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208-079
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): 7,005' 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); SSSV See Schematic; 1,922' MD/ 1,844' TVD 6,781'6,552'6,328' Beluga River Sterling-Beluga Gas 20" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 243-34CO 802A Same 6,770'7" ~551psi 6,976' 6,552' Length September 11, 2025 4-1/2" 6,994' Perforation Depth MD (ft): 3,027' See Attached Schematic 5,750psi 79' 2,827' 79' Size 60' 9-5/8"3,009' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 6,540' 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 FEDA029656|FEDA029657 208-079 50-283-20124-00-00 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 DOA - Noel Nocas outofoffice By Grace Christianson at 10:41 am, Sep 04, 2025 Digitally signed by Stefan Reed (005753) DN: cn=Stefan Reed (005753) Date: 2025.09.04 08:27:43 - 08'00' Stefan Reed (005753) 325-544 SFD 9/4/2025 DSR-9/9/25BJM 9/4/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:44:41 -08'00'09/10/25 RBDMS JSB 091125 Well Prognosis Well Name: BRU 243-34 API Number: 50-283-20124-00-00 Current Status: Gas Producer Permit to Drill Number: 208-079 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: ~765 psi @ 6126’ TVD (Based on 12/27/24 Production Survey) Max. Potential Surface Pressure: ~551 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 ~1097 mcfd, ~80 bwpd @ 53psi. 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 and dropping soap sticks every 3.75hrs to keep well unloaded. 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. This well has a SSSV as it is within 660ft radius of a navigable waterway (Cook Inlet). Per 20AAC25.265(d)(4) the wireline retrievable SCSSSV will be removed while there is a capillary string installed in this well. Notes Regarding Wellbore Condition x 4.5” gravel pack completion x Lower gravel pack 2-7/8” from 5172-6382’ x Inclination o Max deviation of 31.5° @ 1692’ MD x SL tag @ 6,467 w/ 2” DD Bailer (12/26/24) x PLT data on 12-28-24 indicated fluid level @ ~4200 Procedure: 1. MIRU SL PT250/1500 psi 2. Pull SSSV from 1922’ KB 3. PU 2” DD Bailer, RIH and tag bottom. (drift a minimum to 4500) 4. RIH and pull a PT Survey on well a. RIH @ 180fpm b. POOH @ 120 fpm 5. RDMO SL 6. RU Cap String Truck 7. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components (injection valve greater than 1500 psi). Remove soap launcher. 8. Install pack-off and pressure test against swab valve to 1500 psi 9. RIH with 3/8” capillary string to ±4500’ MD 10. Install slips and connect tubing to chemical injection pump 11. Set spool of remaining line near well 12. RD cap string unit, and turn well over to production Well Prognosis 13. 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 14. Pump defoamer as needed into flowline downstream of wing valve Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. 660ft Radius Map of BRU 243-34 _____________________________________________________________________________________ P.1 Updated by CAH 9-2-25 SCHEMATIC Beluga River Unit Well: BRU 243-34 Last Completed: 07/27/2008 PTD: 208-079 API: 50-283-20124-00-00 20” 9-5/8” RKB to MSL = 93.5’ RKB to GL = 16.5’ TMD = 7,005' TVD = 6,781' PBMD = 6,552’ PBTVD = 6,328’ Max Angle = 31.5 deg Kickoff @ 1,692’ 2 3 4 5 3/8” cheml line TOC @ 2,940’ D E 7” SC-2 packer CIBP 6522' E F G SC-1L packer 3852’ SC-1L packer 4252’ SC-1L packer 4650’ SC-2 packer 5141’ SC-2 packer 5162’ FS sump packer 6370’ 2-7/8 isolation string H H H I CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 154.2#X-65 Weld 18''78.5' 9-5/8"Surface 40#L-80 BTC 8.835''3,027' 7''Production 26.4#L-80 BTCM 6.276''6,994' 4.74''Upper Gravel Pack 11#P-110 SLHT 3.47"5,160' 4.74''Lower Gravel Pack 11#P110 SLHT 3.47''6,378' TUBING DETAILS 4.5"Production String 12.6#L-80 IBTM 3.958''6,540' 2-7/8”Lower Iso String 6.4#L-80 Hyd 511 2.37” Gravel Pack Detail Size Type WT Grade Conn ID MD Top MD Btm 4''Upper Gravel Pack Screens 11#P-110 SLHT 3.43'' 3,809' 5,149' 2-7/8''Lower Grav. Pk Iso Strng 6.4#L-80 Hyd 511 2.313''5,141'6,382' 4.5''Lower Grav. Pk Scrns 11#P-110 SLHT 3.43''5,162'6,392' 5.5''Sump Packer 23#L-80 SLHT 4.93''6,370'6,392’' ID.Depth MD (ft.)ID (in.)OD (in.)Description 1 30 3.958 Vetco Gray Tubing Hanger 2 519 3.92 Camco Chemical Injection Nipple w/ 3/8" Control Line 3 1922 2.25 Camco P-6i Hydraulic Landing Nippl w/ .25" Control Line w/ 4.5” WRDP-2-LO SSSV 4 3692 3.938 Camco KBG-2-1R Side Pocket Mandrel w/ DCK-2 SOV Set 5 3740 3.813 HES 'X' Nipple 6 3779 3.9 5.53 4.75" Baker Polished Bore Receptacle 7 3808 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 3809 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile U2 3824 2.81 3.25 4.52 Seal Bore U3 3838 10.35 3.930 4.54 Vent/gravel pack screen U4 3852 3.48 3.25 6.00 SC-1L Packer 70B6-40 U5 3855 2.81 3.25 4.52 Seal Bore U6 3857 18 3.25 5.24 Frac EXT MZ System U7 3894 355 3.5 5.85 Bakerweld Excluder 2000 Screen (3894-4249) U8 4251 3.48 3.62 6.00 SC-1L Packer 70B6-40 U9 4255 2.81 3.25 4.52 Seal Bore U10 4313 18 3.25 5.24 Frac EXT MZ System U11 4313 335 3.5 5.85 Bakerweld Excluder 2000 Screen (4313-4648) U12 4650 3.48 3.62 6.00 SC-1L Packer 70B6-40 U13 4654 2.81 3.25 4.52 Seal Bore U14 4656 18 3.25 5.24 Frac EXT MZ System U15 4687 453 3.5 5.85 Bakerweld Excluder 2000 Screen (4687-5140) U16 4650 3.48 3.62 6.00 SC-1L Packer 70B6-40 U17 5140 9.5 3.26 4.990 Snap latch/seal unit, mule shoe Lower Completion Isolation Assembly ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description L1 5162 18 3.27 3.98 Seal units & space out pups L2 5507 16 2.313 3.160 SLCMU BX Profile & Seal Unit L3 5719 16 2.313 3.160 SLCMU BX Profile & Seal Unit L4 5932 16 2.313 3.160 SLCMU BX Profile & Seal Unit L5 6301 16 2.313 3.160 SLCMU BX Profile & Seal Unit L6 6367 15 3.39 3.220 Seal unit 80-32 S-22 with Mule Shoe Lower Gravel Pack Completion and Perforations Details on Page 2 ____________________________________________________________________________________ Pg. 2 Updated by CAH 9-2-25 SCHEMATIC Beluga River Unit Well: BRU 243-034 Last Completed: 07/27/2008 PTD: 208-079 API: 50-283-20124-00-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Beluga D 3,912' 3,923' 3,689' 3,700' 11' 12 6/24/2008 Perf'd Beluga D 3,944' 3,958' 3,721' 3,735' 14' 12 6/25/2008 Perf'd Beluga D 3,976' 4,000' 3,753' 3,777' 24' 12 6/26/2008 Perf'd Beluga E 4,046' 4,062' 3,823' 3,839' 16' 12 6/27/2008 Perf'd Beluga E 4,076' 4,086' 3,853' 3,863' 10' 12 6/28/2008 Perf'd Beluga E 4,146' 4,156' 3,923' 3,933' 10' 12 6/29/2008 Perf'd Beluga E 4,228' 4,241' 4,005' 4,018' 13' 12 6/30/2008 Perf'd Beluga E 4,333' 4,387' 4,110' 4,164' 54' 12 7/1/2008 Perf'd Beluga F 4,530' 4,544' 4306' 4321' 14' 12 7/2/2008 Perf'd Beluga F 4,562' 4,610' 4339' 4387' 48' 12 7/3/2008 Perf'd Beluga F 4,617' 4,640' 4,394' 4,417' 23' 12 7/4/2008 Perf'd Beluga F 4,696' 4,701' 4,473' 4,478' 5' 12 7/5/2008 Perf'd Beluga F 4,705' 4,715' 4,482' 4,492' 10' 12 7/6/2008 Perf'd Beluga F 4,730' 4,740' 4,507' 4,517' 10' 12 7/7/2008 Perf'd Beluga F 4,821' 4,832' 4597' 4608' 11' 12 7/8/2008 Perf'd Beluga F 4,855' 4,862' 4632' 4639' 7' 12 7/9/2008 Perf'd Beluga F 4,865' 4,900' 4,642' 4,677' 35' 12 7/10/2008 Perf'd Beluga G 4,947' 4,954' 4,724' 4,731' 7' 12 7/11/2008 Perf'd Beluga G 4,974' 4,984' 4,751' 4,761' 10' 12 7/12/2008 Perf'd Beluga G 5,002' 5,008' 4,779' 4,785' 6' 12 7/13/2008 Perf'd Beluga G 5,026' 5,032' 4,802' 4,808' 6' 12 7/14/2008 Perf'd Beluga G 5,092' 5,098' 4,868' 4,874' 6' 12 7/15/2008 Perf'd Beluga G 5,109' 5,117' 4,885' 4,893' 8' 12 7/16/2008 Perf'd Beluga G 5,124' 5,129' 4,900' 4,905' 5' 12 7/17/2008 Perf'd Beluga G 5,294' 5,305' 5,070' 5,082' 11' 14 7/18/2008 Perf'd Beluga H 5,319' 5,324' 5,096' 5,101' 5' 14 7/18/2008 Perf'd Beluga H 5,380' 5,386' 5,157' 5,163' 6' 14 7/18/2008 Perf'd Beluga H 5,402' 5,428' 5,179' 5,205' 26' 14 7/18/2008 Perf&Frac Beluga H 5,469' 5,499' 5,246' 5,276' 30' 14 7/18/2008 Perf&Frac Beluga H 5,533' 5,539' 5,309' 5,315' 6' 14 7/18/2008 Perf'd Beluga H 5,546' 5,564' 5,322' 5,340' 18' 14 7/18/2008 Perf'd Beluga H 5,594' 5,606' 5,370' 5,382' 12' 14 7/18/2008 Perf'd Beluga H 5,614' 5,624' 5390' 5400' 10 14 7/18/2008 Perf'd Beluga H 5,650' 5,660' 5426' 5436' 10 14 7/18/2008 Perf'd Beluga H 5,682' 5,692' 5,458' 5,469' 10' 14 7/18/2008 Perf'd Beluga H 5,734' 5,754' 5,511' 5,531' 20' 14 7/18/2008 Perf&Frac Beluga H 5,770' 5,800' 5,547' 5,577' 30' 14 7/18/2008 Perf'd Beluga H 5,810' 5,868' 5,587' 5,645' 58' 14 7/18/2008 Perf&Frac Beluga H 5,886' 5,910' 5663' 5687' 24 14 7/18/2008 Perf&Frac Beluga H 5,954' 5,978' 5731' 5755' 24 14 7/18/2008 Perf'd Beluga H 5,988' 6,008' 5,765' 5,785' 20' 14 7/18/2008 Perf'd Beluga H 6,030' 6,040' 5,807' 5,816' 10' 14 7/18/2008 Perf'd Beluga I 6,234' 6,244' 6,011' 6,021' 10' 14 7/18/2008 Perf'd Beluga I 6,324' 6,350' 6,100' 6,126' 26' 14 7/18/2008 Perf&Frac Lower Gravel Pack Screens ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description L1 5141 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile L2 5161 20 3.27 4.9 Millout extensions & snaplatch L3 5162 3.78 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile L4 5169 35 3.5 5.78 Frac EXT 80-40 CK 250 w/ KO iso valve C-2 L5 5198 3.31 4.87 5.56 5” Shear out safety joint GPR 24 L6 5287 1082 3.25 5.85 Bakerweld Excluder 2000 Screens (5287- 6369), blank pipe and 3 seal bore receptacles L7 6369 9 3.25 4.990 Snap latch 82-40, Seal Unit & Mule shoe L8 6370 22 4.0 5.85 Sump packer Model FS Size 85-40 w/ Mule shoe GRAVEL PACK / CEMENT DETAILS Beluga H & I sands, 4 separate fracs (total of 240,314#) of 20/40 sand pumped, All zones gravel packed with 20/40 sand 9-5/8" TOC @ Surface: 137 bbl 10.5 ppg lead cement Drop top plug followed w 5 bbls water and 257 bbl of mud, pumped 50 bbls of 10.5 ppg cement dropped closing plug. 35 bbls of cement returned to surface (15 bbls of cement lost during job). 7” 296 bbls (793 sx) 12 ppg Type 1 bumped plug, floats held. 35 bbls of cement to surface. Lost 15 bbls during job. _____________________________________________________________________________________ P.1 Updated by CAH 9-2-25 PROPOSED Beluga River Unit Well: BRU 243-34 Last Completed: 07/27/2008 PTD: 208-079 API: 50-283-20124-00-00 20” 9-5/8” RKB to MSL = 93.5’ RKB to GL = 16.5’ TMD = 7,005' TVD = 6,781' PBMD = 6,552’ PBTVD = 6,328’ Max Angle = 31.5 deg Kickoff @ 1,692’ 2 3 4 5 3/8” cheml line TOC @ 2,940’ D E 7” SC-2 packer CIBP 6522' E F G SC-1L packer 3852’ SC-1L packer 4252’ SC-1L packer 4650’ SC-2 packer 5141’ SC-2 packer 5162’ FS sump packer 6370’ 2-7/8 isolation string H H H I CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 154.2#X-65 Weld 18''78.5' 9-5/8"Surface 40#L-80 BTC 8.835''3,027' 7''Production 26.4#L-80 BTCM 6.276''6,994' TUBING DETAILS 4.5"Production String 12.6#L-80 IBT-M 3.958''6,540' 4''Upper Gravel Pack 11#P-110 SLHT 3.47"5160' 4.5''Lower Gravel Pack 13.5#P-110 SLHT 3.47''6378' 2-7/8”Lower Iso String 6.4#L-80 Hyd 511 2.37” 3/8”Capillary String 0.08#0.049 SS Swagelok 0.0895”±4500’ Gravel Pack Detail Size Type WT Grade Conn ID MD Top MD Btm 4''Upper Gravel Pack Screens 11#P-110 SLHT 3.43'' 3,809' 5,149' 2-7/8''Lower Grav. Pk Iso Strng 6.4#L-80 Hyd 511 2.313''5,141'6,382' 4.5''Lower Grav. Pk Scrns 11#P-110 SLHT 3.43''5,162'6,392' 5.5''Sump Packer 23#L-80 SLHT 4.93''6,370'6,392’' ID.Depth MD (ft.)ID (in.)OD (in.)Description 1 30 3.958 Vetco Gray Tubing Hanger 2 519 3.92 Camco Chemical Injection Nipple w/ 3/8" Control Line 3 1922 2.25 Camco P-6i Hydraulic Landing Nippl w/ .25" Control Line w/ 4.5” WRDP-2-LO SSSV 4 3692 3.938 Camco KBG-2-1R Side Pocket Mandrel w/ DCK-2 SOV Set 5 3740 3.813 HES 'X' Nipple 6 3779 3.9 5.53 4.75" Baker Polished Bore Receptacle 7 3808 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 3809 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile U2 3824 2.81 3.25 4.52 Seal Bore U3 3838 10.35 3.930 4.54 Vent/gravel pack screen U4 3852 3.48 3.25 6.00 SC-1L Packer 70B6-40 U5 3855 2.81 3.25 4.52 Seal Bore U6 3857 18 3.25 5.24 Frac EXT MZ System U7 3894 355 3.5 5.85 Bakerweld Excluder 2000 Screen (3894-4249) U8 4251 3.48 3.62 6.00 SC-1L Packer 70B6-40 U9 4255 2.81 3.25 4.52 Seal Bore U10 4313 18 3.25 5.24 Frac EXT MZ System U11 4313 335 3.5 5.85 Bakerweld Excluder 2000 Screen (4313-4648) U12 4650 3.48 3.62 6.00 SC-1L Packer 70B6-40 U13 4654 2.81 3.25 4.52 Seal Bore U14 4656 18 3.25 5.24 Frac EXT MZ System U15 4687 453 3.5 5.85 Bakerweld Excluder 2000 Screen (4687-5140) U16 4650 3.48 3.62 6.00 SC-1L Packer 70B6-40 U17 5140 9.5 3.26 4.990 Snap latch/seal unit, mule shoe Lower Completion Isolation Assembly ID.Depth MD (ft.)Length (ft.)ID (in.)OD (in.)Description L1 5162 18 3.27 3.98 Seal units & space out pups L2 5507 16 2.313 3.160 SLCMU BX Profile & Seal Unit L3 5719 16 2.313 3.160 SLCMU BX Profile & Seal Unit L4 5932 16 2.313 3.160 SLCMU BX Profile & Seal Unit L5 6301 16 2.313 3.160 SLCMU BX Profile & Seal Unit L6 6367 15 3.39 3.220 Seal unit 80-32 S-22 with Mule Shoe Lower Gravel Pack Completion and Perforations Details on Page 2 Cap String @ ~3,900’ (TBD) _____________________________________________________________________________________ Pg. 2 Updated by CAH 9-2-25 PROPOSED Beluga River Unit Well: BRU 243-034 Last Completed: 07/27/2008 PTD: 208-079 API: 50-283-20124-00-00 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Beluga D 3,912' 3,923' 3,689' 3,700' 11' 12 6/24/2008 Perf'd Beluga D 3,944' 3,958' 3,721' 3,735' 14' 12 6/25/2008 Perf'd Beluga D 3,976' 4,000' 3,753' 3,777' 24' 12 6/26/2008 Perf'd Beluga E 4,046' 4,062' 3,823' 3,839' 16' 12 6/27/2008 Perf'd Beluga E 4,076' 4,086' 3,853' 3,863' 10' 12 6/28/2008 Perf'd Beluga E 4,146' 4,156' 3,923' 3,933' 10' 12 6/29/2008 Perf'd Beluga E 4,228' 4,241' 4,005' 4,018' 13' 12 6/30/2008 Perf'd Beluga E 4,333' 4,387' 4,110' 4,164' 54' 12 7/1/2008 Perf'd Beluga F 4,530' 4,544' 4306' 4321' 14' 12 7/2/2008 Perf'd Beluga F 4,562' 4,610' 4339' 4387' 48' 12 7/3/2008 Perf'd Beluga F 4,617' 4,640' 4,394' 4,417' 23' 12 7/4/2008 Perf'd Beluga F 4,696' 4,701' 4,473' 4,478' 5' 12 7/5/2008 Perf'd Beluga F 4,705' 4,715' 4,482' 4,492' 10' 12 7/6/2008 Perf'd Beluga F 4,730' 4,740' 4,507' 4,517' 10' 12 7/7/2008 Perf'd Beluga F 4,821' 4,832' 4597' 4608' 11' 12 7/8/2008 Perf'd Beluga F 4,855' 4,862' 4632' 4639' 7' 12 7/9/2008 Perf'd Beluga F 4,865' 4,900' 4,642' 4,677' 35' 12 7/10/2008 Perf'd Beluga G 4,947' 4,954' 4,724' 4,731' 7' 12 7/11/2008 Perf'd Beluga G 4,974' 4,984' 4,751' 4,761' 10' 12 7/12/2008 Perf'd Beluga G 5,002' 5,008' 4,779' 4,785' 6' 12 7/13/2008 Perf'd Beluga G 5,026' 5,032' 4,802' 4,808' 6' 12 7/14/2008 Perf'd Beluga G 5,092' 5,098' 4,868' 4,874' 6' 12 7/15/2008 Perf'd Beluga G 5,109' 5,117' 4,885' 4,893' 8' 12 7/16/2008 Perf'd Beluga G 5,124' 5,129' 4,900' 4,905' 5' 12 7/17/2008 Perf'd Beluga G 5,294' 5,305' 5,070' 5,082' 11' 14 7/18/2008 Perf'd Beluga H 5,319' 5,324' 5,096' 5,101' 5' 14 7/18/2008 Perf'd Beluga H 5,380' 5,386' 5,157' 5,163' 6' 14 7/18/2008 Perf'd Beluga H 5,402' 5,428' 5,179' 5,205' 26' 14 7/18/2008 Perf&Frac Beluga H 5,469' 5,499' 5,246' 5,276' 30' 14 7/18/2008 Perf&Frac Beluga H 5,533' 5,539' 5,309' 5,315' 6' 14 7/18/2008 Perf'd Beluga H 5,546' 5,564' 5,322' 5,340' 18' 14 7/18/2008 Perf'd Beluga H 5,594' 5,606' 5,370' 5,382' 12' 14 7/18/2008 Perf'd Beluga H 5,614' 5,624' 5390' 5400' 10 14 7/18/2008 Perf'd Beluga H 5,650' 5,660' 5426' 5436' 10 14 7/18/2008 Perf'd Beluga H 5,682' 5,692' 5,458' 5,469' 10' 14 7/18/2008 Perf'd Beluga H 5,734' 5,754' 5,511' 5,531' 20' 14 7/18/2008 Perf&Frac Beluga H 5,770' 5,800' 5,547' 5,577' 30' 14 7/18/2008 Perf'd Beluga H 5,810' 5,868' 5,587' 5,645' 58' 14 7/18/2008 Perf&Frac Beluga H 5,886' 5,910' 5663' 5687' 24 14 7/18/2008 Perf&Frac Beluga H 5,954' 5,978' 5731' 5755' 24 14 7/18/2008 Perf'd Beluga H 5,988' 6,008' 5,765' 5,785' 20' 14 7/18/2008 Perf'd Beluga H 6,030' 6,040' 5,807' 5,816' 10' 14 7/18/2008 Perf'd Beluga I 6,234' 6,244' 6,011' 6,021' 10' 14 7/18/2008 Perf'd Beluga I 6,324' 6,350' 6,100' 6,126' 26' 14 7/18/2008 Perf&Frac Lower Gravel Pack Screens ID. Depth MD (ft.) Length (ft.) ID (in.) OD (in.) Description L1 5141 4.24 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile L2 5161 20 3.27 4.9 Millout extensions & snaplatch L3 5162 3.78 4 6 Baker SC-2 Packer 70B-40 SLHT Box Nitrile L4 5169 35 3.5 5.78 Frac EXT 80-40 CK 250 w/ KO iso valve C-2 L5 5198 3.31 4.87 5.56 5” Shear out safety joint GPR 24 L6 5287 1082 3.25 5.85 Bakerweld Excluder 2000 Screens (5287-6369), blank pipe and 3 seal bore receptacles L7 6369 9 3.25 4.990 Snap latch 82-40, Seal Unit & Mule shoe L8 6370 22 4.0 5.85 Sump packer Model FS Size 85-40 w/ Mule shoe GRAVEL PACK / CEMENT DETAILS Beluga H & I sands, 4 separate fracs (total of 240,314#) of 20/40 sand pumped, All zones gravel packed with 20/40 sand 9-5/8" TOC @ Surface: 137 bbl 10.5 ppg lead cement Drop top plug followed w 5 bbls water and 257 bbl of mud, pumped 50 bbls of 10.5 ppg cement dropped closing plug. 35 bbls of cement returned to surface (15 bbls of cement lost during job). 7” 296 bbls (793 sx) 12 ppg Type 1 bumped plug, floats held. 35 bbls of cement to surface. Lost 15 bbls during job. SEC. 35 SEC. 34 SEC. 3 13N10W 12N10WBELUGA HWYBELUGA RIVER UNIT S & E FOSTER PROPERTIES LLC TYONEK NATIVE CORPORATION COOK INLET REGION INC MINICH HENRY G THREE MILE CREEK SERVICES INCKENAI PENINSULA BOROUGH D PAD BRU P&S YARD Source: Esri, Maxar, GeoEye, Earthstar Geographics, CNES/Airbus DS, USDA, USGS, AeroGRID, IGN, and the GIS User Community 151°2'0"W151°2'10"W151°2'20"W151°2'30"W151°2'40"W 61°10'25"N61°10'25"N61°10'20"N61°10'20"N61°10'15"N61°10'15"N61°10'10"N61°10'10"N61°10'5"N61°10'5"N61°10'0"N61°10'0"N61°9'55"N61°9'55"N0 130 260 390 520 Feet 1 inch = 250 feet @ 11x17 Page Size Map Date: 3/18/2021 Document Path: O:\Alaska\GIS\cook_inlet\fields\All_Fields\SSSV_TWellman\mxds\All_Fields_Pad_SHL_660ftBuffer_11x17_TWellman_v02.mxdBeluga River Unit BRU D PAD 660 ft Radius around Point of Interest Legend Point of Interest (POI) 660 Foot Buffer from POI Surface Well Location MHW Line (NOAA) KPB Parcels Cook Inlet Oil and Gas Units 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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' • • 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. :)_8 - 0 .7_g Well History File Identifier Organizing (done) ❑ Two -sided 111 11111111 III 11111 ❑ Rescan Needed 1111 111 RES N D IGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. 1 ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: M. Date: -� 3 i 1 l /s/ nie Project Proofing 11! UhIllIIIII 11111 BY: Date: 3 az i ! /s/ ni\ f Scanning Preparation 6" x 30 = 5b + 1 = TOTAL PAGES + i (Count does not include cover sheet) BY: Maria Date: 0:3 11 /s/ Production Scanning 111 1111 II I 1 10 III I Stage 1 Page Count from Scanned File: / 7 (Count does include cover heet) Page Count Matches Number in Scanning Pre aration: (/ YES NO BY: 4/10 Date: 3 a3 1 1 /s/ 1/14f 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 I IIIII ReScanned IIIIIIIIIIIIII III I BY: Maria Date: /s/ Comments about this file: Quality Checked 111 III III I 111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3/14/2011 Permit to Drill 2080790 Well Name /No. BELUGA RIV UNIT 243 -34 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20124 -00 -00 MD 7005 TVD 6781 Completion Date 7/28/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION • Types Electric or Other Logs Run: GR/RES, Dipole, USIT, CCL, Neutron, Density, Formation Micro (magi (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / H ype M-d /Frmt dumber Name Scale Media No Start Stop CH Received Comments ED D Asc ,f Directional Survey 0 7005 Open 6/26/2008 1 ' • Directional Survey 0 7005 Open 6/26/2008 D C Pds 16648 ✓See Notes 0 0 Open 7/24/2008 PDS format of Mud logs with Final Well Report in Word format Rpt Report: Final Well R 0 0 Open 7/24/2008 Final Well Report, Table of Contents, Equip & Crew, Well Data, Geo Data, Press /Form Data, Drill Data, daily Reports 'Log Mud Log 2 Col 3042 7005 Open 7/24/2008 MD Gas Ratio og Mud Log 2 Col 3042 7005 Open 7/24/2008 TVD Gas Ratio III , Mud Log 2 Col 3042 7005 Open 7/24/2008 MD Formation Log 4 Mud Log 2 Col 3042 7005 Open 7/24/2008 TVD Formation Log t l L og Lithology 2 Col 3042 7005 Open 7/24/2008 MD LWD Lithology ✓Log Lithology 2 Col 3042 7005 Open 7/24/2008 TVD LWD fr6g Mud Log 2 Col 3042 7005 Open 7/24/2008 MD Drilling Dynamics g Mud Log 2 Col 3042 7005 Open 7/24/2008 TVD Drilling Dynamics pt LIS Verification 181 7004 Open 8/8/2008 LIS Veri, RPD, RPS, FET, RPM, GR, ROP, PEF, NCNT, FCNT, NPHI, DRHO,RHOB DATA SUBMITTAL COMPLIANCE REPORT 3/14/2011 Permit to Drill 2080790 Well Name /No. BELUGA RIV UNIT 243 -34 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20124 -00 -00 M (CUs16713'uction/Resistivity 7005 TVD �6781 Completion Date 7/28/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N 181 7004 Open 8/8/2008 LIS Veri, RPD, RPS, FET, RPM, GR, ROP, PEF, NCNT, FCNT, NPHI, DRHO, RHOB og Induction /Resistivity 25 Col 231 7005 Open 8/8/2008 MD ROP, DGR, EWR, III CTN, SLD Log Induction /Resistivity 25 Col 231 6780 Open 8/8/2008 TVD DGR, EWR, CTN, SLD // ✓ ED C 16714' See Notes 0 0 8/8/2008 TVD and MD of EWR logs in EMF, CGM and PDS graphics (fLog Induction /Resistivity 2 Blu 2874 6966 Open 8/15/2008 Array Induction, AIT 12- Jun-2008 Log Induction /Resistivity 5 Blu 2874 6966 Open 8/15/2008 Array Induction, AIT 12- Jun -2008 og Neutron 2 Blu 2874 6966 Open 8/15/2008 Neutron, Lithodensity, SNL, LDL, GR 12- Jun -2008 og Neutron 5 Blu 2874 6966 Open 8/15/2008 Neutron, Lithodensity, SNL, LDL, GR 12- Jun -2008 og Sonic 2 Blu 2874 6966 Open 8/15/2008 Dipole Sonic, DSI, FMI, GR 12- Jun -2008 og Sonic 5 Blu 2874 6966 Open 8/15/2008 Dipole Sonic, DSI, FMI, • GR 12- Jun -2008 D C b F S 16768 'See Notes 0 0 Open 8/15/2008 2 -logs for CNL, Induction and Dip in .G6M, FMF and PDS graphics t/rog Cement Evaluation 5 Col 2850 6850 Case 8/15/2008 CEL, USIT, GR, CCL 20- Jun -2008 ED C Pds 16769e ement Evaluation 5 2850 6850 Case 8/15/2008 CEL, USIT, GR, CCL 20- Jun -2008 og See Notes 5 Col 6370 6676 Case 8/15/2008 Bridge Plug, GR, CCL 20- f , Jun -2008 D C Pds 16770 Notes 6370 6676 Case 8/15/2008 Bridge Plug, GR, CCL 20- Jun -2008 L DATA SUBMITTAL COMPLIANCE REPORT 3/14/2011 Permit to Drill 2080790 Well Name /No. BELUGA RIV UNIT 243 -34 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20124 -00 -00 MD 7005 TVD 6781 Completion Date 7/28/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N r Log Formation Micro Ima 5 Blu 3020 6915 Open 8/15/2008 Fullbore Micro Resistivity Imager, FMI, GR 12 -Jun- 2008 ED C Pds 16771" Formation Micro Ima 2 3020 6915 Open 8/15/2008 Fullbore Micro Resistivity 1 Imager, FMI, GR 12 -Jun- 2008 • og Formation Tester 2 Blu 3011 6342 Open 8/15/2008 Modular Formation Dynamic Test, MDT 13- Jun -2008 C Pds 16772Formation Tester 3011 6342 Open 8/15/2008 Modular Formation Dynamic Test, MDT 13- Jun -2008 og Sonic 5 Col 3020 6915 Open 8/15/2008 Dipole Sonic, DSI, FMI, 1 GR 12- Jun -2008 D C Pds 167 Sonic 3020 6915 Open 8/15/2008 Dipole Sonic, DSI, FMI, GR 12- Jun -2008 Rpt LIS Verification 181 7004 Open 9/16/2008 LIS Veri, RPD, RPS, FET, RPM, GR, ROP, PEF, i NCNT, FCNT, NPHI, DRHO,RHOB ED C Las 20020VProduction 3667 4985 Case 8/30/2010 PPL, GR, CCL, Pres, Temp Well Cores /Samples Information: • Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? VP Daily History Received? / N Chips Received? `MT Formation Tops / N Analysis ?Tr Received? DATA SUBMITTAL COMPLIANCE REPORT 3/14/2011 Permit to Drill 2080790 Well Name /No. BELUGA RIV UNIT 243 -34 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20124 -00 -00 MD 7005 TVD 6781 Completion Date 7/28/2008 Completion Status 1 -GAS Current Status 1 -GAS UIC N Comments: Compliance Reviewed By: Date: ) (I 6 1 _ { __h1 1 • • 1 • , tR COnOCOPhilliPS TRANSMITTAL Beluga River Unit development well data FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510 -0360 333 W. 7 Ave, Suite 100 Anchorage, Alaska 99501 -3539 RE: Beluga River Unit production logging DATE: 08/16/2010 Mail delive Transmitted: Cook Inlet, Alaska BRU224 -13 (permit 173- 037 -0) 90 1 I/ Proactive Diagnostic Services, Multi- finger caliper report and 3D data and viewer; 8/28/2007 tvProactive Diagnostic Services, Production profile; 7/18/2008 BRU 211 - 03 (permit 186 - 010 - 0) G if v Proactive Diagnostic Services, Multi -finger caliper report and 3D data and viewer; 6/4/2008 Proactive Diagnostic Services, Gas Entry Survey; 6/5/2008 BRU 212 - 35T (permit 198 161 - 0) D(o ( i/ Proactive Diagnostic Services, Production profile; 7/17/2008 BRU 212 - 24 (permit 172 015 - 0) co( 17 Proactive Diagnostic Services, Multi finger caliper report and 3D data and viewer; 9/22/2005 BRU 243 - 34 (permit 208 O6 a ( Proactive Diagnostic Services, Production profile; 9/2/2008 To all data recipients: please s /on, scan and return this transmittal via e -mail to the e -mail adcress below RECEIVED CC: Art Co I s Geologist g st Receipt: Date: AV:, 3 0 2010 Ag. . , GIS Technical Data M' ar,. ,er ..o,. « " /Alfs ��' .: i Alaska j Ph ' 9075555 Sandra.D.Lemke�n Conocophi /lips com t- G/>' • AUG 1 31ibt z'°y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ri 8SKa O (.,: ° '° ' Cjmr ssiftr? REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well Ef ,.•"Plug Perforations ❑ Stimulate 0 • Other Q remove bridge plug 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 0 • Exploratory ❑ 208 -079 / • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 283 - 20124 - 00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 93.5' . BRU 243 - . 8. Property Designation: 10. Field /Pool(s): A029656, A029657 Beluga River Field / Undefined Gas Pool , 11. Present Well Condition Summary: Total Depth measured 7005' • feet true vertical 6781' . feet Plugs (measured) Effective Depth measured 6552' feet Junk (measured) true vertical 6328' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 60' 20" 78.5' 78.5' Intermediate 3009' 9 -5/8" 3027' 2827' Production 6976' 7" 6994' 6770' Perforation depth: Measured depth: perfs from 3912'- 6350', refer to attachment for list true vertical depth: Tubing (size, grade, and measured depth) 4.5 ", L -80, 3812' MD. W cite Packers & SSSV (type & measured depth) packers from 38t0' to 6370' PoLC e - deft-- ? g2-0 SSSV @ 1922' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 3912' -6350' 540 bbls of 5% HCI 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 5900 - 20 370 Subsequent to operation 7700 - 115 415 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development El 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 -395 . Contact Jim Ennis @ 2.: -1544 Printed Name Jim En Title Wells Engineer ? 2 Signature Phone: 265 -1544 Date t Prepared by haron Al/sup-Drake 263 -4612 Form 10-404 Revised 04/200. RBOMS BFL AuV 1 2G (19 Submit Original Only •BRU 243 -34 Well Events Summary DATE SUMMARY • 6/3/09 Pull 4.5" WRDP from 1922' RKB (SN# HWS -180). Hand well back over to production. 6/4/09 MIRU unit, perform BOP test. (State notified 24 hours prior by telephone). / 6/5/09 RIH and mill through Baker composite plug @ 5196' ctmd, made Venturi junk basket run to tag @ 5213' ctmd, POOH w/ composite millings and scale inside of basket. LDFN. 6/6/09 RIH w/ 2.125" Rotojet nozzle while pumping 5% Hcl w/ 350 scfpm N2. Tagged debris @ 5210' ctmd, pumped 75 bbls of acid, unable to make hole. RIH w/ 2.30" burnover shoe mated to venturi junk basket. OOH with composite plug core and fiber strands. LDFN 6/7/09 RIH w/ 2.125" OD rotojet to 5210' w/ 5% Hcl @ nozzle, unable to make hole. RIH w/ 2.28" five blade junk mill, broke through obstruction and continued to RIH to 5316' ctmd. RIH w/ rotojet while pumping 5% Hcl down to 5356' ctmd. Out of fluids, will resume in the morning. 6/8/09 RIH w/ 2.88" junk mill and clean tubing of scale through tubing tail to 6400' ctmd. Slightly less than 75% returns utilizing only well pressure for returns. Tubing is now clear of any obstructions, will return in the morning for a final acid wash on tubing string. LDFN 6/9/09 STAND BY FOR HALF DAY FOR COMPANY MAN CHANGE OUT. SPENT REMAINDER OF DAY OFF LOADING RETURNS FROM PREVIOUS DAY, MIX ACID FOR ACID JOB IN AM. LOCATE CHEMICALS FOR INHIBITOR SQUEEZE. 6/10/09 RIH W/ 2.125" OD ROTOJET TO 5,195' WITH 5% HCL ACID, JET TUBING THROUGH TUBING TAIL TO 6,400'CTMD. NO OBSTRUCTION ENCOUNTERED, PUMPED TOTAL OF 540 BBLS OF 5% HCL WITH BETTER THAN 1:1 RETURNS, PUMPED @ 150 MCF NITROGEN DURING ACID WASH. RDFN. WILL PUMP REMAINING 270 BBLS 5% HCL IN AM. 6/11/09 PUMPED REMAINING 270 BBLS 5% HCL ACID ACROSS TUBING FROM 3,800' TO 5,150'MD. PUMPED NITROGEN @ MIN. RATE (180 SCFM) THROUGHOUT TUBING WASH. MAINTAIN BETTER THAN 1:1 RETURNS THROUGHOUT. RDFN. SPENT REST OF DAY CLEANING SUPPLY TANKS AND MIXING CHEMICALS FOR SCALE INHIBITOR SQUEEZE TOMORROW. 6/12/09 RIH W/ 2.25" WEATHERFORD CT PACKER SET @ 5,400'MD. PUMPED 589 BBLS SCALE INHIBITOR SQUEEZE THROUGH CT PACKER @ 2.5 BPM AS PER PROCEDURE. MONITOR WELL 24 HOURS, IN PROGRESS. 6/13/09 LEFT WELL SHUT IN 24 HRS FOR SCALE INHIBITOR TO MATURE. RELEASED 2.25" WEATHERFORD CT PACKER @ 5,400'MD. POOH WITH COIL. RDFN. TURN WELL OVER TO PTS FOR FLOW BACK. WILL RIG UP BJ COIL FOR N2 LIFT IF NECESSARY IN AM, IN PROGRESS. 6/14/09 RIH W/ 2.125" NOZZLE TO 6,400'MD. PERFORM N2 LIFT @ 350 SCFM, INITIAL WATER RETURN RATE 160 -180 BPH, AFTER THREE HOURS RATE DROP TO 80 -100 BPH WITH MINIMAL GAS RETURNS. PUT WELL IN PTS TEST SEPARATOR FOR FLOW BACK OVER NIGHT, WELL CURRENTLY PRODUCING 1.4 MILLION AND 75 BBLS WATER PER HOUR, TOTAL FLUID VOLUME RECOVERED 1,100 BBLS. IN PROGRESS. 6/15/09 CONTINUE FLOW BACK THROUGH PTS TEST SEPARATOR. GAS RATE INCREASED FROM 1 MILLION TO 1.4 MILLION DAILY AND WATER RATE DECREASED FROM 70 BPH TO 45 BPH, TOTAL FLUID RECOVERED 2,500 BBLS, FLOW BACK IN PROGRESS. 6/16/09 Continue to flow back well through PTS test separator. WHP stayed between 130 -140 psi. Gas rate 1.3 - 1.4 million gas per day. Water return rate between 30 - 40 BPH. Flow back in progress. 6/17/09 CONTINUE FLOW BACK THROUGH PTS TEST SEPARATOR. WHP 130 PSI. GAS RATE INCREASED FROM 1.4 MILLION TO 1.67 MILLION LAST 12 HOURS. WATER RATE BETWEEN 30-40 BPH. FLOW BACK IN PROGRESS. 6/18/09 CONTINUE FLOW BACK THROUGH PTS TEST SEPARATOR. WHP 170 PSI. GAS RATE INCREASED FROM 1.67 MILLION TO 2.0 MILLION LAST 12 HOURS. WATER RATE BETWEEN 25 -30 BPH. FLOW BACK IN PROGRESS. 6/19/09 CONTINUE FLOW BACK THROUGH PTS TEST SEPARATOR. WHP 170 PSI. GAS RATE INCREASED FROM 2.00 MILLION TO 2.20 MILLION LAST 12 HOURS. WATER RATE BETWEEN 25 BPH. FLOW BACK IN PROGRESS. RIG DOWN BJ EQUIPMENT. SAK 0 BRU 243 -34 COnOCOPh dhhpS Well Attributes Max Angle & MD TD ,VCs Wellbore APIIUWI Field Name Well Status Mc! ( °) MD (ftKB) Act Bhn (1100) C09Q9Wh0I 9 502832012400 BELUGA PEA R UNI PROD 31 47 1,601 54 7,(A)5 0 "" /Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV' WRDP Last WOE _ 7/28/2008 ,_ We8Cn8,9. DEV(ATE,D,_,B 74334.7/28/20097 "034 °M A nnotation Depth ftK61 End Date Ann n L ast Mod End Date Sch Aqubi P ( Y 11111111111111 Last Tag- 1 Rao Reason_ ACID WASH 10P UPDA 1E VI plwj 7/28/2009 , ,.. Casing Strings - _- oT - t Casing Description String 0... String ID ..- Top (tIKB) Set Depth (f__ Set Depth (TVD) __ String Wt... String ... String Top Thrd '....• '-'-- '' CONDUCTOR 20 18.000 20.2 78.5 78.5 Casing Description String 0... String lD... Top (ftKB) Set Depth (f... Set Depth (TVD)._String Wt... String ... String Top Thrd SURFACE 9 5/8 8835 - 4.8 3,026.7 2,826.5 40.00 L - 80 BTC HANGER, 30 __ Casing Description String 0... String ID Top (kKB) Set Depth (f... Set Depth (180) .. String Wt... String .. String Top Thrd ■ CONDUCTOR, ■ '? PRODUCTION 7 8276 18.0 6 994 2 6,770.2 26.40 L-80 20'9 Tubin Strings NIPPLE, 519 _. y . Tubing ...___ WR, 11,92,8222 �- __ _r Tubing Description String 0... String ID Top (ftKB) Set Depth (1.. Set Depth (TVD) .. String Wt... St String Top Thrd NIPP - -- I USING 4 1/2 3 958 13 7 1 _ . 3,811 9 , 3,588.3 12.65 L-80 I IBTM Completion Details SURFACE, Top Depth -5 -3,027 (TVD) Top Intl GAS LIFT, Top (ftKB) (kKB) ( °) Item Description Comment ID (in) 3.893 � _ .. NIPPLE, 3,740 29.9 29.9 0 07 HANGER VETCO GRAY TUBING HANGER 3.250 I 11 Y 518.8 518.7 089 NIPPLE CAMCO CHEMICAL INJECTION NIPPLE with 3/8" CONTROL LINE 3.920 - PBR, 3,780 t 1,922.1 1,843.9 30.82 NIPPLE CAMCO BP-6i HYDRAULIC LANDING NIPPLE with 1/4" CONTROL 3.813 PBR, 3,780 x.,1 ASSY, LINE w/ 2.5" DUMY PACKOFF 3.809 ,_ __.. PACKER,3,820 - 3,740.3 3,517.0 5.59 NIPPLE HESXNIPPLE 3813 3,779.8 3,556.3 1.97 PBR BAKER PBR 3.900 ;s- 3,808.6 3,585.1 1.85 SEAL ASSY BAKER S -22 ANCHOR SEAL ASSY 3.250 INF PEW Tubing Description String O... String ID...', Top (ftKB) Set Depth (f... Set Depth (TVD).. String Wt... St g... String Top Thrd ?» GRAVEL PACK 474 3.470 3,820 3 , 5,160.0 4,936.0 11 00 I P SLHT SBR, 3960 -- Completion Details ... Top Depth .. AMP (TVD) Top Intl Top (MB) ( B) ( °) 1 Item Description Comment ID (In) `2' 3,820.3 3,596.8 1.81 PACKER SC -2 Packer 705-40 Nitrite 4.000 's 3,860.4 3,636.8 1.44 SBR - Seal Bore MZ System 80 -32 3.250 SCREEN, 3,905 - - 3,905.0 3,681.5 1.37 : SCREEN TUBING SCREEN 3.470 Tug Description g 0... String . TOp (MB) bin Descri IStrin o (TVD)... _ ._._ String Wt... [String ... String Tap Thrd ALL , :,- ISO STRING 289 2 370 5,141.0 1 Set Depth (f... Set Depth 6,382.7 6,158.7 6.40 L-80 Hydrill 511 Completion Details 0 Top Depth (TVD) Top Inc! i i11.4 Top(ftKB) ( B) .._ 1 1 ) Item Description Comment ID(in) 5,141.0 4 917.1 0.84 PACKER SC -2 Packer 70840 Nitrile 4.000 5,162.4 4 938.4 0 80 SEAL ASSY Seal Units 8240 90H Stub ACME N tnle 3.270 Add Wash, 3,912 Tubing Des pt on String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String _String Top Thrd iicPiii GRAVEL PACK - 474 3470 I 5,162.4 6,3781 6,1541 1100 P11o _ _ Completion Details • Top Depth (TVD) Top Ind Tep (ftKB) (ftKB) (°) ., .,, Item Description Comment ID (in) 5,162.4 4,938.4 0.80 PACKER SC -2 Packer 70B-40 Nitrite 4.000 MI. 5,169.7 4,945.8 0.79 SBR Seal Bore Receptacle 80-40 CK -250 4.000 5,193.9 4,969.9 0 75 SLEEVE Knock Out Isolation Valve C -2 Isolation Sleeve 3.320 PACKER, 5,141 - 5,287.6 5,063.6 0 78 SCREEN Screen Bakerweld Excluder 2000 4" SLHT 3.470 ii I 1 St ring ... String Top Thrd SSOW' PACK PACKER String 5 4 930 Top 6,370.0 ll .set Depth (TVD)... .. String 23.0 I L SLHT Tubing P 9 9 l ( I P ITV ) 9 ; Completion Details I ,370.0 (TVD) Top o p 068 PACKER PACKER, 5,182 rap(Description MC6) l ) ('( m D comm ID (in) SEAL ASSY, M To De to ,Baker Sump Packer Model Fa S¢e 8540 4.000 SBR, 5,170 as Other In Hole(Wrreline retrievable plugs, valves, pumps, fish, etc.) Top Depth I 1 (TVD) Top Inc! Top (5K6) (ftKB) (1 Description comment Run Date ID (in) - SLEEVE,5,194 - -- - 1,922 1843.9 30.82 WRDP WRDP (11AAL -071) 12/19/2008 2.125 1 Stimulations & Treatments SCREEN, 5,288 Bottom )ftKB (016) 0 (ftKB) 4 (ftKB) Min Top Max Btm Top Depth Depth Depth Depth (TVD( (TVD) I (ftKB) lftlCBl (ftKB) (ftKB) Type Dab Comment .Acid Wash 6/10/2009 Notes: General & Safety End Date Annotation 12/30/2008 NOTE. View Schematic w /Alaska Schematic9.0 I , ( 12/30/2008 NOTE: View Gravel Packs & !so String full details by clicking on Section Mandrel Details Top Depth Top - -�- Port - -- (TVD) Intl OD Valve Latch She TRO Run Stn Top (RKBj (MB) ( ° ) Mak Model (in) Sery Type Type en) (psi) Run Date Com... 1 3,692.6 3,469.6 7.04 CAMCO KBG -2 1 Gas Lift SOV 0.000 3,000.0 7/10/2008 II 1� . PACKER, 6,370 tees PRODUCTION, 1 18- 6,904'\ TD, 7,005 • 1 • • BRU 243 -34 Top Base Footage Beluga D, E, F and G 3944 3958 14 3976 4000 24 4046 4062 16 4076 4086 10 4146 4156 10 4228 4241 13 4333 4387 54 4530 4544 14 4562 4610 48 4617 4640 23 4696 4701 5 4705 4715 10 4730 4740 10 4821 4832 11 4855 4862 7 4865 4900 35 4947 4954 7 4974 4984 10 5002 5008 6 5026 5032 6 5092 5098 6 5109 5117 8 5124 5129 5 Beluga H&I 5294 5305 11 5319 5324 5 5380 5386 6 5402 5428 26 5469 5499 30 5533 5539 6 5546 5564 18 5594 5606 12 5614 5624 10 5650 5660 10 5682 5692 10 5734 5754 20 5770 5800 30 5810 5868 58 5886 5910 24 5954 5978 24 5988 6008 20 6030 6040 10 6234 6244 10 6324 6350 26 Page 1 of 3 • Davies, Stephen F (DOA) From: Little, Julie D. [ Julie .D.Little©conocophillips.comj Sent: Tuesday, April 21, 2009 2:05 PM To: Davies, Stephen F (DOA) Cc: Hartwig, Dennis D; Elgarico, Richard E Subject: BRU 234 - 34: Public Request Steve, Review of our records confirmed that mud log submitted to AOGCC was accidently stamped confidential. AS 31.05.035 (c) does not provide for confidentiality of any well data submitted under AS 31.050035(a) unless it is exploratory, stratigraphic, or likely to affect unleased acreage. BRU 243 -34 well was a development well and CPAI should not have claimed confidentiality for this well data. CPAI does not consider any information provided to AOGCC for BRU 243 -34 well as confidential. We will be revisiting our data stamps and transmittal forms for 2009 BRU drilling program to avoid this confusion in the future. Please contact me if you have any questions or require additional information. Julie D. Little Staff Landman ConocoPhillips Alaska 700 G. Street, ATO 1478 Anchorage, Alaska 99001 phone (907) 265 -6158 fax (907) 263-4966 julie.d.little @conocophillips.com From: Hartwig, Dennis D Sent: Tuesday, April 21, 2009 11:55 AM To: 'Davies, Stephen F (DOA)' Cc: Little, Julie D. Subject: RE: BRU 234 -34: Public Request Steve, I need to confirm with our Land and Legal people and will get back to you ASAP. Dennis Hartwig Drilling Engineer ConocoPhillips Alaska ATO -1592 Office : 907 - 265 -6862 Cell : 907 -575 -7109 6/19/2009 Page 2 of 3 • • Fax : 907-265-1535 From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Tuesday, April 21, 2009 8:49 AM To: Hartwig, Dennis D Subject: RE: BRU 234 -34: Public Request Dennis, Thanks for your help on this. I just need to be certain that ConocoPhillips does not consider any information associated with BRU 243 -34 to be confidential. Am I correct? We have a public request to view the BRU 243-34 information. Thanks again, Steve Davies Sr. Petroleum Geologist AOGCC 793 -1224 From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig @conocophillips.com] Sent: Tuesday, April 14, 2009 5:14 PM To: Davies, Stephen F (DOA) Cc: Levinson, Rick A; Braden, John C; Little, Julie D. Subject: RE: BRU 234 -34: Public Request Steve, I have taken Vern's place as lead Drilling Engineer for the Beluga River Unit. Julie Little copied me on your recent Email concerning mud log information for the BRU 243 -34. We appreciate the courtesy request, find no objection and agree that the confidentiality should not apply to this well. Further, we will communicate this issue with vendors for the upcoming Beluga development drilling season. Please contact me if any questions or concerns arise....Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska ATO -1592 Office : 907- 265 -6862 Cell : 907 -575 -7109 Fax :907- 265 -1535 From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Friday, April 10, 2009 4:44 PM To: Little, Julie D. Subject: BRU 234 -34: Public Request 6/19/2009 Page 3 of 3 . I Julie, I left a couple of voice mail messages for Vern Johnson this week regarding BRU 234 -34 and whom to speak to, but haven't heard back from him. Maybe you could help me. The Commission has received a request to view the well file and log information from this development well. It was permitted, drilled and completed during 2008. In July of 2007, Alaska Statute AS 31.05.035, which governs confidential reports, was revised. Section (c) of this statute does not grant confidentiality to development and service wells. Although the mud log information from BRU 234 -34 is stamped confidential, and confidentiality is mentioned on the transmittal letter for that data, the Commission sees no basis for confidentiality for any information from BRU 234 -34 under the Alaska Statutes. I am notifying you as a courtesy, since this is the first request to view information from a recent ConocoPhillips development well. Unless ConocoPhillips objects by the close of business Wednesday, April 15, 2009, the Commission will make the BRU 234 -34 information available to the requestor. I will be out of the office this week, but can be reached via email. If you have any questions that require immediate response, please call Art Saltmarsh at 793 -1230. Thanks for your help, Steve Davies Sr. Petroleum Geologist AOGCC 6/19/2009 II x ") � r , r ;,7.) ;i / tie p "�� ' i ts � � { (15") ti � { ..J P� � i i 4� t PA r I '` { I SARAH P ALIN, GOVERNOR ' � 2 , ) LI it i U -, ,) L c f �.1 t L Li A . A U _'.) _i \\ A� � w ' ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / i ANCHOORAG�E07AL2ASKA399501 -3539 t FAX (907) 276 -7542 Jim Ennis Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 243 -34 Sundry Number: 308 -395 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, /` Daniel T. Seamount, Jr. Chair DATED this S � day of November, 2008 End. o'6 • A i l ,JOVI Ve ■ STATE OF ALASKA \V ALASKA OIL AND GAS CONSERVATION COMMISSION �� APPLICATION FOR SUNDRY APPROVAL �`� �` " �� 20 AAC 25.280 1 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ,` ❑ - , Other L Alter casing ❑ Repair well # Plug Perforations ❑ Stimulate is Time Extension ❑ Change approved program ❑ Pull Tubing Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 , Exploratory ❑ 208 -079 . 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20124 -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 243 -34 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): a i, A029656, AO29657 r RKB 93.5' • Beluga River Field ASt - Betata Gas Pool 12. N.f PRESENT WELL CONDITION SUMMARY AD / /''f - ob Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7005' , 6781' • 6552' ' 6328' r Casing Length Size MD TVD Burst Collapse Conductor 60' 20" 78.5' 78.5' Intermediate 3009' 9 -5/8" 3027' 2827' Production 6976' 7" 6994' 6770' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3912' 4241', 4228' 4640', 4696 4.5" L -80 3812' Packers and SSSV Type: Packers and SSSV MD (ft) see attachment SSSV @ 1921' 13. Attachments: Description Summary of Proposal 0 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 November 4, 2008 Oil ❑ Gas 0 Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the fore.oing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed Name I Lor IS Title: Wells Engineer Signature , Phone: 265 -1544 Date 11 3 O g Commission Use Only Sundry Number: Conditions of approval: . ify Commission so that a representative may witness y- 39s , Plug Integrity ❑ BOP Test g Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3500 S 1 rN P\_ N ..3 t. C - VC ( Subsequent Form Required: 1..\() 11 APPROVED BY / I C* 77 Approved b .' f' COMMISSIONER THE COMMISSION Date: 1 J , 0 Form 11-403 Revised 06/200 - - -. . . 1 _ DM Submit in Duplicate,, BRU 243 -34 CT Mill Scale & Nitrified Acid Wells Network#: 10236649 The procedure outlined below will mechanically remove CaCO3 scale from the 4.5 "x4 "x2 -7/8" completion utilizing nitrified fluids with a motor & mills. BJ's roto —jet nozzle will then be used to radially wash the gravel pack completion w/ 10000 gals 5% HCL nitrified to remove any remaining scale. An incremental 5 MMCFD is expected following this work. 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/ 3.125" mill & 2.875" gas motor MHA to 3800' CTMD. Establish circ w/ 1 bpm 2 micron filtered 6% KCL water containing 1 gal /1000 gal FRW -14 & 1000 scfm N2. Adjust rates as necessary to maintain good returns. Mill down to 5150' CTMD. POOH. 3. RIH w/ 2.125" mill & 2.125" gas motor MHA to 5100' CTMD. Establish circ w/ 1 bpm 2 micron filtered 6% KCL water containing 1 gal /1000 gal FRW -14 & 1000 scfm N2. Adjust rates as necessary to maintain good returns. Mill down to 6400' CTMD. POOH. 4. RIH w/ 2.125" Roto-jet 90 degree discharge nozzle to 5150' CTMD. Establish circ w/ 1 bpm 5% HCL w/ additives & 1000 scfm N2. Adjust rates as necessary to maintain good returns. Perform up /down passes @ 30 fpm from 5150'- 3800'. After acid has been flushed from CT w/ 2 micron filtered 6% KCL water containing 1 ga1/1000 gal FRW -14 & N2, POOH 5. RIH w/ 2.125" jet nozzle to 6400'. Unload well w/ N2 @ 1500 scfm. POOH. Flow well for cleanup & turn over to production. 11/3/2008 BRU 243 -34 CT mill and acid procedure 10- 24- 08.docCreated by jjennis . . F: Equipment & Services Location: Sales Location: *°` spy 4 n Lafayette, La. - Phone # 337 - 593 -2700 Baker Oil Tools District Manager Steve Zuklic 1010 Rankin Rd. RAKER Biker Oil T . op.. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 HUGH 713 -6 5 -6800 lfiMl��77f7 Operator: Phone # BHP BHT Max. Dev. Zone Dev. Sand Size Page: 1 ,a CONOC 30 30 Company Representative: Phone # Type Of Screen Well Type Date: BRIAR BUCK Excluder 2000 / Bakerweld 10Ga. / Bakerweld 12 Ga. GAS Field: Well # Perforations Completion Fluid BELUGA 243 -34 3912' - 4241' , 4228' - 4640' , 4696' - 5129' ,:, State: Lease Salesman Phone # Job Number AK BELUGA Loading Docks: Phone # Size ID. WT. Grade Thread .a O8K CASING 7" 6.276" 26# L -80 BUTT-MOD Rig Name: Phone # Liner NABORS 129 Liner Prepared By: Phone # WRKSTG 4" 3.340" 16.08# S-135 HT -38 IBT -M ,�. BUDDY ARCENEAUX 337 - 593 -270C WRKSTG Drawing Rev. Date: Revision # TUBING 4 1/2" 3.958" 12.68 L -80 TUBING No Depth Lenpth OD ID Description t n It )))... COMPLETION ASSEMBLY A 4. • 0.00 16.20 Elevation 124 16.20 1.16 10.750 3.958 Tobin` Hanger MB 230 4.909 MCA Box X 4 1/2" IBT Pin 8/N CW344449 -04 i ,n 123 17.36 3.28 5.200 3.958 4 1/2" Pup Jt 12.6# L-80 BxP IBT -M 122 20.64 31.39 5.200 3.958 4 1/2" Tubing 1 Jt 12.6# L-80 BxP IBT -M j 121 52.03 3.49 5.200 3.958 4 1/2" Pup Jt 12.6# L -80 BxP IBT -M 120 55.52 9.67 5.200 3.958 4 1/2" Pup Jt 12.68 L -80 BxP IBT -M „= 119 65.19 443.69 5.200 3.958 4 1/2" Tubing 14 Jts 12.68 L -80 BxP IBT -M 118 508.88 9.67 5.200 3.958 4 1/2" Pup Jt 12.68 L -80 BxP IBT -M 117 518.55 1.24 5.576 3.920 4 1/2" Chemical Injection Nipple IBT-M BxP 116 519.79 9.64 5.200 3.958 4 1/2" Pup Jt 12.68 L -80 BxP IBT -M 115 529.43 1382.67 5.200 3.958 4 1/2" Tubing 45 Jts 12.6# L-80 BxP IBT -M 114 1912.10 9.81 5.200 3.958 4 1/2" Pup Jt 12.6# L -80 BxP IBT -M 113 1921.91 2.67 5.576 2.250 Cameo BP -6i Hydraulic Landing Nipple DB profile w/ 1/4" Control Line "' and 2.25" Dummy 4 1/2" IBT -M BxP 112 1924.58 9.58 5.200 3.958 4 1/2" Pup Jt 12.6# L-80 BxP IBT -M 111 1934.16 1748.53 5.200 3.958 4 1/2" Tubing 57 Jts 12.6# L-80 BxP IBC -M ,,. 110 3682.69 9.66 5.200 3.958 4 1/2" Pup Jt 12.6# L -80 BxP BT -M 109 3692.35 6.86 5.984 3.938 Cameo KBG-2-1R w/ DCK -2 SOV Set for 3000 PSI w/ 4 1/2" IBT -M IMP I ,m 108 3699.21 9.84 5.200 3.958 4 1 /2" Pup Jt 12.6# L -80 BxP IBf -M 'w 107 3709.05 31.02 5.200 3.958 4 1 /2" Tubing 1 Jt 12.6# L-80 BxP IBf -M 106 3740.07 1.13 5.000 3.813 4 1/2" X- Nipple SN- 11X38160 -A 10 105 3741.20 30.60 5.200 3.958 4 1/2" Tubing 1 Jt 12.6# L-80 BxP IBT -M 104 3771.80 7.79 5.200 3.958 4 1/2" Pup Jt 12.68 L -80 BxP IBT -M 103 3779.59 0.83 5.200 3.900 Polished Bore Receptacle 80 -47 Top Sub w/ 4-1/2" 12.68 IBC -M MM 3780.42 16.85 4.740 3.990 80 -47 Seal Units X 1/2 Muleshoe LL 3797.27 End Of Assembly 102 3782.42 18.41 5.540 4.750 Polished Bore Receptacle 80 -47 4 -1/2" 12.6# IBT Mod. 101 3800.83 7.80 4.910 3.958 4 1/2" Pup Jt 12.68 L -80 BxP IBC -M 100 3808.63 1.17 5.200 3.250 Anchorlatch 82 -40 S-22 4-1/2" 12.6# IBT Mod. Box KK 3809.80 1.56 3.980 3.250 Seal Units 82 -40 S-22 90H Nitrile Stub ACME JJ 3811.36 0.50 3.980 3.250 Half Mule Shoe 82 -40 Stub ACME It 3811.86 End Of Assembly /i III „ / • I Equipment 8 Services Location: Sales Location: 99 Lafayette, La. - Phone # 337-593-270C Baker Oil Tools MU ■ 98 District Manager: Steve Zuklic 1010 Rankin Rd. BAKER Baker Oil Tools : s 97 Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 HUGHES { 96 713- 625 -6800 :: 1 9 Operator: Phone # BHP BHT Max. Dev. Zone Dev. Sand Size Page: 1 ° € 9a CONOCO 0 0 30 I 30 0 a 9i Company Representative: Phone # Type Of Screen Well Type Date: Aff8 t' gy BRIAN BUCK Excluder 2000 / Bakerweld 10G.. / Bakerweld 12 Ga. GAS l 88 Field: Well # Perforations Completion Fluid • BELUGA 243 -34 3912' - 4241' , 4228' - 4640' , 4696' - 5129' 0 ag 87 State: Lease Salesman Phone # Job Number lE e e2 AK BELUGA 0 0 1 Loading Docks: Phone # Size ID. WT. Grade Thread a4fY- 0811 CASING 7" 6.276" 26# L-80 BUTT-MOD .f, 80 Ri g Name: Phone # Liner NABORS 129 Liner 79 Prepared By: Phone # WRKSTG 4" 3.340" 16.08# S-135 HT -38 BUDDY ARCENEAUB 337 - 593 -270C WRKSTG :4- t 78 Drawing Rev. Date: Revision # TUBING TUBING n No Depth -- OD ID Description ]5 n, ': 74 e t io di a OP 67 g 1 64 1 63 - 62 lk .' 61 s it i DR M. & s4 }} k S1 99 3809.80 4.15 6.000 4.000 8C -2 Packer 708.40 Nitrile :' _ 1 50 98 3813.95 10.21 5.550 4.700 Millout EXT. 5 -1/2" 23# L -80 SLHT 97 3824.16 2.81 4.520 3.250 Seal Bore 80-32 5-1/2" 23# SLHT Box x 4-1/2" 13.5# SLHT Pin -c 49 96 3826.97 1.73 5.010 3.880 EXT. Sub 4 -1/2" 13.58 P -110 SLHT I 95 3828.70 2.51 5.630 3.320 Knock Out Isolation Valve C -2 Isolation Sleeve4 -1 /2" 13.5# Box x 5" 23# SLHT Pin `:✓'' *,l 1 48 94 3831.21 1.73 5.630 3.340 Knock Out Isolation Valve C -2 5" 23# SLHT Box x 4 -1/2" 13.5# Pin _ 93 3832.94 6.01 4.530 3.930 EXT. Sub 4 -1/2 "13.5# P -110 SLHT 47 92 3838.95 10.35 4.540 3.930 Vent Screen Bakerweld 12 Ga.4 -1 /2" 13.58 P -110 SLHT " ` .` 91 3849.30 0.58 5.000 3.430 X -Over 4 -1/2" 13.5# SLHT Box x 4" 11# SLHT Pin g y ^ , , : I = o, 90 3849.88 2.18 4.500 3.250 Seal Bore MZ System 80 -32 4" 11# SLHT Box x 4 -1/2" Left Hand Square Thread Pu 89 3852.06 3.48 6.000 3.620 8C -1L Packer 7086.40 Left Hand Square Thread Box x Stub ACME No = 88 3855.54 2.09 5.020 3.250 Seal Bore MZ System 80-32 Stub ACME Pin x 4-1/2" 13.5# SLHT Pir s 87 3857.63 3.76 4.530 4.010 Upper EXT. MZ System 80 -32 4 -1/2" 13.58 P -110 SLHT - g 86 3861.39 4.02 5.240 4.010 Frac EXT. MZ System 80 -32 4-1/2" 13.58 P -110 SLHT , ""'' %,, a 4 9 85 3865.41 2.40 5.000 3.250 Seal Bore MZ System 80-32 4 -1/2" 13.5# SLHT -: - 4 3 84 3867.81 5.09 4.530 4.010 Lower EXT. MZ System 80 -32 4 -1/2" 13.58 P -110 SUIT fa - ! (: °2 83 3872.90 2.81 4.510 3.250 Seal Bore MZ System 80-32 4 -1/2" 13.5# SLHT . or 82 3875.71 0.58 5.000 3.500 X -Over 4 -1/2" 13.5# SLHT Box x 4" 11# SLHT Pin 40 81 3876.29 18.23 4.010 3.450 Blank Pipe 4" 11# P -110 SLHT ( 00. 80 3894.52 118.25 5.850 3.470 Sur..n Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT 0e 79 4012.77 19.81 5.850 3.500 Screen Bakerweld 10 Ga ( Joint ( 4" 11# P -110 SLHT _ [ 37 78 4032.58 59.21 5.850 3.470 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT "° ,4 35 77 4091.79 39.42 5.850 3.500 Screen Bakerweld 10 Ga./ 1 Joint) 4" 11# P -110 SLHT ... it 76 4131.21 39.45 5.850 3.470 Screen Bakerweld Excluder 2000( 1 Joint ( 4" 11# P -110 SLHT 00 75 4170.66 39.43 5.850 3.500 Screen Bakerweld 10 Ga.( 1 Joint ( 4" 11# P -110 SLHT ar 30 7 . 74 4210.09 39.37 5.850 3.470 Screen Bakerweld Excluder 2000( 1 Joint ( 4" 11# P -110 SLHT 73 4249.46 2.18 4.520 3.250 Seal Bore MZ System 80 -32 4" 11# SLHT Box x 4-1/2" Left Hand Square Thread Pir {r 2a 72 4251.64 3.48 6.000 3.610 BC -1L Packer 7OB6.4o Left Hand square Thread Box x Stub ACME Pin 71 4255.12 2.09 5.000 3.250 Seal Bore MZ System 80-32 Stub ACME Pin x 4-1/2" 13.5# SLHT Pir M 70 4257.21 3.77 4.540 3.960 Upper EXT. MZ System 80-32 4-1/2" 13.58 P -110 SLHT 69 4260.98 4.01 5.240 4.000 Frac EXT. MZ System 80-32 4-1/2" 13.5# P -110 SLHT r i -. 1 n 68 4264.99 2.40 4.990 3.250 Seal Bore MZ System 80-32 4-1/T 13.58 SLHT 3p 2s 67 4267.39 5.09 4.530 3.960 Lower EXT. MZ System 80-32 4-1/2" 13.5# P -110 SLHT 66 4272.48 2.82 4.500 3.250 Seal Bore MZ System 80 -32 4-1/2" 13.58 SLHT k' 2a 65 4275.30 0.59 5.000 3.480 X - Over 4 - 1 /2" 13.5# SLHT Box x 4" 114 SLHT Pin 22 64 4275.89 37.53 4.010 3.450 Blank Pipe 4" 11# P -110 SLHT 63 4313.42 78.68 5.850 3.740 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT 21 62 4392.10 118.16 5.850 3.500 Screen Bakerweld 10 Ga.( 3 Joints ( 4" 11# P -110 SLHT • l" 20 61 4510.26 137.85 5.850 3.740 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT u Ant 19 60 4648.11 2.18 4.520 3.250 Seal Bore MZ System 80-32 4" 11# SLHT Box x 4-1/2" Left Hand Square Thread Pir. I 59 4650.29 3.48 6.000 3.625 SC-11. Packer 7086 -40 Left Hand Square Thread Box x Stub ACME Pin 1- 58 4653.77 2.09 5.000 3.250 Seal Bore MZ System 80-32 Stub ACME Pin x 4-1/2" 13.5# SLHT Pir 16 57 4655.86 3.77 4.530 4.010 Upper EXT. MZ System 80 -32 4-1/2" 13.5# P -110 SLHT • e 15 56 4659.63 4.01 5.240 4.020 Frac EXT. MZ System 80 -32 4 -1 /2" 13.5# P -110 SLHT 55 4663.64 2.40 5.020 3.250 Seal Bore MZ System 80-32 4-1 /2" 13.5# SLHT o r' All. t is 54 4666.04 5.08 4.530 3.930 Lower EXT. MZ System 80 -32 4-1/2" 13.5# P -110 SLHT 10 53 4671.12 2.81 4.520 3.250 Seal Bore MZ System 80-32 4-1/2" 13.5# SLHT • Ma 11 52 4673.93 0.58 5.000 3.460 X -Over 4-1/2" 13.5# SLHT Box x 4" 11# SLHT Pin €1 51 4674.51 12.66 4.010 3.450 Blank Pipe 4" 11# P -110 SLHT ✓ _. 50 4687.17 59.17 5.850 3.740 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT -= lo 49 4746.34 59.11 5.850 3.500 Screen Bakerweld 10 Ga.( 2 Joints ( 4" 11# P-110 SLHT 1 48 4805.45 98.48 5.850 3.740 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT 47 4903.93 39.43 5.850 3.500 Screen Bakerweld 10 Ga.( 1 Joint (4" 11# P -110 SLHT a 9 46 4943.36 98.34 5.850 3.740 Screen Bakerweld Excluder 2000( 3 Joints ( 4" 11# P -110 SLHT j °. 45 5041.70 39.48 5.850 3.500 Screen Bakerweld 10 Ga.( 1 Joint ( 4" 11# P -110 SLHT a .� 44 5081.18 58.87 5.850 3.740 Screen Bakerweld Excluder 2000( Joints ( 4" 11# P -110 SLHT ' A ' ° 43 5140.05 0.96 4.990 3.270 Snaplatch 82 -40 S-22 4" 11# SLHT Box ■ 6 II 5141.01 2.98 3.980 3.260 Seal Units 82-40 S-22 9011 Nitrile Stub ACME „ : i 5 HH 5143.99 5.00 3.980 3.250 Spacer Sub 82 -40 Stub ACME GG 5148.99 0.50 3.980 3.260 Half Mule Shoe 82 -40 Stub ACME 1 t : a 5149.49 End Of Assembly • • 99 Equipment & Services Location: Sales Location: +^" Lafayette, La. - Phone # 337 - 593 -270C Baker Oil Tools r. 9s District Manager: Steve Zuklic 1010 Rankin Rd. BAKER Baker Oil Tools 97 Ops. Coordinators:Travis Treadway /Fred Gary Houston, TX. 77073 HUGHES 713-625-6800 ( 9 X17 w7 air' '' sa Operator: Phone # BHP BHT Max. Dev. Zone Dev. Sand Size Page: 1 € CONOCO 0 0 30 30 0 991 Company Representative: Phone # Type Of Screen Well Type Date: max 4-," a9 BRIAN BUCK Excluder 2000 / Bakerweld 10Ga. / Bakerweld 12 Ga. GAS ,i sa Field: Well # Perforations Completion Fluid 1 8 ' BELUGA 243 -34 3912' - 4241' , 4228' - 4640' , 4696' - 5129' 0 ff 6, State: Lease Salesman Phone # Job Number - r E AK BELUGA 0 0 V. sr Loading Docks: Phone # Size ID. WT. Grade Thread O8K CASING 7" 6.276" 26# L-80 BUTT-MOD ° Rig Name: Phone # Liner ® NABORS 129 Liner 79 Prepared By: Phone # WRKSTG 4" 3.340" 16.08# S-135 HT -38 BUDDY ARCENEAUX 337 - 593 -2700 WRKSTG rll -Y so Drawing Rev. Date: Revision # TUBING - TUBING 77 N Depth Len OD ID Description s CONTINUED ON NEXT PAGE 72 1 ei 7 0' 42 5141.01 4.20 6.000 4.000 SC -2 Packer 70B-40 Nitrite 4Ir 4 gg 41 5145.21 11.74 4.900 4.900 Millout EXT. 5 -1/2" 23# L-8O SLHT Pin Up X 5 1/2" Butress Thrd Pin Down a, °° 40 5156.95 4.06 4.900 4.900 Millout EXT. 5-1/T 23# L-80 Butress Box X 5 1/2" SLHT Pin 39 5161.01 1.34 5.920 3.270 Snaplatch 82 -40 S-36 5-1 /2" 23 #SLHT Box 69 FF 5162.35 0.82 3.980 3.270 Seal Units 82 -40 90H Stub ACME Nitrile EE 5163.17 5.00 3.980 3.270 Spacer Sub 82 -40 Stub ACME Box x Pin DD 5168.17 3.90 3.980 3.270 Seal Units 82 -40 90H Stub ACME Nitrite 63 CC 5172.07 0.51 3.980 2.440 BTM Sub 82 -40 2 -7/8" 6.4# Hyd. 511 Pin Down BB 5172.58 8.04 2.890 2.370 Space Out Pups 2 -7/8" 6.4# L -8 Hyd. 511 ....= ie 62 AA 5180.62 326.66 2.890 2.370 Tubing 2 -7/8" 6.48 L -80 Hyd. 511 -- _ Z 5507.28 3.93 3.160 2.313 SWAM HZ Profile 2-7/8" 6.4# Hyd. 511 r4;,3 ; or Y 5511.21 1.38 3.220 2.380 Locator Seal Assembly 80 -32 S-22 90H 2 -7/8" 6.48 Hyd. 511 Boo -.; 6 , 6 X 5512.59 10.77 3.220 2.380 Seal Units 80 -32 S -22 90H Stub ACME s9 W 5523.36 0.47 3.210 2.380 BTM Sub 80-32 S-22 2 -7/8" 6.48 Hyd. 511 Pin Down . sa r se V 5523.83 196.12 2.890 2.370 Tubing 2 -7/8" 6.4# L -80 Hyd. 511 1M N U 5719.95 3.93 2.890 2.370 SLCMUBRProftie 2-7/8" 6.4 #Hyd 511 $ sa T 5723.88 1.38 3.160 2.313 Locator Seal Assembly 80 -32 S-22 90H 2 -7/8" 6.48 Hyd. 511 Boo - '' gi S 5725.26 10.78 3.220 2.380 Seal Units 80 -32 S -22 90H Stub ACME or R 5736.04 0.47 3.220 2.380 BTM Sub 80 -32 S-22 2 -7/8" 6.4# Hyd. 511 Pin Down -y. Q 5736.51 196.05 3.210 2.380 Tubing 2 -7/8" 6.4# L-80 Hyd. 511 P 5932.56 3.93 2.890 2.370 SLCMUBRProfile 2-7/8" 6.411 Hyd 511 O 5936.49 1.38 3.160 2.313 Locator Seal Assembly 80-32 S-22 9011 2 -7/8" 6.4# Hyd. 511 13oo - c - 49 N 5937.87 10.78 3.220 2.390 Seal Units 80 -32 S -22 9011 Stub ACME - _ M 5948.65 0.47 3.220 2.380 BTM Sub 80-32 S-22 2 -7/8" 6.4# Hyd. 511 Pin Down 1 ' e t 88 L 5949.12 25.98 3.210 2.380 Space Out Pups 2 -7/8" 6.4# L -8 Hyd. 511 K 5975.10 326.42 2.890 2.370 Tubing 2 -7/8" 6.4# L -80 Hyd. 511 47 J 6301.52 3.93 2.890 2.370 SLCMUBRProflle 2 -7/8" 6.48 Hyd 511 I 6305.45 28.04 3.160 2.313 Space Out Pups 2 -7/8" 6.4# L -8 Hyd. 511 s ■4,r+ 46 H 6333.49 32.71 2.890 2.370 Tubing 2 -7/8" 6.4# L -80 Hyd. 511 C G 6366.20 1.37 2.890 2.370 Locator Seal Assembly 80 -32 S-22 90H 2 -7/8" 6.4# Hyd. 511 Boo F 6367.57 10.77 3.220 2.390 Seal Units 80 -32 S -22 9011 Stub ACME s E 6378.34 0.47 3.220 2.390 BTM Sub 80-32 S -22 2 -7/8" 6.4# Hyd. 511 Pin Down � D 6378.81 3.86 3.210 2.380 Half Mule Shoe 2 -7/8" 6.4# L-80 Hyd. 511 Box "`'�= 99 6382.67 End Of Assembly I - 42 1 41 38 5162.35 3.78 6.000 4.000 SC -2 Packer 70B-40 Nitrite 1 40 37 5166.13 3.60 5.780 4.800 Frac EXT. 80 -40 CK -250 - . 3o. 36 5169.73 2.48 5.550 4.000 Seal Bore Receptacle 80 -40 CK -25C • 1 28 35 5172.21 9.14 5.000 4.280 Lower EXT. 80-40 CK -250 r „ 34 5181.35 3.33 5.540 3.500 Single Indicating Coupling 80-40 CK -25f 00 ,14 as 33 5184.68 0.65 5.030 4.280 EXT. Sub 80 -40 CK -250 c. • is i$ 32 5185.33 3.24 5.540 3.500 Double Indicating Coupling 80-40 CK -250 2 31 5188.57 5.33 5.000 4.280 EXT. Sub 80-40 CK -250 i :3111 30 5193.90 2.67 5.600 3.320 Knock Out Isolation Valve C -2 Isolation Sleeve 5" 18# SLHT 8 29 5196.57 1.73 5.610 3.320 Knock Out Isolation Valve C -2 5" 18# SLHT E 28 5198.30 3.31 5.560 4.870 5" Shear Out Safety Jt GPR 24 5 "SLHT Box X 4" SLHT Pin M 27 27 5201.61 85.94 4.010 3.450 Blank Pipe 4" 11# P -110 SLHT Box x Pin 26 5287.55 216.79 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLHT 25 5504.34 0.89 4.520 3.420 X -Over 4" 11# SLHT Box x 4-1/2" 13.5# SLHT Pin {.r �:x - 26 24 5505.23 10.58 4.520 3.830 Blank Pipe 4-1/2" 13.58P-110 SLHT 23 5515.81 0.58 4.990 3.420 X -Over 4-1/2" 13.5# SLHT Box x 4" SLHT Pin OS 22 5516.39 2.72 4.480 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT 3.25" Bore .. F r 2e 21 5519.11 197.28 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLHT 22 20 5716.39 0.89 4.490 3.420 X -Over 4" 11# SLHT Box x 4 -1/2" 13.5# SLHT Pin �,�,� 19 5717.28 10.55 4.520 3.840 Blank Pipe 4-1/2" 13.5# P -110 SLHT . v 18 5727.83 0. 58 5.000 3.450 X -Over 4-1/2" 13.5# SLHT Box x 4" SLHT Pin - ;: 20 17 5728.41 2.73 4.480 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT 3.25" Bore r_ 1 19 16 5731.14 196.78 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLHT 15 5927.92 0.89 4.520 3.420 X -Over 4" 11# SLHT Box x 4-1/2" 13.5# SLHT Pin yy 14 5928.81 10.55 4.530 3.860 Skulk Pipe 4-1/2" 13.54P-110 SLHT • r i tS 5 E 16 13 5939.36 0.58 4.990 3.420 X -Over 4 -1/2" 13.5# SLHT Box x 4" SLHT Pin . i s 12 5939.94 2.73 4.480 3.250 Seal Bore Receptacle 4" 11# P -110 SLHT 3.25" Bore 1i 5942.67 118.29 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLID , i 3 1 6060.96 157.75 5.850 3.500 Screen Bakerweld 10 Ga. 4" 11# P -110 SLHT 2 9 6218.71 79.06 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLHT s A i i 8 ■6 0.89 4.490 3.450 X -Over 4" 11 # SLHT Box x 4 -1 /2" 13.5# SLHT Pin • : 7 62 98.66 10.55 4.510 3.900 Blank Pipe 4-1/2" 13.5# P -110 31 6 6309 0.57 4.980 3.430 13.5# SLHT Box x 4" SLHT Pin - so 5 6309.78 59.26 5.850 3.470 Screen Bakerweld Excluder 2000 4" 11# P -110 SLHT 4 6369.04 0.96 4.990 3.250 Saaplatch 82.40 11-22B 4" 11# SLHT Box " +� C 6370.00 2.64 3.980 3.250 Seal Units 82 -40 90H Stub ACME Nitrile 1 9 B 6372.64 5.00 3.980 3.250 Spacer Sub 82 -40 Stub ACME Box x Pin e A 6377.64 0.50 3.980 3.250 Half Mule Shoe 82 -40 Stub ACME Box 6378.14 End Of Assembly b 6 3 6370.00 1.98 5.850 4.000 Sump Packer Model FS Sim 85-40 „ p s 2 6371.98 0.84 5.850 4.000 Bottom Guide 85-40 5-1/2" 23# SLHT Box 1 6372.82 19.71 5.540 4.930 Mule Shoe 5-1/2" 23# L -80 SLHT Pin x Mule Shoe v - a = 3 6392.53 End Of Assembly j- 2 • Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 05, 2008 9:20 AM To: 'Ennis, J J' Cc: Allsup- Drake, Sharon K Subject: Oral Approval BRU 243 -34 (208 -079) -- (308 -395) Jim, This confirms our conversation of a few minutes ago. Commissioner Seamount has given his oral approval for the sundry request for this well. Call or message with any questions. Tom Maunder, PE AOGCC 11/5/2008 RE: BRU 243 -34 (PTD #208 -o • Page 1 of 1 Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis @conocophillips.com] Sent: Tuesday, November 04, 2008 3:26 PM To: Maunder, Thomas E (DOA) Subject: RE: BRU 243 -34 (PTD #208 -079) Tom, As discussed, this email requests verbal approval for the 403 which was submitted yesterday so that we can begin operations tomorrow. The equipment is currently being spotted on location. Thanks for your help. Jim Ennis blennis@conocophillips.com (907)265 -1544 (W) (907)632 -7281 (C) From: Ennis, J 3 Sent: Monday, November 03, 2008 1:03 PM To: 'Maunder, Thomas E (DOA)' Cc: Allsup- Drake, Sharon K Subject: BRU 243 -34 (PTD #208 -079) Tom, Sharon is bringing the paper copy over this afternoon but since this has a short fuse I thought I'd give you a preview. « File: BRU 243 -34 CT mill and acid procedure 11- 03- 08.pdf» Jim Ennis i.j.ennis@conocophillips.com (907)265 -1544 (W) (907)632 -7281 (C) 11/4/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Johnson, Vernon T (Halliburton Energy Services) [Vern. Johnson @contractor.conocophillips.com] Sent: Monday, November 03, 2008 1:16 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip Subject: RE: BRU 243 -34 (208 -079) Attachments: Nabors 129 7-4 -8 BOP test.pdf Tom- the best email address for me is vern. johnson @contractor.conocophillips.com - they both lead to the same location, but the other address will stop working in a month or so. I think ConocoPhillips made the change so that there was an obvious difference between contractors and company employees. As for your other questions; 1) the storm packer was not pressure tested, but it was not set for well control or pressure reasons, it was set to save tripping out of the hole with the rest of the drillstring while BOPs were tested. 2) the witness of the test waiver was not recorded on the daily report, as it typically is, we will add that to our reporting database. The BOP test report (attached) indicates that the test witness was waived on July 3. Let me know if you have any other questions. Vern From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, November 03, 2008 10:31 AM To: Johnson, Vernon T (Halliburton Energy Services); Johnson, Vernon T ( Halliburton Energy Services) Cc: Alvord, Chip Subject: BRU 243 -34 (208 -079) Vern, First question, which eddress is the correct to use? I am reviewing the completion report for this well and have some questions ... 1. When the storm packer was set to test BOP on July 4, was a pressure test conducted on the storm packer? 2. There is no information in the test details regarding which Inspector witnessed or waived the test. Such information should be included in the operations summary when BOPs are tested. Please provide this information. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 11/3/2008 '' STATE OF ALASKA {: 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND , LOG ' - *2. la. Well Status: Oil ❑ Gas U • Plugged ❑ Abandoned ❑ Suspended ❑ lb. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: )' A Service ❑ Stratigraphic Test CI 2. Operator Name: 5. Date Comp., Susp., L$ R'i' 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: July2008 208 - 079 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 31, 2008 • 50 283 - 20124 - 00 ' 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1147' FSL, 957' FEL, Sec. 34, T13N, R1OW, SM June 11, 2008 • BRU 243 - 34 • Top of Productive Horizon: 8. KB (ft above MSL): 93.5' RKB . 15. Field /Pool(s): 2087' FSL, 1493' FEL, Sec. 34, T13N, R1OW, SM Ground (ft MSL): 77' AMSL Beluga River Field Total Depth: 9. Plug Back Depth (MD + TVD P 9 TVD): P ( ) 2062' FSL, 1480' FEL, Sec. 34, T13N, R1OW, SM 6552' MD / 6328' TVD Sterling - Beluga Gas Pool 4b. Location of Well (State Base Plane Coordinates): NAD 27 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 316913 • y 2621038 • Zone 4 • 7005' MD / 6781' TVD • ADL A029656, A029657 TPI: x - 316391 y- 2621986 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 316403 ' y- 2621961 Zone 4 1921' MD / 1843' TVD NA 18. Directional Survey: Yes Q No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (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 TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154.2# X -65 18' 78.5' 18' 78.5' na driven 9 -5/8" 40# L -80 18' 3027' 18' 2827' 12.25" 793 sx Class G 10.5 ppg 7" 26# L -80 18' 6994' 18' 6770' 8.75" 250 sx Class G, 70 sx Class G 10.5 ppg 23. Open to production or injection? Yes 0 No ❑ If Yes, list each 24. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 3812' 3810' see attachment 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED frac from 6324' -6344' 61700# 20/40 carbolite frac from 5814' -5904' 72500# 20/40 carbolite frac from 5468' -5498' 78240# 20/40 carbolite frac from 5402' -5428' 89574# 20/40 Econoprop 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 23, 2008 Gas Production Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 8/28/2008 24 hours Test Period - -> 0 6307 1225 not available na Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) press. 830 psi 905 24 -Hour Rate -> - 6307 1225 not available 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No is Sidewall Cores Acquired? Yes 0 No ❑ If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. p., , ,,,,,,, 4)OMPL O r DATE r TO BE SENT UNDER SEPARATE COVER tlfr" ED 4 . (14., Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE SIDE I'm ORIGINAL tibUiVIS ig NN � (3 3 2308 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? Yes EI 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 3255' 3044' Sterling B 3455' 3236' Sterling C 3617' 3395' Beluga D 3768' 3545' Beluga E 4025' 3801' Beluga F 4387' 4009' Beluga G 4924' 4700' Beluga H 5307' 5083' Beluga I 6050' 5826' Beluga I Base 7005' 6781' N/A Formation at total depth: Beluga 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Perforation Intervals 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: V nson @ 265 - 6081 Printed Name / Ch • Alvord Title: GKA Drilling Lead �j' Signature °C Phone C' L . 4 Date lath► Sharon Alisup -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 • • ConocoPhiliips Time Log & Summary W&Mew Web Report!ng Report Well Name: BRU 243 -34 Rig Name: NABORS 129 Job Type: DRILLING ORIGINAL Rig Accept: 5/26/2008 12:00:00 AM Rig Release: 7/28/2008 4:00:00 PM _.a( \:4 a \ "�.�'z�.41 " •..t11 Phi 0:2;1.. ,..,.� a s 05/16/2008 24 hr Summary Haul gravel and level location 00:00 00:00 24.00 MIRU MOVE MOB P Off rig from barge #1. Weaver Broths. trucks and rig equipment. Freeman hauling gravel to location and leveling pad. Offload barge #2. Rig equipment. 05/17/2008 Off load 2 barges. Lay herculite and mats on location 00:00 00:00 24.00 MIRU MOVE MOB P Off load and stage 2 barges of rig equipment. Finish level location. Lay 1 layer felt. Layout 150' x' 100' liner. Lay rig mats. Spot sub base on _ mats. 05/18/2008 Off load 2 barges. Rig up. 00:00 00:00 24.00 MIRU MOVE MOB P Off load and stage 2 barge loads drilling equipment. Spot sub. Set water tank and doghouse. Set drawworks with crane. Set #1 mud pump. Derrick to location. 05/19/2008 Off laod 2 barges. Rig up. 00:00 00:00 24.00 MIRU MOVE MOB P Off load and stage 2 barge loads rig equipment. All rig equipment is at Beluga. Assemble derrick. Pin derrick to sub and set on derrick stand. Spot #2 mud pump and #2 pit section. Cut off 20" conductor and install landing ring.. RKB to top of landing ring = 21.23' RKB to GL = 16.52'. Total of 8 barges to date. 05/20/2008 Off load 2 barges. Rig up. Raise and pin derrick. 00:00 12:00 12.00 MIRU MOVE MOB P Off load and stage 2 barges Swaco and misc drilling equipment. Rig up derrick. String up blocks. Set generator and CanRig modlules. All modules in place. Rig up mud lines, hydraulics and electrical. Fill water tank. Raise and pin derrick. Page 1 of 39 Time Logs \ \ \\ \\ Date F r o m T o Dur S. De „E . 4 th , Phi.:. .Stittortde T\ onement 12:00 00:00 12.00 MIRU MOVE MOB P Off load and stage 2 barges. Rig up topdrive grasshopper. Set degasser. Rig up stand pipe manifold and deadman sensors. Set centrifuge. Set flowline. Circulate water through system. Hand bridle line. Started laying out injection equipment at BRWD. HELD PRE -SPUD MEETING WITH AVAILABLE CONTRACTORS, SUPERVISORS AND CPAI MANAGEMENT. 05/21/2008 Off load 2 barges. Continue rigging up rig equipment. Set Centrifuge. Held pre -Spud meeting with all crews and available service personnel 00:00 00:00 24.00 MIRU MOVE MOB P Offloaded 2 barges. Held Pre -spud meeting with all available contractor personnel and CPAI management. Set centrifuge 05/22/2008 Off load 2 barges. Berm around 1/2 of rig. Pick up Top Drive and torque tube. Pick up floor equipment. Set Vetco -Gray starting head. Set toolpusher's shack and MI mud lab. Set Top Drive motor exhaust. 00:00 00:00 24.00 MIRU MOVE MOB P Offload 2 barges. Pick up Top drive. Set Vetco -Gray diverter adapter. Tested seal to 300 psi. Set roof on mud pits. 05/23/2008 Off load one barge. Finish nippling up diverter and continue rigging up. 00:00 00:00 24.00 MIRU MOVE MOB P Off load one barge in the morning. Unable to load and /or off load the barge due to high winds and seas in the afternoon. Finish nippling up diverter system and hook up accumulater. Continue rigging up. 05/24/2008 Off loaded two barges. Set co. man's trailer. Performed rig acceptance survey. Moved diverter line. Finished berming up around rig. 00:00 00:00 24.00 MIRU MOVE MOB P Off loaded two barges. Continued rigging up. Moved diverter line. Set co. man's office trailer. Set cuttings bins. Finished berming around rig. Performed Rig Pre - acceptance Assessment and started working on deficiencies. 05/25/2008 Hooking up communications at rig site. Continued working on items identified in rig acceptance assessment. Filled suction pit with water and circulated water through hoppers and guns lines with charge pumps. Began setting injection equipment at BRWD. 00:00 00:00 24.00 MIRU MOVE RURD P Continue rigging up and working on rig acceptance assessment items. Laid herculit and started spotting Swaco injection equipment at BRWD. 05/26/2008 Continuing to hook up communications at rig site. Continued working on items identified in rig acceptance assessment. Function tested diverter; witnessed by Chuck Scheve, AOGCC. Circulated water through mud system with mud pumps. Page 2of39 • • t \' \, � \\ 'rite L ,:\. Vim` \.. ��V\ at, `\`N\' : irom . TO Dur ` S. DePth E2Oleth Phase Cede Subc e, T a nt . . 00:00 00:00 24.00 MIRU MOVE RURD P Continued repairing deficiencies found during rig acceptance assessment. Function tested diverter which was witnessed by, Chuck Scheve, AOGCC Circulated water through mud system with mud pumps. Continued installing communication equipment. Installed PVT monitoring equipment. 05/27/2008 Rigged up floor. Loaded pipe racks with 75 joints or 5" drill pipe and 30 joints of 5" HWDP and tallied same. Calibrated Epoch block height and PVT sensors. Mixed 115 bbls of spud mud. Made up 17" mill and 3 joints of HWDP and cleaned out conductor from 25' to 79.87' with no problems. Circulated hole clean and pulled out of the hole. Laid down mill. 00:00 12:00 12.00 80 80 MIRU DRILL OTHR P ACCEPTED RIG AT 00:00 HOURS 5 -27 -2008. Rig up pipe spinners and function test. Check lubricant levels in all equipment. Test hole fill pump. Load 75 joints of 5" DP on pipe racks and tally. Load 30 joints of 5" HWDP on pipe racks and tally. Pick up one joint of 5" drill pipe and tag fill in conductor at 25' MD. Calibrate Epoch block height. Spot directional tools. Fill mud pits with 115 bbls water. 12:00 19:00 7.00 80 80 MIRU DRILL OTHR P Calibrate PVT sensors and install shaker screens 19:00 21:00 2.00 80 80 MIRU DRILL CIRC P Mix 110 bbls of spud mud 21:00 00:00 3.00 80 MIRU DRILL MILL P Make up mill, crossovers and 3 joints of HWDP Clean out conductor from 25' to 79.87'. Had one small bobble at approximatley 76' but milled through it with no problems. Circulated until shakers were clean and pulled out of the hole. 05/28/2008 Finished laying down cleanout bha tools. Held pre -job safety meeting. Picked up 75 joints of 5" drill pipe and stood back in the derrick. Picked up 17 joints of 5" HWDP and set of jars and stood back in derrick. Held diverter drill. Adjusted kelly hose. Picked up motor and stabilizer. Mixing mud. 00:00 01:00 1.00 80 80 MIRU DRILL PULD P Finish laying down mill and crossovers 01:00 03:00 2.00 80 80 MIRU RIGMNT SVRG P Service rig and adjust kelly hose 03:00 03:30 0.50 80 80 MIRU DRILL SFTY P Pre -job safety meeting on picking up drill pipe 03:30 07:30 4.00 80 80 MIRU DRILL PULD P Pick up 75 joints (25 stands) of 5" drill pipe and stand back in derrick 07:30 09:30 2.00 80 80 MIRU DRILL PULD P Pick up 17 joints of 5" HWDP and drilling jars (6 stands) and stand back in derrick 09:30 15:00 5.50 80 80 MIRU DRILL OTHR P Lay out herculite for additional tanks and move discharge for centrifuge. Mix spud mud. Perform diverter drill 15:00 00:00 9.00 80 80 MIRU DRILL PULD P Pick up 3 8" non -mag flex collars and stand back in derrick. Pre to pick up mud motor and stabilizer. Continue mixing mud. Page3of39 • • Time Logs: � ti Date From . • : Qur:',,. „ . nth E. DetetVPheierieee&Ve Subcode T '': Comment. 05/29/2008 24 hr Su ry mma Continue organizing rig and location. Performing necessary preventive maintenance on rig equipment. 00:00 12:00 12.00 80 80 SURFA( DRILL WOEQ P Pick up mud motor and make up bit and stabilizer. Adjust hydraulic hose in top drive service loop. Change oil in #1 generator. Clean and organize parts conex. Install lights on rig floor. Move subs to cat walk. Remove shaker motor. 12:00 17:00 5.00 80 80 SURFA( DRILL WOEQ P Continue building mud volume. Install new shaker motor. 17:00 19:00 2.00 80 80 SURFA( DRILL WOEQ P Change oil and filters in drawworks motor. Continue mixing mud 19:00 00:00 5.00 80 80 SURFA( DRILL WOEQ P Continue cleaning and organizing rig and location 05/30/2008 General housekeeping and maintenance activities while waiting for barge 00:00 12:00 12.00 80 80 SURFA( DRILL WOEQ P Berm around oily waste container. Change oil in welding machine. Clean and organize topdrive parts house. General housekeeping activities 12:00 00:00 12.00 80 80 SURFA( DRILL WOEQ P General housekeeping activities on rig and location 05/31/2008 General housekeeping and maintenance while waiting for injection facility to become functional. Hold prejob safety meeting and inspect mud circulating system. Spud well at 13:00 hours 05/31/2008._ Drill from 79.87' • to 231'. Circulate and condition mud. Trip out of the hole to the mud motor. Make up MWD tools and surface test without success. Trouble shoot MWD tools. Change probes without success. Laydown MWD collars. 00:00 12:00 12.00 80 80 SURFA( DRILL WOEQ P Familiarize new crew with rig. Inspect rigging and inventory parts. Troubleshoot low lube pressure alarm on top drive. Builld mount for test manifold. Rewrite startup /shutdown procedure for topdrive power pack. Inspect derrick and grease crown 12:00 12:30 0.50 80 80 SURFA( DRILL SFTY P Pre -job safety meeting on spudding the well and diverter procedures. 12:30 13:30 1.00 80 80 SURFA( DRILL OTHR P Check surface equipment. Laydown safety valve and pick up one stand of HWDP 13:30 15:30 2.00 80 231 SURFA( DRILL DDRL P Drill from 79.87' to 231' 15:30 16:00 0.50 231 231 SURFA( DRILL CIRC P Circulate and condition mud. Pulled tight at 216' (30K over). Circulate hole clean. 16:00 16:30 0.50 231 231 SURFA( DRILL TRIP P Pull out of the hole. 16:30 19:00 2.50 231 231 SURFA( DRILL PULD P Pick up MWD tools and scribe motor. Pick up DM and RLL tool. 19:00 22:30 3.50 231 231 SURFA( DRILL PULD T Test MWD without success. Break tools down and inspect probe. Retest without success. Change out probes. Make back up and retest without success. 