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HomeMy WebLinkAbout208-172 OF Tk Alaska Oil and Gas ' //j,�s THE STATE °fALASK:A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 01e, STM, Main: 907.279.1433 ALAS Fax: 907 276 7542 www.aogcc alaska.gov Carrie Janowski Well Interventions Specialist �E if\Vm a Ix 4 _/7a.„ BP Exploration (Alaska), Inc. SC�� U P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-05CL 1 Sundry Number: 315-023 Dear Ms. Janowski: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this Vy of January, 2015 Encl. RECEIVED STATE OF ALASKA JAN 13 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 0-� s I Q l S D IS APPLICATION FOR SUNDRY APPROVALS ��G� 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair WellE ' Change Approved Program El Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ ,- Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate El Alter Casing❑ Other f�a fiii y fY 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. I4 4..C/o„,Ad BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ • 208-172-0 ' {�u/e6-- 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. t TL P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20120-60-00 • 7.If perforating• 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU J-05CL1 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number). 10 Field/Pool(s). ADL0028281 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft). Effective Depth TVD(ft). Plugs(measured): Junk(measured): 117=0 j2ges?,.r is- 17er p 117`k j2e6g ' 6,i ...Pori-My' „4. None None Casing ' Length ' r''3”5 Size / MD TV f '5,'> Burst Collapse Structural Conductor 80 20"x 30" 28 09-108.09 28.09-108.09 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 9957 7"26#L-80 25.06-9982.47 25.06-8652.12 7240 5410 Liner None None None None None None Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10110-11740 8678-8704 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program CI BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14.Estimated Date for 15 Well Status after proposed work: Commencing Operations: Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Carrie Janowski Email Carrie.Janowski@BP.Com Printed Name �y Carrie Janowski Title Well Intervetions Specialist Signature / Phone 564-5273 Datej /I / Prepared by Garry Catron 564-4424 (/4( -c e 3q h 6 u j f COMMISSION USE ONLY / Conditions of approval. Notify Commission so that a representative may witness Sundry Number: \5 _ O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No Subsequent Form Required' /t - 4 c APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date:(- 20 _ /S' Form 10-403 Revised 10/2012 � O ,Ap iroved appI Ii�s iLMelid for 12 months from the date of appy\�vaI. Submit Form and Attachments in Duplicate REfMI AC JAN 2 1 2015A:25 4 ' / a) O O O Ln o0 co 00 a0 Ln in U co Ur` Z Z Y Y co J a) Q Popo o O O • CO Cr f� c V N co LU LU IT) U 0 0 o p o 0 i r-- N v CO C) CO CO o N CO C) • (D Ln N- N O) •co 00 a) CO m• L co tN C) O N cD Q (� Lf) LC) LO > L() N co co N CO CO H Q 0 C) N CO CO L() LU N- C) CD Q CV " N CV CV CV Lf) N O CO E CN c 0, CO N- N r- CO CO co cp LO CO CO 4 CO szr CO (N Q LO N O) CO N O) O) U) O 2 C J o < F- co co Lc) Ln N- co (`() CZ Q (V N N N CV O N U 2 Lf) O O p Ln eo O co LO Y U CO CO Z p Y CO J Z CO m cn 4* co -J a. `U c0 CO co (Nj U)NI x (i) o rn cNi N CO C) - pp CO _ CV L(7 I� Ln C I p a0co i V N ti o0 co O CO CO co N N CO N O) CO O) J W W w F- H Z Q Q O o -Oo o wI= j w 000 O• Q t2C CC Q LLL Z Z Z W w O CC CC CO CO Ott CCDDDD 0 cL co co F- f- Packers and SSV's Attachment ADL0028281 Well Facility Type MD Top Description TVD Top J-05C PACKER 5788 7" Baker ZXP Tie-back Packer 5326 J-05C PACKER 5799 7" Baker ZXP Packer 5334 J-05C PACKER 9647 4-1/2" Baker S-3 Perm Packer 8439 J-05C PACKER 9776 4-1/2" Baker SB-3A HYD PERM PKR 8531 by Date: 1-5-15 To: Well Services Operations Team Lead — Len Seymour/Tyler Norene From: Well Interventions Specialist— Carrie Janowski Office 564-5273, Cell 575-7336 Subject: J-05 Welding Program Rev 1 AFE: APBNRWOS Step Type Procedure 1 O/D Prep cellar& cut conductor 2 D Remove cmt from around SC, prep for UT and PMI 3 0 Weld per specified program 4 0 Post weld QC Inspection & MPI (magnetic particle inspection) 5 D MIT-00A with diesel to 600 psi 6 S Contingent: Install GLVs, Pull TTP Obiective: ai This program is for repairing the starting head leak on J-05 by welding. The program includes preparing cellar & conductor, welding, and post weld activities. This work will need to be conducted during the winter months when ground water inflowing to the cellar can be managed. Well Detail: Current Status: Not Operable - Producer Previous Test: PPPOT-IC to 3500 psi passed 03-17-13 PPPOT-OC to 1500 psi passed 8-17-14 MIT-OA to 1200 psi passed 6-13-14 MIT-IA to 3000 psi passed 6-13-14 Note: collapse rating of 13 3/8" K-55 and J-55 is 1950 psi x 80% = 1560 psi Integrity Issues: SH leak confirmed 09-11-11 Last Slickline: Set TTP 6-22-14 Min ID: 3.80" @ 9823' (1-25-09 milled out xn) Max Deviation: 93 deg at 10273' SSSV Status: Not Required - out Last H2S Reading: 2 ppm on 1/27/11 BHP/BHT: 2536 psi @ 8800'SS NOTE: 3-16-13 DHD measured cellar depth to be @ 61'. Relevant Well History: DHD confirmed a starting head leak on the upper threads 2/17/11. The gas lift valves were dummied off and the well passed a MIT-IA to 3000 psi on 4-10-11. Several unsuccessful attempts were made to repair the SH leak with a Furmanite clamp (which was removed for the final time on 4-13-12). Prep work for the SH weld began 3-17-13 with a passing PPPOT-IC. A UT was done on a small section (1/2") of the SH 3-18-13 that showed no signs of corrosion. The well was secured with a TTP at 9673' on 6-22-14. PPPOT-OC passed 8-17-14. Please call Carrie Janowski at 564-5273 or 575-7336 with any questions or concerns regarding this program. 1 Special Projects / DHD: Prep for welding 1. Confirm the well and cellar is prepared for welding operations. Cut and remove 30" conductor to make room for installation of heat blankets during the SH welding operations. Recommend cutting approximately 24" of the conductor, final amount to be determined by WSL. 2 DHD: 1. Remove cement from around Surface Casing and clean for UT inspection & PMI. Note: UT from 3-18-13 covered small section of the surface casing. Once conductor and cement are removed, another UT is required over the areas to be welded. The structural analysis performed by EWI (based off UT results from 3-18-13) will be re-assessed if the more comprehensive UT comes back with varying results. 3 Special Projects: Weld 1. Attach thermal couplings and install tile heating blankets. 2. Weld the connection from wellhead to casing coupler and connection from the casing coupler to casing per specified procedure. Follow the RP: "SP —Wellhead Welding" 4 Special Projects: Post weld 1. Remove thermal couplings. 2. QC Post Weld Inspection & MPI (magnetic particle inspection). 5 DHD: Post weld 1. If NDT Passes MIT-00A with diesel to 600 psi, LLR if fails. (MITOOA post Furmanite wrap on 8-25-11 passed to 600 psi) 6 Slickline: 1. Contingent MIT-00A, pull/install GLVs & TTP. TREE= , CNV _o, ACTUATOR= BAKER C SCAB L,NR HUNG OFEMERGENCY SLIIPS, OKB.ELEV= 58.15 L 9 "'4-1/2"CHROME TBG&NIPPLES"•ORIG WELL, BF.ELEV= 38 25' �1 05A&J-05B NOT SHOWN*** KOP= 3107 1 Max Angie= 93°@ 10273' Datum MJ= NA Datum TVD= 8800'SS 30"CONDUCTOR H 98' ____--1 2046' H PBR,D=? 13-3/8"CSG,68#,D=12.415" H 2151' ♦ 2151' H13-3/8"X 9-5/8'XO,D=8.681" 9-5/8'FOC -I 2197' - — 2235' H4-1/2"FES X NP,D=3.813" 9-5/8"FOC H 2359' 18-5/8"CSG,96.5#/109#,K-55,BTRS, 1 2553' I CANDO GAS LFT MANDRELS D=17.655"117.563"?? ST MD TVD DEV TYPE VLV LATCH POT DATE 4 3095 3092 10 KGB2 DMY BK 0 04/10/11 Minimum ID = 3.80" @ 9823' 3 5468 5081 40 KGB2 DMY BK 0 04/10/11 4-1'2" HES )CN NIPPLE 2 7346 6565 36 KGB2 EMY BK 0 01/19/09 1 8929 7837 34 KGB2 FLWSLV BB( 0 06/22/14 r TISK,26#,L-80 BTD-M,.0383 bpf,D=6.276' - 5802' 5790' H9-5/8"X 7"BKR ZXP TEBK PKR,D=6.313' TOP OF 7'LP 5802' '1 5802' —19-5/8'X 7"BKR ZXP LTP,0=7.50" I 5818' H FM 9-518"X 7"BKR C HGR,D=6.313" TOP OF WHPSTOCK H 5900' 9-5/8"¢SV H 5986' 9628' -14-1/2"FSS X Nom,D=3.813' %' 9-5/8"CSG,47#, 10510' ''!• ��4 X 9649' H7"x 4-1/2"BKR S-3 PKR,D=3.870" L-80,D=8.681" 1'1 N� 9673' -14-112"HES X NIP,D=3.813" 9673' -14-1/2"PX PLUG(06/22/14) 4-1/2'TBG,12.6#,13CR-80 VAM TOP, - 9736' j bpf,D=3.958" 1 9761T-1-1r x 4-1/2"UNDUE OVERSHOT .01523.9 4-1/2'TBG STUB(01/09/09) 9725'ELMD , { 978-57-1-14-1/2"FES XN NP,D=3.725' 9778' HT x 4-1/2"BKR S-3 PKR,D=3.875" ' • 9802' -14-1/2"FES X N1 D=3.813" ' 1-982-3;-1-14-1/2"FES XN(MLL®01/25/09)D=3.80" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' H 9835' "" 9835' H4-1/2"WLEG,D=3.958" 7"LNR,26#,L-80,BTC-M.0383 bpf,0=6.276" -I 9985' lik 10110' H3-3/4"OPBJ HOLE SIDETRACK J-05B OPEN HOLE TD H 11315' L 3-3/4.OP9J HOLE TD 11740' -05C L1 J-05C 4-1/8"OPEN HOLE1D I-- 12070' DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY LINT 07/06/77 ORIGINAL COMPLETION 07/14/10 WBYSV RILL TTP WELL J-05C/J-05L1 03/13/00 TWA SIDETRACK COMPLETION 09/07/10 SMJM3 DRLG DRAFT CORRECTIONS PERA T No: 2081710/2081720 02/01/09 NORDIC2 CTD ST&ML(J-05C/CL1) 04/22/11 MCM'PJC GLV GO(04/10/11) AR No: 50-029-20120.03/60 02/05/09 SV/PJC DRLG CORRECTIONS 06/24/14 DLWJMD SET PLUG/GLV GO(06/22/14) SEC 9,T11N,R13E,650'SNL&1245'WB 02/13/09 /SV GLV GO(02/13/09) 03/19/10 JLW/SV CSG CORRECTION BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~QSJ - L ~ Well History File Identifier Two-sided II I II II II II II I II III ^ f2escan Needed ~~ (~~ ~~ ~~ (~ ~ ~ ~~ ~ ~~~ Organ~z~ng (done) ^ RES AN DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, NolType: ^ Poor Quality Originals: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: NOTES: ^ Logs of various kinds: ^ Other:: BY' ~ Maria Date: L-~-/C~//D ~S~ ~ II _ -~-- ~ ~ Pro "ect Proofing II I II ~I II I I III I I III J BY: Maria Date: /Q ~s~ i -i Scanning Preparation ~_ x 30 = ~ d + ~~ = TOTAL PAGES ~/~ /~© (Count does not include cover sheet) ,/~ n BY: Maria Date: ~s~ r Y' Production Scanning """"""" " "' Stage 7 Page Count from Scanned File: ~ (Count does include co r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: (~. ~ /O ~S~ ~J Y Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO III BY: Maria Date: /Sin II ^I II ~ u 11 I 1111 Scanning is complete at this point unless rescanning is required. ReScanned III IIIIII IIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIIII III IIII III 10!6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3/31 /2010 Permit to Drill 2081720 Well Name/No. PRUDHOE BAY UNIT J-05CL1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20120-60-00 MD 11740 TVD 8704 Completion Date 2/1/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es `'/ DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt LIS Verification 9653 12069 Open 4/22/2009 LIS Veri, GR< ROP, RAD, i RAS, RPD, RPS ~ D C Lis 17892~uctioNResistivity 9653 12069 Open 4/22/2009 LIS Veri, GR< ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 9650 11740 Open 4/22/2009 MD MPR, GR 30-Jan-2009 og Induction/Resistivity 5 Col 10110 11740 Open 4/22/2009 TVD MPR, GR 30-Jan-2009 og Gamma Ray 25 Col 9650 11740 Open 4!22/2009 MD GR 30-Jan-2009 ED D Asc Directional Survey 26 11740 Open 4/16/2009 Diskette in 208-171 well i ~ history ~pt Directional Survey 26 11740 Open 4/16/2009 Induction/Resistivity 25 Col 11000 11710 Open 4/22/2009 MD MPR, GR 30-Jan-2009 Well Cores/Samples Information: • Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/31/2010 Permit to Drill 2081720 Well Name/No. PRUDHOE BAY UNIT J-05CL1 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20120-60-00 MD 11740 TVD 8704 Completion Date 2/1/2009 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ~, Daily History Received? ~N Chips Received? Y7N- Formation Tops ~ N Analysis Y / N Received? Comments: Compliance Reviewed By: INTEQ IJ®g Data Trans ~ttal F®r To: State of Alaska -A®GCC 333 Wv 7t" Aveo Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: J-OSCL1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) I L W 1' D G aster summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional Measured Depth MADPASS Log (to follow) "!' 