5,975,383.97 !i01,441.43 7,400.00 90.09 49.44 3,120.64 3,010.24 4,824.85 2,569.47 5,975,446.70 !i01,514.76 7,500.00 90.09 49.44 3,120.48 3,010.08 4,889.87 2,645.44 5,975,511.70 !i01,590.74 .~ 7,554.31 90.09 49.44 3,120.40 3,010.00 4,925.18 2,686.71 5,975,547.00 !i01,632.00 Target (Toe); 7554' MD, 3120' TVD, 4993' FNL & 2034' FEL; SeC38-T 12N-R08E - 4 1/2" Csg - 8 3/4 " Hole - 2T-208wp05 Toe Geologic Targets Plan: 2T-208 TVD (ft) 3,120.40 -Point 3,120.40 -Point 3,100.40 - Point 3,110:.40 -Point' 3,110,40 -Point'. Target Name -Shape 2T-208wp05 T3 2T-208wp05 Tce 2T-208wp05 Heel 2T-208wp05 T1 2T-208wp05 T2 +N/S +E/-W ft ft 4,735.13 2,464.71 4,925.18 2,686.71 3;560.82 1,100.74 4,018.94 1,630.73 4,409.04 2,085.72 DLSEV (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 3.00 o.oo 0.00 0.00 0.00 0.00 0.00 Vert Section (ft) 3,996.11 4,096.11 4,196.11 4,296.11 4,396.11 4,417.65 4,458.11 4,496.10 4,596.08 4,696.06 4, 796.04 4, 896.02 4, 958.08 3.00 4,996.01 3.00 4,999.50 0.00 5,096.01 0.00 5,196.01 0.00 5,250.31 Easting ift) 501,410.00 501,632.Q0 500,046.00 500,576.00 501,031.00 Northing (ft) 5,975,357.00 5,975,547.00 5, 974,183.00 5,974,641.00 5,975,031.00 11/9/2005 3:28:07PM Page 5 of 6 COMPASS 2003.11 Build 50 ORIGINAL • '/ Speryy Drilling Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User lJb Local Coordinate Re#erence: Company: ConocoPhillips Alaska (Kuparuk) TYD Reference: Project: Kupanik River Unit MD Reference: Site: Kuparuk 2T Pad North Reference: We1L• Plan: 2T-208 Survey Calculation Method: Wellbore: PIan:2T-208 : Design: 2T-208wp05 Prognosed Casi I ng Points • HALLIBURTON Sperry Drilling Services Well Plan: 2T-208 Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) Nordic 3 @ 11 Q40ft (Nordic 3 (80.4+30)) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (~) ("~ 1,670.00 1,536.99 703/d 13-112 5,295.00 3,091.59 7St8 9-1/2 7,554.30 3,120.40 4-112 63/4 Prognosed Formation Intersection Points Measured Vertical ' Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ftl Iftl 1,565.65 37.89 356.29 1,455.40 398.84 -170.39 1,781.85 41.18 8.87 1,622.40 535.67 -163.70 2,896.99 65.38 18.71 2,214.40 1,422.96 113.86 4,113.97 65.38 18.71 2,721.40 2,470.83 468.78 5,244.37 83.45 42.59 3,086.40 3,409.75 944.92 11/9/2005 3:28:07PM ORIGINAL Name Permafrost Top Ugnu C Top West Sak D Base West Sak Tabasco COMPASS 2003.11 Build 50 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-208 Plan: 2T-208 2T-208wp05 Anticollision Report 09 November, 2005 HAL~,.IE3URTQN Sperry Drilling services ORIGINAL ~IOIlUCO~'ll~~l}]5 ~~ HALLI B URTQN Sperry Drilling Services Interpolation Method. MD Interval: SOSlalions Calculation Method: Minimum Curvature De pll a;,:.-, 30.00 To 7554.87 Error Model ISCWSA M m Range: 1018.80/77885164 'cylinder NOnh Error SuAace: Elliptual Conic Reference Well: Plan. 2T-208wpo5 Warning Method'. Rules Based sexces PROCIUII Uate: 3U05.11 A91 UU: W:W 3'alidateA. 1'ea Version: Ueplh From Urpih to Sunet'7'lan Tod 10.W IOW.W 22-30RxoU5 CB-(:7'RPSS Well. Men.2T206 W ltwe. Men.Z1--248 r~arcr ~.rpu ~r ~u Fehr Celsr Te YO -mro arse-~~_ ~ ., . e Issues: • 0 __.. ~z '~~~ r Trn'ellht~ C'321nder Azimuth (TFO+A7.11 I°I 1s C'emre tp C'entre Sepantlon 140 h/inI Traa4line CJlind<r.lzimutA (CFO+.42p I°I rs Centre In Centre Sepm6en ~5 fUia~ SEC'IIO~ DE'CAILS See tm Ioe Ari P71 +~IS +EI-R' Dlee TFere t'Sa Tvget 1 70.00 0.00 0.00 70.W O.W O.W 0.00 O.W O.W 2 290.00 0.00 0.00 290.W O.W O.W 0.00 O.W O.W 3 63J.V IO.W i10.00 631.fi4 18.65 -32.2? 7.00 710.00 -1.66 1 1316.66 76.00 740.00 1255.95 25].13 -1101{ 1.00 39.16 59.10 5 I9W.J2 Ii 50 15.00 1]10.00 60.61 -117.12 1.00 85.68 289.10 6 3152.73 65.78 1R.71 2029.15 1010.09 -15.82 1.00 9.01 fiAb.91 ] 4515.71 65.78 18.]3 28RR.77 2816.74 585.91 0.00 0.00 23R351 8 5463.05 89.18 49.Ifi {100.40 1560.82 1100.]1 1.00 SS.fi6 3158.21 2T-SOBxp01 Heel 9 6162.67 89.IA 99.16 311U./U 4018.9{ 1670.]7 O.UU 0.00 7858.79 3T-308xp03 TI 10 fi193.11 90.06 99.00 t110.M10 90?8.80 IbC1.80 7.00 15.2] 3889.27 11 6731 ~I 90.06 49A0 1110.02 4?83.68 3055,02 O.OD O.W 41I].fi5 l2 fi763.W 88.85 19.29 1110AU 1109.01 3085.72 1.00 -171.81 /458.11 3T-208xp03 T2 33 7162.07 86.85 19.2Y 3120.10 17)5.17 2161.71 0.00 O.W 1958.08 2T-208xpOJ 77 11 ]lOlA9 90.09 49.49 3120.]8 1]63.10 3196.11 7.00 7.06 9999.50 IS 755111 90.09 19.N 313U.40 /93C1A 26A6.71 O.OD O.W 5250.31 2T30Rxp03 Toe 11!9!2005 1:35 PM ConoCOPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 2T Pad Site Error: O.OOft Reference Well: Plan: 2T-208 Well Error: O.OOft Reference Wellbore Plan: 2T-208 Reference Design: 2T-208wp05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: MALLIBIJRTON Sperry Drilling Servic®s NJell Plan: 2T-208 Nordic 3 @ 110.408 (Nordic 3 (80.4+30)) Nordic 3 @ 110.408 (Nordic 3 (80.4+30)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum reference 2T-208wp05 'fitter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria iterpolation Method: MD Interval 25.OOft Error Model: ISCWSA lepth Range: Unlimited Scan Method: Trav. Cylinder North tesults Limited by: Maximum center-center distance of 1,048.80tt Error Surface: Elliptical Conic Yarning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 11;912005 From To (ft) {ft} Survey (Wellbore) Tool Name Description i 30.00 1,000.00 2T-208wp05 (Plan: 2T-208) CB-GYRO-SS Camera based gyro single shot 1,000.00 7,554.31 2T-208wp05 (Plan: 2T-208) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation blaming Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) .Kuparuk 2T Pad 2T-02 - 2T-02 - 2T-02 681.26 725.00 242.80 13.91 229.05 Pass -Major Risk 2T-20 - 2T-20 - 2T-20 700.00 825.00 709.96 13.54 696.91 Pass -Major Risk 2T-202 - 2T-202 - 2T-202 1,076.45 1,175.00 189.67 27.80 164.13 Pass -Major Risk 2T-204 - 2T-204 - 2T-204 294.22 300.00 48.92 5.91 43.03 Pass -Major Risk 2T-207 - 2T-207 - 2T-207 324.20 325.00 9.19 6.03 3.17 Pass -Major Risk 2T-209 - 2T-209 - 2T-209 424.51 425.00 13.10 7.74 5.39 Pass -Major Risk 2T-210 - 2T-210 - 2T-210 568.24 575.00 16.50 10.07 6.48 Pass -Major Risk 2T-215 - 2T-215 - 2T-215 758.96 750.00 75.63 13.81 61.86 Pass -Major Risk 2T-217 - 2T-217 - 2T-217 195.59 200.00 113.04 3.77 109.27 Pass -Major Risk 2T-217 - 2T-217A - 2T-217A 195.64 200.00 113.05 3.77 109.27 Pass -Major Risk 2T-218 - 2T-218 - 2T-218 889.71 875.00 82.15 18.89 63.92 Pass -Major Risk 2T-22 - 2T-22 - 2T-22 311.75 325.00 225.64 5.57 220.07 Pass -Major Risk 2T-220 - 2T-220 - 2T-220 1,570.93 1,475.00 107.89 39.27 76.79 Pass -Major Risk 2T-220 - 2T-220P61 - 2T-220PB1 1,625.22 1,525.00 139.80 40.96 104.22 Pass -Major Risk 2T-23 - 2T-23 - 2T-23 330.51 325.00 211.10 5.90 205.20 Pass -Major Risk 2T-26 - 2T-26 - 2T-26 335.83 350.00 164.99 5.99 159.00 Pass -Major Risk 2T-27 - 2T-27 - 2T-27 359.84 375.00 150.20 6.41 143.80 Pass -Major Risk 2T-28 - 2T-28 - 2T-2S 4,037.73 4,250.00 203.25 164.58 95.66 Pass -Major Risk 2T-29 - 2T-29 - 2T-29 336.50 350.00 121.06 6.00 115.07 Pass -Major Risk 2T-30 - 2T-30 - 2T-30 529.25 550.00 103.67 9.72 94.07 Pass -Major Risk 2T-31 - 2T-31 - 2T-31 408.15 425.00 85.03 7.93 77.13 Pass -Major Risk 2T-32 - 2T-32 - 2T-32 337.18 350.00 76.06 6.01 70.05 Pass -Major Risk Plan: 2T-203 -Plan 2T-203 - 2T-203wp05 738.47 750.00 60.58 16.43 44.41 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/9!2005 1:15:11 PM Page 2 0! 2 COMPASS 2003.1 f Build 50 Sperry Drilling Services Anticollision Report '?RIGINAL Plan: 2T-208w OS Plan: 2T-208/Plan: 2T-20~ P ~ - 2'f-208wP(Li 2T-02, 2"I'-02, 2T-02 V2 2T-20, 2'f-20, 2'I--20 VO 7f-202.2'1'-202, zl'-?02 V2 2T-204, 2"f-204, zl'-204 VO - rr-2ozrr-2m,n'-m7vl z'r-zo9.zr-z(x~,zr-zovvl - zr-zlo,zr-zlo,zr-zlovo zr-zis.zr-zls.zr-zuvo z7'-zn,z'r-zn.zr-zl7vo - 2'I'-217, 2'I'-217A, zl'-217A VO 2'f-21it,'_'f-2171, 2'f-218 V7 2'f-22, 2'I'-22.2'f-22 VO zC-22(1.2"I'-220, zl'-22(1 VO 2T-220, 2'f-220PBI, zf-220PLil V2 - 2"I'-23, zl'-23, z1=23 VO 2T-2C. 2'f-2C, 2T-2ci VO 2'I'-27, 2'I'-27, 7f-27 VO zl'-21i, 2T-Z8, 71'-28 VO 21'-29, 2T-?9, zl'-29 VO - 2'f-30.21-30, Yf-30 VO 2'f-31, 2'I'-31.2'1'-31 VO 2'1'-32, 2'I'-32, zf-32 V(1 I'la¢ 2'1=203, Plan 2'f-203, 2"f-203wp0> VO ~eNieiao South(-)/North(+) (g50 ft/in) D Q Z r 0 W ir'1 m' ~ ~( N D Z Q Z i a v+'~• ~~ z ~~ ~~ DD ~ }X~<~T_ S}-$ipo ~~n~~ ~~°` ~~~~~~3 ~~ s ~~~ ~~~ ~~ 3 ~~ _ ~~ m 8 ~~~~ ~~03 ~SBo a~ ~~g ~~~~ a~~f'' y~. 3 iT m ~ ~ ~ .. N cD C = N ~ ~ m m ~ ~ ~ x x ~ ~ ~ ~ A c~D u~i o°o°waC N N N N N N N N Z -i-i~~1~~1~ ~~~~~~ ~~~~ ~~ s s ~~~ ~i ~~- s ;;;,,~,~ ~~~ooggg ~~~r~c~aaa ~~~~~~~~ V V V V V V V V Z 888$$$$$a~ ~~~~~ ~~o~~, ~ ~~asssss~ ~~ ~~ 8 ~S V z Oparelor'. ConocolM1llllOr Alotka (KUporvk) Nelft Kuparuk Rlver UnX wR,F xr~zoe.pos LQ NN/A weer.'. FO[:eNON ,c N+euN.er rl r: snoezz.e n GAtl COrtN<XOn: -0.01 ' loo NO: NN/A MopnMk rrlCNlgMpn; x<.0U AFF NO: NN/A plp: Be.)A All NO: NN/A DopYpp« IOp Sptem (LVD)Aelersn<e: Mean Seo tell Ckiglnal V5 Plane: 49.25 ' raNMweN nen: zr~xoe View VS Plane: 49.25 ' KKN N.gnc no ao n unu svltem: Section (VS)RMe~ence: ~----- I Plan View N ao 0 o ~ o ~ 0 0 0 -~---~--r---~-'- ~ 5980000 I I I I I I ---1-__-~ -_~I-_..-7-.__-~ --- 2T-28' --~-__-2*f 31 ~-_.- ~ -._-i _-~- s979000 I I I I I -- I I I I I I = I I I I I I I I I I I o --~----1----I---t-~--r - -------i ---t--1---t----r--t-- s97aooo I I I I I I I I I I I I I I I I I I I I I +- I I I I I I I I I I € --~----~----I----F---I--- - --- ----+--~---+---~---+- s9nooo ~ I I I I I I I I I I I Z{ I I I I I I I I I I I ~-__-~-.-~---+-._-~--~.-_ 5976000 ~----~--~--•-+-•--~- -- +- -' I I I I I I I I I I ! 1 I I I I I j I I I I I I I I I I f I I I I I I I I I I ~ ---------------------- -------------, I f ~ I I i---~---L--J----1----L- I I 1 I I I I I I I I 1 ----- -1----L--J---1---L-- I I I I I I I I I I I I _1- I s97sooo ~ Section View z~ zoa OS PI z1 z1 ai ~ - zls a za - . I I I I I I ~ I I I t I ~ _~_. - wP ,,., -- -- - - - -. 1 I ~Ra I ~--~---~---~---+---~- ~---~---+--~---+---~-- ~.- 5974000 ~_ ________________________~ _______--- t I I I I I I I I I I T-2hs I I I I I I I I I I I ___ _ _ -- ` ___ _ _ _ __..