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Home My WebLink About208-143Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:208-143 6.API Number:50-029-21952-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028321 Property Designation (Lease Number):10. 8. PBU 18-24B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY Effective Depth MD: 12.6# L-80 11. Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: TRCF4A (locked out) - No SSSV installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8681 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 4622 / 4620 No SSSV Installed Date: Liner 2655 3-1/2"x3-3/16"x2-3/8"8595 -11250 8262 - 8683 8430 , 11200 7500 , 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 28 - 8005 28 - 7734 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 3506 Structural 7740 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SABL-3 9730 - 11180 8727 - 8685 4-1/2"4658 Production 11215 8684 4669 none 2480 7-5/8" 5-1/2" Contact Phone:(907)564-4672 Date: 6820 3476 521010-3/4"Conductor 4790 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 84 20"30 - 114 470 Surface 7977 6890 Intermediate 4233 4658 - 8891 4656 - 8509 493 3-3/16" 8808 - 9311 8444 - 8725 10160 12530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 1490 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 11382 9-29-2021 30 - 114 30 - 3505 6-29-21 By Samantha Carlisle at 9:25 am, Jun 30, 2021 321-321 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.29 18:10:04 -08'00' Bo York X 10-404 BOPE test to 3000 psi. Annular to 2500 psi. DLB06/30/2021MGR02JUL21 DSR-6/30/21 dts 7/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 13:02:29 -08'00' RBDMS HEW 7/7/2021 RWO Procedure WELL: 18-24B PTD: 2120130 Well Name:18-24B API Number:50029219520200 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:09/29/2021 Permit to Drill Number:2120130 First Call Engineer:Dave Bjork 907-564-4672 (O) 907-440-0331 M Second Call Engineer:Ryan Thompson 907-564-5280 (O) 907-301-1240 M Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE | SBHPS offset 18-14C 12/1/19 Max. Anticipated Surface Pressure:2,470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:300 psi (Taken on 06/21/21) Min ID:1.92” Liner ID @ 8,606’ to TD Max Angle:95 Deg @ 9,523’ Brief Well Summary: 18-24b is a Z1A lateral producer that was CTD sidetracked in 2008 and stayed online until 2017. A caliper indicated 3 potential holes. It is not worth attempting a patch. We will now pursue a RWO to replace the L-80 tubing. Notes Regarding Wellbore Condition: x The 7” production casing passed CMIT-TxIA to 3,100 psi on 04/25/2021. x Ivishak perfs will remain hydraulically isolated throughout RWO by tested 2.31 PX plug and packer combo at 4,633’ and 4,622’. Objective: Pull the existing 4 ½” L80 tubing out of the well and replace with 3-1/2” 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Pre Sundry Work: DHD 1. CMIT-TxIA to 3,000-psi (Done 4/25/21) Repeat if older than 6 months. 2. Cycle LDS’s (Done 3/20/21) 3. PPPOT-T (Done 3/20/21) Repeat if older than 6 months. 4. PPPOT-IC (Failed 3/20/21) Slickline 5. Set 2.31 PX plug in testable seal assembly at 4,633’. 6. Pull DMY from GLM at 4,522’. Sundry Procedure (Approval required to proceed): Eline 7. Cut tubing @ ~ 4,582’ 8. Circulate well to 8.4 ppg 1% KCL or equivalent w/ diesel FP on T & IA Valve Shop/Ops 9. Bleed WHP’s to 0 psi. Bleed control line to 0 psi. 10. Set and test TWC 11. Nipple Down Tree and tubing head adapter. Inspect lift threads. 12. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and flow cross. RWO RWO Procedure WELL: 18-24B PTD: 2120130 13. MIRU Thunderbird #1 Rig. 14. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-½” VBR’s with 4-½” and 3-½” test joints. Test the Annular preventer with a 3-½” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Pull TWC. 16. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~53K 17. Pull 4-½” tubing to floor, circulate bottoms up. LD all tubing. 18. Replace IC packoff (through the stack) and test void to 3,500-psi 19. Run 3-½” 13Cr tubing with stacker packer completion as detailed on proposed schematic. 20. Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 21. Drop ball and rod and set packer with 3,500psi pump pressure. 22. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 23. Shear valve in upper GLM. 24. Set TWC 25. Rig down Thunderbird #1. Valve Shop/Ops 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Slickline 1. Pull Ball and rod and RHC profile, pull PX plug from liner top packer. 2. Set GLV’s per GL Engineer 3. RDMO & pop well. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO Procedure WELL: 18-24B PTD: 2120130 Wellbore Schematic RWO Procedure WELL: 18-24B PTD: 2120130 Proposed Wellbore Schematic RWO Procedure WELL: 18-24B PTD: 2120130 RWO BOPs RWO Procedure WELL: 18-24B PTD: 2120130 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 2-�°tt2.. WELL LOG TRANSMITTAL#904119421 To: Alaska Oil and Gas Conservation Comm. November 21, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA��LQQGGED � i1�/201�' Anchorage, Alaska 99501 iv1 K BENDER DEC 222017 RE: Leak Detect Log: 18-24B Run Date: 6/21/2017 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 18-24B Digital Log Image files _ 1 CD Rom 50-029-21952-02 Leak Detection Log 1 Color Log 50-029-21952-02 SCANNED . .__ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS ANC @halliburton.com Date: Signed: M/a-12-a-n-4) 6..eoceeet a e Pro ct Well History File Cov~age Im g ~ , XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ _ ~ ~-.3 Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY; Maria Project Proofing gY; Maria Scanning Preparation gY; Maria Production Scanning o R„~a~~,.~~, iiiiiaiuuiim OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ P iiuauuiii ~P + __L_~! =TOTAL PAGES (Count does not include cover sheet) , /~ I /s/ v Stage 1 Page Count from Scanned File: ,'' ~ (Count does include cover eet) NO Page Count Matches Number in Scanning Pre aration: YES Date: 3 ~ ~ / `~ /s/ gY: Maria NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: /s/ IIIIIIIIIIIII III III Scanning is complete at this point unless rescanning is required. IIIIIIIIIIIIIIIIIII ReScanned gY; Maria Date: Comments about this file: .,~„~a iiiuimuuiNm DIGIT L DATA iskettes, No. 1 ^ Other, No/Type: Date: p~, Date: l x30= Date: a~a„~~e~,ed uiimiuuuiiu 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3124/2010 Permit to Drill 2081430 Well Name/No. PRUDHOE BAY UNIT 18-24B Operator BP EXPLORATION (ALASKIy INC MD 11382 TVD 8681 Completion Date 10/19/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-21952-02-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES, GR / CCL /CNL Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / ly a IYICUir ffllL ~~uu~uc~ Name .a..a~c mc..~ca ~w .iw~a .awM ...~ ~~c..c..cv ..........`.....~ D D Asc Directional Survey 9297 11382 Open 11/10/2008 ~ I p ' Directional Survey 9297 11382 Open 11/10/2008 ~ D C Lis 17428 ~IVeutron 8282 11206 Open 1/14/2009 LIS Veri, GR, CNT og Neutron 2 Blu 8280 11197 Case 1/14/2009 Mem CNL, Lee, CCI, GR 18-Oct-2008 ,. C Las 17469 Induction/Resistivity 9130 11381 Open RPM, GR, RAD, RAM, ROP, RPD i pt LIS Verification 9129 11382 Open 1/20/2009 LIS Veri, GR, ROP, RAD, / ~ RPD, RPS 4zD C Lis 17483VInduction/Resistivity 9129 11382 Open 1/20/2009 LIS Veri, GR, ROP, RAD, RPD, RPS Log Induction/Resistivity 25 Col 9311 11382 Open 1/26/2009 MD MPR, GR 14-Oct-2008 .Log Induction/Resistivity 5 Col 9311 11382 Open 1/26/2009 TVD MPR, GR 14-Oct-2008 ~og Gamma Ray 25 Col 9311 11382 Open 1/26/2009 MD GR 14-Oct-2008 ~og See Notes 5 Col 9120 11380 Open 1/26/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments •. DATA SUBMITTAL COMPLIANCE REPORT 3/24/2010 Permit to Drill 2081430 Well Name/No. PRUDHOE BAY UNIT 18-24B Operator BP EXPLORATION (ALASFCa INC API No. 50-029-21952-02-00 MD 11382 TVD 8681 Completion Date 10/19/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? N Chips Received? Y-fiC""~- Formation Tops ~'N Analysis Y-f-N-~ Received? - - _ -- -- -- __ - - _ - -_ -- ---- -- - Comments: Compliance Reviewed By: _ Date: _ 4 :.,~ .:t :~,. //tom BAKER HVGMES COMPANY WELL NAME FIELD - ~ .,_. ...:.. Baker Atlas PRINT DISTRIBUTION LIST BP EXYLURA'1'IUN (ALASKA) 1NC CUUN'1'Y NUR'I H SLUPIr BURUUGH 18-24B STATE ALASKA PRUDHOE BAY UNIT DATE 1/19/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO # 2246794 Copies of Copies Digital Copies of Copies Digital Each Log of Film Da[a Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. TTH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: ii ~ ~~~~ ~b ~--~-;':5 l _- ~-- Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 18-24B Contains the following: ~ ~ f 1 LDWG Compact Disc ~~~ (Includes Graphic Image files) 1 LDWG lister summary ~,~ 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow} LAC Job#: 2246794 Sent by: Terri Tuminello ,,' :~ -_~ 3 - Date: Ol/1 i~ Received by: ~~ % ~~~''' Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING°`' RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 `~ IiYTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 01 /08/09 ~chiumherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wen hti ~ NO. 5029 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 K-05C AWJB-00016 •• MEM PROD PROFILE _. ~;~. -- -•~ ' ':~, xy ~~- vaac 12/29/08 oa. 1 6.VIVr VV 1 2-54/0-12 11968974 SBHPSURVEY ; ;.S o_ (~- •, ~~ -~:~-~, ?.~ 11/23/08 1 1 V-223 AXBD-0001 MEM INJECTION PROFILE +~ ~tµ a ..K. _ - r _ -~/ j 12/29/08 1 1 18-24B 12066555 MCNL ,~~t, jC ^~ / (-~ "~ ~ 10/18/08 1 1 J-18 12103680 :: ~ . /j RST "-< ` , k ~ "~ . r~~t ~ }~'- 09/25/08 1 1 1-45/0-26 12088686 RST j ~~°=~ - ~ ~~; r ~ t %~. r_j ~ "'~ 09/22/08 1 1 V-219 40018249 OH MWD/LWD EDIT ~:?~.:, -~ ~ <.+ ')- ,`_ ~.:I ~~, 11/17/08 2 1 DI CACC A/"1C41llUII Cr1!`_C o~ r~ieT nv c~Inw ~~w~i. w BP Exploration (Alaska) Inc. _ ~ v.,,'..-M v,•~ vv, ~^v" ~ v. Petrotechnical Data Center LR2-1 "` ~~, ~~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,~~~:~"~ ~; C~ `~"~~) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 '~ Anchorage, AK 995,03-2838 ~ ATTN: Beth ~ ~ ,' / Received by: ~ ^~ ~~-__.-•---`'~ • Date 12-12-2008 Transmittal Number:93025 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ~01~-21~.Ap. G0=-I~+tr i =)G .3 YT j - - G t ".'. ,.-~~ t . J ::. `. 7, ~ ! ~ / -J~~ 18-24B N-146 N-14BPB1 Y-056PB1 Y-09AL1 Y-09AL1-01 ~ - ~ ~~~, Please ~~ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~7s-1~1~~ i~~~~t ~t/ ~s =~ s ~ i ~'~- ~~ ~- i~ J~`~~- 1~~ I'~`-~~"~'' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~~+ ~ ,y, STATE OF ALASKA ~ - ALASKA OIL AND GAS CONSERVATION COMMISSION ti, ;, ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOGS'' `~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.tos zoAAC 2s.tto ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well t~,lase: ®Developmenf ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp., Susp., or Aba 10 2008 12. Permit to Drill Number 208-143 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/11/2008 - 13. API Number 50-029-21952-02-00' 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 10/13/2008 - 14. Well Name and Number: PBU 18-246 ' 4293' FSL, 4598' FEL, SEC. 19, T11 N, R15E, UM Top of Productive Horizon: 2417' FSL, 4945' FEL, SEC. 19, T11 N, R15E, UM g KB (ft above MSL): 48.65' Ground (ft MSL): 18.1' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3623' FSL, 3539' FEL, SEC. 19, T11 N, R15E, UM 9. Plug Back Depth (MD+TVD) 11215' 8684' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 692117 y- 5960890 Zone- ASP4 10. Total Depth (MD+TVD) 11382' ~ 8681' 16. Property Designation: ADL 028321' TPI: x- 691825 y- 5959006 Zone- ASP4 ASP4 5960248 Z 11. SSSV Depth (MD+TVD) 2207' 2207' 17. Land Use Permit: one- Total Depth: x- 693195 y- TVD f t 18. Directional Survey ®Yes ^ No i I r ni ri inf i n AA 19. Water depth, if offshore N/A ft MSL ( ): ros 20. Thickness of Perma 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information p r 20 AAC 25.071): MWD DIR / GR / RES, GR / CCL ! CNL L,/~i/64~/G .~.3.bMD d~o?6-'s~YYd 22, CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " 1. 