1 color print - MPR/Directional Measured Depth Log (to follow) `~ 1 color print - MPR/Directional TVD Log (to follow) t LAC Job#: 2429264 Sent by: Catrina Guidry Date: 04/21/09 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 :~,~ =~~ ®AI(ER aurswe~ --s-r~ 1 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 (~ ~~ z ~" :s EtAKER N~J6NE5 CUMYANY WELL NAME Bakea- Atlas PRINT DISTRIBUTION LIST BY EXYLURA'11UN (ALASKA) 1NC CUUN'1'Y NUR'1'H SLUYE BURUUGH J-OSCLI STATE ALASKA FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY DATE 4/21/2009 CATRINA GUIDRY SO #: 2429264 Copies of Copies Digital Copia of Copies Digi[al Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DNISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-i 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 I Company STATE OF ALASKA - AOGCC Company Person CHRISTIiVE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE ]00 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Comnleted Bv: ~~-l~ ~- Page 1 of l ~~ BAKER I~JGHES ~. 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: April 15, 2009 Please find enclosed directional survey data for the following wells: K-06B J-OSC E-34L1 J-OSCLl OS-27BPB1 07-02B OS-27B 07-20B 07-29D 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: ~ ,State of Alaska AOGCC DATE: 2 C~ ~ Cc: State of Alaska, AOGCC ~g -~ I`7~ STATE OF ALASKA ~rV~~ '~~%~•O9 ALASK~L AND GAS CONSERVATION COM SION ~~~ ~ 2 2~~19 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~la~ka t]ii ~?a ~ ~on~. Cotrwnissior~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoaa,c zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well C ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/1/2009 12. Permit to Drill Number 208-172 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/27/2009 13. API Number 50-029-20120-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/30/2009 14. Well Name and Number: PBU J-05CL1 650 FNL, 1245 FEL, SEC. 09, T11 N, R13E, UM Top of Productive Horizon: 2054' FSL, 107' FWL, SEC. 03, T11 N, R13E, UM 8. KB (ft above MSL): 65.84' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1794' FSL, 5268' FWL, SEC. 04, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 11740 8704 Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643105 y- 5970695 Zone- ASP4 10. Total Depth (MD+TVD) 11740 8704 16. Property Designation: ADL028281 TPI: x- 644399 y- 5973424 Zone_ ASP4 Total Depth: x- 644286 y- 5973162 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted inf rmati n er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed in rmationper 20 C 25.071): MWD, DIR, GR, RES G~//NDos,> ~ /011D'~~ ~6 ~~ TYD 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 2 " x 30" Surf a 11 urfa 11 ' 1 - / " 1 2 4 PFII 13-3/8" x 9-5/8" 68# N- Surface 5956' Surface 5454' 17-1/2" 150 sx Clas 57 x PF II 7" 2 L- 28' 985' 2 ' 8653' 8-1/2" 1 0 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TusiNG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD None 4-1/2", 12.6#, 13Cr80 / L-80 9835' 9649' & 9778' MD TVD MD TVD 3-3/4" Open Hole 10110' - 11740' 8678' - 8704' 25. ACID; FRACTURE, CEMENT .SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 2000' Freeze Protected with 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ;.~ None ~ Form 10-407 ReVlSed 02/2007 CONTINUED ON REVERSE SIDE .s ~ Hf ~ ~ o ~nOg ) ~~~ 28. l7~OLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. None (From J-05B) Top Sag River 9974' 8648' Top Shublik 11453' 8692' Formation at Total Depth (Name): Shublik 11453' 8692' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that for oing is true and correct to the best of my knowledge. Signed Sondra m Title Drilling Technologist Date ~ ~~~"~ PBU J-05CL1 208-172 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number P rmit No. / A rov I No. Drilling Engineer: Sean McLaughlin, 564-4387 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. bean 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = CM/ • WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 58.15' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93° @ 10273' Datum MD = Datum ND = NA 8800' SS DRLG DRAFT 30" CONDUCTOR 98' 13-3/8" CSG, 68#, ID = 12.415" 2151' 9-518" FOC 219T 9-5/8" FOC 2359' 18-518" CSG, 96.5# / 109#, K-55, BTRS, 2553' ID = 17.655" / 17.b63" ~~ Minimum ID = 3.80" @ 9823' HES XN NIPPLE 7" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' 5802 TOP OF 7" LNR ~ 5$02 TOP OF WHIPSTOCK 9-5/8" Ezsv I~ 5986' 9-5/8" CSG, 47#, I-j 10510, L-80, ID = 8.681" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I~ 9736' I 11315' I J-05C & CL1 9823' 1~4-1/2" HES XN (MILLED 01/25/09), ID = 3.80" ~4-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" I-I 9835' 7" LNR, 26#, L-80, BTGM .0383 bpf, ID = 6.276" ~ 9985' B (previous openhole completion) ~ B Openhole TD I NOTES: WELL ANGLE > 70° @ 10015' RIG WELLBORE NOT SHOWN BELOW *** 7" SCAB LNR HUNG OFF EMERGENCY SLIPS 2046' PBR, ID = ? 2151' 13-3/8" X 9-5/8" XO, ID = 8.681" ~-I4-1 /2" HES X NIP, ID = 3.813" CAMCO GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3095 3092 10 KBG-2 OM BK 16 02/13/09 3 5468 5081 40 KBG-2 SO BK 20 02/13!09 2 7346 6565 36 KBG-2 DMY BK 0 01!19/09 1 8929 7837 34 KBG-2 DMY BK 0 01/19!09 5790' ~ 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 9-5/8" X 7" BKR ZXP LTP, ID = 7.50" 5818' 9-5/8" X 7" BKR HMC HGR, ID = 6.313" MILLOUT WINDOW (J-058) 5956' - 5987' 9628' 4-1/2" HES X NIP, ID = 3.813" 9649' 7" x 4-1/2" BKR S-3 PKR, ID = 3.870" 9673' 4-1/2" HES X NIP, ID = 3.813" 9725' ELM TOP OF TUBING STUB (01/09/09) 9751' UNIQUE OVERSHOT, ID = 4.625" 9765' 4-112" HES X NIP, ID = 3.813" 977$' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9~ 4-1/2" HES X NIP. ID = 3.813" 9835' X14-1/2" WLEG, ID = 3.958" 3-3/4" OH Sidetrack 10110' CL1 3-3/4" Openhole to TD 11740' 4-1/8" Openhole T~ 12070' U C DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06177 ORIGINAL COMPLETION 03/13100 N7ES SIDETRACK COMPLETION 02/01/09 NORDIC 2 CTD SDTRCK (J-05C) 02/05/09 SV/PJC DRLG CORRECTIONS 02/13/09 /SV GLV C/O (02/13/09) PRUDHOE BAY UNIT WELL: J-05C PERMIT No: 2081710 (20) API No: 50-029-20120-03 & O6? SEC 9, T11N, R13E, 650' FNL & 1245' FEL BP Exploration (Alaska) ~ ~ BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date ~ From - To ~ Hours Task Code, NPT Phase Description of Operations -- _ _ - -- 1/14/2009 11:00 - 14:00 3.00 MOB P PRE Hold PJSM w/ crew regarding moving rig. Perform final walk 14:00 - 00:00 10.00 MOB P PRE 1/15/2009 00:00 - 08:30 8.50 MOB P PRE 08:30 - 10:30 2.00 MOB P PRE 10:30 - 11:30 1.00 MOB N WAIT PRE 11:30 - 12:30 1.00 MOB P PRE 12:30 - 13:00 0:50 MOB P PRE 13:00 - 14:30 1.50 MOB P PRE 14:30 - 16:30 2.00 MOB P PRE 16:30 - 16:45 0.25 BOPSU P PRE 16:45 - 21:30 4.75 BOPSU P PRE 21:30 - 22:45 1.25 MOB P PRE 22:45 - 00:00 1.25 BOPSU P PRE 1/16/2009 ~ 00:00 - 01:30 ~ 1.501 BOPSUf~ P ~ ~ PRE 01:30 - 11:00 I 9.501 BOPSUFt P I I PRE 11:00 - 13:00 2.00 BOPSUFj P PRE 13:00 - 19:20 6.33 BOPSU P PRE 19:20 - 21:00 1.67 BOPSUF~ P PRE 21:00 - 00:00 3.00 BOPSU P PRE around. Back rig off well. Clean up location. Move rig to pad entrance. Move rig from MPC pad to spine road. Rig is at MPU spine road intersection at midnight. Move rig from MPU spine road intersection towards J pad. Arrive on J Pad and spot in front of well Fill out Location Condition report w/ DSO. DSO refused to sign Unit Work Permit until GC20TL approved the siting documents for the satellite office Lay herculite around wellhead. Chk IAP & OAP=O Set rig mats for height Drop 4" valve off 7-1/16" stack. Set stack on skid and remove from cellar CH2 140T crane arrived at 0940 hrs and begin to RU. Move RWO BOP skid for lift Safety mtg re: lift 13-5/8" stack off of skid and place behind the wellhead WO approval from GC20TL to begin wellwork. DSO signed Unit Work Permit Lift 13-5/8" stack off skid and place behind wellhead Remove Swaco MPD choke and panel off rig floor RDMO CH2 crane Safety mtg re: move over well Move over well and set down Accept rig for operations at 1430 hrs Berm cellar w/snow. Take on rig fuel and water. Set cuttings box, tree and Sarber spool. Swap satellite office trailer to rig power Safety mtg: RU DSM lubricator Load DSM lubricator to floor. PT 500 psi. Pull 4" BPV. Dry rod TWC. RU & test to 3500psi & chart same. RD DSM lubricator. RD test hose. PJSM regarding moving rig. Jack up rig & center over well. Secure cellar w/ plywood. PJSM regarding ND tree & NU BOPE. Suck down tree. Split tree in 2 pieces & tail roll out of the cellar. RD tubing head adaptor. Continue to RD tree & tubing head adaptor. Inspect top hanger threads -good condition. MU NSCT xo to top hanger threads - 7-1/4 by hand. Cycle LDS -all functioned. Skid in & NU 13-5/8" BOP stack, torque all bolts to spec. Install blind & variable rams. NU HCR, Koomey lines, etc. Chk IAP, OAP=O NU Sarber spool on top of annular NU riser sections. Fill stack and riser w/ water - no leaks. RU 4-1/2" test joint w/ NSCT XO. SWS lower reel to ground to load out ODS reel drive components Function test BOPE. Shell test BOPE, grease leaking choke HCR stem. Shell test -holding. Perform weekly BOPE test per AOGCC regs to 250psi/3500psi - PASS. Jeff Jones waived witness to test. RU 2" circulation Printed: 2/19/2009 10:49:10 AM ~ ~ BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE .Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - To I Hours Task Code NPT Phase... Description of Operations 1/16/2009 21:00 - 00:00 3.00 BOPSU P PRE loop to IA. 1/17/2009 00:00 - 01:30 1.50 BOPSU P PRE Continue to pressure test BOPE per AOGCC regs. 01:30 - 02:30 1.00 BOPSU P PRE RU CIW mandrel x 7" Otis connection w/ _ 17ft of lubricator. Land inside CIW spool & RILDS. 02:30 - 03:15 0.75 BOPSU P PRE Pressure test CIW mandrel x 7" Otis. 03:15 - 06:45 3.50 BOPSU P PRE RU DSM lubricator. P.T. to 250psi. Pull 4" TWC, slight vac. RD DSM lubricator. Back out all LDS on CIW mandrel. RD CIW mandrel & lubricator. RU 3-1/2" elevators. RU landing jt & floor valve. MU landing joint into hanger. RU circ hose to landing jt. P.T. IA circulation loop. Remove Nordic hardline from reel house for inspection 06:45 - 07:00 0.25 BOPSU P PRE Safety mtg re: circ wellbore 07:00 - 07:45 0.75 BOPSU P PRE Reverse circ 2.40/530 w/ SW down the IA and recover 54 bbls of diesel from the tubing (as measured on 'out' MM). Swap to tubing 07:45 - 08:30 0.75 BOPSU P PRE Circ initial 2.41/190 w/ SW w/ Safe Surf-O down the tubing taking diesel returns to the tiger tank 3.01/480 w/ one pump. Pump 300 bbls and SD pumping 08:30 - 10:40 2.17 BOPSU P PRE Let Safe Surf-O soak while attempt to thaw tiger tank hose outlet. Then, WO CHILL pusher to okay using hose 'over the top'. Vac off 200 bbls of mostly diesel and send to GC2 recycle SWS lower reel (for more room when picking up bearing assy) onto CHILL lowboy and park trailer on the side of pad Check derrick for ice-it's 28F! (and calm) 10:40 - 13:00 2.33 BOPSU P PRE Resume circ remainder of Safe Surf 3.01/550. Incr rate to 4.75/1350 w/displacement fluid. Pumped 670 bbls total. RD circ hose. Blow down lines 13:00 - 13:15 0.25 PULL P DECOMP Safety mtg re: pull tubing hanger 13:15 - 15:00 1.75 .PULL P DECOMP BOLDS, drain stack. Unseat hanger w/ 80k, clean. Pull hanger to floor w/ 98k max, then 88k steady. LD hanger and landing jt Now it's 41 F and 20-30 mph wind! 15:00 - 21:20 6.33 PULL P DECOMP POOH LD 4-1/2" 12.6# L-80 IBT tubing. Pin ends on jts 40-80 were heavily corroded. Stop at jt 80. RD 4-1/2" elevators. RU 3-1/2" elevators. 21:20 - 21:30 0.17 PULL P DECOMP PJSM regarding RU RTTS storm packer. 21:30 - 23:30 2.00 PULL P DECOMP RU & run RTTS storm packer. Set RTTS storm packer 2ft below ground level. 55k up wt & 53k do wt. P.T. to 500psi below packer & 1000psi above packer. 23:30 - 00:00 0.50 PULL P DECOMP Blow down choke & kill line. Suck down stack. 1/18/2009 00:00 - 00:30 0.50 PULL P DECOMP Continue to suck down stack. PJSM regarding ND BOP's. 00:30 - 06:00 5.50 PULL P DECOMP Pull upper & lower riser sections. Pull mouse hole. Install BOP lift plate. Disconnect Koomey lines. Hoist BOP's using bridge crane & ND BOP's at top of tubing spool. ND tubing spool. C/O casing packoffs. 06:00 - 09:30 3.50 WHSUR P DECOMP NU new CIW tubing spool. PT packoffs ~ 5000 psi 09:30 - 09:40 0.17 WHSUR P DECOMP Safety mtg re: NU 13-5/8" BOPE 09:40 - 14:00 4.33 WHSUR P DECOMP NU 13-5/8" to tubing spool. NU riser sections. Install Koomey hoses. Set mousehole 14:00 - 15:50 1.83 BOPSU P DECOMP Fill stack and riser w/ water. Function test rams and HCR. Set test plug. PT 250/3500 against blinds. Took several tries to get a test due to air in kill line Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date I, Name: J ell Name: J e: Name: From - To -05 -05 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task ' PLET A Code I E NPT Start Rig Rig Phase Spud Date: : 1/14/2009 End: Release: Number: N1 Description of Operations 1/18/2009 15:50 - 16:00 0.17 WHSUR P DECOMP Safety mtg re: pull packer 16:00 - 16:45 0.75 WHSUR P DECOMP Pull HES Storm packer. LD running tools and load out 16:45 - 00:00 7.25 PULL P DECOMP RU to pull tubing. POOH LD 4-1/2" 12.6# L-80 IBT tubing. 