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Home My WebLink About205-014Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221215 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT CLU 05RD 50133204740100 215160 7/15/2022 YELLOW JACKET PLUG-PERF CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Please include current contact information if different from above. T37376 T37377 T37378 T37379 T37380 T37381 By Meredith Guhl at 10:10 am, Dec 16, 2022 MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.16 10:11:16 -09'00' , f • • RECEIVED STATE OF ALASKA NOV � 9 „�j,{ ALASKA OIL AND GAS CONSERVATION COMMISSION NO 3��3 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved ogram❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Ti Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Convert to Injector El' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill ber. BP Exploration(Alaska),Inc. Exploratory ❑ Development El ' 05-014-0 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Num. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23247-00-00 , 7.If perforating: 8.W I Name and N Ai . What Regulation or Conservation Order governs well spacing in this pool? r KUP MPK-09. Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375133 - f LNE Pe .'' UPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective De th I (ft). � r .s(measured): Junk(measured): 9059 . 7095 , 9059 • 7095 . None None Casing Length Size MD \ ' I Burst Collapse Structural Conductor 79 20”94#H-40 35- \14 35-114 Surface 5138 9-5/8"40#L-80 3 -• `�3 5-5061.57 5750 3090 ip Intermediate None None •n;. `, None None None Production 7873 7"26#L-80 33-791• ` -7045.19 7240 5410 Liner 1291 4-1/2"12.6#L-80 7766-9,0; 69 6.97-7094.63 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Si -.;\_,.., / Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7/8":. ' L L-80 31-7671 Packers and SSSV Type: 5"Baker ZXP Top Packer Packer and SSSV MD(ft)and ND(ft): 7777,7000.85 No SSSV Installed VVV No SSSV Installed 12.Attachments: Description Summary of Proposal \Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct ,the best of my knowledge. Contact Christopher Stone Email Christopher.Stone@BP.Cam Printed Name Christopher Ston- Title MPU Lead Production Engineer I Signature A t'. Phone 564-5518 Date Prepared by Garry Catron 564-4424 ///dl2J," COMMISSION USE ONLY Conditions of approval: Notify Commis ion so that a representative may witness Sundry Number 3V� —CIL\C. Plug Integrity ❑ B c P Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCANNED DE:i A 8 20?3 Spacing Exception •equired? Yes ❑ No ❑ Subsequent Form Required: RBDMS DEC 13 2013 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 10/2012 0 RlG1PJtAsEd for 12 months from the date of approval. Submit Form and Attachments in Duplicate • • Perforation Attachment ADL0375133 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPK-09 4/6/05 SL 7970 - 8219 7065 7072 MPK-09 4/6/05 SL 8392 8638 7075 7084 MPK-09 4/6/05 SL 8681 8765 7086 7089 MPK-09 4/6/05 SL 8808 9013 7091 7095 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF o • ,• Area of Review — Milne Point K-09 (PTD #2050140) This Area of Review is required prior to the conversion of well MPK-09 from a producer to a water injector. This AOR discusses wells within 1/4 mile of the well's entry point into the Kuparuk Formation to the bottom of MPK-09 well bore completion. One other wellbores, MPK-17, enter the Kuparuk formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPK-09, completion details, and annulus integrity/cement conditions based on in-depth review of each well. Distance PTD (feet) Annulus Inte•rit MPK-09 2050140 0 TOC estimated at 7198' MD—based on volume pumped TOC estimated at 4900' MD; Segmented Bond Log dated March MPK-17 1960280 980 1996 Table 1: Table showing distance&annulus integrity of wells within AOR Well Name Casing Hole Vol. of Kuparuk depth(MD) Kuparuk depth (TVDss) Size Cement MPK-09 7" 8-3/4" 22 bbls 7200' 6734' MPK-17 7" 8-1/2" 58 bbls 6887' 6733' Table 2: Completion Detail Well MPK-17 (Permit # 1960280) was completed in May 1996. The completion crossed the Kuparuk formation at 6887' MD. A 9-5/8" casing string was run to 3508' MD and cemented with 740 SX (287 bbls) of 12.0 ppg Type "E" Permafrost and 250 SX (51 bbls) of 15.8 ppg class G cement. A top job was pumped down the 9-5/8" casing to bring the cement top to surface using 96 SX (37 bbls) of 12.0 ppg Type "E" Permafrost cement. A 7" casing was run to 7463' MD and cemented with 285 SX (58 bbls) of 13.1 ppg class G cement with Silicalite. A segmented bond log run in March 1996 showed good cement up to 4900' MD. ll' , • • •, \ i , ,., I -, - , 1 L 1 1 ■ , , I \ i ,,, t s I / ,.'...,` S'`''' i / '' A' / „,.... ,.1 ...,. ..,,,,,' 4.1 ____ .....„1/0"-..- i. - -4-, --------- 1 NIP , .i .-22P131 -, . , i .r),„ MPK-12 2 i , 4 .,P 4 ..,4. 1 ' .AP -....„.., ..„,._ 7= .-., „,,,...... ,-....... .4 TK L 1'040 meters fleetter5 i ..9 pl<'!21A 'Ai, 5, . MPK-43 ■ - ..,„ Figure: Map showing wells within 0.25 mi radius from MPK-09. • • Bettis, Patricia K (DOA) From: Stone, Christopher [Christopher.Stone @bp.com] Sent: Tuesday, November 26, 2013 11:30 AM To: Bettis, Patricia K (DOA) Subject: RE: MPU K-09: Application for Sundry Approval Hi Patricia, It has come to my attention that the conversion of MPK-09 from producer to injector has some uncertainty as it stands. There has been some questions raised from recent modeling suggesting that the area that MPK-09 would sweep to offset producer MPK-17 has already been swept from another neighboring injector. Needless to say the conversion candidate that we thought we had with MPK-09 will require additional work to verify that sweep has already occurred to understand if we ought to move forward. Would it be possible on your part to discard the Application for Sundry Approval and pending the results of the additional work needed to understand the sweep we will resubmit with a detailed operations program and wellbore schematic? Sorry for the confusion regarding this application for conversion. Please contact me if you have any questions. Thanks, Chris Stone BP Exploration (Alaska) Inc. Lead Petroleum Engineer-Milne Point Office:907.564.5518 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis @alaska.gov] Sent: Thursday, November 21, 2013 1:59 PM To: Stone, Christopher Subject: MPU K-09: Application for Sundry Approval Good afternoon Christopher, The Application was missing a detailed operations program and a current wellbore schematic. (Only the Area of Review and the Perforation Attachment was included.) Both the operations program and the wellbore schematic can be submitted to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 i • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • ! • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday, November 21, 2013 1:59 PM To: 'Christopher.Stone @BP.com' Subject: MPU K-09: Application for Sundry Approval Good afternoon Christopher, The Application was missing a detailed operations program and a current wellbore schematic. (Only the Area of Review and the Perforation Attachment was included.) Both the operations program and the wellbore schematic can be submitted to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 NED F E �� Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 0_5-0 1y 333 West 7 Avenue "I Anchorage, Alaska 99501 o v i 1/', 09% Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 `--> MPK-09 2050140 , 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK-30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK -33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK-38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 • • ~,.a t_ MICROFILMED 03/01/2008 DO NOT PLACE -: ,~~ ~Y _- ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicl~\C~+rPgs_Inserts~Mi~film Marker.~c Permit to Drill 2050140 MD 9059./ y I"t~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Well Name/No. MILNE PT UNIT KR K-09 Operator BP EXPLORATION (ALASKA) INC TVD 7095 --" Completion Date 4/8/2005,.- Completion Status i-Oil Current Status i-Oil -~------" REQUIRED INFORMATION .._----~_.~- ~~~,- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Dataset Number Log/ Data Digital Type Med/Frmt j: ~- ::: f6' C Losll5 14104 ¿..fÆ6 C)&t$ {..t 5 14398 --~--~~~---_._-_._._.~ 5{1u.J, 13~~ v API No. 50-029-23247-00-00 UIC N Mud log No Samples No Directional su~ _ MWD, GR, IFR/CASANDRA, RES, ASI, GYRO , (data taken from logs Portion of Master Well Data Maint Name Directional Survey Directional Survey See Notes Induction/Resistivity Log Log Scale Media Interval OH/ Start Stop CH Received 0 9059 Open 4/27/2005 0 9059 Open 4/27/2005 0 0 5/10/2006 100 8934 Open 8/30/2006 100 9058 Open 1/29/2007 Run No I nd uction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? '¥-L..fL- Analysis Received? ~- Interval Start Stop Sample Set Number Comments Sent Received Daily History Received? .~ ())N Formation Tops .~--_._-_.~--~- Comments: ~_.~.._-"-----~- #0 -~-_. Compliance Reviewed By: ;2 j M"~--~ ~-~( Date: - Comments IIFR MWD Physical EOF 7-Jun-2006 GR, ROP, FET, NPHI, RHOS (data sent back due to being corrupt) LIS Veri, GR, ROP, NPHI, NCNT, RHOS, DRHO w/Graphics e · .~, ;,~;f!¥i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn. : Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13,2006 RE: MWD Formation Evaluation Logs: MPK-09, MPS-12_PB1_L1, MPI-13, MPS-18_PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 MPK-09: ao-S-- ð/'-/ -t1: /43CJ?f Digital Log Images: 1 CD Rom 50-029-23247-00 MPS-12 PB1 Ll: ;;)6""3 -ofß ~ /4401 6103 -O&Lf ii /Lf~/Dd- - - ( Digital Log Images: 1 CD Rom 50-029-23133-00, 70, 60 MPI-13: U:r.~ Göl -ö-:r~ I:t ·1l..{3D¡~ Digital Log Images: 1 CD Rom 50-029-23012-00 MPS-18_PB1: UTe... dOd -'(l-IQ Ø' 1'-/t..'¡DO Digital Log Images: 50-029-23133-00, 70 1 CD Rom SCANNED FES 0 1 2007 1 '.0 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907-793-1005 August 28, 2006 RE: MWD Fonnation Evaluation Logs: 1E-I04, CD3-302 PBI, 05-20B, 15-46 L1 PB1, MPK-09, MPE-31, MPC-43, MPE-25A. lE-104 'JOLI- Q';J~ ,~o,S'£.{ CD3-302 PBl (}O<o- 010 /l./lOI 05-20B v QOI;./- ~4 J4049 15-46 Ll PBl QO'-{-/03 1l./lvÛ MPK-09 'é)oõ- 0 f<{ 1~/10t.:{ MPE-3l do5' - Ot-d./L./I 03 MPC-43 øoL/- 03'1 14 10;;) MPE-25A V'I:C- Q04-045" ,g:!)1!J'-! Digital LIS DATA: 1 CD Rom 50-029-23234-00, 50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00, 50-029-23200-00, 50-029-22980-01. l)LEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 15/~o/fY¡;, Signed C~ ~i . {)DS--O/<.J . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 11, 2006 RE: MWD Fonnation Evaluation Logs MPK-09, AK-MW-3591176 1 LIS fonnatted Disc with verification listing. API#: 50-029-23247-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: bf'S-f()b Signed: C _~L ~~CJ p~~ ~b6" -OIL{ . STATE OF ALASKA . ALASKA: L AND GAS CONSERVATION COM .... ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEi\JED 1" 0, 2005 M tW &; R r <'íí:'. Commission lMä~,;K~ç UII Q( O~;¡ \J~ 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: Am:Mrage 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/8/2005 " 205-014 305-073 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3-13-2005 / 50- 029-23247-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4-5-2005 ~ MPK-09 3704' NSL, 2123' WEL, SEC. 03, T12N, R11E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 4202' NSL, 4210' WEL, SEC. 03, T12N, R11 E, UM 63.2' Milne Point Unit / Kuparuk River Sands Total Depth: 9. Plug Back Depth (MD+ TVD) 3814' NSL, 53' WEL, SEC. 04, T12N, R11E, UM 9059 + 7095 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: 6005838 / Zone- /' 9059 + 7095 , Ft ADL 375133 Surface: x- 584433 , y- ASP4 -- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 582339 y- 6006314 Zone- ASP4 Total Depth: x- 581222 y- 6005913 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNa N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , IFR/CASANDRA , RES, ABI , GYRO 2. CASING, LINER AND CEMENTING RECORD CASING SETTING DePTH MD SeTTING JEPTH TVD HOLE AM9\JNT SIZE WT. PER FT. GRADE Top l:iOTTOM lOP BOtTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 114' 35' 114' 42" 260 sx Arctic Set (Approx.) 9-5/8" 47# L-80 35' 5173' 35' 5062' 12-1/4" 690 sx AS Lite, 249 sx Class 'G' 7" 26# L-80 33' 7908' 33' 7046' 8-3/4" 105 sx Class 'G' 4-1/2" 12.6# L-80 7766' 9057' 6997' 7095' 6-1/8" Uncemented Slotted Liner 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) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 7732' N/A MD TVD MD TVD 7979' - 9013' 7067' - 7095' / 25. ACID, FRACTURE, CEMEN"$Q\JEE.ZE,¡:~Ç. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 21, 2005 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF W A TER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rè6i~:r:'T¡¡\1 ~ 1~:\'':',,! ¡ None RBDMS BFL MAY i .!:/.:i 1; .1 1 6 7005 l~L I ~I ~.~~!EIJ r "~""''''''jÅ',_~,,,,,,,,,,,,,,,-,,,,,;. Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TKLB 6831' 6583' None KLGM 6930' 6650' TKUP 7200' 6798' TKUD 7200' 6798' TKC1 7863' 7031' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary. 31. I hereby certify that the fgre¡goíng is true and rrect to the best of my knowledge. Signed Son Title I Technical Assistant' Date DC -ll - cD 2Ô5-014-00 305-073 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. MPK-09 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Walter Quay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE: 2-9/16" - 5M FMC . WELLHEAD: 11" X 2-9/16" 5 Gen 5 Tub hgr. Dual ported 11"x2-7! 'T&B 2.5" ClW;HBPVT Conductor ~ KOP @ 500' Max Hole Angle: 71 degree @ 7450' MD Angle thru perfs = 89° 95/8" 40# L-BO Surface~asing 1 5173' I 27/8" 6,5# EUE 8RD, L-80 tBG. Drift Id: 2.441!'Capacity: 0.00579 7" 26 ppf, L-80, Btre. prod. easing ( drift ID = 6.151 ", eap. = 0.0383 bpf) 7" float collar (PBTD) 7,819'1 7,908'1 7" Weatherford float shoe 4.5" Halliburton float shoe DATE REV. BY COMMENTS Drilled & Completed Doyon-14 04/08/05 MDO a.i. DF Elev. = 34.00Doy-14 a Elev. = 29.20 Doy-14 . B BF. = Camco 2-7/8" x 1" sidepocket KBMM GLM I 150' I Cameo 2-7/8" xi" I 7,517' I sidepoeket KBMM GLM 2-7/8" XN nipple 17,628' I ( Min. Id 2.205" ) Pump, 159 Stg. GC1150, I 7,674'1 Model- GPMTAR 1:1 Intake 400 internials Tandem Seal Section 17,696'1 GSB3DBUT AB/HSN PFSA GSB3DBL T AB/HSN FSA CLS Motor, 171 HP, 3290 V, 44 amp, Model KMH 1 7,710'1 Note: Rerated to below KMH-Ä /1252217 V /34 amps Phoenix MS1 w/Centralizer 1 7,730'1 Baker 7" Tie baek slv. Baker 5"xT'ZXP Liner top pkr. Baker 5"xT' HMC Liner Hanger. Slotted liner 7,970' - 8,219' Blank 8,392' - 8,638' Blank 8,681' - 8,765' Blank 8,808' - 9,013' Blank 7,767' 7,777' 7,784' MILNE POINT UNIT WELL K-09 API NO: 50-029-23247-00 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/12/2005 03:00 - 04:00 1.00 MOB P PRE Skid rig floor 04:00 - 06:00 2.00 MOB P PRE Move rig off well 06:00 - 08:00 2.00 MOB P PRE Moving rig to MPK pad, encountered flat tire, on K pad road 08:00 - 21 :30 13.50 MOB P PRE Repair tire on rig, had to take BOP stack out of cellar, remove spreader beam to repair tire, reinstall stack and beam after repair was done 21 :30 - 00:00 2.50 MOB P PRE Finish move to K pad, on pad ready to spot over well 3/13/2005 00:00 - 02:00 2.00 MOB P PRE Spot rig over well MPK-09 02:00 - 03:00 1.00 RIGU P PRE Skid rig floor, spot rock washer, rigging up, Rig accept @ 03:00 3/13/2005 03:00 - 07:30 4.50 RIGU P PRE Nipple up diverter and diverter lines 07:30 - 09:00 1.50 DRILL P SURF Pre spud Derrick inspection, clear rig floor, police housekeeping thru-out rig 09:00 - 14:30 5.50 DRILL P SURF Picking up 4" pipe out of pipe shed standing in derrick, 52 stands total 14:30 - 17:00 2.50 DRILL P SURF Picking up BHA, Rig up Gyro/wire line unit 17:00 - 18:00 1.00 DRILL P SURF Make up bit and motor, Stab,one stand of HW drill pipe 18:00 - 19:00 1.00 DRILL P SURF Pre spud meeting, diverter test, the right to witness test was wavier by Jeff Jones, witness by WSL 19:00 - 21 :00 2.00 DRILL P SURF Fill stack, check for leaks, drill ice and wood and trash out of conductor to 110ft, Drill to 221' / 21 :00 - 23:30 2.50 DRILL P SURF POH and pick up MWD tool, orient and surface test, Rih 23:30 - 00:00 0.50 DRILL P SURF Drill 221 to 256, with 60 rpms, 900 psi 400 gals per min., Running Gyro ever 100 ft. 3/14/2005 00:00 - 09:00 9.00 DRILL P SURF Drill 256 to 1187, with 80 rpms, 2000 psi 550 gals per min., Running Gyro ever 100 ft. to 352' 09:00 - 10:00 1.00 DRILL P SURF Run New Tech. Gyro 10:00 - 17:00 7.00 DRILL P SURF Drill 1187' to 2311, with 80 rpms, 2400 psi 550 gals per min, TVD 2769 17:00 - 18:00 1.00 DRILL P SURF Circ out Hydrates. raise mud from 9.6 ppg to 10.0 ppg, 6-8 bbls mud over drill nipple into drip pan that drains in to rockwasher - See Remarks Section Of DIMS Report: 18:00 - 22:00 4.00 DRILL P SURF Drill 2311' to 2819 , with 80 rpms, 2700 psi 550 gals per min 22:00 - 22:30 0.50 DRILL P SURF Cirç oot Hydrates, raise mud from 10.0 ppg to 10.3 ppg, 1-2 bbls mud over drill nipple into drip pan that drains in to rockwasher. - See Remarks Section Of DIMS Report: 22:30 - 00:00 1.50 DRILL P SURF Drill 2819' to 3010, with 80 rpms, 2800 psi 550 gals per min 3/15/2005 00:00 - 01 :00 1.00 DRILL P SURF OIrcout Hydrates, mud 10.3 ppg, 1/2 bbl mud over drill nipple into drip pan that drains in to rockwasher - See Remarks Section Of DIMS Report: 01 :00 - 03:00 2.00 DRILL P SURF Drill 3010' to 3299' ,with 80 rpms, 3000 psi 550 gals per min, tvd 3236 03:00 - 04:30 1.50 DRILL P SURF Circulate condition mud for short trip - CBU 2 X - 550 gpm - PP 2840 - RPM 70 TO 5- 04:30 - 09:00 4.50 DRILL P SURF Con't Condition mud due to Hydrates 09:00 - 10:30 1.50 DRILL P SURF Pump out from 3299' to 1793' - Hydtate&iMreased - Hole not taking correct fill- RIH from 1793' to 3299' 10:30 - 11 :30 1.00 DRILL P SURF CBU 1 X - 450 gpm - PP 2000 - RPM 70 - Observed gas cut mud 11 :30 - 12:00 0.50 DRILL P SURF Circulate - Condition mud - 500 gpm - PP 2500 - RPM 70 - TO 5 - PU 122 - SO 108 - ROT 112 - 12:00 - 15:30 3.50 DRILL P SURF Directional Drill from 3299' to 3640' - WOB 35 - RPM 70 - TO on 5 - off 3 - GPM 530 - PP on 2920 - off 2630 - PU 132 - SO Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/15/2005 12:00 - 15:30 3.50 DRILL P SURF 115 - ROT 125 15:30 - 16:30 1.00 DRILL P SURF CBU 1 X - GPM 530 - PP 2810 - RPM 90 - TO 5 16:30 - 19:00 2.50 DRILL P SURF Pump out from 3640' to 710' - Pump at drlg rate - No problems 19:00 - 19:30 0.50 DRILL P SURF CBU 1 X - 425 gpm 1300 psi - Lots of cuttings, sand, and large pieces of gravel back on bottoms up - Flow~ WêIt - Well static - NO Gas cut mud - 10.7 ppg - (in and out) 19:30 - 21 :00 1.50 DRILL P SURF RIH from 710' to 2230' - Fill pipe - Con't RIH from 2230 to 3595' - Break Circulation - Wash from 3595' to 3640' 21 :00 - 22:00 1.00 DRILL P SURF CBU 1.5 X - GPM 500 - PP 2580 - RPM 80 - TO 5 - G8s breaking out at dòg nipple while CBUfrom 850 strokes to 4900 strokes - Mud weight in 10.7 out 10.4 22:00 - 00:00 2.00 DRILL P SURF Directional Drill from 3640' to 3850' - WOB 25 to 35 - RPM 70 to 80 - TO on 5 - off 3 - GPM 530 - PP on 3040 - off 2890 - PU 133 - SO 115 - ROT 125 - MUD weight in 10.7 - out 10.4 3/16/2005 00:00 - 17:00 17.00 DRILL P SURF Directional Drill from 3850' to 4756' - WOB 25 to 30 - RPM 90 - TO on 5 - off 4 - GPM 550 - PP on 3400 - off 3200 - PU 150- SO 125 - ROT 135 17:00 - 21:30 4.50, DRILL P SURF Pump out from 4756' to 710' - Pump at drlg rate - No problems - Hole in good shape - Flow check well- Well static 21 :30 - 23:00 1.50 DRILL P SURF Con't pull out hole with BHA - Break