22:30 00:00 1.50 231 231 SURFA( DRILL PULD T Lay down MWD collars. Page 4 of 39 • • Time :Logs \, xo 4 N1 Date From To Dui 5. Depth E. Depth Phase Cade Subcode . T> ',Cqm A ' ` � = 06/01/2008 24 h S umma ry Finished picking up MWD tools and making up BHA. Drill from 231' to 1380'. Had 30k drag on connections. Circulate and condition mud. Backream from 1380' to 1091'. Trip from 1091' to 270'. Trip back into 1091' and wash and ream from 1091' to 1380'. No fill on bottom. Directionally drill from 1380' to 1807' 00:00 03:30 3.50 231 231 SURFA( DRILL PULD T Make up BHA and take check shot survey at 207' MD. 03:30 06:00 2.50 231 450 SURFA( DRILL DDRL P Directionally drill from 231' MD to 450' MD. Pumping @ 450 gpm @ 480 psi. S/O 35K, P/U 35K, Rot 35K. WOB 5K 75 rpm with 1200 ft -Ibs torque • 06:00 12:00 6.00 450 1,156 SURFA( DRILL DDRL P Directionally drill from 450' MD to 1156' MD. Pumping @ 500 gpm @ 1300 psi. S/O 56K , P/U 58K, Rot 56K. WOB 10K 75 rpm with 3200 ft-Ibs torque 12:00 14:30 2.50 1,156 1,380 SURFA( DRILL DDRL P Directionally drill from 1156' MD to 1380' MD. Pumping @ 550 gpm @ 980 psi. P/U 68K S/O 58K ROT 58k 14:30 15:00 0.50 1,380 1,380 SURFA( DRILL CIRC P Circulate and condition mud 15:00 16:00 1.00 1,380 1,380 SURFA( DRILL REAM P Backream out of the hole from 1347' to 1091' 16:00 17:00 1.00 1,380 1,380 SURFA( DRILL WPRT P Trip out of the hole from 1091' to 270' 17:00 18:30 1.50 1,380 1,380 SURFA( DRILL WPRT P Trip in the hole from 270' to 1091' 18:30 19:00 0.50 1,380 1,380 SURFA( DRILL REAM P Wash and ream from 1091' to 1380'. No fill on bottom 19:00 00:00 5.00 1,380 1,807 SURFA( DRILL DDRL P Directionally drill from 1380' MD to 1807' MD. Pumping @ 550 gpm @ 1030 psi. P/U 68K S/O 58K ROT 58K 06/02/2008 Directionally drilled from 1807' MD to 3041' MD 2839.86' TVD. Circulate and condition mud. Wiper trip from 3041' to 806' MD (Top of HWDP). Worked through tight spot from 1520' to 1490'. Ran back in the hole and reamed from 2814' to 3041' (no fill). Circulate and condition mud. 00:00 12:00 12.00 1,807 2,915 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 1,807' MD to 2,915' MD 2,722' TVD. ART 6.16 hrs AST 7.09 hrs. Pumping 550 gpm @ 1750 psi. WOB 5 K RPM 80 P/U 76 K S/O 65 K ROT 69 K.TgonBtm6.5K off 4.5K. 30 minutes service top drive 12:00 14:30 2.50 2,915 3,041 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 2915' MD to 3041' MD 2839.86' TVD. ART 1.67 hrs, AST .52 hrs, P/U 88 k, S/O 78 K, 550 gpm 1875 psi, 80 rpm, WOB 5 K, 14:30 15:00 0.50 3,041 3,041 SURFA( DRILL CIRC P Circulate and condition mud at 530 gpm, 1700 psi. Torque off bottom 6k 15:00 16:00 1.00 3,041 3,041 SURFA( DRILL REAM P Backream from 3041' to 2814' 16:00 16:30 0.50 3,041 3,041 SURFA( DRILL WPRT P Trip out of the hole from 2814' to 2750'. Hole not taking the correct fill 16:30 17:00 0.50 3,041 3,041 SURFA( DRILL CIRC P CBU- Circulate and condition mud 17:00 18:30 1.50 3,041 3,041 SURFA( DRILL REAM P Back ream from 2814' to 2239. Monitor well- static. Line up trip tank Page 5 of 30 1 Date f Tt Dur ." � � Code $U � `' C om a nt \� 18:30 21:00 2.50 3,041 3,041 SURFA( DRILL WPRT P Trip out of the hole from 2239' to Tin* 806' Work through tight spot from 1520' to 1490' several times. 21:00 22:00 1.00 3,041 3,041 SURFA( DRILL WPRT P Trip in hole from 806' to 1910' and take check shot survey. 22:00 23:00 1.00 3,041 3,041 SURFA( DRILL WPRT P Continue tripping in the hole from 1910' to 2814' 23:00 23:30 0.50 3,041 3,041 SURFA( DRILL REAM P Precautionary ream from 2814' to 3041' no fill 23:30 00:00 0.50 3,041 SURFA( DRILL CIRC P Circulate and condition mud 06/03/2008 Dropped survey and POOH. Rigged up and ran 9 5/8" casing to 3,026'. 0000 02:00 2.00 SURFA( DRILL CIRC P Circulate and Condition mud, drop multishot tool 02:00 03:00 1.00 SURFA( DRILL TRIP P Trip out to 2840 03:00 03:30 0.50 SURFA( DRILL CIRC P C & C mud, spot p ill , pump dry job. 03:30 06:00 2.50 SURFA( DRILL TRIP P Trip out to BHA 06:00 06:30 0.50 SURFA( DRILL SFTY P Pre job for laying down BHA 06:30 07:30 1.00 SURFA( DRILL PULD P Lay down flex collars, retrieve multishot tool 07:30 08:30 1.00 SURFA( DRILL PULD P Down load MWD tools 08:30 10:00 1.50 SURFA( DRILL PULD P Lay down rest of BHA 10:00 12:30 2.50 SURFA( CASING RNCS P Rig up and run 9 5/8" CS 12:30 13:00 0.50 SURFA( CASING SFTY P Held meeting with new crew and Weatherford. 13:00 17:30 4.50 SURFA( CASING RNCS P Run 37 joints CSG to 1548 17:30 18:30 1.00 SURFA( CASING CIRC P CBU 18:30 22:00 3.50 SURFA( CASING RNCS P Run casing to joint # 74 22:00 22:30 0.50 SURFA( CASING RNCS P Pick up landing joint 22:30 00:00 1.50 SURFA( CASING CIRC P Rig up to circulate and begin cleaning hole up for cement job 06/04/2008 Pumped 296 barrels class G cement. Rig down diverter, nipple up 11" Schaffer BOP stack. 00 01:00 1.00 SURFA( CEMEN "CIRC P C C 2 BU's, Prejob with BJ cementers Page6 • Date »lA• r.': t E q.t k _. rr ''' 11,1 ‘ 9, 6 ', a sw T :: r fit: 01:00 03:30 2.50 SURFA( CEMEN DISP P Rig pumped 30 Bbls. Biozan nut plug spacer and dropped bottom plug. Rig pumped 20 Bbls Mudclean 2. Tumed over to BJ pumped 2 Bbls water and tested lines to 2500 psi. Pumped 296 Bbls (793 Sx) of Type 1 cement mixed @ 12 PPG 5 BPM 250 psi. Observed nut plug on shkers at 296 Bbls. Dropped top plug with 4 Bbls water and turned over to rig. Displaced with 9.6 PPG mud @ 7 BPM. Bumped plug with 1100 psi. Floats held. 35 Bbls cement returned to surface. Lost 15 Bbls while pumping cement. CIP @ 0320 Hrs 6/4/08. rig calculations show 32% excess in the hole. 03:30 04:30 1.00 SURFA( CEMEN" RURD P Rig down cement head and lines 04:30 05:00 0.50 SURFA( CEMEN" SFTY P Pre job for nipple down of diverter system, and cement clean up in cellar and pits. 05:00 12:30 7.50 SURFA( WELCTL NUND P Nipple down diverter, remove diverter line, knife valve, flowline, riser, catwalk, place trolley in cellar,mechanic trouble shoot and fix breaks on top drive, clean pits. 12:30 13:30 1.00 SURFA( WELCTL SFTY P Rig meeting with Nabors rig Superintendent from Anc. 13:30 16:30 3.00 SURFA( WELCTL NUND P Rig up 4 ways onto hydril, remove from cellar, rig down Vetco surface adapter wellhead. 16:30 19:30 3.00 SURFA( WELCTI NUND P Nippled up Vetco well head and tested to 5000 psi. 19:30 00:00 4.50 SURFA( WELCTL NUND P Nipple up hydril, double gate, mud cross, single gate, set choke house berm in, make up choke hose, hammer up flange, first spool. 06/05/2008 Nippled up BOP's, tested 00:00 06:00 6.00 SURFA( WELCTL NUND P Install check valve, kill line, Turnbuckles, containment around choke house, spot spool, install catwalk/ beaver slide, super choke„ simops. cleaning pits. 06:00 06:30 0.50 SURFA( WELCTL SFTY P Job training, fall protection refresher. Prepare to enter cellar. 06:30 11:30 5.00 SURFA( WELCTI EQRP P Welder modified the cellar grating for production tree valves. Change top drive saver sub to 4" HT. Vetco installed 2 1/16" 5000# flanges on annulus vlaves. Install drop pan. 11:30 13:30 2.00 SURFA( WELCTL BOPE P Modify bell nipple. Make up test joint. Mech. trouble shoot super choke. Stick in, fill lines choke maifold, 13:30 14:00 0.50 SURFA( WELCTL EQRP T Trouble shoot test pump, repair electrical cable to pump. Page 7 of 39 • C7 ;:aa` - " To " Dur ' S. Depth E. Depth F'hese: " Code ' Subcode T . =C(irrJrliert # ", .:: '" 14:00 19:00 5.00 SURFA( WELCTL BOPE P Hydril flange leaking at mud cross connection. Rig up and tighten with hydraulic 'sweeny' wrench. service all manual valves on stack. 19:00 19:30 0.50 SURFA( RIGMNT SVRG P Serviced rig and Top drive. 19:30 00:00 4.50 SURFA( WELCTL BOPE P Sucessful test on all manuals on stack, HCR, annular, top rams inside and outside kill, choke manifold valves, 12,11,10,9,8,7,6,4,3. 06/06/2008 Finished the BOP test, layed down all 5" drill pipe, picked up 4" drill pipe. 00:00 06:00 6.00 SURFA( WELCTL BOPE P Test BOP'S,, Upper variable pipe rams, kill, choke #2, #5 , check valve, lower pipe rams, koomey accumulator test, blind ram test. 06:00 08:30 2.50 SURFA( WELCTL BOPE P Retest floor valve, dart valve, rig down test equipment 08:30 09:00 0.50 SURFA( WELCTL OTHR P Install wear bushing. 09:00 09:30 0.50 SURFA( DRILL SFTY P Change of job, pre job safety meeting. 09:30 12:00 2.50 SURFA( DRILL PULD P Lay down 5" HWDP, and jars from ; derrick. 12:00 15:30 3.50 SURFA( DRILL PULD P Lay down 5" drill pipe. 15:30 16:00 0.50 SURFA( DRILL SFTY P Change of job, prejob safety meeting. 16:00 16:30 0.50 SURFA( DRILL PULD P Change out handling tools to 4" , strap 4" HT drill pipe. 16:30 21:00 4.50 SURFA( DRILL PULD P Pick up 4" DP. 21:00 22:00 1.00 SURFA( DRILL TRIP P Stand back 2360 feet of 4 ". 22:00 00:00 2.00 SURFA( DRILL PULD P Pick up 4" DP to 1764 feet. 06/07/2008 Picked up the bottom hole assembly, tripped to the collar. Tested the casing to 3000psi for 30 mins. Drilled the collar, shoe track, shoe, 20 feet of new formation, performed LOT to 14.8ppg. EMW. 00:00 03:00 3.00 SURFA( DRILL PULD P Pick up the last 600 feet of 4" drill pipe. 03:00 03:30 0.50 SURFA( RIGMNT SVRG P Service top drive, breaks, swivel. 03:30 04:00 0.50 SURFA( DRILL SFTY P Prejob safety meeting for picking up the BHA. 04:00 08:00 4.00 SURFA( DRILL PULD P Pick up BHA. 08:00 12:00 4.00 SURFA( DRILL PULD T Communication problems with tool string. Unable to up load until the problem was isolated, (the sub base not being securely grounded.) 12:00 17:00 5.00 0 2,776 SURFA( DRILL TRIP P Trip in to 2776' MD. 17:00 18:00 1.00 2,776 2,946 SURFA( DRILL REAM P Ream down to float collar. 18:00 19:00 1.00 2,946 2,946 SURFA( DRILL CIRC P Circulate, rig up BJ to perform casing test. Hold safety meeting with BJ and rig crew. 19:00 20:00 1.00 2,946 2,946 SURFA( DRILL LOT P Pressure test casing to 3000 psi for, l 30 mins. Chart with BJ unit. Rig down test lines. Page 8 of 39 • • N S �� Logs t 3 \ . Dor r c Deoth ' Phi.:: code Sub T C. 20:00 23:00 3.00 2,946 3,041 SURFA( CEMEN DRLG P Drilling float collar @ 2947, cement, shoe @ 3027. 23:00 23:15 0.25 3,041 3,061 PROD1 DRILL DDRL P Drill 20 feet of new hole for LOT. 23:15 00:00 0.75 3,061 3,061 PROD1 DRILL LOT P Hold safety meeting with BJ for LOT, Perform LOT to 14.4ppg EMW._ After .9 bbls were pumped the formation began to take fluid. 790 psi Leak off pressure seen where the curve shifted. Pumped 2.9 BBIs after the LOP was seen. Shut in with 1000 psi. ISIP =970. 15 sec. SIP = 940, 30 sec SIP =930. Held for 10 mins. bleed off pressure was 790 psi. 06/08/2008 Rigged down from the LOT, drilled from 3061 to 4030. Short trip 10 stands. Drill ahead. 00:00 00:30 0.50 3,061 3,061 PROD1 DRILL LOT P Finished LOT and rigged down BJ. 00:30 01:30 1.00 3,061 3,061 PROD1 DRILL CIRC P Displaced mud system to 9.2 PPG FloPro. 01:30 12:00 10.50 3,061 3,741 PROD1 DRILL DDRL P Directionally drilled 8 3/4" hole from 3,061' MD to 3,741' MD 3,125' TVD. ART 4.41 hrs, AST 2.52 hrs, P/U 70 k, S/O 59 K, Rot 62 K. 550 gpm 2100 psi, 90 rpm, WOB 2 - 5 K, Torq on Btm 5,000 Off 4,000. ECD 9.95 PPG EMW. 12:00 18:00 6.00 3,741 4,030 PROD1 DRILL DDRL P Directionally drilled 8 3/4" hole from 3,741' MD to 4030' MD 3808' TVD. P/U 80 k, S/O 65 K, Rot 70 K. 550 gpm 2100 psi, 90 rpm, WOB 2 - 5 K, Torq on Btm 5,000 Off 4,000. ECD 9.78 PPG EMW. 18:00 18:30 0.50 4,030 4,030 PROD1 DRILL CIRC P Circulate and condition the wellbore with 550 gpm's, 100 rpm's. For a 10 stand short trip. 18:30 20:00 1.50 4,030 4,030 PROD1 DRILL WPRT P Trip out of hole from 4030' MD to 2976' MD. Pump out first two stands, and pulled on the elevators for the next 7 stands. Good hole conditions. Monitored well for 15 mins. No flow. 20:00 20:30 0.50 4,030 4,030 PROD1 DRILL WPRT P Trip back to bottom. Good hole conditions. 20:30 21:00 0.50 4,030 4,030 PROD1 DRILL CIRC P Circulate the hole clean, prior to drilling ahead. No gas from BU. 21:00 00:00 3.00 4,030 4,222 PROD1 DRILL DDRL P Directionally drilled from 4030' MD to 4222' MD. TVD= 4000'. Up Wt =80. Dwn Wt =67. Rot Wt =70. WOB= 2 to 6K. 100 rpm. TQ on 5,000 ft/Ibs. TQ off 4,000 ft/Ibs. 535 gpm's. 1900 psi off btm/ 2100 psi on btm. ECD= 9.75 ppg EMW. For Tour: 5.34 hrs drlg. 1.78 hrs slide. 3.56 hrs. rotate. Total for bit run: 12.27 hrs. ART =7.97 hrs. AST= 4.30. 06/09/2008 Drilled from 4,222 to 5,683 ' MD. Conducted 10 stand short trip from 5,035 up to 4,030' MD. The hole remains in good shape. Received 2,400 units of trip gas @ 5035' MD. Page9 • �= tEr rn To `E D eDttr. Phase • ; Code 8ubOo0 .. "T Comment 00:00 00:30 0.50 4,222 4,222 PROD1 DRILL OTHR P Service rig. Top drive, swivel, SPR's. 00:30 12:00 11.50 4,222 5,035 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 4,222' MD 3,998' TVD to 5,035' MD. 4,811' TVD. with 540 GPM, 100 RPM, 2 to 5,000 bit weight, 5 to 7,000 ft/Ibs TQ. P/U 88K, S/O 80K, Rot 82K. ECD =9.90 ppg EMW. Drlg Hrs. on tour, Rot. = 5.84hrs. , Slide = 1.55hrs. total = 7.39 hrs. Hours total for bit run= 19.66 hrs, Rot. = 13.81 hrs. , Slide = 5.85 hrs. 12:00 12:30 0.50 5,035 5,035 PROD1 DRILL OTHR P Service rig. Top drive, swivel, SPR's. 12:30 13:00 0.50 5,035 5,035 PROD1 DRILL CIRC P Circulate the hole clean for the second wiper trip. 13:00 14:30 1.50 5,035 5,035 PROD1 DRILL WPRT P Ream the first three stands, pull 7 more up to 4030' MD. No problems, good hole conditions, monitor well for 15 mins. No flow. 14:30 15:00 0.50 5,035 5,035 PROD1 DRILL WPRT P Trip back to bottom. No problems. 15:00 00:00 9.00 5,035 5,683 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 5,035' MD. 4,811' TVD to 5,683' MD 5476' TVD. with 520 GPM, 100 RPM, 2 to 5,000 bit weight, 5 to 7,000 ft/Ibs TQ. P/U 100K, S/O 78K, Rot 88K. ECD =10.05 PP9 EMW. Clean hole ECD from program = 9.81 ppg. DrIg Hrs. on tour, Rot. = 6.46 hrs. , Slide = 0 hrs. total = 6.46 hrs.Hours total for bit run= 26.13 hrs, Rot. = 20.30 hrs. , Slide = 5.85 hrs. 06/10/2008 Drilled from 5,683' MD to 6,662' MD. Conducted one 10 stand wiper trip. Weighted the mud system up to 9.6 ppg. Added one % lubricant (776) to the hole. No accidents, no spills. 00:00 00:30 0.50 5,683 5,683 PROD1 DRILL OTHR P Service top drive, grease swivel, blocks, obtain slow pump rates (SPR's) @ 5746' MD, 5520' TVD. MP#1 45/380 psi, 50/400 psi, MP#2 45/380psi, 50/395 psi. 00:30 06:00 5.50 5,683 6,030 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 5,683' MD 5,460' TVD to 6,030' MD. 5,806' TVD. with 530 GPM, 100 RPM, 2 to 5,000 bit weight, 5 to 7,000 ft/Ibs TQ. P/U 104K, S/O 84K, Rot 91K. ECD =9.90 ppg EMW. 06:00 06:30 0.50 6,030 6,030 PROD1 DRILL CIRC P Circulate and condition, 530 gpm's, 2600 psi. prejob for short trip. 06:30 08:00 1.50 6,030 6,030 PROD1 DRILL WPRT P Conducted our 3rd wiper trip, 10 stands out, back reaming the first three and then pulling on the elevators. Pulled from 6,030 to 4,988 MD. No hole drag. Max over pull seen 5k. 08:00 09:00 1.00 6,030 6,030 PROD1 DRILL WPRT P Check for flow, and ease back to bottom. 09:00 10:00 1.00 6,030 6,030 PROD1 DRILL CIRC P Circulated bottoms up. No gas from the short trip. No fill. Page 10ef3 Titre Logs FroniATo Qrar.4 : S. Depth E, Deritti ::Subcode TAl dent �. ... 10:00 12:00 2.00 6,030 6,157 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 6,030' MD 5,806' TVD to 6,157' MD. 5,933' TVD. with 530 GPM, 100 RPM, 2 to 5,000 bit weight, 5 to 7,000 ft/Ibs TQ. P/U 108K, S/O 84K, Rot 95K. ECD =9.90 ppg EMW. DrIg Hrs. on tour, Rot. = 5.33hrs. , no Slides on this tour. Hours total for bit run= 31.58 hrs, Rot. = 25.73 hrs. , Slide = 5.85 hrs. 12:00 12:30 0.50 6,157 6,157 PROD1 DRILL OTHR P Service top drive, grease swivel, blocks, obtain slow pump rates. 12:30 00:00 11.50 6,157 6,662 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 6,157' MD. 5,933' TVD to 6,662' MD. 6,438' TVD. with 500 GPM, 100 RPM, 2 to 8,000 bit weight, 5 to 8,000 ft/lbs TQ. P/U 110K, S/O 85K, Rot 98K. ECD =9.87 ppg EMW. Drlg Hrs. on tour, Rot. = 7.99 hrs. , no Slides on this tour. Hours total for bit run= 39.57 hrs, Rot. = 33.72 hrs. Slide = 5.85 hrs. 06/11/2008 • Drilled from 6,662' MD to 7,005' MD. Short tripped into the casing and back to bottom. 00:00 00:30 0.50 6,662 6,662 PROD1 DRILL OTHR P Service rig. Top drive, swivel, crown, pumps, housekeeping. SPR's. MP#1 50 /400psi, MP#2 50/410psi. 00:30 10:30 10.00 6,662 7,005 PROD1 DRILL DDRL P Directionally drilled 8 3/4 hole from 6,662' MD. 6,438' TVD. to 7,005' MD. 6,797' TVD with 500 GPM, 100 RPM, 2 to 8,000 bit weight, 5 to 8,000 ft/Ibs TQ. P/U 110K, S/O 85K, Rot 98K. ECD =9.87 ppg EMW. Drlg Hrs. on tour, Rot. = 7.99 hrs. , no Slides on this tour. Hours total for bit run= 39.57 hrs, Rot. = 33.72 hrs. , Slide = 5.85 hrs. 10:30 12:00 1.50 7,005 7,005 PROD1 DRILL CIRC P Circulate and condition hole. Spill drill 3 min response. 12:00 19:30 7.50 7,005 7,005 PROD1 DRILL WPRT P Trip out to the casing. Tight hole the first 10 stands. Good hole after that. 19:30 20:00 0.50 7,005 7,005 PROD1 DRILL OTHR P Service rig, monitor well. Inside casing. 20:00 23:00 3.00 7,005 7,005 PROD1 DRILL WPRT P Trip back to 6821' MD. Some down drag the last stand from 6750 to 6820. 23:00 23:30 0.50 7,005 7,005 PROD1 DRILL REAM P Ream from 6,828' MD to 7,005' MD. No fill. Ream with 400 gpm /50 rpm. 23:30 00:00 0.50 7,005 7,005 PROD1 DRILL CIRC P Circulate and condition the well with 400 gpm's, 50 rpm's. Slowly break rthe gels down, and come up to 450 gpm's after the first bottoms up. 06/12/2008 Circulated and conditioned the well bore after the wiper trip, monitored the well for 15 mins., dropped the ESS tool, tripped out, layed down BHA, rigged up and ran the first Slumberger wireline Togs. Page -91 of 39 • • - � Date `` ° From To.::... Dor <... S. Depth E. � Phase Code Sub.' r .: Comment 00:00 01:30 1.50 7,005 7,005 PROD1 DRILL CIRC P Circulate and condition the wellbore until the shakers cleaned up. 500 gpm, 100 rpm, 2800 psi pump pressure. ECD= 10.15 ppg. EMW. Mud wt = 9.8 ppg. 01:30 01:45 0.25 7,005 7,005 PROD1 DRILL OWFF P Monitor well for 15 mins. 01:45 02:00 0.25 7,005 7,005 PROD1 DRILL SRVY P Drop ESS. Pump dry job, and pull on the elevators. 02:00 05:45 3.75 7,005 7,005 PROD1 DRILL TRIP P Trip out of hole from 7,005' MD to 2976' MD. Conduct surveys with ESS @ 6912', 4671', 4633'. 05:45 06:00 0.25 7,005 7,005 PROD1 DRILL OWFF P Monitor well for 15 mins inside casing. 06:00 07:30 1.50 7,005 7,005 PROD1 DRILL TRIP P Trip out of hole to bottom hole assembly. Flow check at HWDP, remove corrosion ring. 07:30 08:30 1.00 7,005 7,005 PROD1 DRILL PULD P Begin to lay down BHA, retrieve ESS tool. 08:30 09:00 0.50 7,005 7,005 PROD1 DRILL SFTY P Prejob safety meeting. Removal of sources from Sperry MWD tools. 09:00 11:30 2.50 7,005 7,005 PROD1 DRILL PULD P Lay down bottom hole assembly components. Remove source, turn tools off. Total BBLs lost durin1trip _ was 7.0 bbls. 1 barrel per hour seine rate. 11:30 12:00 0.50 7,005 7,005 PROD1 DRILL OTHR P Service rig. Top drive, swivel, clear and clean rig floor. 12:00 12:30 0.50 7,005 7,005 PROD1 EVALWE SFTY P Prejob safetry meeting with Slumberger team. 12:30 00:00 11.50 7,005 7,005 PROD1 EVALWE ELOG P Logging with Dipole Formation Micro Imager. Sonic, gamma ray. 06/13/2008 Log the wellbore with Slumberger. Two wireline runs, one drill pipe assisted run, still in progress. 00:00 04:30 4.50 7,005 7,005 PROD1 EVALWE ELOG P Open hole Slumberger wireline logging, Sonic, Gamma, Dipole Micro Imaging tool. 04:30 05:30 1.00 7,005 7,005 PROD1 EVALWE PULD P Lay down SLB tools from first run, pick up Tripple Combo tools. 05:30 06:00 0.50 7,005 7,005 PROD1 EVALWE SFTY P Prejob safety meeting for loading the wireline tools with source. 06:00 10:00 4.00 7,005 7,005 PROD1 EVALWE ELOG P Logging with "Platform Express ". 10:00 10:30 0.50 7,005 7,005 PROD1 EVALWE SFTY P Pull source, prejob on DP assisted logging run. 10:30 12:00 1.50 7,005 7,005 PROD1 EVALWE DLOG P Pick up Schlumberger tools, trip in with drill pipe. 12:00 23:00 11.00 7,005 7,005 PROD1 EVALWE DLOG P Trip in with Slumberger tools on bottom of drill string. Trip to 1538' MD, break circ. @ 4 BPM.PSI =150. Trip to 2968' MD. Break circ. © 4 BPM PSI= 200.Trip to 3513' MD, pick up side door entry sub. Pump down , and latch up. Trip slow to 6342' MD. 23:00 00:00 1.00 7,005 7,005 PROD1 EVALWE DLOG P Begin logging coming up. Test © 6342,6340,5974. 06/14/2008 Finish the drill pipe assisted wireling line MDT job. Page 12 of 39 • L . Da .' t . . Dur o a • a Ph -e w Cod * « . e T .\ . t ;F 00:00 12:00 12.00 7,005 7,005 PROD1 EVALWE DLOG P Open hole logging, drill pipe assisted logging operations continued with Slumberger. MDT pressure tool string. Samples @ 5891', 5821', 5784', 5654', 5600', 5484', 5410', 5322', 5298', 5115', 4980', 4951', 4892', 4828', 4710', 4697', 4604', 4573', 4541', 4377', 4236', 4150', 4056', 3986', 3919', 3836', 3795'. Pulled tight at two stations 5600 & 5654', pulled 15k over, and broke free coming back down with 10k extra down weight. Appeared to be wall stuck both times. Stuck mechanism most likely differential. 12:00 15:00 3.00 7,005 7,005 PROD1 EVALWE DLOG P Continue MDT operations with next crew. Samples @ 3795', 3717', 3716', 3673', 3642', 3607', 3575', 3533' 2xs, 3532', 15:00 18:30 3.50 7,005 7,005 PROD1 EVALWE DLOG P Reposition side door entry sub. Move it from 3522 up to 3041. Tool depths. 18:30 22:30 4.00 7,005 7,005 PROD1 EVALWE DLOG P Drop down to 3600, and begin samples @ 3535', 3504', 3488', 3404', 3351', 3321', 3262', Trip back into casing # 3027' MD. 22:30 00:00 1.50 7,005 7,005 PROD1 EVALWE DLOG P Monitor well, pump 10 bbl dry job, Trip out of hole to 1353' MD. 06/15/2008 Complete the formation evaluation phase, release Slumberger, trip in the hole with a rotary clean out assembly to prepare the well bore for 7" casing. 00:00 01:00 1.00 7,005 7,005 PROD1 EVALWE DLOG P Trip out with drill pipe to lay down MDT tools. Trip from 1353 to 200' MD. 01:00 02:00 1.00 7,005 7,005 PROD1 EVALWE PULD P Lay down drill pipe conveyed tools, hold prejob, pick up wireline tools. Sidewall coring run. 02:00 06:30 4.50 7,005 7,005 PROD1 EVALWE ELOG P Run wireline to 6795' MD. No hole problems. Take 6 sample from 6795 to 6342' MD. Tool stopped working. Pull back out to surface. 06:30 10:00 3.50 7,005 7,005 PROD1 EVALWE ELOG T lay down tools, wait on SLB to repair tools. Unable to repair tools, lay down all of SLB equipment. 10:00 11:30 1.50 7,005 7,005 PROD1 DRILL PULD P Pick up 8.75" PDC bit and rotary clean out assembly. 11:30 13:30 2.00 7,005 7,005 PROD1 DRILL TRIP P Trip in to 1528' MD, break circ. trip to 2958' MD, break circ. 13:30 15:30 2.00 7,005 7,005 PROD1 DRILL OTHR P Slip and cut drill line. 100 feet. 15:30 16:00 0.50 7,005 7,005 PROD1 DRILL SFTY P Safety stand down. Roustabout was stuck between jars, pinched lower leg. 16:00 19:00 3.00 7,005 7,005 PROD1 DRILL TRIP P Trip in the hole, break circ. @ 4395, and then again @ 5821' MD. Good hole conditions. Page 13 of 39 • • Tlme Logs 1 Date From To Our �� = . «..t? T C•1 ., 19:00 00:00 5.00 7,005 PROD1 DRILL REAM P Begin reaming to bottom @ 6327' MD. Somes ledges to dress off. Sstart with 360 gpm's /50 rpm's. Stage up to 500 gpm's /100 rpm's on bottom. No fill. Hole was in good shape. Up weight= 118k, Down weight= 92k, rotating weight= 100k. Mud weight in and out 9.8 ppg. 06/16/2008 Circulate and condition the well bore. Trip out, lay down the clean out assembly, rig up and run casing. 00:00 05:30 5.50 7,005 7,005 PROD1 DRILL CIRC P Circulate and condition the mud system, while rotating 100 rpm's, pumping 490 gpm's, working the pipe constantly. Pump pressure= 2200 psi. Torque= 5,000 ft/lbs. Up weight= 114k, Down weight= 96k, Rotate weight= 102k. Bring mud weight down from 9.8+ ppg to 9.6 +ppg. 05:30 06:30 1.00 7,005 7,005 PROD1 DRILL TRIP P Monitor well, static, trip out to 6581' MD. 06:30 07:00 0.50 7,005 7,005 PROD1 DRILL CIRC P Pump dry job. 07:00 10:30 3.50 7,005 7,005 PROD1 DRILL TRIP P Trip out to 2958' MD. Inside casing. 10:30 11:30 1.00 7,005 7,005 PROD1 DRILL TRIP P Monitor well, static. Trip out to BHA. @ 574' MD. 11:30 12:00 0.50 7,005 7,005 PROD1 DRILL TRIP P Trip from 574' to 389' MD. Monitor well, static. 12:00 14:30 2.50 7,005 7,005 PROD1 DRILL PULD P Lay down 3 flex collars, jars, 2 HWDP. Clear and clean rig floor. 7,005 7,005 PROD1 CASING NUND P 14:30 17:30 3.00 005 005 O C S G upper Change out u er variable 3" to 5" pipe rams to rams. Test to Tow, 3500 high. lay down tools. 17:30 21:00 3.50 7,005 7,005 PROD1 CASING RNCS P Rig up to run casing. PJSM. Change bails, rig up power tongs, slips. 21:00 00:00 3.00 7,005 7,005 PROD1 CASING RNCS P Run casing to 417', fill every joint, top off each 5. 20k dwn. wt. 06/17/2008 Finished running 7" production casing. Shoe at 6994.23', float collar at 6908.42' and HES stage collar at 3751.50'. Made up landing joint and hanger and landed casing. Circulated and conditioned mud at final rate of 4 bpm and 607 psi. Batch mixed 137 bbls of Lead slurry while circulating. Pressure tested lines to 4000 psi and dropped bottom plug. Pump 24 bbl of SealBond spacer at 10.0 ppg and 137 bbl slurry at 10.5 ppg. Dropped top plug and displaced with 5 bbl water with BJ and 257 bbl mud with rig pump. Lost 10 bbl mud while displacing first stage. Pumping second stage at report time. 00:00 05:30 5.50 7,005 7,005 PROD1 CASING RNCS P Cont RIH with 7" csg from 417' to 3033'. Fill pipe every jt and top off every 5 jts. 05:30 07:00 1.50 7,005 7,005 PROD1 CASING CIRC P Circ and condition mud at 4 bpm and 195 psi. Install 18 straight blade centralizers with 2 stop rings each on pipe rack. 07:00 12:00 5.00 7,005 7,005 PROD1 CASING RNCS P RIH with 7 "q and Halliburton stage collar from 3033' to 5200'. Fill pipe every jt and top off every 5 jts. No hole problems. 12:00 14:00 2.00 7,005 7,005 PROD1 CASING CIRC P Circ and condition mud at 4 bpm 375 psi. Page 14 of 39 1 • Time Logs \ \\ \ \\ Date Frc , fir beptt Phase Cade Subcode 14:00 18:00 4.00 7,005 7,005 PROD1 CASING RNCS P Run 7" casing from 5200' to 6970'. Make up fluted casing hanger and land. 18:00 22:00 4.00 7,005 7,005 PROD1 CEMEN "CIRC P Rig up cement head and break circulation. Stage rate up to 5 bpm @ 695 psi. P/U 162k, S/O 100k. Lost 10 bbl mud of 30 minutes. Reduced rate to 4 bpm at 607 psi and losses decreased to 4 bph. Started batching up first stage slurry at 20:13 hrs. while circulating. 22:00 00:00 2.00 7,005 7,005 PROD1 CEMEN" DISP P Prejob safety meeting with cement crew and rig personnel. Pressure test lines to 4000 psi. Drop bottom plug. Pump 24 bbl SealBond Spacer @ 10.0 ppg. Pump 137 bbl Lead slurry w/ 1/4 Ib /sk cellophane flake @ 10.5 ppg. Drop top plug and displace with 5 bbl of water with cement pump followed by 257.7 bbl mud with the rig pump. Displacing cement at midnight. 06/18/2008 Continued displacing cement with rig pump at 4 bpm 680 psi. Bumped plug and pressured casing to 1800 psi. Checked floats -ok. CIP @ 00:10 hrs 6/18/2008. Sheared stage collar open with BJ @ 3550 psi. CBU and got 60 bbl cement and contaminated mud to surface. Cleaned stack and circulated and conditioned mud while batch mixing 2nd stage. Held pre -job safety meeting and pumped 24 bbl Sealbond @ 10.0 ppg and 50 bbl slurry at 10.5 ppg. Dropped closing plug and pumped 5 bbl water with BJ and displaced with 138 bbl mud with rig pump. Bumped plug and sheared stage collar closed. Laid down cementing equipment and landing joint. Installed packoff and tested to 5000 psi -OK. Changed upper pipe rams from 7" to 2 -7/8" x 4 -1/2" VBR's. Make upclean out assembly, run in hole and tag stage collar at 3754' DPM. Drilling on stage collar at report time 00:00 00:30 0.50 7,005 7,005 PROD1 CEMEN DISP P Continue displace cement with rig pumps at 4 bpm - 680 psi. Bump plug and pressure csg to 1800 psi. Check floats. OK. CIP @ 00:10 hrs 6/18/2008 00:30 01:30 1.00 7,005 7,005 PROD1 CEMEN" CIRC P BJ sheared open stage tool at 3550, psi. CBU. 60 bbls cement and cement contaminated mud to surface. 01:30 02:30 1.00 7,005 7,005 PROD1 CEMEN" OTHR P Clean out stack. Jet flowline. Clean cement from pits. 02:30 05:30 3.00 7,005 7,005 PROD1 CEMEN" CIRC P Circulate and condition mud at 4 bpm - 300 psi. 05:30 07:00 1.50 7,005 7,005 PROD1 CEMEN" DISP P PJSM. BJ pumped 24 bbls SealBond Spacer @ 10.0 ppg and 50 bbls 10.5 ppg cement. Dropped closing plug. BJ kicked plug out with 5 bbls water. Rig displace with 138 bbls 9.6 mud at 4 bpm - 300 psi. Bumped plug and shear stage tool closed. Annulus was static. 07:00 08:30 1.50 7,005 7,005 PROD1 CEMEN" RURD P LD cement head. RD csg equipment. LD landing joint. 08:30 10:00 1.50 7,005 7,005 PROD1 CASING DHEQ P Install and test 7" pack -off to 5000 psi. Page 15 of 39 • • Time Logs " „ :,1 Date frit t ice. Dot S. Depth E. Depth Phas Code ' Subcode T :Comment . .'.....:` 10:00 16:00 6.00 7,005 7,005 PROD1 WELCTL NUND P Flush stack with ported sub. Change out upper rams from 7" to 2 7/8" x 4 1/2" VBR's. 16:00 20:30 4.50 7,005 7,005 PROD1 CEMEN" COCF P Change bales and gather crossovers for cleanout BHA. Make up BHA and pick up 6 drill collars 20:30 00:00 3.50 7,005 7,005 PROD1 CEMEN" COCF P Trip in the hole with cleanout BHA to3754' DPM and tag stage collar. P/U 60K, S/O 58K, Rot 60K, Test casing to 1000 psi for 5 minutes. Drill through stage collar and plug. ' 06/19/2008 Finish drilling stage collar and pressure test to 1000 psi for 5 minutes. Continue running in the hole. wash and ream from 6661' to 6864' and tag landing collar. Circulate and displace mud with freshwater. Pull out of the hole and laydown bit and bitsub. Cleaning mud pits. 00:00 00:30 0.50 7,005 7,005 PROD1 CEMEN" COCF P Pressure test csg to 1000 psi to check stage tool. OK. 00:30 02:00 1.50 7,005 7,005 PROD1 CEMEN "TRIP P RIH with 4" DP f/ 3754 to 6661'. 02:00 02:30 0.50 7,005 7,005 PROD1 CEMEN" COCF P Wash and ream from 6661' to landing collar at 6684'. 02:30 04:30 2.00 7,005 7,005 PROD1 CEMEN" CIRC P Displace 9.6 mud with fresh water at 4 bpm - 360 psi.. 04:30 06:30 2.00 7,005 7,005 PROD1 CEMEN" OTHR P Clean pits and trip tank. 06:30 09:30 3.00 7,005 7,005 PROD1 CEMEN "TRIP P POH from 6864' to 559'. 09:30 10:30 1.00 7,005 7,005 PROD1 CEMEN" TRIP P Stand back BHA. LD bit and bit sub. 10:30 11:00 0.50 7,005 7,005 COMPZ RIGMN1SVRG P Service top drive and crown 11:00 00:00 13.00 7,005 COMPZ RPCOM OTHR P Haul off mud and clean mud circulating system including pits and pumps 06/20/2008 Continue cleaning mud pits. Pull wear bushing. Test BOPE to 250/3500 psi with 4" test joint. Test pipe rams to 250/5000 psi. Lay down 4" test joint and test blinds to 250/3500 psi. Pick up 5" test joint and retest pipe rams and annular to 250/3500 psi. Set wear bushing. Pick up wash tool and flush BOP stack. Hold safety meeting and rig up e-line. Run in hole with USIT and log up from 6850'. 00:00 06:00 6.00 7,005 7,005 COMPZ RPCOM OTHR P Clean pits. Rack, drift and strap 170 jts 4 1/2" tbg. 06:00 06:30 0.50 7,005 7,005 COMPZ WELCTL OTHR P Pull wear bushing. Set test plug. 06:30 08:00 1.50 7,005 7,005 COMPZ WELCTL OTHR P RU BOP test equipment. 08:00 12:00 4.00 7,005 7,005 COMPZ WELCTL BOPE P Test annular to 250 / 2500 psi. Test upper ram, IBOP, dart vavle, TIW and 6 choke valves to 250 - 3500 psi. 12:00 18:30 6.50 7,005 7,005 COMPZ WELCTL BOPE P Continue testing BOPE. Test all components with 4" test joint to 250 psi lo/ 3500 psi high. Test upper pipe rams and inner choke and kill lines and IBOP to 250 psi low/ 5000 psi high. 18:30 19:00 0.50 7,005 7,005 COMPZ WELCTL OTHR P Lay down 4" test joint 19:00 20:00 1.00 7,005 7,005 COMPZ WELCTL BOPE P Test blind rams to 250 psi low/ 3500 psi high. Pick up 5" test joint. Test upper pipe rams to 250 psi low /3500 psi high. Page 16 of 39 • . Time Logs Td r' `. Phase Code Subcode T Comment 20:00 20:30 0.50 7 7 COMPZ WELCTL OTHR P Install wear bushing 20:30 21:30 1.00 7,005 7,005 COMPZ WELCTL OTHR P Pickup wash tool and flush BOP stack. Function BOP's and reflush stack 2130 22:00 0.50 7,005 7,005 COMPZ EVALWE PULD P Pre-job safety meeting Rig up a -line to run USIT log 22:00 23:00 1.00 7,005 7,005 COMPZ EVALWE ELOG P Run in hole with USIT log to 6850' WLM 23:00 00:00 1.00 7,005 7,005 COMPZ EVALWE ELOG P Pull out of hole with USIR logging up from 6850' WLM. Found RA tags at 5229' WLM and 6372' WLM (2' shallower than casing tally in both cases) 06/21/2008 Finish running USIT log. Laydown USIT tools and pick up Baker Model "K" retainer. Run in hole on a -line and set retainer at 6552' MD. POOH and rig down a -line. Continue cleaning mud pits with hot water pressure washers. Circulate caustic pill (pH of 13.5) with SafeSurf WL through surface circulating system. 00:00 02:00 2.00 7,005 7,005 COMPZ EVALWE ELOG P Continue running USIT log. Laydown USIT tools 02:00 02:30 0.50 7,005 7,005 COMPZ RPCOM PACK P Make up Baker Model "K" retainer on e -line 02:30 05:00 2.50 7,005 7,005 COMPZ RPCOM PACK P Run in hole with retainer. Set Baker Model "K" at 6552' MD. 05:00 19:30 14.50 7,005 7,005 COMPZ RPCOM OTHR P Continue cleaning pits with hot water pressure washers. Change washpipe in swivel 19:30 00:00 4.50 7,005 7,005 COMPZ RPCOM OTHR P Circulate caustic pill (pH of 13.5) with SafeSurf W through surface circulating system. 06/22/2008 Finish circulating caustic pill) through surface mud system. Pump caustic pill out of pits. Circulate fresh water through pits and replace one valve in gun line and air boot on suction line. Make up Swaco scrapers, brushes, magnets and boot baskets and run in the hole to 6548'. 00:00 12:00 12.00 7,005 7,005 COMPZ RPCOM OTHR P Circulate caustic pill through all surface system. Pump caustic pill out of pits 12:00 15:00 3.00 7,005 7,005 COMPZ RPCOM OTHR P Circulate fresh water through pits. Replace leaking valve in gun line and air boot in suction line 15:00 17:00 2.00 7,005 7,005 COMPZ RPCOM OTHR P Circulate fresh water through top drive and choke manifold. 17:00 17:30 0.50 7,005 7,005 COMPZ RPCOM OTHR P Blow down choke manifold and kill lines 17:30 18:00 0.50 7,005 7,005 COMPZ RPCOM PULD P Lay down 4" test joint used to flush the BOP stack 18:00 20:00 2.00 7,005 7,005 COMPZ RPCOM OTHR P Clean Swaco tools of debris 20:00 20:30 0.50 7,005 7,005 COMPZ RPCOM PULD P Pick up Swacoa scrapers, brushes, boot baskets and magnets 20:30 22:30 2.00 7,005 7,005 COMPZ RPCOM TRIP P Run in scrapers, etc. on 34 stands of 4" drill pipe to 3336'. Pick up additional scraper. 22:30 00:00 1.50 7,005 7,005 COMPZ RPCOM TRIP P Continue running the hole from 3336' to 6548' 06/23/2008 Finished wiper trip with scraper BHA. Tested casing to 5000 psi for 30 minutes -OK. Pickled drill pipe with acid pickle followed by caustic pickle. Page 17 of 39 • • Da . Ffom To ... DU De th E Depth Phase ' Code Comm nt ., v•4 . 00:00 02:00 2.00 7,005 7,005 COMPZ RPCOM TRIP P Pull out of the hoe with scraper assembly from 6548' to 3364' 02:00 03:30 1.50 7,005 7,005 COMPZ RPCOM TRIP P Trip in the hole from 3364' to 6548' 03:30 04:00 0.50 7,005 7,005 COMPZ RPCOM CIRC P Circulate and rig up to pump acid pickle 04:00 06:00 2.00 7,005 7,005 COMPZ RPCOM DHEQ P Pre -job safety meeting. Pressure test lines to 6000 psi. Test casing to 5000 psi for 30 minutes with cementing unit. No bleed off. 06:00 10:30 4.50 7,005 7,005 COMPZ RPCOM CIRC P Used cementing unit to pump 20 bbl viscosified fresh water, 10 bbl Safe -T- Pickle, 13 bbl 15% HCI, followed by 56 bbl fresh water at 1.5 bpm. Reversed acid and pills out of the hole with the rig pump at 2.5 bpm @ 260 psi. 10:30 17:00 6.50 7,005 7,005 COMPZ RPCOM CIRC P Build caustic pill, hi -vis pill, and Safe -Surf W pill in pits 17:00 18:30 1.50 7,005 7,005 COMPZ RPCOM CIRC P Displace wellbore to brine by pumping 20 bbl KCI bring w/ 2 ppb Flo -vis L and 2 bpm, 75 bbl caustic washfollowed by 75 bbl water with 2 drums SafeSurf-W followed by 25 bbl water with 2 ppb Flovis L. Displace with 6% KCI brine while rotating and reciprocating. P/U 92K, S/O 88K, Rot 80k 18:30 00:00 5.50 7,005 7,005 COMPZ RPCOM OTHR P Clean pits. Mix, filter and transfer additional brine 06/24/2008 Trip out of hole and lay down scraper assembly. Rig up and run 4 -1/2" frac string to 4901.48'. Pickle frac string with 20 bbl viscosified brine, and 550 gallons 15% HCI. Reverse out acid and viscosified brine until returns less than 10 ntu. Spot a -line unit and prep pad for spotting frac equipment. 00:00 01:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate and build volume until returns were 9.6 ntu. 01:00 04:00 3.00 7,005 7,005 COMPZ RPCOM TRIP P Trip out of the hole from 6552' to 168' 04:00 05:00 1.00 7,005 7,005 COMPZ RPCOM PULD P Laydown scrapers, magnet, boot basket and brushes 05:00 06:30 1.50 7,005 7,005 COMPZ RPCOM RURD P Rig up to run 4 -1/2" frac string 06:30 07:00 0.50 7,005 7,005 COMPZ RIGMNT SVRG P Service crown and top drive 07:00 16:00 9.00 7,005 7,005 COMPZ RPCOM RCST P Run in hole with WLEG, 159 joints of 4 -1/2" 12.6#, L -80 IBTM tubing, crossover, 1 joint 4 -1/2" 15.5 #,1-80, IBTM tubing. Wireline entry guide at 4901.48'. 16:00 19:30 3.50 7,005 7,005 COMPZ RPCOM CIRC P Circulate and clean mud system. Rearrange BJ equipment. Ship brine to BJ 19:30 21:00 1.50 7,005 7,005 COMPZ RPCOM OTHR P Pickle tubing by pumping 20 bbl brine with 2 ppb flo -vis, followed by 550 gallons of 15% HCI. Displaced acid with 60 bbl brine. 21:00 22:30 1.50 7,005 7,005 COMPZ RPCOM CIRC P Reverse out at 4 bpm with 6% KCI brine until returns less than 10 ntu. Page 18 of 39 • • Time Log w ,,ate Fiom ,:: Dur S. DeDflitaDepth Phase Code , ,ttaboode T Comment 22:30 23:00 0.50 7,005 7,005 COMPZ RPCOM PULD P La down head pin, xo. Clear floor of Y p BJ equipment 23:00 00:00 1.00 7,005 7,005 COMPZ RPCOM OTHR P Mix kill weight (9.6 ppg) brine. Spot Schlumberger a -line unit. Clear location to spot frac equipment. Heat frac fluid. 06/25/2008 Run in the hole with tubing to 6039.50'. Take slow pump rates. Rig up frac equipment and fill sand silo. 00:00 11:00 11.00 7,005 7,005 COMPZ RPCOM OTHR P Continue prepping pad for frac equipment 11:00 12:00 1.00 7,005 7,005 COMPZ RPCOM OTHR P Set pipe racks 12:00 15:00 3.00 7,005 7,005 COMPZ RPCOM PULD P Lay down crossover and FOSV. Rig up floor to pick up tubing. Strap and rabbit tubing 15:00 15:30 0.50 7,005 7,005 COMPZ RPCOM TRIP P Run in the hole with 4 -1/2" tubing from 4867' to 6039.50'. 15:30 16:00 0.50 7,005 7,005 COMPZ RPCOM CIRC P Circulate and get slow'pump rates. Pump # 1 down the tubing 52 spm @ 90 psi and 62 spm @ 110 psi. Pump #2 down the annulus 49 spm @ 175 psi and 62 spm @ 275 psi. P/U 72K, S/O 56K 16:00 21:30 5.50 7,005 7,005 COMPZ RPCOM OTHR P Rig up frac equipment and fill 'SandKing' with proppant. Prep to pick up lubricator. 21:30 00:00 2.50 7,005 7,005 COMPZ RPCOM OTHR P Start picking up frac head and lubricator. 06/26/2008 Rig up frac head. Hold safety stand down with CPAI personnel from Anchorage. Rig up 3" hardline. Mix and filter kill weight brine. Displace well with filtered kill weight brine. Wait on schlumberger pressure control equipment. 00:00 10:30 10.50 7,005 7,005 COMPZ RPCOM RURD P Rig up frac head and lubricator spools 10:30 13:00 2.50 7,005 7,005 COMPZ RPCOM SFTY P Safety stand down conducted by CPAI personnel, Jerome Eggemeyer and Vern Johnson 13:00 15:00 2.00 7,005 7,005 COMPZ RPCOM RURD P Rig up 3" hardlines from frac pumps to frac head 15:00 20:30 5.50 7,005 7,005 COMPZ RPCOM CIRC P Mix and filter kill weight brine at 9.6 ppg and transfer to mud pits 20:30 21:00 0.50 7,005 7,005 COMPZ RPCOM CIRC P Displace well with filtered kill weight brine. 21:00 00:00 3.00 7,005 7,005 COMPZ RPCOM WOEQ T Waiting on wireline spool, grease head and grease injector. 06/27/2008 Change out cable on a -line unit. Rig up lubricator and test to 3000 psi -OK. Make up perforating gun and attempt to run in the hole. Could not get past bottom of frac head. Rig down lubricator and frac head. Bottom flange (API 4 -1/2" -5M) had an inside diameter of 3 -1/2 ". Rig up lubricator with out rigging up frac head. Make up perforating gun and test lubricator to 3000 psi- OK. 00:00 07:30 7.50 7,005 7,005 COMPZ RPCOM OTHR T Change out a -line drum. 07:30 12:00 4.50 7,005 7,005 COMPZ RPCOM NUND P Rig up grease head and lubricator 12:00 12:30 0.50 7,005 7,005 COMPZ RPCOM DHEQ P Pressure test lubricator to 3000 psi for 10 minutes pogo 19of39 • • pate . From T4 A ,,.,r < ur!. _ S. Depth E. De ` ° ase ® . abcode comment 12:30 18:00 5.50 7,005 7,005 COMPZ RPCOM PERF T Pick up perforating gun and attempt to run in hole. Could not get gun past bottom of frac head. Rig down frac lines, lubricator and frac head. Frac head bottom flange i.d. is 3.5 ". Flange is 4 -1/2" -5M flange 18:00 23:30 5.50 7,005 7,005 COMPZ RPCOM NUND T Make up adapter flange and lubricator. 