114' 1 I s ~~ ~ ~ " 1000 sx CS III 350 sx'G' 230 sx CS II - / " .7 - 7 -7/ " I ~~ 1 I „ _ ~ ~ -1/ ' &1/2"x3-3/t 6" x 2-3/S" 9.2# / 6.2# / 4.7# 1 1' x ~ 23. Open to production or injec tion? ®Yes ^ No 24. TuarNC RECORD If Yes, list each i nterval open N b SIZE DEPTH SET MD PACKER SET MD er): um (MD+TVD of Top 8 Bottom; Perforation Size and f Di meter 6 s 1 56" G 4-1/2", 12.6#, L-80 4658' 4622' , p . un a MD TVD MD TVD 9730' - 10150' 8727 - 8719' ' ' ' ' 2rj, ACID, FRACTURE, CEMENT $DDEEZE, ETC. - 8710 8714 - 10350 10280 10410' - 1 OBOO' 8708' - 8899' DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED 10670' - 10710' 8697' - 8697' ' ' ' 2500' Freeze Protect w/ McOH 8697 - 8693 10750' - 10850 10960' - 11180' 8690' - 8685' 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing . PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) A wired? ^Yes ®No Sidewall Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and pn;sence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~ ~~}~ ~ T~ .~, . Form 10-407 Revlseo 0"L1UU~ I+ONTINUED VN r(EVERSE JIDE ° """°""`°'- ~4,~ ~~ ~ cuu~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ~' RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested . Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kicked Off in Zone 1A 9282' 8716' None (From 18-24AL2) Formation at Total Depth (Name): Zone 1A (From 18-24AL2) 9282' 8716' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~ 1 ~ ~ ~~~ Signed Terrie Hubble - Title Drilling Technologist Date PBU 18-246 208-143 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. I)ri--ing engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Onry BP EXPLORATION Operations Summary Report Page 1 of 8 Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/9/2008 10:00 - 12:00 2.00 MOB P PRE Move rig from 18-14 to 18-24 12:00 - 16:00 4.00 RIGU P PRE ND tree cap. NU BOP. 16:00 - 18:00 2.00 BOPSU P PRE Pressure test BOP. AOGCC representative Chuck Sheeve 18:00 - 20:00 I 2.00 20:00 - 00:00 I 4.00 10/10/2008 100:00 - 03:00 3.00 03:00 - 03:15 I 0.25 waived witnessing test. N SFAL PRE Found hydraulic leak on blind rams, disassembled hydraulic cylinder, installed new O-rings /reassembled /test good P PRE Pressure test BOP. Swab valve not holding, regreased AOGCC representative Chuck Sheeve waived witnessing test. P PRE P PRE 03:15 - 04:15 1.00 RIGU P 04:15 - 06:00 1.75 RIGU P 06:00 - 08:30 2.50 RIGU P 08:30 - 09:35 1.08 KILL P PRE PRE PRE WEXIT 09:35 - 09:55 0.33 KILL P WEXIT 09:55 - 10:25 0.50 KILL P WEXIT 10:25 - 10:45 0.33 KILL P WEXIT 10:45 - 11:15 0.50 KILL P WEXIT 11:15 - 11:50 0.58 WHIP P WEXIT 11:50 - 14:00 2.17 WHIP P WEXIT 14:00 - 15:10 1.17 WHIP P WEXIT 15:10 - 15:20 0.17 WHIP P WEXIT 15:20 - 17:00 1.67 WHIP P 17:00 - 17:45 0.75 WHIP P 17:45 - 19:45 2.00 STWHIP P 19:45 - 20:00 0.25 STWHIP P I1~22 8 110/11 /2008 100:00 - 03:45 I 3.75 I STW H I P I P 03:45 - 05:00 I 1.251 STWHIPI P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Finish Pressure testing BOP Blind rams failure, R&R ram seal Test good PJSM for removing the BPV, discuss procedure, hazards and mitigations Test lubricator to 2000 psi, Pull BPV. Load out BPV equipment. Prep to Pump slack management Pump 42 bbls to fill coil, reverse circ ~ 3.5 bpm, 4400 psi. Pumped zero slack, a-line is still (~ end of coil. Cut 10' of coil . Test a-line Rehead BHI equipment. Pull test CTC 35K . PT to 4500 psi. PT inner reel valve. Install check valves. PU injector and stab onto well. Bullhead kill well with water thru kill line .Circulate coil to warm CT. Open well 680 psi. Bullhead with both pumps. Bullhead 265 bbls. Flow check well. Slight flow. Bullhead 170 bbl 2# bio to perforations. Shut master valve. Circulate CT to warm coil.Displace CT to Bio. Flow check well. Well dead. PU whipstock assembly. RIH 9,160' Tie-in log. Correction +1'. RIH to place top of WS at 9310'. Close EDC.TF 270RHS. Pressure to 3800 psi. Stack 4K. OK PU 27K. POH. LD WS setting tools and PU milling assy. RIH w/ window milling assembly Dry tag WS, PU 10' and RIH w/pumps on, flag pipe up wt-22K, FS 2340 psi 20:00 1.46/1.46 bpm, 2440 psi, DWOB - 0.46K, 9310' 21:00 1.45/1.45 bpm, 2570 psi, DWOB - 1.73K, 9310.1' 22:00 1.45/1.45 bpm, 2690 psi, DWOB - 2.14K, 9310.5' 23:00 1.44/1.44 bpm, 2540 psi, DWOB - 1.92K, 9111.1' Stall at 9111.1, PU and time drill down ~ 1'/hr Continue milling 00:30 2629 psi, 1.46/1.46 bpm, DWOB - 1.42K, 9311.1' 01:30 2430 psi, 1.45/1.45 bpm, DWOB - 0.84K, 9311.4' 02:00 2470 psi, 1.45/1.45 bpm, DWOB - 1.15K, 9312.2' 03:00 2440 psi, 1.49/1.49 bpm, DWOB - 1.68K, 9313.0' Stall w/ decrease in DWOB and motor work, window exit at 9313.6' - Drill 10 ft of rathole to 9324 ft at 10 ft/hr. Printed: io/3o/zoos 11:"L /:UFi AM +~ BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours I Task Code NPT Phase 10/11/2008 103:45-05:00 1.25~STWHIP P WEXIT 05:00 - 06:30 1.50 STWHIP P WEXIT 06:30 - 07:50 1.33 DRILL P PROD1 07:50 - 10:30 2.67 DRILL P PROD1 10:30 - 11:10 0.67 DRILL P PROD1 11:10 - 12:00 0.83 DRILL P PRODi 12:00 - 16:00 4.00 DRILL P PROD1 16:00 - 16:10 0.17 DRILL P PROD1 16:10 - 16:46 0.60 DRILL P PROD1 16:46 - 18:15 1.48 DRILL P PROD1 18:15 - 18:30 0.25 DRILL P PROD1 18:30 - 19:30 1.00 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 21:15 0.25 DRILL P PROD1 21:15 - 23:30 2.25 DRILL P PROD1 23:30 - 23:45 0.25 DRILL P PROD1 23:45 - 00:00 0.25 DRILL P PROD1 110/12/2008 ~ 00:00 - 01:15 ~ 1.25 ~ DRILL ~ P ~ ~ PROD1 01:15 - 02:45 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 02:45 - 03:15 0.50 DRILL P PROD1 03:15 - 04:45 1.50 DRILL P PROD1 04:45 - 05:45 1.00 DRILL P PROD1 05:45 - 07:45 2.00 DRILL P PROD1 07:45 - 08:25 0.67 DRILL P PRODi 08:25 - 10:20 1.92 DRILL P PROD1 10:20 - 12:10 ~ 1.83 ~ DRILL ~ P ~ ~ PROD1 12:10 - 13:50 ~ 1.67 ~ DRILL ~ P ~ ~ PROD1 13:50 - 14:20 0.50 DRILL P PROD1 14:20 - 14:30 0.17 DRILL P PROD1 14:30 - 14:50 0.33 DRILL P PROD1 14:50 - 16:10 1.33 DRILL P PROD1 Description of Operations Perform 3 up and down passes through window at slow speed. Dry run through window shows no weight bobbles. POOH LD milling assv and PU Drilling assv with 2.5 degree motor.Mill aws 2.73 No Go and String mill 2.74 No GO. M/U Build section BHA &RIH T/ 9,160' Tie-in log F/ 9,160' T/ 9,237', Correction +16' RIH F/ 9,237' T/ 9,320' Drill Build section F/ 9,320' T/ 9,452' Wiper trip T/ 9,325' Drill Build section F/ 9,452' T/ 9,480' POH PJSM for BHA handling, discuss procedures, hazards and mitigation LD 2.5 deg motor, PU 1.1 deg motor and rerun bit for the build RIH Log GR tie-in (+4.5'), RIH to 9480' Drill lateral section, ,1.56/1.56, FS 2900 psi, 3180 psi, ROP 90-100 fph, ECD 9.32, Near bit incln 92, DWOB 1.3K Drill to 9650' Wiper trip Drill lateral section 1.56/1.56, FS 2880 pis, 3190 psi, ROP 50-70 fph, ECD 9.42, Near bit incln 92, DWOB 1.6K Drill to 9660' Continue drilling lateral Q 1.5/1.5 bpm, 3200 psi, FS 2800 psi, ROP 70-80, DWOB - 1.7K, ECD 9.42, Near Bit 92 Drill to 9732' Drill Lateral ~ 1.48/1.48 bpm, 3300 psi, FS 2800 psi, ROP 80 fph, DWOB 1.52K, ECD 9.42, Near bit 89 Drill to 9,850' Wiper trip Drill Lateral C~ 1.5/1.5 bpm, 3290 psi, FS 2900 psi, ROP 80-90 fph, DWOB 2.1 K, ECD 9.48, Near bit 90 Drill to 10,000' Wiper trip, log GR tie-in (+1.5') Drill lateral ~ 1.5/1.5 bpm, 3110 psi, FS 2850 psi, ROP 90-100 fph, DWOB 2K, ECD 9.54, Near bit incln 88-95 Drill to 10,150. Wiper to window. Drill lateral C~? 1.54/1.54 bpm, 3510 psi, FS 2850 psi, ROP 100+ fph, DWOB 2.3K, ECD 9.57, Near bit inc 95 Drill to 10300 Wiper into 5.5" casing to 8700. Open EDC circulate bottoms up from window 140 bbls 2.59 bpm C~ 3880 psi.Close EDC at window. Wiper to TD. Drill lateral ~ 1.58/1.57 bpm, 3428 psi, FS 2850 psi, ROP 100+fph, DWOB 2.3K, ECD 9.57, Near bit inc 92 Swap mud. Drill to 10455 Wiper to window. Log tie-in +4' correction. Wiper to TD. Drill lateral C~ 1.58/1.57 bpm, 3220 psi, FS 2600 psi, ROPO+ fph, DWOB 1.8K, ECD 9.33, Near bit inc 92 BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date 'From - To Hours Task Code NPT ', Phase Description of Operations 10/12/2008 14:50 - 16:10 1.33 DRILL P PROD1 Drill to 10605. 16:10 - 17:10 1.00 DRILL P PROD1 Wiper to window. 17:10 - 18:45 1.58 DRILL P PROD1 Drill lateral ~ 1.58/1.57 bpm, 2950 psi, FS 2550 psi, ROP +100 fph, DWOB 2.3K, ECD 9.33, Near bit inc 91 Drill to 10,700' 18:45 - 19:30 0.75 DRILL P PRODi Drill lateral ~ 1.55/1.51 bpm, 2900 psi, FS 2560 psi, ROP 50 fph, DWOB 2.1 K, ECD 9.36, Near bit incl 90 Drill to 10,730' 19:30 - 20:15 0.75 DRILL P PROD1 Wiper trip 20:15 - 20:45 0.50 DRILL P PROD1 Drill lateral C~ 1.35/1.28 bpm, 2500 psi, FS 2300 psi, ROP 25-50 fph, DWOB 1.72K, ECD 9.34, Near bit incln 90 Drill to 10,750 20:45 - 22:00 1.25 DRILL P PROD1 Drill lateral C~ 1.38/1.3 bpm, 2640 psi, FS 2300 psi, ROP 80-100 fph, DWOB 1.33K, ECD 9.38, Near bit incln 92 Drill to 10,805' 22:00 - 23:00 1.00 DRILL P PROD1 Drill lateral ~ 1.52/1.42 bpm, 2850 psi, FS 2700 psi, ROP 70-80 fph, DWOB 1.45K, ECD 9.46, Near bit incln 92 Drill to 10,850' 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip up to 8700' into the 5-1/2" 10/13/2008 00:00 - 01:30 1.50 DRILL P PROD1 Log GR Tie-in (+2'), RIH to TD 01:30 - 02:45 1.25 DRILL P PROD1 Continue drilling lateral ~ 1.52/1.53, 2840 psi, FS 2500 psi, 70-80 ROP, DWOB 1.9K, 9.42 ECD, near bit incln 92 Drill to 10,920' 02:45 - 03:15 0.50 DRILL P PROD1 Continue drilling lateral C~ 1.38/1.37, 2750 psi, FS 2280 psi, 30-40 fph, DWOB 1.6K, 9.47 ECD, near bit 90 Stacking weight frequently 03:15 - 04:30 1.25 DRILL P PROD1 Continue drilling lateral ~ 1.56/1.48, 3040 psi, FS 2710 psi, DWOB 1.45K, 9.5 ECD, near bit 91 Stacking weight frequently, negative coil weights Drill to 11,000' 04:30 - 05:45 1.25 DRILL P PROD1 Wiper trip 05:45 - 09:05 3.33 DRILL P PROD1 Continue drilling lateral ~ 1.59/1.52, 3050 psi, FS 2710 psi, DWOB 1.33K, 9.55 ECD, near bit 92 Stacking weight frequently, negative coil weights 09:05 - 11:30 2.42 DRILL P PROD1 POH fora itator. 11:30 - 11:45 0.25 DRILL P PROD1 PJSM 11:45 - 13:30 1.75 DRILL P PROD1 BHA change Add agitator to assembly. SLB inspector inspected SLB lifting equipment. Surface test agitator 13:30 - 15:15 1.75 DRILL P PROD1 RIH. 15:15 - 15:30 0.25 DRILL P PROD1 Log tie-in. Correction -1.5'. 15:30 - 16:00 0.50 DRILL P PROD1 RIH set down 10740, 10720 orient to 330R. OK , bauble at 10815, Tag at 11,118'. 16:00 - 16:45 0.75 DRILL P PROD1 Drilling lateral ~ 1.48/1.41, 3050 psi, FS 3440 psi, DWOB 1.94K, 9.79 ECD, near bit 90. ROP 130 Drill to 11,190' 16:45 - 18:00 1.25 DRILL N STUC PROD1 Differentiall stuck at 11 168' shut down pumps and slack off 18:00 - 19:30 1.50 DRILL P PROD1 Log tie-in (+7' correction), RBIH 19:30 - 00:00 4.50 DRILL P PROD1 Drilling lateral @ 1.47/1.41, 3400 psi, 2900 psi FS, DWOB 1.23K, ECD 9.68, near bit 90, ROP 70-80 Drilled to 11,382' Call TD 10/14/2008 00:00 - 01:15 1.25 DRILL P PROD1 Pull up to the window and log GR tie-in (+4') 01:15 - 02:00 0.75 DRILL P PROD1 RIH to TD for final tag C~ 11382, lay in liner pill w/ 2 ppb beads, and POOH. rnniea: i~iovicwa ii:u.uo rave • • BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours I Task ~ Code ~ NPT Phase ~ Description of Operations 10/14/2008 01:15 - 02:00 0.75 DRILL P 02:00 - 04:00 2.00 DRILL P 04:00 - 04:15 0.25 DRILL P 04:15 - 05:15 1.00 DRILL P 05:15 - 05:30 0.25 DRILL P 05:30 - 08:00 2.50 DRILL P 08:00 - 12:00 4.00 DRILL P 12:00 - 12:45 0.75 DRILL P 12:45 - 13:10 0.42 WHSUR P 13:10 - 18:00 4.83 CASE P 18:00 - 20:45 ~ 2.75 ~ CASE ~ P 20:45 - 21:15 0.501 CEMT ~ P 21:15 - 23:15 2.00 CEMT P 23:15 - 00:00 0.75 CEMT P 10/15/2008 00:00 - 00:45 0.75 CEMT P 00:45 - 01:15 ~ 0.50 ~ CEMT ~ P 01:15 - 03:00 1.751 CEMT P PROD1 Once into cased hole and all beads are pumped, open EDC and circ at full rate while POOH PROD1 Lay in 25 bbl liner pill w/ 2 ppb beads, and POOH. Once into cased hole, open EDC and circ at full rate while POOH PROD1 PJSM for LD drilling BHA, discuss procedure, hazards and mitigations PROD1 LD drilling BHA Pump 40 bbl of water through reel PROD1 PJSM for blowdown reel, review procedures, hazards and mitigations PROD1 Cool down N2, While pumping min rate .Pickle and Blow down coil with N2. Cut CTC and install grapple. Secure coil. PROD1 Lower reel and UP cementing reel..lnstall grapple and pull test. Pull CT across and stab in chains. Install weld on connector. Pull test to 37K. OK. PROD1 Circulate volume dart CT reel Vol ~ 41.2bbls PROD1 Pressure test inner reel valve to 4,000psi RUNPRD Run liner as per program. Guide shoe, float collar, 1 jt 2-3/8", float collar, Pup, STL Latch Collar, 86 jts 2-3/8" 4.70# L-80 with cementralizers, Pup jt, XO, Deployment sleeve, LBRT running tool, XO, Swivel, CTC. BHA OAL = 2,655.12_ft_ RUNPRD RIH with 2-3/8" liner pumping min rate, Sat down at 11,257' several times, Bring pumps up but circ pressure not over 1500 psi, after many attempts still have not gained any footage Talk to town and get approval to_leave liner at 11,257' RUNPRD Drop 5/8" AL ball, start pumping at 1.6 bpm to move ball around reel Drop rate at 30 bbl out, Shear out ball at 4000 psi and release from liner RUNPRD Swap wellbore over to KCI pump 1.9 bpm in/ 1.65 bpm out RUNPRD RU cementers RUNPRD RU cementers to pump the job and circulate KCI 1.2 in / 0.9 out PJSM for cement job, discuss procedure, hazards and mitigations RUNPRD Batch cement 14 bbls, Cement at weight at 01:20, by pass MM, PT to 6500 psi Cement at weight at 01:20, mixed 14 bbls RUNPRD Installed wiper dart. Purge lines behind dart with BIO. Launch dart with 600 psi.Displace with 25 bbl Bio and KCL. PU liner wiper at 41.5 bbls. bbls Pressure In Rate Out Rate 5. 