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206-033
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/23/2023 To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: MT ELBERT-01 PTD: 206-033 API: 50-029-23302-00-00 Line Scan Images of Mt. Elbert Cores (December 5-10, 2007) *** Please see the Core Imaging Notes.rtf document describing the core imaging and handling process. SFTP Transfer – Main Folder: MTELBERT-01_GEOSCAN_CORE_IMAGES Please include current contact information if different from above. PTD: 206-033 T38094 10/24/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.24 10:19:10 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/19/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL : WELL: MT ELBERT-01 PTD: 206-033 API: 50-029-23302-00-00 113 Total Mt Elbert 1 Core Image Files (JPG Format) Each jpg image is named as shown in this example: x Each core box was captured in two images – the first is the lower ~half box and the second is the upper ~half box. x ME04-7-8-C_a = Mt. Elbert core intervals 4-7, 4-8, and 4-CC, lower half box x ME04-7-8-C_b = Mt. Elbert core intervals 4-7, 4-8, and 4-CC, upper half box SFTP Transfer – Main Folder: x MTELBERT-01_SLABBED_CORE_PHOTOS Please include current contact information if different from above. PTD: 206-033 T38003 9/20/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.20 09:48:31 -08'00' 2O( 7- O3S • • 2_1214cl bp Date:06/03/2016 Transmittal Number: 93508 RECEIVED BPXA WELL DATA TRANSMITTALJUN ® 6 2016 Enclosed are the materials listed below. AOGCC If you have any questions, please contact Merion Kendall at the PDC: 907-564-5216; merion.kendall@bp.com; gancpdc@bp.com or Joe Lastufka 564-4091. SW Name API Date Company Description Mud Log Data February • Paper Log MT ELBERT-01 50-029-23302-00 2007 BPXA • CD Please Sign an. Return one co.y of this transmittal to gancpdc@bp.com Thank You, it/tenon xenda(l Petrotechnical Data Center SC.1KV Attn: State of Alaska - AOGCC Attn: Meredith Guhl 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99507 Petrotechnical Data Center LR2-1 900 E. Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 ,~.-, ~~ ~~ ~. .. ~~~ _ ~ ~~ ~ . ~. ~ ~.' ~ ~: i 3 '~ . [ i~ . ~.n MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS.PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ • bp , ~~NFI ~ I~L ; t , ~ ~ ~ ~~, ~ r.u .a ~kl R ~ ~ ~W k~'*a..~ _• August 24th, 2009 ~~~, ~ ~ ~~~~ Attn; Alaska Oil and Gas Conservation Commission ~~k~~~~ ~'"" ~` ~~~ ~~;~~ ~~~ p~~~~ °~~ ~ ~~~~:~.ry;~~~~~ RE: Milne Point Liviano-01A Schrader Bluff/Ugnu, Pesado-01A Schrader Bluff and MT. Elbert Special Core Analysis Data Submission. BP Exploration (Alaska) Inc. (BP) is pleased to inform you that the 2009 Special Core Analysis for the above listed wells have been processed. On CD ROM: 1) Conventional Core Analysis 2) Conventional Core Petrology 4) Conventional Core Photography 5) Conventional Core CT Scans 6) Rock Mechanics 7) Special Core Analysis -~a-- ,~(o~ a-rt C~ w =~r~t,~. i d .... .~ ' 'w~ ,. ~ l~~µ. t`Nii~ • ~-~ ~ x.n,. Please acknowledge your receipt of the data by returning a signed copy of this letter to the attention of James Johnson Milne Point Production-Technologist. If you have questions regarding the data, please contact James at 564-4173. ~~ - ~ 1 1~~15~ 1 ~~l`°~~ ~_~ I~C~~o Sincerely, ~v~-d~C~ ~ ~~Co( James H. Johnson Confirmati n o ceipt of Data: ~ ~ Signature: ~ Name: ~ ~ AUG 2 6 2009 Date: ~9aska 9il & Gas Cons. COm~'~~~sior~ Anchoraq~ ~ Download Files • • Page 1 of 1 BP Alaska Liviano-OlA Schrader Bluff Formation ~~~ ~ Milne Point Field Alaska, USA ~$""°~~'"'~°'' "'~' OMNI File #: AK-36771 * April 23, 2007 Download Files , ,pNF~DENTI~~ [ ________e of Contents ] [ Home ] Tabl ~ Conventional Core Analysis: Conventional Core Petrology: Core S~ectral Gamma_Data_and_Lo~ Plots (_ Excel__~_4-23-2007 X-Ra~_Diffraction_~Excel~_1_-21_-2009 Laser Grain_Size_Gra~hs_~Zi~~ed_Excel~_6-25- 2007 Laser Grain_Size Statistics_and_Summar~ (Excel~ 6-25-2007 Conventional Core Photography: Conventional Core CT Scans: Continuous Core Photography_~Zi~~ed_JPGs~ CT_Scans.-_Whole Core_~Zi~pedJPGs~_u~dated 6-5-2007 7-2-2007 Box Format_Photogra~h~_(Zi~~ed_JPGs)_6-8- - --------,._____._ 2009 CT Scans_- Plugs._~_~i~~ed_JPGs_ _5-10-20_ 7 Rock Mechanics: Quick_Look_Plugs_CT_Scans _~Zi~~ed__~PGs~__6-7- 2007 Special Core Analysis: Laser Grain_Size Graphs_-_Rock_Mechanics Zi __ ed Excel Files 3_9 2009 SCAL_Plugs_CT_Scans_(Zi~~ed.~jPGs~ 8-20-2007 ~-- -~~?------ - - _------ - ------~ ---=-------- Laser_Grain_Size_Statistics_and_Summar~_ - ---------- -- - - Rock Mechanics__(Exce1~3-9_-2009 Download Hints: To Open File: Left Click Mouse To Save File: Right Click Mouse, Save Target As Copyright ~O 1998 - 2009 OMNI Laboratories https://www.omnilabs.com/wwwroot2/bp_alaska_liviano-O1_schrader_bluff form_ak-367... 8/21/2009 Download Files ~ ~ Page 1 of 2 r~- ~~ LABtSRATC3RiES ~ FI I BP Alaska Liviano-01 A Ugnu Formation Milne Point Onshore, AK, USA WFT Labs File No.: AK-36770 * Date 4/3/2007 Download Files [ Table_of_Contents ] [ Home ] Conventional Core Analysis: Spectral_Gamma_Log_~Exce1~4-19-2007 Initial_Plu~_Point_Selection_~'hotograph~ ~Zi~~ed_~PGs~_4-25-2007 Laser Grain Size_Analysis_Gra~hs__~Zi~~ed Excel~__5-25-2007 Cony_entional_Core_Analy__sis Summar~ (Excel)_11-5-2007 Laser Grain_Size_Analysis_Stats &_Summar~ ~Excel~_ 6-29-2009 Conventional Core Photography: Core_Photo~r~~hy__-_C~re_1_~Zi~~ed_JPGs)_5- 14-2007 Conventional Core CT Scans: CT_Scans_- Whole_Core__~Zipped~PGs~ Core_Photograph~ -_Core 2__~Zi~~ed_jPGs~__5- CT_Scans Plugs ~Zi~~ed JPGs)_5-4-2007 14-2007 Core Photogra~h_y__ - Core 3__(Zi~~ed.JPGs)_5- CT_Scans_Pl__ugs__-_U~dated_(Zi~~ed_JPGs)_6-5- 14-2007 2007 Core_Photo~raphy_-_Core 4_.~Zi~ped~PGs~,_5- 14-2007 ----------------- Core Photogra~h~._-_Core_5_(Zipped_jPGs~_5- 14-2007 ------------_--- Core_Phot~~ra~h~_- Core_6_(Zi~~ed JPGs~_5- 14-2007 ___-------_._ Core Photograph~__-_Core_7_.~Zi~~ed_jPGs~_5- 14-2007 Box_Format Photogra~hy__~Zi~~ed_JPGs~ 6-8- 2009 Special Core Analysis: CT_Scans_Plugs,_-_SCAL_Wettability_~Zi~~ed IPCs~_s-2s-2oo~ https://www.omnilabs.com/wwwroot2/bp_alaska liviano-O1_milne_point_ak-36770/down... 8/21/2009 Download Files ~ ~• Page 1 of 1 (~ ~ i ~ BP Alaska Pesado-OlA ~~ ~~ Milne Point Field - Schrader Bluff Formation ~ North Slope Borough, AK, USA ~'b~r°°~,'.~'.'"'~. OM1VI File No. AK-36890 * 5/10/2007 Download Files [ Table_~f Contents ] [ Home ] Conventional Core Analysis: S~ectral Gamma_Log_Plot__(Excel) 7-16-2007 Laser_Grain_Size_Anal~sis Gra~hs _(Zi~~ed Excel _6-6-2008 --~ - - ------ - Laser_Grain_Size_Anal~sis _Summar~__(Excel)_6- 6-2008 Conventional Core Photography: Conventional Core CT Scans: Cnntinuous_Core_Photogra~hy__~Zi~ped~~gs) CT_Scan_Images__~Zi~~ed_~p~;s~_5-10-2007 7-9-2007 Box_Format_Phatogra~hy_~Zi~~ed_JPGs)_6-30- Quicklook_Plugs CT_Scans__- U~dated_~Zipped ----- - 2009 jPGs~ 7-26-2007 Whole Core CT_Scans_-_Formation_Damage --- ----- ~Zi~~ed_ j~gs)_12-10-2008 Download Hints: To Open File: Left-Click Mouse on Hyperlink, and Choose 'Open' To Save File: Right-Click Mouse on Hyperlink, and Choose 'Save Target As' If File Does Not Save: Adjust your browser settings to allow file downloads. For Internet Explorer: Tools - Internet Options - Security Tab - Custom Level - Enable File Download. If you open a file from this location, it is read-only and cannot be saved. You must Right-Click and choose 'Save Target As' Copyright ~O 1998 - 2009 OMNI Laboratories https://www.omnilabs.com/wwwroot2/bp_alaska_pesado-O l a_milne_point_ak-36890/dow... 8/21/2009 Download Files Page 1 of 2 ~ ~ ~ I ~~~ BP Alaska ~~~ ~ MT. Elbert - Ol Alaska, USA ~ Lac.orwa~r~~. er~, OMNI File No.: HH-36510 * March 19, 2007 Download Files Table of Contents Home ------ ------. ~ __.__._~ Conventional Core Analysis: Conventional Core Petrology: Conventional Core Gan~ma Log~Excel 3-19- . 2007 'rl~n Section Imag_es (Zi~ped_~s~_6-5-2008 Conventional Cor_e__Anal~sis_Summar~_(Excel) Point Count Anal sis Excel 11-14-2008 3-3-2008 -----~---~----~---- ----- Laser Grain Size Anal~is Graphs_~Zi~ed X_R~Diffractio~Excel~_3-5-2009 Exce~__3-3-2008 Laser_Grain Size Calculated Permeabilit~ ~n Section Descri hons Word 4_2-2009 ~Exce~ 3-3-2008 --~----~ -~-~~--^ ---- Laser Grain Size Ana~sis_ Gra~lls_~Zi~~ed Summary of Petro~r~hic Results.~Word~4-2- Excel~_3-5-2009 2009 Laser Grain_Size_Anal_y_sis_Data__~Excel) 3-5- 2009 Conventional Core CT Scans: Rock Mechanics: Rock_Mechanics_Pro~ressiye Re~ort ~Exce~_ 3- 26-2008 Whole Core~Pl~ Format~_CT Scans_~Zi~~ed jI?~ 6-5_2007 P1u~CT Scans Zi ~ed~PGs~ 6-12-2007 Hy_drate Samples CT Scans Addational_Axials - ------ ----- Ev_er~20mm~Zi~~ed~PG~ 1-15_2008 Special Core Analysis: SCAL P1~CT Scans ~Zi~~ed ~PGs~ 2-12-2008 Download Hints: To Open File: Left-Click Mouse on Hyperlink, and Choose 'Open' To Save File: Right-Click Mouse on Hyperlink, and Choose 'Save Target As' If File Does Not Save: Adjust your browser settings to allow file downloads. For Internet Explorer: Tools - Internet Options - Security Tab - Custom Level - Enable File Download. If you open a file hom this location, it is read-only and cannot be saved. You must Right-Click and choose 'Save Target As' https://www.omnilabs.com/wwwroot2/bp_mt_elbert_O l_hh-36510/downloads/download%... 8/21 /2009 a ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2060330 Well Name/No. MT ELBERT 1 Operator BP EXPLORATION (ALASKA) INC MD 3000 TVD 3000 Completion Date 2/21/2007 Completion Status P&A REQUIRED INFORMATION Mud Log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, AIT, DT, BHC, CNL, LDL, Cal iper, SP, MRES Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name ~ Scale Media No D C Pdf 532 See Notes i ~tD C X595 See Notes ~D D Asc ~ Directional Survey See Notes 5 Col Dip 5 Col 2 ' ', Log per log 5 Col 1 ~og Magnetic Resonance i 5 Col 1 Log a~(nduction/Resistivity 5 Col 2 ~ N t 5 l og ee o es Go 2 I~j ~ -I'Log ,/ Induction/Resistivity 25 Blu 1 ~~-Log ~utron 5 Blu 1 Log Induction/Resistivity 5 Blu 1 API No. 50-029-23302-00-00 Current Status P&A UIC N Directional Survey No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments Open 3/20/2007 MDT Results Power Point File /Core Photos in .bmp format 2025 2484 Open 4/11/2007 Core photos in .BMP format 0 3000 Open 4/23/2007 2012 2161 Open 10/19/2007 MDT, GR 14-Feb-2007 HUGE 1952 2944 Open 10/19/2007 Dipole Sonic Imager Tool, DSI Log 14-Fe-2007 1952 2902 Open 10/19/2007 Power Positioning Caliper Tool, Borehole Graphics 14-Feb-2007 2000 2648 Open 10/19/2007 Combinable MRT, CMR log 14-Feb-2007 1964 2996 Open 10/19/2007 Oil based MIT, OBMI Resistivity Log 14-Feb- 2007 1964 2996 Open 10/19/2007 Elemental Capture Spectroscopy Sonde ECS Log 14-Feb-2007 1952 2994 Open 10/19/2007 RTST, Triaxial Induction Log 14-Feb-2007 1952 2996 Open 10/19/2007 Platform Express, Comp Neutron, Lithodensity Log 14-Feb-2007 1952 2994 Open 10/19/2007 TCOM Log, Nuetron, Lithodensity, Resisitivity 14- Feb-2007 s i DATA SUBMITTAL COMPLIANCE REPORT 11/18/2008 Permit to Drill 2060330 Well Name/No. MT ELBERT 1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23302-00-00 MD 3000 (Cog TVD 3000 Completion Date 2/21/2007 See Notes Completion Status P&A 5 Blu 1 1952 Current Status P&A 2950 Open 10/19/2007 UIC N Electriomagnetic Propagation Tool EPT Log ~ 14-Feb-2007 _ "Lo C ~ 15556 Gamma Ray See Notes 5 Blu 1 1952 1873 2954 2994 Open 10/19/2007 Open 10/19/2007 HNGRS Log 14-Feb-2007 LIS Veri, AIT, SDN, CNT j EPT. With Multi logs in PDS format, with a Tif and ~D C Lis 810 Induction/Resistivity 114 2992 Open 1/4/2008 HDR graphic LIS Veri, ROP, NCNT, '~ ~ FCNT, NPHI, ACAL, DRHO, RHOS, RPM, RPS, RPX, FET, GR ''Log Induction/Resistivity 25 Col 275 3000 Open 1/4/2007 ROP, DGR, EWR, CTN, ~ED C X15809 See Notes 0 0 Open 1/4/2008 ALD 15-Feb-2007 EMF, PDF and TIF graphics Well Cores/Sample s Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ Core Chips 1990 2363 4/10/2007 1159 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 3/6/2006. ADDITIONAL INFO Well Cored? ATION ~N Daily History Received? ~ / N Chips Received? Y~ N Formation Tops ~ N Analysis ~pL, Received? Comments: Compliance Reviewed By: Date: F l ~ 1 ~, ~:' ,r ,r _. Date 01-03-269. ~~~ ~ Transmittal Number:92924 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC ar stia_an91 SW Name Date Contractor Log Run Top De th Bottom De th Lo T e MT. ELBERT-01 02-15-2007 SPERRY 1 275 3000 MD/TVD ROP /DGR / EWR / CTN / ALD MT. ELBERT-01 02-13-2007 SPERRY LIS DATA CD ROM MT. ELBERT-01 02-13-2007 SPERRY DIGITAL LOG IMAGES CD - ROM LIVIANO-01 A 03-26-2007 SPERRY 1 115 3366 MD ROP /DGR / EW R4 LIVIANO-01A 03-26-2007 SPERRY 1 115 3311 TVD ROP /DGR / EWR4 LIVIANO-01A 03-17-2007 SPERRY LIS DATA CD ROM LIVIANO-01A 03-17-2007 SPERRY DIGITAL LOG IMAGES CD - ROM Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Christine Mahnken AOGCC Kristin Dirks DNR s ~'~~~ ~o(o - 033 r ~~t v ~~~-JG7 i t S ~i!t lS~~ ~ ~~1 Y.E j ~ ~~ ~~t~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 1-t ~> iw,, Date 10-16-2007 Transmittal Number:92909 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at Sh4-4(191. SW Name Date Contractor Log Run Top De th Bottom De th Lo T e MT.ELBERT-01 02-14-2007 SCH 4 2012 2161 MODULAR DYNAMIC TESTER LOG MDT /GAMMA RAY `~ ~~ , i ~~ ~' '' l Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Christine Mahnken ~~C~- ~~? DNR AOGCC Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~.~ b~~,, ,~, ,, ~~ ~=., ;'=t Date 10-16-2007 Transmittal Number:92910 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC ~r S~~ _d(1Q 1 Log Top SW Name Date Contractor Run De th Bottom De th Lo T e LDWG EDIT OF OH W IRELINE DATA TIF FORMA MT.ELBERT-01 02-14-2007 SCH 1873 2996 PDS GRAPHICS CD ROM DIPOLE SONIC IMAGER MT.ELBERT-01 02-14-2007 SCH 2 1952 2944 TOOL DSI LOG RT SCANNER TOOL MT.ELBERT-01 02-14-2007 SCH 1 1952 2994 TRIAXIAL INDUCTION LOG PLATFORM EXPRESS COMPENSATED NEUTRON MT.ELBERT-01 02-14-2007 SCH 1 1952 2974 LITHODENSITY LOG POWER POSTIONING CALIPER TOOL BOREHOLE MT.ELBERT-01 02-14-2007 SCH 2 1952 2902 GRAPHICS CALIPER LOG COMBINABLE MAGNETIC MT.ELBERT-01 02-14-2007 SCH 3 2000 2648 RESONANCE TOOL CMR OIL BASED MICRO IMAGER MT.ELBERT-01 0?_-14-2007 SCH ?_ 1964 2996 TOOL OBMI RESISTIVITY ELEMENTAL CAPTURE MT.ELBERT-01 02-14-2007 SCH 3 1952 2974 SPECTROSCOPY SONDE TCOM LOG NEUTRON MT.ELBERT-01 02-14-2007 SCH 1 1952 2994 LITHODENSITY RESISTIVITY ELECTROMAGNETIC MT.ELBERT-01 02-14-2007 SCH 1 1952 2950 PROPAGATION TOOL HOSTILE ENVRIO NATURAL MT.ELBERT-01 02-14-2007 SCH 3 1952 2954 GAMMA RAY SONDE ~ ~ ---, Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Christine Mahnken Tim Collett Ray Boswell Robert Hunter DNR AOGCC US Geological Survey US Department of Energy ASRC Energy Services Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~~ ``" ~ STATE OF ALASKA . 2007 .~~aska ALASKA OIL AND GAS CONSERVATION COMMISSION 0~~ & has Cnn WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~; f~ ~nchora~~. ~°mmission Revision: 06/15/07 Submittal Abandonment Photos 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.,os zoAaczs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ®Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp p., or Aba d Q'~2007 12. Permit to Dritl Number 206-033 - 307-069 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 2/5/2007 13. API Number 50-029-23302-00-00 4a. Location of Well (Governmental Section): Surface: 4038' FSL 4183' FE S C 7. Date T.D. Reached 2/13/2007 14. Well Name and Number: Mt. Elbert-01 , L, E . 30, T13N, R11 E, UM Top of Productive Horizon: N/A 8. KB (ft above MSL): 54.80 ~ Ground (ft MSL): 15. Field /Pool(s): Milne Point Unit Total Depth: 4040' FSL, 4174' FEL, SEC. 30, T13N, R11 E, UM 9. Plug Back Depth (MD+TVD) Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 572199 y- 6016604 Zone- ASP4 10. Total Depth (MD+TVD) 3000. 