23:30 00:00 0.50 7,005 7,005 COMPZ RPCOM DHEQ P Pressure test lubricator to 3000 psi for 5 minutes 06/28/2008 Rig up and perforate from 6324' to 6344' with 3 -1/8" guns at 6 spf. All shots fired. Rigged down e-line. Rig up frac lines and perform data frac and minifrac. Frac perforations. Killing well with 9.6 ppq brine. 00:00 00:30 0.50 7,005 7,005 COMPZ RPCOM NUND P Test lubricator to 3000 psi for 10 minutes -OK 00:30 05:00 4.50 7,005 7,005 COMPZ RPCOM PERF P Run in hole with perforating guns. Tie -in and perforate from 6324' to 6344' with 3 -1/8" guns, 6spf, 20.1 gram charges. POOH with wireline 05:00 07:30 2.50 7,005 7,005 COMPZ RPCOM NUND P Rig down e-line. All shots fired. Rig down lubricator and e-line BOPE 07:30 08:00 0.50 7,005 7,005 COMPZ RPCOM SFTY P Safety meeting on rigging up, testing lines and fracing. 08:00 09:30 1.50 7,005 7,005 COMPZ RPCOM RURD P Rig up frac lines 09:30 10:00 0.50 7,005 7,005 COMPZ RPCOM CIRC P Circulate and displace well! with 8.6 ppg 6% filtered KCI brine at 6.42 bpm, 565 psi 10:00 18:00 8.00 7,005 7,005 COMPZ RPCOM STIM P Perform mini -frac and data frac per completion engineers' direction. Shut in for fracture to close 18:00 21:00 3.00 7,005 7,005 COMPZ RPCOM STIM P Frac interval from 6324' to 6344' with 61,700 lbs. of 20/40 CarboLite proppant at maximum rate of 20 bpm and maximum surface treating pressure of 2200 psi. Maximum bottom hole proppant concentration was 11.8 ppq. 21:00 22:30 1.50 7,005 7,005 COMPZ RPCOM CIRC P Monitor well. SICP stabilized at 925 psi and SICPP stabilized at 675 psi (rig's guages). Circulate 9.6 ppg brine taking returns through the superchoke. Circulate a total of 3600 strokes (225 bbl). Final circulating pressure of 200 psi and final casing pressure of 200 psi. Had gas in returns after pumping 200 strokes and had frac sand over the shakers on bottoms up. 22:30 00:00 1.50 7,005 7,005 COMPZ RPCOM OWFF P Shut well in and monitor pressure. Pressures stabilized at 320 psi casing pressure and 350 psi drill pipe pressure. Page 20 of 3 • • Time Logs pate From To Dur E. Depth Phase Cod 6aelr $ubcode „ T Comment ... \ ;.� 06/29/2008 24 hr S Shut in well. Bleed off 3 bbl to trip tank. Pressures stabilized at 325 psi. Displace well with 9.5 ppg brine at 2.8 bpm. SIDPP stabilized at 220 posi and SICP stabilized at 180 psi. Bled pressure to zero and monitored well. No flow. Rigged down a -line and frac lines. Prepped floor to pull tubing. Circulated bottoms up and well started flowing. SIDPP = 125 psi and SICP = 100 psi. Displace well with 9.8 ppg brine. Secure well and SIDPP= 100 psi and SICP= 60 psi. Increasing brine weight to 10.2 ppg. 00:00 00:30 0.50 7,005 7,005 COMPZ RPCOM OWFF P Bleed off 3 bbl of fluid to trip tank. No decrease in pressure 00:30 05:00 4.50 7,005 7,005 COMPZ RPCOM OWFF P Secure well and monitor pressures. SIDPP and SICP stabilized at 325 psi. Increase brine weight to 9.5 ppg 05:00 08:00 3.00 7,005 7,005 COMPZ RPCOM CIRC P Displace well at 2.8 bpm with 9.5 ppq brine per pumping schedule 08:00 12:00 4.00 7,005 7,005 COMPZ RPCOM OWFF P Monitor pressures. SIDPP = 220 psi and SICP = 180 psi. Mix brine 12:00 13:30 1.50 7,005 7,005 COMPZ RPCOM OWFF P Bleed off pressure to 0 psi. Monitor pressure for 15 minutes and open well to atmosphere. Monitor well 13:30 16:30 3.00 7,005 7,005 COMPZ RPCOM RURD P Rig down frac a -line equipment. Prep floor to pull tubing. 16:30 18:30 2.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate bottoms up and well started flowing. Shut in and SIDPP =125 psi and SICP 100 psi. 18 :30 23:00 4.50 7,005 7,005 COMPZ RPCOM CIRC P Displace well with 9.8 ppg brine 23:00 00:00 1.00 7,005 7,005 COMPZ RPCOM OWFF P Secure well and SIDPP= 100 psi and SICP = 60 psi. Increase brine weight ot10.2ppa 06/30/2008 Monitor well and mix 10.25 ppg kill weight brine. Displace well with kill weight brine. Well dead. Rig down frac lines and run in hole with tubing. Tag sand fill at 6253'. Pull out of the hole to 5454'. Rig up frac lines, frac head, lubricator and a -line bop's. Flush lines prior to spotting sand plug. 00:00 01:00 1.00 7,005 7,005 COMPZ RPCOM OWFF P Observe well SICP = 0 psi, SIDPP = 100 psi 01:00 09:00 8.00 7,005 7,005 COMPZ RPCOM OTHR P Mix and filter 298 bbl 10.4 ooa brin@ 09:00 09:30 0.50 7,005 7,005 COMPZ RPCOM OTHR P Bleed off 5 bbl through choke at 4 bph. 09:30 10:30 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate and kill well with 205 bbl of 10.25 ppg brine @ 3.8 bpm. Final circulating pressure 240 psi. 10:30 11:00 0.50 7,005 7,005 COMPZ RPCOM OWFF P Open rams and monitor well -no flow 11:00 13:30 2.50 7,005 7,005 COMPZ RPCOM RURD P Rig down frac lines. 13:30 16:00 2.50 7,005 7,005 COMPZ RPCOM RURD P Rig up floor to trip in the hole 16:00 17:30 1.50 7,005 7,005 COMPZ RPCOM TRIP P Run in the hole with drill pipe and tag sand at 6253' 17:30 18:30 1.00 7,005 7,005 COMPZ RPCOM TRIP P Pull out of the hole from 6253' to 18:30 00:00 5.50 7,005 7,005 COMPZ RPCOM RURD P Make up frac head , crossover and e -line bop's, lubricator and hardlines. Flush lines and prep to spot sand plug 07/01/2008 Pump sand plug. Mix 400 bbls of frac fluid. Perforate 5888' - 5904', 5842' - 5852', and 5814' - 5832' MD. Perform data frac. Frac well. 72,500 Ibs 20/40 Carbolite in formation. Page 21 of 39 • • Time Le * \ .: : \� \ Date 4Tb1\ Dor S. Depth E E.Deeth •:Rhase r 'Comment 00:00 01:30 1.50 7,005 7,005 COMPZ RPCOM STIM P Pump 5513# sand plug to bottom @5.9 bbls /min, 3000 psi. Let sand settle out and monitor for one hour. Pressure 480 psi. 01:30 02:30 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate 5 bbls. Reverse 5 bbls. Pressure test sand plug to 2000 psi. 02:30 04:00 1.50 7,005 7,005 COMPZ RPCOM CIRC P Mix 400 bbls. 8.6 ppg frac fluid. Displace well @ 7.4 bbls /min, 1600 psi. Max pressure seen 1922 psi. Shut in and monitor. SICP 3000 psi. 04:00 13:30 9.50 7,005 7,005 COMPZ RPCOM PERF P Test lubricator to 2000 psi. Load and pick up 20' of guns. RIH with guns and tag top of sand at 6008' MD (5783' TVD). Perforate zone from / 5888' - 5904' MD. POOH. Load and pick up 10' of guns. RIH. Perforate zone from 5842' - 5852' MD. POOH. Load and pick up 18' of guns. RIH. Perforate zone from 5814' - 5832' MD. UD SWS guns and line up for frac. 13:30 16:00 2.50 7,005 7,005 COMPZ RPCOM STIM P Rig up for frac. Test lines to 5000 psi. Perform data frac. Inject 40 bbls of gel. Perform mini frac. Pump 197 bbls. Shut in, holding 1900 psi. 16:00 21:00 5.00 7,005 7,005 COMPZ RPCOM STIM P Circulate 83 bbls. Close choke. Perform frac. Pump 72,500 lbs 20/40 Carbolite in formation. Maximum bottom hole concentration 11.8 ppg. Max surface treating pressure 2550 psi. Left 4500 Ibs sand in casing for sand plug. 21:00 00:00 3.00 7,005 7,005 COMPZ RPCOM STIM P Shut in well after frac. Pressure 2400 psi. At 2300 hrs, pressure 500 psi. 07/02/2008 Mix 8.6 ppg KCI for frac. RIH with perforating gun. Tag sand plug high. POOH with perforating gun. Pump 10.2 ppg brine. POOH with tubing from 5454' to 5147'. Pump sand plug. 00:00 04:30 4.50 7,005 7,005 COMPZ RPCOM STIM P Well shut in. Monitor pressure. 300 psi SIDDP and 300 psi SICP. Mix 8.6 ppg KCI for frac and fill BJ sand hopper. 04:30 05:00 0.50 7,005 7,005 COMPZ RPCOM SFTY P PJSM on circulating gas out of well with 8.6 ppg fluid. 05:00 06:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulating out fluid and gas at 4 bbls per minute with 450 psi back pressure. 06:00 11:00 5.00 7,005 7,005 COMPZ RPCOM PERF T RU Schlumberger to perforate. RIH and tag up at 5683' (tagged high). , POOH. RU and RIH with dummy gun. Tag same. 11:00 12:30 1.50 7,005 7,005 COMPZ RPCOM OTHR T Pressure test sand to 2000 psi. Not holding. RD Schlumberger. 12:30 14:30 2.00 7,005 7,005 COMPZ RPCOM CIRC P ... holding. 10.2 ppg kill weight brine at 3.8 bbls per minute. 3010 total strokes. 14:30 17:00 2.50 7,005 7,005 COMPZ RPCOM RURD P RD BJ frac head and Schlumberger well control tools. Page 22 of 39 ! • Time Lots Date D th Phase de Sub de, T . • ,.Commit � :.,�r°gr'rf Tam.. ` .�.N�x'. �. S. Depth' E. � 17:00 18:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Well U tubing. Pump 90 bbls of 10.2 ppg brine. 18:00 19:00 1.00 7,005 7,005 COMPZ RPCOM TRIP P POOH with tubing from 5454' - 5147 19:00 21:00 2.00 7,005 7,005 COMPZ RPCOM RURD P RU BJ frac head and well control equipment for sand plug. 21:00 21:30 0.50 7,005 7,005 COMPZ RPCOM SFTY P PJSM on pumping sand plug. 21:30 23:30 2.00 7,005 7,005 COMPZ RPCOM CIRC P Pump sand plug. Allow sand to settle out. 23:30 00:00 0.50 7,005 7,005 COMPZ RPCOM SFTY P PJSM on rigging up lubricator. 07/03/2008 Perforate 5478' - 5498' MD and 5468' - 5478' MD. Build 8.6 ppg KCI frac fluid. Frac well. Pump 78,240 Ibs 20/40 Carbolite and Econoprop into formation. 00:00 02:00 2.00 7,005 7,005 COMPZ RPCOM PERF P RU Schlumberger a -line. Pressure test to 3000 psi. 02:00 03:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate 185 bbls of 8.6 ppg KCI frac fluid at 4 bbls per minute. Held 650 psi back pressure on choke. Test sand •lu• to 2000 •si. 03:00 10:00 7.00 7,005 7,005 COMPZ RPCOM PERF P Hold PJ M. PU and RIH with 20' perforating gun...-1a g.top of sand at 5531' MD. Space out and perforate zone #5 from 5478' - 5498' MD. Lost 100 psi pressure. POOH and lay down guns. MU and RIH with 10' perforating gun. Perforate from 5468' - 5478' MD. Lost 50 psi pressure on DP and annulus. POOH and lay down guns. 10:00 12:00 2.00 7,005 7,005 COMPZ RPCOM OTHR P Build 8.6 ppg frac fluid. SICP 140 psi. Pumped 24 BBL minifrac with 6% KCI at 5.6 BPM. Monitored pressures with BJ. 12:00 18:00 6.00 7,005 7,005 COMPZ RPCOM STIM P Hold PJSF. Perform data frac. Pump 60 bbls linear gel and 100 bbls8.6 ppg KCI at 1640 psi. Monitor well pressures 18:00 21:00 3.00 7,005 7,005 COMPZ RPCOM STIM P Perform frac. Pump 78,240 lbs, 20/40 Carbolite and Econoprop in formation. Propant concentration 10.8 ppg. Pump at 20 bbls per minute, max surface treating pressure 2100 psi. Flush to bottom perforation. Shut in and monitor well pressure. Page ,23af39 • Time Logs k From ' To fur S eth E t" iu :: a Code T : - nt 21:00 00:00 3.00 7,005 7,005 COMPZ RPCOM OTHR T RU lubricator. Pick up weight bar and GR /CCL. RIH and hung up. Could not get past TIW valve. PU and stacked out several times. Broke out lubricator. Gauge weight bar - 3.64 ". Change out with 3 -3/8" weight bar and GC /CCL. RU lubricator. Tag up 6' below lubricator. RD lubricator. LD GR/CCL. Ran 3 -3/8" weight bar. Ran in through TIW valve and to 20' below TIW valve with no problems. LD weight bar. PU 20' hollow carrier with GR/CCL on top and RIH. 07/04/2008 Perforated 5422' - 5428' MD and 5402' - 5422' MD. Frac well. Pump 89,574 Ibs 20/40 Econoprop into formation. Begin testing BOP's. 00:00 02:00 2.00 7,005 7,005 COMPZ RPCOM OTHR P RIH with a -line. Tag sand at 5472' MD. POOH with a -line. 02:00 05:00 3.00 7,005 7,005 COMPZ RPCOM OTHR P Pressure test sand plug to 1700 psi. Pressure bled off. RU BJ and pumped 412 Ibs of sand followed by 60 bbls of flush at 5.5 bbls per minute. Let sand settle one hour. Pressure test sand to 2000 psi. Pressure bled down to 280 psi. 05:00 10:30 5.50 7,005 7,005 COMPZ RPCOM PERF P RU and RIH with Schlumberger perforating gun. Tag top of sand at 5435' MD. Perforate from 5422' - 5428' MD. POOH and lay down gun. PU and RIH with perforating gun. Perforate from 5402' - 5422' MD. POOH and lay down gun. RD Schlumberger. 10 :30 13:00 2.50 7,005 7,005 COMPZ RPCOM STIM P Hold PJSM. RU BJ for mini frac. Pump 30 bbls of 8.6 ppg brine at 5.6 bbls per minute. Shut in and monitor pressures. Decision was made not to pump data frac. 13:00 18:00 5.00 7,005 7,005 COMPZ RPCOM STIM P Pump frac as per schedule. Pump 89,574 Ibs of 20/40 Econoprop into formation. Pump at 20 bbls per minute, max surface treating pressure 2150 psi. Overflush with 20 bbls linear gel. RD BJ surface lines and head. 18:00 20:30 2.50 7,005 7,005 COMPZ RPCOM OTHR P Lay down single. POOH with two stands. MU and set storm packer. 20:30 22:00 1.50 7,005 7,005 COMPZ RPCOM SFEQ P Hold PJSM. Pull wear ring. Set test plug. Fill stack. 22:00 00:00 2.00 7,005 7,005 COMPZ RPCOM SFEQ ,E__Testinq BOP's. Testing annular to 250/3500 psi and pipe rams to 250/5000 psi. 07/05/2008 Finished testing BOP's. TIH to 5322' and tag sand. Wash from 5308' - 5597' MD. Monitor well for losses. 00:00 10:00 10.00 7,005 7,005 COMPZ RPCOM SFEQ P Test BOP's. Annular 250/3500 psi and rams 250/5000 psi. Page24of3 • • Time L A \ ��� i • � Date �� . T .����.. � S. [)e•th.. .���a ° � � . ..•., .,. - T Co ' Su• •.�� .. ' ,-: n 10:00 12:30 2.50 7,005 7,005 COMPZ RPCOM SFEQ P Lay down test tool. Install wear bushing. Retrieve and lay down storm packer. 12:30 13:00 0.50 7,005 7,005 COMPZ RPCOM TRIP P TIH from 4926' - 5322' MD. Tag sand. 1 PU to 5308' MD. 13:00 16:00 3.00 7,005 7,005 COMPZ RPCOM CIRC P Wash down from 5308' - 5404' MD at 427 GPM and 850 psi surface pressure. Pump 15 bbl sweep and circulate out. 16:00 16:30 0.50 7,005 7,005 COMPZ RPCOM OTHR P Monitor well while changing shaker screens from 325 to 200 mesh. Static fluid loss 5.6 bbls per hour. 16:30 18:00 1.50 7,005 7,005 COMPZ RPCOM CIRC P Wash down from 5404' - 5413' MD. Pipe took weight. Set down 13k Ibs and pipe fell though. 18:00 19:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Wash down from 5413' - 5500' at 375 GPM and 775 psi surface pressure. Pump 10 bbl sweep and circulate out. Pull one stand to 5400' MD 19:00 23:00 4.00 7,005 7,005 COMPZ RPCOM OTHR P Monitor well for losses while cleaning filter unit. Building 10 ppg fluid . Static fluid losses decreased from 5.6 bbls per hour to 1.5 bbls per, 23:00 00:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P TIH from 5400' - 5500' MD. Wash down from 5500' - 5598' MD at 375 GPM and 775 psi surface pressure. Pump 10 bbl sweep and circulate out. 07/06/2008 Washed from 5597' - 6547' MD. Monitored well. Slight flow. Circulated 10.2 ppg brine. 00:00 05:00 5.00 7,005 7,005 COMPZ RPCOM CIRC P Wash from 5597' - 6072' MD at 9 bbls per minute, 800 psi surface pressure. Pump 10 bbl viscous sweep every connection. 05:00 09:30 4.50 7,005 7,005 COMPZ RPCOM OTHR P Build 333 bbls of 10.0 ppg brine. 09:30 14:30 5.00 7,005 7,005 COMPZ RPCOM CIRC P Wash down from 6072' - 6547' MD at 9 bbls per minute, 900 psi surface Pressu 14:30 16:30 2.00 7,005 7,005 COMPZ RPCOM CIRC P Pump 15 bbl sweep. Continue to circulate fluid to reduce NTU's. Stand back one stand of DP. 16:30 17:00 0.50 7,005 7,005 COMPZ RPCOM OWFF P Monitor well for losses. Well static. 17:00 18:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Displace well with clean filtered brine at 6 bbls per minute, 450 psi surface pressure. Observe well for 15 minutes. Well flowing slowly. 18:00 19:00 1.00 7,005 7,005 COMPZ RPCOM OWFF P a W top drive to see if pipe dry (was wet). Shut in. No pressure on choke. Open well. Monitor well on ttank. 19:00 20:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate clean filtered brine at 6 bbls per minute, 440 psi surface pressure. Service top drive and blocks. Page 25 of 39 • . erne Logs ` bate From To [fu Corriment � r n th : moth Phase Code Subcode T ; �:° � : .,�� . 20:00 21:00 1.00 7,005 7,005 COMPZ RPCOM OWFF P Monitor well for flow. Well flowing _ approximately 2.25 bbis per hour. Shut in well. No pressure on choke. Open well. 21:00 00:00 3.00 7,005 7,005 COMPZ RPCOM CIRC P Weight up fluid to 10.2 ppg. Circulate at 5.5 bbls per minute. Losing 12 bbis per hour. Slow pumps to 4 bbls per minute, 225 psi i surface pressure. Losing 8.5 bbls per hour. 07/07/2008 - e--- -- Circulated 10.2 ppg fluid. POOH with drill pipe and tubing. RIH with TCP guns and drill pipe. 00:00 03:00 3.00 7,005 7,005 COMPZ RPCOM CIRC P Circulate 10.2 ppg fluid at 4 bbls per minute, 260 psi surface pressure. Check well for flow. Static losses 7 bbls per hour. 03:00 04:30 1.50 7,005 7,005 COMPZ RPCOM TRIP P POOH with drill pipe from 6488' - 4958' MD. 04:30 10:30 6.00 7,005 7,005 COMPZ RPCOM TRIP P PJSM. RU Weatherford. Lay down 1 joint 4 -1/2 ", 15.5 #, P -110, RTS -6 and 68 joints of 4 -1/2 ", 12.6 #, L -80, IBTM tubing. Stand back 31 stands in derrick. Total 41 stands in derrick. RD Weatherford. Total losses during trip 37 bbis. 10:30 11:00 0.50 7,005 7,005 COMPZ RPCOM OTHR P Service top`drive. 11:00 11:30 0.50 7,005 7,005 COMPZ RPCOM SFTY P Hold PJSM on running TCP guns. 11:30 12:00 0.50 7,005 7,005 COMPZ RPCOM WOEQ T Waiting on TCP guns 12:00 12:30 0.50 7,005 7,005 COMPZ RPCOM SFTY P Hold PJSM on picking up TCP guns 12:30 00:00 11.50 7,005 7,005 COMPZ RPCOM TRIP P Pick up TCP guns, firing head, packer assembly, RA marker. TIH with DP from 1319' - 4758' MD filling every stand. Up weight 66k. Down weight 56k. 07/08/2008 Finish running TCP guns in hole. Set guns on depth and fire TCP guns. Reverse out 186 bbls of fluid. Circulate bottoms up. POOH with drill pipe and lay down TCP assembly. 00:00 02:00 2.00 7,005 7,005 COMPZ RPCOM TRIP P RIH with DP from 4758' - 6355' MD. Fill every stand. Left 1045' dry atr, 02:00 05:30 3.50 7,005 7,005 COMPZ RPCOM PLT P Hold PJSM. RU Schlumberger. RIH with a -line. Correlate guns on depth. POOH and RD Schlumberger. 05:30 10:00 4.50 7,005 7,005 COMPZ RPCOM PERF P Space out and set packer. RU manifold to reverse out. Test lines to 3500 psi. Pressure up to 2800 psi and fire guns. Open bypass valve on packer. Reverse circulate 186 bbls at 3 bbls per minute, 1200 psi surface pressure. 71 bbls fluid Toss. Check flow. Pick up 160k Ibs to unset packer. (Rig pumps tripped out multiple times while pressuring up to fire guns.) Page 26of39 • ''''11‘1 . Phase Cole . ,Subco 'e T �. .44C. nt �. 10:00 11:00 1.00 7,005 7,005 COMPZ RPCOM CIRC P POOH with drill pipe from 6355' - 6282' MD. Circulate bottoms up at 6 bbls per minute, 635 psi surface pressure. 21 bbls fluid loss. Check for flow. 11:00 15:30 4.50 7,005 7,005 COMPZ RPCOM TRIP P POOH with drill pipe from 6280' - 1414' MD. 15:30 17:30 2.00 7,005 7,005 COMPZ RPCOM OWFF P Gas bubbling. Shut well in. No pressure. Open and monitor well. 17:30 19:00 1.50 7,005 7,005 COMPZ RPCOM TRIP P POOH. Remove RA marker and lay down packer assembly. 19:00 23:30 4.50 7,005 7,005 COMPZ RPCOM TRIP P Hold PJSM. Lay down TCP guns. 23:30 00:00 0.50 7,005 7,005 COMPZ RPCOM OWFF P Monitor well. Clean rig floor. 07/09/2008 Change upper pipe rams to 7" and test. RU e-line. Run bullnose and tag at 6452'. Run GR/JB and tag at 6320'. TIH with bit and string mill to 5438' MD. POOH. Chance upper pipe rams to 2 -7/8" x 5" VBR. 00:00 00:30 0.50 7,005 7,005 COMPZ RPCOM OWFF P Monitor well for flow. Hole losing 4.5 bbls per hour._ 00:30 02:30 2.00 7,005 7,005 COMPZ RPCOM NUND P Close blind rams. Change upper pipe rams to 7 ". Pull wear bushing. 02:30 05:30 3.00 7,005 7,005 COMPZ RPCOM SFEQ P Test upper pipe rams to 250/3500 psi. Lay down test equipment and install wear bushing. 05:30 13:00 7.50 7,005 7,005 COMPZ RPCOM SLKL P Hold PJSM. RU Schlumberger. EIH with bullnose on a -line and tag at 6452' MD. POOH. RIH with gauge ring/junk basket (5.9375" OD gauge) . Tagq 6320' MD. POOH and RD a -line. RD lubricator. 13:00 18:30 5.50 7,005 7,005 COMPZ RPCOM TRIP T MU bit and string mill. TIH with 4 stands of HWDP and DP to 5438' MD. 18:30 22:30 4.00 7,005 7,005 COMPZ RPCOM TRIP T POOH from 5438' to surface. (POOH to change upper pipe rams.) 22:30 00:00 1.50 7,005 7,005 COMPZ RPCOM NUND P Hold PJSM. Pull wear ring. Change upper pipe rams from 7" to 2 -7/8" x 5" variable rams. 07/10/2008 Test upper VBR to 250/3500 psi. RIH with bit and string mill. Rotate from 6198' - 6400' MD. Tag bottom at 6444' MD. POOH. Safety stand down. Install 7" rams and test to 250/3500 psi. Run sump packer on e -line. 00:00 01:30 1.50 7,005 7,005 COMPZ RPCOM SFEQ P Test upper VBR to 250/3500 psi. RD test equipment. Install wear bushing. 01:30 07:00 5.50 7,005 7,005 COMPZ RPCOM TRIP P MU bit and string mill. TIH with 4 stands of HWDP and DP. Rotate down from 6198' - 6400' at 50 RPM. 5k torque. PU 95k, SO 75k, Rot 85k. Tag bottom�t 6444' MD. , 07:00 12:00 5.00 7,005 7,005 COMPZ RPCOM TRIP P POOH from 6444' - 5251' MD. Check well for flow. POOH from 5251' - 954' MD. 12:00 13:30 1.50 7,005 7,005 COMPZ RPCOM SFTY P Safety stand down. 13:30 15:30 2.00 7,005 7,005 COMPZ RPCOM TRIP P POOH from 954' - surface. Lay down string mill, bit sub, bit, and XO's. Clean off rig floor. Page, 27 of 39 • Time L. Date From To Dur S. tenth. E »ICE Phase, Sutaoode T Cora t 15:30 16:30 1.00 7,005 7,005 COMPZ RPCOM NUND P Hold PJSM. Pull wear ring. Rig up to circulate annulus through choke. Change top pipe rams to 7 ". 16:30 17:30 1.00 7,005 7,005 COMPZ RPCOM NUND T Door seal failure. Change out top pipe rams door seal. 17:30 19:30 2.00 7,005 7,005 COMPZ RPCOM NUND P Make up lubricator for test joint. Test top pipe ram to 250/3500 psi. Rig down test joint to use as lubricator. 19:30 00:00 4.50 7,005 7,005 COMPZ RPCOM PACK P Hold PJSM. PU lubricator. RU Schlumberger and RIH with sump packer on e-line. 07/11/2008 Set sump packer at 6370' MD. Change upper pipe rams to 2 -7/8' x 5 " VBR and test to 250/5000 psi. Make up gravel pack screens, gravel pack packer, and begin TIH on DP. 00:00 03:30 3.50 7,005 6,370 COMPZ RPCOM PACK P RIH with sump packer. Set packer, at 6370' MD. RD Schlumberger. Lay down lubricator. 03:30 04:30 1.00 6,370 6,370 COMPZ RPCOM RURD P , Channe upper pipe rams from 7" to 2 -7/8" x 5" VBR., 04:30 06:00 1.50 6,370 6,370 COMPZ RPCOM SFEQ P Test upper VBR to 250/5000 psi. Remove wear bushing. Set wear ring. 06:00 09:00 3.00 6,370 6,370 COMPZ RPCOM RURD P Rig up gravel pack assembly tools. 09:00 09:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P Hold PJSM for running gravel pack equipment. 09:30 17:00 7.50 6,370 6,370 COMPZ RPCOM TRIP P Pick up and RIH with Baker gravel pack screens. 17:00 20:00 3.00 6,370 6,370 COMPZ RPCOM TRIP P Pick up and RIH with 2 -7/8" inner string. 20:00 20:30 0.50 6,370 6,370 COMPZ RPCOM TRIP P Pick up gravel pack packer. Attempt to make up packer and blank pipe - unsuccessful. Baker did not send out shear out safety joint or XO for 4" pin x5 "box. 20:30 22:30 2.00 6,370 6,370 COMPZ RPCOM WOEQ T Wait on shear out safety joint from Baker. Helicopter joint out to rig. 22:30 23:30 1.00 6,370 6,370 COMPZ RPCOM TRIP P Complete make up of the packer assembly. 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM TRIP P RU to TIH with 4" DP. Pick up and run Stand #1. Drift to 2.31". 07/12/2008 TIH with gravel pack screens to 6350'. Circulate. Space out and tag sump packer. Snap into sump packer. Unlatch from sump packer. Set 5k on packer and drop ball. Set gravel pack packer. Reverse circulate two string volumes. Wait on BJ equipment and troubleshoot. 00:00 07:00 7.00 6,370 6,370 COMPZ RPCOM TRIP P TIH with 4" DP from 1324' - 6350'. Rabbit every stand out of derrick. 07:00 07:30 0.50 6,370 6,370 COMPZ RPCOM CIRC P Circulate at 6350' at 3 bbls per, minute, 225 psi surface pressure to ensure ball seat and DP are clear. 07:30 08:00 0.50 6,370 6,370 COMPZ RPCOM RURD P Hold PJSM. Change out handling equipment to long bales. Page; 28 of 39 • Time Logs �\ [Tate Ft. T'. ; • _ �* ° -‘ w Cod ..fie T •: rent : „ E: 08:00 10:00 2.00 \ 6,370 6,370 COMPZ • • • P Space out to tag sump packer. Up weight 110k, down weight 86k. Add 10' pup joint. Tagged packer at 6387' MD. Set down 10k to verify packer location. Overpull 10k to unlatch. Set down 10k to snap into sump packer. PU to leave 5k set down on packer. Drop 1.75" Bakerlite ball. 10:00 14:00 4.00 6,370 6,370 COMPZ RPCOM - Hold PJSM. RU BJ hard lines. 14:00 14:30 0.50 6,370 6,370 COMPZ RPCOM Hold PJSM on gravel pack job. COMPZ 14:30 16:00 1.50 6,370 6,370 - • • - Test BJ hard lines. • :00 17:30 1.50 6,370 6,370 COMPZ RPCOM Set gravel pack packer. Pull test. Release from X -O. Strip through bag to reverse circulating position. COMPZ 17:30 18:30 1.00 6,370 6,370 - • Reverse circulate two string volumes. COMPZ 18:30 21:00 2.50 6,370 6,370 • • • T Unable to obtain blender output rate on BJ equipment. Troubleshoot equipment. Helicopter part to rig. COMPZ 21:00 00:00 3.00 6,370 6,370 • • T Part arrived at rig. Installation complete by BJ. Continuing to trouble • • • • .1- a . • I : • - - •ack blending equipment. 17/13/2008 Allow BJ gravel pack crew to rest. Perform gravel pack. Did not sandout. Mix CaCl2. Perform second gravel pack. Sanded out. Restressed gravel pack. Reversed out. POOH to above KIOV. KIOV closed. Circulate well. 00:00 01:30 1.50 6,370 6,370 COMPZ RPCOM SFEQ T Continue to troubleshoot problems with gravel pack blending equipment. Repair same. 01:30 07:00 5.50 6,370 6,370 COMPZ RPCOM WOP NP Allow BJ personnel time to sleep. (BJ personnel had been up and working for 20 hours straight.) 07:00 09:00 2.00 6,370 6,370 COMPZ RPCOM RURD P BJ personnel arrive back on rig. Finish RU equipment for gravel pack operations. 09:00 10:30 1.50 6,370 6,370 COMPZ RPCOM GRVL P Hold PJSM. Verify circulation in reverse position. Verify circulation in circulating position. Pressure test BJ lines to 8500 psi. Good test. 10:30 12:00 1.50 6,370 6,370 COMPZ RPCOM GRVL P Pump high rate water pack with BJ, Pump 912 bbls 10.2 ppg suction fluid at rates as high as 14.2 bbls per minute. Pump 30k lbs 20/40 sand. Maintain 25 - 30% return rate. No jndication of sandout - ran out of sand. Shut down to reload BJ with sand and mix more CaCl2 fluid. Final pump rate 11.9 bbls per minute at 1390 psi. Overflush workstring two volumes to ensure resuming the second stage gravel pack later. 12:00 17:30 5.50 6,370 6,370 COMPZ RPCOM GRVL P Mixing 10.2 ppg CaCl2 fluid. Page 29 of 3 1 ate . From .Try' tour Depth E. Depth Phase Su Te ment 17:30 20:00 2.50 6,370 6,370 COMPZ RPCOM GRVL P Pump high rate water pack with BJ. Pump 428 bbls 10.2 ppg suction fluid at 8 bbls per minute at 1300 psi. Pump 31.4k Ibs 20/40 sand. Maintain 25 - 30% return rate. Final pump parameters 4.4 bbls per minute at 1090 psi with no returns. Again ran out of sand but sanded out with 4900 psi during the flush. Restress to 2600 psi. Reversed approximately 6k Ibs of sand out the drillipipe. 20:00 21:30 1.50 6,370 6,370 COMPZ RPCOM GRVL P RD BJ lines and valves from rig floor. Lay down elevators. Change out bales. RU elevators. 21:30 22:30 1.00 6,370 6,370 COMPZ RPCOM TRIP P POOH from 5162' - 3917' MD. Hole took 63 bbls of fluid over displacement during trip. Pull above KIOV. Valve closed. 22:30 23:30 1.00 6,370 6,370 COMPZ RPCOM OWFF P Monitor well for losses. No losses. 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM CIRC P Well U-tubing. Screw into drill pipe and circulate at 4 bbls per minute. X7/14/2008 Circulate 2 BU's to balance well. POOH with drill pipe. Laydown 2 -7/8 ", P -110 tubing. RIH with 2 -7/8 ", L -80 tubing isolation string on 4" drill pipe. Could not break KOIV. POOH with tubing isolation string. 00:00 01:30 1.50 6,370 6,370 COMPZ RPCOM CIRC P Circulate two bottoms up at 5145' MD 4 bbls per minute, 240 psi. Monitor well. Well static 01:30 04:30 3.00 6,370 6,370 COMPZ RPCOM TRIP P POOH with 4" DP from 5 145' 1229' MD. 04:30 08:30 4.00 6,370 6,370 COMPZ RPCOM TRIP P Hold PJSM. RU Weatherford. POOH and lay down 2 -7/8 ", P -119 Hydril 511 pipe from 1229' tot surface. 08:30 09:30 1.00 6,370 6,370 COMPZ RPCOM PULD P Prep to pick up 2 -7/8 ", L -80 tubing and seal assembly. 09:30 14:30 5.00 6,370 6,370 COMPZ RPCOM RCST P RIH with 2 -7/8 ", 6.4#/ft, L -80 tubing, seal assembly, packer assembly; and sliding seal assembly. Torque all connections to 1000 ft-Ibs. Drift to 2.31 ". 14:30 15:00 0.50 6,370 6,370 COMPZ RPCOM PULD P Lay down bails and elevators for 2 -7/8" tubing. PU bails and elevators for 4" drill pipe. 15:00 18:30 3.50 6,370 6,370 COMPZ RPCOM RCST P RIH with packer on 4" drill pipe to 5169' MD. 18:30 19:30 1.00 6,370 6,370 COMPZ RPCOM SFEQ P RU to BJ pumping unit. Test lines. Circulate 5 bbls of 10.2 ppg fluid to make sure pipe is clear. 19:30 23:00 3.50 6,370 6,370 COMPZ RPCOM RCST P RIH to packer. Tag top of packer. Took several attempts to get past packer. TIH to KOIV. Made several attempts to break flapper valve. Unsuccessful. 23:00 00:00 1.00 6,370 6,370 COMPZ RPCOM TRIP T POOH with drill pipe at 3 minutes per stand from KOIV to 4209' MD. Page, 30 of 39 1 • [ r From To .Duo* S. Depth L.'' =Depth Phase Code SUb s e ` N. ommi N 4 07/15/2008 24 hr Summary Finish POOH and lay down 2 -7/8" isolation assembly. Wait on "Harpoon" assembly. Make up Harpoon assembly and run in the hole. Sting into top of packer at 5162.35' and Iocatio KOIV. Spud on KOIV without success. Circulate on top of KOIV and continue spuddingon KOIV. Rig up BJ and set 25,000 lbs on KOIV. Pressure up to 4000 psi without success. Bleed off pressure and pressure up to 4500 psi without success. Rig down BJ and pull one stand. Circulate bottoms ua and POOH to 3766. 00:00 02:30 2.50 6,370 6,370 COMPZ RPCOM TRIP T POH with 4" DP from 4209' to 1252'. Monitor well. Static. 02:30 03:00 0.50 6,370 6,370 COMPZ RPCOM RURD T RU 2 7/8" tbg equipment. 03:00 05:00 2.00 6,370 6,370 COMPZ RPCOM PULD T POH LD 2 7/8" isolation assembly 05:00 15:30 10.50 6,370 6,370 COMPZ RPCOM TRIP T Aircraft unable to leave Kenai with flapper spear due to fog. 15:30 16:00 0.50 6,370 6,370 COMPZ RPCOM PULD T Make up "Harpoon Assembly" 16:00 17:00 1.00 6,370 6,370 COMPZ RPCOM WOEL T Wait on telecom personnel to install equipment at crown 17:00 19:30 2.50 6,370 6,370 COMPZ RPCOM TRIP T Trip in hole with Harpoon assembly to 5162' 19:30 20:00 0.50 6,370 6,370 COMPZ RPCOM TRIP T Sting into top of Packer at 5162.35' and locate KOIV 20:00 21:00 1.00 6,370 6,370 COMPZ RPCOM OTHR T Spud on KOIV with "harpoon assembly" attempting to break KOIV 21:00 22:30 1.50 6,370 6,370 COMPZ RPCOM OTHR T - Safety Meeting. Rig up BJ and pressure up on KOIV to 4000 psi with 25,000 lbs weight on "Harpoon ". Hold pressure for 10 minutes. Bleed off pressure and spud on KOIV. Pressure up again to 4500 psi with 25,000 lbs weight on "Harpoon" and hold for ten minutes without _such Bleed off pressure. 22:30 23:00 0.50 6,370 6,370 COMPZ RPCOM RURD T Rig down head pin and pull 1 stand 23:00 23:30 0.50 6,370 6,370 COMPZ RPCOM CIRC T Circulate bottoms up 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM TRIP T Trip out of the hole to 3766'. 07/16/2008 POOH with "Harpoon" assembly. Cut and slip drilling line. Make up muleshoe and RIH. Wash off KOIV and break disc. POOH. Make up 2 -7/8" isolation assembly and RIH. 00:00 03:00 3.00 6,370 6,370 COMPZ RPCOM TRIP T POH with 4" DP from 3766'. 03:00 03:30 0.50 6,370 6,370 COMPZ RPCOM PULD T LD 1 jt 2 7/8" tbg and spear sub. 03:30 06:00 2.50 6,370 6,370 COMPZ RIGMNT SVRG P PJSM. Slip and cut drilling line. Calibrate blocks. 06:00 06:30 0.50 6,370 6,370 COMPZ RPCOM PULD T MU 1 jt 2 7/8" tbg, pup joint and muleshoe 06:30 08:30 2.00 6,370 6,370 COMPZ RPCOM TRIP T Trip in hole to 5103' 08:30 09:30 1.00 6,370 6,370 COMPZ RPCOM OTHR T Work throuah top of clacker Cal 5171' dpm. Circulate at 13 bpm @ 2650 psi to clean off top of KOIV @ 5203'. Work down to break KOIV. Losing 80 bph. Pick up to 5163' and spot 25 bbl HEC pill. 09:30 11:00 1.50 6,370 6,370 COMPZ RPCOM CIRC I Mo itor well: losing 40 bph. Mix 25 bbl HEC pill • Page 31 of 3 • Time'Logs > \� v. From Dur 8 E,u . a 11 :00 12:30 1.50 6,370 6,370 COMPZ \ RPCOM CIRC T Spot 25 bbl HEC pill at 5163' and monitor losses. Losing 15- 18 bph 12:30 13:00 0.50 6,370 6,370 COMPZ RPCOM TRIP T POOH to 4820' 13:00 13:30 0.50 6,370 6,370 COMPZ RPCOM CIRC T Circulate at 3 bpm 13:30 16:30 3.00 6,370 6,370 COMPZ RPCOM TRIP T POOH and lay down muleshoe 16:30 17:30 1.00 6,370 6,370 COMPZ RPCOM RURD T Pick up beckett bales and tubing tongs. 17:30 20:00 2.50 6,370 6,370 COMPZ RPCOM PULD T Pick up 2 -7/8" isolation assembly • and packer 20:00 20:30 0.50 6,370 6,370 COMPZ RPCOM OTHR T Safety meeting on rabbiting pipe out of the derrick. Rig up rabbit 20:30 00:00 3.50 6,370 6,370 COMPZ RPCOM TRIP T Trip in hole with isolation assembly on d pipe. 07/17/2008 Run in hole with isolation assembly on drillpipe. Space out and latch into top of packer. Test lines to 5000 psi and drop primary setting ball. Ball not on seat. Drop back up ball and set packer. Verify packer set. Pressure test annulus to 500 psi -OK. Release running tool and reverse out back up setting ball Displace well to freshwater and monitor well for 30 minutes- static. Displace well with 8.6 ppg KC l brine and pull out of the hole with setting tool. Pull wear ring and set test plug. Test BOPE 00:00 03:00 3.00 6,370 6,370 COMPZ RPCOM TRIP T RIH w/ isolation assembly on 4" DP to 6310'. ( Drift all DP while RIH) 03:00 03:30 0.50 6,370 6,370 COMPZ RPCOM TRIP P Space out DP. Latch into pkr at 5162'. Snap out. RU BJ and lines. 03:30 03:45 0.25 6,370 6,370 COMPZ RPCOM SFTY P PJSM on setting pkr with BJ. 03:45 05:30 1.75 6,370 6,370 COMPZ RPCOM PACK P BJ tested lines to 5000 psi. Pump down 1 7/16" ball with BJ. Ball would not seat. RD 2" lines. RU ball catcher. 05:30 07:30 2.00 6,370 6,370 COMPZ RPCOM PACK P n " J Seated Pump dow ball Pressure 1 3/4ball DP with to B 1 psi /5 min - 2500 psi /5 min - 3100 psi /5min to set pkr. Perform push /pull test on pkr to confirm set. OK. Pressure annulus to 500 2 min. OK. Rotate 20 turns to right to release setting tool from pkr. 07:30 09:00 1.50 6,370 6,370 COMPZ RPCOM CIRC P PU to 5137'. Reverse circ out 1 3/4" ball at 6 bpm - 980 psi. Displace well to FW at 13 bpm - 2300 psi. Monitor well. Static. 09:00 12:30 3.50 6,370 6,370 COMPZ RPCOM OTHR P Empty and clean pits. Fill pits with clean 8.6+ 6% KCL brine. 12:30 14:30 2.00 6,370 6,370 COMPZ RPCOM CIRC P Displace well with 8.6+ brine at 6 bpm - 525 psi. Clean and fill trip tank. 14:30 17:00 2.50 6,370 6,370 COMPZ RPCOM TRIP P Pull out of hole from 6362'. Laydown packer setting tool 17:00 18:30 1.50 6,370 6,370 COMPZ RPCOM RURD P Make up wear ring puller and pull wear ring. Make up test joint and floor valves to topdrive 18:30 19:00 0.50 6,370 6,370 COMPZ WELCTL BOPE P Fill stack and circulate through c mani Page 32 of 39 • (p rom s , o ur S. Depth . E: �3 \Pha Code Se T Comment 19:00 00:00 5.00 6,370 6,370 COMPZ WELCTL BOPE P Test choke manifold, floor valves, top pipe rams, kill line valves, HCR IBOP's to 250/5000 psi. Test hydril and lower pipe rams to 250/3500 psi. R/D test joint. Tom Maunder, AOGCC, waived witnessing the test on 7/17/2008. 07/18/2008 Finished testing BOPE. Picked up TCP guns and packer and ran in the hole. Rigged up lines, set plug in lower gravel pack and set packer. Perforated per program. Reversed out and monitored well. Rigged down lines and prepped to pull out of the hole. 00:00 04:30 4.50 6,370 6,370 COMPZ WELCTL BOPE P Finished testing BOPE. Tom Maunder, AOGCC, waived witnessing the test 04:30 05:30 1.00 6,370 6,370 COMPZ WELCTL OTHR P Lay down test joint and rig down test pump. Install wear ring (6 -3/8" I.D.) 05:30 06 :30 1.00 6,370 6,370 COMPZ RPCOM RURD P Rig up floor and prep to pick up perforating guns 06:30 07:00 0.50 6,370 6,370 COMPZ RPCOM SFTY P Safety meeting on picking up and running perforating guns 07:00 12:30 5.50 6,370 6,370 COMPZ RPCOM PULD P Pick up 4 -5/8" 14 spf perforating guns, omni valve, RA tang and Champ packer 12:30 17:00 4.50 6,370 6,370 COMPZ RPCOM TRIP P Trip in the hole with perforating guns on 4" drill pipe 17:00 17:30 0.50 6,370 6,370 COMPZ RPCOM OTHR P Tag packer and space out 17:30 18:30 1.00 6,370 6,370 COMPZ RPCOM RURD P Pick up 10' pump and single. Make up head pin and rig up hose from head pin to choke manifold 18:30 22:00 3.50 6,370 6,370 COMPZ RPCOM PERF P Safety meeting, Set packer and fired, guns per program. 22:00 23:00 1.00 6,370 6,370 COMPZ RPCOM CIRC P Reversed out. f ok 22.5 bbl to get returns at shakers. Reversed 2 x surface to surface at 2.3 bpm, 1250 psi. 23:00 23:30 0.50 6,370 6,370 COMPZ RPCOM OTHR P Monitored well. Losing 5 bph. 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM RURD P Rig down headpin, valves and hoses. Lay down single and 10' pup. 07/19/2008 Pull out of hole and lay down perforating guns. Make up milling /cleanout BHA and run in the hole. Rotate through perforations from 3650' to 5129' without circulating. Break circulation and tag plug at 5144'. Circulate bottoms up and had gas to surface. Circulate through open choke. 00:00 01:00 1.00 6,370 6,370 COMPZ RPCOM TRIP P POH from 5119' to 4737'. Had increase in flow and improper hole fill. 01:00 01:30 0.50 6,370 6,370 COMPZ RPCOM OWFF P Monitor well. Well was flowing. Shut well in. 0 psi on annulu and drill pipe. 01:30 02:00 0.50 6,370 6,370 COMPZ RPCOM SFTY P PJSM on circulating well through choke. 02:00 03:00 1.00 6,370 6,370 COMPZ RPCOM CIRC P Circulate bottoms up through choke at 3 bpm 140 psi. Check flow. Static. Open annular. Well is static. 03:00 06:00 3.00 6,370 6,370 COMPZ RPCOM TRIP P POH from 4737' to 1775'. 06:00 06:30 0.50 6,370 6,370 COMPZ RPCOM OWFF P Monitor well. Gun gas perculating at surface. No fluid gain. Page 33 of 3 • Time Logs: Date ..:'... From To Dur S. Depth E. Depth Phi Code Sdbc de ,• . f Comment nt 06:30 07:00 0.50 6,370 6,370 COMPZ RPCOM TRIP P POH from 1775' to 1492'. 07:00 07:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P PJSM with all personnel on laying down TCP guns. 07:30 14:00 6.50 6,370 6,370 COMPZ RPCOM PULD P_ POH LD TCP guns. All shots fired. 14:00 15:00 1.00 6,370 6,370 COMPZ RIGMNT SVRG P Service rig and replace fall protection device in derrick 15:00 16:00 1.00 6,370 6,370 COMPZ RPCOM PULD P Pick up mills and scraper assembly 16:00 18:00 2.00 6,370 6,370 COMPZ RPCOM TRIP P Trip in hole with HWDP to 410' 18:00 20:00 2.00 6,370 6,370 COMPZ RPCOM TRIP P Trip in hole with milling assembly to 3650' 20:00 23:00 3.00 6,370 6,370 COMPZ RPCOM FCO P Ream through perforation without i circulating from 3650' to 5129' 23:00 23:30 0.50 6,370 6,370 COMPZ RPCOM TRIP P Tag fill at 5144' dpm. • 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM CIRC P Circulate. Had gas to surface on bottoms up. Circulate through choke 07/20/2008 Circulate and filter fluid. POOH and laydown mills. Make up Cavins baler and plug plucker and RIH. Decision made to leave plug in place and surge perforations. POOH and laydown Cavins equipment. Make up packer and Omni valve and run in the hole to 1000'. Set packer and attempt to cycle Omni - valve. Running in the hole 00:00 01:00 1.00 6,370 6,370 COMPZ RPCOM CIRC P Continue CBU through choke. Check flow at gas buster. No flow. Open annular. Monitor well. Minor losses. 01:00 01:30 0.50 6,370 6,370 COMPZ RPCOM OTHR P Clean pits to take on clean brine. 01:30 02:00 0.50 6,370 6,370 COMPZ RPCOM CIRC P Circulate at 5 bpm - 805 psi. Filter brine. Return NTU - 12. 02:00 03:30 1.50 6,370 6,370 COMPZ RPCOM TRIP P POH from 5143' to 30'. 03:30 04:00 0.50 6,370 6,370 COMPZ RPCOM PULD P PJSM. LD mill assembly. 