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208-112
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: Install Cap String 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,786'N/A Casing Collapse Structural Conductor Surface Intermediate 3,090psi Production 5,410psi 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 Pkrs (See Schematic); N/A See Schematic; N/A 6,750'7,400'6,365' Beluga River Sterling-Beluga Gas 20" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 211-26CO 802A Same 6,740'7" ~52psi 7,758' N/A Length August 25, 2025 4-1/2" 7,776' Perforation Depth MD (ft): 3,592' See Attached Schematic 5,750psi 85' 2,863' 85' Size 85' 9-5/8"3,574' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 4,483' 7,240psi Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0021127 208-112 50-283-20128-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 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: m n P s 66 t g 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 3:01 pm, Aug 15, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.15 14:36:13 - 08'00' Noel Nocas (4361) 325-483 10-404 DSR=8/19/25A.Dewhurst 18AUG25BJM 8/18/25JLC 8/19/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.20 09:42:36 -08'00'08/20/25 RBDMS JSB 082225 Well Prognosis Well Name: BRU 211-26 API Number: 50-283-20128-00-00 Current Status: Gas Producer Permit to Drill Number: 208-112 First Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (M) Maximum Expected BHP: ~212 psi @ 4581’ TVD (Based on 2025 Production Survey) Max. Potential Surface Pressure: ~52 psi (Based on 0.035 psi/ft gas gradient to surface) Applicable Frac Gradient: NA Cap string only, no new perforations Shallowest Allowable Perf TVD: NA – No perforations to be added Well Status: Gas producer making ~978 mcfd, ~50 bwpd @ 18psi. Brief Well Summary: Drilled and completed in 2008 and was fracked and a gravel pack installed. The well was completed a Beluga D through I sand completion. No workovers have been completed on the well. The well is starting to slug water. The purpose of this work/sundry is to set a 3/8” stainless steel capillary string to inject liquid soap downhole and keep the well from slugging every time a soap stick is dropped. Notes Regarding Wellbore Condition x 4.5” gravel pack completion x Inclination o Max deviation of 54° @ 2864’ MD x SL pulled SSSV on 1/21/25 (Regulations do not require well to have a SCSSSV) x SL tag @ 5657 w/ 2.65” GR (1/21/25) Procedure: 1. RU Cap String Truck 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components(injection valve greater than 1500 psi). Remove soap launcher. 3. Install pack-off and pressure test against swab valve to 1500 psi. 4. RIH with 3/8” capillary string to ±4500’ MD (30 deg deviation). 5. Install slips and connect tubing to chemical injection pump. 6. Set spool of remaining line near well 7. RD cap string unit, and turn well over to production. 8. Monitor results for a day, if soaping does not meet flow requirements, adjust depth of injection point and adjust rates of foamer injection to optimize rate. 9. Pump defoamer as needed into flowline downstream of wing valve. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ P.1 Created By: JJ 7/20/2016 SCHEMATIC Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 20” 9-5/8” RKB to MSL = 91.5’ RKB to GL = 16.5’ TD = 7,786' TVD = 6,750' PBTD = 7,786’ ED = 7,400’ ETVD = 6,273’ Max Angle = 56.33 deg Kickoff @ 2,390.3’ 2 3 4 5 3/8” control line 7/U1 U7/U8 U10-U20 U22 U24-U28 U2 U4/5 I2 L1 L2 L3/L4 G G H L5-L15 H H L16 H L17-L22 H L23 H H L24-L27 L28 I I L29-L36 I I L37 L38 TOC @ 3,610’ Beluga Sands D D D E E E F F F F 7” 6 U3 U6 U9 U21 U23 U30 U32-U34 I1 I3 I5 I5 I6 I7 I8 I9 I10 I11 I12 I13 I14 I15 I16 I17 U29 U31 U35 U36 I4 P2 P3 P1 1 CASING DETAIL Size Type WT Grade Conn ID MD Btm 20''Conductor 94#X-64 Welded 19.124''85' 9-5/8"Surface 40#L-80 BTC 8.835''3,592' 7''Production 26#L-80 BTCM 6.276''7,776' TUBING DETAIL 4-1/2"Prod. Tubing 12.6#L-80 IBTM 3.958''4,483' Gravel Pack Detail Size Type WT Grade Conn ID MD Top MD Btm 4''Upper Gravel Pack Screens 11#P-110 4" 11# SLHT 3.43''4,477.4'5,782.6' 2.89''Lower Grav. Pk Iso Strng 6.4#L-80 2-7/8” Hyd 511 2.37''5,771.8'7,265.4' 4.59''Lower Grav. Pk Scrns 11#P-110 11# SLHT 3.43''5,799.2'7,262.1' 5.54''Sump Packer 23#L-80 SLHT 4.93''7,254'7,276.2' Production Tubing ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description 1 19 1.18 3.958 10.75 Vetco Tubing Hanger 2 451 1.24 3.92 5.57 Camco chem inject. nipple 3/8" Ctrl Line 3 504 2.67 3.813 5.57 Camco BP-6i Hydraulic Landing Nipple w/ DB 4 4,212 6.89 3.938 5.98 Camco GLM 1" KGB-2, 4.5" IBT MOD. BXP (Dummy) w/ DMY Valve & BK Latch 9/25/2008 5 4382 1.17 3.813 5 'X' Nipple 6 4451 18.34 3.9 5.53 4.75" Polished Bore Receptacle 7 4477 3.22 3.25 3.98 Baker S-22 Anchor Seal Assembly w/ mule shoe Upper Gravel Pack Screens ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description U1 4477 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile U2 4482 10.04 4.7 5.55 Seal Bore Ext. U3 4492 2.81 3.25 4.52 Seal Bore 80-32 U4 4501 2.5 3.34 5.63 Knock Out Isolation Valve C-2 Isolation Sleeve U5 4503 1.74 3.34 5.63 Knock Out Isolation Valve C-2 U6 4511 10.54 3.43 4.54 Vent Screen Bakerweld 12 Ga. U7 4522 2.18 3.25 4.53 Seal Bore MZ System 80-32 U8 4524 3.49 3.61 6 SC-1L Packer 70B6-40 U9 4528, 4537, 4545 20.17 3.25 4.98 Seal Bore MZ Systems 80-32 (4527.51- 4529.6) (4537.4-4539.8) (4544.9-4547.71) U10 4589 78.95 3.43 4.83 Screen Excluder 2000 U11 4668 10.55 3.43 4.59 Bakerweld Screen 10 Ga. U12 4679 39.44 3.43 4.83 Screen Excluder 2000 U13 4718 10.54 3.43 4.59 Bakerweld Screen 10 Ga. U14 4729 19.7 3.43 4.83 Screen Excluder 2000 U15 4748 19.83 3.43 4.59 Bakerweld Screen 10 Ga. U16 4768 19.57 3.43 4.83 Screen Excluder 2000 U17 4788 10.53 3.43 4.59 Bakerweld Screen 10 Ga. U18 4798 78.86 3.43 4.83 Screen Excluder 2000 U19 4877 30.34 3.43 4.59 Bakerweld Screen 10 Ga. U20 4907 59.23 3.43 4.83 Screen Excluder 2000 U21 4967 2.18 3.25 4.5 Seal Bore MZ System 80-32 U22 4969 3.48 3.62 6 SC-1L Packer 70B6-40 U23 4972, 4892, 4990 20.18 3.25 5 Seal Bore MZ Systems 80-32 (4972.2-4974.3) (4982.1-4984.5) (4989.6-4992.4) U24 5041 98.5 3.43 4.83 Screen Excluder 2000 U25 5140 39.4 3.43 4.59 Bakerweld Screen 10 Ga. U26 5179 78.89 3.43 4.83 Screen Excluder 2000 U27 5258 10.52 3.43 4.59 Bakerweld Screen 10 Ga. U28 5269 39.45 3.43 4.83 Screen Excluder 2000 U29 5308 2.18 3.25 4.57 Seal Bore MZ System 80-32 U30 5310 3.48 3.625 6.02 SC-1L Packer 70B6-40 U31 5314 20.18 3.25 4.52 Seal Bore MZ Systems 80-32 U32 5596 39.45 3.43 4.83 Screen Excluder 2000 U33 5635 39.3 3.43 4.59 Bakerweld Screen 10 Ga. U34 5674 98.6 3.43 4.83 Screen Excluder 2000 U35 5774 2.98 3.26 3.98 Seal units 82-40 S-22 90H Nitrile U36 5782 0.5 3.26 3.98 Half Mule Shoe 82-40 _____________________________________________________________________________________ Pg. 2 Created By: JJ 7/20/2016 SCHEMATIC Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 Lower Gravel Pack Isolation String ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description I1 5,772 4.24 4 6 Baker SC-2 Iso Packer 70B-40 5.5" 23# SLHT Box Nitrile I2 5,776 19.55 4.65 5.52 Millout EXT. 5.5" 23# L-80 SLHT PinxPin I3 5,796 1.34 3.26 6.05 Snaplatch 82-40 S-36 I4 5,797 & 5806 1.59 & 3.91 3.26 3.98 Seal Units 82-40 90H Stub @ 5797 & 5806 I5 5,845 & 6426 3.94 2.313 3.16 SLCMU BX Profiles @ 5845 & 6426 I6 6,430 1.18 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I7 6,431 11. 2.4 3.23 Seal Units 82-40 S-22 90H I8 6,691 3.93 2.313 3.17 SLCMU BX Profile I9 6,695 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I10 6,696 10.99 2.4 3.23 Seal Units 80-32 S-22 90H I11 6,854 3.93 2.313 3.17 SLCMU BX Profile I12 6,858 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I13 6,859 10.99 2.4 3.23 Seal Units 80-32 S-22 90H I14 7,207 3.93 2.313 3.17 SLCMU BX Profile I15 7,251 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I16 7,252 10.99 2.4 3.23 Seal Units 80-32 S-22 I17 7,264 1.8 2.42 2.91 Half Mule Shoe Lower Gravel Pack Screens ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description L1 5,799 3.78 4 6 Baker SC-2 Packer 70B-40 Nitrile L2 5,807 2.48 4 5.56 Seal Bore Receptacle 80-40 CK-250 L3 5,831 2.67 3.34 5.59 C-2 KnockOut Isolation Valve Isolation Sleeve (OPEN) L4 5,883 1.75 3.31 5.59 Baker C-2 Knock Out Isolation Valve L5 5,947 256.52 3.43 4.83 Baker Screen Excluder 2000 L6 5,986 218.43 3.43 4.59 Bakerweld Screen 10 ga. L7 6,007 39.45 3.43 4.83 Baker Screen Excluder 2000 L8 6,045 30.37 3.43 4.59 Bakerweld Screen 10 ga. L9 6,076 19.76 3.43 4.83 Baker Screen Excluder 2000 L10 6,095 19.8 3.43 4.59 Bakerweld Screen 10 ga. L11 6,115 59.2 3.43 4.83 Baker Screen Excluder 2000 L12 6,174 78.7 3.43 4.59 Bakerweld Screen 10 ga. L13 6,253 39.4 3.43 4.83 Baker Screen Excluder 2000 L14 6,293 69.8 3.43 4.59 Bakerweld Screen 10 ga. L15 6,362 59.2 3.43 4.83 Baker Screen Excluder 2000 L16 6,434 2.73 3.25 5 Seal Bore Receptacle L17 6,436 30.37 3.43 4.59 Bakerweld Screen 10 ga. L18 6,478 118.48 3.43 4.83 Baker Screen Excluder 2000 L19 6,499 89.45 3.43 4.59 Bakerweld Screen 10 ga. L20 6,538 19.8 3.43 4.83 Baker Screen Excluder 2000 L21 6,558 50.04 3.43 4.59 Bakerweld Screen 10 ga. L22 6,608 78.86 3.43 4.83 Baker Screen Excluder 2000 L23 6,699 2.73 3.25 4.49 Seal Bore Receptacle L24 6,701 89.45 3.43 4.59 Bakerweld Screen 10 ga. L25 6,751 79.04 3.43 4.83 Baker Screen Excluder 2000 L26 6,771 19.8 3.43 4.59 Bakerweld Screen 10 ga. L27 6,791 19.8 3.43 4.83 Baker Screen Excluder 2000 L28 6,862 2.74 3.25 4.49 Seal Bore Receptacle L29 6,865 50. 3.43 4.59 Bakerweld Screen 10 ga. L30 6,915 39.4 3.43 4.83 Baker Screen Excluder 2000 L31 6,954 39.4 3.43 4.59 Bakerweld Screen 10 ga. L32 6,994 19.8 3.43 4.83 Baker Screen Excluder 2000 L33 7,014 50. 3.43 4.59 Bakerweld Screen 10 ga. L34 7,064 19.8 3.43 4.83 Baker Screen Excluder 2000 L35 7,083 118.3 3.43 4.59 Bakerweld Screen 10 ga. L36 7,214 .88 3.43 4.83 Baker Screen Excluder 2000 L37 7,254 2.63 3.25 3.98 Seal Unit 82-40 Nitrile L38 7,262 .5 3.25 3.98 Half Mule Shoe 82-40 _____________________________________________________________________________________ Pg. 3 Created By: JJ 7/20/2016 SCHEMATIC Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Status Beluga D 4617' 4656' 3606' 3642' 14 9/14/2008 Slots Beluga D 4683' 4712' 3667' 3693' 14 9/14/2008 Slots Beluga D 4732' 4742' 3712' 3721' 14 9/14/2008 Slots Beluga D 4775' 4782' 3752' 3759' 14 9/14/2008 Slots Beluga D 4802' 4824' 3777' 3798' 14 9/14/2008 Slots Beluga D 4852' 4868' 3825' 3840' 14 9/14/2008 Slots Beluga E 4915' 4932' 3885' 3902' 14 9/14/2008 Slots Beluga E 4950' 4955' 3919' 3924' 14 9/14/2008 Slots Beluga E 5054' 5062' 4021' 4029' 14 9/14/2008 Slots Beluga E 5082' 5097' 4048' 4063' 14 9/14/2008 Slots Beluga E 5110' 5122' 4076' 4088' 14 9/14/2008 Slots Beluga E 5190' 5202' 4155' 4167' 14 9/14/2008 Slots Beluga E 5215' 5228' 4180' 4193' 14 9/14/2008 Slots Beluga E 5235' 5245' 4200' 4210' 14 9/14/2008 Slots Beluga F 5287' 5298' 4252' 4263' 14 9/14/2008 Slots Beluga F 5610' 5617' 4574' 4581' 14 9/14/2008 Slots Beluga F 5680' 5685' 4644' 4649' 14 9/14/2008 Slots Beluga F 5723' 5763' 4687' 4727' 14 9/14/2008 Slots Beluga G 5968' 5976' 4932' 4940' 14 9/8/2008 Slots Beluga G 6008' 6037' 4972' 5001' 14 9/8/2008 Slots Beluga G 6077' 6089' 5041' 5053' 14 9/8/2008 Slots Beluga H 6126' 6141' 5090' 5105' 14 9/8/2008 Slots Beluga H 6154' 6165' 5118' 5129' 14 9/8/2008 Slots Beluga H 6254' 6281' 5218' 5245' 14 9/8/2008 Slots Beluga H 6372' 6383' 5336' 5347' 14 9/8/2008 Slots Beluga H 6399' 6417' 5363' 5381' 14 9/8/2008 Slots Beluga H 6478' 6488' 5442' 5452' 14 9/8/2008 Slots Beluga H 6538' 6548' 5502' 5512' 14 9/8/2008 Slots Beluga H 6625' 6678' 5589' 5642' 14 9/8/2008 Slots Beluga H 6629' 6649' 5593' 5613' 6 9/5/2008 Slots Beluga H 6655' 6675' 5619' 5639' 6 9/5/2008 Slots Beluga H 6754' 6768' 5718' 5732' 14 9/8/2008 Slots Beluga H 6795' 6848' 5759' 5812' 14 9/8/2008 Slots Beluga H 6795' 6815' 5759' 5779' 6 9/4/2008 Slots Beluga I 6930' 6945' 5894' 5909' 14 9/8/2008 Slots Beluga I 6998' 7007' 5962' 5971' 14 9/8/2008 Slots Beluga I 6999' 7008' 5963' 5972' 6 9/2/2008 Slots Beluga I 7065' 7073' 6029' 6037' 14 9/8/2008 Slots Beluga I 7231' 7241' 6195' 6205' 6 9/1/2008 Slots Beluga I 7233' 7244' 6197' 6208' 14 9/8/2008 Slots Sump Packer ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description S1 7,254 1.97 4 5.85 85-40 Baker Model FS Sump Packer S2 7,256 0.83 4 5.85 .83' Blast Joint S3 7,257 19.42 5.54 4.93 Mule Shoe _____________________________________________________________________________________ P.1 Updated by CAH 08-11-25 PROPOSED Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 20” 9-5/8” RKB to MSL = 91.5’ RKB to GL = 16.5’ TD = 7,786' TVD = 6,750' PBTD = 7,786’ ED = 7,400’ ETVD = 6,273’ Max Angle = 56.33 deg Kickoff @ 2,390.3’ 2 3 4 5 3/8” control line 7/U1 U7/U8 U10-U20 U22 U24-U28 U2 U4/5 I2 L1 L2 L3/L4 G G H L5-L15 H H L16 H L17-L22 H L23 H H L24-L27 L28 I I L29-L36 I I L37 L38 TOC @ 3,610’ Beluga Sands D D D E E E F F F F 7” 6 U3 U6 U9 U21 U23 U30 U32-U34 I1 I3 I5 I5 I6 I7 I8 I9 I10 I11 I12 I13 I14 I15 I16 I17 U29 U31 U35 U36 I4 P2 P3 P1 1 3/8” cap string CASING DETAIL Size Type WT Grade Conn ID MD Btm 20''Conductor 94#X-64 Welded 19.124''85' 9-5/8"Surface 40#L-80 BTC 8.835''3,592' 7''Production 26#L-80 BTCM 6.276''7,776' TUBING DETAIL 4-1/2"Prod. Tubing 12.6#L-80 IBTM 3.958''4,483' Gravel Pack Detail Size Type WT Grade Conn ID MD Top MD Btm 4''Upper Gravel Pack Screens 11#P-110 4" 11# SLHT 3.43''4,477.4'5,782.6' 2.89''Lower Grav. Pk Iso Strng 6.4#L-80 2-7/8” Hyd 511 2.37''5,771.8'7,265.4' 4.59''Lower Grav. Pk Scrns 11#P-110 11# SLHT 3.43''5,799.2'7,262.1' 5.54''Sump Packer 23#L-80 SLHT 4.93''7,254'7,276.2' Production Tubing ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description 1 19 1.18 3.958 10.75 Vetco Tubing Hanger 2 451 1.24 3.92 5.57 Camco chem inject. nipple 3/8" Ctrl Line 3 504 2.67 3.813 5.57 Camco BP-6i Hydraulic Landing Nipple w/ DB 4 4212 6.89 3.938 5.98 Camco GLM 1" KGB-2, 4.5" IBT MOD. BXP (Dummy) w/ DMY Valve & BK Latch 9/25/2008 5 4382 1.17 3.813 5 'X' Nipple 6 4451 18.34 3.9 5.53 4.75" Polished Bore Receptacle 7 4477 3.22 3.25 3.98 Baker S-22 Anchor Seal Assembly w/ mule shoe Upper Gravel Pack Screens ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description U1 4477 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile U2 4482 10.04 4.7 5.55 Seal Bore Ext. U3 4492 2.81 3.25 4.52 Seal Bore 80-32 U4 4501 2.5 3.34 5.63 Knock Out Isolation Valve C-2 Isolation Sleeve U5 4503 1.74 3.34 5.63 Knock Out Isolation Valve C-2 U6 4511 10.54 3.43 4.54 Vent Screen Bakerweld 12 Ga. U7 4522 2.18 3.25 4.53 Seal Bore MZ System 80-32 U8 4524 3.49 3.61 6 SC-1L Packer 70B6-40 U9 4528, 4537, 4545 20.17 3.25 4.98 Seal Bore MZ Systems 80-32 (4527.51- 4529.6) (4537.4-4539.8) (4544.9-4547.71) U10 4589 78.95 3.43 4.83 Screen Excluder 2000 U11 4668 10.55 3.43 4.59 Bakerweld Screen 10 Ga. U12 4679 39.44 3.43 4.83 Screen Excluder 2000 U13 4718 10.54 3.43 4.59 Bakerweld Screen 10 Ga. U14 4729 19.7 3.43 4.83 Screen Excluder 2000 U15 4748 19.83 3.43 4.59 Bakerweld Screen 10 Ga. U16 4768 19.57 3.43 4.83 Screen Excluder 2000 U17 4788 10.53 3.43 4.59 Bakerweld Screen 10 Ga. U18 4798 78.86 3.43 4.83 Screen Excluder 2000 U19 4877 30.34 3.43 4.59 Bakerweld Screen 10 Ga. U20 4907 59.23 3.43 4.83 Screen Excluder 2000 U21 4967 2.18 3.25 4.5 Seal Bore MZ System 80-32 U22 4969 3.48 3.62 6 SC-1L Packer 70B6-40 U23 4972, 4892, 4990 20.18 3.25 5 Seal Bore MZ Systems 80-32 (4972.2-4974.3) (4982.1-4984.5) (4989.6-4992.4) U24 5041 98.5 3.43 4.83 Screen Excluder 2000 U25 5140 39.4 3.43 4.59 Bakerweld Screen 10 Ga. U26 5179 78.89 3.43 4.83 Screen Excluder 2000 U27 5258 10.52 3.43 4.59 Bakerweld Screen 10 Ga. U28 5269 39.45 3.43 4.83 Screen Excluder 2000 U29 5308 2.18 3.25 4.57 Seal Bore MZ System 80-32 U30 5310 3.48 3.625 6.02 SC-1L Packer 70B6-40 U31 5314 20.18 3.25 4.52 Seal Bore MZ Systems 80-32 U32 5596 39.45 3.43 4.83 Screen Excluder 2000 U33 5635 39.3 3.43 4.59 Bakerweld Screen 10 Ga. U34 5674 98.6 3.43 4.83 Screen Excluder 2000 U35 5774 2.98 3.26 3.98 Seal units 82-40 S-22 90H Nitrile U36 5782 0.5 3.26 3.98 Half Mule Shoe 82-40 _____________________________________________________________________________________ Pg. 2 Updated by CAH 08-11-25 PROPOSED Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 Lower Gravel Pack Isolation String ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description I1 5,772 4.24 4 6 Baker SC-2 Iso Packer 70B-40 5.5" 23# SLHT Box Nitrile I2 5,776 19.55 4.65 5.52 Millout EXT. 5.5" 23# L-80 SLHT PinxPin I3 5,796 1.34 3.26 6.05 Snaplatch 82-40 S-36 I4 5,797 & 5806 1.59 & 3.91 3.26 3.98 Seal Units 82-40 90H Stub @ 5797 & 5806 I5 5,845 & 6426 3.94 2.313 3.16 SLCMU BX Profiles @ 5845 & 6426 I6 6,430 1.18 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I7 6,431 11. 2.4 3.23 Seal Units 82-40 S-22 90H I8 6,691 3.93 2.313 3.17 SLCMU BX Profile I9 6,695 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I10 6,696 10.99 2.4 3.23 Seal Units 80-32 S-22 90H I11 6,854 3.93 2.313 3.17 SLCMU BX Profile I12 6,858 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I13 6,859 10.99 2.4 3.23 Seal Units 80-32 S-22 90H I14 7,207 3.93 2.313 3.17 SLCMU BX Profile I15 7,251 1.17 2.4 3.23 Locator Seal Assembly 80-32 S-22 90H I16 7,252 10.99 2.4 3.23 Seal Units 80-32 S-22 I17 7,264 1.8 2.42 2.91 Half Mule Shoe Lower Gravel Pack Screens ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description L1 5,799 3.78 4 6 Baker SC-2 Packer 70B-40 Nitrile L2 5,807 2.48 4 5.56 Seal Bore Receptacle 80-40 CK-250 L3 5,831 2.67 3.34 5.59 C-2 KnockOut Isolation Valve Isolation Sleeve (OPEN) L4 5,883 1.75 3.31 5.59 Baker C-2 Knock Out Isolation Valve L5 5,947 256.52 3.43 4.83 Baker Screen Excluder 2000 L6 5,986 218.43 3.43 4.59 Bakerweld Screen 10 ga. L7 6,007 39.45 3.43 4.83 Baker Screen Excluder 2000 L8 6,045 30.37 3.43 4.59 Bakerweld Screen 10 ga. L9 6,076 19.76 3.43 4.83 Baker Screen Excluder 2000 L10 6,095 19.8 3.43 4.59 Bakerweld Screen 10 ga. L11 6,115 59.2 3.43 4.83 Baker Screen Excluder 2000 L12 6,174 78.7 3.43 4.59 Bakerweld Screen 10 ga. L13 6,253 39.4 3.43 4.83 Baker Screen Excluder 2000 L14 6,293 69.8 3.43 4.59 Bakerweld Screen 10 ga. L15 6,362 59.2 3.43 4.83 Baker Screen Excluder 2000 L16 6,434 2.73 3.25 5 Seal Bore Receptacle L17 6,436 30.37 3.43 4.59 Bakerweld Screen 10 ga. L18 6,478 118.48 3.43 4.83 Baker Screen Excluder 2000 L19 6,499 89.45 3.43 4.59 Bakerweld Screen 10 ga. L20 6,538 19.8 3.43 4.83 Baker Screen Excluder 2000 L21 6,558 50.04 3.43 4.59 Bakerweld Screen 10 ga. L22 6,608 78.86 3.43 4.83 Baker Screen Excluder 2000 L23 6,699 2.73 3.25 4.49 Seal Bore Receptacle L24 6,701 89.45 3.43 4.59 Bakerweld Screen 10 ga. L25 6,751 79.04 3.43 4.83 Baker Screen Excluder 2000 L26 6,771 19.8 3.43 4.59 Bakerweld Screen 10 ga. L27 6,791 19.8 3.43 4.83 Baker Screen Excluder 2000 L28 6,862 2.74 3.25 4.49 Seal Bore Receptacle L29 6,865 50. 3.43 4.59 Bakerweld Screen 10 ga. L30 6,915 39.4 3.43 4.83 Baker Screen Excluder 2000 L31 6,954 39.4 3.43 4.59 Bakerweld Screen 10 ga. L32 6,994 19.8 3.43 4.83 Baker Screen Excluder 2000 L33 7,014 50. 3.43 4.59 Bakerweld Screen 10 ga. L34 7,064 19.8 3.43 4.83 Baker Screen Excluder 2000 L35 7,083 118.3 3.43 4.59 Bakerweld Screen 10 ga. L36 7,214 .88 3.43 4.83 Baker Screen Excluder 2000 L37 7,254 2.63 3.25 3.98 Seal Unit 82-40 Nitrile L38 7,262 .5 3.25 3.98 Half Mule Shoe 82-40 _____________________________________________________________________________________ Pg. 3 Updated by CAH 08-11-25 PROPOSED Beluga River Unit Well: BRU 211-026 Last Completed: 09/27/2008 PTD: 208-112 API: 50-283-20128-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Status Beluga D 4617' 4656' 3606' 3642' 14 9/14/2008 Slots Beluga D 4683' 4712' 3667' 3693' 14 9/14/2008 Slots Beluga D 4732' 4742' 3712' 3721' 14 9/14/2008 Slots Beluga D 4775' 4782' 3752' 3759' 14 9/14/2008 Slots Beluga D 4802' 4824' 3777' 3798' 14 9/14/2008 Slots Beluga D 4852' 4868' 3825' 3840' 14 9/14/2008 Slots Beluga E 4915' 4932' 3885' 3902' 14 9/14/2008 Slots Beluga E 4950' 4955' 3919' 3924' 14 9/14/2008 Slots Beluga E 5054' 5062' 4021' 4029' 14 9/14/2008 Slots Beluga E 5082' 5097' 4048' 4063' 14 9/14/2008 Slots Beluga E 5110' 5122' 4076' 4088' 14 9/14/2008 Slots Beluga E 5190' 5202' 4155' 4167' 14 9/14/2008 Slots Beluga E 5215' 5228' 4180' 4193' 14 9/14/2008 Slots Beluga E 5235' 5245' 4200' 4210' 14 9/14/2008 Slots Beluga F 5287' 5298' 4252' 4263' 14 9/14/2008 Slots Beluga F 5610' 5617' 4574' 4581' 14 9/14/2008 Slots Beluga F 5680' 5685' 4644' 4649' 14 9/14/2008 Slots Beluga F 5723' 5763' 4687' 4727' 14 9/14/2008 Slots Beluga G 5968' 5976' 4932' 4940' 14 9/8/2008 Slots Beluga G 6008' 6037' 4972' 5001' 14 9/8/2008 Slots Beluga G 6077' 6089' 5041' 5053' 14 9/8/2008 Slots Beluga H 6126' 6141' 5090' 5105' 14 9/8/2008 Slots Beluga H 6154' 6165' 5118' 5129' 14 9/8/2008 Slots Beluga H 6254' 6281' 5218' 5245' 14 9/8/2008 Slots Beluga H 6372' 6383' 5336' 5347' 14 9/8/2008 Slots Beluga H 6399' 6417' 5363' 5381' 14 9/8/2008 Slots Beluga H 6478' 6488' 5442' 5452' 14 9/8/2008 Slots Beluga H 6538' 6548' 5502' 5512' 14 9/8/2008 Slots Beluga H 6625' 6678' 5589' 5642' 14 9/8/2008 Slots Beluga H 6629' 6649' 5593' 5613' 6 9/5/2008 Slots Beluga H 6655' 6675' 5619' 5639' 6 9/5/2008 Slots Beluga H 6754' 6768' 5718' 5732' 14 9/8/2008 Slots Beluga H 6795' 6848' 5759' 5812' 14 9/8/2008 Slots Beluga H 6795' 6815' 5759' 5779' 6 9/4/2008 Slots Beluga I 6930' 6945' 5894' 5909' 14 9/8/2008 Slots Beluga I 6998' 7007' 5962' 5971' 14 9/8/2008 Slots Beluga I 6999' 7008' 5963' 5972' 6 9/2/2008 Slots Beluga I 7065' 7073' 6029' 6037' 14 9/8/2008 Slots Beluga I 7231' 7241' 6195' 6205' 6 9/1/2008 Slots Beluga I 7233' 7244' 6197' 6208' 14 9/8/2008 Slots Sump Packer ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description S1 7,254 1.97 4 5.85 85-40 Baker Model FS Sump Packer S2 7,256 0.83 4 5.85 .83' Blast Joint S3 7,257 19.42 5.54 4.93 Mule Shoe Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40287BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' • • 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. ( aQ g - t La Well History File Identifier Organizing (done) ❑ Two -sided 11111111111111 11111 ❑ Rescan Needed 111111111111 111 111 RESCAN DIGITAL DATA OVERSIZED (Scannable) Co lor Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: tXher, No/Type: GP N 0. 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: CVlar_Dia Date: / /s/ odP 1 4 7 I Project Proofing 11141111111 IIIII BY: Maria Date: IV L4.1/7/ /s/ ty,p Scanning Preparation x 30 = /SD + /0 = TOTAL PAGES / bo ._,,.. (Count does not include cover sheet) BY: Date: qJ ii /s/ Production Scanning III Ilill III III 1 Stage 1 Page Count from Scanned File: II (C2 1 (Count does include cov sheet) Page Count Matches Number in Scanning P eparation: YES NO BY: 11112, Date: 7 / / /si fop Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 1111111111111111 ReScanned 1111111111 1111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 IllIlIllIIII 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 4/4/2011 Permit to Drill 2081120 Well Name /No. BELUGA RIV UNIT 211 -26 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20128 -00-00 MD 7786 TVD 6750 Completion Date 9/27/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION ID Types Electric or Other Logs Run: GR/RES, Dipole, USIT, CCL, Neutron, Density, Formation Micro Imagi (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments , Rpt Report: Final Well R Open 9/29/2008 End of Well Report, Table of Contents, Equip and Crew, Well Data, Geo Data, Drilling Data, Daily Reports, Formation Logs yED C 16939 `'Report: Final Well R Open 9/29/2008 End of Well Report, Table of Contents, Equip and Crew, Well Data, Geo Data, Drilling Data, Daily Reports, Formation Logs 1 w /3D graphics Log./ Mud Log 2 Col 3600 7786 Open 9/29/2008 MD Formation Log Log/ Mud Log 2 Col 3600 7786 Open 9/29/2008 TVD Formation Log • Log/ Mud Log 2 Col 3600 7786 Open 9/29/2008 MD LWD Combo Log Log! Mud Log 2 Col 3600 7786 Open 9/29/2008 TVD LWD Combo Log Log! Mud Log 2 Col 3600 7786 Open 9/29/2008 MD Gas Ratio 1 Log- Mud Log 2 Col 3600 7786 Open 9/29/2008 TVD Gas Ratio Log, Mud Log 2 Col 3600 7786 Open 9/29/2008 MD Drilling Dynamics Lo Myd'Log 2 Col 3600 7786 Open 9/29/2008 TVD Drilling Dynamics D C Lis 16993 Formation Micro Ima 3546 7760 Open 9/26/2008 LIS Veri, DAS, FMI og Formation Micro Ima 2 Blu 3544 7762 Open 9/26/2008 Dipole Sonic, FMI, GR 18- Aug -2008 DATA SUBMITTAL COMPLIANCE REPORT 4/4/2011 Permit to Drill 2081120 Well Name /No. BELUGA RIV UNIT 211 -26 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20128 -00 -00 MD 7786 TVD 6750 Completion Date 9/27/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N "og Formation Micro lma 5 Blu 3544 7762 Open 9/26/2008 Dipole Sonic, FMI, GR 18- Aug -2008 Log" Sonic 5 Col 3544 7762 Open 9/26/2008 Dipole Sonic, FMI, GR 18- Aug -2008 Log- '- Induction /Resistivity 5 Col 3588 7781 Open 9/26/2008 Fullbore Micro Resistivity, FMI, GR 18- Aug -2008 III Log - --- See Notes 5 Col 4623 7601 Open 9/26/2008 Mech Sidewall coring 18- Aug -2008 Log!' Cement Bond 5 Col 3100 7660 Case 9/26/2008 USIT, CBL 29- Aug -2008 / Log! Formation Tester 2 Col 3750 6998 Case 9/26/2008 MDT 18- Aug -2008 Log Formation Tester 5 Col 3750 6998 Case 9/26/2008 MDT 18- Aug -2008 C Exc Directional Survey 0 7786 Open 10/8/2008 NAD27 and NAD83 on CD 1.11P Directional Survey 0 7786 Open 10/8/2008 NAD27 Report 1 Directional Survey 0 7786 Open 10/8/2008 NAD83 Report sFRp LIS Verification 101 7786 Open 11/5/2008 LIS Veri, GR, RPS, RPD, RPX, RPM, FET, NCNT, RHOB, DRHO, FCNT, NPHIREDO I -D C Lis 1713 Induction /Resistivity 101 7786 Open 11/5/2008 LIS Veri, GR, RPS, RPD, RPX, RPM, FET, NCNT, RHOB, DRHO, FCNT, • NPHI REDO Log Induction /Resistivity 25 Col 226 7786 Open 11/5/2008 MD ROP, DGR, EWR, CTN, ALD 17- Aug -2008 REDO Logue Induction /Resistivity 25 Col 226 7786 Open 11/5/2008 TVD ROP, DGR, EWR, CTN, ALD 17- Aug -2008 REDO "ED C Pds 17135 4ee Notes 0 0 Open 11/5/2008 PDS, EMF and CGM of EWR logs REDO Lot Induction /Resistivity 25 Col 226 7786 Open 11/5/2008 MD ROP, DGR, EWR, CTN, ALD 17- Aug -2008 DATA SUBMITTAL COMPLIANCE REPORT 4/4/2011 Permit to Drill 2081120 Well Name /No. BELUGA RIV UNIT 211 -26 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20128 -00 -00 MD 7786 TVD 6750 Completion Date 9/27/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N og Induction /Resistivity 25 Col 226 7786 Open 11/5/2008 TVD ROP, DGR, EWR, CTN, ALD 17- Aug -2008 Ems'" C Pds 17144 'e Notes 0 0 Open 11/5/2008 PDS, EMF and CGM of EWR logs t1=D C Lis 16886 Induction/Resistivity 101 7733 Open 9/13/2008 LIS Veri, RPD, RPS, FET, RPM, GR, ROP, PEF, • NCNT, FCNT, NPHI, DRHO, RHOB Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM TN Well Cored? O_%�= c p„ s.,-• Daily History Received? (.'-1 N Chips Received? Y I Formation Tops ¥ N Analysis Y A Received? Comments: • Compliance Reviewed By: t t Date ' r` • �I - p l 0. G f A x SARAH PALIN, GOVERNOR AND ALASKA OIL N GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ! PHONE 907A2A 9501 -3539 9-1433 FAX (907) 276 -7542 Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 211 -26 Sundry Number: 309 -194 Dear Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 i Daniel T. Seamount, Jr. Chair DATED this ) 7 day of June, 2009 Encl. 4 CO RECEIVED wa II STATE OF ALASKA JUN 1 0 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL oil & Gas Cons. Commission; 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other IN Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ unload water , 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 Ei , Exploratory ❑ 208 - 112 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20128 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes ❑ No 0 • BRU 211 -26 • 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): L 6 j „ AN, ,; ?, t.- ADL 21127 • RKB 91.5' • Beluga River Field / Steding-13ettga Gas Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7786' 6750' . 7400' 6273' Casing Length Size MD TVD Burst Collapse Conductor 86' 20" 104' 104' Intermediate 3574' 9 -5/8" 3592' 2863' Production 7758' 7" 7776' 6740' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4617' -7244' 3605-6206' 4.5" L -80 4484' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SC -2 pkr @ 4477' Camco SCSSV @ 504' 13. Attachments: Description Summary of Proposal El 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 12, 2009 Oil ❑ Gas 0 ' Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby ce i„ tha oregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed Na' Ennis Title: Wells Engineer Signature � Phone 265 -1544 Date G I'4 01 Commission Use Only Sundry Number: 3 ` f „U- , / i ^ , r Conditions of approval: Notify Commission so that a representative may witness l•/ L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: I D — LI p APPROVED BY Approved by: ___ ' CCIiMmissiq, E THE COMMISSION Date: 6 /2 11 Form 10 -403 Revised 06/2 W 1(33 S ubmit in Dupli J RI❑IN L 6 ,./ . 7 ot • • BRU 211 -26 CT N2 Water Unloading Wells Network#: 10253191 The procedure outlined below will utilize CT and nitrogen to remove any standing • produced water which may be inhibiting gas production. Reminder: All personnel on location are required to have received Beluga orientation training at the CPAI Kenai LNG Plant within the past year. Procedure: 1. MIRU BJ 1.75" CTU & nitrogen unit. Nipple up and test BOP as per SOP. Notify AOGCC 24 hours prior to BOP testing. 2. RIH w/ CT to 4500' CTMD. Begin pumping 500 scfm N2 and RIH to 7250' CTMD unloading produced water. Adjust N2 rates as necessary to maintain full circulation. POOH. 3. RDMO BJ. Flow well for cleanup & turn over to production. 6/10/2009 BRU 211 -26 CT N2 unload procedure 6- 10- 09.doc Created by jjennis ` .. ,f±: , SAK • BRU 211 -26 �+� }r� l Well Attributes ;Max Angle & MD TD G , Wellbore APIIUWI Field Name Well Status Prodllnj Type : Inc] ( °) MD (ftKB) Act Btm (ftKB) Alf. *Ska`iO• t:aneccikxtkps # 502832012800 BELUGA RIVER UNIT PROD 56 33 2,390 27 7,786.0 "" Comment H2S (ppm) Date L t t on tEnd Date KB -Grd (ft) Rig Release Date • Well Contg: DEVIATED .O'u 211 26 '2I307230E 3 00:0'1 Pc S SSV' ast WO: 16 52 /27/2 SOemet - Actual Annotation !Depth (ftKB) End Date Annotation End Date Last I ag: Rev Reason: NEW E 12/30/2008 _- _. -- -- W-._ LL 4444. 4444. -- __ -. - - -- nauoeR, ,a - r Casin • Strin • s '; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd coaoucTCn+am. CONDUCTOR 20 19.124 10.0 85.0 85 -0 94.00 _- _..._..... _._. __. NIPPLE, String '•»�^ Casing Description String 0._ String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String - -- String Top Thrd ; _ SURFACE 95/8 8.835 21.2 3,591.5 2,862.7 40.00 L - 80 BTCM N°eiE +e• Casing Description Strang O String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd ,, PRODUCTION 7 6.276 180 7,775.7 6739.9 2600 L80 BTCM Suarece,bsa•2 s .._ ... __. - _ - -. Tubing Strings '_ f � . ^' i Tubing Description 'String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd woae, S0 1 �. TUBING, 41/2 3.958 1.5 4,482.0 3,488.0 12.60 L -80 18 t ""; „ � Com p letion Details •� Top Depth ''''' : eve.,mo s. � (TVD) Top Inc! sre r e,,.K��Ewq' •a " :aos - ` � ,. T op {ftKB) (NKB) ( °) Item Description C M ID (in) ,.,.. �,. -_._.. - 17.9 17.9 -0.01 HANGER Tubing Hanger 3.958 PACKER SER 4,S14 450.0 450.0 1.25 NIPPLE Camco them injection nipple 3/8" control line 3.9201 Se T USIN O 4af7 5 02.0 502.0 1.31 NIPPLE Camco 3.813" BP -61 hydraulic landing nipple w/ DB 3.813 Sm Teewn - -- Y 9 PP SCREE i1 :ass so» ".9+7.9x9 �.: 4,381.3 3,405.7 37.63 NIPPLE 'X" Nipple 3.813" 3.813 scRtEN.,99e SCREEN, 476 4,449.9 3,461.0 33.04 PBR 4.75" Polished Bore Receptacle 3.900 SCREEN,. n9 I t - . 4,478.8 3,485.3 31.89 SEAL. ASSY Baker S -22 Anchor Seal Assembly with mule shoe dow 3.250 3eleK 7 766_ x9,,,,.77.762 � ..-4 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. Strmg Wt._ String ... String Top Thrd x:SEN. •Sa U -� v Upper Gravel Pack 4 3.430 4,477.4 5,782.6 4,746.9 1 11.00 P -110 4" 11# SLHT S CREEEN, a ce 1 a, xM us2ae �,� u Screens SCRE - ++' Completion Details s°. ps " oas' a SS � T Depth, SeR,.aa7 ----- PAC eii __ _ (TVD) Top Inc! seR, 4vez Top(ftKB) (BKB) (1 ' Item Description Comment 10 (in) _ ...� sen. -- 4,477A 3,484.1 31.95 PACKER Baker SC-2 Packer 706-40 Nnnle ' 4.000 xa. e e c7L_ � ■.� 4,481.6 3,487.7 31.78 SBE Seal Bore Extension 4.700 scare" 1a, + ' x, ► .w.1 „11,2 -_. - ♦ scree" s,. L - �� 4,491.6 3,496.3 31.38 SBR Seal bore 8032 3.250 x:..s,sox,2o2 x :glg.: va -- r- 4,500.5 3,503.8 31.03 SLEEVE Knock Out Isolation Valve C-2 Isolation Sleeve 3.340 s "..".s xse,ae sa s ° ' r r � x xs se = -_ -. . . ♦ , s ,n l e ,2as � ♦: 4,503.0 3,506.0 30 94 VALVE Knock Out Isolation Valve C-2 3.340 PAC s ea .. T 4,510.7 3,512.6 30.63 SCREEN Vent Screen Bakerweld 12 Ga. 3.430 Ne∎. r9s" - __. _ __.. ...,._....... RA� xa'• 4,589.0 3,581.3 26.15 SCREEN Screen Excluder 2000 3.430 sex z aza 4,668.0 3,653.0 23.92 SCREEN Baketweld Screen 10 Ga. 3.430 SEA,. - ! -; & ! -; 4,678.5 3,662.5 23.54 SCREEN Screen Excluder 2000 3.430 scare" 1as9 -- 4,718.0 3,699.5 21.93 SCREEN Bakerweld Screen 10 Ga. 3.430 SCREE" oars o...,_ S,. »" x,asrx99s - ♦�� 4,728.5 3,709.1 21.57 SCREEN Screen Excluder 2000 3.430 .,=.7M2 ∎ ♦ - • ��� 4,748.2 3,727.2 20.89 SCREEN Bakerweld Screen 10 Ga. 3.430 PACKER 1.72 4_44,4 __ ...........,. s: Axsv sn, j " ,. 4,768.0 3, 745.6 20.21 SCREEN Screen Excluder 2000 3.430 r. seR. „ ...:..::...... vn ano _- _...4 Srn xTxa 4,787.6 3,763.9 19.54 SCREEN Bakerweld Screen 10 Ga. 3.430 PACKER, 5.718 J ..�... ....,......,.,,_�,�.. 4 3,773.8 19.17 SCREEN Screen Excluder 2000 3.430 saa sBn, - -. ,..,...,,...._.. c 4,877.0 3,848.9 16.39 SCREEN Bakerweld Screen 10 Ga. 3.430 4,907.3 3,878.0 15.43 SCREEN Screen Excluder 2000 3.430 Reeve o xaS, ._.. NAEK.xa6S - - - -- 4,966.6 3,935.4 13.56 SBR Seal Bore MZ System 80 -32 3.250 t , 4,968.8 3,937.5 13.49 PACKER Baker SC-1L Packer 7086 -40 3.620 .", 5_ _N 4,972.2 3,940.9 13.38 SBR Seal Bore MZ System 80 -32 3.250 = 19865978- -l i 4,982.1 3,950.5 13.07 SBR Seal Bore MZ System 80 -32 3.250 x°'sc�°EN°`. °aa : _ 1 ; : 4,989.6 3,957.8 12.83 SBR Seal Bore MZ System 80 -32 3.250 sz,.: "9pn 9966 " ,ama ---- - - - -- sce eert 9961 5,041.1 4,008.3 11.13 SCREEN Screen Excluder 2000 3.430 ca ., 4444 5,139.6 4,105.3 8.54 SCREEN Bakerweld Screen 10 Go 3.430 '12 9,x.9,91 SCREEN a,74 Sa.." e.a.,., 9n s, -..." a ,25.9,29, s ----- 5,179.1 4,144.2 7 51 SCREEN Screen Excluder 2000 3.430 scREEna,2ss ���•� >�� -- __. r:,. 5,258.0 4,222.6 5.10 SCREEN Bakerweld Screen 10 Ga. 3.430 .o-,8,3998,417 L .. 5,268.5 4,233.1 4.89 SCREEN Screen Excluder 2000 3.430 a 5,307.9 4,272.5 4.35 SBR Seal Bore MZ System 80-32 3.250 MR, anw SCREEN 6.494 + ` ; 5,310.1 4,274.7 4.30 PACKER Baker SC -1L Packer 7066-40 3.625 x »" weans 5,313.6 4,278.2 4.22 SEAL ASSY Seal Bore MZ System 80 -32 3.250 x° ""1' 9. 1'1" 6 . " . ' wS ' 5,315.7 4,280.3 4.17 SEAL ASSY Upper Extension MZ System 80 -32 3.970 SCREE" ASKS- 5,319.4 4,284.0 4.08 SEAL ASSY Fran Extension MZ System 80-32 4.010 saw" e9x.a9.s - ,,..,. ... Saw" 99zsa97s -- -. _ 5,323.5 4,288.0 3.99 SBR Seal Bore MZ System 80 -32 3250 Saw" 89x189 �- 71 „,. - 5,325.9 4,290.4 3.94 SBR Lower Extension MZ System 80-32 3.980 - 5,330.9 4,295.5 3.82 SBR Seal Bore M2 System 80 -32 3.250 SCREEN , a o+ r .�••; 5,595.7 4,560.1 0.57 SCREEN Screen Excluder 2000 3.430 Sao,. 97x.9796 � - --� sa., 'ERIN, 971, Screen s �»° �, " ieagz� KY a . 7 ' ..'9 ^`rTz ra v" :, >,- ; 1 v u - < '' x -4 a rr� Screen, a7 ... s , 7 e.e � - I 1 -. a T � h .., Tep = -, Port • / r' -I r (TVD) Inc' OD Valve Latch Size TRO Run Stn To. KB MKS) C) Make Model (in) Sere Type TYPE (m) (Psi) Run Date Comm_. MR, 6,062 - . 1 4,211.6 3,275.5 44.59 CAMCO KBG -2 -16 1 Gas Lift DMY BK 0 0.0 9/25/2008 SCREE". CMS • "' -- - 0.0.sl SCREEN, 054 a■s67ue Sa,»..A,,ass. " - it PACKER, 7,214 -. musty,, 7 ,29• r SNOE, 7,237 TJ, 7 6 _. _ . t SAK • BRU 211 -26 Conc�coPhill ps g Arasw:a, inn; Unnorvr* r. ' (ft) Rig Release Dale Well Canfig:DEVIATED-BRU21i26 12/0/200830001 PM I --- - I. ..__ ___ 16.52 9/27/2008 Schema c Actal R IS Completion Details Top Depth 3 (N Ind D) Top In CONC,C1.1, 10E NIPPLE, 450 ""•. Top MKS) ( 1168 ) C) Item Description Comment ID (In) 1 5,635.2 4,599.5 0.55 SCREEN Bakerweld Screen 10 Ga. 3.430 NIPPLE,. a 5,674.5 4,638.8 0.53 SCREEN Screen Excluder 2000 3.430 SLAP.l z, US. --_ - 5,774.1 4,738.4 0.51 SEAL ASSY Seal Unit 82- 40S -2290H Nltdle 3.250 ENS v,4z+z 5,777.1 4,7414 0.50 SEAL ASSY Spacer Sub 82 -40 3.250 » rau< ° 5,782.1 4,746.4 0.50 Mule Shoe Mule Shoe 3.260 93 ¢ Tubing Strings i Etlora.e.O, as. Tubing Description String 0 String ID ... Top (HKB) Set Depth (f.. Set Depth (ND) ... String Wt... String ... String Top Thrd � Lower Gravel pack 2 89 2.370 5,771.8 7,265 4 6,229.7 6.40 L-80 2 -7/8 Hyd 511 s 4-' - " "" Isolation Stnng -- P„csea,asw .47. � - Completion Details SSRTUanu,.. Top Depth ssR,uaNG,4,s4s -.30-___, (ND) Top Inc' a - „4 s , �;y,; T op ( HKB ) ( ftKB) ( item Description Comment ID (in) " °h°' - Y 5,771.8 4,736.1 0.51 PACKER Baker SC -2 Isolation packer 708-40 4.000 °N :x, R R i 5,776.0 4,740.4 0.50 MILLOUT Mill out extension 5 -1/2" 235 L-80 SLHT 4.650 sz, 241E SCREE„ ,.;u • 5,795.6 4,759.9 0 49 Snaplatch Snaplatch 3.260 scREEN ° >n .1 51 5,796.9 4,761.3 0.49 SEAL Seal Units 80 -32 S-22 90H 3.260 scaleN .7u .. _ -�... su «".A.44u , 5 4,770.2 0 48 SEAL Seal Units 80-32 S-22 90H 3.260 sa scaeeN ..n .,. ,. « "aeeN..a97 44 sc 4407 6,429.9 5,394.3 0.34 SEAL ASSY Locator Seal Assembly 80 -32 S-22 901 2.400 9.44. °..4434 Puy EA :yei 6,431.1 5,395.4 0.34 SEAL Seal Units 80-32 S-22 90H 2.400 S ea On _„ .._.._. „__..,._ .... Sac 44112 - : 6,694.8 5,659.1 0.90 SEAL ASSY Locator Seal Assembly 80 -32 S-22 90H 2.400 314. 44.1 »" :4:+ :pu 6,696.0 5,660.3 0.90 SEAL Seal Units 80 -32 S -22 90H 2400 sa» "R�E� :„.`( 6,858.0 5,822.3 0.37 SEAL ASSY Locator Seal Assembly 80 -32 S -22 90H 2.400 , : „k,ss yy SCREEN,. d 6,859.1 5,823.4 0.37 SEAL Seal Units 80-32 S -22 90el 2.400 s aleN.4„s� S., «. 3.,34.79 0 F 7,250.9 6,215.2 0.41 SEAL ASSY Locator Seal Assembly 80 -32 S -22 90H 2.400 ,i \ Y - a 7 ,252.1 6,216.4 0.41 SEAL Seal Units 80 -32 S -22 90H 2.400 ': ' ° 7,263.6 6,227.9 0.41 Mule Shoe Mule Shoe 2.420 sln.nss.:, \ _ s1.,..ssv. sat. �-- sea. �rt Tubing Description Skiing 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt... String ... String Top Thrd SERR.,.-- ';:. - Lower Gravel pack 4.59 3.430 5,799.2 7,262.1 6,226 4 11 00 P -110 116 SLHT d•- Screens sa.M. :4,93,4,7 - scale,3A9a'"-- -- C omp l e ti on Details ds SCREE, SOS - .. +x ' Top Depth I (ND) Top Intl 3cRE1,s474 - ►♦ so-4.ns>zsn. . iiii ♦ 4 Top MKS) (MB) (1 Item Description commend ID (in) racaa,3„z _ .....re, ..■ 5,799.2 4,763.6 0.49 PACKER Bake SC -2 Packer 70B -40 Nitrile 4.000 SE, ASSY :774 x ___ ^WSV ::;% 4 5,806.6 4,771.0 048 SBR Seal Bore Receptacle 80-40 CK 250 - 4.280 Seem, , 3,74 -- - ..413 5,749 _ - 5,830.8 4,795.1 0.46 SLEEVE -O C -2 Knockout Isolation Valve Isolation Sleeve (OPEN) 3.310 soa,sam 5,833.4 4,797.8 0.46 VALVE Baker C -2 Knock Out Isolation Valve 3.310 5,946.6 4,910.9 0.38 Screen Baker Screen Excluder 2000 3.430 Excluder co.c 3X+9 -- P-, � 'g','' 5,986.0 4,950.4 0.30 SCREEN Bakerwekl Screen 10 ga. 4" 11# SLHT P -110 3.430 pY l 4 L 6,045.3 5,009.6 0.36 SCREEN Bakerweld Screen 10 ga 4" 11# SLHT P-110 3.430 "- _F 6,075.6 5,040.0 0.39 Screen Baker Screen Excluder 2000 3.430 I :a Excluder s "2R pPP E Ras _._ - I 6,095.4 5,059.8 0.41 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 eviwi SCRIM M . 6,1152 5,079.6 0.43 Screen Baker Screen Excluder 2000 3.430 ..".s,, /.01+ -� _ 4 1 Excluder u .3°az + kt sen. 6,174.4 5,138.8 0.66 SCREEN Bakerwekl Screen 10 ga. 4' 11# SLHT P-110 3.430 ACON .41 _._.. seaeeR 1 8309- -- 6,253.1 5,217.5 0.47 Screen Baker Screen Excluder 2000 3.430 sA »" a37aa,u3 1 I a:,.. "E�.,.., 4409 _ Excluder s< " ssoBSe 6,292.6 5,256.9 0.38 SCREEN Bakerweld Screen 10 ga. 4" 115 SLHT P-110 3.430 313,R, L,434 6 5 0.38 Screen - Baker Screen Excluder 2000 3.430 soft.. mu - Excluder sa «.3109 L/ 4,.,9 6,433.6 5,397.9 0.35 SBR Seal Bore Receptacle 3250 4 a:i ---.4 i 6,436.3 5,400.6 0.35 SCREEN Bakerweld Screen 10 ga 4" 11# SLHT P-110 3430 'q k 6,478.7 5,443.0 0.45 Screen Baker Screen Excluder 2000 3.430 a. aaz:a _ I.i - - Excluder so4.n :33ssa4,: N a .. _ L 6,498.5 5,462.8 0.49 SCREEN Bakerweld Screen 10 ga. 4" 118 SLHT P -110 3.430 6,537.9 5,502.2 0.61 Screen Baker Screen Excluder 2000 3.430 MR, slu - Excluder vv, eL- e., a,7, _ _ . WIEN, 8,771 SER.O. SCREE, 7403 - .NO. p207 Vii .