- _ __ _ _ _ ; I I I I I ---- ---- -- ---- ---- - I I I I_-- I I --- ---- -- ---- - -- -- s97soo0 POO 29 ' to 015' ubse TVDI ~ I , T r ~ I I I I I T , I r r ~ I I I I 1 I - ~ ~ ~ I I I ! I I I I I I I - - 5972000 -- i----i --~-- ----- --r-- ~----t--~--- i - --r -~-- } L_ ; Q N a Combo Preview Page 1 of 1 (TOOlboxl.xls) 11/9!2005 2:47 PM Easl I+I /west I-) U CIS -_ ~ m ~ 2 N ~ ~._ _. ... ____ 4000 N - • ~i 0 I Q~j ~~j$ f~~j ~Qj ~[Qj (np-, Ana} (np5 Q~j 7000 O ~ N t") R ~ ~D ^ W ~Q5 ~ M P ~ ~ ~ ~ P Ve~'iftal Seen along'r'Vlew VS~lane" I I I I I I I I I I I I I I I I I I I I I I I ' --~-__-~---1-_--t-.___ _-__ -f---~-__-t--~-_.-t-._-F--~-_ 5971000 I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I ..,„s ~ ....__..i...._.~..~..,,_....~....._...._~..e..._1 _.. _..u.... 5970000 •i •i ~ • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-208 Plan: 2T-208PB1 Plan: 2T-208PB1wp05 Proposal Report 09 November, 2005 Sped 1?riling Services ORIGINAL. `' Calculetlon MatMd: Mlnknum Curvaluro ~ ConocoPlhillips Erzor System: ISCWSA ~^MatNod. Tmv.L]dlnder"°"° Project: Error SUMete: Elllpdcel COnlc Warnllg Metliotl' Rules Basad Ku aruk River Unit p Y~.M~:i~ Oaodetlc DaNm'. NAD 1987 (NADGON CONUSI Magretk Modal: BCCMZ0o5 Site: Ku aruk 2T Pad p Plan: 2T-208 Well: PIan:2T-208PB1 HALLIBURTON °i" '' ~' " rls h~ I ;o_II ., I ~a.~: 9 ~ Sperry Drilling Services ~,. ~',,u,yASF V, s3~a>~~ .,~,gASPx. ~' Plan: 2T-208PB1wp05 _ ~I 700 G~~ ~~ o a~ 1400 ~" ~' Q. E Q _ ~ V 2100 d €> m L € N 3500 Base West Sak Tabasco SHL; 463T FNL &4724' FEL; Sec01-T11N-R08E KOP @ 290ft MD, 290ft TVD -Build @ 3°/100k Continue Dir @ 4°/100ft, 623ft MD, 622ft TVD 10 3/4" Csg -131/2" Hole 103/4" Csg Pt; 1670' MD, 1536' TVD Sail @ 65.38°Inc 818.71 °Azi : 2452ft MD, 2029ft TVD Sidetrack Point; 4° DLS, 45° TFO, 3490' MD, 2461' TVD; 2704' FNL 84436' FEL; Sec01-T11 N-R08E ~_ Start Sail; 85° INC, 4150' MD, 2630' TVD i -~_~ Continue Dir; 4° DLS,171° TFO, 5330' MD, 2733' TVD - I Target (Toi Tabasco); 6266' MDi 3100' TVD Target (Tce); 6870' MD, 3585' TVD, 309' FNL 82640' FEL; Sec01-T11N-R08E 0 700 1400 2100 2800 3500 Vertical Ser_tic~n at d925° (700 ft/in1 2T-208wp05 -~ 91/2" Open Hole 2T-208PB1wp05 4200 4900 5600 ~,' ~~`~„try~'~'~ ~ ' ' Cabihtlm Matlwtl'. MlnYnun Curvature ~~: Sta~MMfad. Trnv. ~'llntlv NMh " Pro ect: Ku aruk River Unit ~ p ~ ii.iF f.3 w~„~ ~„,o,E~e ; p Bite; Ku aruk 2T Pad ~~.ha cam MME ~ ~ Well: Plan: 2T-208 Wellbore: plan: 2T-208P61 HALLIBURTON ""~ ~~' „1 ~ Nortlti t P i ~Ji V4116J ~ Plan: 2T-208P61wp05 Sperry Drilling Services ~~ 91/2" Open Hole ~i2T- 8P02 61wp05 Target (foe); 6870' MD, 3585' TVD, 309' FNL 8:2640' FEL; Sec01-T11N-R08E ~g ..a.~ ~~,,-- O ~e ~ i ~ _~. Z 'f'~00 I~ SHL; 463T FNL 8 4724' FEL; Sec01-T11N-R08E -2550 -1700 -850 Target (Top Tabasco); 6266' MD, 3100' TVD Continue Dir; 4° DLS,171 ° TFO, 5330' MD, 2733' TVD Start Sail; 85° INC, 4150' MD, 2630' TVD Sidetrack Point; 4° DLS, 45° TFO, 3490' MD, 2461' TVD; 2704' FNL &4436' FEL; Sec01 T11 N-RO8E Sail @65.38°Inc $18.71°Azi : 2452ft MD, 2029ft TVD 103/4" Csg -131/2" Hole 103/4" Csg Pt; 1670' MD,1536' TVD Continue Dir @ 4°/100ft, 623ft MD, 622ft TVD ~~_kCBP' 290ft MD, 290ft TVD -Build @ 3°/100ft 1 850 1700 West(-1/East(+1 (850 ftlii 2550 3400 4250 5100 • ~ Sperry Drilling Services Conaco Phtllips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2T Pad North Reference: Well: Plan: 2T-208 Survey Calculation Method: Wellbore: PIan:2T-208PB1 Design: 2T-208 PB 1 wp05 HALLIBURTGN Sperry Drilling Services Well Plan: 2T-208 Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: 2T-208 Well Position +N/-S 0.00 ft Northing: 5,970,622.69 ft Latitude: 70° 19' 51.492" N +E/-W 0.00 ft Easting: 498,944.87 ft Longitude: 150° 00' 30.810" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 80.40 ft I Wellbore ~ Plan: 2T-208PB1 II Magnetics I Model Name Sample Date BGGM2005 __ 12/31!2005 DesiDesign 2T-208P81wp05 Audit Notes: _ __ I Declination Dip Angle Fiekt Strength 24.00 _ __ 80.76 57,545 _~ Version: Phase: PLAN Tie On Depth: 3,490.00 Vertical Section: Depth From (TVD) +N!-S +E/-W Direction (ft) (ft) (ft) (°) 30.00 0.00 0.00 49.25 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +E!-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°(100ft) (°t100ft) (°1100ft) (°) 3,490.00 65.38 18.71 2,461.45 1,933.56 286.80 0.00 0.00 0.00 0.00 4,150.34 85.00 37.12 2,630.79 2,490.01 586.92 4.00 2.97 2.79 45.00 5,330.90 85.00 37.12 2,733.68 3,427.81 1,296.63 0.00 2.97 2.79 0.00 6,266.59 48.04 43.73 3,100.40 4,073.98 1,837.74 4.00 -3.95 0.71 171.90 6,870.28 23.89 43.73 3,585.40 4,328.28 2,081.01 4.00 -4.00 0.00 180.00 11/9/2005 4:55:24PM Page 2 of 5 COMPASS 2003.11 Build 50 • Conoco hillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unif Srte: Kuparuk 2T Pad Well: Plan: 2T-208 Wellbore: PIan.2T-208P81 Design: 2 T-208 PB 1 wp05 Planned Survey 2T-208P81wp05 Map Map MD Inclination Azimuth TVD SSTVD +N/S +E!-W Northing Eastmg DLSEV Vert Section fftl (°) (°) (ft) lft) (ft) (ftj (ft) eft) (°ft0oftl (ftl 100.00 0.00 0.00 100.00 -10.40 0.00 0.00 5,970,622.69 498,944.87 0.00 0.00 200.00 0.00 0.00 200.00 89.60 0.00 0.00 5,970,622.69 498,944.87 0.00 0.00 300.00 0.30 310.00 300.00 189.60 0.02 -0.02 5,970,622.71 498,944.85 0.30 0.00 400.00 3.30 310.00 399.94 289.54 2.04 -2.43 5,970,624.73 498,942.44 3.00 -0.51 500.00 6.30 310.00 499.58 389.18 7.41 -8.84 5,970,630.10 498,936.04 3.00 -1.85 600.00 9.30 310.00 598.64 488.24 16.14 -19.23 5,970,638.83 498,925.64 3.00 -4.04 700.00 12.53 318.96 696.83 586.43 29.20 -32.79 5,970,651.89 498,912.09 3.64 -5.78 800.00 16.10 326.27 793.72 683.32 48.92 -47.62 5,970,671.62 498,897.27 4.00 -4.14 900.00 19.84 330.93 888.83 778.43 75.30 -63.57 5,970,697.99 498,881.32 4.00 1.00 1,000.00 23.66 334.15 981.70 871.30 108.20 -80.57 5,970,730.89 498,864.32 4.00 9.59 1,100.00 27.53 336.51 1,071.87 961.47 147.47 -98.54 5,970,770.15 498,846.37 4.00 21.61 1,200.00 31.43 338.33 1,158.91 1,048:51 192.90 -117.38 5,970,815.59 498,827.53 4.00 37.00 1,300.00 35.34 339.78 1,242.40 1,132.00 244.30 -137.01 5,970,866.98 498,807.91 4.00 55.67 1,400.00 36.38 345.60 1,323.21 1,212.81 300.39 -154.87 5,970,923.07 498,790.05 3.56 78.75 1,500.00 37.18 352.15 1,403.34 1,292.94 359.07 -166.38 5,970,981.75 498,778.56 4.00 108.34 1,565.65 37.89 356.29 1,455.40 1,345.00 398.84 -170.39 5,971,021.51 498,774.55 4.00 131.26 Permafrost 1,600.00 38.32 358.41 1,482.43 1,372.03 420.01 -171.37 5,971,042.69 498,773.57 4.00 144.34 1,670.00 39.31 2.58 1,536.99 1,426:59 463.86 -170.98 5,971,086.53 498,773.98 4.00 173.27 10 3!4" Csg -13 112" Hole 1,700.00 39.77 4.32 1,560.12 1,449.72 482.93 -169.82 5,971,105.59 498,775.13 4.00 186.58 1,781.85 41.18 8.87 1,622.40 1,512.00 535.67 -163.70 5,971,158.33 498,781.27 4.00 225.65 Top Ugnu C 1,800.00 41.51 9.85 1,636.03 1,525.63 547.50 -161.75 5,971,170.16 498,783.22 3.99 234.85 1,900.00 43.49 14.98 1,709.77 1,599.37 613.42 -147.18 5,971,236.07 498,797.80 4.00 288.92 2,000.00 47.44 15.85 1,779.89 1,669.49 682.11 -128.21 5,971,304.75 498,816.77 4.00 348.13 2,100.00 51.40 16.59 1,844.93 1,734.53 755.02 -106.98 5,971,377.65 498,838.01 4.00 411.80 2,200.00 55.36 17.26 1,904.56 1,794.16 831.79 -83.60 5,971,454.41 498,861.39 4.00 479.62 2,300.00 59.33 17.87 1,958.51 1,848.11 912.04 -58.18 5,971,534.64 498,886.82 4.00 551.26 2,400.00 63.30 18.43 2,006.49 1,896.09 995.38 -30.85 5,971,617.97 498,914.17 4.00 626.38 2,500.00 65.38 18.71 2,049.01 1,938.61 1,081.14 -1.92 5,971,703.72 498,943.10 2.09 704.27 2,600.00 65.38 18.71 2,090.67 1,980.27 1,167.24 27.24 5,971,789.81 498,972.28 0.00 782.57 2,700.00 65.38 18.71 2,132.33 2,021.93 1,253.34 56.41 5,971,875.90 499,001.45 0.00 860.86 2,800.00 65.38 18.71 2,173.99 2,063.59 1,339.45 85:57 5,971,961.99 499,030.62 0.00 939.16 2,896.99 65.38 18.71 2,214.40 2,104.00 1,422.96 113.86 5,972,045.49 499,058.92 0.00 1,015.10 Top West Sak D 2,900.00 65.38 18.71 2,215.65 2,105.25 1,425:55 114.74 5,972,048.08 499,059.80 0.00 1,017.46 3,000.00 65.38 18.71 2,257.32 2,146.92 1,511.65 143.90 5,972,134.17 499,088.97 0.00 1,095.76 3,100.00 65.38 18.71 2,298.98 2,188.58 1,597.76 173.06 5,972,220.26 499,118.14 0.00 1,174.06 3,200.00 65.38 18.71 2,340.64 2,230.24 1,683.86 202.23 5,972,306.36 499,147.32 0.00 1,252.36 3,300.00 65.38 18.71 2,382.30 2,271.90 1,769.97 231.39 5,972,392.45 499,176.49 0.00 1,330.66 3,400.00 65.38 18.71 2,423.96 2,313.56 1,856.07 260:56 5,972,478.54 499,205.66 0.00 1,408.96 3,490.00 65.38 18.71 2,461.45 2,351.05 1,933.56 286.80 5,972,556.02 499,231.92 0.00 1,479.43 Sidetrack Point; 4° DLS, 45° TFO, 3490' MD, 2461' TVD; 2704' FNL S 4436' FEL; Sec01-T11N-R08E 3,500.00 65.66 19.02 2,465.59 2,355.19 1,942.18 289.75 5,972,564.63 499,234.86 3.99 1,487.28 3,600.00 68.53 22.05 2,504.52 2,394.12 2,028.40 322.08 5,972,650.85 499,267.20 4.00 1,568.06 3,700.00 71.44 24.97 2,538.75 2,428.35 2,114:54 359.57 5,972,736.96 499,304.70 4.00 1,652.68 3,800.00 74.40 27.78 2,568.11 2,457.71 2,200.15 402.05 5,972,822.56 499,347.18 4.00 1,740.74 11/9/2005 4:55:24PM Page 3 of 5 COMPASS 2003.1?Build 50 Sperry Drilling Services Planning Report -Geographic HALLIBURT~N Sperry Drilling Services Local Co-ordinate Reference: WeII Plan: 2T-208 ND Reference: Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) MD Reference: Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) North Reference: True Survey Calculation Method: Minimum Curvature ORIGINAL `-' C P illi Sperry Drillin g Services HALLIBURTON onaco h s p Alaska Planning Report -Geographic Sperry Qriiiing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-208 Company: Conoco Phillips Alaska (Kuparuk) TVD Reference: Nordic 3 @ 110.4 0ft (Nordic 3 (80.4+30)) Project: Kuparuk RiverUnit MD Reference: Nordic 3 @ 110.4 0ft (Nordic 3 (80.4+30)) Site: Kupanik 2T Pad North Reference: True Well: Plan: 2T-20$ Survey Calculation Method: Minimum Curvatu re Wellbore: Plan: 2T-208P61 De~;yn; 2T-208P61wp05 Planned Survey 21-208P81wp05 Map Map MD In clination Azimuth ND SSND +N/S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) fft) (ft) (ft) (°It00ft) (ft) 3,900.00 77.40 30.52 2,592.47 2,482.07 2,284.83 449.29 5,972,907.23 499,394.44 4.00 1,831.81 4,000.00 80.42 33.19 2,611.71 2,501.31 2,368.16 501.08 5,972,990.54 499,446.23 4.00 1,925.44 4,100.00 83.46 35.81 2,625.73 2,515.33 2,449.74 557.15 5,973,072.10 499,502.31 4.00 2,021.17 4,150.34 85.00 37.12 2,630.79 2,520.39 2,490.01 586.92 5,973,112.37 499,532.08 4.00 2,070.01 Start Sail; 85° INC, 4150' MD, 2630' TVD 4,200.00 85.00 37.12 2,635.12 