04:00 05:00 1.00 6,370 6,370 COMPZ RPCOM OTHR P Clean and clear rig floor. Bring Cavins tools to rig floor. 05:00 07:00 2.00 6,370 6,370 COMPZ RPCOM PULD P MU Cavins bailer assembly to 1264'. 07:00 08:30 1.50 6,370 6,370 COMPZ RPCOM TRIP P RIH with 4" DP from 1264' to 4232'. 08:30 10:30 2.00 6,370 6,370 COMPZ RPCOM WOOR X Stand by for change in scope decision. 10:30 11:00 0.50 6,370 6,370 COMPZ RPCOM TRIP X RIH from 4232' to 5085'. 11:00 12:30 1.50 6,370 6,370 COMPZ RPCOM CIRC X CBU at 5.5 bpm and 650 psi 12:30 13:00 0.50 6,370 6,370 COMPZ RPCOM OWFF X Monitor well 13:00 13:30 0.50 6,370 6,370 COMPZ RPCOM CIRC X Circulate @ 5.5 bpm and 650 psi 13:30 15:30 2.00 6,370 6,370 COMPZ RPCOM TRIP X POOH 15:30 17:00 1.50 6,370 6,370 COMPZ RPCOM PULD X Laydown Cavins plug plucker and I baler. Clear rig floor 17:00 20:00 3.00 6,370 6,370 COMPZ RPCOM WOEQ X Wait on packer and Omni valve 20:00 21:00 1.00 6,370 6,370 COMPZ RPCOM PULD X Pick up Champ packer, jars and Omni -valve 21:00 22:00 1.00 6,370 6,370 COMPZ RPCOM TRIP X Trip in hole to 1000' Page 34 of 39 • Ti Logs :. ; , A To put'' .. S. Depth E. Depth Phase Code Subcodoe T Comment l 22:00 23:00 1.00 6,370 6,370 COMPZ RPCOM OTHR X Set packer at 992.15' Cycle Omni valve with not indication that it opened. Unseat packer. 23:00 00:00 1.00 6,370 6,370 COMPZ RPCOM TRIP X Trip in hole with papcker assembly to 2614' 07/21/2008 Attempt to cycle Omni -valve without success. Pull out of the hole and check Omni - valve. RIH with packer and Omni - valve. Set packer at 3698' Open Omni -valve and surge perforations. Fluid losses increased to 18 bph. Rig down TIW valve and rig up slickline. Run CCL/memory tool on slick line. Tag fill at 4615. Lossed decreased to 8 bph. R/D slickline and circulate bottoms up. POOH at 2900'. 00:00 00:30 0.50 6,370 6,370 COMPZ RPCOM TRIP X RIH from 2614' to 3660'. 00:30 02:00 1.50 6,370 6,370 COMPZ RPCOM PACK X Set Halliburton pkr at 3660'. Attempt to cycle Omni vavle to the circ u W position with no success. Unset pkr. - Monitor well. Static. 02:00 05:00 3.00 6,370 6,370 COMPZ RPCOM TRIP X POH w/ 4" DP. 05:00 06:00 1.00 6,370 6,370 COMPZ RPCOM PULD X PJSM. LD jars, pkr and Omni valve. 06:00 06:30 0.50 6,370 6,370 COMPZ RIGMNI SVRG X Service top drive, crown and drawworks. 06:30 09:30 3.00 6,370 6,370 COMPZ RPCOM TRIP X Wait on Halliburton service tools to arrive from Kenai. Surface test Omni tool. OK. 09:30 10:00 0.50 6,370 6,370 COMPZ RPCOM PULD X PJSM. MU champ pkr, jars and Omni valve. 10:00 12:30 2.50 6,370 6,370 COMPZ RPCOM TRIP X RIH w/ 4" DP to 3668'. 12:30 13:30 1.00 6,370 6,370 COMPZ RPCOM TRIP X PU 1 single. Make up TIW and head pin. Set pkr at 3699'. 13:30 15:00 1.50 6,370 6,370 COMPZ RPCOM RURD X RU to reverse circulate through choke manifold and gas buster. RU BJ to annulus. 15:00 15:30 0.50 6,370 6,370 COMPZ RPCOM OTHR X Pump down annulus to shift Omni valve with BJ. Pick up and unseat packer. Reverse out with rig pump 15:30 16:30 1.00 6,370 6,370 COMPZ RPCOM OWFF X Open annular and monitor well. Well _taking 18 bph 16:30 18:30 2.00 6,370 6,370 COMPZ RPCOM RURD X Rig down TIW valve and BJ. R/U slickline 18:30 22:00 3.50 6,370 6,370 COMPZ RPCOM SLKL X RIH with CCL memory log. Tag fill at 4615' slickline measurement. POOH at 60 fpm. R/D slickline. Lossed decreased to 8 bph. 22:00 22:30 0.50 6,370 6,370 COMPZ RPCOM CIRC X Circulate 22:30 00:00 1.50 6,370 6,370 COMPZ RPCOM TRIP X Trip out of the hole with packer to 2900' 07/22/2008 Pull out of the hole and lay down packer and Omni - valve. Run in with openended drill pipe and reverse out sand and pert debris from 4585' to 5145'. Losing 18 bph. Pull out of the hole and make up Cavins bailer and plug plucker. Run in the hole and tag fill at 5143'. Wash to 5152'. Latch plug and pull free. Pull out of the hole and lay down bailer and plug. Rig up and run 245' of gravel pack screen at report time. 00:00 01:00 1.00 6,370 6,370 COMPZ RPCOM TRIP X Pull out of the hole from 2109' 01:00 01:30 0.50 6,370 6,370 COMPZ RPCOM PULD X Lay down packer and Omni -valve assembly 01:30 02:30 1.00 6,370 6,370 COMPZ RPCOM OTHR X Clear floor Page 35 of 39 • • Time L y Date From To Dur E, Depth Phase Code : Mode T Comment 02:30 04:00 1.50 6,370 6,370 COMPZ RPCOM TRIP X Run in the hole with open ended drill pipe to 4585' Tagged bridge 04:00 07:00 3.00 6,370 6,370 COMPZ RPCOM FCO X Rig uo and reverse out fill to 5145', Tagged hard spots at 4570' and 4720'. Tagged plug at 5145'. Circulate 2 tubing volumes 07:00 07:30 0.50 6,370 6,370 COMPZ RPCOM OWFF X Monitor well. Losses of 18 bph 07:30 08:30 1.00 6,370 6,370 COMPZ RPCOM CIRC X Circulate and clean surface fluid system of sand and perf debris 08:30 10:30 2.00 6,370 6,370 COMPZ RPCOM TRIP X Trip out of hole. Monitor well -minor losses 10:30 11:00 0.50 6,370 6,370 COMPZ RPCOM PULD X Clear rig floor. 11:00 12:00 1.00 6,370 6,370 COMPZ RPCOM PULD P Make up Cavins bailer and plug plucker 12:00 15:30 3.50 6,370 6,370 COMPZ RPCOM TRIP P Trip in hole with bailer. Losses approximatley 10 -15 bph. Tag fill at 5143'. Wash down and tag plug at 5152'. Latch plug and pull free. Monitor well- losing 12 bph. 15:30 21:00 5.50 6,370 6,370 COMPZ RPCOM TRIP P Pull out oflne K51e with bailer. Losing 12 bph. 21:00 23:30 2.50 6,370 6,370 COMPZ RPCOM OTHR P Layd down bailer and plug. Recovered 10 gallons of perf debris and sand in baler. Rig up floor to run screens 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM PULD P Make up and run in the hole with 245' of gravel pack screens. 07/23/2008 Picked up 4" gravel pack screens and 2 -7/8" and 1.9" inner strings. Attempted to pressure test seal assemblies in 2 -7/8" x 1.9" annulus without success. Pulled out of the hole with 25 joints of 1.9" inner string and reran applying teflon tape to the threads. Retested seal assemblies OK. make up top packer and run in the hole with gravel pack screens. 00:00 00:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P Prejob safety meeting on picking up screens 00:30 04:30 4.00 6,370 6,370 COMPZ RPCOM SCRN P Pick up gravel pack screens. Torque connections to 3600 ft-Ibs 04:30 08:00 3.50 6,370 6,370 COMPZ RPCOM SCRN P Pick up 2 -7/8" inner string. 08:00 09:00 1.00 6,370 6,370 COMPZ RPCOM SCRN P Space out 2 -7/8" seal assembly 09:00 11:00 2.00 6,370 6,370 COMPZ RPCOM SCRN P Pick up 1.9" Hydril inner string 11:00 14:30 3.50 6,370 6,370 COMPZ RPCOM DHEQ P Rig up and test 2 -7/8" inner string to 5000 psi. Test failed 14:30 16:30 2.00 6,370 6,370 COMPZ RPCOM PULD T Pull 25 joints of 1.9" Hydril tubing 16:30 19:30 3.00 6,370 6,370 COMPZ RPCOM SCRN T Pre job safety meeting. Run in the hole with 25 joints of 1.9" Hydril tubing applying teflon tape to the threads. Space out and test seals to 5000 psi -OK. 19:30 23:30 4.00 6,370 6,370 COMPZ RPCOM SCRN P Space out. Make up packer and run screens on 1 stand of drill pipe. Test ball checks -OK 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM SCRN P Trip in hole with screen assembly on drill pipe at 3 min /std. from 1449' to 1830'. Page 36 of 39 1 • Time La9s Date From To Dur 07/24/2008 24 hr Summary Run gravel pack screens on drillpipe to 5151'. Rig up and set packer. Rig up gravel pack head and lines. Verify seal on inner string were properly spaced out. Attempt to test cementing unit at 4500 psia and 5.5 bpm without success. Horsepower rating of cementing unit exceeded. Wait on additonal fittings and rig up frac skid to reverse out. 00:00 01:00 1.00 6,370 6,370 COMPZ RIGMNT SVRG P Service rig, top drive and crown 01:00 07:30 6.50 6,370 6,370 COMPZ RPCOM SCRN P Trip in hole with gravel pack screens to 5151' 07:30 08:00 0.50 6,370 6,370 COMPZ RPCOM DHEQ P Set down 15K to verify packer depth. Pick up 15K over to snap out of packer. Set 10 down on packer and picked up 5K to leave 5K compression on packer 08:00 09:00 1.00 6,370 6,370 COMPZ RPCOM RURD P Rig up gravel pack manifold and lines 09:00 14:30 5.50 6,370 6,370 COMPZ RPCOM OTHR P Verify lines hooked up correctly. Verify seals in seal bores of MZ Gravel Pack system in correct position 14:30 16:00 1.50 6,370 6,370 COMPZ RPCOM OTHR P Pre -job safety meeting. Test gravel pack lines to 8000 psi. Set packer with 1900 psi and test to 2500 psi.. Verify packer set by picking up 20k -OK. 16:00 00:00 8.00 6,370 6,370 COMPZ RPCOM T Attempt to test cementing unit to 4500 psi and 5.5 bpm without success. Trouble shoot cementing unit. Unit not rated to necessary horsepower. Rig up to used frac pump to reverse out. 07/25/2008 Rig up and space out gravel pack jewelry. Gravel pack perforations from 4696' to 5129' with 5599# of 20/40 sand. Reverse out and laydown 12 joints of drill pipe. Space out and gravel pack perforations from 4333' -4640' with 4887# of 20/40 sand. Reverse out and laydown 13 joints of drill pipe. Space out and gravel pack perforations from 3912' to 4241' with 4345# of 20/40 sand. 00:00 09:00 9.00 6,370 6,370 COMPZ RPCOM WOP P Clean rig and wait on BJ 09:00 10:30 1.50 6,370 6,370 COMPZ RPCOM CIRC P Circulate 2 full circulations at 2.5 bpm, 1950 psi 10:30 12:00 1.50 6,370 6,370 COMPZ RPCOM DHEQ P Establish pumping rates for gravel pack 12:00 13:00 1.00 6,370 6,370 COMPZ RPCOM GRVL P Gravel pack perforations 4696' to 5129' with 5599# 20/40 sand behind screens. 13:00 13:30 0.50 6,370 6,370 COMPZ RPCOM CIRC P Reverse out 1786# sand at 3480 psi, 13:30 15:30 2.00 6,370 6,370 COMPZ RPCOM TRIP P Rig down BJ lines. Lay down 12 joints of 4" drill pipe 15:30 18:30 3.00 6,370 6,370 COMPZ RPCOM RURD P R/U BJ lines. Space out. Test lines to 8500 psi. Test backside to 2500 psi. 18:30 19:30 1.00 6,370 6,370 COMPZ RPCOM GRVL P Gravel pack perforations from 4333' -4640' with 4887# 20/40 sand behind screens 19:30 20:00 0.50 6,370 6,370 COMPZ RPCOM CIRC P Reverse out 3484# sand at 3570 psi, 4.6 bpm 20:00 22:00 2.00 6,370 6,370 COMPZ RPCOM TRIP P Rig down BJ lines. Lay down 13 joints fo 4" drill pipe Page 37 of 39 • • Time 1... Date r m S. Depth E Death 44.50 ' Code Subcode T Comment 22:00 23:30 1.50 6,370 6,370 COMPZ RPCOM RURD P R/U BJ lines. Space out. Test lines to 8000 psi and backside to 2500 psi. 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM GRVL P Gravel pack perforatiosn from 3912' -4241' with 4345# 20/40 sand behind screens. 07/26/2008 Finished reversing out the third gravel pack. Laid down gravel pack string and drill string left in the derrick. 00:00 02:00 2.00 6,370 6,370 COMPZ RPCOM CIRC P Reverse out third gravel pack. 02:00 03:00 1.00 6,370 6,370 COMPZ RPCOM PULD P Lay down 13 joints of drill pipe 03:00 04:00 1.00 6,370 6,370 COMPZ RPCOM RURD P Rig down BJ lines and monitor losses -6 bph. 04:00 04:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P Pre job safety meeting on laying down drill pipe 04:30 08:00 3.50 6,370 6,370 COMPZ RPCOM PULD P Lay down 82 joints of 4" drill pipe. KOIV not holding loss declined from 20 BPH to 6 BPH. 08:00 08:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P Pre -job safety meeting on laying down baker equipment and inner strings 08:30 14:00 5.50 6,370 6,370 COMPZ RPCOM PULD P Lay down baker gravel pack tools, 1.9" inner string and 2 -7/8" inner string 14:00 16:00 2.00 6,370 6,370 COMPZ RPCOM RURD P Change out elevators and bales. Rig down Weatherford. Prep floor to run in hole with drill pipe out of the derrick. 16:00 18:00 2.00 6,370 6,370 COMPZ RPCOM TRIP P Trip in hole with 3086' of drill pipe. 18:00 23:00 5.00 6,370 6,370 COMPZ RPCOM PULD P Lay down 96 joints of 4" drill pipe 23:00 23:30 0.50 6,370 6,370 COMPZ RPCOM TRIP P Trip in hole with 4 stands of 4" HWDP out of the derrick 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM PULD P Lay down 4" HWDP 07/27/2008 Finished laying down remaining drill pipe and cleared floor. Rigged up and ran 4 -1/2" completion tubing., Spotted 25 bbl inhibited brine with 53 bbl clean brine. Tagged top gravel pack packer. Tested 7" x 4 -1/2" annulus to 500 psi. Sheared out of PBR and spaced out. Landed tubing hanger. Rigged up cementing united and tested to 7" x 4 -1/2" annulus to 2000 psi for 5 minute and then to 2522 psi for 30 minutes. Pressure bled to 2209 psi in 30 minutes. 00:00 02:00 2.00 6,370 6,370 COMPZ RPCOM PULD P Lay down drill pipe and collars. 02:00 02:30 0.50 6,370 6,370 COMPZ RPCOM OTHR P Pull wear ring 02:30 05:00 2.50 6,370 6,370 COMPZ RPCOM OTHR P Clear floor and rig up to run completion. Lay out jewelry on pipe racks 05:00 05:30 0.50 6,370 6,370 COMPZ RPCOM SFTY P Pre -job safety meeting on running completion string 05:30 14:30 9.00 6,370 6,370 COMPZ RPCOM RCST P Run in hole with completion string. Strap in the hole. Drift pipe out of the derrrick 14:30 15:30 1.00 6,370 6,370 COMPZ RPCOM CIRC P Spot 25 bbl inhibited brine with 53 bbl brine 15:30 16:30 1.00 6,370 6,370 COMPZ RPCOM DHEQ P Run in the hole and tag. Test seals below PBR to 500 psi. Page 38 of 39 • Time Logs �, � \,; = , \ ...: �,�� � \ \, � `\ Date Fri I To DUr S. Depth `` Depth Phi. \fie ' Subcos a T,04 riatm . , ... 16:30 19:00 2.50 6,370 6,370 COMPZ RPCOM RCST P Shear out of PBR with 25k over. Lay down 2 joints, Pick up pups, hanger and landing joint. Land tubing 19:00 22:30 3.50 6,370 6,370 COMPZ RPCOM WOP P Clear floor and wait on BJ pump operation 22:30 23:30 1.00 6,370 6,370 COMPZ RPCOM RURD P Rig up BJ and transfer brine 23:30 00:00 0.50 6,370 6,370 COMPZ RPCOM DHEQ P Test 7" x 4 -1/2" annulus to 2000 psi for 5 minutes. Test 7" x 4 -1/2" annulus to 2522 psi for 30 minutes -bled from 2522 psi to 2509 psi 07/28/2008 Finished testing 7" x 4 -1/2" annulus and rigged down BJ. Nippled down BOPE and nippled up Vetco -Gray dryhole tree. Pulled BPV and set two -way check and tested void and valve to 5000 psi for 10 minutes. Pulled two -way check and set BPV. Released rig at 1 hours 7/27/2008 to move to BUR 211 -26. 00:00 03:00 3.00 6,370 6,370 COMPZ RPCOM DHEQ P Finish testing 7" x 4 -1/2" annulus to 2500 psi. Rig down BJ and flush all service lines. Blow down all lines 03:00 10:00 7.00 6,370 6,370 COMPZ RPCOM NUND P Bleed and rig down accumulater lines. Remove flowline and bell nipple. Nipple down choke hose, kill line, check valve, annulus vale. Install pick up slings and trolley. Remove single gate, mud cross, double gate and annular 10:00 16:00 6.00 6,370 6,370 COMPZ RPCOM NUND P . Bleed pressure. Pull BPV and install 2 -way check. Test void to 5000 psi for 10 minutes. Test valve and flange to 5000 psi for 10 minutes. Install annulus valve. Pull two -way check and set BPV. Install . tree cap. Released rig at 16:00 hours. Page 39 of 3 • • BRU 243 -34 8/6/08 Revised Perf Picks (version 4) FINAL TOTAL 10206 Shots TOTAL 729 Feet Top Base Thickness Added Feet` FIRST TCP RUN Beluga H&I E -LINE PERFS 6324 6350 26 Fracture Intervals Top Bottom ft 6234 6244 10 1 y 6324 6344 20 6030 6040 10 10 2 5888 5604 16 5988 6008 20 10 2 5842 5862 ,, .10 5954 5978 24 2 5814 5832 18 5886 5910 24 \\ , 5810 5868 58 4 5402 5428 26 5770 5800 30 5734 5754 20 5682 5692 10 5650 5660 10 5614 5624 10 5594 5606 12 5546 5564 18 10 5533 5539 6 6 5469 5499 30 5402 5428 26 5380 5386 6 5319 5324 5 5294 5305 11 SECOND TCP RUN Beluga D, E, F and G 5124 5129 5 5109 5117 8 5092 5098 6 6 5026 5032 6 6 5002 5008 6 4974 4984 10 4947 4954 7 1 4865 4900 35 12 4855 4862 7 7 4821 4832 11 1 4730 4740 10 4705 4715 10 4696 4701 5 4617 4640 23 4562 4610 48 4530 4544 14 2 4333 4387 54 2 4228 4241 13 1 4146 4156 10 4076 4086 10 4046 4062 16 3976 4000 24 3944 3958 14 • 3898 3808 a-8 3833 3868 4 3848 382E 3 R ... .. . , Ins zone wilt be available in a rvorkover above the to packet at 77 Additional footage of perforations beyond the perforation plan of 06/18/08 in blue 0 • a ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 243 -34 50- 283 - 20124 -00 , Sperry Drilling . Definitive Survey Report i 23 June, 2008 P1 xp I ir HALLIBURTON Sperry Drilling Services L I 0 ConocoPhillips or its affiliates Definitive Survey Report ConocoPhillips(Alaska) Inc. Local Co -orctf R $ Well BRU 243-34 Beluga River TVD Refere$ 243 34 (16.52 +77) © 93.52ft (Nabors 129) I Beluga River MD Re er>k�, 243 -34 (16.52 +77) © 93.52ft (Nabors 129) BRU 243 -34 North R True ` CIO BRU 243 -34 � alculation Method: ,. Minimum Curvature Design BRU 243 -34 € sR EDM Alaska Prod v16 E. li,-:-,.. ..e;..... ,, . ...a...• " a.s.... „ „, ... , :14iuxao-i a........ .... .... �... , ,,, „ , E;,s:suya:nuEttnz project Beluga River, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Welts p ... BRU 243-34 Well Position +NIS 0.00 ft Northing: 2,621,038.00ft • Latitude: 61° 10' 11.937 N +E/ -W 0.00 ft Easting: 316,913.00 ft • Longitude: 151° 2' 13.244 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 77.00ft - Wrtiiboro BRU 243 -34 Mil € E Mil Name Sample x Decl is ton 1 p E F �; I Hel �[[ EE ` CNI`�F. �E F{ BGGM2007 5/28/2008 16.32 72.91 54,981 BGGM2007 5/27/2008 16.32 72.91 54,981 ISn BRU 243 ,....... -: :i l ......... -: ':. .3YzE E +EE EE ......... : ..... ;: ,. ,.; .. : ,:;: ,.. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 16.52 Vertical Sec n € Depth �r� + Nf-S W + �, t IrecttOrt iE ,,`, l z E) W 16.52 0.00 0.00 331.14 S urvey P rogram i l` EEEE E € €� 4N 4 ` tx Et �r#ftll Tie: � �E„ IR a (ft) ;' 3 (Weilb ) Toot Name Des Survey Date 106.28 6,919.36 BRU 243 -34 MWD +SCC +SAG (BRU 243 MWD +SCC +SAG MWD + Short Collar correction + BHA SAG Co 6/1/2008 12: a a d i I ,` t, t .. ',NIKE' (. E :.1m1110:::-': _ Map € I E E N E ] � idd L�' t MD Inc A�xi E WO TN E +N41 S +Ef W No l _, `€ " DLS _ f 1 ` � : , }" eft } } {ft) � ,,, �rm 16.52 0.00 0.00 16.52 -77.00 0.00 0.00 2,621,038.00 316,913.00. 0.00 0.00 UNDEFINED 106.28 0.47 132.00 106.28 12.76 -0.25 0.27 2,621,037.75 316,913.27 0.52 -0.35 MWD +SCC +SAG (1) 197.46 0.51 132.14 197.46 103.94 -0.77 0.85 2,621,037.22 316,913.84 0.04 -1.08 MWD +SCC +SAG (1) 286.06 0.58 129.32 286.05 192.53 -1.32 1.49 2,621,036.66 316,914.47 0.08 -1.87 MWD +SCC +SAG (1) 374.22 0.69 138.18 374.21 280.69 -2.00 2.19 2,621,035.97 316,915.16 0.17 -2.81 MWD +SCC +SAG (1) 466.93 0.37 18.52 466.91 373.39 -2.13 2.66 2,621,035.82 316,915.63 1.01 -3.15 MWD +SCC +SAG (1) 556.59 1.64 343.44 556.56 463.04 -0.63 2.39 2,621,037.33 316,915.38 1.51 -1.70 MWD +SCC +SAG (1) 650.00 3.99 331.08 649.85 556.33 3.50 0.43 2,621,041.49 316,913.49 2.59 2.85 MWD +SCC +SAG (1) 734.09 6.86 327.98 733.55 640.03 10.32 -3.64 2,621,048.37 316,909.52 3.43 10.80 MWD +SCC +SAG (1) 829.62 8.34 327.83 828.24 734.72 21.03 -10.36 2,621,059.18 316,902.98 1.55 23.41 MWD +SCC +SAG (1) 921.69 10.27 326.04 919.10 825.58 33.49 -18.50 2,621,071.77 316,895.03 2.12 38.26 MWD +SCC +SAG (1) 1,019.30 11.64 324.96 1,014.92 921.40 48.77 -29.02 2,621,087.22 316,884.76 1.42 56.72 MWD +SCC +SAG (1) 1,116.26 15.05 328.83 1,109.25 1,015.73 67.56 -41.16 2,621,106.20 316,872.92 3.63 79.04 MWD +SCC +SAG (1) 6/23/2008 2:03:35PM Page 2 COMPASS 2003.16 Build 42F ill III ConocoPhillips or its affiliates Definitive Survey Report npany •ConocoPhillips(Alaska) Inc. Local Co- Ordinate Reference: Well BRU 243 -34 Beluga River ND Reference 243 -34 (16.52 +77) © 93.52ft (Nabors 129) I t Beluga River MD Regret 4 4 243 -34 (16.52 +77) © 93.52ft (Nabors 129) Weil BRU 243 -34 0 i ltft tC@ € , E True Weiibore: `BRU 243 -34 811 = Calculation Mett ., Minimum Curvature , ice n:\ BRU 243 -34 ©atabas "EDM Alaska Prod v16 , 4 ..1, E 9 � €F F u d € FF )R" E E } k -- . , ii F �✓ // 4 C Map , 104110.11:-%"1:-.- / , MCt � E inc Ati 'E ` . . +i4ii +EI-iiV €HIV€ , Fasting 1 i � ttr (ft} l') ` rift} iii ;S ( (ft) ft i IiN44) viEtit'! (ft } =: x ve 'f `ikir iotne 1,213.14 16.07 330.14 1,202.58 1,10 89.96 -5 2,621,128.80 316,860.09 1.11 105.02 M +SCC +SA ( 1,307.12 17.42 332.08 1,292.57 1,199.05 113.67 -67.41 2,621,152.72 316,847.41 1.55 132.09 MWD +SCC +SAG (1) 1,403.68 18.82 333.22 1,384.34 1,290.82 140.35 -81.19 2,621,179.61 316,834.05 1.49 162.11 MWD +SCC +SAG(1) 1,497.63 19.98 331.80 1,472.96 1,379.44 168.02 -95.61 2,621,207.50 316,820.08 1.34 193.30 MWD +SCC +SAG (1) 1,595.02 26.49 330.85 1,562.40 1,468.88 201.69 - 114.07 2,621,241.46 316,802.15 6.69 231.70 MWD +SCC +SAG (1) 1,691.54 31.47 331.18 1,646.81 1,553.29 242.59 - 136.72 2,621,282.71 316,780.16 5.16 278.45 MWD +SCC +SAG (1) 1,787.73 31.45 331.44 1,728.86 1,635.34 286.62 - 160.82 2,621,327.12 316,756.76 0.14 328.65 MWD +SCC +SAG (1) 1,881.55 31.05 331.35 1,809.07 1,715.55 329.36 - 184.12 2,621,370.21 316,734.14 0.43 377.32 MWD +SCC +SAG(1) 1,978.98 30.49 331.89 1,892.78 1,799.26 373.21 - 207.82 2,621,414.43 316,711.14 0.65 427.17 MWD +SCC +SAG (1) 2,074.89 29.88 332.25 1,975.69 1,882.17 415.81 - 230.41 2,621,457.39 316,689.23 0.66 475.38 MWD +SCC +SAG (1) 2,170.35 29.54 332.55 2,058.60 1,965.08 457.74 - 252.33 2,621,499.65 316,667.98 0.39 522.68 MWD +SCC +SAG (1) 2,265.89 28.56 332.11 2,142.12 2,048.60 498.82 - 273.87 2,621,541.07 316,647.09 1.05 569.06 MWD +SCC +SAG (1) 2,361.08 28.42 332.17 2,225.78 2,132.26 538.97 - 295.09 2,621,581.54 316,626.51 0.15 614.46 MWD +SCC +SAG (1) 2,457.06 28.09 332.51 2,310.32 2,216.80 579.22 - 316.19 2,621,622.12 316,606.06 0.38 659.89 MWD +SCC +SAG (1) 2,552.63 27.90 332.55 2,394.70 2,301.18 619.02 - 336.88 2,621,662.25 316,586.00 0.20 704.75 MWD +SCC +SAG (1) 2,649.26 27.61 332.84 2,480.21 2,386.69 659.01 - 357.53 2,621,702.56 316,565.99 0.33 749.73 MWD +SCC +SAG (1) 2,745.31 25.81 331.55 2,566.01 2,472.49 697.21 - 377.65 2,621,741.06 316,546.48 1.97 792.90 MWD +SCC +SAG (1) 2,840.85 22.87 329.14 2,653.05 2,559.53 731.44 - 397.09 2,621,775.60 316,527.59 3.24 832.26 MWD +SCC +SAG (1) 2,926.43 20.91 328.08 2,732.45 2,638.93 758.69 - 413.69 2,621,803.10 316,511.41 2.33 864.14 MWD +SCC +SAG (1) 2,969.45 20.60 327.54 2,772.68 2,679.16 771.59 - 421.82 2,621,816.13 316,503.50 0.85 879.36 MWD +SCC +SAG (1) 3,067.85 18.54 326.75 2,865.39 2,771.87 799.29 - 439.69 2,621,844.11 316,486.07 2.11 912.24 MWD +SCC +SAG (1) 3,084.27 18.38 327.03 2,880.97 2,787.45 803.64 - 442.53 2,621,848.51 316,483.30 1.15 917.43 MWD +SCC +SAG (1) 3,179.76 17.71 326.55 2,971.76 2,878.24 828.39 - 458.73 2,621,873.51 316,467.49 0.72 946.92 MWD +SCC +SAG (1) 3,275.45 16.78 326.66 3,063.15 2,969.63 852.07 - 474.34 2,621,897.43 316,452.26 0.98 975.20 MWD +SCC +SAG (1) 3,370.99 15.10 327.08 3,155.01 3,061.49 874.04 - 488.68 2,621,919.62 316,438.27 1.76 1,001.36 MWD +SCC +SAG (1) 3,466.07 13.75 327.70 3,247.09 3,153.57 893.98 - 501.45 2,621,939.76 316,425.82 1.42 1,024.99 MWD +SCC +SAG (1) 3,563.41 11.45 325.05 3,342.08 3,248.56 911.68 - 513.16 2,621,957.64 316,414.39 2.44 1,046.14 MWD +SCC +SAG (1) 3,657.55 8.10 323.93 3,434.84 3,341.32 924.70 - 522.42 2,621,970.81 316,405.34 3.56 1,062.02 MWD +SCC +SAG (1) 3,753.80 5.18 317.15 3,530.44 3,436.92 933.38 - 529.38 2,621,979.59 316,398.52 3.13 1,072.97 MWD +SCC +SAG (1) 3,851.95 1.68 303.58 3,628.40 3,534.88 937.42 - 533.59 2,621,983.71 316,394.37 3.64 1,078.55 MWD +SCC +SAG (1) 3,947.32 1.30 294.74 3,723.74 3,630.22 938.65 - 535.74 2,621,984.97 316,392.24 0.47 1,080.66 MWD +SCC +SAG (1) 4,043.25 1.14 305.79 3,819.65 3,726.13 939.67 - 537.51 2,621,986.01 316,390.50 0.30 1,082.40 MWD +SCC +SAG (1) 4,139.56 1.74 278.36 3,915.93 3,822.41 940.44 - 539.73 2,621,986.82 316,388.29 0.93 1,084.15 MWD +SCC +SAG (1) 4,234.58 1.94 267.69 4,010.90 3,917.38 940.58 - 542.76 2,621,987.01 316,385.25 0.42 1,085.74 MWD +SCC +SAG (1) 4,328.98 1.80 228.39 4,105.25 4,011.73 939.53 - 545.47 2,621,986.01 316,382.53 1.34 1,086.13 MWD +SCC +SAG (1) 4,426.52 1.61 192.12 4,202.75 4,109.23 937.18 - 546.90 2,621,983.67 316,381.06 1.10 1,084.76 MWD +SCC +SAG (1) 4,521.26 1.61 195.20 4,297.45 4,203.93 934.60 - 547.53 2,621,981.10 316,380.40 0.09 1,082.80 MWD +SCC +SAG (1) 4,616.47 1.55 198.19 4,392.63 4,299.11 932.08 - 548.28 2,621,978.60 316,379.60 0.11 1,080.96 MWD +SCC +SAG (1) 4,712.94 1.60 171.36 4,489.06 4,395.54 929.51 - 548.49 2,621,976.03 316,379.36 0.76 1,078.81 MWD +SCC +SAG (1) 4,808.15 1.59 132.16 4,584.24 4,490.72 927.31 - 547.31 2,621,973.81 316,380.50 1.12 1,076.31 MWD +SCC +SAG (1) 6/23/2008 2:03:35PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates Definitive Survey Report ConocoPhillips(Alaska) Inc. Local Crdinn Reference Well BRU 243 -34 P>oj t Beluga River `'TVD efe 243 -34 (16.52 +77) @ 93.52ft (Nabors 129) 1l Reference 243 - 16.52 +77 Site Beluga River ( ) © 93.52ft (Nabors 129) Well BRU 243-34 North orth Refe True Well BRU 243 -34 Sunray Ca > < Od» Minimum Curvature t3eS BRU 243 -34 'Datat>aee. (,l EDM Alaska Prod v16 Survey E ; ' N1-S +SJ (tMi Northing E BLS.., Section EI(u,G �` �E (�a €E E E E E EE E R lferti . cal ,.,�. l� { °} ( (ft) { ?.: ( n r ESdBSS (ft j ° A1 11f)7 (ftj Survey 6 4 Tool Ha 4,904.95 1.08 108 4,681.01 4,587.49 926.15 545.43 2,621,972.62 316,382.35 0.80 1,074.39 MWD +SCC +SAG 1 4,998.51 0.76 98.86 4,774.56 4,681.04 925.81 - 543.98 2,621,972.25 316,383.81 0.37 1,073.39 MWD +SCC +SAG (1) 5,095.08 0.78 100.13 4,871.12 4,777.60 925.59 - 542.70 2,621,972.02 316,385.08 0.03 1,072.58 MWD +SCC +SAG (1) 5,189.27 0.76 107.10 4,965.30 4,871.78 925.30 - 541.48 2,621,971.71 316,386.30 0.10 1,071.73 MWD +SCC +SAG (1) 5,284.39 0.61 107.34 5,060.42 4,966.90 924.96 - 540.39 2,621,971.35 316,387.38 0.16 1,070.91 MWD +SCC +SAG (1) 5,380.99 0.57 111.29 5,157.01 5,063.49 924.63 - 539.45 2,621,971.01 316,388.31 0.06 1,070.18 MWD +SCC +SAG (1) 5,475.67 0.36 116.02 5,251.69 5,158.17 924.33 - 538.74 2,621,970.70 316,389.01 0.23 1,069.57 MWD +SCC +SAG(1) 5,568.23 0.48 117.98 5,344.24 5,250.72 924.02 - 538.14 2,621,970.37 316,389.62 0.13 1,069.00 MWD +SCC +SAG (1) 5,662.39 0.52 104.24 5,438.40 5,344.88 923.73 - 537.37 2,621,970.07 316,390.38 0.13 1,068.38 MWD +SCC +SAG (1) 5,756.66 0.48 99.89 5,532.67 5,439.15 923.55 - 536.57 2,621,969.89 316,391.18 0.06 1,067.84 MWD +SCC +SAG(1) 5,850.92 0.40 113.21 5,626.92 5,533.40 923.36 - 535.88 2,621,969.68 316,391.86 0.14 1,067.33 MWD +SCC +SAG (1) 5,945.67 0.51 115.53 5,721.67 5,628.15 923.05 - 535.20 2,621,969.36 316,392.54 0.12 1,066.73 MWD +SCC +SAG (1) 6,040.48 0.64 124.76 5,816.48 5,722.96 922.56 - 534.38 2,621,968.86 316,393.35 0.17 1,065.92 MWD +SCC +SAG (1) 6,136.32 0.60 124.97 5,912.31 5,818.79 921.97 - 533.53 2,621,968.26 316,394.19 0.04 1,064.99 MWD +SCC +SAG (1) 6,231.99 0.53 121.91 6,007.98 5,914.46 921.45 - 532.75 2,621,967.73 316,394.96 0.08 1,064.16 MWD +SCC +SAG (1) 6,328.27 0.65 122.01 6,104.25 6,010.73 920.93 - 531.91 2,621,967.19 316,395.80 0.13 1,063.29 MWD +SCC +SAG (1) 6,420.32 0.72 114.02 6,196.30 6,102.78 920.41 - 530.93 2,621,966.66 316,396.76 0.13 1,062.37 MWD +SCC +SAG (1) 6,515.37 0.80 116.25 6,291.34 6,197.82 919.87 - 529.79 2,621,966.10 316,397.90 0.09 1,061.34 MWD +SCC +SAG (1) 6,609.56 0.88 124.35 6,385.52 6,292.00 919.17 - 528.60 2,621,965.38 316,399.08 0.15 1,060.15 MWD +SCC +SAG (1) 6,706.26 1.02 129.56 6,482.20 6,388.68 918.20 - 527.31 2,621,964.39 316,400.34 0.17 1,058.68 MWD +SCC +SAG (1) 6,800.45 0.91 145.77 6,576.38 6,482.86 917.05 - 526.25 2,621,963.22 316,401.39 0.31 1,057.16 MWD +SCC +SAG (1) 6,895.10 0.94 136.79 6,671.02 6,577.50 915.87 - 525.30 2,621,962.03 316,402.32 0.16 1,055.67 MWD +SCC +SAG (1) 6,919.36 0.86 137.95 6,695.27 6,601.75 915.59 - 525.04 2,621,961.74 316,402.58 0.31 1,055.30 MWD +SCC +SAG (1) • 7,005.00 0.86 137.95 6,780.91 , 6,687.39 914.63 - 524.18 2,621,960.77 316,403.42 0.00 1,054.05 PROJECTED to TD 6/23/2008 2:03:35PM Page 4 COMPASS 2003.16 Build 42F 1 t 08/06/08 ' NO.4816 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit • Well Job # Log Description Date BL Color CD BRU 243 -34 12068362 DS! 06/12/08 1 BRU 243 -34 _ 12068362 FMI 06/12/08 1 BRU 243 -34 12068362 MDT 06/13/08 1 _ BRU 243 -34 12068362 BRIDGE PLUG 06/20/08 1 BRU 243 -34 12068362 _ USIT 06/20/08 1 BRU 243 -34 12068362 OH LDWG EDIT 06/12/08 6 1 a -31 062 -O- , 1 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 July 24, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: BRU243 -34 AK -MW- 574289 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 BRU243 -34 2" x 5" MD TC Logs: 1 Color Log 50- 283 - 20124 -00 2" x 5" TVD TC Logs: 1 Color Log 50- 283 - 20124 -00 Digital Log Images 1 CD Rom 50- 283 - 20124 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 69011 Arctic Blvd— brag Al 99518 Date: Signed: ' • • WELL LOG TRANSMITTAL To: State of Alaska June 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data BRU243-34 AK-MW-574289 1 LDWG formatted CD Rom with verification listing. API#: 50-283-20124-00 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 I 'I Date: , Signed: g 7/6 9/3 Beluga River Unit 243 -34 star. Page 1 of 1 • Maunder, Thomas E (DOA) From: Braden, John C [ John .C.Braden @conocophillips.com] Sent: Thursday, August 07, 2008 1:56 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: Beluga River Unit 243 -34 start -up Dear Tom and Jim - BRU 243 -34 (permit # 208 -079) should be ready to flow in August 2008. Our plan is to vent to atmosphere until the pressure is high enough to put it into the production system. The operator will account for the vented gas and report it on the 10-422 report. Once the well is stabilized, we will perform an open flow test in accordance to 10- 421. I am writing to let you know of our plans and also to ask if I am missing anything regarding moving this well from completion to production. Are there any other regulations to comply with besides 20ACC25.225 and 20ACC.25.235 in this situation? Please advise. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263 -4536 phone (907) 265 -1441 fax john.c.braden @conocophillips.com 11/3/2008 • nocoPhillip TRANSMITTAL Beluga River Unit development well data FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510 -0360 333 W. 7 Ave, Suite 100 Anchorage, Alaska 99501 -3539 RE: BRU 243 -34 Permit 208 -079 DATE: 07/22/2008 Hand car deliver Tran mi -d: Cook Inlet, Alaska Beluga River Unit 243 -34 502832012400 Report and CDROM Final Well Report, Mudlogging Data, BRU 243 -34; Epoch, report date: 6/18/2008. Contents, equipment and crew, well details, geological data, pressure/formation strength data, Drilling data, daily reports, Color log prints: � I Formation logs MD Formation Log TVD; LWD Combo MD; LWD COMBO ND; gas ratio MD; gas ratio ND; drilling dynamics MD; drilling dynamics ND a. 72,9 ;, vio., ats. .f:1?Y ..Eaf3 CC: Rick L Geologist Receipt: w/` Date: Sandra..,Lemkec Conocophfll®ps.core J -Q; • 26- Jun -08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well BRU 243 -34 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: 7,005.00 ' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen @HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date 3 IttNe Signed 0a4 Please call me at 273 -3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) BOP Utilization / Testing • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 03, 2008 12:22 PM To: 'Chambers, Mark A' Cc: Johnson, Vernon T (Halliburton Energy Services); Eggemeyer, Jerome C.; DOA AOGCC Prudhoe Bay \ Subject: RE: BOP Utilization / Testing % > ` ``v . \--CS Mark, D0 �v It is understood that the completion work planned for these wells involves the frequent use of the BOP. Employing the BOP during this work is planned and not the result of encountering something unexpected. If, however, it were necessary to use the BOP "in anger" to halt an unexpected flow from the well then the need to test would apply. Call or message with any questions. Tom Maunder, PE AOGCC From: Chambers, Mark A [mailto :Mark.A.Chambers @conocophillips.com] Sent: Thursday, July 03, 2008 12:04 PM To: Maunder, Thomas E (DOA) Cc: Johnson, Vernon T (Halliburton Energy Services); Eggemeyer, Jerome C. Subject: BOP Utilization / Testing Tom, As you know we have Nabors 129 working for us in our Beluga River Gas Field. Our first well is drilled and cased and we are currently in the completion stage of our operation. The lower Beluga (H, I) intervals are very tight and we are attempting to stimulate these intervals by perforating and fracing underballanced. We are utilizing our BOP's on a regular bases to hold surface pressure and displace any gas generated during the stimulation process. As we discussed, this is a planned operation and the BOP's are not being utilized in a unplanned well control event so we are only testing BOP's every 14 days as per AOGCC regulations (not after every shut -in). Would you please confirm this meets with AOGCC approval. Thank you for the help and call if there are questions. Mark A. Chambers Drilling Superintendent - Alpine / Cook Inlet / Exploration ConocoPhillips Alaska, Inc. 907 - 265 -1319 Office 907 - 240 -5868 Cell 7/7/2008 • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 03, 2008 10:36 AM To: Vern Johnson v LC- Cc: DOA AOGCC Prudhoe Bay Subject: RE: Nabors 129 O% - Q� Vern, et al, Bob Noble forwarded this message regarding witnessing the upcoming BOP test. We will waive witness at this time. Please forward to Larry. Call or message with any questions. Tom Maunder, PE AOGCC From: Noble, Robert C (DOA) Sent: Thursday, July 03, 2008 10:08 AM To: Maunder, Thomas E (DOA) Subject: Nabors 129 Tom I just got a call from Larry Hill on Nabors 129 giving a 24 hr notice for a BOP test. I told him I would let you know. I did not waive it as I dont know if you want someone to witness it or not. Larrys number is 263 -3010 Bob Bob Noble Petroleum Inspector Alaska Oil & Gas Conservation Commission (907) 659 -3607 7/7/2008 • . I 0[F i f j - \ -- _,AsEA SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 C. Alvord FAX (907) 276 -7542 Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 -0360 Re: Beluga River Field, Beluga Undefined Gas, BRU 243 -34 ConocoPhillips Alaska, Inc. Permit No: 208 -079 Surface Location: 1145' FSL, 959' FEL, SEC. 34, T13N, R1OW, SM Bottomhole Location: 3213' FNL, 1463' FEL, SEC. 34, 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 Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. hJ- Chair DATED thisZ- - day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o end. Department of Environmental Conservation w/o end. I I STATE OF ALASKA RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSIONX MAY 0 2 2008 PERMIT TO DRILL Alaska Oil & Gas Cons. Cammissi 20 AAC 25.005 Anchorage la. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1c. Specify if well is proposed for. Drill Q • Re -drill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 . Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone El • Single Zone ❑ Shale Gas❑ 2. Operator Name: 5. Bond: U Blanket I__I Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. .....57, 5 /W BRU 243 - 34 3. Address: 6. Proposed Depth: s 4 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 6920' • TVD: 6692' • Beluga River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1145' FSL, 959' FEL, Sec 34 T13N R10W SM • A029656 A029657 Sterling - Beluga Gas Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3213 FNL 1463' FEL, Sec. 34 T13N R10W SM NA 5/24/2008 Total Depth: 9. Acres in Property: 14. Distance to 3213 FNL 1463' FEL, Sec. 34 T13N R10W SM ' 1394 Nearest Property:6457 ft from MHT lease 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation b v M s ... 4. 4 15. Distance to Nearest Surface: x 316911 , y 2621036 Zone 4 (Height above G X 16.5' RKKB feet Well within Pool: 212 -35T , 1925 ft •/ 16. Deviated wells: Kickoff depth: 597 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 29.8° deg Downhole: 3131 psig - Surface: 2017 psig • 18. Casing Program Setting Depth Quantity of Cement Size Specifications 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 60 18 18 78.5 78.5 driven 12.25" 9 -5/8" 40# L -80 BTC 2987 18 18 3005 -, 2795 - 768 sx 12 ppg Lightweight slurry (BJ) 8.75" 7" 26# L -80 BTCM 6902 18 18 6920 6692 . 300 sx 10 ppg Lightweight slurry (BJ) 4 -1/2" 12.6# L-80 IBTM 6522 18 18 6540 6311 production tubing 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 ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate _ Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Drilling Program Time v. Depth Plot Shallow Hazard Analysis 9 �f 4 9 � ❑ Ys ❑ Property Plat u Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements El 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 C. Alvord Title Drilling Team Lead Signature / 47- 9 � 4 m. Phone Date 4z /or Commission Use Only Permit to Drill API Number. Permit Approval See cover letter Number. f-� /' E3 ��/ so- 203 - �ilic 'L -ebI Date: S 6/ •D > for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: d Samples req'd: Yes ❑ No g Mud log req'd: YeJ Nog Other: ZOO ^S +-, \ r%‘? ,\_ H2S measures: Yes ❑ No g Directional svy req'd: Yes [' No ❑ 5 /2z1 ' /APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 t ,/ GI ,,- , ub,rnit in Du licate C ,77 S: I or ConocoPhillips Alaska, Inc. — P N INr y ost Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 May 1, 2008 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Alaska Oil &Gas Cns. Commission Anchorage, Alaska 99501 Anchorage Re: Application for Permit to Drill BRU 243 -34 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 3005' 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. II • If you have any questions or require further information, please contact Vern Johnson at 265 -6081 or Chip Alvord at 265 -6120. 761y, fig Vern Jo nson Drilling Engineer Attachments cc: BRU 243 -34 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 243 -34 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 drillin g rates, temperatures mud tem eratures 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 243 -34 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 3005' MD / 2795' 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 +/- 6920' MD / +/- 6692' 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.@ 6920' MD/ 6692' 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 • • 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 • Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. BRU 214 -35 is the closest well. Well separation is - 71' at 546' 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. ORIGINAL • • Drilling Fluid Program Surface Interval Fluid Properties Funnel API Fluid Drill Depth MD Mud Wt. Viscosity Yield Point Loss Solids (ft) (113/gal) (cp) (Ib/100ft (m1/30min) pH ( %) MBT 0 - 3002' 8.8 -10 ; 50 -90 30 -40 NC - <10 +1 -9.5 <7% <35 Production Interval Fluid Properties API Fluid Depth MD Mud Wt. Funnel Yield Point Loss Solids (ft) (ppg) Viscosity (lb/1 00ft (ml /30min) pH ( %) 3,002' - 6,924' 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 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 // G i i Chemical injection port with 3/8" SS control line +/- 500' MD i TOC 500' BP6i SCSSSV with ''' /" SS control line to surface OC +1- 2764' MD / 2582' ND a Ste lio p IN @ +/- 2000' MD ' i r g Surface Casing: r 5 i r 9 -5/8 ", 40 #, L -80, BTC r 5 Formaton: Estimated Tops: Pore Pressure Set @ 3005' MD / 2795' TVD (250' TVD above y Sterling -A) i 5 i Sterling A 3264' MD / 3041' TVD Halliburton H ES HO stage tool(a� +/- 3700' MD 3.66 PPG EMW – CONTINGENCY IF THERE ARE LOST CIRCULATION 0 0 0 Sterling B 3472' MD / 3245' TVD Top Sterling A PROBLEMS -- i 4 i i Sterling C 3620' MD / 3392' TVD 4 -%' Camco KGB -2 GLM w/ 1" DCK2 shear valve c 5 i i i i � i i SC -2 Packer w/ Millout Extension SC-1L Isolation Packer i • s Formaton: Estimated Tops: Pore Pressure INII Beluga D 3778' MD / 3550' TVD SC -1L Isolation Packer i _ 5 / p' i Beluga E Beluga F 4033' MD / 3805' ; 5 05' TVD 4398' MD / 4170' TVD g 4.28 PPG EMW Top Beluga F SC-1L Isolation Packer 5 — -- -- ; Beluga G 4934' MD / 4706' ND 4 i Model FS Sump Packer 5 i i 5 Formaton: Estimated Tops: Pore Pressure � SC -2 Packer w/ Alternate Bore % r r 's A i 1 e Beluga H 5309' MD / 5081' TVD Beluga H and I will require 4 8.33 PPG EMW i Beluga I 6040' MD / 5812' TVD Fracs followed by HRWP 5 3 Top Beluga H i Beluga I Base 6540' MD / 6311' TVD i i Model FS Sump Packer ; i i Production Casing: i – -, 7 ", 26.00 #, L -80, BTC -Mod ; _ m . Set @ 6920' MD / 6692' TVD ;fr ( +/- 380' MD Below Beluga I Base) % : BRU 243 -34 prepared by Vern Johnson 4/15/08 Sperry Drilling Services Directional Plan wp05 ORIGINAL BRU 243 -34 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' 8.6ppg . 