bit - Check motor - Clean floor 23:00 - 00:00 1.00 DRILL P SURF Make up bit - MWD - Orient - Con't RIH with BHA - Surface test MWD 3/17/2005 00:00 - 02:00 2.00 DRILL P SURF Con't RIH from 706' to 4350' - Tight @ 2350' to 2430' - Con't RIH at reduced running speed for surge control 02:00 - 02:30 0.50 DRILL P SURF Ream from 4350' to 4756' - (out gauge hole) - GPM 460 - PP 2600 - RPM 60 - TO 4.5 - (Mud weight cut from 10.8 to 9.6 on btms up) 02:30 - 09:00 6.50 DRILL P SURF Directional Drill from 4756' to 5183' - TD 12 1/4" hole - WOB 20 to 30 - RPM 80 - TO on 5.5 - off 4.5 - GPM 550 - PP 3520 on - off 3460 - PU 152 - SO 127 - ROT 140 09:00 - 10:00 1.00 CASE P SURF CBU 1 X - GPM 550 - PP 3460 - RPM 80 - TO 5 10:00 - 11 :30 1.50 CASE P SURF Pump out from 5183' to 4050' - Tight @ 4850' - Back ream from 4824' to 4450' - Pump out from 4450' to 4050' 11 :30 - 12:00 0.50 CASE P SURF RIH from 4050' to 5183' - Hole in good shape 12:00 - 15:00 3.00 CASE P SURF CBU 3 X - GPM 530 - PP 3210 - Flow check - Well static 15:00 - 19:00 4.00 CASE P SURF Pump out from 5183' to 706' - Pump at drlg rate - Hole in good shape - Flow check well - Well static 19:00 - 21 :00 2.00 CASE P SURF Handle BHA - Stand back 5" HWT - Jars - LD Flex Dc's - MWD - Break bit - Flush motor - LD same 21 :00 - 21 :30 0.50 CASE P SURF Clear / Clean rig floor of BHA tools - 21 :30 - 23:00 1.50 CASE P SURF Rig up 9 5/8" casg tools 23:00 - 00:00 1.00 CASE P SURF PJSM ( running casg) - Pick up float equiupment - Check floats - Pick up and run 9 5/8" 47# L-80 - BTC-M casg to 750' 3/18/2005 00:00 - 04:00 4.00 CASE P SURF Run 9 5/8" casg from 750' to 5173' - Tight spots 800', 835', 896',922', 1057' work through without pumping - Break circulation @ 3034',4100' - No returns @ 4571' Run to 4612'- Break circulation @ 4612' wash to 4674' - 4 bpm @ 460 psi - Con't RIH to 5090' Break circulation - wash from 5090' to 5131' - Make up landing joint / hanger - RIH land casg @ 5173' 04:00 - 04:30 0.50 CASE P SURF Break and lay down Franks fill up tool - Blow down Top Drive - Make up Schlumberger Dowell cementing head - Cementing lines Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/18/2005 04:30 - 08:00 3.50 CASE P SURF Stage up pump fom 4 BPM @ 460 psi to 8.5 BPM @ - Circulate I Condition mud for cementing of 9 5/8" surface casg 08:00 - 10:00 2.00 CEMT P SURF Give to Dowell Pump 5 bbls water - 2 bpm @ 100 psi Test lines to 3000 psi Pump 20 bbls CW 100 (one gallon dye in first 5 bbls slurry pumped) - 6 bpm @ 150 psi Pump 50 bbls 10.7 ppg Mud Push - 5 bpm @ 340 psi Drop bottom plug Mix and pump 694 sxs - 550 bbls Type "ASL" Yield 4.45 cflsx Mixed @ 10.7 ppg - 6.5 bpm @ 370 psi Mix and pump 221 sxs - 45.5 bbls Class "G" Yield 1.16 cf/sx Mixed @ 15.8 ppg - 6 bpm @ 400 psi Kick out Top plug with 30 bbls water thru tub Give to rig 10:00 - 11 :00 1.00 CEMT P SURF Displaced with 357.5 bbls of spud mud - 6.5 bpm @ 700 psi- Lost partical returns when Tail cement tumed oomêf - Lost complete returns just before bumping plug - Bumped plug with 1700 psi 1000 psi over circulating pressure - 2U),. lead cement billet to surface 11 :00 - 11 :30 0.50 CASE P SURF Test casg to 1000 psi for 30 mins - Record on chart 11 :30 - 13:00 1.50 CASE P SURF Rig down cement head - Wash out bag - Riser - Flow line - Lay down landing joint 13:00 - 14:00 1.00 CASE P SURF Clear I Clean rig floor - Lay down casg tools 14:00 - 15:30 1.50 CASE P SURF PJSM - Nipple down divertor system 15:30 - 18:00 2.50 CASE P SURF Nipple up Casg head - Tubing spool - Test metal to metal seal to 1000 psi for 10 mins 18:00 - 20:00 2.00 CASE P SURF Nippling up BOP's - Driller notified Well SiteLead$r that .cement belching outof1he ffùted9 5/8" casing hanger - In addition fluid bubbling on exterior öf Céllar box - Stopped nipple up operation 20:00 - 00:00 4.00 CASE N DPRB SURF Monitor And Secure Cellar Area - Make Notifications To Supervisors And Agencies See Remarks Section Of DIMS Report. 3/19/2005 00:00 - 03:00 3.00 CASE N DPRB SURF Monitor Well - Perform A Job Hazard Analysis With HSE Drilling Advisor Herb Williams And All Personal For All Tasks To Be Preformed. 03:00 - 04:30 1.50 CASE N DPRB SURF Monitor Well - Lay Down 5" HWDP And 4" Drill Pipe Out Of Maeun PreparatIon For Rig Move - Remove Fluids Out Of Mud Pits And Rock Washer - Remove Drill Pipe Out Of Pipe Shed 04:30 - 07:00 2.50 CASE N DPRB SURF Monitor Well - Nipple Down BOP And Related Equipment 07:00 - 16:30 9.50 CASE N DPRB SURF Monitor Well - Wait on orders 16:30 - 19:00 2.50 CASE N DPRB SURF Monitor Well - Nipple up BOP's 19:00 - 21 :00 2.00 CASE N DPRB SURF Monitor Well - Rig up testing equipment - Install test plug - open lower annulus valve 21 :00 - 00:00 3.00 CASE N DPRB SURF Monitor Well- Test BOPs - Annular 250 low 2500 high 5 mins each test - Top rams - Floor safety valve - HCR Choke / Kill valves - Dart valve (failed) Manual Choke I Kill valves - 250 low 3500 high 5 mins each test 3/20/2005 00:00 - 03:00 3.00 CASE N DPRB SURF Montior Well - Con't Testing BOPS - Choke manifold - Bottom rams - Blind rams - Upper I lower IBOP valves - 250 low 3500 high 5 mins each test - Dart valve failed test send in for repair - All other associated equipment successfully tested - John Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/20/2005 00:00 - 03:00 3.00 CASE N DPRB SURF Spaulding with AOGCC waived witness of BOP test - WSL witnessed all BOP testing 03:00 - 04:00 1.00 CASE N DPRB SURF Monitor Well - Rig down testing equipment - Shut annulus valve - Pull test plug - Install wear ring - Blow down choke 04:00 - 05:00 1.00 CASE N DPRB SURF Monitor Well - Make up mule shoe - RIH with 4" Drill pipe to 2400' 05:00 - 06:00 1.00 CASE N DPRB SURF Monitor Well - Pump Hi-vis spacer - Displace mud with water - GPM 272 - PP 650 - RPM 75 - Reciprocate string 06:00 - 08:00 2.00 CASE N DPRB SURF Monitor Well - Rig up Little Red Services on pump in sub - Test lines to 2000 psi - Displace water with diesel to freeze protect suspended well - 5 bpm @ 400 psi - (181 bbls) 08:00 - 09:00 1.00 CASE N DPRB SURF Monitor Well - POOH 09:00 - 10:30 1.50 CASE N DPRB SURF Monitor Well - Pick up tubing hanger with TWC installed - RIH Land - RILD 10:30 - 11 :30 1.00 CASE N DPRB SURF Monitor Well - Nipple down BOP's 11 :30 - 13:00 1.50 CASE N DPRB SURF Monitor Well - Nipple up Adapter flange / Tubing spool - Otis quick connect - 41/16" dry hole valve 13:00 - 13:30 0.50 CASE N DPRB SURF Monitor Well - Rig up Hot oil truck - Test adapter and tree to 5000 psi 10 mins - Rig down hot oil truck 13:30 - 15:30 2.00 CASE N DPRB SURF Monitor Well - Pull TWC - InstaffBP\4-~~ V!IIeJI- SUØk out çear - Release rig 15:30 - 22:00 6.50 T A N DPRB ÁBAN PJSM - Prepare to move rig off K-09 - Skid rig loor from drlg position to move position - lay mats - Move rig from K-09 to Stand-by area 22:00 - 00:00 2.00 TA N DPRB ABAN Stand-by - Waiting on trucks to move camp to move rig on K-06 3/21/2005 00:00 - 14:30 14.50 TA N DPRB ABAN Rig on Stand-by - Wait on trucks to move camp - Grind burs off hammer unions - Inspect drive chains on drawworks - Mud pumps - Spread herculite for camp - Inspect Top drive - Change gear oil - Pull top ODS roller assembly - Inspect grease reinstall - Fill top drive gear end - Split Hydril knife valve - Prep location for move - Lay herculite mats around well K-09 14:30 - 17:00 2.50 MOB N DPRB PRE PJSM - Skid rig floor - Move rig off Stand-by mats - Move mats to MPK-09 - Set mats for rig move 17:00 - 20:30 3.50 MOB N DPRB PRE Move rig from Stand-by'srea tb well MPK-09 - Spot rig over well - Skid rig floor from move position to drlg position - Set herculite and mats for rock washer 20:30 - 22:00 1.50 MOB N DPRB PRE Rig up floor - Prepare to take on water - Spot rock washer 22:00 - 23:00 1.00 CASE N DPRB SURF (Resume operations on K-09) - Pull BPV - Install TWC - ND Tubing adapter 4 1/16" dry hole valve 23:00 - 00:00 1.00 CASE N DPRB SURF NU BOP's 3/22/2005 00:00 - 03:30 3.50 CASE N DPRB SURF NU BOP's - Rig up test equip 03:30 - 04:30 1.00 CASE N DPRB SURF Pull Hanger - Install Test plug 04:30 - 05:30 1.00 CASE N DPRB SURF Rig up to test BOP's 05:30 - 11 :30 6.00 CASE N DPRB SURF Testing BOP's - Annular 250 low - 2500 high 5min each test- Top pipe rams - Choke Manifold - HCR Choke I Kill - Manual Choke I Kill - Upper I Lower IBOP - Bottom rams - Blind rams - Floor safety valve and Dart valve (failed) - 250 low 3500 high 5 mins each test - All test were witnessed by WSL - Chuck Sheave with AOGCC waived witness of BOP test - Rig down testing equip - Shut annulus valves - Pull test plug - Install wear ring 11 :30 - 13:00 1.50 CASE N DPRB SURF Make up mule shoe - RIH with 4" DP to 2375' Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/22/2005 13:00 - 13:30 0.50 CASE N DPRB SURF Displace freeze protection (diesel) from 2375' with water 13:30 - 14:00 0.50 CASE N DPRB SURF RIH from 2375' to 3540' 14:00 - 16:00 2.00 CASE N DPRB SURF Displace 10.7 spud mud from well with water - POH from 3540' to 2400' 16:00 - 17:30 1.50 CASE N DPRB SURF Displace water with freeze protection (Diesel) 17:30 - 18:30 1.00 CASE N DPRB SURF POH with 4" drill pipe - Stand back in mast 18:30 - 19:30 1.00 CASE N DPRB SURF PJSM - Rig up tubing equipment to run 3 1/2" tubing 19:30 - 22:30 3.00 CASE N DPRB SURF Pick up and run 111 joints 3 1/2" NSCT 9.3# L-80 tubing - Land same with TWC installed - RILDS 22:30 - 23:30 1.00 CASE N DPRB SURF ND BOP's 23:30 - 00:00 0.50 CASE N DPRB SURF NU tubing adapter spool - 41/16" dry hole valve 3/23/2005 00:00 - 00:30 0.50 CASE N DPRB SURF NU tubing adapter - 41/16" Dry hole valve - Test to 5000 for 10 mins 00:30 - 01 :00 0.50 CASE N DPRB SURF Pull TWC - Install BPV 01 :00 - 01 :30 0.50 CASE N DPRB SURF Secure Tree - Release ri @ 1: 0 Hrs 3/27/2005 23:00 - 00:00 1.00 MOB N DPRB PRE Rig down floor - Skid rig floor from drg to move position - Pull off Well K-06 3/28/2005 00:00 - 03:00 3.00 MOB N DPRB PRE Move rig from K-06 to K-09 - Spot rig over well K-09 03:00 - 03:30 0.50 MOB N DPRB PRE Shim rig 03:30 - 04:00 0.50 RIGU N DPRB PRE Skid rig floor from move to drlg position 04:00 - 04:30 0.50 RIGU N DPRB PRE Spot rock washer - Berm up same - Rig up floor - Prepare to take on water - (Accept rig @ 04:30 hrs) Resume operations 04:30 - 07:30 3.00 CASE N DPRB SURF Spot Milne pt Slop tank - Rig up lines to Displace freeze protection out well (diesel) - Take on water 07:30 - 08:00 0.50 CASE N DPRB SURF Dry Rod BPV out 08:00 - 09:00 1.00 CASE N DPRB SURF Displace 270 bbls diesel out of well @ 4 bpm - 250 ICP - FCP 600 09:00 - 09:30 0.50 CASE N DPRB SURF Install TWC - Test from backside to 1000 psi 09:30 - 10:30 1.00 CASE N DPRB SURF Nipple down tree 10:30 - 15:00 4.50 CASE N DPRB SURF Nipple up BOP's 15:00 - 16:30 1.50 CASE N DPRB SURF PU 4" Drill pipe from pipe shed standing back in derrick 16:30 - 17:30 1.00 CASE N DPRB SURF RU to body test BOP stack - Test stack to 250 low 3500 high 5 mins each test - rig down testing equipment - Pull test joint - Record on chart - WSL Witnessed test 17:30 - 19:00 1.50 CASE N DPRB SURF Make up XO's to pull tubing hanger - Back out LDS - Pull hanger to rig floor - Break out landing joint - XO's - Hanger - XO's below hanger 19:00 - 22:00 3.00 CASE N DPRB SURF Lay down 3 1/2" L-80 9.3# NSCT tubing - 111 joints 22:00 - 23:00 1.00 CASE N DPRB SURF Rig down tubing handling equipment - Power tongs - Clear rig floor 23:00 - 00:00 1.00 CASE P SURF Pick up test joint - Install test plug - Rig up test equipment - Open annulus valves 3/29/2005 00:00 - 03:00 3.00 CASE P SURF Test BOP's - Annular 250 low 2500 high 5 mins each test- Pipe rams - Blind rams - All other associated well control equipment to 250 low 3500 high 5 mins each test - Performed Accumulator test - (Floor dart valve failed new one coming from Weatherford) - All test recorded on chart - WSL witnessed test - John Crisp with AOGCC waived witness of test 03:00 - 04:00 1.00 CASE P SURF Rig down test equipment - Pull test plug - Install wear ring - Lay down test joint - Close annulus valves - Blow down choke manifold 04:00 - 04:30 0.50 CASE P SURF Mobilize short BHA to rig floor 04:30 - 06:30 2.00 CASE P SURF Make up bit to motor - MWD - Orient - Surface test MWD Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 3/29/2005 06:30 - 08:00 1.50 CASE P SURF Picking up HWDP from pipe shed 08:00 - 11 :30 3.50 CASE P SURF Picking up 4" pipe from pipe shed, fill pipe ever 1000 ft to 4250' 11 :30 - 12:00 0.50 CASE P SURF Rih with pipe from derrick to 4930' 12:00 - 12:30 0.50 CASE P SURF Wash from 4930 to 5084 40 rpms @ 4K torque, 412 GPM, 1330 psi 12:30 - 13:00 0.50 CASE P SURF Circ and condo mud for Csg test 13:00 - 14:00 1.00 CASE P SURF Rig up and test Csg to 1000 psi for 30 min. 14:00 - 15:00 1.00 CEMT P SURF Drill out float and shoe track and shoe@ 5173', drill new hole to 5203' 15:00 - 16:00 1.00 CASE P SURF Circ for FIT test, 500 GPM 1880 psi, 40 rpms 16:00 - 17:00 1.00 CASE P SURF FIT test with 9.3 mud wt. 450 psi, TVD 5062', MD 5173= 11.0 EMW 17:00 - 00:00 7.00 DRILL P INT1 Drilling 5203' to 5650 with 525 gpm, 3000 psi, 100 Rpms, 7K TO AST 1.1, ADT 4.04 3/30/2005 00:00 - 02:30 2.50 DRILL P INT1 Drilling 5650' to 5855 with 550 gpm, 3000 psi, 100 Rpms, 7K TO, 02:30 - 03:00 0.50 DRILL N DFAL INT1 lost 500 psi on pump pressure, check pumps, ok 03:00 - 03:30 0.50 DRILL N DFAL INTi Pumping out 126 gpm, looking for wash out, (wet trip called BP EMS @ 3:00 ), found wash out in slip area 1.5 ft below box, on second stand pulled, 03:30 - 04:00 0.50 DRILL N DFAL INT1 Lay down stand with bad jt., RIH 04:00 - 17:00 13.00 DRILL P INT1 Drilling 5855' to 6630 with 550 gpm, 3500 psi, 100 Rpms, 7K TO, not able to hold tool face on motor 17:00 - 18:30 1.50 DRI LL N DPRB INT1 Circ., for trip to change BHA 18:30 - 20:00 1.50 DRILL N DPRB INT1 Pumping out to 5173' with full drilling rate (Wet trip called BP EMS @ 17:30) 20:00 - 21 :30 1.50 DRILL N DPRB INT1 Circ bottoms up from 5173', Safety meeting with Steve Marshall and Gary Christman, slug pipe and flow check well 21 :30 - 23:00 1.50 DRILL N DPRB INT1 Poh to HWD pipe 23:00 - 00:00 1.00 DRILL N DPRB INTi Change to 5" handling Eqp. stand back HWDP and flex DC 3/31/2005 00:00 - 00:30 0.50 DRILL N DPRB INT1 Down load MWD 00:30 - 02:00 1.50 DRILL N DPRB INT1 Change out Bit and stab, surface test MWD 02:00 - 04:30 2.50 DRILL N DPRB INT1 Rih, washed last stand to bottom 04:30 - 22:00 17.50 DRILL P INT1 Drilling 6630' to 7487' with 550 gpm, 3600 psi, 80 Rpms, 7K TO, AST 6.08,ART 6.47 22:00 - 00:00 2.00 DRILL N RREP INT1 Circ with one pump, repair mud end on #1 pump, circ with 400 gals min 1640 psi 50 rpms 4/1/2005 00:00 - 01 :00 1.00 DRILL N RREP INT1 Circ with one pump, repair mud end on #1 pump, circ with 400 gals min 1640 psi 50 rpms 01 :00 - 03:30 2.50 DRILL P INTi Drilling 7487' to 7562 with 500 gpm, 3000 psi, 80 Rpms, 7K TO 03:30 - 04:30 1.00 DRILL P INT1 Circ., Pump repair #2 pump swab and liner 04:30 - 21 :30 17.00 DRILL P INT1 Drilling 7562' to 7918' TD with 500 gpm, 3000 psi, 80 Rpms, 7KTO 21 :30 - 23:30 2.00 CASE P INTi Circ., three bottoms up, 500 gpm 2800 psi, 100 rpms 23:30 - 00:00 0.50 CASE P INT1 Pumping out to shoe. with full drilling rate ( Wet trip, called BP EMS @ 23:15) 4/2/2005 00:00 - 02:00 2.00 CASE P INT1 Pumping out to 5150, with full drilling rate, (tight spot @ 7090' to 6800') (lay down two jts, box and pin washed) 02:00 - 03:30 1.50 CASE P INTi Slip and cut drilling line, service top drive 03:30 - 04:30 1.00 CASE P INTi Rih, worked tight spot 6800' to 7090', washed last stand to bottom @ 7918' Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 4/212005 04:30 - 06:30 2.00 CASE P INT1 Circ. Three bottoms up, with 500 gpms, 2800 psi, 100 rpms 06:30 - 08:30 2.00 CASE P INT1 Pumping out to 5173 with full drilling rate ( wet trip called BP EMS @ 06:30 ) 08:30 - 09:30 1.00 CASE P INT1 Flow check well, Circ, Bottoms up to clear 9 5/8 Csg 09:30 - 11 :00 1.50 CASE P INT1 POH to HWDP 11 :00 - 13:00 2.00 CASE P INT1 Lay down HWDP and BHA 13:00 - 14:00 1.00 CASE P INT1 Clear floor of tools 14:00 - 15:00 1.00 CASE P INT1 Pull wear ring, install test plug, change top rams to 7", test door seales to 1500 psi 15:00 - 16:00 1.00 CASE P INT1 Rig up to run 7" csg 16:00 - 21 :00 5.00 CASE P INT1 PJSM, Picking up 7" 26# L-80 BTC csg to 51610 21 :00 - 22:00 1.00 CASE P INT1 Circ. one Csg volume @ 5161',5 bbls min., 440 psi 22:00 - 00:00 2.00 CASE P INT1 Picking up 7" 26# L -80 BTC csg, total 186 jts, circ last jt. down, land on hanger, Shoe 7908', float 7818' 4/3/2005 00:00 - 00:30 0.50 CASE P INT1 Circ and Reciprocate csg, with franks tool, 5 bbls min. 600 psi, P/U 240K, SIO 175K 00:30 - 01 :00 0.50 CASE P INT1 Rig down Franks tool, rig up cementing head 01 :00 - 02:00 1.00 CASE P INTi Circ and Reciprocate csg" 5 bbls min. 600 psi, PIU 240K, SIO 175K 02:00 - 03:00 1.00 CASE P INT1 Daylight saving time 03:00 - 03:30 0.50 CEMT P INT1 Cement with Schlumberger with 5 bbls water, Test lines to 4000 psi, 10 bbls CW1 00, 20 bbls Mud push mixed @ 11.1, drop bottom plug, 22 bbls, 105.5 sxs. Class G, Yield 1.17, mixed @ 15.8, pumped @ 5 bbls min., drop top plug, kicked out with 20 bbls water 03:30 - 04:30 1.00 CEMT P INT1 Displace with 10.1 mud 278 bbls, pumped @ 5 bbls min 680 psi, reciprocate thru out job, full returns, bumped plug with 1700 psi, float held 04:30 - 06:30 2.00 CASE P INT1 Drain stack, lay down landing jt., install packoff, test to 5000 psi 06:30 - 08:30 2.00 CASE P INT1 Change top rams to 2 7/8 x 5" test same to 250-3500psi 5 min per test, test witness by WSL 08:30 - 09:00 0.50 CASE P INT1 Change out bales, clear floor 09:00 - 11 :30 2.50 CASE P INT1 Picking up BHA #5, Bit 6 1/8 DSX111, 5" sperryDrill1.5 bend,float sub,Stab,4 3/4 Slim phase 4 DGR,DM hang off,4 3/4 Neutron/Density,TM hang off,3 flex dc,jars, surface test MWD 11 :30 - 15:00 3.50 CASE P INT1 RIH to 7418' 15:00 - 15:30 0.50 CASE P INT1 Service rig, and topdrive 15:30 - 16:00 0.50 CASE P INTi Rih to 7812' 16:00 - 17:00 1.00 CASE P INT1 Circ bottoms up with 237 gals min. 1580 psi, 30 rpms 17:00 - 18:00 1.00 CASE P INT1 Test Csg to 1500 psi for 30 min. 18:00 - 19:30 1.50 CEMT P INT1 Drill out float and shoe and 20 ft of new hole to 7938' 19:30 - 23:00 3.50 CASE P INT1 Circ. with 270 gpm 1900 psi, 40 rpms,pump high vis sweep to surface,pump 60 bbls hi vis spacer, displace with 9.0 # flow-pro mud, clean surface Equip., flush kill and choke lines 23:00 - 00:00 1.00 CASE P INT1 Fit test with 9.0 mwt,550 psi,7049 Tvd= 10.5 emwt 4/4/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill 7938 to 8483' with 80 rpms, 260 gpm, 2300 psi Ast 6.84. Art 6.33, PIU 170K, SIO 125, RfT 145, Tq 7K 4/5/2005 00:00 - 01 :00 1.00 DRILL P PROD1 Circ (while Geo. talk to down about dip.) 01 :00 - 17:30 16.50 DRILL P PROD1 Drill 8483' to 9059' TD with 80 rpms, 260 gpm, 2300 psi ./ 17:30 - 19:30 2.00 CASE P PROD1 Circ. three bottoms up with 260 gpm 80 rpms 19:30 - 20:45 1.25 CASE P PROD1 Pump out to csg shoe 7908' with full drilling rate. ( wet trip, called BP EMS @ 19:30) 20:45 - 21 :30 0.75 CASE P PROD1 RIH, wash last stand to bottom to 9059' Printed: 4/11/2005 10:09:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: 4/8/2005 Rig Number: Spud Date: 3/13/2005 End: 4/512005 21 :30 - 23:00 1.50 CASE P PROD1 Circ, three bottoms up with 260 gpm 2300 psi, 80 rpms 23:00 - 00:00 1.00 CASE P PROD1 Pump out to csg shoe 7908' with full drilling rate. ( wet trip, called BP EMS @ 23:30 ) 4/6/2005 00:00 - 01 :00 1.00 CASE P PROD1 Circ bottoms up at 7" csg shoe 7908' 270 gpm, 1930 psi 01 :00 - 03:00 2.00 CASE P PROD1 Poh to BHA 03:00 - 06:00 3.00 CASE P PROD1 laydown BHA and unload Nuclear source, and down load MWD 06:00 - 