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Home My WebLink About207-014 r k.~. ~ ~"' ~. .~ h, ~ y ~' ~;~ ,: ;., ~ ~~ ~d i- MICROFILMED 6/30/201:0 DO.NOT PLACE .ANY NEW MATERIAL UNDER TH1S PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1 ~ ~~,1 DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2070140 Well Name/No. MILNE PT UNIT LIVIANO 1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23343-00-00 MD 4314 TVD 4169 Completion Date 3/17/2007 Complet ion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Too lengthy for this data field. See 10-407 (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 4314 Open 4/23/2007 g Perforation 5 Blu 1 2750 3356 Qpe""rrf 5/1/2007 Pert Depth Control, Pres, Temp, CR, CCL 8-Mar- ~ v `~ ~ C ~ ~ 2007 L lase e nt a~ti Blu 1 2736 3138 Qp 5/1/2007 erl Single Phase Res , Sampler, SRS, Pres, Temp, Gradio, CR, CCL 8- Mar-2007 Cam g Reservoir Saturation 5 Blu 1 3026 3564 peen 5/1/2007 Res Sat Tool, RST, Pres, ~ Temp, Gradio, GR, CCL 8- i Mar-2007 g Cement Evaluation 5 Col 1 70 3622 Case 5/1/2007 CEL, USIT, DSLT, GR, CCL 8-Mar-2007 g Formation Tester 5 Col 1 3521 4150 Case 5/1/2007 MDT 2-Mar-2007 (X- LARGE Blueline) C Las 15277~/Sonic 182 2498 Open 7/12/2007 BAT Proc Comp Slowness, BAT Proc Data Dens C 15709 'See Notes 0 0 11/26/2007 Digital Logs, PDF, EMF and CGM C Lis 15710/Induction/Resistivity 115 4269 Open 11/26/2007 LIS Veri, ROP, NCNT, FCNT, DRHO, RHOB, RPD, RPS, FET, GR w/TXT, HDR and Tif graphics DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2070140 Well Name/No. MILNE PT UNIT LIVIANO 1 MD 4314 TVD 4169 Completion Date 3/17/2007 gg Magnetic Resonance ~ " Log Magnetic Resonance Ste„„ ,J!og See-~NOT1s9 -Cog 5c ~' Log Gamma Ray .Cog Gamma Ray ~g Neutron Cog Neutron C Asc Directional Survey ~ ~ p~ft t Directional Survey Well Cores/Samples Information: Na e --_ -_ Cuttings Interval Start Stop Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23343-00-00 Completion Status P&A 5 Col 5 Col 5 Col 5 Col 5 Col 5 Col 5 Col 5 Col 5 Col 5 Cot Current Status P&A UIC N 115 4168 Open 11/26/2007 MD MRIL-WD, MR, Quad Combo 115 4168 Open 11/26/2007 TVD MRIL-WD, MR, Quad Combo 115 4314 Open 11/26/2007 MD Bat VDL- Quad Combo 115 4314 Open 11/26/2007 TVD Bat VDL-Quad Combo 115 4314 Open 11/26/2007 MD ROP, DGR, EWR Phase 4 115 4314 Open 11/26/2007 TVD ROP, DGR, EWR Phase 4 115 4314 Open 11/26/2007 MD Dual GR, BAT Bi Modal Acoustic 115 4314 Open 11/26/2007 TVD Dual GR, BAT Bi Modal Acoustic 115 4314 Open 11/26/2007 MD DGR, CNT, ALD 115 4314 Open 11/26/2007 TVD DGR, CNT, ALD 0 4314 Open 8/26/2008 Liviano 01A Dir Srvy also on CD 0 4314 Open 8/26/2008 Liviano 01A Dir Srvy also on CD Sample Set Sent Received Number Comments 3/20/2007 1176 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 2/12/2007. 115 4314 DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2070140 Well Name/No. MILNE PT UNIT LIVIANO 1 Operator BP EXPLORATION (ALASKA) INC Completion Status P&A Current Status P&A API No. 50-029-23343-00-00 MD 4314 TVD 4169 Completion Date 3/17/2007 ADDITIONAL INFORMATION Well Cored? Y Chips Received? 'r7'IV~ Analysis 1'-i'Id"' Received? Comments: ___ - -- Compliance Reviewed By: __ /_ Daily History Received? +~N Formation Tops , / N UIC N - - -_ ___ __ _- --- Date: ~ _ ~ v • • 26-Aug-08 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Liviano #01 Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 33.50' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 4,3'14.00' 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 ~ ~ ~ ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) • i f ~. ,~ : ~,~ :~? Date i 1-21-2007 Transmittal Number:92921 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top De th Bottom De th Lo T e LIVIANO-01 03-01-2007 SPERRY DIGITAL LOG IMAGES CD ROM LIVIANO-01 03-01-2007 SPERRY LIS DATA CD ROM LIVIANO-01 03-23-2007 SPERRY 1 115 4314 MRIL-WD QUAD COMBO MD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4168 MRIL-WD QUAD COMBO TVD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4168 DGR /BAT TVD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4168 BAT VDL QUAD COMBO TVD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4314 DGR BAT MD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4314 BAT VDL QUAD COMBO MD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4314 ROP DGR EWR-PHASE 4 MD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4314 DGR CTN ALD MD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4314 ROP DGR EWR-PASE 4 TVD LOG LIVIANO-01 03-23-2007 SPERRY 1 115 4168 DGR CTN ALD TVD LOG / p ~i l r Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Christine Mahnken ~ ; :, ; ,a DNR '~ ~ 5 wog AOGCC ~U~-d~y ~' '~` t S~ c ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99~ 19-6612 ~ ~ ~~~~~ '~ ~~~" Date 07-10-2007 Transmittal Number:92897 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run De th Bottom De th Lo T e UGNU FORMATION MILNE POINT FIELD CORE PHOTOS LIVIANO-01A 07-05-2007 OMNI CD ROM LIVIANO-01 ~ ~ BAT COMPRESSIONAL DATA PESADO-01 07-05-2007 SPERRY LAS FILES CD ROM (~ ~U ~~ Plea e Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Howard Okland AOGCC Kristin Dirks DNR Petrotechnical Data Center LR2-1 900 L. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~~?-Q~-I "~~~~~ ~~~~~~ Date OS-O1-2007 Transmittal Number:92887 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Log Top SW Name Date Contractor Run De th Bottom De th Lo T e PERFORATING DEPTH LIVIANO-01 03-08-2007 SCH CONTROL LOG SINGLE PHASE RESERVOIR LIVIANO-01 03-08-2007 SCH SAMPLER RESERVOIR SATURATION LIVIANO-01 03-08-2007 SCH TOOL CEMENT EVALUATION LOG LIVIANO-01 03-08-2007 SCH USIT MODULAR FORMATION LIVIANO-01 03-02-2007 SCH DYNAMICS TESTER Please Sign an Return one copy of this transmittal. Thank Yo~~, ,~~~ ~=~ -~-~C_. l~- I y • MEMORANDUM TO: Jim Regg `' P. I. Supervisor • State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 24, 2007 FROM: John Crisp, SUBJECT: Pesado - 01 PTD 207-025 Petroleum Inspector Liviano - 01 PTD 207-014 BPX Exploratory Surface Abandonments April 24, 2007: I traveled to BP's Exploratory wells Liviano - 01 &Pesado - 01 to witness surface abandonments. Liviano &Pesado were both cut off 5' below tundra level. Depth proven by measuring cut offs from ice pad tundra transition. Small void in Surface casing to very hard cement found. I requested top off of surface casing with cement. Conductor casing had solid cement to surface. Summary: I witnessed BPX Exploration wells Liviano 01 &Pesado 01 with cement to surface in all casing strings & abandoned according to regulation 20 AAC 25.120 Attachments: Photo's MPU Liviano (BPXA) Surface Abandonment Inspection Photos from John Crisp, AOGCC April 24, 2007 ~~ '~ ~ --~ ~- ~_ ~ ~ ~- .{ ..# - ; .. ~ __ „~ ,, ~' ~~~ ~. a `~ ~' .. ~~ : . • ~ ~ ~ ~ ~ ~" _k. Y .... - r `~, ` ~ . ~ ~ ,~ - - .~• , . ~ ~ '.° f~ . ~- ~,;, ~; ~,. ~.~ a. " , > ~~ .~ CJ Cement to surface in outer annulus Cement near surface inside inner casing Casing stub to tundra level 2007-0424_Surf Abandon_MPU_Liviano-1_jc.doc ! • 16-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Liviano 01 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 4,314.00' 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 / Datet,~_ Aa7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~©?-- ©1~ • STATE ®F54ba( • WELL COMPLET ON OR RE ONMPL~TfO ~~ ORT AND LOG Alaska Oil & Gas Cons. CommissionRevision: os/2a/o7, co ect KB Elevation 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^Susp rage 2oAAC2s.~os 2oAac2s.,~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class ^ Deve(o ment ®Exploratory ^ Serv' ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp, or band. 3/14/2007 12. Per to Drill Number 20 -014 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/23/2007 13. I Number 0-029-23343-00-00 4a. Location of Well (Governmental Section): Surface: ' S ' 7. Date T.D. Reached 2/28/2007 1 Well Name and Number: MPU Liviano-01 3958 F L, 602 FEL, SEC. 24, T13N R09E, UM Top of Productive Horizon: N/A g. KB (ft above MSL): 56.7' Ground (ft MSL): N/A 15. Field /Pool(s): Milne Point Unit / Ugnu Total Depth: 4173' FSL, 1425' FEL, SEC.24, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) Surface Surfa 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 538876 y- 6021555 Zone- ASP4 10. Total Depth (MD+TVD) 4314 41 9 16. Property Designation: ADL 025514 TPI: x- N/A y_ N/A Zone- ASP4 Total Depth: x- 538052 y- 6021766 Zone- ASP4 11. SSSV Depth (MD+ D) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if shore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed informa ' n per 20 AAC 25.071): Photo Gyro, MWD, GR, RES, IFR/Casandra, DEN, NEU w/ACAL, Sonic AT), MRIL, MDT, USIT, RST / PBMS / GRADIO / PCTV 22. CiA$ING, LINER AND EMENT G RECORD CASING SETTING DEPTH MD TTING PTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP <' BOTTOM TOP BOTTOM SIZE CEMENTING-RECORD PULLED 20" 92# H-40 Surface Surf 120' 32" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 35' 4' 2598' 12-1/4" 369 sx AS Lite 230 sx Class 'G' 7" 26# L-80 2720' 30 ' 87' 4161' 8-1 /2" 117 sx A Lite 266 sx Class 'G' 23. Open to production or inject ion? ^ Yes ^ 24. TuslNC RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Stze a u b r): SIZE DEPTH SET MD PACKER SET MD None None MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 3520' - 3532' Test Perforations (Abandon) 3040' Set 7" EZSV with 32 Bbls'G' cement placed 24 Bbls Below and 8 Bbls on top 2624' Set Cement Kick-off Plug with 37 Bbls Class'G' 2626' Top of Window (Liviano-01 A) 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: RODUCTION FOR EST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list form Ions and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or wat r (submit separate sheets with thi form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical r ults per 20 AAC 25 .071. None ATE Form 10-407 Revised 02/2007 ~ ~ ~ ~R ~ ~~ F~LUONTINUED ON REVERSE SIDE ~ 8. GrEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ®Yes ^ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of MA 3486' 3388' MDT Summary Attached Top of M61 3516' 3415' M62 3554' 3449' NA 3758' 3639' NB 3801' 3679' NC 3828' 3705' N E 3854' 3729' N F 3908' 3781' Top of OA 3950' 3821' Base of OA 3990' 3859' Top of OB 4033' 3900' Base of OB 4078' 3943' Formation at Total Depth (Name): 30. List of Attachments: 31. I hereby certify that the foregoing is true a correct to the best of my knowledge. ,., Signed Sondra S man Title Technical Assistant Date ~ -pl~.~ -'Q MPU Liviano-01 207-014 Prepared By Namemlumber: Sondra Stewman, 564-4750 Well Number Permit No. / A rOVal NO. Drilling Engineer: John Rose, 564-5271 INSTRUCTIONS GerreRAL: 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. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ` • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION EQEI~/EQ A ~ ~ Z 3 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG x~las:ta r3~ & Gas Gans. Carnmissi0n 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended ^ WAG 2oAAC zs.,os zoAac 2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ®Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., o Aband. 3/ 2007 12. Permit to Drill Number 207-014 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudde If~• 2/23/2007 - 13. API Number 50-029-23343-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/28/2007 14. Well Name and Number: MPU Liviano-01 ` FSL, 602 FEL, SEC. 24, T13N R09E, UM .- 3958 Top of Productive Horizon: N/A 8. KB Elevation (ft): 54.3' 15. Field /Pool(s): Milne Point Unit / Ugnu , Total Depth: 4173' FSL, 1425' FEL, SEC.24, T13N, R09E, UM ~ 9. Plug Back Depth (MD+TVD) Surface + Surface Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 538876 y- 6021555 Zone- ASP4 10. Total Depth (MD+TVD} 4314 + 4169 Ft 16. Property Designation: ADL 025514 TPI: x- N!A y- N/A Zone- ASP4 Total Depth: x- 538052 y- 6021766 Zone- ASP4 11. Depth where SSSV set N1A MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: Photo Gyro, MWD, GR, RES, IFR/Casandra, DEN, NEU w/ACAL, Sonic (BAT), MRIL, MDT, USIT, RST / PBMS / GRADIO / PCTV 22. CASING, LINER AND CEMENTING RECORD CASING SETTING' DEPTH MD SETTING DEPTH TVD .HOLE AMOUNT SIZE WT. PER FT. GRADE TOP < BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 120' Surface 120' 32" 260 sx Arctic Set A rox. 9-518" 40# L-80 35' 2624' 35' 2598' 12-1 /4" 369 sx AS Lite 230 sx Class 'G' 7" 2 -80 272 ' 4306' 2687' 41 1' 8-1/2" 117 sx AS Lite 26 sx Class' ' 23. Perforations open to Production (MD + TVD of Top and 24: TUBING, RecoRD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD None None MD TVD MD TVD 25:- AGID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3520' - 3532' Test Perforations (Abandon) 3040' Set 7" EZSV with 32 Bbls'G' cement placed 24 Bbls Below and 8 Bbls on top 2624' Set Cement Kick-off Plug with 37 Bbls Class'G' 2626' Top of Window (Liviano-01 A) 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sh ' n ). Submit core chips; if none, state "none". k None ~, APR ~ 5 2DD% Form 10-407 Revised 1212003 ~ ~ CONTINUED ON REV ~~ APR ~ ~ ~( ~.~y fG~NAL 28. f GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summari2e test results. List intervals tested, NaME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of MA 3486' 3388' MDT Summary Attached Top of MB1 3516' 3415' M62 3554' 3449' NA 3758' 3639' N8 3801' 3679' NC 3828' 3705' N E 3854' 3729' N F 3908' 3781' Top of OA 3950' 3821' Base of OA 3990' 3859' Top of OB 4033' 3900' Base of OB 4078' 3943' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, MDT Summary and Leak-Off Test Summa 31. I hereby certify that the foregoing is true nd correct to the best of my knowledge. l Signed Sondra Title Technical Assistant Date ~[ `~ ~ " MPU Liviano-01 207-014 Prepared ByName/Number.• Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: John Rose, 564-5271 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ ~ BP Page 1 of 22 ~ Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Spud Date: 2/23/2007 Event Name: DRILL+COMPLETE Start: 2/23/2007 End: 3/30/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2007 Rig Name: DOYON 14 Rig Number: i Date From - To ~i Hours Task j Code ! NPT Phase ', Description of Operations Install front booster frame and boosters -Remove rear doors - Install rear boosters -Move off Mt Elbert well 21:30 - 00:00 2.50 MOB P PRE Move off ice pad -Move rig through B-pad -Moving toward Milne Pt base camp (2 miles) '2/22/2007 00:00 - 12:00 12.00 MOB P PRE Cont. rig move from Milne Pt base camp to Liviano-01 - Remove Boosters -Install cellar doors and glycol heaters 12:00 - 13:00 1.00 MOB P PRE Position rig over well conductor 13:00 - 14:00 1.00 RIGU P PRE Skid rig floor into drilling position 14:00 - 19:00 5.00 RIGU P PRE Berm rig -Rig up floor -Spot and berm Rockwasher unit - Prepare mud pits to take on spud mud (accept rig CQ2 1900 hrs) 19:00 - 20:00 1.00 RIGU P PRE Spot -rig up Mud loggers unit - Geo unit -Mud engineers shack -Cont. RU prepare rig for spud 20:00 - 00:00 4.00 RIGU P PRE NU Diverter -Riser - Flowline - 4" dump valves -Take on spud 1 mud 2/23/2007 00:00 - 10:30 10.50 RIGU P PRE Strap 5" Corion Drill Pipe - PU from pipe shed -HWDP - JARs -Stand back in derrick 99 stds 10:30 - 11:00 0.50 RIGU P PRE Conduct Diverter Test -Test flow, Pit level, Gas detection, H2s system alarms- Witness AOCGG Inspector Jeff Jones 11:00 - 11:30 0.50 RIGU P PRE Mobilize BHA to rig floor 11:30 - 14:00 2.50 RIGU P PRE MU 12 1/4" BHA (Bit, motor, float, stab, xo) 14:00 - 14:30 0.50 RIGU P PRE Pre-Spud meeting (PJSM) 14:30 - 17:00 2.50 RIGU P PRE Thaw out conveyor #1 -Thaw out #2 charge pump -Fill conductor tattle-tale on divertor leaking (Knife valve) 17:00 - 19:30 2.50 RIGU N SFAL PRE PJSM -Remove knife valve - Gell up - Re-install -Fill conductor - No leaks 19:30 - 22:00 2.50 DRILL P SURF Spud 12 1/4" surface hole -Directional Drill f/ 113' to 314' 22:00 - 22:30 0.50 DRILL P SURF POH -Stand back HWT 22:30 - 23:00 0.50 DRILL P SURF Mob nukes -BHA to rig floor 23:00 - 00:00 1.00 DRILL P SURF MU Bit -Motor - MWD tools 2/24/2007 00:00 - 01:30 1.50 DRILL P SURF MU 8HA -Orient 01:30 - 02:30 1.00 DRILL P SURF Upload MWD -Surface test MWD -GPM 419 - PP 960 -Load Nukes 02:30 - 03:30 1.00 DRILL P SURF Con't MU BHA -Flex DC's -HWDP 03:30 - 09:30 6.00 DRILL P SURF Directional Drill from 314' to 965' (POW 105k -SOW 105k - ROW 105k - PP on 1580 -off 1460 -GPM 450 - TO on 2.5k / Off 1k-W0B10 to 15) 09:30 - 11:00 1.50 DRILL N SFAL SURF Problem mud logging system, able to monitor gas but unable record data -Pull up hole to 780' -Circulate