2600 1.40 1.34 10 3100 1.40 1.30 14 3400 1.40 1.20 -Cement pumped, purge lines behindBlO, Launch dart w/ 1000 psi, Displace w/ BIO and KCI zero MM 10 4010 1.8 1.52 15 3662 1.8 1.62 25 4340 2.0 1.7 35 1350 1.0 0.8 rnmeu: iuiouicwo ~i.ci.w .,~.~ BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date 'From - To Hours Task Code ~ NPT I Phase { Description of Operations 10/15/2008 01:15 - 03:00 1.75 CEMT P RUNPRD 141.4 (calculated 41.2) PU liner wiper plug shear at 4100 psi. Displace to landing collar 45 2650 .90 0.78 51.8 BUMP (Calculated 51.2bbls) @46 Pressure up to 4800 psi for 5 mins Floats held. Bleed off coil Pressure, PU out of liner deployment sub 03:00 - 04:45 1.75 CEMT P RUNPRD POOH while contaminating 04:45 - 05:00 0.25 CEMT P RUNPRD PJSM for LD Liner running BHA and PU C/O assembly 05:00 - 08:45 3.75 CEMT P RUNPRD ~LD liner running BHA and begin picking up cleanout assembly w/ 46 stands of CSH 08:45 - 10:00 1.25 CEMT P RUNPRD RIH with cleanout Assy to 8,400' 10:00 - 10:30 0.50 CEMT N WAIT RUNPRD Work pipe while waiting on UCA to reach 500psi 10:30 - 12:15 1.75 CONDH P RUNPRD cleanout RIH with milling assy from 8,601' tagged ~ 11,194', Pull up to 11,094' & flag pipe, EOP at 8252', cement returns stung out over 50 bbls, weighing 8.6ppg 12:15 - 14:15 2.00 CONDH P RUNPRD POOH 14:15 - 16:00 1.75 CONDH P RUNPRD PJSM for standing bach CSH & UD Milling BHA Stand back CSH & UD Milling BHA 16:00 - 18:00 2.00 EVAL P RUNPRD P/U Logging tools to rig floor, Jet stack, MU logging tools 18:00 - 19:45 1.75 EVAL P RUNPRD points o 1" SH or logging run, PU injector and stab onto well 19:45 - 21:15 1.50 EVAL P LOWERi RIH w/ logging BHA Start loggin down at 8300', get to 8588' and sat down try to work it through, pump 0.4 bpm tagged, brought pumps up to 1 bpm to try and pressure up to straighten the tool, tagged again, tried inching our way in several times, no luck. Possible geometry issue, POOH for_centralizer Get returns w/wet cement back at surface 21:15 - 22:00 0.75 EVAL N DPRB LOWERI POOH for logging centralizer 22:00 - 22:15 0.25 EVAL N DPRB LOW ER1 PJSM for standing back CSH, discuss procedure and hazards 22:15 - 00:00 1.75 EVAL N DPRB LOWERI Stand back 46 stands of CSH 10/16/2008 00:00 - 00:15 0.25 EVAL N DPRB LOWERI PJSM for removing source 00:15 - 01:00 0.75 EVAL N DPRB LOWERI LD logging tools, load out logging tools and check for damage. Add centralizer to tool 01:00 - 01:15 0.25 EVAL N DPRB LOWERI PJSM for source and PU CSH, discuss hazards and procedure 01:15 - 01:30 0.25 EVAL N DPRB LOWERI MU logging tool w/ centralizer 01:30 - 03:30 2.00 EVAL N DPRB LOWERi PU 46 stands of 1"CSH PU injector and stab onto well 03:30 - 04:30 1.00 EVAL N DPRB LOWERI RIH w/ BHA #9 - MCNL logging tools w/ centralizer, 46 stands of 1"CSH TOTAL BHA Length - 2857.55 04:30 - 05:00 0.50 EVAL N DPRB LOWERI RIH to 8300' and begin logging down at 30 fpm Tag at 8 580' PU and run back down to try and get it through, to a ain, PU bring pump rates up to 1.2 bpm and tag at 8,580', try several times w/ no success 05:00 - 05:45 0.75 EVAL N DPRB LOWERI POOH for mill and motor 05:45 - 06:00 0.25 EVAL N DPRB LOWERI PJSM Stand back CSH, discuss hazards 06:00 - 06:15 0.25 EVAL N DPRB LOWERI PJSM handling BHA with source, discuss hazards with new crew 06:15 - 08:45 2.50 EVAL N DPRB LOWERI POH with BHA 9, std back 46 Stds of 1" CSH, LD logging tools, rnntea: iuisuizwo ii:ci:uo rave BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ' Hours Task Code.. NPT Phase Description of Operations 10/16/2008 06:15 - 08:45 2.50 EVAL N DPRB LOWERI load out logging tools and check for damage 08:45 - 09:40 0.92 EVAL N DPRB LOWERI PJSM PU cleanout assy 10, MU BHA 10 with 3.76" PDC mill on 2 7/8" VIP motor, MHA, CTC, stab injector 09:40 - 11:20 1.67 EVAL N DPRB LOWERI RIH with BHA 10, tagged TOL ~ 8,592.7', Corrected Depth to 8,601.8', motor stalled out when tagging up on TOL, sweep hole with 40 bbl 2 ppb Bio pill followed with new double slick 1 percent KCL fluid at 2.8bpm, 3000psi 11:20 - 13:45 2.42 EVAL N DPRB LOWERI Drop 5/8" Steel ball & pump to seat pump ball C~ 2.8bpm 2,800psi,Slowed pumps to 1 bpm ~ 28bbls away, ball seated ~ 35.3bbls shear ~ 3,000psi. POOH while pumping C~ 2.8bpm 2,800psi, Trace of cement on bottoms up 13:45 - 14:30 0.75 EVAL N DPRB LOWERI PJSM for UD of BHA 10, Stand back Injector head, UD BHA 10 14:30 - 15:30 1.00 EVAL N DPRB LOWERI PJSM for P/U of Milling assv. BHA, P/U Milling Assy. BHA 15:30 - 18:00 2.50 EVAL N DPRB LOWERi RIH with BHA 11, Tagged TOL ~ 8,585' tried to enter liner with pum s off, did not enter, P/U 50' Brought pumps online to 0.9bpm & ran back down to TOL while pumping, got through, RIH to PBTD, minimal motor work. 18:00 - 20:00 2.00 EVAL N DPRB LOWERI Tag PBTD and POOH to 8540', RBIH to try w/ pumps off, can't get through, bring pumps up and get t roug no pro em, try one more time w/ pumps off, no luck, again,go through no problem w/ um son. POOH for logging tools w/ centralizer 20:00 - 20:15 0.25 EVAL N DPRB LOWERI PJSM for standing back CSH and BHA handling, discuss procedure and hazards 20:15 - 22:15 2.00 EVAL N DPRB LOWERI Stand back 1" CSH & LD motor and mill 22:15 - 22:30 0.25 EVAL N DPRB LOWERI PJSM for source handling 22:30 - 00:00 1.50 EVAL N DPRB LOWERI PU logging tools to the floor, load source, PU 46 stands of 1" CSH 10/17/2008 00:00 - 00:45 0.75 EVAL N DPRB LOWERI Finish PU CSH 00:45 - 01:45 1.00 EVAL N DPRB LOWERI RIH to 8300' 01:45 - 02:15 0.50 EVAL N DPRB LOW ER1 Start to in down at 30 f m ~ 8300' to at 8 584' um at 0.5 b m PU and t several times with no luck 02:15 - 03:15 1.00 EVAL N DPRB LOWERI POOH 03:15 - 03:30 0.25 EVAL N DPRB LOWERI PJSM for BHA handling 03:30 - 05:00 1.50 EVAL N DPRB LOWERI Standback 46 stands of 1" CSH 05:00 - 05:15 0.25 EVAL N DPRB LOW ERi PJSM for source handling and LD logging tools, discuss procedure and hazards associated 05:15 - 05:30 0.25 EVAL N DPRB LOWERI Remove source and LD logging tools 05:30 - 06:00 0.50 BOPSU P LOWERI Function Test BOP's 06:00 - 06:45 0.75 CEMT P RUNPRD Liner La test to 2,000 si less than 40 si leak off in 30min. Liner Lap Test Good 06:45 - 10:30 3.75 CEMT N DPRB RUNPRD Standby waiting on solution for logging tool problems 10:30 - 12:00 1.50 EVAL N DPRB RUNPRD M/U Deploymnet sleeve Dressing /Milling BHA 12:00 - 13:45 1.75 CASE N DPRB RUNPRD RIH with Milling Assy. Pumps ~ Min. Rate to 100' off the TOL Brought pumps up to 2.5bpm, Tagged TOL ~ 8,589' MD 13:45 - 14:30 0.75 CASE N DPRB RUNPRD Dress /Mill Deployment sleeve collar( Pump rate 2.5bpm / WOB 1,016 / 2,208psi) Mill from 8,589' to 8,597' 14:30 - 16:00 1.50 CASE N DPRB RUNPRD POOH 16:00 - 16:30 0.50 CASE N DPRB RUNPRD UD Milling Assy BHA 16:30 - 16:45 0.25 CASE N DPRB RUNPRD PJSM to P/U, Drift & Strap 3-3/16" TCII Liner 16:45 - 22:15 5.50 CASE N DPRB RUNPRD Load pipe into pipe shed, Drift and Strap 3-3/16" liner 22:15 - 22:30 0.25 CASE N DPRB RUNPRD PJSM for PU 3-3/16" Scab liner and BHA 22:30 - 00:00 1.50 CASE N DPRB RUNPRD PU Seal Assembly w/ indexing shoe, XO, and 3-3/16" TCII liner rnninu. wiowc~~o i i.u.w ~~.~ BP EXPLORATION Page 7 of 8 ~ Operations. Summary Report Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task '~ Code 'NPT I Phase Description of Operations 10/18/2008 00:00 - 07:00 7.00 CASE N DPRB RUNPRD Continue picking up 3-3/16" TCII liner, 3 pup joints of 3-3/16", 1 'ts of 3-3/16" XO, ijt of 3.5" liner, 3.5" rnpp e, 1 ~t o 3.5" Inver, j and BTT deployment sleeve, GS Spear, Hydraulic Disconnect, XO, CTC 07:00 - 09:30 2.50 CASE N RREP RUNPRD CTC Bent, weld on new CTC, Pressure test & pull test CTC 09:30 - 10:45 1.25 CASE N DPRB RUNPRD RIH with 3-3/16"Scab Liner,Tag ~ 8,594' 10:45 - 11:45 1.00 CASE N DPRB RUNPRD To of De to ment sleeve at 8,594' Ran in to 8 604' Pressured up IA to 320psi for 5min (good seal), Pressured up OA to 400psi for 5min (good seal) Stacked weight to 2,5001bs, Pressure up to 500psi Picked up on Coil / No Release Stacked weight to 2,5001bs, Pressure up to 1,000psi Picked up on Coil / No Release Stacked weight to 2,5001bs, Pressure up to 1,200psi Picked up on Coil / No Release Stacked weight to 5,000Ibs, Pressure up to 200psi Picked up on Coil / No Release Stacked weight to 6,000Ibs, Pressure up to 200psi Picked up on Coil / No Release Stacked weight to 7,000Ibs, Pressure up to 350psi Picked up on Coil / No Release Stacked weight to 8,000Ibs, Pressure up to 350psi Picked up on Coil / No Release Stacked weight to 12,000Ibs, Pressure up to 350psi Picked up on Coil / No Release Stacked weight to 18,000Ibs, Pressure up to 1,500psi Picked 11:45 - 13:00 13:00 - 14:45 14:45 - 18:15 18:15 - 19:30 19:30 - 19:45 19:45 - 22:00 22:00 - 22:15 22:15 - 00:00 1.25 CASE N 1.75 EVAL N 3.50 EVAL P 1.25 EVAL P 0.25 EVAL P 2.25 EVAL P 0.25 EVAL P 1.75 EVAL P DPRB RUNPRD POOH, UD Deployment Sleeve Spear DPRB LOWERI PJSM for P/U &RIH with logging tools, Pick up Logging BHA 15 LOWERI RIH with BHA 15 to 8,300', Start logging down at ~ 30 fpm to PBTD, log up at 60 fpm to 8300' LOWERI POOH w/ logging BHA LOWERI PJSM for BHA handling and source handling LOWERI Standback 21 stands of CSH and LD 25 stands, LD logging tools LOWERI PJSM for loading guns into pipe shed LOWERI Load out 50 jts of CSH, and load guns into pipe shed, RU to run guns LOWERI PJSM for picking up guns and 21 stands of CSH LOWERi Make 1462' f unsand PU 21 stands of CSH LOWERI RIH w/ pert assembly, CTC, DBPV, Locking swivel, HDLC 3/4" Ball, xo, 42 jts of 1" CSH, XO, Disconnect 5/8" ball, Firing head and pert guns, Total length - 2765.83' LOWERI RIH with first set of guns. Tag at 11,207' correct to 11,215' PU to ball drop position. Launch 1/2" Aluminum ball with 800 psi and 10 bbl pill. 1.3 bpm ~ 3,100 psi. Reduce rate to 0.5 bpm 824 psi ~ 30 bbl. Ball on seat ~ 40.3 bbls. Pressure to 3,400 psi bottom shot 11,180' on the fly. 1.56' 6SPF 9,730'-10,150' 10,280'-10,350' 10/19/2008 00:00 - 00:30 0.50 PERFO~ P 00:30 - 04:15 3.75 PERFO P 04:15 - 06:00 1.75 PERFO P 06:00 - 07:00 I 1.001 PERFOBI P rnniea: wiowcuua i i:ci.vo ruvi \~ BP EXPLORATION Operations Summary Report Page8of8~ Legal Well Name: 18-24 Common Well Name: 18-24 Spud Date: 6/30/1989 Event Name: REENTER+COMPLETE Start: 10/6/2008 End: 10/20/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/20/2008 Rig Name: NORDIC 1 Rig Number: i Date From - To Hours Task ~ Code ~ NPT Phase Description of Operations 10/19/2008 ~ 06:00 - 07:00 1.00 PERFOB~ P 07:00 - 09:00 2.00 PERFO P 09:00 - 15:00 6.00 PERFO P 15:00 - 16:30 1.50 WHSUR P 16:30 - 17:00 0.50 WHSUR P 17:00 - 19:00 2.00 RIGD P 19:00 - 21:00 2.00 RIGD P 21:00 - 00:00 3.00 RIGD P 10/20/2008 100:00 - 02:00 ~ 2.001 DEMOB ~ P LOWER 10,410'-10,600' 10,670'-10710' 10,750'-10,850' 10,960'-11,180' LOWERI POOH with Perf Assy LOWERI PJSM for UD 1" CSH &Perf Assy, UD remaining 1"CSH & Perf Assy. (ALL SHOTS FIRED ) POST Attach nozzle, RIH & Freeze protect well POST PJSM to Install BPV. Install BPV_. POST Pickle reel-Pump corrosion inhibitor chased with 7bbls methanol, Blow down coil with nitrogen for 15min, bleed off pressure POST C/O 2" combis to 2-3/8" combi's, install 2-3/8" - 3-1/2" Var. POST Stand back injector Cut off coil connection, install grapple, pull test grapple, pull coil acroos to reel and secure. PJSM for reel swap. Discuss procedure and hazards. Drop reel and PU a-line reel POST ND NOP and install tree cap. Pressure test to 3500 psi. Greas master and swab, secure BOP RIG RELEASE 02:00, ALL FURTHER COSTS AND INFORMATION WILL BE ON 18-066 rnmeu. ~uiawcvvo ~ i.u .w .,~., ~ ~' BP Alaska ''~~~ ~ Baker Hughes INTEQ Survey Report rr.r BAKER NuG~s Company: BP Amoco Field: Prudhoe Bay ~ Site: PB DS 18 Well: 18-24 Wclluath: 18-24B __ __ __ __ _ - Date: 10/14/2008 Time: 08:47:50 Page: 1 Cu-urdinate(NE) Reference: Well: 18-24, True North ~~ Vertical (TVD) Rcferencr. 