3000 - 16. Property Designation: ADL 028231 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 572208 y- 6016606 Zone- ASP4 11. SSSV Depth (MD+TVD) 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 offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, DIR, GR, RES, AIT, DT, BHC, CNL, LDL, Caliper, SP, MRES, HRLA, DEN, EPT, Dipole, Sonde, FMI, CMR, XPT, MDT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTW ND .'HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM z SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 112' Surface 112' 30" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 35' 1954' 35' 1954' 12-1 /4" 270 sx AS Lite 464 sx Class 'G' N/A N/A N/A 1954' 3000' 19 4' 3000' 8-1/2" O enhole 23. Open to production or inject ion? ^ Yes ^ No 24. TUBING RECORD If Yes, Itst each Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD None None MD TVD MD TVD 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2310' Set 1st Cement Plug with 50.4 Bbls AS Lite 1806' Set 2nd Cement Plug with 55.5 Bbls Lite Crete 284' SET 9-5/8" Bridge Plug Surface Cement to Surface with 29 Bbls AS Lite 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED Z4-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 formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. Please reference attached Coring Well Summary ~~,;p~ i ~j~~0~ O~ ~HC~NIIS BFL JUN 2 ~ 2007 r=i Form 10-407. Revised 02/2007 ~ D' (- ~ „' ~dLNUED ON REVERSE SIDE 28. GEOL3(dIC MARKERS (LIST ALL FORMATIONS AN ERS 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. SV5 1637' 1637' See Attached: SV4 1820' 1820' Reed Hycalog Coring Services Well Summary SV3 2019' 2019' Schlumberger MDT Job Report SV2 2175' 2175' SV 1 2488' 2488' Formation at Total Depth (Name): 30. List of Attachments: Post Rig Well work Summary and Abandonment Photos. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr tewman Title Technical Assistant Date "' ~ ° Mt. Elbert-01 206-033 307-069 Prepared By NameMumber.~ Sondra Stewman, 564-4750 Drilling Engineer: Paul Hanson, 564-4195 Well Number Permit No. / A royal No. INSTRUCTIONS GeNewa~: 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 ti .. ~..~~ Operations Summary - Surface P & A BP Exploration (Alaska} Inc Mt. Elbert Ol PTD: 206-033 API No. 50-029-23302-00 _April 18, 2007: Excavated around wellhead to remove cellar and expose 20" conductor to a depth of approximately 6 ft below original tundra surface. Rigged up Watchs Saw and cut conductor and 9 s/8" surface casing 4 ft below original tundra surface. Topped off Lite Crete cement in 20" x 9 s/g" annulus. Cement in 20" x 9 5/8" annulus, and top plug inspected and approved by AOGCC inspector Lou Grimaldi. Installed subsurface marker plate as per 20AAC 25.120 (b} (d). Backfilled excavation and left 1-2 ft mound to accommodate normal settling (see attached Near-surface wellbore schematic). MPU iVlt, Elbert (~PXA) Surface Aba~c9onrner~t tnspectior~ Photos from Lou Grimaldi, AOGCC April 18, 2007 Cement to surface Marker plate Installation of marker plate on casing stub STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment /Location Clearance /Suspended Well ( Title 20 AAC 25.170 ) e;;.~/r' ,? FILE INFORMATION: Operator: BP Exploration (Alaska) Inc. Well Name: Mt. Elbert-01 Address: P.O. Box 196612 PTD No.: 206-033 Anchorage, Alaska 99519-6612 API No. 50- 029-23302-00 Surface Location (From Sec. Line): Unit or Lease Name: Milne Point Unit North/South 1242' FNL East/Vliest 4183' FWL Field and Pool: Ku aruk River Field Section: 30 Township: 13N Range: 11 E Meridian: UM Downhole P&A Date: 2/21!2007 20 AAC 25.120 -ABANDONMENT MARKER: Insp. Date: Surface Monument Approval Date: Post OD: (4" min) " Length: ft. Set on (Wellhead, Csg , In Cmt) _ _ Height above final grade (4' min.): ft. Casing stub_ft. below final grade Top of Marker Post Closed ?_ All openings closed ? Inspector: Insp. Date: 4118/07 Subsurface Monument Approval Date: ~ ~- Marker Plate Diameter: 20 Distance below final grade Level: 5 ft Thickness: 3/8 " Side Outlets removed or closed: Yes Marker Plate Attached To Conductor Y (Y/N) Cement to surface (all strings)? Yes Inspector: Lou Grimaldi Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date:4/18/07 Approval Date: ~ 0 BPXA PTD 206-033 Mt. Elbert-01 50-029-23302-00 Inspector: Lou Grimaldi Insp. Date: 20 AAC 25.170 -LOCATION CLEANUP: Approval Date: Pit's filled in? Liners Removed or Buried? Debris Removed: Notes: General condition of padAocation: (Rough, Smooth, Contoured, Flat, Natural ) Notes: Type of area surrounding location: (Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Debris on surrounding area: Notes: Access road present? Type road: (Dirt, Gravel, Ice, Other) Condition: Condition of road: Notes: Cellar filled in? Type of fill: Height above grade: Notes: Type work needed at this location: Ins ector: RECOMMENDED FOR APPROVAL OF ABANDONMEt Yes Distribution: Reason: orig -Well file c -Operator c -Database c -Inspector Final Inspection performed? Yes No (If "No" See Reason } No DATE: Final Approval By: Title: a ~~~-- '~~ Sheet by L.G. 8/5/00 2007-0418_Surf_P&A_MPU_Mt_Elbert-1_Ig.xis 5/4/2007 • NiPIJ SAY. ~9~e~t (~PXA) Sa~~#ace ~ba~d®~me~~ dra~pec~a®~ Photos from Lou Grimaldi, AOGCC April 18, 2007 Cement to surface Marker plate Installation of marker plate on casing stub 17-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well Mt. Elbert #1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 33.70' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 3,000.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date 3 R Signed 4 Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~.o~- X33 . STATE OF ALASKA ~°'t'3'd~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~~~~~ MAR 2 2 2007 Alaska Oil & Gas Cons. Commission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended ^ WAG zoAACZS.,os zoaaczs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: A~1Of8 @ ^ Development Q9 Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab 2/21/2007 - ~~~ 12. Permit to Drill Number 206-033 307-069 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/5/2007 13. API Number 50-029-23302-00-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/13/2007 14. Well Name and Number: Mt. Elbert-01 ~ 4038 FSL, 4183 FEL, SEC. 30, T13N, R11E, UM Top of Productive Horizon:. N/A 8. KB Elevation (ft): 54.80 15. Field /Pool(s): Milne Point Unit , Total Depth: 4040' FSL, 4174' FEL, SEC. 30, T13N, R11 E, UM 9. Plug Back Depth (MD+TVD) Surface + Surface Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 572199 y- 6016604 Zone- ASP4 10. Total Depth (MD+TVD) 3000 + 3000 Ft 16. Property Designation: ADL 028231 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 572208 y- 6016606 Zone- ASP4 11. Depth where SSSV set N/A 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: MWD, DIR, GR, RES, AIT, DT, BHC, CNL, LDL, Caliper, SP, MRES, HRLA, DEN, EPT, Dipole, Sonde, FMI, CMR, XPT, MDT 22. CASING, LINER AND CEMENTING RECORD CASING `SETTING DEPTH MD SETTING DEPTH TVD HOSE' AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 112' Surface 112' 30" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 35' 1954' 35' 1954' 12-1/4" 270 sx AS Lite 464 sx Class 'G' N/A N/A N/A 1 54' 1954' 0 0' 8-1/2" O enhole 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. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2310' Set 1st Cement Plug with 50.4 Bbls AS Lite 1806' Set 2nd Cement Plug with 55.5 Bbls Lite Crete 284' SET 9-5/8" Bridge Plug Surface Cement to Surface with 29 Bbls AS Lite 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 „. s~ary). Submit core chips; if none, state "none". A~Q '~~„~= Please reference attached Coring Well Summary ~~D~ . Form 10-407 Revised 12/2003 ~ ~ ~ ~ n 1 , /~ CONTINUED ON RE ~~ +,~ ~ ~, ~D~~ /~L~ I 28. GEOLOGIC MARKE 29. ORMATION TESTS . Include and briefly summarize test results. List intervals tested, Na,ME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". SV5 1637' 1637' See Attached: SV4 1820' 1820' Reed Hycalog Coring Services Well Summary SV3 2019' 2019' Schlumberger MDT Job Report SV2 2175' 2175' SV1 2488' 2488' NOTE: Will resubmitt 10-407 with Well work Summary and Abandoment Photos once completed. 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Reed Hycalog Coring Well Summary, Schlumber er MDT Job Re ort and a Leak-off Test Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman Title Technical Assistant Date ,1~j -~ -(7`7 Mt. Elbert-01 206-033 307-069 Prepared ByNameilVumber. Sondra Stewman, 564-4750 Drilling Engineer: Well Number Permit No. / A royal No. Paul Hanson, 564-4195 INSTRUCTIONS GeNeRa~: 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. IreM 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). IreM 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". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only by BP EXPLORATION - ~, , .w,, .Y , Mt. Elbert-01 Hydrate Well Field: Milne Point ENG: P. Hanson Pad: F-Pad Abandonment RIG: Doyon 14 RKB: 54.8 ft DIR / LWD OH DEPTH HOLE CASING MUD INFO FORM MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 106' 30" Welded 11" 5K MWD/GR/RES None Lead Cement Test Csg to Neu/Den 216 Bbls 2000 psi 10.7 ppg-4.43 ft3/s 1850' Surface. Casino 9-5/8" 40 Ibs/ft 150% Excess T op Mikkelson Tong 1,450' 1,450' L-80, In Permafrost BTC-M Int. Yield 5750 psi Collaspse 3090 psi Teil Cement 77 bbls Base Permafrost 1,800' 1,800' 1806' 15.8 ppg-1.05 ft3/s Casing Point 1,954' 1,954' 0° 12-1/4" None "D" Hydrate 2,000' 2,000' 55.5 bbl 12.7 PP9 "C" Hydrate 2 100' 2 100' LiteCrete Mineral Oil-Based , , Coring Fluid Coring,E-Line Logs MDTs 2310' Top Staines Tongu 2,770' 2770 50.4 bbl 15.7 PP9 ASL Base Hydrate Stability Zone 2,853' 2,853' 0° 3,000' 3,000' 8-3/4" 3/22/2007 hydrate Well Final Schematic.xls BP AMERICA Page 1 of 9 Operations Summary Report Legal Well Name: Mt Elbert Hydrat e Well Common W ell Name: Mt Elbert Hydrate Welj Spud Date: 2/5/2007 Event Nam e: DRILL+C OMPLE TE Start : 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLIN G INC . Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: Date From - To ~ Haurs Task Code , NPT Phase Description of Operations 2/3/2007 05:00 - 06:00 1.00 MOB P PRE PJSM -Skid rig floor 06:00 - 09:00 3.00 MOB P PRE Demobilize rig -Move off well -Move off mats - P/U mats and herculite 09:00 - 15:30 6.50 MOB P PRE Move rig from S pad to Mt Elbert ice pad (6 mile move) 15:30 - 16:30 1.00 MOB P PRE Spot rig over well and shim rig 16:30 - 17:30 1.00 MOB P PRE PJSM -Skid rig floor 17:30 - 20:00 2.50 MOB P PRE Spot and berm rockwasher - R/U service lines and mud lines (Accepted rig ~ 2200 hours} 20:00 - 22:00 2.00 RIGU P PRE PJSM - C/O saver sub - N/U valves on conductor -Building spud mud 22:00 - 00:00 2.00 RIGU P PRE N/U divertor spool and annular preventer 2/4/2007 00:00 - 05:30 5.50 RIGU P PRE Continue N/U diverter system, riser, and flowline 05:30 - 10:00 4.50 RIGU P PRE C/O saver sub to 4 1/2 IF -Anchor diverter lines 10:00 - 11:00 1.00 RIGU P PRE ATP meeting held with both crews 1 i:00 - 12:00 1.00 RIGU P PRE Load 5" DP in pipeshed 12:00 - 13:00 1.00 DIVRTR P SURF Test diverter, gas alarms, and pvt system -All test witnessed by AOGCC rep Jeff Jones and WSL 13:00 - 13:30 0.50 RIGU P SURF PJSM C/O roughneck dies and air slips to handle 5" DP 13:30 - 16:30 3.00 RIGU P SURF P/U DP 1 X 1 and stand in derrick 16:30 - 18:00 1.50 RIGU P SURF Load HWDP in pipeshed and strap -Mobilize BHA to rig floor 18:00 - 23:00 5.00 RIGU P SURF Rig up mud loggers - M/U BHA #1 drilling assembly -Function and test loggers equipment (good test) 23:00 - 00:00 1.00 DRILL P SURF Pre spud meeting -Fill stack and check for leaks 2/5/2007 00:00 - 00:30 0.50 DRILL P SURF Continue fill hole and check for leaks 00:30 - 02:30 2.00 DRILL P SURF Drill from 110' to 275' 02:30 - 03:00 0.50 DRILL P SURF CBU -Stand back 3 stands HWDP - UD bit sub & bit 03:00 - 07:30 4.50 DRILL P SURF M/U BHA #2 drilling assembly (12 1/4" bit, MWD) -Upload MWD, Surface test MWD, Load gamma ray sources 07:30 - 08:30 1.00 DRILL P SURF M/U DC's -Wash to bottom (275') logging data @ 175' hr 08:30 - 00:00 15.50 DRILL P SURF Drill from 275' to 1289' (PU 100, SO t02, RW 102, 500 gpm, 1410 psi, WOB 25, RPM 90 TO 2) ART=14.1 hrs, 20 units back ground gas -Density tool failed at beginning, no backup tool available 2/6/2007 00:00 - 09:00 9.00 DRILL P SURF Drill from 1289' to 1960' (PU 111, SO 115, RW 113, 495 GPM - @ 1450 psi, 90 RPM, TQ 2, WOB 20) Maximum back ground gas = 30 units @ 1569' 09:00 - 10:00 1.00 DRILL P SURF Circulate hole clean, R & R (500 gpm, 1380 psi) 10:00 - 11:30 1.50 DRILL P SURF Pump out of hole from 1960' to 823' (500 gpm, 1340 psi) (no problems) 11:30 - 12:30 1.00 DRILL P SURF RIH from 823' to 1960' -Wash last stand down 12:30 - 13:30 1.00 DRILL P SURF Circulate hole clean -R & R (RPM 100, TQ 1, 500 GPM, 1420 psi) 13:30 - 15:00 1.50 DRILL P SURF Pump out of hole from 1960' to 823' ~ 500 GPM (no problems) 15:00 - 17:30 2.50 DRILL P SURF POOH UD HWDP, jars and NM DC's 17:30 - 18:30 1.00 DRILL P SURF PJSM -Remove nuclear sources, secure and UD same 18:30 - 19:30 1.00 DRILL P SURF UD NM DC, UBHO and stabilizers 19:30 - 21:00 1.50 DRILL P SURF Download MW D 21:00 - 22:30 1.50 DRILL P SURF Pull probe -Break out & UD TM, DEN/ALGAE, Direct, Res/Gam - UD MW D body, bit sub, and bit 22:30 - 23:00 0.50 DRILL P SURF Clear floor of vendor tools 23:00 - 00:00 1.00 CASE P SURF R/U to run 9 5/8" 40# L-80 casing 2/7/2007 00:00 - 01:00 1.00 CASE P SURF PJSM- Continue rig up to run 9 5/8° 40#, L-80 casing 01:00 - 04:30 3.50 CASE P SURF PJSM -Run 9 5/8" 40# L-80 BTC-M casing -Wash last joint to Printed: 2/26/2007 1:51:47 PM BP AMERICA Operations Summary Report Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~ From - To ~ ' ;Hours Task ~ Code NPT ~ _ _ _ __ 2/7/2007 01:00 - 04:30 -- 3.50 CASE P 04:30 - 05:00 0.50 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 08:00 2.50 CASE P 08:00 - 10:30 2.50 CEMT P 2/8/2007 10:30 - 12:00 12:00 - 17:00 17:00 - 18:00 18:00 - 22:00 22:00 - 00:00 00:00 - 01:00 01:00 - 07:00 1.50 CEMT P 5.00 DIVRTR P 1.00 BOPSU P 4.00 BOPSU P 2.00 BOPSU P 1.00 BOPSU P 6.00 BOPSU P 07:00 - 08:30 ~ 1.501 BOPSUFI P 08:30 - 09:00 0.50 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 14:00 4.00 DRILL P 14:00 - 15:30 1.50 EVAL P 15:30 - 16:00 16:00 - 17:00 17:00 - 00:00 2/9/2007 00:00 - 06:00 06:00 - 11:00 11:00 - 11:30 11:30 - 12:00 0.50 EVAL P 1.00 EVAL P 7.00 EVAL P 6.00 I EVAL I P 5.001 DRILL I P 0.50 DRILL P 0.50 DRILL P Page 2 of 9 Spud Date: 2/5/2007 Start: 2/3/2007 End: 2/25/2007 Rig Release: 2/21/2007 Rig Number: Phase Description of Operations SURF bottom -Land casing (47 jts total) (PU 120, SO 115) SURF CBU with Frank's fillup tool (252 gpm @ 330 psi) SURF PJSM - RD Franks Tool - RU Cement Head SURF Circ. & condition mud for cement job -PJSM w/ Schlumberger - Truck pusher and all involved w! upcoming operation. SURF Pump w/ Schlumberger - 10 bbls H2O -Test lines to 4000 psi - Pump 80 bbls Mud Push ~ 10.2 ppg -Drop bottom plug - Pump lead, 216 bbls 10.7 ppg ArcticSet Lite (Yield 4.49 cf/sx) - Pump Tail, 77 bbls 15.7 ppg (Yield .93 cf/sx) -Drop top plug - displace w/ Schlumberger w/ 144.5 bbls 9.2 ppg MOBM -Initial circulating press 132 psi at 5.4 bpm -Final circulating press. 