while waiting on orders - (GPM 42 - PP 150) Decision was made to record gas manually Cam? 50 intervals 11:00 - 00:00 13.00 DRILL P SURF RIH -Directional drill f/ 965' to 2186' (POW 120k -SOW 115k - ROW 115k -GPM 450 - PP on 1800 psi /off 1520 psi -RPM 100 - TO on 3k /off 1 k - W OB 15 to 35k) Mud logging gas recorder repaired C~ 1360' 2/25/2007 00:00 - 04:00 4.00 DRILL P SURF Directional drill 12 1/4" hole f/ 2186' to 2630' (Surface TD) - W0620to30k-RPM100-TOon3-off1-GPM450-PPon 1670 -off 1540 -POW 124 -SOW 124 - ROTW 126 04:00 - 05:30 1.50 CASE P SURF Circulate and condition for pump out short trip / GPM 460 - PP 1440 05:30 - 07:30 2.00 CASE P SURF Monitor well -Pump out of to HWDP 07:30 - 08:00 0.50 CASE P SURF RIH to 2630' 08:00 - 09:30 1.50 CASE P SURF CBU 2 X -GPM 453 - PP 1450 -RPM 100 - TO 1 K 2/21/2007 02:30 - 21:30 19.00 MOB P PRE PJSM -Skid rig floor from drlg position to move position - Printed: 4/2!2007 11:19:02 AM ti ~ i BP Page 2 of 22 Operations Summary Report Legal Well Name: L iviano-0 1 Common W ell Name: L iviano-0 1 Spud Date: 2/23/2007 Event Nam e: DRILL+C OMPLE TE Start : 2/23/2007 End: 3/30/2007 Contractor Name: DOYON DRILLIN G INC . Rig Release: 3/30/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task ~ Code NPT Phase Description of Operations 2/25/2007 09:30 - 11:00 1.50 CASE P SURF Pump out to HWDP -Pump @ drilling rate 11:00 - 12:00 1.00 CASE P SURF Stand back HWDP -Jars 12:00 - 15:00 3.00 CASE P SURF PJSM - LD Flex DC's -Remove nukes sources - LD Sonic - Down load MWD 15:00 - 17:00 2.00 CASE P SURF LD TM -Remove probe - LD MWD - DM - RLL - Stablizer - Break bit - LD Motor 17:00 - 17:30 0.50 CASE P SURF Clear rig floor of vendor tools 17:30 - 19:30 2.00 CASE P SURF RU 9 5/8" casing equipment 19:30 - 23:30 4.00 CASE P SURF PJSM - PU float equipment -Check floats -Run 9 5/8" L-80 40# BTC casing to 2542' -Break circulation -Precauctionary wash last joint to 2584' -Make up landing joint -Hanger -Break circ -Precauctionary wash landing joint down to 2625' - Landing on hanger -POW 140 -SOW 130 23:30 - 00:00 0.50 CASE P SURF Circulate one casing volume 1900 strokes -GPM 252 - PP 350 2/26/2007 00:00 - 00:30 0.50 CASE P ~ SURF PJSM -Circulate one casing volume 00:30 - 01:00 0.50 CASE P SURF LD Franks tool - RU Dowell cementing head /lines - 01:00 - 02:00 1.00 CASE P SURF Circulate one casing volume -GPM 252 - PP 350 - (PJSM on cementing while circulating) Give to Dowell 02:00 - 04:30 2.50 CEMT P ' SURF Give to Dowell Pump 10 bbls fresh water Test lines to 4000 psi Pump 50 bbls 10.2 ppg Mud Push with one gallon red dye in last 5 bbls Kick out bottom plug with last 5 bbls Mud Push Mix and pump 295.5 bbls of ArticSet Lite mixed @ 10.7 ppg ~, 369 sxs 4.49 cf/sx Mix and pump 47.5 bbls of ArticSet mixed @ 15.8 ppg 228 sxs 1.16 cf/sx Kick out plug with 10 bbls fresh water Give to rig for 182 bbls mud displacement i Bump plug with 1630 psi 1000 over displacement psi Hold for 5 mins -Bleed off pressure -Floats held CIP 04:30 hrs 161 bbls good 10.7 ppg cement observed @ surface 04:30 - 06:30 2.00 CASE P SURF LD cement head -Flush and drain conductor with treated water, taking returns to Rock washer- LD landing joint -Flush flowline line with treated water 06:30 - 07:00 0.50 CASE P SURF Remove casing elavators -change out bails -Clear rig floor 07:00 - 09:00 2.00 CASE P SURF Pull riser - ND annular preventer, knife valve and spool - ', Remove from cellar 09:00 - 10:30 1.50 CASE P SURF MU FMC well head prep and install csg /tubing spool -Test FMC head (seal between hanger and spool) to 1000 psi for 10 minutes (good test) 10:30 - 13:30 3.00 CASE P SURF NU DSA - BOP's - (Install double valve on Annulus) -Choke line -Riser - Flowline 13:30 - 15:00 1.50 CASE P SURF PJSM -Install test plug - RU test equipment 15:00 - 19:00 4.00 CASE P SURF Test ROPE -Annular 250 psi low, 2500 psi high f/ 5 min. each test -Top VBR's 4 1/2" x 7" -Choke manifold -Choke /Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves - Lower VBR's 3 1/2" x 6" tested to 250 psi low, 3500 psi high for 5 minutes each test -Perform Accumulator test - Test Blind rams to 250 psi low, 3500 high f/ 5 min. each test, Printed: 4/2/2007 11:19:02 AM ' ~ ~ BP Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~~ From - To Hours Task ~ Code' NPT 2/26/2007 ~ 15:00 - 19:00 - -~ 4.00 ~ CASE P 19:00 - 20:30 1.50 CASE P 20:30 - 21:00 0.50 CASE P 21:00 - 00:00 3.00 CASE P 2/27/2007 00:00 - 01:00 1.00 CASE P 01:00 - 03:00 I 2.001 CASE I P 03:00 - 04:30 I 1.501 CASE I P 04:30 - 06:00 1.50 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 08:00 0.50 CASE 08:00 - 09:30 1.50 CASE N 09:30 - 11:00 I 1.501 CASE I P 11:00 - 12:00 I 1.001 CASE I P Page 3 of 22 ~ Spud Date: 2/23/2007 Start: 2/23/2007 End: 3/30/2007 Rig Release: 3/30/2007 Rig Number: Phase ~~ Description of Operations SURF all tests recorded on chart -Tested gas detectors and PVT's, - John Crisp with AOGCC witnessed test -All tests witnessed by WSL SURF Close Annulus valves -Align stack - Pull test plug -Install wear ring - RD test equipment -Clear rig floor SURF Mobilize nuke sources - BHA to rig floor SURF MU 8 1/2" BHA -Orient -Upload MWD SURF Attempt to upload MWD, tool too cold to function properly - Pump through MW D to warm up tool SURF Re-attempt to upload MWD, tools not functioning properly - Heat up with steam SURF Upload MWD -Surface test MWD -GPM 380 - PP 620 psi - MU MIRL tool -Load nukes SURF RIH w/ BHA - HWDP - PU 18 joints 1x1 5" Drill pipe -Cont. RIH w/ 5" Corian drill pipe SURF Slip and cut drilling line -Service top drive SURF RIH w/ 5" Corian drill pipe f/ 1350' to 2440' CEMT SURF CBU - GPM 170 - PP 480 -Wash down f/ 2440' to 2535' (5' above float collar) -UCA test sample @ 500 psi compressive strength -Cont. Circulate -GPM 310 - PP 620 (wait on cement to firm up) SURF Rig up test equipment -Test 9 5/8" casing to 2500 psi f/ 30 minutes (Good) Record on chart SURF Drill float collar Q 2540' -Drill 38' soft cement f/ 2541' to 2568' - GPM 350 - PP 800 psi - WOB 3k - ROP 350 fUhr (slacked off 3' without pumps, cement would not take wt.) 12:00 - 14:00 2.00 CASE N CEMT SURF POH 2 stands to 2440' -Circulate -Wait on cement 14:00 - 16:00 2.00 CASE N FLUD SURF Circulate -Wait on new bland 9.0 ppg LSND mud to arrive from 16:00 - 17:00 I 1.001 DRILL I P 17:00 - 19:00 I 2.001 CASE I P 19:00 - 20:30 I 1.501 CASE I P 20:30 - 00:00 I 3.501 DRILL I P 12/28/2007 ~ 00:00 - 12:00 ~ 12.00 DRILL ~ P 12:00 - 23:30 11.501 DRILL P 23:30 - 00:00 0.50 DRILL P 3/1/2007 00:00 - 01:00 1.00 DRILL P MI mud plant SURF UCA update, sample compressive strength 800 psi -RIH tag cement @ 2570' -Drill out cement - WOB 10k - ROP 150 ft/hr - Drill float shoe @ 2630' -Drill 8 1/2" hole to 2650' -GPM 338 - PP 950 psi -ROT 40 - TO 2k -POW 120k -SOW 120k -ROT 120k SURF Circulate hole clean - PJSM -Displace well with new 9.0 ppg LSND mud from MI mud plant -GPM 400 - PP 975 psi -RPM 50 SURF RU test equipment -Perform LOT @ 2604 TVD /Mud wt. 9.0 ppg / 590 psi /LOT = 13.3 ppg EMW INT1 Directional Drill f/ 2650' to 2870' - PUW 125k -SOW 119k - ROT121k-GPM400-PPon 970 psi/off 840 psi-W0B5k- TO on 2k /off 1 k INTi Directional Drill 8 1/2" hole f/ 2870' to 3690' -POW 140k - SOW 125k -ROT 135k -GPM 402 - PP on 1130 psi /off 930 psi -RPM 90 - TO on 6k /off 4k (control ROP @ 100 - 120 fUhr due to Logging restraints) INT1 Directional Drill 8 1/2" hole f/ 3690' to 4314' / TD -POW 153k - SOW 135k -ROT 145k -GPM 400 - PP on 1300 psi /off 1029 psi -RPM 90 - TO on 6k /off 5k (slowed ROP to 70 fUhr due to 5' isotube samples) INTi Circulate well f/ short trip -GPM 407 - PP 1060 psi - R&R 90 RPM INT1 Cont. circulate and condition f/ MIRL Mad Pass and pump out Printed: 4/2/2007 11:19:02 AM r ~ ~} BP Operations Summary Report Page 4 of 22 ~ Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Spud Date: 2/23/2007 Event Name: DRILL+COMPLETE Start: 2/23/2007 End: 3/30/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To ~ Hours L Task Code ~ NPT Phase Description of Operations - - 3/1/2007 _ 00:00 - 01:00 1.00 DRILL _ P INT1 _ _- short trip (CBU x 3) GPM 407 - PP 1060 psi -PJSM -Monitor well f/ flow / 10 min. (static) 01:00 - 14:30 13.50 DRILL P INT1 POH -MIRL Mad Pass f/ 4314' to 3150' -GPM 400 - PP 1025 psi -POW 150k -SOW 135k 14:30 - 15:00 0.50 DRILL P INT1 Cont. pump out short trip to 9 5/8" casing shoe @ 2625' 15:00 - 16:00 1.00 DRILL P INTi Flow check well f/ 10 min. (static) -RIH f/ 9 5/8" casing shoe to 4230' -Break circ -Precautionary wash last stand to bttm f/ 4230' - 4314' -GPM 400 - PP 1040 psi (hole in good shape) 16:00 - 17:30 1.50 DRILL P INT1 Circulate and condition mud (CBU x 3) -GPM 400 - PP 1040 - R&R @ 90 RPM 17:30 - 19:30 2.00 DRILL P INT1 POH w/ pumps @ drill rate f/ 4314' to 9 5!8" shoe @ 2625' - GPM 400 - PP 990 psi (Good hole) 19:30 - 20:30 1.00 DRILL P INTi Flow check well f/ 10 min. (static) -CBU -GPM 400 - PP 980 psi 20:30 - 21:00 0.50 DRILL P INT1 Pump dry job - POH to HWDP @ 778' 21:00 - 22:00 1.00 DRILL INT1 Stand back HWDP -Std back collars 22:00 - 23:00 1.00 DRILL P INTi Down load MIRL -Remove Nuke sources - LD MIRL 23:00 - 00:00 1.00 DRILL P INTi Down load MWD 3/2/2007 13/3/2007 00:00 - 01:30 1.50 EVAL P 01:30 - 02:30 1.00 EVAL P 02:30 - 03:00 I 0.501 EVAL I P 03:00 - 06:00 ~ 3.001 EVAL P 06:00 - 10:00 I 4.001 EVAL 10:00 - 12:00 2.00 EVAL P 12:00 - 13:00 1.00 EVAL P 13:00 - 15:00 I 2.001 EVAL I P 15:00 - 17:00 I 2.001 EVAL I P INT1 Cont. down load MWD - LD Nukes INT1 LD TM -Remove probe - LD MWD - DM - GR/RES - Stablizer - Break bit - LD Motor INTi PJSM w/ SLB crew and rig crew -Discussed job procedures / Mobilizing tools /Lifting operations /Bringing up tools f/ beaver slide /PPE INT1 Mobilize MDT string tools to rig floor - MU drill pipe conveyed MDT tools INT1 RIH w/ DP from 150' to 3220' -filled pipe every 10 stds to 3220' INT1 INTi INT1 INT1 17:00 - 19:00 2.00 EVAL P INT1 19:00 - 21:00 2.00 EVAL P INT1 21:00 - 22:30 1.50 EVAL P INTi 22:30 - 23:30 1.00 EVAL N DFAL INTi 23:30 - 00:00 0.50 EVAL N DFAL INT1 00:00 - 01:30 1.50 EVAL N DFAL INT1 01:30 - 02:00 0.50 EVAL N DFAL INTi 02:00 - 03:00 1.00 EVAL N DFAL INT1 03:00 - 04:00 1.00 EVAL N DFAL INT1 04:00 - 06:30 2.50 EVAL N DFAL INT1 PJSM w/ SWS - RU hang wireline sheaves in derrick RU -side entry sub &wireline -RIH w/ latch head -Break circ - Pump down DWCH -GPM 250 - PP 150 psi -Pull test latch - Secure W. L. to SES -Blow down top drive Attempt to test SWS fluid sample valve (valve stuck,would not function) Tool able to take pressure reading only - No fluid sample data MDT pressure stations - 3521' - 3527' - 3531' - 3547' MDT pressure stations - 3581' - 3595' - 3598' - 3607' - 3784' - 3816' MDT pressure stations - 3837' - 3847' - 3957' - 3965' - 3982' MDT pressure stations - 3982.5' - 3992' - 4045' - 4049' MDT pressure stations - 4056' - 4057' - 4065' - 4153' POH to side entry guide @ 3220' -Release f/ wireline guide - POH w/ line - RD side entry sub POH f/ 3220' to 9 5/8" casing shoe @ 2625' Unlatch SWS head - POH to side entry guide - RD side entry sub -Clear rig floor POH f/ 3220' to 9 5/8" casing shoe @ 2625' CBU x 1 GPM 275 - 200 psi -PJSM -Monitor well for flow - 15 mins. (well static) Pump dry job POH to SWS MDT tools LD failed MDT tools -Clear rig floor -Mobilize new MDT Printed: 4/2/2007 11:19:02 AM >t ~ ~ BP Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To I Hours I Task I Code NPT 3/3/2007 04:00 - 06:30 2.50 EVAL 06:30 - 10:30 4.00 EVAL Start: 2/23/2007 Rig Release: 3/30/2007 Rig Number: Page 5 of 22 ~ Spud Date: 2/23/2007 End: 3/30/2007 Phase i Description of Operations N DFAL INT1 N DFAL INT1 10:30 - 11:00 I 0.501 EVAL I N I DFAL I INT1 11:00 - 11:30 0.50 EVAL N DFAL INT1 11:30 - 13:00 1.50 EVAL N DFAL INT1 13:00 - 15:00 2.00 EVAL P INT1 15:00 - 17:30 2.50 EVAL P INT1 17:30 - 21:30 4.00 EVAL P INT1 21:30 - 00:00 2.50 EVAL P INT1 3/4/2007 00:00 - 00:30 0.50 EVAL P INT1 00:30 - 05:00 4.50 EVAL P INT1 05:00 - 07:00 2.00 EVAL P INT1 07:00 - 09:00 2.00 EVAL P INT1 09:00 - 11:00 2.00 EVAL P INT1 11:00 - 13:00 2.00 EVAL P INTi 13:00 - 13:30 0.50 EVAL P INT1 13:30 - 15:00 1.50 EVAL P INTi 15:00 - 15:30 I 0.501 EVAL I P I I INT1 15:30 - 17:30 2.00 EVAL P INT1 17:30 - 19:00 1.50 EVAL P INT1 19:00 - 20:30 1.50 EVAL P INT1 20:30 - 23:30 3.00 EVAL P INT1 23:30 - 00:00 0.50 EVAL P INTi 3/5/2007 00:00 - 02:00 2.00 EVAL P INT1 02:00 - 04:30 2.50 EVAL P INT1 04:30 - 06:00 1.50 EVAL P INT1 06:00 - 10:30 I 4.501 EVAL I N I DFAL I INTi 10:30 - 12:30 I 2.00 ~ EVAL I P I I INTi 12:30 - 13:30 1.00 EVAL P INT1 13:30 - 14:30 1.00 EVAL P INT1 14:30 - 17:00 2.50 EVAL P INT1 17:00 - 17:30 0.50 CASE P INT1 17:30 - 20:00 2.50 CASE P INT1 sample tool to rig floor - MU SWS MDT tool -Test (Good) RIH w/ SWS MDT on 5" drill pipe f/132' to 2594' -Pump calculated pipe volume every 10 stds Circulate surface to surface volume -GPM 350 - PP 220 psi - Blow down top drive RIH f/ 2594' to 3244' PJSM - RU side entry sub / wireline -RIH w/ latch head -Pump down DWCH w/ 350 GPM - PP 170 psi -Observed 50 psi increase w/ latched -Pull test tools -Secure W L to SES -Run open hole MDTs -POW 120k -SOW 115k Move MDT -Set Pkr -Take OA sample C~3 3974' Move MDT -Set Pkr -Take OA sample Q 3967' Move MDT -Set Pkr -Take OA sample @ 3987' Move MDT -Set Pkr -Take NB sample @ 3819' Cont. MDT -Set Pkr -Take OA sample C~ 3960' Move MDT -Set Pkr -Take OA sample @ 3980' Move MDT -Set Pkr -Take NB sample @ 3811' Move MDT -Set Pkr -Take NC sample @ 3832' Move MDT -Set Pkr -Take OBC sample C~ 4150' Move MDT -Set Pkr -Take OB sample @ 4040' POH w/ SWS MDT tool to side entry sub Release WL from guide -Unlatch DWCH - POH w/ line - RD wire line sheaves SWS equipment POH f/ 3244' to 9 5/8" csg shoe @ 2625' -POW 115k -SOW 115k (no problems) Encountered swivel packing leak -Change out same Circulate hole clean @ 9 5/8" shoe -Monitor well f/ 15 mins (well static) POH f/ 2625' to SWS MDT tools LD SWS MDT tools -Clear rig floor of vendor tools MU BHA -BIT -Float sub -MWD - Cont. MU BHA -MWD - DM - TM -MIRL- Upload mwd - MU Drill collars, 6 stds SHWDP, Jars -Function test MWD tools - GPM350-PP900 psi RIH f/ 718' to TD C~ 4314' (wash last std to bttm) Circulate hole clean (CBU x 4) GPM 400 - PP 940 psi - R&R 80 RPM -POW 150k -SOW 140 -ROW - 145K MAD PASS MRIL f/4180' - 3570' and f/3570' - 3510'. (NOTE: As the T1 data was not recorded as planned when drilling this interval of the well, this MAD pass of the MRIL tool was required to obtain the data. Pump out hole -MIRL mad pass f/ 4180' to 3670' - 3570' to 3510' -Cont. pump out of hole to 9 5/8" csg shoe -GPM 400 - PP 920 psi Circulate hole clean -GPM 400 - PP 840 psi Pump dry job - POH f/ 2620' to 718' Stand back HWDP and Drill collars -Down load MIRL /MWD - LD MIRL - TM - DM - GR/RES -BIT sub -Bit -Clear rig floor vendor tools Pull wear ring Mobilize casing equipment to rig floor - RU 7" casing equipment -PJSM Printed: 4/2/2007 11:19:02 AM ' ~' BP Page 6 of 22 ~ Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date i From - To Hours JJ Task Code NPT 3/5/200720:00 - 00:00 ~ 4.00 I CASE P 3/6/2007 00:00 - 00:30 ~ 0.501 CASE ~ P 00:30 - 02:00 I 1.501 CASE I P Spud Date: 2/23/2007 Start: 2/23/2007 End: 3/30/2007 Rig Release: 3/30/2007 Rig Number: Phase Description of Operations iNT1 PU float equipment -Check tloats -Run 7" 26# L-80 BTC-M casing to 2600' INT1 PJSM -Circulate one casing volume @ shoe -GPM 204 - PP 280 psi -POW 105 -SOW 105k INT1 Run 7" casing in open hole f/ 2600' to 4016' (after circulating the shoe, the bleeder on the manifold was left open. A total of 30 joints were run in the hole with the casing not being filled. the problem was recognized, and the bleeder was closed. When the pumps were turned on the top drive hose was froze up) 02:00 - 02:30 0.50 CASE N SFAL INT1 RU cement line -Filled the casing with 47 bbls mud 02:30 - 03:30 1.00 CASE INT1 Cont. run 7" 26# L-80 BTC-M to 4237' - MU landing joint - RIH w/ hanger -Land 7" casing C~ 4306' 03:30 - 04:30 1.00 CASE P INT1 RD casing equipment - RD franks tool - MU cement head, line 04:30 - 07:00 I 2.501 CEMT I P 07:00 - 08:30 I 1.501 CEMT I P 08:30 - 09:00 I 0.501 CEMT I P 09:00 - 10:30 1.501 CEMT P 10:30 - 11:00 I 0.501 CEMT I P 11:00 - 12:00 1.00 CEMT P 12:00 - 13:30 1.50 CEMT P 13:30 - 14:30 1.00 CEMT ~ N SFAL INT1 14:30 - 16:00 1.50 BOPSU P INT1 16:00 - 17:30 1.50 BOPSUf~ P INT1 17:30 - 19:30 2.00 MOB P INT1 19:30 - 20:00 0.50 BOPSU~ P INT1 20:00 - 21:00 1.00 BOPSU P INT1 21:00 - 00:00 I 3.001 BOPSUp P I I INT1 Break circulation, bring pump up slowly -Circulate and reciprocate casing -POW 155k -SOW 135k -GPM 205 - PP 290 psi PJSM -Cement per plan (Pump 5 bbls water, Test lines to 4000 psi, Pump 25 bbls 11 ppg mud push, Kick out bypass