1/19/2009 00:00 - 02:10 2.17 PULL P DECOMP Continue to POOH LD 4-1/2" 12.6# L-80 IBT tubing. Recovered 234 jts of 4-1 /2" tubing. Cut was 10.5ft from top of jt 235 & was a good uniform cut. 02:10 - 04:00 1.83 BUNCO P RUNCMP RU 13-5/8" mandrel by Otis xo w/ 17ft of lubricator. RU slickline. Simultaneously load new 4-1/2" tubing into pipeshed. 04:00 - 04:35 0.58 BUNCO P RUNCMP RIH w/slickline w/ 6.05" gauge ring & junk basket to 9700ft. 04:35 - 05:35 1.00 BUNCO P RUNCMP POH w/ slickline. 05:35 - 07:00 1.42 BUNCO P RUNCMP Junk basket was empty. RDMO slickline. 07:00 - 07:30 0.50 BUNCO P RUNCMP Pull mandrel and LD lubricator sections 07:30 - 17:00 9.50 BUNCO P RUNCMP Load pipeshed w/ 4-1/2" chrome tubing, drift and strap SWS use reel crane to load in repaired reel drive bearing assy. Mount in place TS NORM tubulars 17:00 - 19:00 2.00 BUNCO WAIT RUNCMP Wait onjewelry/completion equipment. 19:00 - 22:00 3.00 BUNCO P RUNCMP RU Doyon torque turn services. Hoist pup jts to RF, drift & tally same. Load completion jewelry in pipeshed, organize same. 22:00 - 23:00 1.00 BUNCO P RUNCMP PJSM regarding handling/running new completion. MU new 4-1/2" chrome tubing per summary, torqued to 4400ft/Ibs. BakerLok every jt below the packer. Can't get the overshot into the 7" casing -recovered ice on the overshot. 23:00 - 23:30 0.50 BUNCO P RUNCMP Suck down BOP stack. RU 3-1/2" DP & steam wellhead. LD 3-1/2" DP. 23:30 - 00:00 0.50 BUNCO P RUNCMP Continue to run new 4-1/2" chrome tubing per summary, torqued to 4400fUlbs. 1/20/2009 00:00 - 16:00 16.00 BUNCO P RUNCMP Continue to run new 4-1/2" chrome tubing per summary, torqued to 4400ft/Ibs. Tbg hanger arrived at 0945 hrs. Tag up w/ good indication of both sets of shear pins & no-go. Space out as required. RU landing jt & hanger. Suck down stack. Land tubing. Pull LDS & visually see the hanger on seat. Break circulation - ok. RILDS & test hanger. 16:00 - 19:00 3.00 BUNCO WAIT RUNCMP Wait on completion fliud. The order that was placed in the morning got lost. SLB loaded the reel. Clean RF &pipeshed of misc RWO equipment. 19:00 - 20:40 1.67 BUNCO P RUNCMP PJSM regarding handling corrosion inhibitor. Stinger in 1 drum of corrosion inhibitor onto 150bb1s of hot SW, going slow as the inhibitor is very cold. 20:40 - 22:05 1.42 BUNCO P RUNCMP Reverse circulate in 150bb1s of inhibited SW ~ 120degF, 2.25bpm/615psi. 22:05 - 22:40 0.58 BUNCO P RUNCMP PJSM w/ Hot Oil crew regarding pumping diesel & P.T.'n backside. P.T. lines to 3800psi. Reverse circulate in 40bbls of 90deg diesel. 22:40 - 23:10 0.50 BUNCO P RUNCMP Drop ball & rod, let it fall. 23:10 - 00:00 0.83 BUNCO P RUNCMP Pressure up tubing to 3500psi & set packer. P.T. packer at 3500psi for 30min -PASS. Lost 25psi in 1st 15min, 20psi 2nd 15min. ~ 1/21/2009 00:00 - 01:00 1.00 BUNCO RUNCMP Attempt to test casing, slight graylock leak. Steam Hot Oil check valve. Bleed off & tighten graylock fitting. Bleed off tbg to Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 4 of 13 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: J ell Name: J e: Name: From - To -05 -05 REENTE NORDIC NORDIC Hours R+COM CALIS 2 Task PLET TA 'Code E NPT 1/21/2009 00:00 - 01:00 1.00 BUNCO P 01:00 - 02:00 1.00 BUNCO P 02:00 - 03:20 1.33 BOPSU P 03:20 - 06:00 2.67 BOPSU P 06:00 - 12:15 6.25 BOPSU P 12:15 - 13:45 1.50 BOPSU P 13:45 - 18:00 4.25 BOPSU P 18:00 - 19:45 1.75 MOB P 19:45 - 19:50 0.08 MOB P 19:50 - 00:00 4.17 MOB P 1/22/2009 00:00 - 01:30 1.50 MOB P 01:30 - 02:30 1.00 MOB P 02:30 - 06:00 3.50 BOPSU P 06:00 - 07:30 1.50 BOPSU P 07:30 - 12:20 4.83 BOPSU N RREP 12:20 - 15:30 3.17 BOPSU P 15:30 - 00:00 8.50 BOPSU N RREP 1/23/2009 00:00 - 01:00 1.00 BOPSU P 01:00 - 01:55 0.92 BOPSU P 01:55 - 03:45 1.83 RIGU P 03:45 - 05:00 1.25 CLEAN P Spud Date: Start: 1 /14/2009 End: Rig Release: Rig Number: N1 i Phase Description of Operations RUNCMP 1500psi & test IA to 3500psi for 30min -PASS. Lost 25psi in 1st 15min, 20psi in 2nd 15min. RUNCMP Bleed off IA & tubing to Opsi. LD landing jt. RD & release Hot Oil. PRE Dry rod in & set 4" TWC. Close blinds & test TWC, seems to be air in lines. Retest, circle chart is not working, use SLB electronic sensor -PASS. PRE Blow & suck down BOP stack: ND riser. Start ND BOP's. PRE ND HCR, Kill line, drain and remove koomey hoses, open ram doors and remove blocks, grease stack, round trip dirty vac to empty pits. PRE Open cellar doors, Lift BOP stack onto the lifting frame, skid out stack, load tree and adapter flange in the cellar. PRE CIW tech and crew NU adapter and tree, test to 5k psi. PRE Move cuttings box. Secure cellar. Disconnect office camp from rig power. Disconnect tiger tank lihe. Jack up & spin tires to warm up moving system. Open cellar doors. PJSM regarding moving rig. PRE Move rig off well. PRE PJSM regarding using crane w/high winds. RU CHILL crane & move 13-5/8" BOP's. Skid in & PU 7-1/16" w/ rig blocks. Attach koomey lines. C/O 3" slip ram fora 2-3/8" combi ram. RU 7-1/16"x4-1/16" Xo to bottom of BOP's. Take frequent warm up breaks. PRE Continue to C/O BOP rams & install Xo on bottom on BOP's. RU 10ft choke line to BOP stack. PRE PJSM regarding moving rig. Move rig over well. PRE Weather proof cellar. Pull tree cap. NU BOP's. Function test BOP's. Install 7" Otis riser to RF. RU tiger tank line to the rig. Spot cuttings box & hook up cuttings chute. Bring on fluids - 2%KCI with SAFEIube. PRE Crew change. Secure stack and RU lubricator. PRE Test BOPE. Chuck Scheve waived witness to the BOP test. Fix leaking grayloc connection on choke line. Change blind rams, upper seals were tore up. Replace Grayloc connection on choke line, then retighten again. PRE All connection leaks fixed. Start testing rams and valves. PRE Upper 2-3/8" combi not holding. Open up and find 2" ram block w/ 2-3/8" inserts were installed. Change out ram blocks and still fail to test. Reopen doors to inspect. Swap lower rams for upper rams & test -upper set passed. Lower set failed. Swap out test joints -still failed on the lower set. Blow down stack. Remove lower set of rams. Install brand new rams from Nordic 1 into lower cavities. Test failed. Swap lower set for upper set. Test passed on both upper & lower 2-3/8" combi's. PRE Continue to test BOP's. PRE PJSM regarding pulling TWC. RU DSM lubricator & test to 500psi. Pull TWC, lost seal 3.75"od,1/4"W,1/8"T. RD DSM lubricator. PRE PJSM regarding slickline ops. Spot slickline unit. RU slickline w/full pressure gear. P.T. lubricator to 500psi, slight leak, C/O o-ring & re-test. WEXIT Open well & RIH w/ slickline. Recovered ball & rod. Printed: 2/19/2009 10:49:10 AM ~ r BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 i Date From - To Hours Task , Code NPT Phase Description of Operations 1/23/2009 05:00 - 07:00 2.00 CLEAN P WEXIT SL run #2 -recover RHC sleeve 07:00 - 07:20 0.33 CLEAN P WEXIT SL crew change 07:20 - 07:45 0.42 CLEAN P WEXIT PJSM for picking up the pump bailer and slickline operations 07:45 - 11:00 3.25 CLEAN P WEXIT SL run #3 - 3.5" x 10' pump bailer. Recover -20# of sluggits + 1/3 of the TWC seal. 11:00 - 12:50 1.83 CLEAN P WEXIT SL run #4 -rerun bailer. Recover -20# 12:50 - 15:10 I 2.331 CLEAN I P I I W EXIT 15:10 - 17:00 I 1.831 CLEAN I P I I WEXIT 17:00 - 19:00 I 2.001 CLEAN I P I I WEXIT 19:00 - 19:45 0.75 CLEAN P WEXIT 19:45 - 21:05 1.33 CLEAN P WEXIT 21:05 - 00:00 I 2.921 CLEAN I P I I W EXIT 1/24/2009 00:00 - 00:40 0.67 CLEAN P WEXIT 00:40 - 01:15 0.58 CLEAN P WEXIT 01:15 - 04:10 2.92 CLEAN P WEXIT 04:10 - 04:50 0.67 CLEAN P WEXIT 04:50 - 06:00 1.17 CLEAN P WEXIT 06:00 - 06:30 0.50 CLEAN P WEXIT 06:30 - 08:10 1.67 CLEAN P WEXIT 08:10 - 09:50 1.671 CLEAN P WEXIT 09:50 - 11:45 I 1.92 I CLEAN (N I DFAL I W EXIT 11:45 - 12:30 0.751 CLEAN ~ N ~ DFAL ~ W EXIT 12:30 - 13:00 0.50 ~ CLEAN ~ N ~ DFAL ~ W EXIT 13:00 - 14:40 1.67 CLEAN N DFAL WEXIT 14:40 - 15:00 0.33 CLEAN P WEXIT 15:00 - 16:15 1.25 FISH P WEXIT Test reel manifold to 4500psi. SL run #5 -rerun bailer. Recover -5#. Geo confirmed sample is calcium carbonate (sluggits) SL run #6 -sharpen mule shoe and rerun 3.5" bailer. Recover 10#. Marks on mule shoe that indicate the XN plug is near. SL run #7 -rig up 2.25" x 11' bailer. RIH filling across top. Make 20 pump strokes & lubricator o-ring started to leak, POH. Recover 5#. Drop tool string & inspect rope socket & tools. SL run #8 -rerun 2.25" bailer. Recover 3/4 cup. SL run #9 -equalizing device. Good indication that plug was equalized. SL run #10 -pull plug. Jar up for 1 hr. Attempt to disconnect from plug. Beat down for 1 hr & release from plug. PJSM regarding handling slickline. RD slickline. PJSM regarding handling coil. RD DS & ODS tongs. RU stuffing box to the injector. MU stabbing winch. RU & pull coil across. RD stabbing winch. Fill coil w/ 2% KCL+safelube. Pump slack forward. Pressure test packoffs & inner hardline reel 250psi/3500psi. Crew change and PJSM Cut 22' of cable, seal end of eline, dress coil tubing, Install BOT coil connector, Pull test to 40k, pressure test to 3500 psi. MU XN plug fishing BHA #1 -CTC, 1 jt PH6, DFCV, Accelerator, 13' of 3.625" wt bar, Bowen jar, Disco, Circ sub, 4" GS spear. RIH with fishing BHA#1. Load coil with 20 bbl viscous pill at minimum rate. At 7863' circ pressure spiked to 800 psi. Stop coil and walk up pressure to 2000 psi, slow bleed of. Do not want to risk latching up with an open circ sub. POH to BHA. Isolate reel manifold and verify the strainer is clean and in place. Double check SLB reel log and verify 490' of slack was pumped out on previous well. Pop off and pull 71' of cable from the BHA. Position the injector over the bung hole and pump out another 142' of slack (total recovery of 213' of cable). LD BHA and find the missing heat shrink rubber in the DFCV sub. The SLB reel log is inaccurate. DIMS doesn't record any slack being pumped out at the end of the previous well. MU XN plug fishing BHA #2 -CTC, 2 jts PH6, DFCV, Accelerator, 13' of 3.625" wt bar, Bowen jar, Disco, Circ sub, 4" GS spear. RIH with fishing BHA #2. Resume productive time. Continue to RIH. Dry PU weight - 44k. Pump 2.62/2.64 2050 psi. Wash into the fishing neck at 9833' two times with hi-vis pill. CBU. No Printed: 2/19/2009 10:49:10 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Event Name: REENTER+COMPLETE Start: 1/14/2009 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date From - To 'Hours Task Code NPT Phase 1/24/2009 15:00 - 16:15 1.25 FISH P WEXIT 16:15 - 17:15 1.00 FISH N SFAL WEXIT 17:15 - 17:30 0.25 FISH P WEXIT 17:30 - 20:45 I 3.251 FISH I P I I WEXIT 20:45 - 21:50 I 1.081 CLEAN I P I I WEXIT 21:50 - 00:00 I 0.00 I CLEAN I P I I W EXIT 1/25/2009 00:00 - 00:05 0.08 CLEAN P WEXIT 00:05 - 00:15 0.17 CLEAN P WEXIT 00:15 - 00:20 0.08 CLEAN P WEXIT 00:20 - 00:45 0.42 CLEAN P WEXIT 00:45 - 01:00 0.25 CLEAN P WEXIT 01:00 - 01:15 0.25 CLEAN P WEXIT 01:15 - 03:35 2.33 CLEAN P WEXIT 03:35 - 04:00 I 0.42 I CLEAN I P I I W EXIT 04:00 - 04:45 0.751 DRILL P PROD1 04:45 - 05:40 I 0.92 I DRILL I P I I PROD1 05:40 - 06:00 0.33 DRILL P PROD1 06:00 - 09:00 3.00 DRILL P PROD1 09:00 - 10:50 I 1.831 DRILL I P I I PROD1 10:50 - 12:00 1.17 DRILL P PROD1 12:00 - 13:00 1.00 DRILL P PROD1 J ~~-` \ Page 6 of 13 Spud Date: End: Description of Operations solids recovery. Troubleshoot, remove, then install new SLB depth counter. Set down 6k, PU to 48k and let the jars bleed. Straight pull to 55k. Cock jars and pull to 55k. Jars fired hold 52k then pull to 60k. Broke free and pulling heavy at 50k (6k over). Pull heavy through the first nipple. Fill across the top, the well is taking all of the fluid. POH. Flow check at 5000ft - 1.5bpm loss rate. PJSM regarding handling BHA while POH. Lost 122bb1s on trip out of the hole. LD BHA, lost 4 packing elements from XXN plug, 3.75"o.d., 1/8"w, 1/8"t. Fill hole across the top 0.6bpm loss rate. Fill coil 40bbls & attempt to pump out more slack -none. Cut off CTC. Cut Eft of wire & seal end of wire. MU LH CTC, pull test to 40k, P.T. to 3500psi. MU LH BHA #3 -CTC, DFCV, Disco, Circ Sub, Motor, 3.80"go DSM. Stab onto well. Tag up, set counters. RIH w/ LH BHA #3. Pump min rate while RIH - 0.5bpm losses. Continue to RIH. Lost 49 bbls on trip in the hole. Slowly RIH thru overshot area -clean. Dry tag XN profile at 9827', paint yellow flag. PUW=46k, RIW=27k. Get parameters. 