685 psi at 1 bpm -Bump plug w/ 1800 psi -Hold f/ 10 min - Check floats - OK -Total cement returns to surface = 57 bbls - CIP at 10:15 hrs. SURF Flush diverter stack - Flowline -Blow down and flush Schlumberger lines - RD cement head -Clean/Clear floor SURF L/D landing joint -Flush flowline -Pull riser - N/D annular preventor, knife valve and spool SURF M/U FMC speed head and tubing spool -Test head to 1000 psi for 10 minutes (good test) SURF N/U DSA, BOP stack, choke line and flowline -Install double valve on upper annulus SURF PJSM -Install test plug - C/O top rams to 4 1/2" X 7" SURF PJSM- R/U to test BOPE SURF Test BOPE -Annular, Top VBR's -Choke manifold -Choke / Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's tested to 250 psi low, 3000 psi high for 5 minutes each -Perform accumulator test -Test Blind rams to 250 psi low, 3000 high f! 5 min. each, Tested gas detectors and PVT's, Tested Corion coring ball valve to 250 psi low, 3000 psi high -Jeff Jones with AOGCC witnessed test -All tests witnessed by WSL SURF R/D test equipment -Purge mud pumps w/ LVT -Drain BOP's vaccuum all excess water from same -Pull test plug -Install wear ring -Blow down choke manifold and and lines SURF PJSM -Mobilize BHA to rig floor SURF PU 8 3/4" bit, 3- DC's, 3- HWDP, jars SURF RIH w/ 5" DP f/ derrick -Break each connection and drift pin ends w/ 4.1"drift per Reed Hycalog Rep. SURF PJSM with Drill Cool -Test lines -Test unit (no leaks)(pumping 560 gpm ~ 40 psi through unit) SURF Circulate hole clean for casing test SURF Test casing to 2000 psi for 30 minutes (good test) SURF Dummy run with slickline retrieving core barrels from drill string to skate -Dummy run handling core barrels in pipeshed - R/D slickline SURF Continue modifying pipe shed for core processing -Waiting on 5000 psi wireline packoff -Thawing kelly hose SURF Screw in T.D. -Break Circ. -Obtain parameters -Tag float collar at 1870' - Driil F.C., cement and Float shoe to 1954' - Clean out rat hole to 1960' PROD1 Drilling 20' of new hole to 1980' PROD1 Circ. bottoms up -Stand back 1 stand to 1905' - Printed: 226/2007 1:51:47 PM BP AMERICA Operations Summary Report Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date From - To Hours Task i Code ~~_ - -L 2/9/2007 ~ 12:00 - 12:30 ~ 0.50 ~ DRILL ~ P 12:30 - 13:00 0.50 DRILL P 13:00 - 15:30 2.50 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 17:30 1.00 DRILL P 17:30 - 20:30 3.00 DRILL P 20:30 - 22:00 22:00 - 00:00 1.50 DRILL P 2.00 DRILL P 2/10/2007 100:00-02:30 2.50 I EVAL I P Start: 2/3/2007 Rig Release: 2/21 /2007 Rig Number: NPT i Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi 02:30 - 03:00 0.50 EVAL P PROD1 03:00 - 03:30 0.50 EVAL P PROD1 03:30 - 04:30 1.00 EVAL P PRODi 04:30 - 07:30 3.00 EVAL P PROD1 07:30 - 08:00 0.50 EVAL P PROD1 08:00 - 09:00 1.00 EVAL P PROD1 09:00 - 11:00 2.00 EVAL P PROD1 11:00 - 11:30 0.50 EVAL P PROD1 11:30 - 12:00 0.50 EVAL P PROD1 12:00 - 13:30 1.50 EVAL P PROD1 13:30 - 14:30 1.00 EVAL P PROD1 14:30 - 16:00 1.50 EVAL P PRODi 16:00 - 17:00 1.00 EVAL P PROD1 17:00 - 18:30 1.50 EVAL P PROD1 18:30 - 19:30 1.00 EVAL P PROD1 19:30 - 21:00 1.50 EVAL P PROD1 Page 3 of 9 Spud Date: 2/5/2007 End: 2/25/2007 Description of Operations RU & perform Leak off test -Leak off at 450 psi w/ 9.2 ppg & 1953 TVD = EMW of 13.6 ppg CBU -Monitor well PJSM - RU Corion wire line equip. -Dry run w/ retrievable core bbls -Both drilling crews involved (Crew change day) Flow check -Break circulation -Pump dry job - Blowdown top drive POOH from 1900' to 215' UD BHA (jars, HW DP, Stand back flex collars) PJSM - M/U coring BHA (bit, core barrel,) -Run/test inner core barrel seal ~ 229 gpm ~ 400 psi, 127 gpm ~ 140 psi - UD inner core barrel -Install inner drill core assembly - Test ~ 300 gpm ~ 350 psi - P/U 10 coring drill collars & XO to 343' P/U 27 jts DP (1X1) - RIH to 1940' PJSM -Circulate and condition mud (300 gpm @ 410 psi, PU 90, SO 90) - R/U 5000 psi packoff head assemblylpump in sub - SPR with drill core assembly in = #1) 30 = 70, 40 = 130 / #2) 30=80, 40=130 C 1940 MD, 9.3 MW M/U 5000 psi packoff /pump in sub -RIH with wireline and retrieve inner drill core assembly -POOH with wireline at 60 feet per minute / No swabbing observed, pulled slow first run to ensure no tight spots in drill pipe on first wireline retrieval CBU Install inner core barrel -Pump core barrel down #1 Core from 1990' to 2014' Check flow - M/U wireline retrieval head &TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl recovered 17.08' of core) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same. Wash down f/ 1923'-1994' -Wash & ream f/ 1994'-2014' #2 Coring f/ 2014'-2038' - 252 gpm 620 psi - 65 rpm - 2-3k tq -, Check flow -Stand back 2 stands - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 23.58' of core #2) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same - Wash down f/ 1928'-2038' #3 Core f/ 2038'-2062' - 250 gpm 620 psi - 65 rpm 2-3k tq '-' Check flow -Stand back 2 stands - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 23.37' of core #3) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #4 Core f/ 2062'-2085' - 255 gpm 570 psi - 40 rpm .- Check flow -Stand back 2 stands - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 24.0' of core #4) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #5 core f/ 2085'-2109' - 242 gpm 600 psi - 40 rpm - Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 23.66' of core #5) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #6 core f/ 2109'-2133' - 242 gpm 610 psi - 40 rpm Check flow -Stand back 1 stand - M/U wireline retrieval head & Printed: 2/26/2007 1:51:47 PM BP AMERICA Page 4 of 9 Operations Summary Report Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Spud Date: 2/5/2007 Event Name: DRILL+COMPLETE Start: 2/3/2007 End: 2/25!2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours Task Code NPT Phase I _. _ __ 2/10/2007 ~ 19:30 - 21:00 1.50 ~ EVAL P ~ PROD1 21:30 - 23:00 I 10.50 EVAL I p , PROD1 PROD1 23:00 - 23:30 0.50 EVAL P PROD1 23:30 - 00:00 0.50 EVAL P PROD1 2/11/2007 100:00 - 01:00 I 1.001 EVAL I P I I PROD1 01:00 - 02:00 1.00 EVAL P PROD1 02:00 - 03:30 1.50 EVAL P PRODi 03:30 - 04:30 1.00 EVAL P PROD1 04:30 - 06:00 1.50 EVAL P PROD1 06:00 - 07:00 1.00 EVAL P PROD1 07:00 - 09:00 2.00 EVAL P PROD1 09:00 - 10:00 1.00 EVAL P PROD1 10:00 - 11:30 1.50 EVAL P PROD1 11:30 - 12:00 0.50 EVAL P PRODi 12:00 - 13:30 1.50 EVAL P PRODi 13:30 - 14:30 1.00 EVAL P PROD1 14:30 - 16:00 1.50 EVAL P PROD1 16:00 - 17:00 1.00 EVAL P PROD1 17:00 - 18:30 1.50 EVAL P PROD1 18:30 - 19:30 1.00 EVAL P PRODi 19:30 - 21:00 1.50 EVAL P PROD1 Description of Operations TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 24.45' of core #6) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #7 core f/ 2133'-2157' - 234 gpm 590 psi - 40 rpm- Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 24.5' of core #7) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #8 core f/ 2157'-2180' - 234 gpm 590 psi - 40 rpm - Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline POH w/ wireline - LD core bbl (recovered 19.95' of core #8) - Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #9 Core f/ 2180' -2190' - 252 gpm 580 / 800 psi, 40 rpm Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 2.58' of core #9) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #10 Core f/ 2190'-2200' - 252 gpm 580 / 800 psi, 40 rpm Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 6.33' of core #10) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #11 Core f/ 2200-2218' - 231 gpm 650 / 800 psi, 40 rpm Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 14.37' of core #11) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #12 Core f/ 2218-2241' - 273 gpm, 760-1000 psi > Check flow -Stand back 2 stands - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 20.75' of core #12) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #13 Core f/ 2241'-2265' - 273 gpm, 760-1000 psi Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 22.83' of core #13) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #14 Core f/ 2265'-2288' - 260 gpm, 680-920 psi - Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 19.33' of core #14) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #15 Core f/ 2288'-2312' - 255 gpm, 690 psi ... Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve - RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 20.58' of core #15) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same #16 Core f/ 2312'-2337' - 255 gpm, 690 psi _ Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 23.25' of core #16) -Observe well - LD Printed: 2/26/2007 1:51:47 PM BP AMERICA Page 5 of 9 Operations Summary Report Legal Well Name: Mt Elbert Hydrat e Well Common W ell Name: Mt Elbert Hydrat e Well Spud Date: 2/5/2007 Event Nam e: DRILL+C OMPLE TE Start : 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLIN G INC . Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: ~ Date From - To i Hours Task ! Code NPT Phase Description of Operations 2/11/2007 19:30 - 21:00 1.50 EVAL P PROD1 TIW valve -Drop new core bbl -Pump down and seat same 21:00 - 22:00 1.00 EVAL P PROD1 #17 Core f/ 2337' -2361' - 238 gpm, 590 psi - 22:00 - 23:00 1.00 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 16.45' of core #17) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same 23:00 - 00:00 1.00 EVAL P PROD1 #18 Core f/ 2361'-2380' - 260 gpm, 680-920 psi (PU 101, SO - 100, RW 100, RPM 65, TO 1, WOB 3) 2/12/2007 00:00 - 00:30 0.50 EVAL P PROD1 Continue # 18 core f/ 2380' - 2385' - 231 gpm 780 psi 00:30 - 02:00 1.50 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 10.58' of core #18) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same 02:00 - 03:00 1.00 EVAL P PROD1 # 19 core f/ 2385'-2409' - 231 gpm 750 psi 03:00 - 04:30 1.50 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 21.0' of core #19) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same 04:30 - 05:30 1.00 EVAL P PROD1 # 20 core f/ 2409' to 2422 - 231 gpm, 700-900 psi - 05:30 - 07:30 2.00 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 9.58' of core #20) -Observe well - LD ', TIW valve -Drop new core bbl -Pump down and seat same ~, 07:30 - 08:30 1.00 EVAL P PROD1 # 21 core f/ 2422' to 2446 - 235 gpm, 950 psi ^ 08:30 - 10:00 1.50 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve - RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 18. i 6' of core #21) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same 10:00 - 11:00 1.00 EVAL P PROD1 # 22 core f/ 2446' to 2470' - 231 gpm, 700-900 psi - 11:00 - 12:30 1.50 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 19.33' of core #22) -Observe well - LD TIW valve -Drop new core bbl -Pump down and seat same ', 12:30 - 13:30 1.00 EVAL P PROD1 # 23 core f/ 2470' to 2494' - 243 gpm, 960 psi - 13:30 - 17:00 3.50 EVAL P PROD1 Check flow -Stand back 1 stand - M/U wireline retrieval head & TIW valve -RIH w/ wireline -Latch core bbl - POH w/ wireline - LD core bbl (recovered 24.08' of core #23) -Observe well - LD TIW valve -RIH w/drilling insert on wireline -Attempt to unlatch from bit barrel - Wireline parted near surface leaving wire and latch assembly in pipe 17:00 - 17:30 0.50 EVAL P PROD1 Pump out of hole from 2494' to 1953' (170 gpm ~ 180 psi) 17:30 - 18:00 0.50 EVAL P PROD1 CBU ~ shoe (200 gpm, 220 psi) -Flow check -Pump dry job - Slowdown top drive 18:00 - 19:00 1.00 EVAL P PROD1 POOH from 1953' to 343' -Remove wire from each stand 19:00 - 21:00 2.00 EVAL P PROD1 UD BHA -Recover latch assembly - UD core barrel and bit 21:00 - 22:00 1.00 EVAL P PROD1 Clear and clean floor - UD wireline tools -Mobilize holeopener BHA to floor 22:00 - 00:00 2.00 EVAL P PROD1 PJSM - M/U BHA (8 3/4" hole opener, float sub, MWD) - Upload MWD 2/13/2007 00:00 - 00:30 0.50 DRILL P PROD1 Continue upload MWD 00:30 - 01:00 0.50 DRILL P PROD1 P/U stand DC's, HWDP and jars 01:00 - 01:30 0.50 DRILL P PROD1 Surface test MWD 01:30 - 02:30 1.00 DRILL P PROD1 RIH to 1960' -Break circulation (420 gpm. 1280 psi) Printed: 2/26/2007 1:51:47 PM BP AMERICA Page 6 of 9 ~ Operations Summary Report Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Spud Date: 2/5/2007 Event Name: DRILL+COMPLETE Start: 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: Date ;From - To Hours Task Code NPT Phase 2/13/2007 102:30 - 07:00 I 4.501 DRILL I P I I PRODi 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:30 1.00 DRILL P PROD1 09:30 - 11:00 1.50 DRILL P PROD1 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 14:00 0.50 DRILL P PROD1 14:00 - 15:30 1.50 DRILL P PROD1 15:30 - 22:30 I 7.001 DRILL I P I I PROD1 22:30 - 23:30 I 1.001 DRILL I P I I PROD1 23:30 - 00:00 I 0.501 DRILL I P I I PROD1 ',2/14/2007 00:00 - 00:30 0.50 DRILL P PROD1 ~~ 00:30 - 01:30 1.00 DRILL P PROD1 01:30 - 02:00 0.50 DRILL P PROD1 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 04:00 1.50 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 08:30 3.50 EVAL P PROD1 08:30 - 17:00 8.50 EVAL P PROD1 17:00 - 21:00 4.00 EVAL N DFAL PROD1 21:00 - 23:30 2.50 EVAL N DFAL PROD1 23:30 - 00:00 0.50 EVAL N DFAL PROD1 5/2007 00:00 - 00:30 0.50 EVAL N DFAL PROD1 00:30 - 04:30 4.00 EVAL P PROD1 04:30 - 06:30 2.00 EVAL P PROD1 06:30 - 13:30 7.00 EVAL P PROD1 13:30 - 15:00 1.50 EVAL P PROD1 15:00 - 16:00 1.00 BOPSU P PROD1 16:00 - 18:30 ~ 2.50 ~ BOPSUFI P ~ ~ PROD1 18:30 - 19:30 I 1.001 BOPSUR P I I PROD1 19:30 - 20:30 I 1.001 EVAL I P I I PROD1 20:30 - 21:30 1.00 EVAL P PROD1 21:30 - 22:00 0.50 EVAL P PROD1 Description of Operations Open 7 7/8" hole to 8 3/4" from 1990' to 2494' - 420 gpm, 1280 psi - PUW 96k -SOW 96k -ROW 96k - TO 1-3k CBU 3x - 400 gpm 1320 psi Pump out of hole f/ 2494' - 1960' 400 gpm 1200 psi -Pull through shoe at 1954' w/ no pump CBU 1x - 400 gpm 1100 psi -Flow check -Pump dry job POH -stand back DC's - LD under-reamer MU bit, bit sub - RIH to 1245' PJSM -Cut drilling line Service rig -Top Drive, blocks, crown Continue RIH f/ 1245' to 2372' Ream /back ream from 2372' to 2463' -Wash from 2463' to 2494' Drill from 2494' to 3000' - W OB 15 -RPM 100 - TO on 2 -off 0 - -GPM470-PPon890-off 870-PU105-S0103-ROT 107 - Gas back ground 100 to 250 units - 1 Show 2746' to 2752' 600 to 2000 units CBU 3 X -Pump 30 bbl "Safe-carb 40" pill GPM 115 - PP 150 thru open hole Flow check -Pump out from 3000' to 2839" -Pump rate 375 GPM-PP 640 Pump out to shoe from 2839' to 1903' - 400 GPM @ 750 psi CBU 1 X -RPM 80 - TO 0 -GPM 415 - PP 800 -Flow check well 15 mins -Well static -Pump dry job POH from 1903' to 214' @ BHA Stand back Flex DC's -HWDP - LD Bit -Bit sub Down load MWD - LD MWD Clear rig floor of tools -Clean OBM off rig floor PJSM - Moblize equipment to rig floor -Rig up Schlumberger E-line for logging program -Load sources p(~ Run # 1 PEX, EPT, and RT Scanner - POH -Change out tools Run # 2 - OBMI -MSIP -PCC -Tool failure - POH LD MSIP - PU DSI Run # 3 - OBMI -DSI - PPC -Caliper failure - POH Change out caliper Run #4 - OBMI, DSI, PCC, w/ new caliper - POH w/ wireline LD tools - PU next run -Install sources Run #5 - CMR, ECS, HNGS PJSM - LD tools - RD wireline -clear rig floor PJSM -Drain BOP's -Pull wear ring -Install test plug - RU test equipment Test BOPE -Annular, Top VBR's -Choke manifold -Choke / Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves - Lower VBR's tested to 250 psi low, 3000 psi high for 5 minutes each -Perform accumulator test -Test Blind rams to 250 psi low, 3000 high f/ 5 min. each, Tested gas detectors and PVT's -Lou Grimaldi w/ AOGCC waived witness of test -All tests witnessed by WSL Drain stack -Close annulus valves -Pull test plug -Install wear ring -Blow down choke /kill lines MU Clean out BHA - 8 3/4" bit -Bit sub -Flex DC's -HWDP - Jars -HWDP RIH from 186 to 1950' Break circulation -CBU -GPM 300 - PP 340 Printed: 2/26/2007 1:51:47 PM BP AMERICA Page 7 of 9 ~ Operations Summary Report Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Spud Date: 2/5/2007 Event Name: DRILL+COMPLETE Start: 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: i Hours Task Code NPT Phase ate ~ rom - o l -~- 2/15/2007 ~ 22:00 - 23:00 ~ 1.00 EVAL ~ P PROD1 23:00 - 23:30 I 0.501 EVAL I P I I PROD1 23:30 - 00:00 0.50 EVAL P PROD1 2/16/2007 00:00 - 00:30 0.50 EVAL P PROD1 00:30 - 01:30 I 1.001 EVAL P PROD1 01:30 - 02:00 0.50 EVAL P PROD1 02:00 - 02:30 0.50 EVAL P PROD1 02:30 - 03:00 0.50 EVAL P PROD1 03:00 - 06:00 