plug, Reload head w/shut off plug, Pump 47 bbls 12.5# Crete design lead, Pump 55 bbls 15.8 Class G cement, Kick out shut off plug, Wash out cement line to rig floor) Reciprocate pipe through out job Displace with rig (Pump 40 bbls 9.2 brine, Pump 30 bbls retardant fresh water pill, Pump 76 bbls fresh water to bump plug) 168 gpm ~ 810 psi, Cement in place @ 0915 hrs (Reciprocate pipe through out job) Open ES cementer with 3450 psi -Pump 30 bbl hi-vis sweep and pump 310 bbls fresh water until returns come back clean - (+/- 10 bbls cement back) Pump 70 bbls 9.2 brine, 30 bbls 9.2 retardant pill, Kick out ES closing plug, Chase with 98 bbls 9.2 brine, Shut ES cementer with 1600 psi, Check for flow - no flow RD cement lines - LD cement head - LD landing joint Clear rig floor of cementing /casing tools -Realign Riser and adjust flowline Break off TD hose -Attempt to run steam through hose to clear (no success) Install packoff - RILDS -FMC tested to 5000 psi f/ 10 mins. (Good) Change top rams to 2 7/8" x 5" VBRs Change out saver sub -Jaws - Change out Bell guide on top drive -Change out dies on iron roughneck Install test plug - MU 4" test joint RU test equipment -PJSM (discussed job hazards and job procedures) Test BOPE -Annular 250 psi low, 2500 psi high f/ 5 min. each test -Top VBR's 2 7/8" x 5" -Choke manifold -Choke /Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's 3 1/2" x 6" tested to 250 psi low, 3500 psi high for 5 minutes each test -Perform Accumulator test - Test Blind rams to 250 psi low, 3500 high f/ 5 min. each test, INTi INT1 INT1 INT1 INT1 INT1 INT1 Printed: 4/2/2007 11:19:02 AM BP Page 7 of 22 ~ Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Spud Date: 2/23/2007 Event Name: DRILL+COMPLETE Start: 2/23/2007 End: 3/30/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task !Code NPT Phase ' Description of Operations - ~~ _ _ ~ _ - 1-- i 3/6/2007 21:00 - 00:00 3.00 BOPSU P INT1 all tests record on chart -Bob Nobel with AOGCC waived witness of test -All tests witnessed by WSL 3/7/2007 00:00 - 01:00 1.00 BOPSU P INT1 Cont. Test BOPS -Test Blind rams to 250 psi low, 3500 high f/ 01:00 - 02:00 1.00 CASE P INTi 02:00 - 11:00 9.00 CASE N SFAL INTi 11:00 - 13:00 2.00 CASE P INT1 13:00 - 14:00 1.00 CASE P INT1 14:00 - 17:00 3.00 CASE P 1NT1 17:00 - 17:30 0.50 CASE P INT1 17:30 - 18:30 1.00 CASE P INT1 18:30 -19:30 1.00 CASE P INTi 19:30 - 21:00 1.50 CASE P INT1 21:00 - 23:00 2.00 CASE P INT1 23:00 - 23:30 0.50 CASE P INTi 23:30 - 00:00 0.50 CASE P INT1 3/8/2007 00:00 - 01:00 1.00 CASE P INT1 01:00 - 02:30 1.50 CASE P INT1 02:30 - 03:30 1.00 CASE P INT1 03:30 - 04:30 1.00 CASE P INT1 04:30 - 10:30 6.00 CASE P INT1 10:30 - 14:00 3.50 CASE P INT1 14:00 - 15:00 1.00 CASE P INT1 15:00 - 17:30 2.50 CASE P INT1 17:30 - 19:30 2.00 CASE P INT1 19:30 - 20:00 0.50 CASE P INTi 20:00 - 22:00 2.00 CASE P INTi 22:00 - 22:30 0.50 CASE P INT1 22:30 - 23:30 1.00 CASE P INT1 23:30 - 00:00 0.50 CASE P INT1 3/9/2007 00:00 - 02:30 2.50 EVAL INT1 02:30 - 03:00 0.50 EVAL INT1 03:00 - 05:00 2.00 EVAL INT1 5 min. each test, all tests record on chart -Bob Nobel with AOGCC waived witness of test -All tests witnessed by WSL RD test equipment - LD 4" test joint -Clear rig floor -Install wear ring - RILDS PJSM -Disconnect Top drive hose -Steam and thaw out same - PJSM -Connect top drive hose -Pressure test to 3500 psi Install Bails -Elevators -Mobilize BHA to rig floor -Load pipe shed w/ 4" drill pipe MU 6 1/8" clean out assy -RIH to 375' RIH w/ 4" drill pipe 1x1 from pipe shed f/ 375' to 2745' Lubricate and service drawworks, grease blocks Circulate surface to surface strokes -GPM 350 - PP 700 psi RU test equipment -Test 7" 26# L-80 BTC-M casing to 2000 psi f/ 10 min. -Record on chart (Good) Drill out ES Cementer f/ 2770' to 2772' -POW 97k -SOW 95k -ROT96k-GPM275-PP700-RPM 70-W0B6-10k PU 4" drill pipe 1x1 from pipe shed - RIH f/ 2772' to 3600' - Precautionary washed last 40' to bottom -Tagged Baffle adapter C~ 3649' - POW 107k -SOW 100k -ROT 105k -RPM 30 Circulate surface to surface strokes -GPM 350 - PP 1290 psi RU test equipment Test 7" 26# L-80 BTC-M casing to 3000 psi f/ 30 mins - (Good) - Record on chart -PJSM Slip and Cut Drilling line -Service top drive Flow check well f/ 10 mins. (static) - POH f/ 3600' to 374' Stand back Collars - LD BHA -Clear rig floor PJSM - RU SWS wireline sheaves and tools -RIH w/ wireline Junk basket / 6 1/8" Guage ring - POH w/ wireline run #1 RIH w/wireline USIT bond tools to 3649' -USIT bond logs f/ 3649' to 2770' top of cement PJSM - RD SWS sheaves and tools -Clear rig floor of vendor tools Pull wear ring -Mobilize SLB pert tools to rig floor -Mobilize Doyon tubing equipment to rig floor PJSM -RIH w/ Perf Gun assy. and DST tools to PVT @ 138' Pressure test PG /DST assy. to 4000 psi f/ 5 minutes (Good) - Record on chart Cont. RIH w! 3 1/2" 9.2# TCII, SLB DST, Perf Guns to 642' RU test equipment -Pressure test PG /DST assy. to 4000 psi f/ 5 mins. (Good) -Record on chart Cont. RIH w/ DST and Perf gun assy. f/ 642' to 670' MU 3 1/2" TCII tubing using Torque turn equip. - RiH w! 3 1/2" TCII tubing /SLB DST /Perf guns to 859' Cont. RIH w/ 3 1/2" TCII tubing /DST tools /Perf guns to 1617' RU test Equipment -Test DST / PG completion / 3 1/2" tubing to 4000 psi f/ 5 mins. (Good) -Record on chart Cont. RIH w/ 3 1/2" TCII tubing /DST tools /Perf guns to 2565' Printed: 4/2/2007 11:19:02 AM ;~ BP Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ' Hours Task ~ Code NPT 3/9/2007 ~ 05:00 - 05:30 ~ 0.50 ~ EVAL 05:30 - 08:30 I 3.001 EVAL 08:30 - 09:00 I 0.50 (EVAL 09:00 - 10:00 I 1.001 EVAL 10:00 - 14:00 I 4.001 EVAL Start: 2/23/2007 Rig Release: 3/30/2007 Rig Number: Phase INT1 INT1 INT1 INTi INT1 14:00 - 20:00 6.00 EVAL N DPRB INT1 20:00 - 21:00 I 1.001 EVAL I I I INT1 21:00 - 21:30 I 0.501 EVAL I I I INT1 21:30 - 23:30 I 2.001 EVAL I I I INT1 23:30 - 00:00 0.50 EVAL INT1 3/10/2007 00:00 - 03:30 3.50 EVAL P INT1 03:30 - 04:30 1.00 EVAL P INT1 04:30 - 06:00 1.50 EVAL P INT1 06:00 - 07:30 I 1.501 EVAL I P I J INT1 07:30 - 12:00 4.50 EVAL P INT1 12:00 - 14:00 2.00 EVAL P INT1 14:00 - 15:00 1.00 EVAL P INT1 15:00 - 17:30 2.50 EVAL N DPRB INT1 17:30 - 21:30 I 4.001 EVAL I N I DPRB I INT1 Page 8 of 22 ~ Spud Date: 2/23/2007 End: 3/30/2007 Description of Operations RU Test Equipment -Test DST / PG completion / 3 1/2" tubing to 4000 psi f/ 5 mins. (Good) -Record on chart Cont. RIH w/ 3 1/2" 9.2# TCII tubing /DST tools /Perf guns f/ 2565' to 3550' (91 jts total + 10' pup) RU test equipment -Test DST / PG completion / 3 1/2" TCII tubing to 4000 psi f/ 5 mins. (Good) -Record on chart PJSM -Close Annular -Pressure up on annulus to 900 psi - Sheardiscs on PTV and TFTV -Obtain parameters -Set packer @ 3428' Depth -Valve on PCTH will open and close- (will not stay in "Hold open position" ) PJSM -Mob. SW S wireline equip -Hang sheave - PU wireline tools -RIH w/ SWS wireline GR/CCL tools to correlate string depth w/ logs Attempt to get PCTV in "hold open position" cycled pressure on annulus up to 1600 psi repeatedly (No good). NOTE: 4 hrs. NPT due to multipile attempts to cycle PCTV Space out -spot guns on depth - LD 10' pup jt - LD 2 jts 3 1/2" tubing - MU w/ TTurn / 1 pup jt. C~3 19.77" - MU Hanger and landing joint -Drained stack -Land hanger / PU on tubing string 5 1/2' PUW 90k -SOW 87k Obtain parameters -Set Packer @ 3410' slacked off on slip joint (confirm Pkr taking wt) -Land Hanger -DST/ Perf gun assy. @ 3520'-3532' - RILDS PJSM -RIH w/ wireline GR/CCL tools -Correlate 3 1/2" tubing RA tag ~ 3313' -Correlate 7" casing RA tags ~ 3221' and 3272' -Confirmed setting depth - POH w/ wireline LD landing joint -Install TWC PJSM -Blow down Choke and Kill -Bleed off lines - RD Flowline -Riser - ND BOP stack - NU tree -Test adapter flange to 5000 psi f/ 10 mins. (good) PJSM - RU test equipment Pressure test tree to 250 psi low -Test 3000 psi f/ 5 mins. each test -Record on chart -Pull TWC Rig down test equipment -Mobilize wireline equipment and lubricator to rig floor -Mobilize hard line, valves and choke to cellar. PJSM w/ all involved in upcoming operation - RU nitrogen to tree - RU lines to annulus and tree - RU choke to 110% tank - RU lubricator and wireline BOP's from tree to rig floor - RU wireline tools - RU ESD's (2) from tree to rig floor PJSM -Test all lines and equipment w/ nitrogen to 3000 psi Pressure up annulus to 500 psi w/ mud pump -Pressure up on tubing to 1300 psi. Bleed off and cycle 6 times to open MCVL (Multi-Cycle Valve Lock). Line up annulus to take returns to trip tank -Line up to pump down tubing w/ nitrogen -Displace tubing w/ nitrogen -Take 25.5 bbls returns into trip tank -Bleed tubing down f/ 1370 to 870 psi to close MCVL -Attempt to pressure up tubing 1370 psi - No success -Annulus valve was open while bleeding nitrogen off -Bled 4 bbls into trip tank causing over displacement. Bled off remaining nitrogen f/ tubing -Displace well w/ 9.2 ppg brine - 43 bbls to fill tubing - (surf to surf x 1.5) -PJSM - Printed: 4/2/2007 11:19:02 AM BP Page 9 of 22 Operations Summary Report Legal WeII Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ~ Hours Task Code i NPT - _~--- ._ 3/10/2007 117:30 - 21:30 4.00 EVAL ~ N DPRB 21:30 - 23:00 ~ 1.50 ~ EVAL ~ N ~ DPRB 23:00 - 00:00 I 1.001 EVAL I N I DPRB 3/11/2007 100:00 - 03:00 I 3.001 EVAL I P 03:00 - 04:00 I 1.001 EVAL I P 04:00 - 04:30 0.50 EVAL P 04:30 - 05:00 0.50 EVAL P 05:00 - 06:00 ~ 1.00 ~ EVAL ~ P 06:00 - 10:30 I 4.50 I EVAL I P 10:30 - 19:00 I 8.501 EVAL I P 20:00 - 22:00 I 2.001 EVAL I P 22:00 - 00:00 2.00 EVAL P 3/12/2007 00:00 - 01:30 1.50 EVAL P 01:30 - 02:00 0.50 EVAL P 02:00 - 04:00 I 2.001 EVAL I P Spud Date: 2/23/2007 Start: 2/23/2007 End: 3/30/2007 Rig Release: 3/30/2007 Rig Number: Phase ' Description of Operations INT1 Displaced tubing w/ 25 bbls nitrogen / 25.5 bbls returns to trip tank -Tubing press. 1380 psi -Shut in annulus -Bled down tubing to 850 psi -Attempt to press. up on annulus -Pump 4 bbls @ 127 GPM - PP 120 psi -Shut down pump -Bled tubing down to 700 psi -Pumped 4 bbls down annulus @ 169 GPM - PP 230 psi -Bled tubing off to zero -Attempt to pressure up on annulus side /Both annulus and tubing pressure came up - Ann. 660 psi /tubing 720 psi -Bled off both INT1 Displace well with brine - 85 GPM - PP 150 psi (14 bbls to fill tubing) INT1 Pressure up on annulus to 700 psi -Close annulus valve (bled down to 500 psi) -Cycle tubing pressure 1400 psi x 6 - MCVL (Multi Cycle Valve Lock) in circulating position. INT1 PJSM -Increased nitrogen temp to 200 degrees -Pump 15 bbls nitrogen down tubing -allow to equalize t/ 5 mins. -returns to trip tank equaled 16 bbls (1 bbl gain) -Pumped 9 bbls nitrogen down tubing -allow to equalize f/ 5 min. total pumped 24 bbls -Total returns to trip tank 25.5 bbls (1.5 gain) -Shut in annlus valve -Pressure on tubing 1400 psi -Bled of tubing to 1350 psi -Pressure up on annulus to 1640 psi -MCVL (Multi-Cycle Valve Lock) in closed position -Maintaining 1500 to 1700 psi on Annulus to hold PCTV valve in open position INT1 RIH w/ SWS wireline RST /PBMS / GRADIO tools to confirm PCTV in open position INT1 POH w/ SWS wireline tools INT1 PJSM -Close master valve on tree -Bleed off pressure on Lubricator to zero -Break off lubricator from tree -Install bar - MU lubricator -Pressure up on same to 1350 psi -Open master valve on tree -Allow bar to fall -Fire guns (No indication at surface). INT1 RIH w/ wireline while waiting for well to stabilize -Ran tools down to 3479' (10' past where automatic release should be) - Guns dropped -Fluid level dropped 70' from 3292' to 3362' INT1 Begin bleeding down tubing - 25 psi per 1/2 hr from 1325 psi to 1125 psi (pressure read on gage at choke). INT1 PJSM -RIH SWS w/ wireline -PBMS /RST / GRADIO tools to evaluate Water /Oil interface - Run #1 f/ 3484' to 3150' -Run #2 f/ 3484' to 3140' -Run #3 f/ 3575' to 3025' - POH w/ wireline -Annulus press. 1600 psi -Tubing Press. 1010 psi INT1 PJSM -Close master valve on tree -Bleed off Lubricator f/ 1010 psi to 0 -Break off lubricator from tree - C/O SWS logging tools -Install Oilphase SRS sample toot - MU lubricator - Pressure up lubricator w/ Nitrogen to 1070 psi -Open Master valve on tree -Pressure on tubing stabilized ~ 1020 psi -RIH w/ SWS ! Oilphase SRS sample tool - GRADIO and PBMS logging tools to sample retrieving depth INT1 Take Down hole SRS sample #1 @ 3043' Cont. taking down hole Oilphase SRS sample #1 POH f/ 3043' w/ SWS logging tools -PBMS - GRADIO -SRS sample tool -Annulus press. 1600 psi -Tubing press. 970 psi INT1 PJSM -Close master valve on tree -Bleed off Lubricator f/ 970 psi to 0 -Break off lubricator from tree -Recover sample f/ SRS tool - Re-install Oilphase SRS sample tool - MU lubricator Printed: 4/2/2007 11:19:02 AM gP Page 10 of 22 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date II Name: L ell Name: L e: Name: From - To i iviano-0 iviano-0 DRILL+C DOYON DOYON I Hours __- 1 1 OMPLE DRILLIN 14 Task L__ TE G INC Code i . PT I 3/12/2007 02:00 - 04:00 2.00 EVAL P 04:00 - 07:00 3.00 EVAL P 07:00 - 07:30 0.50 EVAL P 07:30 - 09:00 1.50 EVAL P 09:30 - 14:00 4.50 EVAL P 14:00 - 14:30 0.50 EVAL P 14:30 - 16:00 1.50 EVAL P 16:00 - 19:00 3.00 EVAL P 19:00 - 19:30 0.50 EVAL P 19:30 - 22:00 2.50 EVAL P 22:00 - 00:00 2.00 EVAL P 3/13/2007 00:00 - 01:00 1.00 EVAL P 01:00 - 01:30 0.50 EVAL P 01:30 - 02:00 0.50 EVAL P 02:00 - 03:00 1.00 EVAL P 03:00 - 06:00 3.00 EVAL P 06:00 - 07:15 1.25 EVAL P 07:15 - 08:00 0.75 EVAL P Spud Date: 2/23/2007 Start: 2/23/2007 End: 3/30/2007 Rig Release: 3!30/2007 Rig Number: Phase Description of Operations INTi -Pressure up lubricator w/Nitrogen to 1050 psi -Open Master valve on tree -Tubing press. stabilized @ 1010 psi -RIH w/ SWS / Oilphase SRS sample tool - GRADIO and PBMS logging tools to sample retrieving depth @ 3000' INT1 Taking down hole Oilphase SRS samples #2 and #3 @ 3000' INT1 POH f/ 3000' w/ SWS logging tools -PBMS - GRADIO -SRS sample tool -Annulus press. 1600 psi -Tubing press. 1000 psi INT1 PJSM -Close master valve on tree -Bleed off Lubricator f/ 1000 psi to 0 -Break off lubricator from tree -Recover sample f/SRS tool - Re-install Oilphase SRS sample tool - MU lubricator -Pressure up lubricator w/ Nitrogen to 1060 psi - Open Master valve on tree -Tubing press. stabilized @ 1040 psi -RIH w/ SWS / Oilphase SRS sample tool - GRADIO and PBMS logging tools to sample retrieving depth @ 2904' INTi Taking down hole Oilphase SRS samples #4 and #5 @ 2904' INTi POH f/ 2904' w/ SWS logging tools -PBMS - GRADIO -SRS sample tool -Annulus press. 1600 psi -Tubing press. 970 psi INT1 PJSM -Close master valve on tree -Bleed off Lubricator f/ 1000 psi to 0 -Break off lubricator from tree -Recover sample f/ SRS tool - Re-install Oilphase SRS sample tool - MU lubricator -Pressure up lubricator w/ Nitrogen to 1060 psi - Open Master valve on tree -Tubing press. stabilized @ 1060 psi - RIH w/ SWS / Oilphase SRS sample tool - GRADIO and PBMS logging tools to sample retrieving depth @ 2851' INT1 Taking down hole Oilphase SRS samples #6 @ 2851' INTi POH f/ 2851' w/SWS logging tools -PBMS - GRADIO -SRS sample tool -Annulus press. 1660 psi -Tubing press. 