2.5bpm/2050psi w/ 2.1 bpm out. Mill XN profile. Ream & backream thru XN profile until clean. RIH to 9980' -clean. POH. PJSM while POH regarding handling BHA. Lost 55bbls on the trip out of the hole. Pop off well. LD BHA, 4' of wire sticking out end of CTC. Mill was 3.79"go & 3.78" no-go. Clear RF of BOT fishing & milling tools. Cut off CTC. Cut 4' of wire & seal the end. Stab onto well. Fill hole - 15bbls, 1/2bpm loss rate. Close master & pump slack back into the coil. Pop off well. Install night cap & fill across the top PVT=281 at Sam. RU coil cutter. Cut coil to find wire, cut 338'. RD coil cutter. Test wire, insulation test was good & good resistivity 45ohms. Crew change and PJSM PVT=257 at Gam. Dress end of coil. Install CTC. Pull test to 40k -good. P.T. to 3500psi -good. MU BHA #4. HCC bicenter, 1.2 deg motor, RES tool, CoiITRAK assembly. PVT=189 at gam. Open EDC and pump slack forward at 3 bpm. RIH with BHA #4 pumping min rate thru open EDC. Tie-in log from 9700' to 10050'. -11' correction. Start swap to Flo-Pro. Weight check at shoe - 48k at 1 bpm. Run in 6.125" open hole at 1 bpm and HS TF. Run to bottom unobstructed. Losses healed up with the Flo-Pro. Drill 110 fph from 11,315ft at 2.57 / 2.46 bpm. FS=2500psi CP=2850psi ECD=9.6 ppg DWOB is 2.32 Klbs with Ct wt 24 Klbs. Black crumbly chunks of old rubber? (size up to 1 "xi/2"x3/4") over shakers. Drill to 11,450 ft. Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: J ell Name: J e: Name: From - To -05 -05 REENTE NORDIC NORDIC 'Hours R+COM CALIS 2 Task PLET TA Code E NPT Start Rig Rig Phase Spud Date: : 1/14/2009 End: Release: Number: N1 Description of Operations 1/25/2009 14:15 - 14:30 0.25 DRILL P PROD1 Wiper to 11315. 14:30 - 15:15 0.75 DRILL P PROD1 Drill 120 fph-from 11,450ft at 2.57 / 2.48 bpm. PVT = 281 bbls. FS=2650psi CP=2970psi ECD=9.99 ppg DWOB is 1.6 Klbs with Ct wt 19 Klbs. Drill to 11,532 ft. Circ pressure dropped and differential stuck when PU off bottom. 15:15 - 15:45 0.50 DRILL N STUC PROD1 Pull max to 90k several times. Stuck above DGS sub. Shut down pump and let hole relax for 10 min. ECD dropped from 8.66 to 8.23 ppg. Pull to 85k and hold, it popped free after 1.5 minutes. 15:45 - 17:40 1.92 DRILL P PROD1 Wiper to tubing tail clean. Good amount of cuttings unloaded across shaker. Log GR tie-in +7'. Wiper to bottom clean. 17:40 - 18:35 0.92 DRILL P PROD1 Drill 140 fph from 11,532 ft at 2.60 / 2.59 bpm. PVT = 267 bbls. FS=2750psi CP=3080 psi ECD=10.04 ppg DWOB is 1.6 Klbs with Ct wt 19 Klbs. ~ Drill to 11,650 ft. 18:35 - 19:00 0.42 DRILL P PROD1 Wiper to 11315ft -clean. Slight set down at 11,320ft, otherwise clean to TD. 19:00 - 19:35 0.58 DRILL P PROD1 Drill 120 fph from 11,650 ft at 2.60 / 2.56 bpm. PVT = 259 bbls. FS=2700psi CP=3080 psi ECD=10.10 ppg DWOB is 1.6-1.8 Klbs with Ct wt 20 Klbs. Drill to 11,705 ft. 19:35 - 22:00 2.42 DRILL P PROD1 Mini wiper to 11,550ft. Can't seem to RIH & have 25k overpulls. Continue to wiper to 11,315ft. CTD screen went blank, stopped at 11,345ft & were stuck. Pulled free, but very ratty -seems like a cuttings bed. Continue to wiper to 4-1/2" Tbg tail. The shaker decided to quit working. Open EDC & jet to 9000ft. Getting close to 10ppg out MW. Stop at 9900ft & close EDC, blow down kill line & across the stack w/ air to clean the choke line - 22:00 - 22:10 0.17 DRILL P PROD1 Log down for tie-in from 9980ft using reduced pump rate, (+5.5ft corr. 22:10 - 23:00 0.83 DRILL P PROD1 Wiper to 11,315ft. 23:00 - 00:00 1.00 DRILL P PROD1 MAD pass up from 11,315ft to 10,010ft at 500fVhr. 1/26/2009 00:00 - 01:40 1.67 DRILL P PROD1 Continue to MAD pass to 10,010ft. 01:40 - 02:35 0.92 DRILL P PROD1 Wiper to TD -very smooth, 24k RIW. 02:35 - 03:40 1.08 DRILL P PROD1 Drill 120 fph from 11,705 ft at 2.44 / 2.44 bpm. PVT = 267 bbls (topping off). FS=2500psi CP=3080 psi ECD=9.90 ppg DWOB is 1.6-1.9 Klbs with Ct wt 20.5 Klbs. Drill to 11,850 ft. 03:40 - 06:15 2.58 DRILL P PROD1 Wiper to 9840ft -clean. Wiper to TD. 06:15 - 07:30 1.25 DRILL P PROD1 Drill 120 fph from 11,850 ft at 2.45 / 2.44 bpm. PVT = 412 bbls FS=2500psi CP=3020 psi ECD=9.99 ppg DWOB is 2.6 Klbs with Ct wt 20.8 Klbs. Drill to 11,953 ft. ROP down to 40 fph. Start stacking weight and sticking. 07:30 - 09:45 2.25 DRILL P PROD1 Wiper to 9800' -clean both ways. Normal amount of cutting over the shakers. Plan to pump a HI-VIS sweep on the next wiper. 09:45 - 11:10 1.42 DRILL P PROD1 Drill 90 fph from 11,953 ft at 2.42 / 2.40 bpm. PVT = 392 bbls Printed: 2/19/2009 10:49:10 AM • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: J-05 Common W ell Name: J-05 Spud Date: Event Nam e: REENTER+COMPLETE Start : 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date Frorn - To Hours Task Code ~' NPT Phase Description of Operations 1/26/2009 09:45 - 11:10 1.42 DRILL P PROD1 FS=2860 psi CP=31.80 psi ECD=10.00 ppg DWOB is 1.71 Klbs with Ct wt 19.3 Klbs. Start 20 pill of 150LSRV Fol-Pro down the coil. ROP slowed to 55 fph at 12061'. Drill to 12,065 ft. 11:10 - 14:20 3.17 DRILL P PROD1 Wiper to 9800'. Normal cuttings load ahead of the HI-VIS pill. Log GR Tie-in +8.5' correction. Wiper to TD clean. TD well at 12,070' 14:20 - 15:30 1.17 DRILL P PROD1 MAD pass at 600 fph w/ RES to 11,315'. 15:30 - 16:45 1.25 DRILL P PROD1 Wiper to 9800' -Clean. 16:45 - 19:00 2.25 DRILL P PROD1 POH for OHST/Turn assembly. PJSM while POH regarding handling BHA. Bit graded 1-1 & plugged w/ motor rubber. 19:00 - 20:55 1.92 STKOH P PROD1 Tag up. Pop off well & place injector over bung hole. LD BHf coil track tools on the catwalk. Remove MPR & test tools. MU new motor w/ 3.8deg AKO & new 3.75" M609 bit. Attempt to place BHA in hole, can't make it past the hanger. 3 chipped teeth, dial down motor to 3.6 AKO. Tight going, assume it's the wear pad in the chrome tubing. Stab onto well. Power up & test tools. Set counters. 20:55 - 23:35 2.67 STKOH P PROD1 RIH w/ OHST BHA. Tagged GLM#4,#2 & #1 -orientate passed all of them. 23:35 - 23:55 0.33 STKOH P PROD1 Log down for tie-in from 9980ft (-13ft corr. 23:55 - 00:00 0.08 STKOH P PROD1 RIH 10,080ft. 1/27/2009 00:00 - 00:25 0.42 STKOH P PROD1 Log down from 10,080ft to 10,150ft to aid in OHST log comparison. 00:25 - 03:00 2.58 STKOH P PROD1 Trough three times at 50ft/hr from 10,110ft to 10,070ft using :~ .~~~ 2.5bpm/2500psi. 03:00 - 05:40 2.67 STKOH P PROD1 Drill LS OHST with 180 TF from 10,11 at .51 6pm.~Y-~ PVT = 344 bbls FS=2500 psi CP=2500 psi ECD=10:02 ppg DWOB is 0.2-0.4 Klbs with Ct wt 24.7 Klbs. Drill the first 1.5ft at O.ift every 6min. Drill for the next Oft at O.ift every 3min. At 10,116ft drill at 0.3fUhr with good WOB. Drill to 10,118.6ft, getting too much WOB. 05:40 - 06:00 0.33 STKOH P PROD1 Backream & ream 45 deg L & R of LS to permit tools to enter new OHST. 06:00 - 08:00 2.00 STKOH P PROD1 Observe ood WOB and 2de dro at the NBI. Slowl start turning to the right to avoid Shublik. Drill to 10124.9' and 135R TF 10 fph. PUH to roll TF around. - 10126ft; 90R TF; 20 fph; 2.44k WOB; NBI 88.73 deg. - 10132ft; 50R TF; 15 fph; 4.5k WOB; NBI 86.07 deg. - 10136ft; 20R TF; 15 fph; 3.3k WOB; NBI 85.33 deg. - 10145; 20R TF; 30 fph; 4.03 WOB; NBI 84.68 deg. - 10160; 75R TF; 30 fph 3.56 WOB; NBI 87.6 deg. 08:00 - 10:15 2.25 DRILL P PROD1 Drill from 10160 ft at 2.46/ 2.50 bpm. PVT = 370 bbls FS=2600 psi CP=2930 psi ECD=10.03 ppg DWOB is 3.2 Klbs with Ct wt 20.2 Klbs. Increase pump rate to 2.8 bpm. FS= 2850; CP = 3200 psi. Drill to 10180' and observe DLS around 20. GR increase at 10150' and 10169'. Drill ahead with right TF and away from possible geometry or formation problems. Drill to 10,218'. Only getting -20 DLS and it doesn't seem to be improving. 10:15 - 13:10 2.92 DRILL N DPRB PROD1 POH to BHA pumping thru open EDC at 3 bpm. Weight bobble Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date. I From - To Hours Task ', Code' NPT ~ Phase Description of Operations 1/27/2009 10:15 - 13:10 2:92 DRILL N DPRB PROD1 at GLM #1 and 4. PJSM for LD drilling BHA. 13:10 - 16:15 3.08 DRILL N DPRB PROD1 LD drilling BHA. Bit looks good, same 3 chipped cutters that went in the hole. Should not have caused a severe DLS penalty. Swap out the directional package as a precaution. Dial up motor to 3.8 deg and PU a used DS49. Still no go thru the tubing spool. MU BHA #6. DS49, 3.6 deg motor, and CoiITRAK tools. No connection to BHI after stabbing tools. Change out the LOC pin. 16:15 - 18:40 2.42 DRILL N DPRB PROD1 RIH, EDC open 18:40 - 18:50 0.17 DRILL N DPRB PROD1 Log for GR tie in ~ 9980 ft -14 ft correction 18:50 - 21:30 2.67 DRILL P PROD1 Back to drilling with FS=2890 psi @ 2.5/2.5 bpm 22,500# RIW & 44K #'s PUW 21:30 - 22:10 0.67 DRILL P 22:10 - 00:00 1.83 DRILL P 1/28/2009 100:00 - 00:50 I 0.831 DRILL I P 00:50 - 01:45 I 0.921 DRILL I P 01:45 - 03:15 I 1.501 DRILL I P 03:15 - 06:05 2.831 DRILL P 06:05 - 08:00 I 1.921 DRILL I P Drilling C~ 10,274 ft Op=2.5/2.5 bpm ~ 3200 psi &DPRESX=750 psi Den=8.75/8.80 ppg ECD=10.16 ppg DH W06=2400#'s CT WT=20,000#'s ROP=1.1fpm / 69 FPH NBI=92 deg Drill to 10,350 ft PROD1 Wiper to 9840 ft Q 2.5 bpm PROD1 Tag ~ 10,349 ft and drill ahead 10,376 ft PUH for TF change Drilling C~ 10,378 ft Op=2.5/2.5 bpm @ 3030 psi &DPRESX=631 psi Den=8.76/8.8 ppg ECD=10.19 ppg DH W06=1210#'s CT WT=20,000#'s ROP=.9 fpm / 59 FPH NBI=88.91 deg drilled to 10,430 ft PROD1 Continue to drill ahead from 10,430 ft. Drilling C«~ 10,440 ft Op=2.45/2.45 C~ 2800 psi DPRESX=740 psi Den= 8.75/8.83 ppg ECD=10.21 ppg DH WOB=2230 #'s CT WT=20,000 #'s ROP=1.1 fpm / 66 FPH NBI=89.31 deg Hole conditions have continued to be "sticky" with Drill to 10,463 ft PROD1 Wiper to 9,840 ft C~ 2.5 bpm Tag C~ 10,462 ft PROD1 Drill ahead from 10,462 ft. Drilling ~ 10,500 ft Op=2.48 bpm @ 3200 psi DH WOB=3220 #'s CT WT=19,500 #'s ROP=1.1 fpm / 67 FPH Land build section Cad 10,540 ft PROD1 POOH for BHA change out. ~ 9840 ft open EDC and POOH C~ 3.62 bpm PROD1 Crew change, PJSM Inspect coil for wear above connector. Coil ok. Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date I From - To Hours Task I Code NPT I Phase Description of Operations I 1/28/2009 06:05 - 08:00 1.92 DRILL P PROD1 LD turn section BHA. 08:00 - 10:00 2.00 DRILL P 10:00 - 10:15 0.25 DRILL P 10:15 - 10:45 0.50 DRILL P 10:45 - 12:00 ~ 1.25 ~ DRILL ~ P 12:00 - 12:30 0.50 DRILL P 12:30 - 14:30 2.00 DRILL P 14:30 - 15:30 1.00 DRILL P 15:30 - 17:00 1.50 DRILL P 17:00 - 18:35 1.58 DRILL P 18:35 - 20:20 1.75 DRILL P 20:20 - 22:40 2.33 DRILL P 22:40 - 00:00 1.33 DRILL P 1/29/2009 ~ 00:00 - 00:15 ~ 0.25 ~ DRILL ~ P 00:15 - 01:50 1.58 DRILL P 01:50 - 03:25 1.58 DRILL P Bit had one broken cutter on radius. Gauge pads closest to nose was 3.75" no-go. Gauge pads closest to shank was 3.74" no-go. MU 1.1 deg AKO mtr with new 3.75" Hyc DS49 (DSRE413M-A2). Include resistivity tool. Function test BOPs. PROD1 Get on well. Run in hole at 80 fpm. PROD1 Log GR tie in from 10,000'. Subtract 14' correction. PROD1 Run in hole slowly through sidetrack at 10,110'. Hold TF at 150R. Continue to run to btm while circ at min rate (0.21 bpm at 1150 psi) Ta TD t 1 4 ' PROD1 Drill ahead from 10,542'. 3550 psi fs at 2.8 bpm in/out. Drill to 10,610'. Start new flo pro downhole. PROD1 Make wiper trip to 10,150'. New mud back to surface. PROD1 Drill ahead from 10,610'. 3050 psi fs at 2.8 bpm in/out. 100-200 psi mtr work. DHWOB: 1-2k#. PVT: 270 bbls. PROD1 Make wiper trip to 7" csg shoe at 9985'. Hole smooth. PROD1 Drill ahead from 10,700' to 10,814'. 2937 psi fs at 2.74 bpm in/out. PROD1 Make wiper trip. PROD1 Drill from 10,814 ft to 10,965 ft. PRODi Wiper from 10,965 ft. and change out MP #1 liners and swabs. Tie in 9970 ft with +6 ft correction PROD1 FS=2950 ~ 2.75 bpm Drill ahead from 10,965 ft Drilling ~ 11,015 ft Op=2.73 bpm @ 3200 psi DPRESX=650 psi Den=8.73/8.76 ppg ECD=10.2 ppg DH W06=1860#'s CT WT=21,000#'s ROP=.9 fpm / 55 FPH NBI=90.36 deg Drill to 11,057 ft PROD1 Continue drilling from 11,057 ft to 11,070 ft Drilling ~ 11,070 ft Op=2.76 bpm ~ 3230 psi &DPRESX=700 psi Den=8.75/8.81 ppg ECD=10.26 ppg DH WOB=2,260 #'s CT WT=17,800 #'s ROP=1.1 fpm / 66 FPH PROD1 Wiper from 11,070 ft PROD1 Drill ahead from 11,070 ft Drilling C~ 11,090 ft Op=2.73 C~ 3230 psi DPRESX=726 psi Printed: 2/19/2009 10:49:10 AM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALIS TA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 I I Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2009 01:50 - 03:25 1.58 DRILL P PROD1 Den=8.77/8.77 ppg ECD=10.23 ppg DH WOB=2560 #'s CT WT=20,600 #'s ROP=1.2 fpm / 72 FPH Drill to 11,164 ft 03:25 - 05:10 1.75 DRILL P PROD1 Wiper from 11,11,164 ft 05:10 - 07:00 1.83 DRILL P PROD1 Drill ahead from 11,164 ft Drilling ~ 11,190 ft Op=2.76 bpm @ 3300 psi DPRESX=711 psi den=8.8/8.81 ppg ECD=10.33 ppg DH WOB=2630 #'s CT WT=19,400 #'s ROP=.6 fpm / 40 FPH 07:00 - 08:15 1.25 DRILL P PROD1 Drill ahead from 11,244'. 