07:00 1.00 CASE P PROD1 PJSM, Rig up to pickup 4.5 slotted liner 07:00 - 08:30 1.50 CASE P PROD1 Picking up 4.5 slotted liner and Baker HMC liner hanger,Baker ZXP packer, total 30 jts, 11 solid its, 19 slotted its. 08:30 - 11 :00 2.50 CASE P PROD1 Rih with liner to 7900' 11 :00 - 13:00 2.00 CASE P PROD1 Circ. liner, safety stand down meeting with both crews 13:00 - 13:30 0.50 CASE P PROD1 Rih with liner to 9059' ,i 13:30 - 14:30 1.00 CASE P PROD1 Circ, drop ball, pressure up to 2300 psi, set liner hanger, set 70k on liner hanger,to set packer, turn 20 rds. to right to release, pickup 8 ft. to release dogs, set 40k to set packer, liner top @ 7765', shoe 9057' 14:30 - 15:00 0.50 CASE P PROD1 Test liner top packer to 1500 psi for 15 min. 15:00 - 16:00 1.00 CASE P PROD1 Circ bottoms up, pump dry job 16:00 - 19:00 3.00 CASE P PROD1 Poh with running tool, lay down same 19:00 - 22:00 3.00 CASE P PROD1 Pick up Circ sub., Rih to 7760' 22:00 - 23:00 1.00 CASE P PROD1 Displace well with two high vis pills follow by 8.5 seawater, 100 rpms, 500 gpm 3200 psi 23:00 - 00:00 1.00 CASE P PROD1 Cut drilling line, clean pits and shakers 4/7/2005 00:00 - 00:30 0.50 CASE P PROD1 Cut and slip drilling line, service topdrive 00:30 - 01 :00 0.50 CASE P PROD1 Circ with sea water for clean up 01 :00 - 05:30 4.50 CASE P PROD1 PJSM,Poh, laying down excess pipe, 05:30 - 06:00 0.50 CASE P PROD1 Pull wear ring 06:00 - 07:00 1.00 RUNCO RUf\lCMP PJSM, rig up to pickup 2 7/8 tubing and ESP pump 07:00 - 23:00 16.00 RUNCO RUf\lCMP PJSM, Picking up ESP pump and 2 7/8 tubing, total 242 its, 2 GLM, Centralizer 7731', XN 7628', GLM, 7517', GLM 149', Lesalle clamps 127, PIU 105K, SIO 95K 23:00 - 00:00 1.00 RUNCO RUf\lCMP Picking up Tubing hanger, Hooking up ESP cable 4/8/2005 00:00 - 01 :00 1.00 RUNCO RUf\lCMP Hooking up ESP Cable and test, Land tubing, with TWC in place 01 :00 - 02:00 1.00 RUNCO RUf\lCMP Test TWC to 1000 psi, for 5 min, lay down landing it. 02:00 - 04:00 2.00 RUNCO RUf\lCMP Nipple down BOPS 04:00 - 05:30 1.50 RUNCO RUf\lCMP Nipple up Tubing head adapter and CIW 2 9/16 5000k tree, test Tree and adapter to 5000k for 10 min. 05:30 - 06:00 0.50 RUNCO RUf\lCMP Rig up Lubricator and pull TWC and set BPV, check ESP conductivity 06:00 - 07:00 1.00 RUNCO RUf\lCMP Secure well, suck out cellar, Rig release for rig move to MPK-22 @ 07:004/8/2005 Printed: 4/11/2005 10:09:59 AM 3,843 (psi) 10.50 (ppg) - Printed: 4/11/2005 10:09:53 AM 550 (psi 9.00 (ppg) 7,043.0 (ft) 7,938.0 (ft) FIT 4/3/2005 WELL SERVICE REPORT . WELL JOB SCOPE MPK-09 NEW WELL POST DATE DAILY WORK 4/8/2005 FREEZE PROT AFE KEY PERSON MKD337431 LRS-BRENNY JASON MINID 0" DEPTH OFT UNIT LRS 40 DAYSUPV HULME NIGHT SUPV UNKNOWN TTL SIZE 0" DAILY SUMMARY (POST RWO) T/I/O=OIOIO Freeze Protect Well. Pum ed 65 bbls crude down ia and 15 bbls crude down tb . Final WHP=OIOIO Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 14:30 start ticket 15:00 load crude 15:50 mi, stand by for crew workinQ on well 16:40 ru, pt, pism, line up to pump down ia 17:04 1.75 sta rt crude 100 0 0 0 start pumpinQ down ia 17:21 1.1 20 " " 1600 18:02 shut 65 " " 1100 down shut down, ru to tbg 18:28 .8 start " " 0 start pumpinQ 18:33 .5 5 " " 2300 19:10 .5 15 " " 1500 shut down, rd 19:30 mo 20:29 end ticket Final-> 0 0 0 I FLUID SUMMARY 80 bbls crude SERVICE COMPANY - SERVICE DAILY COST CUMULTOTAL BP $0 $0 LITTLE RED $1,410 $16,680 WAREHOUSE $0 $9,336 TOTAL FIELD ESTIMATE: $1,410 $26,016 Halliburton Sperry-Sun Milne Point Unit BPXA MPK-09 Job No. AKZZ3591176, Surveyed: 4 April, 2005 Survey Report 14 April, 2005 Your Ref: API 500292324700 ..... Surface Coordinates: 6005838.54 N, 584432.85 E (70' 25' 33.1718" N, 149' 18' 43.0451" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 63.20ft above Mean Sea Level SP'E!I"""I"""Y-SU"" DRILLING SeR.VICes A Halliburton Company DEFINITI E . . Survey Ref: svy1513 Halliburton Sperry-Sun Survey Report for MPK-09 Your Ref: API 500292324700 Job No. AKZZ3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 0.00 0.000 0.000 -63.20 0.00 0.00 N 0.00 E 6005838.54 N 584432.85 E 0.00 CB-SS-GYRO 168.00 0.750 75.000 104.80 168.00 0.28 N 1.06 E 6005838.84 N 584433.91 E 0.446 -1.06 259.00 0.750 43.000 195.79 258.99 0.87 N 2.04 E 6005839.44 N 584434.88 E 0.454 -2.05 MWD+IIFR+MS+SAG 332.26 0.660 329.820 269.04 332.24 1.59 N 2.16 E 6005840.15 N 584434.99 E 1.151 -2.17 378.16 1.260 304.420 314.94 378.14 2.10 N 1.61 E 6005840.66 N 584434.44 E 1.572 -1.62 . 469.17 2.730 313.100 405.89 469.09 4.15 N 0.80W 6005842.68 N 584432.00 E 1.644 0.77 561.26 5.250 303.230 497.75 560.95 7.96 N 5.93W 6005846.43 N 584426.84 E 2.826 5.88 650.78 5.800 304.850 586.85 650.05 12.79N 13.06W 6005851.18 N 584419.64 E 0.639 12.98 747.49 7.140 302.330 682.95 74615 18.79N 22.15W 6005857.08 N 584410.49 E 1.416 22.04 842.28 8.060 299.390 776.90 840.10 25.21 N 32.92 W 6005863.37 N 584399.65 E 1.053 32.77 938.44 10.330 301.530 871.82 935.02 33.02 N 46.14W 6005871.04 N 584386.33 E 2.387 45.94 1032.99 11.900 305.570 964.60 1027.80 43.13 N 61.30 W 6005880.97 N 584371.07 E 1.853 61.04 1129.45 13.360 303.900 1058.72 1121.92 55.13 N 78.64 W 6005892.78 N 584353.59 E 1.560 78.30 1224.96 13.360 305.310 1151.65 1214.85 67.66 N 96.81 W 6005905.10 N 584335.29 E 0.341 96.39 1321.15 12.710 305.740 1245.36 1308.56 80.27 N 114.46 W 6005917.51 N 584317.49 E 0.683 113.97 1417.06 12.860 306.730 1338.89 1402.09 92.81 N 131.58W 6005929.86 N 584300.23 E 0.277 131.01 1512.99 12.390 306.520 1432.50 1495.70 105.32 N 148.41 W 6005942.18 N 584283.26 E 0.492 147.76 1609.52 12.060 306.550 1526.84 1590.04 117.49N 164.83 W 6005954.16 N 584266.70 E 0.342 164.11 1705.44 13.190 306.660 1620.44 1683.64 129.99 N 181.66W 6005966.47 N 584249.73 E 1.178 180.86 1801.20 13.230 306.230 1713.66 1776.86 142.99 N 199.26 W 6005979.27 N 584231.98 E 0.111 198.39 1897.60 12.360 306.670 1807.67 1870.87 155.67 N 216.44 W 6005991.75 N 584214.66 E 0.908 215.48 . 1993.68 11.760 308.510 1901.63 1964.83 167.91 N 232.35 W 6006003.81 N 584198.62 E 0.742 231.32 2089.74 12.850 316.590 1995.49 2058.69 181.77N 247.35 W 6006017.50 N 584183.46 E 2.119 246.24 2185.58 12.880 317.090 2088.92 2152.12 197.33 N 261.95 W 6006032.90 N 584168.69 E 0.120 260.74 2281.58 12.670 317.070 2182.55 2245.75 212.88 N 276.40 W 6006048.28 N 584154.06 E 0.219 275.10 2377.73 14.020 323.490 2276.10 2339.30 229.96 N 290.52 W 6006065.20 N 584139.75 E 2.083 289.11 2474.28 14.310 324.980 2369.72 2432.92 249.13 N 304.32 W 6006084.21 N 584125.73 E 0.483 302.79 2569.79 13.930 321.770 2462.34 2525.54 267.83 N 318.21 W 6006102.75 N 584111.63 E 0.911 316.57 2665.75 13.310 317.230 2555.61 2618.81 285.01 N 332.86 W 6006119.77 N 584096.79 E 1.287 331.11 2762.17 12.780 317.200 2649.54 2712.74 300.99 N 347.64 W 6006135.57 N 584081.83 E 0.550 345.80 2856.72 12.750 315.970 2741.75 2804.95 316.16 N 362.00 W 6006150.59 N 584067.30 E 0.289 360.06 2952.65 12.480 316.630 2835.37 2898.57 331.31 N 376.47 W 6006165.57 N 584052.65 E 0.319 374.44 3049.42 12.600 317.000 2929.83 2993.03 346.63 N 390.85 W 6006180.72 N 584038.10 E 0.149 388.73 3145.74 13.380 320.550 3023.68 3086.88 362.92 N 405.10 W 6006196.85 N 584023.67 E 1.158 402.87 3242.64 13.560 322.080 3117.92 3181.12 380.54 N 419.20 W 6006214.31 N 584009.37 E 0.412 416.87 14 April, 2005 - 10:02 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPK-09 Your Ref: API 500292324700 Job No. AKZZ3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3338.34 13.770 323.830 3210.91 3274.11 398.58 N 432.82 W 6006232.20 N 583995.55 E 0.485 430.38 3435.18 12.990 318.490 3305.12 3368.32 416.04 N 446.84 W 6006249.49 N 583981.33 E 1.508 444.29 3530.21 12.840 317.080 3397.75 3460.95 431.77N 461.11 W 6006265.06 N 583966.89 E 0.367 458.46 3625.44 12.460 317.030 3490.67 3553.87 447.03 N 475.31 W 6006280.17 N 583952.51 E 0.399 472.57 3720.17 13.700 317.520 3582.94 3646.14 462.78 N 489.86 W 6006295.75 N 583937.79 E 1.314 487.02 . 3816.65 13.710 317.810 3676.67 3739.87 479.68 N 505.25 W 6006312.47 N 583922.20 E 0.072 502.31 3912.61 13.520 317.760 3769.94 3833.14 496.41 N 520.43 W 6006329.03 N 583906.84 E 0.198 517.39 4008.84 13.170 318.770 3863.57 3926.77 512.98N 535.21 W 6006345.43 N 583891.87 E 0.437 532.07 4105.31 12.690 318.210 3957.59 402079 529.15 N 549.52 W 6006361.44 N 58387738 E 0.514 546.28 4200.97 12.900 320.340 4050.88 4114.08 545.20 N 563.34 W 6006377.33 N 583863.38 E 0.540 560.00 4297.36 12.450 321.030 4144.92 4208.12 561.56 N 576.74 W 6006393.54 N 583849.79 E 0.493 573.30 4392.77 12.190 321.800 4238.13 4301.33 577.48 N 589.44 W 6006409.31 N 583836.92 E 0.322 585.90 4489.07 13.620 321 .180 4331.99 4395.19 594.30 N 602.83 W 6006425.98 N 583823.33 E 1.492 599.19 4586.01 13.630 321.520 4426.21 4489.41 612.14 N 617.09 W 6006443.65 N 583808.87 E 0.083 613.34 4680.58 13.030 319.430 4518.23 4581.43 628.96 N 630.96 W 6006460.32 N 583794.81 E 0.814 627.11 4773.28 13.230 319.410 4608.51 4671.71 644.95 N 644.66 W 6006476.16 N 583780.93 E 0.216 640.71 4868.13 13.030 318.470 4700.88 4764.08 661.20 N 658.81 W 6006492.24 N 583766.60 E 0.308 654.76 4962.83 12.780 318.510 4793.18 4856.38 677.03 N 672.83 W 6006507.92 N 583752.40 E 0.264 668.68 5058.24 12.480 317.490 4886.28 4949.48 692.54 N 686.78 W 6006523.26 N 583738.27 E 0.392 682.54 5125.75 12.360 317.360 4952.21 5015.41 703.23 N 696.61 W 6006533.84 N 583728.33 E 0.183 692.30 5248.15 12.330 314.910 5071.79 5134.99 722.09 N 714.74 W 6006552.50 N 583709.99 E 0.429 710.31 5344.56 11 .950 314.720 5166.04 5229.24 736.39 N 729.12 W 6006566.63 N 583695.44 E 0.396 724.61 . 5440.40 13.180 317.930 5259.58 5322.78 751.48 N 743.49 W 6006581.56 N 583680.90 E 1.475 738.89 5536.62 15.140 318.330 5352.88 5416.08 769.01 N 759.20 W 6006598.91 N 583665.00 E 2.040 754.49 5633.54 15.140 316.280 5446.43 5509.63 787.61 N 776.36 W 6006617.32 N 583647.63 E 0.552 771.53 5729.45 15.020 315.410 5539.04 5602.24 805.51 N 793.74 W 6006635.02 N 583630.05 E 0.267 788.81 5822.86 16.250 315.880 5628.99 5692.19 823.52 N 811.34W 6006652.82 N 583612.25 E 1.324 806.29 5920.27 19.160 314.490 5721.78 5784.98 844.51 N 832.23 W 6006673.58 N 583591.11 E 3.019 827.06 6016.68 21.290 305.080 5812.26 5875.46 865.66 N 857.85 W 6006694.44 N 583565.26 E 4.027 852.55 6112.39 21 .630 288.820 5901.42 5964.62 881.35 N 888.80 W 6006709.78 N 583534.14 E 6.207 883.40 6208.72 22.500 276.260 5990.74 6053.94 889.09 N 923.94 W 6006717.12 N 583498.90 E 4.971 918.50 6304.13 23.710 268.710 6078.52 6141.72 890.65 N 961.28 W 6006718.26 N 583461.56 E 3.352 955.82 6400.28 26.520 264.310 6165.57 6228.77 888.09 N 1001.98 W 6006715.24 N 583420.89 E 3.507 996.53 6496.70 29.170 261.340 6250.83 6314.03 882.42 N 1046.64 W 6006709.06 N 583376.30 E 3.101 1041.23 6592.78 32.710 258.430 6333.23 6396.43 873.68 N 1095.24 W 6006699.77 N 583327.80 E 3.999 1089.88 14 April, 2005 - 10:02 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPK-09 Your Ref: API 500292324700 Job No. AKZZ3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/1 DOft) 6687.69 37.720 256.380 6410.75 6473.95 861.69 N 1148.61 W 6006687.18 N 583274.56 E 5.423 1143.33 6783.17 41.510 256.000 6484.29 6547.49 847.15 N 1207.72 W 6006671.98 N 583215.62 E 3.978 1202.52 6879.71 46.640 257.220 6553.62 6616.82 831.64 N 1273.03 W 6006655.72 N 583150.49 E 5.386 1267.93 6974.35 51.810 256.180 6615.41 6678.61 815.14 N 1342.75 W 6006638.43 N 583080.97 E 5.526 1337.74 7070.02 56.890 251.680 6671 .17 6734.37 793.54 N 1417.37 W 6006615.99 N 583006.60 E 6.540 1412.49 . 7166.28 62.410 249.570 6719.79 6782.99 765.95 N 1495.68 W 6006587.52 N 582928.60 E 6.038 1490.97 7261.09 66.440 250.190 6760.71 6823.91 736.55 N 1575.97 W 6006557.21 N 582848.65 E 4.291 1571.44 7357.18 70.690 247.360 6795.83 6859.03 704.15 N 1659.30 W 6006523.87 N 582765.69 E 5.203 1654.97 7452.45 71.270 245.230 682688 6890.08 667.94 N 174176 W 6006486.73 N 582683.64 E 2.200 173765 7548.89 70.880 244.920 6858.16 6921.36 629.49 N 1824.49 W 6006447.35 N 582601.35 E 0.506 1820.61 7644.86 69.440 243.250 6890.73 6953.93 590.05 N 1905.68 W 6006406.99 N 582520.61 E 2.220 1902.04 7741.59 68.980 243.680 6925.06 6988.26 549.65 N 1986.59 W 6006365.68 N 582440.17 E 0.632 1983.20 7837.76 70.030 243.590 6958.73 7021.93 509.64 N 2067.30 W 6006324.76 N 582359.91 E 1.095 2064.15 7929.69 70.160 244.580 6990.03 7053.23 471.87 N 2145.05 W 6006286.11 N 582282.60 E 1.022 2142.12 8026.50 82.680 242.940 7012.72 7075.92 430.32 N 2229.27 W 6006243.60 N 582198.86 E 13.036 2226.60 8073.62 89.490 242.780 7015.94 7079.14 408.88 N 2271.07 W 6006221.70 N 582157.29 E 14.456 2268.53 8121.19 93.880 241.630 7014.54 7077.74 386.72 N 2313.13 W 6006199.06 N 582115.50 E 9.539 2310.72 8170.13 93.320 242.120 7011.47 7074.67 363.69 N 2356.20 W 6006175.55 N 582072.68 E 1.519 2353.94 8215.98 93.440 242.530 7008.76 7071.96 342.43 N 2396.74 W 6006153.83 N 582032.39 E 0.930 2394.60 8265.81 92.150 247.880 7006.33 7069.53 321.57 N 2441.90W 6006132.46 N 581987.47 E 11.032 2439.89 8312.02 86.950 252.750 7006.69 7069.89 306.01 N 2485.38 W 6006116.41 N 581944.16 E 15.415 2483.47 8360.99 85.730 252.700 7009.82 7073.02 291.50 N 2532.05 W 6006101.38 N 581897.67 E 2.493 2530.22 . 8406.38 86.640 249.880 7012.84 7076.04 276.98 N 2574.94 W 6006086.36 N 581854.94 E 6.515 2573.20 8453.12 86.520 249.930 7015.63 7078.83 260.95 N 2618.75 W 6006069.84 N 581811.31 E 0.278 2617.11 8501.52 89.060 251.320 7017.49 7080.69 244.90 N 2664.38 W 6006053.28 N 581765.87 E 5.981 2662.83 8550.25 88.310 252.860 7018.61 7081.81 229.92 N 2710.73 W 6006037.78 N 581719.69 E 3.514 2709.27 8596.94 88.070 254.200 7020.09 7083.29 216.69 N 2755.48 W 6006024.04 N 581675.09 E 2.914 2754.11 8645.58 89.180 255.230 7021.26 7084.46 203.87 N 2802.39 W 6006010.69 N 581628.34 E 3.113 2801.09 8693.15 86.160 254.490 7023.19 7086.39 191.46N 2848.26 W 6005997.76 N 581582.61 E 6.536 2847.04 8741.43 88.870 254.930 7025.28 7088.48 178.74 N 2894.78 W 6005984.52 N 581536.23 E 5.686 2893.64 8789.01 86.960 253.960 7027.01 7090.21 165.99 N 2940.59 W 6005971.25 N 581490.57 E 4.502 2939.52 8837.54 88.320 251.610 7029.01 7092.21 151.64 N 2986.90 W 6005956.38 N 581444.43 E 5.591 2985.92 8884.82 88.010 250.330 7030.53 7093.73 136.24 N 3031.57 W 6005940.47 N 581399.93 E 2.784 3030.68 8933.18 89.240 251.000 7031.69 7094.89 120.23 N 3077.19 W 6005923.94 N 581354.50 E 2.896 3076.40 8980.86 90.420 252.070 7031.83 7095.03 105.13 N 3122.41 W 6005908.33 N 581309.45 E 3.341 3121.71 14 April, 2005 - 10:02 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPK-09 Your Ref: API 500292324700 Job No. AKZZ3591176, Surveyed: 4 April, 2005 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8994.66 90.290 252.220 7031.74 7094.94 100.90 N 3135.55 W 6005903.95 N 581296.36 E "'" 9059.00 90.290 252.220 7031.42 7094.62 - 81.25 N 3196.81 W 6005883.61 N 581235.32 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 269.650' (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9059.00fl., The Bottom Hole Displacement is 3197.85fl., in the Direction of 271.456° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9059.00 7094.62 3196.81 W Projected Survey 81.25 N Survey tool proqram for MPK-09 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 259.00 0.00 258.99 258.99 CB-SS-GYRO 7094.62 MWD+IIFR+MS+SAG 259.00 9059.00 Dogleg Rate (0/100ft) 1.438 0.000 BPXA Vertical Section Comment 3134.87 3196.26 Projected Survey . . 14 April, 2005 - 10:02 Page 5 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPK-09 (mwd) Your Ref: API 500292324700 Job No. AKMW3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth mcl. Azim. Depth Depth Northjngs Eastings Northings Eastings Rate Section Cornment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8994.66 90.060 252.830 7031.15 7094.35 130.12 N 3148.09 W 600593303 N 581283.49 E 1.852 3147.24 9059.00 90.060 252.830 7031.08 7094.28 111.12 N 3209.56 W 6005913.34 N 581222.23 E 0.000 3208.82 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. . The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 269.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9059.00ft., The Bottom Hole Displacement is 3211.49ft., in the Direction of 271.983° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9059.00 7094.28 111.12 N 3209.56 W Projected Survey Survey tool program for MPK-09 (mwd) . From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 259.00 0.00 258.99 259.00 9059.00 258.99 CB-SS-GYRO 7094.28 MWD Magnetic 14 April, 2005 - 10:04 Page 5 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Milne Point Unit BPXA IlI/PK-09 (mwd) . Job No. AKMW3591176, Surveyed: 4 April, 2005 Survey Report 14 April, 2005 Your Ref: API 500292324700 Surface Coordinates: 6005838.54 N, 584432.85 E (70025' 33.1718" N, 149018'43.0451" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 63.20ft above Mean Sea Level SpE!ï"ï"Y-SUI! OFULL..tNG se~vlc:es A Halliburton Company Survey Ref: svy1514 Halliburton Sperry-Sun Survey Report for MPK-09 (mwd) Your Ref: API 500292324700 Job No. AKMW3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -63.20 0.00 0.00 N 0.00 E 6005838.54 N 584432.85 E 0.00 CB-SS-GYRO 168.00 0.750 75.000 104.80 168.00 0.28 N 1.06 E 6005838.84 N 584433.91 E 0.446 -1.06 259.00 0.750 43.000 195.79 258.99 0.87 N 2.04 E 6005839.44 N 584434.88 E 0.454 -2.05 MWD Magnetic 332.26 0.740 330.350 26904 332.24 1.64 N 2.14 E 6005840.20 N 584434.97 E 1.205 -2.15 378.16 1.360 304.910 314.94 378.14 2.21 N 1.54 E 6005840.76 N 584434.37 E 1.659 -1.56 . 469.17 2.900 312.800 405.88 469.08 4.39 N 1.03W 6005842.92 N 584431.77 E 1.719 1.01 561.26 5.450 303.230 497.72 560.92 8.37 N 6.40 W 6005846.83 N 584426.36 E 2.861 6.35 650.78 6.080 305.250 58679 649.99 13.43 N 13.83 W 6005851.82 N 584418.87 E 0.739 13.75 747.49 7.350 302.640 682.83 746.03 19.73 N 2322 W 6005858.00 N 584409.41 E 1.350 23.10 842.28 8.280 299.810 776.74 839.94 26.39 N 34.25 W 6005864.54 N 584398.31 E 1.061 34.09 938.44 10.570 301.770 871.60 934.80 34.48 N 47.76 W 6005872.4 7 N 584384.71 E 2.404 47.54 1032.99 12.160 305.410 964.29 1027.49 44.81 N 63.25 W 6005882.64 N 584369.10 E 1.844 62.97 1129.45 13.630 304.220 1058.31 1121.51 5709 N 80.92 W 6005894.71 N 584351.28 E 1.549 80.57 1224.96 13.620 305.790 1151.14 1214.34 70.00 N 99.35 W 6005907.41 N 584332.71 E 0.387 98.92 1321.15 12.970 306.230 1244.75 1307.95 83.00 N 117.25 W 6005920.21 N 584314.67 E 0.684 116.74 1417.06 13.120 307.220 1338.18 1401.38 95.95 N 134.60 W 6005932.96 N 584297.18 E 0.281 134.01 1512.99 12.650 306.980 1431.70 1494.90 108.85 N 151.66 W 6005945.67 N 584279.97 E 0.493 150.99 1609.52 12.310 306.920 1525.95 1 589.15 121.39 N 168.33 W 6005958.02 N 584263.16 E 0.352 167.58 1705.44 13.440 307.100 1619.45 1682.65 134.26 N 185.39 W 6005970.69 N 584245.95 E 1.179 184.57 1801.20 13.490 306.630 1712.58 1775.78 147.63 N 203.23 W 6005983.86 N 584227.96 E 0.126 202.33 1897.60 12.610 307.290 1806.49 1869.69 160.72N 220.63 W 6005996.75 N 584210.42 E 0.926 219.64 . 1993.68 12.010 309.150 1900.36 1963.56 173.38 N 236.73 W 6006009.23 N 584194.18 E 0.748 235.66 2089.74 13.100 317.170 1994.13 2057.33 187.68 N 251.88 W 6006023.36 N 584178.86 E 2.138 250.73 2185.58 13.110 317.620 2087.47 2150.67 203.67 N 266.59 W 6006039.18 N 584163.97 E 0.107 265.34 2281.58 12.900 317.480 2181.01 2244.21 219.61 N 281.17W 6006054.96 N 584149.21 E 0.221 279.82 2377.73 14.280 323.930 2274.47 2337.67 237.11 N 295.41 W 6006072.29 N 584134.78 E 2.130 293.95 2474.28 14.550 325.440 2367.98 2431.18 256.72 N 309.30 W 6006091.75 N 584120.67 E 0.479 307.72 2569.79 14.170 322.270 2460.51 2523.71 275.85 N 323.26 W 6006110.71 N 584106.49 E 0.914 321.57 2665.75 13.560 317.670 2553.68 2616.88 293.46 N 338.02 W 6006128.15 N 584091.53 E 1.312 336.22 2762.17 13.030 317.530 2647.51 2710.71 309.83 N 352.97 W 6006144.36 N 584076.40 E 0.551 351.07 2856.72 12.990 316.360 2739.64 2802.84 325.38 N 367.50 W 6006159.74 N 584061.69 E 0.282 365.51 2952.65 12.740 316.930 2833.16 2896.36 340.91 N 382.17 W 6006175.11 N 584046.85 E 0.292 380.08 3049.42 12.830 317.420 2927.53 2990.73 356.62 N 396.72 W 6006190.65 N 584032.12 E 0.146 394.54 3145.74 13.640 320.920 3021.29 3084.49 373.31 N 411.12 W 6006207.17 N 584017.53 E 1.183 408.83 3242.64 13.820 322.470 3115.42 3178.62 391.36 N 425.37 W 6006225.06 N 584003.08 E 0.423 422.97 14 April, 2005 - 10:04 Page 2 of5 DrillQuest 3.03.06.008 Halliburlon Sperry-Sun Survey Report for MPK-09 (mwd) Your Ref: API 500292324700 Job No. AKMW3S91176, Surveyed: 4 April, 200S BPXA Milne Point Unit Measured True Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Inet. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3338.34 14.030 324.320 3208.31 3271.51 409.85 N 439.10 W 6006243.39 N 583989.14 E 0.514 436.59 3435.18 13.250 318.900 3302.42 3365.62 427.74 N 453.24 W 6006261.13 N 583974.80 E 1.545 450.62 3530.21 13.090 317.610 3394.95 3458.15 443.90 N 467.66 W 6006277.12 N 583960.20 E 0.352 464.94 3625.44 12.710 317.480 348778 3550.98 459.58 N 482.01 W 6006292.64 N 583945.67 E 0.400 479.19 . 3720.17 13.950 317.940 3579.96 3643.16 475.74 N 496.70 W 6006308.63 N 583930.80 E 1.314 493.79 3816.65 13.940 318.230 3673.59 3736.79 49305 N 512.23 W 6006325.76 N 583915.07 E 0.073 509.21 3912.61 13.750 318.140 3766.76 3829.96 510.16 N 527.54 W 6006342.70 N 583899.57 E 0.199 524.42 4008.84 13.430 319.100 3860.30 3923.50 527.12 N 542.49 W 6006359.49 N 583884.43 E 0.407 539.26 410531 12.910 318.580 395423 4017.43 543.67 N 556.96 W 6006375.88 N 583869.78 E 0.553 553.62 4200.97 13.130 320090 4047.43 4110.63 560.02 N 571.00 W 600639206 N 583855.55 E 0.423 567.56 4297.36 12.690 321.120 4141.39 4204.59 576.66 N 584.67 W 6006408.55 N 58384170 E 0.515 581.13 4392.77 12.440 322.000 4234.51 4297.71 592.92 N 597.57 W 6006424.66 N 583828.61 E 0.330 593.94 4489.07 13860 321.060 4328.28 4391.48 610.06N 611.21 W 6006441 .65 N 583814.78 E 1 .491 607.47 4586.01 13.880 321.880 4422.40 4485.60 628.24 N 625.68 W 6006459.66 N 583800.10 E 0.204 621.83 4680.58 13.280 319850 4514.32 4577.52 645.47 N 639.69 W 6006476.73 N 583785.90 E 0.810 635.73 4773.28 13.480 319.690 4604.51 4667.71 661.84 N 653.54 W 6006492.95 N 583771.86 E 0.219 649.49 4868.13 13.290 318.700 4696.78 4759.98 678.46 N 667.89 W 6006509.40 N 583757.33 E 0.314 663.73 4962.83 13.040 318.720 4788.99 4852.19 694.67 N 682.12 W 6006525.45 N 583742.91 E 0.264 677.87 5058.24 12740 316.920 4882.00 4945.20 710.44N 696.41 W 6006541.06 N 583728.45 E 0.525 692.06 5125.75 12.620 317.580 4947.86 5011.06 721.33 N 706.47 W 6006551.83 N 583718.27 E 0.279 702.05 5248.15 12.330 315.420 5067.37 5130.57 740.50 N 724.66 W 6006570.80 N 583699.86 E 0.449 720.12 . 5344.56 12.010 315.110 5161.62 5224.82 754.94 N 738.97 W 6006585.07 N 583685.39 E 0.339 734.34 5440.40 13.210 318.920 5255.14 5318.34 770.26 N 753.20 W 6006600.23 N 583670.98 E 1.523 748.48 5536.62 15.200 319.280 5348.42 5411.62 788.11 N 768.65 W 6006617.90 N 583655.33 E 2.070 763.83 5633.54 15.190 317.160 5441.95 5505.15 807.05 N 785.58 W 6006636.65 N 583638.19 E 0.573 780.63 5729.45 15.050 315.530 5534.54 5597.74 825.15 N 802.84 W 6006654.56 N 583620.72 E 0.467 797.79 5822.86 16.330 316.030 5624.47 5687.67 843.26 N 820.46 W 6006672.46 N 583602.90 E 1.378 815.29 5920.27 19.210 314.690 5717.22 5780.42 864.39 N 841.36 W 6006693.35 N 583581.76 E 2.986 836.07 6016.68 21.340 304.840 5807.68 5870.88 885.57 N 867.05 W 6006714.25 N 583555.84 E 4.166 861.62 6112.39 21.650 289.280 5896.80 5960.00 901.37 N 898.03 W 6006729.69 N 583524.68 E 5.950 892.51 6208.72 22.530 276.660 5986.11 6049.31 909.38 N 933.16 W 6006737.30 N 583489.47 E 5.001 927.58 6304.13 23.770 269.050 6073.86 6137.06 911.18 N 970.55 W 6006738.68 N 583452.06 E 3.392 964.96 6400.28 26.580 264.840 6160.87 6224.07 908.92 N 1011.36 W 6006735.96 N 583411.27 E 3.464 1005.79 6496.70 29.220 261.930 6246.08 6309.28 903.68 N 1056.15 W 6006730.21 N 583366.54 E 3.080 1050.61 6592.78 32.710 258.810 6328.46 6391.66 895.34 N 1104.86 W 6006721.33 N 583317.93 E 3.997 1099.37 14 April, 200S - 10:04 Page 3 ofS DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPK-09 (mwd) .. Your Ref: API 500292324700 Job No. AKMW3591176, Surveyed: 4 April, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Ir:c!. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 6687.69 37.730 255.660 6405.98 6469.18 883.17 N 1158.19 W 6006708.55 N 583264.75 E 5.623 1152.77 6783.17 41.530 255.000 6479.50 6542.70 867.73 N 1217.09 W 6006692.45 N 583206.02 E 4.004 1211.76 6879.71 46.650 256.540 6548.82 6612.02 851.27 N 1282.18 W 6006675.25 N 583141 .12 E 5.418 1276.96 6974.35 51.820 256.930 6610.60 6673.80 834.84 N 1351.93W 6006658.03 N 583071.56 E 5.472 1346.80 7070.02 56.920 252.370 6666.33 6729.53 814.17 N 1426.83 W 6006636.52 N 582996.90 E 6.588 1421.83 . 7166.28 62.420 249.960 6714.93 6778.13 787.32 N 1505.41 W 6006608.77 N 582918.63 E 6.108 1500.57 7261.09 66.460 250.390 6755.83 6819.03 758.32 N 1585.86 W 6006578.87 N 582838.52 E 4.281 1581.19 7357.18 70.700 247.830 6790.92 6854.12 726.41 N 1669.39 W 6006546.01 N 582755.35 E 5.061 1664.92 7 L¡..52.45 7Î.290 245.390 6821.94 6885.14 690.65 N 1752.06 W 6006509.32 N 582673.09 E 2.499 1747.80 7548.89 70.890 244.690 6853.20 6916.40 652.15 N 183477 W 6006469.89 N 582590.82 E 0.802 1830.75 7644.86 69.450 243.190 6885.76 6948.96 612.49 N 1915.87 W 6006429.32 N 582510.17 E 2.101 1912.09 ï741.59 69.000 244.240 6920.07 6983.27 572.44 N 1996.96 W 6006388.35 N 582429.55 E 1.116 1993.42 7837.76 70.040 243.930 6953.71 7016.91 533.07 N 2077.99 W 6006348.06 N 582348.97 E 1.123 2074.69 792969 69.930 245.050 6985.18 7048.38 495.87 N 2155.94 W 6006309.99 N 582271.44 E 1.151 2152.87 8026.50 82.450 242.470 7008.25 7071.45 454.34 N 2240.06 W 6006267.51 N 582187.79 E 13.188 2237.25 8073.62 89.260 242.400 7011.65 7074.85 432.61 N 2281.70 W 6006245.30 N 582146.40 E 14.453 2279.02 8121.19 93.640 242.100 7010.45 7073.65 410.47 N 2323.78 W 6006222.69 N 582104.58 E 9.229 2321.23 8170.13 93.090 242.850 7007.57 7070.77 387.89 N 2367.10 W 6006199.62 N 582061.51 E 1.898 2364.69 8215.98 93.210 242.530 7005.05 7068.25 366.89 N 2407.78 W 6006178.16 N 582021.07 E 0744 2405.49 826581 91.910 248.440 7002.83 7066.03 346.24 N 2453.05 W 6006157.00 N 58197604 E 12.132 2450.89 8312.02 86.730 253.400 7003.38 7066.58 331.15 N 2496.69 W 6006141.42 N 581932.57 E 15.517 2494.62 . 8360.99 85.490 253.600 7006.70 7069.90 317.27 N 2543.54 W 6006127.01 N 581885.89 E 2.565 2541.55 8406.38 86.420 251.440 7009.90 7073.10 303.67 N 2586.72 W 6006112.92 N 581842.86 E 5.170 2584.81 8453.12 86.290 250.480 7012.87 7076.07 288.45 N 2630.81 W 6006097.21 N 581798.94 E 2.069 2629.00 8501.52 88.830 251.750 7014.93 7078.13 272.80 N 2676.56 W 6006081.04 N 581753.38 E 5.866 2674.84 8550.25 88.090 253.100 7016.24 7079.44 258.10 N 2723.00 W 6006065.81 N 581707.11 E 3.158 2721.37 8596.94 87.840 254.170 7017.90 7081.10 244.95 N 2767.77 W 6006052.16 N 581662.49 E 2.352 2766.22 8645.58 88.950 255.370 7019.26 7082.46 232.18 N 2814.68 W 6006038.86 N 581615.73 E 3.360 2813.21 8693.15 85.930 254.600 7021.39 7084.59 219.87 N 2860.57 W 6006026.03 N 581569.97 E 6.551 2859.18 8741.43 88.640 254.930 7023.67 7086.87 207.20 N 2907.10 W 6006012.83 N 581523.59 E 5.654 2905.78 8789.01 86.730 253.920 7025.59 7088.79 194.43 N 2952.89 W 6005999.55 N 581477.95 E 4.540 2951.65 8837.54 88.090 251.660 7027.79 7090.99 180.09 N 2999.20 W 6005984.68 N 581431.81 E 5.431 2998.04 8884.82 87.780 250.440 7029.49 7092.69 164.75 N 3043.89 W 6005968.84 N 581387.30 E 2.661 3042.82 8933.18 89.010 251.400 7030.85 7094.05 148.94 N 3089.57 W 6005952.52 N 581341.79 E 3.226 3088.60 8980.86 90.190 252.610 7031.18 7094.38 134.22 N 3134.91 W 6005937.28 N 581296.62 E 3.545 3134.04 14 April, 2005 - 10:04 Page 4 of 5 DrillQuest 3.03.06.008 . . I AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPk-09 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,059.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed :1L-.J ð;!¿. 1 Date ~? (1f~ S- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment{s) 25-Apr-05 Åð)--~)~I . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPk-09 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD 9,059.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1 / ~ / J I Date !).. ? flp ÅM )- Signed ~ ~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 25-Apr-05 ~~ S----C) ¡ ~ . r . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg~? P. I. Supervisor I i14/11c5 DATE: March 26, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Well Inspection MPU K-09 BPX PTD 205-014 March 26. 2005: I traveled to BP's MPU K-09 to inspect the wellhead, surface casing & conductor for hydrate gas release to atmosphere. I arrived on Location & Little Red Hot Oil Services was circulating 150 degree H20 down Kill String & out Surface casing annulus valve @ 2.1 BPM. Hot Oil had been circulating approximately 22 hours before my arrival. No gas was detected between surface casing & conductor casing. I inspected cement between conductor & surface casing & cement seemed solid to surface. The attempt to warm up permafrost to produce hydrate gas outside surface casing with hot water failed to produce gas to surface. With the approval of the Commission I saw no reasons Drilling Operations should not continue on MPU K.. 09. Summary: I inspected well MPU K-09 for gas release on & around wellhead & cellar area. No problems witnessed. Attachments: DSC 00059.JPG & DSC 000060.JPG Non-Confidential MPU K-09 Well Inspection 03-26-05 jc.doc 4' Milne Point Unit K-09 Photos by AOGCC Inspector John Crisp March 28, 2005 MP K-Pad Drilling Update - e The proposed MPK-09 well integrity test has been started to determine if gas hydrates are still a problem on the MPK-09 well. Tubing was installed in the well to a depth of 3500'. The well is presently being circulated with 150 degree hot water to determine if hydrate gas is still a problem on this well. Circulation began at 2200 hrs on March 23 and is planned to continue for a 48 hour total time period. If no significant gas hydrate breakout is observed at surface BP would consider the well to have the required integrity to continue the approved drilling program. In the event that we are not able to resume drilling operations on the MPK-09 well, a replacement well (MPK-14) has been planned and a 401 Permit application has been submitted to AOGCC requesting expedited review. The rig is presently replacing the ESP pump in MPK-06 and is expected to finish this work over the upcoming weekend. We would then be prepared to move the rig onto the MPK-14 well to start drilling operations if we had the required Permit to Drill. To minimize potential rig standby time BP like to have the 401 Permit Application reviewed and approved this week if possible. Your attention to this matter is greatly appreciated. 1 of 1 )..~ \..ð\ ~ st\~ ~C.P\J 3/7/2006 10:06 AM rmf &u rñJ \\. ru·ì.ì ~ . cilÞ- od- I I FRANK H. MURKOWSKI, GOVERNOR i I l ! I 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 A ",ASIiA. OIL AND GAS CONSERVATION COMMISSION ¡ j J Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPK-09 Sundry Number: 305-073 Dear Mr. Johnson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior unless rehearing has been requested. DATED trusz-td11Y of March, 2005 Enc!. \,¡Jl:¡ A .~ Il -s I z..." 0 5 . STATE OF ALASKA .. Ji..0 :;/z.4-!-<s ALASKA OIL AND GAS CONSERVATION COM~SION RE;C~'>~IVI!!D APPLICATION FOR SUNDRY APPROVAL t: . r:: . 20 MC 25.280 MAR 2 2 lOds 1. Type of Request: Alaska OiL&ñs Cons. Commís . o Abandon o Repair Well o Plug Perforations o Stimulate o Other Anchorage o Alter Casing / o Pull Tubing o Perforate New Pool o Waiver o Time Extension a Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. a Development o Exploratory /205-014..00- IIJ c.1\- . 3. Address: o Stratigraphic o Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23247-00-00 7. KB Elevation (ft): 63.5' 9. Well Name and Number: MPK-09 / 8. Property Designation: 10. Field / Pool(s): ADL 375133 Milne Point Unit / Kuparuk River Sands 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5183 5071 5183 5071 N/A N/A .> LêÎ"ldti'l> .> BiZê .>·.:\'v1E ....;. ./ /TVD; i·/ .Bur$t / ..>/;> Structural r.nnrllll~tnr 79' 20" 114' 114' 1530 520 Surface 5138' 9-5/8" 5173' 5071' 5750 3090 Intermediate Pr' f Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal o BOP Sketch o Exploratory a Development o Service a Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 22,2005 a Oil '0 Gas o Plugged o Abandoned 16. Verbal Approval: Date: 3/21f2005 o WAG / 0 GINJ OWINJ o WDSPL Commission Representative: Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Na¡ Fred Johnson Title Senior Drilling Engineer Siqnature- d Æ.fl Date3h ¿/O,\ Prepared By Name/Number: Phone 564-5427 Sondra 564-4750 Xl . II...... A.....;. ......... '. I Sundry Number: .:;-c,:J ,-C' 7=5 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Cleara~{)MS 8Ft. 2 9 2005 Other: S"b,eq"ec:n;tí: 4°'1 t\.ç.t~Þ"" u-U'tl ~ pie t;(tÿ>- Or su)p~çtO~. t\L /' Approved B}t: J '/ v -~ ~ APPROVED BY Dateß/t tfj 05 COMMISSIONER THE COMMISSION Form 1 0-403 ~ ~d 0~4 ßubmit (n Duplicate lOR . . Application for Sundry Approval Change Approved Program MPK-09 BP requests Sundry approval for changes to the approved MPK-09 well program. History and Present Status MPK-09 was spudded on March 13. Gas hydrates were encountered while drilling from 2000'md to 3000'md in the 12-1/4" surface hole. The surface hole interval below the / hydrate was drilled to 5183' without significant gas hydrate being observed. The 9-5/8" surface casing was run to TD and cemented to surface with 200 barrels of lead cement *" returns to surface. The casing was tested to 1000 psi for 30 minutes after bumping the cement plug. Later, while installing the BOP's, hydrate gas bubbling was observed in and around the conductor and cellar of the well. Operations were suspended and the rig / was moved off the well. Verbal approval for suspending the well was obtained from Tom Maunder with AOGCC on March 19,2005. The gas bubbling gradually subsided and stopped approximately 36 hours after it had been reported. Proposed Change BP proposes to further evaluate the integrity of the MPK09 well and determine if it is possible to continue safe drilling operations on the well. This evaluation will be done by / heating the well back up and observing the well for gas hydrate bubbling. A tubing string will be run in the well to 3500' with the drilling rig. The rig will then be moved off, and the well will be heated back up by circulating hot water using a hot oil unit and temporary pumping equipment. If no significant gas hydrate bubbling is observed during this test, the well will be considered to have adequate integrity to continue with the / approved drilling program. The drilling rig would then be moved back onto the well to finish the well construction. Conversely, if significant gas hydrate bubbling is observed, the well would not be / considered to have adequate integrity to continue the well program at this time. In this case the well would be freeze protected and suspended. This is a change to the approved well program and is in response to gas hydrate issues encountered while drilling the well. Verbal approval for this change was obtained from Winton Aubert on March 21,2005. Iœ.e.;, 4-1/8"5KDryHoleTr~ MPK-09 Present -.us DFelev.= 53.5f! Wellhead: FMC Gen 5 Syst~".5M S1Irt Tubirtg Head: FMC 11"x4-1/2" Tubing Hanger BPV March 21. 2005 Lead Cement To Surface 20" 91.1-lb/ft H-40 Tail Cement Top 500' above shoe 9.625-in 4O-lbfft L-BO BTC casing DATE REV. BY COMMENTS 19 Mar-05 WDQ Proposed Suspension / Diesel Freeze Protect to 2400' Float Collar at 5086'md Float Shoe at 5173' md 12-1/4" hole TD at 5183' md MILNE POINT UNIT WELL MPK~ API NO: 50-0 BP EXPLORATION (AKl ~ 4-1/8" 5K Dry Hole Tr!þ Wellhead: FMC Gen 5 Syste ",5M Tubin.g Head: FMC 11" x 4-1/ , Tubing Hanger BPV MPK-09 Proposecehang;v.= 63.5f! Lead Cement To Surface 20" 91 .1-lb/ft H-40 OÐ 10.5 Ib/gal Spud Mud 3-1/2" 9.3 Ib/ft L80 Tubing Tail Cement Top 500' above shoe 9.625-in 4O-lb/ft L-BO BTC casing DATE REV. BY COMMENTS 19 Mar-05 WOO Proposed Suspension March 21, 2005 Diesel Freeze Protect to 2400' Float Collar at 5086'md Float Shoe at 5173' md 12-1/4" hole TD at 5183' md MILNE POINT UNIT WELL MPK-O.i.. API NO: 50-0 BP EXPLORATION (AKl. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: Rig Number: Spud Date: 3/13/2005 End: 3/12/2005 03:00 - 04:00 1.00 MOB P PRE Skid rig floor 04:00 - 06:00 2.00 MOB P PRE Move rig off well 06:00 - 08:00 2.00 MOB P PRE Moving rig to MPK pad, encountered flat tire, on K pad road 08:00 - 21 :30 13.50 MOB P PRE Repair tire on rig, had to take BOP stack out of cellar, remove spreader beam to repair tire, reinstall stack and beam after repair was done 21 :30 - 00:00 2.50 MOB P PRE Finish move to K pad, on pad ready to spot over well 3/13/2005 00:00 - 02:00 2.00 MOB P PRE Spot rig over well MPK-09 02:00 - 03:00 1.00 RIGU P PRE Skid rig floor, spot rock washer, rigging up, Rig accept @ 03:00 3/13/2005 03:00 - 07:30 4.50 RIGU P PRE Nipple up diverter and diverter lines 07:30 - 09:00 1.50 DRILL P SURF Pre spud Derrick inspection, clear rig floor, police housekeeping thru-out rig 09:00 - 14:30 5.50 DRILL P SURF Picking up 4" pipe out of pipe shed standing in derrick, 52 stands total 14:30 - 17:00 2.50 DRILL P SURF Picking up BHA, Rig up Gyro/wire line unit 17:00 - 18:00 1.00 DRILL P SURF Make up bit and motor, Stab,one stand of HW drill pipe 18:00 - 19:00 1.00 DRILL P SURF Pre spud meeting, diverter test, the right to witness test was wavier by Jeff Jones, witness by WSL 19:00 - 21 :00 2.00 DRILL P SURF Fill stack, check for leaks, drill ice and wood and trash out of conductor to 110ft, Drill to 221' 21 :00 - 23:30 2.50 DRILL P SURF POH and pick up MWD tool, orient and surface test, Rih 23:30 - 00:00 0.50 DRILL P SURF Drill 221 to 256, with 60 rpms, 900 psi 400 gals per min., Running Gyro ever 100 ft. 3/14/2005 00:00 - 09:00 9.00 DRILL P SURF Drill 256 to 1187, with 80 rpms, 2000 psi 550 gals per min., Running Gyro ever 100ft. to 352' 09:00 - 10:00 1.00 DRILL P SURF Run New Tech. Gyro 10:00 - 17:00 7.00 DRILL P SURF Drill 1187' to 2311, with 80 rpms, 2400 psi 550 gals per min, TVD 2769 17:00 - 18:00 1.00 DRILL P SURF Circ out Hydrates, raise mud from 9.6 ppg to 10.0 ppg, 6-8 bbls mud over drill nipple into drip pan that drains in to rockwasher - See Remarks Section Of DIMS Report: 18:00 - 22:00 4.00 DRILL P SURF Drill 2311' to 2819, with 80 rpms, 2700 psi 550 gals per min 22:00 - 22:30 0.50 DRILL P SURF Circ out Hydrates, raise mud from 10.0 ppg to 10.3 ppg, 1-2 bbls mud over drill nipple into drip pan that drains in to rockwasher. - See Remarks Section Of DIMS Report: 22:30 - 00:00 1.50 DRILL P SURF Drill 2819' to 3010, with 80 rpms, 2800 psi 550 gals per min 3/15/2005 00:00 - 01 :00 1.00 DRILL P SURF Circ out Hydrates, mud 10.3 ppg, 1/2 bbl mud over drill nipple into drip pan that drains in to rockwasher - See Remarks Section Of DIMS Report: 01 :00 . 