1080 psi INT1 PJSM -Close master valve on tree -Bleed off Lubricator f/ 1000 psi to 0 -Break off lubricator from tree - LD SRS sample tool - RD Nitrogen equipment - RD SWS wireline tools - Lubricator - Wireline BOPS -Clear rig floor of vendor tools INT1 PJSM -Bleed pressure off annulus to 0 -close PTV -Pressure up on annulus to 400 psi -Pressure up on tubing f/ 1010 psi to 2400 psi -Attempt to cycle MCVL to open position INT1 Cont. pressure up /bleed off on tubing to open SWS MCVL ( 3 full cycles to open) Annulus 500 psi -Tubing 1700 psi INT1 Wait on oil to migrate up hole -PJSM INT1 Reverse circulate 24 bbls taking returns up tubing -Taking returns to 110% tank (Oil came back very sporadic -thick small globs) INT1 Let oil migtrate up -Held table top drill on H2S, Fire, Spill, Man down, Rig Evuation -Discuss w/ GEOs and engineer sample catching process INT1 Reverse circulate 25 bbls taking returns up tubing -Rate 1 BPM -Catch oil samples as per on site engineer (5 quarts plus filled two sample drums w/ returns -Pump additional 30 bbls to 110% tank INTi Cycle MCVL to close position -Pressure up annulus to open PCTV -Bull head 5 bbls down tubing string to kill well - 1.3 bpm @ 940 psi -Bleed off pressure on both sides -Monitor well 5 mins -Test tubing to 1000 psi PCTV confirmed closed - Well static -Blow down all lines - RD lines INT1 Set TWC -Test to 1000 psi for 15 mins Printed: 4/2/2007 11:19:02 AM gp Page 11 of 22 Operations Summary Report t Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC .Rig Name: DOYON 14 Date ,From - To Hours ~ Task Code NPT 3/13/2007 ~ 08:00 - 11:00 ~ 3.00 ~ EVAL ~ P I~ 11:00 - 12:00 I 1.00 I EVAL I P 12:00 - 17:00 ~ 5.00 ~ EVAL ~ P 17:00 - 18:30 I 1.501 EVAL I P 18:30 - 19:30 1.00 ~ EVAL P 19:30 - 20:00 0.50 EVAL P 20:00 - 23:00 3.00 EVAL P 23:00 - 00:00 1.00 EVAL P 3/14/2007 00:00 - 04:30 4.50 PULL P 04:30 - 05:30 1.00 RIGD ~ P 05:30 - 07:00 1.50 BOPSU P 07:00 - 11:30 4.50 BOPSU P 11:30 - 13:00 1.50 BOPSU P 13:00 - 15:00 2.00 PXA P 15:00 - 15:30 0.50 PXA P 15:30 - 17:30 2.00 PXA P 17:30 - 19:30 I 2.00 I PXA I P Spud Date: 2/23/2007 Start: 2/23/2007 End: 3/30/2007 Rig Release: 3/30/2007 Rig Number: Phase Description of Operations INTi ND tree -Remove drums from cellar - NU stack -Install riser, Flowline INT1 RU test equipment to test BOP body 250 low 3500 high - 5 mins each test -Record on chart -Function test rams - RD test equipment INT1 Vac out stack - MU XO - RU lubricator -Pull TWC - RD Lubricator INT1 Pressure up Annulus to 1600 psi to open PCTV -Close Blinds - Bullhead 5 bbls 9.2 ppg brine down tubing -Observe well 10 mins -Pressure up on annulus to 2800 psi -Open SHRV - BOLDS -Pull hanger unseat packer @ 95K PUW -String weight 90K -Well static INT1 MU Head pin circulating lines -Circulate STS 1.5 X -GPM 190 - PP 370 - RD circulating lines head pin -Flow check -Well static INT1 PJSM -Pull hanger to rig floor - LD hanger - RU power tongs INT1 LD 3 1/2" TC 11 tubing 1 x 1 INT1 LD BHA - XN -Slip joints -Make service breaks ABAN LD Testing BHA -Bleed pressure from PCTV -Packer in good shape -Recovered all equipment from Auto release SHAR ABAN Clear rig floor of all Vendors equipment -Tubing equipment ABAN RU testing equipment -Install Test plug ABAN Test BOPE -Annular 250 psi low, 2500 psi high f/ 5 min. each test -Top VBR's 2 7/8" x 5" -Choke manifold -Choke /Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's 3 1/2" x 6" tested to 250 psi low, 3500 psi high for 5 minutes each test -Perform Accumulator test - Test Blind rams to 250 psi low, 3500 high f/ 5 min. each test, all tests recorded on chart -John Crisp with AOGCC waived witness of test -All tests witnessed by WSL ABAN RD Testing equipment -Close annulus valves -Pull test plug - Install wear ring -Blow down choke, Top Drive ABAN PJSM - PU 7" EZSV running tool -Install EZSV - RIH on 4" DP to 3040' - ABAN Set EZSV @ 3040' -Shear out with 45K up to 140K -Set down 20K on EZSV to 73K ABAN Establish injection rates - 1.5 bpm @ 940 psi - 3 bpm @ 1020 - 4 bpm @ 1130 - 5 bpm @ 1260 - Un-sting from retainer -Blow down TD - RU cementing lines -Circulate 5 bpm @ 380 psi ABAN PJSM -Close bag -taking returns through choke Pump 5 bbls water Test lines to 4000 psi Pump 24 bbls cemet mixed @ 15.8 ppg Class "G" yield 1.17 cufUsx 2 bbls water (Holding back pressure on well to keep cement from falling away) Close choke Sting into retainer Displace /inject with 30.7 bbls brine (Open choke bleed off pressure -Open bag while displacing) Un-sting from retainer CBU 1.5 X - BPM 7.5 @ 800 psi - No cement seen on surface Pump 10 bbls water Pump 8 bbls cement Class "G" mixed @ 15.8 ppg -Yield 1.17 Printed: 4/2/2007 11:19:02 AM gp Page 12 of 22 ~ Operations Summary Deport Legal Well Common W Event Nam Contractor Rig Name: Date I Name: L ell Name: L e: Name: From - To ~ iviano-0 iviano-0 DRILL+C DOYON DOYON Hours 1 1 OMPLE DRILLIN 14 Task TE G INC Code'. . NPT Start Rig Rig Phase Spud Date: 2/23/2007 : 2/23/2007 End: 3/30/2007 Release: 3/30/2007 Number: Description of Operations 3/14/2007 17:30 - 19:30 2.00 PXA P ABAN cufUsx - 3 bpm @ 170 Pump 3.4 bbls water Displace with 26.7 bbls brine - 5 bpm @ 270 to 500 Pull 5 stands of 4" DP to 2566' John Crisp with AOGCC witnessed setting cement plug 19:30 - 20:30 1.00 PXA P ABAN Pump 30 bbls nut plug sweep - 8 bpm @ 750 psi -Trace cement returns at bottoms up -Check flow -Well static -Blow down TD -Choke 20:30 - 21:30 1.00 PXA P ABAN POH from 2566' to surface 21:30 - 22:30 1.00 PXA P ABAN LD Howco EZSV running tool -Clear rig floor - Moblize Baker 7" Multi string cutter to rig floor 22:30 - 23:30 1.00 PXA N RREP ABAN Change out top jaw ram and hydraulic fitting on iron roughneck 23:30 - 00:00 0.50 PXA P ARAN MU Baker 7" Multi string cutter assy 3/15/2007 00:00 - 02:00 2.00 PXA P ARAN RIH to 2662' - MU Top Drive -RIH to 2700' Break circulation - Con't RIH tag collar @ 2727' - PU to 2720' 02:00 - 02:30 0.50 PXA P ARAN PJSM -Cut 7" Casing -RPM 50 - TO 1.5 -GPM 170 - PP 250 - PUW 90 -SOW 90 - PU to 2715' 02:30 - 03:30 1.00 PXA P ABAN Shut Annular -Circulate 7" X 9 5/8" annulus 2 X taking returns into the pits -GPM 190 - PP 310 -Open Annular -Check for flow -Well static 03:30 - 05:00 1.50 PXA P ABAN Blow down T.D. - POH from 2720' to BHA -Clear rig floor 05:00 - 08:00 3.00 PXA P ABAN Pull wear ring -Install test plug - RU test equipment -Change top VBR's to 7" casing rams -Test door seals to 2500 psi - RD test equipment -Pull test plug ', 08:00 - 10:00 2.00 PXA P ABAN PJSM - MU 7" casing spear -RIH spear 7" casing at wellhead - PU to ensure catch -BOLDS -Pull hanger free -Pull casing to rig floor w/ 115k up wt. 10:00 - 12:00 2.00 PXA P ABAN Release spear - LD 4" DP - RU 7" casing equipment -Mobilize protectors to floor - LD hanger -Break spear & LD same. 12:00 - 15:00 3.00 PXA P ABAN PJSM - LD 7" casing -Recovered 65 jts. + cut jt (35.28') 15:00 - 16:00 1.00 PXA P ABAN Clear rig floor - LD casing equip. - RU to change rams & test 16:00 - 18:30 2.50 PXA P ABAN Change 7" rams to 2 7/8" X 5" VBR's -Test door seals to 2500 psi - RD test equipment -Pull test plug -Install wear ring 18:30 - 21:00 2.50 WHIP P WEXIT MU 4" mule shoe -RIH with 4" DP to 2750' -Break ciculation - BPM 6 - PP 300 -Wash from 2750' to 2813' -Tag up with 8K @ 2814' - PU to 2800' -Rotate RPM 30 -BPM 8 - PP 340 - Con't wash to 2847' tag firm cement -Taking 4K with RPM 30 - CBU -BPM 4.5 - PP 200 -RPM 30 -Cement /sand back to surface -Shut down - MU cementing equipment -Blow down T.D. -PJSM 21:00 - 21:30 0.50 REMCM P WEXIT Give to Dowell Pump 15 bbls water Test lines to 2500 Pump 7.4 bbls water Pump 37 bbls cement -Class "G" mixed @ 17 ppg -Yield 1.01 Pump 4 bbls water Displace with 20.8 bbls 9.4 brine CIP @ 21:20 Hrs 21:30 - 22:00 0.50 REMCM P WEXIT Pull 8 stands slowly -from 2845' to 2085' 22:00 - 23:30 1.50 REMCM P WEXIT Pump 30 bbl nut plug sweep -STS - 10 bpm @ 640 psi -Slight traces cement back on bottoms up -Flow check -Well static - Blow down T.D. 23:30 - 00:00 0.50 REMCM P WEXIT POH from 2085' - LD Mule shoe Printed: 4/2/2007 11:19:02 AM gp Page 13 of 22 Operations Summary Report Legal Well Name: Liviano-01 Common Well Name: Liviano-01 Spud Date: 2/23/2007 Event Name: DRILL+COMPLETE Start: 2/23/2007 End: 3/30/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2007 Rig Name: DOYON 14 Rig Number: Date I From - To Hours Task 3 Code NPT Phase Description of Operations 3/16/2007 00:00 - 02:00 2.00 REMCM P WEXIT PJSM -Move HWDP -From ODS to DS of derrick -RIH 13 stands of 5" Weatherford DP - LD 13 stands of 5" DP 02:00 - 05:00 3.00 STKOH P WEXIT PJSM - PU 1 X 1 - 45 joints of 5" Corion DP - POH -Stand back 15 stands in derrick 05:00 - 07:30 2.50 STKOH P WEXIT RU & change saver sub on Top Drive to 4 1/2" IF 07:30 - 12:00 4.50 EVAL P WEXIT Mobilize Corion equipment to rig floor -Test Corion TIW valve to 250 psi low, 3500 high -Test 4 1/2" IF TIW and IBOP floor valves to 250 psi low, 3500 high -Service Top Drive 12:00 - 14:00 2.00 STKOH P WEXIT WOC -Change out handling equipment -Air slips segments - Mud bucket rubbers to 5" -Moblize Corion equipment to rig floor -Moblize BHA to rig floor -Clean pits 14:00 - 15:00 1.00 EVAL P WEXIT RU test equipment -Test 9 5/8" casing to 2500 psi for 10 mins - Record on chart - RD test equiment -Blow down Kill /Choke lines 15:00 - 17:30 2.50 STKOH P WEXIT PJSM - MU 8 1/2" bit -Motor -MWD - Up load MWD -Flex DC's -HWDP - (Surface test MWD -GPM 395 - C 700 psi) - Jars -HWDP 17:30 - 18:00 0.50 STKOH P WEXIT RIH from 709' to 2020 -Wash last stand down 18:00 - 19:00 1.00 STKOH P WEXIT Circulate hole -STS -with 9.2 brine - R&R - 30 RPM -GPM 340 C~? 660 19:00 - 23:30 4.50 STKOH P WEXIT PJSM - RU Corion -Dry run with core barrels on slick line - RD Corion equipment 23:30 - 00:00 0.50 STKOH P WEXIT RIH -Stringers at 2280' -Washed to top of cement C~2 2295' - Drilling cement to 2310' - 60 RPM - TO 2K - WOB 12K -GPM 420 - PP 1070 -PUW 112 -SOW 112 - ROTW 112 3/17/2007 00:00 - 04:00 4.00 STKOH P WEXIT Drill cement from 2310' to 2624' -RPM 60 - TO 3K -GPM 400 - r~-" ~,, ~ ' ' y~' - ( PP 1120 -PUW 120 -SOW 120 - ROTW 120 04:00 - 06:00 ~, 2.00 STKOH P ~ WEXIT Time drill to KO from 2624' to 2650' (20' of new hole) ^ 06:00 - 07:30 1.50 DRILL P PROD2 Circulate hole clean - 400 gpm 960 psi - 60 rpm 2k torque -Pull into 9 5/8' shoe. 07:30 - 11:00 3.50 DRILL P PROD2 Clean pits 3 & 4 -Under shakers, troughs -Vac out standing water in same -Clean suction tubes on pumps -Flush pits, all related lines and equipment w/ LVT -Flush mud pumps w LVT 11:00 - 13:00 2.00 DRILL P PROD2 Fill pits with OBM -Mix sweep - Con't Load pits with OBM 13:00 - 15:00 2.00 DRILL P PROD2 PJSM -Displace Brine with 10.2 ppg MOB -Pump 30 bbls Safe-O Spacer - 50 bbls 9.7 ppg MOB spacer - 10.2 ppg MOB surface to surface 15:00 - 16:00 1.00 DRILL P PROD2 POH to 2583' -Blow down T.D. - RU test equip -FIT TVD 2604' -MUD WT 10.2 -Pressure 135 =MWD 11.2 - RD testing equip -Blow down Choke /Kill Lines -Choke Mnifold -Take SPR's 16:00 - 00:00 8.00 DRILL P PROD2 Directional Drill from 2650' to 3366' - TD 8 1/2" Hole -RPM 70 - TOon2k-offlk-WOB10 to 15-GPM400-PPon 1560-off 1460 -PUW 127 -SOW 122 - ROTW 125 3/18/2007 00:00 - 00:30 0.50 DRILL P PROD2 CBU 1X -GPM 400 - PP 1460 -RPM 60 - TO 1 K -Flow check - Well static 00:30 - 01:00 0.50 DRILL P PROD2 Pump out to shoe from 3366' to 2586' -Pump @ drlg rate 01:00 - 01:30 0.50 DRILL P PROD2 CBU 2 X -Condition mud as per Mud Engineer -GPM 400 - PP 1370-RPM 60-T01K 01:30 - 02:00 0.50 DRILL P PROD2 RIH from 2586' to 3366' -Precautionary washed last stand to btm 02:00 - 02:30 0.50 DRILL P PROD2 CBU 1 X -GPM 400 - PP 1400 -RPM 60 - TO 1 K -Flow check - Well static Printed: 4/2/2007 11:19:02 AM Orig. KB Elev. = 54.3` Orig. GL Elev. = 23.2' 150' - 15.7 ppg Arctic Set Cement NOTE: Surface casing and con- ductorcasing to be cut below ground level and removed. An Abandonment Marker will be installed per AOGCC regulations. 8-1/2" KOP -2628' MD (Liviano-01 A) 15.8 ppg G Cement f/2725' to2525' MD ' L0-9.4 ppg Mutl/tan 500' above top - Hydrocarbon = 2909' MD (Top Ugnu at 3409' MD) -20" Conductor Casing at -80' MD 9-5/8" Cement Retainer (150' MD) (possible use of) - 9.0-9.4 ppg Mud/Brine -50' Cement Above Retainer to -2475' MD •9-5/8" Cement Retainer (-2525` MD) - "Planned" TOC 2525' MD 9-5/8", 40#/ft., L-80 BTC at -2625' MD (Fully Cemented to Surface) _ 17.0 ppg G Cement Kick-Off Plug f/2847' MD -Top 7" Stub 2720' MD -15.8 ppg G Cement f/3040' - 2847' MD (above retainer) '7"Cement Retainer (-3040' MD) 15.8 ppg G Cement 15.8 ppg G Cement flWell TD -4239' to - 500' aoove top Ugnu at 2909' MD 7" 26#/ft., L-80 BTC -production casing, (Drift ID = 6.151", cap. = 0.0383 bpf) -Cemented Ugnu Perfs (-3520' - 3532' MD) 7" Float Collar 3650' MD Liviano-01 A ~ Planned TD - 4239' MD DATE REV. BY 01/25/07 JGR 03/19/07 JGR ', ~ (7" Shoe Track ,~'~ ~ ~ ~' f/3650' - 4306' MD) ., ., . ~ ; ' -7" Float Shoe 4306' MD Liviano-01~ Open-HoIeTD 4314' MD / 4169' TVD COMMENTS MII NE POINT UNIT Final P&A Schematic Liviano-01 A Application f/Sundry Approval II Halliburton Company Survey Report - - -- -- Company: BP Amoco __ Date: 4/10/2007 Time: 16:55:31 Page: 1 Field: Milne Point Co-ordinate(NE1 Reference: Well: MPU-Liviano-01, True North Site: Milne Point Exploration Vertical (TVD) Rci'er ence: Liviano-01:56.7 WeIL• fvtPU-Liviano-01 Section (VS) Reference: Well (O.OON,O.OOE,284.68Azi) Wellpath: Liviano-01 Survey Calculation MMhod: Mi nimum Curvature Db: Oracle Field: Milne Point - -_ _ _ _ __ __ North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 GeoDatum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: MPU-Liviano-01 Slot Name: Well Position: +N/-S -2339.97 ft Northing: 6021554.76 ft Latitude: 70 28 11.453 N +E/-W -1303.97 ft Easting : 538876.56 ft Longitude: 149 40 57.054 W Position Uncertainty: 0.00 ft Wellpath: Liviano-01 Drilled From: Well Ref. Point 500292334300 Tie-on Depth: 33.50 ft Current Datum: Liviano-01: Height 56.70 ft Above System Da tum: Mean Sea Level Magnetic Data: 2/21 /2007 Declination: 23.63 deg Field Strength: 57627 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.50 0.00 0.00 284.68 Survey Program for Definitive Wellpath Date: 4/10/2007 Validated: No Version: 8 Actual From To Survey Toolcode Tool Name ft ft 256.16 4248.77 Liviano-01 IIFR+MS+Sag (256.16 MWD+IFR+MS MWD +IFR + Multi Station Survey - - b1D Iucl Azim TV"D __ Sys TVll _ ___ - N/S E/VV MapN MapE __ Tool ft deg deg ft ft ft ft ft ft 33.50 0.00 0.00 33.50 -23.20 0.00 0.00 6021554.76 538876.56 TIE LINE 256.16 0.39 244.42 256.16 199.46 -0.33 -0.68 6021554.43 538875.88 MWD+IFR+MS 347.54 0.63 242.49 347.53 290.83 -0.69 -t.41 6021554.06 538875.15 MWD+IFR+MS 435.92 0.85 239.44 435.91 379.21 -1.25 -2.41 6021553.50 538874.16 MWD+IFR+MS 527.10 0.56 241.09 527.08 470.38 -1.81 -3.38 6021552.93 538873.19 MWD+IFR+MS 615.92 0.50 218.42 615.90 559.20 -2.32 -4.00 6021552.42 538872.57 MWD+IFR+MS 706.98 0.61 202.86 706.95 650.25 -3.08 -4.43 6021551.66 538872.14 MWD+IFR+MS 801.38 0.79 207.05 801.35 744.65 -4.12 -4.92 6021550.61 538871.66 MWD+IFR+MS 894.04 1.00 199.50 893.99 837.29 -5.46 -5.49 6021549.28 538871.10 MWD+IFR+MS 987.25 0.98 190.07 987.19 930.49 -7.01 -5.90 6021547.72 538870.70 MWD+IFR+MS 1079.99 1.07 216.27 1079.92 1023.22 -8.49 -6.55 6021546.24 538870.06 MWD+IFR+MS 1174.40 2.63 259.78 1174.28 1117.58 -9.58 -9.20 6021545.13 538867.41 MWD+IFR+MS 1268.88 3.35 267.62 1268.63 1211.93 -10.08 -14.09 6021544.61 538862.52 MWD+IFR+MS 1363.20 4.07 276.83 1362.75 1306.05 -9.80 -20.17 6021544.86 538856.44 MWD+IFR+MS 1457.44 4.77 292.56 1456.71 1400.01 -7.90 -27.11 6021546.72 538849.50 MWD+IFR+MS 1550.08 4.73 294.21 1549.04 1492.34 -4.85 -34.15 6021549.73 538842.44 MWD+IFR+MS 1645.72 4.92 296.02 1644.34 1587.64 -1.44 -41.43 6021553.11 538835.14 MWD+IFR+MS 1740.21 4.93 297.01 1738.48 1681.78 2.19 -48.69 6021556.69 538827.86 MWD+IFR+MS 1835.10 5.59 293.05 1832.97 1776.27 5.85 -56.57 6021560.31 538819.96 MWD+IFR+MS 1929.19 6.62 286.07 1926.52 1869.82 9.14 -66.00 6021563.56 538810.52 MWD+IFR+MS 2019.51 8.20 282.85 2016.09 1959.39 12.02 -77.29 6021566.37 538799.22 MWD+IFR+MS 2113.18 10.47 284.64 2108.51 2051.81 15.65 -92.04 6021569.93 538784.45 MWD+IFR+MS 2204.68 12.08 288.66 2198.24 2141.54 20.82 -109.15 6021575.01 538767.31 MWD+IFR+MS 2297.70 14.87 290.00 2288.69 2231.99 28.02 -129.59 6021582.10 538746.83 MWD+IFR+MS 2392.58 17.27 290.12 2379.86 2323.16 37.03 -154.26 6021590.98 538722.12 MWD+IFR+MS 2485.62 20.00 288.70 2468.01 2411.31 46.88 -182.31 6021600.68 538694.03 MWD+IFR+MS 2559.93 20.61 288.04 2537.71 2481.01 55.01 -206.78 6021608.68 538669.52 MWD+IFR+MS 2638.14 21.23 288.27 2610.76 2554.06 63.71 -233.31 6021617.24 538642.94 MWD+IFR+MS 2689.07 20.99 288.41 2658.27 2601.57 69.48 -250.73 6021622.92 538625.50 MWD+IFR+MS 2781.58 20.39 287.15 2744.82 2688.12 79.46 -281.85 6021632.74 538594.33 MWD+IFR+MS Halliburton Com an p Y Survey Report Company: BP Amoco Field: Milne Point Site: Milne Point Exploration Nell: MPU-Liviano-01 Wellpath: Liviano-01 Survev __ - __ D1D Incl Azim TVll Sys'1'Vll N/ ft deg deg ft ft ft Date: 4/10/2007 Time: 16:55:31 Page: 2 Co-ordinate(NE) Reference: Well: MPU-Liviano-01, True North Vertical (TVD) Keference: Liviano-01:56.7 Section (VS) Reference: Well (O.OON,O.OOE,284.68Azi) Survey Calculation Method: Minimum Curvature Db: Oracle E/~~' MapN DIapE Tool ft ft ft ti 2873.78 20.71 284.35 2831.15 2774.45 88.24 2968.54 22.07 282.07 2919.38 2862.68 96.12 3063.78 23.81 284.85 3007.09 2950.39 104.79 3158.81 25.30 283.61 3093.52 3036.82 114.48 3248.76 26.76 285.12 3174.35 3117.65 124.29 3343.49 26.11 285.91 3259.17 3202.47 135.56 3437.53 25.58 284.30 3343.81 3287.11 146.25 3531.33 24.60 285.55 3428.76 3372.06 156.49 3626.69 22.93 285.29 3516.03 3459.33 166.71 3720.39 20.16 281.80 3603.18 3546.48 174.82 3812.59 18.52 284.22 3690.17 3633.47 181.67 3906.67 18.22 283.19 3779.46 3722.76 188.70 4000.72 17.40 282.73 3869.00 3812.30 195.15 4095.55 16.85 283.69 3959.63 3902.93 201.53 4187.67 16.78 283.35 4047.81 3991.11 207.76 4248.77 16.65 282.34 4106.33 4049.63 211.67 4314.00 16.65 282.34 4168.82 4112.12 215.66 -312.99 6021641.36 -346.63 6021649.06 -382.72 6021657.54 -421.00 6021667.03 -459.23 6021676.63 -499.86 6021687.70 -539.44 6021698.18 -577.87 6021708.21 -614.91 6021718.24 -648.33 6021726.18 -678.08 6021732.87 -706.89 6021739.74 -734.92 6021746.05 -762.10 6021752.29 -788.01 6021758.38 -805.15 6021762.20 -823.40 6021766.10 538563.15 MWD+IFR+MS 538529.46 MWD+IFR+MS 538493.34 MWD+IFR+MS 538455.01 MWD+IFR+MS 538416.73 MWD+IFR+MS 538376.05 MWD+IFR+MS 538336.42 MWD+IFR+MS 538297.94 MWD+IFR+MS 538260.85 MWD+IFR+MS 538227.39 MWD+IFR+MS 538197.60 MWD+IFR+MS 538168.77 MWD+IFR+MS 538140.70 MWD+IFR+MS 538113.49 MWD+IFR+MS 538087.55 MWD+IFR+MS 538070.40 MWD+IFR+MS 538052.12 PROJECTED to TD Liviano Sample Summary Sampie No. File No. De th TVD Mud Pressure Before Formation Pressure Mud Pressure After Tem Pump Out Time Pump Out Volume Chamber 1 Size Chamber 1 T e Chamber 1 No. Chamber 2 size Chamber 2 t pe Chamber 2 No. Chamber 3 size Chamber 3 t pe Chamber 3 no. Chamber 4 size Chamber 4 t pe Chamber 4 no. 7 49 3960 3&30.3G 1903 1h51 'S 93 102 45b cc P:iPSR ?