3300 psi fs at 2.70 bpm in/out. 150 psi mtr work. DHWOB: 1-2k#. OA/IA/PVT: 10/129/271 bbls. Drill through some hard stuff, then ROP pickerd back up to 50-100 fph. BHP/ECD: 4630 psi/ 10.36 ppg at 8612' TVD. Drill to 11,300'. 08:15 - 11:00 2.75 DRILL P PROD1 Make long wiper up to 8000' inside 7" liner. Open EDC in cased hole. 3.5 bpm. Notes lots of cuttings over shaker, must have done 11:00 - 11:15 0.25 DRILL P PROD1 Log GR tie in. Add 6' correction. 11:15 - 12:00 0.75 DRILL P PROD1 Run in hole. Smooth to bottom. 12:00 - 15:00 3.00 DRILL P PROD1 Drill ahead from 11,300'. 3230 psi fs at 2.76 bpm in/out. DHWOB: 1-2k#. Wt transfer still good. ROP: 60-80 fph. 15:00 - 17:05 2.08 DRILL P PROD1 Wiper trip to 9840'. Hole very smooth. 17:05 - 20:00 2.92 DRILL P PROD1 Drill from 11,450 ft to 11,553 ft 20:00 - 22:20 2.33 DRILL P PROD1 Wiper from 11,553 ft, Hole still smooth. Tag bottom ~ 11,551 ft 22:20 - 23:15 0.92 DRILL P PROD1 Drill ahead from 11,551 ft FS=3650 psi C~ 2.74 bpm. Drilling ~ 11,557 ft Op=2.74 bpm ~ 3850 psi &DPRESX = 697 psi. Den=8.80/8.82 ppg ECD=10.73 ppg DH WOB=1820 #'s CT WT=16,600 #'s ROP=1.3 fpm / 79 FPH 23:15 - 23:35 0.33 DRILL P PROD1 Geo wiper from 11,605 ft to 11,480 ft. - GR high and ress falling. 23:35 - 00:00 0.42 DRILL P PROD1 Drill ahead from 11,605 ft. with TF=195 deg. Drill to 11,616 ft. 1/30/2009 00:00 - 00:45 0.75 DRILL P PROD1 Continue to drill ahead from 11,616 ft Drilling ~ 11,617 ft Op=2.82 bpm @3700 psi &DPRESX=645 psi Den=8.82/8.87 ppg ECD=10.76 ppg DH WOB=1860 #'s CT WT=16,000 #'s ROP=.9 fpm / 51 FPH 00:45 - 03:15 2.50 DRILL P PROD1 Wiper trip from 11,650 ft. to 9840 ft. @ 2.8 bpm Pump min rate while RIH through build section. 03:15 - 05:05 1.83 DRILL P PROD1 Drill ahead from 11,650 ft Drilling ~ 11,668 ft Printed: 2/19/2009 10:49:10 AM • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date I From - To Hours Task I Code i NPT i Phase ~ Description of Operations 1/30/2009 03:15 - 05:05 1.83 DRILL ~P PROD1 Op=2.8 bpm Ca? 3800 psi DPRESX=672 psi 05:05 - 07:30 I 2.421 DRILL I P 11/31/2009 07:30 - 08:00 08:00 - 09:15 09:15 - 11:00 11:00 - 15:15 15:15 - 19:50 19:50 - 20:30 20:30 - 21:45 21:45 - 00:00 00:00 - 02:45 02:45 - 03:45 03:45 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 09:30 09:30 - 12:30 12:30 - 12:45 12:45 - 13:45 13:45 - 15:30 15:30 - 17:00 17:00 - 17:45 17:45 - 18:15 18:15 - 19:45 19:45 - 19:55 19:55 - 20:15 20:15 - 21:15 0.50 DRILL P 1.25 DRILL P 1.75 DRILL P 4.25 DRILL N 4.58 DRILL N 0.67 DRILL N 1.25 DRILL N 2.25 DRILL N 2.75 DRILL N 1.00 DRILL N 0.25 DRILL N 1.50 DRILL N 0.50 DRILL N 0.50 DRILL N 2.00 DRILL N 1.00 DRILL N 3.00 DRILL N 0.25 DRILL N 1.00 DRILL P 1.75 DRILL P 1.50 DRILL P 0.75 DRILL P 0.50 WHSUR P 1.50 WHSUR N 0.17 WHSUR P 0.33 WHSUR P 1.00 WHSUR P Den=8.84/8.86 ppg ECD=10.85 ppg DH WOB=2300 #'s CT WT=16,500 #'s ROP=1.3 fpm / 76 FPH NBI=85.83 w/ TF=195 deg ROP has been slowing i PROD1 Wiper trip to 9,840 ft C~ 2.8 bpm. Open EDC and jet ~ 4 bpm to 8000'. Call TD due to faultin into Shublik formation. PROD1 Log GR tie in. Add 3' correction. PROD1 Run in hole to TD. Official TD is 11,740'. PROD1 Make MAD logging pass from 11,740' to 11026'. SFAL PROD1 Coil has pin holed. 353K runnin feet with 67% wear (at pin hole area). All foota a was in chrome tubin , Secure well. Close 2-3/8" pipe/slip rams on coil. Hold PJSM with crew. Strip up off well. Find 3/8" pin hole on reel side of pipe. Check i e wall. Minimal near in hole. Weld and dress hole. Stri back on to well. SFAL PROD1 Pull 75k#. Pi a came free. Pull out of hole at 30 fpm. SFAL PROD1 LD BHA SFAL PROD1 Circulate coil to 2% KCL SFAL PROD1 Blow down coil with N2. Cut off CTC, Rig up to unstab pipe, pull coil across and secure to reel. SFAL PROD1 Swapped out reels. SFAL PROD1 RU new reel. SFAL PROD1 PJSM on stabbing in coil SFAL PROD1 MU grapple and PT. Pull coil across and stab into injector. Test Eline -PASS. Terminate eline. SFAL PROD1 MU SLB CTC and stab on well. SFAL PROD1 Crew change. Make rounds. Hold PJSM for slack management. SFAL PROD1 Reverse 115 bbls kcl water 3.25 bpm at 1800 psi. Make up a-coil head. Test same. SFAL PROD1 MU 1.75 AKO mtr w/ 3.75" HYC bit. Stab coil. Test tools. Get on well. SFAL PROD1 Run in hole. SFAL PROD1 Log GR tie in from 9985'. Subtract 14'. PROD1 Run in to CL1 lateral. PROD1 POOH. Disp lace well to 2% kcl water. Attempt to get in to C lateral. Try numerous TF settin s. No go. PROD1 Circulate out of hole. Displace well to KCL water. PROD1 LD drilling BHA and tools / PU FP Nozzle with checks. POST RIH with nozzle to 2,000 ft for FP. WAIT POST Wait on LRHOS -Truck delayed for maintenance, Then wait on crew change while on location. POST PJSM with LRHOS on FP job POST Spot, RU, and PT to 4,000 psi. POST laod 35 bbls into coil to FP well from 2,000 ft to surface, POOH Printed: 2/19/2009 10:49:10 AM • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: J-05 Common Well Name: J-05 Spud Date: Event Name: REENTER+COMPLETE Start: 1/14/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N1 Date -From - To Hours Task Code NPT Phase Description of Operations 1/31/2009 20:15 - 21:15 1.00 WHSUR P POST while laying in diesel to surface. 21:15 - 23:40 2.42 WHSUR P POST OOH, Shut in well, remove BHA and UOC check valves, stab on well and blow back reel. kill line was froze, unstab from well and stand back injector. Hook up to rig air on rig floor and blow back reel. 23:40 - 23:50 0.17 WHSUR P POST PJSM on setting BPV Open swab and monitor well -Vac. 23:50 - 00:00 0.17 WHSUR P POST Set BPV 2/1/2009 00:00 - 00:15 0.25 WHSUR P POST PJSM - ND of BOP's and preparing for rig move 00:15 - 02:30 2.25 WHSUR P POST ND BOP's Prep for rig move 02:30 - 03:00 0.50 WHSUR P POST NU tree cap PT to 5000 psi Rig released @ 03:00 Printed: 2/19/2009 10:49:10 AM .~'j ~ BP Alaska ~ BA ~~~ `~ by Baker Hughes INTEQ Survey Report INTEQ 6~S Company: BP Amoco Date: 2/3/2009 Time: 13:23:26 Page Field: Prudhoe Bay Site: PB J Pad ~ Well: J-05 Co-ordinate(NE) Reference: Well: J-05, True North Vertical (TVD) Reference: J-056:65.8 Section (VS) Reference: Well (O.OON,O.OOE,26.68Azi) ~ Wellpath: J-05CL1 Survey Calculation Method: .Minimum Curvature. Db: Oracle ~eld: 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 J Pad _ TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5968224.22 ft Latitude: 70 19 14.845 N From: Map Easting: 641155.79 ft Longitude: 148 51 20.092 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.08 deg Well: J-05 Slot Name: 05 5002920120 Well Position: +N/-S 2433.87 ft Northing: 5970695.00 ft Latitude: 70 19 38.779 N +E/-W 1995.49 ft Easting : 643105.00 ft Longitude: 148 50 21.840 W Position Uncertainty: 0.00 ft Wellpath: J-OSCL1 Drilled From: J-056 500292012060 Current Datum: J-05B : Height 65.84 Tie-on Depth: 10088.30 ft ft Above System Datum: Mean Sea Level Magnetic Data: 1 /2 712 0 0 8 Declination: 23.33 deg Field Strength: 57660 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 26.34 0.00 0.00 26.68 Survey Program for Definitive Wellpath Date: 1/27/2009 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.00 5950.00 J-056 GYD-CT-CMS Gyrodata Top GYD CT-CMS Gyrodata cont.casing m/s 5956.00 6000.00 J-056 GYD-CT-CMS Gyrodata Btm GYD-CT-CMS Gyrodata cont.casing m/s i 6050.96 10088.30 J-056 MWD Sperry (6050.96-1124 MWD MWD -Standard j 10102.00 11740.00 MWD (10102.00-11740.00) MWD MWD -Standard Annotation MD TVD ft ft ~ 10088.30 8678.52 TIP ~~ 10102.00 8678.39 KOP !.11740.00 8704.37 TD ~ Survey: MWD Stall Date: 2/2/2009 ', Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path BP Alaska ~ ~~ ~r by Baker Hughes INTEQ Survey Report Nuys INTEQ ~, Company: BP - Amoco -- -------- -- Date: 2/3/2009 Time: 13:23:26 --- Page: -- 2 Field: Prudhoe. Bay Co-ordinate(NE) Reference: Well: J-05, True North Site: PB J Pad Vertical (TVD) Reference: J-056:65.8 Well: J-0 5 Section (VS) Reference: Well (O.OON,O.OOE,26.68Azi) ~ '; R'etlpath: J-0 5CL1 Survey Calculafion Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE VS DL S -- Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10088 .30 89.75 13. 89 8678 .52 8612. 68 3432 .25 1652 .15 5974157 .87 644691 .26 3808. 64 0. 00 MWD ~ 10102 .00 91.31 17. 67 8678 .39 8612. 55 3445 .43 1655 .87 5974171 .12 644694 .73 3822. 09 29. 85 MWD 10112 .04 88.68 19. 36 8678 .39 8612. 55 3454 .95 1659 .06 5974180 .70 644697 .74 3832. 03 31. 14 MWD 10132 .42 84.74 23. 07 8679 .56 8613. 72 3473 .91 1666 .42 5974199 .79 644704 .73 3852. 27 26. 53 MWD 10150 .16 88.07 24. 96 8680 .68 8614. 84 3490 .08 1673 .63 5974216 .09 644711 .63 3869. 96 21. 57 MWD 10178 .96 90.40 30. 72 8681 .06 8615. 22 3515 .53 1687 .07 5974241 .80 644724 .58 3898. 73 21. 57 MWD 10205 .32 92.67 36. 53 8680 .35 8614. 51 3537 .46 1701 .65 5974264 .00 644738 .74 3924. 88 23. 65 MWD 10235 .02 93.47 49. 15 8678 .76 8612. 92 3559 .16 1721 .78 5974286 .08 644758. 45 3953. 30 42. 52 MWD 10266. 33 91.69 65. 78 8677 .34 8611. 50 3575 .92 1748 .05 5974303 .34 644784. 40 3980. 08 53. 36 MWD I, 10295. I 13 91.90 80. 68 8676 .43 8610. 59 3584 .20 1775 .54 5974312 .14 644811. 72 3999. 82 51. 72 MWD ' 10333. 44 89.75 101. 51 8675 .87 8610. 03 3583 .47 1813 .62 5974312 .14 644849. 81 4016. 26 54. 65 MWD 10363. 96 89.14 117. 44 8676 .17 8610. 33 3573 .33 1842 .30 5974302 .55 644878. 67 4020. 08 52. 23 MWD 10396. 14 88.07 134. 12 8676 .96 8611. 12 3554 .59 1868 .31 5974284 .30 644905. 03 4015. 01 51. 92 MWD 10432. 43 89.54 152. 78 8677 .72 8611. 88 3525 .57 1889 .82 5974255 .70 644927. 09 3998. 74 51. 57 MWD '; 10467. 40 91.84 171. 15 8677 .30 8611. 46 3492 .47 1900 .60 5974222 .81 644938. 50 3974. 00 52. 93 MWD i ' 10506. 52 91.10 191. 43 8676 .28 8610. 44 3453 .58 1899 .72 5974183 .91 644938. 36 3938. 85 51. 86 MWD 10537. 94 90.15 205. 33 8675 .94 8610. 10 3423 .83 1889 .84 5974153 .99 644929. 05 3907. 84 44. 34 MWD 10566. 39 90.00 209. 58 8675 .90 8610. 06 3398 .59 1876 .73 5974128 .51 644916. 42 3879. 40 14. 95 MWD 10596. 37 90.80 213. 64 8675 .69 8609. 85 3373 .07 1861 .02 5974102 .69 644901. 20 3849. 53 13. 80 MWD 10632. 97 91.10 218. 50 8675 .09 8609. 25 3343 .50 1839 .48 5974072 .72 644880. 23 3813. 44 13. 30 MWD 10662. 06 90.61 221. 86 8674 .65 8608. 81 3321 .28 1820 .71 5974050 .14 644861. 90 3785. 16 11. 67 MWD 10708. 75 90.12 227. 61 8674 .35 8608. 51 3288 .13 1787 .87 5974016 .37 644829. 69 3740. 79 12. 36 MWD 10740. 77 89.45 231. 94 8674 .47 8608. 63 3267 .45 1763 .42 5973995 .24 644805. 65 3711. 35 13. 68 MWD 10770. 48 88.37 235. 21 8675 .04 8609. 20 3249 .82 1739 .53 5973977 .15 644782. 09 3684. 86 11. 59 MWD 10799. 92 87.88 233. 84 8676 .00 8610. 16 3232 .74 1715 .56 5973959 .62 644758. 47 3658. 84 4. 94 MWD 10831. 44 88.25 230. 24 8677 .07 8611. 23 3213 .37 1690 .73 5973939 .78 644734. 01 3630. 38 11. 47 MWD 10871. 25 89.54 226. 45 8677 .83 8611. 99 3186 .92 1661 .00 5973912 .77 644704. 79 3593. 40 10. 05 MWD 10899. 43 89.97 224. 00 8677 .96 8612. 12 3167 .07 1641 .00 5973892 .55 644685. 17 3566. 68 8. 83 MWD 10931. 82 89.69 221. 16 8678 .05 8612. 21 3143 .22 1619 .08 5973868 .29 644663. 72 3535. 54 8.. 81 MWD 10956. 78 90.58 218. 24 8677 .99 8612. 15 3124 .02 1603 .14 5973848 .79 644648. 14 3511. 22 12. 23 MWD 10985. 27 90.34 215. 40 8677 .76 8611. 92 3101 .22 1586 .07 5973825 .67 644631. 51 3483. 18 10. 00 MWD 11018. 69 89.88 212. 15 8677 .70 8611. 86 3073 .44 1567 .49 5973797 .54 644613. 47 3450. 02 9. 82 MWD 11055. 81 90.15 208. 83 8677 .69 8611. 85 3041 .46 1548 .66 5973765 .21 644595. 25 3412. 99 8. 97 MWD 11083. 36 89.82 206. 45 8677 .70 8611. 86 3017 .06 1535 .88 5973740 .57 644582. 94 3385. 45 8. 72 MWD 11116. 90 88.65 203. 48 8678 .15 8612. 31 2986 .66 1521 .73 5973709 .91 644569. 37 3351. 93 9. 52 MWD 11146. 78 89.05 200. 41 8678 .75 8612. 91 2958 .95 1510 .56 5973682 .00 644558. 74 3322. 16 10. 36 MWD 11182. 95 89.02 202. 02 8679 .35 8613. 51 2925 .24 1497 .48 5973648 .04 644546. 30 3286. 16 4. 45 MWD 11211. 43 88.71 205. 22 8679 .92 8614. 08 2899 .15 1486 .07 5973621 .75 644535. 39 3257. 73 11. 29 MWD 11243. 01 88.74 209. 33 8680 .62 8614. 78 2871 .10 1471 .61 5973593 .42 644521. 47 3226. 17 13. 01 MWD 11273. 14 88.31 213. 00 8681 .40 8615. 