2;524.72 2,529.46 616.77 5,973,151.81 499,561.93 0.00 2,118.37 4,300.00 85.00 37.12 2,643.83 2;533.43 2,608.90 676.89 5,973,231.23 499,622.06 0.00 2,215.77 4,400.00 85.00 37.12 2,652:55 2,542.15 2,688.33 737.00 5,973,310.65 499,682.18 0.00 2,313.16 4,500.00 85.00 37.12 2,66126 2,550.86 2,767.77 797.12 5,973,390.07 499,742.30 0.00 2,410.56 4,600.00 85.00 37.12 2,669.98 2,559.58 2,847.21 857.24 5,973,469.49 499,802.42 0.00 2,507.95 4,700.00 85.00 37.12 2,678.69 2,568.29 2,926.64 917.35 5,973,548.91 499,862.54 0.00 2,605.35 4,800.00 85.00 37.12 2,687.41 2,577.01 3,006.08 977.47 5,973,628.33 499,922.66 0.00 2,702.74 4,900.00 85.00 37.12 2,696.12 2,585.72 3,085.51 1,037.58 5,973,7D7.75 499,982.78 0.00 2,800.14 5,000.00 85.00 37.12 2,704.84 2,594.44 3,164.95 1,097.70 5,973,787.17 500,042.91 0.00 2,897.53 5,075.27 85.00 37.12 2,711.40 2,601.00 3,224.74 1,142.95 5,973,846.95 500,088.16 0.00 2,970.84 Base West Sak 5,100.00 85.00 37.12 2,713.56 2,603.16 3,244.39 1,157.82 5,973,866.59 500,103.03 0.00 2,994.93 5,200.00 85.00 37.12 2,722.27 2,611.87 3,323.82 1,217.93 5,973,946.01 500,163.15 0.00 3,092.32 5,300.00 85.00 37.12 2,730.99 2,620.59 3,403.26 1,278.05 5,974,025.43 500,223.27 0.00 3,189.72 5,330.90 85.00 37.12 2,733.68 2,623.28 3,427.81 1,296.63 5,974,049.97 500,241.85 O.OD 3,219.81 Continue Dir; 4° DLS, 171° TFO, 5330' MD, 2733' ND 5,400.00 82.26 37.51 2,741.34 2,630.94 3,482.42 1,338.25 5,974,104.57 500,283.48 4.00 3,286.99 5,500.00 78.31 38.09 2,758.22 2,647.82 3,560.28 1,398.65 5,974,182.42 500,343.88 4.00 3,383.58 5,600.00 74.35 38.68 2,781.85 2,671.45 3,636.43 1,458.97 5,974,258.55 500,404.20 4.00 3,478.98 5,700.00 70.39 39.30 2,812.14 2,701.74 3,710.49 1,518.92 5,974,332.60 500,464.16 4.00 3,572.74 5,800.00 66.44 39.95 2,848.92 2,738.52 3,782.10 1,578.21 5,974,404.19 500,523.45 4.00 3,664.40 5,900.00 62.49 40.64 2,892.03 2,781.63 3,850.91 1,636.54 5,974,472.99 500,581.79 4.00 3,753.51 6,000.00 58.54 41.38 2,941.24 2,830.84 3,916.59 1,693.64 5,974,538.65 500,638.89 4.00 3,839.63 6,100.00 54.60 42.19 2,996.33 2,885.93 3,978.81 1,74923 5,974,600.85 500,694.48 4.00 3,922.36 6,200.00 50.66 43.08 3,D57.02 2,946.62 4,037.27 1,803.03 5,974,659.30 500,748.29 4.00 4,001.28 6,265.10 48.10 43.71 3,D99.40 2,989.00 4,073.17 1,836.97 5,974,695.20 500,782.23 4.00 4,050.43 Tabasco 6,266.59 48.04 43.73 3,100.40 2,990.00 4,073.98 1,837.74 5,974,696.00 500,783.D0 4.00 4,051.54 Target (Top Tabasco); 6288' MD, 3100' ND - 2T-208P81wp05 Top Tabasco 6,300.00 46.70 43.73 3,123.02 3,012.62 4,091.74 1,854.73 5,974,713.76 500,799.99 4.00 4,076.00 6,400.00 42.70 43.73 3,194.09 3,083.69 4,142.56 1,903.35 5,974,764.57 500,848.61 4.00 4,146.00 6,500.00 38.70 43.73 3,269.88 3,159.48 4,189.67 1,948.42 5,974,811.67 500,893.68 4.00 4,210.90 6,600.00 34.70 43.73 3,350.04 3,239.64 4,232.85 1,989.72 5,974,854.84 500,934.99 4.00 4,270.38 6,700.00 30.70 43.73 3,434.17 3,323.77 4,271.89 2,027.06 5,974,893.86 500,972.33 4.00 4,324.15 6,800.00 26.70 43.73 3,521.86 3,411.46 4,306.58 2,060.25 5,974,928.55 501,005.52 4.00 4,371.94 6,870.28 23.89 43.73 3,585.40 3,475.00 4,328.28 2,081.01 5,974,950.25 501,026.28 4.00 4,401.83 Target (Tce); 6870' MD, 3585' TVD, 309' FNL S 2840' FEL; Sec01-T1 1N-R08E -9 1!2" Open Hole -2T-208P61wp05 BaseTabasco i i/9/2005 4:55:24PM Page 4 of 5 COMPASS 2003.11 Build 50 ORIGINAL • / Sperry Drilling Services HALLIBURTON ConocoPhillips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single UserDb Local Co-ordinate Reference: Well Plan: 2T-208 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)) Project: Kuparuk River Unit MD Reference: Nordic 3 @ 110-40ft (Nordic 3 (80.4+30)) Site: Kupanik 2T Pad North Reference: True Well: Plan: 2T-208 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2T-208PB1 Design: 2T-208 PB 1 wp05 - _ --- Geologic Targets Plan: 2T-208PB1 TVD Target Name +N1S +E!-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,585.40 2T-208P61wp05 BaseTabasco 4,073.98 1,837.74 5,974,696.00 500,783.00 - Point 3,100.40 2T-208PB1wpO5Top Tabasco 4,073.98 1,837.74 5,974,696.00 500,783.00 - Point Prognosed Casing Points j Measured Vertical Casing bole Depth Depth Diameter Diameter (ft) lft) (~~) (") 1, 670.00 1, 536.99 10.3/4 13-1/2 6,870.27 3,585.39 9-1/2 9-112 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N(-E +FJ-W ~'~ (ft) f°) (°j (ftj (ft} (ftj Name 1,565.65 37.89 356.29 1,455.40 398.84 -170.39 Permafrost 1,781.85 41.18 8.87 1,622.40 535.67 -163.70 Top Ugnu C 2,896.99 65.38 18.71 2,214.40 1,422.96 113.86 Top West Sak D 5,075.27 85.00 37.12 2,711.40 3,224.74 1,142.95 Base West Sak 6,265.10 48.10 43.71 3,099.40 4,073.17 1,836.97 Tabasco 11/9/2005 4:55:24PM Page 5 of 5 COMPASS 2003.11 Build 50 ~~~~~~~ ~~ 5 ~ ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-208 Plan: 2T-208PB1 2T-208PB1wp05 Anticollision Report 09 November, 2005 HAR~.~~t ~ V ~TO~ Sperry [gifting Service ORIGINAL COIlGtO~li~~i}'~S Yak a HALLIBURTON Sperry drilling Services ..ai¢~<,a. >I,~~, ..?ooaW6, r.[rt~h n.~ r.~. u.Ai.~..r. I t Method: MD Interval: 505tations Calculal on Melh d. M Curvaturo - 7490 TO 6870.28 Error Mod 1. 16CWSA ximum Rarye. 1016.60 41 7 8 6 516 4 Cylintler NOnh Error Surlace: Elliptical Conic Re/arence Wdl: plan: 2T-206pB1wp05 Warning Method: Rubs Based SLUR\'El' PROGRAM Uate: 3UU5-11.0910U:W:00 Validated. l'es \'ersimr llepth From Drplh To 5nn'e1'IPlen god lU.UO IIIW.UO CB-Gl'RO-SS na. eao. taro .,_,. - enw- v ,,.. - ..r06 --. ~~,. .. ,- ,- rsa,cwe-~c~- . , -_ ~. ~i . ^_ .n=zf4m •a0a~T5 - ~ ,. ~ v. ~~- • O ~~~ ~rl! frwrellhtR Clllnder Ariumlh ITFO+p7.Il I°I is Centre to Centre tirpnretiun IOU R4nl Irndllnr CWinder Azimuth ITFO+ALIt I°~ vs Cealre to Ceetrr Srparation 120 Nla~ SECTIOk DETAILS I/D Inc Azi TD 1~IS +EI-W' DLee ipsce \'Sec Tar(d ?190.00 65.18 18.71 2161.15 1911.56 286.80 0.00 0.00 1179.11 1150 ~1 85.00 17.13 2Q10.79 2/90A1 586.92 1.00 15.00 2070.01 5330.90 85.00 17.12 371168 ?13 ].RI 1296.61 0.00 0.00 ?219.81 (i2fi(i.59 18.04 47.71 3100A0 /073.98 IBI].71 1.00 171.90 105151 IT-308PBIMp05 Top Tebesm 6870.38 21.89 47.]7 1585.10 6128.28 2081.01 1.00 180.00 4401.81 2T-208PB1wp05 BeseTnbasco 11 /9/2005 4:53 PM :] ConotaPh'rllips Alaska Company: ConocoPhillipsAlaska (Kuparuk)- Project: Kuparuk River Uhi6 Reference Ske: Kuparuk 2TPad Site Error: O.OOft Reference Well: Plan: 2T-208 - Well Error: O.OOft Reference Wellbore Plan. 2T-208PB1 Reference Design: 2T-208P81wp05 Sperry Drilling Services Anticollision Repoli Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLIBURTON Sperry Drilling Services Well Plan: 2T-208 Nordic 3 @ 110.40ft (Nordic 3 (80.4+30)j Nordic 3 @ 110 40ft (Nordic 3 (80.4+30)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum ieference 2T-208PB1wp05 =filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria nterpolation Method: MD Interval 25.OOft Error Model: ISCWSA )epth Range: 3,490.00 to 6,870.28ft Scan Method: Trav. Cylinder North tesults Limited by: Maximum center-center distance of 1,048.SOft Emor Surface: Elliptical Conic Naming Levels evaluated at: 0.00 Sigma Survey Tool Program __ __ __ Date 11!9/2005 __ From To (ft) (ft) Survey (Wellbore) Tool Name Description 30.00 1,000.00 2T-208wp05 (Plan: 2T-208) CB-GYRO-SS Camera based gyro single shot 1,000.00 3,490.00 2T-208wp05 (Plan: 2T-208) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,490.00 6,870.28 2T-208P61wp05 (PIan:2T-208P61) 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 - Welllwre -Design (ft) (ft) (ft) (ft) Kuparuk 2T Pad 2T-02 - 2T-02 - 2T-02 Out of range 2T-20 - 2T-20 - 2T-20 4,305.90 4,825.00 912.64 179.68 751.71 Pass -Major Risk 2T-209 - 2T-209 - 2T-209 3,493.64 3,875.00 787.03 132.09 667.75 Pass -Major Risk 2T-210 - 2T-210 - 2T-210 Out of range 2T-215 - 2T-215 - 2T-215 4,096.32 4,025.00 395.28 149.05 259.35 Pass -Major Risk 2T-217 - 2T-217 - 2T-217 3,490.00 3,300.00 431.39 135.84 361.79 Pass -Major Risk 2T-217 - 2T-217A - 2T-217A 3,490.00 3,300.00 431.40 135.84 361.80 Pass -Major Risk 2T-218 - 2T-218 - 2T-218 Out of range 2T-220 - 2T-220 - 2T-220 3,492.00 3,350.00 324.04 129.73 215.88 Pass -Major Risk 2T-220 - 2T-220P61 - 2T-220P61 3,841.92 3,675.00 264.48 143.35 141.71 Pass -Major Risk 2T-23 - 2T-23 - 2T-23 Out of range 2T-26 - 2T-26 - 2T-26 3,499.99 3,850.00 529.14 130.67 457.76 Pass -Major Risk 2T-27 - 2T-27 - 2T-27 3,490.00 4,075.00 1,009.06 137.18 888.24 Pass -Major Risk 2T-28 - 2T-28 - 2T-28 3,587.13 3,800.00 188.86 140.64 117.81 Pass -Major Risk 2T-29 - 2T-29 - 2T-29 Out of range 2T-30 - 2T-30 - 2T-30 3,496.15 3,775.00 551.10 141.88 417.93 Pass -Major Risk 2T-31 - 2T-31 - 2T-31 6,787.20 6,400.00 309.86 250.03 144.50 Pass -Major Risk 2T-32 - 2T-32 - 2T-32 Out of range Plan: 2T-203 -Plan 2T-203 - 2T-203wp05 Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 11/9/2005 4:47:17PM Page 2 of 2 COMPASS 2003.11 Build 50 2T-208 L~)Irillina Hazard (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13 1/2" Surface Hole / 10 3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate y Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 9 7/8" Intermediate/Pilot Hole ! 7 5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low ~ Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool decreased mud wei ht. Abnormal Pressure Low ~ BOP training and drills, material on location for increased mud wei ht. Lost circulation Moderate Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6 3/4" Production Hole / 4 i/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low ;; Stripping drills, shut-in drills, material on Pressure location for increased mud wei ht. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool, decreased mud wei ht Lost Circulation Moderate Reduced um rates mud rheolo LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 2T--208 Drilling Hazards Summary.doc 1: CemCADE Preliminary Job Design 10 3/4" Surface on purposes Rig: Nordic 3 Location: Tabasco Client: ConocoPhillips Alaska, Inc. Revision Date: 11/11/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 110' MD < Top of Tail at 1,370' MD < Base of Permafrost at 1,565' MD (1,455' ND) < 10 3/4", 45.5# casing in 13 1/2" OH TD at 1,670' MD (1,537' ND) * Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 40% excess below the permafrost. The top of the tail slurry is designed to be at 1,370' MD. Lead Slurry Minimum pump time: 180 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (110') x 1.00 (no excess) = 70.2 ft3 0.3637 ft3/ft x (1370' - 110') x 3.50 (250% excess) = 1603.9 ft3 70.2 ft3 + 1603.9 ft3 = 1674.1 ft3 1674.1 ft3 / 4.45 ft3/sk = 376.2 sks Round up to 380 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 130 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft3/ft x (1565' - 1370') x 3.50 (250% excess) = 248.2 ft3 0.3637 ft3/ft x (1670' - 1565') x 1.40 (40% excess) = 53.5 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 248.2 ft3 + 53.5 ft3 + 43.2 ft3 = 344,9 ft3 344.9 ft3/ 0.93 ft3/sk = 370.9 sks Round up to 380 sks BHST = 32°F, Estimated BHCT = 56°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (mint CW100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Pause 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 5.0 298.2 59.6 94.6 AS 1 5.0 61.4 12.3 106.9 Pause 0.0 0.0 5.0 111.9 Water 5.0 20.0 4.0 115.9 Pause 0.0 0.0 5.0 120.9 Mud 7.0 123.9 17.7 138.6 Mud 3.0 9.0 3.0 141.6 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint throughout tail slurry ~~~ ~ ~ M Rig: Nordic 3 Location: Tabasco Client: ConocoPhillips Alaska, Inc. Revision Date: 11/11/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com s Previous Csg. < 10 3/4", 45.5# casing at 1,670' MD < Top of Tail at 2,395' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 5,295' MD (3,092' TVD) CemCADE Preliminary Job Design 7-5/8" Intermediate Casing ~eliminary Job Design based on limited input data. For estimate purposes only 5chlu eager Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above West Sak - (2900' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2900' x 1.25 (25% excess) = 778.7 ft3. 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 778.7 ft3 + 20.6 ft3 = 799.3 ft3 799.3 ft3/ 2.25 ft3/sk = 355.2 sks Round up to 360 sks BHST = 73°F, Estimated BHCT = 65°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 20.0 4.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 MP II 5.0 50.0 10.0 31.0 DeepCRETE 6.0 142.3 23.7 54.7 Drop top plug 0.0 0.0 5.0 59.7 Water 5.0 20.0 4.0 63.7 Switch to rig 0.0 0.0 5.0 68.7 Mud 6.0 210.4 35.1 103.8 Mud 3.0 9.0 3.0 106.8 MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend Weatherford Tandem Rise centralizers placed at: 2415 -2815 @ 1 per joint 2815 - 5215 @ 3 per 2 joints 5215 - 5295 @ 2 per joint 2T-208 I~rizontal Proposed Completion Schematic ~- ConocoPhillips Descrietion Size Tots Btm TVD Wt Grade Connection Conductor 16 0 108 108 62.5# H-40 Welded Surface 10.75 0 1670 1537 45.5# L-80 BTCM Intermediate 7.625 0 5295 3092 29.7# L-80 BTCM Production 4.5 4995 7554 3120 12.6# CR13 VAM Tubing 4.5 0 +/-4900 12.6# L-80 IBTM (2) Camco 4 1/2" X 1" KBMG Side Pocket Mandrels set at: TVD Aoorox MD 2400 3400 2900 4600 (max depth <70 deg) 10 3/4" shoe @ 1670' MD / 1537' ND Baker 4'/z' CMD Sliding Sleeve with 3.81" Camco profile Centrilift ESP @ +/-4900' MD Baker SC-1 R Liner Top PKR @ +/-4995' MD 7-5/8" shoe @ 5295' MD / 3092' TVD TD @ 7554' MD / 3120' TVD " ORIGINAL °'°" • • a _ ------ SHARON K. ALLSUP-DRAKE 1 ~ 1$ CONOCOPHILLIPS ATO 1530 700 G ST. - ANCHORAGE AK 99501 DATE ~~ - /311 PAY TO THE ~~~ (~ ~ l p~ SIB-f'( f'CC./L'7 C C ORDER OF ( is ~ ~ /~.rY7 /i7/~`~ ~ _ DOLLARS t' I axe. CHASE Chase Manhattan Bank USA, N.A. V811d Up TO ,5000 DOIIarS r. 200 WNite Clay Center Or., Newark, OE 19it1 4 /////A MEMO --- ~'7-~ _~ ~ rl/f ~- x:03 ~ L00 ~44~:2 L847 L9079 276n' 4 LiiB I~ . a • • TRAiYSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGR.APHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAyIE !~-~~'~ ~ ~ ' ~C?? PTD# ~~ ry ~.~ ^ ~ CHECK WHAT , ADD-ONS ~ "CLUE" APPLIES ~ (OPTIONS) MULTI The permit is for a new wellbore segment of ~ LATERAL existing well , Permit No, API No. (If API number i Production should continue to be reported as 'last two (2) digits ' a function of .the original API number stated are between 60-69) i above. i ~ PILOT HOLE ~ In accordance with 20 AAC 25.005(fj, all (per ~ records, data and logs acquired for the pilot /' ~ hole must be clearly differentiated in both ;name (name on permit plus PH) ~ Zl~-~'~-~-t-(~ and API number (50 - iC%',' ~ ,~ from records, data and togs acquired j ~ for well (name on permit). f~` ~ ~ ~/ SPACIlVG !The permit is approved subject to full EXCEPTION ~ compliance with 20 AAC 25.055. Approval to j `perforate and produce/infect is contingent ~ .upon issuance of a conservation order approving a spacing exception. ~ i _ (Company Name) assumes ~ ~ the liability of any protest to the spacing ~ I exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' ~ sample intervals from below the permafrost or from where samples are first caught and l 10' sample intervals through target zones. S /~ .,~~; Rev: 04/01/05 C\jody\transmittal_checklist Wf LL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, TABASCO OIL -490160 Well Name: KUPARUK RIV U TABS 2T-208 Program DEV Well bore seg ^ PTD#:2051870 Company CONOCOPHILLIPS ALASKA. INC Initial Class(fype DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Permit_feeattached------------------------ -_-_--_..- _--_....-Yes-- _____.--_.__-._ 2 Lezsenumberappropriate________-._____________________ _________Yes__ _.-_Surfacean_diopprodintervalinADL25569,T1)inADL25548__--_-____---___-____-_____ 3 Unique well-name and number - - - - - - - - - - - - - Yes - - - - - - - - - - ~ - - - - - - - 4 Well locatedin_a_defined-pool.-____-_____________ ________ _________Yes__ .-_-_KUPARUKRIVER,_TABA$000IL-49016Qgoverned by-CO435A-__--_._----_-__---__--._--. ~ 5 Well located proper distance from drilling unitboundary.. - - - - . - - - Yes _ _ _ - - - _ _ - - 6 Well located proper distance from other wells. - - _ Yes - -Nominal spacing units within the-pool is_ 1.0_acres.. . 7 Sufficient acreageayailableindril_lingunit_______________________ _________Yes__ __-____-,.____-_._ 8 If_deviated, is_wellbore plat_included - - - - - -Yes - - - - 9 Operator only affected party____-------.------------- --- Yes-- ----------------.- _-. 10 Operator has appropriate_bondinforce------------------------ ---------Yes__ ___-..__.-_.,.__- 11 Permiteanbeissuedwjthoutconservationorder.__.,__,.-________ _________Yes_ _-_ __-_,____._-_____---______-_____--____----___-.-.._------_-.-._ -.__ Appr Date 12 Pe(mitcanbeissuedwithoutadministrative_approval_______________ _________Yes__ ___----_-____--____--._-__-_-______--__ --.-._-._-.----_-..-_-_-..__-.-_- SFD 11121/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthorizedby-InjectionOrder#(put1O#in-comments)-(For_NA___ ____________----____.--____-_____--_____--_____.--,-___._______-__.-_ i 15 All wells within 114_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA, . _ _ _ _ _ _ . - 16 Pre-produced injector; duration of pre production less_ than_ 3 months_ (For_service well only) - NA_ _ _ - . ---------------------------------------------------------------- 17 ACMP_Finding of Consistency-has been issued_for_this project_ _ _ _ - _ NA_ _ _ - _ - - - Engineering 18 Condu_ctorstring-p-rovided - - - - Yes i 19 Surface casing_protectsallknownllSDWS______________________ _________ NA__. .._-_Allaquifersexempted, 4DCFR,147.1D2_(b)-(3).-___--___,__-____---.-_ _--___,-____-- ~ 20 _C_MTvoladequ_ate_tocirculate_onconductor&surf_csg_______________ _____--_ Yes-_ -.____--___--_--___----_ _----______-_____._______-- __-.--___.-_-..._ 21 CMT_v_ol_adegu_aie_toiie-in long string tosurfcsg_.____________ _________ No__- _,_,_Allhyd[ocarbon_zoneswill_be_coyered_._-__-____---.___-__--_-_-_-____._-___--.____- 22 CMT-willcoverallknown_productiyehorizons-_-_____-..-________ _________ No_-- -.__Screenedcompletionplanned.__.-__,____________,-__-_____- 23 Casing designs adequate forC,T,B&_permafr_ost__-------------- ---- Yes-- ----------.--------------------------------------------------- ..- -- 24 Adequate tankage_or reserve pit . , - - - _ - - _ - - Yes _ . .. - .Rig is_e_quipped with steel_pits. _No reserve-pitplanned, All waste to_approved disposal wells._ 25 If_a_re-drill,has-a_10-403 for abandonment been approved_____-_----- --------- NA__- .,____.----___--____,___-____-_-___-,-,__.___-__---,____.--___---______ 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _Yes _ _ _ , _ _ _ Proximity analysis performed, Traveling cylinder path calculated, Gyros possible, _ _ _ . - _ _ _ . _ _ _ _ _ _ - - - _ 27 Ifdiverterrequired,doesitmeetregulations--___________________ ___ ___ _Yes_ _.__-___,--____-__.._____-_-____--__ - - - Appr Date 28 Dril_linq fiuid.program schematic & equip listadequate- - _ , _ - - _ _ - _ Yes - .. - ..Maximum expected fo[mation pressure 6,3-EMW._ Planted mud weyhts up to_ 9.3 ppg, , _ _ - - _ - TEM 11122120D5 29 BOPEs,-dotheymeetregulation____________________ _______ __-__-_Yes_- ____-________--___--_____._-________,_____-____-__-___.______-_-_ ~!t~ _ 30 BOPE_press rating appropriate; test to-(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ Yes _ _ _ _ _ , _ MA$P calculated at 789_psi. 3000 psi BOP test-proposed, _ _ _ . - _ _ - - _ _ - - _ - _ _ - , _ - _ _ _ _ _ - , _ _ . - - ` 31 Choke.manifoVd complieswlAPl_RP-53 (May 84) - - - Yes - - - - 32 Work willoccurwithoutoperationshutdown__________ __________ ___--_-_.Yes_- _____---_ _--._____---______-______--_____--______-____-_______ __-___ 33 I& presenceof H2S gas_probable.. - _ _ - Yes - - - H2S is present on 2T pad, Mud should_preclude H2$ on rig. Rig is equipped with sensors and alarms. 134 Mechanical condition of wells within AOR verified CFO[service well only) . NA_ _ - - - -- - - - Geology 35 Permit_can be issued w/o hydrogen_sulfidemeosures - - - - - -- - - - - - -- - - - - - ---- No_ - - - _ Nearby wells 2T-215, 2T-217 & 2T-220_ measured from 50-220_ppm_ in 2004,1ikely in power fluid, but caution- _ - - 36 Data-presented on_ potential overgres_sure zones _ _ , Yes - . is best .. H2S measures-will be_required. _Expected,reservo[rpressvre is 4.9-6,3_ppg EMW; will-be drilled. _ - Appr Date 37 Seismic analysis of shallow gas_zones- . _ _ _ NA_ _ _ - _ - _ _ with.9.t-9.3 ppq mud. _Hydrates may be encountered as-noted in program and- in Drilling_Hazards Summary. SFD, SFD 11!2112005 38 Seabed condition survey_(if off_-shore) - - - - NA - - - - 39 _Contactname/phone-for weeklyprogress_reports [exploratory only]________ __ ______NA_-- ____,_____ --_-_-_--___.