_Bfi8 450 a: ~,1PSR 2675 3785A rr MRSC 2 5[ 36uu 3ss49.45 1514 15yrs.y 7F a:? is.5 450 cc MPSR 866 450 ce MPSR 1294 _ 63 3811 3608 78 189 1 fr12.6 75 ~JB 13.9 450 c~ MPSR 1397 450 cc 1.1PSR ?867 ,1 3 .,-.. - L'.-l- 1~~61 ~P-t=~ ,4~ ~~, 11 1~?~:~ G1FSR 2876 450° !:1PSR ?873 5 55 4150 4U11 B i 2000.05 1701.8 19°3.3 - - 10.1 450 cc E.1FSR 2870 45Q cc I~1RSA ?_874 -}-iS:~ 1 ~4 t ~- 1 ~ 1?4~; - 1"" _ I tF~SR 1397 -4`~> ~~ L1FSR 7_867 i7 4053 3918.9 1963 1.3'J 1938 '8 'u.A 9 599.8 1) 11 1 1 14 75 _ 1 gallon = 3785.4 cc 2.75 gallon = 10409.85 cc • Schlumberger Private .. ~ , • Sample Summary Sample no. 1 Depth (MD): 3960 Log File No. 49 Hydrostatic Pressure (psia): 1903 psia Formation Pressure (psia): 1691 psia Temperature (degf) 75 Degf Pump out time: 93 min. Pump out Volume: 10.2 gal. Chamber size: 450 cc Chamber Number: Chamber size: 450 cc Chamber Number: Chamber size: 3785.4 cc Chamber Number: Remarks: LFA GOR = 35- scf/bbl, Sampling flowing pressure = 1570 psia Sample taken using inflatable packer. Depth (TVD): MPSR MPSR MRSC Sample no. 2 Depth (MD): 3980 Depth (TVD): Log File No. 52 Hydrostatic Pressure (psia): 1914 psia Formation Pressure (psia): 1698.9 psia Temperature (degf) 75 Degf Pump out time: 83 min. Pump out Volume: 8.5 gal. Chamber size: 450 cc Chamber Number: MPSR Chamber size: 450 cc Chamber Number: MPSR Remarks: LFA GOR = 350 scf/bbl. PO short stroking during sampling operation. 3830.35 2868 2875 292 3849.49 2866 1294 Schlumberger Private ,: Sample no. Depth (MD): Log File No. Hydrostatic Pressure (psia) Formation Pressure (psia) Temperature (degf) Pump out time: Pump out Volume: Chamber size: Chamber size: Remarks: LFA GOR = 350 scf/bbl • 3 3811 53 1843 psia 1642.8 psia 75 Degf 86 min. 13.9 .gal. 450 cc Chamber Number: 450 cc Chamber Number: Sample no. Depth (MD): Log File No. Hydrostatic Pressure (psia) Formation Pressure (psia) Temperature (degf) Pump out time: Pump out Volume: Chamber size: Chamber size: 4 3832 54 1845 psia 1651 psia 74.2 Degf 145 min. 14.2 gal. 450 cc Chamber Number: 450 cc Chamber Number: Remarks: LFA GOR = 300 scfrt/bbl Sample flowing pressure = 1530 psia Sample no. 5 Depth (TVD): MPSR MPSR Depth (TVD): MPSR MPSR 3688.78 1397 2867 3708.79 2876 2873 Schlumberger Private • Depth (MD): 4150 Depth (TVD): 4011.93 Log File No. 55 Hydrostatic Pressure (psia): 1999.3 psia Formation Pressure (psia): 1764.8 psia Temperature (degf) 77.7 Degf Pump out time: 52 min. Pump out Volume: 10.1 gal. Chamber size: 450 cc Chamber Number: MPSR 2870 Chamber size: 450 cc Chamber Number: MRSR 2874 Chamber size: 0 Chamber Number: 0 0 Chamber size: 0 Chamber Number: 0 0 Remarks: LFA GOR = 400 scf/bbl, MRPO short stroking, must divide flowate and recorded flow volume by 2. Sample no. 6 Depth (MD): 4040 Depth (TVD): 0 Log File No. 56 Hydrostatic Pressure (psia): 1946.7 psia Formation Pressure (psia): 1731.59 psia Temperature (degf) 78.6 Degf Pump out time: 70 min. Pump out Volume: 8.2 gal. Chamber size: 450 cc Chamber Number: MPSR 1397 Chamber size: 450 cc Chamber Number: MPSR 2867 Remarks: LFA GOR = 400 scf/bbl Sample no. 7 Depth (MD): 4053 Depth (TVD): 3918.9 Log File No. 57 Schlumberger Private 1 s r • Liviano MDT Sample Summary Hydrostatic Pressure (psia): 1948 psia Formation Pressure (psia): 1737.7 psia Temperature (degf) 78 Degf Pump out time: 70.8 min. Pump out Volume: 8.9 gal. Remarks: PO to confirm fluid type LFA GOR = 400 scf/bbl NO sample acquisition attempted Sample no. 8 Depth (MD): 0 Log File No. 0 Hydrostatic Pressure (psia): 0 psia Formation Pressure (psia): 0 psia Temperature (degf) 0 Degf Pump out time: 0 min. Pump out Volume: 0 gal. Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Remarks: Sample no. 9 Depth (MD): 0 Log File No. 0 Hydrostatic Pressure (psia): 0 psia Depth (TVD): Depth (TVD): 0 0 0 0 0 0 0 0 0 0 Schlumberger Private J i ~ t Formation Pressure (psia) Temperature (degf) Pump out time: Pump out Volume: Chamber size: Chamber size: Chamber size: Chamber size: Remarks: • 0 psia 0 Degf 599.8 min. 0 gal. 0 Chamber Number: 0 Chamber Number: 0 Chamber Number: 0 Chamber Number: Sample no. 10 Depth (MD): 0 Log File No. 0 Hydrostatic Pressure (psia): 0 psia Formation Pressure (psia): 0 psia Temperature (degf) 0 Degf Pump out time: 0 min. Pump out Volume: 0 gal. Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Chamber size: 0 Chamber Number: Remarks: Depth (TVD): 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Schlumberger Private Zone MD TVD API N B 3811 3688.78 13.8 AP NC 3832 3708.79 12.8 OA 3960 3830.35 16.5 ~ ~ 12 14 16 18 20 22 OA 3980 3849.49 15.4 36JO -'r- __ __ OB 4040 3906.54 18.9 OB 4053 3918.9 Obd 4150 4011.93 21.2 370 ~- _..- -- -- • Schlumberger Private • Date: March 14, 2007 Sperry Drilling Services To: Alaska Oil & Gas Conservation Commission Attn: Kristin Dirks 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 From: Sperry Sun Drilling Services Attn: Steve Carroll 6900 Arctic Blvd. Anchorage, AK 99518 From: B P Exploration (Alaska) Job# AK-AM-4913290 AFE# MSD337473 Liviano-01 North Slope, Alaska l~~ Shipment Includes: l Washed and Dried Cutting Samples 1 Set 3 Boxes Received By: Print Name Sign Name 2,u~ ~ 0 c ~( RE: Liviano-01 Well Completion Report (407) • Subject: RE: Liviano-O1 Well Completion Report (407) Frorn: "Rose, John G (FAlRWEATHER)" <John.G.Rose@bp.com> Date: Mon, 26 Mai- 2007 ] 6:29:59 -0800 To: Thomas E 1~1~iun~ier ~~tot~rt m~~unclcn~r:~ui~~~in.state.ak.us=~ Thanks. John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Cell 907/748-5223 Fax 907/564-4040 ~~ aoh-~ ~~ Original Message----- From: Thomas E Maunder [zna..l.to : tozi zr:.auz-z:.er=~adr:.zi-ri . state . ak . us] Sent: Monday, March 26, 2007 4:15 PM To: Rose, John G (FAIRWEATHER) Cc: Stewman, Sondra D Subject: Re: Liviano-O1 Well Completion Report (407) John and Sondra, That is correct that no sundry was required for the plugging work on Liviano-O1. Tom Maunder, PE AOGCC ------ Original Message ----- From: "Rose, John G (FAIRWEATHER)" <.;:>~x~..G.Ros~~~~bp,corz> Date: Monday, March 26, 2007 4:10 pm Subject: Liviano-O1 Well Completion Report (407) To: "Stewman, Sondra D" ~'S0;1dra..~''.:;e`r:mall~:-u~;~}.COLil> Cc: Thomas Maunder <tom maunderGadrnin.stat.e.ak.us> Sondra, As it relates to the completion of AOGCC's Well Completion Report ', (10-407) for the Liviano-Ol well, we finished that well on 3/17/07 at 06:00 hours as began our Liviano-OlA sidetrack. That being the case, ', please proceed with completion of that report as required by AOGCC regulations. As for the need for Sundry Approval (10-403) for the P&A of this well (Liviano-O1), it is my understanding that one is not required for this well. If you have any questions or require ', additionalinformation, please advise. Thanks - JR John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Cell 907/748-5223 Fax 907/564-4040 1 of I 3/27/2007 7:44 AM RE: FW: Liviano-Ol Weekly Report • Subject: RE: FW: Liviano-Ol Weekly Report From: "Rose, John G (FAIRWEATHER)" <John.G.Rose~ci~bp.com? Date: Fi-i, 16 Mar 2007 10:52:04 -0800 To: l~homas Maunder ~t~~m niaun~lci~~iad~»in.~tate.ak.u~ CC: "Kar~i, Dannyl~"~l~ann~~.flara~rhp.com ~~`~_~ ~l-~ During the DST, we collected 6 - 600 oc samples with the E-line retrieval system. Of those 6 samples; the asset has indicated that it looks like we have at least 3 good PVT quality oil samples, however, as those fluid samples are currently in the Schlumberger lab this report is somewhat speculative. if the samples are good and as the objective of the DST was to provide the asset with 3 PVT quality samples, it looks as if we have met our test objective. Jt~J~r~ ~. }~C}SP S#~-,~1ask~s C~ritl~r~ry ,;~tr~ ~f~ic~ 9tI7l5Es-~?71 ~~19t?7J73- 5223 r~zx t?7r'Sti4-~t~4L7 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 16, 2007 10:34 AM To: Rose, John G (FAIRWEATHER) , Cc: Kara, Danny T Subject: Re: FW: Liviano-01 Weekly Report Thanks John, Are any details available regarding the Ugnu DST? Tom Rose, John G (FAIlZWEATHER) wrote, On 3/16/2007 10:07 AM: Tom, Per the requirements of the Liviano-01 Drilling Permit (#207-014), the following is a summary of the fast week of operations on this well: 03109107 - RIN wIDST test string for Ugnu DST, spaced-out test sting and set packer. 03110107 - D BOPEINU Tree to perform DST. Pressure test tree to 3000 psi. Began DST procedure to include nitrogen cushion as planned. 03111/07 -Continued DST work to include perforating 12' of Ugnu sands f13520' - 3532' MD, 03112107 -Continued DST work to include the E-line recovery of formation fluids. {dote: By DST design, no formation fluids were allowed t0 flow to surface.} 03113/07 -Complete DST work. Killed well with 9.2 ppg brine, r~D Tree1U BOPE (tested "breaks" to 250 psi Iowf300 psi high). Began to pull DST test string. 03111107 - Gomplete POflN w1DST test string. RU test equipment and perform weekly BC~PE test (John Grisp (AOGCC Inspector) waived witness of this test}, RI wlcement retainer to PA the Ugnu perforations. Set the retainer at 3040' D in 7" casing and confirmed set with 73K weight (top 1 of 3 3/16/2007 11:02 AM RE: FW: Liviano-O1 Weekly Report • perforation at 3520' t^~D - PBTD at 3650' MD}. Squeezed below the retainer with 24 bbls 15.8 ppg G slurry cement. Placed 8 bbls of cement on top of the retainer brining estimated TC7C to ~-2830', P&A was witnessed by ~lohn Crisp {AOGCC}. Prepared to cut 7" casing, 03115107 - RIH w1T' casing cutter and cut casing at 2720' D. Circulated the 7" x 9-5f8" annulus to confirm cut. Pulled 7" casing ff2720° MD. RIH w14" mule shoe and set 37 bbl 17.0 ppg kick-off plug. from top of the lower cement plug at 2830' N1D to 300' back into the -518° casing to ~ 2325' iViD (9-518" shoe at 2625' MD}. 3116f07 Current Qperations - PU BHA and prepare to sidetrack the well below the 9-518" casing shoe {K{~ point 2652' 11~D). ~1lfe will begin operations under the Liviano-01A Drilling Permit {207-021} once a successful kick-off is established. if you have any concerns or require additional information, please advise. Thanks - JR .Tohr~ G. Rose P-tlfasf« C?riflfr~g rc~~rf~ t~ffic~ 9L37/564-571 Golf 9071748-523 ~~ax 9t17s` a6~-4t14tJ From: Rose, John G (FAIRWEATHER) Sent: .Friday, March 09, 200711:32 AM To: 'Thomas Maunder' Cc: .Kara, Danny T Subject: FW: Liviano-O1 Weekly Report Tom, Per the requirements of the Liviano-01 Drilling Permit (#207-014), the following is a summary of the last week of operations on this well: 03102107 Ran MDT tools on drillpipe for UgnulSchrader formation pressures and fluid samples. 03103107 Cantinas to perform MDT work. 03104107 Complete MDT G^rork. Make-up BHA for wiper trip. 03105f01 RiH to $-112" TD at 4314` MD and circulate hole clean. P®OH (with MAD pass) in preparation to run 1`° casing. 03106107 Ran and cemented 7" casing at 4306' MD. NU an 7" and ran weekly SC}P test (Bab Nobel (AC3GCC) waived witness of test). 03107107 Made-up 7° clean-out assembly and cleaned-aut the 7" to the top ofi the float collar at 3649` MD (casing successfully tested to 3000 psi). 03!08101 Rigged-up E-line and ran gauge ringljunk basket to TD (2 runs). Ran USIT/GR lag to confirm cement band and far DST tie-in, 03109/07 Current ~3perations: RIH with DST test string for planned Ugnu DST, If you have any concerns or require additional information, please advise. Thanks - JR .dohrt {:~. Rose ~'-Afr~ska £?ri6fi~r~ rc~trls Q~fce 9G~715~a~-5271 2 of 3 3/16/2007 11:02 AM RE: FW: Liviano-01 Weekly Report Cell ~C17f7413-5223 Fix 9~J71 s~a4-4t1~t? From: Rose, John G (FAIRWEATHER) Sent: Friday, March 02, 2007 12:59 PM To: 'Thomas Maunder' Cc: Kara, Danny T Subject: Liviano-01 Weekly Report Tom, • Per the requirements of the Liviano-01 Drilling Permit (#207-014), the following is a summary of the last week of operations on this well: 02/21/07 - Rig move to Liviano-01 A. 02/22/07 - Continued rig move to location, positioned rig and rig-up over conductor (rig accepted at 19:00 hours), NU diverter system. 02/23/07 - Function test diverter system (witnessed by Jeff Jones - AOGCC), PU BHA and drillpipe in preparation to spud well 02/24/07 - Spud well with 12-1/4" bit and drill to 2186' MD. 02/25/07 - Drill 12-1/4" hole to surface hole TD at 2630' MD. Circulate and condition well for surface casing. 02/26/07 - Run and cement 9-5/8" surface casing at 2625' MD (161 bbls 10.7 ppg cement to surface). N.U BOPE and test (witnessed by John Crisp - AOGCC). MU 8-1/2" BHA. 02/27/07 - Drill out of surface casing w/ 8-1/2" BHA (2500 psi casing test) and drill to 2870' MD. 02/28/07 - Drill 8-1/2" hole to final well TD at 4314' MD. Circulate and condition hole at TD prior to MAD pass LWD. 03/01/07 - Mad pass LWD logs to above Ugnu to 3150' MD. Run back to bottom and condition welt for trip out for planned MDT sampling. Trip out of hole. 03;02/07 Current operations: RIH w/MDT tools for testing/sampling Ugnu and Schrader Bluff targets. If you have any concerns or require additional information, please advise. Thanks - JR John G. /;'case S,~-dd#~s1~~ C?ril#iny Cr~~~e/~ t~f/lc~ U7/.~64-5271 Coll (~7l748-5223 1"~~ ~?7I5f~-1-4{l~l~ 3 of 3 3/16/2007 11:02 AM • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~, , DATE: March 14, 2007 P. I. Supervisor ~~ 3~"z3~~ ~ FROM: John Crisp, SUBJECT: Cement Plug Placement Petroleum Inspector MPU Liviano - 01 BPX Exploratory PTD 207-014 March 14, 2007: I traveled to BP's Exploratory well Liviano - 01 to witness perforation plugging by the downsqueeze method. Well plugging requirements 20 AAC 25.112 (c) (1) (D) were followed by setting cement retainer @ 3040' MD. Perforated interval located 3520' MD to 3532' MD_ I witnessed cement retainer set @ 3040' & 20K DP weight set down on retainer to verify retainer integrity. 24 bbl's 15.8 ppg class G cement squeezed /~ thru retainer & 8 bbl's class G cement placed on top of retainer. +~ Summary: BPX Exploratory well Liviano - 01 production interval was successfully plugged using downsqueeze method in accordance with AOGCC regulation 20 AAC 25.112(c) (1) (D ). Attachments: None Confidential 2007-0314_P&A~erfs_MOli_Liviano-1 _j c. doc • i~abo~-s 27E ®iverter inspection - yak ~2iver #~ (PT® 2®6167) Photos by John Crisp, ,~OGCC March 16. 2007 Diverter vent line exiting substructure Diverter vent line F' ._~ Annular, knife valve, and observation port downstream of knife valve (bull plug) • ~~ ®~i ~ ~ic~~ COI~TSERQ~1'IO1~T C®M1~IISSIOIQ Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH P,4LlN, GOVERn/OR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Unit, Ugnu Undefined and Schrader Bluff Oil Pool, Liviano-O1 BP Exploration (Alaska) Inc. Permit No: 207-014 Surface Location: 1321' FNL, 602' FEL, SEC. 24, T13N, R09E, UM Bottomhole Location: 1151' FNL, 1243' FEL, SEC. 24, T13N, R09E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced exploration well. Please note that this permit authorizes drilling activities in the planned cased hole section only. A separate permit application must be submitted for the sidetrack/redrill hole section. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 Liviano-01 207-014 witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this 7~ day of February, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~} ~ ~ ~~~ ALASK~ AND GAS CONSERVATION COMMIS~~ PERMIT TO DRILL ~~ ,,~ -~ ~ ~ Z0~7 20 AAC 25.005 ~.. 1a. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ®Exploratory ~ ^ DevelopmentGas ^ Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1c. Sp~k1~1 ~3 ~ ii~8.f ' ~~iz~iss~on ^ Coalbed Meth~~ Hydrates ^' $}~a~ Q~ - - .; 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193- 11. Well Name and Number: MPU Liviano-01 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 4239' TVD 4151' ~ 12. Field /Pool(s): Milne Point Unit / Ugnu ~ S'~ 4a. Location of Well (Governmental Section): Surface: 1321' FNL 602' FEL SEC UM l 24 T13N R09E 7. Property Designation: ADL 025514 , , . (p , , anned) Top of Productive Horizon: 1207' FNL, 1031' FEL, SEC. 24, T13N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 25, 2007 Total Depth: 1151' FNL, 1243' FEL, SEC.24, T13N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3950' 4b. Location of Well (State Base Plane Coordinates): Surface: x-538876 y-6021555 ~ Zone-ASP4 10. KB Elevation (Height above GL): 54.3' feet 15. Distance to Nearest Well Within Pool: 2840' 16. Deviated Wells: Kickoff Depth: 1300 ' feet Maximum Hole An le: 27 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1744 - Surface: 1359 18. Casin Pr ram: S ifi ns To - in D th - Bo m u nti of nt c.f. or sa k Hole asin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 32" 20" 92# H-40 Weld 120' urface Surface 120' 120' 260 x Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 2626' Surface Surface 2626' 2601' 389 sx AS Lite 197 sx Class 'G' -1/2" 7" 26# L- BTC-M 42 9' rf urface 42 ' ~ 4148' ~ 224 sx I 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length:.; ize _CementVotume MD Conductor /Structural Surface Intermediate Pro coon Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact John Rose, 564-5271 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Si nature -~. Phone ~~`~~07 Date t '~.5 o Sondra Stewman, 564-4750 Commission Use Oni Permit To Drill " , N m er: zl~?'v~7 API Number: 50- d Zq - z33 y~3~L~ Permit Approval See cover letter for Da h r r irem n Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalb~d methane, gas hydrates, or gas contained shales: [~ Samples Req'd:L_IS,/Yes -^Jn1o Mud Log Req'd: dyes ^ No HZS Measures: ^ Yes tld'No rectional Survey Req'd: dyes ^ No Other: APPROVED BY THE COMMISSION Date ~$~Q~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate 30.0 7 ~~/l0~ • • To: Tom Maunder, Petroleum Engineer `~ ~ Alaska Oil & Gas Conservation Commission ~ s From: John Rose, ODE - _, - - Date: January 25, 2007 - ` °' ' 3~ - Re: MPU Liviano-O1 Permit to Drill The MPU Liviano-O1 appraisal well is scheduled to be drilled by Doyon Rig #14 with an estimated spud date of 2/25/07. The basic drilling plan is to spud the well with a 12-1/4" bit and drill to the surface hole TD at 2626' MD where 9-5/8" surface casing will be run and cemented to surface. An 8-1/2" hole will then be drilled the P_B1 TD at 4299' MD. After gathering open- hole data from this leg, 7" casing will be run and cemented to accommodate a planned cased hole DST program. With the cased hole DST program completed, the open perforations of the 7" casing will be squeezed with cement prior to cutting and pulling the 7" from 100' below the surface casing shoe to drill the O1 leg of the well. The O1 leg of the well will be cored (7-7/8" core) and drilled to a final well TD of 4239' MD (8-1/2" hole) where again open-hole logging data will be obtained. With the objectives of the appraisal well met, the P&A process will begin. That final P&A process will include: 1. Spot/squeeze cement plug(s) (15.8 ppg G) across all cased-hole perforations and/or open- hole hydrocarbon zones (Schrader Bluff/iJgnu) in both legs of the well. 2. In conjunction with the P&A work of the O1 leg, bring cement (15.8 ppg G) 100' back into the 9-5/8" surface shoe. 3. Spot 150' cement surface plug (10.7 ppg Arctic Set). 4. Cut the surface casing and conductor casings below the ground elevation and remove those components. 5. Place Abandonment Marker. Please note the Wellplan Summary as provided below for specific details concerning the drilling and P&A of this appraisal well: MPU Liviano-01 Page 1 Well Name: I MPU Liviano-01 Ugnu -Schrader Bluff Appraisal Well Drilling and Evaluation Plan Summary T e of Well: Appraisal Well Surface Location: 1,321' FNL and 602' FEL (As Proposed) Section 24, T13N, R9E UM ' ' N = 6,021,555 E = 538,876 T1 -Surface Casing Point 1,265' FNL and 812' FEL Section 24, T13N, R9E UM E = 538,665' N = 6,021,610' Z = 2,547' TVDSS T2 -Top of SBF OA (PB1) 1,265' FNL 1 E - UM T13N, R9E Section 24, E = 538,160' N = 6,021,740' Z = 3,747' TVDSS T3 - TD (PB1) 1,105' FNL and 1,420` FEL Section 24, T13N, R9E UM E = 538,057' N = 6,021,766' Z = 4,093' TVDSS T1 - 15' above MA (01) 1207 FNL and 1013' FEL Section 24, T13N, R9E UM E = 538,446' N = 6,021,667' Z = 3,277' TVDSS T2 - 15' below Base OB-SBA5 1166 FNL and 1184' FEL (01) Section 24, T13N, R9E UM ' ' ' E = 538,293 N = 6,021,707 Z = 3,870 TVDSS T3 - TD (01) 1151' FNL and 1243` FEL Section 24, T13N, R9E UM E = 538,234' N = 6,021,722' Z = 4,096' TVDSS Distance to Property line 3,950' (distance from SHL to MPU/KRU unit boundary) Distance to nearest well 2840' from MPM-01 (TSBD-OA) AFE Number: Estimated Start Date: 25 Feb 2007 Ri Doyon 14 Ri da s to com lete: 33 4,299 4,148' MD: (PB1 leg) ' TVD: (P61 leg) ' Max Inc: 27° KOP: 1300' KBE: 54 3' / 4,239 / 4,151 . 01 le 01 le Well Desi n: Ultra Slimhole Ob'ective: U nu M Sands and Schrader Bluff Nand OSands -Data Ac uisition - MPU Liviano-01 Page 2 Mud Program: 12-1 /4" Surface Hole (0' - 2.626' MD): Soud Densit PV YP H API Filtrate Chlorides m /1 8.6-9.8 10-25 30-50 8.5-9.5 NC-8 <1000 8-1/2" Hole - PB1 2,626' - 4,299' MD LSND T h~~ ~~~ ~ Densit PV YP H API Filtrate MBT 8.8-9.4 8- 15 26-32 9.0-9.5 6-8 <25 8-1/2" Hole - 01 (2.652' - 4,239' MDI: LSND Densit PV YP H API Filtrate MBT O` 8.8-9.4 8-15 26-32 9.0-9.5 6-8 <25 \v~~G~ 8-1/2" Coring Section - 01 (3.331± to 3.910±'1: 100% Mineral Oil-Based Densit PV YP H HTHPFiltrate % Oil ~9.0-9.3 20-35 20 - 30 N/A < 2 100 Upon completion of coring operations, the well will be displaced back to LSND fluid for reaming out the cored hole to the full 8-1/2" gauge and drilling to the final well TD of 4,239' MD and the logging/pressure survey program to follow. Waste Disposal: NO ANNULAR INJECTION~Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program Hole Size Csg Diam WUFt Grade Conn Burst Collapse Length Top Bottom MD/ MD/ TVDrkb TVDrkb 32-in 20-in un- 92 H-40 Weld 1530 520 120-ft 0 120-ft / insulated 120-ft 12.25 9 5/8-in 40 L-80 BTC 5750 3090 2,626' 0 2,626'/ 2,601 8.5-in 7-in 26 L-80 BTC-M 7240 6600 4,299' 0 4,299'/ 4,148' N/A 3.5-in 9.2 L-80 Vam-Top 10160 10540 3,436' 0 3,436'/ or TC-II 3338' MPU Liviano-01 Page 3 • Cement Program: • Casin Size 9-5/8", 40#, L-80, BTC Surface Casin Lead cement = 2100' MD to surface with 40% excess below the PF and Basis 150% excess above through the PF. Tail cement = 526' MD above shoe lus 40% excess Total Cement Volume: 463 bbl Wash 5 bbl water S acer 50 bbls of MudPush Lead 284 bbls, 389 sxs of Arctic Set Lite: 10.7 and 4.4 ft /sx Tail 41 bbls, 197 sxs "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Casin Size 7", 26#, L-80, BTC-M Production Casin Basis Tail cement = 200' MD below the surface casing shoe 2826' MD plus 40% Excess over Gau a Hole Total Cement Wash 5-bbl water Volume: 35 bbl 10 bbl CW 100 S acer 35 bbls of MudPush Tail 46.6 bbls, 224 sxs "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST ~80°F from SOR Evaluation Program: 12-1 /4" Section Open Hole: Photo Gyro • MWD/GR/Res • IFR/CASANDRA, • Sperry InSite • DEN/NEU w/ACAL ' • Sonic (BAT) • Mudloggers ~ • Cuttin Sam les ' 8-1/2" Section • MWD/GR/RES • I FR/CASAN D RA, • Sperry InSite • DEN/NEU w/ACAL • MRIL • Mudloggers • Cutting Samples • Isotubes • MDT-Schrader Bluff Cased Hole: . GR/USIT • PSP/DEFT • DST-U nu contin enc Schrader Bluff MPU Liviano-01 Page 4 Formation Marks: • Formation Tops MD (FT) TVD (FT) TVDss (FT) Pore Pressure si EMW (ppg) BPRF 1905 1904.3 -1850 803 8.35 TUZC 3156 3088.3 -3034 1,317 8.35 M87F (MA) 3445 3346.3 -3292 1,429 8.35 M80T (MB1) 3486 3382.3 -3328 1,445 8.35 SBF2-NA 3734 3610.3 -3556 1,609 8.70 SBF1-NB 3778 3651.3 -3597 1,627 8.70 TSBD-Top OA 3936 3801.3 -3747 1,695 8.70 BA5-Base OB 4049 3909.3 -3855 1,744 8.70 TD 4299 4148.3 -4094 Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 12-1/4" 0 - 2,626' 2,626' Baker Hughes MX1 .5 - .7 550-650 2 8-1/2" 2,626' - 4,299' 1,673' Baker Hughes MX1 .5 - .7 500-600 3 8-1/2" 2,626' - 4,239' 1,613' Baker Hughes MX1 .5 - .7 500-600 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Integrity tests: • Kick tolerance: ~\~~~C'v-CVO-. S~~s~ ~cr~~~- 1,744 psi at 3,855' TVDss (SBA5-Base OB) `~ rv~ 1,359 psi at (Based on a full column of gas at O.t psi/ft) 3,500 psi FIT or LOT to 13.1 Ib/gal 20' below the 9-5/8" shoe. 50.5 BBIs with 9.4 Ib/gal mud at below the 9-5/8" shoe. • Planned completion fluid: N/A. Drilling Hazards & Contingencies: • Running Gravel/heavy clay problems have been encountered in some MPU wells. High Vis Mud should be utilized. f • This is an appraisal well. Hydrates could be encountered. Expected potential depth for hydrates would be from base of permafrost at 1904' TVD to 2500' TVD. Keep the Mud as Cool as possible. Lost Circulation • Lost Circulation is not anticipated as a major problem. However, good drilling practices need to be maintained to minimize the potential for pressure induced lost circulation. Expected Pressures Formation pressure in the Ugnu is expected to be 8.35 ppg. Formation pressure in the Schrader Bluff is expected to be 8.7 ppg. MPU Liviano-01 Page 5 Pad Data Sheet • Refer to the MPB-Pad and MPE-Pad Pad Data Sheets for off-set well data. Hydrocarbons • Hydrocarbons are anticipated in the Ugnu & Schrader Bluff interval. `' Faults • No major faults are predicted on this well. The closest fault is +/- 500' away at TD. Hydrogen Sulfide • Hydrogen sulfide is not anticipated. The closest wells had 2ppm. Anti-collision Issues • There are no anti-collision issues on this well. Distance to Nearest Property • Liviano-01 is 3,950' (distance from SHL to MPU/KRU unit boundary) Distance to Nearest Well Within Pool • Liviano-01 is 2840' from MPM-01 (TSBD-OA) DRILL & COMPLETION PROCEDURE Pre-Rig Operations Install 20" conductor casing to --120' MD. Drillin 1. MIRU and NU Diverter. 2. Function Test Diverter, PU 5" DP and BHA. 3. Drill 12-1/4' surface hole to 2626'~MD (2601' TVD) with water base mud. 4. Run 9-5/8" surface casing and cement to surface. 5. ND diverter and NU BOPE and test as required. 6. Drill out 9-5/8" casing plus 20'. Perform a FIT. 7. Drill 8-1/2" hole (PB1 leg) with water based mud through both the Ugnu and Schrader to 4299' MD (4148' TVD). 8. Conduct open-hole evaluation (logs/MDT work (Schrader)). ~~ l~ w Ssl~„ ~c9 ~~i,rSS~ 9. Case the hole with 7" casing. Bring cement no more then 200' ve MA target 3346' TVD TOC to be at~~` D, ~ ~~ s' `~ ~~ ` ~~ 1/, 10. RIH w/3-1/2" test string and set up for DST work. 11. ND BOPE/NU Tree and test as required (will conduct DST through Tree to keep testing operations below the rig floor). MPU Liviano-01 Page 6 12 L ' . Run DST(s) on Schra er (If needed -contingency) and Ugnu a s planned for fluid samples. (NOTE: Fluids will not be allowed to flow to surface.) 13. ND Tree/NU BOPE and test as re uired. q 14. Pull 3-1/2" test string. 15. RIH w/DP and P&A the PB1 leg (open perfs) with cement. a. If the Schrader is perforated and tested in Step #12, RIH and seta 7" cement retainer within 100' above the top Schrader perforation and squeeze a volume of 15.8 ppg G cement equal to the casing volume from 100' below the bottom Schrader perforations back to the bottom of the cement retainer (per AOGCC regulations). Prior to moving to the next step of this procedure, set ~20K weight on the retainer with the drillpipe to confirm the retainer is properly set. b. To plug the Ugnu perforations related to the DST work in Step #12, seta 7" cement ~- r retainer ~50' - 500' above the top Ugnu perforation and squeeze a volume of 15.8 Cjh .~-^ C ppg G cement equal to the cased hole volume from 100' below the lowest Ugnu `~~ . ~5 ~~- perforation (or the top of the Schrader retainer if present as detailed in Step 15-a) ~ : cv w ~ ~{-p back to the bottom of the cement retainer (per AOGCC regulations). With the ~~ ~ ~ correct volume of cement squeezed below the retainer, set ~20K weight on the ~ S~ 6~ Y retainer with the drillpipe to confirm the retainer is properly set. With retainer weight tested to confirm correct placement, place a volume of 15.8 ppg cement equal to a minimum of 50' of casing volume above/on top of this cement retainer. (NOTE: This exact placement of this upper most cement retainer will be designed to enhance the planned cement kick-off plug that will be required to sidetrack this well below the 9- 5/8" surface casing shoe as detailed in Step #18 of this procedure.) 16. Cut and pull 7" casing from 2,726' for 8-1/2" sidetrack at2,652'.' 17. Set kick-off plug (cement) from top 7" stub (from top of upper most cement retainer as detailed in Ste #15-b of this rocedure back to surface casin shoe at 2,626' MD. 18. Kick-off cement plug with 8-1/2" bit at -2,6 52' for the drilling of the 01 leg. C ~ s ~o r .~ ,c~ Z+ ~ y 19. _ ~ - ~ S ~ss c - ~ ~ Drill to 3430' MD (~15' above the top of the MA sand) and displace the~well to tTie UB' cor ni g ~ fluid. ~` 20. Using OBM, core the well (7-7/8" core head) to 4064' (-15' below the base of the OB-SBA5 ~~ sand). ~ ~ 21. ~ With the coring assembly in the well at -4064' MD, displace the well back to a fresh water LSND ~ ~~ ~ mud. TOOH. N et yc '~' ~.'~ 22. , Ream the cored hole out to 8-3/4 and drilling the 01 leg to the final well TD of 4,239 MD. t °~ Qp' ~ 23. _.. Run open-hole logs as required. „~ 24. P&A the 01 leg by RIH w/open-ended drillpipe and lay cement plugs from the 01 leg TD of 4239' ~" ~ MD to 100' above the upper most hydrocarbon zone (top Ugnu MA 3445' MD /bring cement to --3345' MD) per AOGCC regulations. io oving to then edure, this ce ted to a pressure e D of footage to the 9-5 25. Continue the P&A process by setting cement plug(s) as required to bring 15.8 ppg G cement from the top of the last plug set in Step #24 to 100' above the surface casing shoe to 2,526' MD (per AOGCC regulations). Prior to moving to the next step of this procedure, this cement squeeze will be tested to a pressure equal to .25 psi per TVD of footage to the 9-5/8" casing shoe (2601' TVD). 26. Continue the P&A process by moving up the well to -155' below the top of the well and seta 150' balanced cement plug (11.5 ppg Arctic Set) to within 5' of the top of the well (per AOGCC regulations). (NOTE: The 9.0-9.4 ppg water based mud used to drill this well will be left in all sections of the well be low and between all cement plugs.) MPU Liviano-01 Page 7 27. ND BOPE and release drilling rig. Post Rig: 1. Cut surface casing and conductor casing below ground level and remove. 2. Install Abandonment Marker per AOGCC regulations. MPU Liviano-01 Page 8 ~; 3-1/8" - 5M Tre Wellhead: 11" 5M FMC 150' - 11.5 ppg Arctic Set Cement NOTE: Surtace casing and con- ductorcasing to be cut below ground level and removed. An Abandonment Marker will be installed per AOGCC regulations. 8-1/2" KOP -2652' MD 15.8 ppg G Cement Top 7" Stub -2726' MD 7" Cement Retainer (-2960` MD) ~:~~ ro-o tR 7" 26#lft., L-80 BTC -production casing, (Drift ID = 6.151", cap. = 0.0383 bpf) 15.8 ppg G Cement 01 Leg ~ TD - 4239' MD Liviano-01 Orig.K 54.3' Orig. GL . _ ##.#' ~ -20" Conductor Casing at -120' MD o -9.0-9.4 ppg WB Mud '? " "~~ "`° "` TOC 2526` MD ~. -9-5/8", 40#/ft., L-80 BTC at -2626' MD (Fully Cemented to Surtace) `'` ~ - 15.8 ppg G Cement »~ DATE REV. BY COM 01/25/07 JGR Finale&A Schematic 15.8 ppg G Cement -Cemented Ugnu Perfs (-3445' - 3734' MD) - 9.0-9.4 ppg WB Mud -7" Cement Retainer (-3734' MD) -Cemented Schrader Perfs (-3734' - 4049' MD) - 9.0-9.4 ppg WB Mud 7" Float Collar 7" Float Shoe 4219` I 4299` MILNE POINT UNIT Liviano-01 W le Ibore BP EXPLORATION (AKl d P81 Leg ~ TD - 4299' MD - o ° ' ~ __-._-.. ~ - - - Y o . o in rn ~ b , ~ °o ` v' o •t 07 :' 0 - - - - - a ~ W ~i O a v ~ ~ ' m Z J ' ° ~ .+ ~ ~rba~Mb m Om(~bN O { . O C Q ~ > M Q .~ O\ N 7 ~~ ~ t ~ f 9 0 NNMVV~ibb Q N ~O ~ z ! h ,. 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O .