56 2845 .33 1456 .02 5973567 .36 644506. 38 3196. 14 12. 26 MWD 11310. 48 88.31 216. 36 8682 .50 8616. 66 2814 .64 1434 .79 5973536 .28 644485. 73 3159. 19 8. 99 MWD 11349. 66 85.64 219. 24 8684 .57 8618. 73 2783 .73 1410 .81 5973504 .92 644462. 36 3120. 81 10. 02 MWD 11379. 81 85.06 221. 53 8687 .01 8621. 17 2760 .84 1391 .34 5973481 .66 644443. 33 3091. 61 7. 81 MWD 11406. 87 85.86 219. 72 8689 .15 8623. 31 2740 .37 1373 .78 5973460 .86 644426. 16 3065. 43 7. 29 MWD 11435. 77 86.69 216. 30 8691 .03 8625. 19 2717 .65 1356 .03 5973437 .81 644408. 84 3037. 16 12. 15 MWD 11466. 86 87.76 213. 18 8692 .54 8626. 70 2692 .13 1338 .33 5973411 .96 644391. 64 3006. 42 10. 60 MWD 11494. 10 88.16 210. 55 8693 .51 8627. 67 2669 .02 1323 .96 5973388 .58 644377. 72 2979. 31 9. 76 MWD 11536. 58 89.57 207. 48 8694 .35 8628. 51 2631 .88 1303 .37 5973351 .06 644357. 83 2936. 88 7. 95 MWD 11565. 99 89.72 204. 49 8694 .53 8628. 69 2605 .45 1290 .48 5973324 .39 644345. 46 2907. 48 10. 18 MWD 11594. 89 92.15 202. 42 8694 .06 8628. 22 2578 .94 1278 .98 5973297 .67 644334. 46 2878. 63 11. 04 MWD 11625. 53 88.96 200. 54 8693 .76 8627. 92 2550 .44 1267 .76 5973268 .96 644323. 79 2848. 12 12. 08 MWD 11651. 58 86.19 201. 15 8694 .86 8629. 02 2526 .12 1258 .50 5973244 .46 644315. 00 2822. 23 10. 89 MWD ~ 11681. 38 83.35 200. 24 8697 .58 8631. 74 2498 .36 1248 .02 5973216 ..51 644305. 05 2792. 72 10. 00 MWD li .~"~ ~ BP Alaska ~,~~~ by Baker Hughes INTEQ Survey Report -i~r BAKER HYGFGS INTEQ ~, Company: ----- BP Amoco ------ ------ Date: 2/3/2009. Time: 13:23:26 Page: 3 I ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: J-05, True North Site: PB J Pad Vertical (TVD) Reference: J-05B :65.8 Well: J-05 Section (VS) Reference: Well (O.OON,O.OOE,26.68Az) ~ R'ellpath: ~__ --- J-05Ct_1 - - Survey Calcula[ion Method: - Minimum Curvature Db: Oracle -- - J Survey -------__- ----- ---- - ..._...__ - -- --- - MD fncl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool e ~ ft .deg deg ft ft ft ft ft ft fl deg/100ft 11740.0 0 83.35 200.24 8704.37 8638.53 2443.73 1227.87 5973161.51 644285.95 2734.86 0.00 MWD • ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Ten-ie.Hubble@bp.com] Sent: Monday, March 09, 2009 12:05 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU J-05C /PTD # 208-171 & J-05CL1 /PTD # 208-172 Hi Art, Please reference the following well: Well Name: PBU J-05C & PBU J-05CL1 Permit #: 208-171 & 208-172 API #: 50-029-20120-03-00 & 50-029-20120-60-00 Top Perf MD: N/A, Open Hole Bottom Perf MD: N/A, Open Hole This well began Production on March 7, 2009 Method of Operations is: Flowing Date of Test: 03/07/09 Hours Tested: 8 24-Hour Rate /Oil-Bbl: 1,483 24-Hour Rate /Gas-Mcf: 31,279 24-Hour Rate /Water-Bbl: 63 Test Rate /Oil-Bbl: 494 Test Rate /Gas-Mcf: 10,426 Test Rate /Water-Bbl: 21 Choke Size: 12.3 Gas-Oil Ration: 21,092. Flow Tubing Pressure: 1,160 Casing Pressure: 1,400 Oil Gravity-API: Not Available 3/9/2009 <,?„~' L~ ~ ~ ~ i'7~j SARAH PALIN, GOVERNOR ~'_ ~. ~S~A OIL tustl ll[t1•S 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMl-iISSI0IIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-05CL1 BP Exploration Alaska Inc. Permit No: 208-172 Surface Location: 650' FNL, 1245' FEL, SEC. 09, T1 1N, R13E, UM Bottomhole Location: 1674 FSL, 5194' FWL, SEC. 04, Tl 1N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well PBU J-05C, Permit No 208-171, API 50-029-20120-03. Production should continue to be reported as a function of the original API number stated above. 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). S' cerely, ``~ ~~'~ aniel T. Seamount, Jr. Chair DATED this ~ ~ day of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 1.~.. ~ _ '~ ~ ~ ._ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1c. Spr;ifMisli is proposed for. ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ^ Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU J-05CL1 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 11900' TVD 8618' ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 650' FNL 1245' FEL SEC 09 T1 N R E M 7. Property Designation: ADL028281 Pool , , . , 1 , 13 , U Top of Productive Horizon: 2660' FSL, 408' FWL, SEC. 03, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 1, 2009 Total Depth: 1674' FSL, 5194' FWL, SEC. 04, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13230' 4b. Location of Well (State Base Plane Coordinates): Surface: x-643105 y- 5970695 Zone-ASP4 10. KB Elevation (Height above GL): 65.84' feet 15. Distance to Nearest well within Pool: 74' 16. Deviated Wells: Kickoff Depth: 10080 feet Maximum Hole An le: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3018 Surface: 2158 1 in Pr r m: ' i i n T in h- o n i t f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11315 Total Depth TVD (ft): Plugs (measured): 9823 Effective Depth MD (ft): 11315 Effective Depth TVD (ft): 8685 Junk (measured): N/A Casin Len th'' ize Cement:Volume MD TVD Conductor /Structural 1 ' Surface 1 - / " x PF I ' Intermediate 1 N N I I I 1 Liner 7' 7" 1 I ' Perforation Depth MD (ft): 9985' - 11315' Perforation Depth TVD (ft): 8653' - 8685' 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~oregoing is true and correct. Printed Name Joh ~' ' t Si nature Contact Sean McLaughlin, 564-4387 Title En ineerin Team Leader .Prepared By NameMumber: Phone 564-4711 Date Ib ~ ~~~ Sondra Stewman, 564-x750 Commission Use Ont Permit To ill • 0`l0~ 1~a"~ API Number: 50-029-20120-60-00 Permit A proval See cover letter for r r 'r 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: ^ es l!S No Mud Log Req'd: ^ Yes [~No ~~,yy~ HZS Measures: ®Yes ^ No Directional Survey Req'd: (l~Yes ^ No Other: ~~,' ~g ~ ~ ~ ~'S~ ,-~` = ~ ~-~ ~``1 ~ `~ /~ ~ / / APPROVED BY THE COMMISSION ~~ Date ~~ '~'~ COMMISSIONER Form 10-401 Revised 12/2005 y ~ ;.- ~~~AL ~~ ~~~~~~ Submit In Duplicate by CTD RWO + Sidetrack Summary BPXA Prudhoe Bay J-05CL1 CTD Sidetrack October 20, 2008 Pre-Rig Work: 1. O Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. 2. O CMIT-TxIA to 3500 psi 3. S Pull PXN plug, set XXN plug, dump sluggits 4. E Chemical cut @ 9725', 10' from the top of the 1st full joint above the packer (Ref: 03/13/00 tubing tally). 5. F Circulate bullhead seawater thru the cut. Bleed WHP's to 0 psi. 6. O Blind and bleed lines, remove well house, level pad Rig Work: (Scheduled to begin on February O1, 2009) Tubing Swap 1. MIRU, Set TWC, ND Tree, NU BOPE and test BOPE to 250 psi low and 3500 psi high. 2. Pu114-1/2" L-80 tubing 3. Replace 7" packoffs 4. Run 4-1/2" Chrome completion C Lateral 5. ND RWO BOPS, NU Tree, NU CT Drilling BOPE and test. 6. Pull ball and rod, RHC plug, and XXN plug CLl Lateral 8. OH sidetrack at 10,080' 9. Dri113.75" lateral section to 11,900'. 10. FP well to 2000' with diesel. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. ~~~ ~ ~ 2. Pull BPV. ~~~ ~ ~ 3. Run live gas lift design. 4. Flow well to test separator Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg 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: 3.75" (gauge bit used) Casing Program: None- Open hole 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. Maximum planned hole angle is 91 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 13,230 ft. • Distance to nearest well within pool - 74 ft. (J-19) Anti-Collision Issues • J-19 - 74' ctr-ctr, Ivishak producer. Logging • MW D directional, Gamma Ray, Resistivity will be run over all of the open hole section. Hazards • The maximum recorded H2S level on J pad is 110 ppm on well J-26. • No planned fault crossings Reservoir Pressure • The reservoir pressure on J-05CL1 is expected to be 3,018' psi at 8,600' TVDSS. (6.8 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,158 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble tEE = 4-1/8" CNV WELLHFAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 65.8' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93 @ 10119' Datum MD = NA Datum TV D = 8800' SS 30" CONDUCTOR ~-~ 98 13-3/8" CSG, 68#, ID = 12.415" 2151' 9-5/8" FOC 2197' s-5/a" Foc 2359' 18-5/8" CSG, 96.5# / 109#, K-55, BTRS, 25$3' ID = 17.655" / 17.563" ?? Minimum ID = 3.725" @ 9823' 4-1 /2" HES XN NIPPLE 7" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' TOP OF 7" LNR 2~1 PBR, ID = ? 2151' 13-3/8" X 9-5/8" XO, ID = 8.681 " 221$' 4-1/2" HES X NIP, ID = 3.813" CAMCO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3053 3051 9 KGB2 DMY INT 0 03/10/07 3 5442 5062 40 KG62 DMY INT 0 03/10/07 2 7348 6567 36 KG82 DMY INT 0 03/13/00 1 8920 7813 34 KG62 DMY INT 0 03/13/00 r.~802' 5790' 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 5802' 9-5/8" X 7" BKR ZXP LTP, ID = 7.50" 5818' 9-5/8" X 7" BKR HMC HGR, ID = 6.313" TOP OF WHIPSTOCK ~~ 5900' 9-518" EZSV 5986' 9-5/8" CSG, 47#, 10510' L-80, ID = 8.681" 4-1 /2" HES X NIP, ID = 3.813" 977$' H7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9802' 4-1/2" HES X NIP, ID = 3.813" ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ ~ 7" LNR 26#, L-80, BTGM .0383 bpf, ID = 6.276" ~ OPEN HOLE TD J -0 ~ ~ N~OWN 7" SCAB LONRGHUNG OEFF BORE E GENCYSLIPS. MILLOUT WINDOW (J-056} 5956' - 5987' 9823' H4-1/2" HES XN NIP, ID = 3.725" 9823' 4-1/2" PXN PLUG (07/08/08) 9$35' 4-1/2" WLC-G, ID = 3.958" ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06/77 ORIGINAL COMPLETION 7/5/2007 SWGSV SET PXN PLUG (03/16/07) 03/13/00 TWA SIDETRACK COM PLETION 08/22/07 CAZ/PJC 7" TIEBK CORRECTIONS 07/15/03 CMO/TLP KB ELEVATION, MAX ANGLE 07/22/08 JRS/SV RESET PXN PLUG (07/08/08) 05/29/06 CO/DTM TREE CORRECTIONS (06/13/04) 03/10/07 CJWPAG GLV GO 03/13/07 ALH/PJC CSG &LTP CORRECTIONS PRUDHOE BAY UNIT WELL: J-05B PERMff No: FL000180 API No: 50-029-20120-02 SEC 9, T11 N, R13E, 650' SNL & 1245' WEL BP Exploration (Alaska) TREE= 4-1/8" CNV WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 65.8' BF. ELEV = 38.25' KOP = 3107' Max Angle = 93 @ 10119' Datum MD = Datum TV D = NA 8800' SS ~ J 0 5 C& C L 1 SAFETYNOTES. NOTE: ORIGINAL WELLBORE ~ OT SHOWN. 7" SCAB LNR HUNG OFF Proposed CTD Extension and Lateral EIV>ERGENCYSLIPS. 30" CONDUCTOR 98' 13-3/8" CSG, 68#, ID = 12.415" 2151' 9-5/8" FOC 2197' 9-5/8" FoC 2359' 18-5/8" CSG, 96.5# / 109#, K-55, BTRS, 2553' ID = 17.655" / 17.563" ?? Minimum ID = 7" TIEBK, 26#, L-80 BTD-M, .0383 bpf, ID = 6.276' 5802 TOP OF 7" LNR --I 5802 TOP OF WHIPSTOCK ~-~ 5900' 9-5/8" EZSV L-80, ID = 8.681" 2046' PBR, ID = ? 2151' 1 13-3/8" X 9-5/8" XO. ID = 8.681" H4-1/2" HES X NIP, ID = 3.813" CAMCO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 2 1 5790' 9-5/8" X 7" BKR ZXP TIEBK PKR, ID = 6.313" 5802' 58~ 9-5/8" X 7" BKR ZXP LTP, ID = 7.50" 9-5/8" X 7" BKR HMC HGR, ID = 6.313" MILLOUT WINDOW (J-05B) 5956' - 5987' A ~ 9765' 4-1/2" HES X NIP, ID = 3.813" 977$' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9$Q2' 4-112" HES X NIP, ID = 3.813" ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 7" LNR, 26#, L-80, BTGM .0383 bpf, ID = 6.276" I 9985' B (current openhole completion) Openhole TD 11315' 4-1/8" Openhole TD 12025' U C 9823' ~-~4-1/2" HES XN NIP, ID =milled to 3.80" ~ 9835' H 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED _ CL1 3-3/4" Openhole to TD 11900' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06/77 ORIGINAL COMPLETION 7/5/2007 SWGSV SET PXN PLUG (03/16/07) 03/13/00 TWA SIDETRACKCOMPLETION 08/22/07 CAZ/PJC 7"TIEBKCORRECTIONS 07/15/03 CMO/TLP KB ELEVATION, MAX ANGLE 07/22/08 JRS/SV RESET PXN PLUG (07108/08) 05/29/06 CO/DTM TREE CORRECTIONS (06/13/04) 08/06/08 MSE PROPOSED CTD SIDETRACKS 03/10/07 CJNIPAG GLV GO 03/13/07 ALHIPJC CSG &LTP CORRECTIONS PRUDHOE BAY UNfr WELL: J-05C 8 CL1 PERMfr No: API No: 50-029-20120-03 & 06? SEC 9, T11 N, R13~ 650' SNL & 1245' WEL BP Exploration (Alaska) # • by BP Alaska Baker Hughes INTEQ Planning Report pt~ INTEQ --- Company: BP Amoco - Date:. 10/21/2008 Time - 1.4:15:17 `Page: ' 1 Field: Prudhoe Bay Co-ardinate(NE) Reference: Well: J-05, True North 'Site: PB J'Pad Vertical (TVD) Reference: J-056:65.8 Well: J-05 Section (VS) Reference: Well (f):OON,O.OOE,197.OQAzi) Wellpath: Plan 2, J-05CL1 Survey Calculation Method: Minimum Curvature Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 '~ Geo Datum: NAD27 (Clarke 1866) 1' Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB J Pad ~- _ TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5968224.22 ft Latitude: 70 19 14.845 N From: Map Easting: 641155.79 ft Longitude: 148 51 20.092 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.08 deg Well• J-05 Slot Name: 05 002920120 j Well Position: +N/-S 2433.87 ft Northing: 5970695. 