--___--.._-.--.-_--.--_-_--.___.--.--...-_ Geologic Engineering P Commissioner: Date: Commissioner: Date issi er Date 1l-Zz~~ ~/ Z Z ~a~ • • • Well History File APPENDIX ~~A:IVNE® JUL 2 ~ 200$ • Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • 2t-208pb3.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jun 18 15:58:55 2008 Reel Header Service name .............LISTPE Date . ...................08/06/18 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/06/18 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing • Library. scientific Technical services Library. scientific Technical Services Physical EOF ~~~~~ JUL ~ ~ X008 comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: 2T-208PB3 API NUMBER: 501032051872 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 18-JUN-08 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW-000411143 MW-000411143 MW-000411143 LOGGING ENGINEER: E. QUAM J. BOBBITT J. BOBBITT OPERATOR WITNESS: P. WILSON P. WILSON P. WILSON MWD RUN 6 MWD RUN 7 JOB NUMBER: MW-000411143 MW-000411143 LOGGING ENGINEER: J. BOBBITT J. BOBBITT OPERATOR WITNESS: D. HIEM D. HIEM SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: 8E FNL: 4637 FSL: FEL: 4724 FWL: Page 1 2t-208pb3.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 110.79 GROUND LEVEL: 80.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 1689.0 2ND STRING 6.750 7.625 5425.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1-2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWO RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4),. COMPENSATED NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 4 & 5 ARE DIRECTIONAL WITH DGR, EWR-4, AND PWD. RUN 4 EXITS 2T-208 PB1 AT 3450'MD/2429'TVD. RUN 5 EXITS 2T-208 P62 AT 4812'MD/2972'TVD. 6. MWD RUNS 6-7 ARE DIRECTIONAL WITH DGR, EWR-4, CTN, ALD, AND PWD. 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06 FROM P. PERFETTA (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-7 REPRESENT WELL 2T-208 WITH API#: 50-103-20518-72. THIS WELL REACHED A TOTAL DEPTH (TD) of 7594'MD/3151'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. Page 2 ~ • 2t-208pb3.tapx SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTH ALD SLIDE = NON ROTATED INTERVALS REFERRING TO ALD SENSOR DEPTH ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 9-7/8" HOLE SECTION - FROM ACAL; 6-3/4" HOLE - FIXED HOLE SIZE MUD WEIGHT: 9.0 -9.2 PPG MUD SALINITY: 300 PPM CHLORIDES & 20000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLI6.000 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 FET 1647.0 7542.0 GR 1655.0 7535.0 RPX 1684.0 7542.0 RPS 1684.0 7542.0 RPM 1684.0 7542.0 RPD 1684.0 7542.0 PEF 1686.0 7523.5 NPHI 1689.0 7506.5 FCNT 1689.0 7429.5 NCNT 1689.0 7506.5 DRHO 1691.0 7523.5 RHOB 1691.0 7523.5 ROP 1700.5 7594.0 Page 3 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED 2t-208pb3.tapx DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 3 1647.0 3450.0 MwD 4 3450.0 4812.0 MwD 5 4812.0 5436.0 MwD 6 5436.0 7203.0 MwD 7 7203.0 7594.0 S REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 1647 7594 4620.5 11895 1647 7594 ROP MWD FT/H 0 273.38 103.834 11788 1700.5 7594 GR MWD API 18.57 150.97 76.5423 11761 1655 7535 RPX MWD OHMM 0.47 2000 32.6773 11650 1684 7542 RPS MWD OHMM 0.41 2000 249.316 11650 1684 7542 RPM MWD OHMM 2.69 2000 448.61 11650 1684 7542 RPD MWD OHMM 1.13 2000 484.593 11206 1684 7542 FET MWD HOUR 0.34 139.1 2.75952 11724 1647 7542 NPHI MWD Pu-s 8.46 91.22 34,0916 7697 1689 7506.5 FCNT MWD CNTS 185.9 1781.5 586.464 7543 1689 7429.5 NCNT MWD CNTS 14507.4 158187 69794.7 7697 1689 7506.5 RHOB MWD G/CM 1.174 3.356 2.10037 7727 1691 7523.5 Page 4 • 2t-208pb3.tapx DRHO MWD G/CM -2.31 0.676 0.0830267 PEF MWD BARN 0.36 12.76 1.92223 First Reading For Entire File..........1647 Last Reading For Entire File...........7594 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 1647.0 3449.5 GR 1655.0 3450.0 RPD 1684.0 3450.0 RPS 1684.0 3450.0 RPM 1684.0 3450.0 RPx 1684.0 3450.0 PEF 1686.0 3450.0 FONT 1689.0 3450.0 NCNT 1689.0 3450.0 NPHI 1689.0 3450.0 RHOB 1691.0 3450.0 DRHO 1691.0 3450.0 OP 1700.5 3450.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION; DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): • 7727 1691 7523.5 7747 1686 7523.5 header data for each bit run in separate files. 3 .5000 28-DEC-05 Incite 6.02 Memory 3450.0 1647.0 Page 5 • • 2t-208pb3.tapx BOTTOM LOG INTERVAL (FT): 3450.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.6 MAXIMUM ANGLE: 7$,$ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 1844674407370955 ALD AZIMUTHAL LITHO-DEN 10718055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 52.0 MUD PH: 8,9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): ,0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.618 90.0 MUD FILTRATE AT MT: 5.000 70.0 MUD CAKE AT MT: 3.500 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Page 6 . ~ • 2t-208pb3.tapx NPHI MWD030 Pu-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 1647 3450 2548.5 3607 1647 3450 ROP MWD030 FT/H 2.39 273.38 127.964 3500 1700.5 3450 GR MWD030 API 18.57 108.96 66.5016 3591 1655 3450 RPX MWD030 OHMM 2.59 2000 28.4261 3533 1684 3450 RPS MWD030 OHMM 2.96 2000 29.9554 3533 1684 3450 RPD MWD030 OHMM 5.55 2000 40.527 3533 1684 3450 RPM MWD030 OHMM 6.2 2000 31.0698 3533 1684 3450 FET MWD030 HOUR 0.34 93.25 3.58945 3606 1647 3449.5 NPHI MwD030 Pu-S 16.86 91.22 42.3144 3523 1689 3450 FCNT MWD030 CNTS 470.2 1781.5 743.092 3523 1689 3450 NCNT MwD030 CNTS 106212 158187 125616 3523 1689 3450 RHOB MWD030 G/CM 1.174 2.678 1.91536 3519 1691 3450 DRHO MWD030 G/CM -0.139 0.423 0.0627775 3519 1691 3450 PEF MWD030 BARN 0.36 9.57 1.97166 3529 1686 3450 First Reading For Entire File..........1647 Last Reading For Entire File...........3450 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 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.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 7 2t-208pb3.tapx FET 3450.0 4812.0 RPM 3450.5 4812.0 RPS 3450.5 4812.0 RPx 3450.5 4812.0 GR 3450.5 4811.5 ROP 3450.5 4812.0 RPD 3450.5 4812.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4812.0 TOP LOG INTERVAL (FT): 3450.0 BOTTOM LOG INTERVAL (FT): 4812.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.9 MAXIMUM ANGLE: 85.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 63.0 MUD PH: 10.3 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.690 72.0 MUD AT MAX CIRCULATING TER MPERATURE: 1.376 90.0 MUD FILTRATE AT MT: 1.650 70.0 MUD CAKE AT MT: 1.810 67.0 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 Page 8 n • 2t-208pb3.tapx Frame Spacing.. ..... ............60 .lIN Max frames per record .............undefined Absent value ... ...................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3450 4812 4131 2725 3450 4812 ROP MWD040 FT/H 0.04 243.5 100.538 2724 3450.5 4812 GR MWD040 API 58.79 145.66 95.8236 2723 3450.5 4811.5 RPX MWD040 OHMM 3.25 25.11 7.21101 2724 3450.5 4812 RPS MWD040 OHMM 3.4 27.59 7.75822 2724 3450.5 4812 RPM MWD040 OHMM 3.46 26.14 8.02709 2724 3450.5 4812 RPD MWD040 OHMM 3.66 24.3 8.28266 2724 3450.5 4812 FET MWD040 HOUR 0.39 139.1 1.13033 2725 3450 4812 First Reading For Entire File..........3450 Last Reading For Entire File...........4812 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File TyPe ................L0 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.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: header data for each bit run in separate files. 5 5000 Page 9 • • 2t-208pb3.tapx FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4812.0 5388.5 ROP 4812.5 5436.0 FET 4812.5 5381.5 RPD 4812.5 5381.5 RPM 4812.5 5381.5 RPS 4812.5 5381.5 RPX 4812.5 5381.5 LOG HEADER DATA DATE LOGGED: 03-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5436.0 TOP LOG INTERVAL (FT): 4812.0 BOTTOM LOG INTERVAL (FT): 5436.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.8 MAXIMUM ANGLE: 80.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 63.0 MUD PH: 10.3 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.690 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.376 90.0 MUD FILTRATE AT MT: 1.650 70.0 MUD CAKE AT MT: 1.810 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ........ ..0 Data specification Block Type... ..0 Page 10 • • 2t-208pb3.tapx Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4812 5436 5124 1249 4812 5436 ROP MWD050 FT/H 0.27 186.78 79.8917 1248 4812.5 5436 GR MWD050 API 54.32 150.97 111.523 1154 4812 5388.5 RPX MWD050 OHMM 2.4 11.49 4.93178 1139 4812.5 5381.5 RPS MWD050 OHMM 2.6 11.56 5.18033 1139 4812.5 5381.5 RPM MWD050 OHMM 2.82 12.25 5.44903 1139 4812.5 5381.5 RPD MWD050 OHMM 3.05 26.19 5.77505 1139 4812.5 5381.5 FET MWD050 HOUR 0.54 28.5 1.42421 1139 4812.5 5381.5 First Reading For Entire File..........4812 Last Reading For Entire File...........5436 File Trailer Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSL2B.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.004 comment Record FILE HEADER FILE NUMBER: RAW MWD Page 11 n ~~ r~ 2t-208pb3.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5389.0 7144.5 PEF 5415.0 7133.0 RPD 5415.5 7152.0 RPx 5415.5 7152.0 RPS 5415.5 7152.0 RPM 5415.5 7152.0 FET 5415.5 7152.0 RHOB 5420.0 7133.0 NPHI 5420.0 7116.5 NCNT 5420.0 7116.5 DRHO 5420.0 7133.0 FONT 5420.0 7116.5 ROP 5436.5 7203.5 LOG HEADER DATA DATE LOGGED: 09-]AN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7203.0 TOP LOG INTERVAL (FT): 5436.0 BOTTOM LOG INTERVAL (FT): 7203.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 73634 ALD AZIMUTHAL L ITHO-DEN 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5425.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 67.