03:00 2.00 DRILL P SURF Drill 3010' to 3299' ,with 80 rpms, 3000 psi 550 gals per min, tvd 3236 03:00 - 04:30 1.50 DRILL P SURF Circulate condition mud for short trip - CBU 2 X - 550 gpm - PP 2840 - RPM 70 TO 5 - 04:30 - 09:00 4.50 DRILL P SURF Con't Condition mud due to Hydrates 09:00 - 10:30 1.50 DRILL P SURF Pump out from 3299' to 1793' - Hydrates increased - Hole not taking correct fill - RIH from 1793' to 3299' 10:30 - 11:30 1.00 DRILL P SURF CBU 1 X - 450 gpm - PP 2000 - RPM 70 - Observed gas cut mud 11 :30 - 12:00 0.50 DRILL P SURF Circulate - Condition mud - 500 gpm - PP 2500 - RPM 70 - TO 5 - PU 122 - SO 108 - ROT 112- 12:00 - 15:30 3.50 DRILL P SURF Directional Drill from 3299' to 3640' - WOB 35 - RPM 70 - TO on 5 - off 3· GPM 530 - PP on 2920 - off 2630 - PU 132 - SO Printed: 312212005 2:32:26 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: Rig Number: Spud Date: 3/13/2005 End: 3/1512005 12:00 - 15:30 3.50 DRILL P SURF 115 - ROT 125 15:30 - 16:30 1.00 DRILL P SURF CBU 1 X - GPM 530 - PP 2810 - RPM 90 - TO 5 16:30 - 19:00 2.50 DRILL P SURF Pump out from 3640' to 710' - Pump at drlg rate - No problems 19:00 - 19:30 0.50 DRILL P SURF CBU 1 X - 425 gpm 1300 psi - Lots of cuttings, sand, and large pieces of gravel back on bottoms up - Flow check well - Well static - No Gas cut mud - 10.7 ppg - (in and out) 19:30 - 21:00 1.50 DRILL P SURF RIH from 710' to 2230' - Fill pipe - Con't RIH from 2230 to 3595' - Break Circulation - Wash from 3595' to 3640' 21:00 - 22:00 1.00 DRILL P SURF CBU 1.5 X - GPM 500 - PP 2580 - RPM 80 - TO 5 - Gas breaking out at drlg nipple while CBU from 950 strokes to 4900 strokes - Mud weight in 10.7 out 10.4 22:00 - 00:00 2.00 DRILL P SURF Directional Drill from 3640' to 3850' - woe 25 to 35 - RPM 70 to 80 - TO on 5 - off 3 - GPM 530 - PP on 3040 - off 2890 - PU 133 - SO 115 - ROT 125 - MUD weight in 10.7 - out 10.4 3/16/2005 00:00 - 17:00 17.00 DRILL P SURF Directional Drill from 3850' to 4756' - WOB 25 to 30 - RPM 90- TO on 5 - off 4 - GPM 550 - PP on 3400 - off 3200 - PU 150- SO 125 - ROT 135 17:00 - 21 :30 4.50 DRILL P SURF Pump out from 4756' to 710' - Pump at drlg rate - No problems - Hole in good shape - Flow check well - Well static 21 :30 - 23:00 1.50 DRILL P SURF Con't pull out hole with BHA - Break bit - Check motor - Clean floor 23:00 - 00:00 1.00 DRILL P SURF Make up bit - MWD - Orient - Con't RIH with BHA - Surface test MWD 3/17/2005 00:00 - 02:00 2.00 DRILL P SURF Con't RIH from 706' to 4350' - Tight @ 2350' to 2430' - Con't RIH at reduced running speed for surge control 02:00 - 02:30 0.50 DRILL P SURF Ream from 4350' to 4756' - (out gauge hole) - GPM 460 - PP 2600 - RPM 60 - TO 4.5 - (Mud weight cut from 10.8 to 9.6 on btms up) 02:30 - 09:00 6.50 DRILL P SURF' Directional Drill from 4756' to 5183' - TD 12 1/4· hole - WOB 20 to 30 - RPM 80 - TO on 5.5 - off 4.5 - GPM 550 - PP 3520 on - off 3460 - PU 152 - SO 127 - ROT 140 09:00 - 10:00 1.00 CASE P SURF CBU 1 X - GPM 550 - PP 3460 - RPM 80 - TO 5 10:00 - 11 :30 1.50 CASE P SURF Pump out from 5183' to 4050' - Tight @ 4850' - Back ream from 4824' to 4450' - Pump out from 4450' to 4050' 11 :30 - 12:00 0.50 CASE P SURF RIH from 4050' to 5183' - Hole in good shape 12:00 - 15:00 3.00 CASE P SURF CBU 3 X - GPM 530 - PP 3210 - Flow check - Well static 15:00 -19:00 4.00 CASE P SURF Pump out from 5183' to 706' - Pump at drlg rate - Hole in good shape - Row check well - Well static 19:00 - 21:00 2.00 CASE P SURF Handle BHA - Stand back 5· HWT - Jars - LD Flex Dc's - MWD - Break bit - Flush motor - LD same 21:00 - 21 :30 0.50 CASE P SURF Clear / Clean rig floor of BHA tools - 21:30 - 23:00 1.50 CASE P SURF Rig up 9 5/8· casg tools 23:00 - 00:00 1.00 CASE P SURF PJSM ( running casg) - Pick up float equiupment - Check floats - Pick up and run 95/8· 47# L-80 - BTC-M casg to 750' 3/18/2005 00:00 - 04:00 4.00 CASE P SURF Run 9 5/8· casg from 750' to 5173' - Tight spots 800', 835', 896',922', 1057' work through without pumping - Break circulation @ 3034',4100' - No retums @ 4571' Run to 4612'- Break circulation @ 4612' wash to 4674' - 4 bpm @ 460 psi- Con't RIH to 5090' Break circulation - wash from 5090' to 5131' - Make up landing joint I hanger - RIH land casg @ 5173' 04:00 - 04:30 0.50 CASE P SURF Break and lay down Franks fill up tool - Blow down Top Drive- Make up Schlumberger Dowell cementing head - Cementing lines Printed: 3/22/2005 2:32:26 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: Rig Number: Spud Date: 3/13/2005 End: 3/1812005 04:30 - 08:00 3.50 CASE P SURF Stage up pump fom 4 BPM @ 460 psi to 8.5 BPM @ - Circulate I Condition mud for cementing of 9 5/8" surface casg 08:00 - 10:00 2.00 CEMT P SURF Give to Dowell Pump 5 bbls water - 2 bpm @ 100 psi Test lines to 3000 psi Pump 20 bbls CW 100 (one gallon dye in first 5 bbls slurry pumped) - 6 bpm @ 150 psi Pump 50 bbls 10.7 ppg Mud Push - 5 bpm @ 340 psi Drop bottom plug Mix and pump 694 sxs - 550 bbls Type "ASL" Yield 4.45 cflsx Mixed @ 10.7 ppg - 6.5 bpm @ 370 psi Mix and pump 221 sxs - 45.5 bbIs Class "G" Yield 1.16 cflsx Mixed @ 15.8 ppg - 6 bpm @ 400 psi Kick out Top plug with 30 bbls water thru tub Give to rig 10:00 -11:00 1.00 CEMT P SURF Displaced with 357.5 bbls of spud mud - 6.5 bpm @ 700 psi- Lost partical returns when Tail cement tumed comer - Lost complete returns just before bumping plug - Bumped plug with 1700 psi 1000 psi over circulating pressure -210 bbls lead cement baCk to surface 11:00 -11:30 0.50 CASE P SURF Test casg to 1000 psi for 30 mins - Record on chart 11 :30 - 13:00 1.50 CASE P SURF Rig down cement head - Wash out bag - Riser - Flow line - Lay down landing joint 13:00 - 14:00 1.00 CASE P SURF Clear I Clean rig floor - Lay down casg tools 14:00 - 15:30 1.50 CASE P SURF PJSM - Nipple down divertor system 15:30 - 18:00 2.50 CASE P SURF Nipple up Casg head - Tubing spool- Test metal to metal seal to 1000 psi for 10 mins 18:00 - 20:00 2.00 CASE P SURF Nippling up BOP's - Driller notified Well Site Leader that cement belching out of the fluted 9 5/8" casing hanger - In K addition fluid bubbling on exterior of cellar box . Stopped nipple up operation 20:00 - 00:00 4.00 CASE P SURF Monitor And Secure Cellar Area - Make Notifications To *" Supervisors And Agencies See Remarks Section Of DIMS Report. 3/19/2005 00:00 - 03:00 3.00 CASE P SURF Monitor Well - Perform A Job Hazard Analysis With HSE Drilling Advisor Herb Williams And All Personal For All Tasks To Be Preformed. 03:00 - 04:30 1.50 CASE P SURF Monitor Well - Lay Down 5" HWDP And 4" Drill Pipe Out Of Mast In Preparation For Rig Move - Remove Fluids Out Of Mud Pits And Rock Washer - Remove Drill Pipe Out Of Pipe Shed 04:30 - 07:00 2.50 CASE P SURF Monitor Well - Nipple Down BOP And Related Equipment 07:00 - 16:30 9.50 CASE P SURF Monitor Well - Wait on orders 16:30 - 19:00 2.50 CASE P SURF Monitor Well- Nipple up BOP's 19:00 - 21:00 2.00 CASE P SURF Monitor Well - Rig up testing equipment - Install test plug - open lower annulus valve 21:00 - 00:00 3.00 CASE P SURF Monitor Well - Test BOPs - Annular 250 low 2500 high 5 mins each test - Top rams - Floor safety valve - HCR Choke I Kill valves - Dart valve (failed) Manual Choke I Kill valves - 250 low 3500 high 5 mins each test 3/20/2005 00:00 - 03:00 3.00 CASE P SURF Montior Well - Con't Testing BOPS - Choke manifold - Bottom rams - Blind rams - Upper I lower IBOP valves - 250 low 3500 high 5 mins each test - Dart valve failed test send in for repair - All other associated equipment successfully tested - John Printed: 3I22!2oo5 2:32:26 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: Rig Number: Spud Date: 3/13/2005 End: 3/20/2005 00:00 - 03:00 3.00 CASE P SURF Spaulding with AOGCC waived witness of BOP test - WSL witnessed all BOP testing 03:00 - 04:00 1.00 CASE P SURF Monitor Well - Rig down testing equipment - Shut annulus valve - Pull test plug - Install wear ring - Blow down choke 04:00 - 05:00 1.00 CASE P SURF Monitor Well - Make up mule shoe - RIH with 4· Drill pipe to 2400' 05:00 - 06:00 1.00 CASE P SURF Monitor Well - Pump Hi-vis spacer - Displace mud with water- GPM 272 - PP 650 - RPM 75 - Reciprocate string 06:00 - 08:00 2.00 CASE P SURF Monitor Well - Rig up Little Red Services on pump in sub - Test lines to 2000 psi - Displace water with diesel to freeze protect suspended well- 5 bpm @ 400 psi - (181 bbls) 08:00 - 09:00 1.00 CASE P SURF Monitor Well - POOH 09:00 - 10:30 1.50 CASE P SURF Monitor Well - Pick up tubing hanger with TWC installed - RIH Land - RILD 10:30 - 11 :30 1.00 CASE P SURF Monitor Well - Nipple down BOP's 11 :30 - 13:00 1.50 CASE P SURF Monitor Well - Nipple up Adapter flange / Tubing spool - Otis quick connect - 41/16· dry hole valve 13:00 - 13:30 0.50 CASE P SURF Monitor Well - Rig up Hot oil truck - Test adapter and tree to 5000 psi 10 mins - Rig down hot oil truck 13:30 - 15:30 2.00 CASE P SURF Monitor Well - Pull TWC - Install BPV - Secure well - Suck out cellar - Release rig 15:30 - 22:00 6.50 T A P ABAN PJSM - Prepare to move rig off K-09 - Skid rig floor from drlg position to move position - lay mats - Move rig from K-09 to Stand-by area 22:00 - 00:00 2.00 TA P ABAN Stand-by - Waiting on trucks to move camp to move rig on K-06 3/21/2005 00:00 - 14:30 14.50 TA P ABAN Rig on Stand-by - Wait on trucks to move camp - Grind burs off hammer unions - Inspect drive chains on drawworks - Mud pumps - Spread herculite for camp -Inspect Top drive- Change gear oil - Pull top ODS roller assembly - Inspect grease reinstall - Fill top drive gear end - Split Hydril knife valve - Prep location for move - Lay herculite mats around well K-09 14:30 - 17:00 2.50 MOB P PRE PJSM - Skid rig floor - Move rig off Stand-by mats - Move mats to MPK-09 - Set mats for rig move 17:00 - 20:30 3.50 MOB P PRE Move rig from Stand-by area to well MPK-09 - Spot rig over well - Skid rig floor from move position to drlg position - Set herculite and mats for rock washer 20:30 - 22:00 1.50 MOB P PRE Rig up floor - Prepare to take on water - Spot rock washer 22:00 - 23:00 1.00 CASE P SURF (Resume operations on K-09) - Pull BPV -Install TWC - ND Tubing adapter 41/16· dry hole valve 23:00 - 00:00 1.00 CASE P SURF NU BOP's 3/22/2005 00:00 - 03:30 3.50 CASE P SURF NU BOP's - Rig up test equip 03:30 - 04:30 1.00 CASE P SURF Pull Hanger - Install Test plug 04:30 - 05:30 1.00 CASE P SURF Rig up to test BOP's 05:30 - 11 :30 6.00 CASE P SURF Testing BOP's - Annular 250 low - 2500 high 5min each test- Top pipe rams - Choke Manifold - HCR Choke / Kill - Manual Choke / Kill - Upper I Lower IBOP - Bottom rams - Blind rams - Floor safety valve and Dart valve (failed) - 250 low 3500 high 5 mins each test - All test were witnessed by WSL - Chuck Sheave with AOGCC waived witness of BOP test - Rig down testing equip - Shut annulus valves - Pull testy plug - Install wear ring 11:30 - 0.00 CASE P SURF Make up mule shoe - RIH with 4· DP to 2375' Printed: 3122/2005 2:32:26 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operation~ Sum MPK-09 MPK-09 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/12/2005 Rig Release: Rig Number: Spud Date: 3/13/2005 End: 3/22/2005 0.00 CASE P SURF Displace freeze protection (diesel> from 2375' with water 0.00 CASE P SURF RIH from 2375' to 3540' 0.00 CASE P SURF Displace 10.7 spud mud from well with water - POH from 3540' to 2400' 0.00 CASE P SURF Displace water with freeze protection (Diesel) 0.00 CASE P SURF POH Printed: 3/2212005 2:32:26 PM STATE OF ALASKA 1 128/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ¡¡m reQQ@admín.state.ak.us aOQcc prudhoe bav@adm;f1.state.ak.lis bob fieckef1ste;f1@admin.state.ak.us Contractor: Doyon Rig No.: 14 DATE: 3/22/2005 Rig Rep.: Egholm/Gooch Rig Phone: 670-3270 Rig Fax: 670-3269 Operator: BP Op. Phone: 670-3268 Op. Fax: 670-3269 Rep.: Green / Brown Field/Unit & Well No.: MP K-09 PTD # 205-014 Meridian: UM Location: Section: 3 Township: 12N Range: 11E Operation: Drlg: Workover: Explor.: Test: Initial: XXXXXX Weekly: Other: Test Pressure: Rams: 250/3500 Annular: 250/2500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign p Upper Kelly 1 P Housekeepi ng: P Dr!. Rig p Lower Kelly 1 P PTD On Location P Hazard Sec. p Ball Type 1 F Standing Order Posted P Inside BOP 1 F BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 P Quantity Test Result Pipe Rams 1 2 7/8 x 5 P No. Valves 14 P Lower Pipe Rams 1 3 1/2 x 6 P Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3 1/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 2950 P Pressure After Closure 1870 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 33 sec P Trip Tank P P Full Pressure Attained 2 min 54 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 2300 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time: ~ Hours Components tested Repair or replacement of equipment will be made within 1 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ¡¡m reQg@admín.state.ak.us Remarks: TIW and Dart valve failed test - Will replace both within 1 day 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Sheave Date 03/21/05 Time 4:00 PM Witness D Green / M Egholm Test start 2100hrs Finish 0300hrs BOP Test (for rigs) BFL 1/28/04 BOP Doyon 14 3-22-05.xls Re: MPK-09 Well Suspension e e Subject: Re: MPK-09 Well Suspension From: STMaunder@ao1.com Date: Sat, 19 Mar 200521:01:06 EST JO S- -0 \L\ To: JoOOsoFC@BP.com CC: QuayWD@BP.com, MillerME@BP.com, NSUADWDrlgRig14@BP.com, john _ spaulding@admin.state.ak.us, chuck_ scheve@admin.state.ak.us, jim _regg@admin.state.ak.us, winton _ aubert@admin.state.ak.us Fred, Your message documents our discussions over the last day or so regarding the situation on MPK-09. Given the uncertainties, your proposal to suspend operations is prudent. Please submit the 403 follow-up as detailed in you note. If the condition of MPK-09 should change, please notify us. Tom Maunder, PE AOGCC Re: MPK-09 Well Suspension.eml 1 of 1 3/25/20057:13 AM MPK-09 Drilling Operations e ~ c905-0 ( L\ Subject: MPK-09 Drilling Operations From: "Johnson, Frederick C" <JohnsoFC@BP.com> Date: Tue, 15 Mar 2005 12:22:47 -0900 To: tom_maunder@admin.state.ak.us CC: "NSU, ADW Drlg Rig 14" <NSUADWDrlgRigI4@BP.com>, "Miller, Mike E" <MillerME@BP.com>, "Christman, Gary E" <christge@BP.com>, "Quay, Walter (Natchiq)" <QuayWD@BP.com>, "NSU, ADW Drlg HSE Advisor" <NSUADWDrlgHSEAdvisor@BP.com> This email is to document our telephone discussion this morning concerning the gas hydrate drilling issues that have occurred on the MPK-09 well being drilled in Milne Point. Gas hydrates have been encountered in the wells previously drilled on MP K-Pad and are well documented on our K-Pad Data Sheet. Gas hydrates were prognosed to be encountered in the MPK-09 Application for Permit to Drill, and the Wellplan. On the current MPK-09 well, gas hydrates were first observed at surface in the return mud flow while drilling at a depth of approximately 2050'md. While drilling the hydrate interval, the return mud overflowed the bell nipple on 3 occasions. The mud overflow was caught in the drip pans under the rig floor. The mud overflow did not come above or on to the rig floor and did not escape from the drip pan system. The cause of this mud return overflow is interpreted to be the near surface expansion of the hydrate gas that is created in the annulus as the drilled hydrate material melts and liberates its gas while being circulated to surface. This situation is interpreted as a normal hydrate drilling issue that is experienced in the hydrate prone areas. This overflow situation was reported to our Environmental Advisor, who classified it as a spill and started the required agency notifications. As of this time there have been 3 mud overflow events that have occurred while drilling at 2311',2819', and 3010'md. The rig response has been to stop drilling, reduce circulation rate until the gas content decreases, and then resume drilling. The mud weight has also been increased to provide additional hydrostatic to offset gas cut mud effects. 1 of 1 3/15/2005 1 :22 PM gas hydrate release Doyon 14 dO 5 -0 \L.\ Darrel Greene (BPXA Co. Rep) notified me at 0830 today that at approx. 1700 hrs yesterday, gas hydrates were encountered at approx. 2220' TVD while drilling surface hole with 9.4 PPG fluid on well K-09 at Milne Point Field / MPU. He indicated that at that time drilling fluid was surging out of the well and estimated that initially approx. 5 or 6 BBLS of drilling fluid "burped" out of the bell nipple and into the drip pan system and then flowed to the rock washer. At this time they began raising mud weight & continued drilling to 2311' TVD where more surging occurred, possibly evacuating 1 or 2 more BBLS of drilling fluid in the same manner as before. He indicated that drilling fluid escaped the primary containment (well bore) and entered secondary containmet (drip pan system) but no fluid was released to the ground. At this point they stopped drilling and began circulating the well while raising mud weight until things settled down. Currently they have 10.3 PPG drilling fluid all around and are still conditioning the drilling fluid to prepare for a wiper trip. He said that ACS, DEC and Tom Maunder (AOGCC) had been notified and I requested that he send us a detailed report as soon as possible. This is the first notification I've had regarding this incident. Thanks, Jeff Hello Jim, I of! 3/15/20059:07 AM Re: Diverter Line Waiver For MPK-09 e . Subject: Re: Diverter Line Waiver For MPK-09 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 14 Mar 200508:09:27 -0900 To: Fred Johnson <JohnsoFC@BP.com> d'O$' ~Ol ~ Fred, Further to our conversation yesterday, is there a "contingency plan" in place for these installations where a shorter diverter line winds up pointed at existing lines and trays? If such a plan exists, I'd like to see a copy. If not, it seems appropriate that one be developed. I know that the likelihood of needing to divert is small, but it is not zero. If a situation were to develop, quickly deenergizing any power and shutting in any production and injection would seem to be very important. Thanks, call or message to discuss. Tom Maunder, PE AOGCC Green, Darrell (Fairweather) wrote: Gentleman; After Moving Doyon 14 To MPK-09 Location And Positioning The Rig The 16" Diverter Line Was Installed. I Spoke With Fred Johnson About Contacting Tom Maunder With The AOGCC Regarding Getting A Waiver For The Length Of Diverter Line. On MPK-09 The Length Of Line Is 45 Feet And To Obtain The Required 75 Feet We Would Have To Fish A 30 Foot Section Of Pipe Between The ESP Electric Cable Tray's, The Production And Gas Injection Lines. Fred Johnson Spoke With Tom Maunder And Obtained A Verbal Variance For The Length Of Line From 75 Feet To 45 Feet. In Addition Tom Asked That The 16" Diverter Line Be Clear Of Any Snow Or Foreign Material, It Has Been Inspected And Is Clear. Darrell W. Green Doyon Rig 14 - Drilling Supervisor Phone (907) 670-3268 Fax (907) 670-3269 1 of 1 3/14/2005 10:02 AM ~ ]"ffifŒlE lill' &\ 1 ~ ~ lK\ O~ . / FRANK H. MURKOWSKI, GOVERNOR AIASIiA OIL AND GAS / CONSERVATION COMMISSION , , 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: MilnePoint~mpK-orl/. BP Exploration (Alaska) Inc. Permit No: 205-014 Surface Location: 3704' NSL, 2123' WEL, SEC. 03, TI2N, RIlE, UM Bottomhole Location: 3684' NSL, 113' WEL, SEC. 04, TI2N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t wi ess any required test. Contact the Commission's petroleum field inspector at 907 659 607 ager). BY ORDER OF THE COMMISSION DATED this~ day of February, 2005 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ,/' -¡.' .. 1 a. Type of work II Drill o Redrill 11 b. Current Well Class o Exploratory (iDevelopment Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service 0 Development Gas o Single Zone 2. Operator Name: 5. Bond: 1m Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 , MPK-09 3. Address: 6. Proposed Depth: , 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9134' , TVD 7073' Milne Point Unit I Kuparuk River 4a. Location of Well (Governmental Section): 7. Property Designation: Sands Surface: ADL 375133 3704' NSL, 2123' WEL, SEC. 03, T12N, R11E, UM ., Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4189' NSL, 4209' WEL, SEC. 03, T12N, R11E, UM 03/01/05 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3684' NSL, 113' WEL, SEC. 04, T12N, R11 E, UM . 