--~ ° ° ~ - L ,~ c ~ ;~~. ,M ~ ~ O N r o ~ Ck PaN ~ ~ ~ ) ~-) mo z -NMQ ~. ~ ~ + 8 4 4 S / ~' Sperry-Sun BP Planning Report Company: BP Amoco Date: 12/8/2006 Time: 10:43:45 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPU-Liviano-01, True North Site: Milne Point Exploration Vertical (TVD) Reference: 20GL+34.30RKB 54.3 Well: MPU-Liviano-01 Section (VS) Reference: WeII (O.OON,O.OOE,284 .90Azi) Wellpath: Plan Liviano-01 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: Plan Liviano-01 Wp 4 Date Composed: 12/4/2006 Version: 15 Principal: Yes Tied-to: From: Definitive Path Field: Milne Point North Slope UNITED STATES Map SysteniJS State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumiVAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: Milne Point Exploration Site Position: Northing: 6023901.50 ft Latitude: 70 28 34.467 N From: Map Easting: 540167.75 ft Longitude: 149 40 18.722 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Well: MPU-Liviano-01 Slot Name: Well Position: +N/-S -2339.72 ft Northing: 6021555.00 ft Latitude: 70 28 11.455 N +E/-W-1304.53 ft Easting : 538876.00 ft Longitude: 149 40 57.070 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 3240.84 3186.41 9.625 12.250 9 5/8" Formations MD TVD Formations Lithology Dip Angl e Uip Direction ft ft deg deg 3992.29 3912.30 Top OB 0.00 0.00 3887.74 3811.30 Top OA 0.00 0.00 3700.36 3630.30 TSBF 0.00 0.00 3390.84 3331.30 Top Core 0.00 0.00 Targets Map Map <__-- Latitude ----> <_-- Longitude --- Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Liviano T1 (Core) 3734.30 141.88 -533.22 6021694.08 538342.10 70 28 12.850 N 149 41 12.745 W -Circle (Radius: 100) -Plan hit target Plan Section Information b1D Incl Azim TVD +N/-S +E/-W DLS Build 't'urn 'I'FO Target ft deg deg ft ft ft deg/100ftdeg/100ftdeg/100ft deg 2652.00 20.99 284.90 2625.31 58.47 -219.73 0.00 0.00 0.00 0.00 2702.00 19.99 284.90 2672.14 62.96 -236.64 2.00 -2.00 0.00 180.00 3202.00 14.99 284.90 3148.89 101.58 -381.78 1.00 -1.00 0.00 180.00 3390.84 14.99 284.90 3331.30 114.14 -428.97 0.00 0.00 0.00 0.00 3808.02 14.99 284.90 3734.30 141.88 -533.22 0.00 0.00 0.00 0.00 4004.71 14.99 284.90 3924.30 154.96 -582.37 0.00 0.00 0.00 0.00 4239.19 14.99 284.90 4150.80 170.55 -640.96 0.00 0.00 0.00 0.00 Sperry-Sun • BP Planning Report Company: BP Amoco Date: 12!8!2006 Time: 10:43:45 Page: 2 Field: Mi lne Point Co-ordinate(NE) Refer ence: We ll: MPU-Liviano-0 1, True North Site: Mi lne Point Exploration Vertical (TV D) Refere nce: 20GL+34.30RK6 54 .3 Well: MPU-Livian o-01 Section (VS) Reference: We ll (O.OON,O.OOE,2 84.90Azi) Wellpath: Plan Liviano-0l Survey Calc ulation Method: Min imum Curvature Db: Oracle Sur~e~ MD loct Azim TVD Sys TVD VS ti/S E/W DLS MapN MapE Tool/Co n ft deg deg ft ft ft ft ft deg/100ft ft ft 2652.00 20.99 284.90 2625.31 2571.01 227.37 58.47 -219.73 0.00 6021612.31 538655.99 Start Dir 2 / 2700.00 20.03 284.90 2670.26 2615.96 244.19 62.79 -235.98 2.00 6021616.55 538639.72 MWD+IFR 2702.00 19.99 284.90 2672.14 2617.84 244.87 62.96 -236.64 2.00 6021616.72 538639.06 Start Dir 1 / 2800.00 19.01 284.90 2764.52 2710.22 277.58 71.37 -268.25 1.00 6021624.97 538607.41 MWD+IFR 2900.00 18.01 284.90 2859.35 2805.05 309.32 79.54 -298.92 1.00 6021632.97 538576.70 MWD+IFR 3000.00 17.01 284.90 2954.72 2900.42 339.40 87.27 -327.99 1.00 6021640.55 538547.59 MWD+IFR 3100.00 16.01 284.90 3050.60 2996.30 367.81 94.58 -355.44 1.00 6021647.71 538520.10 MWD+IFR 3200.00 15.01 284.90 3146.96 3092.66 394.55 101.45 -381.28 1.00 6021654.45 538494.23 MWD+IFR 3202.00 14.99 284.90 3148.89 3094.59 395.06 101.58 -381.78 1.00 6021654.58 538493.73 End Dir 3240.84 14.99 284.90 3186.41 3132.11 405.11 104.17 -391.49 0.00 6021657.11 538484.01 9 5/8" 3300.00 14.99 284.90 3243.55 3189.25 420.40 108.10 -406.27 0.00 6021660.97 538469.21 MWD+IFR 3390.84 14.99 284.90 3331.30 3277.00 443.89 114.14 -428.97 0.00 6021666.89 538446.48 Top Core 3400.00 14.99 284.90 3340.15 3285.85 446.26 114.75 -431.26 0.00 6021667.48 538444.19 MWD+IFR 3500.00 14.99 284.90 3436.75 3382.45 472.12 121.40 -456.25 0.00 6021674.00 538419.17 MWD+IFR 3600.00 14.99 284.90 3533.35 3479.05 497.98 128.05 -481.24 0.00 6021680.52 538394.15 MWD+iFR 3700.00 14.99 284.90 3629.95 3575.65 523.84 134.70 -506.22 0.00 6021687.04 538369.13 MWD+IFR 3700.36 14.99 284.90 3630.30 3576.00 523.93 134.72 -506.32 0.00 6021687.06 538369.04 TSBF 3800.00 14.99 284.90 3726.55 3672.25 549.70 141.35 -531.21 0.00 6021693.56 538344.11 MWD+IFR 3808.02 14.99 284.90 3734.30 3680.00 551.77 141.88 -533.22 0.00 6021694.08 538342.10 Liviano T1 3887.74 14.99 284.90 3811.30 3757.00 572.38 147.18 -553.14 0.00 6021699.27 538322.16 Top OA 3900.00 14.99 284.90 3823.15 3768.85 575.56 147.99 -556.20 0.00 6021700.07 538319.09 MWD+IFR 3992.29 14.99 284.90 3912.30 3858.00 599.42 154.13 -579.27 0.00 6021706.09 538295.99 Top OB 4000.00 14.99 284.90 3919.75 3865.45 601.41 154.64 -581.19 0.00 6021706.59 538294.07 MWD+IFR 4004.71 14.99 284.90 3924.30 3870.00 602.63 154.96 -582.37 0.00 6021706.90 538292.89 MWD+IFR 4100.00 14.99 284.90 4016.34 3962.04 627.27 161.29 -606.18 0.00 6021713.11 538269.04 MWD+IFR 4200.00 14.99 284.90 4112.94 4058.64 653.13 167.94 -631.17 0.00 6021719.63 538244.02 MWD+IFR 4239.19 14.99 284.90 4150.80 4096.50 663.26 170.55 -640.96 0.00 6021722.18 538234.22 Total Dept nent Nume MPU-Liviam0l wELL DETAILS +N/S +g/-W NrMldng Pxaing Latitude Langlrude Slat -2379.72 -170453 !021555.(X1 538R'16.(Nl 70"28'11.455N 149°4057.070W WA ANTI-COLLISION SETTINGS Interpolation Method:MD Interval: SQOU Dcpth Range Fiom: 26$2.00 To: 4239.19 Maximum Range: 620.49 Reference: Plari: Plan Liviano-01 Wp 4 COMPANY Dsrnas BP Amaco Gah+dation Mcthud: Mirtiunw Curvaturo Error system: ISCWSA Scan MethoJ~ 'I'rcv Cylinder Noah Ertor Surface: Elliptical+Caaing Warning McNal: Rules Baeed suevev PROGRAM Dcpth Pm Depth To Survey/Phm Tarl 2652.0(1 4239.19 Platakd: Plan Livuno-0I Wp4 MWD+IFR+MS WELLPATH DETAILS 16O - From Colour To MD Plan Llvlnm+01 15O 2652 6000 Parem Wcllpntht Plan Livinm-01 PB7 Tkon MD' 2652.00 6000 62SO 33 0 6250 °°°~°°°° 6500 Ref. Datum' 206E+34.30RI03 54.30fl 6500 67SO '""'°"`"" """" 6750 7000 v.sectian Origin Origin starting Mgle +N/-5 -F/-W Pmm TVD [ 12 7000 7250 00 0 00 34 30 284 9(1" 0 7 ~ "_ 7250 7500 . . . . 7500 7750 7750 8000 p BOOO """" 82SO LEGEND Liviam*01 PBI) NOF RRORS U M (Pl 1 OO C 8250 8500 , . LL1d~ an PIa~ .~ ,~ 8500 - ------- 8750 "~ 9000 .~ .... ~ 8750 9000 92so - Plno Liviann-nl wpa a 30 0 75 `' 0 a ars - ,..~ ~~ ~~ ' 0 270 90 5 ~~ 0 75 ~ - / 100 240 \ ~ / 120 Pre Plans Re moved. See AC Scan for Plans Pa rents Profile @ No Errors 125 SECTION DETAILS Sx MD Inc Azi TVD +N/-S +PJ-W DLeg TFaea VSec Target 21 50 I 2652(1(1 20.99 2 270200 19 99 2ga_9a 262531 90 2672.14 284 58.47 -219.73 000 0-00 227.77 (2.96 -236.64 2.00 18000 244.87 150 ` .. . 3 3202.!1!1 14.99 4 319(1.84 14.99 5 3808.02 14.99 . 264.90 3148.R9 284.90 3331.30 284.9(1 373430 10158 -381.78 100 180.1X1 395.06 114.14 -028.97 000 R(la 447.89 141 NA -531.22 0.00 0.00 551.77 8 3 0 00 O O I 602 63 160 1 ~ 6 4004.71 14.99 7 4?39.19 14.99 284.9(1 392430 284.90 4150.80 I549fi -5 7 . . I . 2. 17055 -64096 00(1 01X1 6631fi Trarcllin~~ C~linrlcL :Aiimuilt (TFO-i-~\T1) [d eg] vs Centre To Centre Separatirln ~ ~Uft/in] Sperry-Sun Anticollision Report Company: BP Amoco Date: 12/8/2006 Time: 10:40:01 Page: 1 Field: Milne Point Reference Site: Milne Point Exploration Co-ordinat e(NE) Re ference: Well: MPU -Liviano-01, True North Reference We11: MPU-Liviano-01 Vertical (T VD) Refe rence: 20GL+34. 30RKB 54. 3 Reference WellpatfP.lan Liviano-01 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Meth odMD Interval: 50.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 2652.00 to 4239.19 ft Scan Method: Trav Cylinder North Maximum Radius: 620.49 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/6/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 54.30 1180.00 Planned: Liviano-01 Location1 wp06 V22 (0~B-GYRO-SS Camera based gyro single shots 1180.00 2652.00 Planned: Liviano- 01 Locati on1 wp0 6 V22 (O~IWD+IFR+MS MWD +IFR + Multi Station 2652.00 4239.19 Planned: Plan Livi ano-01 Wp 4 V15 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3240.84 3186.41 9.625 12.250 9 5/8" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-C'tr No-Go Allowabl e Site Well Wellpath MD MD DistanceArca Deviatio n Warning ft ft ft ft ft Milne Point Explorat MPU-Liviano-01 Plan Liviano-01 P61 V1 2700.00 2700.00 0.40 0.80 -0.40 FAIL: NOERRORS Site: Milne Point Exploration Well: MPU-Liv iano-01 Rule Assigned: NOERRORS Wellpath: Plan Liviano-01 P61 V1 Plan: Liviano-01 Location1 Inter-Site Error: 0.00 ft Reference Offset Scmi-Major Axis Ctr-Ctr No-Go Allowabl e MD TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/ HBistanccArca Deviatio n Warning ft ft ft ft ft ft deg deg in ft ft ft 2700.00 2670.26 2700.00 2670.12 3.06 3.10 284.90 0.00 7.000 0.40 0.80 -0.40 FAIL 2749.98 2717.30 2750.00 2716.81 3.09 3.20 284.90 0.00 7.000 1.47 0.80 0.67 Pass 2799.93 2764.46 2800.00 2763.49 3.11 3.29 284.90 0.00 7.000 2.98 0.80 2.18 Pass 2849.86 2811.73 2850.00 2810.14 3.14 3.39 284.88 -0.02 7.000 5.03 0.80 4.23 Pass 2899.69 2859.06 2900.00 2856.51 3.17 3.49 284.79 -0.11 7.000 8.26 0.80 7.46 Pass 2949.40 2906.39 2950.00 2902.54 3.21 3.61 284.70 -0.20 7.000 12.80 0.80 12.00 Pass 2998.92 2953.68 3000.00 2948.23 3.24 3.72 284.64 -0.26 7.000 18.64 0.80 17.83 Pass 3048.22 3000.88 3050.00 2993.56 3.28 3.85 284.58 -0.32 7.000 25.76 0.80 24.96 Pass 3097.25 3047.95 3100.00 3038.51 3.32 3.98 284.54 -0.36 7.000 34.18 0.80 33.37 Pass 3145.98 3094.85 3150.00 3083.12 3.37 4.11 284.51 -0.39 7.000 43.78 0.80 42.97 Pass 3194.53 3141.67 3200.00 3127.66 3.41 4.25 284.50 -0.40 7.000 53.92 0.80 53.11 Pass 3243.37 3188.85 3250.00 3172.21 3.44 4.39 284.48 -0.42 7.000 64.32 0.80 63.52 Pass 3292.27 3236.09 3300.00 3216.76 3.46 4.54 284.48 -0.42 7.000 74.73 0.80 73.93 Pass 3341.17 3283.33 3350.00 3261.31 3.47 4.68 284.47 -0.43 7.000 85.14 0.80 84.34 Pass 3390.08 3330.57 3400.00 3305.86 3.48 4.83 284.47 -0.43 7.000 95.55 0.80 94.75 Pass 3438.99 3377.82 3450.00 3350.43 3.49 4.96 284.46 -0.44 7.000 105.93 0.80 105.12 Pass 3488.03 3425.19 3500.00 3395.28 3.50 5.03 284.46 -0.44 7.000 115.67 0.80 114.87 Pass 3537.23 3472.72 3550.00 3440.51 3.51 5.03 284.45 -0.45 7.000 124.56 0.80 123.76 Pass 3586.58 3520.39 3600.00 3486.10 3.53 5.03 284.45 -0.45 7.000 132.59 0.80 131.79 Pass 3636.07 3568.19 3650.00 3532.05 3.55 5.03 284.44 -0.46 7.000 139.76 0.80 138.96 Pass 3685.67 3616.10 3700.00 3578.33 3.58 5.04 284.43 -0.47 7.000 146.07 0.80 145.26 Pass 3735.37 3664.12 3750.00 3624.94 3.60 5.04 284.43 -0.47 7.000 151.50 0.80 150.70 Pass 3785.16 3712.21 3800.00 3671.86 3.63 5.05 284.42 -0.48 7.000 156.07 0.80 155.27 Pass 3835.02 3760.38 3850.00 3719.07 3.67 5.06 284.41 -0.49 7.000 159.77 0.80 158.97 Pass 3884.94 3808.60 3900.00 3766.56 3.70 5.06 284.40 -0.50 7.000 162.60 0.80 161.79 Pass 3934.90 3856.86 3950.00 3814.30 3.74 5.08 284.38 -0.52 7.000 164.58 0.80 163.78 Pass 3984.87 3905.13 4000.00 3862.12 3.78 5.14 284.37 -0.53 7.000 166.34 0.80 165.54 Pass ... ;, a ~o m N "' o ° "' O ~ ~ r ,, ---. .7 m F ~ O .9 - 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Point Field: Milne Point North Slope UNITED STATES Map Systerrl~S State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumiJAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: Milne Point Exploration Site Position: Northing: 6023901.50 ft Latitude: 70 28 34.467 N From: Map Fasting: 540167.75 ft Longitude: 149 40 18.722 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.31 deg Well: MPU-Liviano-01 Slot Name: Well Position: +N/-S -2339.72 ft Northing: 6021555.00 ft Latitude: 70 28 11.455 N +E/-W-1304.53 ft Fasting : 538876.00 ft Longitude: 149 40 57.070 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Na me ft ft in in 2626.29 2601.30 13.375 17.500 13 3/8" 4299.02 4148.07 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 3445.38 3346.30 MA 0.00 0.00 3936.40 3801.30 Top Schrader OA 0.00 0.00 4049.34 3909.30 Base Schrader OB 0.00 0.00 Targets Map Map <____ Latitude ----> <_-- Longitude --- Name Description TVD +N!-S +El-W Northing Fasting Deg Alin Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Liviano T1 Rev 1 3801.30 188.75 -715.09 6021740.00 538160.00 70 28 13.311 N 149 41 18.092 W -Circle (Radius: 100) -Plan hit target Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn `I'FO Target ft deg deg ft ft ft deg/100ftdeg/100ftdeg/100ft deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 .1300.00 0.00 0.00 1300.00 0.00 0.00 0.00 0.00 0.00 0.00 1801.44 7.52 284.90 1800.00 8.45 -31.76 1.50 1.50 0.00 284.90 1952.74 7.52 284.90 1950.00 13.54 -50.90 0.00 0.00 0.00 0.00 2625.97 20.99 284.90 2601.00 56.07 -210.72 2.00 2.00 0.00 0.00 2825.97 20.99 284.90 2787.73 74.49 -279.94 0.00 0.00 0.00 0.00 3126.81 27.00 284.69 3062.45 105.68 -398.17 2.00 2.00 -0.07 -0.93 3436.29 27.00 284.69 3338.19 141.30 -534.09 0.00 0.00 0.00 0.00 3936.40 17.00 284.70 3801.30 188.75 -715.09 2.00 -2.00 0.00 179.97 Liviano T1 Rev 1 4049.02 17.00 284.70 3909.00 197.11 -746.94 0.00 0.00 0.00 0.00 .4299.02 17.00 284.70 4148.08 215.66 -817.64 0.00 0.00 0.00 0.00 Sperry-Sun BP Planning Report Company: BP Amoco Date: 12!8/2006 Time: 10:3723 Page: 2 Field: Mil ne Point Co-ordinute( NE) Refer ence: We ll: MPU-Liviano-01, True North Site: Mil ne Point Exploration Vertical (T~'D) Referen ce: 20GL+34.30RK6 54 .3 Well: MP U-Liviano-01 Section (YS) Reference: We ll (O.OON,O.OOE,2 84.78Azi) Wellpath: Pla n Liviano -01 PB1 Survey Calcu lation Method: Min imum Curvature Db: Oracle Surveil A1D Inc! Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 34.30 0.00 0.00 34.30 -20.00 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 100.00 0.00 0.00 100.00 45.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 200.00 0.00 0.00 200.00 145.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 300.00 0.00 0.00 300.00 245.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 400.00 0.00 0.00 400.00 345.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 500.00 0.00 0.00 500.00 445.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 600.00 0.00 0.00 600.00 545.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 700.00 0.00 0.00 700.00 645.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 800.00 0.00 0.00 800.00 745.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 900.00 0.00 0.00 900.00 845.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 1000.00 0.00 0.00 1000.00 945.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 1100.00 0.00 0.00 1100.00 1045.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 CB-GYRO 1200.00 0.00 0.00 1200.00 1145.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 MWD+IFR 1300.00 0.00 0.00 1300.00 1245.70 0.00 0.00 0.00 0.00 6021555.00 538876.00 Start Dir 1. 1400.00 1.50 284.90 1399.99 1345.69 1.31 0.34 -1.26 1.50 6021555.33 538874.73 MWD+IFR 1500.00 3.00 284.90 1499.91 1445.61 5.23 1.35 -5.06 1.50 6021556.32 538870.93 MWD+IFR 1600.00 4.50 284.90 1599.69 1545.39 11.77 3.03 -11.38 1.50 6021557.97 538864.61 MWD+IFR 1700.00 6.00 284.90 1699.27 1644.97 20.92 5.38 -20.22 1.50 6021560.27 538855.75 MWD+IFR 1800.00 7.50 284.90 1798.57 1744.27 32.68 8.40 -31.58 1.50 6021563.24 538844.38 MWD+IFR 1801.44 7.52 284.90 1800.00 1745.70 32.87 8.45 -31.76 1.50 6021563.28 538844.20 End Dir : 1 1900.00 7.52 284.90 1897.71 1843.41 45.77 11.77 -44.23 0.00 6021566.54 538831.71 MWD+IFR 1952.74 7.52 284.90 1950.00 1895.70 52.67 13.54 -50.90 0.00 6021568.28 538825.03 Start Dir 2 / 2000.00 8.47 284.90 1996.80 1942.50 59.24 15.23 -57.25 2.00 6021569.93 `538818.67 MWD+IFR 2100.00 10.47 284.90 2095.43 2041.13 75.69 19.46 -73.15 2.00 6021574.08 538802.76 MWD+IFR 2200.00 12.47 284.90 2193.43 2139.13 95.57 24.57 -92.36 2.00 6021579.09 538783.53 MWD+IFR 2300.00 14.47 284.90 2290.68 2236.38 118.86 30.56 -114.86 2.00 6021584.96 538760.99 MWD+IFR 2400.00 16.47 284.90 2387.05 2332.75 145.52 37.42 -140.63 2.00 6021591.68 538735.19 MWD+IFR 2500.00 18.47 284.90 2482.43 2428.13 175.54 45.14 -169.63 2.00 6021599.25 538706.15 MWD+IFR 2600.00 20.47 284.90 2576.71 2522.41 208.86 53.71 -201.84 2.00 6021607.65 538673.90 MWD+IFR 2625.97 20.99 284.90 2601.00 2546.70 218.05 56.07 -210.72 2.00 6021609.96 538665.01 End Dir 2626.29 20.99 284.90 2601.30 2547.00 218.17 56.10 -210.83 0.00 6021609.99 538664.90 13 3/8" 2700.00 20.99 284.90 2670.12 2615.82 244.56 62.89 -236.34 0.00 6021616.64 538639.36 MWD+IFR 2800.00 20.99 284.90 2763.49 2709.19 280.38 72.09 -270.95 0.00 6021625.67 538604.70 MWD+IFR 2825.97 20.99 284.90 2787.73 2733.43 289.68 74.49 -279.94 0.00 6021628.02 538595.70 Start Dir 2 / 2900.00 22.47 284.84 2856.51 2802.21 317.08 81.52 -306.43 2.00 6021634.91 538569.18 MWD+IFR 3000.00 24.47 284.76 2948.23 2893.93 356.90 91.69 -344.92 2.00 6021644.88 538530.64 MWD+IFR 3100.00 26.47 284.70 3038.51 2984.21 399.90 102.62 -386.51 2.00 6021655.59 538489.00 MWD+IFR 3126.81 27.00 284.69 3062.45 3008.15 411.96 105.68 -398.17 2.00 6021658.59 538477.32 End Dir 1 3200.00 27.00 284.69 3127.66 3073.36 445.19 114.10 -430.32 0.00 6021666.84 538445.13 MWD+IFR 3300.00 27.00 284.69 3216.76 3162.46 490.59 125.61 -474.24 0.00 6021678.12 538401.16 MWD+IFR 3400.00 27.00 284.69 3305.86 3251.56 535.99 137.12 -518.16 0.00 6021689.40 538357.19 MWD+IFR 3436.29 27.00 284.69 3338.19 3283.89 552.47 141.30 -534.09 0.00 