3.00 EVAL P PROD1 06:00 - 08:00 2.00 EVAL P PROD1 08:00 - 08:30 0.50 EVAL P PROD1 08:30 - 12:00 3.50 EVAL P PROD1 12:00 - 14:00 2.001 EVAL P PROD1 14:00 - 19:00 I 5.001 EVAL I P I I PROD1 19:00 - 00:00 5.00 EVAL P PROD1 2/17/2007 00:00 - 07:30 7.50 EVAL P PROD1 07:30 - 18:00 10.50 EVAL P PROD1 18:00 - 18:30 0.50 EVAL P PROD1 18:30 - 19:00 0.50 EVAL P PROD1 19:00 - 21:30 2.50 EVAL P PROD1 21:30 - 22:30 1.00 EVAL P PROD1 22:30 - 00:00 1.50 EVAL P PROD1 2/18/2007 00:00 - 02:00 2.00 EVAL P PROD1 02:00 - 03:00 I 1.001 EVAL I P I I PROD1 03:00 - 05:00 2.00 EVAL P PROD1 05:00 - 06:30 1.50 EVAL P PROD1 06:30 - 07:30 1.00 PXA P ABAN 07:30 - 08:00 0.50 PXA P ABAN 08:00 - 09:30 1.50 PXA P ABAN 09:30 - 11:00 I 1.50 I PXA I P I I ABAN 11:00 - 12:00 I 1.00 I PXA I P I I ABAN 12:00 - 13:30 1.50 PXA P ABAN 13:30 - 16:30 3.00 PXA N WAIT ABAN 16:30 - 17:30 1.00 PXA P ABAN Description of Operations Con't RIH to 2350' - 2218 and 2282' 5 to 8K down weight - Break circulation - Con't RIH from 2350' to 3000' CBU 2 X -GPM 400 - PP 680 -RPM 50 - TO 1 -Flow check - Well static Pump out from 3000' to 2525' -GPM 350 - PP 525 Pump out to shoe from 2450' to 1950' -GPM 400 - PP 650 - (Pin on bottom stand # 22 washed -replace when trip in hole) CBU 1.75 X -GPM 400 - PP 670 -RPM 50 - TO 1 -Flow Check -Well static -Pump dry job POH from 1950' to 186' Stand back BHA Clear floor -Clean up OBM off rig floor PJSM - Moblize ! MU MDT tools -Surface test same MU SWS XO -RIH w/ DP from 122' to 1813' CBU 1 X - 230 gpm, 120 psi. -Blow down top drive PJSM - RU side entry sub & wireline -RIH w! latch head - Pump down same w/ 340 gpm 240 psi -Observe pressure increase of 50 psi when latched -Test tools -Secure W.L. to SES -Blow down T.D. RIH f/ 1815' to 2142' (btm of tool depth) -Spot packers at 2130' - Test and calibrate tools -PUW 90 -SOW 90 Tool set C~3 2161' -Run open hole MDT's -Release packers - (No over pulls noted when string picked up) Reset tool ~ 2151' -Run open hole MDT's Run MDT's -Tool set 2151' -Release packers Move tool up to 2047' -Set packers -Run MDT's -Packer seal failed at end of D-1 interval test Move probe to 2038' -Probe seal failure Move probe to 2031' -Probe seal failure Move probe to 2025' - D2 interval test Move probe to 2036' - D3 interval test Move probe to 2012' - D4 interval test - MDT's completed POH to side entry guide -Release line from guide - POH with line - RD wire line sheaves SWS equipment -Clear rig floor CBU -GPM 255 - PP 130 psi -Flow check - 15 mins -Well static -Pump dry job POH to SWS MDT tools PJSM - LD MDT tools -Clear rig floor LD Flex DC's - HWDP -Jars RU 3 1/2" Tubing equipment -Handling equipment PJSM - PU 3 1/2" mule shoe - 21 joints 3 1/2" tubing - XO's - 684' RIH from 684' to 1950' (4' above 9 5/8" shoe) -Circ. Pipe volume w/ 264 gpm, 240 psi -Continue RIH to TD at 3000' Circ. & reciprocate -Condition mud for cement job - 424 gpm, 560 psi -PUW 95k, SOW 95k PJSM w/ Schlumberger/Dowel) - RU cement head & lines Wait on VECO truck - Contnue to circ. - 356 gpm, 610 psi Give to Schlumberger Pump 8 bbls CW 100 spacer Test lines to 2500 psi Pump 55.5 bbls Cement mixed ~ 15.7ppg yield .93 304 sxs Pump 2 bbls water Printed: 2/26/2007 1:57:47 PM BP AMERICA Operations Summary Report Page8of9~ Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Spud Date: 2/5/2007 Event Name: DRILL+COMPLETE Start: 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code i NPT Phase I Description of Operations 2/18/2007 16:30 - 17:30 1.00 PXA P ARAN 17:30 - 18:00 0.50 PXA P ABAN 18:00 - 18:30 0.50 PXA P ABAN 18:30 - 21:30 3.00 PXA P ABAN 21:30 - 00:00 I 2.501 PXA I P I I ABAN 2/19/2007 100:30 - 01:00 I 0.501 PXA I P I (ABAN 01:00 - 10:00 9.00 PXA P ABAN 10:00 - 11:00 1.00 PXA P ARAN 11:00 - 22:00 11.00 PXA P ARAN 22:00 - 22:30 I 0.50 I PXA I P I I ABAN 22:30 - 00:00 I 1.501 PXA I N I DPRB I ABAN 2/20/2007 100:00 - 03:00 I 3.001 PXA I N I DPRB I ABAN 03:00 - 06:00 I 3.00 I PXA I N I DPRB I ABAN 06:00 - 10:30 I 4.501 PXA I P I I ABAN Displace with rig 34.3 bbls OBM CIP ~ 17:22 hrs Break off cementing lines -Pull 8 stands 5" dp to 2280' Pump 25 bbl nut plug pill - 500 gpm @ 630 psi - No cement seen on bottoms up - Circulate well while waiting on cement to thicken -RIH tag cement @ 2305 -Wash to 2310 -CBU -GPM 450 - PP 600 - LD 2 joints - RU cementing lines Give to Schlumberger - Pump 2 bbls water Test lines to 2500 psi Flush water thru wash up line with Mud Push 10.7 ppg Pump 8 bbls Mud Push mixed ~ 10.7 ppg Pump 55.5 bbls Cement mixed @ 12.8 ppg -Yield 2.26 - sxs 147 Pump 3 bbls Mud Push mixed @ 10.7 ppg Displace with 21.8 bbls OBM CIP 23:45 hrs Pull 8 stands from 2305' to 1514' Pump Wiper ball / 25 bbl nut plug pill - No Cement back to surface -CBU 2 X -GPM 510 - PP 600 -Stand back 1 stand @ 1419' WOC - RD mud chiller unit -Flush unit -suck out all lines - Empty all but 1 pit of OBM -Clean pit # 4 for WB Gel Mud - LD 5" DP from derrick using mousehole - Displace well w/ 10.7 ppg water based gel/bar drilling mud from1520' - 190-380 gpm, 130-320 psi Continue to circulate w/ 3 bpm, 140 psi at 1520' while W.O.C. - Con't clean pits -Clean Rig of OBM -Clean drip pans under pipe rack area of OBM -Clean drip pans under rig floor of OBM RIH from 1526' to 1745' -Tag soft cement taking 1 K Con't to 1750' still would not hold weight - PU to 1700' Break circulation - Pump 1.7 bpm C~ 210 psi -Wash from 1700' to 1806' -Last 3 to 4 feet taking 2K with increase of 30 psi on pump pressure - Cement would not hold weight -Pull back to 1715' -Lou Grimaldi with AOGCC on location to witness tagging plug - WOC additional 8 hrs CBU -GPM 254 - PP 420 -Cement contaminated mud -Green cement back to surface - (3 to 5 bbls green cement back) - Overboard cement, cement contaminated mud to rock washer - 80 to 85 bbls Flush BOPs from well head with treated water -Function close / open Top / Btm rams - Annuluar -Flush stack with treated water -Flush choke -Choke line -Kill line with treated water - Clean under shakers -possum belly -flow line -trough -Clean out rock washer Circulate well @ 1800' - on bottoms up ~ 1800' 2 bbls green cement back to surface -Treating cement contaminated mud adding water, sap - 3 to 8 bpm - PP 240 to 186 - Vis 40 -Mud wt 9.0 in and out Flow check well -Pump dry job - LD 5" dp 8 stands to pipe shed Printed: 2/26/2007 1:51:47 PM BP AMERICA Operations Summary Report Page9of9~ Legal Well Name: Mt Elbert Hydrate Well Common Well Name: Mt Elbert Hydrate Well Spud Date: 2/5/2007 Event Name: DRILL+COMPLETE Start: 2/3/2007 End: 2/25/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/21/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task ~ Code ( NPT ~ Phase Description of Operations 2/20/2007 10:30 - 11:00 0.50 PXA P ABAN 11:00 - 12:00 1.00 PXA P ABAN 12:00 - 12:30 0.50 PXA P ABAN 12:30 - 14:30 2.00 PXA P ABAN 14:30 - 18:00 I 3.50 I PXA I P I I ABAN 18:00 - 19:00 1.00 PXA P ABAN 19:00 - 21:00 2.00 PXA N WAIT ABAN 21:00 - 23:00 2.00 PXA P ARAN 23:00 - 00:00 1.00 PXA P ABAN 2/21/2007 00:00 - 01:00 1.00 PXA P ABAN 01:00 - 03:00 2.00 PXA P ABAN 03:00 - 04:00 1.00 PXA P ABAN 04:00 - 04:30 I 0.50 I PXA I P I I ABAN 04:30 - 06:30 2.00 PXA P ARAN 06:30 - 07:30 1.00 PXA P ABAN 07:30 - 12:00 4.50 PXA P ABAN 12:00 - 14:30 2.50 PXA P ABAN RIH 8 stands from derrick Displace well to 10.7 ppg -Gel /Bar drilling mud -GPM 170 to 230 - PP 80 to 130 Flow check -Pump dry job LD 5" drill pipe 1 x 1 - RU with 3 1/2" power tongs -Change out handling equipment - LD 3 1/2" tubing 1 X 1 -Stand 2 stands in derrick Pull wear bushing -RIH with 3 1/2" tubing to 250 feet - RU head pin -Cement hoses - RU to upper annulus to flowline and cement line -Blow air clear lines - RD cementing lines - PJSM - LD 3 1/2" tubing - RU to test casing RU test equipment -Test casing to 500 psi for 30 mins - Record on chart - RD test equipment Wait on bridge plug -Remove stairs -Install front booster frame PU / MU 9 5/8" EZ-SVB Howco bridge plug -RIH set ~ 284' - POH LD 5" DP - LD running tool - RU test equipment -Test to 1000 psi - RD test equipment Change out handling tools - PU mule shoe 8 jts 3 1/2" tubing to 284' -Displace 10.7 gel mud to fresh water Displace 10.7 gel mud to fresh water RU head pin -Cement hoses - RU to upper annulus to flowline and cement line -Blow air through lines -tubing Close bottom VBR's 3 1/2" X 6" -Open annulus valve going to pits -Give to Schlumberger Pump 5 bbls water Test lines to 1000 psi Pump 29 bbls 15.7ppg Artic set cement Pump 1 bbls water Flush across well head with treated water taking returns to rock washer Bleed off any pressure Open bottom VBR's Pull 3 1/2" tubing to 39' - RU head pin /circulating lines -Close bottom VBR's flush well head and 9 5/8" casing to 5' below ground -Flush well head and injection line to flow line with treated water -Open rams - LD remaining tubing LD 3 1/2" tubing - LD Tubing equipment Blow down lines to stack -Suck out stack ND stack -Remove well head and clean up cellar box - Confirmed cement depth 5 ' below GL. - Con't clean pits /rock washer -Prep rig for release -Release rig ~ 14:30 hrs Printed: 2/26/2007 1:51:47 PM Halliburton Company Survey Report - -- --- Cumpamy: BP Amoco Date: 2'26'2001 Time 11:30:54 Pa~c 1 I~icld: Milne Point Co-ordinatc~Vi~:)Re1'crence: W ell: Mt Elbert, Tru e North Site: Milne Point Exploration Vertical f~f~ Di Refer ence: Mt . Elbert: 54.8 I Well: Mt Elbert Section (VS) Referen ce: W ell (O.~JON,O-OOE. 77.91 P,zi} i ~t~ellpatb: Mt. Elbert Survey Calculation b lcthod: Mi nimurn Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: Mt Elbert Slot Name: Well Position: +N/-S -7471.29 ft Northing: 6016603.73 ft Latitude: 70 27 20.313 N +E/-W31994.48 ft Easting : 572198.95 ft Longitude: 149 24 38.857 W Position Uncertainty: 0.00 ft Wellpath: Mt. Elbert Drilled From: Well Ref. Point 500292330200 Tie-on Depth: 33.70 ft Current Datum: Mt. Elbert: Height 54.80 ft Above System Datum: Mean Sea Level Magnetic Data: 2/4/2007 Declination: 23.65 deg Field Strength: 57626 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.70 0.00 0.00 77.91 Survey Program for Definitive Wellpath Date: 2/26/2007 Validated: Yes Version: 8 Actual From To . Survey Toolcode Tool Name ft ft 162.00 2979.60 Mt. Elbert IIFR+MS+Sag (162.00 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD Sys TVD N/S E/VV MapN n1apE Tool ft deg deg ft ft ft ft ft ft 33.70 0.00 0.00 33.70 -21.10 0.00 0.00 6016603.73 572198.95 TIE LINE 162.00 0.06 320.93 162.00 107.20 0.05 -0.04 6016603.78 572198.91 MWD+IFR+MS 246.24 0.45 202.46 246.24 191.44 -0.22 -0.20 6016603.51 572198.76 MWD+IFR+MS 340.36 0.29 216.39 340.36 285.56 -0.75 -0.48 6016602.97 572198.48 MWD+IFR+MS 430.19 0.17 176.44 430.19 375.39 -1.07 -0.61 6016602.66 572198.35 MWD+IFR+MS 518.27 0.09 150.87 518.27 463.47 -1.26 -0.56 6016602.47 572198.40 MWD+lFR+MS 609.84 0.18 147.26 609.84 555.04 -1.44 -0.45 6016602.28 572198.51 MWD+IFR+MS 698.51 0.20 147.66 698.51 643.71 -1.69 -0.29 6016602.04 572198.67 MWD+IFR+MS 786.12 0.23 118.31 786.11 731.31 -1.90 -0.06 6016601.83 572198.91 MWD+IFR+MS 882.17 0.42 113.57 882.16 827.36 -2.14 0.44 6016601.60 572199.41 MWD+IFR+MS 975.58 0.33 102.02 975.57 920.77 -2.33 1.01 6016601.41 572199.99 MWD+IFR+MS 1070.66 0.34 83.83 1070.65 1015.85 -2.36 1.56 6016601.39 572200.53 MWD+IFR+MS 1165.63 0.20 67.31 1165.62 1110.82 -2.26 1.99 6016601.49 572200.97 MWD+IFR+MS 1259.05 0.28 63.56 1259.04 1204.24 -2.10 2.35 6016601.66 572201.32 MWD+IFR+MS 1350.35 0.32 60.31 1350.34 1295.54 -1.87 2.77 6016601.89 572201.74 MWD+IFR+MS 1444.45 0.50 75.56 1444.43 1389.63 -1.64 3.40 6016602.12 572202.36 MWD+IFR+MS 1540.04 0.33 56.41 1540.02 1485.22 -1.38 4.03 6016602.39 572202.99 MWD+IFR+MS 1633.47 0.26 62.31 1633.45 1578.65 -1.14 4.44 6016602.64 572203.40 MWD+IFR+MS 1728.25 0.26 61.74 1728.23 1673.43 -0.93 4.82 6016602.84 572203.78 MWD+IFR+MS 1821.42 0.19 69.88 1821.40 1766.60 -0.78 5.15 6016603.00 572204.11 MWD+IFR+MS 1914.28 0.19 121.20 1914.26 1859.46 -0.81 5.43 6016602.98 572204.39 MWD+IFR+MS 2070.49 0.43 124.32 2070.47 2015.67 -1.27 6.13 6016602.52 572205.10 MWD+IFR+MS 2163.45 0.44 125.26 2163.42 2108.62 -1.67 6.71 6016602.12 572205.68 MWD+IFR+MS 2257.92 0.28 65.38 2257.89 2203.09 -1.79 7.22 6016602.01 572206.19 MWD+IFR+MS 2352.35 0.36 43.82 2352.32 2297.52 -1.48 7.64 6016602.33 572206.60 MWD+IFR+MS 2442.60 0.44 24.99 2442.57 2387.77 -0.96 7.98 6016602.85 572206.94 MWD+IFR+MS 2534.99 0.44 39.62 2534.96 2480.16 -0.36 8.35 6016603.45 572207.31 MWD+IFR+MS 2631.61 0.39 23.63 2631.57 2576.77 0.22 8.72 6016604.04 572207.67 MWD+IFR+MS 2726.67 0.25 352.36 2726.63 2671.83 0.73 8.82 6016604.54 572207.77 MWD+IFR+MS 2821.17 0.33 346.27 2821.13 2766.33 1.19 8.73 6016605.01 572207.67 MWD+IFR+MS • H 11' m • a iburton Co pany Survey Report Company: BP AmoCO Date: 2/26/2007 Time: 11:0:54 Pagc: 2 j Field: Milne Point Co-ordinate(NE) Reference: Welf: Mt Elbert, True North Site: Milne Point Exploration Vertical (TVD) Reference: Mt. Elbert: 54.8 Wcll: Mt Elbert Section (VS) Reference: Well (O.OON,0-OOE,77.91 Azi) Wellpath: Mt. Elbert SurveyCalculation Method: Minimum Curvature Db: OraC(e ~ Survey' MD Incl Aiim TVD Sys T~ D N/5 E/W MapN MapE Tool ft deg deg ft tt ft ft ft ft 2914.70 0.19 349.26 2914.66 2859.86 1.61 8.64 6016605.42 572207.57 MWD+IFR+MS 2979.60 0.14 346.15 2979.56 2924.76 1.79 8.60 6016605.60 572207.53 MWD+IFR+MS 3000.00 0.14 346.15 2999.96 2945.16 1.84 8.59 6016605.65 572207.52 PROJECTED to TD BP AMERICA Page 1 of 1 Leak-Off Test Summary Legal Name: Mt Elbert Hydrate Well Common Name: Mt Elbert Hydrate Well Test Date Test Type Test Depth (TMD) Test Depth (TVD) ~' AMW j Surface Pressure Leak Off Pressure (BHP) EMW • Printed: 2/26/2007 1:51:42 PM REEDHycalog Coring Services 816 North Circle Drive Casper, Wyoming 82601 ~~ _ ~ i ~ Cp ri f"f ~ s@ rY ~ C @S WELL SUMMARY ^ 0 ^ ~ O b 11 diamond ATM:=~~:~ <_ Customer Well Name Drilling Contractor State Barrel Number Hole Size Date Start 10-Feb Date Finish 12-Feb Coring Technicians BP MT. Elbert Doyon Rig #14 Alaska HDCE 25 8 3/4 Time Start Time Finish Kevin Leroux :28 1:31 Rusty Linn Job Number Date Company Man County Barrel Size Hole Angle 1847 12-Feb-07 Jerry H 6.5x4.25x24 Bit Type Bit Size Serial Number Damage Total Feet CSS-513 7 718x3 DDD-038 CSS-513 7 718x3 Total Footage: 504 Core # Bit # Depth In Depth Out Feet Drilled Feet Cored Feet Recd Time (mins) Formation 1 1 1990 2014 24 17.10 58 2 1 2014 2038 24 23.60 59 3 1 2038 2062 24 23.40 21 4 1 2062 2086 24 24.00 16 5 1 2086 2110 24 23.60 22 6 1 2110 2134 24 24.50 23 7 1 2134 2158 24 24.50 17 8 1 2158 2180 22 19.90 20 9 1 2180 2190 10 2.60 28 10 1 2190 2200 10 6.30 30 11 1 2200 2218 18 14.40 53 12 1 2218 2241 23 20.80 51 13 1 2241 2265 24 22.80 20 14 1 2265 2289 24 19.30 32 15 1 2289 2313 24 20.60 49 16 1 2313 2337 24 23.30 39 17 1 2337 2361 24 16.50 44 18 1 2361 2385 24 10.60 48 19 1 2385 2409 24 20.80 44 20 1 2409 2422 13 9.60 45 21 1 2422 2446 24 18.20 60 22 1 2446 2470 24 19.30 67 23 1 2470 2494 24 24.10 41 Totals 504 429.80 887 Recovery 85.3% Coring ROP (feet /hr) 34.1 Drilling ROP (feet/hr) Core was boxed by Core Barrel Serviced ? Parts Used or Notes Omni Core was Delivered to Reason Bit Pulled Wireline busted while setting drill insert Via corrected by Collett 3/7/07 S. Thornhill Mt Elbert-Oi MDT.xIs 3!21/2007 • • Date 04-10-2007 Transmittal Number:92884 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 MT ELBERT-01 04-01-2007 BPXA MILNE POINT CORE PHOTOS CD ROM ~~ P1 ase Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Howard Okland r~ ~ ~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~v~-- ~ 33 Laboratories, Inc. State of Alaska Oil and Gas Conservation Comm. 333 7`I' Ave Anchorage, AK OMNI Laboratories, Inc. 3209 Denali St. Ancharage, Alaska 99503 907-646-8605 REC~10iED Chip Samples BP Alaska APR ~ ~ 2081 Mt. Elbert-Ol ssi0a Milne Point Field ~,laska Oil & Gas Cons• ~~ North Slope, AK ArN Depths: Additional samples 1990,1992, 2006, 2014, 2034, 2193, 2221, 2323,and 2363. ~ ..e.