2560 /cCj¡' ~ ~ ~ - t-t...<.$':: .. :>;...L.^ A..i""¿" ';¿;..:. . Co' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 1 ;.' piS~~ Nearest Well Within Pool .(1 p Surface: x-584433 , y- 6005838 ' Zone- ASP4 (Height above GL): 63.5' feet IktOD away from ~ K ,. 16. Deviated Wells: Kickoff Depth: 300' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ¿ Maximum Hole Angle: 93 dearees Downhole: 2924 Surface: 2244 "'" z' 16. oisingprogram: Specifications Setting Depth <.11J~ntity;ofCern~nt Size Top Bottom .... (cJ.or sacks) Hole Casina WeiQht Grade Couplina LenQth MD TVD MD TVD Cincludina staae data) 42" 20· 92# H-40 Welded 115' Surface Surface 115' 115' 260 sx Arctic Set lAccrox.) 12-1/4" 9-518" 40# L-80 BTC 5073' Surface Surface 5073' 4963' 649 sx AS Lite, 204 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 7843' Surface Surface 7843' 7033' 105 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC 1391' 7743' 6996' 9134' 7073' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed förRedriUANPRe-éntrýOPeratiön$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft): Junk (measured): CasinQ LenQth Size Cement Volume MD TVD !=ìtrllr:tll r::! I r.nnrh Il'tnr """" -,,- -., ,.- f"\ C \._1 r:: I V'r- I J In i Production ~-!:-B U 1 lLUj limH t,t~~'f"tf~' f1~~ f,: ~~Ag ~nn~_ r~ , . Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments 1m Filing Fee, $100 o BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Walter Quay, 564-4178 Printed Name Fred Johnson Title Senior Drilling Engineer -1AOJ IL¡J Date '2.// / (;I.5~ Prepared By Name/Number. SiQnature Phone S-~ t¡ ___ç-'i 2. 7 Sondra Stewman, 564-4750 '( V Commission Use Only '. Permit To Drill ..I API Number: I Permit APprov~ In I b5 1 See cover letter for Number: 2Õ~-OIë../ 50- Oz.'f- 232.'-/7~OO Date: other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Require~ I DYes ,8(No ~ en Sun;de Measures þ?Yes No Directional Survey Required Q(Yes UNo Other. ~...ç.- , ;¿ "..\0 "-~ ~ \.o.",<-<'ð, ~~ ~">-\-\" ~~(J. \ l.::.. \ ~ ~ û'i .;. "/8/,£ ~"roved ~ ~ ff7L nDlclí\.JÔI APPROVED BY THE COMMISSION Date Form 10-401 Revised ~ '--'" '_'! '" ¡ '-" ¡ JJI \1-. gubm1t In Duplicate . STATE OF ALASKA I ALASk..oIL AND GAS CONSERVATION C :1MISSION PERMIT TO DRILL 20 AAC 25 005 þÞ 1. ,ç k.~/ J-. U. 7 b 2,t:Ç . . bp I Well Name: I MPK-09 I Kuparuk Horizontal Producer Drilling and Completion Plan Summary I Type of Well: I Kuparuk C Sand Horizontal Producer Surface Location: 3,704' FSL and 2,123' FEL .. (As Built) Section 3, T12N, R11E UM E = 584,433' - N = 6,005,838' , T1 - In Kuparuk D 4,259' FSL and 4,024' FEL Section 3, T12N, R11 E UM E = 582,524' N = 6,006,373' Z = 6,958' TVD T2 -- Top Kuparuk C1 4189' FSL and 4,209' FEL Section 3, T12N, R11 E UM E = 582,340' N = 6,006,300 ' Z = 7,033' TVD T3 - Lower C1 4091' FSL and 4441' FEL Section 3, T12N, R11 E UM E = 582,110 ' N = 6,006,200 ' Z = 7,063 ' TVD T4 - Lower C1 3997' FSL and 4652' FEL Section 3, T12N, R11 E UM E = 581,900' N = 6,006,103' Z = 7,053 ' TVD T5 - BHL in Lower C1 3684' FSL and 113' FEL , Section 4, T12N, R11 E UM E = 581,164' N = 6,005,782' Z = 7,073' TVD Distance to Property line 2,520' Distance to nearest well 280' from Cascade 1 A AFE Number: 1 Estimated Start Date: 11 Mar 05 Ri Ri 19 Page 1 . . <" Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D8-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. CasingITubing Program 42in 20 in* 92# H-40 Welded 115 0' 115' 1 115' 12.25 in 9.625 in 40# L-80 BTC 5073' 0 5073' 1 4963' 8.75 in 7.0 in 26# L-80 BTC-M 7843' 0' 7843' 1 7033' 6.125 4.5 12.6 L-80 BTC 1391 7743'/6996 9134/7073 Cement Program: Casin Size Basis 9-5/8",40#, L-80, BTC Surface Casin Tail cement = 500' MD above shoe. 40% Excess over Gauge Hole Lead to surface. 40% Excess over Gauge Hole to PF, 150% Excess over Gau e Hole from PF to Surface Wash 10 bbl water 20 bbl CW 100 50 bbl of MudPush 494 bbl, 649 sx of ArcticSet Lite: 10.7 and 4.28 ft Isx 42 bbl, 204 sx "G" mixed at 15.8 Ibl al & 1.16 ft Isx S acer Lead Tail Total Cement Volume: 536 bbl Casin Size Basis Total Cement Volume: 22 bbl 7",26#, L-80, BTC-M Intermediate Casin Tail cement = 500' MD above shoe. 40% Excess over Gau e Hole Wash 5-bbl water 10 bbl CW 100 20 bbl of MudPush 22 bbl, 105sx "G" mixed at 15.8 Ibl al & 1.17 ft Isx BHST ::::170°F from SOR S acer Tail Tern Page 2 . . Evaluation Program: 12-1/4" Section Open Hole: · MWD/GR · IFR/CASANDRA, · S er InSite , 8-3/4" Section · MWD/GR/RES · IFR/CASANDRA, · S er InSite , 6-1/8" Section Open Hole: · MWD/GR/RES/RES (ASI) · IFR/CASANDRA, · S er InSite Cased Hole: Formation Markers: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (I b/aa I) BPRF 1711 1688 706 8.35 Top Ugnu (TUZC) 4200 4113 1759 8.35 Top Schrader 4658 4558 1952 8.35 Schrader OA 4786 4653 2006 8.35 Base Schrader OB , r.,17 4822 4718 2021 8.35 Top HRZ "... . 6678 6458 2777 8.35 Top Kalubik 6852 6583 2831 8.35 Kalubik Gamma Marker 6959 6653 2861 8.35 Top Kuparuk D 7219 6798 2924 7.8 Top Kuparuk Cl _.l 7829 7028 2467 7.8 - . ~ ~ Recommended Bit Program: 1 2 3 12.25" 8.75" 6.125" o - 5073 5073 - 7843 7843' - 9134' 5073' 2770 1291 MX-1 Page 3 . . Well Control: Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity tests: Kick tolerance: . Integrity tests: · Planned completion fluid: 2,924 psi at 6,798' TVD (Top of the Kuparuk D) # 2,244 psi at (Based on a full column of gas at 0.1 psi/ft) ~ 3,000 psi FIT to 11.0 Ib/gal 20' below the 9-5/8" shoe. Infinite with 9.0 Ib/gal mud at below the 9-5/8" shoe. FIT to 10.5 Ib/gal 20' below the 7" shoe. Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: · Large (1" to 2") Gravel has been encounterd in some K-Pad wells. High Vis Mud should be utilized. · Hydrates have been reported on K-Pad. Expected Depth for hydrates 2200' SS to 2900' SS. Keep the Mud as Cool as possible. · Tight hole and stuck pipe due to clays and poor hole cleaning have occurred on K Pad wells. ~ Lost Circulation Lost Circulation has been encountered in both the surface and production intervals. · The surface interval incidents appear to result from higher MW (>10.5ppg) utilized for hydrate issues. The higher MW did not effectively combat the hydrates and was eventually lowered to TD and run casing. · The lost circulation in the production intervals is associated with conductive faults; We do not expect losses while drilling this well if there is good hole cleaning. If seepage and/or losses occur, follow the LOST CIRCULATION DECISION MATRIX in the well plan. Expected Pressures · All Formation are expected to be normally pressured: 8.35 ppg or less 7.8 ppg in the Kuparuk. / Pad Data Sheet · Please Read the K-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons are possible in the Schrader Bluff interval. Faults · Two (2) faults are mapped in the intermediate hole section at 4626' MD(4528' TVD) & 7198' MD (6788' TVD). Fault #1 is just below or within the Schrader. Fault #2 is above the HRZ. Neither fault are expected to cause issues,. Ensure safe distance from the fault when setting surface casing. Hydrogen Sulfide · MPK Pad is not designated as an H2S Pad, H2S detected from Kuparuk wells on the pad: ~. MPK-06 20.9 ppm 3/2001 MPK-38 20.5 ppg 3/2001; Page 4 . . Anti-collision Issues . MPK-09 passes the Major Risk Criteria. Gyro surveys will be required until clear of magnetic interference. Distance to Nearest Property · MPK-09 is planned to be 2520ft from the nearest Milne Point property line. ,/ Distance to Nearest Well Within Pool . MPK-09 is 280ft from the nearest sand penetration in the Cascade 1-A. ,; Page 5 . . DRILL & COMPLETION PROCEDURE Pre-Ria Operations 1. The 20" conductor will be installed pre-rig. Drillina: 1. MIRT and NU Diverter. 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 12-1 /4" surface hole below the Schrader Bluff interval. ' 4. Run and cement 9-5/8" sruface casing. 5. ND diverter, install wellhead and NU/Test BOPE. ' 6. Drill 8-3/4" hole to intermediate casing point. 7. Run and cement 7" intermediate casing. 8. Drill 6-1/8" Horizontal Interval. ' 9. Run and set 4-1/2" Slotted Liner. ' 10. Displace to Brine. 11. Run a 2-7/8" ESP Completion 12. ND BOP/NU Tree. 13. Freeze Protect With Diesel 14. RD & MO Doyon 14. Page 6 ~ 2-9/165K I MPK-09 Propos. Wellhead: FMC Gen 5 Sys m 11",5M Tubing Head: FMC 11" x 2.875" 20" 91.1-lb/ft H-40 Tail Cement Top 500' above shoe 9.625-in 40-lb/ft L-80 BTC casing 15073'1 7.0-in 26-lb/ft L-80 BTC-M casing (drift ID = 6.151", cap = 0.0383-bbl/ft) 2-7/8", 6.5#/ft, L-80, EUE Production Tubing Drift ID - 2.347", Cap. = 0.00579 bpf Tail Cement Top 500' above shoe Top 4-1/2" Liner X,xxx' ZXP Liner Top Packer 7.O-in Casing Shoe 7843' Kup C-Sand Lateral DAlE REV. BY COMMENTS WOO Proposed Kuparuk Producer 26-Jan-D5 DF elev. = 63.5 ft KOP @ 300' Max hole angle in tubing =70 degrees then horizontal Centrilift ESP 6 1/8" Hole TD @ 9,134' 4.5-in Slotted Liner L-BO IBT MILNE POINT UNIT WELL MPK-09... API NO: 50-0 BP EXPLORATION (AKl. COMPANY DETAILS REfERENCE INfORMA nON BPAmoco Co-orilinate (NlE) Reference: Well Centre: Plan MPK-09, True North Vertical (TVD) Reference: 29.2 + 34.3 6350 Section (VS) Reference: Slot- (O.OON,O.ooE) Measured Depth Reference: 29.2 + 34.3 63.50 Calculation Method: Minimwn Curvature Calculation Method: Minimwn Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warning Method: Rules Based -" '" ... o ~ 'Ë > ... 2 ¡... : 300' MD, 300'TVD FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 1688.50 1711.70 BPRF 2 4113.50 4200.89 TUZC 3 4558.50 4657.64 Top Schrader 4 4683.50 4785.94 Schrader OA 5 4718.50 4821.86 base Schrader OB 6 6458.50 6678.92 Top HRZ 7 6583.50 6851.97 Top Kalubik/Base HRZ 8 6653.50 6958.80 Kalubik gamma marker 9 6798.50 7219.13 Top Kuparuk D 10 7028.50 7829.01 Top Kuparuk C1 : 600' MD, 599.86'TVD Djr 3/100' : 750' MD, 749.38'TVD : 1928.94' MD, 1900'TVD 220 End Djr : 2093.57' MD, 2060.38' TVD ~ g 330 ::: Start Djr 4/100': 5776.04' MD, 5648.14'TVD : 7421.62' MD, 6883.59' TVD Start Djr 4/100' : 7811.88' MD, 7022.49'TVD End Djr : 7843.65' MD, 7033.5' TVD Start Djr 12/100' : 7858.65' MD, 7038.56'TVD End Djr : 8050.02' MD, 7065.93' TVD Start Dir 7/100' : 8066.89' MD, 7065"IVD End Djr : 8121.34'MD, 7062.5I'TVD Start Dir6/100': 8284.07' MD, 7054.62'TVD nd Djr : 8360.7' MD, 7053.88' TVD Depth: 9134.11' MD, 7073.5' TVD -09T5 -09 WP05 SURVEY PROGRAM Plan: MPK-09 WP05 (Plan MPK-09/Plan MPK-09) Depth Fm Depth To Survey/Plan 34.30 1000.00 Planned: MPK-09 WP05 V64 1000.00 9134.11 Planned: MPK-09 WP05 V64 Tool Created By: Digital Business Client User Date: 12/14/2004 CB-GYR()..SS MWD+IFR+MS Checked: Reviewed: Date: Date: WELL DETAILS N.., +N/-S +E/-W Northing """"8 Latitude Longitude Slot Plan MPK..o9 11085.19 961.60 6005838.54 584432.85 70~25'33.I72N 149~18'43.045W N/A TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape MPK-09 TI 6958.50 556.00 -1903.00 6006372.92 582523.86 Point MPK-09 T2 7033.50 485.15 -2087.69 6006300.00 582340.00 Point MPK-09 T4 7053.50 293.00 -2530.00 6006102.87 581899.93 Point MPK-09T3 7063.50 387.75 -2318.83 6006200.00 582110.00 Point MPK-{9 T5 7073.50 -20.01 -3270.00 6005781.54 581163.59 Point SECTION DETAILS See MD 1nc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 600.00 3.00 305.00 599.86 4.50 -6.43 1.00 305.00 6.40 4 750.00 6.00 305.00 749.38 11.25 -16.07 2.00 0.00 16.00 5 990.00 13.20 305.00 985.87 34.20 -48.84 3.00 0.00 48.63 6 1928.94 13.20 305.00 1900.00 157.17 -224.47 0.00 0.00 223.50 7 2093.57 13.02 319.53 2060.38 182.07 -251.91 2.00 100.13 250.79 8 5776.04 13.02 319.53 5648.14 813.37 -790.50 0.00 0.00 785.51 9 7239.05 61.90 248.10 6808.00 686.90 -1564.70 4.00 -78.67 1560.47 10 7421.62 69.15 249.06 6883.59 626.29 -1719.30 4.00 7.07 1715.44 11 7632.10 69.15 249.06 6958.50 556.00 -1903.00 0.00 0.00 1899.56 MPK-09 Tl 12 7811.88 69.15 249.06 7022.49 495.95 -2059.92 0.00 0.00 2056.85 13 7843.65 70.28 248.44 7033.50 485.15 -2087.69 4.00 ·27.11 2084.68 MPK-09 T2 14 7858.65 70.28 248.44 7038.56 479.96 -2100.82 0.00 0.00 2097.85 15 8050.02 93.16 246.43 7065.93 407.70 -2274.51 12.00 -5.15 2271.97 16 8066.89 93.16 246.43 7065.00 400.97 -2289.94 0.00 0.00 2287.44 17 8098.69 92.25 244.40 7063.50 387.75 ·2318.83 7.00 -114.15 2316.41 MPK-09 T3 18 8121.34 92.78 245.90 7062.51 378.24 -2339.36 7.00 70.55 2337.00 19 8284.07 92.78 245.90 7054.62 311.87 -2487.72 0.00 0.00 2485.77 20 8330.39 90.00 246.00 7053.50 293.00 -2530.00 6.00 177.87 2528.16 MPK-09 T4 21 8360.70 88.55 247.09 7053.88 280.93 -2557.80 6.00 143.05 2556.04 22 9134.11 88.55 247.09 7073.50 -20.01 -3270.00 0.00 0.00 3270.06 MPK-09 T5 CASING DETAILS No. TVD MD Name Size 1 4963.50 5073.33 95/8" 9.625 2 7033.28 7843.00 7" 7.000 3 7073.50 9134.00 4 1/2" 4.500 o 2200 3300 Vertical Section at 269.65° [1100ft/in] 4400 1100 5500 : COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: MPK·09 WP05 (Plan MPK·09/Plan MPK-09) .-. bp . ÐP Amoco Co-ordinate (NÆ) Reference: Well Centæ: Plan MPK..09, True North Deptb fro Depth To Survey/Plan Tool Created By: Digital Business Client User Date: 12/14/2004 W Vertîcal (TVD) Reference: 29.2+34.363.50 Calculi: ~;:I:::: ~~M ClUVSture Me:~:~~~ ~:~=; ~~~"+ )04~N,O·~~~O ~ri:oo ~~:r: ~:=~ ~~~: ~~~ ~:: ~~~~~;~S Checked: Dale: Scan Methou: Trav Cylinder North Calculation Method: Mlliimum Curvature WELL DETAILS Error Surface: Elliptical + Casing I Warning Method: Rules Based Nwne +N/-S +EI-W Northing Easting Latitude Longitude Slot SECTION DETAILS PlanMPK.09 11085.19 961.60 6005838,54 584432.85 7002S'33.172N 149°t8'43,045W N/A TARGET DETAILS See MD Ine Azí TVD +N/-S +E/- W DLeg TFaee VSee Target Name TVD +N/-S +E/-W Northíng EasHng Shape 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0,00 MPK-09 Fault1 4528.50 1029.21 -671.31 6006860.00 583750.00 Polygon 3 600.00 3.00 305.00 599.86 4.50 -6.43 1.00 305.00 6.40 MPK-09 Fault2 6788.50 490.64 -362.36 6006325.00 584065.00 Polygon 4 750.00 6.00 305.00 749.38 11.25 -16.07 2.00 0.00 16.00 MPK-09 Tl 6958.50 556.00 .1903.00 6006372.92 582523.86 Point 5 990.00 13.20 305.00 985.87 34.20 -48.84 3.00 0.00 48.63 MPK-09 T2 7033.50 485.15 .2087.69 6006300.00 582340.00 Point 6 1928.94 13.20 305.00 1900.00 157.17 -224,47 0,00 0.00 223.50 MPK-09 Geo Poly 7033.50 373.74 -1610.87 6006194.00 582818.00 Polygon 7 2093.57 13,02 319.53 2060.38 182.07 -251.91 2.00 100.13 250.79 MPK-09 T4 7053.50 293.00 -2530.00 6006102.87 581899.93 Poínt 8 5776.04 13.02 319,53 5648.14 813.37 -790.50 0.00 0.00 785.51 MPK-09T3 7063.50 387.75 -2318.83 6006200.00 582110.00 Poínt 9 7239.05 61.90 248.10 6808.00 686.90 -1564.70 4.00 -78.67 1560.47 MPK-09 T5 7073.50 -20.01 -3270.00 6005781.54 581163.59 Point 10 7421.62 69.15 249.06 6883.59 626.29 -1719.30 4.00 7.07 1715.44 11 7632.10 69.15 249.06 6958.50 556.00 -1903.00 0.00 0.00 1899.56 MPK-09 Tl CASING DETAILS 12 7811.88 69.15 249.06 7022.49 495.95 -2059.92 0.00 0.00 2056.85 13 7843.65 70.28 248.44 7033.50 485.15 -2087.69 4.00 -27.11 2084.68 MPK-09T2 No. TVD MD Name Size 14 7858.65 70.28 248.44 7038.56 479.96 -2100.82 0.00 0.00 2097.85 15 8050.02 93.16 246.43 7065.93 407.70 -2274.51 12.00 -5.15 2271.97 1 4963.50 5073.33 95/8" 9.625 , 16 8066.89 93.16 246.43 7065.00 400.97 -2289.94 0.00 0.00 2287.44 2 7033.28 7843.00 7" 7.000 17 8098.69 92.25 244.40 7063.50 387.75 -2318.83 7.00 -1I4.t5 2316.41 MPK-09 T3 3 7073.50 9134.00 41/2" 4.500 18 8121.34 92.78 245.90 7062.51 378.24 -2339.36 7.00 70.55 2337.00 19 8284.07 92.78 245.90 7054.62 311.87 -2487.72 0.00 0.00 2485.77 20 8330.39 90.00 246.00 7053.50 293.00 -2530.00 6.00 177.87 2528.16 MPK-09 T4 I I FORMATION TOP DETAILS 21 8360.70 88.55 247.09 7053.88 280.93 -2557.80 6.00 143.05 2556.04 , . ..., 22 9134.11 88.55 247.09 7073.50 -20.01 ·3270.00 0.00 0.00 3270.06 MPK-09T5" , I'" No. TVDPath MDPath Fonnatíon : :; : , '" ' 'm;:m,m, i i 1 1688.50 1711.70 BPRF ¡I'm....' , i . , . ' ,2 4113.50 4200.89 TUZC I I j , i' " I ' I ,I I I ' ¡ 3 4558.50 4657.64 Top Schrader , , . .' . , I , , ' ~ ~~~~.~~ ~?~??~ ~ehra_der OA î2u- i ,-.i.... ;) 't/lð.)U 'tö¿l.lSO oase::scnraderOB t tm t .......,.. t MPK-09 Fa Itl····,,····, ........ 6 6458.50 6678.92 Top HRZ . . ; im' fm.; ,'" 7 6583.50 6851.97 Top Ka1ubd<lBase HRZ , .:' , '. : __1. ' ,\ 8 6653.50 6958.80 Kalub,k gamma marker ',. '. ,IE! '~]~r1. 421.~, 2'M¡D,6883.5 VI) \ ' " , 9 6798.50 7219.13 TopKupanrkD ¡m " ; I , :' ,;J,;' \ ,. 10 7028.50 7829.01 Top Kupanrk CI ; ,...... m StaàHí+100"f811-F8 MDJ7322'.49'TVD \( .. """.j lòfd riif :J84jf6~'*7fjt·5!TÞD ..., .. ,., , "j 80,,'m ., ' i .L ,i;, .J:m -- '--.... JU. . . 95/8" C mJII;"'. ....i.......... ''i'", ~.tar¡t,.tt ir ".121" 10.0' 1"'" 7858, .~?'¥q"". ", 5 " , . ... '"m""" '5 I '". ", , "\ ,;:V ,.0'" , . 'i-, "<IT , :5 , Énd Dir 805Q.02' MD, 7065.93' T \ \: ,. I V ð. '., I ~, .. , " ',' T", 'T'''''' , t . ."." :/ J'" - ' StartDir 71,. 100.', ··8 k«t, &9, 'MD." 7065'1vDim / ... ' +' ., 'Fr'·.. I' * "" j f I En.lbít;:!,. J.;;;.i.~'~E~'V, ~~;~,. ;'.'~~'~.' , /1" .. + " 45{ " ~ ~ ~ Iii I ',L't i',mmm L> ' ' 40C ,\; II ... ... '7' ' I '. 'Mpv. 9 ~'"" '. m' ."--" . ..A' , ,.. - ¡ i f'-- :1',: i '_~......""~ ;~ ,." ~ ~ '.. - is ..?'5~"'" ..,.. , ' 350 VJ 'me V::.y " :.--.,.m; ",' . , 'm 'm, /'" ..... ~ MP' _C , .:\ , -". ... ..,.."" ~v . . vi' V x' 112':·...., 1-- ,. En I * " ,J( ,,+.. 2{UU. " , ,....y < ~n, <0 '~;; ~nn'"""""i... '..m.'..m --'Cf 'JVV l' . i- / . , , .. m;m':,+L: ,;---: u( , En Dir:990'I>1Dì985.87'T D', /' /.. 0 .....,.... kl=~ ~/ " '.' ,:T'm, . I : .k--:..