6021693.50 538341.23 Start Dir 2 / 3445.38 26.82 284.69 3346.30 3292.00 556.58 142.34 -538.07 2.00 6021694.52 538337.24 MA 3500.00 25.73 284.69 3395.28 3340.98 580.76 148.47 -561.46 2.00 6021700.53 538313.82 MWD+IFR 3600.00 23.73 284.69 3486.10 3431.80 622.59 159.08 -601.93 2.00 6021710.92 538273.31 MWD+IFR 3700.00 21.73 284.69 3578.33 3524.03 661.23 168.88 -639.30 2.00 6021720.52 538235.89 MWD+IFR 3800.00 19.73 284.69 3671.86 3617.56 696.62 177.85 -673.53 2.00 6021729.32 538201.62 MWD+IFR 3900.00 17.73 284.70 3766.56 3712.26 728.72 186.00 -704.59 2.00 6021737.30 538170.52 MWD+IFR 3936.40 17.00 284.70 3801.30 3747.00 739.59 188.75 -715.09 2.00 6021740.00 538160.00 Liviano T1 4000.00 17.00 284.70 3862.12 3807.82 758.18 193.47 -733.08 0.00 6021744.62 538141.99 MWD+IFR 4049.02 17.00 284.70 3909.00 3854.70 772.51 197.11 -746.94 0.00 6021748.19 538128.11 MWD+IFR 4049.34 17.00 284.70 3909.30 3855.00 772.61 197.13 -747.03 0.00 6021748.21 538128.02 Base Schr 4100.00 17.00 284.70 3957.75 3903.45 787.42 200.89 -761.36 0.00 6021751.89 538113.68 MWD+IFR ment S S S S ~5 S S ~6 S S S S S ev S S ler O S Sperry-Sun BP Planning Report Company: BP Amoco Date: 12/8/2006 Time: 10:37:23 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: MPU-Liviano-01, True North Site: Milne Point Exploration Vertical (TVD) Reference: 20GL+34.30RKB 54.3 Well: MPU-Liviano-01 Section (VS) Reference: Well (O.OON,O.OOE,284.78Azi) Wellpath: Plan Liviano-01 PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Sun~ev M1fD Incl Azim TVD Sys TVD VS N/S ElW DLS MapN MapE Tool/Co n ft deg deg ft ft ft ft ft deg/100ft ft ft 4200.00 17.00 284.70 4053.38 3999.08 816.66 208.31 -789.64 0.00 6021759.16 538085.36 MWD+IFR 4299.02 17.00 284.70 4148.08 4093.78 845.61 215.66 -817.64 0.00 6021766.36 538057.32 7" nent Neme MPU-Liviaru>•01 WELL DETAILS +W-g +FJ_W NnMing Eas9mg LalituJe Longitude Slot I -2119.72 -1304.53 (r021S55 (10 53X876 fNl 70"2R'I1.4SSN 149"40'S].070W N/A D ANTI-COLLISION SETTINGS olation Method:MD Interval: 50.00 p[h Range From: 34.30 To: 4299.02 ximum Range: 626.47 Reference: Plan: LIVIanO-0I LUCationl wpO6 COMPANY DETAILS BP Amoco Culculalion MethuJ; MiNmum Curvatum Ertor Symem: ISCWSA Scan Method: Trav Cylinler NnrO~ rrtor Surface: Elliptical+Cxving blaming MethoJ: Rules BmeJ SURVBY PROGRAM Depth Pm Depth To Survey/Plm 34.70 1125.70 PlanneJ: Livialxr-07 Location) 712570 4299.02 Planned: Liviam411 Lcea0onl Tool CB-GYRO-SS MWD+IPR+MS WGLLPATH DETAILS 16O From Colour To MD Pw,u"iatu.m PBl 15O 34 6000 ~g° R f D 1 m: 206 E+143nRRB 54.308 ~ 6000 6250 33 /`/ 0 62.50 ~ 6500 _ ~ 6500 6750 ~S tinn Angk 2807X" on~n +N/S o al ~;an 3Wrting +E/-W Pmm TVD ocxl s43o 125 / _ 6750 7000 ~"`^~.~ 7250 '--' 7000 7250 ----'- 7500 . `\ 7500 7750 7750 8000 8000 8250 LEG END lOO 8250 8500 -' Plan Liv~enn411 --W uv~anonl Locu PBI tion) wpm 8500 8750 75 / / 3O 8750 O 9000 9000 9250 0 5 0 270 90 5 \ ..~ 0 / 75 \ 240 ' ` ., / 120 100 Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors 125 ..~ SECTION DETAILS Sec MD Bw A~i TVD +N/-S +E/-W DLeg Th'ace VSec Targcl 21 50 1 3430 000 0.00 34.30 O.INI 2 1300.00 0.00 0.00 110800 II00 0.1X1 0.00 000 0.110 000 0.110 0.00 0.!10 150 •~•~,~"~ ~r ] 1801.44 7.5 4 1952.74 7.5 2 284.90 18011.00 8.45 2 28490 1950.181 13.54 -31.76 I.SO -50.90 0.11[1 284.9(1 (1.011 12.87 52.67 1 60 - ~ 5 2625.97 20.99 284.90 2601 Oft 56.07 6 2825.9] 20.99 28490 278771 74.49 ] 3126.81 2700 284.69 3062.45 105.68 -2I0,~2 2011 -279.94 0.011 -398.17 2.(NI 0.110 0.00 -091 218.05 269.68 41196 1 OO 0 8 30.3629 ?700 284,69 7738.19 141.30 9 3936.40 I].(Nl 28470 1811130 IRR.75 10 4M9.02 17.00 284.70 39119.(X1 197.11 _.. II 429902 1700 284.70 4148.08 215.66 -574.119 0.00 -715.03 2.00 -746.94 0.00 -RI7.64 11.00 0.11!1 17997 0.00 0.00 SS247 '73959 LivUuw Tl Rev l 772.51 845.61 ~ ra~~cllin~ Cylinder Azimuth (TFO-i ~V_11 ~~ IL; . , ic~~ vs C~ntrc to C~nn~ Separation [SOft/in] Sperry-Sun Anticollision Report Company: BP Amoco Date: 12/8/2006 Time: 10:33:36 Page: ] Field: Milne Point Reference Site: Milne Point Exploration Co-ordinat e(NE) Re ference: Well: MPU-Liviano-0 1, True North Reference Well: MPU-Liviano-01 Vertical (T VD) Refe rence: 20GL+34. 30RKB 54. 3 Reference WellpatlPJan Liviano-01 P61 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan 8~ PLANNED PROGRAM Interpolat ion Meth odMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.30 to 4299.02 ft Scan Method: Trav Cylinder North Maximum Radius: 626.47 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/6/2006 Validated: No Version: 1 Planned F rom To Survey Toolcode Tool Name ft ft 34.30 1125.70 Planned: Liviano-01 Location1 wp06 V22 CB-GYRO-SS Camera based gyro single shots 1125.70 4299.02 Planned: Liviano-01 Locati on/ wp06 V22 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD ~I`VD Diameter Hol e Size Name ft ft in in 2626.29 2601.30 13.375 17.500 13 3/8" 4299.02 4148.07 7.000 8. 500 7" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Cfr-Ctr No-Go Allowabl e Site Well Wellpath MD MD Distance Area Deviation Warning ft tt ft ft ft Milne Point Explorat MPU-Liviano-01 Plan Liviano-01 VO Pla 2450.00 2450.00 0.00 1.13 -1.13 FAIL: NOERRORS Site: Milne Point Exploration Well: MPU-Livi ano-01 Rule Assi gned: NOERRORS Wellpath: Plan Liviano-01 VO Plan: Plan Li viano-01 Wp 4 V15 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowahl e MD ['VD MD TVll Ref Offset TFO+A ZI TFO-HS Casing/ HBistanceArea Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 34.30 34.30 34.30 34.30 0.00 0.00 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 50.00 50.00 50.00 50.00 0.04 0.04 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 100.00 100.00 100.00 100.00 0.15 0.15 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 150.00 150.00 150.00 150.00 0.32 0.32 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 200.00 200.00 200.00 200.00 0.50 0.50 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 250.00 250.00 250.00 250.00 0.61 0.61 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 300.00 300.00 300.00 300.00 0.72 0.72 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 350.00 350.00 350.00 350.00 0.81 0.81 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 400.00 400.00 400.00 400.00 0.91 0.91 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 450.00 450.00 450.00 450.00 1.00 1.00 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 500.00 500.00 500.00 500.00 1.08 1.08 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 550.00 550.00 550.00 550.00 1.17 1.17 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 600.00 600.00 600.00 600.00 1.25 1.25 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 650.00 650.00 650.00 650.00 1.33 1.33 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 700.00 700.00 700.00 700.00 1.42 1.42 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 750.00 750.00 750.00 750.00 1.49 1.49 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 800.00 800.00 800.00 800.00 1.57 1.57 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 850.00 850.00 850.00 850.00 1.65 1.65 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 900.00 900.00 900.00 900.00 1.73 1.73 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 950.00 950.00 950.00 950.00 1.81 1.81 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1000.00 1000.00 1000.00 1000.00 1.89 1.89 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1050.00 1050.00 1050.00 1050.00 1.96 1.96 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1100.00 1100.00 1100.00 1100.00 2.04 2.04 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1150.00 1150.00 1150.00 1150.00 2.07 2.07 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1200.00 1200.00 1200.00 1200.00 2.11 2.11 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1250.00 1250.00 1250.00 1250.00 2.11 2.11 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL 1300.00 1300.00 1300.00 1300.00 2.11 2.11 0.00 0.00 9.625 0.00 1.13 -1.13 FAIL RE: Liviano-O1 • Subject: RE: Liviano-O1 From: "Rose, John G (FAIRWEATHER)" ~John.G.Rose@bp.com> Date: Fri, 02 Feb' 2007 10:16:41 -0900 To: Thomas Maunder °~'tom maunder(~i'~admin.state.ak.us- CC: "ftara, Daunv ~I~" ~~~Dannv.Kara~u~~.bp.com=> Tom, See response to your questions/comments below and thanks for you help. -jr John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Cell 907/748-5223 Fax 907/564-4040 -----Original Message----- From: Thomas Maunder [mailto:tom maiznder:~?admin.st;ate.ak.us] Sent: Friday, February 02, 2007 9:26 AM To: Rose, John G (FAIRWEATHER) Subject: Re: Liviano-O1 John, I am further reviewing the application and have the following questions. 1. In the cementing section (page 4) it is stated that the target TOC for the 7" is 200' (2826' md) below the surface casing shoe. In the procedure (page 6) step 9 says 200' above the MA sands (3245' md). Could you reconcile these numbers? * THE PLANNED TOP OF CEMENT WILL BE 200' BELOW THE SHOE AT 2826' MD 2. With regard to the P&A of the cased hole leg, when the time comes the actual depths should be communicated to me so I can advise the Inspectors. I will recommend that submitting a 403 not be required. Please note that I don't know if this recommendation will be accepted. OK. 3. The Inspector should be notified for an opportunity to witness the setting of the shallow retainer. OK. 4. Prior to drilling off the cement plug to sidetrack for the cored section, the casing should be pressure tested. OK 5. Since the abandonment of the cored penetration will result in .cutoff, etc, this activity will need a sundry.. OK Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 1/31/2007 4:25 PM: John, Steve Davies and I have talked further on the naming of the "legs". While the initial penetration will be abandoned, casing will be set and perforations shot to recover formation fluids. Even with the produced volume being small, the well will have been completed. Further, the installed casing will be cut and pulled with the original penetration being abandoned. All of this activity goes well beyond what we consider a plug back. That said, the activities through step 1 of 2 2/2/2007 10:29 AM RE: Liviano-O1 • r 17 would be considered on the 1st penetration. The remaining activities would be covered on another permit with the name Liviano-OlA. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 2/2/2007 10:29 AM EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 ~ s 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000'. • 'f ~ ~ ~ G~~~;~- ~ s ~ ~ ~ SC~c.~'b ~~ ~~ , , ~_ ~ ~ `~C~~~~ (~~ ~ r ~?~- ~ a-S ~ C~ ~~C9-~~ (~ v.~ ~ ~ ~ ~ ~, r- C ~~ S ~~ ~ ~ ~~ ~. ~~C~- C~-.SC~ ~~C~ c ~ Cam. ~~~ ~~ ~ ~ ~ cam, .~,~~ ~. T ~ ~~ ~~ ~ 1 of 1 ~ ~~CC~ C~y, ~..C~ ~ ~` '~- Fri '~i.3 ~ A \ ~CC- `~~~~~ .~ ,~`~SS o ~~ /2007 9:04 AM ~. Sondra D. Stewman BP Exploration AK INC. PO Box 196612 MB 7-5 Anchorage, AK 99519-6612 PAY TO THE ORDER OF 89-6/1252 1] "Maste'rcard Check" DATE. / l-Z~ o~t . ~ ~t~o _ ~ DOLLARS First National Bank~4t~ska Anch~ora~ge~, AjK~99501 MEMO T ' \ C" ~~ -~L~ t~ I~~' ~:L25200060~:99~46227L564~~• Oi55 • TRANSMITTAL LETTER CHECKLIST WELL NAME _~/~~~~ ~ / //Q, `2~ PTD# ~ 7^ d lY Development Service / Exploratory Stratigraphic Test Non-Conventional Well ~~~` ~ ~~~` Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing wel l (If last two digits in permit No. API No. 50- - - API number are , ~ ' between 60-69) (Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent ~ upon issuance of a conservation order approving a spacing ~ exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed f Well for (name of well} until after (Company NameZhas designed and ~ implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25/06 C:~j ody\transmittal_checklist Administration 1 Permit_feeattached- .. Yes - - . 2 Lease number appropriate, - . Yes Entire well within ADL 025514 3 Unrquewell_nameandnumb_er___,-____ _-- ____- _-___--__--_ Yes--_ ___------------------_ ----- - - - 4 Well loczt_ed in a_d_efined.pool- - , - Yes - - - . MPU Ugnu Undefned Oil Pool delineation well, but MPU Schrader_Bluff Oil_Pool will be lagged & tested: MI5 Well located proper distance_from drilling unit_boundary- - - eS i,6 Well located proper distance from other wells. _ Yes _ - - - - - .Nearest well, MPU M-1, is about 112 mile away, _ - '7 Sufficient acreage available in_drilling unit--- - - - - - - - - - - - Yes '~8 If deviated, is-wellbore plat.included Yes '9 Operatoronlyaffectedparty_____________________-_________----,.. Yes-_-. _-Welllies_w_ithinboundariesof,MPU._.________-_-___-_-__, -_-- -_-______ __ -_--_ 10 Operatorhas-appropriate-bondi_n force_________________________________ Yes____ __-..._ 111 Permit can pe issued without conservation grder_ _ Yes Appr Date i 12 Permit can be issued without administrative_approval _ - .. --------------- Yes _ _ _ - . - - . - - - - SFD 1!30!2007 '13 ~' Can permit be approved before l5-daywait__________________ Yes-___ ___ ___ _______ __ ___ -__ _-- ,--- ',14 Well located within area andstrata authorized by Injection Order # (put_IO# in_comments}-(For_ NA_ - . - - . . 115 All wells_within 1/4_mile area-of review identified (For service well only) NA_ - _ - - . . '16 Pre-produced injector duration-of pre production Less than 3 months. (For service well only) NA_ '17 Nonconven, gas conforms to AS31,05,030([.1.A),(j.2.A-D) _ . - - - - - - - NA_ Engineering ',18 Conductorstring_provided _ - .. Yes 119 Surface casing-protects all known USDWs - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ... - - -Surface casing set at 2626' Ml) and cemented to surface will protect any potential_shallow aquifers, SFD _ - - - _ - 20 CMT_voladequate_to circul_ale_on conductor_& surf-csg _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ - _ _ _ _Altaquifers exempted, 40 CFR 147.102_(b)(3)._ _ _ 21 CMT vol. adequate.tgtie-in long string to surf csg. - . - - - - - . - - - No_ - All hydrocarbons will be covered, Plan to cut and-pull 7"-for sidetrack._ 22 CMT will cover all known_productiye horizons_ - . - _ _ Yes - - . - _ _ 23 Casing designs adequate f_or C, T, B &. pe[ma-frost. - Yes . - - - - - - - ~24 Adequate tankage,or reserve pit Yes . - _ - -Rig is equipped with steel_pits. No reserve.pitplanned: All waste to approved disposal well(s). _ ~25 If_a_re-drill, has_a_ 1.0-403 for abandonment been approved - , _ _ _ _ _ _ _ _ _ _ tJA_ - _ _ 26 Adequate wellbore separationproposed________ ___________________ Yes-- No proximate wellbores.___-_.----..-.--.____-__--_-.- .---._---_-,-__--. , 27 If diverter required, does it meet. regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ . _ - Appr Date 28 Drilling fluid-program sehematic_& equip list adequate. _ Yes Maximum expected formation pressure 8,7-EMW, PI_anned MW up to-9.4 ppg, _ TEM 2!2!2007 29 BOPEs, do they meet_regulation - - - Yes - . - - - - - 30 BOPEpressratingappropriate;testko-(putpsigincomments)_______________ ____ Yes-__ _--MASPcalculatedat 1359 psi, 3500.psi,-.-_,_______________.----_-__________ __ - 31 Choke-manifgld compliesw/APtRP-53 (May 84) Yes - - - ~ 32 w'orkwilloccurwithoutoperationshutdown_____________________ Yes____ ______._----_------__ X 33 Is presence_of H2S gas probable.. - _ No- - - - - H2S is not_reported in SBlUgnu production. ', 34 Mechanical-condition of wells within AOR verified (FOr_service well only) - . NA_ -- Geology i 35 Permit_can be issued w!o hydrogensul_fidemeosures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - ---- - - - -Nearest pads produce 2_ppm_H2S-or less. - . - - - - _ _ - _ - _ - _ _ _ _ _ _ - _ - - - - - - . - _ , _ - _ _ _ - - - ~ 36 Data_presented on_pote_ntial overpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - _ _ _ Expected pressure is 8.4 through Ugnuand up to 8:7_in Schrader Bluff.- _ - _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ _ _ _ _ Appr Date X 37 Seismic analysis-of shallow gas zones. _ - _ - - - - - - - - - -- - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ Will be drilled and cored_with 8,8-9.4 water-based_and oil based mud. Noseis analysis required, many offsets.- - _ SFD 113012007 38 Seabed condition surve rf off-shore - y( ) NA- . - - Gas h grates ma be encountered at base_of ermafrost; mitt ation measures discussed in_Drillin Hazards Y Y- P 9 9-- 39 Contact namelphone for weekly_progress reports [exploratory only] - - _ - - , Yes seckion: Uontact Dan Kara 564-5667_ - - - - - - - - - - - - - Geologic Engineering Delineation well for U nu Undefined Oil Pool and Schrader Bluff Oil Pool under AOGCC re s delineation wells are classified Commissioner: Date: Commissioner Date mi r Date 9 ( g as Exploratory wells). Operator plans to mud log the well and catch samples. ~- •-