46:24 5/31/1996 08:49 48.6 Section (VS) Reference: Well (O.OON,O.OOE,122.24Azi) Sw~vey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Fasting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-24 Slot Name: 24 18-24 Well Position: +N/-S 1663.16 ft Northing: 5960890.35 ft Latitude: 70 17 51.609 N +E/-W 575.87 ft Easting : 692116.70 ft Longitude: 148 26 38.768 W Position Uncertainty: 0.00 ft Wellpath: 18-24B Drilled From: 18-24AL2 500292195202 Tie-on Depth: 9297.07 ft Current Datum: 46:24 5/31/1996 08:49 Height 48.65 ft Above System Datu m: Mean Sea Level Magnetic Data: 7/11/2008 Declination: 23.26 deg Field Strength: 57686 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.65 0.00 0.00 122.24 Survey Program for Definitive Wellpath Date: 7/11/2008 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 98.65 8000.00 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 8010.00 8801.00 1 : MWD Rotary Drillout (8010. MWD MWD -Standard 8826.00 9297.07 1 : MWD (8826.00-10489.00) (3) MWD MWD -Standard 9311.00 11382.00 MWD (9311.00-11382.00) MWD MWD -Standard Annotation N1D .TVD ft ft 9297.07 8720.74 9311.00 8724.76 11382.00 8680.54 TIP KOP TD Survey: MWD Start Date: 10/13/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~~ ~ ~' BP Alaska ,,' by °~~~~~~~ Baker Hughes INTEQ Survey Report BAKER HUGHES INTEQ ~ - - - Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-24 Wellpath: 18-246 Surve~~ MD Incl ft deg - zim deg D ft s TVD ft Date: 10/14/2008 'Dime: 08:47:50 Page: 2 Cu-ordinate(NE) ReScrencc: Well: 18-24, True North Vertical (TVll) Reference: 46:24 5/31/1996 08:49 48.6 Section (VS) Reference: Well (O.OON,O.OOE,122.24Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S E/W J1apN MapE VS DLS Tool ft ft ft ft ft deg/100ft 9297.07 72.86 133.14 8720.74 8672.09 -1886.24 -329.12 5958996.42 691835.92 727.86 0.00 MWD 9311.00 73.62 132.07 8724.76 - 8676.11 -1895.27 -319.30 5958987.65 691845.97 740.98 9.18 MWD 9330.27 74.17 122.35 8730.11 8681.46 -1906.45 -304.58 5958976.85 691860.97 759.40 48.53 MWD 9363.99 82.80 105.93 8736.88 8688.23 -1919.83 -274.54 5958964.24 691891.34 791.95 54.09 MWD 9394.91 87.79 99.56 8739.42 8690.77 -1926.62 -244.50 5958958.22 691921.54 820.97 26.11 MWD 9425 00 90.28 89.63 8739.93 8691.28 -1929.03 -214.56 5958956.58 691951.54 847.59 34.02 MWD . 9454 99 91.44 78.73 8739.48 8690.83 -1925.99 -184.77 5958960.38 691981.24 871.16 36.55 MWD . 9488 05 93.16 71.74 8738.15 8689.50 -1917.58 -152.85 5958969.60 692012.93 893.68 21.76 MWD . 9522.59 95.13 76.88 8735.65 8687.00 -1908.26 -119.69 5958979.76 692045.83 916.75 15.90 MWD 9551.71 94.73 77.68 8733.15 8684.50 -1901.88 -91.39 5958986.87 692073.96 937.28 3.06 MWD 9582.61 93.87 86.52 8730.83 8682.18 -1897.65 -60.90 5958991.88 692104.33 960.81 28.66 MWD 9614.17 92.79 89.92 8728.99 8680.34 -1896.67 -29.42 5958993.66 692135.78 986.92 11.29 MWD 9644.03 92.09 93.91 8727.72 8679.07 -1897.67 0.39 5958993.43 692165.60 1012.67 13.55 MWD 9673 59 91.69 92.09 8726.75 8678.10 -1899.21 29.89 5958992.64 692195.13 1038.44 6.30 MWD . 9707.69 89.60 89.11 8726.36 8677.71 -1899.57 63.98 5958993.15 692229.22 1067.47 10.67 MWD 9736 93 87.60 84.10 8727.08 8678.43 -1897.84 93.15 5958995.62 692258.33 1091.22 18.44 MWD . 49 9765 89.97 79.61 8727.68 8679.03 -1893.79 121.41 5959000.39 692286.47 1112.96 17.77 MWD . 41 9796 90.52 76.05 8727.55 8678.90 -1887.28 151.63 5959007.68 692316.52 1135.04 11.65 MWD . 27 9825 91.90 71.35 8726.94 8678.29 -1879.18 179.32 5959016.48 692343.98 1154.14 16.97 MWD . 9856.69 89.75 67.93 8726.49 8677.84 -1868.25 208.76 5959028.15 692373.14 1173.22 12.86 MWD 9885.69 89.39 63.72 8726.71 8678.06 -1856.38 235.21 5959040.70 692399.28 1189.26 14.57 MWD 9914 51 88.13 60.30 8727.33 8678.68 -1842.86 260.65 5959054.86 692424.36 1203.56 12.64 MWD . 9943.75 88.62 55.75 8728.16 8679.51 -1827.39 285.44 5959070.97 692448.74 1216.27 15.64 MWD 9972 59 90.03 52.08 8728.50 8679.85 -1810.40 308.74 5959088.54 692471.60 1226.92 13.63 MWD . 10002.14 89.79 47.88 8728.55 8679.90 -1791.41 331.36 5959108.11 692493.73 1235.92 14.24 MWD 10032.16 93.25 44.80 8727.75 8679.10 -1770.69 353.07 5959129.36 692514.90 1243.23 15.43 MWD 10064.22 93.93 40.38 8725.74 8677.09 -1747.14 374.72 5959153.46 692535.94 1248.98 13.92 MWD 10094.84 94.02 35.78 8723.62 8674.97 -1723.11 393.55 5959177.97 692554.15 1252.09 14.99 MWD 10124 68 94.61 31.09 8721.37 8672.72 -1698.28 409.94 5959203.20 692569.90 1252.71 15.80 MWD . 10157.60 94.58 26.43 8718.73 8670.08 -1669.52 425.73 5959232.35 692584.94 1250.72 14.11 MWD 51 10187 92.73 21.83 8716.82 8668.17 -1642.29 437.92 5959259.89 692596.44 1246.51 16.55 MWD . 10217 53 91.59 17.36 8715.69 8667.04 -1614.04 447.98 5959288.39 692605.77 1239.94 15.36 MWD . 10248 23 91.50 13.09 8714.86 8666.21 -1584.43 456.04 5959318.19 692613.07 1230.96 13.91 MWD . 49 10281 91.87 7.63 8713.88 8665.23 -1551.74 462.02 5959351.02 692618.21 1218.58 16.45 MWD . 10312.03 93.47 6.67 8712.46 8663.81 -1521.47 465.81 5959381.37 692621.23 1205.64 6.11 MWD 10342 09 94.85 11.29 8710.28 8661.63 -1491.87 470.49 5959411.08 692625.15 1193.81 16.00 MWD . 10372 19 94.02 15.36 8707.95 8659.30 -1462.67 477.41 5959440.45 692631.31 1184.08 13.76 MWD . 10403.37 93.35 19.83 8705.95 8657.30 -1433.02 486.81 5959470.33 692639.95 1176.22 14.47 MWD 10448 77 92.18 25.20 8703.76 8655.11 -1391.15 504.17 5959512.63 692656.24 1168.56 12.09 MWD . 10477.59 91.26 28.88 8702.89 8654.24 -1365.49 517.26 5959538.61 692668.67 1165.95 13.16 MWD 10507 19 91.90 33.04 8702.07 8653.42 -1340.13 532.48 5959564.35 692683.23 1165.29 14.21 MWD . 07 10539 92.27 37.33 8700.91 8652.26 -1314.09 550.83 5959590.84 692700.91 1166.93 13.50 MWD . 25 10568 91.69 42.03 8699.90 8651.25 -1291.66 569.45 5959613.75 692718.95 1170.70 16.22 MWD . 97 10600 90.92 46.18 8699.16 8650.51 -1268.17 592.21 5959637.81 692741.10 1177.43 12.90 MWD . 10641.81 92.33 53.52 8698.00 8649.35 -1241.87 623.39 5959664.90 692771.60 1189.77 18.29 MWD 10678.13 90.80 58.58 8697.01 8648.36 -1221.60 653.50 5959685.93 692801.17 1204.42 14.55 MWD 10712 93 89.82 56.93 8696.82 8648.17 -1203.03 682.93 5959705.24 692830.12 1219.41 5.51 MWD . 10744 13 88.96 52.04 8697.15 8648.50 -1184.92 708.32 5959724.00 692855.03 1231.22 15.91 MWD . 93 10773 93.04 50.25 8696.63 8647.98 -1166.23 731.51 5959743.27 692877.74 1240.87 14.95 MWD . 10802.83 92.58 46.63 8695.21 8646.56 -1147.08 753.11 5959762.96 692898.84 1248.92 12.61 MWD 10835 31 92.58 42.92 8693.75 8645.10 -1124.05 775.96 5959786.57 692921.09 1255.96 11.41 MWD . 10870.65 92.79 39.23 8692.09 8643.44 -1097.45 799.15 5959813.76 692943.59 1261.38 10.45 MWD 10900.61 91.20 36.53 8691.05 8642.40 -1073.81 817.53 5959837.85 692961.36 1264.33 10.45 MWD ~, BAKER • ~ ~ BP Alaska ~ rya HUGHES ~y ' ~ by "~~~~ Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 WeU: 18-24 Wellpath: 18-24B Survey ~blll Ind I ~l deg zim deg VD ft ys TVD ft Date: 10/14/2008 Time: 08:47:50 Page: 3 Co-ordinate(NE) Reference: Well: 18-24, True North Vertical (TVD) Reference: 46:24 5/31/1996 08:49 48.6 Section (VS) Rei'crencc: Well (O.OON,O.OOE,122.24Azi) Survev Calculation Method: Minimum Curvature Db: Oracle N/S E/W ~~1apN NIapE VS DLS Tool ft ft ft ft ft deg/100ft I 10928.69 90.95 32.58 8690.52 8641.87 -1050.70 833.45 5959861.36 692976.69 1265.46 14.09 MWD 10962.09 91.90 28.07 8689.69 8641.04 -1021.88 850.30 5959890.60 692992.80 1264.34 13.80 MWD 10991.75 91.57 23.64 8688.80 8640.15 -995.21 863.23 5959917.59 693005.04 1261.05 14.97 MWD 11021.01 93.66 20.07 8687.46 8638.81 -968.09 874.11 5959944.98 693015.22 1255.78 14.13 MWD 13 11053 91.96 16.32 8685.88 8637.23 -937.62 884.12 5959975.69 693024.45 1248.00 12.81 MWD . 11085.51 91.07 16.18 8685.03 8636.38 -906.54 893.18 5960006.99 693032.71 1239.08 2.78 MWD 11111.47 89.57 19.28 8684.88 8636.23 -881.82 901.09 5960031.90 693039.98 1232.58 13.27 MWD 11140.93 89.17 21.76 8685.21 8636.56 -854.23 911.41 5960059.74 693049.60 1226.59 8.53 MWD 11168.75 90.52 26.79 8685.28 8636.63 -828.88 922.84 5960085.38 693060.38 1222.74 18.72 MWD 11202.19 92.28 31.14 8684.47 8635.82 -799.64 939.03 5960115.02 693075.81 1220.83 14.03 MWD 11237.55 92.37 35.77 8683.03 8634.38 -770.17 958.50 5960144.98 693094.52 1221.58 13.09 MWD 11267.57 92.52 41.16 8681.75 8633.10 -746.70 977.15 5960168.92 693112.56 1224.83 17.95 MWD 11294 77 91.50 45.22 8680.79 8632.14 -726.88 995.75 5960189.20 693130.65 1229.99 15.38 MWD . 11325.84 89.66 49.11 8680.48 8631.83 -705.76 1018.53 5960210.89 693152.88 1237.99 13.85 MWD 11338.61 89.97 49.65 8680.52 8631.87 -697.45 1028.22 5960219.45 693162.35 1241.76 4.88 MWD 11382.00 89.97 49.65 8680.54 8631.89 -669.36 1061.29 5960248.38 693194.69 1254.74 0.00 MWD JELLHEAD= FMC ,CTUATOR= BAKERC B. ELEV = 48.6' F. ELEV = NIA OP = 4900' Tax Angle = 97 @ 9855' Tatum MD = N/A Datum TVD = 8800' SS DRLG DR~ 18-24B SAFETY NOTES: MULTILATERAL WELL WI 3 LEGS # 1 & 2 ISOLATED BY IBP @ 9100' 48' OF SAND?. WELL ANGLE > 70° @ 9271' &>90°@9517'. I 4-1/2" CAMCO TRCF-4A-TRSSSV, ID = 3.81 ~ LOCKED OUT(07/29/95) GAS LIFT MANDRELS V TYPE VLV LATC 10-3/4" CSG, 45.5#, L-80, ID = 9.950" ~ 3506' Minimum ID = 2.786" @ 8816' 3-1 /2" X 3-3/16" LNR X-OVER TOP OF TIEBACK SLV, ID = 5.75" 4651' 7-5/8" X 5-1/2" BKR H PKR, ID = 4.813" 4658' 7-5/8" X 5-1/2" SLH-6 HGR, ID = 4.875" 4664' 3-1/2" X 3-3/16" LNR XO, ID = 2.786" 4700 7-5/8" X 5-1/2" BKR LNR HGR ASSY 7$54' BTM OF BKR SEAL ASSY, ID = 4.875" ~-{ 7860' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~~ 8005' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" ~~ 8592' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" ~~ 8808' 3-1/2" X 3-3/16" LNR XO, ID = 2.786" ~~ 8816' Z I45202I40520I 3 I KBMGI~Ort BK I 20 110/29/08 4622' ~ 7-5/8" X 4-112" BKR S-3 PKR, ID = 3.875" 464$' 4-1/2" HES X NIP, ID = 3.813" 4631' ~BTT Deployment sleeve w / 4" GS Profile 4656' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958 4658' 4-1 /2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 8595' ~OL 2-3/8", TOC 5-1/Z" MILLOIIT' WINDOW (18-24AL2) 8891' - 8895' 9311' ~~ 3-3/16" packer w hipstock 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 9485' PERFORATION SUMMARY REF LOG: MCNL 10/18/08 A NGLE AT TOP PERF: 88 @ 9730' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56 6 9730 - 10150 O 10/19/08 1.56 6 10280 - 10350 O 10/19108 1.56 6 10410 - 10600 O 10/19/08 1.56 6 10670 - 10710 O 10/19/08 1.56 6 10750 - 10850 O 10/19/08 1.56 6 10960 - 11180 O 10/19/08 ~_ ~, PBTD 11215' 2-3/8" L-80 LINER. Cemented & Perforated 11250' FISH-DUAL PETREDAT GAUGES (08/11/07) PBTD 10451' 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" ~ 10486' 18-24AL2 (LEG #3~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/17/89 ORIGINAL COMPLETION 10/19/08 NORDIC1 CTD SIDETRACK (18-246) 05/01/95 R1G SIDETRACK (18-24A) 10/25/08 /TLH CORRECTIONS 05/27/95 CTD-IXTEND WELL-2-7/8"LN 11/10/08 JCM/SV GLV C/O (10/29/08) 10/25/95 CTD (18-24AL1) 05/24/99 CTD (18-24AL2) ~ n~ r~cvn~ ~ rurv n v ~ r~ ~uu~r ~ i v.nrc n ~ ~ PRUDHOE BAY UNff WELL: 18-24B PERMIT No: API No: 50-029-21952-02 SEC 19, T11 N, R15E, 4293' NSL & 4598' WEL ~~ ~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 07, 2008 Please find enclosed directional survey data for the following wells: 06-23C 07-30B 18-14C 18-24B 18-06B Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: U ,State of Alaska AOGCC DATE: ~ ~ ~ ~,, ~~ Cc: State of Alaska, AOGCC ~. 