-< .ifDii3/l00't'750' MD;:7 9.38'TVD,<:lm. ii, '" ¡m......' ,., ,. I' "... ............j... --t .0" . : IStart\Didl100''~OO¡~ D,599,&6'TVD,m,.f liT ,'Stì!rtjD¡r 1(11)0'73 0' MD,300'TVD+ .. ...,...,......; .,., , ·····T, I , ......,... :"¡" I ; mT' ;'iT ..' ¡ 'i'T' , ....,... ~ , -3200 -2800 -2400 -2000 -1600 -1200 ·800 -400 0 West(-)/East(+) [400ft/ín] . . Sperry-Sun BP Planning Report Field: Milne Point North Slope UNITED STATES Map System: us State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: M PI K Pad TR-12-11 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 27.90 ft 5994744.31 ft 583595.36 ft Latitude: 70 23 Longitude: 149 19 North Reference: Grid Convergence: 44.152 N 11.252 W True 0.64 deg Well: Plan MPK-09 Slot Name: Well Position: +N/-S 11085.19 ft Northing: 6005838.54 ft Latitude: +E/-W 961.60 ft Easting: 584432.85 ft Longitude: Position Uncertainty: 0.00 ft 70 25 33.172 N 149 18 43.045 W Casing Points 1711.70 1688.50 BPRF 0.00 0.00 4200.89 4113.50 TUZC 0.00 0.00 4657.64 4558.50 Top Schrader 0.00 0.00 4785.94 4683.50 Schrader OA 0.00 0.00 4821.86 4718.50 base Schrader OB 0.00 0.00 6678.92 6458.50 Top HRZ 0.00 0.00 6851.97 6583.50 Top Kalubik/Base HRZ 0.00 0.00 6958.80 6653.50 Kalubik gamma marker 0.00 0.00 7219.13 6798.50 Top Kuparuk D 0.00 0.00 7829.01 7028.50 Top Kuparuk C1 0.00 0.00 Targets MPK-09 Fault1 4528.50 1029.21 -671.31 6006860.00 583750.00 70 25 43.294 N 149 19 2.739 W -Polygon 1 4528.50 511.80 -907.20 6006340.00 583520.00 70 25 38.205 N 149 19 9.658 W -Polygon 2 4528.50 779.60 -709.14 6006610.00 583715.00 70 25 40.839 N 149 19 3.848 W -Polygon 3 4528.50 1029.21 -671.31 6006860.00 583750.00 70 25 43.294 N 149 19 2.739 W -Polygon 4 4528.50 779.60 -709.14 6006610.00 583715.00 70 25 40.839 N 149 19 3.848 W MPK-09 Fault2 6788.50 490.64 -362.36 6006325.00 584065.00 70 25 37.997 N 149 18 53.675 W -Polygon 1 6788.50 793.73 -1074.04 6006620.00 583350.00 70 25 40.977 N 149 19 14.553 W -Polygon 2 6788.50 490.64 -362.36 6006325.00 584065.00 70 25 37.997 N 149 18 53.675 W -Polygon 3 6788.50 108.11 -586.72 6005940.00 583845.00 70 25 34.235 N 149 19 0.256 W -Polygon 4 6788.50 490.64 -362.36 6006325.00 584065.00 70 25 37.997 N 149 18 53.675 W MPK-09 T1 6958.50 556.00 -1903.00 6006372.92 582523.86 70 25 38.638 N 149 19 38.870 W MPK-09 T2 7033.50 485.15 -2087.69 6006300.00 582340.00 70 25 37.940 N 149 19 44.287 W . . Sperry-Sun BP Planning Report MPK-09 Goo Poly 7033.50 373.74 -1610.87 6006194.00 582818.00 70 25 36.846 N 149 19 30.299 W -Polygon 1 7033.50 373.74 -1610.87 6006194.00 582818.00 70 25 36.846 N 149 19 30.299 W -Polygon 2 7033.50 837.35 -1658.64 6006657.00 582765.00 70 2541.405 N 149 19 31.703 W -Polygon 3 7033.50 468.83 -2412.92 6006280.00 582015.00 70 25 37.779 N 149 19 53.828 W -Polygon 4 7033.50 386.60 -2658.89 6006195.00 581770.00 70 25 36.969 N 149 20 1.042 W -Polygon 5 7033.50 99.32 -3345.25 6005900.00 581087.00 70 25 34.141 N 149 20 21.172 W -Polygon 6 7033.50 -146.44 -3458.05 6005653.00 580977.00 70 25 31.724 N 149 20 24.478 W -Polygon 7 7033.50 -241.80 -3251.09 6005560.00 581185.00 70 25 30.787 N 149 20 18.406 W MPK-09 T4 7053.50 293.00 -2530.00 6006102.87 581899.93 70 25 36.049 N 149 19 57.260 W MPK-09 T3 7063.50 387.75 -2318.83 6006200.00 582110.00 70 25 36.982 N 149 19 51.067 W MPK-09 T5 7073.50 -20.01 -3270.00 6005781.54 581163.59 70 25 32.968 N 149 20 18.963 W Plan Section Information 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 3.00 305.00 599.86 4.50 -6.43 1.00 1.00 0.00 305.00 750.00 6.00 305.00 749.38 11.25 -16.07 2.00 2.00 0.00 0.00 990.00 13.20 305.00 985.87 34.20 -48.84 3.00 3.00 0.00 0.00 1928.94 13.20 305.00 1900.00 157.17 -224.47 0.00 0.00 0.00 0.00 2093.57 13.02 319.53 2060.38 182.07 -251.91 2.00 -0.11 8.83 100.13 5776.04 13.02 319.53 5648.14 813.37 -790.50 0.00 0.00 0.00 0.00 7239.05 61.90 248.10 6808.00 686.90 -1564.70 4.00 3.34 -4.88 -78.67 7421.62 69.15 249.06 6883.59 626.29 -1719.30 4.00 3.97 0.53 7.07 7632.10 69.15 249.06 6958.50 556.00 -1903.00 0.00 0.00 0.00 0.00 MPK-09 T1 7811.88 69.15 249.06 7022.49 495.95 -2059.92 0.00 0.00 0.00 0.00 7843.65 70.28 248.44 7033.50 485.15 -2087.69 4.00 3.56 -1.94 -27.11 MPK-09 T2 7858.65 70.28 248.44 7038.56 479.96 -2100.82 0.00 0.00 0.00 0.00 8050.02 93.16 246.43 7065.93 407.70 -2274.51 12.00 11.96 -1.05 -5.15 8066.89 93.16 246.43 7065.00 400.97 -2289.94 0.00 0.00 0.00 0.00 8098.69 92.25 244.40 7063.50 387.75 -2318.83 7.00 -2.87 -6.39 -114.15 MPK-09 T3 8121.34 92.78 245.90 7062.51 378.24 -2339.36 7.00 2.33 6.61 70.55 8284.07 92.78 245.90 7054.62 311.87 -2487.72 0.00 0.00 0.00 0.00 8330.39 90.00 246.00 7053.50 293.00 -2530.00 6.00 -6.00 0.22 177.87 MPK-09 T4 8360.70 88.55 247.09 7053.88 280.93 -2557.80 6.00 -4.79 3.61 143.05 9134.11 88.55 247.09 7073.50 -20.01 -3270.00 0.00 0.00 0.00 0.00 MPK-09 T5 Survey 34.30 0.00 0.00 34.30 -29.20 0.00 0.00 0.00 6005838.54 584432.85 CB-GYRO-SS 100.00 0.00 0.00 100.00 36.50 0.00 0.00 0.00 6005838.54 584432.85 CB-GYRO-SS 200.00 0.00 0.00 200.00 136.50 0.00 0.00 0.00 6005838.54 584432.85 CB-GYRO-SS 300.00 0.00 0.00 300.00 236.50 0.00 0.00 0.00 6005838.54 584432.85 Start Dir 1/100 400.00 1.00 305.00 399.99 336.49 0.50 -0.71 1.00 6005839.03 584432.13 CB-GYRO-SS 500.00 2.00 305.00 499.96 436.46 2.00 -2.86 1.00 6005840.51 584429.97 CB-GYRO-SS 600.00 3.00 305.00 599.86 536.36 4.50 -6.43 1.00 6005842.97 584426.37 Start Dir 2/100 700.00 5.00 305.00 699.61 636.11 8.50 -12.15 2.00 6005846.91 584420.61 CB-GYRO-SS 750.00 6.00 305.00 749.38 685.88 11.25 -16.07 2.00 6005849.61 584416.65 Start Dir 3/100 800.00 7.50 305.00 799.04 735.54 14.62 -20.89 3.00 6005852.93 584411.80 CB-GYRO-SS 900.00 10.50 305.00 897.79 834.29 23.60 -33.70 3.00 6005861.75 584398.89 CB-GYRO-SS 990.00 13.20 305.00 985.87 922.37 34.20 -48.84 3.00 6005872.18 584383.63 End Dir : 990' 1000.00 13.20 305.00 995.60 932.10 35.51 -50.71 0.00 6005873.47 584381.75 MWD+IFR+MS . . Sperry-Sun BP Planning Report 1100.00 13.20 305.00 1092.96 1029.46 48.60 -69.41 0.00 6005886.35 584362.90 MWD+IFR+MS 1200.00 13.20 305.00 1190.32 1126.82 61.70 -88.12 0.00 6005899.23 584344.05 MWD+IFR+MS 1300.00 13.20 305.00 1287.68 1224.18 74.80 -106.82 0.00 6005912.12 584325.20 MWD+IFR+MS 1400.00 13.20 305.00 1385.03 1321.53 87.90 -125.53 0.00 6005925.00 584306.35 MWD+IFR+MS 1500.00 13.20 305.00 1482.39 1418.89 100.99 -144.23 0.00 6005937.89 584287.50 MWD+IFR+MS 1600.00 13.20 305.00 1579.75 1516.25 114.09 -162.94 0.00 6005950.77 584268.65 MWD+IFR+MS 1700.00 13.20 305.00 1677.11 1613.61 127.19 -181.64 0.00 6005963.65 584249.79 MWD+IFR+MS 1711.70 13.20 305.00 1688.50 1625.00 128.72 -183.83 0.00 6005965.16 584247.59 BPRF 1800.00 13.20 305.00 1774.47 1710.97 140.29 -200.35 0.00 6005976.54 584230.94 MWD+IFR+MS 1900.00 13.20 305.00 1871.82 1808.32 153.38 -219.06 0.00 6005989.42 584212.09 MWD+IFR+MS 1928.94 13.20 305.00 1900.00 1836.50 157.17 -224.47 0.00 6005993.15 584206.64 Start Dir 2/100 2000.00 13.02 311.22 1969.21 1905.71 167.10 -237.14 2.00 6006002.94 584193.86 MWD+IFR+MS 2093.57 13.02 319.53 2060.38 1996.88 182.07 -251.91 2.00 6006017.74 584178.92 End Dir : 2093 2100.00 13.02 319.53 2066.65 2003.15 183.18 -252.85 0.00 6006018.83 584177.96 MWD+IFR+MS 2200.00 13.02 319.53 2164.07 2100.57 200.32 -267.48 0.00 6006035.80 584163.15 MWD+IFR+MS 2300.00 13.02 319.53 2261.50 2198.00 217.46 -282.10 0.00 6006052.78 584148.33 MWD+IFR+MS 2400.00 13.02 319.53 2358.93 2295.43 234.61 -296.73 0.00 6006069.75 584133.51 MWD+IFR+MS 2500.00 13.02 319.53 2456.36 2392.86 251.75 -311.36 0.00 6006086.73 584118.69 MWD+IFR+MS 2600.00 13.02 319.53 2553.79 2490.29 268.89 -325.98 0.00 6006103.70 584103.88 MWD+IFR+MS 2700.00 13.02 319.53 2651.21 2587.71 286.04 -340.61 0.00 6006120.68 584089.06 MWD+IFR+MS 2800.00 13.02 319.53 2748.64 2685.14 303.18 -355.23 0.00 6006137.65 584074.24 MWD+IFR+MS 2900.00 13.02 319.53 2846.07 2782.57 320.32 -369.86 0.00 6006154.63 584059.43 MWD+IFR+MS 3000.00 13.02 319.53 2943.50 2880.00 337.47 -384.48 0.00 6006171.60 584044.61 MWD+IFR+MS 3100.00 13.02 319.53 3040.93 2977.43 354.61 -399.11 0.00 6006188.58 584029.79 MWD+IFR+MS 3200.00 13.02 319.53 3138.35 3074.85 371.75 -413.74 0.00 6006205.55 584014.97 MWD+IFR+MS 3300.00 13.02 319.53 3235.78 3172.28 388.89 -428.36 0.00 6006222.53 584000.16 MWD+IFR+MS 3400.00 13.02 319.53 3333.21 3269.71 406.04 -442.99 0.00 6006239.50 583985.34 MWD+IFR+MS 3500.00 13.02 319.53 3430.64 3367.14 423.18 -457.61 0.00 6006256.48 583970.52 MWD+IFR+MS 3600.00 13.02 319.53 3528.06 3464.56 440.32 -472.24 0.00 6006273.45 583955.70 MWD+IFR+MS 3700.00 13.02 319.53 3625.49 3561.99 457.47 -486.86 0.00 6006290.43 583940.89 MWD+IFR+MS 3800.00 13.02 319.53 3722.92 3659.42 474.61 -501.49 0.00 6006307.40 583926.07 MWD+IFR+MS 3900.00 13.02 319.53 3820.35 3756.85 491.75 -516.11 0.00 6006324.38 583911.25 MWD+IFR+MS 4000.00 13.02 319.53 3917.78 3854.28 508.90 -530.74 0.00 6006341.35 583896.44 MWD+IFR+MS 4100.00 13.02 319.53 4015.20 3951.70 526.04 -545.37 0.00 6006358.33 583881.62 MWD+IFR+MS 4200.00 13.02 319.53 4112.63 4049.13 543.18 -559.99 0.00 6006375.30 583866.80 MWD+IFR+MS 4200.89 13.02 319.53 4113.50 4050.00 543.34 -560.12 0.00 6006375.45 583866.67 TUZC 4300.00 13.02 319.53 4210.06 4146.56 560.33 -574.62 0.00 6006392.28 583851.98 MWD+IFR+MS 4400.00 13.02 319.53 4307.49 4243.99 577.47 -589.24 0.00 6006409.25 583837.17 MWD+IFR+MS 4500.00 13.02 319.53 4404.92 4341.42 594.61 -603.87 0.00 6006426.23 583822.35 MWD+IFR+MS 4600.00 13.02 319.53 4502.34 4438.84 611.76 -618.49 0.00 6006443.20 583807.53 MWD+IFR+MS 4626.85 13.02 319.53 4528.50 4465.00 616.36 -622.42 0.00 6006447.76 583803.55 MPK-09 Fault1 4657.64 13.02 319.53 4558.50 4495.00 621.64 -626.92 0.00 6006452.99 583798.99 Top Schrader 4700.00 13.02 319.53 4599.77 4536.27 628.90 -633.12 0.00 6006460.18 583792.71 MWD+IFR+MS 4785.94 13.02 319.53 4683.50 4620.00 643.63 -645.69 0.00 6006474.77 583779.98 Schrader OA 4800.00 13.02 319.53 4697.20 4633.70 646.04 -647.75 0.00 6006477.15 583777.90 MWD+IFR+MS 4821.86 13.02 319.53 4718.50 4655.00 649.79 -650.94 0.00 6006480.87 583774.66 base Schrader 4900.00 13.02 319.53 4794.63 4731.13 663.19 -662.37 0.00 6006494.13 583763.08 MWD+IFR+MS 5000.00 13.02 319.53 4892.06 4828.56 680.33 -677.00 0.00 6006511.10 583748.26 MWD+IFR+MS 5073.33 13.02 319.53 4963.50 4900.00 692.90 -687.72 0.00 6006523.55 583737.40 95/8" 5100.00 13.02 319.53 4989.48 4925.98 697.47 -691.62 0.00 6006528.08 583733.44 MWD+IFR+MS 5200.00 13.02 319.53 5086.91 5023.41 714.62 -706.25 0.00 6006545.05 583718.63 MWD+IFR+MS 5300.00 13.02 319.53 5184.34 5120.84 731.76 -720.87 0.00 6006562.03 583703.81 MWD+IFR+MS . Sperry-Sun BP Planning Report . 5400.00 13.02 319.53 5281.77 5218.27 748.90 -735.50 0.00 6006579.00 583688.99 MWD+IFR+MS 5500.00 13.02 319.53 5379.20 5315.70 766.05 -750.12 0.00 6006595.98 583674.18 MWD+IFR+MS 5600.00 13.02 319.53 5476.62 5413.12 783.19 -764.75 0.00 6006612.95 583659.36 MWD+IFR+MS 5700.00 13.02 319.53 5574.05 5510.55 800.33 -779.38 0.00 6006629.93 583644.54 MWD+IFR+MS 5776.04 13.02 319.53 5648.14 5584.64 813.37 -790.50 0.00 6006642.84 583633.27 Start Dir 4/1 00 5800.00 13.24 315.43 5671.47 5607.97 817.38 -794.18 4.00 6006646.80 583629.55 MWD+IFR+MS 5900.00 14.80 300.16 5768.52 5705.02 831.96 -813.27 4.00 6006661.17 583610.30 MWD+IFR+MS 6000.00 17.16 288.36 5864.67 5801.17 843.03 -838.32 4.00 6006671.95 583585.12 MWD+IFR+MS 6100.00 20.03 279.58 5959.46 5895.96 850.53 -869.22 4.00 6006679.10 583554.15 MWD+IFR+MS 6200.00 23.22 273.03 6052.43 5988.93 854.42 -905.80 4.00 6006682.58 583517.52 MWD+IFR+MS 6300.00 26.62 268.02 6143.12 6079.62 854.69 -947.89 4.00 6006682.38 583475.43 MWD+IFR+MS 6400.00 30.16 264.10 6231.08 6167.58 851.34 -995.29 4.00 6006678.48 583428.08 MWD+IFR+MS 6500.00 33.80 260.94 6315.90 6252.40 844.37 -1047.77 4.00 6006670.92 583375.69 MWD+IFR+MS 6600,00 37.50 258.33 6397.15 6333.65 833.83 -1105.06 4.00 6006659.73 583318.53 MWD+IFR+MS 6678.92 40.45 256.56 6458.50 6395.00 823.01 -1153.49 4.00 6006648.38 583270.23 Top HRZ 6700.00 41.24 256.13 6474.45 6410.95 819.76 -1166.89 4.00 6006644.97 583256.87 MWD+IFR+MS 6800.00 45.03 254.23 6547.41 6483.91 802.23 -1232.96 4.00 6006626.70 583191.00 MWD+IFR+MS 6851.97 47.01 253.35 6583.50 6520.00 791.79 -1268.87 4.00 6006615.85 583155.22 Top Kalubik/Ba 6900.00 48.84 252.57 6615.68 6552.18 781.34 -1302.95 4.00 6006605.02 583121.26 MWD+IFR+MS 6958.80 51.09 251.69 6653.50 6590.00 767.52 -1345.79 4.00 6006590.72 583078.58 Kalubik gamma 7000.00 52.68 251.10 6678.93 6615.43 757.18 -1376.51 4.00 6006580.03 583047.98 MWD+IFR+MS 7100.00 56.53 249.77 6736.85 6673.35 729.86 -1453.30 4.00 6006551.85 582971.52 MWD+IFR+MS 7198.67 60.34 248.57 6788.50 6725.00 699.95 -1531.85 4.00 6006521.05 582893.32 MPK-09 Fault2 7200.00 60.39 248.55 6789.16 6725.66 699.53 -1532.92 4.00 6006520.62 582892.25 MWD+IFR+MS 7219.13 61.13 248.33 6798.50 6735.00 693.40 -1548.44 4.00 6006514.31 582876.80 Top Kuparuk D 7239.05 61.90 248.10 6808.00 6744.50 686.90 -1564.70 4.00 6006507.63 582860.62 MWD+IFR+MS 7300.00 64.32 248.43 6835.57 6772.07 666.77 -1615.19 4.00 6006486.94 582810.36 MWD+IFR+MS 7400.00 68.29 248.95 6875.74 6812.24 633.51 -1700.49 4.00 6006452.71 582725.46 MWD+IFR+MS 7421.62 69.15 249.06 6883.59 6820.09 626.29 -1719.30 4.00 6006445.28 582706.73 End Dir : 7421 7500.00 69.15 249.06 6911.49 6847.99 600.12 -1787.71 0.00 6006418.34 582638.63 MWD+IFR+MS 7600.00 69.15 249.06 6947.08 6883.58 566.72 -1874.99 0.00 6006383.96 582551.74 MWD+IFR+MS 7632.10 69.15 249.06 6958.50 6895.00 556.00 -1903.00 0.00 6006372.92 582523.86 MPK-09 T1 7700.00 69.15 249.06 6982.67 6919.17 533.32 -1962.27 0.00 6006349.57 582464.85 MWD+IFR+MS 7800.00 69.15 249.06 7018.26 6954.76 499.92 -2049.55 0.00 6006315.19 582377.97 MWD+IFR+MS 7811.88 69.15 249.06 7022.49 6958.99 495.95 -2059.92 0.00 6006311.11 582367.64 Start Dir 4/100 7829.01 69.76 248.73 7028.50 6965.00 490.17 -2074.88 4.00 6006305.16 582352.74 Top Kuparuk C 7843.00 70.26 248.46 7033.28 6969.78 485.38 -2087.12 4.00 6006300.23 582340.56 7" 7843.65 70.28 248.44 7033.50 6970.00 485.15 -2087.69 4.00 6006300.00 582340.00 MPK-09 T2 7858.65 70.28 248.44 7038.56 6975.06 479.96 -2100.82 0.00 6006294.66 582326.93 Start Dir 12/10 7900.00 75.23 247.98 7050.82 6987.32 465.31 -2137.48 12.00 6006279.59 582290.44 MWD+IFR+MS 8000.00 87.18 246.94 7066.08 7002.58 427.49 -2228.59 12.00 6006240.75 582199.78 MWD+IFR+MS 8050.02 93.16 246.43 7065.93 7002.43 407.70 -2274.51 12.00 6006220.44 582154.09 End Dir : 8050 8066.89 93.16 246.43 7065.00 7001.50 400.97 -2289.94 0.00 6006213.54 582138.73 Start Dir 7/1 00 8098.69 92.25 244.40 7063.50 7000.00 387.75 -2318.83 7.00 6006200.00 582110.00 MPK-09 T3 8100.00 92.28 244.49 7063.45 6999.95 387.19 -2320.00 7.00 6006199.42 582108.83 MWD+IFR+MS 8121.34 92.78 245.90 7062.51 6999.01 378.24 -2339.36 7.00 6006190.25 582089.58 End Dir : 8121 8200.00 92.78 245.90 7058.70 6995.20 346.16 -2411.07 0.00 6006157.36 582018.24 MWD+IFR+MS 8284.07 92.78 245.90 7054.62 6991.12 311.87 -2487.72 0.00 6006122.21 581941.99 Start Dir 6/100 8300.00 91.82 245.93 7053.98 6990.48 305.37 -2502.25 6.00 6006115.55 581927.53 MWD+IFR+MS 8330.39 90.00 246.00 7053.50 6990.00 293.00 -2530.00 6.00 6006102.87 581899.93 MPK-09 T4 8360.70 88.55 247.09 7053.88 6990.38 280.93 -2557.80 6.00 6006090.49 581872.27 End Dir : 8360 8400.00 88.55 247.09 7054.88 6991.38 265.64 -2594.00 0.00 6006074.79 581836.25 MWD+IFR+MS 8500.00 88.55 247.09 7057.42 6993.92 226.73 -2686.08 0.00 6006034.85 581744.62 MWD+IFR+MS . . Sperry-Sun BP Planning Report 8600.00 88.55 247.09 7059.95 6996.45 187.82 -2778.17 0.00 6005994.90 581652.99 MWD+IFR+MS 8700.00 88.55 247.09 7062.49 6998.99 148.91 -2870.25 0.00 6005954.95 581561.36 MWD+IFR+MS 8800.00 88.55 247.09 7065.03 7001.53 110.00 -2962.33 0.00 6005915.01 581469.73 MWD+IFR+MS 8900.00 88.55 247.09 7067.56 7004.06 71.09 -3054.42 0.00 6005875.06 581378.10 MWD+IFR+MS 9000.00 88.55 247.09 7070.10 7006.60 32.18 -3146.50 0.00 6005835.11 581286.47 MWD+IFR+MS 9100.00 88.55 247.09 7072.63 7009.13 -6.73 -3238.59 0.00 6005795.17 581194.84 MWD+IFR+MS 9134.00 88.55 247.09 7073.50 7010.00 -19.96 -3269.90 0.00 6005781.59 581163.69 41/2" 9134.11 88.55 247.09 7073.50 7010.00 -20.01 -3270.00 0.00 6005781.54 581163.59 MPK-09 T5 Name +N/-S PlanMPK..()9 11085.19 80 75 38 13 13 38 WELL DHAILS ANTI-COLLISION SETTINGS COMPANY DETAILS +E/-W Northing 6005838.54 Basting 584432.85 latitude Longitude Slot 70"25'33.172N 149"18'43.045W N/A BP Amoco Interpolation Method:MD Depth Range From: 34.30 Maximwn Range: 1109.98 Interval: 25.00 To: 9134.1I Reference: Plan: MPK-09 WP05 961.60 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptica1+Casing Warning Method: Rules Based 5 From Colour 34 500 1000 1500 2000 2500 3000 4000 5000 6000 8000 10000 12000 (}14000 'f65000 o o o o o o 5 o SURVEY PROCìRAM Depth Fm Depth To SurveyIPIan 34.30 1000.00 Planned: MPK..()9 WP05 V62 1000.00 9134.11 Planned: MPK-09 WP05 V62 ToMD 500 1000 1500 2000 2500 3000 4000 5000 6000 8000 10000 12000 14000 165000 o o o o o o 90 Tool CB-GYRO-SS MWD+IFR+MS WELLPATHDETAlLS Plan MPK-09 Rig: Ref. Datum: 29.2+34.3 63.50ft V.Section Origin Origin ~~fVD ^"''' +N/-S +E/-W 269.65° 0.00 0.00 34.30 LEGEND CASCADE-IA (CASCADE-I A), Major Risk MPK-02 (MPK"()2), . . MPK..()5 (MPK..()5), MPK-06 (MPK-06), MPK-13 (MPK-13), MPK-17 (MPK-I7), MPK-18A (MPK-18A). Major Risk MPK-18 (MPK-18), Major Risk MPK-21 (MPK-21), Major Risk MPK-21 (MPK-2IA), Major Risk MPK-21 (MPK-2IAPBI), Major Risk MPK-25 (MPK-25), Major Risk MPK-30 (MPK-30), Major Risk. MPK-33 (MPK-33), Major Risk. MPK-34 (MPK-34), Major Risk MPK-37 (MPK-37), Major Risk MPK-38 (MPK-38), Major Risk. MPK-38 (Plan MPK-38A), Major Risk MPK-43A (MPK-43A), Major Risk MPK-43 (MPK-43), Major Risk Plan MPK-22 (Plan MPK-22 old), Major Risk Plan MPK-22 (Plan MPK-22), Major Risk. Plan MPK-09 ~ MPK..()9 WP05 SECTION DETAILS Soc MD In< Azi TVD +N/-S +EI-W DLog TFace VS<o Target 1 34.30 0.00 0.00 34.30 000 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 600.00 3.00 305.00 599.86 4.50 -6.43 100 305.00 6.40 4 750.00 6.00 305.00 749.38 11.25 -16.07 2.00 0.00 16.00 , 990.00 13.20 305.00 985.&7 34.20 -48.84 3.00 0.00 48.63 6 1928.94 13.20 305.00 1900.00 157.17 -224.47 0.00 0.00 223.50 7 2093.57 13.02 319.53 2060.38 182.07 -251.91 2.00 100.13 250.79 8 5776.04 13.02 319.53 5648.14 813.37 -790.50 0.00 0.00 785.51 . 7239.05 61.90 248.10 6808.00 686.90 -1564.70 4.00 -78.67 1560.47 10 7421.62 69.15 249.06 6883.59 626.29 -1719.30 4.00 7.07 1715.44 11 7632.10 69.15 249.06 6958.50 556.00 -1903.00 0.00 0.00 1899.56 MPK-09TI 12 7811.88 69.15 249.06 7022.49 495.95 -2059.92 0.00 0.00 2056.85 13 7843.65 70.28 248.44 7033.50 485.15 -20&7.69 4.00 -27.11 2084.68 MPK-09T2 14 7858.65 70.28 248.44 7038.56 479.96 -2100.82 0.00 0.00 2097.85 " 8050.02 93.16 246.43 7065.93 407.70 ·2274.51 12.00 -5.15 2271.97 16 8066.89 93.16 246.43 7065.00 400.97 -2289.94 0.00 0.00 2287.44 17 8098.69 92.25 244.40 7063.50 387.75 -2318.83 7.00 -114.15 2316.41 MPK-09T3 18 8121.34 92.78 245.90 7062.51 378.24 -2339.36 7.00 70.55 2337.00 " 8284.07 92.78 245.90 7054.62 311.87 -2487.72 0.00 0.00 2485.77 20 8330.39 90.00 24600 7053.50 293.00 -2530.00 6.00 177.87 2528.16 MPK-09T4 21 8360.70 88.55 247.09 7053.88 280.93 -2557.80 6.00 143.05 2556.04 22 9134.11 88.55 247.09 7073.50 -20.01 -3270.00 0.00 0.00 3270.06 MPK-09T5 3 . . Sperry-Sun Anticollision Report GRJ 7" 41/2" MPK-09 WP05 Date Composed: Version: Tied-to: 3/2/2004 62 From Well Ref. Point Yes Summary M pt Cascade CASCADE-1A CASCADE-1A V1 7767.93 8525.00 216.32 195.13 21.19 Pass: Major Risk M Pt K Pad MPK-02 MPK-02 V1 672.76 675.00 125.59 13.19 112.41 Pass: Major Risk M Pt K Pad MPK-05 MPK-05 V1 800.70 800.00 23.74 13.99 9.74 Pass: Major Risk M Pt K Pad MPK-06 MPK-06 V1 324.83 325.00 116.27 6.77 109.50 Pass: Major Risk MPtKPad MPK-13 MPK-13 V5 349.75 350.00 32.49 6.76 25.74 Pass: Major Risk MPtKPad MPK-17 MPK-17 V1 423.86 425.00 60.83 8.30 52.54 Pass: Major Risk MPtKPad MPK-18A MPK-18A V1 349.03 350.00 127.81 7.32 120.49 Pass: Major Risk MPtKPad MPK-18 MPK-18 V24 349.03 350.00 127.81 7.32 120.49 Pass: Major Risk MPtKPad MPK-21 MPK-21 V3 546.74 550.00 91.91 10.14 81.77 Pass: Major Risk MPtKPad MPK-21 MPK-21A V9 546.74 550.00 91.91 10.25 81.66 Pass: Major Risk MPtKPad MPK-21 MPK-21APB1 V3 546.74 550.00 91.91 10.25 81.66 Pass: Major Risk MPtKPad MPK-25 MPK-25 V2 Plan: Undefi 471.96 475.00 118.87 9.07 109.81 Pass: Major Risk MPtKPad MPK-30 MPK-30 V4 445.27 450.00 184.99 8.85 176.14 Pass: Major Risk MPtKPad MPK-33 MPK-33 V1 348.69 350.00 182.01 7.12 174.90 Pass: Major Risk MPtKPad MPK-34 MPK-34 V3 324.11 325.00 211.17 6.35 204.81 Pass: Major Risk MPtKPad MPK-37 MPK-37 V1 348.48 350.00 211.47 7.12 204.36 Pass: Major Risk MPtKPad MPK-38 MPK-38 V1 323.99 325.00 239.47 6.55 232.92 Pass: Major Risk MPtKPad MPK-38 Plan MPK-38A V5 Plan: 323.99 325.00 239.47 6.50 232.97 Pass: Major Risk MPtKPad MPK-43A MPK-43A V3 444.58 450.00 256.74 8.17 248.57 Pass: Major Risk MPtKPad MPK-43 MPK-43 V1 444.58 450.00 256.74 8.17 248.57 Pass: Major Risk MPtKPad Plan MPK-22 Plan MPK-22 old VO Pia 519.66 525.00 144.56 11.44 133.12 Pass: Major Risk M Pt K Pad Plan MPK-22 Plan MPK-22 V2 Plan: M 519.66 525.00 144.56 11.59 132.97 Pass: Major Risk Site: M Pt Cascade Well: CASCADE-1A Rule Assigned: Major Risk Wellpath: CASCADE-1A V1 Inter-Site Error: 0.00 ft 5064.87 4955.26 5625.00 5191.53 7.22 19.86 120.41 160.88 7.000 1109.77 81.49 1028.29 Pass 5083.84 4973.74 5650.00 5208.34 7.25 20.16 120.99 161.46 7.000 1098.05 82.50 1015.55 Pass 5102.72 4992.14 5675.00 5225.03 7.29 20.47 121.59 162.06 7.000 1086.32 83.55 1002.78 Pass 5121.51 5010.44 5700.00 5241.61 7.32 20.78 122.21 162.68 7.000 1074.58 84.61 989.97 Pass 5140.23 5028.68 5725.00 5258.10 7.35 21.09 122.84 163.31 7.000 1062.89 85.71 977.18 Pass 5158.90 5046.87 5750.00 5274.53 7.38 21.40 123.48 163.95 7.000 1051.28 86.83 964.45 Pass 5177.51 5065.00 5775.00 5290.91 7.41 21.71 124.14 164.61 7.000 1039.77 87.99 951.78 Pass 5196.08 5083.09 5800.00 5307.23 7.44 22.02 124.82 165.29 7.000 1028.35 89.17 939.19 Pass 5214.61 5101.15 5825.00 5323.52 7.47 22.33 125.52 165.99 7.000 1017.06 90.38 926.68 Pass 5233.11 5119.17 5850.00 5339.76 7.50 22.64 126.23 166.70 7.000 1005.88 91.62 914.26 Pass 5251.58 5137.17 5875.00 5355.97 7.53 22.95 126.96 167.43 7.000 994.84 92.89 901.95 Pass 5270.03 5155.14 5900.00 5372.16 7.57 23.25 127.70 168.17 7.000 983.94 94.17 889.76 Pass 5288.48 5173.12 5925.00 5388.33 7.60 23.54 128.46 168.93 7.000 973.14 95.45 877.69 Pass 5306.95 5191.11 5950.00 5404.50 7.63 23.83 129.23 169.70 7.000 962.45 96.76 865.69 Pass I , " ----------------------- I I I I I I I ~ I I III I I I I K-P AD , I I I I I I I I -IIIIj- I I I I I I I I I I I I 1 0 0 2 I I K-~t 0 4 I I 0 6 I I f ~-1O I I K-9 I I 11 12 I I 13 0 0 14 I I 15 0 0 16 I I 17 . . 