~,rt Signed: ~~`~~ Dave Foster Omni Labs r- , 1~ ' ~ „~ . ,~_.~-~ State of Alaska: ~isq ~~to-~,~ Re: FW: Mt. Elbert Hydrate P & A Subject: Re: FW: Mt. Elbert Hydrate P & A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 06 Apr 2007 11:18:27 -0800 'f'o: "Kara, Dann~~ T" ~-Dai~nv.Kara~n~b}~.~om~~:, Dan, 3' is the minimum depth it must be cut, so it appears no problem. Tom Maunder, PE AOGCC Kara, Danny T wrote, On 4/6/2007 11:07 AM: -033 Tom. The regulations state that cutting the casings need only be 3' below surface (original tundra level). I have 4' stated below. We would rather cut only 3' due to the extra excavation rertuired for going deeper. We're not going to excavate any deeper than necessary because of confined space entrylshoring up gravel walls, etc for safety. I would like to change the plan from cutting 4' to cutting 3' below ground ievel. ': Are you OK with that? Dan From: Thomas Maunder [mailto:tom maunder@admin.state.ak,us] Sent: Friday, February 23, 2007 1:50 PM To: Kara, Danny T Cc: Hanson, Paul; Bob Gardner (Fairweather); NSU, ADW Drlg Field Engr; Rose, John G (FAIRWEATHER); AOGCC North Slope Office Subject: Re: FW: Mt. Elbert Hydrate P & A Dan, Although the surface work was not described in Paul's email, that work must be accomplished to finish the "A" part of the work. I will attach this message to the sundry. By copy of this message, you have "verbal" approval to proceed. Contact the Inspectors as you have noted. Call or message with any questions. Tom Maunder, PE AOGCC Kara, Danny T wrote, On 2/23/2007 12:52 PM: Tom, ', The Mt. Elbert P&A summary listed in the a-mail from Paul Hanson does not include the surface abandonment information -only down hole abandonment operations completed by the rig are included. A summary of planned aperations for the surface abandonment is as follows: - The wellhead has already been removed by the rig - Excavate and remove well cellar. Extend excavation to about 6' below original tundra level - Rig up Wachs cutter -cut both the 20" conductor and 9-5i8" casing 4' below original tundra level s 1 of 3 4/6/2007 11:47 AM Re: FW: Mt. Elbert Hydrate P & A - Fili any voids in annular space, if present, and photo-document cement at surface before installing marker plate - Notify AOGCC Inspector to witness TOC - Weld well marker plate on outermost casing string as per 20 AAC 25.120. Photo-document. Notify AOGCC Inspector to witness plate. Backfill excavation to original tundra elevation as per 20 AAC 25.170 Clean up location and obtain final location inspection from AOGCC and DNR, if applicable 2 of 3 Please contact me if there is any additional information required for this abandonment. Thanks for your time. Dan From: Hanson, Paul Sent: Friday, February 23, 2007 10:34 AM To: Kara, Danny T Subject: FW: Mt. Elbert Hydrate P & A From: anson, Paul Sent: Friday, bruary 16, 2007 2:04 PM To: 'tom maunderaa in.state.ak.us' Cc: Kara, Danny T Subject: Mt. Elbert Hydrate P & A Tom, This is a brief summary of the P&A plan. A told you on the phone, i don't think we'll get to this over the weekend, but i can't rule it out. Seta 15.7 ppg ArcticSet plug (approximately 66 bbl suming 10% excess) from 3,000 to 2200', which is the approximate depth of the water zone. I intentionally ade the excess small because if the plug level is deeper than 2200` it will just increase the standoff from th ydrate zone. Pull out and circulate out catching spacers. Set the 12.5 ppg t_iteCrete from --2200' to 1754' (200` above the sh }. I estimate the volume at 40 bbl assuming 30% excess. If top is higher, that's fine. Circulate out as ab e per Mi's recommendation to save as much MOBM as possible. The LiteCrete has about one third the heat hydration as the Arctic Set, so the goal is not to "stir up" the hydrates as the cement sets. At this point, we'll C per SLB and tag to confirm top. After that; N envision displacing out the remaining MOBM using a 10.7 ppg gellbar m per Ml. This shouid come from the mudplant and be pumped directly off the truck, saving as much MOB a ossible. Now set the 250` 10,7 ppg Arctic Set on top. it is desired to have TOC within 5' of surface wherl~te're all 11:47 AM Date 03-20-2007 .:z<y .> Transmittal Number:92880 .,,.~ n~ .~-. ' ~~. ~~~ F. ~~ 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 op De th Bottom De th Lo T e T ELBERT-01 3-19-2007 PXA MILNE POINT SUMMARY OF WIRELINE FORMATION TEST CD-ROM / PPT & PDF FORMAT ~ 1 ~.s3 ~ n Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Kristin Dirks Howard Okland Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RECEIVED MAR 2 0 2007 ~laslca Od & Gas Cons. Commission ~,oc.- 033 A , ~+ - 5 a ` ~ / ' t '~ ,~~ LZiIA~7~,®i~/ Al~i1 ~-7 COI~TSERQA~'IO1~T COl-II~iISSIOI~T Dan Kara Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ,', SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Unit, Exploration, Mt. Elbert-Ol Sundry Number: 307-069 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. \111 /~PY'P~~ T DATED thisvl~ay of February, 2007 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ FEB 2 0 2007 ~a APPLICATION FOR SUNDRY APPROVAL p~aska Oil & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ®Exploratory - 206-033 - ~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-23302-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Mt. Elbert-01 `- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028231 ~ 24 ~ Milne Poini Unit 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3000 3000 2310 2310 2310 None C sin L n th iz MD TVD Burst Colla se Structural Conductor 112' 20" 112' 112' 1530 20 Surface 1920' 9-5/8" 1954' 1954' 5750 3090 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None N/A Packers and SSSV Type: None Packers and SSSV MD (ft): N/A 13. Attachments:' 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ~ ®Exploratory ^ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 18th, 2007 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: t.(Date: 2/16/2007 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Signature ~-~~, Phone 564-5667 Date Z-~t9 o•~r Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: _ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ocation Clearance ~ Other: cA~~~'i~S (~~ ~----~tJ ~ ~`~'h.~SS Lv`~~ W ~' ` rC ~~ ~~ C? ~ vs ~- S ~ m ~, I - ~@.. 4"i ~'1 N ~ f~V'UF Subsequent Form Required: ~~ APPROVED BY ~. D A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 V v ~ / Submit In Duplicate ~<~~~I~~~ ~ ~/~6~7~ Z~~~7 Mt. Elbert Weekly Report - 2/16 thru 2/21 Subject: Mt. Elbert Weekly Report - 2/16 thru 2/21 Froth: "Hansol3, Paul" <Paul.Hansonl~bp.com> Date: Fri, 23 Feb 2007 11:19:38 -0900 'f'o: ~[~hontas Maunder <tom ntaund~r(u<<dmin.statc.ak.us> CC': "Kara, DatlnyT" <Danny.Kara(~i<hp.com== WEEK 1 REPORT ~lCti~;c~ Jr~ 1. February 3, 2007 - Doyon 14 was released from MPS-33A at 0:500 and commenced operations to move to the Mt. Elbert Ice Pad (south of Milne Point B-Pad). Rig was accepted at 22:00. (MIRU). 2. February 4, 2007 - N/U diverter, C/O Saver Sub, Diverter test witnessed by Jeff Jones of AOGCC, PU drillpipe and rig up mud loggers. Pre-spud meeting. 3. February 5, 2007 -Spud, Drill out conductor to 275' MD/TVD and trip for BHA#2. Drill to 1289' MD. 4. February 6, 2007 -Drill to TD of surface hole at 1960'. Circulate hole clean and pump out to 823'. RIH to TD Circulate. POOH. R/U to run casing. 5. February 7, 2007 -Run 9-5/8" 40# casing and Cement. Pumped 80 bbls MudPush @ 10.2 ppg. Pumped 216 bbl 10.7 ArcticSet Lite followed by 77 bbl 15.7 ppg, got 57 bbl of cement back. 6. February 8, 2007 - NU and Test BOPE to 3000 psi as witnessed by Jeff Jones-AOGCC. MU BHA#3, RIH and test casing to 2000 psi for 30 min. on chart (GOOD TEST), POOH. Conduct practice runs with CORION (REED-HYCALOG) wireline retrievable coring system. WEEK 2 REPORT C~c~~wc c~ ~` (~ ~, 7. February 9, 2007 -Drilled out shoe and 20' of new hole, circulated 1 BU and conducted LOT to 13.6 ppg EMW. CBU and monitor well, POOH. Rig up CORION wireline system. PJSM with Coring and Core handling crews. 8. February 10, 2007 -Coring runs 1 - 8. 9. February 11, 2007 -Coring runs 9 - 18. 10. February 12, 2007 -Coring runs 18 - 23. Complete Coring with ~85% recovery. Hydrate was recovered in all but 2 of the first 10 cores. Cores 4 & 5 did not have hydrates. A water contact was identified at ~ 2200'. POOH with Corion. Coring Interval Summary: MD Cut (ft) Recovered (ft) Core #1 1990-2014 24' 17.1 Core #2 2014-2038 24' 23.6 Core #3 2038-2062 24' 23.4 Core #4 2062-2086 24' 24.0 ~ ~ 9 ~ Core #5 2086-2110 24' ~ .~ ho rcz. 23.7 Core #6 2110-2134 24' 24.5 Core #7 2134-2158 24' 24.5 Core #8 2158-2180 23' 20.0 Core #9 2180-2190 10' 2.6 Core #10 2190-2200 10' 6.3 1 of 3 2/23/2007 11:25 AM Mt. Elbert Weekly Report - 2/16 thru 2/21 • • MD Cut (ft) Recovered (ft) Core #11 2200-2218 18 172.5 Core #12 2218-2241 23 20.8 Core #13 2241-2265 23 22.8 Core #14 2265-2289 24 19.3 Core #15 2289-2313 24 20.6 Core #16 2313-2337 24 23.3 Core #17 2337-2361 24 16.5 Core #18 2361-2385 24 10.6 Core #19 2385-2409 24 21.0 Core #20 2409-2422 13 9.6 MD Cut (ft) Recovered (ft) Core #21 2422-2446 24 18.17 Core #22 2446-2470 24 1.61 Core #23 2470-2494 24 24.08 TOTAL 1990-2494 504 429.88 11. February 13, 2007 -Opened 7-7/8" hole to 8-3/4" to 2,494'. POOH. PU 8-3/4" Bit/BHA w/MWD GR and drill to TD at 3,000'. CBU X 3 and POOH. 12. February 14, 2007 -Continue POOH to shoe. Flow Check and CBU. POOH. Clear rig floor and rig up Schlumberger a-line for logging runs. Log runs 1,2 &3. 13 . February 15, 2007 - Complete logging runs 4 & 5. (Re-runs for tool problems). POOH and rig down SLB. Test BOPs. MU Cleanout BHA and run to bottom - no problems. CBU x 1.75 and POOH. Stand back BHA and MU MDT tools. WEEK 3 REPORT 14. February 16, 2007 - PU MDT tools and RIH and test tool. Set tool at 2161' and conduct 5-hour test. Reset tool at 2151' and commence testing. 15. February 17, 2007 - Completed 10.5-hour MDT at 2151' and move tool. Had some problems with sealing failures at two different stations. Tested D2 interval @ 2025' for 2.5 hrs. Tested D3 interval @ 2036' for 1 hr. and D4 interval @2012' for 1.5 hrs. Good tests. MDTs complete. 16. February 18, 2007 - POOH and lay down MDT tools. Lay down collars, jars etc and RU tubing stinger to set cement plugs. Plug 1 : 8 bbt CW 100 spacer, 55.5 bbl 15.7 ppg ArcticSet, and 2 bbl water in ballanced plug. Cement in place at 17:22 hrs. Tag at 2305', wash to 2310'. Pump Plug 2: 8 bbl water, 55.5 bbl 12.5 LiteCrete, 3 bbl MudPush @ 10.7 ppg. CIP at 23:45. WOC. 17. February 19, 2007 - WOC. Soft tag at 1745' (22:00 hr). Continued on to 1806' Saw approximately 2K Ibs on indicator as witnessed by Lou Grimaldi. Circulate out cement contaminated mud. WOC additional 8 hrs. 18. February 20, 2007 - WOC. Pressure test plug to 500 psi for 30 minutes and record on chart. 500 psi with 10.7 ppg mud was equivalent to 15.5 ppg EMW. This was 1.9 ppg over the original L.O.T. Set HOWCO bridge plug at 284' MD and test to 1000 psi. Displace mud above plug to water. 19. February 21, 2007 - Pump 5 bbl water, 29 bbl 15.7 ppg ArcticSet. Flush excess cement to 5' below ground level. Lay down cement stinger, etc. ND stack and confirm cement top. Clean pits, RD and prepare for move to Liviano-01 location. Release rig at 14:30. 2 of 3 2/23/2007 11:25 AM Mt. Elbert Weekly Report - 2/16 thru 22l Rig was accepted at 19:00 yesterday, and spud should occur this afternoon. Thank you for your help during this "adventure". Best Regards, Paul Hanson 3 of 3 2/23!2007 ] 125 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~} ~ DATE: February 20, 2007 P.I. Supervisor ~ ~~~ ~ Z ~ THRU: FROM: Lou Grimaldi Petroleum Inspector SUBJECT: Plug & Abandonement Mt Elbert #1 BP Exploration Kuparuk River Field Milne Point Unit PTD #206-033 NON- CONFIDENTIAL Section: 30 Township: 13N Range: 11 E Meridian: Umiat Lease No.: ADL 028231 Drilling Rig: Rig Elevation: 31 Total Depth: 4000 Operator Rep.: Haberthur/Brown Casin9lTubing Data: Casing Removal: Conductor: O.D. Shoe@ Casing Cut@ Feet Surface: 95/8 O.D. Shoe@ 1954 Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plugging Data: ' Tvpe Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom uo- of Cement Depth Verified? above plus Test Applied 3000-2200 ~ Bottom 3000 2200 DP to not wit. No 2200 Bottom lu 2200 1806 DP to failed ~ ~ I Tvpe Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface The tag of the top plug failed, circulated out cement like substance after 22 hour thickening time. Sent sample to Dowell lab for analysis. Sample came back unsuitable for plug integrity. cc; Attachments: Distribution: a~ ~~,,~~ ~p !,~ ~,,,r, orig -Well File l~c.'Te- - ~ ~'w'~~" t'~~ ~`~ L1~ ~ ~ -rte c - O erator $ c - DNR/DOG Z~"ZtI ~ Z~i;~ %a.S ~ (~.~~ ~e:5 c -Database ~ ,~ c - Rpt File ~' Z ~'l~'°' ' "`~L~ ~ ~,LL c ~~~ c -Inspector ~ ~,. Rev.:5/28/00 by L.R.G. Plug verification Mt Elbert 02-20-07 LG.xls 2/22/2007 RE: P & A Plug on Mt Elbert Hydrate Well Subject: RE: P & A Plug on Mt Elbert Hydrate Well From: "Hanson, Paul" <PauLHansonl@bp.com> Date: Tue, 20Feb 2007 12:52:18 -0900 To: Thomas I~1au~~dtr ~~tom maunder(~ladmin.state.ak.us== Thank You! Best Regards, Paul From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, February 20, 2007 11:09 AM To: Hanson, Paul Subject: Re: P & A Plug on Mt Elbert Hydrate Well • Paul, Your understanding is correct. Lou called me this morning and related the information you have included below. It appears that cement was clearly encountered above the depth listed in the regulations for cement height. It is acceptable to continue with the surface plug as planned. Tom Maunder, PE AOGCC Hanson, Paul wrote, On 2/20/2007 11:02 AM: Tom, It is my understanding that you are aware of recent events on the Mt. Elbert Hydrate well concerning the upper cement plug inside the 9-5/8" casing. To recap, while Lou Grimaldi was out on Doyon 14 last night they ran in the hole to tag cement prior to continuing with the abandonment. At approximately 1745' the tagged "soft" cement taking about 1000 Ibs on the weight indicator. They picked up to 1700' and washed from 1700' to 1806', with the last 3-4 ft they saw about 2000 Ibs on the indicator and a corresponding increase in pump pressure. At this time they POOH to 1715' and circulated, electing to wait an additional 8 hours. While circulating they brought back an estimated 6 bbl of green cement. Since last night the mud engineer tested pH and exposed the sample to phenophthalein. In addition, he did a calcium titration. All tests confirm cement. A sample has also been sent to SLB for confirmation that the returns were cement. All these tests should confirm that we have cement to 1806', which is 148' inside casing. It is my understanding that Lou Grimaldi has spoken with you, and if the returns are indeed cement, then BP is clear to proceed with the surface abandonment as planned and the State is satisfied that we have brought cement at least 100' inside casing. Can you please confirm? Best Regards, Paul Hanson 1 of 1 2/20/2007 3:33 PM BP Drills Alaska North Slope Gas Hydrate Te~ ell to Assess Poten... -, ,-. +'~'`s''vty: - __ Site lnde,X ~..E}(?tact US l~el7E;rtS and publications L3',~' we Search: Press R BP GlcbaE - Press Press releases F /~~~~w+ rr ~"` _ Press releases - - iJ[` ~~~r~ t.~x. ~ ~ j l~'."~ ~ Ec,~~ ~ ~ <:~... 3.iy ~ Q ~~~ f ~ Speeches ~Ck~C:6'~i~,~a ~:~3..I'1~`~' ~.~C~'Si?IL: Features and ne~.vs Images and graphics h ~IVhat is PS5? Reiease date: 2Q February 2QQ7 [V(ilne Point, Alaska ;Feb. 19. 