«„7.39 >.« -- ,0,121, ' 9 w110 e, 7o, 570 ` - - - SAK BRU 211 -26 ConocoPhillips A/c.., - - - - - -- _ -- KB -Grd (k) Rig Release Date "' 16.52 9/27/2008 Well Config; DEVIATED 68321 +26,? 28W2008380. 0 i PM _ -. - - -- - - - - - -_ - S[he.atc AC.ual H,... ,6 - ? Completion Details ' , j , Top Depth I coxos:roAoes , (TVD) Top Ind r.Pxe,4so Top MOO (KB) 11 I tem . Description Comment - -.. [ ID(in) rope va 6,557.7 5,522.0 0.65 SCREEN Bakerweld Screen 10 ga. 4" 116 SLHT P -110 3430 6,607.7 5,572.1 0.74 Screen Baker Screen Excluder 2000 3.430 susn,a x, 9AZ� - I- Excluder r __. _ . 6,698.6 5,662.9 0.90 SBR Seal Bore Receptacle 3.250 Nov...., OM 6,701.4 5,665.7 0.91 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P-110 3.430 PrC s M _ �, <e>9 \\ 6,751.3 5,715.6 0.61 Screen Baker Screen Excluder 2000 3.430 We iea1x : Excluder e..roa Sal, 4.494 F• _ . ._..... �- 6,771.1 5,735.4 0.56 SCREEN Bakerweld Screen 10 ga. 4' 115 SLHT P-110 3.430 ""= , - 6,790.9 5,755.2 0.52 Screen Baker Screen Excluder 2000 3.430 P.cKea•u - Excluder BM Taexq 4A7- - 6,862.2 5,826.5 0.36 SBR Seal Bore Receptacle 3.250 MOMS., 4,5•5 --- - _ • .vim SCREEN. O 6,864.9 5,829.2 0.36 SCREEN Bakerweld Screen 10 ga. 4" 116 SLHT P -110 3.430 " scaeex .au - i . 6,914.9 5,879.2 0.14 Screen Baker Screen Excluder 2000 - - 3.430 n e N. a, n4 A REe s r Excluder '2i a lit" ._ 1 ,.. SCREEN. :: 4. t 7441 R 6,954.3 5,918.6 0.16 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 -- I• 6,993.7 5,958.0 0.19 Screen Baker Screen Excluder 2000 3.430 sx ash _ _ Iw Excluder scacex.4a6t a P - -�-.�._ __. 7,013.5 5,977.8 0.12 SCREEN Bakerweld Screen 10 ga. 4" 118 SLHT P 3.430 _ • srwn 4aswasx _ . 464 -_ 7,063.5 6,027.8 0.21 Screen Baker Screen Excluder 2000 3.430 seFoOM -- Excluder see.•090 - - -- 7,083.3 6,047.6 0.24 [SCREEN Bakerweld Screen l0 ga. 4" 116 SLHT P-110 3.430 9u..n.=JtsasPd2 -.- 2000 sa Seld U.sre�\ yam♦ 7,254.0 6,218.3 0 41 E xcIud Baker Screen Excluder 2000 3.430 sCReex s,.+ - �,�. 7,213.6 6,177.9 0.421 Excluder Su..n,=„p =txx - SCR .,... 9 � � - ■ s...,, s,.wzu � SEAL Seal Unit 82 -40 Nlinle 3.250 9caeex s.,rd� scaeex szu - �_ 7,261 6 6 225.9 0 41 Mule Shoe 1 Mule Shoe 3.250 String 0... String ID ._IT - �..... - Tubing Strings � _ • .._ g g op (ftKB) Set Depth (f Set Depth (TVD) . String Wt... String Stri g Top Thrd sas S Su Completion Description Details 5 54 4.930 7,254 0 I 7,276 2 I 6 240 5 23 00 L-80 1 SLHT Tubing a+sL � Sump Packer la. ails Top Depth b b .. - (TVD) Top Inc scx As : s : Top (kK6) (*KB) C .s�rip I Item Comment IBS ' �u , - �� 7,254.0 6,218.3 0.41 PACKER Baker Model FS Sump Packer Size 85-40 4.000 - ' / 7,256.0 6,220.3 0.41 Blast Joint Blast Joint 4.000 ARue s 7,256.8 6,221.1 0.41 SHOE Mule Shoe 4.930 n��9rsa Perforations r z -- -- _- Shot 9101. M307 -- Top (TVD) Btm (TVD) Dens Top (ftKB) efm (ftKB) (ftK8) lftKel Zone Date (.h... Type Comment .2 4,617.0 4,656.0 3,606.4 3,641.8 9/14/2008 14.0 Screen "T:5.5-:3:1111- . - --»w -- - - - 4,683.0 4,712.0 3,666.6 3,694.1 9/14/2008 14.0 Screen - 4,732.0 4,742.0 3,712.3 3,721.5 9/14/2008 14.0 Screen 1- 5. .--C1 4,775.0 4,782.0 3,752.1 3,758.6 9/14/2008 14.0 Screen ads r - __. 4't r- 4,802.0 4,824.0 3,777.4 3,798.7 9/14/2008 14.0 Screen sI kD a 9B6A 4 6w -- I 1 4,852.0 4,868.0 3,825 1 3840.3 9/14/2008 14 0 Screen ,..:In A sca A A 4,915.0 4,932.0 3,8854 3,901 9 9/14/2008 140 Screen 11 4,950.0 4,955.0 3,919.4 3,924.2 9/14/2008 14 0 Screen 5,054.0 5,062.0 4,020 8 4,028 7 9/14/2008 14.0 Screen a9 , - _ 1 _ 6372,103 -._ j 5,082.0 5,097.0 4,048.3 4,063.1 9/14/2008 14.0 Screen __LI 5,110.0 5,122.0 4,075 9 4,087.8 9/14/2008 14.0 Screen I C J. 5,190.0 5,202.0 4,155.2 4,1671 9/14/2008 140 Screen 980. 644 SC.., aPSa f 5,215.0 5,228.0 4,180.0 4,192.9 9/14/2008 n 14.0 Scree ,,,,,,. B;-; L 5,235.0 5,245.0 4,199 8 4,209.8 9/14/2008 14 0 Screen Scareµ 6P99 T dl u ---! d . 5 5298.0 4,251.7 4 262 7 9/14/2008 14 0 Screen .n 4.39..19 19 . . i4 - i S..mi. xee 6�e-. 5,610.0 5,617.0 4,574.4 4,581.4 9/14/2008 14 0 Screen _ s ' z '"d :, l .danda n _ - + I i 11 5,680.0 5,685.0 4,644.4 4,649.4 9/14/2008 14.0 Screen lit. L 5,723.0 5,763.0 4,687.4 4,727.4 9/14/2008 14.0 Screen 5,968.0 5,976.0 4,932.4 4,940.4 9/8/2008 14.0 Screen .51,4.60 _. __.. ....e...... w,,.....,..:..__:. Mare, 6,1 6,008.0 6,037.0 4,972.4 5,001.4 9/8/2008 14.0 Screen Me, 8,71,4,71t11 w.x,ax, ' x51 d.», Mom d,,z=da+= Moon _ R nen cad ems... Moon 9 "sd0 6 . x. 9,14 . 9mm SCRerS>A9 Tuexq rasr - sa« R94iRw41 T m ' SPAL ASS, 7,231 - P„CiaR.,za4 ___. . "Tue .. i aes- i _ 7.464 --. ro"9rge, 9.499 r' SAK 0 BRU 211 -26 ConomPPhillips ,a, <.,F A e3ka,Inc:. KB -Grd (ft) Rig Release Date • Well Conflg. D MATED - 6R112126, 12/30E20063000 ?. Pfei - - - I .... 16 52 9/27/2008 _ Schema-ic • Actual x. :r : ,. ' --- ,, a Perforations „ - -- -- TShoi Top (TVD) Bin (TVD) Dens c.o.-re toes NIPPLE Top(EKB) Btm(RKB) (RKB) (MB) Zone Data (sh Typ° Comment ,w _. _.... __ 111118k. 6,077M 6,089.0 5,041.4 5,053.4 9/82008 14.0 Screen Nw.E.w9 6,126.0 6,141.0 5,090.4 5,1054 9/8/2008 14.0 Screen suRrncEsa,Six -- '' L 6,154.0 6,165.0 5,118.4 5,129 4 _ - 9/8/2008 14.0 Screen -� — Ows.rr,,,Q,2 - ■ 6,254.0 6,281.0 5,218.3 5,245 3 9/8/2008 14.0 Screen i t ._- .. _.. M. 6,372.0 6,383.0 5,336.3 5,347.3 9/8/2008 14 0 Screen R. "em ;,.. 6,399.0 6,417.0 5,363.3 5,381.3 9/8/2008 14 0 Screen „ ,;.� ►'°�^ 6,478.0 6,488.0 5,442.3 5,452.3 9/8/2008 14 0 Screen ..Aii - - -- 6,538.0 6,548.0 5,502.3 5,512.3 9/8/2008 14.0 Screen ▪ a,uaxo 6,625.0 6,678.0 5,589.3 5,642.3 9/8/2008 14.0 Screen eartTa 4a17 6,629.0 6,649.0 5,593.3 5,613.3 9/5/2008 6.0 Screen siR,aaxn. u+s - -- -' 6,655.0 6,675.0 5,619.3 5,639.3 9/5/2008 6.0 Screen ARE a 'aicRE'e'V',;,as _ - R . -i 6,754.0 6,768.0 5,718.3 5,732.3 9/8/2008 14.0 Screen v 9 5 SCREEN , 7 ..:....6. sa „� , »„ � -- _- R '- 6,795.0 6,815.0 5,759.3 5 , 7 79. 3 9/4/2008 6.0 Screen :=:::;:e-T----- . a 6,795.0 6,848.0 5,759.3 5,812.3 9/8/2008 14.0 Screen S d »N> z 6,930.0 6,945.0 5,894.3 5,909.3 9/8/2008 14.0 Screen s` • an16: . • 14:►f 9w 6,998.0 7,007.0 5,962.3 5,971.3 9/8/2008 14.0 Screen SCAM. 0177 em.,A,S,, s ap> • = t; 6,999.0 7,008.0 5,963.3 5,972.3 19/2/2008 6. 0 S creen ,Aai -..__ -- eACRJR 7,065.0 7,073.0 6.029.3 6,037.3 9/8/2008 14.0 Screen ... .R.°. __ 7,231.0 7,241.0 6,195.3 6,205.3 9/12008 6.0 Screen SW, 4,900 .- ---4.• sa «. sS.sAa9 i 7,233 0 7,244 0 6,197 3 6,208 3 i 9/8/2008 14 0 Screen 1 SCREEN. sA. +� __.. . • Sa«,..t,66,i � '► Notes; General & Safety sca -S . —... ! '+ � E d 0 to ,. -:••: s Soto, s,ios2o2 w n a Annotat BCRE.EN5,7L v_ w.«ssss,»i Iii 12/30/2008 NOTE: View Schematic w /Alaska Schematic9 0 s s R"" nx � ai� —. �� T2730/2008 NOTE: To view Gravel Packers, !so String, etc, click on that TOG Section mrtsaw y� —"_ _- ,. S G: C ASSSY, BM N. MS+Aiv..- sEnt / AZ sa,a nssv, sA,i�— - - SW, S,129 • ti SI 5e SCREEN. saes _ , ?w -c±w Scr.. SAL SAS 0,...,1,0 -. " +~• SEAL ASSY, 5,77. nw. 5.798 PACKER 6,799 SI SAG> v :It — - y ai SW » aroo-am7 - S«C^6A —. —. � « wv, outs SCaeEx, outs - -- atlaC,t„1__ s r 6� s n ¢ x - r .I,xm _.. Y we Re ? 5?at~ SCREEN a,. ww 5 yS .... tr .S.M.6.356— —. • 6r a,9 a m� SCREEN a}9v� ■ '''' ▪ saald4 O .:: . Sawn 6 m a' A, t 9— ' +� R. aaa9 .. it SCAM. 7A1. »n,7W>A7 - , SCREEN, 7,489 - ♦uax0,7p67 A a PACKER, 72. :Mr li l e , 7,257 o ilj9ai_,N, 0 EIVED STATE OF ALASKA �����nn66� ALASKA OIL AND GAS CONSERVATION COMIVt b4Q 7 2009 REPORT OF SUNDRY WEL.Aia TPNPo 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimula)krf orag Other Ei Scale Squeeze • 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: ConocoPhillips Alaska, Inc. Development El . Exploratory ❑ 208 -112 / • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20128 -00 7. KB Elevation (ft): 9. Well Name and Number: RKB 91.5' . BRU 211 - - 8. Property Designation: 10. Field /Pool(s): a , d /),.7•6 ADL 21127 • Beluga River Field / St - uga Gas Pool • 11. Present Well Condition Summary: Total Depth measured 7786' , feet true vertical 6750' • feet Plugs (measured) Effective Depth measured 7400' feet Junk (measured) true vertical 6273' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 86' 20" 104' 104' Intermediate 3574' 9 -5/8" 3592' 2863' Production 7758' 7" 7776' 6740' Perforation depth: Measured depth: 4617' -7244' true vertical depth: 3605-6206' Tubing (size, grade, and measured depth) 4.5 ", L -80, 4484' MD. Packers & SSSV (type & measured depth) see attached diagram Camco SCSSV @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 5835' 1257 bbls scale inhibition squeeze Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na 6 mmcfd Subsequent to operation na • 1.7 mmcfd (cleaning up) -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development 0 • Service ❑ Daily Report of Well Operations _X 16. Well Status after work: Oil❑ Gas El • WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308 -402 Contact Jim Ennis @ 265 -1544 Printed Name m Ennis Title Wells Engineer , 1� 1 Og 1 Signature 1, / Phone: 265 -1544 Date r �� � Prepared by Sharon ARsup -Drake 263 -4612 ,,,eD r. 7.e9 Form 10 404 \ vised 04/2006 BFL JAN 1 4 NH \' 13 Sub it Ori final Only BRU 211 -26 Well Work Summary DATE SUMMARY • 11/26/08 Continue rigging up BJ surface equipment. Perform initial BOP test. RIH with 2.875" 42B0 shifting tool on 1.75" coil. Tagged restriction in 2.875" tubing @ 5,845'CTMD just above top CMU to be shifted open @ 5,847'MD. Unable to work through restriction. POOH with coil to check BHA. On surface with coil, no indication of restriction on BHA. Job in progress. 11/27/08 Removed jars and shifting tool from BHA, add 2.18" nozzle. RIH w/ nozzle to 5,845'CTMD. Made several attempts to work through restriction in tubing with no success. Changed penetration rate and several pump rate changes, flowed well with no success. POOH with coil. Rack back injector head assembly. Stand by for remainder of day waiting on crossover from BJ BOP connection back to Pollard W /L. Will rigging up Pollard in AM. Job in progress. 11/28/08 MIRU Pollard W /L. Pulled 4.5" Dummy SSSV @ 488'WLM. Tagged debris in 2.875" tubing @ 5,847' WLM. Bail debris in tubing to 6,375'WLM, unable to make hole beyond this point. Tubing appears to have metal debris as well. Suspend job till later date. 11/30/08 MIRU POLLARD W /L. RIH W/ 1.75" MAGNET TO 6,375'WLM SET DOWN COUPLE TIMES, POOH. SMALL AMOUNT OF METAL SHAVINGS. RIH W/ 2" DD BAILER TO 5,831'WLM SET DOWM, WORK BAILER TO 5,863'WLM, UNABLE TO MAKE HOLE, NOTHING IN BAILER. RIH W/ 2.25" DD BAILER TO 5,381'WLM UNABLE TO MAKE HOLE, STUCK ONE HOUR, PULLED FREE, POOH. RDFN. 12/1/08 CONTINUED BAILING DEBRIS FROM 2.875" TUBING FROM 6,375' TO 6,377'WLM. SEVERAL LARGE PIECES OF PACKER RUBBER AND THREE CUPS OF SAND. JOB IN PROGRESS. 12/2/08 REMOVED BJ BOP STACK FROM WELLHEAD. MIRU POLLARD W /L. CONTINUED BAILING DEBRIS IN TUBING FROM 6,377' TO 6,380'WLM. THREE MORE PIECES OF PACKER RUBBER AND THREE CUPS SAND. JOB IN PROGRESS. 12/3/08 CONTINUE BAILING DEBRIS FROM 2.875" TUBING FROM 6,379' TO 6,381'WLM. TWO LARGER PIECES OF RUBBER RECOVERED WITH APPROXIMATELY 3 CUPS SAND. BAILING IN PROGRESS. 12/4/08 CONTINUE BAILING DEBRIS IN TBG @ 6,381'WLM. SEVERAL RUNS WITH ASSORTED WIRE GRABS AND BAILER, RECOVERED ONLY MINIMAL SAND. LOST W/L SPANGS IN HOLE. JOB IN PROGRESS. 12/5/08 FISHED WIRELINE MECHANICAL JARS LOST FROM PREVIOUS, RECOVERED SMALL METAL TOOTH LOST FROM WIRE GRAB. BAIL DEBRIS FROM TBG 6,380' TO 6,383'WLM. SAND, RUBBER, AND SMALL AMOUNT OF METAL IN RETURNS. JOB IN PROGRESS. 12/6/08 CONTINUE BAILING DEBRIS IN TUBING, ONLY MADE ONE FOOT OF HEAD WAY ALL DAY. THREE SMALL PIECES OF RUBBER, MINIMAL METAL, AND APPROXIMATELY THREE CUPS SAND RECOVERED TODAY. APPEARS THERE IS A LARGER METAL PIECE HINDERING PROGRESS. JOB IN PROGRESS. 12/7/08 CONTINUE BAILING OPERATIONS FROM PREVIOUS DAY. BAIL FROM 6,388' TO 6,422'WLM, CONTINUE GETTING RUBBER, METAL, AND SAND. CURRENTLY AT SECOND BAKER CMU. JOB IN PROGRESS. 12/8/08 CONTINUE BAILING SAND AND PACKER ELEMENT RUBBER IN TUBING FROM 6,424' TO 6,428'WLM. APPEAR TO BE JUST BELOW SECOND CMU SLIDING SLEEVE. RECOVERED SEVERAL MORE SMALLER PIECES OF RUBBER AND MINIMAL SAND. BAILING IN PROGRESS. 12/9/08 Continue bailing of rubber element pieces down to hard obstruction 6427' wlm. Decision made to open CMU's. Unable to latch sleeve @ 6409' RKB, PUH to sleeve @ 5859' RKB. Locate and hit fives times before releasing, tool string was blown up hole. (Anti -blow up tool did not appear to hold). Lost use of spangs, knuckle spangs and mechanical counter for accurate depth. (Approximate tool depth of 5823' wlm) TS will not go up or down. WHP increased to 1250 psi. RU BJ coil pump and pumped 100 bbls of 6% KCI to attempt to dislodge tools without success. Wire worked maximum cycles, standby for cutter bar to arrive from Kenai. BRU 211 -26 Well Work Summary 12/10/08 D rop 2.25" OD Kinley Cutter to sever .125" slickline. Cutter stopped and cut wire 7' be�Tow tubing hanger, leaving a remaining 5850' of wire and cutter in hole. RIH w/ 3.50" LIB to 7' and hit slush, RIH w/ 3.0" LIB to 22' and hit slush, RTH w/ 2.70" LIB to 50' stopped due to dangers of wire in hole. POOH w/ no marks on LIB. Pumped 10 bbls of 60/40 MEOH down tubing, LDFN standby for fishing tools from Kenai,. 12/11/08 Wrap tree and thaw ice at flowcross. RIH w/ 4.5" wire finder, sat down at 64' wlm. RIH w/ 3.5" LIB, got picture of wire at 64'. RDMO slickline unit, Braided line unit arriving from Kenai on afternoon barge. 12/13/08 RU .25" braided line unit, locate top of wire © 70' wlm w/ wire finder. Latched into wire, and dropped 2.25" Kinley cutter. Stripped out 3,750' of .125" slickline. (Kinley cutter left in hole). LDFN 12/14/08 Retrieved additional 1750' of .125 slickline wire out of well. (Approximately 350' remaining). LDFN 12/15/08 Continue fishing .125" slickline wire, retrieved 50' out of hole. LDFN 12/16/08 Continue w/ fishing operations. Retrieved two Kinley cutters and 1.5" slickline tool string from well. ((( During fishing operations, left one finger from wirefinder and two barbs from wire grab in hole.))) 12/17/08 Drift tubing for remaining wire and or scale from crossflow. Tubing is clear down to top of CMU @ 5846' RKB. 12/19/08 Set Coil tubing mechanical isolation packer @ 5835' RKB. Pumped 1257 bbl scale inhibition squeeze. (Job complete, CMU @ 5844' RKB left in open position). At surface, CT packer missing one slip and upper packer element. Pictures in well file. Ai SAK BRU 211 -26 Conoco Ph Well Attributes lMax Angie & MD TD , AMC' A Inc Wellbore API/UWI Field Name ,Well Status prod /ln) Type � Ind (') MD (ft KBI Act B)m (ftKB) 502832012800 BELUGA RIVER UNIT '' PROD I 56.33 I 2,390 27 7,786.0 'Comment 112S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well Confg: DEVIATED Bau 21x28, 1255/2008300:01 PM SSSV� WRDP �. ( Last WO: 16.52 9/27/2008 Schematic Actual Annotation Depth (ftKB) End Date Annotation End Date Last Tag- I 'Annotation Reason: NEW WELL 12)30/2008 wwsw.,e a -- V Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd caaov �,nn CONDUCTOR 20 19124 10.0 85.0 85.0 94.00 W .a.i _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f . Set Depth (ND) ... String Wt... String ... String Top Thrd M'B SURFACE 9 ing 5/8 8. 835 g ID ... To 21.2 _ _ 2 862 7 00 L -80 BTCM MAKE. 0'MAKE. C 9 Des pt on St 0... Strinp (ftKB) Set Depth 3.591 5 (f... Set D 0th (ND) ... Str 40. g Wt... String SW rg Top Thrd PRODUCTION 7 6.276 18.0 7, /7S 7 6,739 9 26.00 L-80 BTCM (MS LAMAS. Completion Details - -�- _ - -_ °�- - 'Tubing Strings Tubin Desc tion Sfr n O String ID Top (ftKB) Set Depth f... Set Depth (ND) ... 'String WI ... String Top Thrd . 'String < ei M ' I UBING 4 1/2 3 958 1 5 4,482.0 3,488.0 12 -60 L 80 IBTM BS NTS p SEAL E s E, M. F B �� ,3t j a (TVD) Depth ND) Top Inc' r ` MR " _ - €'�" Top (ftKB) (ftKB) (°I Item Description Comment - _ ID (in) mss 17.9 17.9 -0.01 HANGER Tubing Hanger ■ 3.958 PACKER ° i 450.0 450.0 1.25 NIPPLE Camco chem injection nipple 3/8' control line 3.920 MR iuM N0 ' ' ^s' 502.0 502.0 1.31 NIPPLE Camco 3.813" BP-6i hydraulic landing nipple w/ DB 3.813 sCraEN..Aeo _ Su.. .i.Aia '` 4,381.3 3,405.7 37.63 NIPPLE "X" Nipple 3.813" 3.813 .. A .Ai ': A R 4,449.9 3,461.0 33.04 PBR 4.75" Polished Bore Receptacle 3.900 O ' sakes.... R 4,478.8 3,485.3 31.89 SEAL ASSY Baker S -22 Anchor Seal Assembly with mule shoe slow 3.250 SCREEN. AMR Tubing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd A _ - Upper Gravel Pack Screens 4 3.430 4,477.4 I 5,782.6 4,746.9 11.00 P -110 4" 1111 SLHT sc ____ - �1� .._. S,- ^ °A'S10 -- .► 4 Com letion Details SM. A A y ,� �r � ► Top Depth P.cBea.,.Be- _ , -, (ND) Top Inc! a.An a..•�.rb Top (ftKB) (ftKB) (7 Item Description Comment ID (In) s Z' 4,477.4 3,484.1 31.95 PACKER Baker SC-2 Packer 708 -00 Nitrile 4.000 sn -n Sm.s4 S , -" ,�, � • ;� 4,481.6 3,487.7 31.78 SBE Seal Bore Extension 4.700 sb« 1'62 u� - - - -- � �� 1 w2ioi� • Mika.. 4,491.6 3,496.3 31.38 SBR Seal bore 80-32 3250 r� SceeEa.B,, ,*��_ 4,500.5 3,503.8 31.03 SLEEVE Knock Out Isolation Valve C -2 Isolation Sleeve 3.340 "LB 4,503.0 ��� 4,503.0 3,506.0 30.94 VALVE Knock Out Isolation Valve C -2 3.340 PAC S sa,2� � =' 4,510.7 3,512.6 30.63 SCREEN Vent Screen Bakerweld 12 Ga 3.430 . ..A m - - - »-- 4,589.0 3,581.3 26.15 SCREEN Screen Excluder 2000 3.430 . SEALA , . ua . -- - M san . -- mRea., 4,668.0 3,653.0 23.92 SCREEN B G akelweld Screen 10 Ga. 3.430 sea. S1S, -- - 4,678.5 3,662.5 23.54 SCREEN Screen Excluder 2000 3.430 ''"SC"'ee� -- '. 4,718.0 3,699.5 21.93 SCREEN Bakerweld Screen 10 Ga. 3.430 se:m..BABS - - - Samn,SABASASS - • ♦ 4,728.5 3,709.1 21.57 SCREEN Screen Excluder 2000 3.430 4 4,748.2 3,727.2 20.89 SCREEN Bakerweld Screen 10 Ga. 3.430 PALMA 3772 SEAL ASSY. 5,774 � , 4,768.0 3, 745.6 20.21 SCREEN Screen Excluder 2000 3.430 • „..8x61 S ..wun SAM " . 4,787.6 3,763.9 19.54 SCREEN Bakerweld Screen 10 Ga. 3.430 N. PACKER. 6.790 i 4,798.1 3,773.8 19.17 SCREEN Screen Excluder 2000 3.430 seR SAO? Igt 4,877.0 3,848.9 16.39 SCREEN Bakerweld Screen 10 Ga. 3.430 t. 4,907.3 3,878.0 15.43 SCREEN Screen Excluder 2000 3.430 ,ri.K as"s 4,966.6 3,935.4 13.56 SBR Seal Bore MZ System 80-32 3.250 4,968.8 3,937.5 13.49 PACKER Baker SC -1L Packer 70B6-40 3.620 4,972.2 3,940.9 13.38 SBR Seal Bore MZ System 80-32 3250 S°- • �"p^ "f a ' $` /116- :' 4,982.1 3,950.5 13.07 SBR Seal Bore MZ System 80 -32 3250 sceeenea:�__.._:,. x" " " 4,989.6 3,957.8 12.83 SBR Seal Bore MZ System 80-32 3250 ......p.-0. SAM M F 5,041.1 4,008.3 11.13 SCREEN Screen Excluder 2000 3.430 ACeNe.s- %s^^^ A 5,139.6 4,105.3 8.54 SCREEN Bakerweld Screen 10 Ga. 3.430 1s 4' J 5,179.1 4,144.2 7.51 SCREEN Screen Excluder 2000 3.430 - _ a xe.�v �_ j} I 5,258.0 4,222.6 5.10 SCREEN Bakerweld Screen 10 Ga. 3.430 5,268.5 4,233.1 4.89 SCREEN Screen Excluder 2000 3.430 5,307.9 4,272.5 4.35 SBR Seal Bore MZ System 80 -32 3.250 sm B.B 11' 8 SCFAM.6Are .. - 5,310.1 4,274.7 4.30 PACKER Baker SC -1 L Packer 70.16,10 3.625 �' 5,313.6 4,2782 4.22 SEAL ASSY Seal Bore MZ System 80-32 3250 A c µ.1,1S0 4 5,815.7 4,280.3 4.17 SEAL ASSY Upper Extension MZ System 80-32 3.970 w" a &2596 ,• s ` SM,e 11 - 5 4,284.0 4.08 SEAL ASSY Frac Extension MZ System 80-32 4.010 »" B,e.6A _ «.`BssBO rs � 1 1 su- MdAesdA - 5,323.5 4288.0 3.99 SBR Seal Bore MZ System 80 -32 3250 '' 5,325.9 4,290.4 3.94 SBR Lower Extension MZ System 80 -32 3.980 5,330.9 4,295.5 3.82 SBR Seal Bore MZ System 80 -32 3.250 so,--,. 5,595.7 4,560.1 0.57 SCREEN Screen Excluder 2000 3.430 • SCReEN. Val ..n B66M1 r ..w. ......z`.e ` 3r °` ` . L - ,�, ,.., i. :,' =gT:.' ze w.',,. * 's^5«2 +. se"« ar.seb.e� ., •.. -�.� p� Top Depth Top Port (TVD) Mott OD Valve Latch She TRO Run Stn Top (MB) (ftKB) ("1 Mate Model On) Sery Tyre Type )tn) (ps9 Run Date Comm... see. elk - 1 4,211.6 3,275.5 44.59 CAMCO KBG -2 -1R 1 Gas Lift DMY BK 0 0.0 9/25/2008 =. 0,1.11 Sr _ , sd- Scram p , AM ' I I , SCREEN, 7,01.1 xn.nwv,,AU ._. ' SceeEN, x,1.1.1 -. {A SuerW 7107- A H -4 I , SEAL ASSY, 7.231 _ Acaa t.s. sEA 114-- r b•s mm y Sr - s r Ali. 7-.0 , 1i Shoe. rl4 ro1i . w SAK BRU 211 -26 CornocoPhilli Ps ; A18 8, Inc. KB (f0 Rig Release Date ••• 16.52 9/27/2008 Well CCnfip- DEVIATED 81211211 - 26,1213012001 30D 01 PM __ S hemaoC Actual a Completion Details - ` Top Depth ca.oumo3. na - - a �� (TVD) Top Inc! .��_ __ �i Top(ftKB) (KKB) (°) Item Desaitp - bn -,. Comment ID On) M._, 5,635.2 4,599.5 0.55 SCREEN Bakerweld Screen 10 Ga. 3.430 NIPLE,M. 5,674.5 4,638.8 0.53 SCREEN Screen Excluder 2000 3.430 SuRFACE,11 e,.. 5,774.1 4,738.4 0.51 SEAL ASSY Seal Unit 82-40 S -22 90H Ngrile 3.250 o.s.n..xt 5,777.1 4,741.4 0.50 SEAL ASSY Spacer Sub 82-40 3.250 NIPPLE. 001 1 M1 I e....m«auw . Tubing g Description Str D D T Mule Shoe 3.260 SeR,4A'A Imo' , [ Tubing Strings s setuu rin ._ .eve,acc op (ftKB) Sat Depth ( Set Depth (TVD)... String Wt... String Top Thrd sK _ �. - I I Lower Gravel pack 289 2.370 5,771.8 7,2654 6,229.7 6.40 L-80 2 -7/8 Hyd 511 ""`ue,4,55 __ Isolation Stnng aw.cN S 01O .. , sa. Completion Details .a [Y. Top Depth Q �.s (ND) Top Inc! Top (ftKB) MKS) (1 Item Description Comment ID (in) ; W 5,771.8 4,736.1 0.51 PACKER Baker SC -2 Isolation packer 706 -40 4.000 sceEO..e - f s,. »..,.,v,,,.z # 5,776.0 4,740.4 0.50 MILLOUT Mill out extension 5-1/2" 23# L -80 SLHT 4.650 5,795.6 4,759.9 0.49 Snaplatch Snaplatch 3.260 F Z SCAM, 4,711. ea* as ` ���; 5,796.9 4,761.3 0.49 SEAL Seal Units 80 -32 S-22 90H 3.260 "7 1Z • :� +� 5,805.8 4,7702 0A8 SEAL Seal Units 80 -32 S-22 90H 3.260 ' 6 sa � =�; 6,429.9 5,394.3 0.34 SEAL ASSY Locator Seal Assembly 80 - 32 S-22 90H 2.400 e .au Ac ww- - -- � ' 6,431.1 5,395A 0.34 SEAL Seal Units 80 -32 S-22 90H 2.400 IBA, Se.a Sea.aa -. 6,694.8 5,659.1 0.90 SEAL ASSY Locator Seal Assembly 80 -32 S-22 90H 2.400 9e' 6,696.0 5,660.3 0.90 SEAL Seal Units 80-32 S -22 90H 2.400 = Sc o s y a4•'�i 6,858.0 5,822.3 0.37 SEAL ASSY Locator Seal Assembly 80 -32 S -22 90H 2.400 SCeLE" ' 6,859.1 5,823.4 0.37 SEAL Seal Units 80-32 S-22 90H 2.400 Sr.n.5,, Sr«m.51AJ5aA2 � SCa a165afa i "724e= 5 ! 7,250.9 6,215.2 0.41 SEAL ASSY Locator Seal Assembly 80 -32 S-22 90H 2.400 Scaeen sash _ ....... S„;;,, .; a ;a e t 7,252.1 6,216.4 0.41 SEAL Seal Units 80-32 S-22 90H 2.400 PACR ,± = _.._ -. -_. ar=se „� 7,263.6 6,227.9 0A1 Mule Shoe Mule Shoe 2.420 a Assv sal e_ _ - SeA.Aav s a+A - Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) .. String Wt... Siring ... String Top Thrd sea, ; Lower Gravel pack 4.59 3.430 5,799.2 7,262.1 6,226 4 11.00 P-110 11# SLHT Setl, Screens ear KnEF„ ,',5 Completion Details SCREEN, 5.1515 Top Depth - -� - - - S;. »n 5,46x06 *."1110 (TVD) Top lncl s .Ex ,4,. - , E 4 .,1 s,zm o♦., Top MKS) (KKB) ( °) Item Description Comment ID (In) PAC.E,26 „: ♦ 5 4 0 49 PACKER Bake SC -2 Packer 706-40 Hanle 4.000 SEN.'S, s. w.su.arr S»..sna 5,u�, 3t - ; ' 5,806.6 4,771.0 0 48 SBR Seal Bore Receptacle 80-40 CK 250 4.280 s+n.,,n 5.796 ._._. PACKER, 5,700 5,830.8 4,795.1 0.46 SLEEVE-0 C -2 Knockout Isolation Valve Isolation Sleeve (OPEN) 3.310 aR SAO - 5,833.4 4.797,8 0.46 VALVE Baker C -2 Knock Out Isolation Valve _ 3.310 5,946.6 4,910.9 0.38 Screen Baker Screen Excluder 2000 3.430 Excluder siECa :II `"`K seat - 5,986.0 4,950.4 0.30 SCREEN Bakerweld Screen 10 ga. 4 SLHT P-110 3.430 6,045.3 5,009.6 0.36 SCREEN Bakerwekd Screen 10 ga. 4" 11# SLHT P -110 3.430 s,..M E..�.,., un 6,075.6 5,040.0 0.39 Screen Baker Screen Excluder 2000 3.430 s.7.:nwa= - - Excluder , _ - 6,095.4 5,059.8' 0.41 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 Sup. p Ex.., ° d En era, 6,115.2 5,079.6 0.43 Scree n Baker Screen Excluder 2000 3.430 :. giii� - �I [ - Excluder s., »° az5. 6,174.4 5,138.8 0.66 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 6,9714,389 M 1. 6 5 0.47 Screen Baker Screen Excluder 2000 3.430 .. . .»�, a nes.,. eau_ -. • Excluder Sc., ,aAl.aan -. - it 1 - 6,292.6 5,256.9 0.38 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 UR aet. - 6,362.3 5,326.7 0.38 Screen Baker Screen Excluder 2000 3.430 SCREEN, ,,As■ - Excluder 9x. a p A a � -• 6,433.6 5,397.9 0.35 SBR Seal Bore Receptacle 3.250 . atta _ 6,436.3 5,400.6 0.35 SCREEN Bakerweld Screen 10 ga. 4" 118 SLHT P -110 3.430 Baa v= SCR ,4aSSy $SB P "' - • Ki 6,478.7 5,443.0 0.45 Screen Baker Screen Excluder 2000 * 3.430 s n,4n Excluder u..n S 6,431,015 - 1 < - 3 �' 6,498.5 5,462.8 0.49 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 6,537.9 5,502.2 0.61 Screen Baker Screen Excluder 2000 3.430 sa..a0a - Excluder v 12 a >A asa15 -- so....arAsai:i� (.° c Sea dlid2 - aas-�_ 4714- i [--.. .._ , '� III, _ a1. - . ... ''..=[1. »n , 'Aa1 . -... 15 •M , a , - xu ASV, ,a51 - .. . - PACKER 7a5. -- 1 11 410 ia.5," S- > - oyead-'[,. _ J s :II': SAK • BRU 211 -26 C�oPhillips Aral. Inc . k r7Mnkps `_ _.. ' IKB -Grd (ft) Rig Release Date • Config: DEVIATED BR42"126126002200830001 PM _ 16.52 r 9/2712008 Schematic . Aclual a, ,a co Completion Details Top Depth o � o � a (TVD) Top Inel " Top (ftKBL (ftKB) C) i tem Description Comment ID (in) -._ 6,557.7 5,522.0 0.65 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 - -: 6,607.7 5,572.1 0.74 Screen Baker Screen Excluder 2000 3.430 Excluder 9u"t.Ge, 2+9,fa2� ..- _..J _ ...1..... 6,698.6 5,662.9 0.90 SBR Seal Bore Receptacle 3.250 ._ ,: Nrasix- aa , 6,701.4 5,665.7 0.91 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 s41,50 I s�e i e �. 6,751.3 5,715.6 0.61 Screen Baker Screen Excluder2000 3.430 40.1.401 F Excluder s""s' 6,771.1 5,735.4 0.56 SCREEN Bakerweld Screen 10 ga. 4" 11 #SLHT P -110 3.430 rryN..Q��= 6,790.9 5,755.2 0.52 Screen Baker Screen Excluder 2000 3.430 sc .. n=12, --- -- '- - Excluder ON SBA Henn 4,537 6,862.2 5,826.5 0.36 SBR -. Seal Bore Receptacle 3.250 aBNTUa 10..0 __ __... ec µ 4sa cc 6,864.9 5,829.2 0.36 SCREEN BakerweB Screen 10 ga. 4" 11# SLHT P -110 3.430 suw 4asa 122= R 1 6,914.9 5,879.2 0.14 Screen Baker Screen Excluder 2000 3.430 aE ju - _ __ R # - Excluder e " sm - CRRee R S 6,954.3 5,918.6 0.16 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P -110 3.430 » "...» Ili 6,993.7 5,958.0 0.19 Screen Baker Screen Excluder 2000 3.430 scNC' a Excluder �� a'T -�_ ♦. ■ 7,013.5 5,977.8 0.12 SCREEN Bakerweld Screen 10 ga. 4" 11# SLHT P-110 3.430 L ' = PACK= 7,063.5 6,027.8 0.211 Screen Baker Screen Excluder 2000 3.430 s�0 Excluder M1,9. i,,,aa 7,083.3 6,047.6 0.24 SCREEN Bakerweld Screen 10 ga. 4" 11 #SLHT P -110 3.430 - ^',� _ 7,213.6 6,177.9 0.42 Screen Baker Screen Excluder 200 3.430 - scuesp., ��'� 0 Excluder 'Tccae si:i N 6 A • tom: _ __. _.� _. - W _ so- ".s,waza2_� -�„ 7,254.0 0218.3 0.41 SEAL Seal Unit 82 -40 NINIe 3.250 \\ z9 �+ 7,261.6 6,225.9 0 41 Mule Shoe Mule Shoe 3.250 i Tubing Strings a e� - I T ban Description 'String 0... String ID ... Top (ftKB) Set Depth (f... Depth (TVD) ... ing Wt.. String String Top Thrd as + - Sump Packer 5 54 I 4.930 I 7,254.0 I 7,276 2 I Set D Str 6.2405 I 23.00 I L-80 SLHT E e `' - =' Completion Details Mk Top Depth s., »o ap,uapr7 (WD) Top Mot cer s ass To B (ftKB) ( Nam Description _ _ Comment ID (in) • s„»" 50,5015 a t, 7,254.0 6,218.3 041 PACKER Baker Model FS Sump Packer Size 85-40 4.000 � "ai ".sin. •,. _ - .._.....- ..._._. sr " rzsszas :: 7,256.0 6,220.3 0.41 Blast Joint Blast Join 4000 1°`csv ' iii: . 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SEAL 'AV, 7,211 V c g Li. 4 1 I 1 r oe; iga7 7F. 7111 - t - , SAK • BRU 211 -26 CP c co ps -- s`' r x — _ KB-Grd .5 Rig Release Date I bVeO Canfig: DEV,ATED BRU 211 26,12/30/200 5 3 00.01 PM _._ 16.52 9/27/2008 ScnemaOC Actua x.xoes 13 - Perforations Shot Top (TVD) Btm (TVD( D s cowucraz, 7334 ?' Top Ban (ftKB) (ftKB) ( ftKB ) Zone Date (sh . 1p Comment 1.41114,433 ,.(ft �.. s 6,077.0 6,089.0 5,041A 5,053.4 9/82008 14.0 Screen 6,126.0 6,141.0 5,090.4 5,105.4 9/8/2008 14.0 Screen suvace.31dmx — , -- II 6,154.0 6,165.0 5,118.4 5,129.4 9/8/2008 -�- 140 Screen S .4. u,2 -- 6,254.0 6,281.0 5,218.3 5,245.3 9/8/2008 n 008 14 0 Screen NIPPLE .1 u IIIP 6,372.0 6,383.0 5,336.3 5,347.3 9/82008 140 Screen WNW 442.3 �»� �. .._. v u73�_ 6,399.0 6,417.0 5,363 3 5,381.3 9/82008 14 0 Screen SeP U E Hoot F' 0 S 6,478.0 6,488.0 5,442.3 5,452.3 9/8/2008 14.creen . K:.5 a5 s ,.- r- :� rv. ex W nu33 __ - -,,, 6,538.0 6,548.0 5,502.3 5,512.3 9/82008 14.0 Screen 422 - x4wn 6,625.0 6,678.0 5,589.3 5,642.3 9/8/2008 14.0 Screen .5x. _. "axa.5x7 6,629.0 6,649.0 5,593.3 5,613.3 9/52008 6.0 Screen ""'43'4 6,655.0 6,675.0 5,619.3 5,639.3 9/5/2008 6.0 Screen s`"s4a4erv..bb3L _ l 6 6 5,718.3 5,732.3 9/8/2008 - 14.0 Screen so «n bnan2 R - xaeex,.373— ... x .4,7 .,.3 R 6,795.0 6,815.0 5,759.3 5,779.3 9/4/2008 6.0 Screen x34e...,7x3 6,795.0 6,848.0 5,759.3 5,812.3 9/8/2008 14.0 Screen SCNeeµ.7.3 ■ ...AM I. � 6,930.0 6,945.0 5,894.3 5,909.3 9/8/2008 14.0 Screen 3 C • 33, - - - -- � 6,998.0 7,007.0 5,962.3 5,971.3 9/8/2008 ---.-- 14 0 Screen 3axw.;;.'t -... _ r=`� 6,999.0 7,008.0 5,963.3 5,972.3 9/2/2008 6.0 Screen � 43"]„- 7,065.0 7,073.0 6,029.3 6,037.3 -- 9/8/2008 14.0 v Screen Vi a.. ....J.— i 7,231.0 7,241.0 6,195.3 6,205.3 9/1/2008 60 3e3.33w— _. i s sot »n 434.333 0 x «naaex =: Notes: 7,233. 7 244 6,197 -3 6,208.3 9/8/2008 14 0 Screen C1 HeN 3 1 3 a ► Genera & Safety "74%' ,, ` ,;, 2 : , , :'- - 4 �� Y _ t —__ Z, «n s,W3Rax �. n a Annotation i4 : 12/30/2008 NOTE: View Schematic w /Alaska Schematic9 -0 • $63� � .. 12/30/2008 NOTE: To view Gravel Packers, Iso String, etc, click on that TBG Section z - 333 sea. 3o3 :: ii,. i...,,. SEAL c"7147.44/34 it:- _... SW, Sat Sax, _.:--- S S G ., 3333 ; _- 1 s � j s,.bsty an. 1 ]3 4.2040.4733 _.. - 41 tie m.,43m . 3x9 - -_ -.. - .. S:a4eN COO , S SCe4440 bp4 1' Snow. d 1.83.1 -. .. Sono uw, d 1 I aas 1 1 1 • 3 a� I 3336,] t l li 3008.x• "8 " ' x343",6444 - Sw � n AGY e k � -\ `'t C' nhkere.dSxd� -- -, � Sr.MdF.dN3 2 " Sr _ -... ' `. eo..ndbssdn - iL SBrt. ab33 - -- SCREEN 3.701 e •.'�. 0.n, VW 3a »n a]33aaw .d2 ! x,4335 _ nx 4333,,,V 33..^1» 34 r r Pds]A 63+ri 7337 a - EzZita 3......734, v -_____ F - i 3 n6aR 734. " _' � vengixL. l i .. Ken Sqe. 7,237 744 • G. C. Alvord Kuparuk Drilling Team Leader Drilling & Wells P. Bag 100360 Anchorage, AK AK 99510 -0360 • ConocoP l i ps Phone. 907 - 265 -6120 October 30, 2008 Commissioner .. State of Alaska Alaska Oil & Gas Conservation Commission t. f i 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 I Subject: Well Completion Report for BRU 211 -26 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Beluga River well BRU 211 -26. If you have any questions regarding this matter, please contact me at 265 -6120. Sincerely, 4,6 .0<- G. C. Alvord Kuparuk Drilling Team Leader CPAI Drilling GCA/skad Rs :, • STATE OF ALASKA • ,!C T 3 i 200 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '' la. Well Status: Oil ❑ Gas U Plugged ❑ Abandoned ❑ Suspended ❑ lb. Wet Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: September 27, 2008 ' 208 - 112 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 4, 2008 • 50 283 - 20128 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 625' FSL, 2570' FWL, Sec. 23, T13N, R1OW, SM • August 16, 2008 BRU 211 - 26 • Top of Productive Horizon: 8. KB (ft above MSL): 91.5' RKB , 15. Field /Pool(s): 538' FNL, 690' FWL, Sec. 26, T13N, R10W, SM Ground (ft MSL): 75' AMSL , Be uga River Field Total Depth: 9. Plug Back Depth (MD + N i, D): _ j ,4 �t � .44,- lb (f . At 690' FNL, 568' FWL, Sec. 26, T13N, R10W, SM 7400' MD / 6273' TVD / ,` Sterling - Beluga Gas Pool • 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. Total Depth (MD + ND): 16. Property Designation: Surface: x 320588 • y 2631019 • Zone 4 . 7786' MD / 6750' TVD • ADL 21127 TPI: x - 318691 y - 2629886 Zone 4 11. SSSV Depth (MD + ND): 17. Land Use Permit Total Depth: x 318568 • y 2629735 - Zone 4 504' MD / 504' ND NA 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (ND): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, Dipole, USIT, CCL, Neutron, Density, Formation Micro Imaging, MDT formation tester 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154.2# X -65 18' 104' 18' 104' na driven 9 -5/8" 40# L -80 18' 3592' 18' 2863' 12.25" 894 sx Light weight cmt 7" 26# L -80 18' 7776' 18' 6740' 8.75" 295 sx 10.5 ppg light weight cmt 23. Open to production or injection? Yes El No ❑ If Yes, list each 24. TUBING RECORD Interval open (MD +ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 4484' 4482' 7231' -7241' MD 6195-6205' ND 6 spf 6999' - 7008' MD 5963' - 5972' ND 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6795 MD 5759' - 5779' ND 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6655' -6675' MD 5619' -5639' ND 6 spf 6655' -6675' 65000# proppant 6629' -6649' MD 5593' -5613' ND 6 spf 6795-6815' 47000# proppant refer to attachment for additional tubing conveyed perforations 6999' -7008' 16500# proppant 7231' -7241' 37000# proppant 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 19, 2008 Gas Production Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 10/19/2008 24 hours • Test Period - -> 0 3.4 2.5 bbls /hr not available I not applicable Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (con) press. psi 24 -Hour Rate -> 0 3.4 2.5 bbls /hr not applicable 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No , Sidewall Cores Acquired? Yes Q , No ❑ If Yes to either question, list formations and intervals cored (MD +ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. # COMPLETION DDT" TO BE SENT UNDER SEPARATE COVER f. 21 Form 10-407 Revised 2/2007 Z " CONTINUED ON REVERSE SIDE l /./g k ', 3D s BR. DEC 1 1 2008 ,1, %. ,e/i.9 G � • - 28. GEOLOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes IS No . If yes, list intervals and formations tested, Permafrost - Top not applicable not applicable briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom not applicable not applicable needed, and submit detailed test information per 20 AAC 25.071. Sterling A 3992' 3122' Sterling B 4247' 3302' Sterling C 4436' 3450' Beluga D 4610' 3600' Beluga E 4888' 3859' Beluga F 5254' 4219' Beluga G 5765' 4729' Beluga H 6108' 5072' Beluga I 6867' 5831' Beluga I Base 7341' 6305' N/A Formation at total depth: Beluga ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, perforation list 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: r Johnson 265 - 6081 Printed Name i Alvord Title: GKA Drilling Lead �, Date (C) r3. Signature Phone 2 r , Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and • • BRU 211 -26 Perf Intervals Tubing Conveyed Perforating Run #1 Proposed Gravel Pack Interval Top Perf to bottom Interval Top, MD Bot, MD Net ft, MD pert I 7233 7244 11 I 7065 7073 8 I 6998 7007 9 I 6930 6945 15 I 6795 6848 53 H 6754 6768 14 H 6625 6678 53 H 6538 6548 10 1276 H 6478 6488 10 H 6399 6417 18 H 6372 6383 11 H 6254 6281 27 H 6154 6165 11 H 15 G 6077 6089 12 G 6008 6037 29 G FQPR Fg76 ti Total 314 Tubing Conveyed Perforating Run #2 G 5723 5763 40 153 G 5680 5685 5 G 5610 5617 7 G 5287 5298 11 F 5235 5245 10 F 5215 5228 13 F 5190 5202 12 F 5110 5122 12 244 F 5082 5097 15 F 5054 5062 8 F 4950 4955 5 E 4915 4932 17 E 4852 4868 16 D 4802 4824 22 338 D 4775 4782 7 D 4732 4742 10 D 4683 4712 29 D 4617 4656 39 Total 278 Grand Total 592 i 0 1 I i E ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 211 -26 50- 283 - 20128 -00 ii , „ Sperry Drilling Services Definitive Survey Report I 25 August, 2008 I ii 111 E ii i P :,",.1 1 f HALUBURTON I :!: : ! :'i!!: I ' Sperry Drilling Services 1 ii • • ConocoPhillips or its affiliates Definitive Survey Report �w Company` ConocoPhillips(Alaska) Inc. - 'LOcalCo rdlnateReference :: Well BRU 211 -26 Project Beluga River ND Reference; ' v. BRU 211 -26 @ 91.52ft (Nabors 129) S) i Beluga River " Reference BRU 211 -26 @ 91.52ft (Nabors 129) Welt: BRU 211-26 "NOrtII'Rainnt:e ?; �£ True Wellper* BRU 211 -26 Surer Calculaflo Ml1d Minimum Curvature D esign 'ea E :? BRU 211 -26 P��h EDM Alaska Prod v16 .: , ' •p E 0 111,; g r I t d . £ 'k-,:-- zg- ''''''-",,,,z,, :.(, N��g� 1111D, Inc Azi ND TV' �� +N!