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): .190 70.0 MUD AT MAX CIRCULATING TER MPERATURE: .151 90.0 MUD FILTRATE AT MT: .160 70.0 MUD CAKE AT MT: .235 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 12 • 2t-208pb3.tapx 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 ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MwD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MwD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5389 7203.5 6296.25 3630 5389 7203.5 ROP MWD060 FT/H 0 235.77 98.0887 3535 5436.5 7203.5 GR MWD060 API 29.42 98.45 54.9086 3512 5389 7144.5 RPX MWD060 OHMM 0.47 2000 68.2298 3474 5415.5 7152 RPS MWD060 OHMM 0.41 2000 743.04 3474 5415.5 7152 RPM MWD060 OHMM 9.74 2000 1357.76 3474 5415.5 7152 RPD MWD060 OHMM 1.13 2000 1573.68 3474 5415.5 7152 FET MWD060 HOUR 0.37 102.51 2.61808 3474 5415.5 7152 NPHI MWD060 Pu-S 8.46 39.31 24.4168 3394 5420 7116.5 FCNT MWD060 CNTS 185.9 1758.2 464.956 3394 5420 7116.5 NCNT MWD060 CNTS 14507.4 39336.5 23683 3394 5420 7116.5 RHOB MWD060 G/CM 1.776 3.356 2.27664 3427 5420 7133 DRHO MWD060 G/CM -2.31 0.676 0.0927459 3427 5420 7133 PEF MWD060 BARN 1.06 12.76 1.87615 3437 5415 7133 First Reading For Entire File..........5389 Last Reading For Entire File...........7203 File Trailer Service name... .......STSLIB.005 Service Sub Level~Name... Page 13 2t-208pb3.tapx version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 7117.0 7506.5 FCNT 7117.0 7506.5 NCNT 7117.0 7506.5 PEF 7133.5 7523.5 RHOS 7133.5 7523.5 DRHO 7133.5 7523.5 GR 7145.0 7535.0 RPM 7152.5 7542.0 RPS 7152.5 7542.0 RPD 7152.5 7542.0 FET 7152.5 7542.0 RPx 7152.5 7542.0 ROP 7204.0 7594.0 LOG HEADER DATA DATE LOGGED: 11-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7594.0 TOP LOG INTERVAL (FT): 7203.0 BOTTOM LOG INTERVAL (FT): 7594.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 96.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 73634 Page 14 • • 2t-208pb3.tapx ALD AZIMUTHAL LITHO-DEN 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5425.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 50.0 MUD PH: $.7 MUD CHLORIDES (PPM): 20000 FLUID LO55 (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .210 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .169 95.0 MUD FILTRATE AT MT: .190 75.0 MUD CAKE AT MT: .240 75.0 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 ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 NPHI MWD070 PU-S 4 1 68 32 9 FCNT MWD070 CNTS 4 1 68 36 10 NCNT MWD070 CNTS 4 1 68 40 11 RHOB MWD070 G/CM 4 1 68 44 12 DRHO MWD070 G/CM 4 1 68 48 13 PEF MWD070 BARN 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading Page 15 Last Reading • • 2t-208pb3.tapx DEPT FT 7117 7594 7355.5 955 7117 7594 ROP MWD070 FT/H 0 192.25 71.4605 781 7204 7594 GR MWD070 API 53.67 141.29 101.079 781 7145 7535 RPX MWD070 OHMM 1.82 1608.24 23.0399 780 7152.5 7542 RPS MWD070 OHMM 2.4 2000 244.025 780 7152.5 7542 RPM MWD070 OHMM 2.69 2000 476.394 780 7152.5 7542 RPD MWD070 OHMM 3.04 2000 587.411 780 7152.5 7542 FET MWD070 HOUR 0.42 42.09 7.19429 780 7152.5 7542 NPHI MWD070 PU-S 17.9 57.6 39.05 780 7117 7506.5 FONT MWD070 CNTS 229.3 1235.8 373.441 743 7117 7506.5 NCNT MWD070 CNTS 14726.6 28868 18314 780 7117 7506.5 RHOB MWD070 G/CM 1.862 2.788 2.16046 781 7133.5 7523.5 DRHO MWD070 G/CM 0.018 0.621 0.131617 781 7133.5 7523.5 PEF MwD070 BARN 1.22 5.29 1.90164 781 7133.5 7523.5 First Reading For Entire File..........7117 Last Reading For Entire File...........7594 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/18 Maximum Physical Record..65535 File Ty e ................L0 Next Fie Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/18 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/06/18 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF writing Library. scientific Technical services writing Library. Page 16 scientific Technical services • 2t-208pb3.tapx End Of LIS File Page 17 2T-208pb2.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 24 14:51:29 2008 Reel Header Service name .............LISTPE Date . ...................08/06/24 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................08/06/24 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • scientific Technical services scientific Technical services Physical EOF ~~~~~ ~U~ ~ ~ ~~~8 Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: 2T-208PB2 API NUMBER: 501032051871 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 24-JUN-08 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: MW-000411143 MW-000411143 LOGGING ENGINEER: E. QUAM J. BOBBITT OPERATOR WITNESS: P. WILSON P. WILSON SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: 8E FNL: 4637 FSL: FEL: 4724 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 110.79 GROUND LEVEL: 80.40 WELL CASING RECORD Page 1 ~oSI'~s3 ~/~~ • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 9.875 2T-208pb2.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 1689.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1-2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 4 IS DIRECTIONAL WITH DGR, EWR-4, AND PWD. RUN 4 EXITS 2T-208 PB1 AT 3450'MD/2429'TVD. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06 FROM P. PERFETTA (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 2T-208PB2 WITH API#: 50-103-20518-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5642'MD/3118'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTH ALD SLIDE = NON ROTATED INTERVALS REFERRING TO ALD SENSOR DEPTH Page 2 • • 2T-208pb2.tapx ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 9-7/8" HOLE SECTION - FROM ACAL MUD WEIGHT: 9.0 -9.2 PPG MUD SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/24 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 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 FET 1647.0 5587.0 GR 1655.0 5595.0 RPD 1684.0 5587.0 RPS 1684.0 5587.0 RPM 1684.0 5587.0 RPx 1684.0 5587.0 PEF 1686.0 3450.0 NCNT 1689.0 3450.0 FCNT 1689.0 3450.0 NPHI 1689.0 3450.0 DRHO 1691.0 3450.0 RHOB 1691.0 3450.0 ROP 1700.5 5642.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 3 1647.0 3450.0 MWD 4 3450.5 5642.0 Page 3 • . 2T-208pb2.tapx REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 1647 5642 3644.5 7991 1647 5642 ROP MWD FT/H 0.04 273.38 110.953 7884 1700.5 5642 GR MWD API 18.57 145.72 84.9747 7881 1655 5595 RPX MWD OHMM 2.48 2000 16.3208 7807 1684 5587 RPS MWD OHMM 2.69 2000 17.389 7740 1684 5587 RPM MWD OHMM 2.86 2000 18.0508 7740 1684 5587 RPD MWD OHMM 3.05 2000 22.338 7807 1684 5587 FET MWD HOUR 0.34 139.1 2.2385 7881 1647 5587 NPHI MWD PU-S 16.86 91.22 42.3144 3523 1689 3450 FONT MWD CNTS 470.2 1781.5 743.092 3523 1689 3450 NCNT MWD CNTS 106212 158187 125616 3523 1689 3450 RHOB MWD G/CM 1.174 2.678 1.91536 3519 1691 3450 DRHO MWD G/CM -0.139 0.423 0.0627775 3519 1691 3450 PEF MWD BARN 0.36 9.57 1.97166 3529 1686 3450 First Reading For Entire File..........1647 Last Reading For Entire File...........5642 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/24 Maximum Physical Record..65535 File Type ................Lo Page 4 • • 2T-208pb2.tapx Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/24 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 1647.0 3450.0 GR 1655.0 3450.0 RPD 1684.0 3450.0 RPX 1684.0 3450.0 RPM 1684.0 3450.0 RPS 1684.0 3450.0 PEF 1686.0 3450.0 NCNT 1689.0 3450.0 FCNT 1689.0 3450.0 NPHI 1689.0 3450.0 DRHO 1691.0 3450.0 RHOB 1691.0 3450.0 ROP 1700.5 3450.0 LOG HEADER DATA DATE LOGGED: 28-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3450.0 TOP LOG INTERVAL (FT): 1647.0 BOTTOM LOG INTERVAL (FT): 3450.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.6 MAXIMUM ANGLE: 78.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 1844674407370955 ALD AZIMUTHAL LITHO-DEN 10718055 BOREHOLE AND CASING DATA Page 5 • 2T-208pb2.tapx OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 52.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.300 MUD AT MAX CIRCULATING TERMPERATURE: 2.618 MUD FILTRATE AT MT: 5.000 MUD CAKE AT MT: 3.500 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 Logc~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel 70.0 90.0 70.0 70.0 DEPT FT 4 1 68 0 1 ROP MwD030 FT/H 4 1 68 4 2 GR MwD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MwD030 HOUR 4 1 68 28 8 NPHI MwD030 Pu-s 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MwD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 1647 3450 2548.5 3607 1647 3450 ROP MWD030 FT/H 2.39 273.38 127.964 3500 1700.5 3450 GR MWD030 API 18.57 108.96 66.5016 3591 1655 3450 RPX MWD030 OHMM 2.59 2000 28.4261 3533 1684 3450 Page 6 • 2T-208pb2.tapx r~ RPS MWD030 OHMM 2.96 2000 29.9554 3533 1684 3450 RPM MWD030 OHMM 6.2 2000 31.0698 3533 1684 3450 RPD MWD030 OHMM 5.55 2000 40.527 3533 1684 3450 FET MWD030 HOUR 0.34 93.25 3.5887 3607 1647 3450 NPHI MWD030 PU-S 16.86 91.22 42.3144 3523 1689 3450 FCNT MWD030 CNTS 470.2 1781.5 743.092 3523 1689 3450 NCNT MWD030 CNTS 106212 158187 125616 3523 1689 3450 RHOB MWD030 G/cM 1.174 2.678 1.91536 3519 1691 3450 DRHO MWD030 G/CM -0.139 0.423 0.0627775 3519 1691 3450 PEF MWD030 BARN 0.36 9.57 1.97166 3529 1686 3450 First Reading For Entire File..........1647 Last Reading For Entire File...........3450 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/24 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.......08/06/24 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3450.5 5587.0 ROP 3450.5 5642.0 GR 3450.5 5595.0 RPx 3450.5 5587.0 FET 3450.5 5587.0 RPS 3450.5 5587.0 RPM 3450.5 5587.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 7 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 2T-208pb2.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units ............ ... ..... Datum Specification Block sub-type...0 • 5642.0 3450.0 5642.0 56.9 85.6 TOOL NUMBER 132477 96540 9.875 1689.0 Native/Spud Mud 9.00 63.0 10.3 600 .0 1.690 72.0 1.376 90.0 1.650 70.0 1.810 67.