2Q07) -- EiP Exploration {Alaska; Inc. „,.task" s~~oeesstully drifle;d a research well on the North Slope in partnership with the t U.S. Departmer:.t of Energy and the U.S. Geological Survey to collect samples ` ~ and gather knc4vledge about gas hydrate, a potential forg-term unconventional ~ten:ia gas energy resource. P~ The stratigraphic tes*, well enabled BP and the Department of Energy to gather ~- c ~,f UK'- ,~ ~. core, log, reservoir performance and fluid data from an ice pad location at , ~"" ` Mine l {Jiro. ' ?"he drilling began Feb 3, Field teams began pulling hydrate core "'' samples on Feb. 10. Extensive well logging and wireline formation tesfing was , ~~ r competed between Feb. ; 4-° 8. ~~~, "~,Nith th€s project, we have significan#ly iracreased our understanE:ing cf gas ~ I/ ~ ~- hydrate-bearing formations on the Alaska North Slope," sand Scott Digert, HP ~ Fr ~n~ I-„c resource manager and the project's technical adviser. "The results also illustrate the value of collaborative research,:' he said. ~ i=...nun; r ,~~~ ~ . ~„~ 5~~ This test well is part of the ongoing research partnership between BP and the `~ c a C3epartment of Energy, which began in 241Q2. ~ ~'~"''r Known deposits of methane hydrate in Alaska and ether parts of the world are enormous. However, the challenge is finding tlJe technology to unlock the energy, to separate the natural gas from the sc=id gas-water-ice "clatt~rate'° in t which it accurs. DOE National The DGE has identified gas hydrate as a research target and funded the Technical Labora estimated 54.6 million cost of drilling the t~lilne test well. BP contributed seismic data; staffing and preJgram oversight. The on-site coring and data team ! E~OE Alaska h included sokentists from the USGS, FJOE, Oregon State University and an ~ USG ,hydrate observer from India's hydrate program. Drilling crews and research team members cailected about 43Q feet of core samples. The cylindrical core segments, about 3 inches in diameter, were initially sut3sampled and analyzed on site due to the time-and temperature-dependent data regsairements. They Uvill be shipped to Anchorage for temporary storage before being distributed to gas hydrate researchers around the coctntry. Subsettuent data collection and analysis will continue'for several months. A report of findings will be released thereafter. Well lrformatitan • This well pravided a stratigraphio test of interpreted gas hydrate accurmuiations from Milne seismic and weal data. Core; wireiine logs, an:.4 e^~ireline do~,vn hole tasting will help assess gas hydrate-nearing sedirment, shallovr reservoirs; and fluid properties. • Location; ice :gad 1.4 miles sor.th of the Milne ~3-pad, reached by an ice road. The Milne Poini oilfield is northwest of the Prudhoe Say oil field, and is oGVned and operated by t3?. • Depth: 3,CQ0 feet * Target: Gas hydrate within the Sagavanirktok formation in the Mt. Elbert prospect accurmuiaiion, identified by seismic, veil, and reservoir moEeiir~g studies during in Ph<~ses 1-2 E~f this research program. • l4ey data acruired: 430 feet of ftydratF: Dore; Logging 1`Vhile I3rillirtg & 1 of 2 2/20/2007 3:38 PM BP Drills Alaska North Slope Gas Hydrate Te ell to Assess Poten... extensive wireline open-hole ic~gs, ar?d lvic>dular Uynarnic Tester sampling for fluid anti reservoir flaw-„re;,erties data. Unique technology: Drilling €~ud chillers and tle Peed Nycalog (Canon} Lvireline-deployed caring system, both of which have heart €~sed in Canada and in the laver-48 taut not in Alaska. The Project. This is a joint effort of the DBE's C'>fatiartal Energy Tec;hnaloc y Laboratory (IVETI_}, the SGS, SP Exploration (Alaska} lnc., Arctic Slope Ragianal Corparatian, the universities of Alaska and Arizona, and ethers. The project recorded a number of firsts; int;luding the firs# significant gas hydrate-bearing core in Alaska, at?d tle first delineation of seismically-defined gas hydrate prospect in Alaska. Key an-site participants: The caring & data Learn included scientists from the USGS; DOE; PE ; ASRC Energy Services, Oregon State University, and an observer from India`s gas hydrate program. Hydrates: br<efly: tvlethane hydrate is a solid subsfance that fours by combining gas and water within the pare space of sediments within a defined pressurettemperature stability window. Those conditions occur Gvithin and beneath permafrost ir:. inshore :.seas and beneath the sea#3oar in offshore regions. On the earth Slope; gas hydrate has been found in nun~eraus locations during drilling for ail artd gas. At Milne It is 3ocated in the Sagavanirktak farmatiart; in dispersed deposits beneath the permafrost, about 9&€00 to 2600 feet below the surface. The gas s contained vrithin a solid "clathrate" structure which co€rpressc:s 160-18€J unit volumes of gas into a single volume of gas hydrate. UVhat happens next'? L'tr'ill There be a hydrates production tesf? E3~`s current focus is an the suc,:,essf€al rornpletion of this stratigraphic tesf well; anti subsequent analysis of the data, The direction of pafentia( future program efforts grill be determined with DOE fallowit~a those evaluations. illustrations: • f49ap of the project site (BP} Graphic of hydrate ma€ecule (BP-USGS} • Stratigraphia illustration of Milne hydrate deposit, (SP} • Graphic of care sample {~3P) • Pf!atas: 1. Technicians preparing core samples (BP-DC)E} 2. Scientist cleaning inspecting samples(BP-DC}E} 3. Close-up of hydrate samples {~P-DOE} 4. Scientist balding sa€rple in hand (SP-DC?E} 5. Doyon drilling rig on site {SP-DOE) Further inforatican, Edema: Steve f~tinehart Office: [3P Press office Location; Alaska Phone : +9 907-564-56ei8 Name: =:.)aren ~eaudo Office; F~l' ?ress of#ice Location: Alaska Phone : +1 9t?7-564-5404 r` 9996-200°? BP p.l.c. j Legal EVotice Privacy Stafement 2 of 2 2/20/2007 3:38 PM Re: Mt. Elbert Hydrate P & A Subject: Re: Mt. Elbert Hydrate P & A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 16 Feb 2007 14:27:57 -0900 'To: "Hai~sorl, Paul" ~~~Paul.Hansonliu'bh.com::. CC: "Kara. Danny T" <D~nnti.l4arau',bp.con~=~, .~OGCC North Slope Office <-ao~~cc _prudhoe _bav~ci%admin.state.ak.u~==- ~~ ~ .- ~ ~`~ Paul, Your proposal is as we discussed. By copy of this message you may proceed as proposed. I understand that this operation might not happen over the weekend. Please plan to file the sundry on Monday. Have the rig contact the Inspectors to witness the tag on the LiteCrete and the cutoff prior to welding on the plate. No tag on plug #l is needed provided no problems are encountered setting that plug. Call or message with any questions. Tom Maunder, PE AOGCC Hanson, Paul wrote, On 2/16/2007 2:03 PM: Tom, This is a brief summary of the P&A plan. As I told you on the phone, I don"t think we`ll get to this over the weekend, but I can't rule it out. Seta 15.7 ppg ArcticSet plug (approximately 66 bbl assuming 10% excess} from 3,000 to 2200', which is the approximate depth of the water zone. I intentionally made the excess small because if the plug level is deeper than 2200' it will just increase the standoff from the hydrate zone. Pull out and circulate out catching spacers. Set the 12.5 ppg LiteCrete from 2200" to 1754" (200` above the shoe}. l estimate the volume at 40 bbl assuming 30°!° excess. If top is higher, that's fine. Circulate out as above per MI`s recommendation to save as much MOBM as possible. The LiteCrete has about one third the heat of hydration as the Arctic Set, so the goal is not to "stir up°° the hydrates as the cement sets. At this point, we`ll WOC per SLB and tag to confirm top. After that, I envision displacing out the remaining MOBM using a 10.7 ppg gel/bar mud per MI. This should come from the mudplant and be pumped directly off the truck, saving as much MOBM as possible. Now set the 250' 10.7 ppg Arctic Set on top. It is desired to have TOC within 5° of surface when we're all done. Please call if you have any comments or concerns. Best Regards, Paul Hanson -ODE (907) 564-4195 or (907) 360-0388 1 of 1 2/16/2007 2:28 PM Re: FW: Mt. Elbert Hydrate P & A Subject: Re: FW: Mt. Elbert Hydrate P & A From: Thomas Maunder <tom_maunder ~r admin.state.ak.us> ~ ~ _ (`~ Date: Fri, 23 Feb 2007 13:49:49 -0900 To: "Kara, Danny T" <Danny.Kara@bp.com> ('C: "fIanson. Paul" ~=l'~iul.llansonl@bp.c~~~z>>, "Bob Gardner (huir~~~ealhcr)" hoh~~i~lairti~~cathcr.com.>. "~1S1_'_ ~~~1~~~' Drl~~, I:ieldLn~r~~ ~~NSU~~D~1~~Dr1~~l=ieldl=i~Lr~rI3P.c~~m,.. "Rose. John G (F~~IRWEATI~IEIZ)" ~_-,lohn.G.Rosectbp.con>>, ,4OGCC North Slope Ofticc ~~~-ao<~c~prudhoe hay(u!adrnin.state.ak.us> Dan, Although the surface work was not described in Paul's email, that work must be accomplished to finish the "A" part of the work. I will attach this message to the sundry. By copy of this message, you have "verbal" approval to proceed. Contact the Inspectors as you have noted. Call or message with any questions. Tom Maunder, PE AOGCC Kara, Danny T wrote, On 2/23/2007 12:52 PM: Tom, The Mt. Elbert P&A summary listed in the a-mail from Paul Hanson does not include the surface ', abandonment information -only down hole abandonment operations completed by the rig are included. A summary of planned operations for the surface abandonment is as follows: - The wellhead has already been removed by the rig - Excavate and remove well cellar. Extend excavation to about 6' below original tundra level - Rig up Wachs cutter -cut both the 20" conductor and 9-518" casing 4' below original tundra level - Fill any voids in annular space, if present, and photo-document cement at surface before installing marker plate - Notify AOGCC Inspector to witness TOC - Weld well marker plate on outermost casing string as per 20 AAC 25.120. Photo-document. Notify AOGCC Inspector to witness plate. - Backfill excavation to original tundra elevation as per 20 AAC 25.170 - Clean up location and obtain final location inspection from AOGCC and DNR, if applicable Please contact me if there is any additional information required for this abandonment. Thanks for your time. Dan From: Hanson, Paul ', Sent: Friday, February 23, 2007 10:34 AM To: Kara, Danny T 1 of 2 2/23/2007 1:50 PM Re: FW: Mt. Elbert Hydrate P & A Subject: FW: Mt. Elbert Hydrate P & A From: Hanson, Paul Sent: Friday, February 16, 2007 2:04 PM To: 'tom maunder@admin.state.ak.us' Cc: Kara, Danny T Subject: Mt. Elbert Hydrate P & A Tom, This is a brief summary of the P&A plan. As I told you on the phone, I don`t think we'll get to this over the weekend, but l can`t rule it out. Seta 15.7 ppg ArcticSet plug {approximately 66 bbl assuming 10% excess} from 3;000 to 2200'; which is the approximate depth of the water zone. i intentionally made the excess small because if the plug level is deeper than 2200' it will just increase the standoff from the hydrate zone. Pull out and circulate out catching spacers. Set the 12.5 ppg LiteCrete from °2200' to 1754' (200' above the shoe}. I estimate the volume at 40 bbl assuming 30% excess. If top is higher, that's fine. Circulate out as above per Ml's recommendation to save as much MOBM as possible. The LiteCrete has about one third the heat of hydration as the Arctic Set, so the goal is net to "stir up" the hydrates as the cement sets. At this point, we'll WOC per SLB and tag to confirm top. After that, I envision displacing out the remaining MOBM using a 10.7 ppg gelfbar mud per MI. This should come from the mudplant and be pumped directly off the truck, saving as much MOBM as possible. Now set the 250' 10.7 ppg Arctic Set on top, It is desired to have TOC within 5' of surface when we°re all done. Please call if you have any comments or concerns. Best Regards, haul Hanson -ODE {907} 564-4195 or (307} 360-0388 2 of 2 2/23/2007 1:50 PM RE: Cement Plug Test for Mt. Elbert Subject: RE: Cement Plug Test for Mt. Elbert From: "Hanson, Paul" <Paul.Hansonl ~bp.com> Date: Wed, 21 Feb 2007 15:07:35 -0900 '['o: '[~hontas Maunder <ton~ maunder(uadmin.state.ak.us~=~~ Tam, I just gat this from SLB, I guess I shouldn't be surprised that when one circulates ~6 bb( of cement through about 136 bbls of mud the sample ends up being predominantly mud - contaminated by cement rather than cement contaminated by mud. Best Regards, Paul Hanson From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, February 21, 2007 10:39 AM To: Hanson, Paul Cc: Kara, Danny T; Tim Regg Subject: Re: Cement Plug Test for Mt. Elbert Paul, This appears to have worked well. One other item, do you all have a copy of Schlumberger's "report" regarding their assessment of the cement sample circulated from the tagging? We would appreciate a copy of that report. Thanks in advance, Tom Maunder, PE AOGCC Hanson, Paul wrote, On 2/21/2007 9:26 AM: «Chart Record of Plug Test - Mt Elbert 2-20-2007.ZIP» «Mt Elbert Hydrate PA Plug TestExceI.XLS» Tom, Sorry for the delay in sending this to you....l had to figure out how to scan the chart recorder into a pdf. As you will see, the plug held the 500 psi "rock-solid" for 30 minutes. Thanks for your guidance in getting this P&A done. Best Regards, Paul Hanson ''Doyon 14 Mt Elbert Shaker Samplel.zip Content-Description: Doyon 14 Mt Elbert Shaker Samplel.zip Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 2/22/200? 8:14 AM • ~c~~~mber~~r ~~ -C~3~ Doyon 14: Mt Elbert Shaker Sample An a lys i s Prudhoe Bay, Alaska February 20, 2007 Client :British Petroleum District :Prudhoe Bay Requested by BP/State of Alaska Report Date :February, 21 2007 Author :Robert Nelson, Fluids Technical Engineer, WCS Proprietary Rights: This report is based on confidential information and neither this report nor any other part may be disclosed directly or indirectly to any third party without the prior written authorization of Schlumberger. Liability: This report is presented in good faith, but no warranty is given and any user of this report agrees to absolve and hold Schlumberger harmless against any consequences resulting from the use thereof. ~ ~ ~cl~lu~nb~rg~n ~~_~3~ 1. INTRODUCTION A sample of a cement/mud like substance was taken from the shakers on Doyon 14 on February 20, 2007. The sample was delivered to the Prudhoe Bay laboratory with the instructions to identify whether or not the sample was cement. 2. EXPERIMENTAL APPROACH The sample was initially placed in HCL to determine reactivity. Due to the nature of CRETE slurries this is not necessarily a good indicator of the sample properties, at the same time part of it was placed in the oven to dry. The sample showed no reaction in the HCL but this is not uncommon for CRETE. The pH of the sample was measured and was 10.5. A sample of the field blend from the lab was mixed and the pH was 12.5. The 12.5 ppg CRETE was sampled from the batch mixer on site and returned to the lab for a UCA analysis, the remaining sample was hard and was chipped apart for X-Ray Diffraction. The sample was crushed and scanned utilizing an XRD. The scan data of the sample was analyzed utilizing a computerized search match program that compares a database of known crystal structures to the XRD scan. The mud/cement sample was crushed after drying and analyzed in the same manner. 3. RESULTS AND DISCUSSION The XRD scan indicates the primary components of the cement sample are as follows: Quartz- Si02 Portlandite- CaIOH-Z Calcium Magnesium Aluminum Oxide Silicate CA~,MgA120~ The primary components of the shaker sample are as follows: Barite (Synthetic) BaSO, The x-ray scan of the sample is compared using a database of known scans. The computer creates a simulated pattern based on the components of the sample. This is represented by black markers in the cement sample scan, and by red markers in the mud/cement sample scan, the blue lines are the actual sample scans. Even when we compare the two scans we do not see any similar reflection peaks, indicating they are not composed of the same materials. 4. CONCLUSION The cement sample from the job site and the sludge sample taken from the shaker do not show any remarkable common traits. This indicates that despite the high pH the sample is primarily composed of Barite, which is consistent with Mi's description of the OBM for the job. C c~0~ "~~~ L d7 L .