18 I I 19 0 0 20 I I 21 0 0 22 I I 23 0 0 24 I I 25 . 0 26 I I 27 0 0 28 I I 29 0 0 30 I I 31 0 0 32 I I 33 0 0 34 I I 35 0 0 .36 I I 37 0 . .38 I I 39 0 0 40 I I 41 0 0 42 I I 4.3 0 0 44 I I I I I I I I I I I I I I I I I I I I ---------------------------- I LOCATED WITHIN PROTRACTED SEC. 3, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA VICINITY MAP N.T.S. NOTEs.. 1. DATE OF SURVEY: MARCH 21-25, 1996. 2. REFERENCE FIELD BOOK: MP 96-04 (pgs.13-21). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.99990812 5. HORIZONTAL CONTROL IS BASED ON USGS. MONUMENT "FOX" AND MPU MONUMENT C-1 6. ELEVATIONS ARE BP MPU M.S.L. DATUM. 7. VERTICAL CONTROL IS BASED ON BRAIDEN CAP AT WELL C-1, ELEVATION = 16.86', ESTABLISHED BY BOMHOFF & ASSOCIATES. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 24, 1996. WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINA TES COORDINATES POSITION(DMS) POSI TION(D.DD) ELEVATION OFFSETS K-5 y= 6,005,865.94 N. 9,969.79 70'25' 33. 443" 70.4259564' 29." 3,731' FSL LEGEND x= 584,422.05 E. 4999.99 149'18' 43.353" 149.3120425' 2,133' FEL -+- AS-BUILT CONDUCTOR K-9 Y= 6,005,838.54 N. 9,940.34 70'25'33.172" 70.4258811" 29.2' 3,704' FSL . EXISTING WELL X= 584,432.85 E. 4999.55 14918'43.045" 149.3119569' 2,123' FEL K-l0 Y= 6,005.880.17 N. 9,939.93 70'25'33.570" 3,744' FSL o FUTURE PROPOSED WELL 70.4259917" 29.3' x= 584,535.02 E. 5,109.88 149'18'40.034" 149.3111206' 2.020' FEL DRAIfj, STOll . CHECKED: AWSON BP EXPLORATION DATE: 4/2/96 .. .~ WPUKAB MILNE PO!NT UNIT K PAD SHEET: JQØ "'" AS BWl T WEll CONDUCTORS 1 of 1 4 RN ..- ". &.- 1UI'ttWII 1'-100' M1LS K-5 K-9 & K-1D NO. at( --,..- .... <::> <::> <::> -6 "I""'" q <D ! 149 22 00 \II 14'~ 00 Vi ! 149 18 00 W MPU K..09 Proposed 1-0il 2050140 SFD SONDRAD STEWMAN BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7~5 ANCHORAGE,AK .99519-6612 89-6/1252 1 20 DATE D~-D I-or::; . 6~6:~cirE .Anc~C~· .. . ... ........... ... l$j(~·fD~ ~~~~~foAú~x&õ. . lJOLLAR$ First National Bank . ka Anchorage,AK..99501..... ... 6~ MEM;¥Y\? 'A ~ e .. 1J:.X:Y-- _: 1.252000£;01:1:11:1 ¡'l.lllb 2 2711. ¡'5bl.lI· 0 I. 20 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME IJ?r!J k- 09 2£;Ç-O// PTD# v' Development Service Exploration Stratigraphic CHECKWHAT ADD-ONS ~'CLUE", APPLJÈS (OPTIONS) MULTI Tbe permit is for a new w eJl bore segment of LATERAL existing well . Permit No, APJ No. . (If API number Production. sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. .' Pn..OT HOLE )n accordance with 20 AAC 25.005(1), aU (PH) records, data and logs acquired for tbe piJot bole must be dearly differentiated "in both name (name OD permit plus PH) " and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.,OSS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacing ,~:Jception that may occur. : DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ·tban 30' .' sample intervals from below tbe permafrost or from where samples are fint caught and ] 0' sample hiter:vals througb target zones. .' 00 Date: :(3/S Geologic Commissioner: Engineering Commissioner: Date Appr SFD Date 2/2/2005 35 36 37 38 39 Se<lbedconditioo survey Conta.ct namelphonefor oveJl~res_sure _zones _SeismicaJl<llysjs of shaJlow gaszooes_ wee~ly progress reports [exploratory _only] if oft -s ho re) No_ Y_es No NA NA MPU K~38, less.tban_1mileaway, ,.. ";:..... in 200 !\Iormal preSSLJre to top KLJparUk reservoir; the Jes_ervoir itself will. drilled with.8.6 9.. tHYdrates expected frrom 2200' to 2900' - ppgmu.d beuOderpresSLJred (7.8.ppgEMy\{)~ wilJ be TVDss. Geology Appr TEM Date 2/2/2005 8 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Permit Üata.preseoted on pote.ntial c.ao Þe issued w/o hydrogen sulfide meaSUres wells within AOB yerified (fots_ervjce we only) .lest to .Choke manjfoll !S w/API RF'-53 Work will OCCUI Is presence_ of ! '..'" ",,~ Mecbanicalcoodjt[on of U"~ n.~~ prob_able B.OPEpress Adequ¡; ,erve pit Ifa. reo: (for abandonment beeo approved Adequ.<i ..~!'"~''' ,<~..-...I Ifdivert ~q.uired, does _Drilliog ",wJ" BOPEs, do _operatjonsbutdown {pu.l (May 84) they meet reguJation ". ':d. program schem<ltic.& equip meet regulations. ist.adequate -,N°""'...ro <"on~'atjo_n .proposed It CMT will COYer all .C.âsing designs <ld.ettLJate for CoT, B&. permaftost koownproductiye borizon_s .CMT v_ol adequate to known USDWs _CMT vol adequ.ateJo çirc.ulate_on_cond_uçtor. ie-in long string to surf çsg. & surfcsg Yes NA Yes No No_ Yes Yes NA Yes Yes Yes Y_es Yes Yes Yes No NA .me_asuJed_ 21 pp~ U?" 20 ppm H2S has been reported in MPC wells. MLJd shoLJld preçlude.H2_Son rig Ri9.has Sensors <Ind. alarms. ratiog appropriate; psig in.comments) MASf> çalculatedat 224~ psi, 30QOpsiBQF' test.proposed.. BHf> expected less.tban8.35.EMW, 1.8 EMW.io Kup.aruk. Plaoned_mudweigbt9..Q PP9.+ io KLJparu.k._ plot iocJu.ded Closeappro<lcheS identifieda.nd gyros likely f>roJ5imitj' anj:llysis Performed, Jrayeling Cj'lioder Big isequippedwitb steelpits No reserv'e.pjtplanoe_d All waste toapprovedCJass I weiJs~ All Slotted hydrocarbon.zooes_are ioer planoe_djn inteoded to be. c.oyered.. Kuparuk. Allaquifers exempted ~O cm 47. t02(b){3). Engineering Appr SFD 2/2/2005 Date Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 7 Cooductor .Surface stringprov[ded .c<lsing protec.ts all ACMP findjngof Con.sistencyh.as been issued_ for. tbis project # (putlO# .AJI welJs.within .1 14. mile.area_of reyiew ideotified (For servjc.ewellonly). . . Pre-produced injector; duration of pre-Produc:;tioo less th<ln. 3 months. (For service well bas. appropriate. bond in.forçe Permit c.an be issued without conservation order Permit c.ao be issued witbout <ldministrative.approval Can permit 15-day wait Well located within area <lndstr<ltaautborized by. be approved before Perrr .Leasl .U.niq! Well Well _Wel'-,.....~...~" ....y..'<. _U,~,w,.~~ tber _S_ufficient _açreag.e _ayailable ,., u~ ....,_, Ifdevi<lted iocJuded _Oper_ator .Operator only affected party js. weJlbore plat 1^,..~4.c...t n"....nor ....i~+.."...,..1I::I! located proper Field & Pool INC MILNE POINT, KUPARUK RIVER OIL - 525100 -- lojectioo Order in c_ommeots). wells :" .Jr""ng unit from drilling unit b_ound_ary_ nitial ClasslTy,E: Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA -.- onJy) (For Oil F'o.ol, n.orthern bounda_f)' of Jease ADL 37.5133 is 1400'aw.ay (MF'U K-H) 10_9'1' .from_ !\Iearest welL Kuparuk River governed by Con_servatioo Ord_er !\Io. 432C _DEV Well Name: MILNE PT UNIT KR K-09 PEND GeoArea B9D Unit lt32.8 Program DEV__ On/Off Shore Qn Well Annular bore seg Disposal D D . . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. aos-- ()/<{ Sperry-Sun Dr~ng Services LIS Scan Utility . $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 07 15:19:59 2006 Reel Header Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/07 Origin.................. .STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name. ......UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPK-09 500292324700 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 07-APR-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003591176 R. FRENCH D. GREEN MWD RUN 2 MW0003591176 C.A. DEMOSKI D. GREEN MWD RUN 3 MW0003591176 J. BOBBITT E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003591176 J. BOBBITT E. VAUGHN MWD RUN 5 MW0003591176 J. BOBBITT E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3 12N 11E 3704 2123 MSL 0) 63.20 29.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS {)D5'-6/<-/ 1t 14104 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 12.250 8.750 6.125 SIZE (IN) 20.000 9.625 7.000 DEPTH (FT) 115.0 5173.0 7908.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND AT-BIT INCLINATION (ABI) 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL RECEIVED FROM D. DORTCH (SAICjBP) ON 21 MARCH 2006, QUOTING AUTHORIZATION FROM MIKIE WEEKS (BP GEOSCIENTIST) . 6. MWD RUNS 1 - 5 REPRESENT WELL MPK-09 WITH API#: 50-029-23247-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9059'MDj7095'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.9-9.1 PPG MUD SALINITY: 20000 PPM CHLORIDES FORMATION WATER SALINITY: 20000 PPM CHLORIDES FLUID DENSITY: 1.0 Gjcc MATRIX DENSITY: 2.65 GjCC LITHOLOGY: $ sA TONE . File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..06/04/07 Maximum Physical Record. .65535 File Type......... ... ....LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPX RPM RPS FET NPHI NCNT FCNT RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 100.0 130.0 5150.0 5150.0 5150.0 5150.0 5150.0 7834.5 7834.5 7834.5 7848.5 7848.5 7848.5 STOP DEPTH 9009.0 9058.5 9016.0 9016.0 9016.0 9016.0 9016.0 8972 .5 8972.5 8972.5 8934.0 8934.0 8934.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 100.0 4756.0 MWD 2 4756.0 5183.0 MWD 3 5183.0 6630.0 MWD 4 6630.0 7918.5 MWD 5 7918.5 9058.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...... .........0 Data Specification Block Type... ..0 Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing......... .... ....... .60 .1IN Max frames per record............ .Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT FCNT MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 CNTS 4 1 68 4 2 NCNT MWD CNTS . 1 68 8 3 . RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 100 9058.5 4579.25 17918 100 9058.5 FCNT MWD CNTS 160 1078 483.855 2277 7834.5 8972.5 NCNT MWD CNTS 15997 36683 25130.7 2277 7834.5 8972.5 RHOB MWD G/CM 0.15 3.149 2.39288 2172 7848.5 8934 DRHO MWD G/CM -3.375 0.653 -0.015994 2172 7848.5 8934 RPD MWD OHMM 0.57 2000 32.8236 7733 5150 9016 RPM MWD OHMM 0.33 2000 17.5675 7733 5150 9016 RPS MWD OHMM 0.47 2000 6.57047 7733 5150 9016 RPX MWD OHMM 0.39 1681.79 5.59243 7733 5150 9016 FET MWD HOUR 0.24 296.13 4.54065 7733 5150 9016 GR MWD API 19.25 422.61 88.912 17819 100 9009 PEF MWD BARN 0.37 13.14 3.37473 2172 7848.5 8934 ROP MWD FT/H 0.05 654.87 144.718 17858 130 9058.5 NPHI MWD PU-S 15.81 47.97 26.0195 2277 7834.5 8972.5 First Reading For Entire File...... ....100 Last Reading For Entire File.......... .9058.5 File Trailer Service name........ .....STSLIB.001 Service Sub Level Name. . . Version Number.. ........ .1.0.0 Date of Generation..... ..06/04/07 Maximum Physical Record. .65535 File Type..... .......... .LO Next File Name.... ..... ..STSLIB.002 Physical EOF File Header Service name. .... ....... .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .06/04/07 Maximum Physical Record. .65535 File Type........ ...... ..LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 2 header data for each bit run in separate files. 1 .5000 VENDOR TOOL CODE GR ROP $ START .TH 100.0 130.0 STOP DEPTH 4712.0 4756.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ............ ...0 Data Specification Block Type... ..0 Logging Direction. .... .......... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value........ ...... ...... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD010 ROP MWD010 Units FT API FT/H Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 16-MAR-05 Insite 66.37 Memory 4756.0 221.0 4756.0 .7 14.3 TOOL NUMBER 120557 12.250 115.0 SPUD MUD 10.00 168.0 8.0 400 18.0 .000 .000 .000 .000 .0 107.6 .0 .0 Offset o 4 8 Channel 1 2 3 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 100 4756 2428 9313 100 4756 GR MWD010 API 19.25 128.3 68.0346 9225 100 4712 ROP MWD010 FT/H 0.24 654.87 195.145 9253 130 4756 First Reading For Entire File......... .100 Last Reading For Entire File..... ..... .4756 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .06/04/07 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name....... ......STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation. ......06/04/07 Maximum Physical Record. .65535 File Type. .... .......... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 4712.5 4756.5 STOP DEPTH 5139.0 5183.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-MAR-05 Insite 66.37 Memory 5183.0 4756.0 5183.0 12.4 13.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ...... ....... ....0 Data Specification Block Type. ....0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.. ........ .Feet Data Reference Point............ ..Undefined Frame Spacing. ................... .60 .1IN Max frames per record. ........... .Undefined Absent value.......... .......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD020 ROP MWD020 Units FT API FT/H Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 12.250 115.0 SPUD MUD 10.80 80.0 8.0 500 8.6 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 107.6 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4712.5 5183 4947.75 942 4712.5 5183 GR MWD020 API 42.99 138.98 92.1833 854 4712.5 5139 ROP MWD020 FT/H 0.07 289.29 92 .5077 854 4756.5 5183 First Reading For Entire File......... .4712.5 Last Reading For Entire File.......... .5183 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .06/04/07 Maximum Physical Record. .65535 File Type........... .....LO Next File Name.......... .STSLIB.004 . Physical EOF File Header Service name. ........... .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......06/04/07 Maximum Physical Record. .65535 File Type... .... ....... ..LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPS RPM RPX ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 5139.5 5150.0 5150.0 5150.0 5150.0 5150.0 5183.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6594.0 6586.5 6586.5 6586.5 6586.5 6586.5 6630.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 30-MAR-05 Insite 66.37 Memory 6630.0 5183.0 6630.0 12.3 29.2 TOOL NUMBER 163686 121079 8.750 5173.0 LSND 9.70 52.0 9.5 600 5.8 2.600 1.600 2.300 2.200 70.0 118.0 70.0 70.0 # . . NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. .... ....... ....Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5139.5 6630 5884.75 2982 5139.5 6630 RPD MWD030 OHMM 0.57 2000 34.7283 2874 5150 6586.5 RPM MWD030 OHMM 0.59 1293.31 5.67593 2874 5150 6586.5 RPS MWD030 OHMM 0.62 2000 5.40161 2874 5150 6586.5 RPX MWD030 OHMM 0.64 1293.39 4.14042 2874 5150 6586.5 FET MWD030 HOUR 0.24 296.13 7.84714 2874 5150 6586.5 GR MWD030 API 35.75 211.58 117.947 2910 5139.5 6594 ROP MWD030 FT/H 1. 43 407.25 115.319 2894 5183.5 6630 First Reading For Entire File........ ..5139.5 Last Reading For Entire File... ........6630 File Trailer Service name.... ........ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/07 Maximum Physical Record..65535 File Type... ............ .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number........ ..~0.0 Date of Generation. ..... .06/04/07 Maximum Physical Record..65535 File Type. '" ........... .LO Previous File Name. ..... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPM RPD RPX GR ROP $ 5 . header data for each bit run in separate files. 4 .5000 START DEPTH 6587.0 6587.0 6587.0 6587.0 6587.0 6594.5 6630.5 STOP DEPTH 7875.5 7875.5 7875.5 7875.5 7875.5 7883.0 7918.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 01-APR-05 Insite 66.37 Memory 7918.0 6630.0 7918.0 32.7 71.3 TOOL NUMBER 163686 121079 8.750 5173.0 LSND 10.10 55.0 8.0 500 4.2 1. 200 .690 1. 500 1. 300 72.0 130.0 72.0 72.0 EWR FREQUENCY (HZ): . . # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............. ... . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value......... ........ .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6587 7918.5 7252.75 2664 6587 7918.5 RPD MWD040 OHMM 1. 28 8.68 3.05071 2578 6587 7875.5 RPM MWD040 OHMM 1.2 8.72 3.05263 2578 6587 7875.5 RPS MWD040 OHMM 1.2 7.42 2.77943 2578 6587 7875.5 RPX MWD040 OHMM 1.19 6.86 2.69801 2578 6587 7875.5 FET MWD040 HOUR 0.44 12.5 1.74325 2578 6587 7875.5 GR MWD040 API 63.74 422.61 145.077 2578 6594.5 7883 ROP MWD040 FT/H 3.85 433.24 60.9217 2577 6630.5 7918.5 First Reading For Entire File......... .6587 Last Reading For Entire File....... ....7918.5 File Trailer Service name....... ......STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..06/04/07 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name... ......... .STSLIB.006 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation... ....06/04/07 Maximum Physical Record..65535 File Type.. .... ........ ..LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI RHOB DRHO PEF RPD RPX RPS FET RPM GR ROP $ . 6 . header data for each bit run in separate files. 5 .5000 START DEPTH 7834.5 7834.5 7834.5 7848.5 7848.5 7848.5 7876.0 7876.0 7876.0 7876.0 7876.0 7883.5 7919.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD $ # STOP DEPTH 8972.5 8972.5 8972.5 8934.0 8934.0 8934.0 9016.0 9016.0 9016.0 9016.0 9016.0 9009.0 9058.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 05-APR-05 Insite 66.37 Memory 9059.0 7918.0 9059.0 70.2 93.9 TOOL NUMBER 87224 10603685 130908 159401 6.125 7908.0 FLO-PRO 9.00 50.0 9.5 20000 6.0 .100 .050 .210 .200 74.0 145.0 72.0 71.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): . . # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing. ................... .60 .1IN Max frames per record.............Undefined Absent value.. .................. ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD050 CNTS 4 1 68 4 2 NCNT MWD050 CNTS 4 1 68 8 3 RHOB MWD050 G/CM 4 1 68 12 4 DRHO MWD050 G/CM 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HOUR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 BARN 4 1 68 44 12 ROP MWD050 FT/H 4 1 68 48 13 NPHI MWD050 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7834.5 9058.5 8446.5 2449 7834.5 9058.5 FCNT MWD050 CNTS 160 1078 483.855 2277 7834.5 8972.5 NCNT MWD050 CNTS 15997 36683 25130.7 2277 7834.5 8972 . 5 RHOB MWD050 G/CM 0.15 3.149 2.39288 2172 7848.5 8934 DRHO MWD050 G/CM -3.375 0.653 -0.015994 2172 7848.5 8934 RPD MWD050 OHMM 2.25 2000 64.0731 2281 7876 9016 RPM MWD050 OHMM 0.33 2000 48.9554 2281 7876 9016 RPS MWD050 OHMM 0.47 1609.24 12.3279 2281 7876 9016 RPX MWD050 OHMM 0.39 1681.79 10.6932 2281 7876 9016 FET MWD050 HOUR 0.26 52.1 3.53619 2281 7876 9016 GR MWD050 API 38.25 104.6 71.3789 2252 7883.5 9009 PEF MWD050 BARN 0.37 13 .14 3.37473 2172 7848.5 8934 ROP MWD050 FT/H 0.05 583.81 91.6516 2280 7919 9058.5 NPHI MWD050 PU-S 15.81 47.97 26.0195 2277 7834.5 8972.5 First Reading For Entire File....... ...7834.5 Last Reading For Entire File....... ... .9058.5 File Trailer Service name. .... ....... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/04/07 Maximum Physical Record..65535 File Type.. ... .......... .LO Next File Name.. ........ .STSLIB.007 . . Physical EOF Tape Trailer Service name.... .........LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name..... .... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ........... ..UNKNOWN Continuation Number. .... .01 Next Reel Name.......... .UNKNOWN Comments........ ...... ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File