51 NA TVD 9 -5/8" 3005' MD / 2795' 9.0 ppg 1308 51 psi TVD 7" 6920' MD / 6692' 9.0 ppg 3131 . 2017 psi - TVD Expected Maximum Mud Weights: • 12 -1/4" surface hole to 3005' MD / 2795' TVD: 10.2 ppg, pore pressures of up to 9.0 ppg may be present. • 8 -3/4" intermediate hole to 6920' MD / 6692' TVD: 10 ppg. The pore pressure is not expected to be above 9 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 • MASP = FPP — (0.11 x D) = 1308 — (0.11 x 2795') = 1000 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 2795' MASP = 2017 psi OR MASP = FPP — (0.11 x D) = 3131 — (0.11 x 6692') = 2394 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" @ 3005' 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" © 6920' MD RKB Production 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 ORIGINAL . • Cementing Program: 9 5/8" Surface Casing run to 3005' MD / 2795' TVD Cement from 3005' MD to surface with lightweight 12 ppg slurry. Assume 100% excess annular volume. Lead slurry:(3005'- surface') X 0.3132 ft /ft X 2 (100% excess) = 1882.3 ft => 768 sx @ 2.45 System: 768 Sx Type I Cement + 22% bwoc LW -6 + 20% bwoc MPA -1 + 1% bwoc Sodium Metasilicate + 0.3% bwoc CD -32 + 0.05% bwoc Static Free + 1 gal /100sk FP -6L + fresh water @ 12ppg, Yielding 2.45 ft /sk 7" Production, Casing run to 6920' MD / 6692' TVD Cement from 6920' MD to +/- 2764' MD (minimum 500' MD above top of Sterling formation) with lightweight cement 10 ppg. Assume 40% excess annular volume. Tail: (6920' — 2764') X 0.1503 ft /ft X 1.4 (40% excess) = 874.5 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 874.5 + 17.2 = 891.7 ft => 300 Sx @ 2.99 ft /sk System: 300 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 t J1 • 4 ConocoPhillips(Alaska) Inc. Beluga River (NAD 27) Beluga River Plan: BRU 243 -34 Plan: BRU 243 -34 Plan: BRU 243- 34wp05 Standard Proposal Report 30 April, 2008 L\LA D 2 7 I 4 A ug f IHALLBURTDN Sperry Drilling Services ORIGINAL • • ConocoPhillips H A LLIBLiRTON Standard Proposal Report Dat base EDM v16 Prod Loca Co -ordif R Well Plan: BRU 243 -34 r • r ConocoPhillips(Alaska) Inc. TVD Re Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 ,'° .,i`... , Beluga River (NAD 27) MD Reference:. Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 ( a . Beluga River North Reference: True e Plan: BRU 243 -34 Survey Method Minimum Curvature Weilbore,.: Plan: BRU 243 -34, Des : A. It BRU 243- 34wp05 Project Beluga River (NAD 27) Map System: US State Plane 1927 (Exact solution) -" System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor = ;' Beluga River .t „ Site Position: Northing: 5,954,045.13ft Latitude: 70° 17 7.882 N From: Map Easting: 529,129.90ft Longitude: 149° 45' 51.288 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.22 ° Well Plan: BRU 243 - 34 Well Position +N / -S 0.00 ft Northing: 2,621,036.00 ft - Latitude: 61° 10' 11.917 N +E/ -W 0.00 ft Easting: 316,911.00 ft s Longitude: 151° 2' 13.284 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 75.00ft We , : , Plan BRU 243 -34 Magnetics r • ei Na Sampl Date `beclinad ' BGGM2007 4/7/2008 16.36 72.91 54,978 • n ,:wv BRU 243 34w 05 Audit Notes: Version: 3 Phase: PLAN Tie On Depth: 16.50 S �. `, p e:f �5on .- Vertical �� ��' Depth From }`� '* ��<� � � `��� � � i''' 16.50 0.00 0.00 331.30 •',(t•ns . ,4;,.: a / .. • TVD it Dog , Built z , Tu '° '3 Inclination Azimut# :� s System +tW"S +Ei- O. "*:!?..4, Rate` ool F t r 16.50 0.00 0.00 16.50 ° -75.00 0.00 0.00 0.00 0.00 0.00 0.00 596.50 0.00 0.00 596.50 505.00 0.00 0.00 0.00 0.00 0.00 0.00 1,788.06 29.79 331.30 1,735.10 1,643.60 265.64 - 145.43 2.50 2.50 0.00 331.30 2,785.42 29.79 331.30 2,600.67 2,509.17 700.26 - 383.37 0.00 0.00 0.00 0.00 3,778.39 0.00 327.44 3,549.50 3,458.00 921.63 - 504.56 3.00 -3.00 0.00 180.00 6,540.39 0.00 327.44 6,311.50 6,220.00 921.63 - 504.56 0.00 0.00 0.00 327.44 6,620.39 0.00 327.44 6,391.50 6,300.00 921.63 - 504.56 0.00 0.00 0.00 327.44 6,920.39 0.00 327.44 6,691.50 6,600.00 921.63 - 504.56 0.00 0.00 0.00 327.44 4/30/2008 1:38:48PM Page 2 COMPASS 2003.16 Build 42F DRILL • 0 ConocoPhillips HALL HALL1BURTON Standard Proposal Report ` EDM v16 Prod Local Co- ordinate ce ti Well Plan: BRU 243 -34 „ . ConocoPhillips(Alaska) Inc. WO nce 'F ' Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' ' , k. Beluga River (NAD 27) MD Referents. i # Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' S t 'r Beluga River North T 'i r, ( r True Webs k .' = Plan: BRU 243 -34 Survey #f-i :ag , Meth. , t _' Minimum Curvature Welbore Plan: BRU 243 -34 4 a* _ , ' , Design ' BRU 243-34wp05 'ci n • Survey p d � ou� , . . Vertical x Map = f ` i ® `� Inclination 4�jf l� Depth `. � +N /-S +E/ -W Northing l LS k = ert S tio% 4 ` f3 ( °) $ ' , ' (ft) ft _„ (�) (ft a ( ft ) x# '14:01;1/4., 75 i , t 16.50 0.00 0.00 16.50 -75.00 0.00 0.00 2,621,036.00 316,911.0 0.00 0.00 100.00 0.00 0.00 100.00 8.50 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 200.00 0.00 0.00 200.00 108.50 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 300.00 0.00 0.00 300.00 208.50 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 400.00 0.00 0.00 400.00 308.50 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 500.00 0.00 0.00 500.00 408.50 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 596.50 0.00 0.00 596.50 505.00 0.00 0.00 2,621,036.00 316,911.00 0.00 0.00 1 KOP; 2.5 DLS x;: ' ' - 600.00 0.09 331.30 600.00 508.50 0.00 0.00 2,621,036.00 316,911.00 2.50 0.00 700.00 2.59 331.30 699.96 608.46 2.05 -1.12 2,621,038.07 316,909.91 2.50 2.34 800.00 5.09 331.30 799.73 708.23 7.92 -4.34 2,621,043.99 316,906.79 2.50 9.03 900.00 7.59 331.30 899.11 807.61 17.60 -9.64 2,621,053.75 316,901.65 2.50 20.07 1,000.00 10.09 331.30 997.92 906.42 31.08 -17.01 2,621,067.34 316,894.48 2.50 35.43 1,100.00 12.59 331.30 1,095.96 1,004.46 48.32 -26.45 2,621,084.73 316,885.32 2.50 55.09 1,200.00 15.09 331.30 1,193.05 1,101.55 69.30 -37.94 2,621,105.88 316,874.17 2.50 79.00 1,300.00 17.59 331.30 1,289.00 1,197.50 93.97 -51.44 2,621,130.76 316,861.06 2.50 107.13 1,400.00 20.09 331.30 1,383.64 1,292.14 122.29 -66.95 2,621,159.32 316,846.01 2.50 139.41 1,500.00 22.59 331.30 1,476.78 1,385.28 154.20 -84.42 2,621,191.51 316,829.04 2.50 175.80 1,600.00 25.09 331.30 1,568.24 1,476.74 189.65 - 103.83 2,621,227.26 316,810.20 2.50 216.21 1,700.00 27.59 331.30 1,657.85 1,566.35 228.56 - 125.13 2,621,266.50 316,789.52 2.50 260.57 1,788.06 29.79 331.30 1,735.10 1,643.60 265.64 - 145.43 2,621,303.89 316,769.81 2.50 302.84 1,800.00 29.79 331.30 1,745.46 1,653.96 270.84 - 148.28 2,621,309.14 316,767.05 0.00 308.77 1,900.00 29.79 331.30 1,832.25 1,740.75 314.42 - 172.13 2,621,353.09 316,743.89 0.00 358.45 2,000.00 29.79 331.30 1,919.03 1,827.53 358.00 - 195.99 2,621,397.03 316,720.72 0.00 408.13 2,100.00 29.79 331.30 2,005.82 1,914.32 401.57 - 219.85 2,621,440.98 316,697.56 0.00 457.81 2,200.00 29.79 331.30 2,092.60 2,001.10 445.15 - 243.71 2,621,484.93 316,674.40 0.00 507.50 2,300.00 29.79 331.30 2,179.39 2,087.89 488.73 - 267.56 2,621,528.88 316,651.24 0.00 557.18 2,400.00 29.79 331.30 2,266.18 2,174.68 532.31 - 291.42 2,621,572.83 316,628.08 0.00 606.86 2,500.00 29.79 331.30 2,352.96 2,261.46 575.88 - 315.28 2,621,616.77 316,604.91 0.00 656.54 2,600.00 29.79 331.30 2,439.75 2,348.25 619.46 - 339.13 2,621,660.72 316,581.75 0.00 706.22 2,700.00 29.79 331.30 2,526.54 2,435.04 663.04 - 362.99 2,621,704.67 316,558.59 0.00 755.90 2,785.42 29.79 331.30 2,600.67 2,509.17 700.26 - 383.37 2,621,742.21 316,538.81 0.00 798.34 2,800.00 29.35 331.30 2,613.35 2,521.85 706.57 - 386.83 2,621,748.57 316,535.45 3.00 805.53 2,900.00 26.35 331.30 2,701.75 2,610.25 747.55 - 409.26 2,621,789.90 316,513.67 3.00 852.25 2,998.93 23.38 331.30 2,791.50 2,700.00 784.04 - 429.23 2,621,826.69 316,494.28 3.00 893.84 9'5/8" x 12 1/4 " .. 3,000.00 23.35 331.30 2,792.48 2,700.98 784.41 - 429.44 2,621,827.07 316,494.08 3.00 894.27 3,100.00 20.35 331.30 2,885.29 2,793.79 817.05 - 447.31 2,621,859.99 316,476.73 3.00 931.48 3,200.00 17.35 331.30 2,979.91 2,888.41 845.39 - 462.82 2,621,888.57 316,461.67 3.00 963.79 i 3,264.20 15.43 331.30 3,041.50 2,950.00 861.28 - 471.52 2,621,904.59 316,453.22 3.00 981.90 Sterling A top 3,300.00 14.35 331.30 3,076.10 2,984.60 869.35 - 475.94 2,621,912.73 316,448.94 3.00 991.10 3,400.00 11.35 331.30 3,173.58 3,082.08 888.86 - 486.62 2,621,932.40 316,438.57 3.00 1,013.34 3,472.08 9.19 331.30 3,244.50 3,153.00 900.13 - 492.79 2,621,943.77 316,432.58 3.00 1,026.19 1 Sterling B top 4/30/2008 1:38:48PM Page 3 COMPASS 2003.16 Build 42F flR!GINAL • • ConocoPhillips HALL 1 L RTON Standard Proposal Report Data: EDM v16 Prod L ttb ,'t Well Plan: BRU 243 -34 M Co • . a 1 * ConocoPhillips(Alaska) Inc. ® � r,, tce :' Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' ` Project Beluga River (NAD 27) MD Retert3i Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' < : Melt ` m Beluga River ' for ham;° True Well: Plan: BRU 243 -34 4 lation - - Minimum Curvature Ypellbore'" Plan: BRU 243 -34 ,, ;. ` .n ' "" .BRU 243- 34wp05 Survey • a < beat Ma map a , : � Inciina ti on " ® Typ +NI-S " . +E/ -W Northing D g -1 °-, (ft) (') A . f t ( ft j (f (ft �. � ! .., . (, 1.. x,180.' -_ o� it " F A A .. .„ ,� 3,500.00 8.35 331.30 3,272.10 3,180.60 903.86 - 494.83 2,621,947.54 316,430.59 3.00 1,030.45 3,600.00 5.35 331.30 3,371.37 3,279.87 914.33 - 500.56 2,621,958.09 316,425.03 3.00 1,042.38 3,620.21 4.75 331.30 3,391.50 3,300.00 915.89 - 501.42 2,621,959.66 316,424.20 3.00 1,044.16 Sterling Clop 3,700.00 2.35 331.30 3,471.14 3,379.64 920.22 - 503.79 2,621,964.03 316,421.90 3.00 1,049.10 3,778.39 0.00 327.44 3,549.50 3,458.00 921.63 - 504.56 2,621,965.45 316,421.15 3.00 1,050.70 Beluga D top - BRU 243 34wp03 Beluga D (copy) 3,800.00 0.00 327.44 3,571.11 3,479.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 3,900.00 0.00 327.44 3,671.11 3,579.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,000.00 0.00 327.44 3,771.11 3,679.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,033.39 0.00 327.44 3,804.50 3,713.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 Beluga E top ' " : .. <, , 4,100.00 0.00 327.44 3,871.11 3,779.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,200.00 0.00 327.44 3,971.11 3,879.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,300.00 0.00 327.44 4,071.11 3,979.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,398.39 0.00 327.44 4,169.50 4,078.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 Beluga ;F tOP : 4,400.00 0.00 327.44 4,171.11 4,079.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,500.00 0.00 327.44 4,271.11 4,179.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,600.00 0.00 327.44 4,371.11 4,279.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 I 4,700.00 0.00 327.44 4,471.11 4,379.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,800.00 0.00 327.44 4,571.11 4,479.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,900.00 0.00 327.44 4,671.11 4,579.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4,934.39 0.00 327.44 4,705.50 4,614.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 Beluga G top 5,000.00 0.00 327.44 4,771.11 4,679.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,100.00 0.00 327.44 4,871.11 4,779.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,200.00 0.00 327.44 4,971.11 4,879.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,300.00 0.00 327.44 5,071.11 4,979.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,309.39 0.00 327.44 5,080.50 4,989.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 Setup H top 5,400.00 0.00 327.44 5,171.11 5,079.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,500.00 0.00 327.44 5,271.11 5,179.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,600.00 0.00 327.44 5,371.11 5,279.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,700.00 0.00 327.44 5,471.11 5,379.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 i 5,800.00 0.00 327.44 5,571.11 5,479.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 5,900.00 0.00 327.44 5,671.11 5,579.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,000.00 0.00 327.44 5,771.11 5,679.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,040.39 0.00 327.44 5,811.50 5,720.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 Beluga -l.top 6,100.00 0.00 327.44 5,871.11 5,779.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,200.00 0.00 327.44 5,971.11 5,879.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,300.00 0.00 327.44 6,071.11 5,979.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,400.00 0.00 327.44 6,171.11 6,079.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,500.00 0.00 327.44 6,271.11 6,179.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 4/30/2008 1:38:48PM Page 4 COMPASS 2003.16 Build 42F ORIGINAL • • ConocoPhillips HALLIBURTON Standard Proposal Report o EDM v16 Prod t.Co -o - W ell Plan: BRU 243 -34 . :, ConocoPhillips(Alaska) Inc. ce t Plan. 243-34 (16.5 +75) @ 91.50ft (Nabors 129 (' Project Beluga River (NAD 27) MD Re a ee� � :' Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (• Site: Beluga River North j? � .' It i r True Well: °-.- Plan: BRU 243 -34 Survey' '° � ' a = ' '-, Minimum Curvature ;X bore: Plan: BRU 243 -34 'n: BRU 243- 34wp05 �d °be v rt ,,, f. i M Map IY Y inclination Azimuth +El W a � � yt C -71,_,' ert (ft r ( °) ( °) ( , ' 7 .4 A ' ( , ' w ,tft) , , (") qki )�W *4° . 6,540.39 0.00 327.44 6,311.50 6,220.00 921.63 - 504.56 2,621,965.45 316,421. 0 .00 1,050.70 Beluga 1 base - BRUK243*34wp03 Beluga Base (copy) 6,600.00 0.00 327.44 6,371.11 6,279.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,620.39 0.00 327.44 6,391.50 6,300.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 7 1,050.70 Estimated Lowest Perfs a: 6,700.00 0.00 327.44 6,471.11 6,379.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,800.00 0.00 327.44 6,571.11 6,479.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,900.00 0.00 327.44 6,671.11 6,579.61 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 6,920.39 0.00 327.44 6,691.50 6,600.00 921.63 - 504.56 2,621,965.45 316,421.15 0.00 1,050.70 l i a(ss target . Dip Angle . „ ®� TfVVD , 4 ng ti -Ys . '4, ., ' :(0) I f (ft) `` .it: +z .a^, it z .. . * ` s x.� . . ,, s; . ,. BRU 243- 34wp03 Beluga Base (copy) 0.00 0.00 6,311.50 921.63 - 504.56 2,621,965.45 316,421.15 - plan hits target Point BRU 243- 34wp03 Beluga D (copy) 0.00 0.00 3,549.50 921.63 - 504.56 2,621,965.45 316,421.15 - plan hits target - Point Casing � , �. r Ptre D pea l o p i s Diameter eter, ` # � {ft) Name $, () ff,u , _ ) ,1 ` . 2,998.93 2,791.50 9 5/8 x 12 1/4 9-5/8 12 -1/4 6,920.39 6,691.50 7" x 8 -3/4" 7 8 - 3/4 Formations �, Measur , erticai„ Depth Depth x �' pth sS f p D t► i ; (ft) (ft) <. ' ' , , Name `:. Lith . Y ; 0) a 5,309.39 5,080.50 Beluga H top 0.00 3,620.21 3,391.50 Sterling C top 0.00 4,398.39 4,169.50 Beluga F top 0.00 6,540.39 6,311.50 Beluga I base 0.00 3,264.20 3,041.50 Sterling A top 0.00 3,778.39 3,549.50 Beluga D top 0.00 4,934.39 4,705.50 Beluga G top 0.00 3,472.08 3,244.50 Sterling B top 0.00 6,040.39 5,811.50 Beluga I top 0.00 4,033.39 3,804.50 Beluga E top 0.00 4/30/2008 1:38:48PM Page 5 COMPASS 2003.16 Build 42F ORIGINAL • • ConocoPhillips HALLI URTON Standard Proposal Report tz EDM v16 Prod Local Co - ordinate Reference: Well Plan: BRU 243 -34 y: ConocoPhillips(Alaska) Inc. TVD Reference: Plan 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 q _ „, Beluga River (NAD 27) MD Reference: Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' Beluga River North Reference: N x True Weil; Plan: BRU 243 -34 Survey Calculation' • • Minimum Curvature Plan: BRU 243 -34 ®r jrex BRU 243- 34wp05 1 Local Coordf' (ft) 596.50 596.50 11L 0.00 0.00 KOP; 2.5 DLS 6,620.39 6,391.50 921.63 - 504.56 Estimated Lowest Perfs 4/30/2008 1 :38 :48PM Page 6 COMPASS 2003.16 Build 42F OR!GIN • • l y Y t o I o :L ConocoPhillips (Alaska) Inc. -Expl South Alaska Beluga River Unit 1 ' Plan: BRU 243 -34 F f Plan: BRU 243 -34 Plan: BRU 243- 34wp05 , z Standard Proposal Report 07 April, 2008 7, M HALLIBURTON Sperry Drilling Services � ORIGINAL aicu System :IISCWSA urvdmie 0 or Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic South Alaska Warring Method: Rules Based ConocoPhillips Geodetic Datum: North American Datum 1983 Beluga River Unit i1RU 243- 34wp05 Magnetic Model: BGGM2007 Plan: BRU 243 -34 Ground Level: 75.00 Plan: BRU 243 -34 RKB: Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (16.5 +75)) Northing/ASP Y: 2620796.55 BRU 243- 34wp05 Fasting /ASP X: 1456937.80 Q Q5 T x 8 -3/4" ��� BRU 243- 34wp03 Beluga Base 9 5/8" x 12 1/4" BRU 243- 34wp03 Beluga D 750 1 O in N 4 o z l o250 0— 61 l -1000 -750 -500 -250 0 250 500 West( -) /East( +) (250 ft /in) m 0 c o• S 10' Z1' O O u7 �-' 2500 3 p 95/8"x121/4" co n _- o n BRU 243- 34wp03 Beluga D Rchrnla n r., - — ca — Beluga E top -- U Beluga F top g 5000 -r BelugaGtop N Beluga H top H Beluga I top BRU 243- 34wp03 Beluga Base Beluga I base T x 8 -3/4" - - -"BRU 243- 34wp85 I - 7500 -5000 -2500 0 2500 5000 7500 -r - .1 to 111 ORIGINAL 4i • ConocoPhillips HALLIBCJRTON Standard Proposal Report Database 40 EDM v16 Prod Local Go -Ordtt , ] Well Plan: BRU 243 -34 Company ConocoPhillips (Alaska) Inc. -Expl TVD,Reerence" $ ;414 Plan: 243 -34 (18.5 +75) @ 91.50ft (Nabors 129 Project: South Alaska 1MD9r+ence: : ` Plan: 243 -34 (16.5 +75) © 91.50ft (Nabors 129 ( Site: x Beluga River Unit N rence: True Wef Plan: BRU 243 -34 riottiCtIattola , : Minimum Curvature ce b Plan: BRU 243 -34 BRU 243.34wp05 wl 0 , South Alaska, 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 Site ', ^ , Beluga River Unit Site Position: Northing: 2,630,670.44ft Latitude: 61° 11' 48.996 N From: Map Easting: 1,469,272.80ft Longitude: 150° 58' 12.824 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.85 ° Well ,+ P lan • B RU 243 - 34 Well Position +N / -S 0.00 ft Northing: 2,620,796.55 ft Latitude: 61° 10' 9.906 N +E/ -W 0.00 ft Easting: 1,456,937.80 ft Longitude: 151° 2' 21.316 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 75.00ft 5. f71 °,!.„,,:` Plan: BRU 243 - 34 Magnetics . ,....4,...; Sample Date DeChna c tt , Dip Ang1 ° a BGGM2007 4/7/2008 19.16 73.96 55,677 I Design y z � te BRU 243- 34wp05 Audit Notes: Version: 3 Phase: PLAN Tie On Depth: 16.50 * ,..4. °' .° Section: i u '' :. { TVD) ; . ' = +141-5 +E/-W �_ .•.a ., } 4'4. A 16.50 0.00 0.00 331.30 OliettectiOns ,W . „' IAi -, , ,? y��� S i` y � �{/ ` � } $ Build S . f Y inclination 'Al' ,`0, E i , 5 + 4 1 11 8 «1) -W 0 / ' e Rate k Rate 3 ool yo- C) Cl ' r AN-, s , ft , ( � H 1 1�10 S i!..1 1 ti x i , t ., r , 16.50 0.00 0.00 16.50 -75.00 0.00 0.00 0.00 0.00 0.00 0.00 596.50 0.00 0.00 596.50 505.00 0.00 0.00 0.00 0.00 0.00 0.00 1,788.00 29.79 331.30 1,735.05 1,643.55 265.61 - 145.41 2.50 2.50 0.00 331.30 2,785.45 29.79 331.30 2,600.71 2,509.21 700.26 - 383.36 0.00 0.00 0.00 0.00 3,778.37 0.00 327.44 3,549.50 3,458.00 921.61 - 504.54 3.00 -3.00 0.00 180.00 6,540.37 0.00 327.44 6,311.50 6,220.00 921.61 - 504.54 0.00 0.00 0.00 327.44 6,620.37 0.00 327.44 6,391.50 6,300.00 921.61 - 504.54 0.00 0.00 0.00 327.44 6,920.37 0.00 327.44 6,691.50 6,600.00 921.61 - 504.54 0.00 0.00 0.00 327.44 4/7/2008 3 :46 :19PM Page 2 COMPASS 2003.16 Build 42F OR ICINAL 0 • Conoco Phillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod , 1 Caeraliiele Relereete: Well Plan: BRU 243-34 ConocoPhillips (Alaska) Inc. -Expl IVO Reference. Plan: 243-34 (16.5+75) © 91.50ft (Nabors 129 (' South Alaska =Reference: ';', . Plan: 243-34 (16.5+75) © 91.50ft (Nabors 129 (' '4 Site: Beluga River Unit North Reference: - --1.-,! True Well: i7 Plan: BRU 243-34 Survey Caleeletten , , , ,,, ,, • =1::::" - Minimum Curvature Wellbore: e.,:::* Plan: BRU 243-34 Design: 'On, BRU 243-34wp05 4 - ‘ ,. - -,,,,,,,,,,,,,,,,,, ., ,,,,,,,,,,A,,z,;, Mon Nan ''%'.'5''''' '' ' ,.. ! , . li '', ,. . I'. . 4 •.;,- ''';': '''' ' Inahlati°11 .: ) .‘ 31 f ilitifh ' - `.:11 ' *t 40 -W Northing "AtIV -- ti Niii o'k;'.i -. e) -;:,--: , ' e) A (ftv (ft) (ft) 4t) ;ItAttx , -" 16.50 0.00 0.00 16.50 -75.00 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 100.00 0.00 0.00 100.00 8.50 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 200.00 0.00 0.00 200.00 108.50 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 300.00 0.00 0.00 300.00 208.50 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 400.00 0.00 0.00 400.00 308.50 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 1 500.00 0.00 0.00 500.00 408.50 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 596.50 0.00 0.00 596.50 505.00 0.00 0.00 2,620,796.55 1,456,937.80 0.00 0.00 KOP; 2.5 DLS 600.00 0.09 331.30 600.00 508.50 0.00 0.00 2,620,796.55 1,456,937.80 2.50 0.00 700.00 2.59 331.30 699.96 608.46 2.05 -1.12 2,620,798.62 1,456,936.71 2.50 2.34 800.00 5.09 331.30 799.73 708.23 7.92 -4.34 2,620,804.54 1,456,933.59 2.50 9.03 900.00 7.59 331.30 899.11 807.61 17.60 -9.64 2,620,814.30 1,456,928.45 2.50 20.07 1,000.00 10.09 331.30 997.92 906.42 31.08 -17.01 2,620,827.89 1,456,921.28 2.50 35.43 1,100.00 12.59 331.30 1,095.96 1,004.46 48.32 -26.45 2,620,845.28 1,456,912.12 2.50 55.09 1,200.00 15.09 331.30 1,193.05 1,101.55 69.30 -37.94 2,620,866.44 1,456,900.97 2.50 79.00 1,300.00 17.59 331.30 1,289.00 1,197.50 93.97 -51.44 2,620,891.32 1,456,887.86 2.50 107.13 1,400.00 20.09 331.30 1,383.64 1,292.14 122.29 -66.95 2,620,919.88 1,456,872.81 2.50 139.41 1,500.00 22.59 331.30 1,476.78 1,385.28 154.20 -84.42 2,620,952.06 1,456,855.85 2.50 175.80 1,600.00 25.09 331.30 1,568.24 1,476.74 189.65 -103.82 2,620,987.81 1,456,837.01 2.50 216.21 1,700.00 27.59 331.30 1,657.85 1,566.35 228.56 -125.13 2,621,027.06 1,456,816.33 2.50 260.57 1,788.00 29.79 331.30 1,735.05 1,643.55 265.61 -145.41 2,621,064.42 1,456,796.64 2.50 302.81 1,800.00 29.79 331.30 1,745.46 1,653.96 270.84 -148.27 2,621,069.70 1,456,793.86 0.00 308.77 1,900.00 29.79 331.30 1,832.25 1,740.75 314.42 -172.13 2,621,113.64 1,456,770.70 0.00 358.45 2,000.00 29.79 331.30 1,919.04 1,827.54 357.99 -195.99 2,621,157.59 1,456,747.54 0.00 408.13 2,100.00 29.79 331.30 2,005.82 1,914.32 401.57 -219.84 2,621,201.54 1,456,724.38 0.00 457.81 2,200.00 29.79 331.30 2,092.61 2,001.11 445.15 -243.70 2,621,245.48 1,456,701.22 0.00 507.49 2,300.00 29.79 331.30 2,179.40 2,087.90 488.72 -267.55 2,621,289.43 1,456,678.06 0.00 557.17 I 2,400.00 29.79 331.30 2,266.18 2,174.68 532.30 -291.41 2,621,333.38 1,456,654.90 0.00 606.84 1 2,500.00 29.79 331.30 2,352.97 2,261.47 575.87 -315.26 2,621,377.32 1,456,631.74 0.00 656.52 2,600.00 29.79 331.30 2,439.76 2,348.26 619.45 -339.12 2,621,421.27 1,456,608.59 0.00 706.20 2,700.00 29.79 331.30 2,526.55 2,435.05 663.02 -362.98 2,621,465.22 1,456,585.43 0.00 755.88 2,785.45 29.79 331.30 2,600.71 2,509.21 700.26 -383.36 2,621,502.77 1,456,565.64 0.00 798.33 2,800.00 29.35 331.30 2,613.36 2,521.86 706.56 -386.81 2,621,509.12 1,456,562.29 3.00 805.51 2,900.00 26.35 331.30 2,701.77 2,610.27 747.53 -409.24 2,621,550.44 1,456,540.51 3.00 852.22 2,998.91 23.38 331.30 2,791.50 2,700.00 784.01 -429.21 2,621,587.24 1,456,521.13 3.00 893.81 9 5/1?' x 12 1/4" 3,000.00 23.35 331.30 2,792.50 2,701.00 784.39 -429.42 2,621,587.62 1,456,520.92 3.00 894.24 3,100.00 20.35 331.30 2,885.30 2,793.80 817.04 -447.29 2,621,620.54 1,456,503.58 3.00 931.46 3,200.00 17.35 331.30 2,979.93 2,888.43 845.37 -462.80 2,621,649.12 1,456,488.51 3.00 963.77 3,264.18 15.43 331.30 3,041.50 2,950.00 861.26 -471.50 2,621,665.14 1,456,480.07 3.00 981.87 Sterling Atop 3,300.00 14.35 331.30 3,076.11 2,984.61 869.33 -475.92 2,621,673.28 1,456,475.78 3.00 991.08 3,400.00 11.35 331.30 3,173.60 3,082.10 888.84 -486.60 2,621,692.95 1,456,465.42 3.00 1,013.32 3,472.06 9.19 331.30 3,244.50 3,153.00 900.11 -492.77 2,621,704.32 1,456,459.43 3.00 1,026.16 Sterling B top 4/7/2008 3:46:19PM Page 3 COMPASS 2003.16 Build 42F r ) 1 7) 1 ri NI A ' _ - ',.„... i i NI 1 'N ,_ I • 0 Conoco Phillips HALLIBURTON Standard Proposal Report .3.:. ..,:;:,..•::.-,, EDM v16 Prod Local Co-ordinate finference:4* Well Plan: BRU 243-34 1 ,C • i • --: : ConocoPhillips (Alaska) Inc. -Expl TVD Reference: 4 444„ 4 Plan: 243-34 (16.5+75) @ 91.50ft (Nabors 129 (' A South Alaska MO Reftwonco: ,.:4,.:..,1„ Plan: 243-34 (16.5+75) @ 91.50ft (Nabors 129 (' 1 •-" "'--- .- , - .03..0,7,' , q Beluga River Unit North ReferenOtE 44 4 True Weft '' Plan BRU 243-34 Survey .. .. . , ;.' - . -"•=7 Minimum Curvature WellbOrE , .: .. Plan: BRU 243-34 ,. - - ‘i`••• - , " - -*.kbg i ,Design: ;4•11 BRU 243-34wp05 Planned Survey , , ,. , Wasered Verticai 1.14? , ,..`k Map l`W.A.,'".--z ' ' '''.?:::N andlnaflOn Azimuth Depth TliDes - " +N1-S +EJ-W i,,, .:„.. , 44 , * - -' d .• '' ' ' ''' ' Vert V . •:'. 4 '.: a' C) (ft) ' - ft (ft) , (ft) ' 4 .: ,7,7-:4 z,- 3,1:3 ...„,:,,./, .,,, . , - - ,,! . . , ..04,it.. v,g.. 3,500.00 8.35 331.30 3,272.11 3,180.61 903.84 -494.81 2,621,708.09 1,456,457.44 3.00 1,030.42 3,600.00 5.35 331.30 3,371.39 3,279.89 914.31 -500.54 2,621,718.64 1,456,451.88 3.00 1,042.35 3,620.19 4.75 331.30 3,391.50 3,300.00 915.86 -501.39 2,621,720.21 1,456,451.05 3.00 1,044.13 Sterling C top 3,700.00 2.35 331.30 3,471.15 3,379.65 920.20 -503.77 2,621,724.58 1,456,448.75 3.00 1,049.07 3,778.37 0.00 327.44 3,549.50 3,458.00 921.61 -504.54 2,621,726.00 1,456,448.00 3.00 1,050.67 Beluga D top - BRU 243-34wp03 Beluga D 3,800.00 0.00 327.44 3,571.13 3,479.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 3,900.00 0.00 327.44 3,671.13 3,579.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,000.00 0.00 327.44 3,771.13 3,679.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,033.37 0.00 327.44 3,804.50 3,713.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Beluga E top 4,100.00 0.00 327.44 3,871.13 3,779.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,200.00 0.00 327.44 3,971.13 3,879.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,300.00 0.00 327.44 4,071.13 3,979.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,398.37 0.00 327.44 4,169.50 4,078.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Beluga F top 4,400.00 0.00 327.44 4,171.13 4,079.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,500.00 0.00 327.44 4,271.13 4,179.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,600.00 0.00 327.44 4,371.13 4,279.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,700.00 0.00 327.44 4,471.13 4,379.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,800.00 0.00 327.44 4,571.13 4,479.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,900.00 0.00 327.44 4,671.13 4,579.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4,934.37 0.00 327.44 4,705.50 4,614.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Beluga G top '. 5,000.00 0.00 327.44 4,771.13 4,679.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,100.00 0.00 327.44 4,871.13 4,779.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,200.00 0.00 327.44 4,971.13 4,879.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,300.00 0.00 327.44 5,071.13 4,979.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,309.37 0.00 327.44 5,080.50 4,989.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Beluga H top 5,400.00 0.00 327.44 5,171.13 5,079.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,500.00 0.00 327.44 5,271.13 5,179.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,600.00 0.00 327.44 5,371.13 5,279.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,700.00 0.00 327.44 5,471.13 5,379.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,800.00 0.00 327.44 5,571.13 5,479.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 5,900.00 0.00 327.44 5,671.13 5,579.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,000.00 0.00 327.44 5,771.13 5,679.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,040.37 0.00 327.44 5,811.50 5,720.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Beluga 1 top 6,100.00 0.00 327.44 5,871.13 5,779.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,200.00 0.00 327.44 5,971.13 5,879.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,300.00 0.00 327.44 6,071.13 5,979.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,400.00 0.00 327.44 6,171.13 6,079.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,500.00 0.00 327.44 6,271.13 6,179.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 4/7/2008 3:46:19PM Page 4 COMPASS 2003.16 Build 42F (") r) ! r° 1 ,N, I ik I Conoco Phillips HALLIBLIPTON Standard Proposal Report Database:Ii;:it EDM v16 Prod - Leaf Co-orditRofemttee: Well Plan: BRU 243-34 Company• ConocoPhillips (Alaska) Inc. -Expl plan: 243-34 (16.5+75) © 91.50ft (Nabors 129 (' Project South Alaska MO RefEsviitA Plan: 243-34 (16.5+75) 91.50ft (Nabors 129 ( p315p,.., Beluga River Unit North Referefle True Plan: BRU 243-34 Surrey eaktiliiiieff Matfled: Minimum Curvature elfbere; Plan: BRU 243-34 BRU 243-34wp05 VertiCat N Elating ";:rgtilit Sectb*ri Azimuth Depth TVDss +Nf-S § 04; 10 • , - (ft) 6 ,e 4;; , (ft) ft (ft) (ft t ' 6,540.37 0.00 327.44 6,311.50 6,220.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 , Beluga 1 base -'BRU 243.34v/p03 Beluga Base 6,600.00 0.00 327.44 6,371.13 6,279.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,620.37 0.00 327.44 6,391.50 6,300.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Estimated Lowest Perfs 6,700.00 0.00 327.44 6,471.13 6,379.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,800.00 0.00 327.44 6,571.13 6,479.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,900.00 0.00 327.44 6,671.13 6,579.63 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 6,920.37 . 0.00 327.44 6,691.50 • 6,600.00 921.61 -504.54 2,621,726.00 1,456,448.00 0.00 1,050.67 Targets Tarp:4148Mo- Tvp +16t-ft t, -.'";*•! , E • Shape *) (°) , hifftniss target Angle -wr {to (ft) ' .4-.."4*••14.17( lrst, BRU 243-34wp03 Beluga Base 0.00 0.00 6,311.50 921.61 -504.54 2,621,726.00 1,456,448.00 - plan hits target - Point BRU 243-34wp03 Beluga D 0.00 0.00 3,549.50 921.61 -504.54 2,621,726.00 1,456,448.00 - plan hits target - Point ASSIT■roA.. " - Casing P°0El kg" - .1 * .t. ,, ' IN- lc • • 4, fdetatured Vertical 4,:ilf,-,1*•%-:,414 . 44,4".44iti .^.- Phile# Depth Depth (ft) -- 2,998.91 2,791.50 9 5/8" x 12 1/4" 9 12 6,920.37 6,691.50 7" x 8-3/4" 7 8 . Formation 44.1 ,•"" ediftft P Vertical • *k Depth D�pth SS • 14.% N ame • 5,309.37 5,080.50 Beluga H top 0.00 3,778.37 3,549.50 Beluga D top 0.00 3,264.18 3,041.50 Sterling A top 0.00 4,398.37 4,169.50 Beluga F top 0.00 4,033.37 3,804.50 Beluga E top 0.00 6,040.37 5,811.50 Beluga I top 0.00 3,620.19 3,391.50 Sterling C top 0.00 4,934.37 4,705.50 Beluga G top 0.00 3,472.06 3,244.50 Sterling B top 0.00 6,540.37 6,311.50 Beluga I base 0.00 C 4/7/2008 3:46:19PM Page 5 COMPASS 2003.16 Build 42F n I tk I 4 • 1111 ConocoPhillips HALL1BURTDN Standard Proposal Report Database: EDM v16 Prod Local, Co - Ordinate ' Well Plan: BRU 243 -34 Company:- ConocoPhillips (Alaska) Inc. -Expl IVO' Reforel ' , , : Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' Protect: South Alaska ND Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (' Site: ,4 *< Beluga River Unit North - t- - - . >, �' .' . , , True Well: " Plan: BRU 243-34 s urvey 1 . . ' ; ,-- , ' - Minimum Curvature Welibore ° # l ' Plan: BRU 243 -34 � iii . Design: BRU 243- 34wp05 �. ti`fi- ^su?.:,. .e.�^s :..:r; •. .,,,�. su: +.:.$r °�z.. `z'ro : - ;.x;�s -:a;'. _�,1 ra , sz ffii�7a. -"' " x i Lc i1 COOrdb � f. # ( _ 0 (ft) Comment 1 , R. x _, 596.50 596.50 0.00 0.00 KOP; 2.5 DLS 6,620.37 6,391.50 921.61 - 504.54 Estimated Lowest Perfs 4/7/2008 3 :46 :19PM Page 6 COMPASS 2003.16 Build 42F OR 1G ! ! t 1 ConocoPhillips (Alaska) Inc. -Expl South Alaska xt ;: Beluga River Unit Plan: BRU 243-34 Plan: BRU 243-34 BRU 243- 34wp05 • nI n D 1 Sperry Drilling Services Ti f k Clearance Summary D . J,I 4 i Anticollision Report . i 07 April, 2008 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) `; Reference Design: Beluga River Unit - Plan: BRU 243-34 - Plan: BRU 243 -34 - BRU 243- 34wp05 i„ Well Coordinates: 2,620,796.55 N, 1,456,937.80 E (61° 10' 09.91" N, 151° 02' 21.32" W) • Datum Height: Plan: 243 -34 (16.5 +75) @ 91.50ft (Nabors 129 (16.5 +75)) $ Scan Range: 0.00 to 6,920.37 ft. Measured Depth. Scan Radius is 890.39 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Yl fi ; Version: 2003.16 Build: 42F 4 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 J HALLIBURTt3N if Sperry Drilling Services 15: 56, April 072008 Geodetic Datum: North American Datum 1983 IP" BRU 243-34wp05 Ellipsoid: GRS 1980 16.50 To 6920.37 Zone: Alaska zone 4 GonoeoP"hillips From Colour To MD ANT1-COLLISION SETTINGS Critical Interpolation Method: MD, Interval: 25.00 I M aximum Range: 890.19 Issues: Project: South Alaska 17 247 2497 2997 8997 9997 Scan Method: Trap. Cylinder North Site: Beluga River Unit Error face Elliptical Conic 247 497 2997 3497 9997 11997 Well Plan: BRU 243 -34 waon mina Method Rule. Based Parent Well No wellbore data is available GLOBAL FILTER APPLIED: All wellpaths within 200' +100 /1000 of reference 497 747 3497 3997 11997 13997 Wellbore: Plan: BRU 243 -34 SU RVEV PROGRAM 747 997 3997 4497 13997 15997 997 1247 4497 4997 15997 17997 REFERENCE INFORMATION : 2008 00 Validated: Yes Versioo:3 1247 1497 4997 5997 17997 . "." 19997 Co-ordinate (N /E) Reference: Well Plan. BRU 243 -34, True North Depth From Depth To Survey/11m Tool 1497 1747 5997 6997 19997 24997 Vertical (TVD) Reference: Plan 243 -34 (16.5 +75) a 91.500 (Nabors 129 (16.5 +75)) 10.56 6920.37 BRU 243 p05 (Kati: BR['ulap nnvmscc 1747 1997 6997 7997 Section (VS) Reference: Slot - (0.00N, 0.00E) 1997 2497 7997 8997 Measured Depth Reference: Plan. 243 -34 (16.5 +75) a 91.505 (Nabors 129 (16.5 + - 5)) 0 0/360 150 s�r� -30 / 330 30 ' 0/360 \.�/ 40 7 3 "'1 ts -30 / 330 30 101 tis"� 43 - 347 (wp02) -60 / 300 - 60 -60 / 300 60 50 ' a t �a�* T a S `�,, `` 14- 35ALTwpO ' , h eliP �� -90 / 270 90 1 .'i 1 , Ig4, g 10 y . -90 / 270 s _ I eix.`" /� 9 ,13 lyMM I ' ft RU 214 - gitiliwall 411F - 120/240 120 S Ss j 120 / 240 120 - 150 / 210 150 40 - - 180/180 101 SECTION DETAILS -150 / 210 150 Sec MD Inc Azi TVD +N / -S +61 -W DLeg TFace VSec Target 1 16.50 0.00 0.00 16.50 0.00 0.00 0.00 0.00 0.00 150 2 596.50 0.00 0.00 596.50 0.00 0.00 0.00 0.00 0.00 3 1788.00 29.79 331.30 1735.05 265.61 - 145.41 2.50 331.30 302.81 -180 / 180 4 2785.45 29.79 331.30 2600.71 700.26 - 383.36 0.00 0.00 798.33 5 3778.37 0.00 327.44 3549.50 921.61 - 504.54 3.00 180.00 1050.67 BRU 243- 34w1)03 Beluga D 6 6540.37 0.00 327.44 6311.50 921.61 - 504.54 0.00 327.44 1050.67 BRU 243- 34wp03 Beluga Base 7 6620.37 0.00 327.44 6391.50 921.61 - 504.54 0.00 327.44 1050.67 8 6920.37 0.00 327.44 6691.50 921.61 - 504.54 0.00 327.44 1050.67 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [50 ftin] ConocoPhillips (Alaska) Inc. -Expl HALLI9URTDN South Alaska Anticollision Report for Plan: BRU 243 -34 - BRU 243- 34wp05 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River Unit - Plan: BRU 243 -34 - Plan: BRU 243 -34 - BRU 243- 34wp05 Scan Range: 0.00 to 6,920.37 ft. Measured Depth. Scan Radius is 890.39 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 - Welibore Name - Design (ft) (ft) (ft) (ft) ft Beluga River Unit • BRU 214 -35 - BRU 214 -35 - BRU 214 -35 446.50 71.15 446.50 55.66 450.00 4.592 Centre Distance Pass - Major Risk BRU 214 -35 - BRU 214 -35 - BRU 214 -35 546.48 72.69 546.48 53.03 550.00 3.697 Clearance Factor Pass - Major Risk BRU 214 -35 - Prelim: BRU 214 -35ALT - BRU 214 -35A 596.50 71.15 596.50 61.27 600.00 7.198 Centre Distance Pass - Major Risk BRU 214 -35 - Prelim: BRU 214 -35ALT - BRU 214 -35A 646.44 71.47 646.44 60.80 650.00 6.697 Clearance Factor Pass - Major Risk C D Prelim: BRU 243 -34T - Prelim: 243 -34T - 243 -34T (wpl 596.50 71.15 596.50 61.27 600.00 7.198 Centre Distance Pass - Major Risk Prelim: BRU 243 -34T - Prelim: 243 -34T - 243 -34T (wp( 821.23 72.98 821.23 59.52 825.00 5.423 Clearance Factor Pass -Major Risk W) Some of these offset wells are currently being reviewed for inaccuracies. AC data is subject to change once position data is corrected. Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 16.50 6,920.37 BRU 243- 34wp05 MWD +SCC 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. 07 April, 2008 - 15:53 Page 2 of 4 COMPASS Calculation Method: Minimum Curvature Error System: ISCWSA Project: South Alaska Scan Method: Tray. Cylinder North ConocoPhilli 7 Error Surface: Elliptical conic Be U a River unit P Warning Method: Rules Based Site: g BRU 243- 34wp05 Geodetic Datum: North American Datum 1983 Well: Plan: BRU 243 -34 Magnetic Model: BGGM2007 Wellbore: Plan: BRU 243 -34 Quarter Mile View Ground Level: 75.00 RKB: Plan: 2434 4( 16. 5+ 75) @91.5099 (Nabors 129(16.5+75)) BRU 243- 34wp05 Northing/ASP Y: 2620796.55 Easting/ASP X: 1456937.80 2600 "` - BRU 2123l 1950 e qv r a) O X 1300 I $ a �QN � r . - c RU 243- 34wp03 Beluga Basecle' 0 Z 650 i , 0 • -I 0 ,, ,b , - BRU 241 -34 � 6 -650 g 03 2 0.35 I -- 1 -3250 -2600 -1950 -1300 -650 0 650 1300 1950 West( -) /East( +) (650 ft/in) Operator ConacoP061p. ( Almka) Inc. -.PI Gnd Correction: .091 Job No: EN /A Field' South Alaska Magnetic Declination. 19.16 ° APE No: IIN /A Well: 152 233.34wp05 Dip: 73.96 ° API No: EN /A Ng: /WA Doyley per 100 ft Sysem (109) Reference: Mean Sea level Surface loca000 Original VS Plane: 331.30 ° Parentwer: Plan: BRU 20340 X: 1456937.30 n View VS Plane: 331.30 RRR Neigh: 91.50 It 1: 2620296.55 II Unit System: API Eased / PPS Section (VS) Reference: Slot Comments: POOL: 8 Plan View' 8 $ 0 BRU 243- 34wp05 Plan: 3458' to 6220' TVDss - - 2624000 BRU 212 -35T: 3458' to 6220' TVDss BRU 224 -34: 3458' to 6220' TVDss BRU 214 -35: 3458' to 6220' TVDss • - -- 2623000 A • t 2622000 CD Section View' -4.- BRU 243- 34wp05 Plan —BRU 212 -35T —BRU 224 -34 - - -- BRU 214 -35 2621000 ( , )':.e 2 3 - - - - 2620000 � .... 