~ v y ;~: a c c, w lLl li~l J J W 2 W tt W S • ~~ • ~ ~ ~~ L Q! L .O _~ v (s~uno~)tiisua~u~ w U a o: w J J ?w S w a w S_ J U in Cement Plug Test for Mt. Elbert ~ i Subject: Cement Plug Test for Mt. Elbert From: "Hanson, Paul" <Paul.Hansonl@,bp.com> Date: Wed, 21 Feb 2007 09:26:41 -0900 To: Thomas Matlnd~r ~ ~uun rl~aundrr~`~~ad~liin.tate.~tk.t-s> . CC: "Kara, D~mm~ l~" <i)an~~.Kari ~rh1~.c~uii'- c~' «Chart Record of Plug Test - Mt Elbert 2-20-2007.ZIP» «Mt Elbert Hydrate PA Plug TestExceI.XLS» Tom, Sorry for the delay in sending this to you....l had to figure out how to scan the chart recorder into a pdf. As you will see, the plug held the 500 psi "rock-solid" for 30 minutes. Thanks for your guidance in getting this P&A done. Best Regards, ~.c~S~~ ~~ Q`~~ ~~ Paul Hanson ~~~~~~: ~~`~ O ~ ~~ '~ ~ ~~ ~~~ 'Content-Description- Chart Record of Plug Test - Mt Elbert 2-20-2007.ZIP -Chart Record of Plug Test - Mt Elbert 2-20-2007.ZIP Content-Type• application/x-zip-compressed': Content-Encoding: base64 Content-Description: Mt Elbert Hydrate PA Plug TestExcel.XLS Mt Elbert Hydrate PA Plug TestExcel.XLS' Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 2/21/2007 9:59 AM ~e,b 21 2L707 7:59RM ~LRSERJET FRX ~ p.l ~1;_l~ _~ ~ ~ __.~__~.~.- • Lined spaces provided. Do Not add or delete rows from the tables. If you have more data than s CASING AND LEAK-OFF FRACTURE TESTS Well Name: Mt Elbert Csg Size/Wt/Grade 9 518" 40# L-80 Csg Setting Depth: 1953 Mud Weight: 10.7 LOT= 15.62 psi Fluid Pumped= ided. do ~ - ~ ~ ~ Date: 2/20/2007 Supervisor: Vaughn/Oglesbee MD 1953 TVD ~g Leakoff pressure(K 500 Hole Depth (md)= 1980 bls Volume Back (bbls)= ~~~ LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ~_~ _> _> _> _> _> _, _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> _> 2 90 4 6 180 350 8 550 .> .> _> .> _> _> a _> _> _> -> _, _> 2 200 4 500 6 780 8 990 10 1200 12 1400 14 1650 ----T- 16 -- -_ ._ 1880 18 2150 Enter Holding Enter Holding Time Here Pressure Here -> 1 2050 > -' - --- 2 --- - - _ __ 2050 > _-- --. _-____3 , _ . --_-_ _.._-2050 - -> 4 2050 > -------5- - -,-- - - ---- 2050 -> 6 2050 -> 7 2050 -- ---- - -- -> 8 2050 -> 9 2050 -> 10 2050 "'~ t Enter Holding Enter Holding Time Here Pressure Here • • ~r~'t use all data points. Record all casing test pressures and volumes even though the higher values will not appear an th 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 v- 2100 2000 N aNi 1900 L a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 -LEAK-OFF DATA -CASING TEST DATA _----- - - - _ f. _ -- - _ __-__ ____ ---__- `1 0 10 20 Strokes (# o~ ~e graph 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 a 2100 m ~ 2000 N ~ 1900 L a 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 ~-y,~ ~ ,_~ ~ ~ ~-®- LEAK OFF DATA CASING TEST_DATA 0 5 10 15 20 25 30 Time (Minutes- Re: Mt. Elbert well plug -MPU hydrate well API 50-029-23302-00 Subject: Re: Mt. Elbert well plug - MPU hydrate well APT 50-029-23302-00 From: Thomas E Maunder <tom maunder c~admin.state.ak.us> Date: Tue, 20 Feb 2007 17:51:41 -0900 ~'~ `~° ` ~ ~~ To: "~lillcr, ~~like C" ~'N~iikc.~~lill~•r~~rbp.~om CC: "Kara, Danny ~~~" <-Danny_Kara~u~F3P.com-'>"14 (\S~(.:~D1V Drl<, Ri~~ l~)" NSU~~D~1'Drl'~Ri~r,l~@BP.com~-~,"Hanson.Paul"~:Paul.flansonl~~i'E3P.rom~ . aogcc_E~ru~ihocbav@adn~in.state.ak. us Mike, et al: A pressure test is an acceptable method of testing a plug. I understand that you have laid down the drill pipe. Plotting volume versus pressure gives those on the rig the ability to track the pressure buildup and see if the slope changes while attempting to ~~ Sc C~ build up to 500 psi . Bleed off after achieving 500 psi will be ~~~~~~~~~.~~ v 't interesting to watch. ~ ~.w~~ ~~~~~,~~~~~~~~~~_ I look forward to hearing from you or the rig after the test is ~ ~ conducted. Good luck, Tom Maunder, PE AOGCC ----- Original Message ----- From: "Miller, Mike E" <Mike.rit.l.ler.>bx>.c:or:.t> Date: Tuesday, February 20, 2007 5:44 pm Subject: Mt. Elbert well plug - MPU hydrate well API 50-029-23302-00 To: t,om maunder adm~>~ . state . ak. us Cc: "Kara, Danny T" .Danry.Karac-L~BP.cor1>; "14 (NSU, ADW Drlg Rig 14)" <'~dS?~ADWDrlgRigl4{%~BP.com>, "Hanson, Paul" <Pat<1.=Iansor=l;~BP.com> Tom - as we discussed Feb. 20, 2007,1725 hrs: '; We laid down all the drill pipe, so we are not is a good position to tag ' the plug at the surface casing shoe. We are in a position to pressure test. We propose the following procedure: We will pressure test the well to 500 psi. this test will be performedlike a leakoff test, plotting volume vs. pressure. 340 psi surface ~ Oc'~ \~~~~~ ~ ~ pressure with this mud weight, 10.7 ppg, is equivalent to the leakoff ~~~~~~ ~~ test of 13.6ppg. The 500 psi will provide pressure in excess of the leakoff, equivalent to 15.5 ppg, to ensure a good plug test. A '~_-~~~~,~~~;-~~~ successful pressure test will be a solid 500 psi test for 30 minutes, ~'1~ charted. ~"~--~ If the pressure test is successful, we will leave the 10.7 ppg water based mud in the hole, set a cast iron bridge plug at 250 ft from surface and set cement on top of that bridge plug to surface. If the pressure test is unsuccessful, we will pick up drill pipe and a cement retainer. RIH with retainer and set at 1800' (shoe is at 1954 ft, we first tagged soft cement this morning at 180 so don't want to ~i 5o,w.~tS~ C`~~CJ~v.~ esjj~~~~ ~ct~--4~- Cv~ ~~~lv~'~; risk sticking the retainer into soft cement and not being able to S~v~.\_~ ~~ gl~_ ~~\ pump ~ ~ "-~~ 1 ', cement through it) . With the retainer set at 1800' , we will pump ~hG.~'CSL~.~~ ~jOJ~~ 200 ft and of cement below the retainer and lay 50' on top of the retainer. ~'L ', Then we will leave the 10.7 ppg water based mud in the hole, set a ~~~~` castiron bridge plug at 250 ft from surface and set cement on top of that 1 of 2 2/21/2007 9:59 AM Re: Mt. Elbert well plug - MPU hydrate wel I 50-029-23302-00 bridge plug to surface. Please confirm that this is agreeable. ', thanks for your help on this Tom. a pleasure as always, Mike Miller BP Alaska ACT Drilling Manager office: 907-564-5066 cell 907-240-8066 ~;i.1 ~.erme:~-bp . core 2 of 2 2/21/2007 9:59 AM -~ >~ ~ Page 1 of 1 Hanson, Paul From: Thomas Maunder [tom maunder@admin.state.ak.us] Sent: Friday, February 16, 2007 2:28 PM To: Hanson, Paul Cc: Kara, Danny T; AOGCC North Slope Office Subject: Re: Mt. Elbert Hydrate P & A Paul, Your proposal is as we discussed. By copy of this message you may proceed as proposed. I understand that this operation might not happen over the weekend. Please plan to file the sundry on Monday. Have the rig contact the Inspectors to witness the tag on the LiteCrete and the cutoff prior to welding on the plate. No tag on plug #1 is needed provided no problems are encountered setting that plug. Call or message with any questions. Tom Maunder, PE AOGCC Hanson, Paul wrote, On 2/16/2007 2:03 PM: Tom, This is a brief summary of the P&A plan. As I told you on the phone, I don't think we'll get to this over the weekend, but I can't rule it out. Seta 15.7 ppg ArcticSet plug (approximately 66 bbl assuming 10% excess) from 3,000 to --2200', which is the approximate depth of the water zone. I intentionally made the excess small because if the plug level is deeper than 2200' it will just increase the standoff from the hydrate zone. Pull out and circulate out catching spacers. Set the 12.5 ppg LiteCrete from 2200' to 1754' (200' above the shoe). I estimate the volume at 40 bbl assuming 30% excess. If top is higher, that's fine. Circulate out as above per MI's recommendation to save as much MOBM as possible. The LiteCrete has about one third the heat of hydration as the Arctic Set, so the goal is not to "stir up" the hydrates as the cement sets. At this point, we'll WOC per SLB and tag to confirm top. After that, I envision displacing out the remaining MOBM using a 10.7 ppg gel/bar mud per MI. This should come from the mudplant and be pumped directly off the truck, saving as much MOBM as possible. Now set the 250' 10.7 ppg Arctic Set on top. It is desired to have TOC within 5' of surface when / we're all done. Please call if you have any comments or concerns. Best Regards, Paul Hanson -ODE (907) 564-4195 or (907) 360-0388 7I1 A/~(1f17 ~~`~ ~ ~ , ~ .t~~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~' ~~~~ ~~~~++ ~~a~ ~ ~~+ ~-7~ OIL tusi/ ~ ~~ 333 W. 7r" AVENUE, SUITE 100 COI~TSFiRQA'1'IOI1T COh'II~IISSIOl~ ;~y ANCHORAGE, ALASKA 99501-3539 Dan Kara y' PHONE (907) 279-1433 Senior Drilling Engineer FAX (907) 276-7542 BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Mt. Elbert-01 BP Exploration (Alaska) Inc. Permit No: 206-033 Surface Location: 1242' FNL, 4183' FEL, SEC. 30, T 13N, R 11 E, (Planned) Bottomhole Location: 1242' FNL, 4183' FEL, SEC. 30, T 13N, R 11 E, (Planned) Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced exploration well. 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 witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Mt. Elbert-O1 206-033 Sincerely, • Cathy . Foerster / Commissioner DATED this (Oday of March, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIv~ON PERMIT TO DRILL .~"4 3'~d~ 20 AAC 25.005 1a. Type of work ® Drill ' ^Redrill ^ Re-Entry 1b. Current Well Class Exploratory ^ Development Gas ^ Service ^ Multiple Zone ~ Stratigraphic Test ^ Development Oil ^ Single Zone ic. Specify if well is propos~d~~o~d~ ^Coalbed Methane ~~~~`U TT~~Yy~orates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 / 11. Well Name and Number: Mt. Elbert-01 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 4000 TVD 4000 ~ 12. Field /Pool(s): Milne Point Unit 4a. Location of Well (Governmental Section): Surface: 1242' FNL 4183' FEL SEC 30 T13N R11 E (Planned) ' 7. Property Designation: ADL 028231 , , . , , , Top of Productive Horizon: 1242' FNL, 4183' FEL, SEC. 30, T13N, R11E, (Planned) 8. Land Use Permit: 13. Approximate Spud Date: April 1, 2006 Total Depth: 1242' FNL, 4183' FEL, SEC. 30, T13N, R11E, (Planned) 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 7545' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 572199 ' y- 6016604 Zone- ASP4 10. KB Elevation (Height above GL): 24 feet 15. Distance to Nearest Well Within Pool: 734' at 4000' away from MPE-08 16. Deviated Wells: Kickoff Depth: None feet Maximum Hole Angle: N/A de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1740 ~ Surface: 1340 18. Casin Pro ram: S cations T - Setdn D -'Bottom Quan of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 30" 20" 92# H-40 Weld 80' 20' 20' 100' • 100' - 60 sx Arctic Set A rox. 12-1 /4" 9-5/8" 40# L-80 BTC 1932' 18' 18' 1950' ~ 1950' ' 70 sx AS Lite, 446 sx Arctic Set 8-1 /2" 7" 26# L-80 BTC 2150' 1850' 1850' 4000' - 4000' ~ 0 sx AS Lite, 256 sx Class 'G' 19. PRESE NT'WELL!GONDITION S UMMARY (To be completed f or Redrill and Re-entry Operations) Total Depth MD (tt): Total Depth TVD (tt): Plugs (measured): Effective Depth MD (ff): Effective Depth TVD (ff): Junk (measured): Casin " Len h Size Cement Volume MD TVD Conductor /Structural Surface Intermediate 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. 1 hereby certify that the foregoing is true and correct. Contact Steve Lewis, 252-3457 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~~~ Phone 564-5667 Date Zy n~ Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill Number: Z~lo'U~3 API Number: 50- ~~q"Z.3~dZ'"v~ Permit Approval Date: See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: y©~ ~~~~~ '~ ~~~~, ~ Samples Req'd: ~es ~^~~~No Mud Log Req'd: Yes ~^/No HZS Measures: Y p'No Direction I Survey Req'd: ^ Yes L~ Nc~ Other: ~~O Qs. C3Q~ 4cs~ • VJ~\\ MGM I~OT' ~jc~~ry~~-e~ ~~"~t- ~ x~i.aR.~e.~,smrve~ ~y i•2 ~-ht,,,~ yOC~Qt -t'V~ iJJ'~4~®`1k- E P ~s~A~~S~o~ca G@~(~1~fG.\ , D 3 ~ APPROVED BY THE COMMISSION - Q Date ~ ,COMMISSIONER ~- IZECEiVED ' 3/3 FER 2 4 2006 z , .W' Form 10-401 Revised 12/2005 v t i ~ ~ f I !i ! ~/L. ~ r f ~- Submit In Duplicate by ~ Well Name: I Mt. Elbert # 1 Drilling Plan Summary T e of Well: Strati ra hic Test Surface Location: 1242 ft. FNL and 4,183 ft. FEL (As Proposed) Section 30, T13N, R11 E UM X=572199, Y=6016604 ASP4 Lat = 70.455641846, Lon= -149.410786174 Note: the section is ~40 short of 5,280 in EW direction. Distance to Pro ert line 7545 ft. MPU unit bounda Distance to nearest well 734' @ 4000 ft. MD from MP E-08 AFE Number: GS2420H15 Estimated Start Date: April l , 2006 Ri Do on Arctic Fox Rig days to complete: 25 MD: 4,000' TVD: 4,000' Max Inc: KOP: None KBE: 24' Well Desi n: Strati ra hic Test Ob'ective: Gas H drates Mud Program: 12'/a" Surface Hole (0' -19501: Fresh water spud mud Densit PV YP H API Filtrate Chlorides m I <9.4 10-30 25-50 9-9.5 NC-10 NC 8'/s" Intermediate Hole (1.950' - 4.000'1: 8% KCI LSND (-3.78° C TCT ) Densit PV YP H API Filtrate Chlorides MBT 8.9 -9.6 10 - 25 15 -20 7.0 - 8.0 <8 39,950 <25 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 CPAI KRU 1 R-18. 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 1 of 7 ~ ~ Casing Program: Hole Size Csg Diam Wt/ Grade Conn Burst Collapse Length Top Bottom Ft MD/ MD/ TVDrkb TVDrkb 30" 20" 92 H-40 Weld 1530 520 80 ft 20 100 ft 12'/a" 95/a" 40 L-80 BTC 5750 3090 1932 ft 18 1950 ft 8'/z" 7" 26 L-80 BTC 7240 5410 2150 ft 1850 ft 4,000 ft contingency liner Cement Program: Casin Size 95/8", 40 f, L-80, BTC T e: Surface Casin to 1950'. Basis for 80' shoe jts, 150% in permafrost (12-1/4" hole), and cement to Calculation surface. Shoe Depth: 1950' MD. 1450' Arctiset Lite @ 10.7 ppg and 500 ArcticSet @ 15.8 Cement Volume: S acer 5 bbl of water, 10 bbl CW 100 and 40 bbl Mud Push Lead (BOC @ 270 sxs (212.5 bbls), ArcticSet Lite @ 10.7 ppg. Yield 1450 ft 4.43 ft3/sx, mix fluid 20.667 gps. Tail (TOC @ 446 sxs (79.50 bbls), ArcticSet @ 15.8 ppg. Yield 1.05 1450 ft ft3/sx, mix fluid 4.10 gps. Tem 2 °C @ 1950 ft MD. Casin Size 7" 26 f, L-80, BTC Contin enc Liner T e: Production Liner from 4000' TD to 1800' 150' liner la Basis for 80' shoe joints, 30 % excess in open hole. 500' ArcticSet Lite @ Calculation 10.7 and 1700' Class G at 15.8 Cement Volume: S acer 5 bbl of water, 10 bbl CW 100 and 30 bbl Mud Push Lead (BOC @ 20 sxs (15.8 bbls), ArcticSet Lite @ 10.7 ppg. Yield 2300 ft 4.43 ft3/sx, mix fluid 20.667 gps. Tail (TOC 256 sxs (53.0 bbl) Class G @ 15.8 ppg. Yeild 1.16 @ 2300 ft ft3/sx, mix fluid 4.97 s. Tem 24 ° C @ 4000 ft MD. 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 2 of 7 Evaluation Prom: 12'/a" Surface Hole Coring Program: None Mud Logging: Surface to casing shoe ' Open hole Logs: . MWD:Directional/Gamma/Resistivity ' 8'/i" Intermediate Hole Coring Program: Run 1: Continuous Core, Wireline retrieved from - 2000' to 2600' Mud Logging: Casing point to TD. - Open hole Logs: . Run-1: 1850-4000 Platform Express (hydrate) -High Resolution Laterolog Array-SP Log (HRLA) -Compensated Neutron Litho Density Log -Array Induction-SP Log (AIT) -Electromagnetic Propagation Tool Log (EPT) - DiElectric msmt • Run-2: 1850-3500 Dipole Shear Imager (hydrate) - -Dipole Shear Imager Log -Natural Gamma Ray Spectroscopy Log -Environmental Measurement Sonde Log • Run-3: 1850-3500 Formation Microlmager - (hydrate) -FMI Borehole Image Log • Run-4: 1850-3500 Combinable Magnetic Resonance Tool (hydrate) -Combinable Magnetic Resonance Log -Natural Gamma Ray Spectroscopy Log -Environmental Measurement Sonde Log -CMR Station Log-Elemental Capture Sonde • Run-5: XPT (Optional) • Run-6: MDT Open Hole; 2 points per sand, two sands expected Cased Hole Logs: • Run-1: MDT cased hole contin enc onl 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 3 of 7 Formation Mark: Formation Tops MD ft TVD (ft) Pore Pressure si EMW Ib/ al Top Mikkelson Tongue 1450 1450 630 8.35 Base Permafrost 1800 1800 782 8.35 "D" Hydrate 2000 2000 868 8.35 "C" Hydrate 2100 2100 912 8.35 Top Staines Tongue 2770 2770 1203 8.35 Base Gas Hydrate Stability Zone 2853 2853 1239 8.35 C12 Seismic Marker 3390 3390 1472 8.35 Top Ugnu 3710 3710 1736 8.35 Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit-Type TFA GPM 1 12'/a" 0 - 1950' 1950' Baker Hughes MX-1 .84 650 2 8'/z" 1,800' - 4,000' 2,200' Baker Hughes MX-1 .71 450 Well Control: Surface/Intermediate hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Integrity tests: • Wireline core retrieval: 1,740 psi C«~ 4000' TVD 1,340 psi (Based on full gas column to surface C~3 0.1 psi/ft) - 3,000 psi , FIT to 11.5 Ib/gal 20' below the 9 5/8" shoe. Wireline BOP, circulating sub and packoff to be utilized when retrieving cores. Drilling Hazards & Contingencies: Hydrate drilling, coring and handling: Hydrates will be present from the base of the permafrost to approximately 2850 ft MD. Mud system design specifies an 8 % KCI Low Solids Non Dispersed system which will have a thermal crystallization temperature of minus 3.78 ° C. Operating temperature of mud being pumped down hole will be maintained at minus 2.0 ° C. Circulating temperature, mud chemistry and drilling mechanics will be optimized to minimize hydrate sublimation while maintaining primary well control. • All circulating system components will be monitored and actively protected from freeze up both while circulating and during static periods. 