$ 4E1'W t� E EE 01- r ,: Oi (,pi /p . ,.E p {{� ,O i ,,„ E ,,,111 ,x ` .. i" ? «, E.I ,, _ � it�. I , - -mt iix t t 8 t 'i - . n E , � � VY1 N N! ! !1i< �x _ , 1,241.55 14.13 290.53 1,234.97 1,143.45 60.94 -42.62 2,631,080.59 320,546.33 1.36 -4.43 MWD +SCC +SAG (1) 1,340.57 15.86 293.31 1,330.62 1,239.10 70.54 -66.37 2,631,090.55 320,522.73 1.89 8.23 MWD +SCC +SAG (1) 1,434.97 18.81 290.32 1,420.72 1,329.20 80.93 -92.50 2,631,101.35 320,496.78 3.26 22.25 MWD +SCC +SAG (1) 1,524.60 22.15 283.97 1,504.68 1,413.16 90.03 - 122.46 2,631,110.91 320,466.96 4.48 40.08 MWD+SCC +SAG (1) 1,624.53 29.32 275.92 1,594.67 1,503.15 97.11 - 165.14 2,631,118.66 320,424.40 7.96 69.14 MWD +SCC +SAG (1) 1,675.01 32.28 274.04 1,638.03 1,546.51 99.34 - 190.89 2,631,121.28 320,398.69 6.18 87.94 MWD +SCC +SAG (1) 1,720.13 33.44 272.71 1,675.93 1,584.41 100.78 - 215.33 2,631,123.10 320,374.28 3.02 106.20 MWD +SCC +SAG (1) 1,816.96 35.45 268.35 1,755.79 1,664.27 101.23 - 270.06 2,631,124.41 320,319.57 3.29 148.82 MWD +SCC +SAG(1) 1,912.82 40.32 257.64 1,831.51 1,739.99 93.78 - 328.23 2,631,117.86 320,261.29 8.52 199.05 MWD +SCC +SAG (1) 1,961.19 43.04 252.62 1,867.64 1,776.12 85.49 - 359.29 2,631,110.06 320,230.11 8.90 228.54 MWD +SCC +SAG (1) 2,006.89 46.10 250.62 1,900.20 1,808.68 75.37 - 389.71 2,631,100.41 320,199.53 7.36 258.67 MWD +SCC +SAG (1) 2,051.91 47.87 249.49 1,930.91 1,839.39 64.13 -420.65 2,631,089.66 320,168.42 4.33 289.90 MWD +SCC +SAG (1) 2,103.18 48.80 247.84 1,964.99 1,873.47 50.20 -456.32 2,631,076.28 320,132.54 3.01 326.52 MWD +SCC +SAG(1) 2,152.43 49.84 245.96 1,997.09 1,905.57 35.54 - 490.67 2,631,062.16 320,097.97 3.58 362.54 MWD +SCC +SAG (1) 2,199.85 52.36 243.00 2,026.87 1,935.35 19.63 - 523.96 2,631,046.77 320,064.44 7.20 398.52 MWD +SCC +SAG (1) 2,249.25 54.58 240.62 2,056.28 1,964.76 0.87 - 558.94 2,631,028.56 320,029.18 5.93 437.58 MWD +SCC +SAG (1) 2,293.41 54.81 238.24 2,081.80 1,990.28 -17.46 - 589.96 2,631,010.72 319,997.87 4.43 473.28 MWD +SCC +SAG(1) 2,346.99 55.18 235.30 2,112.54 2,021.02 - 41.51 - 626.67 2,630,987.24 319,960.80 4.54 516.98 MWD +SCC +SAG(1) 2,390.27 56.33 231.72 2,136.90 2,045.38 -62.78 - 655.42 2,630,966.42 319,931.73 7.33 552.73 MWD +SCC +SAG (1) 2,437.70 56.24 229.33 2,163.23 2,071.71 - 87.86 - 685.87 2,630,941.82 319,900.89 4.21 592.17 MWD +SCC +SAG (1) 2,485.90 54.54 225.52 2,190.62 2,099.10 - 114.68 - 715.08 2,630,915.46 319,871.27 7.39 631.72 MWD +SCC +SAG (1) 2,534.05 52.91 223.38 2,219.11 2,127.59 - 142.38 - 742.26 2,630,888.19 319,843.66 4.92 670.23 MWD +SCC +SAG (1) 2,582.60 52.77 223.06 2,248.43 2,156.91 - 170.58 - 768.76 2,630,860.41 319,816.73 0.59 708.51 MWD +SCC +SAG (1) 2,678.44 52.88 224.96 2,306.35 2,214.83 - 225.49 - 821.82 2,630,806.33 319,762.82 1.58 784.20 MWD +SCC +SAG (1) 2,774.47 53.61 226.87 2,363.81 2,272.29 - 279.01 - 877.08 2,630,753.68 319,706.74 1.76 860.75 MWD +SCC +SAG (1) 2,864.40 54.36 227.53 2,416.69 2,325.17 - 328.43 - 930.46 2,630,705.09 319,652.60 1.03 93328 MWD +SCC +SAG (1) 2,965.37 53.19 225.52 2,476.36 2,384.84 - 384.46 - 989.57 2,630,650.00 319,592.63 1.98 1,014.40 MWD +SCC +SAG (1) 3,058.01 52.30 226.21 2,532.45 2,440.93 - 435.80 - 1,042.49 2,630,599.49 319,538.92 1.13 1,087.76 MWD +SCC +SAG(1) 3,149.27 52.38 226.79 2,588.20 2,496.68 - 485.53 - 1,094.90 2,630,550.59 319,485.75 0.51 1,159.72 MWD +SCC +SAG (1) 3,248.58 51.98 227.97 2,649.10 2,557.58 - 538.65 - 1,152.63 2,630,498.38 319,427.21 1.02 1,237.96 MWD +SCC +SAG (1) 3,341.60 51.24 227.96 2,706.86 2,615.34 - 587.46 - 1,206.78 2,630,450.41 319,372.30 0.80 1,310.72 MWD +SCC +SAG (1) 3,437.05 51.60 228.42 2,766.39 2,674.87 - 637.20 - 1,262.40 2,630,401.55 319,315.92 0.53 1,385.20 MWD +SCC +SAG(1) 3,534.64 51.37 229.90 2,827.16 2,735.64 - 687.13 - 1,320.16 2,630,352.52 319,257.39 1.21 1,461.48 MWD +SCC +SAG (1) 3,551.98 51.48 230.12 2,837.98 2,746.46 - 695.85 - 1,330.55 2,630,343.97 319,246.87 1.21 1,475.03 MWD +SCC +SAG (1) 3,632.30 51.09 230.70 2,888.21 2,796.69 - 735.79 - 1,378.85 2,630,304.79 319,197.96 0.75 1,537.69 MWD +SCC +SAG (1) 3,656.27 51.19 230.53 2,903.25 2,811.73 - 747.63 - 1,393.27 2,630,293.18 319,183.36 0.69 1,556.35 MWD +SCC +SAG (1) 3,750.95 50.26 230.86 2,963.18 2,871.66 - 794.06 - 1,449.99 2,630,247.64 319,125.93 1.02 1,629.64 MWD +SCC +SAG(1) 3,847.29 48.85 232.03 3,025.68 2,934.16 - 839.76 - 1,507.32 2,630,202.84 319,067.90 1.73 1,702.95 MWD +SCC +SAG (1) 3,942.99 48.02 231.07 3,089.17 2,997.65 - 884.28 - 1,563.39 2,630,159.20 319,011.14 1.15 1,774.56 MWD +SCC +SAG (1) 4,033.47 47.01 230.87 3,150.28 3,058.76 - 926.30 - 1,615.23 2,630,118.00 318,958.66 1.13 1,841.28 MWD +SCC +SAG(1) 8/25/2008 1:21:52PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates Definitive Survey Report ... Company: , ?A ,; ConocoPhillips(Alaska) Inc. Local Co-nrdh1at nce. Wet BRU 211 -26 R i €E i Beluga River TVD Refer ,, z BRU 211 -26 @ 91.52ft (Nabors 129) j EI€ € E Beluga River MD_Ref h ` BRU 211 -26 © 91.52ft (Nabors 129) �I € E We l � , ` N E BRU 211 -26 North Reference: ,<<E; `True We ibore BRU 211 -26 ; $nrueg Calculation Method. A E ••• Minimum Curvature Design: BRU 211 -26 Database: EDM Alaska Prod vl6 Survey z c' € Map :? Map el'$ tai �f E IilC i,`11 /1r1 1 t TVDSS +N/S + �Not'thing Easttng �» , DL SS Secti L[ $ roil"` aY ( E P`) - '' Yt} „= E r 1 ,,E €F - _ t W �{{ ( (It) ' S, .. trey TOOL Name i's-j;,:,-:'2! iv Z L 4,132.45 45.13 231.06 3,218.94 3,127.42 - 971.19 - 1,670.60 2,630,073.97 318,902.60 1.91 1,912.56 M■D +SCC +SAG (1) 4,228.72 43.66 230.65 3,287.73 3,19621 - 1,013.70 - 1,722.84 2,630,032.28 318,849.71 1.56 1,979.90 MWD +SCC +SAG(1) 4,324.05 38.49 229.51 3,359.57 3,268.05 - 1,053.86 - 1,770.88 2,629,992.88 318,801.05 5.48 2,042.50 MWD +SCC +SAG (1) 4,376.29 36.87 226.40 3,400.91 3,309.39 - 1,075.22 - 1,794.60 2,629,971.89 318,777.01 4.79 2,074.35 MWD +SCC +SAG (1) 4,422.20 35.14 225.45 3,438.05 3,346.53 - 1,093.99 - 1,813.99 2,629,953.43 318,757.33 3.96 2,101.21 MWD +SCC +SAG (1) 4,469.53 32.26 224.53 3,477.43 3,385.91 - 1,112.55 - 1,832.56 2,629,935.15 318,738.47 6.17 2,127.29 MWD +SCC +SAG (1) 4,518.48 30.32 222.50 3,519.25 3,427.73 - 1,130.98 - 1,850.07 2,629,917.00 318,720.68 4.51 2,152.46 MWD +SCC +SAG (1) 4,615.45 25.39 219.40 3,604.97 3,513.45 - 1,165.11 - 1,879.82 2,629,883.34 318,690.40 5.30 2,196.97 MWD +SCC +SAG (1) 4,666.54 23.92 218.12 3,651.40 3,559.88 - 1,181.73 - 1,893.17 2,629,866.93 318,676.80 3.06 2,217.75 MWD +SCC +SAG (1) I I I 4,711.71 22.33 217.95 3,692.94 3,601.42 - 1,195.70 - 1,904.10 2,629,853.13 318,665.65 3.52 2,235.00 MWD +SCC +SAG (1) 4,806.11 18.90 217.52 3,781.28 3,689.76 - 1,221.98 - 1,924.45 2,629,827.18 318,644.90 3.64 2,267.27 MWD +SCC +SAG (1) 4,901.12 15.63 215.66 3,871.99 3,780.47 - 1,244.59 - 1,941.28 2,629,804.83 318,627.71 3.50 2,294.50 MWD +SCC +SAG (1) 4,996.81 12.60 217.61 3,964.78 3,873.26 - 1,263.34 - 1,955.17 2,629,786.30 318,613.54 3.20 2,317.03 MWD +SCC +SAG(1) 5,092.81 9.77 219.97 4,058.95 3,967.43 - 1,277.88 - 1,966.80 2,629,771.95 318,601.69 2.99 2,335.17 MWD +SCC +SAG (1) 5,188.81 7.25 231.10 4,153.89 4,062.37 - 1,287.93 - 1,976.75 2,629,762.05 318,591.58 3.12 2,349.21 MWD +SCC +SAG (1) 5,280.75 4.65 244.24 4,245.33 4,153.81 - 1,293.19 - 1,984.62 2,629,756.91 318,583.63 3.18 2,358.65 MWD +SCC +SAG (1) 5,377.79 2.73 198.56 4,342.19 4,250.67 - 1,297.09 - 1,988.90 2,629,753.08 318,579.29 3.47 2,364.42 MWD +SCC +SAG (1) 5,467.42 0.65 146.74 4,431.78 4,340.26 - 1,299.54 - 1,989.30 2,629,750.64 318,578.86 2.66 2,366.25 MWD +SCC +SAG (1) 5,568.04 0.54 148.56 4,532.39 4,440.87 - 1,300.42 - 1,988.73 2,629,749.75 318,579.40 0.11 2,366.36 MWD +SCC +SAG (1) 5,672.10 0.53 146.59 4,636.45 4,544.93 - 1,301.25 - 1,988.21 2,629,748.92 318,579.92 0.02 2,366.46 MWD +SCC +SAG (1) 5,758.74 0.48 173.25 4,723.08 4,631.56 - 1,301.94 - 1,987.94 2,629,748.22 318,580.17 0.28 2,366.69 MWD +SCC +SAG(1) 5,851.40 0.45 163.30 4,815.74 4,724.22 - 1,302.67 - 1,987.79 2,629,747.48 318,580.31 0.09 2,367.03 MWD +SCC +SAG (1) 5,948.15 0.38 155.15 4,912.49 4,820.97 - 1,303.33 - 1,987.55 2,629,746.82 318,580.54 0.09 2,36724 MWD +SCC +SAG (1) 6,044.74 0.36 183.44 5,009.08 4,917.56 - 1,303.93 - 1,987.43 2,629,746.22 318,580.65 0.19 2,367.52 MWD +SCC +SAG (1) 6,139.91 0.46 179.66 5,104.24 5,012.72 - 1,304.61 - 1,987.45 2,629,745.55 318,580.62 0.10 2,367.95 MWD +SCC +SAG (1) 6,232.66 0.52 214.54 5,196.99 5,105.47 - 1,305.32 - 1,987.68 2,629,744.83 318,580.38 0.32 2,368.58 MWD +SCC +SAG (1) 6,329.55 0.31 219.03 5,293.88 5,202.36 - 1,305.89 - 1,988.10 2,629,744.27 318,579.95 0.21 2,369.26 MWD +SCC +SAG (1) 6,423.10 0.44 201.81 5,387.43 5,295.91 - 1,306.42 - 1,988.40 2,629,743.75 318,579.65 0.18 2,369.82 MWD +SCC +SAG (1) 6,517.61 0.54 213.70 5,481.93 5,390.41 - 1,307.12 - 1,988.78 2,629,743.05 318,579.26 0.15 2,370.56 MWD +SCC +SAG (1) 6,613.58 0.75 222.21 5,577.90 5,486.38 - 1,307.96 - 1,989.45 2,629,742.22 318,578.58 0.24 2,371.60 MWD +SCC +SAG (1) 6,708.64 0.92 220.71 5,672.95 5,581.43 - 1,309.00 - 1,990.36 2,629,741.20 318,577.65 0.18 2,372.96 MWD +SCC +SAG (1) 6,803.97 0.49 220.21 5,768.27 5,676.75 - 1,309.89 - 1,991.12 2,629,740.32 318,576.87 0.45 2,374.12 MWD +SCC +SAG (1) 6,89924 0.28 221.87 5,863.54 5,772.02 - 1,310.37 - 1,991.54 2,629,739.84 318,576.44 0.22 2,374.74 MWD +SCC +SAG(1)I 6,994.17 0.18 247.31 5,958.47 5,866.95 - 1,310.60 - 1,991.83 2,629,739.62 318,576.15 0.14 2,375.12 MWD +SCC +SAG (1) 7,088.86 0.25 234.86 6,053.16 5,961.64 - 1,310.78 - 1,992.15 2,629,739.44 318,575.83 0.09 2,375.47 MWD +SCC +SAG (1) 7,185.96 0.41 232.36 6,150.25 6,058.73 - 1,311.12 - 1,992.60 2,629,739.11 318,575.37 0.17 2,376.04 MWD +SCC +SAG(1) 7,281.07 0.41 254.34 6,245.36 6,153.84 - 1,311.42 - 1,993.20 2,629,738.82 318,574.77 0.17 2,376.70 MWD +SCC +SAG (1) 7,375.47 0.63 237.85 6,339.76 6,248.24 - 1,311.79 - 1,993.97 2,629,738.46 318,573.99 0.28 2,377.53 MWD +SCC +SAG (1) 7,472.17 0.70 238.43 6,436.45 6,344.93 - 1,312.38 - 1,994.92 2,629,737.89 318,573.03 0.07 2,378.64 MWD +SCC +SAG(1) l i 7,567.33 0.80 231.64 6,531.60 6,440.08 - 1,313.10 - 1,995.94 2,629,737.19 318,572.01 0.14 2,379.88 MWD +SCC +SAG (1) 8/25/2008 1:21:52PM Page 4 COMPASS 2003.16 Build 42F S ConocoPhillips or its affiliates Definitive Survey Report Compan*Fmlyet j ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference ; Well BRU 211 - Project Beluga River TvO Reference: ,l,' BRU 211 -26 @ 91.52ft (Nabors 129) Site ? Beluga River MD Reference BRU 211 - @ 91.52ft (Nabors 129) 4Ve i BRU 211 -26 i brtrt Reference True Welit E E BRU 211 -26 Sunrey�aicalaltrinijkljpeod Minimum Curvature Design: BRU 211 - 26 f EDM Alaska Prod v16 �� Survey � tt � R IS (EE E E E EI I AEI E E Map Map Vertical z Ma Inc *zi WD Ci� ` Ef Yfi Nort ing Ed tlll DLS Settle» E St y Tt1oi t 1m 7,661.42 1.16 242.05 6,625.68 6,534.16 - 1,313.95 - 1,997.29 2,629,736.35 318,570.64 0.42 2,381.47 MWD +SCC +SAG(1) 7,704.27 1.16 241.23 6,668.52 6,577.00 - 1,314.36 - 1,998.05 2,629,735.95 318,569.87 0.04 2,382.33 MWD +SCC +SAG(1) 7,786.00 1.16 241.23 6,750.23 • 6,658.71 - 1,315.16 - 1,999.50 2,629,735.18 318,568.41 0.00 2,383.95 PROJECTED to TD 8/25/2008 1:21:52PM Page 5 COMPASS 2003.16 Build 42F • A 45 4 A 0 0 e ConocoPhillips (Alaska) Inc. -Expi Beluga River Beluga River � a BRU 211 -26 50- 283 - 20128 -00 N14o8) Sperry Drilling Services Definitive Survey Report } 25 August, 2008 { y 0 10 10 0 0 0 �� N _ I HALLIBURTON Sperry Drilling Services • • ConocoPhillips or its affiliates . Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co- ordinate Reference: Well BRU 211 -26 Project: Beluga River TVD Reference: BRU 211 -26 © 91.52ft (Nabors 129) Site: ` Beluga River MD Reference: BRU 211 -26 @ 91.52ft (Nabors 129) Well: BRU 211 -26 North Reference: True Welibore: BRU 211 -26 Survey Calculation Method: Minimum Curvature Design; BRU 211 -26 Database: EDM Alaska Prod v16 Project Beluga River, Alaska, USA Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well BRU 211 -26 1 Well Position +N/-S 0.00 ft Northing: 2,630,779.41ft Latitude: 61° 11' 48.772 N! +E / -W 0.00 ft Easting: 1A60,615.32 ft Longitude: 151° 1' 9.515 W 1 Position Uncertainty 1.00 ft Wellhead Elevation: ft Ground Level: 75.00ft 1 � Wellhore BRU 211 -26 l j Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) (°) (nT) j BGGM2007 8/4/2008 19.06 73..99 55,691 � Design BRU 211 -26 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 16.52 1 Vertical Section: Depth From (TVD) +N/,S +El -W Direction (ft) ` (ft) (ft) ( 16.52 0.00 0.00 231.61 Survey Program Date 8125/2008 From To ((t) (ft) Survey (Wellbore) Tool Name Description Survey Date 116.50 7,704.27 BRU 211 -26 MWD +SCC +SAG (BRU 211 MWD +SCC +SAG MWD + Short Collar correction + BHA SAG Co 8/4/2008 12: Survey Map Map Ver MD Inc Azi TVD TVDSS +N /-S +El-W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft)` (ft) (ft) (ft) ( ° / 100`} (ft) S Tool Name 16.52 0.00 0.00 16.52 -75.00 0.00 0.00 2,630,779.41 1,460,615.32 0.00 0.00 UNDEFINED 116.50 0.28 192.70 116.50 24.98 -0.24 -0.05 2,630,779.17 1,460,615.26 028 0.19 MWD +SCC +SAG (1) 212.88 0.57 192.70 212.88 121.36 -0.93 -0.21 2,630,778.48 1,460,615.10 0.30 0.74 MWD +SCC +SAG (1) 311.32 0.15 171.53 311.31 219.79 -1.54 -0.30 2,630,777.87 1,460,615.00 0.43 1.19 MWD +SCC +SAG (1) 391.95 0.48 33.22 391.94 300.42 -1.37 -0.10 2,630,778.05 1,460,615.20 0.75 0.92 MWD +SCC +SAG (1) 1 490.80 1.30 31.34 490.78 399.26 -0.06 0.71 2,630,779.34 1,460,616.03 0.83 -0.52 MWD +SCC +SAG (1) 587.95 1.42 10.86 587.90 496.38 2.07 1.51 2,630,781.45 1,460,616.87 0.51 -2.47 MWD +SCC +SAG (1) 674.62 2.69 5.43 674.52 583.00 5.14 1.91 2,630,784.52 1,460,617.31 1.47 -4.69 MWD +SCC +SAG (1) 763.06 4.45 356.02 762.78 671.26 10.63 1.87 2,630,790.01 1,460,617.35 210 -8.07 MWD +SCC +SAG (1) 859.13 6.20 352.59 858.43 766.91 19.50 0.94 2,630,798.89 1,460,616.56 1.85 -12.85 MWD +SCC +SAG (1) 954.07 7.37 341.23 952.71 861.19 30.36 -1.68 2,630,809.79 1,460,614.11 1.87 -17.53 MWD +SCC +SAG (1) 1,049.84 8.88 323.09 1,047.53 956.01 42.09 -8.10 2,630,821.62 1,460,607.88 3.08 -19.79 MWD +SCC +SAG (1) 1,144.68 12.31 294.93 1,140.80 1,049.28 52.21 -21.68 2,630,831.95 1,460,594.46 6.45 -15.43 MWD +SCC +SAG (1) I 1,177.18 13.59 293.37 1,172.48 1,080.96 55.18 -28.32 2,630,835.03 1,460,587.86 4.08 -12.07 MWD +SCC +SAG (1) 8/25/2008 1 :00 :06PM Page 2 COMPASS 2003.16 Build 42F • • . ConocoPhillips or its affiliates . Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co- ordinate Reference: Well BRU 211 -26 Project: Beluga River TVD Reference: - BRU 211 -26 @ 91.52ft (Nabors 129) Site: Beluga River MD Reference: BRU 211 -26 @ 91.52ft (Nabors 129) Well: BRU 211 -26 North Reference: True Weilbore: BRU 211 -26 Survey Calculation Method: Minimum Curvature Design: BRU 211 -26 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +EI -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name 1,241.55 14.13 290.53 1,234.97 1,143.45 60.94 -42.62 2,630,841.00 1,460,573.65 1.36 -4.43 MWD +SCC +SAG(1) 1,340.57 15.86 293.31 1,330.62 1,239.10 70.54 -66.37 2,630,850.97 1,460,550.06 1.89 8.23 MWD +SC,C +SAG (1) 1 1,434.97 18.81 290.32 1,420.72 1,329.20 80.93 -92.50 2,630,861.76 1,460,524.10 3.26 22.25 MWD +SQC +SAG (1) 1 1,524.60 22.15 283.97 1,504.68 1,413.16 90.03 - 122.46 2,630,871.33 1,460,494.29 4.48 40.08 MWD +SCC +SAG (1) 1,624.53 29.32 275.92 1,594.67 1,503.15 97.11 - 165.14 2,630,879.08 1,460,451.72 7.96 69.14 MWD +SCC +SAG (1) 1,675.01 32.28 274.04 1,638.03 1,546.51 99.34 - 190.89 2,630,881.70 1,460,426.02 6.18 87.94 MWD +SCC +SAG (1) i 1,720.13 33.44 272.71 1,675.93 1,584.41 100.78 - 215.33 2,630,883.52 1,460,401.60 3.02 106.20 MWD +SC:C +SAG (1) 1,816.96 35.45 268.35 1,755.79 1,664.27 101.23 - 270.06 2,630,884.83 1,460,346.89 3.29 148.82 MWD +SCC +SAG (1) 1,912.82 40.32 257.64 1,831.51 1,739.99 93.78 - 328.23 2,630,878.28 1,460,288.61 8.52 199.05 MWD +SC. +SAG (1) 1,961.19 43.04 252.62 1,867.64 1,776.12 85.49 - 359.29 2,630,870.49 1,460,257.43 8.90 228.54 MWD +SCC +SAG (1) 2,006.89 46.10 250.62 1,900.20 1,808.68 75.37 - 389.71 2,630,860.84 1,460,226.85 7.36 258.67 MWD +SCrC +SAG (1) I 2,051.91 47.87 249.49 1,930.91 1,839.39 64.13 - 420.65 2,630,850.09 1,460,195.75 4.33 289.90 MWD +SCC +SAG (1) 2,103.18 48.80 247.84 1,964.99 1,873.47 50.20 - 456.32 2,630,836.71 1,460,159.86 3.01 326.52 MWD+SC:C +SAG (1) 2,152.43 49.84 245.96 1,997.09 1,905.57 35.54 - 490.67 2,630,822.59 1,460,125.29 3.58 362.54 MWD +SCC +SAG (1) 2,199.85 52.36 243.00 2,026.87 1,935.35 19.63 - 523.96 2,630,807.20 1,460,091.76 7.20 398.52 MWD +SCC +SAG (1) 2,249.25 54.58 240.62 2,056.28 1,964.76 0.87 - 558.94 2,630,788.99 1,460,056.50 5.93 437.58 MWD +SCC +SAG (1) 2,293.41 54.81 238.24 2,081.80 1,990.28 -17.46 - 589.96 2,630,771.15 1,460,025.19 4.43 473.28 MWD +SCC +SAG (1) 1 2,346.99 55.18 235.30 2,112.54 2,021.02 -41.51 - 626.67 2,630,747.68 1,459,988.12 4.54 516.98 MWD +SCC +SAG (1) 2,390.27 56.33 231.72 2,136.90 2,045.38 -62.78 - 655.42 2,630,726.86 1,459,959.05 7.33 552.73 MWD +SCC +SAG (1) 2,437.70 56.24 229.33 2,163.23 2,071.71 - 87.86 - 685.87 2,630,702.26 1,459,928.21 4.21 592.17 MWD +SCC +SAG (1) 1 2,485.90 54.54 225.52 2,190.62 2,099.10 - 114.68 - 715.08 2,630,675.90 1,459,898.59 7.39 631.72 MWD +SCC +SAG (1) 2,534.05 52.91 223.38 2,219.11 2,127.59 - 142.38 - 742.26 2,630,648.63 1,459,870.98 4.92 670.23 MWD +SCC +SAG (1) 2,582.60 52.77 223.06 2,248.43 2,156.91 - 170.58 - 768.76 2,630,620.85 1,459,844.04 0.59 708.51 MWD +SCC +SAG(1) I 2,678.44 52.88 224.96 2,306.35 2,214.83 - 225.49 - 821.82 2,630,566.77 1,459,790.14 1.58 784.20 MWD +SCC +SAG (1) 2,774.47 53.61 226.87 2,363.81 2,272.29 - 279.01 - 877.08 2,630,514.12 1,459,734.05 1.76 860.75 MWD +SCC +SAG (1) 1 2,864.40 54.36 227.53 2,416.69 2,325.17 - 328.43 - 930.46 2,630,465.54 1,459,679.91 1.03 933.28 MWD +SCC +SAG(1) 2,965.37 53.19 225.52 2,476.36 2,384.84 - 384.46 - 989.57 2,630,410.45 1,459,619.94 1.98 1,014.40 MWD +SCC +SAG(1) 3,058.01 52.30 226.21 2,532.45 2,440.93 - 435.80 - 1,042.49 2,630,359.94 1,459,566.23 1.13 1,087.76 MWD +SCC +SAG (1) 1 3,149.27 52.38 226.79 2,588.20 2,496.68 - 485.53 - 1,094.90 2,630,311.04 1,459,513.05 0.51 1,159.72 MWD +SCC +SAG (1) 3,248.58 51.98 227.97 2,649.10 2,557.58 - 538.65 - 1,152.63 2,630,258.83 1,459,454.51 1.02 1,237.96 MWD +SCC +SAG (1) 3,341.60 51.24 227.96 2,706.86 2,615.34 - 587.46 - 1,206.78 2,630,210.87 1,459,399.60 0.80 1,310.72 MWD +SCC +SAG (1) 1 3,437.05 51.60 228.42 2,766.39 2,674.87 - 637.20 - 1,262.40 2,630,162.00 1,459,343.22 0.53 1,385.20 MWD +SCC +SAG(1) 1 3,534.64 51.37 229.90 2,827.16 2,735.64 - 687.13 - 1,320.16 2,630,112.98 1,459,284.69 1.21 1,461.48 MWD +SCC +SAG(1) 3,551.98 51.48 230.12 2,837.98 2,746.46 - 695.85 - 1,330.55 2,630,104.43 1,459,274.17 1.21 1,475.03 MWD +SCC +SAG(1) 3,632.30 51.09 230.70 2,888.21 2,796.69 - 735.79 - 1,378.85 2,630,065.25 1,459,225.26 0.75 1,537.69 MWD +SCC +SAG(1) , 3,656.27 51.19 230.53 2,903.25 2,811.73 - 747.63 - 1,393.27 2,630,053.64 1,459,210.65 0.69 1,556.35 MWD +SCC +SAG (1) ■ 3,750.95 50.26 230.86 2,963.18 2,871.66 - 794.06 - 1,449.99 2,630,008.10 1,459,153.22 1.02 1,629.64 MWD +SCC +SAG (1) 3,847.29 48.85 232.03 3,025.68 2,934.16 - 839.76 - 1,507.32 2,629,963.31 1,459,095.19 1.73 1,702.95 MWD +SCC +SAG (1) 3,942.99 48.02 231.07 3,089.17 2,997.65 - 884.28 - 1,563.39 2,629,919.67 1,459,038.43 1.15 1,774.56 MWD +SCC +SAG (1) 4,033.47 47.01 230.87 3,150.28 3,058.76 - 926.30 - 1,615.23. 2,629,878.46 1,458,985.95 1.13 1,841.28 MWD +SCC +SAG (1) 8/25/2008 1:00 :06PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates • Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co- ordinate Reference: Well BRU 211 -26 Project: Beluga River TVD Reference:? BRU 211 -26 @ 91.52ft (Nabors 129) Site: Beluga River MD Referencec BRU 211 -26 © 91.52ft (Nabors 129) Well BRU 211 -26 North Reference: True Welibore: BRU 211 -26 Survey Calculation Method: Minimum Curvature Design: BRU 211 -26 Database: EDM Alaska Prod v16 1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/.W Northing Fasting' DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100`) (ft) Survey Toot Name 4,132.45 45.13 231.06 3,218.94 3,127.42 - 971.19 - 1,670.60 2,629,834.44 1,458,929.89 1.91 1,912.56 MWD +SCC +SAG (1) 4,228.72 43.66 230.65 3,287.73 3,196.21 - 1,013.70 - 1,722.84 2,629,792.75 1,458,877.00 1.56 1,979.90 MWD +SCC +SAG (1) 4,324.05 38.49 229.51 3,359.57 3,268.05 - 1,053.86 - 1,770.88 2,629,753.35 1,458,828.34 5.48 2,042.50 MWD +SCC +SAG (1) 4,376.29 36.87 226.40 3,400.91 3,309.39 - 1,075.22 - 1,794.60 2,629,732.36 1,458,804.29 4.79 2,074.35 MWD +SCC +SAG (1) 4,422.20 35.14 225.45 3,438.05 3,346.53 - 1,093.99 - 1,813.99 2,629,713.90 1,458,784.61 3.96 2,101.21 MWD +SCC +SAG(1) 4,469.53 32.26 224.53 3,477.43 3,385.91 - 1,112.55 - 1,832.56 2,629,695.63 1,458,765.76 6.17 2,127.29 MWD +SCC +SAG(1) 4,518.48 30.32 222.50 3,519.25 3,427.73 - 1,130.98 - 1,850.07 2,629,677.48 1,458,747.96 4.51 2,152.46 MWD +SCC +SAG (1) 4,615.45 25.39 219.40 3,604.97 3,513.45 - 1,165.11 - 1,879.82 2,629,643.81 1,458,717.68 5.30 2,196.97 MWD +SCC +SAG (1) 4,666.54 23.92 218.12 3,651.40 3,559.88 - 1,181.73 - 1,893.17 2,629,627.41 1,458,704.08 3.06 2,217.75 MWD +SCC +SAG (1) 4,711.71 22.33 217.95 3,692.94 3,601.42 - 1,195.70 - 1,904.10 2,629,613.61 1,458,692.93 3.52 2,235.00 MWD +SCC +SAG (1) 4,806.11 18.90 217.52 3,781.28 3,689.76 - 1,221.98 - 1,924.45 2,629,587.65 1,458,672.18 3.64 2,267.27 MWD +SCC +SAG (1) 4,901.12 15.63 215.66 3,871.99 3,780.47 - 1,244.59 - 1,941.28 2,629,565.31 1,458,654.99 3.50 2,294.50 MWD +SCC +SAG (1) 4,996.81 12.60 217.61 3,964.78 3,873.26 - 1,263.34 - 1,955.17 2,629,546.79 1,458,640.82 3.20 2,317.03 MWD +SCC +SAG (1) 5,092.81 9.77 219.97 4,058.95 3,967.43 - 1,277.88 - 1,966.80 2,629,532.43 1,458,628.97 2.99 2,335.17 MWD +SCC +SAG (1) 5,188.81 7.25 231.10 4,153.89 4,062.37 - 1,287.93 - 1,976.75 2,629,522.54 1,458,618.86 3.12 2,349.21 MWD +SCC +SAG (1) 5,280.75 4.65 244.24 4,245.33 4,153.81 - 1,293.19 - 1,984.62 2,629,517.40 1,458,610.91 3.18 2,358.65 MWD +SCC +SAG (1) 5,377.79 2.73 198.56 4,342.19 4,250.67 - 1,297.09 - 1,988.90 2,629,513.56 1,458,606.57 3.47 2,364.42 MWD +SCC +SAG (1) 5,467.42 0.65 146.74 4,431.78 4,340.26 - 1,299.54 - 1,989.30 2,629,511.12 1,458,606.13 2.66 2,366.25 MWD +SCC +SAG (1) 5,568.04 0.54 148.56 4,532.39 4,440.87 - 1,300.42 - 1,988.73 2,629,510.23 1,458,606.68 0.11 2,366.36 MWD +SCC +SAG (1) 5,672.10 0.53 146.59 4,636.45 4,544.93 - 1,301.25 - 1,988.21 2,629,509.40 1,458,607.19 0.02 2,366.46 MWD +SCC+SAG (1) 5,758.74 0.48 173.25 4,723.08 4,631.56 - 1,301.94 - 1,987.94 2,629,508.70 1,458,607.45 0.28 2,366.69 MWD +SCC +SAG (1) 5,851.40 0.45 163.30 4,815.74 4,724.22 - 1,302.67 - 1,987.79 2,629,507.96 1,458,607.59 0.09 2,367.03 MWD +SCC +SAG (1) 5,948.15 0.38 155.15 4,912.49 4,820.97 - 1,303.33 - 1,987.55 2,629,507.30 1,458,607.82 0.09 2,367.24 MWD +SCC +SAG (1) 6,044.74 0.36 183.44 5,009.08 4,917.56 - 1,303.93 - 1,987.43 2,629,506.70 1,458,607.93 0.19 2,367.52 MWD +SCC +SAG (1) 6,139.91 0.46 179.66 5,104.24 5,012.72 - 1,304.61 - 1,987.45 2,629,506.03 1,458,607.90 0.10 2,367.95 MWD +SCC +SAG (1) 6,232.66 0.52 214.54 5,196.99 5,105.47 - 1,305.32 - 1,987.68 2,629,505.32 1,458,607.65 0.32 2,368.58 MWD +SCC +SAG(1) 6,329.55 0.31 219.03 5,293.88 5,202.36 - 1,305.89 - 1,988.10 2,629,504.75 1,458,607.23 0.21 2,369.26 MWD+SCC+SAG (1) 6,423.10 0.44 201.81 5,387.43 5,295.91 - 1,306.42 - 1,988.40 2,629,504.23 1,458,606.93 0.18 2,369.82 MWD +SCC +SAG (1) 6,517.61 0.54 213.70 5,481.93 5,390.41 - 1,307.12 - 1,988.78 2,629,503.53 1,458,606.54 0.15 2,370.56 MWD +SCC +SAG (1) 6,613.58 0.75 222.21 5,577.90 5,486.38 - 1,307.96 - 1,989.45 2,629,502.70 1,458,605.85 0.24 2,371.60 MWD +SCC +SAG (1) 6,708.64 0.92 220.71 5,672.95 5,581.43 - 1,309.00 - 1,990.36 2,629,501.68 1,458,604.92 0.18 2,372.96 MWD +SCC +SAG (1) 6,803.97 0.49 220.21 5,768.27 5,676.75 - 1,309.89 - 1,991.12 2,629,500.80 1,458,604.15 0.45 2,374.12 MWD +SCC +SAG (1) 6,899.24 0.28 221.87 5,863.54 5,772.02 - 1,310.37 - 1,991.54 2,629,500.32 1,458,603.72 0.22 2,374.74 MWD +SCC +SAG (1) 6,994.17 0.18 247.31 5,958.47 5,866.95 - 1,310.60 - 1,991.83 2,629,500.10 1,458,603.42 0.14 2,375.12 MWD +SCC +SAG (1) 7,088.86 0.25 234.86 6,053.16 5,961.64 - 1,310.78 - 1,992.15 2,629,499.92 1,458,603.11 0.09 2,375.47 MWD +SCC +SAG (1) 7,185.96 0.41 232.36 6,150.25 6,058.73 - 1,311.12 - 1,992.60 2,629,499.59 1,458,602.65 0.17 2,376.04 MWD +SCC +SAG(1) 7,281.07 0.41 254.34 6,245.36 6,153.84 - 1,311.42 - 1,993.20 2,629,499.30 1,458,602.04 0.17 2,376.70 MWD +SCC +SAG (1) 7,375.47 0.63 237.85 6,339.76 6,248.24 - 1,311.79 - 1,993.97 2,629,498.95 1,458,601.27 0.28 2,377.53 MWD +SCC +SAG (1) 7,472.17 0.70 238.43 6,436.45 6,344.93 - 1,312.38 - 1,994.92 2,629,498.37 1,458,600.31 0.07 2,378.64 MWD +SCC +SAG (1) 7,567.33 0.80 231.64 6,531.60 6,440.08 - 1,313.10 - 1,995.94 2,629,497.67 1,458,599.28 0.14 2,379.88 MWD +SCC +SAG (1) 8/25/2008 1:00:06PM Page 4 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co- ordinate Reference: Well BRU 211 -26 Project: Beluga River TVD Reference: BRU 211 -26 © 91.52ft (Nabors 129) Site: Beluga River MD Reference: BRU 211 -26 @ 91.52ft (Nabors 129) Well: BRU 211 -26 North Reference: True Weilbore: BRU 211 -26 Survey Calculation Method: Minimum Curvature Design: BRU 211 -26 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi T1/D TVDSS +N /-S +E/ -W Northing Easting DLS ' Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( °/1001 (ft) Survey Tool Name 7,661.42 1.16 242.05 6,625.68 6,534.16 - 1,313.95 - 1,997.29 2,629,496.84 1,458,597.91 0.42 2,381.47 MWD+SCC4*SAG (1) 7,704.27 1.16 241.23 6,668.52 6,577.00 - 1,314.36 - 1,998.05 2,629,496.44 1,458,597.15 0.04 2,382.33 MWD +SCC +SAG(1) 7,786.00 1.16 241.23 6,750.23 6,658.71 - 1,315.16 - 1,999.50 2,629,495.66 1,458,595.69 0.00 2,383.95 PROJECTED to TD 8/25/2008 1 :00 :06PM Page 5 COMPASS 2003.16 Build 42F S ConoccPhillips Time Log & Summary WelMew Web Reporting Report w.� Well Name: BRU 211 - 26 Rig Name: NABORS 129 Job Type: DRILLING ORIGINAL Rig Accept: 8/2/2008 4:00:00 PM Rig Release: 9/27/2008 11:59:00 PM Date F :g t lYa.<.':., , • Dtir ligatkE, DeOt Phas ' Code „,; t1b Commen> 07/28/2008 24 hr Summary Rig down and move. 16:00 00:00 8.00 MIRU MOVE DMOB P Rig down and move rig to BRU 211 -26 07/29/2008 Continue to rig down and move. 00:00 00:00 24.00 0 0 MIRU MOVE P Move mud product, Company Man, Tool Pusher shacks, lay down derrick, move pump units. 07/30/2008 Completed moving rig parts from BRU 243 -34 to BRU 211 -26. Cut conductor 61.64" from top of cellar box. Install nipples in cellar, set landing ring. 00:00 00:00 24.00 0 0 MIRU MOVE RURD P Completed the rig move. Laid down the felt, and herculite, followed by the rig mats. Work on mud pits roof frames. Cut conductor set landing ring, and weld in clean out nipples in cellar. 07/31/2008 Set drilling adapter on conducter, set sub base, set draw works on base, set 400 bbl water tank, and dog house in place. Set derrick on rig floor, and pin. Place plugs in 224 -23 & 232 -26 with wireline, place SSSVs in with boom truck and Cameron service hand. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P 12:00 00:00 12.00 0 0 MIRU MOVE RURD P 08/01/2008 Set wireline plugs in 224 -23, 1 & 2. Set wireline plugs in 232 -26, 1 & 2. Cameron SSSVs in 224 -23 -1 & 2 and a Cameron SSSV was set on the long string of 232 -26. Set a second WL plug @ 76' on 232 -26 -2 short string. Perform critical lift on derrick, continue to rig up drilling equipment and office buildings on location. Including MWD shack/TP trailer /CoMan trailer. Set and fill BJ silos with surface cement. Stand up derrick. Rig up Pollard to bring 224 -23 back on production. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Set wireline plug in 224 -23 -1 @ 500', Cameron SSSV below master valve. Set WL plug @ 881' in 224 -23 -2. Cameron SSSV's set in both strings in profile below master valve. Set WL plug in 232 -26 -1 @ 1055', set WL plugs in 232 -26 -2 @ 785' and 76'. A Cameron valve was placed in 232 -26 -1. Unable to seat a valve in profile of 232 -26 short string. SIMOPS: Nabors 129 set up lines, hoses, BOP rails, cuttings tanks, prepare to stand up derrick. Page 1 of 37 . • Time Logy \ ;17:111t7- E a y r.. From To Dur , DOOM ,. E` .Death Phase Coda _ T „ 'commit . 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Perform critical lift of derrick off truck bed and onto A frame derrick rack. Pin A legs to back side, set and fill BJ cement silos. Continue to rig up to spud, and stand derrick up. Stand up derrick. 08/02/2008 Stand up derrick, set up top drive system, bring on water to mix spud mud, Inventory and prepare BHA for drilling, Displace 155 BBLs of inhibited brine 8.6ppg into BRU 243 -34. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Stand up derrick, pick up and install top drive rails and top drive. Begin to bring on water to make spud mud. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Set up diverter line wool, ni 1e up in cellar. Set up diverter line. Continue to bring on water into mud pits, rig up to drill. 08/03/2008 Rig up to drill. build spud mud, clean out conductor, pick up and stand back drill pipe and heavy weight. 00:00 12:00 12.00 85 85 MIRU MOVE RURD P Finish setting up diverter system, top drive, pits, solid control equipment, build berm for SWACO mixing unit, set Tank, and generator. 12:00 16:00 4.00 85 85 MIRU MOVE RURD P Pick up a single, function test accumulator, make up bit/bit sub. Inspection of Diverter waived by Jeff jones AOGCC. 16:00 17:00 1.00 85 85 MIRU MOVE RURD P Clean out conductor to 85 feet. 17:00 18:00 1.00 85 85 MIRU MOVE RURD P Circulate conductor clear. 18:00 19:00 1.00 85 85 MIRU MOVE RURD P Gyro with gyro Data North seeking gyro, determine true North Bearing for kick off. 19:00 00:00 5.00 85 85 MIRU MOVE RURD P Pick up and stand back drill pipe, heavy weight. 08/04/2008 Pick up HWDP, BHA, spud well, directionally drill 00:00 06:00 6.00 85 85 MIRU MOVE RURD P Pick up and stand back 5" drill pipe and heavy weight drill pipe, prepare to spud. 06:00 08:00 2.00 85 85 SURFA( DRILL PULD P Pick up bit, mud motor, float sub, stab. 08:00 12:00 4.00 85 226 SURFA( DRILL DDRL P Rotar�r drill from 85' to 226'. 450 gpm, 80 rpm, 10k wob. Spudded well 08:00 hrs 8/4/08. 12:00 12:30 0.50 226 226 SURFA( DRILL CIRC P Circulate and condition the hole for short trip. 12:30 13:00 0.50 226 226 SURFA( DRILL WPRT P Trip out to pick up MWD tools. 13:00 15:30 2.50 226 226 SURFA( DRILL PULD P Pick up MWD system, gamma, resistivity, directional, UBHO, orient, pick up 3 monel collars 15:30 16:30 1.00 226 226 SURFA( DRILL WPRT P Trip in the hole with new tools. 16:30 00:00 7.50 226 813 SURFA( DRILL DDRL P Directionally drill with 450 gpm,s 80 rpm, 10k wob. ART =4.02, AST= 2.41.total bit hrs =9.57. 08/05/2008 Directionally drilled to 1056', Tripped out for a short trip and to turn the bend up on the mud motor, tripped back to bottom, Directionally drilled to 2234'. Page 2 of 37 0 ! Date 2,:, ew ".. � _ :���... . . E =��tt1 � E = aeSil °.1a$4 s . s ie •, ' ' :.fl meat , ,. •.•` i.� .•.�,', F };:. 00:00 02:30 2.50 813 1,056 SURFA( DRILL DDRL P Drilling, sliding from 813 to 1056' MD. 350 to 450 gpm's, 1000 psi off, 1200 psi on bottom, up Wt =64k, Dn Wt= 63, rotate Wt= 62, 20k Wob. 1.13 slid hrs. 10.7 hrs for bit run. Stop drilling. Not getting the needed doglegs. 02:30 03:00 0.50 1,056 1,056 SURFA( DRILL CIRC P Circulate bottoms up, prepare to trip out to reset bend in motor from 1.5 to 1.83. 03:00 04:30 1.50 1,056 1,056 SURFA( DRILL TRIP P Monitor well,Trip out of hole. Pump out to BHA. 04:30 06:00 1.50 1,056 1,056 SURFA( DRILL PULD P Inspect BHA, reset bend in motor, orient. 06:00 07:00 1.00 1,056 1,056 SURFA( DRILL TRIP P Trip back to bottom. 07:00 12:00 5.00 1,056 1,433 SURFA( DRILL DDRL P Drilling from 1056 to 1433' MD. Total hrs =2.03. ART =.50 hrs.,AST =1.53 hrs. Up wt =66, Dn wt =64, Rot wt =65. 12:00 00:00 12.00 1,433 2,234 SURFA( DRILL DDRL P Drilling from 1433' to 2234' MD. Survey every 45 feet. Back ream each 45 feet. 7.18 hrs for bit run. 5.15 hrs on tour. ART= 1.0 hr. AST= 4.15 hrs. 550 gpm while reaming and rotating. 400 to 450 gpm's while sliding. 60 rpm's, 20k to 40k bit weight. 80k up wt/ 62k do wt/ 70k rot wt. 08/06/2008 Directionally drilled from 2234' MD to 3602' MD. TD. Circulate and condition well, and begin short trip. 00:00 06:00 6.00 2,234 2,537 SURFA( DRILL DDRL P Drilling from 2234' MD to 2537' MD. with 60 rpm's, 475 to 550 gpm's, 20,000 to 30,000 lbs bit weight. 8k torque on btm., 7k torque off btm. 1450 psi on btm, 1150 psi off btm. 06:00 12:00 6.00 2,537 3,025 SURFA( DRILL DDRL P Directional drilling from 2537 MD to 3025' MD. with 60 rpm's 500 to 575 gpm's, 20,000 to 30,000 lbs. bit weight, Up wt= 98k, Dn wt =56, Rot wt= 72k. check for flow every connection. total hrs on bit =12.01 hrs. ART =3.98 hrs, AST =8.03 hrs. On tour, ART =2.48 hrs, AST =2.35 hrs. Jar hours = 43.06 12:00 13:00 1.00 3,025 3,112 SURFA( DRILL DDRL P Directional drilling from 3025' MD to 3112' MD. with 60 rpm's 500 to 575 gpm's, 20,000 to 30,000 lbs. bit weight, Up wt= 98k, Dn wt =56, Rot wt= 72k. check for flow. every connection. ART = .61 hrs. 13:00 13:30 0.50 3,112 3,112 SURFA( DRILL SRVY P Directional Work, surveying in all 4 quadrants for JORPS. Page 3 of 37 • a ••n .• �si�.� .;� �. ,, � .:,.,.1. � t t) Phase Code U �i..d... . .'� " �+€tmI�l�'Itt: .. .\�� \ ...'', 13:30 18:30 5.00 3,112 3,436 SURFA( DRILL DDRL P Directional drilling from 3112' MD to 3436' MD. with 60 rpm's 500 to 575 gpm's, 20,000 to 30,000 lbs. bit weight, Up wt= 98k, Dn wt =56, Rot wt= 72k. check for flow. every connection. 18:30 19:00 0.50 3,436 3,436 SURFA( DRILL WOOR P Geologist picking TD with MWD logs. 19:00 21:30 2.50 3,436 3,602 SURFA( DRILL DDRL P Directional drilling from 3436' MD to 3602' MD. with 60 rpm's 500 to 575 gpm's, 20,000 to 30,000 lbs. bit weight, Up wt= 108k, Dn wt =66k, Rot wt= 72k. check for flow every connection. total hrs on bit =16.61 hrs. ART =7.77 hrs, AST =8.84 hrs. On tour, ART =3.79 hrs, AST =.98 hrs. Jar hours = 47.83 (TD surface hole 3602' MD, 2867' ND.) 21:30 23:30 2.00 3,602 3,602 SURFA( DRILL CIRC P Circulate and condition mud system. Weight up from 9.1 to 9.4 ppg prior to trip. CBU 3.5 times. Monitor well. Static. 23:30 00:00 0.50 3,602 3,602 SURFA( DRILL SRVY P Lay down single we had picked up to reach TD. Take final survey for 12.25" hole. 08/07/2008 Conducted short trip to top fo HWDP and back to bottom. Circulated the well clean, tripped out. Laid down the surface BHA tools, ran 9 5/8" casing. 00:00 06:00 6.00 3,602 3,602 SURFA( DRILL WPRT P Monitor well, static, trip out of hole. Pumping out from 3602 to 2538. 450 gpm's, 1250 psi, Pulled on elevators from 2538 to the top of the HWDP. Clean rig floor, monitor well 10 mins. Static. 06:00 09:00 3.00 3,602 3,602 SURFA( DRILL WPRT P Trip back in the hole to 3496' MD. Wash and ream to bottom. No fill. Hole in good shape. Ream w/ 450 gpm's, 60 rpm's. 9k tq. PU Wt. =95k, SO Wt. =65k, Rot= 75k. 09:00 11:00 2.00 3,602 3,602 SURFA( DRILL CIRC P Ccirculate and condition hole with 550 gpm's, 60 rpm's. Reduce flow rate to 450 gpm's on down stroke. Lay down single, drop Sperry ESS. 11:00 12:00 1.00 3,602 3,602 SURFA( DRILL TRIP P Begin trip out to lay down BHA. Trip from 3602 to 2545' MD. Stop for Sperry surveys @ 3403', 3112', 3106'. Pump dry job. 12:00 14:30 2.50 3,602 3,602 SURFA( DRILL TRIP P Trip out of hole. No overpull. 14:30 18:30 4.00 3,602 3,602 SURFA( DRILL PULD P Lay down bottom hole assembly with Peak boom truck. Lay down 2 jts HWDP, jars, 3 flex collars, MWD, motor. Clear and clean rig floor. Page 4of37 • Date \ < .... ` :bur' . \ . Depth . E. I rh iiiilase ode OtAtitent 4 18:30 21:30 3.00 3,602 3,602 SURFA( DRILL RURD P Rigging up to run 9 5/8" casing, Change out elevators, bales, rig up casing equipment. Make dummy run with casing hanger. Mark landing @ joint 21.23 feet. joint 21:30 22:00 0.50 3,602 3,602 SURFA( DRILL SFTY P Pejob safety meeting with Weatherford casing crew and day light driller. 22:00 00:00 2.00 3,602 3,602 SURFA( CASING RNCS P Run casing as per well plan. TIH with 9 5/8" 10 joints. 08/08/2008 Ran 9 5/8" 40# casing to 3592' MD. Cemented. Rig down diverter line. Nipple down 20" Hydril, spool, pull drilling adaptor, orient and set Vetco well head. 00:00 03:00 3.00 3,602 3,602 SURFA( CASING RNCS P Running casing. 9 5/8" 40#, run 42 jts to 1720' MD. PU WT =74k, SO WT =55k. 03:00 03:30 0.50 3,602 3,602 SURFA( CASING CIRC P Circulate 1800 strokes. @ 200 gpm's. 100 psi. Hole in good shape. 03:30 08:30 5.00 3,602 3,602 SURFA( CASING RNCS P Run joints # 42 to 87. Land well head 3592 shoe depth. 2862 ND. rig up BJ cement head. 08:30 10:30 2.00 3,602 3,602 SURFA( CASING CIRC P Circulate and condition mud for cement job. PV less than 30, YP less than 20. 10:30 11:00 0.50 3,602 3,602 SURFA( CEMENT SFTY P Hold safety meeting with morning tour and BJ cementers. 11:00 12:00 1.00 3,602 3,602 SURFA( CEMENT DISP P Pump 26 BBL Nut Plug / Drop 1st plug, pump 24 BBLs mudclean 2 spacer. Test BJ lines to 3000 psi, Pump 12 ppg slurry. Start of 921 sacks. 12:00 14:00 2.00 3,602 3,602 SURFA( CEMENT DISP P BJ pumped 333 BBLs of 12 pps slurry total. Emptied the silos. Drop 2nd plug, pump 5 BBLs of water / Displace with 263 BBLs 9.6 ppg mud. Did not bump the plug, 20 BBLs of cement back to surface, Floats held pressure. 14:00 16:30 2.50 3,602 3,602 SURFA( CEMENT RURD P Blow down BJ unit, rig down cement head, lay down landing joint, rig down casing bales. elevators, flush out stack, flow line shakers, clean up cellar, flush all valves, hoses, lines. Release BJ. 16:30 18:30 2.00 3,602 3,602 SURFA( WELCTL NUND P Nipple down diverter line, nipple down knife valve, remove catwalk, pull mouse hole, wash out knife valve, hydil, bleed off accumulator, remove knife valve. 18:30 22:30 4.00 3,602 3,602 SURFA( WELCTL NUND P Nipple down, rig down turnbuckles, remove flow nipple, clean out flow line, rig down 2000 psi hydril, deverter tee, adaptor flange. remove with trolley and forklift. 22:30 00:00 1.50 3,602 3,602 SURFA( WELCTL NUND P Nipple up, orient and install Vetco MB 230 wellhead. 08/09/2008 Nippled up and tested the 5000 psi 5k Shaffer 11' BOP stack. Page 5 of 37 • • Ti , 2- Date . S. Death E Deot' : ' ,, se a• u '3Co111 00:00 01:30 1.50 3,602 3,602 SURFA( WELCTL NUND P Nipple up, continue to nipple up Vetco MB 230 split bowl system.Test VG seal ring to 5000 psi for 20 mins. witnessed by Coman. Good. 01:30 02:00 0.50 3,602 3,602 SURFA( WELCTL NUND P Nipple up. Clear and clean up cellar in preparation to begin nippling up BOP's. 02:00 07:30 5.50 3,602 3,602 SURFA( WELCTL NUND P Nipple up Shaffer 5000 psi 11" BOP stack up to Annular. Set in place. 07:30 12:00 4.50 3,602 3,602 SURFA( WELCTL NUND P Install riser, flowline, bell nipple, koomey lines, upper annulus valve. 12:00 16:30 4.50 3,602 3,602 SURFA( WELCTL NUND P Nipple up, continue to install flowline and riser. NU kill line 90 flange, MU kill line hose, install drip pan, change out Top drive dies from 5" size to 4" DP. change out top drive quill. 16:30 18:00 1.50 3,602 3,602 SURFA( WELCTL BOPE P Test BOP's, function test rams, lower pipe rams. Gas alarms. Methane and H2S. 18:00 00:00 6.00 3,602 3,602 SURFA( WELCTL BOPE P Test BOP's, Upper well control, lower well control, inside kill, outside kill, choke manifold vavles, 1 through 11. HCR valve/ manual on HCR side/ Inside choke / lower pipe rams, all to 250 low, and 3500 high. Charted 5 mins each. Accumulator test. 08/10/2008 Finished BOP test @ 0300 Hrs. 8/10/2008. Laid down all the 5" DP. Picked up & strapped 4" DP, 150 jts. stood back in derrick. 00:00 03:00 3.00 3,602 3,602 SURFA( WELCTL BOPE P Test BOP's, Test 250 psi low, 3500 psi high. Blind rams, TIW valve, and dart valve, BOP witnessed by Bob Noble of AOGCC. 03:00 03:30 0.50 3,602 3,602 SURFA( WELCTL BOPE P Test BOP's, lay down test joint, rig down test equipment, blow down choke manifold. 03:30 04:00 0.50 3,602 3,602 SURFA( WELCTL EQRP P Install Vetco MB 230 Long wear bushing, H281973 -5. 04:00 04:30 0.50 3,602 3,602 SURFA( DRILL SFTY P Hole safety meeting with rig crew and Peak hands about laying down the 5" DP. 04:30 10:00 5.50 3,602 3,602 SURFA( DRILL PULD P Lay down all the 5" drill pipe from the derrick, trip in and come out sideways, two times. Vaccum out each joint with Super Sucker. 10:00 12:00 2.00 3,602 3,602 SURFA( DRILL PULD P Haul all the 5" to storage pad, bring in 4" drill pipe, strap, number 150 joints. 12:00 13:00 1.00 3,602 3,602 SURFA( DRILL PULD P Crew change, finish numbering 150 joints of 4" DP to be stood back in derrick. Prejob about picking up tools. 13:00 17:30 4.50 3,602 3,602 SURFA( DRILL PULD P Pick up running in the hole, 25 stands of 4" DP. Rack back all 25 stands. 17:30 18:30 1.00 3,602 3,602 SURFA( DRILL RURD P Replace, repair Epoch depth encoder on crown. Page 6 of 37 • • Time Lofts' kAVk Dab ..-. Fri .To ..:..'bur' , . 8, ' Depth, . E, Deoth, wise \ ubcode 18:30 23:00 4.50 3,602 3,602 SURFA( DRILL PULD P Pick up running in the hole, 25 stands of 4" DP. Rack back all 25 stands. 50 stands in the derrick. 23:00 23:30 0.50 3,602 3,602 SURFA( DRILL SFTY P Prejob for picking up BHA. 23:30 00:00 0.50 3,602 3,602 SURFA( DRILL PULD P Bottom Hole Assembly components brought up to the rig floor, and arranged on the cat walk for picking up. 08/11/2008 Picked up BHA #3. PDC bit motor set on 1.22. MWD system. Gamma /Res /PWD /Nutron /Density, tripped in the hole, tested casing, drilled float and shoe, 20 feet new hole, Performed FIT to 15.8 ppg EMW. started drilling 8.75" hole. 00:00 03:00 3.00 3,602 3,602 SURFA( DRILL PULD P Picking up BHA #3. Bit / motor / float sub / lead collar / stab / MWD system/ one flex collar. 03:00 07:45 4.75 3,602 3,602 SURFA( DRILL PULD T Failed shallow pulse test. Rig up cables for tool comms. No com. with upper bus. Trouble shoot, reseat battery, bring over back up tools, check for side stab, not a problem, a the DM, check Nuc/Den conn, sidestab found. Repair, download, reorient, Good shallow pulse test @ 0745. 07:45 08:00 0.25 3,602 3,602 SURFAI DRILL CIRC P Good shallow pulse test. 08:00 09:00 1.00 3,602 3,602 SURFA( DRILL PULD P Hold nuclear safety meeting, load sources, pick up 2 monel flex collars. 09:00 12:00 3.00 3,602 3,602 SURFA( DRILL TRIP P Pick up drill pipe of catwalk. singling in with HWDP, and 4" HT38. to 3071' MD. 12:00 12:30 0.50 3,602 3,602 SURFA( DRILL TRIP P Run two stands out of the derrick to reach 3360' MD. 12:30 14:00 1.50 3,602 3,602 SURFA( DRILL CIRC P Circulate and condition the wellbore for the casing test. 14 :00 15:00 1.00 3,602 3,602 SURFA( DRILL OTHR Presure test casing to 3,000 psi, chart for 30 mins. BJ cement truck. 15:00 16:00 1.00 3,602 3,602 SURFAI DRILL OTHR P Slip and cut drilling line. Slip 100', cut 100'. 16:00 17:00 1.00 3,602 3,602 SURFA( DRILL OTHR P Service top drive. Blocks. Brakes. Crown. 17:00 17:30 0.50 3,602 3,602 SURFA( DRILL TRIP P Trip to float collar. 3509" MD. 17:30 18:45 1.25 3,602 3,602 SURFA( DRILL REAM P Drill float, 85 feet of cement, shoe, w/ 450 gpm's, 60 rpm's, 5 to 10k weight on bit. 18:45 19:00 0.25 3,602 3,622 SURFA( DRILL DDRL P Drill 20 feet of new hole for FIT. 19:00 20:00 1.00 3,622 3,622 SURFA( DRILL CIRC P Circulate the hole until MW in and out were equal and the shakers had cleaned up. 20:00 20:30 0.50 3,622 3,622 SURFA( DRILL SFTY P Safety meeting with BJ. Rig up to perform FIT. Page 7of37 II • • Time!: ' ‘ •� x :k0;10- �� ' 9 ∎411 %YPhase 17 s «rs , T a men \ > 20:30 21:30 1.00 3,622 3,622 SURF/NC DRILL FIT P Pressure test lines to 2000 psi, give 10 BBIs water to BJ, close pipe rams, pump down inside and outside to 1000 psi. Max surface pressure, shut in and chart. FIT= 15.8 ppq EMW. chart for 15 minutes, pump 1.6 bbls, .75 bleed back. Rig down BJ 21:30 23:30 2.00 3,622 3,622 PROD1 DRILL CIRC P Hole prejob meeting to change over to Flo Pro mud system, change over to drill in fluid. 23:30 00:00 0.50 3,622 3,644 PROD1 DRILL DDRL P Directionally drilled from 3622 to 3640' MD. 465 gpm's, 60 rpm's, ART =.37 08/12/2008 Directionally drill from 3644' MD to 4699' MD. Load and strap 7" casing, perform the first 10 stand short trip. 00:00 12:00 12.00 3,644 4,314 PROD1 DRILL DDRL P Directionally drill from 3644' MD to 4314' MD. 480 gpm's, 100 rpm's, 2,000 Ibs wob, 1575 psi off btm, 1715 psi on btm, ECD =10.03 ppg. Total bit hours =7.19, tour AST =1.4, ART =5.79 12:00 13:30 1.50 4,314 4,410 PROD1 DRILL DDRL P Directionally Drill from 4314' to 4410' MD. 100% slide. 400 gpm's. AST =.95 13:30 15:00 1.50 4,410 4,410 PROD1 DRILL CIRC P Circulate and condition the wellbore for a short trip to the shoe. CBU 3x's. 15:00 16:30 1.50 4,410 4,410 PROD1 DRILL WPRT P Short trip into the casing. No over pull. Hole in good shape. No fill. 16:30 17:00 0.50 4,410 4,410 PROD1 DRILL REAM P Pecautionary ream the last stand. No fill. 17:00 20:30 3.50 4,410 4,599 PROD1 DRILL DDRL P Directionally drill from 4410 to 4599' MD. 100% slide. AST =1.96. 