2619000 a ... e.' East ( +) / West ( -) in P.) 3000 II .) t 0 J 0 2 4000 E d 5000 ---- -- -- - - -- ------ --- - --- -- 6000 7000 0 p 0 8 0 0 8 e N ID N 00 00 c co N Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (BRU 243- 34wp05 Toolbox.xls) 4/7/2008 4:22 PM Closest in POOL Closest Approach: Reference Well: BRU 243-34w.05 Plan Offset Well: BRU 212 -35T Coords. - Coords. - ASP ASP 3 -D ctr -ctr .; Subse Meas. Subsea N( +) /S( -) View VS Meas. Subsea N( +) /S( -) View VS • Distance. L.. _ Difference Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments POOL Min Distance POOL Min Distance (1924.56 ft) in POOL (1924.56 ft) in POOL (3458 - 6220 TVDss) (3458 - 6220 TVDss) to BRU 243- 34wp05 to BRU 212 -35T Plan (3458 - 6220 D 1924.56 > . 4900 0 327.44 4579.598 2621726 1456448 1050.752 (3458 - 6220 TVDss) 4801 8.62 216.8 4585.657 2622787 1458053 1240.744 TVDss) Closest Approach: Reference Well: BRU 243- 34wp05 Plan Offset Well: BRU 224 -34 Coords. - Coords. - ASP ASP 3 -D ctr -ctr HarSan `a ' Meas. Subsea N( +) /S( -) View VS Meas. Subsea N( +) /S( -) View VS Distance. L5stae e Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments POOL Min Distance POOL Min Distance (2179 ft) in POOL °" "� " (2179 ft) in POOL (3458 - 6220 TVDss) (3458 - 6220 TVDss) to BRU 243- 34wp05 '. to BRU 224 -34 (3458 Plan (3458 - 6220 ° 2179 21 21 .r. `t 4800 0 327.44 4479.598 2621726 1456448 1050.752 6220 TVDss) 4884 3.53 327.18 4479.07 2620564 1454605 1351.29 TVDss) Closest Approach: Reference Well: BRU 243- 34wp05 Plan Offset Well: BRU 214 -35 Coords. - Coords. - ASP ASP 3 -D ctr -ctr FtorHontal Subse; Meas. Subsea N( +) /S( -) View VS Meas. Subsea N( +) /S( -) View VS Distance. 'ster Di fern :.a Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments Depth Incl. Angle TRUE Azi. TVD E( +)/W( -) (331.3 °) Comments POOL Min Distance 0 POOL Min Distance (3025.78 ft) in POOL 1 (3025.78 ft) in POOL (3458 - 6220 TVDss) (3458 - 6220 TVDss) to BRU 243- 34wp05 to BRU 214 -35 (3458 Plan (3458 - 6220 3025.78 '5 6 - 33.0573 3800 0 327.44 3479.598 2621726 1456448 1050.752 6220 TVDss) 4315 25.49 135.27 3446.54 2619827 1458803 - 1724.9 TVDss) BRU 243- 34wp05 POOLSummary.xls 4/7/2008 4:32 PM • • BRU 243-34wp05 Surface Location (as- staked): CL a T`A 4 44 ' 1 1 :trta114 . 1 1a rear D I From: r-- To: I } Datum: INAD83 A Region: lalaska j Datum: INAD27 J Region: lalaska . j • LatitudelLongitude 'Decimal Degrees C Latitude /Longitude 'Decimal Degrees � 3 !' UTM Zone: r South r UTM Zone: "True r South C` State Plane Zone: I4 Units: lus -ft J $ C State Plane Zone: 4 s Units: us-ft • j ✓ Leai L?N , r.., k €r YCs H' 6 Legal Description (NAD27 only) r Starting Coordinates: -i - Legal Description ~ - -_ — X: 11456937.80 Townsh' : _ Range: � 013 N • ng 010 W Y: 2620796.55 i Mericfian g Section: s FNL 14134.8550 FEL 1959.18942 3 V Transform I Quit I Help I BRU 243- 34wp05 TD/Toe: ,%, ,fir.•+ #*;;� a "+a:+' ..: ' .'"_"'. ,...,v .. ' From: — To: _. - Datum: INAD83 A Region: lalaska J j Datum 1NAD A R egion: lalaska J • Lattude/Longitude 'Decimal Degrees A C Latitude/Longitude (Decimal Degrees J l C UTM Zone: r South I r UTM Zone: True r South f: State Plane Zone: Units: lus-ft J € C State Plane Zone: IT — E, Units: us -ft Ir31 .a;1v! ; C■ Legal Description (hlAD27 only) 1 Starting Coordinates: - Legal D escription — — —� X: _ 11456448.00 � ! Township: 013 N . Range: 010 W Y: 12621726.00 Meridian: g ., Sectian: g4 j I 13213.2410 11462.8367 1 ' FNL 3213.2410 FEL I € I, Transform Quit I Help I ORIGINAL. REV DATE BY CK APP •DESCRIPTION REV DATE BY !APP DESCRIPTION NOTES: T13N 21 22 23 3 1. ALL COORDINATES SHOWN IN ASP ZONE 4 NAD 8.3. ✓ 24 0 GEOGRAPHIC COORDINATES SHOWN IN NAD 83. &I 2. VERTICAL BENCHMARK IS TOP RIM OF METAL WELL 27 26 25 CELLAR ON NORTH SIDE, REFERENCE LOUNSBURY AS BUILT DATED 08- 04-80. 28 F Or .3. SURVEY CONTROL POINT "CPI— SOUTH" IS A SET PK E PA`' NAIL IN TOP CENTER OF 8" WOOD POST, 4' ABOVE o� GROUND. CONTROL POINT "CP2— SOUTH" IS A PK 3 34 35 �o NAIL SET FLUSH WITH GRAVEL PAD. o C 4. ALL DISTANCES ARE TRUE. BELUGA . THIS RUNWAY SURVEY 5. PAD IS ROTATED 6140'52" WEST FROM NORTH. LAKE I 'S LEGEND: T12N � y,Q o o`� ® SURVEY CONTROL 4 . G • EXISTING WELL 5 J c,� • PROPOSED CONDUCTOR X 0 1 BOLLARD 8 9 — GAS LINE CPI SOUTH VICINITY MAP - 1" = 1 MILE DENOTES SPILL TRAJECTORY s e, 9s BRU 243 -34 (PROPOSED) \9 o Oc- i% �� .` * LOCATED WI THING PROTRACTED �2.aF 5 � ` SEC. 34, T. 13 N., R. 10 W., �...� ` 'Q HEATE? 11 R .� -,,,F� 5I ig,s 5 z �/ 8'JI5:7c SEWARD MERIDIAN. . --- ,,.._ ,l ' 0 6 / 1,145' F.S.L., 959' F.E.L. ' _,a,, —. "� / \° TENNA \ LAT.= 6110'09.91"N i, 0 LONG. = 151'02'21.32"W \�. Y = 2,620,797' ' / X = 1,456,938' ............. 1 \ \ _- \E 0 .. A� li 11 `, . B DGE _ : .0P . • �SL �/ \ CP2 SOUTH RU 214 -35 EEXlS7lNG OF • • "1 / ' WORTH. ti C / N au�u we / � \ � GRAVEL PAD �2 .n•n � * : TM /\ • ...* / � � m' 4 u5 §vAr 1 i B RU 243 -3 ` A O P ' : Francis J. Corning' o i , ffi �n \ \ I t J, • LS -10685 .- . J� r RIOW / / I I Pf S �- \ \ s K r� Op -•.......••'PL = 1 \ \ 34 II I I Ir 10NP `` LA\ ' p ` APPEGETATED A H GHER �. THAN EXISTING PAD SURVEYOR'S CERTIFICATE \ -. OF GRAVEL PAD I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND` B oP P RO LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF I " \ .0,00.‘6"-' SCALE: 1 " =80' ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND ` \. 4 LOUNSBURY THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT \ �� . & ASSOCIATES. INC. AS OF FEB 27, 2008. suxvEy07 >n'G s PLANNERS ''� (am)zre -6451 AREA: MODULE: UNIT: ConocoPhillips BRU 243 -34 WELL AS STAKED DRAWING WITH PAD CONFIGURATION Alaska, Inc. INCLUDING CONTOURS AND SPILL TRAJECTORY CADD FILE NO. DRAWING NO: PART: REV: BRU 243 -34 AS STAKED_NAD83.dwg BRU 243 -34 AS STAKED_NAD83.dwg 1 OF 1 0 ORIGINAL • , � ' , U ! (7 fADL058814 r --1‘.17____ 6 31 r (-_, r Q ' • ---n. , i 7/ ,,, 8 AD 0. A 3 32 • / • Pretty ii.ai • BRWD -1 • Unit 1 ADL390385 • 212 - 16 5 1 1 3 93,1 r - f 4 , ADL0588 .,� . 7 931913 ADL06305� ' • 224 13 A.- �. 221 23 I �� 1 r 't ADL390572 r �.a �� 93191 ' • 2 12 - 24 ADEN' /•• I „,r' 21 I 20 r — BRU 224 -23 ' ♦ BRU 232 - 26 • 14 - 19 .mom._ A 1 �-I A' � Electric _ I �,a !,. - r -212-25 ...--it 30 29 I 23:T-27 I .214-26 r— I 241 -34 • Beluga River ' - 'q�'fz Air Strip ;212 -35T � '} Y , N. G ' 35 36 31 32 ' . . 3 . 2 ADL Su ace Location ADL017599 ' • 31730 J ' 232 -4 • C: EATS, E. F. Beluga RivE a 1 6 •��� _4 Unit Li I 32 -9 V CO � Y^l. k ,, al la C O 3,727 1 ConocoPhillips A DL017592 ® 11 1 Alaska, Inc. /` d '' 31727 ,At * # J ET A 017592 Beluga River Unit 0 , ;z 1 Surface Map li — R 61 M �E 4 -10-08 05012501 E01 J ,=1=, l 11" 5k PSI 3'-11 8„ HYDRIL ANNULAR BOP SCREWED HEAD I f FLANGED BOTTOM CONNECTION • I � I I � 10'-4" — — W 1 Rl4 11" 5k PSI SHAFFER p ' -g " 3" #5000 DOUBLE GATE PREVENTOR --� HCR VALVE -- 1 - RAIVf -- -- STUDDED CONNECTION p - �`� 3" CHOKE LINE 1 - i1�11 I i 9 ,-- 2" #5K GATE VALVE °°s3 ' ------- �� - T__________ /d I 11" 5000 # API 2 KILL LINE FLANGED MUD CROSS G) _ 3-1/8" # 5000 11" 5k PSI SHAFFER + GATE VALVE 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 SU it V= SIMIZEUMTIMPLIE l O Nabors Alo�lm 2225 D SbM! ROD .N iV10YN1Y10��� '" 00003 -2079 p° NABORS ALASKA RIG 129 Tina 11" BLOW —OUT PREVENTOR 3 RAM STACK CONFIGURATION I IAPR08 A JA JA ISSUED "' JOE ALSION 'M WIN 'm" BY PAUL SWRI M A MT N V V' OCKRIFIM scut WA DM Mk 2000 ' t 1 29_0002 - RAM SHE 1 or I 1 3000PSI MLES 1. DIVERTER ANNULAR NORMALLY 111 OPEN. TIN • 2. VALVE NORMALLY CLOSED. TO ACCUMULATOR 1 HYDRIL CK — — — — 21 I/4' • �"1 2000PSI • J ` FROM ACCUIRAAIOR ANNULAR r ..J ..— .. —..— -- - 21 I/4 2000PSI FLANGES !ILA !' omen UA DIVERTER SPOOL \ ■i 11 4 1 '+ 6 II!_�'�I IMAIII _ . M _ ow �' ^ tam FABRI -VALVE 16' FIG. 36 KNIFE VALVE II - m �, I: _ I � - 1 =m- 9 9 r _ _ „ DIVERTER CONFIGURATION P I __ _ _ _ 1 1 :._,I . .1 '_ .I111111=1. ■ IIIIIIIII i 1 `...V me M9k1 _ .I I IIIlii, ; • loll mis -> ..tb , 41 Man aR � � ' :' Z'7B�I : I 1 , I II 1': ���� III ii ' NABORS ALASKA RIG 129E GENERAL ARRANGEMENT O;a EaTaAnaterwxxo re"lli" Ag DARnp Ma. ,,N uorsou Alaska amo. 99 2- • 96R— z6� e000 PRAT NABORS ALASKA RIG 129 MIL GENERAL ARRANGEMENT 16' DIVERTER SYSTEM 1 IAPR08 A 44 PS „ a ISSUED AISTON PAUL SMRN 1rv9o+4 RI PAUL SIMRI 'el. . A 661E It 6I 6Y pp. DESCRF11011 SOU WA OM APRIL 2008 d10. 1 29_0001 1 of 1 Iril • ' li. 7 :. 'II ,, I.,. . . i „.. i.,.. , ...FT= r PEI r r :,- ........_ , iv 23 ; .�.,N ■ . I ,1 = -- �� ■ itmliiIMIIMM iii I d 1 I. o I N I • .. � _ I Fl em. TOP OF 6" MATTING BOARDS o 1..... r �� t o _ � _ _ _ EXISTING GROUND TOP OF • N WELLHEAD DIVERTER CENTERLINE 11 ' - 6" 7' -0" -1 - - 11 ' -0" - - 11 ' -5" — — NABORS RIG 129 20" NYDRIL SP 2000 ANNULAR sa a " a 20" DIVERTER SPOOL w/ 16" OUTLET ► ° °. 1. RS RIG 129 OB 50J 2639 WELL SIDE ELEVATION "u 20" MSP 2K x 16' DIVERTER ASSEMBLY VIM B L r L SIDE ELEVATION IOMRO6 A ,14 PS ISSUED °PNM1 ALS10N JOE NS10A ' PMA SMM It'. A Mit v, it Vn DESrnvno■ 30■E N/A DATE AR 2008 1N ..20 -m OWEMkR I of 1 6" x 4" "l 4' 4' x 6' NABORS ALASKA RIG RETURNS D Au ❑ _ M R /� E . HOP EIR D STEM SCHEMA ■ I 12" -- NOT SHOWN ARE TANK CLEANOUTS r ■ 6" x 4' 4" „ /4' 4" x 6" SUMP SUCTION OR STEAM LINES B" ❑ 0 iAi ❑ MUD MIX • HOPPER 6' _ � • 6' 6' 6" �„I,�,�,1,J„t —_ CENTRIFUGE SHALE SHAKE SHALE SHAKER I i I i i I VI SUMP 6' I 6' DESILTER 6 , MI TO SUMP 6' 6'' ^ IN DISCHARGE 6'— 6' 6' — MANIFOLD ; 5' x 6' QP 1 H • SAND -4:;i'i i I �--, TRAP 6 1 I 6' 115' a, - 6 6' , , , —710"1—H."1-1— f 0" �6 0 6"., 5x6 . 5'x6'_ I I I ) CENTRIFUGALS _ 6 " I��116' ' 6' 6' 6' , 6' , • Q. Q I I - 6 ' 6' r i 6' r 'v i 6 . 6 - f • c • • i r i ■ 5 x 6" 116 , � 6. vil or -��, �I I I 8' 6' _ .- 6• 6 . ® e \ 3' _ 3' 3' 3' 3' 3' 3' 1 FROM 39 Bbls A 167 Bbls A 167 Bbla A 174 bls A 197 Bbla A 196 Bbls A MANIFOLD 243 Bbls A 41 Bbls A 49 Bbla G 207 Bbls G 207 BbIs G 216 Bbla C 245 Bbla C 244 able G 302 Bbls G 51 Bbls G I PILL TANK 8' 6" x 3' 3' TRIP TANK 36" MUD GAS N. ❑ 0 — SEPARATOR 8" FLOW LINES • TO MUD PUMPS TO FLARE • I LEGEND —D— CONCENTRIC REDUCER ® BOTTOM MUD GUN LOW PRESSURE TYPE TOTAL ACTIVE VOLUME = 1183 Bbls. —a4— GATE VALVE TOTAL GROSS VOLUME = 1470 Bbls. •<„, AGITATOR 70 mrlitiZMEp i BUTTERFLY VALVE C/W FLANGES r xoew, AIw1, rang GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK _ ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH ►: xs2s a se..■ ma96a91N1a/C.q :Mgr 99."37263g 907- 263 -9000 SUCTION VALVE, TEE TYPE ( NOT INCLUDING TRIP TANK ) mace NABORS ALASKA RIC 129 TANK EQUALIZER TOLE OR SKIMMER MUD SYSTEM SCHEMATIC 1183 BBL ACTIVE SYSTEM SUCTION VALVE, ELL TYPE 6aaa If MOM BY APPROiED ■ EVE RREF: HODGSON INDUSTRIAL DESIGN LTD. 'AE ALS ON MA. SUM PAUL SAM _ DWG. NO. RJ052-05 Mit Et V V DESCRIPTION SCAM N/A w O CTOINY 2003 "C. xa 129_0002 54 d 1 • • Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: The application of ConocoPhillips Alaska, Inc. for a spacing exception to allow for the drilling, completion and production of the Beluga River Unit 243 -34 well within 3,000 feet of other wells capable of producing from the same gas pool. ConocoPhillips Alaska, Inc. by a letter dated and received March 28, 2008, requests the Alaska Oil and Gas Conservation Commission (Commission) issue an order allowing an exception to the spacing requirements of 20 AAC 25.055 (a)(4) to allow for the drilling, completion and production of the Beluga River Unit 243 -34 well within 3,000 feet of other wells capable of producing from the same gas pool. The proposed surface and bottomhole locations for this well are as follows: Surface Location: 959' FEL, 1145' FSL, Sec. 34, T13N, R1OW, Seward Meridian (SM) Bottomhole Location: 1463' FEL, 2067' FSL, Sec. 34, T13N, R1OW, SM The Commission has tentatively scheduled a public hearing on this application for May 22, 2008 at 9:00 ant at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on April 30, 2008. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793 -1221 after May 15, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7 Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on May 12, 2008 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the May 22, 2008 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact the Commission's Special Assistant Jody Colombie at 793 -1221. Daniel T. Seamount, Jr. Chair • • TRANSMITTAL LETTER CHECKLIST zea WELL NAME 2 T 3 - '3 PTD# 2-40E - 0 7 Development, Service Exploratory Stratigraphic Test P Non-- Conventional Well FIELD: id∎e-- 7 �. v�1� POOL: le147-- atapie-te-coe Circle Appropriate Letter / 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 25.005t0, 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 f •mpliance with 20 AAC EXCEPTION 25.055. Approval to perforate an • r • • / in t is contingent upon issuanc of a cons ati' • r approving a spacing exception. [Cry U � assumes the liability of any protest tote spaci exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 WELL PERMIT CHECKLIST Field & Pool BELUGA RIVER, UNDEFINED GAS - 92500 Well Name: =E GA RI NIT 43 -4 Program DEV Well bore seg ❑ PTD#: 2080790 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PE.4._GeoArea 820 Unit 50220 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached _ _ NA - 2 Lease number appropriate _ - _ Yes Surface loc in federal Iease_A029656; -top prod interval_and TD infederal lease AQ29657_ 3 Unique welt name and number _ - - Yes 4 -Well located in_adefined _pool _ _ No Beluga Riveer Gas Pool is undefined. 5 _Well located proper distance-from drilling unit_boundary - No - SPACING EXCEPTION NEEDED: Violates 20 MC 25.Q55_ less than 1500 feet from property 6 Well located proper dtstance from other wells _ No _ line and less than 3000 feet from offset welts 211-_03,224-34, 212 -35, 212 -35T & 214 -35. 7 Sufficient acreage_available in_drilling unit No _ 8 if deviated, is welibore plat included _ Yes 9 Operator only affected party _ No Shoreline ( <1500 feet away) is the_property line between federal (onshore) &state (offshore) 10 Operator has_ appropriate bond in force _ Yes 11 Permit can be issued without conservation order Ito - - Appr Date 12 Permit can be issued without administrative_approval - Yes SFD 5/7/2008 13 Can permit be approved before 15-day wait No 14 Welllocated within area and_strata authorized by Injection Order # (put IO# in comments) (For No _ 15 All s_within 1 /4_mile area_of review identified (For service well only) _ NA 16 Pre- produced injector; duration_of preproduction less than 3 months- (For service welt only) NA 17 - Nonconven, gas conforms to AS31,05.030(1.1.A),(j_2.A -D) _ NA Engineering 18 Conductor string- provided _ _ Yes - 19 Surface casing_ protects ali_known USDWs Yes Surface casing planned at -2800' tvd cemented to surface. - 20 CMT_v-ol adequate_to circulate_on_conductor & surf csg _ - Yes 21 CMT vol adequate to tie- iniong 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 been approved _ NA - 26 Adequate wellbore separationproposed _ _ - Yes Proximity analysis performed. Traveling cy linder path calculated, Below -800', well paths diverge. 27 Ifdiverterrequired 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 5/20/2008 29 BOPI*a,_do they meet regulation - _ Yes _ �` 30 BOPE_press rating appropriate; testto_(put psig in comments) Yes _ MASP calculated a2 2017psi, 3500_psi_BOP test appropriate. 31 Chpke_manifold compliesw /API_RP -53 (May 84) - Yes - 32 Work will occur without operation shutdown _ Yes - 33 is presence of H2$ gas probable - No H2S is not reported in Beluga production. Rg_equipped with sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only) NA - _ Geology 35 Permit can be issued w/o hydrogen_ sulfide measures Yes 36 Data_presented on potential overpressure zones Yes _ Pressure within reservoir may vary- from 8.4 to_3.5 ppg, _ Appr Date 37 Setsrnic analysis of shallow gas zones - NA _ SFD 5/7/2008 38 Seabed condition survey (if off- shore) NA - - 39 Contact name /phone for weekly_ progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: C omm i ssioner D ssioner Date 5- 2/-06 weti ..5 8 • • 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 BRU243- 34.tapx Sperry -sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jul 09 15:09:41 2008 Reel Header Service name LISTPE Date 08/07/09 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 08/07/09 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 243 - API NUMBER: 502832012400 OPERATOR: Conoco Phillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 09- JUL -08 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: MW- 000574289 MW- 000574289 LOGGING ENGINEER: B. STEPHENS B. STEPHENS OPERATOR WITNESS: L. HILL L. HILL SURFACE LOCATION SECTION: 34 TOWNSHIP: 13N RANGE: lOW FNL: FSL: 1145 FEL: 959 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 93.52 GROUND LEVEL: 77.00 WELL CASING RECORD Page 1 ot-O 1(0(0 1 S BRU243- 34.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 .000 .0 2ND STRING 8.750 9.000 3027.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -4). 4. MWD RUN 2 IS DIRECTIONAL WITH DGR, EWR -4, COMPENSATED NEUTRON POROSITY (CTN), AND STABILIZED LITHO- DENSITY (SLD), AT BIT GAMMA RAY (ABG), AND PRESSURE WHILE DRILLING (PWD). ABG DATA IS PRESENTED SPLICED TO DGR AT THE END OF THE RUN. SLD TOOL CLOCK PROBLEMS CAUSED A FAILURE IN RECOVERING RECORDED DENSITY DATA, AND REAL -TIME AND MAD PASS DATA ARE UTILIZED IN THE FOLLOWING INTERVALS ACCORDINGLY: DEPTH INTERVAL (MD /TVD) DATA TYPE DATA 4316 - 6478/4092 -6254 REAL TIME CONVENTIONAL DEN NO PE OR SO 6478- 6622/6254 -6398 RECORDED CONY. DEN., SO. Pe 6622 - 6917/6398 -6693 RECORDED RAPID SAMPLE DEN.,CONZV. SO., Pe ALL FROM TRIP OUT 5. MWD DATA IS CONSIDERED PDC PER THE E -MAIL FROM RICK LEVINSON OF CONOCOPHILLIPS ALASKA, INC. TO ROB KALISH OF SPERRY DRILLING SERVICES DATED 7/8/08. 6. RUNS 1 -2 REPRESENT WELL BRU243 -34 WITH API #:50 -283- 20124 -00 THIS WELL REACHED A TOTAL DEPTH (TD) OF 7005'MD /6781'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA- SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE Page 2 S BRU243- 34.tapx TIME -HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (LOW COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON- ROTATED INTERVALS REFLECTING BIT DEPTH SLD SLIDE = NON ROTATED INTERVALS REFERRING TO SLD SENSOR DEPTH ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 8 -3/4" NOMINAL, FIXED HOLE SIZE MUD WEIGHT: 9.3 -9.5 PPG MUD SALINITY: 33,000 PPM CHLORIDES 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 08/07/09 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 RPD 181.5 6944.0 RPS 181.5 6944.0 FET 181.5 6944.0 RPM 181.5 6944.0 RPX 181.5 6944.0 GR 190.0 6951.5 ROP 231.5 7004.0 PEF 3020.0 6907.5 Page 3 • 40 BRU243- 34.tapx NCNT 3027.0 6894.5 FCNT 3027.0 6894.5 NPHI 3027.0 6894.5 DRHO 3030.0 6907.5 RHOB 3030.0 6907.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 181.5 3041.0 MWD $ 2 3041.0 7005.0 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 1 Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value - 999.25 Depth units Datum Specification Block sub- type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT /H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU -S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G /CM 4 1 68 44 12 DRHO MWD G /CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 7004 3592.75 13646 181.5 7004 ROP MWD FT /H 0 743.39 152.021 13544 231.5 7004 GR MWD API 15.99 116.37 68.041 13524 190 6951.5 RPX MWD OHMM 0.21 2000 24.8099 13461 181.5 6944 RPS MWD OHMM 0.27 2000 36.9839 13461 181.5 6944 RPM MWD OHMM 0.27 2000 46.6154 13461 181.5 6944 RPD MWD OHMM 0.55 2000 52.3659 13461 181.5 6944 FET MWD HR 0.1 131.39 1.36296 13461 181.5 6944 NPHI MWD PU - 12.72 109.74 39.1891 7736 3027 6894.5 Page 4 BRU243- 34.tapx FCNT MWD CNTS 367.8 2383.2 843.272 7736 3027 6894.5 NCNT MWD CNTS 87260.4 167148 117536 7736 3027 6894.5 RHOB MWD G /CM 1.15 2.94 2.22213 7713 3030 6907 DRHO MWD G /CM -0.26 0.75 0.0791664 3179 3030 6907.5 PEF MWD B/E 0.08 12.84 2.07992 3202 3020 6907.5 First Reading For Entire File 181.5 Last Reading For Entire File 7004 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 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 08/07/09 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 FET 181.5 2991.0 RPD 181.5 2991.0 RPX 181.5 2991.0 RPM 181.5 2991.0 RPS 181.5 2991.0 GR 190.0 2999.0 ROP 231.5 3041.0 LOG HEADER DATA DATE LOGGED: 02- JUN -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3041.0 TOP LOG INTERVAL (FT): 181.0 BOTTOM LOG INTERVAL (FT): 3041.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 5 BRU243- 34.tapx MINIMUM ANGLE: .5 MAXIMUM ANGLE: 31.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): .0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (S): 223.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.300 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.400 87.8 MUD FILTRATE AT MT: 3.800 68.0 MUD CAKE AT MT: 2.500 .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 - 999.25 Depth Units Datum Specification Block sub- type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT /H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWDO10 HR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 3041 1611.25 5720 181.5 3041 ROP MWD010 FT /H 4.1 716.93 220.829 5620 231.5 3041 Page 6 4 BRU243- 34.tapx GR MWD010 API 23.57 92.92 54.7358 5619 190 2999 RPX MWD010 OHMM 6.2 153.3 43.6344 5620 181.5 2991 RPS MWD010 OHMM 6.45 330.66 65.0556 5620 181.5 2991 RPM MWD010 OHMM 6.62 1349.47 86.6532 5620 181.5 2991 RPD MWD010 OHMM 7.22 1784.35 100.664 5620 181.5 2991 FET MWD010 HR 0.1 4.78 0.614945 5620 181.5 2991 First Reading For Entire File 181.5 Last Reading For Entire File 3041 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 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 08/07/09 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 GR 2999.5 6951.5 PEF 3020.0 6907.5 RPD 3024.0 6944.0 RPX 3024.0 6944.0 FET 3024.0 6944.0 RPS 3024.0 6944.0 RPM 3024.0 6944.0 NCNT 3027.0 6894.5 FCNT 3027.0 6894.5 NPHI 3027.0 6894.5 DRHO 3030.0 6907.5 RHOB 3030.0 6907.0 ROP 3041.5 7004.0 LOG HEADER DATA DATE LOGGED: 11- JUN -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite Page 7 • BRU243- 34.tapx DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 7005.0 TOP LOG INTERVAL (FT): 3041.0 BOTTOM LOG INTERVAL (FT): 7005.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 22.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 253600 EWR4 ELECTROMAG. RESIS. 4 216787 SLD STABILIZED LITHO DEN 078609 CTN COMP THERMAL NEUTRON 231174 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3027.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB /G): 9.30 MUD VISCOSITY (S): 70.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 33 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.100 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .629 124.0 MUD FILTRATE AT MT: .110 68.0 MUD CAKE AT MT: .090 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 - 999.25 Depth Units Datum Specification Block sub- type...0 Name Service order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT /H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 Page 8 a • BRU243- 34.tapx RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G /CM 4 1 68 44 12 DRHO MWD020 G /CM 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2999.5 7004 5001.75 8010 2999.5 7004 ROP MWD020 FT /H 0 743.39 103.249 7926 3041.5 7004 GR MWD020 API 15.99 116.37 77.4986 7905 2999.5 6951.5 RPX MWD020 OHMM 0.21 2000 11.3176 7841 3024 6944 RPS MWD020 OHMM 0.27 2000 16.8636 7841 3024 6944 RPM MWD020 OHMM 0.27 2000 17.9185 7841 3024 6944 RPD MWD020 OHMM 0.55 2000 17.7481 7841 3024 6944 FET MWD020 HR 0.41 131.39 1.89909 7841 3024 6944 NPHI MWD020 PU -S 12.72 109.74 39.1891 7736 3027 6894.5 FCNT MWD020 CNTS 367.8 2383.2 843.272 7736 3027 6894.5 NCNT MWD020 CNTS 87260.4 167148 117536 7736 3027 6894.5 RHOB MWD020 G /CM 1.15 2.94 2.22213 7713 3030 6907 DRHO MWD020 G /CM -0.26 0.75 0.0791664 3179 3030 6907.5 PEF MWD020 B/E 0.08 12.84 2.07992 3202 3020 6907.5 First Reading For Entire File 2999.5 Last Reading For Entire File 7004 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 08/07/09 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 08/07/09 Origin STS Reel Name UNKNOWN Page 9 I • BRU243- 34.tapx Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 10 • BRU243- 34.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jul 09 15:09:41 2008 Reel Header Service name LISTPE Date 08/07/09 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 08/07/09 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 243 -34 API NUMBER: 502832012400 OPERATOR: Conoco Phillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 09- JUL -08 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: Mw 000574289 Mw 000574289 LOGGING ENGINEER: B. STEPHENS B. STEPHENS OPERATOR WITNESS: L. HILL L. HILL SURFACE LOCATION SECTION: 34 TOWNSHIP: 13N RANGE: 10W FNL: FSL: 1145 FEL: 959 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 93.52 GROUND LEVEL: 77.00 WELL CASING RECORD Page 1 c -ate • /6,9/3 • • BRU243- 34.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 .000 .0 2ND STRING 8.750 9.000 3027.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -4). 4. MWD RUN 2 IS DIRECTIONAL WITH DGR, EWR -4, COMPENSATED NEUTRON POROSITY (CTN), AND STABILIZED LITHO - DENSITY (SLD), AT BIT GAMMA RAY (ABG), AND PRESSURE WHILE DRILLING (PWD). ABG DATA IS PRESENTED SPLICED TO DGR AT THE END OF THE RUN. SLD TOOL CLOCK PROBLEMS CAUSED A FAILURE IN RECOVERING RECORDED DENSITY DATA, AND REAL -TIME AND MAD PASS DATA ARE UTILIZED IN THE FOLLOWING INTERVALS ACCORDINGLY: DEPTH INTERVAL (MD /TVD) DATA TYPE DATA 4316 - 6478/4092 -6254 REAL TIME CONVENTIONAL DEN NO PE OR SO 6478- 6622/6254 -6398 RECORDED CONV. DEN., SO. Pe 6622 - 6917/6398 -6693 RECORDED RAPID SAMPLE DEN.,CONZV. SO., Pe ALL FROM TRIP OUT 5. MWD DATA IS CONSIDERED PDC PER THE E -MAIL FROM RICK LEVINSON OF CONOCOPHILLIPS ALASKA, INC. TO ROB KALISH OF SPERRY DRILLING SERVICES DATED 7/8/08. 6. RUNS 1 -2 REPRESENT WELL BRU243 -34 WITH API #:50 - 283 - 20124 -00 THIS WELL REACHED A TOTAL DEPTH (TD) OF 7005'MD /6781'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA- SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE Page 2 i . BRU243- 34.tapx TIME -HOURS TNPS = SMOOTHED THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF NEUTRON FAR DETECTOR COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEUTRON NEAR DETECTOR COUNT RATE. SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (LOW COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION )LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT RATE BIN) SLIDE = NON- ROTATED INTERVALS REFLECTING BIT DEPTH SLD SLIDE = NON ROTATED INTERVALS REFERRING TO SLD SENSOR DEPTH ENVIRONMENTAL PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 8 -3/4" NOMINAL, FIXED HOLE SIZE MUD WEIGHT: 9.3 -9.5 PPG MUD SALINITY: 33,000 PPM CHLORIDES 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 08/07/09 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 RPD 181.5 6944.0 RPS 181.5 6944.0 FET 181.5 6944.0 RPM 181.5 6944.0 RPX 181.5 6944.0 GR 190.0 6951.5 ROP 231.5 7004.0 PEF 3020.0 6907.5 Page 3 III BRU243- 34.tapx NCNT 3027.0 6894.5 FCNT 3027.0 6894.5 NPHI 3027.0 6894.5 DRHO 3030.0 6907.5 RHOB 3030.0 6907.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 181.5 3041.0 MWD 2 3041.0 7005.0 $ # 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 .AIN Max frames per record undefined Absent value - 999.25 Depth Units Datum Specification Block sub- type...0 Name Service Order units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 ROP MWD FT /H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU -S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G /CM 4 1 68 44 12 DRHO MWD G /CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 7004 3592.75 13646 181.5 7004 ROP MWD FT /H 0 743.39 152.021 13544 231.5 7004 GR MWD API 15.99 116.37 68.041 13524 190 6951.5 RPX MWD OHMM 0.21 2000 24.8099 13461 181.5 6944 RPS MWD OHMM 0.27 2000 36.9839 13461 181.5 6944 RPM MWD OHMM 0.27 2000 46.6154 13461 181.5 6944 RPD MWD OHMM 0.55 2000 52.3659 13461 181.5 6944 FET MWD HR 0.1 131.39 1.36296 13461 181.5 6944 NPHI MWD Pu - 12.72 109.74 39.1891 7736 3027 6894.5 Page 4 • BRU243- 34.tapx FCNT MWD CNTS 367.8 2383.2 843.272 7736 3027 6894.5 NCNT MWD CNTS 87260.4 167148 117536 7736 3027 6894.5 RHOB MWD G /CM 1.15 2.94 2.22213 7713 3030 6907 DRHO MWD G /CM -0.26 0.75 0.0791664 3179 3030 6907.5 PEF MWD B/E 0.08 12.84 2.07992 3202 3020 6907.5 First Reading For Entire File 181.5 Last Reading For Entire File 7004 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 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 08/07/09 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 FET 181.5 2991.0 RPD 181.5 2991.0 RPX 181.5 2991.0 RPM 181.5 2991.0 RPS 181.5 2991.0 GR 190.0 2999.0 ROP 231.5 3041.0 LOG HEADER DATA DATE LOGGED: 02- JUN -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3041.0 TOP LOG INTERVAL (FT): 181.0 BOTTOM LOG INTERVAL (FT): 3041.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 5 BRU243- 34.tapx MINIMUM ANGLE: .5 MAXIMUM ANGLE: 31.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): .0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (5): 223.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.300 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.400 87.8 MUD FILTRATE AT MT: 3.800 68.0 MUD CAKE AT MT: 2.500 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value - 999.25 Depth units Datum Specification Block sub- type...0 Name Service Order units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 ROP MWD010 FT /H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 3041 1611.25 5720 181.5 3041 ROP MWD010 FT /H 4.1 716.93 220.829 5620 231.5 3041 Page 6 BRU243- 34.tapx GR MWD010 API 23.57 92.92 54.7358 5619 190 2999 RPX MWDO10 OHMM 6.2 153.3 43.6344 5620 181.5 2991 RPS MWDO10 OHMM 6.45 330.66 65.0556 5620 181.5 2991 RPM MWDO10 OHMM 6.62 1349.47 86.6532 5620 181.5 2991 RPD MWDO10 OHMM 7.22 1784.35 100.664 5620 181.5 2991 FET MWD010 HR 0.1 4.78 0.614945 5620 181.5 2991 First Reading For Entire File 181.5 Last Reading For Entire File 3041 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 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 08/07/09 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 GR 2999.5 6951.5 PEF 3020.0 6907.5 RPD 3024.0 6944.0 RPX 3024.0 6944.0 FET 3024.0 6944.0 RPS 3024.0 6944.0 RPM 3024.0 6944.0 NCNT 3027.0 6894.5 FCNT 3027.0 6894.5 NPHI 3027.0 6894.5 DRHO 3030.0 6907.5 RHOB 3030.0 6907.0 ROP 3041.5 7004.0 $ LOG HEADER DATA DATE LOGGED: 11- JUN -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite Page 7 • BRU243- 34.tapx DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER FT : 7 ( ) 7005.0 TOP LOG INTERVAL (FT): 3041.0 BOTTOM LOG INTERVAL (FT): 7005.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 22.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 253600 EWR4 ELECTROMAG. RESIS. 4 216787 SLD STABILIZED LITHO DEN 078609 CTN COMP THERMAL NEUTRON 231174 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3027.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB /G): 9.30 MUD VISCOSITY (S): 70.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 33 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.100 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .629 124.0 MUD FILTRATE AT MT: .110 68.0 MUD CAKE AT MT: .090 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 - 999.25 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT /H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 Page 8 410 111 BRU243- 34.tapx RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 NPHI MWD020 PU -S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G /CM 4 1 68 44 12 DRHO MWD020 G /CM 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2999.5 7004 5001.75 8010 2999.5 7004 ROP MWD020 FT /H 0 743.39 103.249 7926 3041.5 7004 GR MWD020 API 15.99 116.37 77.4986 7905 2999.5 6951.5 RPX MWD020 OHMM 0.21 2000 11.3176 7841 3024 6944 RPS MWD020 OHMM 0.27 2000 16.8636 7841 3024 6944 RPM MWD020 OHMM 0.27 2000 17.9185 7841 3024 6944 RPD MWD020 OHMM 0.55 2000 17.7481 7841 3024 6944 FET MWD020 HR 0.41 131.39 1.89909 7841 3024 6944 NPHI MWD020 PU -S 12.72 109.74 39.1891 7736 3027 6894.5 FCNT MWD020 CNTS 367.8 2383.2 843.272 7736 3027 6894.5 NCNT MWD020 CNTS 87260.4 167148 117536 7736 3027 6894.5 RHOB MWD020 G /CM 1.15 2.94 2.22213 7713 3030 6907 DRHO MWD020 G /CM -0.26 0.75 0.0791664 3179 3030 6907.5 PEF MWD020 B/E 0.08 12.84 2.07992 3202 3020 6907.5 First Reading For Entire File 2999.5 Last Reading For Entire File 7004 File Trailer Service name STSLIB.003 Service sub Level Name Version Number 1 0 0 Date of Generation 08/07/09 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 08/07/09 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 08/07/09 Origin STS Reel Name UNKNOWN Page 9 BRU243- 34.tapx Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 10 /(V (L og 7c7 • 'Iry o nocoPh il hi Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA BRU 243 -34 CONFIDENTIAL Provided by: El EPOCH Approved by: Compiled by: Steven Pike Ryan Massey Date: 06/18/08 Distribution: 4 / (v6,,o ConocoPhillips Alaska, Inc. BRU- 243 -34 CONF1UENT1L • 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 Daily Activity Summary 4 3 GEOLOGICAL DATA 5 3.1 Lithostratigraphy 5 3.2 Mudlog Summary 6 3.3 Connection Gases 12 3.4 Trip (Wiper) Gases 12 3.5 Sampling Program / Sample Dispatch 13 4 PRESSURE / FORMATION STRENGTH DATA 14 4.1 Pore Pressure Gradient Evaluation 14 4.2 Quantitative Methods 15 5 DRILLING DATA 16 5.1 Survey Data 16 5.2 Bit Record 18 5.3 Mud Record 18 6 MORNING REPORTS 19 Enclosures 2 "/100' Formation Log (MD and TVD) 2 "/100' LWD / Lithology Log (MD and TVD) 2 "/100' Gas Ratio Log (MD and TVD) 2 "/100' Drilling Dynamics Log (MD and TVD) • HI EPOCH 1 ConocoPhillips Alaska, Inc. BRU- 243 -34 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime QGM Agitator (Mounted in possum Ditch as belly) 0 Flame ionization total gas & chromatography. Effective Circulating Density From Sperry-Sun 3041' to TD 0 (ECD) Hook Load / Weight on bit RigWatch Sensors 0 Mud Flow In RigWatch Sensors 0 Mud Flow Out RigWatch Sensors 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 system Rigwatch) Mudlogging unit DAC box In -unit data collection /distribution 0 center Pit Volumes, Pit Gain /Loss RigWatch Sensors 0 Pump Pressure RigWatch Sensors 0 Pump stroke counters RigWatch Sensors 0 Totco Well Monitoring Totco RigWatch Sensors 0 Components Rate of penetration RigWatch Sensors 0 RPM RigWatch Sensors 0 Torque RigWatch Sensors 0 1.2 Crew Unit Type • Arctic Steel Unit Number : ML030 Mudloggers Years Days Sample Catchers Years Days Technician Days Steven Pike 5 17 Emil Opitz 0.6 15 Allan 3 Williams Ryan Massey 1 18 Matt Smith 0.6 15 Years experience as Mudlogger "2 Days at wellsite between spud and total depth of well • HI EPOCH 2 ConocoPhillips Alaska, Inc. BRU- 243 -34 2 WELL DETAILS 2.1 Well Summary Well: BRU- 243 -34 API Index #: 50- 283 - 20124 -00 Field: Beluga River Unit Surface Co- Ordinates: 1147' FSL, 957' FEL Sec 34, T13N, R1OW Borough: Kenai Primary Target Depth: State: Alaska TD Depth: 7005' Rig Name / Type: NAD #129, Triple Suspension Date: Primary Target: Sterling A, B , C and License: g Beluga D thru 1 Spud Date: 6/1/2008 Ground Elevation: 77.00 Completion Date: 6/18/2008 RT Elevation: 93.52' Completion Status: Secondary Target: Depth: Classification: TD Date: 6/11/2008 TD Formation: Beluga I Days Testing: NONE Days Drilling: 11 2.2 Hole Data Maximum Depth Mud Shoe Depth LOT ip Hole TD Dev. Casing/ Section MD TVDSS Formation Weight ( o inc) Coring Liner MD TVDSS (ppg (ft) (ft) (ppg) (ft) (ft) 12.25" 3041' 2841' NA 9.7 19.5 NA 10.625" 3027' 2825' 16.0 8.5" 7005' 6781' Beluga I 9.5 0.86 NA 7" Base Additional Comments • EPOCH 3 ConocoPhillips Alaska, Inc. BRU- 243 -34 • 2.3 Daily Activity Summary 6/02/2008: Rig up Epoch unit. 6/03/2008: Continue rig up. 6/04/2008: Finish rigging up logging unit. 6/05/2008: Test BOPs. 6/06/08: Continue to test BOPs. 6/07/08: Continued testing BOP's. Rig down test equipment. Install wear bushing. Lay down 20 joints of drill pipe. Prep rig floor to lay down drill pipe. Mixing mud in pits. Lay down drill pipe from 2360' to surface. Clean and clear rig floor. Pick up 150 joints of 4" drill pipe. 6/08/08: P/U drill pipe and stand back. Service top drive, grease ID, blocks, swivel and adjust draw works brake. P/U BHA, bit, motor, float sub, NM pony collar, stab; RLL smart tool. Program MWD, load nuclear sources. Circ and condition due to lost circulation, shallow pulse test. P/U remainder of PD 4" 57 joints. Circ and condition mud to 9.2 ppg. M/U testing equipment and test casing to 16 ppg FIT. Drill shoe track plus 20' of new hole. 6/09/08: Finish LOT, broke down at 800 psi or 14.4 pounds /gallon EMW. Displace mud to Flo -Pro system, 206 barrels, 1400 psi. Clean pit 6 and drill ahead with new mud. Drill from 3061' to 4030', short trip to wipe hole. Back ream and pump out first two stands, no problems. POOH to 2976'. Good hole, monitor for 15 minutes, no problems. TIH, wash down last stand. Continue drilling ahead from 4030'. • 6/10/08: Service rig -top drive, grease swivel, blocks. Rotary drilling from 4222' to 5035'. Service top drive and draw works, circulate and condition mud @ 550 GPM at 2400 psi. Trip to shoe at 5035' MD, no problems. Drilling gas of 780 units found @ 5491'. Rotary drilling ahead from 5743' ahead. 6/11/08: Service top drive, grease swivel, blocks, TD. SPR @ 5746' MD 5520'TVD. Rotary drilling ahead from 5722'MD with GPM, 2650 psi off, 2820 psi on, 53% flow, 100 RPM, 6 -7k torque, PU= 104k, So= 84k, Rot 91 k. Short trip at 6030' after circulating bottoms up. Back ream 3 stands out, max overpull 5k. Check flow - no flow. Run in hole from 4988' MD. Wash last stand to bottom @ 6030'. Continue rotary drilling ahead. 