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 4 of 7 • Rig gas detector sy~ will be fully operational and portable sensors will be utilized in the ' affected areas prior to cuttings handling or core processing. • During coring operations mud properties and temperatures will be maintained to minimize hydrate sublimation. • Core retrieval will be conducted with wireline utilizing wireline BOP, circulating sub and packoff head. • Cores will be allowed to pressure stabilize below the wellhead and flow checks will be conducted prior to continuing the retrieval and opening the wireline riser to lay down cores. • Core will be recovered in 24 ft sections contained in aluminum core sleeves. The sleeves are slotted to prevent pressure entrapment. The core will be lain down, removed from the floor, sectioned and containerized all at sub freezing temperatures. • All core storage and on site geo-science will be conducted in a refrigerated containerized unit remote from the well bore. Drilling mechanics, lost circulation and stuck pipe: Losses are possible in the entire interval due to tight hole or pack off. NOTE: Elevated mud weights are NOT required for controlling hydrates. Control hydrate gas evolution with mud properties and hole cleaning. Sticky clays may be present from the lower permafrost on down to total depth. Potential for packing off/stuck pipe, tight hole, and swabbing exists throughout the well and particularly from 2,800' to total depth. Expected Pressures: • Pore pressure is expected to be a fresh water gradient (8.35 ppg) from surface to total depth. Pad Data Sheet: • Review MPU E and B Pad Data Sheets Hydrocarbons: • Hydrocarbons in the form of Methane Hydrates are expected from the base of the permafrost through the base of the hydrate stability zone at ± 2850'. • No liquid hydrocarbons are anticipated in any well section. • No free gas hydrocarbons are anticipated in any well section. ` Faults: • No fault intersections are expected in this vertical well. Hydrogen Sulfide: • MP is not designated as an H2S area. ' Anti-collision Issues: • Mt. Elbert #1 poses no collision risk to any MPU wells. • Mt. Elbert #1 surface location is 7545 ft. from the MPU unit boundary ' • Mt. Elbert #1 is 734' @ 4000 ft. MD from MP E-08 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 5 of 7 DRILLING PROC~DURE: Pre-Ria Operations: 1. Survey in ice road and pad. 2. Construct ice road and pad. 3. Drill and set and cement 20" conductor casing and well cellar. 4. Drill mouse hole and rat hole. 5. Install FMC landing ring on conductor. 6. N/U Doyon Drilling Diverter System prior to rig move. 7. Hold pre-spud meeting in Anchorage and at MPU Base Camp. 8. Conduct emergency response training with MPU ERT, BP Drilling, and Doyon Rig Crews. Drillina and Evaluation: 1. Move in and rig up Doyon Arctic Fox Drilling Rig. 2. Install and test Mud Chiller, MWD unit, LWD unit, Wireline unit. 3. Take on water and spud mud. 4. Function Test Diverter System. 5. Make up121/a" Tricone drill bit on packed rotary assembly and spud to ± 300'. POOH 6. Make up BHA #1: 12'/a" packed rotary assembly w/ MWD tools. Drill 12'/a" surface hole to +/- 1,950'." Maintain mud temperature at -2° C with mud cooler. 7. Circulate and condition for casing. •---~ 8. Run 9 5/8" surface casing. 9. Cement 9 5/8" surface casing. 10. ND diverter system, install wellhead and NU/Test BOPE. 11. M/U BHA #2, 7 7/8" core bit with drilling insert on packed rotary coring assembly. RIH to ± 1800' and test casing to 3000 psi. 12. Drill out shoe track, floats, rathole and 20' of new formation. 13. POOH to 1850' and perform FIT to 11.5 PPG EMW. 14. Drill to core point at ± 2000'. 15. Wireline retrieve drilling insert and run core sleeve. 16. Core 7 7/8" open hole section from ± 2000' to ±2600'. 17. POOH and lay down core barrel. 18. P/U 8'/z" bit and MWD on packed rotary assembly. 19. Ream and MWD log to 2600' 20. Drill 8'h" intermediate hole section to TD at ±4000'. 21. POOH and Lay down MWD. 22. R/U Wireline loggers. 23. Run open hole a-line logs. 24. P/U 8'/z" cleanout assembly. 25. Make clean out run to ± 3200' 26. POOH and UD clean out BHA. 27. M/U MDT tools for drill stem conveyed MDT 28. RIH to first MDT point at ± 2600' 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 6 of 7 29: Perform 4 sequenti~IDT from 2600'= to 2000'. 30. POOH and VD MDT tools. Abandonment: ~ 1. P/U cementing stinger and RIH to 200' below bottom hydrate interval. (± 2600') 2. Spot 100' viscous mud pill. 3. POOH 100' and set balanced plug from ± 2500' to 2100' 4. POOH to 2000' and clear cementing string 5. WOC 6 hrs and tag plug per AOGCC regulations. 6. Clear cementing string and set balanced plug from 2100' to 1700' 7. POOH to 1600' and clear cement string. 8. WOC 6 hrs and tag plug per AOGCC regulations. Clear cement string and POOH laying down pipe. 9. VD remaining drill pipe in derrick. 10. RIH with drill pipe and side ported stinger. 11. Spot 100' (5 bbl) of weighted viscous mud pill from 350' to 250'. 12. POOH to 250'. 13. Rig up cement lines and cement to surface. 14. POOH to 25' and flush casing, wellhead and BOP. 15. POOH and UD stinger. 16. Nipple down BOP and wellhead. Confirm TOC and top up to 5' sub surface if required. 17. Externally cut off 20" conductor and 9 5/8" casing at least 3' below tundra surface. 18. Weld on prefabricated well cap and marker per AOGCC requirements. 19. Move Arctic Fox Drilling Rig off location. 20. Abandon well cellar and conductor section as per AOGCC regulations. 21. Clean up location and ice road. Notify MPU Environmental Dept. for site inspection. 2/22/2006 Mt. Elbert #1 Well Plan Summary / APD Page 7 of 7 • • BP Gas Hydrate Stratigraphic Test - Mt. Elbert #1 Proposed Completion with Open Hole 30" Hole to 98 M D 20"Conductor @t98'MD 12'/a" Hole to ± 1960' ~t x K 9 5/8" Surface X~' CSG @ ± 1950' MD - ~ X `~' 8'/z Open Hole ~ S ..•~ TD @ t 4000 MD Wellhead Design: 11" 5K FMC Generation V Wellhead on 20" starter spool. Casing Design and Open Hole Description Hole CSG MD . Wt. Grade Size OD ND Conductor 30.0" 20.0 98' 94# H-40 Surtace 12.250" 9.625 1950' 40# L-80 Open Hole 8.5" - 4000' - - Cementing Program Conductor: Cement to surface. ~ Surface casing: ArcticSet Lite at 10.7 ppg to 1450' &ArcticSet at 15.8 ppg from 1450' to 1950' Abandonment Barriers Open hole plug will be set from 100' below any hydrocarbon interval to 100' above the casing shoe 150' surface plug from 4' below ground level will be set in 9 5/8" casing February 23, 2006 Stephen K. Lewis/ASRC Energy L MILNE POINT.18~01 ~. ~ ~ '~ LLl ~ I ~ '. D '~~Op oo a U~ ::.. 12 _ ~ 7 8 ~ 9 10~ ' MPU ,'~ <, - - C PAD ~~JJ ' oOo~ ~ o"~ ~ ~,i '~ ~ ~ ° A ~e ~~ ,° ,-'r ~- - d o -f- ~~" --~--~ , I ;~ AD # 047 ~ f ` ~ MPU D PAD -- 15 14. 13 I ~ ~ ~ ~ !3' ' ~1~5 ~~~° ~~i . B PaD PROJECT LOCATION ~, a. ; - ----- , ,, __ __ __ - --- -, _ J _ ~i ~J~~ MPU' ° A PAD, - ( ~ ~~~ ~" _ o ~ o q J n 22 \ ~ 23 `. 24 _ p a 1°~ ~ Q D O ° 19 ~ I ;1 ~ s o .ti ~ MPU ~~ _ ~ ', CFP ' a i '_ c a ° QOod~ ~ ) ~ 0 ._ ---_ ~ ~ ~ ~ ~ 0 _ - ' ,.~ ~_.. MP --- - (~ 0 ~ ^~ ~ MINES ~H ~~~~ o)~ 0 1 I 27 a~ 26 - °j ,o a~ ~ t ~ 3o 29 Z ~ 2840 27 -~ ,'' ~ I ~ "° . ° a G PAD ~ ~ ~ = o MPU H PAD ~ ° oa ~~~ 3'1 ~ l ~ ~ ' a ~~ ° ~ °`~ ~~,, ~~ a ~ ~ V° ' ~~ 5 3 32 ~ ~~ ~ a Dc ~, ~ V ~ I o ,~, 34 ~V ,o ~- ° ~ ~~ "~ ,~o„~ ADL 028231 ,I ~~_? , I T13N T12N This map is based on U.S.G.S. quad Beechy Point (B-4, B-5) ' and on the Unit Operator's Facility Maps. ~©~~~ PROJECT LOCATION: CENTROID FOR GAS HYDRATES STRATIGRAPHIC WELL LAT. = 70° 27' 20.31" NORTH LONG. = 149° 24' 38.83" WEST X = 572198.88 FEET EAST ' Y = 6016603.50 FEET NORTH ALASKA STATE PLANE ZONE 4, NAD 27 - SEC. 19 & 30, T13N, R11 E, UMIAT M. ADL # 047438, ADL # 028231 ~ 0 1 2 Miles I ~ ~ DATUM: MEAN SEA LEVEL PURPOSE: EXPLORATION WELL BP EXPLORATION (ALASKA) INC. ADJACENT PROPERTY OWNER: STATE OF ALASKA MILNE POINT UNIT GAS HYDRATES STRATIGRAPHIC WELL VICINITY MAP DATE: SCALE: FIGURE: January 2006 Approximate 1 ' 1 = 1 MILE ip15132V.dgn ACCUMULATOR: OILCO, 6 STATION TRIPLEX PUMPS: 2/575 VAC, 25 HP 11.4 GPM, 3,000 PSI AIR PUMP: 2/40:1, 8 GPM, 3,000 PSI FLUID RESERVOIR: 450 GALLON ACCUMULATOR MANIFOLD 12 BOTTLES, 15 GALLONS EACH, TOP LOAD 3,000 PSI W.P. 180 GALLON (BLADDER TYPE) VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR O O O O O O O O O u O O O O O O D O O O O E REMOTE PANEL IN DOGHOUSE (TYPICAL) iRIL GK ANNULAR BOP, ;ED BOTTOM BLE RAM BODY DED BOTTOM /Y ML OPERATORS, /Y ML OPERATORS, ICR VALVE :ATE VALVE PSI, 81/Y ML OPERATORS, ~DED BOTTOM 21 i/4', 2000 PSI, MSP HYDRIL BOP/DNERTER STUDDED TOP/FLANGED B01TOM DNERTER SPOOL NITROGEN BACKUP BOTTLES 6 BOTTLES, 337 CU. FT. ~ • • • Mt. Elbert Prospect Thickness "C" Hydrate Hydrate Thickness (Feet) 35 ^ 40 o~ zoao~ aooo~ 45 50 55 60 65 $~ _..~ 70 78 • • RE: Mt. Elbert-O1 • • Subject: RE: alt. Elbert-01 From: "Kara, Danny-I-" <Danne.Kara(~i~bp.com Date: Fri, O ~ ,'~~1ar ?00(i 09:41:40 -0900 To: T1lomas ~taundcr ~ton~ maw7der(a~admin.state.ak.us CC: "Sie~ e. Le~~-is (AS[ZC}" <StcphenK.Le~~~i5«iasrcener~ry.co~n>, 'Bob Hunter (ASRC)" <roberthunler~rl',asrcener~;y.com Tom, thanks for reviewing the drilling permit application. Below are responses to your questions: 1. Spider plots attached. The well directly below the Mt. Elbert O1 proposed location, MPU well E-32 N-Sand lateral, is at 4324'ss. TD of the proposed well is 4000' TVD (hardline depth) and is designed to penetrate the Ugnu (-3710' md). Intent is to see the Ugnu on resistivity logs. Note that on the PTD, Distance to Nearest Well in Pool is listed as 734' at the 4000' depth (MPE-28). This is true but only at the 4000' level, a horizontal 2D scan. More accurately, MPE-32 is the closest well. I did not have anti-collision completed. 2. Contingency liner will be set only if we have hole stability problems. Intent is to get openhole logs, then a couple of days of MDT logging. If there is instability in the 8-1/2" openhole, 7" will be set and MDT'ing will be done cased hole (a less preferable option). We probably can set casing off bottom, as high as the base of the hydrate stability zone (-3000' ss). We do however, need an excellent cement job on the liner for the (expensive) MDT to yield meaningful data. Given a choice, I'd rather cement from bottom of the hole. 3. Per Bob Hunter (project manager), drilling to 4000' would allow correlation into USGS seismic marker C10 at -3390' ss and the Ugnu at 3710' ss. If we were to run out of time (ice road limitations), we would likely TD near -3200' to maximize data acquisition in the hydrate zone. 4. Geologic interpretation places the Ugnu far down dip of the oil bearing area. We are expecting the Ugnu to be wet. If oil is present, the Ugnu will be isolated with a cement plug. Please give me a call with any additional questions. Dan -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin.state.ak.usl Sent: Tuesday, February 28, 2006 3:01 PM To: Kara, Danny T Cc: Steve Davies Subject: Mt. Elbert-O1 Dan, I have tried the numbers I have for Steve without success and I don't have his email. Would you please forward this on? Thanks. 1. Could you provide a spider plot of the vicinity of the proposed well. According to the information we can access there are a few wells (E-06, E-04, E-10 and E-21) that are in the area. 2. What will be the basis for setting the contingency liner? As presented it would be set to proposed TD. Is it possible that it could be set shallower? 3. After drilling to TD at 4000' and logging, all subsequent activities 1 of 2 3/3/2006 12:23 PM RE: Mt. Elbert-O1 • • go to a maximum of 3200'. Is the additional hole to allow geologic correlation? Will there be any attempt to "maintain/keep" these intervals open/accessible? 4. As planned, the well will TD in the Ugnu. As presented, your plan does not anticipate placing a plug across the Ugnu. Placing a cement plug to isolate the Ugnu may be necessary. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC - __ Content-Description: Spider3.ZIP Spider3.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 2 of 2 3/3/2006 12:23 PM -~C 3 o ~ ~ J ~ ~ 3 ~~ ~~ ~~l ~ ~ `~ X `o g~ ~- Q f //~( J ~~~ Y v v O N, 1 ~ ^~ f v^~ ~ O Q 1 O r0 ~ ~ ~ ~ 9 ~. ~ ~~~ -~~/ U ,{~ ~ a ~ ~ J 'n ''~ 9 `~ f 7 ~/~1~ f / ~ o- J J ~ N`~° ~ ~ u k U (>- ~ f ~ : '~ ~ / ~ pN i~ n " Y ~~)®, yO~ CG v, ~ w !~ ~ Q C ~_ a ,~~ ~~ _~ ~ ~, o z C ~I ~ ai ° -~ ~, ~ ti_ ~ U 611 w o --~~. JI ~ ~ w'.. ~ ~ w , o- ~ I~ C ~ ~ E WI ® ~ ~ r~ ~I ~ • _,~ r1 U -1._ j i;. _ M f ' ~,. +~ iS C `' h- ~ =i ~ _ C O YYY ti r~ X ~ 7-. 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J ~ u ~ - ~ _ T ~ N __ -. r~ --~ i EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) an~nnnn , _ _ _ - . vvvvvvv 6000000 --- 5950000 ', - - 5900000- - 5850000 -~~ -- - ----- 400000 -- ---- -- --- -~ - , m__ 500000 600000 700000 800000 ~~ 3~~~©~ ~ iocc~~ o ~ `~ 5 a~sc~ cnv ~. ~J Zo ~-~.-k- ~~be ~ L= ~ ~--- • • ASP "X" ASP "Y" •,~ 700000 700000 5880000 5920000 f"'`~~~ , \ 640000 5940000 o c ~~1-~~r ~~ 600000 5960000 A ~° ~ ` 600000 6040000 ~~ ,~, (~.~ [~ ~ ~ V 500000 6040000 ~ ~ ~ 460000 6000000 ~ 460000 5980000 440000 5960000 440000 5880000 700000 5000000 572199 6016604 Mt. Elbert 01 SONDRA D STEWII~-AN BP EXPLORATION AK INC PO BOX 19661 Z MB 7-5 ' Mastercard Check" 89-6/1252 142 ANCHORAGE, AK 99519-.6612 /~ ' - DATE v ~r ~~'l'V YJ ORDER OF E ) S ~,(~_ L~ ~,~ First Nationa ank Alaska ~ Anchorage, AK 99501 DOLLARS MEMO~~~. ~,~~,~ , ~: i 25 200060:49 i4,.,6 2 2?~.~ _ 156411 0 i4 2 ,~ • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ,~/~~ ~/~~ Y~ ~ I PTD# ~CD ~~~ evelo ment Service ~ . p Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter .CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , - between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in r` 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 Weil 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. SCompany Name must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist • • ^^ o m ~ ° o N ~ d x m a ; ; ; ; ; ; ; ; -~ U' - a~ N a~ ~ ; ; ; ; ; ; ; ; ; ; ~; a ; ; a~ 3 ~ Q ~ u~, aUi; -° - ; ; • a, ~ = o ; ~ 3 ; -°; ; ~ ; ~ °~ E, 0 3 N c ; ; ; ; ; ; ; a. ; f6. v, f9. o. O f0, -d , N °O, ~ to j N ~ ; ; ~ ; ; c; a °, ~~ ~; a, m, rn d o. co. ~; ... o O m ~ L ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~ y W ~ ~ ~ ~ ~ 7, O ~ ~ C 7 ~ K fQ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ a, ~ a, ~ pp ~ ~ ~ y, ~~ ~~ ~, ~ C p W O ~ ~ O. 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