0 $ - l ~~ • i ALASSA OIL A1~TD GA.S C01~TSERVATIOI~T COMhII55I01~ Ron Phillips CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-24B BP Exploration Alaska Inc. Permit No: 208-143 Surface Location: 4293' FSL, 4598' FEL, SEC. 19, T11N, R15E, UM Bottomhole Location: 3574' FSL, 3736' FEL, SEC. 19, T11N, R15E, UM Dear Mr. Phillips: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this L Y day of September, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~&qp6~~ STATE OF ALASKA 9- ALAS~IL AND GAS CONSERVATION COMMI~N SAP Q ~ ~~~~~ PERMIT TO DRILL ~~~~ 20 AAC 25.005 q;<;~ Gi! & Gas Cari~o ~y ~°?at'~?i3sI0C2 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ ^ Service ^ ^ Stratigraphic Test ®Development Oil ^ Development Gas Multiple Zone Single Zone 1 c. Specify if well is propq(lifg~~6 ^ Coalbed Methane ^ Gas Hy rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 18-241 $ 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 11200' TVD 8640'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028321 Pool ~ ~ , FEL, SEC. 19, T11 N, R15E, UM 4293 FSL, 4598 Top of Productive Horizon: T11 N R14E UM 15' FEL SEC. 24 2451' FSL 8. Land Use Permit: 13. Approximate Spud Date: November 7, 2008 , , , , , Total Depth: 3574' FSL, 3736' FEL, SEC. 19, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-692117 y-5960890 Zone-ASP4 10. KB Elevation (Height above GL): 48.65' feet 15. Distance to Nearest Well Within Pool: 650' 16. Deviated Wells: Kickoff Depth: 9300 feet Maximum Hole An le: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3318 Surface: 2438 1 'n Pr r m: S if i n - in h- B m n' f nt .f. Y a Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data - / " 4.7# L- 0 T 25 7 8 11 I ' 1 g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10489' Total Depth TVD (ft): 7 2' Plugs (measured): None Effective Depth MD (ft): 10451' Effective Depth TVD (ft): 8730' Junk (measured): Yes, Unknown Depth Casing;.; Length Size Cement Volume MD TVD Conductor /Structural 1 4' 1 ' Surface 3 07' 1- /4" 1 x III x l I 7' ' Intermediate 7- / " 05' 7 4' in Liner 4 -1 x I ' - 1' 4 ' - 8 ' ' r 1 7' - /1 1 x '-1 8' '- 7 2' Perforation Depth MD (ft): 9350' - 10444' Perforation Depth TVD (ft): 8735' --8730' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property. Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Ron Phillips Si nature ~ a $ A ~' K f Contact Ron Phillips, 564-5913 Title CT Drilling Engineer. Prepared By Name/Number: oa hone 564-5913 Date b~' Terrie Hubble, 564-4628 Commission Use Od Permit To Drill N mb r• o?D~ ~,3 API Number: 50-029-21952-02-00 Permit Ap royal See cover letter for p ~ ther r it Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ,-/ Samples Req'd: ^ yes Ld No Mud Log Req'd: ,^,/Yes I~ No •~ HZS Measures: Yes ^ No Directional Survey Req'd: IYJ Yes ^ No Other: ~5~ PS°~ ~~ ~C ~S~ l Z~f - ~ Date APPROVED BY T COMMIASSIONER ~: Form 10-401 Revised 12/2005 Submit In Duplicate ,~ ~~.. ., by To: Tom Maunders Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips, CTD Engineer Date: August 25, 2008 RE: 18-24B Permit to Drill Request The sidetrack, 18-24B, is scheduled to be drilled by Nordic 1 around November 7~', 2008. The plan calls for a slimhole lateral with a solid liner and 1000 ft of perforations in Zone lA. Pre-Rig Work: 1. MIT-IA, and OA. 2. Dummy WS (15' x 2.625") drift to 9340' 3. Set BPV 4. AC-LDS; AC-PPPOT-T 5. Test MV, SV, WV 6. Bleed gas lift and production flowlines down to zero and blind flange 7. Remove wellhouse, level pad The pre CTD work is slated to begin on October 15th, 2008. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high, Pull BPV '~ Cat '2_2/1 F,"mnnnhnra narlrar uihinetnrlr (7 Q'2(1(1' 3. Mi112.74" window at 9300' and 10' of openhole. Swap the well to Flo-Pro 4. Drill Build: 3" OH, 380', 30 deg/100 (plan #1) 5. Drill Lateral: 3" OH, 1,520' horizontal, 12 deg/100 (plan #1) 6. Run 2 3/8" solid liner leaving TOL at 8700' . 7. Pump primary cement job to TOL, 11.3 bbl of 15.8 ppg cmt planned. 8. Run CO assembly 9. Run MCNL/GR/CCL log 10. Test liner lap to 2000 psi. 11. Perforate, planned 1000ft. 12. Freeze protect well, Set BPV, RDMO Post-Rig Work: 1. Pull BPV 2. Re-install wellhouse and FL's. 3. Generic GLV design i 1r~"~ S ~Jct_~~c"~ Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" r ~ • Casing Program: • 2 3/8", 4.7# , L-80, STL connection Solid liner - 8700' - 11200' MD • A minimum of 11.3 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 8700' (TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 93 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 24,700' • Distance to nearest well within pool - 650' ft to L2-03A Anticollision Summary • With Global Scan Applied all wells pass major anticollision. Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on DS 18 is 20 ppm on 18-14B. • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3,318 psi at 8,800'ss (7.25 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2438 psi. Ron Phillips CTD Drilling Engineer 564-5913 CC: Well File Sondra Stewman/Terrie Hubble TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATO)~ = BAKER C KB. ELEV = 48.6' BF. ELEV - WA KOP = 4900' Max Angle = 97 @ 9855' Datum MD = WA Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.950" Minimum ID = 2.786" @ 8816' 3-1/2" X 33/16" LNR X-0VER TOP OF TIEBACK SLV, ID = 5.75" 4651' 7-5/8" X 5-1/2" BKR H PKR ID = 4.813" 4658' 7-5/8" X 5-1/2" SLH-6 HGR, ID = 4.875" 4664' 7-518" X 5-1/2" BKR LNR HGR ASSY ~~ 7$54' BTM OF BKR SEAL ASSY, ID = 4.875" ~~ 7$60' SAFETY NOTES: MULTILATERAL WELL W/ 3 18-24AL2 4SAND. WELLANGLE~O°@g@1100'W/ 7-5/8" CSG, 29.7#, L-80, ID = 6.875" $005' ~ 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" ~ 3-1/2" X 3-3/16" LNR XO, ID = 2.786" ~-~ $816' 2;207' 4-1/2" CAMCO TRCF-4A-TRSSSV, ID = 3.812" LOCKED OUT(07/29/95) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3020 4522 3019 4520 2 3 KBMG KBMG DMY DMY BK BK 0 0 08/15/95 04/07/08 7-5/8" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP,ID = 3.813" 4~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 465$' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 5-1/2" MILLOUT WINDOW (18-24AL2) 8891' - 8895' ? ~-~ FISH-DUAL PEfREDAT GAUGES (08/11 TOP OF SAND (05/09/99) ~ 9046' 3.38" OD BKR IBP (05/05/99) 9100' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 9485' PERFORATION SUMMARY REF LOG: BHCA ON 04/25/95 A NGLE AT TOP PERF: 76 @ 9350' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9350 - 9400 O 05/24/99 2-7/8" SLTD 9513 - 10395 C 05/05/99 2-7/8" SLTD 9518 - 9932 C 05/05/99 2" 4 9670 - 10225 O 05/24/99 2" 4 10274 - 10444 O 05/24/99 I PBTD 1 18-24AL2 (LEG #3) 3-3/16" LNR 6.2#, L-80, .0076 bpf, ID = 2.786" ~--~ 1 I I _ I ~-~ __ ~- '~- _ 1 I'~-~ ~~-_ _ I ~ ~-_~_ l ~ "- ~ ~ ~~~ ~ ~ ~~ ~~ ~~\ 18-24AL1 (LEG#2) ~ ~ ~ ~ ~ ~ ~ ~ 18-24A (LEG #1) ~ ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/17/89 ORIGINAL COMPLETION 06/15/03 CMO/TLP KB ELEVATION CORRECTION 05/01/95 RIG SIDETRACK (18-24A) 09/13/03 CMO/TLP DATUM MD & PERF ANGLE 05/27/95 CTD-IXTEND WELL-2-7/8"LN 09/22/07 RCT/SV FISH (08/11/07) 10/25/95 CTD (18-24AL1) 04/17/08 KJB/TLH GLV GO (04/08/08) 05/24/99 CTD (18-24AL2) 01/29/02 CH/KAK CORRECTIONS PRUDHOE BAY UNff WELL: 18-24AL2 PERMIT No: 1990410 API No: 50-029-21952-61 SEC 19, T11 N, R15E, 4293' NSL & 4598' WEL BP 6cploration (Alaska) TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 48.6' BF. ELEV = WA KOP = 4900' Max Angle = 97 @ 9855' Datum MD = WA Datum TVD = 8800' SS ~ 18 2 4 B SAFETY NOTES: MULTILATERAL WELL W/ 3 L~LEGS # 1 8~ 2 ISOLATED BY IBP @ 9100' W/ Proposed CTD Sidetrack 4 SAND. WELL ANGLE> 70° @x271'. 2207' 4-1/2" CAMCO TRCF-4A-TRSSSV, ID = 3.812" LOCKED OUT(07/29/95) GAS LIFT MANDRELS 10-314" CSG, 45.5#, L-80, ID = 9.950" ~~ 3506' Minimum ID = 2.786" @ 8816' 3-1/2" X 3-3/16" LNR X-OVER TOP OF TIEBACK SLV, ID = 5.75" 4651' 7-5/8" X 5-1/2" BKR H PKR, ID = 4.813" 4658' 7-5/8" X 5-1/2" SLH-6 HGR, ID = 4.875" 4664' 7-5/8" X 5-1/2" BKR LNR HGR ASSY 11 785x' BTM OF BKR SEAL ASSY, ID = 4.875" 7860' ~ 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3020 3019 2 KBMG DMY BK 0 08/15/95 2 4522 4520 3 KBMG DMY BK 0 04/07/08 7-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4656' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 4658' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 8700' ~~ TOL 2-3/8", TOC ~ 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" ~ 3-1/2" X 3-3/16" LNR XO, ID = 2.786" ~~ 8816' 5-1/2" MILLOUT WINDOW (18-24AL2) 8891' - 8895' 9300' )~ 3-3/16" monobore w hipstock 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 9485' PERFORATION SUMMARY REF LOG: BHCA ON 04/25/95 ANGLE AT TOP PERF: 76 @ 9350' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9350 - 9400 O 05/24/99 2" 4 9670 - 10225 O 05/24/99 2" 4 10274 - 10444 O 05/24/99 2-3/8" L-80 LINER, Cemented & Perforated 11200' FISH-DUAL PETREDAT GAUGES (08/11/07) I PBTD I I3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" 18-24AL2 (LEG #3) DATE REV BY COMMENTS DATE REV BY COMMENTS 07/17/89 ORIGINAL COMPLETION 06/15/03 CMO/TLP KB ELEVATION CORRECTION 05/01/95 RIG SIDETRACK (18-24A) 09/13/03 CMO/TLP DATUM MD & PERF ANGLE 05/27/95 CTD-IXTEND WELL-2-7/8"LN 09/22/07 RCT/SV FISH (08/11/07) 10/25/95 CTD (18-24AL1) 04/17/08 KJB/TLH GLV GO (04/08/08) 05/24/99 CTD (18-24AL2) 06/25/08 MSE PROPOSED CTD SIDETRACK PRUDHOE BAY UNff WELL: 18-24B PERMff No: API No: 50-029-21952-02 SEC 19, T11 N, R15E, 4293' NSL & 4598' WEL BP Exploration (Alaska) by i BP Alaska Baker Hughes INTEQ Planning Report I/.~~ sAg u. a "'a,~ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 i Well: 18-24 Wellpath: Plan 1, 18-24B Date: 7/11 /2008 Time: 11:36:10 Page: l Co-ordinate(NE) Reference: W ell: 18-24, True North Vertical (TVD) Reference: 46:24 5/31/1996 08:49 48.6 Section (VS) Reference: Well (O.OON,O.OOE,35.OOAzi) Surve Calculatign Method: Minimum Curvature Db: Oracle ------ y - -- -__- __ _-~ Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.46 deg Well: 18-24 Slot Name: 24 18-24 Well Position: +N/-S 1663.16 ft Northing: 5960890.35 ft Latitude: 70 17 51.609 N +E/-W 575.87 ft Easting : 692116.70 ft Longitude: 148 26 38.768 W Position Uncertainty: 0.00 ft Wellpath: Plan 1, 18-246 Drilled From: 18-24AL2 50029 Tie-on Depth: 9297,07 ft Current Datum: 46:24 5/31 /1996 08:49 Height 48.65 ft Above System Datum: Mean Sea Level Magnetic Data: 7/11/2008 Declination: 23.26 deg Field Strength: 57686 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.65 0.00 0.00 35.00 Plan: Plan #1 Date Composed: 7/11/2008 copy Marys plan 1 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets -- -- -__ - Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +FJ-W Northing Eastin g Deg Min Sec Deg Mi n Sec Dip. Dir. ft ft (t ft ft 18-246 Fault 1 48.65 -1558.58 -796.85 5959312 .00 691360 .00 70 17 36 .280 N 148 27 1.991 W -Polygon 1 48.65 -1558.58 -796.85 5959312 .00 691360 .00 70 17 36 .280 N 148 27 1.991 W -Polygon 2 48.65 -1444.64 263.47 5959453 .00 692417 .00 70 17 37 .401 N 148 26 31.090 W -Polygon 3 48.65 -1556.98 548.71 5959348 .00 692705 .00 70 17 36 .296 N 148 26 22.777 W -Polygon 4 48.65 -1742.97 663.00 5959165 .00 692824 .00 70 17 34 .467 N 148 26 19.446 W -Polygon 5 48.65 -101987.30 -1850.48 5858895 .00 692874 .00 70 1 8 .551 N 148 27 31.921 W -Polygon 6 48.65 -1742.97 663.00 5959165 .00 692824. 00 70 17 34. 467 N 148 26 19.446 W -Polygon 7 48.65 -1556.98 548.71 5959348 .00 692705. 00 70 17 36. 296 N 148 26 22.777 W -Polygon 8 48.65 -1444.64 263.47 5959453 .00 692417. 00 70 17 37. 401 N 148 26 31.090 W 18-24B Polygon 48.65 -1787.84 -281.51 5959096 .00 691881. 00 70 17 34. 026 N 148 26 46.972 W -Polygon 1 48.65 -1787.84 -281.51 5959096 .00 691881. 00 70 17 34. 026 N 148 26 46.972 W -Polygon 2 48.65 -2161.27 -153.01 5958726 .00 692019. 00 70 17 30. 353 N 148 26 43.227 W -Polygon 3 48.65 -1715.57 686.71 5959193 .00 692847. 00 70 17 34. 736 N 148 26 18.755 W -Polygon 4 48.65 -650.67 1098.09 5960268 .00 693231. 00 70 17 45. 209 N 148 26 6.762 W -Polygon 5 48.65 -586.10 724.60 5960323 .00 692856. 00 70 17 45. 845 N 148 26 17.648 W -Polygon 6 48.65 -1473.73 344.76 5959426 .00 692499. 00 70 17 37. 115 N 148 26 28.721 W 18-246 Target 3 8688.65 -712.75 865.41 5960200 .00 693000. 00 70 17 44. 599 N 148 26 13.544 W 18-246 Target 2 8700.65 -1268.33 645.13 5959639 .00 692794. 00 70 17 39. 135 N 148 26 19.966 W 18-248 Target 1 8725.65 -1747.72 144.68 5959147. 00 692306. 00 70 17 34. 