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Page 8 2T-208pb2.tapx • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3450.5 5642 4546.25 4384 3450.5 5642 ROP MWD040 FT/H 0.04 243.5 97.3718 4384 3450.5 5642 GR MWD040 API 58.79 145.72 100.438 4290 3450.5 5595 RPX MWD040 OHMM 2.48 25.11 6.3143 4274 3450.5 5587 RPS MWD040 OHMM 2.68 27.59 6.77309 4274 3450.5 5587 RPM MWD040 OHMM 2.86 26.14 7.05432 4274 3450.5 5587 RPD MWD040 OHMM 3.05 24.3 7.3025 4274 3450.5 5587 FET MWD040 HOUR 0.39 139.1 1.09901 4274 3450.5 5587 First Reading For Entire File..........3450.5 Last Reading For Entire File...........5642 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/24 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/24 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/06/24 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF Library. scientific Technical services Library. scientific Technical services End Of LIS Fi 1 e Page 9 • 2T-208pb2.tapx • Page 10 2T-208PBl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 27 11:10:03 2008 Reel Header Service name .............LISTPE Date . ...................08/06/27 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header service name .............LISTPE Date . ...................08/06/27 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA • scientific Technical Services Library. scientific Technical services ~~~tdN~~ JUL ~ ~ 2008 2T-208 PB1 501032051870 ConocoPhillips Alaska Inc. Sperry Sun 27-JUN-08 MWD RUN 3 JOB NUMBER: MW-000411143 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: P. WILSON SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: SE FNL: 4637 FSL: FEL: 4724 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 110.79 GROUND LEVEL: 80.40 WELL CASING RECORD Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 9.875 2T-208PBl.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 1689.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1-2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). WELL BORES FOR 2T-208 PB2, 2T- 208 PB3, AND 2T-208 EXIT THIS WELL BORE AT 3450'MD/ 2429'TVD. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06 FROM P. PERFETTA (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 2T-208PB1 WITH API#: 50-103-20518-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6732'MD/3542'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTH ALD SLIDE = NON ROTATED INTERVALS REFERRING TO ALD SENSOR DEPTH ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG Page 2 PROCESSING: 2T-208PBl.tapx • HOLE SIZE: 9-7/8~~ HOLE SECTION - FROM ACAL MUD WEIGHT: 9.0 -9.2 PPG MUD SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 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 1655.0 6686.5 PEF 1684.0 6650.0 FET 1684.0 6679.0 RPX 1684.0 6679.0 RPM 1684.0 6679.0 RPS 1684.0 6679.0 RPD 1684.0 6624.0 FONT 1689.0 6636.5 DRHO 1689.0 6650.0 RHOB 1689.0 6650.0 NPHI 1689.0 6636.5 NCNT 1689.0 6636.5 ROP 1700.5 6732.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 1655.0 6732.0 REMARKS: MERGED MAIN PASS. Page 3 • • 2T-208PBl.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 1655 6732 4193.5 10155 1655 6732 ROP MWD FT/H 0 273.38 118.896 10064 1700.5 6732 GR MwD API 18.57 136.17 83.6909 10064 1655 6686.5 RPX MWD OHMM 1.99 2000 16.6215 9991 1684 6679 RPS MWD OHMM 2.15 2000 17.9331 9991 1684 6679 RPM MWD OHMM 2.32 2000 18.6998 9991 1684 6679 RPD MWD OHMM 1.84 2000 23.7939 9881 1684 6624 FET MWD HOUR 0.3 93.24 1.3255 9991 1684 6679 NPHI MWD Pu-S 8.88 91.22 40.4547 9896 1689 6636.5 FCNT MWD CNTS 470.2 2605.5 771.832 9896 1689 6636.5 NCNT MWD CNTS 106212 175113 126036 9896 1689 6636.5 RHOB MWD G/CM 1.174 2.741 2.02952 9923 1689 6650 DRHO MWD G/CM -0.139 0.554 0.0630695 9923 1689 6650 PEF MWD BARN -0.13 9.57 1.97916 9933 1684 6650 First Reading For Entire File..........1655 Last Reading For Entire File...........6732 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/27 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLI6.002 Page 4 2T-208PBl.tapx Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/27 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1655.0 6686.5 RPD 1684.0 6624.0 PEF 1684.0 6650.0 FET 1684.0 6679.0 RPM 1684.0 6679.0 RPS 1684.0 6679.0 RPx 1684.0 6679.0 DRHO 1689.0 6650.0 RHOB 1689.0 6650.0 NCNT 1689.0 6636.5 FONT 1689.0 6636.5 NPHI 1689.0 6636.5 OP 1700.5 6732.0 $ LOG HEADER DATA DATE LOGGED: 28-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6732.0 TOP LOG INTERVAL (FT): 1655.0 BOTTOM LOG INTERVAL (FT): 6732.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.6 MAXIMUM ANGLE: 78.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 1844674407370955 ALD AZIMUTHAL LITHO-DEN 10718055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 Page 5 • 2T-208PBl.tapx BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): ~ 52.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LO55 (C3): .O RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F ) MUD AT MEASURED TEMPERATURE (MT): 3.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.618 90.0 MUD FILTRATE AT MT: 5.000 70.0 MUD CAKE AT MT: 3.500 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type .... ........ .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Point ......... .....undefine d Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefine d Absent value ................. .....-999.25 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 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MwD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1655 6732 4193.5 10155 1655 6732 ROP MWD030 FT/H 0 273.38 118.896 10064 1700.5 6732 GR MwD030 API 18.57 136.17 83.6909 10064 1655 6686.5 RPX MWD030 OHMM 1.99 2000 16.6215 9991 1684 6679 RPS MWD030 OHMM 2.15 2000 17.9331 9991 1684 6679 RPM MWD030 OHMM 2.32 2000 18.6998 9991 1684 6679 Page 6 • 2T-208PBl.tapx • RPD MWD030 OHMM 1.84 2000 23.7939 9881 1684 6624 FET MwD030 HOUR 0.3 93.24 1.3255 9991 1684 6679 NPHI MwD030 PU-s 8.88 91.22 40.4547 9896 1689 6636.5 FCNT MWD030 CNTS 470.2 2605.5 771.832 9896 1689 6636.5 NCNT MWD030 CNTS 106212 175113 126036 9896 1689 6636.5 RHOB MWD030 G/CM 1.174 2.741 2.02952 9923 1689 6650 DRHO MWD030 G/CM -0.139 0.554 0.0630695 9923 1689 6650 PEF MWD030 BARN -0.13 9.57 1.97916 9933 1684 6650 First Reading For Entire File..........1655 Last Reading For Entire File...........6732 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/27 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/27 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 . ...................08/06/27 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Physical EOF End Of LIS File Page 7 2T-208.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jun 11 12:08:43 2008 Reel Header Service name .............LISTPE Date . ...................08/06/11 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reei Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date .....................08/06/11 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record S~:ANNE~ JUL ~ ~ 2~~8 TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: Mw-000411143 Mw-000411143 LOGGING ENGINEER: E. QUAM J. BOBBITT OPERATOR WITNESS: P. WILSON P. WILSON MWD RUN 6 MWD RUN 8 JOB NUMBER: Mw-000411143 MW-000411143 LOGGING ENGINEER: J. BOBBITT E. QUAM OPERATOR WITNESS: D. HIEM D. HIEM SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: 8E FNL: 4637 FSL: FEL: 4724 FWL: Page 1 • scientific Technical services scientific Technical services 2T-208 501032051800 ConocoPhillips Alaska Inc. Sperry Sun 11-JUN-08 MWD RUN 5 Mw-000411143 J. BOBBITT P. WILSON • 2T-208.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 110.79 GROUND LEVEL: 80.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750. 1689.0 2ND STRING 9.875 10.750 1689.0 3RD STRING 6.750 7.625 5425.0 PRODUCTION STRING REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1-2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 4 & 5 ARE DIRECTIONAL WITH DGR, EWR-4, AND PWD. RUN 4 EXITS 2T-208 PB1 AT 3450'MD/2429'TVD. RUN 5 EXITS 2T-208 P62 AT 4812'MD/2972'TVD. 6. MWD RUNS 6-8 ARE DIRECTIONAL WITH DGR, EWR-4, CTN, ALD, AND PWD. MWD RUN 8 EXITS 2T-208 PB3 AT 6930'MD/3138'TVD. MWD RUN 7 DOES NOT APPEAR IN THIS WELL BORE. 7. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06 FROM P. PERFETTA (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-6 & 8 REPRESENT WELL 2T-208 WITH API#: 50-103-20518-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7654'MD/3144'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE Page 2 • • 2T-208.tapx MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT RATE BIN). SC02 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTH ALD SLIDE = NON ROTATED INTERVALS REFERRING TO ALD SENSOR DEPTH ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 9-7/8~~ HOLE SECTION - FROM ACAL; 6-3/4" HOLE - FIXED HOLE SIZE MUD WEIGHT: 9.0 -9.2 PPG MUD SALINITY: 300 PPM CHLORIDES & 20000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET GR RPD RPX RPM RPS PEF NCNT FCNT 1 clipped curves; all bit runs merged. .5000 START DEPTH 1647.0 1655.0 1684.0 1684.0 1684.0 1684.0 1686.0 1689.0 1689.0 STOP DEPTH 7602.0 7595.0 7602.0 7602.0 7602.0 7602.0 7583.5 7566.5 7566.5 Page 3 ~ • 2T-208.tapx NPHI 1689.0 7566.5 DRHO 1691.0 7583.5 RHOB 1691.0 7583.5 $oP 1700.5 7654.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 1647.0 3450.0 MwD 4 3450.0 4812.0 MwD 5 4812.0 5436.0 MwD 6 5436.0 6930.0 wD 8 6930.0 7654.0 $ REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD SROP 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 NPHI MWD PU-S 4 1 68 28 8 FCNT MWD CNTS 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 RHOB MWD G/CM 4 1 68 40 11 DRHO MWD G/CM 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 RPD MWD OHMM 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1647 7654 4650.5 12015 1647 7654 ROP MWD SROP 0.04 473.84 104.88 11908 1700.5 7654 GR MWD API 18.57 150.97 74.7488 11881 1655 7595 RPx MwD OHMM 0.47 2000 33.9049 11508 1684 7602 RPS MWD OHMM 0.41 2000 233.933 11508 1684 7602 RPM MWD OHMM 2.82 2000 384.52 11508 1684 7602 FET MWD HOUR 0.34 139.1 2.38028 11582 1647 7602 Page 4 • • 2T-208.tapx NPHI MWD Pu-s 8.46 91.22 32.9748 7780 1689 7566.5 FCNT MWD CNTS 185.9 1781.5 580.739 7780 1689 7566.5 NCNT MWD CNTS 14507.4 158187 69730.4 7780 1689 7566.5 RHOB MWD G/CM 1.174 3.356 2.11514 7847 1691 7583.5 DRHO MWD G/CM -2.31 0.676 0.0811584 7847 1691 7583.5 PEF MWD BARN 0.36 12.76 1.95254 7867 1686 7583.5 RPD MWD OHMM 1.13 2000 447.291 11508 1684 7602 First Reading For Entire File..........1647 Last Reading For Entire File...........7654 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 1647.0 3449.5 GR 1655.0 3450.0 RPX 1684.0 3450.0 RPS 1684.0 3450.0 RPM 1684.0 3450.0 RPD 1684.0 3450.0 PEF 1686.0 3450.0 NCNT 1689.0 3450.0 FCNT 1689.0 3450.0 NPHI 1689.0 3450.0 DRHO 1691.0 3450.0 RHOB 1691.0 3450.0 OP 1700.5 3450.