00 ft Latitude: 70 19 38.779 N ! +E/-W 1995.49 ft Position Uncertainty: 0.00 ft Easting : 643105. __ 00 ft Longitude: 148 50 21.840 W Wellpath: Plan 2, J-05CL1 __ _.__ -- -- - Drilled From: J-056 - 500292012060 Tie-on De the 10 p 077.50 ft ~ Current Datum: J-05B : Height 65. 84 ft Above System Datum: Mean Sea Level Magnetic Data: 10/13/2008 Declination: 22.93 deg Field Strength: 57677 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 26.34 0.00 0.00 197.00 Plan Plan #2 Date Composed: 10/13/2008 copy Sean's plan 2 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets _-- --- - Map Map <---- Latitude ---> <-° Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip, Dir. ft ft ft ft ft J-05CL1 Polygon 65.84 3605.15 1614.18 5974330.00 644650.00 70 20 14.234 N 148 49 34.696 W -Polygon 1 65.84 3605.15 1614.18 5974330.00 644650.00 70 20 14.234 N 148 49 34.696 W -Polygon 2 65.84 2306.16 1019.25 5973020.00 644080.00 70 20 1.460 N 148 49 52.076 W -Polygon 3 65.84 2250.82 1298.27 5972970.00 644360.00 70 20 0.915 N 148 49 43.929 W -Polygon 4 65.84 3368.31 1969.75 5974100.00 645010.00 70 20 11.904 N 148 49 24.313 W ~ -Polygon 5 65.84 3607.90 1994.33 5974340.00 645030.00 70 20 14.260 N 148 49 23.593 W J-05C Fault 1 65.84 3814.70 329.84 5974515.00 643362.00 70 20 16.296 N 148 50 12.206 W -Polygon 1 65.84 3814.70 329.84 5974515.00 643362.00 70 20 16.296 N 148 50 12.206 W -Polygon 2 65.84 4090.86 1426.39 5974812.00 644453.00 70 20 19.011 N 148 49 40.178 W J-05C Fault 2 65.84 1384.13 798.61 5972094.00 643877.00 70 19 52.392 N 148 49 58.522 W -Polygon 1 65.84 1384.13 798.61 5972094.00 643877.00 70 19 52.392 N 148 49 58.522 W -Polygon 2 65.84 1629.36 1471.46 5972352.00 644545.00 70 19 54.803 N 148 49 38.875 W -Polygon 3 65.84 1842.89 1708.59 5972570.00 644778.00 70 19 56.902 N 148 49 31.950 W -Polygon 4 65.84 2483.45 1897.86 5973214.00 644955.00 70 20 3.201 N 148 49 26.419 W -Polygon 5 65.84 2871.00 2293.35 5973609.00 645343.00 70 20 7.012 N 148 49 14.866 W -Polygon 6 65.84 2959.77 2726.16 5973706.00 645774.00 70 20 7.884 N 148 49 2.226 W -Polygon 7 65.84 2898.76 2883.03 5973648.00 645932.00 70 20 7.283 N 148 48 57.646 W -Polygon 8 65.84 2994.10 3653.05 5973758.00 646700.00 70 20 8.217 N 148 48 35.157 W -Polygon 9 65.84 2898.76 2883.03 5973648.00 645932.00 70 20 7.283 N 148 48 57.646 W -Polygon 10 65.84 2959.77 2726.16 5973706.00 645774.00 70 20 7.884 N 148 49 2.226 W -Polygon 11 65.84 2871.00 2293.35 5973609.00 645343.00 70 20 7.012 N 148 49 14.866 W -Polygon 12 65.84 2483.45 1897.86 5973214.00 644955.00 70 20 3.201 N 148 49 26.419 W -Polygon 13 65.84 1842.89 1708.59 5972570.00 644778.00 70 19 56.902 N 148 49 31.950 W ~ -Polygon 14 65.84 1629.36 1471.46 5972352.00 644545.00 70 19 54.803 N 148 49 38.875 W J-05C Fault 3 65.84 2203.46 792.23 5972913.00 643855.00 70 20 0.450 N 148 49 58.706 W by BP Alaska Baker Hughes INTEQ Planning Report qtr ~~ INTEQ -- (Company: BPAmoCO _-- Date: 10/21/2008.. Time: 14;15x7 Page: 2 ,Field. P rudhoe Bay Co-ordinate(NE) Reference: Well: J-05, True North Sites P B J Pad Vertical (TVD) Reference: J-056: 65.8 Well: J-05 Section (VS) Reference: Well (O .OON,I).OOE,197.OOAz i) ~I Wellpath: P lan 2 J-05CL1 Survey Calculation Methods Minimum Curvature Db: Sybase Targets Map Map <---- Latitude ----> <--- Longitude ---> ~ame Description TVD +N!-S +E/-W Northing Easting Deg Min Sec Deg Min.: Sec :.Dip. ' Dir. ft ft ft ft ft -Polygon 1 65.84 2203.46 792.23 5972913.00 643855.00 70 20 0.450 N 148 49 58.706 W -Polygon 2 65.84 1969.09 860.78 5972680.00 643928.00 70 19 58.145 N 148 49 56.705 W -Polygon 3 65.84 1610.26 689.89 5972318.00 643764.00 70 19 54.616 N 148 50 1.696 W -Polygon 4 65.84 1969.09 860.78 5972680.00 643928.00 70 19 58.145 N 148 49 56.705 W J-05CL1 Target 1 8675.84 3483.92 1676.88 5974210.00 644715.00 70 20 13.042 N 148 49 32.865 W J-05CL1 Target 2 8675.84 3064.40 1383.80 5973785.00 644430.00 70 20 8.916 N 148 49 41.427 W J-05CL1 Target 3 8675.84 2323.39 1164.62 5973040.00 644225.00 70 20 1.629 N 148 49 47.832 W~ Annotation MD TVD ft ft - - -- - - 10077.50 8678.25 TIP - - _ _ - 10080.00 8678.35 KOP 10095.00 8679.57 3 j 10110.00 8681.46 4 10140.00 8683.00 5 10340.00 8678.71 6 10540.00 8676.94 7 10590.00 8676.83 End of 40 Deg/100' DLS 10890.00 8677.84 9 11340.00 8681.16 10 11640.00 8682.58 11 11900.00 ~ 8683.59 TD - j - ___ Plan Section Information _ - ~ MD Incl Azim TVI) +N/-S +E/-W DLS Build Turn _ _ TFO Target I ft deg deg ft ft ft deg/100ft degllOOft deg/100ft deg 10077.50 87.40 11.26 8678.25 3421.71 1649.80 0.00 0.00 0.00. 0.00 I 10080.00 87.94 11.87 8678.35 3424.16 1650.30 32.57 21.60 24.40 48.47 10095.00 82.75 14.89 8679.57 3438.70 1653.76 40.00 -34.61 20.13 1 50.00 10110.00 82.79 20.94 8681.46 3452.85 1658.33 40.00 0.27 40.32 90.00 10140.00 91.32 29.39 8683.00 3479.91 1671.06 40.00 28.44 28.19 45.00 10340.00 90.72 109.41 8678.71 3544.67 1843.39 40.00 -0.30 40.01 89.50 10540.00 10590.00 90.13 90.12 189.41 209.41 8676.94 8676.83 3386.16 3339.24 1937.09 1920.56 40.00 -0.30 40.00 40.00 -0.02 40.00 90.00 90.00 10890.00 89.51 245.40 8677.84 3139.52 1703.33 12.00 -0.20 12.00 91.00 11340.00 89.71 191.40 8681.16 2799.79 1434.03 12.00 0.05 -12.00 270.00 11640.00 89.77 227.40 8682.58 2542.72 1289.16 12.00 0.02 12.00 90.00 11900.00 89.80 196.20 8683.59 2324.47 1153.83 12.00 0.01 -12.00 270.00 Survey ,biD Incl Azim SSTVD NJS E/W MapN VIapE DI.S VS TFO To ft deg deg ft ft ft ft ft deg/100ft ft deg 10077.50 87.40 11.26 8612.41 3421.71 1649.80 5974147.29 644689.11 0.00 -3754.55 0.00 MWD1 10080.00 87.94 11.87 8612.51 3424.16 1650.30 5974149.75 644689.57 32.57 -3757.04 48.47 MWD 10095.00 82.75 14.89 8613.73 3438.70 1653.76 5974164.35 644692.75 40.00 -3771.95 150.00 MWD 10100.00 82.75 16.91 8614.36 3443.47 1655.12 5974169.14 644694.01 40.00 -3776.91 90.00 MWD 10110.00 82.79 20.94 8615.62 3452.85 1658.33 5974178.58 644697.05 40.00 -3786.83 89.75 MWD i 10125.00 87.05 25.18 8616.95 3466.59 1664.18 5974192.43 644702.64 40.00 -3801.68 45.00 MWD 10140.00 91.32 29.39 8617.16 3479.91 1671.06 5974205.88 644709.25 40.00 -3816.43 44.62 MWD 10150.00 91.35 33.40 8616.93 3488.44 1676.26 5974214.51 644714.30 40.00 -3826.11 89.50 MWD ~ 10175.00 91.40 43.40 8616.33 3508.01 1691.77 5974234.37 644729.42 40.00 -3849.35 89.59 MWD 10200.00 91.41 53.40 8615.71 3524.58 1710.43 5974251.29 644747.77 40.00 -3870.65 89.83 MWD i 10225.00 91.38 63.40 8615.10 3537.66 1731.69 5974264.77 644768.77 40.00 -3889.38 90.08 MWD • by BP Alaska Baker Hughes INTEQ Planning Report r><.r s Company:. BP Amoco --- - Date: ..10/21/2008 Time 14:15:17 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well J-05, True North Site: PB J Pad VerticaC(TVD) References J-056 `: 65.8 Well: J-05 Section (VS) Reference: Well (O.OON,O.OOE,197.OOAzi) s Wellpath: Plan 2, J-05CL1 Survey Calculation Method: Minimum Curvature Dh: Sybase Survey MD Intl Azitn ft deg deg. 10250.00 91.30 73.41 10275.00 91.18 83.41 10300.00 91.03 93.41 10325.00 90.84 103.41 10340.00 90.72 109.41 10350.00 90.72 113.41 10375.00 90.70 123.41 10400.00 90.66 133.41 10425.00 90.60 143.41 10450.00 90.52 153.41 10475.00 90.42 163.41 10500.00 90.32 173.41 10525.00 90.20 183.41 10540.00 90.13 189.41 10550.00 90.13 193.41 10575.00 90.12 203.41 10590.00 90.12 209.41 10600.00 90.10 210.61 10625.00 90.04 213.61 10650.00 89.99 216.61 10675.00 89.94 219.61 10700.00 89.89 222.61 10725.00 89.83 225.61 10750.00 89.78 228.61 10775.00 89.73 231.61 10800.00 89.68 234.60 10825.00 89.63 237.60 10850.00 89.58 240.60 10875.00 89.54 243.60 10890. 00 89. 51 245.40 10900. 00 89. 51 244.20 10925. 00 89. 51 241.20 10950. 00 89. 51 238.20 10975. 00 89. 52 235.20 11000. 00 89. 52 232.20 11025. 00 89 .53 229.20 11050. 00 89 .53 226.20 11075. 00 89 .54 223.20 11100. 00 89 .55 220.20 11125. 00 89 .57 217.20 11150. 00 89 .58 214.20 11175. 00 89 .59 211.20 11200. 00 89 .61 208.20 11225. 00 89 .62 205.20 11250. 00 89 .64 202.20 11275. 00 89 .66 199.20 11300. 00 89 .68 196.20 11325. 00 89 .70 193.20 11340. 00 89 .71 191.40 11350.00 89.71 192.60 11375.00 89.71 195.60 11400.00 89.71 198.60 11425.00 89.72 201.60 SS TVD N/S E/W ft ft ft 8614.52 3546.84 1754.90 8613.97 3551.86 1779.36 8613.49 3552.55 1804.31 8613.08 3548.90 1829.01 8612.87 3544.67 1843.39 8612.75 3541.02 1852.69 8612.44 3529.14 1874.65 8612.14 3513.63 1894.22 8611.87 3494.96 1910.79 8611.62 3473.69 1923.87 8611.41 3450.47 1933.06 8611.25 3426.02 1938.07 8611.14 3401.06 1938.77 8611.10 3386.16 1937.09 8611.08 3376.36 1935.11 8611.02 3352.67 1927.23 8610.99 3339.24 1920.56 8610.97 3330.58 1915.56 8610.94 3309.41 1902.27 8610.93 3288.96 1887.90 8610.95 3269.29 1872.47 8610.99 3250.45 1856.04 8611.05 3232.50 1838.64 8611.13 3215.49 1820.33 8611.24 3199.46 1801.15 8611.37 3184.45 1781.16 8611.52 3170.51 1760.41 8611.69 3157.67 1738.96 8611.88 3145.98 1716.87 8612.00 3139.52 1703.33 8612.09 3135.27 1694.28 8612.31 3123.80 1672.07 8612.52 3111.19 1650.48 8612.73 3097.47 1629.59 8612.94 3082.67 1609.45 8613.15 3066.84 1590.10 8613.35 3050.02 1571.61 8613.56 3032.25 1554.03 8613.75 3013.59 1537.40 8613.94 2994.09 1521.77 8614.13 2973.79 1507.18 8614.31 2952.75 1493.68 8614.49 2931.04 1481.29 8614.65 2908.71 1470.06 8614.81 2885.82 1460.01 8614.97 2862.44 1451.17 8615.11 2838.63 1443.57 8615.25 2814.45 1437.23 8615.32 2799.79 1434.03 8615.38 2790.01 1431.95 8615.50 2765.77 1425.86 8615.63 2741.88 1418.51 8615.75 2718.40 1409.92 MapN MapE DLS VS TFO Too ft ft deg/100ft ft .deg 5974274.40 644791.80 40.00 -3904.95 90.32 MWD 5974279.88 644816.15 40.00 -3916.89 90.56 MWD 5974281.05 644841.09 40.00 -3924.85 90.78 MWD 5974277.87 644865.85 40.00 -3928.58 90.97 MWD' 5974273.91 644880.31 40.00 -3928.74 91.13 MWD 5974270.44 644889.68 40.00 -3927.97 90.00 MWD 5974258.98 644911.86 40.00 -3923.03 90.05 MWD 5974243.85 644931.72 40.00 -3913.92 90.17 MWD 5974225.50 644948.64 40.00 -3900.91 90.29 MW D ~I 5974204.48 644962.12 40.00 -3884.39 90.40 MWD 5974181.45 644971.75 40.00 -3864.88 90.50 MWD' 5974157.09 644977.23 40.00 -3842.95 90.58 MWD 5974132.15 644978.40 40.00 -3819.29 90.65 MWD 5974117.23 644977.01 40.00 -3804.55 90.69 MWD 5974107.39 644975.22 40.00 -3794.60 90.00 MWD 5974083.56 644967.79 40.00 -3769.64. 90.01 MWD 5974070.00 644961.38 40.00 -3754.85 90.03 MWD ~ 5974061.25 644956.54 12.00 -3745.10 91.00 MWD ~ 5974039.83 644943.66 12.00 -3720.97 91.00 MWD 5974019.11 644929.68 12.00 -3697.21 91.01 MWD 5973999.15 644914.63 12.00 -3673.89 91.01 MWD 5973980.01 644898.56 12.00 -3651.08 91.01 MWD 5973961.73 644881.51 12.00 -3628.82 91.00 MWD 5973944.37 644863.53 12.00 -3607.20 90.99 MWD 5973927.98 644844.66 12.00 -3586.26 90.98 I MWD ~ 5973912.60 644824.96 12.00 -3566.06 90.97 MWD 5973898.26 644804.48 12.00 -3546.67 90.95 MWD 5973885.02 644783.28 12.00 -3528.12 90.94 MWD 5973872.91 644761.42 12.00 -3510.48 90.92 MWD 5973866.20 644748.01 12.00 -3500.35 90.89 MWD , 5973861.77 644739.05 12.00 -3493.63 270.00 MWD'; 5973849.89 644717.06 12.00 -3476.17 270.01 MWD ~ 5973836.87 644695.72 12.00 -3457.80 270.04 MWD 5973822.75 644675.09 12.00 -3438.57 270.06 MWD 5973807.57 644655.24 12.00 -3418.53 270.09 MWD 5973791.38 644636.20 12.00 -3397.74 270.11 MWD 5973774.21 644618.04 12.00 -3376.24 270.14 MWD. 5973756.11 644600.80 12.00 -3354.11 270.16 MWD. 5973737.13 644584.53 12.00 -3331.40 270.19 MWD 5973717.33 644569.27 12.00 -3308.18 270.21 MWD 5973696.76 644555.08 12.00 -3284.50 270.23 MWD 5973675.48 644541.98 12.00 -3260.44 270.26 MW D 5973653.53 644530.01 12.00 -3236.06 270.28 MWD'; 5973630.99 644519.20 12.00 -3211.42 270.30 MWD 5973607.92 644509.59 12.00 -3186.59 270.32 MWD 5973584.38 644501.21 12.00 -3161.65 270.34 MWD 5973560.42 644494.06 12.00 -3136.65 270.36 MWD 5973536.13 644488.18 12.00 -3111.67 270.37 MW D 5973521.42 644485.26 12.00 -3096.73 270.39 MWD 5973511.60 644483.37 12.00 -3086.76 90.00 MWD 5973487.25 644477.74 12.00 -3061.80 89.99 MWD 5973463.22 644470.85 12.00 -3036.80 89.98 MWD 5973439.59 644462.71 12.00 -3011.84 89.96 MWD C~ by BP Alaska Baker Hughes INTEQ Planning Report ~.r ~ s INTEQ Company: BP AmoCO Date: 1 0121 /200 8 Time. 14x 5:17 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: J-05, True North Site: PB J Pad Vertical (TVD) Reference: J-05B : $5.8 Well: J-05 Section (VS)Reference: Well (O.OON,O.OOE,197.OOAzi) Wellpatb: Plan 2, J-05CL1 Survey Calculation Method: Minimum Curvat ure Db: Sybase Survey MD ` Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Too ~ ft deg deg ft ft ft ft ft deg/100ft ft deg _ ~~ 11450. 00 89.72 204. 60 8615. 88 2695. 41 1400.11 5973416.42 644453.34 12.00 -2986.99 89.95 MWD 11475. 00 89.72 207. 60 8616. 00 2672. 