20:30 21:30 1.00 4,599 4,599 PROD1 DRILL REAM P Ream the full stand for 2 bottoms up. 21:30 00:00 2.50 4,599 4,699 PROD1 DRILL DDRL P Directionally drill from 4599 to 4699' MD. 480 gpm's, 100 rpm's, 5,000 wob, Total bit hrs= 11.91. AST =7.48/ ART= 4.43. Tour, AST =3.17, ART =1.64. 08/13/2008 Directionally drill from 4699' MD to 5663' MD. Finish strapping, rabbiting 7" casing, perform the 2nd 10 stand short trip @ 5450' MD. 00:00 12:00 12.00 4,699 5,271 PROD1 DRILL DDRL P Directionally drill from 4699' to 5271' MD. 490 gpm's, 100 rpm's, 2 to 10k wob, TQ =4.0k off btm, 5.5k on btm, up Wt =85 / dn Wt =68 / rot Wt =74. AST =4.24 / ART =2.57 / ADT =6.81 hrs. Over pull 15k coming out of slide from 5137' MD. Reestablished rotary and dressed off the slide, the hole was slick. 12:00 16:30 4.50 5,271 5,461 PROD1 DRILL DDRL P Directionally drill from 5271' to 5461' MD. 490 gpm's, 100 rpm's, 2 to 10k wob, TQ =4.0k off btm, 5.5k on btm, up Wt =90 / dn Wt =68 / rot Wt =78. Page 3 of 37 • 2 • Time L ! \ \ \ Date. .{ To D . .. ..1 . �* ase r r Sub r r Com "1= x 16:30 18:00 1.50 5,461 5,461 PROD1 DRILL DDRL P Circulate and condition the wellbore for the 2nd short trip. 18:00 18:30 0.50 5,461 5,461 PROD1 DRILL WPRT P Pull 10 stands. Hole in good shape. No over pull. 18:30 19:00 0.50 5,461 5,461 PROD1 RIGMNT SVRG P Service top drive. 19:00 19:30 0.50 5,461 5,461 PROD1 DRILL WPRT P Trip back to bottom. Precautionary ream the last stand. 19:30 20:30 1.00 5,461 5,461 PROD1 DRILL CIRC P Circulate a high vis sweep after the short trip. No fill, hole clean, no trip gas. 20:30 00:00 3.50 5,461 5,663 PROD1 DRILL DDRL Directionally drill from 5461' to 5663' MD. 490 gpm's, 100 rpm's, 2 to 10k wob, TQ =4.0k off btm, 5.5k on btm, up Wt =92 / do Wt =68 / rot Wt =78. AST =1.8 / ART =2.72 / ADT =4.52 hrs. 22.73 hrs on bit total. Jar hrs= 69.76 08/14/2008 Drilled from 5663' MD to 6507' MD. All rotary drilling, no slides. The wellbore remains vertical to TD. Conducted the 3rd short rip. Good hole conditions. Seepage loss rate measured @ 2 BBLs /hr. 00:00 12:00 12.00 5,663 6,248 PROD1 DRILL DRLG P Drill from 5663' MD to 6248' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =100, Dn Wt =75, Rot Wt =86. Pump P =2230 off btm, 2350 on btm, TQ= 6k off btm, 7k on btm. No slides on this tour. ART =7.90. ECD= 10.19 ppg. 12:00 14:30 2.50 6,248 6,413 PROD1 DRILL DRLG P Drill from 6248' to 6413' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =100, Dn Wt =75, Rot Wt =86. Pump P =2230 off btm, 2350 on btm, TQ= 6k off btm, 7k on btm. No slides. ART =1.74 14:30 15:30 1.00 6,413 6,413 PROD1 DRILL CIRC P Circulate and Condition the wellbore for the 3rd short trip. 500 gpm's, 100 rpm's. ECD's dropped from 10.26 ppq to 10.00 ppq duringthe„ ,$S,. 15:30 17:00 1.50 6,413 6,413 PROD1 DRILL WPRT P Pull 10 stands, wiper trip. 10k over pull # 5400. 17:00 17:30 0.50 6,413 6,413 PROD1 RIGMNT SVRG P Service top drive, wash pipe, tongs, TQ tube. 17:30 18:00 0.50 6,413 6,413 PROD1 DRILL WPRT P Trip back to bottom, precautionary ream last stand. No fill, hole in good shape. Lost 2 BBLs of mud during try. 18:00 19:00 1.00 6,413 6,413 PROD1 DRILL CIRC P Circulate bottoms up for possible trip gas. 243 units of short trio aas. 19:00 20:00 1.00 6,413 6,457 PROD1 DRILL DRLG P Drill from 6413' MD to 6457' MD.. 490 gpm's, 100 rpm's, 10k wob, Up Wt =108, Dn Wt =76, Rot Wt =86. Pump P =2230 off btm, 2350 on btm, TQ= 6k off btm, 7k on btm. No slides. ART =.45 20:00 22:30 2.50 6,457 6,457 PROD1 RIGMNT RGRP T Middle piston, #2 pump. Replace liner, gasket, check pistions 1 & 3. Replace all expendables on leaking cylinder. Page 9 of 37 • '7 our A 22:30 00:00 1.50 6,457 6,507 PROD1 DRILL DRLG P Drill from 6457' to 6507' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =108, Dn Wt =76, Rot Wt =86. Pump P =2230 off btm, 2350 on btm, TQ= 6k off btm, 7k on btm. No slides. ART =.59 08/15/2008 Drilled from 6507' MD to 7238' MD. Slide a total .5 hrs 36 feet. The wellbore remains vertical to TD. Good hole conditions. Seepage loss rate @ 2 BBLs /hr. 00:00 07:30 7.50 6,507 6,720 PROD1 DRILL DDRL P Drill from 6507' MD to 6720' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =111, Dn Wt =78, Rot Wt =93. Pump P =2320 off btm, 2530 on btm, TQ= 7k off btm, 8k on btm. 07:30 08:00 0.50 6,720 6,720 PROD1 RIGMNT RGRP P Circulate and condition on one pump. change out a swab on Pump #2. 08:00 12:00 4.00 6,720 6,887 PROD1 DRILL DDRL P Drill from 6720' MD to 6887' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =111, Dn Wt =78, Rot Wt =93. Pump P =2320 off btm, 2530 on btm, TQ= 7k off btm, 8k on btm. AST =.53, ART= 6.20. ADT = 6.73 hrs. 12:00 18:00 6.00 6,887 7,078 PROD1 DRILL DDRL P Drill from 6887' MD to 7078' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =120, Dn Wt =81, Rot Wt =92. Pump P =2450 off btm, 2675 on btm, TQ= 8k off btm, 10k on btm. 18:00 00:00 6.00 7,078 7,238 PROD1 DRILL DDRL P Drill from 7078' MD to 7238' MD. 490 gpm's, 100 rpm's, 10k wob, Up Wt =120, Dn Wt =81, Rot Wt =92. Pump P =2450 off btm, 2675 on btm, TQ= 8k off btm, 10k on btm. AST =.50, ART= 9.36 ADT = 9.86 hrs. ECD =10.11 ppg. 08/16/2008 Drilled from 7238' MD to TD 7786' MD. Circulate 3 bottoms up, and tripped out to 6602' MD. short trip into the casing 00:00 07:00 7.00 7,238 7,525 PROD1 DRILL DDRL P Drill from 7238' MD to 7525' MD. 490 gpm's, 110 rpm's, 10k wob, Up Wt =120, Dn Wt =81, Rot Wt =92. Pump P =2450 off btm, 2675 on btm, TQ= 7k off btm, 9k on btm. 07:00 08:00 1.00 7,525 7,525 PROD1 RIGMNT RGRP P Circulate and condition the well with one pump. change out a swab and liner on #2 pump #2 cylinder. Page 10 of 37 • D21:1 From T. [fur a .th Ph Su • T. «.a men : .:` 08:00 12:00 4.00 7,525 7,650 PROD1 DRILL DDRL P Drill from 7525' MD to 7650' MD. 490 gpm's, 110 rpm's, 20k wob, Up Wt =120, Dn Wt =81, Rot Wt =92. Pump P =2550 off btm, 2775 on btm, TQ= 7k off btm, 9k on btm. AST =0, ART= 10.01 ADT = 10.01 hrs. ECD =10.15 ppg. 12:00 18:00 6.00 7,650 7,786 PROD1 DRILL DDRL P Drill from 7650' MD to 7786' MD. TD @ 18:00 hrs. 490 gpm's, 110 rpm's, 20k wob, Up Wt =122, Dn Wt =84, Rot Wt =98. Pump P =2550 off btm, 2775 on btm, TQ= 7k off btm, 9k on btm. AST =0, ART= 5.5 ADT = 5.5 hrs. ECD =10.19 ppg. 18:00 22:00 4.00 7,786 7,786 PROD1 DRILL CIRC P Circulate and condition the wellbore for a short trip into the casing. 3x's BU. 22:00 00:00 2.00 7,786 7,786 PROD1 DRILL WPRT P Pulled the first 5 stands with no over pull. Began swabbing and pulling 20k over on stand #6 on the way out. Began to back ream with 80 rpm's, 430 gpm's. Bit depth @ 6602 at midnight. The hole remained tight, and required pumping and reaming to avoid swabbing, and any over pull. 08/17/2008 Completed the short trip from TD to the shoe and back to bottom, tripped out to the BHA, and laid down the monels, downloaded the MWD system. 00:00 01:00 1.00 7,786 7,786 PROD1 DRILL REAM P Backream out of the hole from 6602' MD to 6317' MD. RW =80 / 415 gpm, 100 rpm, 7K TQ. 01:00 01:30 0.50 7,786 7,786 PROD1 DRILL WPRT P Began to pull again from 6317' MD to 6127' MD. UW =110, began pulling 30k over, and started to try to swab. Stopped. 01:30 02:15 0.75 7,786 7,786 PROD1 DRILL REAM P Backream out from 6127' MD to 5936' MD. 490 gpm, 110 rpm, 02:15 02:30 0.25 7,786 7,786 PROD1 DRILL WPRT P The wellbore cleaned up. Stop reaming. Monitor hole for 15 mins. Measure a 2 BBL per hour loss rate. 02:30 03:00 0.50 7,786 7,786 PROD1 DRILL WPRT P'�Trip on the elevators from 5936' MD to 5461' MD. UW 110. DW =65 03:00 03:30 0.50 7,786 7,786 PROD1 DRILL CIRC P Circulate, spot dry job. 28 BBL. 11.2 ppg 03:30 05:00 1.50 7,786 7,786 PROD1 DRILL WPRT P Trip out of hole into casing. 05:00 05:30 0.50 7,786 7,786 PROD1 RIGMNT SVRG P Service top drive, and crown. 05:30 09:30 4.00 7,786 7,786 PROD1 DRILL WPRT P Trip back to bottom. 09:30 12:00 2.50 7,786 7,786 PROD1 DRILL REAM P Begin reaming down from 7641' MD. 495 gpm, 110 rpm, 8.5 TQ. 10 feet of fill on bottom. Coal, and shale seen on the shakers. 12:00 12:30 0.50 7,786 7,786 PROD1 DRILL CIRC P Circulate, ream and reciprocate the drill string. PJSM. Prepare to trip out. Page 11 of 37 • e tl�[ E" �A�. e 's . _ 9 . e y. C \ 12:30 14:30 2.00 7,786 7,786 PROD1 DRILL WPRT P Drop ESS tool and trip out on the elevators. Take surveys @ 4009' MD, 3722', 3698'. Trip into the casing. Shoe @ 3592' MD. 14:30 15:30 1.00 7,786 7,786 PROD1 DRILL CIRC P Circulate and condition inside the shoe. Flow check, flowing, circ. @ 400 gpm's for 30 more mins. Flow check, static. Hole taking fluid again. 15:30 21:30 6.00 7,786 7,786 PROD1 DRILL WPRT P Trip out of hole, stop for flow check every 5 stands for 5 mins. Hole taking fluid @ 1 BBL per hour. Monitor well for 10 mins @ HWDP. Fluid dropping (C17, 1.5 BBUHr. 21:30 22:00 0.50 7,786 7,786 PROD1 DRILL SFTY P Hold prejob, about laying down bottom hole assembly with the Peak boom truck. 22:00 00:00 2.00 7,786 7,786 PROD1 DRILL PULD P Lay down BHA. Lay down 3 monel flex collars, hold prejob for retrieving the sources, pull sources, download. Still downloading at midnight. 08/18/2008 Rig up and run Schlumberger wireline logs. (SP /SBL, DSI, FMI,) Lay down wireline tools. rig up and run in the hole with drill pipe assisted MDT tool. Prognosed to measure 60 stations. 00:00 02:30 2.50 7,786 7,786 PROD1 DRILL PULD P Hold prejob safety meeting about laying down BHA w/ Boom Truck. Lay down MWD tools and Mud Motor. Vacuum tools on the ground w/ Peak Vac truck. Clear and clean rig floor. Monitor well bore. 2 BBLs an hour seepage. 02:30 05:00 2.50 7,786 7,786 PROD1 EVALWE ELOG P Hold pejob safety meeting w/ SLB. R/U SLB wireline truck. Pick up E line tools. 05:00 08:00 3.00 7,786 7,786 PROD1 EVALWE ELOG P Open hole wireline logging. (SP/ SBL / DSI.) 08:00 10:00 2.00 7,786 7,786 PROD1 EVALWE ELOG T DSI tool failure. Pull out for backup. Able to log from 7786 up to 6700' MD before trouble began 10:00 12:00 2.00 7,786 7,786 PROD1 EVALWE ELOG P Open hole wireline logging. Finish 1st WL run. (SP / SBL / DSI / FMI). 12:00 14:00 2.00 7,786 7,786 PROD1 EVALWE ELOG P Crew change continue open hole wireline logging. Finish 1st WL run. (SP / SBL / DSI / FMI). 14:00 14:30 0.50 7,786 7,786 PROD1 EVALWE PULD P Lay down all wireline tools, and prepare for drill pipe assisted run. 14:30 15:00 0.50 7,786 7,786 PROD1 EVALWE SFTY P Prejob safety meeting with SLB for DP convelred logs. MDT. 15:00 16:30 1.50 7,786 7,786 PROD1 EVALWE DLOG P Drill pipe assisted logging operations. Trip in the hole 3 mins a stand. 16:30 19:30 3.00 7,786 7,786 PROD1 EVALWE DLOG P Continue drill pipe assisted logging operations. Trip in the hole 3 mins a stand. Stop to circulate @ 2014' MD. 19:30 20:30 1.00 7,786 7,786 PROD1 EVALWE CIRC P Circulate heavy mud out of the wellbore. 9.8 ppg coming out 9.6+ going in. Once we saw 9.6 in and out the trip continued. Page 12 of 37 • • eate Ts . jj1' - !s �a� [...'^. 0 . e. L:. >,n `.•�aaa \ s � �., 20:30 22:30 2.00 7,786 7,786 PROD1 EVALWE DLOG P Continue drill pipe assisted logging operations. Trip in the hole 3 mins a stand. Stop to circulate @ 3592' MD. The 9 5/8" casing shoe. 22:30 23:30 1.00 7,786 7,786 PROD1 EVALWE CIRC P Circulate heavy mud out of the wellbore. 9.8 ppg coming out 9.6+ going in. Once we saw 9.6 in and out the trip continued. (The wellbore displayed the 2 to 3 BBL per hour seepage rate as expected.t Record up and down weights 52 up, 47 Dn. 23:30 00:00 0.50 7,786 7,786 PROD1 EVALWE DLOG P Continue drill pipe assisted logging operations. Trip in the hole 3 mins a stand to 4023' MD. 08/19/2008 Make up MDT tools and run in the hole on drill pipe to 5070'. Pump down wet connect and latch. Run in the hole to 7165' and take MWDT samples to 6462'. Run in the hole to 7060' and verify correlation. Pull out of the hole to 6838' and continue taking MDT samples. 00:00 02:00 2.00 7,786 7,786 PROD1 EVALWE DLOG P Trip in the hole from 4023' to 5070'. Circulate every 5 stands 02:00 03:30 1.50 7,786 7,786 PROD1 EVALWE CIRC P Circulate and conditon mud. P/U 68k, S/O 58k. 03:30 06:00 2.50 7,786 7,786 PROD1 EVALWE DLOG P Pre -job safety meeting. Rig up a -line and pump down wet connect at 3.5 bpm at 270 psi. Increase to 300 psi to verify latch up 06:00 10:00 4.00 7,786 7,786 PROD1 EVALWE DLOG P Trip in the hole from 5070' to 7165'. P/U 102k, S/O 72k. 10:00 11:00 1.00 7,786 7,786 PROD1 EVALWE DLOG P Correlate depths from 7165' to 6880'. 11:00 15:00 4.00 7,786 7,786 PROD1 EVALWE DLOG P Take MDT samples from 7165' to 6462'. Correlation failure 15:00 16:00 1.00 7,786 7,786 PROD1 EVALWE DLOG P Trip in the hole from 6462' to 7060'. 16:00 16:30 0.50 7,786 7,786 PROD1 EVALWE DLOG P Trip out of the hole from 7060' to 6690' 16:30 17:00 0.50 7,786 7,786 PROD1 EVALWE DLOG P Trip in the hole from 6690' to 7060' 17:00 17:30 0.50 7,786 7,786 PROD1 EVALWE DLOG P Trip out of the hole from 7060' to 6838' 17:30 00:00 6.50 7,786 7,786 PROD1 EVALWE DLOG P Continue getting MDT data from 6838' to 6162'. P/U 88k, Break free wt 42k, S/O 65k. Logging tool does not require additional tension to pull free. Slacking off to 42k to get drill string moving. 08/20/2008 Log with drill pipe conveyed MDT tools from 6138' to 5088'. Unlatch from wet connect and pull out of the hole with a -line. Pull out of the hole with drill pipe from 5071' to 3508'. Rig up a -line and latch into wet connect. Correlate and log with MDT tool from 3508' to 4480'. 00:00 10:30 10.50 7,786 7,786 PROD1 EVALWE DLOG P Run drill pipe conveyed MDT logs from 6138' to 5088';. 10:30 11:30 1.00 7,786 7,786 PROD1 EVALWE DLOG P Unlatch from wet connect and pull out of the hole with a -line. Rig down e -line 11:30 13:30 2.00 7,786 7,786 PROD1 EVALWE DLOG P Trip out of the hole from 5071' to 3508'. Page 13of37 • . Time r tie- From `T6 > ° \ . #tt €}ham. d o c . . .... � .. i .a, .. +. =�°lA�'_ „• a.m�i.. v.. \c,"A�.t�ts ee .: Ce !1 .� «�'< . �.'_ : . 13:30 15:30 2.00 7,786 7,786 PROD1 EVALWE DLOG P Rig up side entry sub and latch into wet connect 15:30 00:00 8.50 7,786 7,786 PROD1 EVALWE DLOG P Correlate depths and log down with MDT from 3508' to 4408' •8/21/2008 Take MDT pressures from 4504' to 4990'. Pull out of hole with MDT tools. Make up rotary sidewall coring tool and in hole on a -line. Attempt to take 52 cores. Pull out of hole with a -line. Recovered 47 cores. 00:00 05:00 5.00 7,786 7,786 PROD1 EVALWE DLOG P Gather MDT data from 4504' to 4990'. Losing 1/2 to 1 bph 05:00 07:00 2.00 7,786 7,786 PROD1 EVALWE DLOG P Pull out of the hole with e-line from 4990' to 3540' 07:00 09:00 2.00 7,786 7,786 PROD1 EVALWE DLOG P Unlatch wet connect. Rig down _ e -line and monitor well. 09:00 11:00 2.00 7,786 7,786 PROD1 EVALWE DLOG P Trip out of hole with drill pipe from 3540' to 190'. 11:00 12:00 1.00 7,786 7,786 PROD1 EVALWE PULD P Lay down MWD logging tools from 190' 12:00 13:00 1.00 7,786 7,786 PROD1 EVALWE PULD P Rig up a -line sheaves and pick up_ rotary sidewall coring tool 13:00 22:30 9.50 7,786 7,786 PROD1 EVALWE ELOG P Take rotary sidewall cores. Attempted 52 cores. Recovered 47 cores. Missed 5 cores 22:30 23:00 0.50 7,786 7,786 PROD1 EVALWE ELOG P Pull out of the hole with a -line 23:00 00:00 1.00 7,786 7,786 PROD1 EVALWE PULD P Rig down a -line and recover core samples 68/22/2008 Rig down a -line. Make up clean out assembly. Run in the hole to 7786'. Circulate and condition mud. Pull out of the hole and laydown BHA. Pull wear bushing and prepare to change ?ipe rams 00:00 01:00 1.00 7,786 7,786 PROD1 EVALWE ELOG P LOGGING OPEN HOLE LOGS- UD SWS SIDEWALL CORING TOOLS. R/D SHEAVES 01:00 01:30 0.50 7,786 7,786 PROD1 RIGMN7 SVRG P SERVICE TOP DRIVE & CROWN 01:30 03:30 2.00 7,786 7,786 PROD1 CASING OTHR P P/U BHA #4 T/ 112'. C/O HANDLING _ EQP/ 03:30 08:00 4.50 7,786 7,786 PROD1 CASING OTHR P TIH F/ 112' T/ 6920' 08:00 12:00 4.00 7,786 7,786 PROD1 CASING OTHR P REAMING/WASHING DN F/ 6920' T/ 7786' 12:00 14:30 2.50 7,786 7,786 PROD1 CASING CIRC P CIRCULATE & CONDITION MUD 14:30 21:30 7.00 7,786 7,786 PROD1 CASING OTHR P TOH F/ 7786' T/ 109' 21:30 23:30 2.00 7,786 7,786 PROD1 CASING OTHR P UD BHA PER SPERRY 23:30 00:00 0.50 7,786 7,786 PROD1 CASING OTHR P REMOVE WEAR BUSHING, CLEAN RIG FLOOR, CELLAR F/ TRIP, PREPARE F/ RAM CHANGE TO 7" •8/23/2008 AND TEST Change pipe rams to 7 ", tested to 3500 PSI, R/U & ran 188 jts of 7" 26# L -80 csg, circulate & condition mud prior to cement. 00:00 00:30 0.50 7,786 7,786 PROD1 RIGMN1 RGRP P REPAIR DW DECODER ADAPTER & CALIBRATE EPOCH PUMP PSI SENSOR 00:30 02:30 2.00 7,786 7,786 PROD1 CASING NUND P CHANGE UPPER PIPE RAMS T/ 7" 02:30 03:30 1.00 7,786 7,786 PROD1 CASING OTHR P P/U TEST TOOLS Page 14of37 • • r Ord . :3 Dc,r E :,. 7 a z 03:30 04:30 1 7,786 7,786 PROD1 CASING DHEQ P TEST BOP'S, TEST 7" RAMS: 250 PSI LOW, 3500 PSI HIGH 04:30 05:00 0.50 7,786 7,786 PROD1 CASING OTHR P UD TEST TOOLS 05:00 06:00 1.00 7,786 7,786 PROD1 CASING NUND P RIG DOWN TO RUN CASING 06:00 06:30 0.50 7,786 7,786 PROD1 CASING SFTY P PJSM RUN CASING W/ WEATHERFORD 06:30 14:30 8.00 7,786 7,786 PROD1 CASING RNCS P RIH 7" 26# L -80 T/ 3519' 14:30 15:00 0.50 7,786 7,786 PROD1 CASING CIRC P CIRCULATE & CONDITION MUD @ 3519'; 115 STK, 180 PSI, 252 GPM 15:00 16:00 1.00 7,786 7,786 PROD1 CASING SFTY P PJSM CHANGING OUT BALE 16:00 22:00 6.00 7,786 7,786 PROD1 CASING RNCS P RIH 7" 26# L -80 F/ 3519' T/ 7753' 22:00 23:00 1.00 7,786 7,786 PROD1 CASING PUTB P P/U LANDING HANGER, BJ CEMENT HEAD, & RIG CIRC HOSE 23:00 00:00 1.00 7,786 7,786 PROD1 CASING CIRC P CBU PRIOR TO CEMENT JOB 08/24/2008 Circulate & condition mud prior to cement job, cement csg w/ 156 bbls of 10.5 ppg slurry, displaced cement w/ 291 bbls of mud, install packoff & test to 5000 psi, change out 7" rams t/ variable bore rams, commence cleaning of mud pits & tanks. Testing BOP. 0000 01:00 1.00 7,786 7,786 PROD1 CEMEN CIRC P CIRCULATE & CONDITION MUD PRIOR TO CEMENT JOB 01:00 01:30 0.50 7,786 7,786 PROD1 CEMEN P PJSACEMENTING CASING 01:30 03:30 2.00 7,786 7,786 PROD1 CEMEN' DISP P CIRCULATE & DISPLACE CEMENT -10 BBLS H2O, TEST LINES T/ 4500 PSI, PUMP 40 BBLS SPACER 154 BBLS 10.5 PPG CEMENT SLURRY @ 5 BBLS /I , M`N `I 775 PSI, DROP PLUG & DISP W/ X1, 291 W/ RIG @ 7 BBLS /C�7,5 PSI. DID NOT BUMP PLUG. P ED 2.7 BBLS OVER CALCS, CHK FLOATS 03:30 04:30 1.00 7,786 7,786 PROD1 CEMEN RURD P RIG DOWN BJ SERVICES FOLLOWING DISPLACEMENT OF CEMENT 04:30 08:30 4.00 7,786 0 PROD1 CASING DHEQ P INSTALL WELLHEADS, VETCO INSTALL & TEST PACKOFF T/ 5000 PSI 08:30 09:30 1.00 0 0 PROD1 WELCTL NUND P CHANGE UPPER RAMS T/ VRBLS 09:30 12:00 2.50 0 0 PROD1 RPCOM OTHR P Worked on BOP doors while cleaning mud pits. Ordered parts. 12:00 14:45 2.75 0 0 PROD1 RPCOM OTHR P Worked on BOP doors while cleaning mud pits. 14:45 00:00 9.25 0 0 PROD1 WELCTL BOPE P Set test plug and tested BOP to 250/5000 psi. Tested Choke manifold, Lower Pipe Rams and Floor valves. Worked on Hinge for upper rams. Rebuilt 1 valve in manifold and retested OK. Tested IBOP. Note: Upper ram door needs new Hinge tube. Parts coming from Lower 48 tomorrow.(Cleaning Mud Pits for Brine.). Page 15 of 37 k.§ ate `. rem «.. %;, , DU .a..: _ S. � t E �"�« € Phase ...> « «e 08/25/2008 24 hr Summary Clean pits. Remove centrifuge. Service rig. Replace hinge pin on upper pipe rams. Test upper pipe rams to 250psi /5000 psi and annular to 250 psi/ 3500 psi. Pick up brush /scraper assembly 00:00 18:00 18.00 7,786 7,786 PROD1 CEMEN" OTHR P Clean Pits & Service Rig 7 786 PROD1 CEMEN" OTHR P Remove Centerfuge, Feed Pump 18:00 21:30 3.50 7,786 g p Control, & Steam Clean Pits 21:30 22:30 1.00 7,786 7,786 PROD1 WELCTI BOPE P Test BOP's; Test Annular Preventer 250 - 3500 PSI, Upper Pipe Rams 250 - 5000 PSI. Jeff Jones, AOGCC, waived witnessing the BOP test. 22:30 23:00 0.50 7,786 7,786 PROD1 CEMEN" PULD P UD Test Tool 23:00 00:00 1.00 7,786 7,786 PROD1 WELCTL BOPE P Remove Wear Bushing, Pull Test Plug & Set Wear Ring 08/26/2008 Clean pits, P/U BHA for clean out run, TIH T/ 7552', Circulated & displaced mud w/ H2O 00:00 01:30 1.50 0 3,800 COMPZ RPCOM PULD P P/U BHA #5 FOR Clean out TRIP 01:30 03:30 2.00 3,800 3,800 COMPZ RPCOM TRIP P TIH W/ CLEAN OUT ASSEMBLY T/ 3777' 03:30 05:00 1.50 3,800 7,552 COMPZ RIGMNT SVRG P SLIP & CUT 106' OF DRILL LINE 05:00 08:00 3.00 7,552 7,552 COMPZ RPCOM TRIP P TIH F/ 3777' T/ 7235' 08:00 11:00 3.00 7,552 7,552 COMPZ RPCOM CIRC P REAM/WASH F/ 7235' T/ 7552' PR @ 8 BLLS /MIN, 1200 PSI, 60 RPM, 10/12K TORQ, PU 120K, SO 75K, ROT 92K. 11:00 11:30 0.50 7,552 7,552 COMPZ RPCOM TRIP P TOH F/ 7552' T/ 6472', 10 MIN FLOW CHECK 11:30 12:00 0.50 7,552 7,552 COMPZ RPCOM TRIP P TIH F/ 6472' T/ 7552' 12:00 13:30 1.50 7,552 7,552 COMPZ RPCOM CIRC P CIRCULATE & DISPLACE MUD W/ H2O @ 150 STKS /MIN, 336 GPM, 1200 -1300 PSI, RECIP DP, DW -76K, UW -132K 13:30 00:00 10.50 7,552 7,552 COMPZ RPCOM OTHR P STEAM CLEAN PITS, FLUSH LINES & CHOKE MANIFOLD, PULL BUSHINGS & CLEAN SAME, DRIP PAN, & FLOW LINES. CONDUCTED SPILL DRILL CRT -55 SECS. 08/27/2008 Clean pits, spot tanks & berm, RU MI Swaco, mix 10 bbls h20 w/ 3 ppg caustic, spotted BJ services and prepared for pickle job 00:00 06:00 6.00 7,552 7,552 COMPZ RPCOM OTHR P Clean Pits, Service Rig 06:00 12:00 6.00 7,552 7,552 COMPZ RPCOM OTHR P Spot Tanks, Build Berm, Mix 100 bbls H2O w/ 3 ppg Caustic & Thouroughly Flush All Surface Equipment, RU MI Swaco Filtration 12:00 18:00 6.00 7,552 7,552 COMPZ RPCOM OTHR P Continue Cleaning Pits, Build Berm For Brine Tanks, Conducted Spill Drill CRT -1 min. 18:00 00:00 6.00 7,552 7,552 COMPZ RPCOM OTHR P Continue Cleaning Pits, Ready Rig For Completion Work, Spot Brine Tanks 08/28/2008 Pickled DP, Caustic Washed Casing, Cleaned Pits & Prepared Mud Pits for 8.6 Brine Displacement. Brought 580 BBIs of 9 NTU brine on board. Page 16 of 37 1 Time .. �� \ / � \�y Date i;:t Dur' .t • • 9 !u Pt Cad- 11; T' j a men 00:00 04:30 4.50 7,552 7,552 COMPZ RPCOM RURD P Continue to RU Filtration Unit, Filter 300 bbls H2O < 10 NTU, & RU BJ T/ Pickle DP 04:30 05:00 0.50 7,552 7,552 COMPZ RPCOM SFTY P PJSM w/ BJ, MI Swaco, & Crew over Pickling DP w/ HCL 05:00 06:30 1.50 7,552 7,552 COMPZ RPCOM CIRC P Clean Out Mud System -BJ Pump 20 bbls Flo Vis, 10 bbls Safe Pickle, 13.09 bbls HCL, 67 bbls Filtered H2O @ 1.5 bbls /min. 06:30 08:00 1.50 7,552 7,552 COMPZ RPCOM CIRC P Clean Out DP - Reverse Out Pickle w/ Filtered H2O @ 2.6 bbls /min, 275 psi 08:00 12:00 4.00 7,552 7,552 COMPZ RPCOM OTHR P Clean Pits & Prep for Caustic Washing of Casing 12:00 14:00 2.00 7,552 7,552 COMPZ RPCOM CIRC P Displace T/ Completion Fluid, Put Filtered Brine f/ Swaco / Rig Pits, Mix Sweeps & Caustic Wash. 14:00 15:30 1.50 7,552 7,552 COMPZ RPCOM CIRC P PJSM, Pump Sweeps - 20 bbls Flo Vis, 75 bbls 12.5 Caustic, 75 bbls Safe Serf (Mixed with defoamer), 25 bbls Flo Vis © 142 stks /min, 315 gpm, 1200 psi 15:30 22:30 7.00 7,552 7,552 COMPZ RPCOM OTHR P Clean Pits of Flo Vis, Sweeps, Caustic, & Safe Serf(Defoamer added), Defoamer was preloaded in Vac truck. Conducted Fire Drill CRT - 1min 10 sec 22:30 00:00 1.50 7,552 7,552 COMPZ RPCOM OTHR P Change Out Mud System, Pumped 580 bbls of 8.6 Brine F/ Swaco Press Filters T/ Rig Pits. 08/29/2008 Displaced well to 8.6 ppg brine from fresh water. Tested the casing to 5,000 psi for 30 mins. Circulated, and filtered the brine in the wellbore to 9 NTU's going in, and 30 NTU's steady coming out. TOOH, laid down the casing clean out assembly. Rigged up SLB wireline truck, and ran CBUUSIT logs. Strap and rabbit 4.5" work string. 00:00 01:30 1.50 7,552 7,552 COMPZ RPCOM CIRC P Circulate and condition, Displace to 8.6 ppg brine, filtered completion fluid. Pump 265 BBLs @ 8 BBIs a minute. 1200 psi. 01:30 03:30 2.00 7,552 7,552 COMPZ RPCOM OTHR P Perform casing pressure test. Test with BJ cement truck. Pressure up to — 5000 psi, for 30 minutes. Good test. 03:30 09:00 5.50 7,552 7,552 COMPZ RPCOM CIRC P Circulate and condition, filtering the brine through SWACO press. Seven surface to surface volumes were pumped. NTU's in were 1 to 2, NTU's out were 30. 09:00 11:30 2.50 7,552 0 COMPZ RPCOM TRIP P Trip out of hole with BHA #5. Casing cleanout assembly. razor back, magnets. Trip from 7552' MD to 1300' MD. 11:30 12:00 0.50 0 0 COMPZ RIGMNT SVRG P Service topdrive. crew change 12:00 15:00 3.00 0 0 COMPZ RPCOM TRIP P Trip out of hole from 1300' MD to surface, lay down all tools. Retrieve 12.5 Ibs of casing shavings from magnets and boot baskets. Page 11 of 37 1 • ate _' To " r s Ito ..: c . • • = T " • ... \ 15:00 22:00 7.00 0 0 COMPZ EVALWE ELOG P Cased hole logging. CBUUSIT /Gamma ray. casino c9Jlar locator. 22:00 00:00 2.00 0 0 COMPZ EVALWE ELOG T Computers in logging unit froze up, due to excess logging speed. Had to drop back to down to bottom and relog coming up. 08/30/2008 Completed the cement bond logging run, set the Baker bridge plug @ 7500' MD. Pick up and trip in the hole with singles, 4.5" IBTM workstring. Pickle the work string with 13 BBLs of 15% HCL. 00:00 06:00 6.00 0 0 COMPZ EVALWE ELOG P Complete Slb wireline work with CBUUSIT tools. Rig up to run bridge plug, Baker tool. Conduct prejob, RIH with brides plug, and set A 7500m MD. Set @ 0500 HRS. POOH and R/D wireline. 06:00 07:00 1.00 0 0 COMPZ RPCOM PULD P Pepare to pick up 4.5" 12.6# IBTM tubing work string. 07:00 12:00 5.00 0 3,200 COMPZ RPCOM PULD P Pick up 4.5" 12.6# IBTM tubing work string down to 3200' MD. 12:00 15:00 3.00 3,200 5,000 COMPZ RPCOM PULD P Pick up 4.5" 12.6# IBTM tubing work string down to 5000' MD. 15:00 16:00 1.00 5,000 5,000 COMPZ RIGMNT SVRG P Service the top drive, draw works, crown. 16:00 22:00 6.00 5,000 6,781 COMPZ RPCOM PULD P Pick up 4.5" 12.6# IBTM tubing work string down to 6780.63' MD. 22:00 22:30 0.50 6,781 6,781 COMPZ RPCOM SFTY P Hole prejob safety meeting with BJ for pickle job. 22:30 00:00 1.50 6,781 6,781 COMPZ RPCOM CIRC P Pump 20 BBLs Vis pill spacer, followed by 13 BBIs of 15% HCL, then 88.5 BBLs of brine.@ 1.5 BPM. 08/31/2008 Reverse, circulate out the pickle job. Displace the brine in the wellbore with clean brine. Filter the brine to 25 NTU's coming out, & 2 to 5 NTU's •oing in. Rig up frac head, rig up BJ frac equipment. 00:00 00:30 0.50 6,781 6,781 COMPZ RPCOM CIRC P Complete pickle job, pump 13 BBIs of 15% HCL, followed by 88.5 BBLs filtered 8.6 ppg brine to within one barrel of mule shoe. 00:30 02:00 1.50 6,781 6,781 COMPZ RPCOM CIRC P Reverse circulate the pickle job out of the hole with rig pumps @ 2.6 BPM. 220 BBLs. Discard all annular fluid, high NTU's. 185 psi 02:00 05:30 3.50 6,781 6,781 COMPZ RPCOM CIRC P Circulate and condition 8.6 ppg brine the long way. Filter system to a steady 25 NTU's coming out. 05:30 07:00 1.50 6,781 6,781 COMPZ RPCOM NUND P Rig up BJ Frac head on rig floor. 07:00 11:00 4.00 6,781 6,781 COMPZ RPCOM RURD P Rig up Slumberger Lubricator system with BOP's on top of frac head. 11:00 12:00 1.00 6,781 6,781 COMPZ RPCOM SFEQ P Rig up to test, and conduct test of SLB lubricator to 1500 psi, for 10 mins. Page 48 "of 37" • • .. ;:.0�\ �• t.,tt �, t ; Dur 12:00 00:00 12.00 6,781 6,781 COMPZ RPCOM RURD P Rig up frac trucks, hard lines, cement truck, connect all units together, load 160,000 lbs of propant into BJ sand bulk trailer, heat 880 BBIs 8.6 ppg brine to 80 degs. Inspect all equipment for 1502's only. Inspect all lines for correct flow pattern. 09/01/2008 Rig up BJ Services, test all lines. Perforate @ 7238 to 7248' MD. 60 shots. 00:00 08:00 8.00 6,781 6,781 COMPZ RPCOM WOCC P Waiting on BJ Services crew. Rig maintainance, inspect derrick, lines, rig team cross training. 08:00 12:00 4.00 6,781 6,781 COMPZ RPCOM RURD P BJ Services, finish rig up, Slumberger prepare for perforation job, test fire head. Test lines. 12:00 13:30 1.50 6,781 6,781 COMPZ EVALWE ELOG P Prepare to run in the hole with guns on wireline. Rig up and place guns in lubricator. 13:30 16:00 2.50 6,781 6,781 COMPZ RPCOM RURD P BJ Services test lines to 6000 psi, test annulaus to 3500 psi. Test frac head to 6000 psi. 16:00 20:30 4.50 6,781 6,781 COMPZ EVALWE ELOG P Wireline run to 7248' MD. Beluga I formation. Close upper pipe rams, hold 450 psi on annulus, fire guns, 10 feet of quns. 60 shots. POOH with guns, brake lubricator apart to verify guns fired. Spent guns. 20:30 00:00 3.50 6,781 6,781 COMPZ RPCOM GRVL P Perform 8 step initial rate study. Perform frac model formation injection study, pump 20 BBL viscous pill, flush with 220 BBLs brine. Pump rate 15.2 BPM, pressure 3100 psi, ISIP = 1950 psi. Build model for first frac and sand pack job. 09/02/2008 Complete first gravel pack job. Sanded off after 37,000 lbs of propant had been pumped. Reversed out 10,000 lbs through choke, and gas buster, then over shakers. Shut down to let BJ rest. Performed second perforation job @ 6999 to 7008' MD. Begin second frac ob in the Beluga I formation. 00:00 03:00 3.00 6,781 6,781 COMPZ RPCOM GRVL P BJ Services frac Beluga I formation. Perf zone #1 7238 to 7248' MD. Pump rate 15 BBL/min, pump 37,000 lbs propant, screened out with 10,000 lbs inside workstrina. Pump pressure while pumping 2323 psi. Packed off to 4100 psi annular pressure. Stop prepare to reverse out. Page 19 of 37 • • D, :kF t T . D _ ;v ,` aw 4 ' 1 �� «® T y 6o1'r1 "\ 03:00 06:00 3.00 6,781 6,781 COMPZ RPCOM GRVL P Reverse circulate through Degasser, over shakers w/ BJ. Pump @ 3BPM, Pumped @ 800 psi, 116 BBIs. Poor Boy packed off. Shut down. Shut in well monitor pressures for 30 mins, (Ann. P= 1546. Tubing P= 1190) clear sand w/ vac truck in 15 mins. Pump 30 more barrels until all propant out of workstring. Shut in well, monitor pressures. 30 mins. Ann. P =1350, tubing P= 1020. 06:00 10:00 4.00 6,781 6,781 COMPZ WELCTLWOCC P Well Control. Monitor annular and workstring pressures while BJ frac Team rests. Rig maintainance. SITP= 880psi. SICP= 1125psi. Stable. 10:00 12:00 2.00 6,781 6,781 COMPZ EVALWE ELOG P Wireline w/ Schlumberger. Verify sand height with spent guns from 1st pert job. Run in hole to top of sand @ 7060' MD. 12:00 14:00 2.00 6,781 6,781 COMPZ WELCTL WOCC P Monitor well. Wait on BJ frac Team. 14:00 15:00 1.00 6,781 6,781 COMPZ WELCTL SFTY P Safety stand down meeting due to 4 spills in 48 hours. 15:00 19:30 4.50 6,781 6,781 COMPZ EVALWE ELOG P Rig up with SLB WL. Perforation #2 6999 to 7008' MD. Perf. Pull out into the lubricator. Verify guns are spent. 19:30 00:00 4.50 6,781 6,781 COMPZ RPCOM GRVL P Frac job #2. Perform pressure test to 2000 psi to FOSV. Perform initial step frac test. Perform modeling test with Viscous pill. Build model for full fracture job. 09/03/2008 Frac job #2, sanded off with 16,500 lbs of proppant away. Reversed out 18,000 lbs. Shut in well, monitor for 30 mins. Pressures equalized at 700 psi. Circulated through kill and choke line into choke manifold with lower pipes closed. Flushed each valve. rig down SLB. Kill well. Trip out 369 feet, lay down 12 joints of work string. Position mule shoe for two more frac jobs. Displace 10.2 ppg out with the 8.6 ppg filtered brine. 775 psi seen from formation with light brine all the way around. Rig up and test SLB lubricator, Test BJ lines, Hold safety meeting with SLB. Prepare to load _guns. 00:00 01:30 1.50 6,781 6,781 COMPZ RPCOM GRVL P Gravel pack job #2 6999 -7008' MD. Pumped away 764BBLs @ 15 BPM, placed 16,500 lbs of propant in the formation. Sanded out with 18,000 lbs still in the workstring. Reverse circulate out 151 BBLs. 103 BBLs =100% of tubing volume. Shakers cleaned up. 01:30 04:00 2.50 6,781 6,781 COMPZ WELCTL OWFF P Monitor well. 700 psi SITP, 700 psi SICP. Flush all lines on surface, clear out sand from valves in choke house, mud lines, kill line, choke line, remove ceramic propant from cuttings tank. Prepare wireline in the well to tag top of sand. 04:00 08:30 4.50 6,781 6,781 COMPZ EVALWE ELOG P Run in the wellbore with spent guns to tag top of sand. Top found @ 6891' MD. Pull out and rig down SLB WL. Page 20of37 '_ • • 111 \\ \: From TT3' r••' (sth %;a s - s s sx _ 4A0.: 08:30 11:30 3.00 6,781 6,781 COMPZ WELCTL KLWL P Kill well. Pump 10.2 ppg kil brine CACL @ 3.5 BPM. Drillers Method. Hold 700 psi on casing side. Secure well, 30 min flow check. 11:30 12:00 0.50 6,781 6,781 COMPZ WELCTL NUND P Rig down frac head, rig up Weatherford to lay down 12 joints of the 4.5" workstring. 12:00 14:00 2.00 6,781 6,781 COMPZ WELCTL CIRC P Circulate 1.5 x's bottoms up. No gas seen. 14:00 16:00 2.00 6,781 6,411 COMPZ WELCTL TRIP P Lay down the top 12 joints of the workstriny. Placing the muleshoe Ca)_ 6411' MD. 16:00 17:00 1.00 6,411 6,411 COMPZ RPCOM NUND P Rig up frac head and rig floor hard lines to prepare to displace kill mud out of the wellbore. 17:00 18:30 1.50 6,411 6,411 COMPZ RPCOM CIRC P Circulate @ 3.5 BPM, Use Drillers Method. Displace 10.2 ppg with 8.6 ppg filtered brine. 65 spm 725 psi final pressures. Secure well. Monitor pressures. 18:30 22:30 4.00 6,411 6,411 COMPZ EVALWE RURD P Hold prejob with SLB and BJ Services. Rig up lubricator with Schlumberger wireline team. Test lubricator to 2,000 psi for 15 mins. Rig up BJ services rig floor hardlines to perform fracture #3. Test lines to 6,000 psi. All lines good. 22:30 22:45 0.25 6,411 6,411 COMPZ EVALWE SFTY P Hole prejob with Schlumberger to load perforation guns. 20 feet of guns. 22:45 00:00 1.25 6,411 6,411 COMPZ EVALWE ELOG P Load guns, make up firing head .Place guns in the lubricator, pressure up to 500 psi above master valve to equalize pressure. RIH with guns. Crew change. 09/04/2008 Perf #3 6795 - 6815. 20 feet 6 shots per foot. 120 shots. Frac Zone #3. 47k of proppant, 878 BBLs of brine. Monitor pressures, load sand king. 00:00 01:30 1.50 6,413 6,413 COMPZ EVALWE ELOG P Wireline run w/ SLB to locate top of sand @ 6824'. Target pert zone of 20 feet was covered 15 feet. 01:30 05:30 4.00 6,413 6,413 COMPZ EVALWEWOOR X Completion Engineers study the zone immediately above the original zone #3 to determine if a pert /frac job would be economical. Yes they decided. 05:30 07:00 1.50 6,413 6,413 COMPZ EVALWE ELOG P Release BJ Services to get 9 hours of sleep. Perforate Zone #3. 20 feet of guns. 6 shots per foot. 120 shots total. 6795 to 6815. After shots were fired the WL was pulled into the lubricator, and the guns were confirmed to be shot. Spent guns. 07:00 12:00 5.00 6,413 6,413 COMPZ WELCTL WOCC P Well closed in. Monitor pressures. SITP= 600psi, SICP= 500psi. Page 21 of 37 • �... r�e - ub T C4.14 ment 12:00 15:00 3.00 6,413 6,413 COMPZ WELCTLWOCC P Well closed in. Monitor pressures. SITP= 600psi, SICP= 500psi. SWACO building the final volumes for frac job, 10.4 brine and filling the rig tanks. All tanks topped off. Heated 1200 BBLs of 8.6 PPG. 15:00 22:00 7.00 6,413 6,413 COMPZ RPCOM GRVL P BJ Services back on location. Hold prejob. Perform initial step test with 58 BBLs. Perform 'mini frac' with 200 BBLs brine. Build model. Perform frac lob #3. Pump 47,000 Ibs of proppant away with 620 BBLs of 8.6 ppg heated brine. Good job. All goals met. Sand in place. 22:00 00:00 2.00 6,413 6,413 COMPZ RPCOM P Load 14 sacks (3200 lbs each) into Sand King. Release BJ Services. Monitor well. Well secure. ISITP =1900 psi, down to 1320 at midnight. ISICP =1900 psi, down to 1220 at midnight. Crew change. 09/05/2008 Monitor well after frac job #3. Run Schlumberger WL to verify sand height. Top of sand from job #3 was 6774' MD. WL perforate zone #4. Two 20 foot guns. 6655 - 6675, 6629 - 6649' MD. Rig down Schlumberger. Perform step test with BJ Services frac Team, followed by a 200 BBL 'mini frac' for modeling. Run frac model, and perform frac job #4. 00:00 03:00 3.00 6,413 6,413 COMPZ WELCTL OWFF P MonitoUhe well. Allowing frac job #3 _ sand volume to settle out. SICP =920, SITP =1000. 03:00 03:15 0.25 6,413 6,413 COMPZ EVALWE SFTY P Prejob meeting with Schlumberger. Discuss WL operations, and equalizing the pressure to the lubricator with the test pump. 03:15 07:00 3.75 6,413 6,413 COMPZ EVALWE ELOG P Equalize pressure with rig test pump. 900 psi. RIH with WL, and dummy gun. tag top of sand @ 6774' MD. POOH. 07:00 12:00 5.00 6,413 6,413 COMPZ EVALWE ELOG P Safety meeting w/ SLB live guns. Pick up 20 feet of guns. RIH to Zone 4a.6655 - 6675'. Perforate. 6 shots /ft. POOH. Verify gun was spent, Load new 20 foot gun. RIH. 12:00 16:00 4.00 6,413 6,413 COMPZ EVALWE ELOG P Perforate Zone 4b.6629'- 6649'. 6 shots /ft. POOH, verify gun was spent. 16:00 16:30 0.50 6,413 6,413 COMPZ RPCOM SFTY P Prejob safety meeting with BJ Services for frac job #4. 16:30 21:30 5.00 6,413 6,413 COMPZ RPCOM GRVL P Hydraulic fracture, gravel pack. Step test with 17 BBLs. followed by a 'mini frac' with 200 BBLs. Main frac job for Zone 4. pumped 65k lbs. of proppant, and 893 BBLs heated 8.6 _ppg brine. Good job.ISIP =2452 psi. 21:30 00:00 2.50 6,413 COMPZ WELCTL OWFF P Rig down BJ Serives. Monitor wellbore pressures. Midnight:SITP =700, SICP =550. Crew change. Page 22 of 37 "`' • Frs Dur a% : ase e Com fl1' 09/06/2008 24 hr Su ry mma Kill the well with the 10.4 ppg, rig down frac head, lay down top joint of 15# tbg., trip to CIBP, reverse circulate all sand out of wellbore. 00:00 01:30 1.50 6,413 6,413 COMPZ WELCTL OWFF P Monitor well bore pressures after frac job #4. SITP =625, SICP =500 psi. 01:30 02:00 0.50 6,413 6,413 COMPZ WELCTL SFTY P Conduct prejob meeting. Well kill proceedure. Drillers Method. 10.4 ppg kill weight to be used. 02:00 04:00 2.00 6,413 6,413 COMPZ WELCTL KLWL P Displace 8.6 ppg brine out of the hole w/ 10.4 ppg. ICP =850, FCP =325. 04:00 04:30 0.50 6,413 6,413 COMPZ WELCTLOWFF P Well Kill complete. No pressure. The hole began to take 18 BBLs per hour static. 04:30 06:30 2.00 6,413 6,413 COMPZ RPCOM NUND P Rig down frac head, and lay down top cross over joint of 15# tubing. cross over to HT 38 drill pipe. 06:30 07:00 0.50 6,413 6,413 COMPZ RPCOM RURD P Rig up to reverse circulate the proppant inside the casing out of the wellbore. 07:00 07:30 0.50 6,413 6,413 COMPZ RPCOM SFTY P Conduct prejob meeting. Reverse circulation. 07:30 12:00 4.50 6,413 6,857 COMPZ RPCOM CIRC P Reverse circ. from 6412' to 6857' MD. Top of sand found a. 6628' MD. 6 BPM 565 psi. UP Wt= 98k, DN Wt= 55k. 12:00 15:00 3.00 6,857 7,238 COMPZ RPCOM CIRC P Reverse circ. from 6857' to 7238' MD. 110spm, 6 BPM 565 psi. UP Wt= 98k, DN Wt= 55k. 15:00 17:00 2.00 7,238 7,238 COMPZ RPCOM CIRC P Stop going in to build volume back up. Circulate above the sand, build saved 8.6 brine up to 10.4. Two batches of 90 barrels each. 17:00 19:00 2.00 7,238 7,333 COMPZ RPCOM CIRC P Reverse circ. from 7238' to 7333' MD. 110spm, 6 BPM 565 psi. UP Wt= 98k, DN Wt= 55k. 19:00 21:00 2.00 7,333 7,333 COMPZ RPCOM OWFF P Clean SWACO filter press. Repack diatomaceous earth , and build one batch of 90 BBLs. Losses 9 BBIs per hour. 21:00 00:00 3.00 7,333 7,500 COMPZ RPCOM CIRC P Reverse circ. from 7238' to 7333' MD. 110 spm, 6 BPM 525 psi. UP Wt= 98k, DN Wt= 55k. Loss rate while Pumping 50 to 60 BBIs /hr� 09/07/2008 Finish reversing all the sand out, POOH to tubing, LD 67 joints, stand back 47 stands, PU Halliburton TCP guns, TIH, fill each stand, 1249' of pipe will be dry, 00:00 00:30 0.50 7,500 7,500 COMPZ RPCOM CIRC P Reverse circulate, clean out sand from work string. Build volume with SWACO mix tank. 12 BBUhr loss static. 25 BBLs /hr pumping 5 BPM. 00:30 02:00 1.50 7,500 7,500 COMPZ RPCOM CIRC P Reverse circulate two tubing volumes. Shakers cleaned up. 5 BPM 425 psi. 40 BBI /hr loss rate, while pumping,,,„, 02:00 02:30 0.50 7,500 7,500 COMPZ WELCTL OWFF P Observe well for 30 mins. 12 BBI /hr loss rate. 02:30 03:00 0.50 7,500 6,570 COMPZ RPCOM TRIP P POOH from 7500 to 6570' MD. Above pert. zones. Page 23 of 37 • • From Tom; Dur c Ph S . ' . ` O om °Tim 03:00 04:30 1.50 6,570 6,570 COMPZ RPCOM CIRC P Build loss circulation pill as per wellplan. HEC pill. 25 BBL. Spot pill with 3 barrels still inside tubing. Prepare to trip out. 04:30 05:00 0.50 6,570 6,380 COMPZ RPCOM TRIP P Trip out two more stands to the top of the 4.5" workstring. 05:00 05:30 0.50 6,380 6,380 COMPZ RPCOM SFTY P Prejob safety meeting with Weatherford to lay down 4.5" tubing. 05:30 08:00 2.50 6,380 4,325 COMPZ RPCOM TRIP P Lay down 67 joints of 4.5" TBG. 08:00 10:30 2.50 4,325 0 COMPZ RPCOM TRIP P Stand back 47 stands on Drillers side. 4.5" TBG. 10:30 11:00 0.50 0 0 COMPZ RPCOM RURD P Rig down power tongs, change out handling equipment. 11:00 11:30 0.50 0 0 COMPZ RPCOM SFTY P Prejob safety meeting with Halliburton TCP hands. Discuss live guns, perforation process, and all safety aspects of picking up the BHA. 11:30 12:00 0.50 0 65 COMPZ RPCOM PULD P Pick up TCP BHA to 65' as per Halliburton reps. Crew change. 