421 N 148 26 34.552 W by • BP Alaska Baker Hughes INTEQ Planning Report ri~r s ~ %s INTEQ Company: BP Amoco Date: 7!11/2008 Time: 11 :36:10 Page: 2 ~ Field: Prudhoe Bay Go-ordinate(NE) Reference: Well: 18-24, T rue North Site: PB DS 18 Vertical (TVD) Reference: 46:24 5/31 /1996 08:49 48 .6 W'e1L 18-24 Section (VS) Reference: Well (O.OON,O. OOE,35.OOAzi) Wellpath: Plan 1, t8-246 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation NID T VD ft ft 9297.07 8720.74 TIP 9300.00 8721.60 KOP 9320.00 8727.14 End of 9 Deg/100' DLS 9350.00 8733.00 4 9380.00 8735.65 5 9580.00 8735.40 End of 30 Deg/100' DLS 9680.00 8731.24 7 9880.00 8725.06 8 10180.00 8715.32 9 10280.00 8711.78 10 10580.00 8699.90 11 10780.00 8693.59 12 11030.00 8689.39 13 11200.00 8688.16 TD Plan Section Information MD Inc! Azim TVD +N/-S +Ef-W DLS 'Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9297.07 72.86 133.14 8720.74 -1886.24 -329.12 0.00 0.00 0.00 0.00 9300.00 73.02 132.91 8721.60 -1888.15 -327.07 9.28 5.46 -7.85 306.01 9320.00 74.82 132.91 8727.14 -1901.24 -313.00 9.00 9.00 0.00 0.00 9350.00 82.65 128.39 8733.00 -1920.37 -290.69 30.00 26.11 -15.08 330.00 9380.00 87.21 120.59 8735.65 -1937.27 -266.08 30.00 15.18 -25.98 300.00 9580.00 92.92 60.84 8735.40 -1939.66 -75.11 30.00 2.86 -29.88 275.00 9680.00 91.82 48.88 8731.24 -1882.25 6.44 12.00 -1.10 -11.96 265.00 9880.00 91.67 72.89 8725.06 -1785.69 179.81 12.00 -0.08 12.01 90.00 10180.00 91.93 36.87 8715.32 -1616.04 421.06 12.00 0.09 -12.01 271.00 10280.00 92.10 48.88 8711.78 -1542.93 488.93 12.00 0.17 12.01 89.00 10580.00 92.29 12.85 8699.90 -1289.84 640.20 12.00 0.06 -12.01 271.00 10780.00 91.28 36.84 8693.59 -1109.78 723.60 12.00 -0.51 12.00 92.00 11030.00 90.61 6.85 8689.39 -880.40 815.54 12.00 -0.27 -12.00 269.00 11200.00 90.22 27.24 8688.16 -718.73 865.10 12.00 -0.23 12.00 91.00 Survey MD Inc! Azim SSTVD N/S- E/W MapN MapE DLS VS TFO 'Cool ` #t deg deg ft ft ft ft ft degl100 ft ft deg I 9297.07 72.86 133.14 8672.09 -1886.24 -329.12 5958996.42 691835.92 --- 0.00 -1733.90 0.00 MWD 9300.00 73.02 132.91 8672.95 -1888.15 -327.07 5958994.56 691838.02 9.28 -1734.29 306.01 MWD 9314.41 74.32 132.91 8677.00 -1897.57 -316.95 5958985.41 691848.38 9.00 -1736.19 360.00 18-24B 9320.00 74.82 132.91 8678.49 -1901.24 -313.00 5958981.84 691852.42 9.00 -1736.93 0.00 MWD 9330.00 77.42 131.37 8680.89 -1907.75 -305.80 5958975.52 691859.78 30.00 -1738.14 330.00 MWD 9340.00 80.03 129.87 8682.84 -1914.13 -298.36 5958969.33 691867.39 30.00 -1739.10 330.37 MWD 9350.00 82.65 128.39 8684.35 -1920.37 -290.69 5958963.29 691875.21 30.00 -1739.81 330.66 MWD 9360.00 84.16 125.78 8685.49 -1926.36 -282.77 5958957.50 691883.29 30.00 -1740.17 300.00 MWD 9370.00 85.68 123.18 8686.38 -1932.00 -274.56 5958952.08 691891.64 30.00 -1740.08 300.30 MWD 9380.00 87.21 120.59 8687.00 -1937.27 -266.08 5958947.03 691900.24 30.00 -1739.54 300.53 MWD 9390.00 87.47 117.60 8687.46 -1942.13 -257.35 5958942.40 691909.09 30.00 -1738.51 275.00 MWD 9400.00 87.74 114.61 8687.88 -1946.52 -248.38 5958938.23 691918.17 30.00 -1736.96 275.14 MWD 9410.00 88.02 111.62 8688.25 -1950.44 -239.19 5958934.54 691927.46 30.00 -1734.91 275.26 MW D 9420.00 88.31 108.63 8688.57 -1953.88 -229.81 5958931.35 691936.93 30.00 -1732.34 275.37 MW D 9430.00 88.59 105.65 8688.84 -1956.83 -220.26 5958928.65 691946.55 30.00 -1729.27 275.47 MWD 9440.00 88.89 102.66 8689.06 -1959.27 -210.56 5958926.45 691956.30 30.00 -1725.72 275.55 MW D 9450.00 89.18 99.67 8689.23 -1961.21 -200.76 5958924.77 691966.15 30.00 -1721.68 275.62 MW D 9460.00 89.48 96.69 8689.35 -1962.63 -190.86 5958923.60 691976.08 30.00 -1717.17 275.67 MW D 9470.00 89.78 93.70 8689.41 -1963.54 -180.90 5958922.95 691986.06 30.00 -1712.20 275.70 MW D 9480.00 90.08 90.72 8689.43 -1963.92 -170.91 5958922.82 691996.06 30.00 -1706.78 275.72 MW D 9490.00 90.37 87.73 8689.39 -1963.79 -160.91 5958923.21 692006.05 30.00 -1700.94 275.73 MWD 9500.00 90.67 84.75 8689.30 -1963.13 -150.94 5958924.12 692016.00 30.00 -1694.68 275.71 MWD by ~ BP Alaska Baker Hughes INTEQ Planning Report ~i.r ~g u. a .•.~ Company: ' BP Amoco Field: Prudhoe Bay Site: PB DS 18 Wcll: 18-24 Weltpath: Plan 1, 18-24B Survev MI) Incl Aa ft deg 9510.00 90.97 ~~ 9520.00 91.26 9530.00 91.55 9540.00 91.84 9550.00 92.12 9560.00 92.39 9570.00 92.66 9580.00 92.92 9600.00 92.71 9625.00 92.44 9650.00 92.16 9675.00 91.88 9680.00 91.82 9700.00 91.82 9725.00 91.81 9750.00 91.80 9775.00 91.79 9800.00 91.77 9825.00 91.74 9850.00 91.71 9875.00 91.67 9880.00 91.67 9900.00 91.71 9925.00 91.75 9950.00 91.79 9975.00 91.83 10000.00 91.86 10025.00 91.89 10050.00 91.91 10075.00 91.93 4 10100.00 91.94 4 10125.00 91.94 4 10150.00 91.94 4 10175.00 91.94 3 10180.00 91.93 3 10200.00 91.98 3 10225.00 92.02 4 10250.00 92.06 4 10275.00 92.09 4 10280.00 92.10 4 10300.00 92.14 4 10325.00 92.19 4 10350.00 92.22 4 10375.00 92.26 3 10400.00 92.28 3 10425.00 92.30 3 10450.00 92.32 2 10475.00 92.32 2 10500.00 92.33 2 10525.00 92.32 1 10550.00 92.31 1 10575.00 92.29 1 10580.00 92.29 1 Date: 7/11/2008 Time: 11:36:10 Page. 3 Co-ordinate(NE) Reference: Well: 18-24, True North Vertical (TVD) Reference: 46:24 5/31 /1996.08:49 48.6 :Section (VS) Reference: Well (O.OON,O.OOE,35.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle _ _- ___ _~ m SS TVD deg'. ft 81.76 8689.15 78.77 8688.96 75.79 8688.71 72.80 8688.42 69.81 8688.07 66.82 8687.68 63.83 8687.23 60.84 8686.75 58.45 8685.76 55.45 8684.64 52.47 8683.63 49.48 8682.75 48.88 8682.59 51.28 8681.95 54.28 8681.16 57.28 8680.37 60.28 8679.59 63.29 8678.81 66.29 8678.05 69.29 8677.30 72.29 8676.56 72.89 8676.41 70.49 8675.82 67.49 8675.07 64.49 8674.30 61.49 8673.51 58.48 8672.70 55.48 8671.88 52.48 8671.05 9.48 8670.22 6.48 8669.37 3.48 8668.53 0.47 8667.68 7.47 8666.83 6.87 8666.67 9.27 8665.98 2.28 8665.11 5.28 8664.22 8.28 8663.31 8.88 8663.13 6.48 8662.39 3.48 8661.45 0.47 8660.49 7.47 8659.51 4.47 8658.52 1.47 8657.52 8.46 8656.51 5.46 8655.50 2.46 8654.48 9.46 8653.47 6.45 8652.46 3.45 8651.45 2.85 8651.25 N/S E/W MapN ft ft ft 1961. 96 -141 .01 5958925.55 1960. 27 -131 .15 5958927.49 1958. 06 -121 .40 5958929.94 1955. 36 -111 .78 5958932.89 1952. 16 -102 .32 5958936.33 1948. 46 -93 .03 5958940.26 1944. 30 -83 .96 5958944.66 1939. 66 -75 .11 5958949.52 1929. 56 -57 .88 5958960.05 1915. 94 -36 .94 5958974.20 1901. 25 -16 .75 5958989.41 1885. 52 2 .66 5959005.63 1882. 25 6 .44 5959008.99 1869. 42 21 .77 5959022.20 1854. 31 41 .67 5959037.82 1840. 26 62. 33 5959052.39 1827. 31 83 .69 5959065.88 1815. 50 105. 71 5959078.25 1804. 86 128. 32 5959089.47 1795. 41 151. 45 5959099.50 1787. 19 175. 04 5959108.32 1785. 69 179. 81 5959109.94 1779. 41 198. 79 5959116.70 1770. 46 222. 11 5959126.25 1760. 29 244. 94 5959137.00 1748. 94 267. 20 5959148.91 1736. 44 288. 83 5959161.96 1722. 83 309. 78 5959176.10 1708. 14 329. 99 5959191.31 1692. 41 349. 40 5959207.52 1675. 69 367. 96 5959224.72 1658. 01 385. 61 5959242.83 1639. 44 402. 32 5959261.83 1620.02 418. 04 5959281.64 1616. 04 421. 06 5959285.70 1600. 30 433. 38 5959301.74 1581. 38 449. 70 5959321.07 1563. 35 466. 98 5959339.54 1546. 24 485. 18 5959357.11 1542. 93 488. 93 5959360.51 1529. 48 503. 71 5959374.34 1511. 81 521. 36 5959392.45 1493. 24 538. 07 5959411.44 1473. 82 553. 78 5959431.26 1453. 60 568. 45 5959451.84 1432. 65 582. 04 5959473.13 1411. 01 594. 52 5959495.08 1388. 75 605. 84 5959517.62 1365. 92 615. 98 5959540.70 1342. 60 624. 92 5959564.24 1318. 84 632. 62 5959588.19 1294. 71 639. 06 5959612.48 1289. 84 640. 20 5959617.37 NIapE DLS ft deg/100ft 692025.90 30.00 692035.71 30.00 692045.40 30.00 692054.94 30.00 692064.32 30.00 692073.51 30.00 692082.48 30.00 692091.20 30.00 692108.17 12.00 692128.75 12.00 692148.56 12.00 692167.56 12.00 692171.25 12.00 692186.25 12.00 692205.75 12.00 692226.04 12.00 692247.07 12.00 692268.78 12.00 692291.10 12.00 692313.98 12.00 692337.36 12.00 692342.09 12.00 692360.90 12.00 692383.99 12.00 692406.54 12.00 692428.50 12.00 692449.81 12.00 692470.40 12.00 692490.22 12.00 692509.22 12.00 692527.35 12.00 692544.55 12.00 692560.78 12.00 692575.99 12.00 692578.90 12.00 692590.82 12.00 692606.65 12.00 692623.46 12.00 692641.22 12.00 692644.88 12.00 692659.31 12.00 692676.51 12.00 692692.73 12.00 692707.94 12.00 692722.09 12.00 692735.14 12.00 692747.06 12.00 692757.81 12.00 692767.36 12.00 692775.70 12.00 692782.79 12.00 692788.61 12.00 692789.62 12.00 VS ft TFO deg Tool -1688.02 275.69 MWD -1680.98 275.64 MWD -1673.59 275.59 MWD -1665.85 275.51 MWD -1657.80 275.42 MW D -1649.45 275.32 MW D -1640.83 275.20 MWD -1631.96 275.07 MWD -1613.80 265.00 MWD -1590.64 264.88 MWD -1567.02 264.75 MWD -1543.00 264.63 MWD -1538.16 264.52 MWD -1518.86 90.00 MWD -1495.06 90.08 MWD -1471.71 90.17 MW D -1448.84 90.27 MW D -1426.54 90.36 MWD -1404.85 90.45 MW D -1383.85 90.55 MWD -1363.58 90.64 MWD -1359.62 90.72 MWD -1343.59 271.00 MWD -1322.87 270.93 MWD -1301.45 270.84 MWD -1279.39 270.75 MWD -1256.75 270.65 MW D -1233.58 270.55 MWD -1209.95 270.46 MWD -1185.94 270.36 MWD -1161.59 270.26 MWD -1136.99 270.16 MWD -1112.19 270.05 MWD -1087.27 269.95 MWD -1082.27 269.85 MWD -1062.31 89.00 MWD -1037.46 89.08 MW D -1012.77 89.19 MW D -988.32 89.29 MW D -983.46 89.40 MW D -963.96 271.00 MW D -939.36 270.91 MW D -914.57 270.80 MW D -889.65 270.68 MW D -864.67 270.56 MW D -839.71 270.45 MW D -814.83 270.33 MW D -790.10 270.20 MW D -765.59 270.08 MW D -741.36 269.96 MW D -717.48 269.84 MW D -694.01 269.72 MW D -689.37 269.60 MW D by ~ BP Alaska ~ ~~a~ Baker Hughes INTEQ Plannin Report g INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 We1L• 18-24 Wellpath: Plan 1, 18-248 Survey MD Inc! Azim ft deg deg S TVD ft /S ft /W `ft Date: 7!11/2008 Time: 11:36:10 Page: 4 Co-ordinate(NE) Reference: W ell: 18-24, True North Vertical (TVD) Reference: 46:24 5/31 /1996 08:49 48.6 Section (YS) Reference: Well (O.OON,O.OOE,35.OOAzi) SurveyCalcula6onMethod: Minimum Curvature Db: Oracle RfapN NIapE DLS VS TFO Tool ft ft deg/100ft ft deg 10600.00 92 .20 15.25 8650.47 -1270.46 645 .05 5959636.87 692793.98 12. 00 -670.71 92.00 MWD 10625.00 92 .09 18.25 8649.53 -1246.54 652 .25 5959660.97 692800.57 12. 00 -646.99 92.09 MWD 10650.00 91 .97 21.25 8648.65 -1223.03 660 .69 5959684.68 692808.40 12. 00 -622.89 92.21 MWD 10675.00 91 .85 24.25 8647,82 -1199.99 670 .36 5959707.96 692817.47 12. 00 -598.47 92.31 MWD 10700.00 91 .72 27.25 8647.04 -1177.48 681 .21 5959730.73 692827.75 12. 00 -573.81 92.41 MWD 10725.00 91 .58 30.25 8646.32 -1155.58 693 .23 5959752.94 692839.20 12. 00 -548.97 92.51 MWD 10750.00 91 .45 33.25 8645.66 -1134.33 706. 38 5959774.52 692851.80 12. 00 -524.03 92.59 MWD 10775.00 91 .30 36.24 8645.06 -1113.79 720 .62 5959795.41 692865.51 12. 00 -499.04 92.67 MWD 10780.00 91 .28 36.84 8644.94 -1109.78 723. 60 5959799.50 692868.39 12. 00 -494.04 92.74 MWD 10800.00 91 .23 34.44 8644.51 -1093.53 735. 25 5959816.04 692879.62 12. 00 -474.05 269.00 MWD 10825.00 91 .18 31.44 8643.98 -1072.56 748. 84 5959837.35 692892.67 12. 00 -449.07 268.95 MW D 10850.00 91 .12 28.44 8643.48 -1050.90 761. 31 5959859.32 692904.58 12. 00 -424.18 268.88 MW D 10875.00 91 .05 25.44 8643.01 -1028.62 772. 64 5959881.88 692915.33 12. 00 -399.43 268.82 MWD 10900.00 90 .99 22.44 8642.56 -1005.78 782. 78 5959904.97 692924.89 12. 00 -374.90 268.77 MWD 10925.00 90 .92 19.44 8642.15 -982.43 791. 71 5959928.53 692933.22 12. 00 -350.66 268.71 MW D 10950.00 90 .85 16.44 8641.76 -958.66 799. 41 5959952.50 692940.31 12. 00 -326.76 268.66 MW D 10975.00 90. 77 13.44 8641.41 -934.51 805. 86 5959976.80 692946.14 12. 00 -303.28 268.62 MW D 11000.00 90 .70 10.45 8641.08 -910.05 811. 03 5960001.38 692950.68 12. 00 -280.28 268.58 MW D 11025.00 90 .62 7.45 8640.80 -885.36 814. 92 5960026.16 692953.94 12. 00 -257.83 268.54 MW D 11030.00 90. 61 6.85 8640.74 -880.40 815. 54 5960031.14 692954.43 12. 00 -253.41 268.50 MW D 11050.00 90. 56 9.25 8640.54 -860.60 818. 34 5960051.00 692956.72 12. 00 -235.58 91.00 MW D 11075.00 90. 51 12.25 8640.31 -836.04 823. 00 5960075.67 692960.75 12. 00 -212.79 91.02 MW D 11100.00 90. 45 15.24 8640.10 -811.76 828. 94 5960100.09 692966.07 12. 00 -189.50 91.05 MW D 11125.00 90. 40 18.24 8639.91 -787.82 836. 14 5960124.20 692972.66 12. 00 -165.76 91.08 MW D 11150.00 90. 34 21.24 8639.75 -764.30 844. 58 5960147.94 692980.50 12. 00 -141.64 91.10 MW D 11175.00 90. 28 24.24 8639.62 -741.24 854. 25 5960171.23 692989.57 12. 00 -117.22 91.12 MWD 11200.00 90. 22 27.24 8639.51 -718.73 865. 10 5960194.01 692999.84 12. 00 -92.54 91.14 MW D BP Alaska wELL.wTKDETNLB LEGEND ~r.~r1 --- ,e-241,8-z4, 18-24 l1&24A) BAKER ,B.y41,B.24AL,) Hu~~~ by __ ,6an4 (,B 24AL2) PI 1. 18-248 Plan yt vv.. n.~xi lia zvrx.,~ ~azae . w°,°v eLL,,,.,.Wa Ma°nnK~~nz3 n ryL~F.Mp ~nre sz°°a51 ~im o e c . .. Tl.aa a2~,a o: NTEQ nma~ an~ ~ae. ~lila oue eso~i amn~uaemzwz I~zj~nxe szo t,na.a ~ a7~,m i - - I a2 BB 3,aa' aa4 aaa - 10 I . ~ _ - -r ~n- _-- - - - -- ---~ i .. i. 1 .I , 4 ~ ~- 1 I ~ ~ I _ II: _ I ... 