6/12/08: Drill from 6030' to 7005'. Circulate hole clean and pull out of hole to the shoe to monitor well. Losses at 1 Bph when in shoe. Run in hole to 7000', circulate and condition mud for logging run. 6/13/08: Pull out of hole, lay down BHA. Rig up Schlumberger to run E -line. Log the hole. 6/14/08: Pull out of hole with E -line, rig down and rig up for drill pipe conveyed log. Run in hole and log. 6/15/08: MDT log. Pull out of hole for E -line side core log. 6/16/08: Pull out of hole, rig up E -Line side wall core BHA, run in hole and log. Pull out of hole due to tool problems, Run in hole with clean out assembly. Circulate and condition mud. 6/17/08: Reamed 900' to bottom, Circulate and condition mud. Pull out of hole, lay down cleanout BHA. Rig up and run casing. • Li EPOCH 4 ConocoPhillips Alaska, Inc. BRU- 243 -34 3 GEOLOGICAL DATA • 3.1 Lithostratigraphy LWD tops refer to provisional picks by the ConocoPhillips Alaska, Inc. (CPAI) well site geologist. FORMATION PROGNOSED LWD PICK MD SSTVD MD SSTVD (ft) (ft) (ft) (ft) Sterling A NA 2965' 3222' 2919' Sterling B NA 3165' 3458' 3146' Sterling C NA 3315' 3617' 3303' Beluga D NA 3470' 3771' 3453' Beluga E NA 3725' 4026' 3710' Beluga F NA 4090' 4388' 4070' Beluga G NA 4620' 4924' 4606' Beluga H NA 4995' 5309' 4992' Beluga I NA 5715' 6052' 5734' • Beluga I Base NA 6215' 6509' 6242' 1 III El EPOCH 5 ConocoPhillips Alaska, Inc. BRU- 243 -34 • 3.2 Mudloq Summary Sterling A Group ( -2919' to -3145' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 198 13 105 15 4 9 This interval from around 3,222 feet measured depth (MD) to about 3,457 feet MD and consists of alternating sequences of sand, siltstone and shale with very thin beds of coal dispersed throughout. Sands /Sandstones are commonly clear to white with some translucent; predominantly quartz grain sand matrix; upper very fine to upper fine grain sand; moderate to poorly sorted; very angular to subangular with some subrounded; moderate to high sphericity; slightly polished to somewhat frosted grains were observed; very thin lenses of sand interbedded with thin beds of claystone and shale; no visible sample fluorescence; no other oil indicators were present. Siltstones are usually siltstone = light gray to medium gray with some light brown hues; mushy to slightly stiff in places; brittle to crumbly; irregular fracture; amorphous cuttings habit; dull to earthy luster; very silty to slightly gritty texture; very thin grading upward to a silty sand with some carbonaceous shales; no visible fluorescence; no other oil indicators were present. Shales are commonly g medium to dark gray with some light gray to brownish gray hues; moderately firm to slightly stiff; very brittle to clumpy; planar to slightly blocky fracture, amorphous cuttings habit; waxy to slightly greasy luster; smooth to somewhat silty in places; very thin slightly fissile in places; some carbonaceous shale included; no sample fluorescence was observed; no other oil indicators were present. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 3055 15 2833 NA NA NA NA NA NA Sterling B Group ( -3146' to -3302' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 187 25 106 30 4 17 This section which starts at around 3458 feet MD to approximately 3616 feet MD is comprised of alternating beds of shale, claystone, tuffaceous claystone, tuffaceous siltstone and sands, with very thin stringers of intermittent seams of coal. The shale in this section is composed of medium to light gray with some grayish brown to brownish gray hues; moderately firm to slightly stiff; very brittle to clumpy; planar to slightly blocky fracture amorphous cuttings habit; greasy to slightly waxy luster; smooth to somewhat silty in places; very thin slightly fissile in places; some carbonaceous shale with some coal interbedded; no visible no sample fluorescence was observed. Claystone is composed of light gray to medium gray with some brownish gray hues; mushy to pasty; very brittle; irregular fracture; amorphous cuttings habit; very earthy to clayey luster; clayey texture with some • slightly gritty in places; pale yellow green sample fluorescence was observed; no solvent cut. El EPOCH 6 ConocoPhillips Alaska, Inc. BRU- 243 -34 The tuffaceous claystone and siltstone is comprised of light gray to pinkish gray with some hues of grayish orange pink; clumpy to clotted with some pasty to clumpy; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some vitreous in places; very clayey texture with some slightly gritty in places; thinly interbedded with thin beds of coal and thin beds of claystone and shale; very faint yellow green sample fluorescence was observed; no solvent cut; no other petroleum indicators were observed. The average sands in the sequence are made up of clear to translucent with some white to gray; predominantly quartz sand matrix; upper very fine to upper fine grain sand; moderately to poorly sorted; very angular to subangular with some rounded; moderate to high sphericity; slightly impacted to frosted grains were observed; very faint pale yellow green sample fluorescence was observed; no other oil indicators were present. The beds of coal encountered in this section are comprised of mostly black with blackish red and brownish black to very dusky red hues; very stiff; very firm to stiff; somewhat dense to brittle in places; blocky to irregular fracture; amorphous cuttings habit; vitreous luster. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 3530' 30 5968.7 NA NA NA NA NA NA Sterling C Group ( -3303' to -3452' SSTVD) Drill Rate (ft/hr) T otal Gas (units Maximum Minimum Average Maximum Minimum Average 190 25 215 19 12 16 This section which was encountered at approximately 3617 feet MD to approximately 3770 feet MD and is comprised of shales, siltstone, tuffaceous siltstone and claystones with a lesser percentage of sands and coals. The representative shale formation in this section is composed of light to medium gray with some grayish brown to brownish gray hues; slightly firm to soft; mostly brittle to clumpy; planar to slightly blocky; butter curl PDC cuttings habit; greasy to slightly waxy luster; smooth to somewhat silty in places; very thin slightly fissile in places; no visible sample fluorescence; no other oil indicators were observed. The tuffaceous siltstones and claystones are comprised of very light gray to gray with some brownish gray hues; mushy to pasty; very brittle; irregular fracture; amorphous cuttings habit; very clayey to earthy luster; clayey texture to somewhat gritty in places; very faint pale yellow green sample fluorescence was observed; no solvent cut. The siltstones in this group is comprised of medium to light gray with some light brown hues; mushy to slightly pasty in places; crunchy to crumbly; irregular fracture; amorphous cuttings habit; dull to earthy luster; very silty to slightly gritty texture; very thin interbedded with thin lenses of sand and very thin beds of shale; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 3636' 19 3684.9 NA NA NA NA NA NA • El EPOCH 7 ConocoPhillips Alaska, Inc. BRU- 243 -34 Beluga D Group (- 3453' to 3709' SSTVD) • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 249 20 135 31 1.5 16 This interval from around 3,771 feet MD to about 4,025 feet MD consists of mainly alternating sequences of siltstone and shale with some tuffaceous siltstone and tuffaceous claystone and sand in lesser amounts. The shale formation in this sequence is comprised of mostly medium to light gray; mushy to slightly stiff in places; brittle to slightly stiff throughout; irregular to blocky to somewhat planar fracture; butter curl PDC cuttings habit; greasy to slightly waxy luster; clayey to smooth luster with some slightly gritty; slightly fissile in places; thin laminae interbedded with thin lenses of sand and thin beds of siltstone; no visible sample fluorescence; no solvent cut. The representative siltstone formation in this section consists of light gray to dominantly medium gray with common brownish hues; firm; crumbly; irregular fracture; platy to irregular cuttings habit; trace very fine lower sand size clasts interbedded throughout; silty to gritty to slightly sandy texture in spots; dull earthy luster; thin beds of carbonaceous material interbedded throughout as parallel laminae and occasionally as contorted laminae. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 3994' 31 6328.2 NA NA NA NA NA NA Beluga E Group ( -3725' to -4089' SSTVD) • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 378.1 20.1 125.4 49.9 2 9.2 This interval from around 4026 feet MD to about 4387 feet MD consists of siltstone, sand, sandstone, tuffaceous siltstone, tuffaceous claystone, and tuffaceous sandstone. The siltstone interval is light gray to dominantly medium gray with common brownish hues; firm; crumbly; irregular fracture; platy to irregular cuttings habit; trace very fine lower sand size clasts interbedded throughout; silty to gritty to slightly sandy texture in spots; dull earthy luster; thin beds of carbonaceous material interbedded throughout as parallel laminae and occasionally as contorted laminae. The sand /sandstone sections are very light gray to medium gray; very fine lower to fine upper grain size present in sandstone with ashy tuff matrix; ranges from easily friable to moderately hard; grain size ranges from medium upper to fine lower in unconsolidated fraction; sub angular to dominantly sub rounded; moderately to moderately well sorted in sandstone; slight ashy matrix present; easily to firmly friable; occasionally very light blue hue in matrix; commonly poorly sorted in loose sand with grain supported matrix; 90% translucent to smokey quartz; 10% coal carbonaceous material, bluish green to slightly pink lithics and coal fragments. The coal section is black with slight brownish hues present; stiff to very firm; blocky to planar fracture in sub mature spots; platy to somewhat bladed cuttings habit; brittle to dense; moderate outgassing present. The tuffaceous siltstone interval is light gray to medium gray to bluish gray with some hues of grayish brown; clumpy to clotted with some pasty to clumpy; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some vitreous in places; very clayey PI EPOCH 8 ConocoPhillips Alaska, Inc. BRU- 243 -34 texture with some slightly gritty in places; thinly interbedded with thin beds of coal and thin beds of • claystone and shale; no oil indicators visible. The tuffaceous claystone section is very light gray to gray with some brownish gray hues; mushy to pasty; very brittle; irregular fracture; amorphous cuttings habit; very clayey to earthy luster; clayey texture to somewhat gritty in places; no oil indicators visible. The tuffaceous sandstone interval is very light gray to gray with some light pinkish to light tan hues; easily friable to firmly friable; grain size ranges from very fine upper to fine lower; moderately to well sorted in spots; dominantly sub rounded grains to sub angular grains; ashy matrix ranges from firm to mushy; non cohesive and non adhesive; grains become more tightly packed with depth; translucent quartz dominates grain composition with trace carbonaceous material; no oil indicators present. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 4081' 49.9 9925.91 NA NA NA NA NA NA Beluga F Group ( -4070' to -4605' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 279.7 24.5 119.5 231.3 1 13.7 This section begins around 4388 feet MD to approximately 4923 feet MD is comprised of siltstone, tuffaceous siltstone, tuffaceous claystone, tuffaceous shale, and intermittent beds of coal stringers. • The siltstone intervals are light gray to gray with some grayish brown hues very pasty to slimy; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster; silty texture with some slightly gritty in places; thinly interbedded with thin beds of shale and thin beds of tuffaceous siltstone tuffaceous claystone; no sample fluorescence; no solvent cut; no oil indicators were observed. The tuffaceous siltstone intervals are light gray to medium gray with some very light gray with some bluish white; lumpy to clumpy to slightly clotted; somewhat crumbly to slightly crunchy; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some vitreous In places; very clayey texture with some slightly gritty in places; thinly Interbedded with thin beds of coal and thin beds of claystone, shale and some very thin beds of coal; also interbedded with thin layers of volcanic tuff in places; no visible sample fluorescence; no solvent cut; no other oil indicators were observed. The tuffaceous claystone section is light gray to medium gray with some hues very light gray and bluish white; very mushy to pasty; very brittle; irregular fracture; amorphous cuttings habit; very clayey to earthy luster; clayey texture to somewhat gritty in places; no visible sample fluorescence was observed; no solvent cut; no other petroleum indicators were present. The tuffaceous shale interval is medium gray to medium dark gray with some light gray to grayish brown hues; moderately firm to slightly mushy; very clumpy to very crumbly; irregular to slightly blocky fracture PDC butter curl cuttings habit; greasy to waxy luster; smooth to somewhat silty in places; very thin interbedded with thin beds of coal and tuffaceous claystone and tuffaceous siltstone; no sample fluorescence was observed; no solvent cut; no other petroleum indicators were present. The coal sections are black with blackish red hues; very firm to stiff; dense; blocky to planar fracture; blocky to somewhat planar cuttings habit; slightly metallic to vitreous; crystalline texture throughout; moderate outgassing present. HI EPOCH 9 II ConocoPhillips Alaska, Inc. BRU- 243 -34 • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4821' 231.3 36935 NA NA NA NA NA NA Beluga G Group ( -4606' to -4991' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 152.0 30.6 109.0 104.6 7.6 16.2 This section begins around 4924 feet MD to approximately 5308 feet MD is comprised of shale, tuffaceous claystone, siltstone, tuffaceous siltstone, and tuffaceous sandstone. The shale section is medium gray to light gray with some light medium gray and bluish white and very light gray hues; predominantly clumpy to lumpy; mostly crumbly to crunchy; irregular to blocky fracture PDC butter curl cuttings habit; greasy to slightly waxy luster; smooth to somewhat silty in places; very thin interbedded with tuffaceous siltstone and tuffaceous claystone with a small amount of tuffaceous shale; no visible sample fluorescence; no solvent cut; no other petroleum indicators were observed. The tuffaceous claystone intervals are light gray to medium gray with some hues bluish white and very light gray; pasty to very mushy; crumbly to crunchy to occasionally firm; irregular fracture; platy to amorphous cuttings habit; very clayey to earthy luster; ashy to slightly silty to clayey texture to somewhat gritty in places; no visible sample fluorescence; no solvent cut. 411 The siltstone is light gray to medium light gray with some very light gray hues; slightly pasty in places; crunchy to crumbly; irregular fracture; amorphous cuttings habit; dull to earthy luster; very silty to slightly gritty texture; very thin interbedded with thin lenses of sand and very thin beds of shale; no visible sample fluorescence; no solvent cut; no other petroleum indicators were present. The tuffaceous siltstone is light gray to medium gray to medium dark gray with some brownish hues; crumbly to slightly crunchy; irregular fracture; easily friable to friable; dull to commonly earthy luster; silty to gritty texture; interbedded with thin laminae of carbonaceous material and tuffaceous clay throughout; silt size particles grade into very fine lower sand size particles; dominantly sub round quartz; no sample fluorescence present. The tuffaceous sandstone section is very light gray to gray with trace light tan hues; soft to easily friable; ashy matrix easily washes away; grain size ranges from very fine lower to fine lower; moderate to moderately well sorted in spots; sub rounded grains to less common sub angular grains; predominantly translucent quartz clast composition; non cohesive and non adhesive; grains loosely consolidated within matrix; no sample fluorescence present. Peaks Depth h TG C1 C2 C3 C41 C4N C51 C5N 5121' 104.6 20730 NA NA NA NA NA NA • El EPOCH 10 ConocoPhillips Alaska, Inc. BRU- 243 -34 Beluga H Group ( -4992' to -5733' SSTVD • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 328.3 25.3 97.1 768.4 7.1 28.2 This section begins around 5309 feet MD to approximately 6051 feet MD is comprised of coal, tuffaceous claystone, sand, tuffaceous siltstone and siltstone. The coal section is black with slight brownish hues present; stiff to very firm; blocky to planar fracture in sub mature spots; tabular to somewhat bladed cuttings habit; brittle to dense; moderate outgassing present. The tuffaceous claystone intervals are light gray to light medium gray with hues of bluish white and brownish gray; firm to mushy; brittle; irregular fracture; clayey to dull earthy luster; amorphous cuttings habit; dominantly clayey to ashy ranging to silty to gritty texture; occasionally carbonaceous laminae interbedded throughout as stringers; no visible sample fluorescence was present. The sand intervals are light gray to gray; grain size ranges from medium upper to fine upper to fine lower; poorly to moderately well sorted in spots; moderate sphericity; dominantly sub rounded grading to sub angular; trace impact features present on quartz; 40 % -80% clear to translucent to slightly smokey quartz; 20 % -40% gray to dark gray volcanic lithics; 10 % -30% multicolored lithics dominated by light bluish green clasts and mature coal fragments; no sample fluorescence was present. The tuffaceous siltstone intervals are light gray to medium gray to medium dark gray with strong light blue and tan hues; crumbly to slightly crunchy; irregular fracture; easily friable to friable; dull to commonly earthy luster; silty to gritty texture; interbedded with thin laminae of carbonaceous material and tuffaceous clay throughout; ashy clay matrix throughout; silt size particles grade into very fine lower sand size particles; dominantly sub round quartz; no sample fluorescence present. The siltstone section is medium light gray to light gray with some very light gray and grayish brown hues; mushy to pasty; crumbly to crunchy; irregular to slightly blocky fracture; amorphous cuttings habit; earthy to dull luster; very silty to slightly gritty texture; very thin interbedded with thin lenses of sand and very thin beds of shale and tuffaceous siltstone and tuffaceous claystone; no visible sample fluorescence; no solvent cut. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5492' 768.4 118911 NA NA NA NA NA NA Beluga I Group ( -5734 to 6242' SSTVD Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 131.0 16.1 77.0 28.7 5.9 14.7 This section begins around 6052 feet MD to approximately 6508 feet MD is comprised of shale, tuffaceous claystone, siltstone, tuffaceous siltstone, and sand. The shale interval is medium gray to light gray with some brownish gray hues; moderately firm to slightly stiff; clumpy to lumpy; irregular to slightly planar fracture amorphous cuttings habit with some PDC butter U EPOCH 11 Conoco Phillips Alaska, Inc. BRU- 243 -34 curl; slightly dull to greasy luster; very thin slightly fissile in places; no visible sample fluorescence; no solvent cut. The tuffaceous claystone sections are very light gray to light medium gray with hues of blackish gray to bluish white very light gray; very lumpy to clumpy; mushy to pasty; dense to brittle; amorphous to somewhat blocky cutting habit; crumbly; irregular fracture; very clayey to earthy luster; amorphous cuttings habit; clayey texture to somewhat gritty in places; abundant dark colored lithic fragments throughout; moderately thick interbedded with thin beds of tuffaceous siltstone; bits of sub mature coal present; dominantly clayey with ash with abundant dark colored lithic fragments throughout; no visible sample fluorescence; no solvent cut; no other petroleum indicators were observed. The tuffaceous siltstone intervals are light gray to medium gray to very light gray with light blue and green hues; very clotted to very clumpy; irregular fracture; amorphous to PDC butter curl cuttings; dull to earthy luster; very silty to gritty texture; interbedded with thin laminae of carbonaceous material and tuffaceous clay and tuffaceous silt throughout; predominantly silty grading into a silty gritty clay; silty grading into very fine sand grains; no visible sample fluorescence; no solvent cut; no other oil indicators were visible. The sand section is very light gray to gray; grain size ranges from fine lower to medium lower; dominantly sub angular to slightly angular to sub rounded; moderate sphericity; moderately to moderately well sorted; 90% clear to translucent to slightly smokey quartz present; 10% sub mature coal carbonaceous material and bluish green lithics; no sample fluorescence was visible. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6484' 28.7 5189.7 NA NA NA NA NA NA • 3.3 Connection Gases lunit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 4987' 192 3.4 Trip (Wiper) Gases lunit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 5083' 4080' 2,406 1.5 7005' 3030' 175 5 • El EPOCH 12 ConocoPhillips Alaska, Inc. BRU- 243 -34 • 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples Bayview Geologic Facility A Set owner: CPAI 30' 3042' — 7005' 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples Bayview Geologic Facility B Set owner: CPAI 30' 3042' — 7005' 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 7 Sample frequency was locally altered according to drill rate constraints and zones of interest. • • U EPOCH 13 4110 Concithillips Alaska, Inc. • BRU- 243 -34 4 PRESSURE / FORMATION STRENGTH DATA The pore pressure gradient (PPG) is estimated to have varied from 9.5 in the Sterling A Group to 9.4 in the Beluga I Group. The mud weight was raised from 9.2 ppg to 9.6 before drilling the Beluga I formation. 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Interval Tops Pore Pressure (EMW) Trend Lithology Lithology MD SSTVD Min Max Interval ( "�o) ( %) (ft) (ft) (ppg) (ppg) Sterling A Sltst, Sh Sn, Co 3222' 2919' 9.4 9.5 Slight FG,CG Increase Sterling B TffSlst, Sn, Co 3458' 3146' 9.4 9.5 Slight FG,CG,TG TffClyst, Sltst Increase Sterling C TffClyst, Sn, Co 3617' 3303' 9.4 9.5 Slight FG,CG, TG TffSltst Increase Beluga D TffSlst, TffClyst Sn, Co 3771' 3453' 9.4 9.5 Slight FG,CG, TG Increase Beluga E TffSlst, Sn, Co 4026' 3710' 9.1 9.2 Slight FG,CG, TG TffClyst, Sltst Increase TffSlst, Sn, Co Slight Beluga F TffClyst, Sltst, 4388' 4070' 9.1 9.2 Increase FG,CG, TG Sh Beluga G TffSlst, Sn, Co 4924' 4606' 9.1 9.2 2 Slight FG,CG, TG TffClyst, Sltst Increase Beluga H Clyst, Sh, Sltst, Sn Co 5309' 4992' 9.1 g 2 Slight FG,CG, TG TffSltst Increase Beluga I Clyst, Sh, Sltst, Sn, Co 6052' 5734' 9.3 9.4 Slight FG,CG, TG TffSltst, Increase NOTE: TffClyst = Tuffaceous Claystone, TffSltst= Tuffaceous Siltstone, Clyst = Claystone /Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sn = Sand, Coal =Co EPOCH 14 Conoi h illi p s Alaska, Inc. • BRU- 243 -34 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) +(0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PPG range, when establishing trends, as with DXC data, with data points in shale intervals. El I EPOCH 15 ConocoPhillips Alaska, Inc. BRU- 243 -34 • 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Depth Incl. I . dam Vertical (ft) (ft) Section Rate (ft) () () Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 16.52 0.00 0.00 16.52 0.00N 0.00E 0.00 0.00 106.28 0.47 132.00 106.28 0.25N 0.27E -0.35 0.52 197.46 0.51 132.14 197.46 0.77S 0.85E -1.08 0.04 286.06 0.58 129.32 286.05 1.32S 1.49E -1.87 0.09 374.22 0.69 138.19 374.21 2.00S 2.19E -2.81 0.17 466.93 0.37 18.52 466.91 2.13S 2.66E -3.15 1.01 556.59 1.64 343.45 556.56 0.63S 2.39E -1.70 1.51 650.00 3.99 331.08 649.85 3.50S 0.44E 2.85 2.59 734.09 6.86 327.98 733.55 10.32N 3.64E 10.80 3.43 829.62 8.34 327.83 828.24 21.03N 10.36W 23.42 1.55 921.69 10.27 326.04 919.10 33.49N 18.50W 38.26 2.12 1019.30 11.64 324.96 1014.92 48.77N 29.02W 56.72 1.42 1116.26 15.05 328.83 1109.25 67.56N 41.16W 79.04 3.63 1213.14 16.07 330.14 1202.58 89.96N 54.34W 105.02 1.11 1307.12 17.42 332.08 1292.57 113.67N 67.41W 132.09 1.55 1403.68 18.82 333.22 1384.34 140.35N 81.19W 162.11 1.49 • 1497.63 19.98 331.80 1472.96 168.02N 95.61W 193.30 1.34 1595.02 26.49 330.85 1562.40 201.69N 114.07W 231.70 6.69 1691.54 31.47 331.18 1646.81 242.59N 136.72W 278.45 5.16 1787.73 31.45 331.44 1728.86 286.63N 160.82W 328.65 0.14 1881.55 31.05 331.35 1809.07 329.36N 184.12W 337.32 0.43 1978.98 30.49 331.89 1892.78 373.21N 207.82W 427.17 0.65 2074.89 29.88 332.25 1975.69 415.81N 230.40W 475.38 0.66 2170.35 29.54 332.55 2058.60 457.74N 252.33W 522.68 0.39 2265.89 28.56 332.11 2142.12 498.82N 273.87W 569.06 1.05 2361.08 28.42 332.17 2225.78 538.97N 295.09W 614.46 0.15 2457.06 28.09 332.51 2310.32 579.22N 316.19W 659.89 0.38 2552.63 27.90 332.55 2394.70 619.03N 336.88W 704.75 0.20 2649.26 27.61 332.84 2480.21 659.01N 357.53W 749.74 0.33 2745.31 25.81 331.56 2566.01 697.21N 377.65W 792.90 1.97 2840.85 22.87 329.14 2653.05 731.44N 397.08W 832.26 3.24 2926.43 20.92 328.08 2732.45 758.69N 413.69W 864.14 2.33 2969.45 20.60 327.53 2772.68 771.59N 421.82W 879.36 0.85 3067.85 18.54 326.75 2865.39 799.29N 439.69W 912.25 2.11 3084.27 18.38 327.03 2880.97 803.65N 442.53W 917.43 1.15 3179.76 17.71 326.55 2971.76 828.39N 458.73W 946.92 0.72 3275.45 16.78 326.66 3063.15 852.08N 474.34W 975.20 0.98 3370.99 15.10 327.08 3155.01 874.04N 488.68W 1001.36 1.76 • 3466.07 13.75 327.70 3247.09 893.99N 501.45W 1024.99 1.42 3563.41 11.45 325.05 3342.08 911.68N 513.16W 1046.14 2.44 El EPOCH 16 ConocoPhillips Alaska, Inc. BRU- 243 -34 3657.55 8.10 323.93 3434.84 924.71N 522.42W 1062.02 3.56 3753.80 5.19 317.15 3530.44 933.38N 529.38W 1072.97 3.13 3851.95 1.68 303.58 3628.40 937.43N 533.59W 1078.55 3.64 3947.32 1.30 294.74 3723.74 938.66N 535.74W 1080.66 0.47 4043.25 1.14 305.78 3819.65 939.67N 537.50W 1082.40 0.30 4139.56 1.74 278.36 3915.93 940.44N 539.73W 1084.15 0.93 4234.58 1.94 267.69 4010.90 940.59N 542.76W 1085.74 0.42 4328.98 1.80 228.39 4105.25 939.54N 545.47W 1086.13 1.34 4426.52 1.61 192.13 4202.75 937.18N 546.90W 1084.76 1.10 4521.26 1.61 195.20 4297.45 934.60N 547.53W 1082.79 0.09 4616.47 1.55 198.19 4392.63 932.08N 548.28W 1080.95 0.11 4712.94 1.60 171.36 4489.06 929.51N 548.49W 1078.80 0.76 4808.15 1.59 132.16 4584.24 927.32N 547.31W 1076.31 1.12 4904.95 1.08 106.49 4681.01 926.16N 545.44W 1074.39 0.80 4998.51 0.75 98.86 4774.56 925.81N 543.98W 1073.38 0.38 5095.08 0.78 100.13 4871.14 925.55N 542.67W 1072.86 0.03 5189.27 0.76 107.10 4965.32 925.25N 541.44W 1071.99 0.10 5284.39 0.61 107.34 5060.44 924.92N 540.35W 1071.16 0.16 5380.99 0.57 11.29 5157.03 924.59N 539.41W 1070.41 0.06 5475.67 0.36 116.02 5251.71 924.29N 538.71W 1069.80 0.23 5568.23 0.48 117.98 5344.26 923.98N 538.10W 1069.23 0.13 5662.39 0.52 104.24 5438.42 923.69N 537.34W 1068.60 0.13 5756.66 0.48 99.89 5532.69 923.51N 536.54W 1068.60 0.06 5850.92 0.40 113.21 5626.94 923.32N 535.85W 1067.53 0.14 5945.67 0.51 115.53 5721.69 923.00N 535.16W 1066.92 0.12 6040.48 0.64 124.75 5816.50 922.52N 534.35W 1066.09 0.17 6136.32 0.60 124.97 5912.33 921.93N 533.50W 1065.15 0.04 6231.99 0.53 121.91 6008.00 921.41N 532.71W 1064.31 0.07 6328.27 0.65 122.01 6104.25 920.93N 531.91W 1063.29 0.13 6420.32 0.72 114.02 6196.42 920.42N 530.94W 1062.37 0.13 6515.37 0.80 116.25 6291.34 919.88N 529.79W 1061.34 0.09 6609.56 0.88 124.35 6385.52 919.18N 528.60W 1060.15 0.15 6706.26 1.02 129.56 6482.20 918.21N 527.32W 1058.69 0.17 6800.45 0.91 145.77 6576.38 917.06N 526.25W 1057.16 0.31 • El EPOCH 17 • Conchillips • Alaska, Inc. BRU- 243 -34 5.2 Bit Record Depth In Total Bit Avg WOB PP Bit Size Make Type / S# Jets / TFA MD / Footage Hrs (ft/hr (Klbs) RPM (psi) Wear BHA 1 8.75" Hughes HCM506Z 6x15s/1.035 3041' 3964' 47 84 5 -10 30 3000 #3 5.3 Mud Record Contractor: MI SWACO Mud Type: LSND Date Depth MW ECD VIS PV YP Gels FL FC Sols O/W Sd pH CI Ca (ppg) (ppg) (s /qt) (cc) (%) Ratio (%) (m1/1) (m1 /1) 6/6/08 3041 9.7 9.5 122 28 20 9/16/22 7 3/- 8 -/92 0.75 8.5 100 30 6/7/08 3041 9.2 9.1 76 17 21 6/7/7 5 1/- 5 -/95 - 9.9 33000 80 6/8/08 4091 9.3 9.1 58 16 20 6/7/7 2.5 1/1 5 -/95 Tr 10.3 37000 100 6/9/08 5464 9.3 9.1 70 23 24 6/7/9 2.0 1/1 5.5 -/95 Tr 9.9 33000 100 6/10/08 6590 9.5 9.3 67 26 25 8/10/12 1.8 1/1 8 1/92 Tr 10.0 34000 100 6/11/08 7005 9.6 9.3 60 23 23 7/9/11 1.6 1/1 8 1/91 Tr 9.8 29000 100 6/12/08 7005 9.8 9.5 68 26 27 7/11/13 3.6 2/1 9 1/90 Tr 10.1 30000 100 6/13/08 7005 9.8 9.5 68 26 25 6/10/13 3.6 2/1 9 1/90 Tr 10.0 29000 100 6/14/08 7005 9.8 9.6 66 26 27 7/11/14 1.8 2/1 9 1/90 Tr 9.9 30000 100 6/15/08 7005 9.8 9.6 89 22 22 5/7/9 4 2/2 8 1/91 Tr 10.1 28000 80 6/16/08 7005 9.6 9.4 72 22 22 5/7/9 4 2/2 8 1/91 Tr 10.0 28000 80 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 EPOCH 18 6 MORNING REPORTS • • El EPOCH 19 ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Larry Hill Date: 6/6/08 Time: 4:36 Current Depth (MD): 3041 Current Testing BOP's Current Depth (TVD): Operations: 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: CI Ca + +: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG: 411) 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 C4l C4N C5l C5N Lithologies: Current: Last 24 hrs: Operational Summary: Tested BOP's. Calibrations: None Failures: None Daily Cost: $3,890.00 • EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Larry Hill Robert Wahl Date: 6/7/08 Time: 4:36 Current Depth (MD): 3041' Current Picking up BHA Current Depth (TVD): 2839' Operations: 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 @ 12:00 MW: 9.7 FV: 122 PV: 28 YP: 20 FL: 7 Gels: 9/16/22 Sol: 8 pH: 8.5 Cl 100 Ca + +. 30 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 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: Continued testing BOP's. Rig down test equipment. Install wear bushing. Lay Operational Summary: down 20 joints of drill pipe. Prep rig floor to lay down drill pipe. Mixing mud in pits. Lay down drill pipe from 2360' to surface. Clean and clear rig floor. Pick up 150 joints of 4" drill pipe. Calibrations: THA, Chromatograph, and Integrator Failures: None • Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Larry Hill Robert Wahl Date: 6/8/08 Time: 5:27 Current Depth (MD): 3329' Current Drilling Ahead Current Depth (TVD): ' Operations: 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 @ 12:00 MW: 9.2 FV: 76 PV: 17 YP: 21 FL: 5 Gels: 6/7/7 Sol: 5 pH: 9.9 Cf 33000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 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: P/U drill pipe and stand back. Service top drive, grease ID, blocks, swivel and adjust draw works brake. P/U BHA, bit, motor, float sub, NM pony collar, stab; Operational Summary: RLL smart tool. Program MWD, load nuclear sources. Circ and condition due to lost circulation, shallow pulse test. P/U remainder of PD 4" 57 joints. Circ and condition mud to 9.2 ppg. M/U testing equipment and test casing to 16 ppg FIT. Drill shoe track plus 20' of new hole. Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Larry Hill Robert Wahl Date: 6/9/08 Time: 5:27 Current Depth (MD): 4550' Current Drilling Ahead Current Depth (TVD): Operations: 24 hr Footage (MD): Drilling Parameters ROP: Current: 95.326 Max: 378.1 Torque: Current: 5.410 Max: 12 WOB: Current 3.331 Max: 17 RPM: Current: 100.785 Max: 108 PP: Current: 1957.466 Max: 2827 Lag: Strokes: 3233 Time: 16.75min Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 12:00 MW: 9.2 FV: 70 PV: 17 YP: 22 FL: 5 Gels: 6/7/7 Sol: 5 pH: 10.0 Cl - 32000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 4020' 60u 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: Siltstone, Tuffaceous Claystone, Carbonaceous Shale. Last 24 hrs: Clay, Tuffaceous Claystone, Shale, Tuffaceous Siltstone, Siltstone, Sand, Sandstone, Tuffaceous Sandstone, Sand, Coal, Ash. Finish LOT, broke down at 800 psi or 14.4 pounds /gallon EMW. Displace mud to Flo -Pro system, 206 barrels, 1400 psi. Clean pit 6 and drill ahead with new mud. Operational Summary: Drill from 3061' to 4030', short trip to wipe hole. Back ream and pump out first two stands, no problems. POOH to 2976'. Good hole, monitor for 15 minutes, no problems. TIH, wash down last stand. Continue drilling ahead from 4030'. Calibrations: THA, Chromatograph, and Integrator 41) Failures: None Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 • Daily Report Report for: Larry Hill Robert Wahl Date: 6/10/08 Time: 2:00 Current Depth (MD): 5760' Current Drilling Ahead Current Depth (TVD): 5438' Operations: 24 hr Footage (MD): 1210' Drilling Parameters ROP: Current: 87.538 Max: 328.3 Torque: Current: 6.665 Max: 9 WOB: Current 1.025 Max: 8 RPM: Current: 93.807 Max: 107 PP: Current: 2737.270 Max: 2845 Lag: Strokes: 4135 Time: 20.78 Surf-Surf: Strokes: 4706 Time: 23.65 ECD: Current: Max: Mud Properties @ 21:00 MW: 9.3 FV: 70 PV: 23 YP: 24 FL: 4 Gels: 6/7/9 Sol: 5.5 pH: 9.9 CI 33000 Ca + +. 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 14u 768u 5492'/5174' • Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 2406u 5083' Connection Gases C1 C2 C3 C41 C4N C51 C5N 193u 4887' 300u 5564' None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Ash, Tuffaceous Claystone, Tuffaceous Siltstone, Sand. Last 24 hrs: Clay, Tuffaceous Claystone, Shale, Tuffaceous Siltstone, Siltstone, Sand, Sandstone, Tuffaceous Sandstone, Sand, Coal, Ash. Service rig -top drive, grease swivel, blocks. Rotary drilling from 4222' to 5035'. Operational Summary: Service top drive and draw works, circulate and condition mud @ 550 GPM at 2400 psi. Trip to shoe at 5035' MD, no problems. Drilling gas of 780 units found @ 5491'. Rotary drilling ahead from 5743' ahead. • Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 Ell EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/11/08 Time: 2:00 Current Depth (MD): 6680' Current Drilling Ahead Current Depth (TVD): 6361' Operations: 24 hr Footage (MD): 920' Drilling Parameters ROP: Current: 36.317 Max: 176.3 Torque: Current: 6.975 Max: 10 WOB: Current 1.440 Max: 25 RPM: Current: 102.207 Max: 107 PP: Current: 2916.852 Max: 3017 Lag: Strokes: 4922 Time: 25.32 Surf-Surf: Strokes: 5608 Time: 5.99 ECD: Current: Max: Mud Properties @ 21:00 MW: 9.5 FV: 67 PV: 26 YP: 25 FL: 3.7 Gels: 8/10/12 Sol: 8 pH: 5.5 CF 34000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG : 14u 80u 6650'/6331' 4110 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas No Noticeable Gas 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: Ash, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone. Last 24 hrs: Clay, Tuffaceous Claystone, Shale, Tuffaceous Siltstone, Siltstone, Sand, Sandstone, Tuffaceous Sandstone, Sand, Coal, Ash. Service top drive, grease swivel, blocks, TD. SPR @ 5746' MD 5520'TVD. Rotary drilling ahead from 5722'MD with GPM, 2650 psi off, 2820 psi on, 53% Operational Summary: flow, 100 RPM, 6 -7k torque, PU= 104k, So= 84k, Rot 91k. Short trip at 6030' after circulating bottoms up. Back ream 3 stands out, max overpull 5k. Check flow- no flow. Run in hole from 4988' MD. Wash last stand to bottom @ 6030'. Continue rotary drilling ahead. 4110 Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/12/08 Time: 1:00 Current Depth (MD): 7005' Current Circulating bottoms up. Current Depth (TVD): 6780' Operations: 24 hr Footage (MD): 325' Drilling Parameters ROP: Current: Max: 165.7 Torque: Current: Max: 11 WOB: Current Max: 16 RPM: Current: Max: 109 PP: Current: Max: 3410 Lag: Strokes: 5010 Time: 26.6 Surf-Surf: Strokes: 5709 Time: 30.37 ECD: Current: Max: Mud Properties @ 13:30 MW: 9.6 FV: 60 PV: 23 YP: 23 FL: 3.2 Gels: 7/9/11 Sol: 8 pH: 9.8 Cl 29000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG : 42u 6973'/6655' • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5l C5N Trip Gas 170u 7005' Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD /TVD) TG Cl C2 C3 C4I C4N C51 C5N Lithologies: Current: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Clay, Tuffaceous Claystone, Shale, Tuffaceous Siltstone, Siltstone, Sand, Sandstone, Tuffaceous Sandstone, Sand, Coal, Tuff. Drill from 6030' to 7005'. Circulate hole clean and pull out of hole to the shoe to Operational Summary: monitor well. Losses at 1 Bph when in shoe. Run in hole to 7000', circulate and condition mud for logging run. Calibrations: THA, Chromatograph, and Integrator Failures: None • Daily Cost: $3,890.00 EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/13/08 Time: 1:00 Current Depth (MD): 7005' Current Wireline Logging Current Depth (TVD): 6780' 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 @ 13:30 MW: 9.8 FV: 68 PV: 26 YP: 27 FL: 3.6 Gels: 7/11/13 Sol: 9 pH: 10.1 Cr 30000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Operational Summary: Pull out of hole, lay down BHA. Rig up Schlumberger to run E -line. Log the hole. Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 El • EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/14/08 Time: 5:00 Current Depth (MD): 7005' Current Logging on drill pipe Current Depth (TVD): 6780' 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 @ 13:30 MW: 9.8 FV: 68 PV: 26 YP: 25 FL: 3.6 Gels: 6/10/13 Sol: 9 pH: 10.0 Cr' 29000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 C4l C4N C51 C5N Gases None Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Operational Summary: Pull out of hole with E -line, rig down and rig up for drill pipe conveyed log. Run in hole and log. Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/15/08 Time: 4:20 Current Depth (MD): 7005' Current Pulling out of hole Current Depth (TVD): 6780' 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 @ 22:00 MW: 9.8 FV: 66 PV: 26 YP: 27 FL: 3.6 Gels: 7/11/14 Sol: 9 pH: 9.9 Cr 30000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG: • Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5l C5N Trip Gas 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: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Operational Summary: MDT log. Pull out of hole for E -line side core log. Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 • El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report • Report for: Donnie Lutrick Robert Wall Date: 6/16/08 Time: 4 :20 Current Depth (MD): 7005' Current Current Depth (TVD): 6780' Operations: Clean out run 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 @ 22:00 MW: 9.8 FV: 89 PV: 22 YP: 22 FL: 4 , Gels: 5/7/9 Sol: 8 pH: 10.1 CI_ 28000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG : 5u 25u • Gas Events Depth (MD /TVD) Cl C2 C3 C41 C4N C51 C5N Trip Gas 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: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Pull out of hole, rig up E -Line side wall core BHA, run in hole and log. Pull out of Operational Summary: hole due to tool problems, Run in hole with clean out assembly. Circulate and condition mud. Calibrations: THA, Chromatograph, and Integrator Failures: None • Daily Cost: $3,890.00 El EPOCH ConocoPhillips Alaska Inc. BRU243 -34 Daily Report Report for: Donnie Lutrick Robert Wall Date: 6/17/08 Time: 4:25 Current Depth (MD): 7005' Current Run Casing Current Depth (TVD): 6780' 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 @ 22:30 MW: 9.6 FV: 72 PV: 22 YP: 22 FL: 4 Gels: 5/7/9 Sol: 8 pH: 10.0 Cl 28000 Ca + +: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 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 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Shale, Tuffaceous Clay, Claystone, Siltstone, Sandstone. Last 24 hrs: Operational Summary: Reamed 900' to bottom, Circulate and condition mud. Pull out of hole, lay down cleanout BHA. Rig up and run casing. Calibrations: THA, Chromatograph, and Integrator Failures: None Daily Cost: $3,890.00 • El EPOCH