12:00 17:00 5.00 65 1,543 COMPZ RPCOM PULD P Pick up TCP BHA to 1543' as per Halliburton reps. 17:00 00:00 7.00 1,543 6,125 COMPZ RPCOM TRIP P Trip in the hole with 4" HT 38 drill pipe. Fill each stand. Up WT= 75k, Dn WT= 52k. Stand 48. 09/08/2008 Trip in the hole with the TCP guns. RU and run WL to correlate on depth. RD WL. position the guns, fire, reverse out one TBG vol, and then pull 15 feet to release packer, pump two BU the long way. Monitor well, pump Lost circ, HEC pill (30 BBLs), trip out of the hole, lay down the TCP guns. 00:00 02:00 2.00 6,125 7,266 COMPZ RPCOM TRIP P Trip in the hole with TCP guns (Run #1). Stop filling on stand #48, runin to stand #60. 12 stands dry for under balance. , 02:00 02:15 0.25 7,266 7,266 COMPZ RPCOM SFTY P Prejob safety meeting with SLB for WL run. 02:15 03:30 1.25 7,266 7,266 COMPZ EVALWE RURD P Rig up with SLB. PU floor valve, XO to lubricator. Stand up lubricator, and sheaves. 03:30 05:30 2.00 7,266 7,266 COMPZ EVALWE ELOG P Wireline run to correlate for TCP firing position. Adjust 14 feet uQ. 05:30 06:30 1.00 7,266 7,266 COMPZ EVALWE RURD P Rig down SLB wireline, lubricator, sheaves, lay down, XO. 06:30 07:00 0.50 7,266 7,266 COMPZ RPCOM PULD P LD 1 jt. 4" DP. PU 15' pup, TIW, 5' pup, head pin. 07:00 07:30 0.50 7,266 7,248 COMPZ RPCOM PACK P Space out to required depth, 7248' MD Set packer in tension, set down 30k to verify. 07:30 08:00 0.50 7,248 7,248 COMPZ RPCOM SFTY P Prejob safety meeting for perforation. 08:00 08:30 0.50 7,248 7,248 COMPZ RPCOM RURD P Line up BJ Servies to pump down annulus to fire guns, test to 4,000 psi. Good Page 24 of 37 • • -: logs ¢ `. i U r E ys f __ 1� !. .:Cod [��• s C T •m v 08:30 09:30 1.00 7,248 7,248 COMPZ RPCOM PERF P Pressure up to 2800 psi W/ BJ, Positive indication guns fired. (a7_ 08:35. 14 SPF. 314 feet of guns. Big Hole shots. (Top perf. @ 5968, bottom perf A 7248) PU 5' to open circ. port. REV. circulate. S to S @ 6 BPM. 600 psi. Super choke wide open, 09:30 12:00 2.50 7,248 7,233 COMPZ RPCOM CIRC P Pick up 15' to unseat packer, RD Reverse Circ. equipment. Pump the long way 2 surface to surface volumes. 450 psi, well flowing. 12:00 12:30 0.50 7,233 7,233 COMPZ RPCOM CIRC P Crew change Circulate. Finish last circulation. 12:30 13:00 0.50 7,233 7,233 COMPZ WELCTL OWFF P Observe well bore. Losing 10 _BBLs /hour. 13:00 13:30 0.50 7,233 7,233 COMPZ WELCTL CIRC P Spot HEC lost circulation pill on bottom. 30 BBLs. 13:30 18:00 4.50 7,233 1,829 COMPZ RPCOM TRIP P Trip out of the hole from 7233' to 1829' MD. 18:00 20:00 2.00 1,829 1,542 COMPZ WELCTLOWFF P Stop tripping when hole fill was inadequate. Observe well flowing gun gas, allow the next 4 stands to vent and relax for 15 mins per stand. Each stand the gas slowed and well, began losing fluid. Hole fill volumes. recorded 5 to 8 BBUhr loss, but still . alot of gas each gun. 20:00 20:15 0.25 1,542 1,542 COMPZ RPCOM SFTY P Prejob safety meeting with Halliburton. Laying down TCP guns. Sand seen inside TCP guns. 20:15 00:00 3.75 1,542 500 COMPZ RPCOM PULD P Lay down BHA as per Halliburton. Get to gun # 34. (Note simultaneous operation, test BOP's, test in choke house. See remarks for details. 09/09/2008 Finish laying down TCP guns. Test BOPE -lower pipe rams, blind rams and annular preventer to 250 psi /3500 psi and upper pipe rams to 250/5000 psi. Make up clean out assembly and run in the hole to 5847'. Ream through perforations from 5847' to 7315'. Pull out of the hole to 2506'. 00:00 03:00 3.00 500 0 COMPZ RPCOM PULD P Continue laying down TCP guns from 615'. Clear floor and monitor well -minor losses 03:00 04:30 1.50 0 0 COMPZ WELCTL OTHR P Rig up BOP test equipment.. Set test plug 04:30 11:00 6.50 0 0 COMPZ WELCTL BOPE P Test lower pipe rams, blind rams and annular preventer to 250 psi low and 3500 psi high. Test upper rams to 250 psi low and 5000 psi high. Lou Grimaldi, AOGCC, waived witnessing BOP test. Had to repair valve #9 on the choke manifold. 11:00 11:30 0.50 0 0 COMPZ WELCTL OTHR P Rig down test equipment and pull test plug 11:30 12:00 0.50 0 0 COMPZ WELCTL OTHR P Install wear bushing with 6.375" i.d. Run in lockdown screws. 12:00 12:30 0.50 0 503 COMPZ RPCOM PULD P Make up cleanout assembly (Flat bottom mill, string mill, and junk basket) Page 25 of 37 F ` ' $ a : . ' ; r .. a - Phase • v , , ' b«.. ` \ om . \: 12:30 17:00 4.50 503 5,847 COMPZ RPCOM TRIP P Run in the hole from 503' to 5847' with cleanout assembly 17:00 20:00 3.00 5,847 7,315 COMPZ RPCOM FCO P Ream with clean out assembly from 5847' to 7315' without pumping. Rotate at 60 rpm. 20:00 00:00 4.00 7,315 2,506 COMPZ RPCOM TRIP P Trip out of the hole from 7315 to 2506' 09/10/2008 Finish pulling out of the hole and lay down clean out assembly and HWDP. While picking up sump packer, slips on packer broke. Made up back up sump packer and ran in the hole. Rigged up a -line and correlated depth of sump packer to openhole logs. Rigged down a -line and rigged up cementing unit. Set packer with 2500 psi and sheared off top of sump packer. Top of sump packer set at 7254' WLM. Pulled out of the hole with setting tool from 7254' to 5933'. 00:00 01:00 1.00 2,506 480 COMPZ RPCOM TRIP P Trip out of the hole from 2506' to 480' 01:00 02:30 1.50 480 0 COMPZ RPCOM PULD P Laydown 4" HWDP and clean out assembly. Clear rig floor 02:30 03:00 0.50 0 0 COMPZ RIGMNT SVRG P Service rig and top drive 03:00 05:30 2.50 0 211 COMPZ RPCOM PULD P Attempt to pickup sump packer. Broke slips on sump packer. Made up back up packer 05:30 15:30 10.00 211 7,303 COMPZ RPCOM TRIP P Run in the hole with sump packer on drill pipe from 211' to 7303' 15:30 21:30 6.00 7,303 7,252 COMPZ RPCOM HOSO P Rig up a -line and correlate packer placement to openhole logs. Pull out of the hole with a -line and pull out of the hole with drill pipe to 7254 dpm. Rig up a -line and verify correlation. Pull out of the hole with a -line and pull up to 7252' dpm. P/U 112k, S/O 72k. Rig down a -line 21:30 22:30 1.00 7,252 7,254 COMPZ RPCOM RURD P Drop setting ball and rig up cementing unit. Test lines to 3500 psi. Pressure up on drill pipe to 2500 psi. Pick up to 118k and shear off top of packer. Top of packer set at 7254' WLM. 22:30 00:00 1.50 7,254 5,933 COMPZ RPCOM TRIP P Trip out of the hole with packer setting tool from 7254' to 5933'. 09/11/2008 Trip out of hole and laydown packer setting tool. Pick up gravel pack screens and 2 -7/8" inner string and run in the hole to 3376' 00:00 03:00 3.00 5,933 18 COMPZ RPCOM TRIP P Trip out of the hole from 5933' to 18' 03:00 03:30 0.50 18 0 COMPZ RPCOM PULD P Lay down packer setting tool and clear rig floor 03:30 04:00 0.50 0 0 COMPZ RIGMN1 SVRG P Service top drive and rig 04:00 05:00 1.00 0 0 COMPZ RPCOM RURD P Rig to run gravel pack screens 05:00 19:00 14.00 0 1,422 COMPZ RPCOM PULD P Pick up gravel pack screens. Rig up and pick up 2 -7/8" Hydril 511 inner string. Make up packer and crossover 19:00 20:30 1.50 1,422 1,422 COMPZ RPCOM OTHR P Telecom hand working on antenna in derrick while BJ was loading sand silo. Page 26 of 37 • 'Time Legs \ bate,; From ,Our ,: S. Dept.. stti Phe N � a:.e \ \. T CorO 20:30 00:00 3.50 1,422 3,376 COMPZ RPCOM TRIP P Trip in the hole from1422' to 3376' at 3 minutes per stand. 09/12/2008 Run in the hole with gravel pack assembly. Latch into sump packer. Test lines and establish circulation and injection rates. Gravel pack lower interval with 22000 Ibs of sand. Reverse out and monitor well. Initially losing 72 bph. Rate decreased to 40 bph. Pulled out of the hole and closed KOIV valve. Losses stopped. Pulling out of the hole with gravel pack assembly 00:00 05:00 5.00 3,376 7,220 COMPZ RPCOM TRIP P Trip in the hole with Baker gravel pack assembly and screens from 3376' to 7220'. 05:00 07:30 2.50 7,220 7,254 COMPZ RPCOM RURD P Make up TIW valve and crossover. Space out to 7254'. Set down 10k and latch into sump packer. Overpull 8K to unlatch. Latch back into sump packer. Left 5K on sump packer 07:30 09:30 2.00 7,254 7,254 COMPZ RPCOM RURD P Rig up BJ hardlines 09:30 10:00 0.50 7,254 7,254 COMPZ RIGMNT SVRG P Service rig 10:00 11:00 1.00 7,254 7,254 COMPZ RPCOM OTHR P Inspect all lines while working on communications system 11:00 11:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Prejob safety meeting on gravel pack operations 11:30 16:30 5.00 7,254 7,254 COMPZ RPCOM GRVL P Check lines. Test lines to 6000 psi. Drop ball and set packer, P/U 140k and S/O 52k to vefiry packer set. Test annulus to 2000 psi. Reverse out setting ball. Establish reverse point and circulating point. 16:30 17:30 1.00 7,254 7,254 COMPZ RPCOM GRVL P Establish rate of 12.2 bpm at 2240 psi with 3.2 bpm returns. Establish injection rate of 12 bpm @ 2160 psi 17:30 19:30 2.00 7,254 7,254 COMPZ RPCOM GRVL P Pickup and shear out FAS tool. Spot 50 bbl brine in drill pipe and set tool in circulating position. Peform gravel pack at 12 bpm @ 1920 psi. Reduced rate to 8 bpm @ 1050 psi and pumped flush. Screened out at 4000 psi. Picked up and reversed out sand. Placed approximately 22000 Ibs of sand behind screens. 19:30 21:00 1.50 7,254 7,254 COMPZ RPCOM RURD P Rig down treating lines and laydown one joint of drill pipe with TIW valve and crossover 21:00 22:30 1.50 7,254 7,254 COMPZ RPCOM OWFF P Observed well. Initially losing 72 bph. Losses decreased to 40 bph. Working on communication system 22:30 23:30 1.00 7,254 7,254 COMPZ RPCOM RURD P Change out bales and break out TIW valve and crossover 23:30 00:00 0.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of hole and closed Knock Out Isolation Valve. Losses stopped 09/13/2008 Pull out of the hole with innerstring to 5785'. Close Hydril and strip through to close KOIV. Monitor well- static. Pull out of the hole and laydown packer running tool. Rig up and laydown 2 -7/8" innerstring. Load pipe rack and pick up isolation string and packer. Run in the hole and break through KOIV. 00:00 01:00 1.00 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole from 5957' to 5785'. Close Hydril and IBOP. Strip through Hydril to close KOIV. Monitor well. Static Page 27 of 37 Ti 'ate ' m \��, �� ��'� Date tiol t : ' t _ Code ± code wiment a 01:00 02:30 1.50 7,254 7,254 COMPZ RPCOM RURD P Change out handling equipment. Rig down crossover, TIW valve and pump -in sub from gravel pack operations. 02:30 04:30 2.00 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole from 5785' to 1468' 04:30 05:00 0.50 7,254 7,254 COMPZ RPCOM PULD P Lay down packer running tool and monitor well. Static 05:00 06:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Pre -job safety meeting. Rig up to laydown 2 -7/8" tubing 06:00 08:00 2.00 7,254 7,254 COMPZ RPCOM PULD P Laydown 1468' of 2 -7/8" tubing 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM RURD P Clear rig floor and lay down 2 -7/8" P -110 pups 08:30 09:00 0.50 7,254 7,254 COMPZ RIGMNT SVRG P Service top drive and rig 09:00 10:00 1.00 7,254 7,254 COMPZ RPCOM OTHR P Load pipe rack with isolation assembly 10:00 10:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Pre job safety meeting on running isolation assembly 10:30 16:00 5.50 7,254 7,254 COMPZ RPCOM PULD P Pick up 2 -7/8" 6.4# L -80 Hydril 511, tubing and seal assemblies. Rabbit tubing with 2.75" drift. Check seals. Pick up packer. 16:00 16:30 0.50 7,254 7,254 COMPZ RPCOM RURD P Laydown tubing tongs, beckett bales, elevators and rig up to run in hole with drill pipe 16:30 00:00 7.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole with isolation assembly. Drift drill pipe out of the derrick. Break through KOIV. 09/14/2008 Run in the hole and set isolation assembly. Pull out of the hole and laydown setting tool. Pick up TCP gun and run in the hole. Rig up and set packer. Fire TCP guns and reverse out two drill pipe volumes. 00:00 01:00 1.00 7,254 7,254 COMPZ RPCOM TRIP P Trip in hole with isolation assembly from 6465' to 7226' 01:00 01:30 0.50 7,254 7,254 COMPZ RPCOM PACK P Snap into snaplatch with 10k down. Snap out with 12 k overpull. Set down and leave 5k compression on packer 01:30 02:00 0.50 7,254 7,254 COMPZ RPCOM SFTY P Safety meeting on setting packer 02:00 03:30 1.50 7,254 7,254 COMPZ RPCOM PACK P Set packer hydraulically in stage at 1900 psi, 2500 psi, 3100 psi, 5 minutes per stage. Test tubing by casing annulus to 2000 psi for 20 minutes -ok. Pull up to 130k to release without success. Mechanically release from packer 03:30 05:00 1.50 7,254 7,254 COMPZ RPCOM CIRC P Displace well with 8.6 ppg filtered KCI brine. Monitor well for 30 minutes- static 05:00 07:00 2.00 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole with packer setting tool 07:00 07:30 0.50 7,254 7,254 COMPZ RPCOM PULD P Laydown packer setting tool and clear floor 07:30 08:00 0.50 7,254 7,254 COMPZ RIGMNT SVRG P Service rig 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM RURD P Rig up to pick up TCP guns Pag28of37 • • t h E. u i b Gcmment Date , _ ��� , '•' ': ,.� � � ��� : o... • . �. �,� «.. , , �. ... 08:30 12:00 3.50 7,254 7,254 COMPZ RPCOM PULD P Pickup 4 -5/8" 14 spf, Bh perf gun assembly 12:00 13:30 1.50 7,254 7,254 COMPZ RPCOM PULD P Make up Champ packer, jars, R/A marker sub 13:30 21:00 7.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in hole to 5777'. Fill 27 stands with water. Verify on depth. 21:00 22:30 1.50 7,254 7,254 COMPZ RPCOM PERF P Rig up lines and test to 4000 psi. Set packer. Close annular and pressure up annulus to 500 psi. Close pipe rams and detonate charges with 2500 psi at 22:30 hours. Perforated 4,656 to 5,763'. Had good blow in bottom of bubble bucker. Bleed annulus pressure to 500 psi and open pipe rams. 22:30 23:30 1.00 7,254 7,254 COMPZ RPCOM CIRC P Open bypass on packer and reverse out two drill pipe volumes. 23:30 00:00 0.50 7,254 7,254 COMPZ RPCOM RURD P Rig down reversing lines and laydown top joint of drill pipe. Losing 10 bph 09/15/2008 Pull out of the hole with TCP assembly. Make up Clean out assembly and run in the hole to 4430'. Rotate clean out assembly through perforations without pumping from 4430' to 5762'. Pull out of the hole and lay down cleanout assembly. Make up Cavins bailer andrun in the hole. 00:00 06:00 6.00 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole from 5777' to 1308' 06:00 06:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Pre job safety meeting on laying down p erforatin 9 assembly 06:30 10:00 3.50 7,254 7,254 COMPZ RPCOM PULD P Laydown TCP assembly. All shots. fired 10:00 10:30 0.50 7,254 7,254 COMPZ RPCOM RURD P Laydown TCP tools and cler rig floor 10:30 11:00 0.50 7,254 7,254 COMPZ RIGMN7 SVRG P Service rig and top drive 11:00 11:30 0.50 7,254 7,254 COMPZ RPCOM PULD P Make up cleanout assembly with mills and junk basket 11:30 14:00 2.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole with cleanout assembly from 1275' to 4430' 14:00 16:30 2.50 7,254 7,254 COMPZ RPCOM FCO P Trip in hole from 4430' to 5762'. Rotate at 60 rpm with no pump 16:30 19:30 3.00 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole from 5762' to 37' with cleanout assembly 19:30 20:00 0.50 7,254 7,254 COMPZ RPCOM PULD P Laydown cleanout assembly) 20:00 22:00 2.00 7,254 7,254 COMPZ RPCOM PULD P Pick up Cavins bailer assembly 22:00 00:00 2.00 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole to 4609' with Cavins bailer 09/16/2008 Trip in the hole to 5771' and attempt to bail fill without success. Pull) out of the hole and redress bailer. Cut and slip 98' of drilling line. Make up bailer and run in the hole to 5771' and attempt to bail fill and retrieve plug without success. Pull out of the hole and redress bailer and run back in the hole to 5771' 00:00 01:00 1.00 7,254 7,254 COMPZ RPCOM TRIP P Trip in hole with Cavins bailer from 4609' to 5751' 01:00 02:00 1.00 7,254 7,254 COMPZ RPCOM OTHR P Taq fill at 5765'. Make several attempts to function bailer with out success. Unable to move pipe. Pick up 30k over and apply 10k ft-Ibs torque to break free from fill /debris. U -tubed 12 bbl through bailer Pag 29of37 • • Da ...� �, �" ��..., DuC`: �...' .�ftfl' E.a�<. : .tom... N :± .. Uba.o ". Com 02:00 05:30 3.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of hole with bailer 05:30 06:00 0.50 7,254 7,254 COMPZ RPCOM PULD P Lay down bailer assembly. Sand and perf debris plugged bailer. Clear rig floor 06:00 07:30 1.50 7,254 7,254 COMPZ RIGMNT SVRG P Slip and cut 98' of drilling line. 07:30 08:00 0.50 7,254 7,254 COMPZ RIGMNT SVRG Service Top Drive. 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM PULD P Makeup Cavins bailer assembly 08:30 13:00 4.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole with bailer to 5771' 13:00 13:30 0.50 7,254 7,254 COMPZ RPCOM OTHR P Attempt to bail fill off plug at 5771' 13:30 18:00 4.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole with bailer 18:00 20:30 2.50 7,254 7,254 COMPZ RPCOM PULD P Laydown bailer and rebuild. Bailer plugged with 2 -3 gallons of perf debris and sand 20:30 00:00 3.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole with bailer at 2 min. /stand to 5771' 09/17/2008 Worked bailer from5770' to 5775'. Unseated plug. Pulled out of the hole. Recovered plug. Made up gravel pack screens, 2 -7/8' inner string and 1.900" inner string. Testing innerstrings. 00:00 00:30 0.50 7,254 7,254 COMPZ RPCOM OTHR P Tag debris at 5770 and set down to trip bailer. Work down to 5775'. Bailed 3.5 bbl. Picked up 13k over string weight to unseat packer plug. 00:30 05:30 5.00 7,254 7,254 COMPZ RPCOM TRIP P Monitor well. Pull out of the hole from 5775' 05:30 06:30 1.00 7,254 7,254 COMPZ RPCOM PULD P Laydown Cavins bailer. Retrieved _packer pluct Clear rig floor 06:30 07:00 0.50 7,254 7,254 COMPZ RIGMN1 SVRG P Service top drive and rig 07:00 08:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Rig up to run MZ gravel pack assembly 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Safety meeting on picking up screens and assembly 08:30 12:00 3.50 7,254 7,254 COMPZ RPCOM PULD P Pick up and run in the hole with MZ gravel pack screens 12:00 12:30 0.50 7,254 7,254 COMPZ RPCOM WOP P Wait on arrival of crane operator 12:30 18:00 5.50 7,254 7,254 COMPZ RPCOM PULD P Finished picking up SC -11 packer and seal assemblies. Made up 35 joints of 2 -7/8" tubing and seals 18:00 23:00 5.00 7,254 7,254 COMPZ RPCOM PULD P Changeover 25 j of 1.900" tubing and and seal pick assemblies up oints 23:00 00:00 1.00 7,254 7,254 COMPZ RPCOM DHEQ P Attempt to test 2 -7/8" and 1.900" tubing strings. 09/18/2008 Attempt to test 1.900" inner string without success. Pull 1.900" inner string and change stinger. Run in hole with 1.900" inner string and retest to 7000 psi -OK. Make up packer and run in the hole to 5590' and unable to move screens. Set packer and release running tool. Top of packer at 4290' dpm. Pull out of the hole to 1211' and rig up to laydown 1.900" inner string. When pulling inner strings through top of packer set down to break KOIV. 00:00 01:30 1.50 7,254 7,254 COMPZ RPCOM DHEQ P Continue testing inner 1.900" string. Trouble shoot and retest 01:30 03:00 1.50 7,254 7,254 COMPZ RPCOM PULD T Pull out of the hole with 1.900" inner stringy and laydown Page 30 - of 37 • L ' `A To E x..14 �.�.... �.c. S 03:00 05:00 2.00 7,254 7,254 COMPZ RPCOM PULD T Inspect 1.900 "jewelry. Seals on stinger bad. Change out stinger and pickup 1.900" tubing and run in the hole 05:00 06:00 1.00 7,254 7,254 COMPZ RPCOM DHEQ T Rig up test equipment and test 1.900" tubing to 7000 psi for 5 minutes -OK. 06:00 06:30 0.50 7,254 7,254 COMPZ RPCOM TRIP P Space out 1.9" inner string 06:30 07:00 0.50 7,254 7,254 COMPZ RPCOM SFTY P Pre -job safety meeting on picking up packer 07:00 08:00 1.00 7,254 7,254 COMPZ RPCOM PULD P Pick up packer and make up to 1.900" and 2 -7/8" inner strings. Rig down tongs 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM DHEQ P Verify seals were effective by reversing with charge pump and testing tubing to 300 psi for 5 minutes 08:30 17:00 8.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in hole with gravel pack assembly from 1314' to 5590'. Set down 8k. Pull up to 150k with no movement. Close annular and pressure up to 300 psi to verify if packer is set. Packer not set. , 17:00 18:30 1.50 7,254 7,254 COMPZ RPCOM PACK T Rig up cementing unit and test lines to 3500 psi. Set packer by pressuring up to 1900 psi and holding for 5 minutes, bled pressure and pressured up to 2500 psi and held for 5 minutes, bled pressure and pressured up to 3100 psi and held for 5 minutes, bled pressure. Closed annular and pressured up on annulus to 500 psi to verify packer set. Release from packer. Top of packer, at 4290' dpm. Bottom of screens _5604' dpm. 18:30 23:00 4.50 7,254 7,254 COMPZ RPCOM TRIP T Trip out of the from 5590' to 1211'.. Pulled over 20k at 5485'. Pulled inner strings above KOIV. KOIV held for 15 minutes. Set back down and broke KOIV with inner strings. 23:00 00:00 1.00 7,254 7,254 COMPZ RPCOM RURD T Rig up to laydown 1.900" tubing 09/19/2008 Laydown 1.900" and 2 -7/8" inner strings. Make up packer retrieving tool and run in the hole. Latch packer at 4295' and pull out of hole to 4003' and lost fish. Pull out of hole and latch (grapple) was missing from retrieving tool. Make up spear and run in the hole. Engage fish at 4133'. Attempted to pull fish but lost fish. Run in the hole to 4344' and re- engage fish. Pulled 135k and fish came free. 00:00 01:00 1.00 7,254 7,254 COMPZ RPCOM PULD T Lay down 1.9" inner string 01:00 01:30 0.50 7,254 7,254 COMPZ RPCOM SFTY T Pre -job safety meeting on rigging up andlaying down 2 -7/8" inner string 01:30 03:30 2.00 7,254 7,254 COMPZ RPCOM PULD T Lay down 2 -7/8" inner string 03:30 04:00 0.50 7,254 7,254 COMPZ RPCOM RURD T Rig dow tongs and bales. Clear floor 04:00 04:30 0.50 7,254 7,254 COMPZ RIGMN1 SVRG T Service rig and top drive Page31 of37 • • ; \ 04:30 06:30 2.00 7,254 7,254 COMPZ RPCOM WOC T Trip in hole with packer retrieving tool to 4295' 06:30 09:00 2.50 7,254 7,254 COMPZ RPCOM TRIP T Set down 15k to latch onto screen assembly. pull 24k over string weight to unseat packer. Trip out of the hole from 4295' to 4003'. Worked through several tight spots. Pulled 90k over string weight at 4000' and, lost fish. 09:00 10:30 1.50 7,254 7,254 COMPZ RPCOM TRIP T Trip out of the hole from 4003' to 3256'. 10:30 11:30 1.00 7,254 7,254 COMPZ RIGMN ?SVRG T Service rig. Inspect derrick and travelling equipment after pulling off top of fish 11:30 14:00 2.50 7,254 7,254 COMPZ RPCOM TRIP T Pull out of the hole from 3256'. No recovery. Grapple on top of packer retrieving tool missing. 14:00 14:30 0.50 7,254 7,254 COMPZ RPCOM PULD T Lay down retrieving tool 14:30 16:00 1.50 7,254 7,254 COMPZ RIGMNI SVRG T Check and adjust drawworks brakes 16:00 20:00 4.00 7,254 7,254 COMPZ RPCOM PULD T Pick up 6 drill collars,jars, bumper sub, intensifier and spear. 20:00 00:00 4.00 7,254 7,254 COMPZ FISH TRIP T Trip in the hole and latch onto fish at 4133'. Pull 90 k and increase to 120k (40 k over) and pulled off top of fish. Trip in the hole to 4342' and latch fish. Latch fish and pickup to 100k. Lost fish. Ran in to 4344' and set down 25k to latch fish. Pull 135k and fish came free. Picked up additional 20k. 09/20/2008 Pull out of the hole with fish. Lay down MZ gravel pack assembly. Recovered 5 of 6 latch segments from packer retrieving tool. Left packer element from bottom SC -1 L packer in the hole. Made up reverse circulating basket, boot baskets, string magnet, string mill, MI basket, bumper sub, jars, and pump out sub and tripped in the hole. Washed from 5683' to 5774'. Circulated until returns were 15 ntu. Pulled out of the hole to 60'. 00:00 03:30 3.50 7,254 7,254 COMPZ FISH TRIP T Pull out of the hole withfish from 4342' to BHA. Stood back collars. 03:30 04:00 0.50 7,254 7,254 COMPZ FISH SFTY T Safety meeting to discuss laying down screens 04:00 04:30 0.50 7,254 7,254 COMPZ FISH PULD T Lay down spear and top packer 04:30 11:30 7.00 7,254 7,254 COMPZ FISH PULL T Lay down MZ gravel pack screens and jewelry 11:30 12:00 0.50 7,254 7,254 COMPZ FISH RURD T Rig down tongs and crane 12:00 15:30 3.50 7,254 7,254 COMPZ FISH PULD T Make up reverse circulating junk basket, boot baskets, string mill, MI bsaket, bumper sub, jars and 6 drill collars 15:30 17:30 2.00 7,254 7,254 COMPZ FISH TRIP T Trip in the hole to 5683'. Circulate down to 5774' 17:30 21:00 3.50 7,254 7,254 COMPZ FISH CIRC T Circulate through reverse circulating junk basket at 11.5 bpm 1960 psi approximately 5 bottoms up until returns were less than 20 ntu 21:00 00:00 3.00 7,254 7,254 COMPZ FISH TRIP T Pull out of the hole from 5774' to 60' Page, 32 of 37 • • Time ® e �.• E. r .4 Phase . « T ��#e '; From To ; D r ' . � 09/21 /2008 24 hr Summary Redress cleanout assembly and run in the hole to 4542'. Circulate and rotate through the perforations from 4542' to 5774'. Work junk baskets and pull out of the hole. Make up dummy seal assembly and run in the hole to 5300'. 00:00 02:00 2.00 7,254 7,254 COMPZ FISH PULD T Pull out of the hole with clean out assembly. Inspect assembly, empty boot baskets and clean magnets 02:00 02:30 0.50 7,254 7,254 COMPZ RIGMNT SVRG T Service rig and top drive. 02:30 04:30 2.00 7,254 7,254 COMPZ FISH TRIP T Run in the hole with cleanout assembly to 4542' 04:30 11:30 7.00 7,254 7,254 COMPZ FISH FISH T Wash and rotate through perforations from 4542' to 5774'. Pump at 3 bmp and rotate at 60 rpm 11:30 13:00 1.50 7,254 7,254 COMPZ FISH CIRC T Circulate and work junk baskets 13:00 17:30 4.50 7,254 7,254 COMPZ FISH TRIP T Pull out of the hole from 5774' to 60' 17:30 21:00 3.50 7,254 7,254 COMPZ RPCOM TRIP T Lay down clean out assembly. Clean magnets and boots baskets. Pick up 20' long 2 -7/8" muleshoe, seal sub, snap latch, jars, magnet and scraper 21:00 00:00 3.00 7,254 7,254 COMPZ RPCOM TRIP T Trip in the hole to 5300'. 09/22/2008 Run in the hole with dummy seal assembly to 5774'. Snap in to top of CK packer three times to verify top of packer was clear of debris. Circulate and filter brine. Pull out of the hole and laydown dummy seal assembly and drill collars. Test BOPE to 250/3500 psi except for UPR's and choke line /manifold to 250psi /5000 psi. Rig up and start running MZ gravel pack assembly. 00:00 01:00 1.00 7,254 7,254 COMPZ RPCOM TRIP T Run in the hole from 5300' to 5774' with dummy seal assembly 01:00 02:00 1.00 7,254 7,254 COMPZ RPCOM DHEQ T Circulate at 4.5 bpm, Latch in with seal assembly with 10k. Unlatch with 12k ovepull. Repeat 2 more times to verify latch area was clear of debris 02:00 03:30 1.50 7,254 7,254 COMPZ RPCOM CIRC T Circulate and filter fluid. Lost 18 bbl of brine while circulating 03:30 06:00 2.50 7,254 7,254 COMPZ RPCOM TRIP T Trip out of the hole from 5,743 to BHA 06:00 08:00 2.00 7,254 7,254 COMPZ RPCOM PULD T Lay down drill collars and dummy seal assembly 08:00 08:30 0.50 7,254 7,254 COMPZ WELCTL OTHR T Pull wear bushing 08:30 11:30 3.00 7,254 7,254 COMPZ WELCTL BOPE T Pick up test joints and rig up 11:30 20:00 8.50 7,254 7,254 COMPZ WELCTL BOPE T Test BOPE to 250 psi /3500 psi., Test UPR's and choke manifold /lines to 250/5000 psi with 4" and 4 -1/2" test joints. Chuck Sheve, AOGCC, was notified of the test at 09:00 hrs 9/21/2008 and he waived witnessing the test. 20:00 20:30 0.50 7,254 7,254 COMPZ WELCTL BOPE T Rig down test equipment and clear floor. Set wear ring 20:30 21:00 0.50 7,254 7,254 COMPZ RPCOM SFTY T Safety meeting on rigging up and running gravel pack screens 21:00 22:00 1.00 7,254 7,254 COMPZ RPCOM RURD T Rig up to pick up gravel pack screens Page', 33 of 37 • • 8. i19 Phase -&il atdT 22:00 00:00 2.00 7,254 7,254 COMPZ RPCOM PULD T Pick up snap -latch seal assembly and gravel pack screens 09/23/2008 Pick up and run in the hole with gravel pack screens. Ran in the hole with the 2 7/8" and 1.90" strings. Tripped in the hole on 4" drill pipe to 5763' MD. 00:00 04:00 4.00 7,254 7,254 COMPZ RPCOM RURD P Run in the hole with 4" gravel pack screens. 04:00 05:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Rig up landing plate bowl for 2 7/8" multizone tools. 05:00 05:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Prejob safety meeting. Running 2 7/8" multizone tools. 05:30 10:00 4.50 7,254 7,254 COMPZ RPCOM PULD P Running downhole jewelry w/ 2 7/8" multizone tools. BOP drill 10 min response. 10:00 11:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Running downhole jewelry. rig up to run 1.90" 3.3" Ib. Hydril CS washpipe. 11:00 12:00 1.00 7,254 7,254 COMPZ RPCOM TRIP P Running downhole jewelry. Trip in the hole with 1.90" Hydril CS washpipe. 12:00 15:00 3.00 7,254 7,254 COMPZ RPCOM RURD P Trip the 1.90" tubing. Pick up 1.90" P110 pipe, set down seals, Test 2 7/8" to 4,000 psi, 1.90" to 7,000 psi. 15:00 16:30 1.50 7,254 7,254 COMPZ RPCOM RURD P Pick up SC -2 Packer, make up to 2 7/8" & 1.90" cross over to 4" drill pipe. 16:30 18:00 1.50 7,254 7,254 COMPZ RPCOM RURD P Rig down power tongs, clean and clear rig floor, prepare to run DP out of the derrick. 18:00 23:00 5.00 7,254 7,254 COMPZ RPCOM TRIP P Test annulus to DP to packer. 300 psi for 5 mins. Good. Trip in the hole 3 mins per stand to 5763' MD. Up Wt =104k, Dn WT =64k. 23:00 00:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Lay down one single, change out bales, for long bales. 09/24/2008 Performed gravel pack job #1 @ 5774' MD. Performed gravel pack job #2 @ 5310' MD. Positioned the Baker tools for job #3 @ 4969' MD. 00:00 03:30 ' 3.50 7,254 7,254 COMPZ RPCOM RURD P Make up FOSV / pump in sub to set packer. 03:30 05:30 2.00 7,254 7,254 COMPZ RPCOM RURD P Test surface lines to 4000 psi, set Baker packer on depth for araveL _ pack job #1 A5774' MD. Verify packer set by pulling 30k over. Test annular to 1500 psi. Bleed off and rotate 15 times to release. 05:30 08:00 2.50 7,254 7,254 COMPZ RPCOM RURD P Rig up BJ lines for gravel pack job. 08:00 08:30 0.50 7,254 7,254 COMPZ RPCOM SFTY P Prejob safety meeting. "Testing lines, and gravel packing ". Page 34 of 37 • Date T! r w a± E. s - •{11' ` ase Iv f tib ? meat • \ v' 08:30 15:00 6.50 7,254 7,254 COMPZ RPCOM GRVL P Test BJ lines to 8,000 psi. Set lower zone SC -1 L packer. Performed reverse friction test, step rate tests. Pumped 3,375 Ibs of sand behind pipe• Pumped 250 BBLs brine. Gravel pack job pumped @ 9 BPM, returns @ 2.8 BPM. Screen out pressure = 5640 psi. 24 Ibs /ft per perforation. Reversed sand out @ 5 BPM. 15:00 16:00 1.00 7,254 7,254 COMPZ RPCOM GRVL P Trip out to next gravel pack depth. Lay down 10 joints. Rig up BJ lines. 16:00 20:00 4.00 7,254 7,254 COMPZ RPCOM GRVL P Test BJ lines to 8,000 psi. Set middle zone packer. Performed reverse friction test, step rate tests. Pumped 3,241 Ibs of sand behind pipe. Pumped 200 BBLs brine. Gravel pack job pumped @ 7 BPM, returns @ 2.5 BPM. Screen out pressure = 5357 psi. 9.8 Ibs /ft per perforation. Reversed sand out @ 5.39 BPM. 20:00 22:30 2.50 7,254 7,254 COMPZ RPCOM GRVL P Trip out to next gravel pack depth. Lay down 14 joints. Rig up BJ lines. 22:30 00:00 1.50 7,254 7,254 COMPZ RPCOM GRVL P Rig up BJ lines for Upper gravel pack job. Test lines to 8000 psi. Set Baker packer with 3100 psi. 09/25/2008 Performed gravel pack job #3. Tripped out 4 stands, closed the ceramic flapper, Iayed down drill pipe, 1.90" tubing, 2 7/8" tubing, all Baker jewelry, ran the remainder of the 4" drill pipe, and laid all of down. Cleared the derrick. 00:00 02:30 2.50 7,254 7,254 COMPZ RPCOM GRVL P Test BJ lines to 8,000 psi. Set upper zone packer. Performed reverse friction test, step rate tests. Pumped 7,105 Ibs of sand behind pipe. Pumped 287 BBLs brine. Gravel pack job pumped @ 8.2 BPM, ended with 4 BPM. returns @ 2.2 BPM. Screen out pressure = 3,734 psi. 25.5 Ibs /ft per perforation. Reversed sand out @ 5.0 BPM. 2 tubing volumes after no sand seen on shakers. 02:30 04:00 1.50 7,254 7,254 COMPZ RPCOM RURD P Rig down BJ Services hard lines on rig floor, change out long bales to short bales. 04:00 09:30 5.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of hole, 5 stands, close ceramic flapper t 4506' MD, Stopped losing 20 BBLs/hr. Fluid loss went to zero. UD 99 jts. 4" DP. 09:30 10:30 1.00 7,254 7,254 COMPZ RPCOM SFTY P Nabors safety stand down. Hazard recognition, and identification. 10:30 12:00 1.50 7,254 7,254 COMPZ RPCOM RURD P Pick up tools to lay down 1.90" inner string. 12:00 13:00 1.00 7,254 7,254 COMPZ RPCOM RURD P Lay down 26 joints of 1.90" inner string tubing. 13:00 13:30 0.50 7,254 7,254 COMPZ RPCOM RURD P Rig up to lay down 2 7/8" string with Weatherford. Page. 35 of 37 11111 41111 a��� Da k:1 . From To M r . �' .tt E, tti Go .. tt ... ul rid � ? ..:O rra t# 13:30 18:00 4.50 7,254 7,254 COMPZ RPCOM TRIP P Trippi out sideways, laying down n 2 7/8" tubing. 35 jts. L/D Upper and lower isolation seal assemblies. 18:00 19:30 1.50 7,254 7,254 COMPZ RPCOM RURD P Rig down power tongs, rig up to run in the hole with the 4" DP. 19:30 21:30 2.00 7,254 7,254 COMPZ RPCOM TRIP P Trip all pipe out of the derrick. 3052' MD. 21:30 00:00 2.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole laying down singles from 3052' to 2100'. 09/26/2008 Ran the 4.5" upper completion string, landed, tested annulus to 500 psi for 10 mins. Tested control lines to 5,000 for 10 mins. Tested hanger seal to 5,000 for 10 mins. Set BPV. Rig down BJ, flush all rig lines with fresh water. 00:00 01:30 1.50 7,254 7,254 COMPZ RPCOM TRIP P Trip out of the hole laying down singles from 2100' to surface. 01:30 03:30 2.00 7,254 7,254 COMPZ RPCOM RURD P Rig up power tongs. rig up Weatherford to run 4.5" tubing. 03:30 12:00 8.50 7,254 7,254 COMPZ RPCOM TRIP P Trip in the hole with 4.5" upper completion string to 4300'. Rig up Schlumberger control and injection lines. 12:00 14:00 2.00 7,254 7,254 COMPZ RPCOM TRIP P Trip in the last 500 feet of the 4.5" completion string banding the control and injection lines to the tubing with 22 bands to the surface. 14:00 14:30 0.50 7,254 7,254 COMPZ RPCOM CIRC P Displace wellbore to inhibited brine. 190 BBLs of 8.6 pp clean brine. 14:30 20:30 6.00 7,254 7,254 COMPZ RPCOM PULD P Pick up two space out pup joints, make up chemical injection line and control line to hanger. Work torque down to half mule shoe, land hanger. Up Wt= 65k, Dn Wt= 48k. 20:30 21:30 1.00 7,254 7,254 COMPZ WELCTL BOPE P Test hanger to 5,000 psi, retest control line to 5,000 psi. Rig up BJ, test surface lines to 2,000 psi. Test Annulus with BJ to 500 psi for 10 mins. chart. Good. Blow down, rig down BJ cement truck and all lines. 21:30 22:30 1.00 7,254 7,254 COMPZ WELCTL NUND P Install Vetco Gray BPV, rig up to flush all lines with fresh water, 22:30 23:00 0.50 7,254 7,254 COMPZ WELCTL OTHR P H2S alarm went off in shaker area, 43 ppm. Evacuate rig, conduct head count. All hand accounted for in muster area. TP and Driller don SCBA, secure well, inspect pits, cellar, take readings with hand held. No confirmation of high H2S. Reset alarm. Zeroed out. Return to work. 23:00 00:00 1.00 7,254 7,254 COMPZ WELCTL NUND P Flush all lines with 100 BBIs fresh water. Choke manifold, poor boy, take returns to pit #1. 09/27/2008 Nipple down and remove 11" Shaffers. Nipple up production tree. Test tree to 1,000 psi low/ 5,000 psi high. Test Annulus 2500 psi 5 mins, 3500 psi 30 mins. Install BPV. Secure well for rig move. Simops while work was ongoing in the cellar, rig down and move all SWACO equi ment, berms, docks, tubulars. 00:00 02:00 2.00 7,254 7,254 COMPZ WELCTL NUND P Nipple down 11" Schaffer BOP's, rig down tongs, kelly hose, and catwalk. Page 36 of 37 • • Dates.. From 1' ur . S. Depth E. Depth 'Mike \Code. : Stt 02:00 12:00 10.00 7,254 7,254 COMPZ WELCTL NUND P Continue Nipple down job in cellar, rig down choke house, clean all pits. 12:00 14:30 2.50 7,254 7,254 COMPZ WELCTL NUND P Nipple up Production tree, with Vetco Gray Service hands. 14:30 21:30 7.00 7,254 7,254 COMPZ WELCTL NUND P Prepare Xmass tree, test tree to 1000 psi low 5 mins, 5,000 psi high 10 mins, test annular to 2500 psi 5 mins, test annular to 3500 psi 30 mins. Install BPV, pressure gauges, . secure well. 21:30 00:00 2.50 7,254 7,254 COMPZ MOVE RURD P Make pits ready for move, remove flow line, gas buster, inspect mud pumps, Rig Release @ 23:59. Page', 37 of 37 • ti .,'■ 1 K t ) 'T. 1 L 7 7. :' ir, "7' r ,T ir-) {7! A '7 r, - 0 Fp - ifi � � LTK Q.I) u v i l , SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Jim Ennis Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Beluga Gas Pool, BRU 211 -26 Sundry Number: 308 -402 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 0 li Daniel T. Seamount, Jr. Chair DAZED this 2 day of November, 2008 Encl. 0015"—lca UftOf iV STATE OF ALASKA 411, -�. ; _ ' t , ALASKA OIL AND GAS CONSERVATION COMMISSION ` ' 4 414, ` APPLICATION FOR SUNDRY APPROVAL' ' • . 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other is Alter casing ❑ Repair well ❑ Plug Perforations El Stimulate Li Time Extension ❑ scale squeeze 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 El • Exploratory ❑ 208 - 112 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 283 - 20128 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes ❑ No El BRU 211 -26 • 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): 9,T' ADL 21127 ' RKB 91.5' \ Beluga River Field / St eluga Gas Pool 12. PRESENT WELL CONDITION SUMMARY / /( - 10. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7786' 6750' 7400' 6273' Casing Length Size MD TVD Burst Collapse Conductor 86' 20" 104' 104' Intermediate 3574' 9 -5/8" 3592' 2863' Production 7758' 7" 7776' 6740' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4617-7244' 3605' -6206' 4.5" L -80 4484' Packers and SSSV Type: Packers and SSSV MD (ft) see attached diagram Camco SCSSV @ 504' 13. Attachments: Description Summary of Proposal Ei 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El - Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat November 12, 2008 Oil ❑ Gas El - Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify th- he foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed N ` Jim Ennis Title: Wells Engineer Signature -,i Phone: 265 -1544 Date if ,. 0 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness :g. 'A) a Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: i\� -A... Q. Lt3C.�kc._.i`: i`�-�O:r1 W,��wo 1 ` APPROVED BY / /� /— / / Approved by.�\ COMMISSIONER THE COMMISSION Date: ` C (5)1 " t Form 10 -40 - evised 06/2006 ; / R J 1 3 2008 Submit in Duplicate �4 / 8 • BRU 211 -26 CT Scale Inhibitor Squeeze Wells Network#: 10236650 The procedure outlined below will utilize CT to open the six CMU's in the 2.875" isolation assembly and pump a scale inhibitor squeeze through the CMU's. The scale inhibitor squeeze is to prevent CaCO3 scale from depositing on the completion when calcium weighted completion fluid is flowed back as was seen on BRU 243 -34. Reminder: All personnel on location are required to have received Beluga orientation training at the CPAI Kenai LNG Plant within the past year. Procedure: 1. MIRU BJ 1.75" CTU. Nipple up and test BOP as per SOP. Notify AOGCC 24 hours prior to BOP testing. 2. RIH w/ shifting tool & Bakke hammer to 7250' CTMD. Locate and open CMU's @ 7206', 6854', 6691', 6471', 6426' & 5845'. If Bakke hammer proves necessary, use 2 micron filtered 6% KCL water for power fluid. Mark CT for depth reference while at top CMU. POOH. 3. RIH w/ inflatable packer to 30' above top CMU depth (5815'MD). Set inflatable packer and establish injection rate w/ 2 micron filtered 6% KCL water containing 1 gal /1000 gal FRW -14. Using same base fluid, pump 23 bbls pre -flush containing 10 gals Techni -Wet 4353 & 0.25 gals Techni -Hib 604, 92 bbls inhibitor containing 10 gals Techni -Wet 4353, 0.5 gals Techni -Hib 604 & 385 gals Scaletrol 720 & 1100 bbls flush containing 116 gals Techni -Wet 4353 & 2.25 gals Techni -Hib 604 at max rate. Release inflatable packer. POOH. 4. Flow well for cleanup & turn over to production. 