1 a I N 8 IaN0 Ii• OIR 5 I I rR I C a ~ ++ - + Y r ~->- I_-. '. .. _, ~ i T i - - tt ~ ~ , } - +T ,.. ? -~ (.. 78.248 Tar at7 ~ ( _. I-~ r B Mr ire aB65 'Jnc rva ~.e c:z c, n u M.nw M ~ - ~ iI 7 . ~~ ~ . I I ~ ... L - Plen 1 18-248 ~~ II qp r ~ - YTr I i ~y ~ t I _ __ y `` , 1' 1~k I I .r ~ .~ L~..1 ~ _.~ ~ waaw. ~~ ~ 55 aw r~ nr a ti Tamar * _ - 1 - t- ~-. L } L } ..:. I '-I- -(- .I l .. y- ~ 7 _ 1 1 ~..~ r + I w J. 1 1 i ~ r ~ F- - h r r.. 11 ~ ~~ 1L 1 ~ III } ~' ~l _ a oast ra~°n iai°°ia ~~°1-°r° ~°w_~iii _ a aaaaa tea= • aaataa sus I . (.. :- i _ ._ m T -... ~~ aaaaaa aaaan -naa i0aa° n~°° ~aiy ~ nap°iaS°i ~~ aiai • wawa uw area rasa aai°ia° na~wa f swam aM a r°'°° ~~ ~ u I ~ I 1 i +' - I .. L 4 I rr }- yr 1 ( -. t 1 ~ 1 {~ i~~ s ' - - - T t ' - t I r t ~~ ~ ~ 4 ' 1 y I .. '. ' ~ i aw r n v waaa ia oaaa ia aa nv nwarr naamaw 1Y° ~aJ°ya as aaarr 6°° atria mN ~ iiiaaw°°°anaa wa sass wa°wn nas atw ~~ aar. ii ^ w s °u° 1°°~ V° 'r 1 i f~ Y I I ~ I ~ t I t ~j I r+ T. 1...- ~ I i i ' I, i ~~ -f I F-- ~ 1' ~ ~ T - T7 - ri T , 1. I I .~ L ~' i - n ia sa waur~ nx aa ia ia ss ' - ~~~ `_ .anal.,,ana s .I Y F i ~ r t ~R I ~ ~ I T; ~,t ~I~ ~ ss rvo ao t,.,.aau.,, u.nK aaax °a azaT.or ie zae ya~ni aana n°o aa Kov I 1-. ~ ~ z{ r r ~ y. . 76248 T i C ~ { y ~ 1 ~ T + ~ ~ ~ ~ (- 1.a., 1 13 1 1 ~ - ~ I I I +~ " r at2 a . azae ao rv.,~ e°au is °°zsoa aw mvars'aw ws ie zae r.ramn a°w.oa a la zae m z Nan _ + ~ y. '. ° + (' nD 1 .. -- ~ . _ ~ a ~ ~ I . T ,pa ewa oo ai rwvaw wa iazae a noo n°-z.~z vane ,u.s° 1 -... ~ ~-il -+- y # J1 Tt~ i-' i . t ` ~ ~~ # - ~~ +. ~ - - aa.~w.a,ww ,: I _ T T. z , 4 - + L. ,-. _ ~ _ a ~ I. 18-248 Fault 1 ~ l i -~-~ l~ t I _~ ~ I t _ 10 1 { ~ 1 J r ' =- o I ~~ - 116248 Polygon }- - ' fff % t -- rr I 162a to-24 I ^e - }~?~F ~ ~r -- I - 1_ ~ ' ~ ~,-1 ~ I` ~j amo1 * r ~~ i- }~T y, r li II I _~ r --, I - y ~ - i r~ -- }+ -~ I -. -T.-Y t I J ~ - TIP ~ ~ •-•. I T ~ I~ .~ IT- ,_-r i I, T' - I I_ 't-i I~I ,. I I 1 ~ 11 1 ~ { 1 - f ~ I I .~ .. III j ;.. -[ 1 't ' l .aaw_ a8-2118-24AL1 KOP 7 Entl of 9 Da I10g' D \ + ` r ~ 1 ~~ - ~ ~ I { i 4 _ r _ ~ ~ ~O _ ~ rt g ~ } ~ t 1~ f I [ 24B T i I p t ' - - _ I ez ' II ~~~ r~.rT I I r. . \ .. - arge zwo ~ i _ Ti _ \ I tot ~f} ~1 i..~. ++-t~ .~~ rf~~~ t t - 18 24 1624A L .. F-.~. . I I, I T+' t t + ~. i ... 1 . ~ -z a° , Entl of 30 Deg1100' Dl -'~- -- -- T -^T _ + .~ ~ nxsu ~,~ ,z~ .-- -_ . - 1624 1624AL2fl I ..:. .._ . - ,...-.. I TF T ~ i I D Z ~ '. ' ~. ~ '- - ~ ~ T _ . w+ - - . . ia° laa° -°°o a°° aa° a°a so° m° aiu mu im a + w ~ + - - < ma ,ro ~ ~aoo m a eoo iaoo Tlw 'im a u° - ~ ".. -T I ~~ I ~ West(-)/Eas!(i) [t gowinJ ~I I .- ',. -.---... u f i [ l } itt- + ; h ~ t~ ~ ~ ' T ~ j I { j I'_ {~ t ~I jl }Ii II~~ I i~ '+ I. I o a '. I + ~ t~- i•-t I - f i -J- I itl ' ' I t T &241824wL>~ !. ~. t ; l ,`} ::.. i .. ~ I..-.. ., a _, ~ I'r _ _1 - ~ ~... 1. ': I1 II ~ 11 18 24 t&24AL3 0 11 * I} ~ 11 II T 1 1 t t ~ I ~ 1 t J~ 1 ~. I1 / ; t t ± } l f .. Plan 1, tB-348 - I ~ ~ + , T 13 -. _ ! 12 I l iIP End of 9 De 100• U 0 ~ _ a ' I r' ~-_- KOP - . . _ _._1... _ 4 - • __ -+ I _. ._ y .. ~- _. - - - ' \ _+. .- _ 18.248 Target 3 i- ~ ___ , . ~. ~ \ 118-248 Tar at t&240 Tar alt - ~ - y ~ I I 1- + ~ 2- + I I IIrI I-' } I " } ~ - i : Eno o/ 30 D 100' DL , I1 1 T 1 i -.. ~ ,y i } ~ ~ ° -I ~' _i i 1 I.r- tll ,_-r i I ICI T~ - ' tj_r r. I ~... - I ~ ~ i I il , ~t tIl t I y I i ,, .. I- I rrlr _~ 1FZ41e24 ~ I~ - °a5~ . - ... ) I L I I. 1 ~ - : _ - - ~ - ~T~ '- 7 ~~ - I ieoo +aw -pax, nw zoo iaw Iwo ~sw . i , w° ..se +w° .a _ . _T r~~~~ T Imo ~ ma }-, ,-,~. i~ ,-,- I , , -I __ ssu ..°°° .az~ ..zoo .,in ,rw Faso zm as° aaa Veltieal Seetion at 35.08' [SDevinj T ~T .-'Tr} rT_, y T ~ ss° °aa <s° ~m °s° aro zw zW +so +m w w .w aw an l~z o3nl o ,Tp BP Alaska -- °'°"°" .E...,.ND~T.r" ~sg Pe31 ~ ~1~340 02j Ter ~e-tYIS i<L~e atl Tie on MD. 9riT.OT ~6~P ~1 ON. Datum. M.MbOtnO%M.40 N.OSD Swan Y 9 501 8ec^~N OrWO ~EI-W ire~n lVD _ 22jv~21A1 V. a3.00• 0.00 O.OO ]3.05 II( 2ne url _ 63a tt&2aK31 REFERENCE INFORMATION -Tap sae Co-ortlinate (NIE) Reference: Well Centre: 18-24, True Nonh VerBcal (TVD) Reference: 46:24 513111996 08:4948.65 Section (VS) Reference: Slot - 24 (O.OON,O.OOE) Measured Depth Reference: 46:24 513111996 08:49 48.65 Calculation Method: Minimum Curvature C w O O L ~' O 2 L 0 N _ T Plan: Plan #1 118-24/Plan 1, 18-248) ~~ ~ M nzimNls ro True N°M Greatetl By: BP Date: ]/1112008 BAKER Magnetic Nalh 33.36° Checked: Dale'. Mgga9nelK Fiep NV~s~ ~ 60ipnNgla~8095' Conac~lnlamaiae Dare: )Ittn000 BAI Michaelson EQ Model o9e~n3od] Cell'. 190]130135]0 E-mail. dllmicheNeor~iNeq can 1/ 1l u ~ ~ are from top of Riser i ~_ Itop of bag BAG F bag of blind/shears Bllrld/$11e1rS TOTs ~, ~;~~ 2" combi pipe/slips _, Mud Cross Mud Cross of flow cross of rams 2 3/8" x 3 1/2" VBR's TOTs Of DIDB/SIIDS 2" combi aiae/slips . ~ ~ Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of~ ~ ~., ~ ^ i . ~~ ,,~~ _a. ~~ . _: , ~ ._ ... . ;er's 5earcfa State Cabins ~~~~~ 3~4iPC~5 Alaska DNR Case Summary File Type: ADL File Number: ..28321 ~ Printable Case File_Summ.. ary See Township, Range, Section and Acreage? ~ Yes No New Search LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract ~, File: ADL 24321 `~~~'~ Search for Status Plat Updates ,~s o1 09Q=1;?OOS Customer: 000107377 BP EXPLUIZA1~1ON (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~4 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DN OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2480.000 Date Initiated. 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: @VS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED I~Ic~rrc~rc-xr~: U l~~tii~~~~{~r~~: 0f IN R~~i~ge: OISE Sectiujr: ~~ S'c~clirul,lcr~~s.~ 6111 Search Mats ~Ir7Yc1[c/Il: ~~ ~ON'i1.S'11I~1: 0~ ~N tyClfl~r~': ~) ~ ~l'. SeCtll~/l.~ ~ ii .1C~C"IlUYI . ~C"Y('.~': l~)t) 1lrri~liu~t.~ (_~ lutisn.~~hij>: O1IN hcn~~c~~ (11~I~, .~'ectiurt.~ I~) .S~rc~lfu~~:Irf~c~~~: 601 ~~~C'/'![~lail' j, l UIL!)C{711: ~) ~~ ~ l~all~c': O ~ ~t". ,~2Ct1<)il: 2~ ~~~'~"llrN1 r1C1'c'.~': 6=1~) Legal 1)csceil3tion 0~-28-196 ~'~` ~` .SALE NOTICE LEGAL DESCRIPTION * ~`* Cl~l-1~1 TIIN. RISE, UMI?, 18, 19, 20?-180.00 Last updated on 09/04/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28321 &... 9/4/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~,/~ f~ ~,f(~ PTD# a?O~ /yC3 / Developments _ Service _____ Exploratory Stra ' _Non-Conventional WeU hgraphie Test FIELD: ~~ E ~G,~ POOL. ~ Circle Appropriate Letter /Paragraphs to be included in Transmittal Letter CHECK ADD-ONS ~yI.IAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If Iast two digits in well API number are Permit No. . API No. 500 between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both wall name ( PIS and AP[ number (50 = :____) ~m records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and producg /___nieet is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. "" ` "" `~'`~ All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples arc first caught and ] 0' sample intervals you t zones. Non-Conventional please note the followin s Well 8 pedal condition of this permit: production or production testing of coal bed me~leane is not allowed for [dame of welD until after fComuanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity,lCom4anv Name) must contact the Commission to obtain advance approval of such water well testing -_ tfmo~sm Rev: I/112008 WELL PERMIT CHECKLt3T` Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT 18-246 Program DEV Well bore seg PTDk:2081430 Company BP EXPLORATION (ALAS 1NC Initial CiasslType DEV 1 PEND GeoArea 690 Unit 11650 OnlOff Shore .~ Annular Disposal ^ Administration 1 Petmitfeeattaghed-----------.__-------------------- ---------NA----- -------------.-...-------- i 2 Ltrasengmherapprgpnate----- -- - -- -- -- --------Yes -- - --- - _..__. ~ 3 Unigfrewelfnameandnumber - -- ---- - -- - - - Yes- - - -- -- - - ------- - --- - ----- -- 4 Well located ina_defnedpogl___.____-------------------- ---------Yes----- ------------- -- ----------------------------------------------------- 5 Well locatedptoperdistanoefromdrilling~nit_boundary------------ ---------Yes---- ----------------------------------------------------------- ----- 6 Well locatedptoperdistangeftomotherwelis------------------ ---------Yes----- ----.---.---------------------------,------------_.. ----- 7 SutfigientaGreage_ayailableindrillingcnjt_______________________ ___.___Yes_____ _256Qacres._____--._____-___-__________- 8 lideyiated, is-welibore plat_included - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Opetakot gnryc affegtf;d party- - - - - - - - - - - - Yes - - - - - - - - - - - - - - - ------------------------------------ 10 Opetatorhas_appr_opriakebor~inforge_--_______-_--_-_----- ---------Yes____- __BlanketBgnd#6194193.__-_________--__-_.__--------,--__-___--_ 11 Pe[mitcanbeissuedwithoutgonser~atigngrder------------------ ------_-Yes----- -----------------,------------ ---- Appr Date 12 Petmitcanbeissuedwithoutadministtative_appLoyal---------------- ---------Yes----- -----.---------------------------------------_-_------------------- 13 wait ---- --------- Can permit beapprgve~befgre15-day --------Yes--- - -- --- ACS 9118!2008 ----- -- _ -------------------------------------------,---------------- - - 14 Well locatedwiihinarQaandstrataauthgrizedby_InjectionOrde[#(puf_1O#in_cgmments)_(For- NA____- -__--__--__-_________________________________________________--_--_ 15 All wells-within114_miie areaofreviewidentified(Fgtservieewellgnly)._-__ -______- NA____- ___.-_________________--_---_-_____----.---.-._____-------_ _ 16 Pre-prgducedinjegtgr duration ofpreproduotignlessthan3mgnths_(Fgrservicewellgnly)__NA----- -----------------------------------_-_------____----------_-__--_-- 17 tdonconyen,gas_cgnfgrms to AS31,05.03Q(y1.A).(12.A-i7) - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering X 18 Conductorstting-RrovidQd---------------------------- --------- NA------ -ConduotorsetinDS16.24(189-063).-----_------------------------------------- 19 Sutface_casingprgteelsal!kngwrtUBDWs--------------__-_. --.__ -- NA______ __NOaquifersperAIQ4B,cone!usign5.---_--_..__--_______--__--__--________-- 20 CMT-yotadeguate_tgcireulateoncgnd~rgtgt&surf_csg-------------_ _________ NA_-____ __Surfat~~singsetinDS18-24.-___________________-__-__----_--__.__-._----- 29 CMTyoul adequatetg tie-in longstring to srrrf csg- - - _ _ _ _ _ _ . - - - - - - - NA- - - - - - Production-casing set in-D& 18-24, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ _ . - - - - - _ _ - - - 22 CMT-willGOVer allicnown-ptoductiyeborizons-------------------- ---_-_--Yes----- ----------------------------------------------------------- _ _-- 23 Casing desjnsadequatefotC,T,B&_permaftost----------------- ---------Yes----- ----------------------------------------------------------------- 24 Adequate tankage_ or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ - - .Rig equipped with steel pits; No reserve pit planned•_ All waste_tg approved disposal well(s}, _ - _ _ - _ _ _ - _ _ 25 Ifa-re-dtil(,has.a10$03forabandgnment been approved_____________ _________Yes-__-_ __308-31fi____-__--__-._____--__--___._---------___.,_-_----___ 26 Adequate w-ellbo-re separationpropgsed . . . . . . . . .. . . ... .. . . . .. Yes _ _ _ _ Proximity analysis performed, Nearest segment is P$A portion of 16-24AL2 and paths_diye[ge.- - _ _ _ _ _ . - - - - ~27 Ifdiverterreq_wired,dgesitmeetregulafigns-------_------------- ----------~1A----- --B4Pstack_aireadyinpiace,----------------------------------- Appr Date 26 J?rilling fluid_prggram schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - _ - - - _ Maximum expected formation pressure 7,3_EMW.. MW planned 6.6 ppg.. - , _ _ - - _ _ - _ _ - .. - _ _ _ - - _ TEM 9!1912008 29 BQPBs,.do-they meetregulatign - - - -- -- -- -- -------- Yes- --- --- - ------- - -- =- - -- -- - - ---- ~,/~ . 30 BOPE_press rating approp[late; test to-(put prig in comments), _ - - - _ - _ _ . - _ Yes - . _ - . _ _ MASP calculated x12438 psi, 350D_psi-BOP test planned_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ h 31 Choke.manifglds2mRlieswlAPLftP-53 (May84_)- -- -- -- ---- -- ---- Yes --- ------- - -- --- -- ---~ - -- - -- - - -- 32 Wgrkwilloccurwithgutoperationsbutdgwn______________________ _________Yes___-_ ___-.______..______________.,___---_-.___- 33 Is Rresence of H2$ gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ - _ H2S is repotted-at DS 16._ Mgd should Preclude H2$ on_rig, Rg has sensors and alarms.