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE Page 5 28-DEC-05 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: 2T-208.tapx Insite 6.02 Memory 3450.0 1647.0 3450.0 47.6 78.8 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 134758 CTN COMP THERMAL NEUTRON 1844674407370955 ALD AZIMUTHAL LITHO-DEN 10718055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITION S MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 52.0 MUD PH: $,9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2,618 90.0 MUD FILTRATE AT MT: 5.000 70.0 MUD CAKE AT MT: 3.500 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 SROP 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Page 6 • 2T-208.tapx RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 FET MWD030 HOUR 4 1 68 24 7 NPHI MwD030 Pu-s 4 1 68 28 8 FCNT MWD030 CNTS 4 1 68 32 9 NCNT MWD030 CNTS 4 1 68 36 10 RHOS MwD030 G/CM 4 1 68 40 11 DRHO MWD030 G/CM 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 RPD MWD030 OHMM 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 1647 3450 2548.5 3607 1647 3450 ROP MWD030 sROP 2.39 273.38 127.964 3500 1700.5 3450 GR MWD030 API 18.57 108.96 66.5016 3591 1655 3450 RPX MWD030 OHMM 2.59 2000 28.4261 3533 1684 3450 RPS MWD030 OHMM 2.96 2000 29.9554 3533 1684 3450 RPM MWD030 OHMM 6.2 2000 31.0698 3533 1684 3450 FET MWD030 HOUR 0.34 93.25 3.58945 3606 1647 3449.5 NPHI MWD030 PU-s 16.86 91.22 42.3144 3523 1689 3450 FONT MWD030 CNTS 470.2 1781.5 743.092 3523 1689 3450 NCNT MWD030 CNTS 106212 158187 125616 3523 1689 3450 RHOB MWD030 G/CM 1.174 2.678 1.91536 3519 1691 3450 DRHO MWD030 G/CM -0.139 0.423 0.0627775 3519 1691 3450 PEF MWD030 BARN 0.36 9.57 1.97166 3529 1686 3450 RPD MWD030 OHMM 5.55 2000 40.527 3533 1684 3450 First Reading For Entire File..........1647 Last Reading For Entire File...........3450 File Trailer service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........sTSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. Page 7 BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 3450.0 RPD 3450.5 ROP 3450.5 RPM 3450.5 RPX 3450.5 GR 3450.5 $PS 3450.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT); BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 2T-208.tapx • STOP DEPTH 4812.0 4812.0 4812.0 4812.0 4812.0 4811.5 4812.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record 02-7AN-06 Incite 6.02 Memory 4812.0 3450.0 4812.0 56.9 85.6 TOOL NUMBER 132477 96540 9.875 1689.0 Native/spud Mud 9.00 63.0 10.3 600 .0 1.690 72.0 1.376 90.0 1.650 70.0 1.810 67.0 Page 8 2T-208.tapx Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 SROP 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 i 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 FET MWD040 HOUR 4 1 68 24 7 RPD MwD040 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3450 4812 4131 2725 3450 4812 ROP MWD040 SROP 0.04 243.5 100.538 2724 3450.5 4812 GR MWD040 API 58.79 145.66 95.8236 2723 3450.5 4811.5 RPX MWD040 OHMM 3.25 25.11 7.21101 2724 3450.5 4812 RPS MWD040 OHMM 3.4 27.59 7.75822 2724 3450.5 4812 RPM MWD040 OHMM 3.46 26.14 8.02709 2724 3450.5 4812 FET MWD040 HOUR 0.39 139.1 1.13033 2725 3450 4812 RPD MWD040 OHMM 3.66 24.3 8.28266 2724 3450.5 4812 First Reading For Entire File..........3450 Last Reading For Entire File...........4812 File Trailer Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File TyL~e ................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.......08/06/11 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER Page 9 • • 2T-208.tapx 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 GR 4812.0 5388.5 RPS 4812.5 5381.5 FET 4812.5 5381.5 RPM 4812.5 5381.5 ROP 4812.5 5436.0 RPD 4812.5 5381.5 RPx 4812.5 5381.5 LOG HEADER DATA DATE LOGGED: 03-7AN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5436.0 TOP LOG INTERVAL (FT): 4812.0 BOTTOM LOG INTERVAL (FT): 5436.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 6$,$ MAXIMUM ANGLE: 80.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 1689.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 63.0 MUD PH: 10.3 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT): 1.690 72.0 MUD AT MAX CIRCULATING TER MPERATURE: 1.376 90.0 MUD FILTRATE AT MT: 1.650 70.0 MUD CAKE AT MT: 1.810 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 10 2T-208.tapx Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDOSO SROP 4 1 68 4 2 GR MwD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 FET MWD050 HOUR 4 1 68 24 7 RPD MWD050 OHMM 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4812 5436 5124 1249 4812 5436 ROP MWD050 SROP 0.27 186.78 79.8917 1248 4812.5 5436 GR MwD050 API 54.32 150.97 111.523 1154 4812 5388.5 RPX MWD050 OHMM 2.4 11.49 4.93178 1139 4812.5 5381.5 RPS MWD050 OHMM 2.6 11.56 5.18033 1139 4812.5 5381.5 RPM MwD050 OHMM 2.82 12.25 5.44903 1139 4812.5 5381.5 FET MwD050 HOUR 0.54 28.5 1.42421 1139 4812.5 5381.5 RPD MWD050 OHMM 3.05 26.19 5.77505 1139 4812.5 5381.5 First Reading For Entire File..........4812 Last Reading For Entire File...........5436 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.004 Page 11 • 2T-208.tapx Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for ea ch bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5389.0 6930.0 PEF 5415.0 6930.0 RPM 5415.5 6930.0 RPS 5415.5 6930.0 FET 5415.5 6930.0 RPX 5415.5 6930.0 RPD 5415.5 6930.0 NPHI 5420.0 6930.0 NCNT 5420.0 6930.0 FONT 5420.0 6930.0 RHOB 5420.0 6930.0 DRHO 5420.0 6930.0 ROP 5436.5 6930.0 LOG HEADER DATA DATE LOGGED: 09-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6930.0 TOP LOG INTERVAL (FT): 5436.0 BOTTOM LOG INTERVAL (FT): 6930.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 73634 ALD AZIMUTHAL LI THO-DEN 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5425.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 67.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .190 70.0 MUD AT MAX CIRCULATING TERM PERATURE: .151 90.0 MUD FILTRATE AT MT: .160 70.0 Page 12 I • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 2T-208.tapx Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 • 235 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 SROP 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MwD060 OHMM 4 1 68 20 6 FET MwD060 HOUR 4 1 68 24 7 NPHI MwD060 Pu-S 4 1 68 28 8 FCNT MWD060 CNTS 4 1 68 32 9 NCNT MWD060 CNTS 4 1 68 36 10 RHOB MWD060 G/CM 4 1 68 40 11 DRHO MWD060 G/CM 4 1 68 44 12 PEF MwD060 BARN 4 1 68 48 13 RPD MwD060 OHMM 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 5389 6930 6159.5 3083 5389 6930 ROP MWD060 SROP 0.66 235.77 104.313 2988 5436.5 6930 GR MwD060 API 29.42 98.45 52.9722 3083 5389 6930 RPX MWD060 OHMM 0.47 2000 70.1991 3030 5415.5 6930 RPS MWD060 OHMM 0.41 2000 796.712 3030 5415.5 6930 RPM MwD060 OHMM 9.74 2000 1374.11 3030 5415.5 6930 FET MWD060 HOUR 0.37 102.51 2.59334 3030 5415.5 6930 NPHI MWD060 PU-S 8.46 39.21 24.1284 3021 5420 6930 FCNT MWD060 CNTS 185.9 1758.2 471.321 3021 5420 6930 NCNT MWD060 CNTS 14507.4 39336.5 23815.9 3021 5420 6930 RHOB MWD060 G/CM 1.776 3.356 2.28545 3021 5420 6930 DRHO MWD060 G/CM -2.31 0.676 0.0959523 3021 5420 6930 PEF MWD060 BARN 1.06 12.76 1.9036 3031 5415 6930 RPD MWD060 OHMM 1.13 2000 1584.11 3030 5415.5 6930 First Reading For Entire File..........5389 Last Reading For Entire File...........6930 Page 13 • • 2T-208.tapx File Trailer Service name... .......STSLIB.005 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File TyE~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI RHOB DRHO GR NCNT FCNT PEF ROP RPD RPS RPX RPM FET 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: header data for each bit run in separate files. 8 .5000 START DEPTH 6930.5 6930.5 6930.5 6930.5 6930.5 6930.5 6930.5 6930.5 6971.5 6971.5 6971.5 6971.5 6971.5 STOP DEPTH 7566.5 7583.5 7583.5 7595.0 7566.5 7566.5 7583.5 7654.0 7602.0 7602.0 7602.0 7602.0 7602.0 12-7AN-06 Insite 6.02 Memory 7654.0 6930.0 7654.0 86.4 91.9 Page 14 • • 2T-208.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 73634 ALD AZIMUTHAL LITHO-DEN 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5425.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 51.0 MUD PH: 9,4 MUD CHLORIDES (PPM): 20000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .100 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .084 89.6 MUD FILTRATE AT MT: .120 74.0 MUD CAKE AT MT: .170 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 ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order DEPT ROP MWD080 GR MWD080 RPX MWD080 RPS MWD080 RPM MWD080 FET MWD080 NPHI MWD080 FCNT MWD080 NCNT MWD080 RHOB MWD080 DRHO MWD080 PEF MWD080 RPD MWD080 units FT SROP API OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN OHMM Size 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 Rep Code 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Page Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 15 • s 2T-208.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6930.5 7654 7292.25 1448 6930.5 7654 ROP MWD080 SROP 0.14 473.84 79.9625 1448 6930.5 7654 GR MWDO80 API 48.74 108.62 72.4395 1330 6930.5 7595 RPX MWD080 OHMM 9.07 1449.35 47.8606 1082 6971.5 7602 RPS MWD080 OHMM 22.66 1732.8 134.195 1082 6971.5 7602 RPM MWD080 OHMM 27.48 1240.14 114.287 10$2 6971.5 7602 FET MWD080 HOUR 0.39 4.9 1.90828 1082 6971.5 7602 NPHI MwD080 PU-S 12.28 37.43 27.976 1236 6930.5 7566.5 FCNT MWD080 CNTS 200.9 1235.8 385.416 1236 6930.5 7566.5 NCNT MWDO80 CNTS 15822.4 37017.9 22661.8 1236 6930.5 7566.5 RHOB MWD080 G/CM 1.392 2.683 2.25939 1307 6930.5 7583.5 DRHO MWD080 G/CM -0.151 0.583 0.0964529 1307 6930.5 7583.5 PEF MWD080 BARN 0.43 4.57 2.01441 1307 6930.5 7583.5 RPD MWD080 OHMM 42.44 1124.56 161.975 1082 6971.5 7602 First Reading For Entire File..........6930.5 Last Reading For Entire File...........7654 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/11 Maximum Physical Record..65535 File TyE~e ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/11 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/11 Ori9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services scientific Technical Services Page 16 Physical EOF End Of LIS File • 2T-208.tapx Page 17 •