11/4/2008 BRU 211 -26 CT scale inhibitor squeeze procedure 11- 4- 08.docCreated by jjennis 1 l e Equipment & Services Location: Sales Location: r ��■ .. so Lafayette. La. - Phone # 337 -593 -2700 Baker Oil Tools District Manager: Steve Zuklic 1010 Rankin Rd. RAKER Baker ail Tools Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 H[16HES 713 - 625 -6800 ss Operator: Phone # BHP BHT Max. Dev. Zone Dev. Sand Size Page: 1 CONOCO Company Representative: Phone # Type Of Screen Well Type Date: BRIMS BUCK GAS 9/26/2008 88 Field: Well # Perforations Completion Fluid BELUGA 211 -26 8.6# 87 State: Lease Salesman Phone # Job Number AK BELUGA Loading Docks: Phone # Size ID. WT. Grade Thread OSK CASING 7' 6.276" 26# L-80 BUTT -MOD es Rig Name: Phone # Liner NABOBS 129 Liner Prepared By: Phone # WRKSTG 4" 3.340" 16.08# 8 -135 HT -38 BOBBY DEAN 337 - 593 -2700 WRKSTG 85 Drawing Rev. Date: Revision # TUBING 4 1/2" 3.958" 12.60 L-80 IBT MOD. TUBING _,. I 84 No Depth I Length OD ID Description 83 82 87 6 4f 80 79 TOP FLANGE OF WELLHEAD 11" 5M TOP OF HANGER LIFT THREAD 4.909" MCA 78 SEAL ASSEMBLY LOCATOR SPACE 3.12' ABOVE PBR 141 JTS. TOTAL IN HOLE 1 77 ' 72 3 75 74 t F 73 0.00 16.40 RKB ELEVATION 90 16.40 1.18 10.75 3.900 10 3/4" X 4 1/2" VETCO HANGER 89 17.58 3.10 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 88 20.68 31.30 4.530 3.958 4.5" 12.6# IBT MOD. BXP TUBING JT. (1 JT. ) 72 87 51.98 22.47 4.530 3.958 4.5" 12.6# IBT MOD. BXP SPACEOUT PUP JTS. ( 14.72', 5.83', 1.92' ) 86 74.45 367.59 4.530 3.958 4.5" 12.6# IBT MOD. BXP TUBING. ( 12 JTS. ) 85 442.04 10.10 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 84 452.14 1.24 5.570 3.920 CAMCO CHEMICAL INJECT. VALVE 4.5" 1BT MOD. BXP 83 453.38 10.06 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 1 71 82 463.44 30.60 4.530 3.958 4.5" 12.6# IBT MOD. BXP TUBING JT. (1 JT. ) 81 494.04 10.09 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. _. 80 504.13 2.67 5.570 3.813 CAMCO SCSSV 4.5" ffiT MOD. BXP 7500 PSI WP 70 79 506.80 10.11 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 78 516.91 3683.17 4.530 3.958 4.5" 12.6# IBT MOD. BXP TUBING. ( 120 JTS. ) 77 4200.08 10.13 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. � :� 76 4210.21 6.89 5.980 3.938 GLM 1" KGB -2, 4.5" MT MOD. BXP ( DUMMY ) 75 4217.10 10.10 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 69 74 4227.20 152.71 4.530 3.958 4.5" 12.68 IBT MOD. BXP TUBING. (5 JTS. ) 73 4379.91 1.17 5.000 3.813 Cameo "X" Nipple 4.5" ffiT MOD. BXP 72 4381.08 61.61 4.530 3.958 4.5" 12.6# IBT MOD. BXP TUBING. (2 JTS. ) 71 4442.69 5.82 4.530 3.958 4.5" 12.6# IBT MOD. BXP PUP JT. 70 4448.51 0.82 5.500 3.958 Seal Assembly Locator, 4.5" IBT Mod x 1/2 Mule Shoe 69 4452.45 18.34 5.530 4.750 Polished Bore Receptacle Seal Surface Up x 4.5 IBT Mod Pin ( PBR ) 68 4470.79 9.69 4:530 3.970 Production Tube 4.5" 12.68 L -80 1ST Mod. Box x Pin 6e 67 4480.48 1.16 5.200 3.260 Anchor latch 82 -40 S -22 9011 Nitrile 4 -1/2" 12.6# IBT Mod. Box 67 66 4481.64 1.56 3.980 3.260 Seal Unit 82 -40 9011 Nitrile TPI Stub ACME • e i 64 65 4483.20 0.50 3.980 3.260 Half Mule Shoe 82 -40 TPI Stub ACME 66 4483.70 END OF ASSEMBLY 41 .. €t 65 ! 64 4481.64 4.24 6.000 4.000 UPPER WIZ SC -2 Packer 70B -40 Nitrile 5 -1/2" 23# SLHT Box Equipment & Services Location: Sales Location: s Tio Lafayette, La. - Phone # 337 - 593 -2700 Baker Oil Tools 66 District Manager: Steve Zuklic 1010 Rankin Rd. Baker Oil Tools Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 I � F 65 713- 625 -6800 IES ,t ` 64 Operator: Phone # BHP BHT Max. Dev. Zone Dev. Sand Size Page: 1 r CONOCO 0 0 30 30 0 63 Company Representative: Phone # Type Of Screen Well Type Date: Ir BRIAN BUCK Excluder 2000 / Bakerweld 10Ga. / Bakerweld 12 Ga. GAS 9/14/2008 1 ; 62 Field: Well # Perforations Completion Fluid F 61 BELUGA 211 -26 4617 -4955 5054 -5298 5610 -5763 8.6 [ = 60 State: Lease Salesman Phone # Job Number :■ ' , , 58 AK BELUGA 0 0 57 Loading Docks: Phone # Size ID. WT. Grade Thread { '- 56 OSK CASING 7" 6.276" 26# L -80 BUTT -MOD wk- ' 55 Rig Name: Phone # Liner - ,g `' 54 NABORS 129 907- 263 -3010 Liner r IF 53 Prepared By: Phone # WRKSTG 4" 3.340" 16.08# S -135 HT -38 AI i 11 52 BUDDY ARCENEAUX 337 -593 -2700 WRKSTG . 1 t , 51 Drawing Rev. Date: Revision # TUBING 0 0.000 0 0 0 a i 49 TUBING . W ; 48 No I Depth I Length I OD I ID I Description al 1' i" 46 I 45 i ' 44 MULTI ZONE ASSEMBLY RUN IN DRAWING 4 I E = , W, 43 a # 42 ' £ _ 41 -- d 40 123 - 39 EFFECTIVE BHA = 1306.17' 3 l ' 38 TOTAL BHA = 1314.66' i = 37 mist ' 3 '36 1' I. ; : 35 Work String To Surface - -- 66 4467.91 5.54 4.000 2.440 4" 16.08# HT -38 JT. PUP § 34 65 4473.45 1.29 4.920 1.980 4" HT -38 Box x 2 -7/8" IF Pin Crossover x 64 4474.74 6.90 5.680 1.880 Setting Tool HP -70 2-7/8" IF Box 33 63 4481.64 4.24 6.000 4.000 SC -2 Packer 70B -40 Nitrile 5 -1/2" 23# SLHT Box 32 62 4485.88 10.04 5.550 4.700 Millout EXT. 5 -1/2" 23# L -80 SLHT Pin x Pin o 1 0 31 61 4495.92 2.81 4.520 3.250 Seal Bore 80 -32 5 -1/2" 23# SLHT Box x 4 -1/2" 13.5# SLHT Pin . ' t 30 60 4498.73 1.73 5.010 3.880 EXT. Sub 4 -1/2" 13.5# P -110 SLHT Box x Pin i 29 59 4500.46 2.50 5.630 3.320 Knock Out Isolation Valve C -2 Isolation Sleeve4 -1/2" 13.5# Box x 5" 23# SLHT Pin 27 9 58 4502.96 1.74 5.630 3.340 Knock Out Isolation Valve C -2 5" 23# SLHT Box x 4 -1/2" 13.5# Pin 41i 1 = 26 57 4504.70 6.02 4.530 3.930 EXT. Sub 4 -1/2" 13.5# P -110 SLHT Box x Pin 25 56 4510.72 10.54 4.540 3.930 Vent Screen Bakerweld 12 Ga.4 -1/2" 13.5# P -110 SLHT Box x Pin 1 } ' 24 55 4521.26 0.58 5.000 3.430 X -Over 4 -1/2" 13.5# SLHT Box x 4" 11# SLHT Pin - £ 23 54 4521.84 2.18 4.530 3.250 Seal Bore MZ System 80 -32 4" 11# SLHT Box x 4-1/2" Left Hand Square Thread Pin t11a I j " 53 4524.02 3.49 6.000 3.610 SC -1L Packer 70B6 -40 Left Hand Square Thread Box x Stub ACME Box 52 4527.51 2.09 5.060 3.250 Seal Bore MZ System 80 -32 Stub ACME Pin x 4-1/2" 13.5# SLHT Box - ! It 51 4529.60 3.77 4.530 3.970 Upper EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Pin x Pin L. 22 50 4533.37 4.01 5.230 4.010 Frac EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Box x Pin 49 4537.38 2.40 4.980 3.250 Seal Bore MZ System 80 -32 4-1/2" 13.5# SLHT Box x Box 1 48 4539.78 5.09 4.520 3.990 Lower EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Pin x Pin I, , 47 4544.87 2.81 5.000 3.250 Seal Bore MZ System 80 -32 4 -1/2" 13.5# SLHT Box x Pin 46 4547.68 0.57 5.000 3.480 X -Over 4 -1/2" 13.5# SLHT Box x 4" 11# SLHT Pin 45 4548.25 40.78 4.000 3.450 Blank Pipe 4" 11# P -110 SLHT Box x Pin 44 4589.03 78.95 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.45, 39.50) 43 4667.98 10.55 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ' �' 42 4678.53 39.44 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ¢ } ; \ f ' 20 41 4717.97 10.54 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 40 4728.51 19.70 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 4 39 4748.21 19.83 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 19 38 4768.04 19.57 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 1 37 4787.61 10.53 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin a 1 i ) 18 36 4798.14 78.86 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.44, 39.42 ) Ir`=' i 35 4877.00 30.34 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 1 19.78, 10.56 17 f � �: 34 4907.34 59.23 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.44, 19.79 ) It L 16 33 4966.57 2.18 4.500 3.250 Seal Bore MZ System 80 -32 4" 11# SLHT Box x 4 -1/2" Left Hand Square Thread Pin 11-L ` I 15 32 4968.75 3.48 6.000 3.620 SC -1L Packer 70B6 -40 Left Hand Square Thread Box x Stub ACME Box -,.� . ' 14 31 4972.23 2.09 5.060 3.250 Seal Bore MZ System 80 -32 Stub ACME Pin x 4 -1/2" 13.5# SLHT Box 4 i 12 30 4974.32 3.77 4.530 3.970 Upper EXT. MZ System 80 -32 4-1/2" 13.5# P -110 SLHT Pin x Pin 11 29 4978.09 4.01 5.230 4.010 Frac EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Box x Pin r _ ! 10 28 4982.10 9 2.40 5.000 3.250 Seal Bore MZ System 80 -32 4-1/2" 13.5# SLHT Box x Box - 27 4984.50 5.09 4.520 3.960 Lower EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Pin x Pin 1 a 26 4989.59 2.81 5.000 3.250 Seal Bore MZ System 80 -32 4 -1/2" 13.5# SLHT Box x Pin f 25 4992.40 0.57 5.000 3.480 X - Over 4-1/2" 13.5# SLHT Box x 4" 11# SLHT Pin 3 8 24 4992.97 6.08 4.000 3.450 Blank Pipe Pup 4" 11# P -110 SLHT Box x Pin 23 4999.05 42.08 4.000 3.450 Blank Pipe 4" 11# P -110 SLHT Box x Pin 1 1 22 5041.13 98.50 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.37, 39.43, 19.70 ) + 21 5139.63 39.43 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin j ' 20 5179.06 78.89 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 1 39.44, 39.45 19 5257.95 10.52 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin - � ' 18 5268.47 39.45 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin °' l " 7 17 5307.92 2.18 4.570 3.250 Seal Bore MZ System 80 -32 4" 11# SLHT Box x 4 -1/2" Left Hand Square Thread Pin si§i3 16 6 5310.10 3.48 6.020 3.625 SC -1L Packer 70B6 -40 Left t Hand Square Thread Box x Stub ACME Box 15 5313.58 2.09 5.060 3.250 Seal Bore MZ System 80 -32 Stub ACME Pin x 4 -1/2" 13.5# SLHT Box 3 14 5315.67 3.77 4.530 3.970 Upper EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Pin x Pin 13 5319.44 4.01 5.230 4.010 Frac EXT. MZ System 80 -32 4-1/2" 13.5# P -110 SLHT Box x Pin 12 5323.45 2.40 4.980 3.250 Seal Bore MZ System 80 -32 4 -1/2" 13.5# SLHT Box x Box i�= _: 11 5325.85 5.09 4.520 3.980 Lower EXT. MZ System 80 -32 4 -1/2" 13.5# P -110 SLHT Pin x Pin r; -_ 1_' 6 10 5330.94 2.82 5.000 3.250 Seal Bore MZ System 80 -32 4-1/2" 13.5# SLHT Box x Pin ® 9 5333.76 0.57 5.000 3.470 X -Over 4 -1/2" 13.5# SLHT Box x 4" 11# SLHT Pin 8 5334.33 261.40 4.000 3.450 Blank Pipe 4" 11# P -110 SLHT Box x Pin ( 42.59, 43.75, 43.77, 43.92, 43.71, 43.66 _ 7 5595.73 39.45 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 6 5635.18 39.30 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin : _; 5 5674.48 98.64 4.830 3.430 Screen Excluder 2000 4" 1l# P -110 SLHT Box x Pin I 39.44, 39.43, 19.77 ) 4 .1 1 4 5773.12 0.96 4.990 3.270 Snaplatch 82 -40 S -22 4" 11# SLHT Box x ACME Pin 1 I g 3 5774.08 2.98 3.980 3.260 Seal Units 82 -40 S -22 90H Nitrile Stub ACME Box x Pin 2 5777.06 5.01 3.980 3.250 Spacer Sub 82 -40 Stub ACME Box x Pin -= 1 5782.07 0.50 3.980 3.260 Half Mule Shoe 82 -40 Stub ACME Box '"' is q 5782.57 End Of Assembly ` < 0 I Equipment & Services Location: Sales Location: 'z �r'-' ,, 68 Lafayette, La. - Phone # 337 -593 -2700 Baker Oil Tools �� all , ( District Manager: Steve Zuklic 1010 Rankin Rd. RAKER Baker Oil Tools AI 4 67 Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 HuGHEs 66 713- 625 -6800 V fidr! Operator: Phone # EST .BHP EST. BHT Max. Dev. Zone Dev. Sand Size 20/40 Page: 1 CONOCO 2300 110 56 0.92 6¢Q1 Company Representative: Phone # Type Of Screen Well Type Date: 5$ BRIAN BUCK Excluder 2000 / Bakerweld lOGa. GAS 9/13/2008 57 Field: Well # Perforations Completion Fluid 55 BELUGA 211 -26 5968 -7244 10.4 CACL2 • 4 54 State: Lease Salesman Phone # Job Number 53 AK BELUGA Loading Docks: Phone # Size ID. WT. Grade Thread 52 OSK CASING 7" 6.276" 26# L-80 BUTT -MOD _ Rig Name: Phone # Liner r NABORS 129 907- 263 -3010 Liner +s` I, 51 Prepared By: Phone # WRKSTG 4" _ 3.340" 16.08# S -135 _ HT -38 ,,,� BUDDY ARCENEAUX 337 -593 -2700 WRKSTG e 50 Drawing Rev. Date: Revision # TUBING 0 0.000 0 _ 0 _ 0 TUBING i 41 4 1 49 No I Depth I Length I OD I ID I Description 1111 E 48 '-4. i 47 46 tillg rt. 45 44 p ° LOWER CK ASSEMBLY #i} t 43 68 5799.21 3.78 6.000 4.000 SC -2 Packer 70B -40 Stub ACME Box Down Nitrile 67 5802.99 3.61 5.800 4.800 Frac EXT. 80 -40 CK -250 ACME Box x Box 66 5806.60 2.48 5.560 4.000 Seal Bore Receptacle 80 -40 CK -250 ACME Pin x Box 42 65 5809.08 9.14 5.040 4.280 Lower EXT. 80 -40 CK -250 5" 18# SLHT Pin x Pin a:. 64 5818.22 3.33 5.560 3.500 Single Indicating Coupling 80 -40 CK -250 5" 18# SLHT Box x Box i^ 63 5821.55 0.65 5.040 4.280 EXT. Sub 80 -40 CK -250 5" 18# SLHT Pin x Pin ' ii 41 62 5822.20 3.24 5.560 3.500 Double Indicating Coupling 80 -40 CK -250 5" 18# SLHT Box x Box 61 5825.44 5.32 5.040 4.280 EXT. Sub 80 -40 CK -250 5" 18# SLHT Pin x Pin 40 60 5830.76 2.67 5.590 3.340 Knock Out Isolation Valve C -2 Isolation Sleeve 5" 18# SLHT Box x Pin I, 3g 59 5833.43 1.75 5.590 3.310 Knock Out Isolation Valve C -2 5" 18# SLHT Box x Pin 37 58 5835.18 1.00 5.580 3.430 X -Over 5" 18# SLHT Box x 4" 11# SLHT Pin 36 57 5836.18 3.11 4.590 3.420 Shear Out Safety Joint GPR -24 4" 1141 P -110 SLHT Box x Pin -- s °- 35 56 5839.29 0.89 4.510 3.460 X -Over 4" 11# SLHT Box x 4-1/2" 13.5# SLHT Pin 55 5840.18 10.24 4.530 3.950 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin 33 54 5850.42 0.59 4.530 3.480 X -Over 4 -1/2" 13.5# SLHT Box x 4" SLHT Pin 3 32 53 5851.01 7.82 4.000 3.450 Blank Pipe Pup Joints 4" 11# P -110 SLHT Box x Pin ( 4.10, 3.72 1 . ... 0 t P 52 5858.83 87.72 4.000 3.450 Blank Pipe 4" 11# P -110 SLHT Box x Pin/ 43.89, 43.83 51 5946.55 39.46 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin =1 31 50 5986.01 19.80 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 49 6005.81 39.45 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 1r 48 6045.26 30.37 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 19.87, 10.50 ) tai i 30 47 6075.63 19.76 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin '" a^ 46 6095.39 19.80 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin - 29 45 6115.19 59.21 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.43, 19.78 MOE 44 6174.40 78.71 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 39.30, 39.41 ) l' 43 6253.11 39.44 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin t , 7 42 6292.55 69.75 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 39.40, 19.80, 10.55 # • 28 40 6421.50 0.89 4.530 3.490 X -O r ver 4" 11# SLHT Box x 4 -1 2 SLHT Pin ( 39.42, 19.78 1 - 41 6362.30 59.20 4.830 3.430 27 39 6422.39 10.56 4.530 3.940 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin :_. • I. 25 38 6432.95 0.59 5.000 3.490 X -Over 4-1/2" 13.5# SLHT Box x 4" SLHT Pin , 24 37 6433.54 2.73 5.000 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT Box x Pin 3.25" Bore 23 36 6436.27 30.37 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 19.83, 10.54 35 6466.64 0.89 4.520 3.490 X -Over 4" 11# SLHT Box x 4 -1/2" 13.5# SLHT Pin ;' 34 6467.53 10.54 4.520 3.920 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin all _; 22 33 6478.07 0.59 5.010 3.500 X -Over 4 -1/2" 13.5# SLHT Box x 4" SLHT Pin __ r- 32 6478.66 19.82 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin .,- 7 21 31 6498.48 39.41 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin IMMUNE r 30 6537.89 19.80 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 29 6557.69 50.04 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin I 39.51, 10.53 # i ' 28 6607.73 78.86 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.43, 39.43 ) 4IA 20 27 6686.59 0.89 4.500 3.460 X -Over 4" 11# SLHT Box x 4-1/2" 13.5# SLHT Pin 19 26 6687.48 10.54 4.520 3.920 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin • i8 25 6698.02 0.59 5.010 3.500 X -Over 4 -1/2" 13.5# SLHT Box x 4" SLHT Pin 17 24 6698.61 2.73 4.490 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT Box x Pin 3.25" Bore a: 16 23 6701.34 49.97 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 1 39.43, 10.54 1 15 22 6751.31 19.78 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 21 6771.09 19.80 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P - 110 SLHT Box x Pin ,. 20 6790.89 59.26 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin ( 39.49, 19.77 1 't3 14 19 6850.15 0.89 4.530 3.490 X -Over 4" 11# SLHT Box x 4-1/2" 13.5# SLHT Pin 18 6851.04 10.54 4.530 3.940 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin - 1" 17 6861.58 0.58 5.000 3.490 X -Over 4-1/2" 13.5# SLHT Box x 4" SLHT Pin u 13 16 6862.16 2.74 4.490 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT Box x Pin 3.25" Bore 15 6864.90 49.97 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 39.43, 10.54 ) i 14 6914.87 39.44 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 12 13 6954.31 39.41 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin 12 6993.72 19.78 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin T 11 7013.50 50.01 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 39.48, 10.53 1 a® : 11 10 7063.51 19.77 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin 3^ 9 7083.28 118.34 4.590 3.430 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT Box x Pin ( 39.40, 39.42, 39.52 ) 1 1 10 8 7201.62 0.88 4.500 3.490 X -Over 4" 11# SLHT Box x 4 -1/2" 13.5# SLHT Pin e ! I 7 7202.50 10.54 4.520 3.910 Blank Pipe 4 -1/2" 13.5# P -110 SLHT Box x Pin w 6 7213.04 0.58 5.000 3.490 X -Over 4-1/2" 13.5# SLHT Box x 4" SLHT Pin ® - 5 7213.62 39.42 4.830 3.430 Screen Excluder 2000 4" 11# P -110 SLHT Box x Pin III 9 4 7253.04 0.96 4.990 3.250 Snaplatch 82 -40 S -22B 4" 11# SLHT Box x ACME Pin C 7254.00 2.63 3.980 3.250 Seal Units 82 -40 90H Stub ACME Box x Pin Nitrile mix B 7256.63 5.00 3.980 3.250 Spacer Sub 82 -40 Stub ACME Box x Pin ® 8 A 7261.63 0.50 3.980 3.250 Half Mule Shoe 82 -40 Stub ACME Box 7 7262.13 End Of Assembly 6 3 7254.00 1.97 5.850 4.000 Sump Packer Model FS Size 85 -40 ACME Pin Down r; 5 2 7255.97 0.83 5.850 4.000 Bottom Guide 85 -40 ACME Box x 5 -1/2" 23# SLHT Box ' l. 1 7256.80 19.42 5.540 4.930 Mule Shoe 5 -1/2" 23# L-80 SLHT Pin x Mule Shoe NM -I- 4 7276.22 End Of Assembly 3 1 AO 41----- + I Equipment & Services Location: Sales Location: 1 41 Lafayette, La. - Phone # 337- 593 -2700 Baker Oil Tools rirgi Ill i 1 . - ' District Manager: Steve Zuklic 1010 Rankin Rd. RAKER Baker Oil Tools 40 Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 HUGHES III 713- 625 -6800 " 39 Operator: Phone # EST .BHP EST. BHT Max. Dev. Zone Dev. Sand Size Page: 1 38 CONOCO 2300 110 56 0.92 20/40 - IN 3 , Company Representative: Phone # Type Of Screen Well Type Date: 36 BRIAN BUCK Excluder 2000 / Bakerweld 10Ga. GAS 9/13/2008 sm, Ts 35 Field: Well # Perforations Completion Fluid r � 34 BELUGA 211 -26 5968 -7244 10.4 CACL2 s State: Lease Salesman Phone # Job Number a AK BELUGA , 1 33 Loading Docks: Phone # _ Size ID. WT. Grade Thread ,, OSK CASING 7" 6.276" 26# L -80 BUTT -MOD e F � 32 Rig Name: Phone # Liner a ; NABORS 129 907 - 263 -3010 Liner b, � ' Prepared By: Phone # WRKSTG 4" 3.340" 16.08# S -135 HT -38 31 BUDDY ARCENEAUX 337 -593 -2700 WRKSTG Drawing Rev. Date: Revision # TUBING 7/13/2008 TUBING ira t, 'pp 3 No I Depth I Length I OD I ID I Description sra, r AY f a q f ;mss ' - ...mot ,B , l ._ r 4 30 rY � .. '�: 1 1E h,a`a I 12 Fi . '6 5 2 - ,i i ! 24 F , 23 iY t a � , ® ay J 22 is I r ra t - f 3 21 _ ISOLATION ASSEMBLY ' i 20 Naill ' 19 40 5774.08 4.24 6.000 4.000 SC -2 Isolation Packer 70B -40 5 -1/2" 23# SLHT Box Nitrile - i. 18 39 5778.32 19.55 5.520 4.650 Millout EXT. 5 -1/2" 23# L-80 SLHT Pin x Pin _® :: 17 38 5797.87 1.34 6.050 3.260 Snaplatch 82 -40 S -36 5 -1/2" 23# SLHT Box x ACME Pin 37 5799.21 1.59 3.980 3.260 Seal Units 82 - 40 90H Stub ACME Box x Pin Nitrile �� 36 5800.80 5.00 3.980 3.260 Spacer Sub 82 -40 Stub ACME Box x Pin �_ � 35 5805.80 3.91 3.980 3.260 Seal Units 82 -40 90H Stub ACME Box x Pin Nitril _ . 34 5809.71 0.52 3.980 2.410 BTM Sub 82 -40 ACME Box x 2 -7/8" 6.4# Hyd. 511 Pin Down 33 5810.23 2.04 2.890 2.370 Space Out Pup 2 -7/8" 6.4# L-8 Hyd. 511 Box x Pin _, 32 5812.27 32.68 2.890 2.370 Tubing 2 -7/8" 6.4# L-80 Hvd. 511 Box x Pin ( 1 Joint a.,i� 31 5844.95 3.94 3.160 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd. 511 Box x Pin at. 15 30 5848.89 22.14 2.890 2.370 Space Out Pups 2 -7/8" 6.4# L-8 Hyd. 511 I Pups 10.05, 8.05, 4.04 ) , , 29 5871.03 554.96 2.890 2.370 Tubing 2 -7/8" 6.4# L -80 Hvd. 511 117 Joints ) ' 28 6425.99 3.93 3.170 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd 511 Box x Pin r - J ! 14 27 6429.92 1.18 3.230 2.400 Locator Seal Asse mbly 8 - 32 S -2 2 90H 2 -7/8" 6. H yd. 511 Box a ACME Pin 3 1 12 26 6431.10 11.00 3.230 2.400 Seal Units 80 -32 S -22 90H Stub ACME Box x Pin � 7 _ = 11 25 6442.10 0.47 3.230 2.390 BTM Sub 80 -32 S -22 ACME Box x 2 -7/8" 6.4# Hyd. 511 Pin Down - = 24 6442.57 28.10 2.890 2.370 Space Out Pups 2 -7/8" 6.4# L -8 Hvd. 511 Box x Pin ( 10.03. 10.03, 8.04) 23 6470.67 3.93 3.170 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd 511 Box x Pin . ± p ; 10 22 6474.60 20.09 2.890 2.370 Space Out Pups 2 -7/8" 6.4# L -8 Hvd. 511 Box x Pin ( 10.04, 10.05 ) + . 21 6494.69 196.20 2.890 2.370 Tubing 2 -7/8" 6.4# L-80 Hvd. 511 Box x Pin ( 6 Joints I ' 20 6690.89 3.93 3.170 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd 511 Box x Pin - } 19 6694.82 1.17 3.230 2.400 Locator Seal Assembly 80 -32 S -22 9011 2 -7/8" 6.4# Hyd. 511 Box a ACME Pin _ 18 6695.99 10.99 3.230 2.400 Seal Units 80 -32 S -22 90H Stub ACME Box x Pin - N ; 17 6706.98 0.47 3.230 2.390 BTM Sub 80 -32 S -22 ACME Box x 2 -7/8" 6.4# Hyd. 511 Pin Down $ a E" j3 J{ 16 6707.45 16.10 2.890 2.370 Space Out Pups 2 -7/8" 6.4# L-8 Hvd. 511 Box x Pin 1 8.06, 8.04 ) 15 6723.55 130.47 2.890 2.370 Tubing 2 -7/8" 6.4# L-80 Hvd. 511 Box x Pin ( Joints ) 4 14 6854.02 3.93 3.170 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd. 5I1 Box x Pin _ " 13 6857.95 1.17 3.230 2.400 Locator Seal Assembly 80 -32 S -22 90H 2 -7/8" 6.4# Hyd. 511 Box a ACME Pin 12 6859.12 10.99 3.230 2.400 Seal Units 80 -32 S -22 90H Stub ACME Box x Pin *. :*. !' 1 � 11 6870.11 0.47 3.230 2.390 BTM Sub 80 -32 S -22 ACME Box x 2 -7/8" 6.4# Hyd. 511 Pin Down r 10 6870.58 10.00 2.890 2.370 Space Out Pup 2 -7/8" 6.4# L-8 Hyd. 511 Box x Pin - r �:: 9 6880.58 325.93 2.890 2.370 Tubing 2 -7/8" 6.4# L-80 Hvd. 511 Box x Pin ( 10 Joints ) 8 7206.51 3.93 3.170 2.313 SLCMU BX Profile 2 -7/8" 6.4# Hyd 511 Box x Pin ®`E x 1 9 7 7210.44 8.03 2.890 2.370 Space Out Pup 2 -7/8" 6.4# L -8 Hyd. 511 Box x Pin ® - 6 7218.47 32.43 2.890 2.370 Tubing 2 -7/8" 6.4# L-80 Hyd. 511 Box x Pin ( 1 Joint ) .1 5 7 ® 5 7250.90 1.17 3.230 3.800 Locator Seal Assembly 80 -32 S -22 90H 2 -7/8" 6.4# Hyd. 511 Box a ACME Pin 4 7252.07 10.99 3.230 2.400 Seal Units 80 -32 S -22 90H Stub ACME Box x Pin ` s 8 3 7263.06 0.49 3.230 2.390 BTM Sub 80 -32 S -22 ACME Box x 2 -7/8" 6.4# Hyd. 511 Pin Down r x .) 7 2 7263.55 1.80 2.910 2.420 Half Mule Shoe 2 -7/8" 6.4# L -80 Hyd. 511 Box a aa 'a' + te r 1 7265.35 End Of Assembly 5 4 ' " 3 { I • WELL LOG TRANSMITTAL To: State of Alaska October 29, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: BRU 211 -26 REDO AK- MW- 5743286 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 211 -26 REDO 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 283 - 20128 -00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 283 - 20128 -00 Digital Log Images 1 CD Rom 50- 283 - 20128 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907 -273 -3536 Date: Signed: _ • 5- Oct -08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well BRU 211 -26 Dear Dear Sir /Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie -on Survey: 16.52 ' MD Window / Kickoff Survey: 0.00 ' MD (if applicable) Projected Survey: 7,786.00 ' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen @HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 rr Si Date 1 51 ned c� �� Signed call me at 273 -3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) • WELL LOG TRANSMITTAL To: State of Alaska October 13, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data BRU 211 -26 REDO AK -MW- 5743286 1 LDWG foiinatted CD Rom with verification listing. API #: 50 -283- 20128 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907 - 273 -3536 Date: Signed: cgOt l r 2 I P- 13 `i • • COnOCOPhilliPS TRANSMITTAL Beluga River Unit development well data FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, , Inc. State of Alaska p P.O. Box 100360 AOGCC Anchorage AK 99510 -0360 333 W. 7 Ave, Suite 100 Anchorage, Alaska 99501 -3539 RE: BRU 211 -26 Permit: 208 -112 DATE: 09/24/2008 Hand carry delivery Transmitted: Cook Inlet, Alaska Beluga River Unit 211 -26 5028320128000 Report and CDROM Final Well Report, Mud logging Data, BRU 211 -26; Epoch, report date: 9/2/2008. Contents, equipment and crew, well details, geological data, Drilling data, daily reports, Color log prints: Formation logs MD Formation Log TVD; LWD Combo MD; LWD COMBO TVD; Gas ratio MD; Gas ratio TVD; Drilling dynamics MD; Drilling dynamics TVD To all data [90 ients; All data is OI7 id rId /al until Sate of Alaska desr rated AO G ; r lease date CC: Rick L in-..n , PAI Geologist Receipt: _ Date: rt�� ,r G ,_. r , r± r -, r 3 �h. t 3n fl .... o� ] �c Alaska .., 907.266947 7, � - � �. � ' -� -: ®.� °...,� ra,�. ?r'.,Ja� � .,.�: ,��.at..� ;`'L � �, vt_m ;7z,.I � t��rrw /. >ol:��� i°� r,?� � `; r, .. SandraD,Lemke@Conacophillips.com 2 o15 - - I(. .#/6,93 ` 09/22/08 ( illtv, 1 Schhomherier NO. 4898 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Company: Alaska 011 & Gas Cons Comm ATTN: Beth Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit • Well Job # Log Description Date BL Color CD BRU 211-26 12092160 DS! 08/18/08 1 BRU 211-26 12092160 FMI 08/18/08 1 BRU 211-26 12092160 MSCT 08/18/08 1 BRU 211-26 12092160 MDT (SUMMARY PRINT) 08/18/08 1 BRU 211-26 12092160 MDT 08/18/08 1 BRU 211-26 12090930 USIT 08/29/08 1 BRU 211-26 12092160 LDWG OH EDIT 08/18/08 2 1 _ — Otri, I /*- I (0 • . _ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. - _ ..) 1 • WELL LOG TRANSMITTAL To: State of Alaska September 11, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: BRU 211 -26 AK -MW- 5743286 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 pn'Y g g, BRU 211 -26 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 283 - 20128 -00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 283 - 20128 -00 Digital Log Images 1 CD Rom 50- 283 - 20128 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: a Obis -I • WELL LOG TRANSMITTAL To: State of Alaska Aug 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data BRU 211-26 AK-MW-5743286 1 LDWG formatted CD Rom with verification listing. API#: 50-283-20128-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 E - Date: - = Signed: e'eg • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 16, 2008 9:29 AM To: 'Johnson, Vernon T (Halliburton Energy Services)' Cc: Chambers, Mark A Subject: RE: BRU 211 -26 Permit application cement plan clarification Thanks Vern. This helps me clarify what I read in the application. Tom Maunder, PE AOGCC From: Johnson, Vernon T (Halliburton Energy Services) [ mailto: Vern.J ohnson @contractor.conocophillips.com] Sent: Wednesday, July 16, 2008 9:23 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: BRU 211 -26 Permit application cement plan clarification Tom, Per our discussion yesterday, we plan to pump 50% excess cement on our surface casing cement job. Based on the volume of cement to surface observed on the last Beluga well, BRU 243 -34, we feel that 50% excess is a good number for planning purposes. If there are problems while drilling or suspected washouts, we will adjust this accordingly. The yield on BJ Services Lightweight 12 ppg slurry is 2.09 ft^3 /sk, so we plan to pump 775 sacks during the surface cement job. Let me know if you need further details. Vern Johnson 265 -6081 w 748 -3906 c 7/16/2008 • • 7 n: h d �' I I LI W € p [ i i g IA\ 1 SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 • CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 C. Alvord FAX PHONE (907) 279-1433 276-7542 Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 -0360 Re: Beluga River Field, Beluga Undefined Gas Pool, BRU 211 -26 ConocoPhillips Alaska Inc. Permit No: 208 -112 Surface Location: 625' FSL, 2570' FWL, SEC. 23, T13N, R1OW, SM Bottomhole Location: 643' FNL, 4300' FEL, SEC. 26, T13N, R1OW, SM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commissio • ' . etroleum field inspector at (907) 659 -3607 (pager). ` fir ' ` . ni -1T. - amount, Jr. ./ Chair DATED this / day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RE E -I. STATE OF ALASKA ? int ; ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 � Jt,v PERMIT TO DRILL , ,, F r( 20 AAC 25.005 NaS °'$ ''A j # la. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development 011 ❑ lc. Specify f well is pro for: Drill 0 . Re -drill ❑ Stratigraphic Test ❑ Service ❑ Development Gas Q Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ` Single Zone ❑ Shale Gas❑ 2. Operator Name: 5. Bond: U Blanket LJ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. . Bond No. 59 52 180 • BRU 211 - 26 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 7407' • TVD: 6642' , Beluga River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 625 FSL, 2570' FWL, Sec 23 T13N R10W SM ADL 021127 t Sterling - Beluga Gas Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 618 FNL 4280' FEL, Sec. 26 T13N R1 OW SM NA 7/18/2008 Total Depth: 9. Acres in Property: qSo fg • 14. Distance to 643 FNL 4300' FEL, Sec. 26 T13N R10W SM 1294 7.7• Nearest Property:8613 ft from MHT lease 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 91.5' above MSL • 15. Distance to Nearest Surface: x - 320588 • y - 2631019 • Zone 4 (Height above GL): 16.5' RKB feet Well within Pool: 232 -26 , 2049 ft • 16. Deviated wells: Kickoff depth: 399 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 50.4° deg Downhole: 3453 psig • Surface: 2723 psig 18. Casing Program Setting Depth Quantity of Cement Specifications Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) na 20" 154.2# X -65 Welded 88 16 16 104 104 driven 12.25" 9 -5/8" 40# L -80 BTC 3429 18 18 3447 2482 - 775 sx 12 ppg Lightweight slurry (BJ) 8.75" 7" 26# L -80 BTCM 7389 18 18 7407. 6642 - 295 sx 10 ppg Lightweight slurry (BJ) 4 -1/2" 12.6# L -80 IBTM 6522 18 18 6540 6311 production tubing and sand 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 Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Jl �f � Perforation Depth TVD (ft): 20. Attachments: Filing Fee ' t BOP Sketch Drilling Program❑ Time v. Depth Plot❑ Shallow Hazard Analysis ❑ Property Plat [J Diverter Sketch Seabed Report Drilling Fluid Program!! 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson Printed Name A C. Alvord Title Drilling Team Lead Signature ` ,/ F /�_n Phone �,��(� t 20 Date 7 ( Z ( �, 6 („_ (�' Commission Use Only Permit to Drill � API Number: Permit Approval See cover letter Number: ZG..�S � ( Z _ 50- ? 3 • 26 f Zt '� Date: 1.6 e . D e for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: r Samples req'd: Yes ❑ No Mud log req'd: YeCI No[✓ Other: H2S measures: Yes ❑ No RI ► recti.nal svy req'd: Yes Rt No ❑ ^D /, APPROVED BY THE COMMISSION DATE: r . ( l / , COMMISSIONER 1 . Form 10 -401 Revised 12/2005 ° ` " Submit in Duplicate X 7.6$ ConocoPhillips Alaska, Inc. `� Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 RECEIVED July 2, 2008 JUL 0 2 2008 Alaska Oil and Gas Conservation Commission Alaska Cil Gas Cons. Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill BRU 211 -26 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development gas well from an existing pad in the Beluga River Field, Alaska. The well is designed to penetrate the Beluga sands, log, evaluate and be completed as a gravel pack gas • producer. As indicated in the attachments, the drilling program will include drilling 12 -1/4" surface hole to approximately 3447' MD, cement 9 -5/8" surface casing, followed by drilling an 8- 3/4" hole through the Sterling and Beluga sands. After logging with LWD and electric line tools, 7" casing will be run and cemented. The completion program will include perforating, fracturing and gravel packing the target zones. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 6. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 7. A description of the drilling fluids handling system. • If you have any questions or require further information, please contact Vern Johnson at 265 -6081 or Chip Alvord at 265 -6120. Si rely, Vern Johnson Drilling Engineer Attachments cc: BRU 211 -26 Well File Chip Alvord ATO -1570 Mark Chambers ATO -1566 John Braden ATO -1392 Marta Czarneski Kenai LNG plant Greg Noble. BLM Anchorage Field Office • • BRU 211 -26 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy Gas Hydrates Low Monitor well, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures 9 P Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight. Offset Surface Formations drilling does not indicate abnormal pressures in the surface hole. Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled running speeds. 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real . time equivalent circulating density (ECD) monitoring, mud rheology, Pre - planned LCM pills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Medium BHA design, geologic review and advisement of potential slump blocks. Sloughing Shale, Tight High Increased mud density to control the shales and Hole ' fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Tight hole in coals Medium . Control drilling, mud logs, crew awareness Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Beluga : BRU 211 -26 General Procedure: 1. MIRU Nabors Rig 129 over pre - installed 20" conductor casing with welded landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 3447' MD / 2482' TVD. Run MWD / LWD logging tools (GR /RES) in drill string as required for directional monitoring and formation data gathering. • 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. • Employ lightweight cement lead slurry assure cement returns to the surface in a one -stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 3/4" bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 8. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 9. Drill 8 -3/4" hole to +/- 7407' MD / +/- 6642' TVD. Run MWD / LWD • (GR /RES /DENS /POROSITY) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for logging operations. 10. Log 8 -3/4" open hole with electric line tools (SP /SBL, DSI, FMI, RSWC, MDT). 11. Run and cement 7" casing per program to TD (est.@ 7407' MD/ 6642' TVD). Cement casing to bring cement +/- 500' above Sterling A sand. • If there are signs of lost circulation prior to running casing, install a Halliburton H ES stage cementing tool at +1- 3700' MD. 12. Run in hole with casing cleanup assembly on drillpipe. 13. Clean casing and pickle drillpipe. 14. Displace well to clean filtered brine. 15. Test casing to 5000 psi. 16. Rig up eline and run cement bond log GR / CCL. ORIGINAL i 1 17. Pick up and run in hole with tubing frac. String (4 -1/2" tubing). 18. Set tubing in slips, close pipe rams, and rig up electric line 19. Perforate with wireline tools 20. Fracture Stimulate 1 zone 21.Sand Back 22. Repeat perforating and fracturing 2 -3 times as needed 23. Clean out proppant 24. POOH with tubing string 25. Pick up approximately 1200' gross tubing conveyed perforating guns on drillpipe. 26. Perforate with large hole perforations- 4 -5/8" guns 27. Run Conventional gravel pack equipment with 2 -7/8" inner string to gravel pack lower interval. 28. Pump high rate water pack (HRWP). 29. Run inner string to isolate pack. 30. Pick up approximately 1500' gross 4 -5/8" tubing conveyed perforating guns. Perforate. 31. Run Multizone gravel pack completion, complete with 2 -7/8" and 1.9" inner strings. 32. Set packers, pump three HRWPs, and POOH with inner strings as required. 33. Run Upper completion per completion schematic. (Latch into anchor, shear PBR, space out, etc.) 34. Land tubing and test tubing hanger. 35.Test inner annulus to 2500 psi for 30 minutes. (Note: This will test our tubing integrity.) 36. Pressure up on IA to shear SOV at 3000 psi. 37. Set BPV and ND BOP. 38. Nipple up tree and test same. 39. RDMO. ORIGINAL . 1 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. BRU 232 -26 is the closest well. Well separation is 40' at 448' MD. Drilling Area Risks: The interbedded layers of the Sterling and Beluga sands may have reservoir pressure that varies from normal (water gradient) to depleted 3.5 - 4 ppg. Sufficient mud weight to control the shale and coal layers could provide very high (1700 psi +) overbalance on the depleted sand layers. Lost circulation is a risk. This will be mitigated by LCM, low fluid loss mud additives and wellbore strengthening additives. n n r‘INIAI • Drilling Fluid Program Surface Interval Fluid Properties Funnel API Fluid Drill Depth MD Mud Wt. Viscosity Yield Point Loss Solids (ft) (lb/gal c Ib /100ft m1/30min pH (%) MBT 0 - 3447 8.8 - 10 50 - 90 30 - 40 NC — <10 +/ - 9.5 <7% <35 Production Interval Fluid Properties API Fluid Depth MD Mud Wt. Funnel Yield Point Loss Solids u (ft) (ppg) Viscosity (Ib /100ft) z (m1/30min) pH (%) 3,447' — 7407' 9.0 —10 42 - 55 22 - 28 <6 9.0 — 9.5 9 —14 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Beluga Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are KCI which will be maintained at 6% by wt, and a proprietary shale inhibitor designed to enhance the inhibition of KCL as well as provide inhibition on it own. Other components of the system are Well Bore Strengthening p Y 9 9 materials designed to prevent lost circulation in low pressure depleted Zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times, as well as the option to increase KCL concentration for added density. ORIGINAL • . Completion Schematic: Conductor (Driven): 20 ", .75 ", API 5L GRB, Full Grvd, R3 Set @ Refusal Point i i • i %lee: • Chemical injection port with 3/8" SS control line 9 ; ::z r +/- 500' MD % :oat: - i • TOC 500' e above to p BP6i SCSSSV with Yr" SS control line to surface TOC +/- 3305 MD / 2750 TVD Sterling @c +/- 2000' MD Al r r. Ae 9 Surface Casino: e e i 9 -5/8 ", 40 #, L -80, BTC Formaton: Estimated Tops: Pore Pressure Set @ 3447' MD / 2841' TVD (200' TVD above Sterling -A) Sterling A 3805' MD / 3041' TVD Halliburton H ES HO stage tool@ + /- 3700' MD 3.66 PPG EMW -CONTINGENCY IF THERE ARE LOST CIRCULATION IQ 0 • Sterling B 4023' MD / 3276' ND Top Sterling A PROBLEMS- r rA ; Sterling C 4185' MD / 3426' TVD 4 -14" Camco KGB -2 GLM w/ 1" DCK2 shear valve M II r _I SC -2 Packer w/ Millout Extension - ; SC -1L Illation Packer • Formaton: Estimated Toos: Pore Pressure 0 r S o r ir Beluga D 4351' MD / 3586' TVD SC-1L Isolation Packer _ y • Ul I Beluga E 4602' MD / 3836' TVD 4.28 PPG EMW O % Too Bel ga F Beluga F 4957'MD/4191'TVD r SC -1L Isolation Packer • = i Beluga G 5447' MD / 4681' TVD r N i s O r Model FS Sumo Packer $ t +S Formaton: Estimated Toos: Pore Pressure SC -2 Packer w/ Alternate Bore r r Beluga H 5797' MD / 5031' ND Beluga H and I will require 4 m 8.33 PPG EMW y' Fracs followed by HRWP - ' Beluga I 6497' MD / 5734' TVD Top Beluga H ; Beluga I Base 7007 MD / 6421' ND t r A Model FS Sump Packer @ +/ -7000 ft MD m Production Casing: _$ 7 ", 26.00#, L -80, BTC -Mod Set @ 7407' MD / 6642' TVD r ( +/- 380' MD Below Beluga I Base) x 10 BRU 211 -26 prepared by Vern Johnson 7/2/08 Sperry Drilling Services Directional Plan wp06 ORIGINAL • BRU 211 -26 PRESSURE INFORMATION AND CASING DESIGN: Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Casing Setting Maximum Pore Pore Size Depth Pressure Pressure MASP Gradient Drilling 20" 110' MD / 110' 8.6 ppg 51 NA TVD 9 -5/8" 3447 MD / 2841' 9.0 ppg 1308 51 psi TVD 7" 7407' MD / 6641' 10 ppg 3453 2017 psi TVD Expected Maximum Mud Weights: • 12 -1/4" surface hole to 3447' MD / 2841' TVD: 9.4 ppg, pore pressures of up to 9.0 ppg may be present. • 8 -3/4" intermediate hole to 7407' MD / 6642' TVD: 10.4 ppg. The pore pressure is not expected to be above 10 ppg from offset drilling data and depletion due to production Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi /ft 0.11 = Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) — 0.11] x D = [(11.0 x 0.052) — 0.11] x 110' = 51 psi OR ORIGINAL 1 MASP = FPP — (0.11 x D) = 1330 — (0.11 x 2841') = 1017 psi 2. Drilling below 9 -5/8" Surface Casing MASP = [(FG x 0.052) — 0.11] x D MASP = [(16 x 0.052) — 0.11] x 2841' MASP = 2051 psi OR MASP = FPP — (0.11 x D) = 3453 - (0.11 x 6642') = 2723 psi See the included BOP schematics, diverter layout and for a minimum 3000 psi BOP configuration, it is planned to use a 5000 psi stack due to availability. Casing Design Performance Properties Size Hole Weight Grade Conn. Internal Collapse Tensile Yield Strength Joint Body 20" NA 154.2 X65 Welde conducto ppf d r 9 -5/8" 12.25 40 ppf L -80 BTC _ 5750 psi 3090 947 M 916 M 7" 8.75 26 ppf L -80 BTC -M 7240 psi 5410 641 M 604 M Casing Setting Depth Rational: 20" @ 110' MD RKB Conductor casing driven to provide sufficient anchor for diverter system. 9 -5/8" @ 3447' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8 -3/4" hole to top of reservoir. 