- _ _ - _ _ _ - _ _ _ - _ _ _ 34 Mechanical_cgnditionofwellswithinAQRyerified(Fotservicewellonly)----- --------- NA------ -----.-,------------------------------------------------_- -- Geology 35 Permit can be issued wlg hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ _ Max level H2S on DS 18 is 2Qppm_Qn_vrell 16-146. _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ ` 36 Data-presentedgn potential gyerpresstrrezgnes--_.---------.-- -..--.--f~iA__--_ ------------------________-_____________-------------------_----- Appr Date 37 Seismicanalysisefshallgwgas_zones-.---------------------- --------- NA------ ----------,-------------------------- ACS 9118!2008 38 Seabed condition sunrey.(if off-shore) - - - - - - - - - - - - - - - - - - - - - ----- 39 Contacfnamelphoneforweekly_progressrsports,(exploratgrygnry]_______ _________Yes_--__ _RonPhillips-564-5913.__--__________-____-____----------,-,-.__-----_---_ Geologic Engineering Public Commissioner. Date: 'sinner: Date C loner ~ ~~ ~ C~~~~~ Date ~ ~ /~ ~ Q • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e tapescan.txt **** REEL HEADER **** MWD 09/01/15 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/10/14 2246794 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~J version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9129.0000: Starting De th STOP.FT 11382.0000: Ending Dept h STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 18-24B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 51.609"N 148 deg 26' 38.768"w CNN. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 14 Oct 2008 API API NUMBER: 500292195202 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R15E , PDAT. MSL EPD .F 0 LMF DF FAPD.F 48.65 DMF DF . EKB .F 0 EDF .F 48.65 EGL .F 0 Page 1 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~~~~-~~r= ~r3 ~ ~L1~3 CASE.F N/A OS1 DIRECTIONAL tapescan.txt Casing Depth Other Services Line Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 18 oct 2008 per Doug stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 18-24AL2 through a milled window in a (10) The interval from 11382 feet to 11342 feet MD (8631.89 feet to 8631.87 feet TvDSS) was not logged due to sensor to bit offset at well TD. 3 1/2 inch liner. Top of window 9311 ft.MD (8676.1 ft.TVDSS) Bottom of window 9315 ft.MD (8677.2 ft.TVDSS) (9) Tied to 18-24AL2 at 9297.07 feet MD (8672.09 feet TvDSS). MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~vG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9135.55, 9134.31, ! -1.24316 9141.98, 9141.98, ! 0 9155.66, 9156.7, ! 1.03613 9164.99, 9165.4, ! 0.414062 9171.62, 9171, ! -0.621094 9174.73, 9174.94, ! 0.208008 9177.63, 9177.22, ! -0.414062 9179.71, 9179.29, ! -0.415039 9184.27, 9185.1, ! 0.829102 9193.18, 9193.18, ! 0 9199.14, 9198.72, ! -0.414062 9211.99, 9211.57, ! -0.415039 9218.83, 9219.66, ! 0.829102 9305.09, 9304.88, ! -0.208008 9309.03, 9308.61, ! -0.415039 9314.62, 9314.62, ! 0 9318.77, 9319.6, ! 0.829102 9334.53, 9334.94, ! 0.415039 9363.07, 9363.28, ! 0.208008 9375.51, 9376.96, ! 1.4502 9404.06, 9405.72, ! 1.6582 9458.41, 9458.2, ! -0.207031 9508.67, 9510.95, ! 2.28027 9524.27, 9527.79, ! 3.52441 9529.66, 9531.52, ! 1.86523 9547.12, 9551.68, ! 4.56055 Page 2 ~J 9624.37, 9630.59, 9652.97, 9655.88, 9669.14, 9671.21, 9736.76, 9734.48, 9815.14, 9816.18, 9824.88, 9825.5, 9830.48, 9830.69, 9840.84, 9840.43, 9858.05, 9860.12, 9866.13, 9867.17, 9871.32, 9872.56, 9878.78, 9878.78, 9919.34, 9919.55, 9922.66, 9923.7, 9927.84, 9927.63, 9934.21, 9934.83, 9955.93, 9953.86, 9978.32, 9976.45, 9996.04, 9993.13, 10015.4, 10014.5, 10021.6, 10018.9, 10045.6, 10044.4, 10059.8, 10056.9, 10070.6, 10070.6, 10081.2, 10079.5, 10087.8, 10085.9, 10094.1, 10090.5, 10107.7, 10106.9, 10113.5, 10112.9, 10117.7, 10115.4, 10120.4, 10118.1, 10123.1, 10120.6, 10130.1, 10129.7, 10146.7, 10145.4, 10165.8, 10166.7, 10170.6, 10169.8, 10176.2, 10177, 10179.3, 10181, 10189.8, 10186.5, 10194.8, 10192.5, 10204.1, 10200.4, 10207.9, 10203.7, 10209.5, 10205.6, 10212, 10208.5, 10223.4, 10220.3, 10235.2, 10233.1, 10240.4, 10237.7, 10245.2, 10244.2, 10251.6, 10249.9, 10254.1, 10252.6, 10261.6, 10259.3, 10268, 10264.3, 10285.2, 10280.9, 10290.2, 10285.8, 10308, 10307.6, 10318.4, 10317.7, 10321.7, 10320.6, 10325.8, 10324.8, 10335.2, 10333.3, 10343.6, 10339.7, 10350.4, 10346.7, 10354.8, 10353.1, 10366.8, 10361.2, tapescan.txt 6.21875 2.90234 2.07324 -2.28027 1.03613 0.62207 0.207031 -0.414062 2.07324 1.03711 1.24414 0 0.208008 1.03613 -0.208008 0.621094 -2.07324 -1.86523 -2.90234 -0.829102 -2.69434 -1.24414 -2.90234 -1.6582 -1.86621 -3.52344 -0.829102 -0.62207 -2.28027 -2.28027 -2.4873 -0.414062 -1.24414 0.829102 -0.829102 0.830078 1.6582 -3.31641 -2.28027 -3.73145 -4.14648 -3.93848 -3.52441 -3.10938 -2.07324 -2.69531 -1.03711 -1.65918 -1.45117 -2.28027 -3.73145 -4.35352 -4.35352 -0.415039 -0.62207 -1.03613 -1.03613 -1.86523 -3.93848 -3.73145 -1.65918 -5.59668 v Page 3 10376.1, 10369, 10378.8, 10373.2, 10381.7, 10375.3, 10389.1, 10387.3, 10397.2, 10394.5, 10399.7, 10396.4, 10400.5, 10397.9, 10403, 10399.5, 10405.5, 10403, 10408.6, 10406.1, 10411.4, 10409.5, 10412.6, 10411.6, 10417, 10415.1, 10431.7, 10427.3, 10437.5, 10432.5, 10441, 10435, 10445.2, 10437.5, 10447.6, 10441.6, 10454.6, 10445.5, 10477, 10468.3, 10485, 10477.2, 10487.5, 10481.3, 10497.9, 10490.9, 10502.3, 10495.2, 10517.2, 10508.7, 10520.3, 10514.1, 10545.8, 10541.9, 10552.5, 10545.8, 10556.2, 10549.8, 10558.1, 10551.2, 10564.7, 10557.8, 10566.8, 10560.5, 10573.7, 10567.1, 10581.2, 10577.2, 10594.2, 10593, 10599.2, 10597.7, 10620.5, 10614.7, 10622.6, 10616.8, 10641.3, 10634.8, 10644.2, 10639.2, 10646, 10641.1, 10657.6, 10651.6, 10694.7, 10689.9, 10710.2, 10706, 10713.7, 10711.2, 10721.1, 10719, 10725.2, 10723.3, 10731.8, 10730.4, 10734.5, 10732.7, 10748.2, 10746.1, 10755.8, 10752, 10769.6, 10766.1, 10771.7, 10768.6, 10776.7, 10773.3, 10784.7, 10781.4, 10786.6, 10784.3, 10801.9, 10799.8, 10811.2, 10805, 10814.1, 10810, 10824.4, 10821.9, 10838.3, 10832.1, 10853.2, 10849.5, 10856.5, 10853.6, tapescan.txt ! -7.04785 ! -5.59766 ! -6.42578 ! -1.86523 ! -2.69531 ! -3.31641 ! -2.69434 ! -3.52344 ! -2.48828 ! -2.48828 ! -1.86621 ! -1.03711 ! -1.86523 ! -4.35254 ! -4.97461 -6.01172 ! -7.66992 ! -6.01172 ! -9.12109 ! -8.70605 ! -7.87793 ! -6.21875 ! -7.04883 ! -7.04785 ! -8.49902 ! -6.21875 ! -3.93848 ! -6.63379 ! -6.42578 ! -6.84082 ! -6.84082 ! -6.21875 ! -6.63379 ! -3.93945 ! -1.24414 ! -1.45117 ! -5.80469 ! -5.80469 ! -6.42578 ! -4.97559 ! -4.97461 ! -6.01172 ! -4.76855 ! -4.14648 ! -2.4873 ! -2.07324 ! -1.86523 ! -1.45117 ! -1.86523 ! -2.07324 ! -3.73145 ! -3.52441 ! -3.10938 ! -3.31641 ! -3.31738 ! -2.28027 ! -2.07324 ! -6.21875 ! -4.14648 ! -2.4873 ! -6.21875 ! -3.73145 ! -2.90234 Page 4 tapescan.txt 10860.6, 10856.7, ! -3.93848 10869.5, 10864.1, ! -5.38965 10881.9, 10877.4, ! -4.56055 10888.4, 10883.4, ! -4.97461 10891.5, 10885.9, ! -5.59668 10896.7, 10891.7, ! -4.97559 10923, 10915.7, ! -7.25488 10970.6, 10964.8, ! -5.80371 10974, 10969, ! -4.97461 10976.9, 10971.7, ! -5.18262 10984.3, 10977.4, ! -6.84082 10989.5, 10982.6, ! -6.83984 10996.5, 10990.1, ! -6.42676 11000.4, 10992.8, ! -7.66992 11002.5, 10995.7, ! -6.84082 11005.2, 10999.6, ! -5.59668 11009.6, 11005.9, ! -3.73145 11012.9, 11008.6, ! -4.35254 11017.2, 11011.6, ! -5.59668 11035.1, 11032.2, ! -2.90234 11096.8, 11090.3, ! -6.42578 11100.2, 11094, ! -6.21875 11103.8, 11098, ! -5.80371 11106.7, 11102.1, ! -4.56055 11112.7, 11109.6, ! -3.11035 11116.4, 11113.3, ! -3.10938 11155.6, 11153.3, ! -2.28027 11160, 11157.7, ! -2.28027 11164.9, 11164.3, ! -0.621094 11172.4, 11170.3, ! -2.07227 11183.2, 11181.1, ! -2.07227 11200, 11198.1, ! -1.86523 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 259 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** • !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 18 Oct 2008 per Doug stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Page 5 tapescan.txt Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code Samples units 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 126 Tape File start De th = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 139 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .001 1024 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 9129.000000 11380.000000 0.500000 feet records... bytes bytes *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Page 6 ~ ~ tapescan.txt Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) opticall Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 251 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File start De th = 9130.000000 Tape File End Depth = 11380.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 264 records... Minimum record length: 34 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/10/14 2246794 O1 **** REEL TRAILER **** MWD 09/01/15 BHI Page 7 O1 Tape subfile: 4 Minimum record length Maximum record length tapescan.txt 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9129.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9129.5000 26.1186 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 43.8211 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 84.2973 60.0685 143.1266 417.3008 180.5630 259.0971 9500.0000 85.9533 97.8107 83.1207 192.1053 177.1990 265.1915 9600.0000 71.7351 79.4477 217.9392 740.0847 212.7491 303.7040 9700.0000 92.7894 79.9093 184.9614 2000.0000 207.1463 316.1500 9800.0000 79.1603 90.4469 146.2707 988.0640 195.2380 320.6190 9900.0000 74.2000 101.6689 224.9876 482.1087. 202.3098 311.7148 10000.0000 67.1484 52.8482 85.2437 238.3906 187.5690 319.2308 10100.0000 68.6467 140.5891 196.2144 2000.0000 207.9500 322.9554 10200.0000 117.9264 77.6595 1813.6584 1696.0168 210.2378 302.4369 10300.0000 59.8872 72.8342 81.6943 70.2580 142.0577 289.8033 10400.0000 87.3286 276.9572 254.4558 2000.0000 Page 8 tapescan.txt 257.7417 400.8813 10500.0000 42.1859 139.5535 2000.0000 332.5016 300.8345 716.6178 10600.0000 82.8679 64.0553 416.1219 983.5399 316.2792 971.2748 10700.0000 76.8587 95.9122 346.9821 262.6036 191.7889 317.9095 10800.0000 52.0865 55.7764 170.0175 325.2421 279.6190 715.2065 10900.0000 95.1989 56.3450 1786.4553 480.2833 257.5860 528.4657 11000.0000 77.3445 93.1636 212.8258 563.4214 353.0444 1131.6213 11100.0000 86.6007 29.1094 73.0848 156.0098 208.8077 498.8818 11200.0000 77.4605 92.0594 2000.0000 2000.0000 250.6780 537.7350 11300.0000 49.8559 106.9527 2000.0000 113.0413 2000.0000 2000.0000 11380.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500. -999.2500 Tape File Start De th = 9129.000000 Tape File End Depth = 11380.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9130.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9130.2500 24.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 49.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 76.5000 63.9000 156.1420 768.4550 180.5630 259.5240 9500.0000 86.6000 98.0000 86.4420 266.6270 177.1990 268.7900 9600.0000 77.1000 85.2000 216.1590 1398.3508 218.8460 314.2280 Page 9 1 tapescan.txt 9700.0000 93.5000 79.8000 207.9500 316.1500 9800.0000 77.4000 90.6000 195.2380 320.6190 9900.0000 74.2000 101.8000 201.9660 312.0720 10000.0000 68.7000 92.1000 186.2420 310.8480 10100.0000 68.5000 137.9000 212.5500 322.8990 10200.0000 102.1000 74.1000 203.5390 285.3790 10300.0000 65.9000 104.4000 132.3450 260.1800 10400.0000 97.6000 159.4000 307.8470 599.1949 10500.0000 50.9000 146.9000 322.1790 829.2150 10600.0000 62.6000 90.7000 319.2440 1200.7300 10700.0000 69.6000 103.0000 217.1760 423.9880 10800.0000 49.4000 69.5000 279.6190 706.0020 10900.0000 87.1000 107.3000 256.6580 582.8230 11000.0000 111.3000 72.2000 231.9370 461.3620 11100.0000 83.7000 81.4000 205.4410 463.1140 11200.0000 79.7000 87.4000 246.6820 517.7009 11300.0000 58.1000 80.2000 95550.8906 98641.8906 11380.0000 -999.2500 39.2000 -999.2500 -999.2500 Tape File start Depth = p 9130.000000 Tape File End ~ept = 11380.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS 179.2620 142.2250 215.5460 79.0250 215.1660 2162.8501 79.5480 231.6290 448.7380 431.9250 188.9140 135.1740 515.3779 135.8940 83.4390 2162.8501 2162.8501 -999.2500 6933.3096 743.6439 426.2120 4558.9004 6933.3096 5268.5420 72.5780 2878.3867 1636.6709 281.2780 5271.1387 1912.6230 394.2700 1777.2988 149.6470 818.1539 167.7760 -999.2500 Page 10