7" @ 7407' MD RKBProduction casing is near the bottom of the Beluga sands to provide pressure integrity and zonal isolation. Assumptions a) Use of lightweight cement slurries cement slurries for design purposes b) Temperature deration of pipe properties has not been applied to all strings c) Assume higher than expected mud weight, - conservative for most cases DRIGINAL • Cementing Program: 9 5/8" Surface Casing run to 3447' MD / 2841' TVD Cement from 3447' MD to surface with lightweight 12 ppg slurry. Assume 100% excess annular volume. 1)ccx A °< (‘t,, Lead slurry:(3447'- surface) X 0.3132 ft /ft X 1.5 ( % excess) = 1619.4 ft => 775 sx @ 2.09 ft /sk System: 775 Sx Type 1 Cement + 0.9% bwoc BA -10A + 0.1% bwoc FL -52 + 0.05% bwoc Static Free + 25% bwoc LW -6 + 0.6% bwoc CD -32 + 1 gals /100 sack FP -6L + 0.4% bwoc Sodium Metasilicate + 5% bwoc MPA -1 + 67.9% Fresh Water , Yielding 2.09 ft3 /sk 7" Production, Casing run to 7407' MD / 6642' TVD Cement from 7407' MD to +/- 3305' MD (minimum 500' MD above top of Sterling formation) with lightweight cement 10 ppg. Assume 40% excess annular volume. Tail: (7407' — 3305') X 0.1503 ft /ft X 1.4 (40% excess) = 863.1 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 863.1 + 17.2 = 880.3 ft => 295 Sx @ 2.99 ft /sk System: 295 Sx Class G + 22% bwoc LW -7 -6 + 15% bwoc BA -90 + 1% bwoc CD -32 0.6% bwoc Sodium Metasilicate + 1.2 % bwoc FL -52 + 0.05% bwoc static free + 1 gal /100sk FP -6L + fresh water@ 10.0 ppg, yielding 2.99 ft /sk If there are problems with lost circulation during drilling, logging or tripping, consideration will be made to including a hydraulic opening stage tool in the casing string, to help ensure cement coverage of the Sterling formation. ORIGINAL • 0 1 * i l 1 1 } ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 211 -26 Plan: BRU 211 -26 Plan: BRU 211-26wp06 Standard Proposal Report 24 June, 2008 Gm. In HALLIBUPTON Sperry Drilling Services 1 I I ORIGINAL Beluga River Beluga River Ground Level: 75.00 Plan: BRU 211 -26 RKB: Plan: BRU 211-26 (16.5+75) @ 91.50ft (Nabors 129) BRU 211 26wp06 Plan. BRU 211 -26 Northing/ASP Easting/ASP X: 1460615.32 BRU 211- 26wp06 0 -350 r' o co / L 8 -700 z C n - - - 95/8 " x121/4" -1050 BRU 211 -26wp 7" x 8 -3/4" I ' BRU 211 -26w03 Base Beluga I I 1 I -1750 -1400 -1050 -700 -350 0 350 West( -) /East( +) (350 ft/in) 4 0 o° c 10` O V. o 4o un N 6 : 95/8'x121/4' —2500 (0 7 . o _ ` p .t^ - BRU 211 -26w03 Beluga D U B E top — - L Beluga F top j 5000 - = Beluga G top — -- - - a) Beluga H top H Beluga I top_ BRU 211 -26w03 Base Beluga Beluga I base BRU 211- 26wp06 7" x 8 -3/4" -5000 -2500 0 2500 5000 7500 Vertical Section at 231.61° (2500 ft/in) ORIGINAL S 4 ConocoPhillips(Alaska) Inc. 0 Beluga River Beluga River Plan: BRU 211 -26 Plan: BRU 211 -26 0 Plan: BRU 211- 26wp06 ra { Standard Proposal Report 25 June, 2008 [NA D 27 C. i MALLIBURTON Sperry Drilling Services I i L ORIGINAL • III0 Conoco Phillips HALLIBURTONI Standard Proposal Report -,.., EDM v16 Prod Local Co-ordinate Reference: Well Plan: BRU 211-26 ConocoPhillips(Alaska) Inc. TVD Reference: .. , Plan: BRU 211-26 (16.5+75) @ 91.50ft (Nabors Beluga River MD Reference: "47 Plan: BRU 211-26 (16.5+75) @ 91.50ft (Nabors , • siai - 7: 7 ''' - A, Beluga River North Reference: True ' „,_....„.„„,„„„-, ' ,',., Welk '", .ii"? Plan: BRU 211-26 Survey varres won , 0 . -' 0'.., +7.' Minimum Curvature , Welibore: Plan: BRU 211-26 Design: '':.: BRU 211-26wp06 'project ..,' Seluga River, Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADGON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site - .„7,,, 1:777v Beluga River, Site Position: Northing: 5,959,669.68ft Latitude: 70° 18' 1.318 N From: Map Easting: 561,086.44ft Longitude: 149° 30' 18.921 W Position Uncertainty: 0.00 ft Slot Radius: 36" Grid Convergence: 0.47 ° PI ty BRU 211-26 . ' I Well Position +N/-S 0.00 ft Northing: 2,631,019.00 ft • Latitude: 61° 11' 50.781 N +E/ 0.00 ft Easting: 320,588.00 ft . Longitude: 151° 1' 1.488 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 75.00ft ," • , . -re ‘77„, Plan . BRU 211 "` - WI *del Name 7 ,:i Sample Date Declination Dip Angle , iieid Strength "07T , 77 74 t7-7 7 (0) BGGM2007 6/24/2008 16.31 72.93 54,995 Design ...... .. ..,„- 7 .'' ' •77 7...7 7 - , 7 ■ ■ , , 7 ' ' ' BRU 211-26wp06 Audit Notes: Version: 3 Phase: PLAN Tie On Depth: 16.50 ": ..: ... , . : , , - :...4::;:,.;:.: from (TVD) +N/-S 7' +EI-W 7 7 ,.. - '3"` 7 , 111 - '*".....*: , ;; k (ft) (ft) , (ft) . ,, ,-:,,,4,1*,it , (4, , ,,,, ,, , :; ;A• ii , pp , s, ,,.. ,, : ,,,,.. 16.50 0.00 0.00 231.61 System ,02!„.., ,, .. ' , , . ell, ,,--, ,,.; '1 -' - 7.: 1 77 -." .. - .,•raiti7Z 1 - : 77 Mu -!,...;- , - „Vertical TVD " ,, ' i '''," ..`;':',.' ' 41 ! eg ild .1 ,, inclination Azim ' f . '4.? , i -... . S: 4+11-S - '3::. ' Rate Ric Rate Toot FO Taat: c.,) . ft ''' ' (ft) (ft) '42 (0 (0IMf) 16.50 0.00 0.00 16.50 -75.00 0.00 0.00 0.00 0.00 0.00 0.00 398.50 0.00 0.00 398.50 307.00 0.00 0.00 0.00 0.00 0.00 0.00 598.50 3.50 0.00 598.38 506.88 6.11 0.00 1.75 1.75 0.00 0.00 2,355.06 50.41 230.17 2,145.42 2,053.92 -403.05 -559.73 3.00 2.67 -7.39 -131.94 3,542.85 50.41 230.17 2,902.46 2,810.96 -989.34 -1,262.57 0.00 0.00 0.00 0.00 4,350.97 10.00 230.93 3,586.50 3,495.00 -1,243.63 -1,568.94 5.00 -5.00 0.09 179.80 4,636.68 0.00 0.00 3,870.77 3,779.27 -1,259.30 -1,588.25 3.50 -3.50 0.00 180.00 7,007.42 0.00 0.00 6,241.50 6,150.00 -1,259.30 -1,588.25 0.00 0.00 0.00 0.00 7,407.42 0.00 0.00 6,641.50 6,550.00 -1,259.30 -1,588.25 0.00 0.00 0.00 0.00 [NAD 2 71 6/25/2008 10:45:42AM Page 2 COMPASS 2003.16 Build 42F ORIGIN AL ConocoPhillips HALLIBURTON Standard Proposal Report r Dc .. EDM v16 Prod LocaiCo.ordin Reference: Well Plan: BRU 211 -26 Company t - ' ConocoPhillips(Alaska) Inc. 'ND R Plan: BRU 211 -26 (16.5 +75) © 91.50ft (Nabors project 'ill Beluga River MD Reference: Plan: BRU 211 -26 (16.5 +75) @ 91.50ft (Nabors ` Beluga River North ce: True u k _ Plan: BRU 211 -26 Survey Calculation Method: Minimum Curvature r` Plan: BRU 211 -26 ® q a , . BRU 211- 26wp06 G i a =. i %Fi`ve74�F;,. try. sku =37i3u 2.. Y ' P RIM, --..;P,-; . i m' '§ $ '7 v . t ..' ": pY Mea9 V ' ° 'ma ,: ma g , t , ,.0 Depth , , Azimuth ' ,. ' 4 :+EI W ing ' = Fasting D Vert t „ ; (ft) ° (ft) ft ztt ( AN:: - '''..,';,...:, 'i - 7 1 ° 16.50 0.00 0.00 16.50 -75.00 0.00 0.00 2,631,019.00 320,588.00 0.00 0.00 100.00 0.00 0.00 100.00 8.50 0.00 0.00 2,631,019.00 320,588.00 0.00 0.00 200.00 0.00 0.00 200.00 108.50 0.00 0.00 2,631,019.00 320,588.00 0.00 0.00 300.00 0.00 0.00 300.00 208.50 0.00 0.00 2,631,019.00 320,588.00 0.00 0.00 398.50 0.00 0.00 398.50 307.00 0.00 0.00 2,631,019.00 320,588.00 0.00 0.00 r Start Build 1.75 400.00 0.03 0.00 400.00 308.50 0.00 0.00 2,631,019.00 320,588.00 1.75 0.00 500.00 1.78 0.00 499.98 408.48 1.57 0.00 2,631,020.57 320,588.02 1.75 -0.98 598.50 3.50 0.00 598.38 506.88 6.11 0.00 2,631,025.10 320,588.09 1.75 -3.79 Start DLS 3.00 TFO -131.94 600.00 3.47 359.45 599.87 508.37 6.20 0.00 2,631,025.19 320,588.10 3.00 -3.85 700.00 2.70 302.86 699.75 608.25 10.50 -2.01 2,631,029.53 320,586.16 3.00 -4.95 800.00 4.53 263.06 799.56 708.06 11.30 -7.90 2,631,030.42 320,580.28 3.00 -0.83 900.00 7.19 249.13 899.03 807.53 8.60 -17.67 2,631,027.86 320,570.47 3.00 8.51 1,000.00 10.04 242.88 997.90 906.40 2.39 -31.28 2,631,021.87 320,556.76 3.00 23.03 1,100.00 12.96 239.40 1,095.88 1,004.38 -7.30 -48.70 2,631,012.46 320,539.19 3.00 42.70 1,200.00 15.91 237.19 1,192.71 1,101.21 -20.44 -69.88 2,630,999.65 320,517.81 3.00 67.47 1 1,300.00 18.88 235.65 1,288.13 1,196.63 -37.00 -94.77 2,630,983.48 320,492.68 3.00 97.26 1,400.00 21.85 234.52 1,381.87 1,290.37 -56.93 - 123.28 2,630,963.99 320,463.85 3.00 131.99 1,500.00 24.83 233.65 1,473.67 1,382.17 -80.19 - 155.36 2,630,941.24 320,431.42 3.00 171.57 1,600.00 27.82 232.95 1,563.29 1,471.79 - 106.70 - 190.90 2,630,915.29 320,395.47 3.00 215.89 1,700.00 30.80 232.38 1,650.48 1,558.98 - 136.39 - 229.82 2,630,886.21 320,356.10 3.00 264.83 1,800.00 33.79 231.91 1,735.00 1,643.50 - 169.18 - 271.99 2,630,854.08 320,313.42 3.00 318.25 1,900.00 36.78 231.50 1,816.61 1,725.11 - 204.98 - 317.32 2,630,818.99 320,267.55 3.00 376.02 2,000.00 39.78 231.14 1,895.10 1,803.60 - 243.70 - 365.67 2,630,781.03 320,218.60 3.00 437.96 2,100.00 42.77 230.83 1,970.25 1,878.75 - 285.23 - 416.92 2,630,740.31 320,166.72 3.00 503.91 2,200.00 45.76 230.55 2,041.86 1,950.36 - 329.44 - 470.91 2,630,696.94 320,112.05 3.00 573.69 2,300.00 48.76 230.30 2,109.72 2,018.22 - 376.23 - 527.51 2,630,651.04 320,054.74 3.00 647.11 2,355.06 50.41 230.17 2,145.42 2,053.92 - 403.05 - 559.73 2,630,624.73 320,022.11 3.00 689.02 2,355.09 50.41 230.17 2,145.44 2,053.94 - 403.06 - 559.74 2,630,624.71 320,022.09 0.00 689.04 Start 1187.76 hold at 2355:09 MD 2,400.00 50.41 230.17 2,174.06 2,082.56 - 425.23 - 586.32 2,630,602.96 319,995.17 0.00 723.63 2,500.00 50.41 230.17 2,237.80 2,146.30 - 474.59 - 645.49 2,630,554.53 319,935.25 0.00 800.67 2,600.00 50.41 230.17 2,301.53 2,210.03 - 523.95 - 704.66 2,630,506.10 319,875.32 0.00 877.70 2,700.00 50.41 230.17 2,365.27 2,273.77 - 573.31 - 763.84 2,630,457.67 319,815.39 0.00 954.73 2,800.00 50.41 230.17 2,429.00 2,337.50 - 622.67 - 823.01 2,630,409.24 319,755.46 0.00 1,031.76 2,900.00 50.41 230.17 2,492.74 2,401.24 - 672.03 - 882.18 2,630,360.81 319,695.53 0.00 1,108.80 3,000.00 50.41 230.17 2,556.47 2,464.97 - 721.39 - 941.35 2,630,312.38 319,635.60 0.00 1,185.83 3,100.00 50.41 230.17 2,620.21 2,528.71 - 770.75 - 1,000.53 2,630,263.95 319,575.67 0.00 1,262.86 3,200.00 50.41 230.17 2,683.94 2,592.44 - 820.11 - 1,059.70 2,630,215.52 319,515.74 0.00 1,339.89 3,300.00 50.41 230.17 2,747.68 2,656.18 - 869.47 - 1,118.87 2,630,167.09 319,455.81 0.00 1,416.93 3,400.00 50.41 230.17 2,811.41 2,719.91 - 918.83 - 1,178.05 2,630,118.66 319,395.88 0.00 1,493.96 3,447.20 50.41 230.17 2,841.50 2,750.00 - 942.13 - 1,205.98 2,630,095.80 319,367.59 0.00 1,530.32 95/8" x 121/4" 3,500.00 50.41 230.17 2,875.15 2,783.65 - 968.19 - 1,237.22 2,630,070.23 319,335.95 0.00 1,570.99 6/25/2008 10:45:42AM Page 3 COMPASS 2003.16 Build 42F flR • • ConocoPhillips HALL HALLIBLJRTON Standard Proposal Report taGase. EDM v16 Prod Local Co -ord • nce Well Plan BRU 211 -26 pang- ConocoPhillips(Alaska) Inc. ' /bitigeren e: Plan: BRU 211 -26 (16.5 +75) © 91.50ft (Nabors Beluga River MD Reference:, ii Plan: BRU 211 -26 (16.5 +75) © 91.50ft (Nabors Beluga River - a True i " Plan: BRU 211 -26 Survey C e , w , 't od.. M Curvature U bore Plan: BRU 211 -26 s . - . • BRU 211- 26wp06 , _.. , . ". o,... ."w•, ter• 'Survey., Measured u Vertical Map Map , f " ° DOpptr I nclination Azh Depth T1VD +HAS +Ei-W Northing Easting DLL._ ert Sectio r� 1 * (°) � , t ' ( ft (ft) " (ft) (It) (ft) 2,8101= ` . 3,542.85 50.41 230.17 2,902.46 2,810.96 - 989.34 - 1,262.57 2,630,049.48 319,310.27 0.00 1,604.00 Sta. 5:,0O ITO 179.80 3,600.00 47.55 230.18 2,939.97 2,848.47 - 1,016.95 - 1,295.68 2,630,022.39 319,276.74 5.00 1,647.10 3,700.00 42.55 230.21 3,010.60 2,919.10 - 1,062.24 - 1,350.03 2,629,977.95 319,221.69 5.00 1,717.82 3,800.00 37.55 230.24 3,087.12 2,995.62 - 1,103.39 - 1,399.47 2,629,937.57 319,171.63 5.00 1,782.12 3,805.51 37.27 230.24 3,091.50 3,000.00 - 1,105.53 - 1,402.04 2,629,935.47 319,169.02 5.00 1,785.47 Sterling A top 3,900.00 32.55 230.28 3,168.97 3,077.47 - 1,140.09 - 1,443.61 2,629,901.57 319,126.92 5.00 1,839.52 4,000.00 27.55 230.34 3,255.50 3,164.00 - 1,172.06 - 1,482.13 2,629,870.20 319,087.91 5.00 1,889.56 4,023.56 26.37 230.35 3,276.50 3,185.00 - 1,178.88 - 1,490.35 2,629,863.52 319,079.59 5.00 1,900.24 Sterling B top 4,100.00 22.55 230.42 3,346.07 3,254.57 - 1,199.06 - 1,514.73 2,629,843.72 319,054.90 5.00 1,931.87 4,185.84 18.26 230.51 3,426.50 3,335.00 - 1,218.10 - 1,537.80 2,629,825.04 319,031.54 5.00 1,961.78 Sterling C top 4,200.00 17.55 230.53 3,439.98 3,348.48 - 1,220.87 - 1,541.16 2,629,822.32 319,028.14 5.00 1,966.14 4,300.00 12.55 230.74 3,536.52 3,445.02 - 1,237.34 - 1,561.22 2,629,806.17 319,007.82 5.00 1,992.09 4,350.97 10.00 230.93 3,586.50 3,495.00 - 1,243.63 - 1,568.94 2,629,800.00 319,000.00 5.00 2,002.05 Beluga D top - BRU 211 - 26w03 Beluga D 4,350.99 10.00 230.93 3,586.52 3,495.02 - 1,243.63 - 1,568.95 2,629,800.00 319,000.00 0.00 2,002.05 Start Drop -3.50 4,400.00 8.28 230.93 3,634.91 3,543.41 - 1,248.54 - 1,574.99 2,629,795.19 318,993.88 3.50 2,009.84 4,500.00 4.78 230.93 3,734.24 3,642.74 - 1,255.71 - 1,583.83 2,629,788.15 318,984.93 3.50 2,021.22 4,600.00 1.28 230.93 3,834.08 3,742.58 - 1,259.05 - 1,587.93 2,629,784.88 318,980.77 3.50 2,026.51 4,602.42 1.20 230.93 3,836.50 3,745.00 - 1,259.08 - 1,587.97 2,629,784.85 318,980.73 3.50 2,026.56 Beluga E top 4,636.68 0.00 0.00 3,870.77 3,779.27 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 3.50 2,026.92 4,636.70 0.00 0.00 3,870.79 3,779.29 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 ;.::Start 2370.73NOM rt. 6.7O MD 4,700.00 0.00 0.00 3,934.08 3,842.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 4,800.00 0.00 0.00 4,034.08 3,942.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 4,900.00 0.00 0.00 4,134.08 4,042.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 4,957.42 0.00 0.00 4,191.50 4,100.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Beluga F top 5,000.00 0.00 0.00 4,234.08 4,142.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,100.00 0.00 0.00 4,334.08 4,242.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,200.00 0.00 0.00 4,434.08 4,342.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,300.00 0.00 0.00 4,534.08 4,442.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,400.00 0.00 0.00 4,634.08 4,542.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,447.42 0.00 0.00 4,681.50 4,590.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Beluga G top 5,500.00 0.00 0.00 4,734.08 4,642.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,600.00 0.00 0.00 4,834.08 4,742.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,700.00 0.00 0.00 4,934.08 4,842.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,797.42 0.00 0.00 5,031.50 4,940.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Beluga H top , , , . 6/25/2008 10:45:42AM Page 4 COMPASS 2003.16 Build 42F ORIGINAL ConocoPhillips H HALLIBURTCIN Standard Proposal Report Database EDM v16 Prod L tl- ordinate Ft ce Well Plan: BRU 211 -26 pany: ConocoPhillips(Alaska) Inc. 4 T Reference Plan: BRU 211 -26 (16.5 +75) © 91.50ft (Nabors Beluga River )i r �- Plan: BRU 211 -26 (16.5 +75) @ 91.50ft (Nabors t'a`7 Beluga River r ce, i True Plan: BRU 211 -26 Survey u llmion " t Minimum Curvature ° Plan: BRU 211-26 ® BRU 211- 26wp06 Planned Survey as y: H " Map pth 'south ' IVDss W N ` in Eas�i o �n a " (ft) x ft ) f V " 5,800.00 0.00 0.00 5,034.08 4,942.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 5,900.00 0.00 0.00 5,134.08 5,042.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,000.00 0.00 0.00 5,234.08 5,142.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,100.00 0.00 0.00 5,334.08 5,242.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,200.00 0.00 0.00 5,434.08 5,342.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,300.00 0.00 0.00 5,534.08 5,442.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,400.00 0.00 0.00 5,634.08 5,542.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,497.42 0.00 0.00 5,731.50 5,640.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Beluga I top 6,500.00 0.00 0.00 5,734.08 5,642.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,600.00 0.00 0.00 5,834.08 5,742.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,700.00 0.00 0.00 5,934.08 5,842.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,800.00 0.00 0.00 6,034.08 5,942.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 6,900.00 0.00 0.00 6,134.08 6,042.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,000.00 0.00 0.00 6,234.08 6,142.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,007.42 0.00 0.00 6,241.50 6,150.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Beluga I base BRU 1t1 =26v Base Beluga 7,007.44 0.00 0.00 6,241.52 6,150.02 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 Start 400.00 hold at 7007.44 MD 7,100.00 0.00 0.00 6,334.08 6,242.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,200.00 0.00 0.00 6,434.08 6,342.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,300.00 0.00 0.00 6,534.08 6,442.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,400.00 0.00 0.00 6,634.08 6,542.58 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7,407.42 0.00 0.00 6,641.50 .6,550.00 - 1,259.30 - 1,588.25 2,629,784.63 318,980.45 0.00 2,026.92 7" x tt "- gym., , Target Name g - hiUmiSs, e Di Dir. Nf °°,-",' N o t`th n9 Shape s ( + � (ft) Y BRU 211 -26w03 Base Beluga 0.00 0.00 6,241.50 - 1,243.63 - 1,568.94 2,629,800.00 319,000.00 - plan misses by 24.87ft at 7007.42ft MD (6241.50 TVD, - 1259.30 N, - 1588.25 E) - Point BRU 211 -26w03 Beluga D Circle 0.00 0.00 3,586.50 - 1,243.63 - 1,568.94 2,629,800.00 319,000.00 - plan hits target - Circle (radius 1,320.00) BRU 211 -26w03 Beluga D 0.00 0.00 3,586.50 - 1,243.63 - 1,568.94 2,629,800.00 319,000.00 - plan hits target - Point 6/25/2008 10:45:42AM Page 5 COMPASS 2003.16 Build 42F OR! NtJ • • ConocoPhillips H LLI T Standard Proposal Report Data EDM v16 Prod Local C o -ordi Referen Well PlanBR: BRU 211 -26 211 -26. �Compart „ ConocoPhillips(Alaska) Inc. 1VD Reference i , 4 Plan: U (16. @ . Project ,I Beluga River MD Referrent ± '' . p Plan: BRU 211 -26 (16.5 +75) 5 +75) @ 91 50ft (Nabors (Nabors Site: Beluga River h ° R afe a :. True WeIL '' Plan: BRU 211 -26 Caicu M ini m u m Curvature W '''' Plan: BRU 211 -26 max, BRU 211- 26wp06 ri C asing P oints AS '0_ M eas u rei i ' g z ,� eptii Depth ° ® a. r0 ' i r . .. '31 (ft) (ft) _:*Voi - :F. S k i 'Y � +. k�... "ten" rRy 1/4'-':'*" ..�E '12-:174' + *, *F ,p` y+Y . 3,447.20 2,841.50 9 5/8" x 12 1/4" 9 5/8 7,407.42 6,641.50 7" x 8 -3/4" 7 8 -3/4 Formatio a Ver tical Dip ®: . Dew �� D ip Directusn Y,., (ft? µ . ,' ib � ., °'' r. off : � � 4,350.97 3,586.50 Beluga D top 7,007.42 6,241.50 Beluga I base 3,805.51 3,091.50 Sterling A top 4,957.42 4,191.50 Beluga F top 5,447.42 4,681.50 Beluga G top 5,797.42 5,031.50 Beluga H top 6,497.42 5,731.50 Beluga I top 4,602.42 3,836.50 Beluga E top 4,185.84 3,426.50 Sterling C top 4,023.56 3,276.50 Sterling B top a ons M Y " #, } Local co±; r hates ; ,. „ , - ,, pu, Dtp :IV 39 th .„..g.. .. ,, � u « x. Con 4 , 1 8.50 398.50 0.00 0.00 Start Build 1.75 598.50 598.38 6.11 0. DFO 131.94 2,355.09 2,145.44 -403.06 55900 .74 StartStart 1187.76 LS 3.00 ho at 2355.09 MD 3,542.85 2,902.46 - 989.34 1,262.57 Start DLS 5.00 TFO 179.80 4,350.99 3,586.52 -1,243.63 1,568.95 Start Drop 3.50 4,636.70 3,870.79 - 1,259.30 1,588.25 Start 2370.73 hold at 4636.70 MD 7,007.44 6,241.52 -1,259.30 1,588.25 Start 400.00 hold at 7007.44 MD 7,407.44 TD at 7407.44 [NAD 7 ] 6/25/2008 10:45:42AM Page 6 COMPASS 2003.16 Build 42F U t ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 211-26 Plan: BRU 211-26 BRU 211- 26wp06 • } Sperry Drilling Services s , : Clearance Summary Anticollision Report 24 June, 2008 F T. Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River - Plan: BRU 211 -26 - Plan: BRU 211 -26 - BRU 211- 26wp06 Well Coordinates: 2,630,779.41 N, 1,460,615.32 E (61° 11' 48.77" N, 151° 01' 09.51" W) Datum Height: Plan: BRU 211 -26 (16.5 +75) @ 91.50ft (Nabors 129) Scan Range: 0.00 to 7,407.44 ft. Measured Depth. Scan Radius is 939.09 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 . HALLIBURTON . i Sperry Drilling Services 1 BRU 211 26wp06 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference p Elli soid Color 16.50 To 7407.44 17 249 1749 1999 4999 ---" 5999 13999 15999 3RU 224 -22 249 499 1999 ' 2499 5999 6999 15999 17999 499 749 2499 2999 6999 7999 17999 19999 749 "— - 999 2999 3499 7999 8999 19999 24999 0 / 360 999 - -- 1249 3499 3999 8999 9999 1249 1499 3999 4499 9999 11999 MI� .: 1I 30 / 330 i l►0 � `I 0 30 1499 1749 4499 4999 11999 13999 'A �i 200 � - 0/360 • i��a�•f 50 ;:wemo. -60 / 300 . 60 -30 / 330 30 _ .` 101 _01 ® -60 / 300 60 G) -90 / 270 90 : ► ►.�� -90 / 270 Tg liliril 90 � ���I r ;I ���111,I4i A wI i ��,,� ���� �� < ✓iii:: -120 / 240 °•el O i 120 V � �Ii� 0i�; —4 120 / 240 �� 0 0 / 11F6e, „ 120 1 �� mss.. , .r ,. �; 200 3RU 232 2E 0 • -150 / 210 150 -150 / 210 ti j ( 4 j3�150 -180 /180 - 180/180, EIRU 232 - 26 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation MOO ft/in] Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON Beluga River Anticollision Report for Plan: BRU 211 -26 - BRU 211- 26wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River - Plan: BRU 211 -26 - Plan: BRU 211 -26 - BRU 211- 26wp06 Scan Range: 0.00 to 7,407.44 ft. Measured Depth. Scan Radius is 939.09 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Beluga River BRU 224 -23 - BRU 224 -23 - BRU 224 -23 728.08 113.63 728.08 95.92 725.00 6.416 Centre Distance Pass - Major Risk BRU 224 -23 - BRU 224 -23 - BRU 224 -23 803.15 114.42 803.15 94.90 800.00 5.863 Clearance Factor Pass - Major Risk BRU 232 -26 - BRU 232 -26 - BRU 232 -26 448.47 39.51 448.47 30.65 450.00 4.459 Centre Distance Pass - Major Risk CD BRU 232 -26 - BRU 232 -26 - BRU 232 -26 850.75 41.01 850.75 24.67 850.00 2.510 Clearance Factor Pass - Major Risk Prelim: BRU 232- 26ALT(3) - Prelim: BRU 232- 26ALT(; 398.50 40.33 398.50 33.46 400.00 5.876 Centre Distance Pass - Major Risk 70 Prelim: BRU 232- 26ALT(3) - Prelim: BRU 232- 26ALT(: 523.35 40.62 523.35 31.79 525.00 4.601 Clearance Factor Pass - Major Risk Prelim: BRU 232- 26ALT(5) - Prelim: BRU 232- 26ALT(E - V ) Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 16.50 7,407.44 BRU 211- 26wp06 MWD +SCC +SAG Ellipse error terms are correlated across survey tool tie -on points. • Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. I 24 June, 2008 - 15:39 Page 2 of 4 COMPASS I 1455600 1456000 1456400 1456800 1457200 1457600 1458000 1458400 1458800 1459200 1459600 1460000 1460400 1460800 1461200 1461600 1462000 1462400 Date prepared: 2632400- 15:44, June 24 2008 632400 2632000- - - 2632000 2631600- BRU 224 -23 - - 2631600 2631200- - 2631200 • 2630800- - 2630800 2630400- - 2630400 0 630000- - 2630000 629600- - 2629600 r ".4 2629200- - - 2629200 BRU 211- 26wp06 2628800- - 2628800 • 2628400- - 2628400 BRU 232 -26 = 2628000- - 2628000 2627600- - 2627600 = ConocoPhillips (Alaska) Inc. -Expl = Beluga River - 2627200- Beluga River - 2627200 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 1 I I I I l I I I I l I I I 1 1 i I l 1 1 I 1 1 1 1 I I l I l I I I I l I I I l I I l 1 1 1 I I I I l I I I I l I l l l l 1455600 1456000 1456400 1456800 1457200 1457600 1458000 1458400 1458800 1459200 1459600 1460000 1460400 1460800 1461200 1461600 1462000 1462400 Easting (800 ft/in) °Paulen ConocoPhlips (Alaska) Inc..E Grid Correction: -0.89 ° lob No: YX /A belch Beluga duet Magnetic Declination: 19.10 ° APE No: IIN /A Wet IRE 211- 26wp06 Dia: 73.99 ° API No: !X /A NW 8N /A Dogleg P.7 100 ft System (ND) Reference: Mean Sea level Surface location Original VS Plane: 231.61 ° Parentwel: 9lan:1110 211 -26 X: 146061,32 ft View VS Plane: 231.61 ° RYE Neigh: 97.50 R 3: 2630779.41 ft unit Syd.m: API eased / UPS Section (VS) Reference: got Comments: POOL: flon View! i 8 BRU 211- 26wp06 Plan: 3495' to 6150' TVDss BRU 232 -26: 3495' to 6150' TVDss BRU 224 -23: 3495' to 6150' TVDss ------------------------- - - - - -- 2631200 A A A A A • < A X A N Ar .--r -- -- 2630200 P S r zo r Ar r A'f Section View' - y - —..—BRU (���) BRU 2,1- 26wp06 Plan BRU 232 -26 224 -23 � V -- -- - 2629200 t _______- ............... ' :3 26 p - r ti- 2628200 _� �� `--- A ,- -A. East ( +( / West ( -) N �' 3200 E — 4200 5200 Ilii 21 ff 6200 23:22 7200 0 0 8 8 8 o co Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (BRU 211- 26wp06 Toolbox.xls) 6/24/2008 4:08 PM Closest in POOL Closest Approach: Reference Well: BRU 211- 26wp06 Plan Offset Well: BRU 232 -26 Coords. - Coords. - ASP ASP • 3 -D ctr -ctr Horizc s Meas. Incl. Subsea N( +) /S( -) View VS Meas. Incl. Subsea N( +) /S( -) View VS Distance. D ,tan ..> •.ce Depth Angle TRUE Azi. TVD E( +)/W( -) (231.61 °) Comments Depth Angle TRUE Azi. TVD E( +)/W( -) (231.61 °) Comments POOL Min Distance POOL Min Distance (2048.98 ft) in POOL (2048.98 ft) in POOL (3495 - 6150 TVDss) (3495 - 6150 TVDss) to BRU 211- 26wp06 to BRU 232 -26 (3495 - Plan (3495 - 6150 2048.98 3 r 4375.99 9.12 230.92 3519.58 2629558 1459024 2006.28 6150 TVDss) 4175 28.03 177.11 3490.44 2629017 1461000 734.61 TVDss) Closest Approach: Reference Well: BRU 211- 26wp06 Plan Offset Well: BRU 224 -23 Coords. - Coords. - ASP ASP 3 -D ctr -ctr ;- onr<: , Meas. Incl. Subsea N( +)/S( -) View VS Meas. Incl. Subsea N( +) /S( -) View VS Distance. ice Depth Angle TRUE Azi. TVD E( +)/W( -) (231.61 °) Comments Depth Angle TRUE Azi. TVD E( +)/W( -) (231.61 °) Comments POOL Min Distance POOL Min Distance (2212.56 ft) in POOL (2212.56 ft) in POOL (3495 - 6150 TVDss) (3495 - 6150 TVDss) to BRU 211- 26wp06 to BRU 224 -23 (3495 - Plan (3495 - 61 511 2212.56 2.42 4375.99 9.12 230.92 3519.58 2629558 1459024 2006.28 6150 TVDss) 3658 1.71 329 3494.37 2631380 1460278 -113.4 TVDss) ';D } =�.e` ,i BRU 211- 26wp06 PoolSummary.xls 6/25/2008 8:55 AM I I IREV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION • T13N 3 cz 18 14 13 Eg > 16 i ma y' ' 23 3 T r -2- 21 22 //: n TOM J THIS ' ' v SURVEY / i WC 23 r 27 26 25 28 I SCALE: 1%1 OW CP1 NORTH ,` 33 34 38 \�\. �.. i _ 7 0 BELUGA - C ' \ 9 RUNWAY s / 1" \s s, :m_ ___. 1. ' VICINITY TY MA 1 MILE .- NOTES: �\ �. \ 6 , c ' j PRaou wATEl: 7 Ahl eEO S ECOSdCA�Y �', , Q I* t Tt. CONTAINMENT ` '\ \' 1. IN - ASP ZONE 4 NAD 27. ALL h ; " `` GEOGRAPHIC COORDINATES BRU 211 -26 \ `� "` r `' ` \ kn ARE NAD 27 LOOMED WITHIN PROTRACTED `; , \ ■ a _ ' ' _ •r' SEWARD MERIDIAN 10 W!, \ ■ '=, `j`_ 2. VERTICAL BENCHMARK IS TOP 625' F.S.L, 2570' F.W.L. +, ■ . ; 'i V w� NORTH E ER RIM LO OF NSEU R, LAT.= 6171'50.78" BRU 2244 -2 ` x REFERENCE LOUNSBURY AS LONG= 151 � ` ` `nx \ = ``� BUILT DATED 10- 31 -84. Y 2631.019 rn 3. ALL DISTANCES ARE TRUE W . "a� 4. PAD IS ROTATED 6314'06" R ` ...... , »‘xtt s \ `\ ° WEST FROM TRUE NORTH. 4, .. ' ' . ,,,r 1 i/ ` 'r %' BRU 232 -26 ..'.i, EDGE OF PROPrGED _ „ s f AVER PAO - ^9 /// \ �r ;*BRU 211 -26‘ *:.49 , /0 * 1 R k LEGEND: SURYEY CONTROL i oN" k � EXISTING *ELL i '.Francis J. arning: � ‘ ; D . // -r '. LS -10685 .' a te,: V; $ ASBUILT CONDUCTOR g` Y BOLLARD - : � 3 :;. GAS UNE <<1I '' 5 6 '3 t k � t �„ ` ��� ` . � DENOTES SPILL IRA;ECTORY •- EWE OF EX S I NG GRAVEL SURVEYOR'S CERTIFICATE 0AC' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF LOUNSBURY ALASKA AND THAT THIS REPRESENTS A SURVEY DONE BY ME & ASSOCIATES, INC. OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS sus ENGUOINES PLANNERS AND OTHER DETAILS ARE CORRECT AS OF MAY 7, 2008. 1 10 MEI zrz - 5451 y,/ AREA: MODULE: UNIT: ConocoPhillips BRU 211 -26 WELL CONDUCTOR ASBUILT Alaska, Inc. CADL) FILE NO. DRAWING NO: PART: I REV: 211 -26 ASBUILT CONDUCTOR 211 -26 ASBUILT CONDUCTOR.dw. 1 OF 1 ' 0 L i GI �. Material List Item Description 10 - 11 4- 1/16" 10M Gate Valve 3, 4, 7, 8, 9 3-1/8" 5M Gate Valve 1, 2, 5, 6, 12 3-1/16" 10M Manual Choke Valves • A 2- 9/16" 10M SWACO Super Choke B 3- 1/16" 10M Manual Choke i 41* 40 icz 4 — i _ 1110 , A r . ,,s 411 ,,, , ,,, f f :il ia .41 C P; 11 10 fl 1 Legend White [4a rxiiP Valves Normally Open ( ' 5 0. la Red Handle Valves Illi IM' Normally Closed Crate 12 -23 -05 Rev. _, ri N • t 1 • l■ 4 ii ` ii ii i!.. `• I i ,E,i ......e wisp,-,.. _ ,,, N j imiiiimmoommor _ 2 - I -I d I ill PI I N „ ti �_, o' . TOP OF 6" MATTING BOARDS • - - EN — L J . •° �� _ _ _ EXISTING GROUND f f N TOP OF • WELLHEAD DIVERTER a - CENTERLINE - 11 ' - 6 " - 7' -0" - 14' -0" - 11 ' -0" - - 11 ' -5" - .---1 NABORS RIG 129 20" HYDRIL MSP 2000 ANNULAR a yam" 20" DIVERTER SPOOL w/ 16" OUTLET CAI A Mdwra l Ilaaka99593 -2939 907-493-6009 WELL SIDE ELEVATION "'°., NABORS RIG 129 ""° 20' MSP 2K x I6 DNERTER ASSEMBLY WELL SIDE ELEVATION 10APR08 A a4 PS ISSUED ,pE ALSEON w PAUL SLMTH A REV . . 7 17 SC. DATE DWG NO. SM. DATE N9: ar 9r oFSCRCnax N/A APRIL 2008 I29_20 -2K MERTER 1 of 1 6" 04" X4" 4" x 6" NABORS ALASKA RIG 129 WELL RETURNS • MUD MIX MUD SYSTEM SCHEMATIC HOPPER 12' 12" • NOT SHOWN ARE TANK CLEANOUTS 6" x 4' 4" 4" 4' x 6" SUMP SUCTION OR STEAM LINES 8• ❑ IN ❑ MUD MIX HOPPER 6' ISHALE 6' -- 6' ' 6" III Ill I CENTRIFUGE SHALE SHAKE SHAKER • 6' 6' DESILTER SUMP O _ TO SUMP 6" 6 DISCHARGE 6 "- 6" 6" MANIFOLD 5" x 6" I I , I I _ SAND 11 -'_ I L i6„ _ I T RAP P B" „ . 1 1 6 . + 6 " - 6 . 6 f0" 33 - CENTRIFUGALS 5" x 6' : 6 6" I I 6' 6' 1111 6" 6 ,■ c 6 i e" -_ s" Q TY • ., \ , ■ � \ . 5" x 6" 116" . ■ .6" ✓ 0 1. ✓ 1 `6 . ✓ \ o + 6• f ■ -i,Il 1 I 6" CI 8" 8" 8" \ _ 3' 3' _ 3" ' ; 1 .3" 6" x 8' - e e e 0 e .> 3 " — ,� FROM 39 Bbls A 167 Bbls A 167 Bbls A 174 bls A 197 Bbls A 196 Bbls A MANIFOLD 243 Bbls A 41 Bbls A 49 Bbls G 207 Bbls G 207 Bbls G 216 Bbls G 245 Bbls G 244 Bbls G 302 Bbls G 51 Bbls G PILL TANK 8" 6" x 3" 3" TRIP TANK 36" MUD GAS • D"--#—o•— SEPARATOR 8" FLOW LINES • TO MUD PUMPS TO FLARE LEGEND — D--- CONCENTRIC REDUCER BOTTOM MUD GUN LOW PRESSURE TYPE TOTAL ACTIVE VOLUME = 1183 Bbls. - GATE VALVE TOTAL GROSS VOLUME = 1470 Bbls. fir AGITATOR It PERMS. ONLY 710 BY a — BUTTERFLY VALVE C/W FLANGES ✓ ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH 0 Nab= Menke 25525 c s sor:�200 GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK .amswslsc.� rm . Alooko 98603 -2639 NOT INCLUDING TRIP TANK PROJECT 6 G 2 9 6090 �— SUCTION VALVE, TEE TYPE ) NABORS ALASKA RIG 129 �C TANK EQUALIZER 1TRE MUD SYSTEM SCHEMATIC OR SKIMMER 1183 BBL ACTIVE SYSTEM SUCTION VALVE, ELL TYPE DRAM 9 APPRO. 9r sRO. 9r M. REF: HODGSON INDUSTRIAL DESIGN LTD. JOE ALSTON PAUL 516711 PAUL 91114 DWG. NO. R3052 -05 a ' >E W T. V' DESCRIPTION N/A OCTOBER 2003 °�. N0. 129 -0003 i of 1 II I 'l 11" 5k PSI HYDRIL ANNULAR BOP 3' 118" \ I ---.011 HYDRIL HEAD FLANGED BOTTOM CONNECTION • 1 ,r --- -PiPE— ,RAMS- - - --- 11" 5k PSI SHAFFER 10'—" 8 2' ,, 3" #5000 I --e DOUBLE GATE PREVENTOR HCR VALVE —\ ---- $LIND - - -- STUDDED CONNECTION i • I I i- 2" #5K GATE VALVE 1 3" • C_ HOK E LINE _ _ _ ■ A ;� All _ L Q 11 " 5000# API p# 2 � 2" KILL LINE FLANGED MUD CROSS 1 1 3 -1/8" #5000 - -PIP — RAMS- „ � — 11" 5k PSI SHAFFER 1'-712" GATE VALVE _� R 2 #5000 CHECK VALVE HYDRAULIC RAM SINGLE GATE /' 2" #5000 STUDDED CONNECTION GATE VALVE • NABORS ALASKA RIG 129 11" BLOW -OUT PREVENTOR 3 RAM STACK CONFIGURATION Zas 16 r4Erss 1E OO e F MAINE HI Y-IING 9Y eaIAW�A a O �������� Alaska Nubma Akska Dullin Inc. 9pyyN!) Alaska 2525 C abet SAl. 200 AIM IIOWTh c Mchaau . Naeka 9950.7 -2639 907 -2 - 6000 NABORS ALASKA RIG 129 ME 11' BLOW —OUT PREVENTOR 3 RAM STACK CONFIGURATION Armowo I IAPR08 A JA JA ISSUED JOE ALSTON �� PA UL SMITH m PAUL SAM 'v. A YIIE M'E 0". N0. n 00. W. W '7 ��� N/A APRIL 2008 129_0002 -J RAN 1 of I STATE OF ALASKA • ALASKA OIL AM) GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF CONOCOPHILLIPS ) Conservation Order No. 603 ALASKA, INC. for an order granting an exception to ) Docket No. CO -08 -24 the spacing requirements of 20 AAC 25.055 to allow ) for drilling, completing, testing and regular ) Beluga River Unit No. 211 -26 production of the Beluga River Unit No. 211 -26 well. ) Gas Production Well ) June 2, 2008 IT APPEARING THAT: ConocoPhillips Alaska, Inc. ( "ConocoPhillips "), by letter dated March 28, 2008 and received by the Alaska Oil and Gas Conservation Commission ( "Commission ") that same day, requests that the Commission issue an order granting an exception to the spacing requirements of 20 AAC 25.055 to allow for drilling, completing, testing and regular production of the Beluga River Unit ( "BRU ") No. 211 -26 gas production well ( "BRU 211 -26 "). 1. The Commission published notice of opportunity to comment and request a public hearing in the ANCHORAGE DAILY NEWS on April 11, 2008, pursuant to 20 AAC 25.540. 2. No comments concerning the application or requests for a hearing were received. 3. The public hearing was vacated by the Commission on May 19, 2008. FINDINGS: 1. BRU 211 -26 will be an onshore, conventional gas production well. The surface location will be 2,571' from the west line and 625' from the south line of Section 23, Township 13N, Range 10W, Seward Meridian ( "SM "), within state lease ADL -021 127. The bottom hole location will be 976' from the west line and 637' from the north line of Section 26, Township 13N, Range 10W, SM, which is also within state tease ADL -021127. 2. The productive interval for BRU 211 -26 will lie within 3,000' of gas production wells BRU 214- 26, BRU 224 -23 and BRU 232 -26 and within the same governmental section as gas production wells BRU 214 -26 and BRU 232 -26. The bottom hole location of BRU 211 -26 will be within 1,500' of the property lines separating state lease ADL - 021127 from federal lease A- 029657 and state lease ADL- 021126. 3. ConocoPhillips, the Municipality of Anchorage, and Chevron U.S.A. Inc. each own 33-1/3 percent of state lease ADL - 021127, state lease ADL - 021126 and federal lease A- 029657. ConocoPhillips is the operator of these leases. 4, The proposed well is positioned on the underlying geologic structure to access gas accumulations trapped within discontinuous channel sands that cannot be drained by existing wells. CONCLUSIONS: I. An exception to the well spacing requirements of 20 AAC 25.055 is necessary to allow for drilling, completing, testing and regular production of BRU 211 -26. 2. Granting a spacing exception to allow drilling, completing, testing and regular production of BRU 211 -26 will not result in waste or jeopardize correlative rights. Conservation Order 603 10 • June 2, 2008 Page 2 of 2 NOW, THEREFORE, IT IS ORDERED: ConocoPhillips' application for an exception to spacing requirements of 20 p pp pt o the pa mg regwre o AAC 25.055 to allow for drilling, completing, testing and regular production of BRU 211 -26 is granted. ENTERED at Anchorage, Alaska, and dated June 2, 2008. i _41 ____________,. Daniel T. .. o . t, Jr., Chair pit. MO cits. • ' : *. 14 ' and Ga. Conservation Commission ' 4 �. 1 ' J W ir : t '.. 'oner • , .. t. A : ka 0 • d Gas Conserv. ion Commission Cathy P oerst , Commissioner Alaska • it and Gas Conservation Commission RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsid- eration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for re- consideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Fail- ure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days af- ter the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final, Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission oth- erwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on ap- peal are limited to the questions presented to the Commission by the application for reconsideration_" In computing a period of time above, the date of the event or default after which die designated period begins to run is not in- cluded in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the pe- riod runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • TRANSMITTAL LETTER CHECKLIST WELL NAME /el-C. 2-1 2 4 PTD# zo g / Development, Service Exploratory Stratigraphic Test Non - Conventional) Well - /w1 • FIELD: S /L-L 4 t 'tX-v POOL: 4X(j4 # 1 l/ (it•Ch.(1 7 ;tecite ft g Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to fu 6 tZ pliance with 20 AAC EXCEPTION 25.055. Approval to perforate an , produ • - / inject is contingent upon issuance o a cone o; • approving a spacing c exception. on i S assumes the liability of any protest to the spacing o eption that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. • Rev: 1/11/2008 Field & Pool BELUGA RIVER, UNDEFINED GAS - 92500 _ Well Name: BELUGA RIV UNIT 211 -26 _ Program DEV Well bore seg ❑ PTD#: 2081120 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 820 Unit 50220 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool No Beluga River Undefined Gas Pool 5 Well located proper distance from drilling unit boundary No SPACING EXCEPTION REQUIRED: CO No. 603 issued 6/2/2008 6 Well located proper distance from other wells No 7 Sufficient acreage available in drilling unit No 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes 11 Permit can be issued without conservation order No Appr Date 12 Permit can be issued without administrative approval Yes SFD 7/7/2008 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA III 15 All wells within 1/4 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 Nonconven. gas conforms to AS31.05.030(j.1.A)42.A -D) NA Engineering 18 Conductor string provided Yes 19 Surface casing protects all known USDWs Yes Surface casing planned at — 2500' tvd and cemented to surface. 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg Yes 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. Beluga has a disposal well. ,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. Below — 450', well paths diverge. 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Potential BHPs range from 8.4 - 3.5 EMW. MW planned up to 10.0 ppg. TEM 7/16/2008 29 BOPEs, do they meet regulation Yes MiVI 130 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 2723 psi 3500 psi BOP test appropriate. ill ,31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S is not reported in Beluga production. Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 1 Geology 1 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated, but H2S detection systems, alarms will be used. Mud scavengers will be available. 36 Data presented on potential overpressure zones Yes Pressures expected to range from depleted to 10 ppg EMW. Mud weights to 10.4 ppg planned. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 7/7/2008 38 Seabed condition survey (if off - shore) NA ,39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering - bli Date: Date . % Date Commissioner: Coy issioner C• s n IA r ' "7-, -08 19, 1.../‘ , g • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. S BRU 211- 26_REDO_LDWG.tapx Sperry - Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed oct 08 11:13:47 2008 Reel Header Service name LISTPE Date 08/10/08 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS writing Library. scientific Technical Services Tape Header Service name LISTPE Date 08/10/08 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Beluga River Field MWD /MAD LOGS WELL NAME: BRU 211 - API NUMBER: 502832012800 OPERATOR: Conoco Phillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 08- OCT -08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw 000574328 Mw 000574328 Mw 000574328 LOGGING ENGINEER: S. POLAK S. POLAK S. POLAK OPERATOR WITNESS: L. HILL L. HILL L. HILL SURFACE LOCATION SECTION: 23 TOWNSHIP: 13N RANGE: 10W FNL: FSL: 625 FEL: FWL: 2570 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 91.52 GROUND LEVEL: 75.00 WELL CASING RECORD Page 1 20 l-13g � <R. 411 111 BRU 211- 26_REDO_LDWG.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 20.000 102.0 2ND STRING 8.750 9.625 3592.0 3RD STRING PRODUCTION STRING REMARKS: 1. RE- ISSUE, THIS DATA REPLACES THE TIF FILE CREATED 09 - SEP - 2008. DATA RE- ISSUED DUE TO CHANGES IN NEUTRON POROSITY VALUES BASED ON POST - PROCESSING CORRECTIONS. 2. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. MWD RUN 1 - COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDSr) COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD) , ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA IS CONSIDERED PRIMARY DEPTH CONTROL (PDC) PER THE E -MAIL FROM RICK LEVINSON OF CONOCOPHILLIPS ALASKA, INC. TO BRYAN BURINDA OF SPERRY DRILLING SERVICES DATED 03 -SEP -2008. 7. MWD RUNS 1 - REPRESENT BRU 211 - WITH API #: 50 283 - 20128 - 00. THIS WELL REACHED A TOTAL DEPTH OF 7786' MD / 6750' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. Page 2 • BRU 211- 26_REDO_LDWG.tapx SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (LOW -COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT RATE BIN). SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR LOW -COUNT RATE BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: CALIPER CORRECTED (8 3/4" NOMINAL) AVG OFFSET: CALIPER DERIVED (.3" NOMINAL) MUD WEIGHT: 9.4 - 9.7 PPG MUD SALINITY: 28,000 PPM CHLORIDES MUD TYPE: WATER BASED FORMATION WATER SALINITY: 345 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 08/10/08 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 101.5 7733.5 RPS 162.0 7726.0 RPD 162.0 7726.0 RPX 162.0 7726.0 RPM 162.0 7726.0 ROP 226.0 7786.0 FET 226.0 7726.0 NCNT 3582.0 7675.0 RHOB 3582.0 7688.5 DRHO 3582.0 7688.5 FCNT 3582.0 7675.0 PEF 3582.0 7688.5 NPHI 3582.5 7675.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH Page 3 40 1 BRU 211- 26_REDO_LDWG.tapx BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 101.5 1056.0 1 MWD 2 1056.0 3602.0 MWD 3 3602.0 7786.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 1 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 j ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 101.5 7786 3943.75 15370 101.5 7786 FCNT MWD CP30 395.1 2361.3 876.459 8182 3582 7675 NCNT MWD CP30 93477.9 161400 121792 8182 3582 7675 RHOB MWD G /CC 1.27 3.07 2.25216 8211 3582 7688.5 DRHO MWD G /CC -3.87 0.46 0.126354 8212 3582 7688.5 RPD MWD OHMM 2.54 2000 104.651 15003 162 7726 RPM MWD OHMM 2.29 2000 116.43 15002 162 7726 RPS MWD OHMM 2.26 1885.79 47.4253 15003 162 7726 RPX MWD OHMM 1.87 1884.61 30.3836 15002 162 7726 FET MWD HR 0.1415 122.69 2.21344 14895 226 7726 GR MWD API 11.41 127.66 65.3702 15226 101.5 7733.5 PEF MWD B/E 1.29 11.01 2.68957 8212 3582 7688.5 ROP MWD FPH 0.51 1656.36 152.619 15102 226 7786 NPHI MWD PU 10.14 116.72 38.5591 8187 3582.5 7675.5 First Reading For Entire File 101.5 Last Reading For Entire File 7786 Page 4 4 BRU 211- 26_REDO_LDWG.tapx File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 101.5 1003.5 RPD 162.0 993.5 RPM 162.0 993.5 RPX 162.0 993.5 RPS 162.0 993.5 ROP 226.0 1056.0 FET 226.0 993.5 LOG HEADER DATA DATE LOGGED: 05- AUG -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 1056.0 TOP LOG INTERVAL (FT): 101.5 BOTTOM LOG INTERVAL (FT): 1056.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 7.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 11166264 EWR4 EWR Phase -4 67981 Page 5 4 i BRU 211- 26_REDO_LDWG.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 102.0 # BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 8.80 MUD VISCOSITY (5): 129.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 180 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.000 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.810 76.0 MUD FILTRATE AT MT: 3.400 68.0 MUD CAKE AT MT: 3.900 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth units Datum Specification Block sub- type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWDO10 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 101.5 1056 578.75 1910 101.5 1056 RPD MWDO10 OHMM 9.91 2000 534.648 1644 162 993.5 RPM MWD010 OHMM 8.65 2000 568.744 1643 162 993.5 RPS MWDO10 OHMM 8.45 1885.79 128.383 1644 162 993.5 RPX MWD010 OHMM 8.02 1884.61 61.1831 1643 162 993.5 FET MWD010 HR 0.1415 5.7478 0.770424 1536 226 993.5 GR MWD010 API 23.06 116.47 50.1564 1780 101.5 1003.5 ROP MWD010 FPH 7.37 858.4 286.875 1661 226 1056 Page 6 BRU 211- 26_REDO_LDWG.tapx First Reading For Entire File 101.5 Last Reading For Entire File 1056 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 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 08/10/08 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 994.0 3539.0 FET 994.0 3539.0 RPX 994.0 3539.0 RPD 994.0 3539.0 RPM 994.0 3539.0 GR 1004.0 3549.5 ROP 1056.5 3602.0 LOG HEADER DATA DATE LOGGED: 06- AUG -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3602.0 TOP LOG INTERVAL (FT): 1056.0 BOTTOM LOG INTERVAL (FT): 3602.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 8.9 MAXIMUM ANGLE: 56.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 11166264 Page 7 ID • BRU 211- 26_REDO_LDwG.tapx EWR4 EWR Phase -4 67981 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 102.0 # BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.10 MUD VISCOSITY (S): 200.0 MUD PH: 9.1 1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 12.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.000 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.420 98.6 MUD FILTRATE AT MT: 3.400 68.0 MUD CAKE AT MT: 3.900 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service order units Size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 994 3602 2298 5217 994 3602 RPD MWD020 OHMM 8.97 2000 106.975 5090 994 3539 RPM MWD020 OHMM 8.3 2000 132.504 5090 994 3539 RPS MWD020 OHMM 7.79 1179.15 70.5978 5090 994 3539 RPX MWD020 OHMM 7.5 347.51 49.2074 5090 994 3539 FET MWD020 HR 0.17 82.12 2.9937 5090 994 3539 Page 8 r BRU 211- 26_RED0_LDWG.tapx GR MWD020 API 26.01 98.47 52.3289 5087 1004 3549.5 ROP MWD020 FPH 0.87 644.34 210.717 5092 1056.5 3602 First Reading For Entire File 994 Last Reading For Entire File 3602 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3550.0 7733.5 DRHO 3582.0 7688.5 PEF 3582.0 7688.5 RHOB 3582.0 7688.5 NCNT 3582.0 7675.0 FCNT 3582.0 7675.0 NPHI 3582.5 7675.5 RPM 3591.5 7726.0 RPX 3591.5 7726.0 RPD 3591.5 7726.0 FET 3591.5 7726.0 RPS 3591.5 7726.0 ROP 3602.5 7786.0 LOG HEADER DATA DATE LOGGED: 16- AUG -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 7786.0 TOP LOG INTERVAL (FT): 3602.0 Page 9 4 BRU 211- 26_REDO_LDWG.tapx BOTTOM LOG INTERVAL (FT): 7786.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .2 MAXIMUM ANGLE: 51.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR Phase -4 96540 CTN Comp Thermal Neutron 244601 ALD Azimuthal Litho Dens 10603721 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3592.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.60 MUD VISCOSITY (S): 56.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 12.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .095 134.6 MUD FILTRATE AT MT: .190 68.0 MUD CAKE AT MT: .170 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 Page 10 I 4 BRU 211- 26_REDO_LDWG.tapx RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3550 7786 5668 8473 3550 7786 FCNT MWD030 CP30 395.1 2361.3 876.459 8182 3582 7675 NCNT MWD030 CP30 93477.9 161400 121792 8182 3582 7675 RHOB MWD030 G /CC 1.27 3.07 2.25216 8211 3582 7688.5 DRHO MWD030 G /CC -3.87 0.46 0.126354 8212 3582 7688.5 RPD MWD030 OHMM 2.54 1915.1 17.7311 8269 3591.5 7726 RPM MWD030 OHMM 2.29 1854.24 16.6642 8269 3591.5 7726 RPS MWD030 OHMM 2.26 1791.19 17.0658 8269 3591.5 7726 RPX MWD030 OHMM 1.87 1778.54 12.6769 8269 3591.5 7726 FET MWD030 HR 0.3 122.69 2.0012 8269 3591.5 7726 GR MWD030 API 11.41 127.66 76.5465 8359 3550 7733.5 PEF MWD030 B/E 1.29 11.01 2.68957 8212 3582 7688.5 ROP MWD030 FPH 0.51 1656.36 90.4755 8349 3602.5 7786 NPHI MWD030 PU 10.14 116.72 38.5591 8187 3582.5 7675.5 First Reading For Entire File 3550 Last Reading For Entire File 7786 File Trailer Service name STSLIB.004 Service sub Level Name Version Number 1 0 0 Date of Generation 08/10/08 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 08/10/08 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 08/10/08 Origin STS Reel Name UNKNOWN continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. scientific Technical Services Page 11 • • BRU 211- 26_RED0_LDWG.tapx Physical EOF Physical EOF End of LIS File Page 12 z % ConocoPhillips 2ioff-112.- 0 Alaska, Inc. 0\3191 FINAL WELL REPORT MUDLOGGING DATA BELUGA RIVER UNIT BRU 211 -26 y •1. II S ii t! • t 1 %, i thitit :L'L.I. .f i ,..,, .... ._:: _AN.mwm-----------d■---i — , r " ' 1 7 ',II: 1 , i: ': Li' -; Arillirs 1111r7r.- 1 1.41 .. :, Provided by: E EPOCH Approved by: Compiled by: Larry Resch Ryan Massey Date: August 16, 2008 • Distribution: September 2, 2008 ConocoPhillips Alaska, Inc. BRU 211 -26 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Additional Comments 3 2.4 Daily Activity Summary 4 3 GEOLOGICAL DATA 6 3.1 Lithostrati ra h 6 9 p Y 3.2 Mudlog Summary 7 3.3 Connection Gases 9 3.4 Trip (Wiper) Gases 9 3.5 Sampling Program / Sample Dispatch 9 4 DRILLING DATA 10 4.1 Survey Data 10 4.2 Bit Record 11 4.3 Mud Record 12 5 MORNING REPORTS 13 Enclosures 2 "/100' Formation Log (MD, TVD) 2 "/100' Drilling Dynamics Log (MD/TVD) 2 "/100' LWD / Combo Log (MD/TVD) 2 "/100' Gas Ratio Log ( MD/TVD) • El EPOCH 1 ConocoPhillips Alaska, Inc. BRU 211 -26 • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime QGM Agitator (Mounted in possum belly) g as Ditch 0 Flame ionization total gas & chromatography. Effective Circulating Density From Sperry-Sun 3592' to TD 0 Hook Load / Weight on bit Epoch Line Strain Gage 0 Mud Flow In Derived from Strokes /Minute and 0 Pump Output Mud Flow Out Flow Paddle 0 Mudlogging unit computer HP Compaq (X2, DML & Rigwatch) 0 system Mudlogging unit DAC box Rig mounted and in -unit data 0 collection /distribution center Pit Volumes, Pit Gain /Loss Pit probes and Vega sonic sensors 0 Pump Pressure 1502 sensor on stand pipe 0 Pump stroke counters Micro - switches on mud pumps 0 WITS feed to Sperry-Sun Torque, RPM, ROP, Gas 0 Rate of penetration Crown sheave encoder 0 RPM From top drive sensor. 0 • Torque From top drive sensor. 0 1.2 Crew Unit Type: Steel Arctic Unit Number: ML030 Mudloggers Years Days Sample Catchers Years Days Technician Days Larry Resch 5.5 18/18 Rick Frederick 2.5 9/11 Allen 3 Williams Ryan Massey 1 15/18 Emil Opitz 1 9/11 (in training) Years experience as Mudlogger '2 Days at wellsite between casing point and total depth of well. El • EPOCH 2 ConocoPhillips Alaska, Inc. BRU 211 -26 0 2 WELL DETAILS 2.1 Well Summary Well: BRU 211 -26 API Index #: 50- 283 - 20128 -00 Field: Sterling - Beluga Gas Pool Surface Co- Ordinates: 625' FSL, 2570' FWL Sec 23, T13N, R10W SM Borough: Tyonek Primary Target Depth: 4147'MD/3586'TVD State: Alaska TD Depth: 7786'MD/6750'TVD Rig Name / Type: Nabors 129 /Land /Triple Suspension Date: August 24, 2008 Primary Target: Top Beluga License: AOGCC 208 -112 Spud Date: August 3, 2008 Ground Elevation: 75.0' MSL Completion Date: August 16, 2008 RT Elevation: 91.5' MSL Completion Status: Run 7" casing to 7775' Secondary Target: None Depth: Classification: Production TD Date: August 16, 2008 TD Formation: Base Beluga! Days Testing: 3 Days Drilling: 14 2.2 Hole Data iii Maximum Depth Mud Casin Shoe Depth H ole TD Dev. FIT MD TVD Weight o Section (ft) (ft) Formation (PPM (ft) (ft) (ppg) 12/14" 3602 2864 9.6 51.48 none 9 5/5" 3592 3096 15.8 Base 8 3/4" 7786 6750 Beluga I 9.6 1.16 idell 7" 7775 6740 1 2.3 Additional Comments BRU 211 -26 was drilled as a grass roots, Beluga 'S' shaped gravel packed gas well with a planned depth of 7407' MD/ 6642' TVD with a maximum inclination of 50.4 degrees. Total depth achieved was 7786' MD/ 6750 TVD. The objective was the top of the Beluga Formation with multiple sand targets. Concerns while drilling included lost circulation in depleted sands; sloughing shales /swelling clays; tight hole in coals. Several zones with gas readings over 1000 units were observed. No connection gasses were recorded while drilling and . wiper trip gasses were kept below 250 units. No problems were encountered while drilling, the exception being very minor tight hole at TD. This issue was resolved during the wiper trip immediately proceeding TD. El EPOCH 3 ConocoPhillips Alaska, Inc. BRU 211 -26 2.4 Daily Activity Summary August 10, 2008 Continue testing BOP's: Blinds; TIW and Dart valve. BOP tests witnessed by AOGCC Bob Noble; WSL Robert Wahl; NAD tool pusher Larry Applegate. Epoch records and provides hard copy plus digital charts of all BOP test results. Rig down test tools and equipment. Blow down choke manifold. Remove /replace wear bushing. Run in hole to 2852 ft and lay down 5" drill pipe. Conduct miscellaneous work as directed by operator. Load 4" drill pipe on racks; strap same and inspect with 2.375" drift. Pick up and stand back 25 stands of 4" drill pipe. Work as directed by operator. Replace Epoch crown sheave transducer and recalibrate block travel. Pick up and rack back an additional 25 stands of 4" drill pipe. Rig up pony line and prepare to pick up BHA. August 11, 2008 Continue to pick up BHA from 26 ft to 155 ft. Tests of MWD tools indicate a problem with communications. Troubleshoot Sperry MWD tools and resolve problems. Load sources. Pick up remaining collars and HWDP. Trip in hole to 3262 ft. Wash and ream from 3262 ft to 3360 ft. Test 9 5/8" casing to 3000 psi with BJ: Test passes. Cut and slip drill line. Service rig top drive and crown. Continue trip in hole. Tag at 3500 feet. Drill out float equipment, shoe track and 20 foot of new formation. Circulate and condition. Conduct FIT at 3549 ft EMW = 15.8 ppg. Circulate and condition; displace to FloPro at 456 gpm, 250 psi. Circulate bottoms up 2 times. Drill ahead from 3622 ft to 3644 ft. August 12, 2008 Drill ahead from 3644' to 4410'. Short trip 10 stands at 4410 ft into shoe. Run back to bottom. Drill ahead from 4410 ft to 4709 ft. August 13, 2008 Rotary drill /slide from 4709 ft to 5340 ft. Circulate and condition 2 bottoms up at 500 gpm and 2000 psi. Short • trip to 4400 ft with no overpull. Service rig top drive. Precautionary ream from 5366 ft to 5461 ft. Circulate and condition 2 bottoms up while pumping high vis sweep at 500 gpm and 1950 psi. Drill ahead from 5461 ft to 5670 ft. August 14, 2008 Rotary drill from 5670 ft to 6413 ft. Circulate and condition hole clean. Wiper trip from 5413 ft to 5400 ft with 10k overpull. Service rig top drive; wash pipe; tong sheaves; torque tube. Run in hole from 5400 ft; precautionary ream from 6318 ft to 6413 ft. Circulate bottoms up and condition mud. Drill ahead from 6413 ft to 6457 ft. Repair #2 mud pump at report time while slow circulating at 215 gpm, 750 psi. August 15, 2008 Rotary drill from 6507 ft to 7238 ft at report time. Slight increase in torque with depth. August 16, 2008 Drill ahead from 7238 ft to TD at 7786 ft. Experienced some torque during today's drilled interval. Circulate bottoms up 3 times to condition hole. Dropped carbide and believe hole to be in good gage. Currently working pipe /washing and reaming on wiper trip at bit depth 7200 ft. August 17, 2008 Continue wiper trip from 7786 ft TD to 5400 ft. Experienced some tight hole: Wash and ream as necessary. Run back to bottom at 7786 ft; record 212 units of gas maximum. Circulate and condition hole. Spot pull and dry job. Pull out of hole for wire line logs. Laying down Sperry BHA -smart tools at report time. 4110 El EPOCH 4 ConocoPhillips Alaska, Inc. BRU 211 -26 • Auqust 18, 2008 Continue laying down BHA from 156 ft. Spot Schlumberger and rig up wire line tools. Run in hole and log from 7786 ft to 6700 ft. Encounter problems with logging tool. Pull out of hole from 6700 ft with tool. Troubleshoot failed communication with DS! tool: Change out same. Run back in hole and log up from 6700 ft. Rig down e- line tools. Pick up pipe conveyed logging tools: WRPP -AA; GSR -U/Y; WITM (CST) -A. Establish communications with tools. Run in hole at 3 minutes /stand. Break circulation and condition mud to equal mud weights in and out at 2014 ft, 3541 ft, and 4023 ft. Circulating and conditioning mud at report time. August 19, 2008 Continue drill pipe conveyed logs. August 20, 2008 Continue drill pipe conveyed Togs. Auqust 21, 2008 Continue with and complete drill pipe conveyed Togs. Rig up, run and complete side wall coring. Rigging down Schlumberger operations at report time. August 22, 2008 Rig down Schlumberger. Service rig top drive and crown. Pick up BHA#4 and run in hole for clean out. Wash and ream from 6920 ft to 7786 ft due to excessive set down weight: UP 120k, DN 62k, RW 94k; RPM 100, Torque 7000. Circulate and condition hole. Pull out of hole from 7786 ft. Lay down BHA per Sperry. Pull wear bushing and prepare to test 7" pipe rams. Auqust 23, 2008 Continue testing 7" pipe rams. Epoch calibrates sensor; records and charts test. Change out elevators, tongs, • spinners and prepare to run 7 ", 26# L -80 casing. Rig up Weatherford and run casing to 7753 ft. Pick up and make up hanger, landing joint. and BJ cement head. Circulate from rig mud pump through hose. Attempt to reciprocate: SW 85k, UW 180k. Land 7" casing at 7775 ft. Circulate and condition hole at 210 GPM, 550 PSI. Epoch records 89 units of trip gas maximum. Background gas settles to 20 -25 units. Preparations are underway for cement job at report time. • E I EPOCH 5 ConocoPhillips Alaska, Inc. BRU 211 -26 0 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops are provisional picks supplied by CPAI geologist. PROGNOSED LWD PICK FORMATION MD TVD MD TVD (ft) (ft) (ft) (ft) Sterling A 3805 3041 3991 3122 Sterling B 424 9 3303 4023 3276 Sterling C 4185 3426 4436 3450 Beluga D 4351 3586 4608 3599 Beluga E 4602 3836 4887 3859 Beluga F 4957 4191 5253 4218 Beluga G 5447 4681 5764 4729 Beluga H 5797 5031 6110 5075 Beluga I 6497 5734 6867 5832 • Beluga I Base 7007 6421 7342 6307 7" Casing Point 7407 6642 7786 6750 • El EPOCH 6 ConocoPhillips Alaska, Inc. BRU 211 -26 3.2 Mudloq Summary Casing Point to Total Depth 3592' to 7786' MD (3096' to 6750' TVD) Drill Rate (ft/hr) T otal Gas (units Maximum Minimum Average Maximum Minimum Average 140 8 94.1 3257 6 175.3 This logged interval includes the Tertiary-aged Sterling and Beluga Formations. The Sterling consisted of mostly unconsolidated sand, occasional conglomeratic sand and some very minor coals. Sands varied from medium to lower coarse grain; angular to subangular in part with poor sphericity and poor to no rounding characteristics. Moderate to well sorting was indicated with observed samples. However it is noted that large diameter screens were installed on the shakers that perhaps may have precluded observation of finer grained materials and clays. Occasional bit fractured moderately rounded/ moderately spherical pebbles were observed. The sands were evaluated as immature with dominate translucent to transparent and milky white quartz; abundant light feldspars; light to dark gray and grayish black mafics common, often with biotite. Irregularly interbedded, poorly developed woody coals were observed as black to brownish black; generally dull to subvitreous in part; soft, crumbly; platy to sub - fissile in part. The base of the Sterling also includes yellowish brown to brownish gray, earthy, non - hydrophilic claystone which often contained carbonaceous material. The Beluga is characterized by claystone and siltstone; sandstones and unconsolidated sands; coals. Both claystones and siltstones are generally various shades of light to medium light gray, often with light • brownish coloration. Generally soft to firm, these clays are locally tuffaceous in part, well indurated in part, and generally non - hydrophylic. The exception to this is the lower part of the hole, from 7400'MD/6415'TVD, where clays become somewhat more tuffaceous, gummy and swell easily. Clays are silty to sandy in part and often grade from a dull, consistent claystone to an argillaceous siltstone to a dirty, matrix supported sandstone. Scale -like to spiky, reworked carbonaceous fragments and soft interbedded coals are common. The colors of observed consolidated sandstones were grays with shades of brown similar to the aforementioned claystones: Sandstones were dominantly argillaceous /tuffaceous matrix supported very fine to fine subangular to subrounded grains with poor to locally fair sphericity; fair to occasionally moderate sorting. Visible porosity is generally poor to fair at best. Unconsolidated medium to lower coarse grained sands are common. Occasional small freshly fractured well rounded pebbles with moderate to good sphericity are common. These sands are assessed to be immature. Translucent to milky white and commonly transparent quartz provides the basis of these sediments. Light colored feldspars and light to grayish black mafic clasts occur frequently throughout this section. Carbonaceous detritus is locally common to abundant. Cuttings samples often reveal sands in direct contact with coal /carbonaceous material. Observed coals are considered poorly developed ranging from soft, pulpy, carbon rich; carbonaceous shale; an earthy /argillaceous coal. Generally soft and crumbly, occasionally platy to sub - fissile in part, firmer coals were often observed with fine stream outgassing bubbles. This is indicative of mud weight being at or very close to approximating geostatic pressure. These coals were interbedded with earthy claystones and argillaceous sandstones. While several significantly high gas readings were observed while drilling through coals, background gas dropped rapidly after penetration and did not linger. EPOCH 7 ConocoPhillips Alaska, Inc. BRU 211 -26 0 Gas Peaks: Drilled gas Depth Gasd C1 C2 C3 C4I C4N C51 C5N (MD /TVD) (units) (ppm) (ppm) (ppm) (ppm) (Ppm) (ppm) (ppm) 4726/3705 622 131134 - - - - - - 4763/3745 424 39890 - - - - - - 4786/3663 987 198064 - - - - - - 4793/3671 465 107283 - - - - - - 4798/3675 311 58613 - - - - - - 4837/3810 1338 218602 - - - - - - 4891/3863 608 122644 - - - - - - 4909/3882 896 177814 - - - - - - 4983/3954 485 95938 - - - - - - 5003/3972 397 79831 - - - - - - 5071/4039 432 84023 - - - - - - 5257/4221 730 145940 - - - - - - 5311/4277 838 166784 - - - - - - 5420/4387 346 66772 - - - - - - 5615/4579 476 90366 - - - - - - 5674/4639 1180 189903 - - - - - - 5769/4735 1374 277019 - - - - - - 5836/4801 375 65570 - - - - - - 6029/4995 1424 278432 34 - - - - - 6066/5032 353 36667 - - - - - - 6085/5051 626 116652 17 - - - - - III 6110/5079 502 94490 34 6162/5130 3264 574875 109 6196/5165 424 62029 5 - - - - - 6255/5221 385 65024 - - - - - - 6278/5243 393 65943 - - - - - - 6339/5304 642 133048 - - - - - - 6356/5322 655 112206 11 - - - - - 6380/5346 1268 217266 79 - - - - - 6389/5356 830 86464 27 - - - - - 6410/5380 566 102795 - - - - - - 6572/5549 154 33490 - - - - - - 6642/5610 291 57193 - - - - - - 6837/5804 200 36163 - - - - - - 7713/6695 113 22898 - - - - - - El EPOCH 8 ConocoPhillips Alaska, Inc. BRU 211 -26 • 3.3 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) No connection gasses were observed. 3.4 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 5461 4400 223 2 6413 5400 312 2.2 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to CPAI Washed, screened & 30 ft 3600 ft — 6780 ft Bayview Geologic Facility A dried reference samples. 619 East Ship Creek Ave Ste 102 20 ft 6780 ft — 7786 ft Set owner: CPAI Anchorage, AK 99510 Attn: D. Przywojski 263 -4859 CPAI • Washed, screened & 30 ft 3600 ft — 6780 ft Bayview Geologic Facility B dried reference samples. 20 ft 6780 ft — 7786 ft 619 East Ship Creek Ave Ste 14 Set owner: CPAI Anchorage, AK 99501 Attn: D. Przywojski 263 -4859 Sample frequency was locally altered according to drill rate. • El EPOCH 9 ConocoPhillips Alaska, Inc. BRU 211 -26 0 4 DRILLING DATA 4.1 Survey Data Measured True Latitude Departure Vertical Dogleg Depth Inc I. Azim. °► Vertical (ft) (ft) Section Rate (ft) O O Depth (ft) N( +), S(-) E( +), W( -) (ft) ( /100ft) , 3847.29 48.85 232.03 3025.68 839.75 1507.32 1702.93 1.73 3942.99 48.02 231.07 3089.17 884.27 1563.40 1774.54 1.15 4033.47 47.01 230.87 3150.28 926.29 1615.23 1841.26 1.13 4132.45 45.13 231.06 3218.94 971.19 1670.60 1912.54 1.91 4228.72 43.66 230.65 3287.73 1013.70 1722.84 1979.88 1.56 4324.05 38.49 229.51 3359.56 1053.85 1770.89 2042.48 5.48 4376.29 36.87 226.40 3400.91 1075.22 1794.60 2074.34 4.79 4422.20 35.14 225.45 3438.05 1093.98 1813.99 2101.19 3.96 4469.53 32.26 224.53 3477.42 1112.55 1832.56 2127.27 6.17 4518.48 30.32 222.50 3519.25 1130.97 1850.07 2152.44 4.51 4615.45 25.39 219.40 3604.96 1165.11 1879.83 2196.96 5.30 4666.54 23.92 218.12 3651.40 1181.72 1893.17 2217.74 3.06 4711.71 22.33 217.95 3692.93 1195.70 1904.10 2234.98 3.52 4806.11 18.90 217.52 3781.27 1221.98 1924.45 2267.25 3.64 4901.12 15.63 215.66 3871.99 1244.59 1941.29 2294.49 3.50 III 4996.81 12.60 217.61 3964.78 1263.33 1955.18 2317.01 3.20 5092.81 9.77 219.97 4058.95 1277.87 1966.80 2335.16 2.99 5188.81 7.25 231.10 4153.89 1287.92 1976.75 2349.20 3.12 5280.75 4.65 244.24 4245.33 1293.19 1984.62 2358.63 3.18 5377.79 2.73 198.56 4342.19 1297.08 1988.90 2364.41 3.47 5467.42 0.65 146.74 4431.77 1299.53 1989.30 2366.24 2.66 5568.04 0.54 148.56 4532.39 1300.41 1988.74 2366.35 0.11 5672.10 0.53 146.60 4636.45 1301.24 1988.21 2366.45 0.02 5758.74 0.48 173.26 4723.08 1301.94 1987.95 2366.67 0.28 5851.40 0.45 163.30 4815.74 1302.67 1987.80 2367.01 0.09 5948.15 0.38 155.15 4912.49 1303.33 1987.55 2367.23 0.09 6044.74 0.36 183.44 5009.07 1303.92 1987.44 2367.51 0.19 6139.91 0.45 179.66 5104.24 1304.60 1987.45 2367.94 0.10 6232.66 0.52 214.54 5196.99 1305.32 1987.69 2368.57 0.32 6329.55 0.32 219.03 5293.88 1305.89 1988.11 2369.25 0.21 6423.10 0.44 201.81 5387.42 1306.42 1988.40 2369.81 0.18 6517.61 0.54 213.70 5481.93 1307.12 1988.78 2370.54 0.15 6613.58 0.75 222.21 5577.89 1307.96 1989.45 2371.59 0.24 6708.64 0.92 220.71 5672.94 1308.99 1990.36 2372.95 0.18 6803.97 0.49 220.21 5768.27 1309.89 1991.13 2374.10 0.45 6899.24 0.28 221.87 5863.54 1310.37 1991.54 2374.73 0.22 6994.17 0.19 247.31 5958.46 1310.60 1991.84 2375.10 0.14 7088.86 0.25 234.86 6053.15 1310.78 1992.15 2375.46 0.09 • • 7185.96 0.41 232.36 6150.25 1311.12 1992.60 2376.02 0.17 El EPOCH 10 ConocoPhillips Alaska, Inc. BRU 211 -26 • 7281.07 7375.47 0.41 254.34 6245.36 1311.42 1993.21 2376.68 0.17 0.63 237.85 6339.76 1311.79 1993.97 2377.51 0.28 7472.17 0.70 238.43 6436.45 1312.38 1994.92 2378.63 0.07 7567.33 0.80 231.64 6531.60 1313.09 1995.94 2379.87 0.14 7661.42 1.16 242.05 6625.68 1313.95 1997.30 2381.46 0.42 7704.27 1.16 241.23 6668.52 1314.36 1998.06 2382.31 0.04 7786.00 1.16 241.23 6750.23 1315.16 1999.51 2383.94 0.01 4.2 Bit Record Bit Depth Total Bit Avg. WOB No. Size Make Type / S# Jets In FTG Hrs (fRt/�hr (Klbs) RPM Grade 8 Hughe DP506X- 6 x 4194 59. 1-2-WT-G- 3 3/4" s #7120849 13 3592' 9 70.01 2 - 30 100 X- 1/16 -ER- TD • III El EPOCH 11 • Conohillips • Alaska, Inc. BRU 211 -26 4.3 Mud Record Contractor: MI SWACO Mud Type: Kla- Stop /KCI Polymer Date Depth MW ECD VIS PV YP FL Gels Cl- FC SOL Sd Ca MBT pH (ppg) (ppg) (s /qt) (cc) ( %) (m1 /1) 8/11/08 3645 9.6 9.91 62 10 20 6 5/7/9 29000 1/1 7 Tr - 10.5 40 8/12/08 4711 9.6 10.12 54 16 22 4.8 6/8/9 29000 1/2 8 Tr 3 10.4 40 8/13/08 5670 9.6 10.14 61 16 24 4.8 8/10/11 26000 1/2 9 0.5 4 10.1 40 8/14/08 6504 9.6 10.03 47 14 24 3.8 6/7/9 26000 1/2 8 0.25 3 10.1 40 8/15/08 7237 9.6 10.04 50 16 22 4.4 7/9/12 26000 1/2 8 0.25 3 9.9 80 8/16/08 7786 9.6 9.99 46 15 20 3.8 5/9/10 28000 1/2 9 0.3 4 9.8 80 8/17/08 7786 9.6 - 45 11 18 4.2 6/7/10 28000 1/2 8 0.3 3 9.8 60 8/18/08 7786 9.7 9.97 48 12 17 4.5 5/7/9 28000 1/2 8 0.3 3 9.8 60 8/19/08 7786 9.7 9.99 47 10 17 4.8 5/6/9 29000 1/2 8 0.1 3 9.8 80 8/20/08 7786 9.7 9.7 53 11 17 4 5/7/9 29000 1/2 7.5 Tr 2 9.9 88 8/21/08 7786 9.6 9.6 44 10 18 5 4/5/8 31000 1/2 7 Tr 3 9.8 90 8/22/08 7786 9.8 9.8 50 10 21 5 5/7/9 31000 1/2 8.5 Tr 2.5 9.9 92 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point El I EPOCH 12 ConocoPhillips Alaska, Inc. BRU 211 -26 5 MORNING REPORTS • 1110 El I EPOCH 13 ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wahl Date: 08/10/08 Time: 2359 Current Depth (MD): 3592' Current P/u BHA Current Depth (TVD): Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cf Ca + +: MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): • Avg. BG : Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Summary: Complete BOP tests. Lay down 5" drill pipe. Pick up 4" drill pipe. Making up bit, Ope rational mud motor and first collar at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $4110.00 • El EPOCH Conoco hillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Rick Levinson Robert Wahl Date: 8/11/08 Time: 2359 Current Depth (MD): 3644 Current Drilling Ahead Current Depth (TVD): 2911 Operations: 24 hr Footage (MD): 44 Drilling Parameters ROP: Current: 85.5 Max: 777 Torque: Current: 1073 Max: 1141 WOB: Current 1.5 Max: 20 RPM: Current: 57.4 Max: 60 PP: Current: 1380 Max: 1840 Lag: Strokes: 4296 Time: 23.5 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 3645' MD MW: 9.5 FV: 62 PV: 10 YP: 20 FL: 6 Gels: 5/7/9 Sol: 7 pH: - Cr ' 29k Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): • Avg. BG : 5 units 5 3632/2902 units Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas n/a Connection n/a C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: 100 % Sand Last 24 hrs: 100% Sand; trace coal /carbonaceous material Continue picking up BHA. Trip in hole: Wash and ream from 3262 ft. Tag at Operational Summary: 3500. Drill out float, shoe and new formation to 3624 ft. Conduct FIT at 3549 ft: EMW = 15.8 ppg. Circulate and condition; displace old mud. Drill ahead from 3622 ft to 3644 ft at report time. Calibrations: THA. Failures: None • Daily Cost: $4,110.00 Ell EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 S Daily Report Report for: Robert Wahl, Rick Levinson Date: 8/12/08 Time: 2359 Current Depth (MD): 4709 Current Drilling Ahead Current Depth (TVD): 3691 Operations: 24 hr Footage (MD): Drilling Parameters ROP: Current: 46.8 Max: 840 Torque: Current: 2950 Max: 10189 WOB: Current 2 Max: 20 RPM: Current: 0 Max: 102 PP: Current: 1853 Max: 1987 Lag: Strokes: 5326 Time: 24.1 Surf-Surf: Strokes: Time: ECD: Current: 9.98 Max: Mud Properties @ 4711 MW: 9.6 FV: 54 PV: 16 YP: 22 FL: 4.8 Gels: 6/8/9 Sol: 8 pH: 10.4 Cr 29k Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: fl Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG: Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 4410/3429 0 Connection none C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 4650 -4680: 40% siltstone; 30% claystone; 20% sandstone; 10% carbonaceous material Last 24 hrs: 50% sand and sandstone; 30% claystone; 20% siltstone; 10% coal /carbonaceous material Operational Summary: Drill ahead from 3644' to 4410'. Short trip 10 stands into shoe. Run back to bottom. Drill ahead from 4410' to current depth of 4709' at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $4,110 till EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 I Daily Report Report for: Robert Wahl, Jeffrey Harrison Date: 8/13/08 Time: 2359 Current Depth (MD): 5670 Current Drilling Ahead Current Depth (TVD): 4558 Operations: 24 hr Footage (MD): 961 Drilling Parameters ROP: Current: 92.2 Max: 324.6 Torque: Current: 5544 Max: 9816 WOB: Current 6.2 Max: 20 RPM: Current: 96 Max: 101 PP: Current: 2287 Max: 2338 Lag: Strokes: 6061 Time: 27.3 Surf-Surf: Strokes: Time: ECD: Current: 10.05 Max: Mud Properties @ 5670' MW: 9.6 FV: 61 PV: 16 YP: 24 FL: 4.8 Gels: 8/10/11 Sol: 9 pH: 10.1 CI' 26k Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: 0 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg. BG : 180u 1089u 4837/3888 Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 5461/4390 38361 Wiper 223 u Connection none C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: 5700 ft: 70% claystone; 20% sandstone; 10% carbonaceous material Last 24 hrs: 60% claystone; 30% sandstone; 10% coals and carbonaceous materials Operational Summary: Rotary drill /slide from 4709 ft to 5340 ft as directed by DD. Short trip to 4400 ft with no problems. Rotary drill from 4610 ft to 5670 ft at report time. Calibrations: Chromatograph, THA. Failures: None 40 Daily Cost: $4110.00 El EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wall, Jeffrey Harrison Date: 8/14/08 Time: 2359 Current Depth (MD): 6507 Current Work On Mud Pump #2 Current Depth (TVD): 5442 Operations: 24 hr Footage (MD): Drilling Parameters ROP: Current: 47.9 Max: 265 Torque: Current: 5964 Max: 9474 WOB: Current 10.7 Max: 39 RPM: Current: 84 Max: 103 PP: Current: 2006 Max: 2573 Lag: Strokes: 7119 Time: 31.5 Surf-Surf: Strokes: Time: ECD: Current: 10.2 Max: Mud Properties @ 6504' MW: 9.6 FV: 47 PV: 14 YP: 24 FL: 3.8 Gels: 6/7/9 Sol: 8 pH: 10.1 CI' 26k Ca + +: 40 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg. BG : 311u 3257u 6162/5154 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas 6413/5364 46673 Wiper 312u Connection 0 C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: 6507 ft: 40% claystone; 30% siltstone; 20% sandstone; 10% carbonaceous material Last 24 hrs: 50% claystone; 30% sandstone; 20% coal /carbonaceous material Rotary drill from 5670 ft to 6413 ft. Circulate and condition hole clean for wiper trip Operational Summary: to 5400 ft. Record 10k overpull and 312 units gas with 2.6 hours down time. Run to bottom and drill ahead to 6457 ft at report time. Calibrations: Chromatograph, THA. Failures: None • Daily Cost: $4,110.00 El EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wall, Jeffrey Harrison Date: 8/15/08 Time: 2359 Current Depth (MD): 7238 Current Working through high Current Depth (TVD): 6151 Operations: torque 24 hr Footage (MD): 731' Drilling Parameters ROP: Current: 71.2 Max: 141 Torque: Current: 8698 Max: 9381 WOB: Current 1.5 Max: 41 RPM: Current: 96 Max: 105 PP: Current: 2618 Max: 2982 Lag: Strokes: 8030 Time: 36.5 Surf-Surf: Strokes: Time: ECD: Current: 10.2 Max: Mud Properties @ 7210' MW: 9.6 Vis 50 PV 16 YP: 22 FL: 4.4 Gels: 7/9/12 Sol: 8 pH: 9.9 CI ' 26k Ca + +: 80 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: 0 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg. BG : 15 -35u 291u 6642/5645 Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas n/a Connection none C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 7500 ft: 80% claystone, 20% sandstone, trace carbonaceous material Last 24 hrs: 70% claystone, 20% sandstone, 10% carbonaceous materials Operational Summary: Rotary drill from 6507 ft to 7238 ft at report time. Slight torque increase with depth. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $4310.00 • Li EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wall, Jeffery Harrison Date: 8/16/08 Time: 2359 Current Depth (MD): 7786 Current Wiper trip at TD Current Depth (TVD): 6750 Operations: 24 hr Footage (MD): 548 Drilling Parameters ROP: Current: 0 Max: 130 Torque: Current: 0 Max: 10655 WOB: Current 0 Max: 25 RPM: Current: 0 Max: 116 PP: Current: 0 Max: 3174 Lag: Strokes: 8685 Time: 39.5 Surf -Surf: Strokes: 10225 46.5 ECD: Current: 10.4 Max: Mud Properties @ 7786 MW: 9.6 FV: 46 PV: 15 YP: 20 FL: 3.8 Gels: 5/9/10 Sol: 9 pH: 9.8 CI 28k Ca + +: 80 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): 41) Avg. BG : 15 -20 159 7433/6466 while circulating Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas none Connection C1 C2 C3 C4I C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: 7786 ft: 50% claystone, 50% sandstone Last 24 hrs: 80% claystone, 20% sandstone Drill ahead from 7238 ft to TD at 7786 ft. Experienced some torque during todays Operational Summary: drilled interval. Circulate bottoms up 3 times. Drop carbide and believe hole to be in good gage. Currently working pipe /washing and reaming on wiper trip at bit depth 7200 ft at report time. Calibrations: Chromatograph, THA. Failures: None 411 Daily Cost: $4310.00 Ell EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 Daily Report Report for: Robert Wall Jeffery Harrison Date: 8/17/08 Time: 2359 Current Depth (MD): 7786 Current Current Depth (TVD): 6750 Operations: 24 hr Footage (MD): 0 Lay down BHA Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 7786 MW: 9.6 FV: 45 PV: 11 YP: 18 FL: 4.2 Gels: 6/7/10 Sol: 8 pH: 9.8 CI 28k Ca + +: 60 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data 41) Ditch Gas: Current: Max: Depth (MD /TVD): Avg. BG : n/a Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 7786/6750 Wiper 212u Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new footage drilled this period. Last 24 hrs: Continue wiper trip from 7786 ft to 5400 ft. Experienced some tight spots. Wash Operational Summary: and ream as necessary. Run back to bottom at 7786 ft; record 212 units of wiper trip gas. Circulate and condition hole. Spot pill and dry job. Pull out of hole for wire line logs. Laying down Sperry BHA -smart tools at report time. Calibrations: THA. Failures: None Daily Cost: $4110.00 Pi EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 11 10 Daily Report Report for: Robert Wall Jeffery Harrison Date: 8/18/08 Time: 2359 Current Depth (MD): 7786 Current E -Lo in Current Depth (TVD): 6750 Operations: gg g 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties 7786 MW: 9.7 FV: 48 PV: 12 YP: 17 FL: 4.5 Gels: 5/7/9 Sol: 8 pH: 9.8 CI ' 28k Ca + +: 60 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg. BG : 5 -6U while circulating in casing Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas none Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: No new footage drilled today Operational Summary: Wire line logging with Schlumberger. Currently running to bottom with drill pipe conveyed log at casing shoe 3600 ft at report time. Calibrations: THA. Failures: None • Daily Cost: $3110.00 El EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wall Jeffery Harrison Date: 8/19/08 Time: 2359 Current Depth (MD): 7786 Current Current Depth (TVD): 6750 Operations: Logging 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cf Ca + +: MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG: Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas none Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: No new footage drilled Operational Summary: Continue drill pipe conveyed logs. Calibrations: THA. Failures: None • Daily Cost: $3110.00 E1 EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Robert Wall Jeffery Harrison Date: 8/20/08 Time: 2359 Current Depth (MD): 7786 Current Logging Current Depth (TVD): 6750 Operations: gg g 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg. BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas n/a Connection n/a C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: Last 24 hrs: No new footage drilled this period. Operational Summary: Continue drill pipe conveyed logs. Calibrations: THA. Failures: None Daily Cost: $3110.00 EPOCH Cono coPhillips Alaska, Inc. BRU 211 -26 Daily Report Report for: Larry Hill, Guy Whitlock Jeffrey Harrison Date: 8/21/08 Time: 2359 Current Depth (MD): 7786 Current Rig down Schlumberger Current Depth (TVD): 6750 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: CI Ca + +: MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: 4110 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG: Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas n/a Connection n/a C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: No new footage drilled this period. Operational Summary: Continue with and complete drill pipe conveyed logs. Rig up, run and complete side wall coring. Rigging down Schlumberger operations at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3110.00 El EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 Daily Report Report for: Guy Whitlock Jeffrey Harrison Date: 8/22/08 Time: 2359 Current Depth (MD): 7786 Current Prepare to test 7" rams Current Depth (TVD): 6750 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 7786' MW: 9.8 FV: 50 PV: 10 YP: 21 FL: 5 Gels: 5/7/9 Sol: 8.5 pH: 9.9 CI 31k Ca + +: 92 MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG: Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas B/U 350u Connection C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: No new footage drilled Rig down Schlumberger side wall core tools. Service rig top drive and crown. Pick up BHA #4 and run in hole for cleanout. Wash and ream from 6920 ft to 7786 ft Operational Summary: due to excessive down weight: UP 120k, DN 62k, RW 94k; RPM 100, TRQ 7000. Circulate and condition hole. Pull out of hole from 7786 ft. Lay down BHA per Sperry. Pull wear bushing and prepare to test 7: pipe rams. Calibrations: Chromatograph, THA. Failures: None • Daily Cost: $3110.00 El EPOCH ConocoPhillips Alaska, Inc. BRU 211 -26 • Daily Report Report for: Guy Whitlock Jeffrey Harrison Date: 8/23/08 Time: 2359 Current Depth (MD): 7786 Current Circulate through 7" Current Depth (TVD): 6750 Operations: casing at 7775 ft. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cf Ca + +: MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): 411 Avg. BG : 20 -25u Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 7786/6750 89 u Connection none C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Continue testing 7" pipe rams. Epoch calibrates sensor; records and charts test. Change out elevators, tongs, spinners and prepare to run 7 ", 26# L -80 casing. Rig up Weatherford and run casing to 7753 ft. Pick up and make up hanger, landing Operational Summary: joint and BJ cement head. Circulate from rig mud pump through hose. Attempt to reciprocate: SW 85k, UW 180k. Land 7" casing at 7775 ft. Circulate and condition hole at 210 gpm, 550 psi. Epoch records 89 units maximum trip gas. Background gas settles to 20 -25 units. Preparations are underway for cement job at report time. Calibrations: THA. Failures: None Daily Cost: $3110.00 L5 I EPOCH