96 1389.11 5973393.77 644442.77 12.00 -2962.31 89.93 MWD i 11500. 00 89.73 210. 60 8616. 12 2651. 12 1376.95 5973371.70 644431.04 12.00 -2937.86 89.92 MWD ~ 11525. 00 89.73 213. 60 8616. 24 2629. 95 1363.67 5973350.28 644418.16 12.00 -2913.73 89.90 MWD 11550. 00 89.74 216. 60 8616. 35 2609. 50 1349.30 5973329.56 644404.18 12.00 -2889.97 89.89 MWD 11575. 00 89.74 219. 60 8616. 46 2589. 83 1333.87 5973309.60 644389.13 12.00 -2866.65 89.88 MWD 11600. 00 89.75 222. 60 8616. 57 2570. 99 1317.44 5973290.45 644373.06 12.00 -2843.83 89.86 MWD 11625. 00 89.76 225. 60 8616. 68 2553. 04 1300.04 5973272.18 644356.01 12.00 -2821.58 89.85 MWD ~' 11640. 00 89.77 227. 40 8616. 74 2542. 72 1289.16 5973261.65 644345.33 12.00 -2808.53 89.84 MWD 11650. 00 89.77 226. 20 8616. 78 2535. 87 1281.87 5973254.67 644338.17 12.00 -2799.85 270.00 MWD 11675. 00 89.77 223. 20 8616. 89 2518. 11 1264.29 5973236.57 644320.93 12.00 -2777.72 270.00 MWD 11700. 00 89.77 220. 20 8616. 99 2499. 44 1247.66 5973217.59 644304.66 12.00 -2755.01 270.02 MWD 11725. 00 89.77 217. 20 8617. 09 2479. 94 1232.03 5973197.79 644289.41 12.00 -2731.78 270.03 MWD 11750. 00 89.77 214. 20 8617. 19 2459. 64 1217.44 5973177.22 644275.21 12.00 -2708.11 270.04 MWD 11775. 00 89.78 211. 20 8617. 29 2438. 60 1203.93 5973155.93 644262.11 12.00 -2684.04 270.05 MWD 11800. 00 89.78 208. 20 8617. 38 2416. 89 1191.55 5973133.99 644250.14 12.00 -2659.66 270.07 MWD 11825. 00 89.78 205. 20 8617. 48 2394. 56 1180.31 5973111.45 644239.34 12.00 -2635.02 270.08 MWD 11850. 00 89.79 202. 20 8617. 57 2371. 67 1170.27 5973088.38 644229.73 12.00 -2610.19 270.09 MWD 11875. 00 89.79 199. 20 8617. 66 2348. 29 1161.43 5973064.83 644221.34 12.00 -2585.25 270.10 MWD 11900. 00 89.80 196. 20 8617. 75 2324. 47 1153.83 5973040.88 644214.20 12.00 -2560.25 270.11 4.50" 1 BP Alaska WELLf~TM DE7RILE 9ooie~0o i0e t f. nTlti~on YD: t00)i.30 RBI. Dal„m. YY J~05Ee:2 fS.lNt nnYy V3 •nfM ~•M~i ~E~i1 FmmITVD 10).00' O.DO 0.00 26.)~ R EFERENGE INFORMATION Co-ordinate INIE) Reference: Well Centre: J-O5. True NorN Vertical lTVD)Refe rence: J-05B .65.84 Section lVB)Reference: Slot-DS ID.ODN.D.DOE) M easu rod Depth ftefe re nca J-OSB 65.84 Calculabun Melhod Minimum Curv aW re 3800 J-07 )J-07). 7500 3700 I 500 3600 3500 7400 3300 C 3200 O 3100 6900 r f 3000 Z ~ 2900 7. Z 2800 J-12 J-12) ~ 6600 ~ 9300 M voo 2600 9000 250D 8300 z4DO le7oD 2300 VIRn 2, aaoo zzoo { 6000 \ z1DD -300 -200 -100 0 100 200 300 000 500 600 700 800 900 10( 1_ T Plan: Plan k21J-05/Plan 2 J-05DL1) .'_.~~ M Anmwhs to True N0M Created By: BP Dafe'. 10/222008 BAKER Mgpwtr N0M 22 e3 Checked: Dale: Nua~s by spio~~~a ~ -eMa~lln,o,~,~~b~ Oate'101L2008 C bill nr~c nagLen EQ i Mgaai: oEDm2oD7 l,~ Gck i90%130iJ5]0 E-nlair OiII.mlcFae~on®iMnq q,r. .~~ b ~ BP Alaska °><ti~~ Anticollision Report • rr,~~ BAKER HUGHES 1NTEQ f Company: BP Amoco Date: 10/13/2008 Time: 08:51:05 Page: 1 Field: Prudhoe Bay Reference Site: PB J Pad Co-ordinate(NE) Refe rence: Well: J-05, True North Reference Well: J-05 Vertical (TVD) Reference: J-Q56 : 65.8 Reference Wellpath: Plan 2, J-05CL1 Db: Oracle ~ G AL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Rlseells in thisR9ehHipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval. 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10080.00 to 11900.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1387.37 ft Error Surface: Ellipse + Casing I Survey Program for Definitive Wellpath I Date: 10/13/200$ Validated: No Version: 0 ', Planned From To Survey Toolcode Tool N ame II ft ft __ '~ 100.00 5955.00 J-05B GYD-CT-CMS Gyrodata Top GYD-CT-CMS Gyrodata cont.casing m/s -Used in Preference ~~, ~ 5956.00 6000.00 J-056 GYD-CT-CMS Gyrodata Btm GYD-CT-CMS Gyrodata cont.casing m/s -Used in Preference 6050.96 10080.00 J-056 MWD Sperry (6050.96-1124 MWD MWD -Standard 10080.00 11900.00 Planned: Plan #2 V1 MWD MWD -Standard Casing Points MD TVD Diameter ~ Hole Size 'Nam e ft ft in in 11900.00 8683.58 3_500 _ 4_125 3.50" Summary <---------- O ffset Wellpath ----- -------> Reference "Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft r- ---- _ --- - PB J Pad - J-05 __ _ - _ J-05 V16 _ _ - Out of range PB J Pad J-05 J-05A V7 Out of range ', PB J Pad J-05 J-05APB1 V11 Out of range PB J Pad J-05 J-05B V14 10222.57 10225.00 11.49 150.83 -139.35 FAIL: Major Risk PB J Pad J-07A J-07A V1 Out of range PB J Pad J-08 J-08A V8 10375.11 10450.00 1194.90 96.55 1098.34 Pass: Major Risk PB J Pad J-12 J-12 V1 11900.00 9850.00 1076.34 448.37 627.97 Pass: Major Risk ~ II PB J Pad J-13 J-13 V3 Out of range ~ ~ PB J Pad J-19 J-19 V1 10634.26 9625.00 73.81 205.08 -131.28 FAIL: Major Risk , PB J Pad J-24 J-24 V3 Out of range ', PB J Pad J-24 J-24A V9 Out of range PB J Pad J-24 J-24AP61 V7 Out of range PB J Pad J-24 J-24AP62 V5 Out of range Site: PB J Pad Well: J-05 Rule Assigned: Major Risk Wellpath: J-056 V14 Inter-Site Error: 0.00 ft Refereuce Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing(HSflistance Area Deviation Warning L ft ft ft ft ft ft deg deg in ft ft ft 11687.31 8682.76 8300.00 7335.85 20.70 17.50 210.32 348.60 1374.04 74.83 1299.21 Pass 11659.47 8682.65 8325.00 7355.69 20.37 17.24 213.85 348.79 1352.78 74.11 1278.67 Pass ~ 11638.13 8682.56 8350.00 7375.54 20.15 17.09 216.20 349.02 1331.42 73.58 1257.83 Pass 11630.44 8682.53 8375.00 7395.41 20.33 17.33 215.52 349.27 1310.04 73.59 1236.45 Pass 11622.57 8682.49 8400.00 7415.32 20.52 17.58 214.83 349.52 1288.69 73.59 1215.10 Pass 11614.51 8682.46 8425.00 7435.24 20.71 17.83 214.11 349.77 1267.38 73.58 1193.80 Pass ~~ 11606.13 8682.43 8450.00 7455.05 20.91 18.09 213.36 350.02 1246.25 73.58 1172.67 Pass i 11597.38 8682.39 8475.00 7474.71 21.12 18.36 212.56 350.27 1225.31 73.58 1151.73 Pass ', 11588.27 8682.35 8500.00 7494.22 21.33 18.63 211.72 350.53 1204.57 73.56 1131.01 Pass 11578.82 8682.31 8525.00 7513.64 21.55 18.90 210.84 350.78 1183.99 73.55 1110.43 Pass 11569.12 8682.26 8550.00 7533.07 21.77 19.18 209.92 351.02 1163.47 73.54 1089.92 Pass 11559.17 8682.22 8575.00 7552.51 21.99 19.45 208.96 351.26 1143.01 73.53 1069.47 Pass 11548.97 8682.17 8600.00 7571.96 22.22 19.73 207.96 351.48 1122.60 73.53 1049.07 Pass 11538.60 8682.12 8625.00 7591.49 22.44 20.01 206.93 351.70 1102.19 73.53 1028.66 Pass 11528.11 8682.08 8650.00 7611.14 22.66 20.29 205.88 351.90 1081.74 73.54 1008.20 Pass 11517.50 8682.03 8675.00 7630.89 22.88 20.57 204.80 352.09 1061.24 73.54 987.69 Pass 11506.79 8681.97 8700.00 7650.75 23.09 20.85 203.69 352.27 1040.68 73.56 967.12 Pass 11495.99 8681.92 8725.00 7670.71 23.31 21.12 202.56 352.44 1020.09 73.58 946.51 Pass are n ser i ~ J-05C and ~ CL1 of bag BAG 7 1/16" 5000 psi. slips of pipes middle of flow cross middle of blind/shears Blind/Shears TOTs 2 3/8" Combi ram/Slips ~ ~ 1/16" 5000psi Mud Cross I I Mud Cross 7 1 /16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs 2 3/8" combi ram/slips ~ 1/is" 5ooopsi ab Valy Flow Tee Alaska Department of Natural Resources Land Administration System ' •i~~. ~~ ~~:~ .... ;_=is~tc, ~ :=1~ts ~e~e}reler`~ ~eas~ch Sfate Gabins Page 1 of~ [~~t~t~1 lurrc+es _ .~~.~.,,,,_ Alaska DNR Case surnrnar File Type A~~..___ File Number: 28281 M ~o~ Printable Case File, Summary See Township, Range, Section and Acreage? New Search ~ Yes ~ No ~.. _._._ ._ ~ _, ____~ _ LA's MAn~a ~ Case Abstract ~ Case detail ~ Land Abstract File: aDL 25231 aearch for Status Plat Updates \.ti cal ~ lI'Q>;~'I)Oti Customer: 000107377 BP EXPLORATION (ALASKA) INC . PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tvpe: 74 OiL & GAS LEASF, COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV O1L AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Dute Initiated: 05/28/1965 Office of Primary Responsibilih~: DOG DIV OIL AND GAS Last Transaction Date: ] 2/04/2006 Case Szrbtyhe : ~~~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED I~Ieridiczn: U To~>ylshi~r U I l ~ Ran; ~r.~ (11 ~ E . Section: 0 ~ S<~r ~~ion Acres~: 640 ~~aech t'i:'s Ilc~~-i~G~u~: U Towrzshi~: 0 L 1 \ Ran,~c: (1 I ~ I: .`iection: 04 ti"~~~~trurr Acres: 640 1~I~'i'1(~IUII.~ I_~ Toti1'Ylshlp: O1 ~ ~~ J~(dJd~C': ~) ~ i ~ ; .ti~~'CIZOn: ~~) S('~"I/l~fl .'IC'7'E'S: 640 ~llc°t~i~licn~.~ l1 Township: 01 1N R~~~t,~~~.~ (1 I ~1~: ,ti'~~~~~rnr~: I U ,~'~~~~unii _lcres: 640 Lc~~al llescription 0~-?8-196 ` ~ * ~SALE.NOTI('E LEGAL L)E.SC'RIPTION ** ~` C: I =J- 92 I'll w RI ~I:: U~~I 3, ~l, 9, 10 ?, 560.00 x"11 ~ I t1 ~"/ Last updated on 11/05/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28281 &... 1175/2008 TRA-NSMTTTAL LETTER CIiECKLIST WELL NAME _ ~h'L~ ~T D` j G'~f PTD# ~O~'- /~~ Developments ,_,_ _, Noa-Conventional Wetl Service ____. Exploratory Strati t*mp6ic Test FIELD: .~.E'G'Df,/D~' A li POOL: /~.ev/~.,c~OE' /~4y ©/L. Circle Appropriate Letter !Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) APPLIES ~~. FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existin ~` ~ (If last two digits g well_~V y_~--~`. in ' Permct No. ~~~s-1 l ~, - ~'\/ Apt number are .API No. 50-Od - ~O\~ 'I,;~, between 60-64) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with ZO AAC 25.005(fj, alt records, data and logs acquires! for the pilot hole must be clearly differentiated in both well name ( PH) and API number (sue --- _~ fc'om records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approve[ to perforate and produce / i~ is contingeet upon issuance of a conservation order approving a spacing exception. assumes the liability ofany protest to the spacing exception that may occur. DRY DITCH SAMPLE Ali dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are fist caught and 10' sample intervals throu et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed far (name of wets unfit after LComaanv NaraeZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. SComoanv Name) must contact the Commission to obtain advance approval of su fi t l c wa er we t testing ro Rte: v~ ~nooa WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Wel(Name: PRUDHOE BAY UNIT J-05CL1 Program DEV Well bore seg ^ PTD#:2081720 Company 8P EXPLORATION (ALASKA) INC Initial Classtl'ype DEV! PEND GeoArea 890 Unii 11650 OnlOff Shore Q Annular Disposal ^ Administration 1 Pe[mitfeeatkached- ------ ---- -- - -- - -------~_- - ------ - -- -- - - --- ---- - ------ - ----- - 2 Lease number appropriate- ------ -- --- -- - ----Y~ - --------------- ----- --- ----- -- - - - -- --- ---- - 3 Unique well name and number - ------ -- ------ Yes----- - - --- - --------- -- --- 4 Well locatedinsdefinedpool_____._.-___--____-_-__-___ __----___Yes---- --P[udhoeBaYOiIPOQL-------------------------------------------------- 5 WfllllocatedProperdistanCef[omdri)lingunitboundary--------------- --------Yes----- ------------------------------------------------------------------- 6 Well located proper distance from other wells______-________-- ___-_. --Yes----- -------------------------------------------------------------- _-- 7 Suff'icierrtacreageayailableindrillingunii_________-___-------- ---------Yes----- --2569acres.---_-----_---______-__----_--__--------------_----- 8 Ifdevieted,is-wellborePlat_included - ----- - -- --- - ---- Yes - - --- - --- - - ----------- -- -- - ------ 9 Operator only affectedparfy--- - --- -- -- -- -- -- -Yes ----- - ---- - - -------- - --- -- - - ------ 10 operatorhas_apprapriatebondinforce-_--.-___--_---____ ----_----Yes----- --BlanketBond#6194193-------------------------------------------------__-- 11 Pe[mitcanbe(ssuedwithouiconservstionorder_-_____-_-_-_-__-- ___ _--Yes----- ------------------------------------------------------------ -- -- Appr Date 12 Pemtitcanbeissuedwithoutadministrative_approval---------------- ---------Yes----- --------------------------.----------------------------------------- 13 Can permB bs aPPr4v ed before 15•day wait - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 11!5!2008 _ 14 Well located within area and strataa~thorizedbylnjectionO[der-#(put1O#Jn_comments)(For__NA-_---_ ---____-----_-__-_------------------_-----.-------__-------_--- 15 All wells-witnin174_mil®ereaofreyiewidenti#igd(Forservicewellonly)------ --------- NA._---_ -___-----_--.---_----_--_-----_----------------------------------- 16 Pte-produced inle~or; duration of pre production less than 3 months (For service well onJY) - - -~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 NoncAnven,gaa-conforms tc AS31,05A3QQ.1.A),Q.2.A-D) - - - - - - - - - - - - - - - NA. - - - - - - - - - - - - - - - - - - - - - - - - - - Englneering 18 Conductorstrirl9-prov~ed.--._---_._------_------------ -___-_-NA_-___ _-GonductorsetinJ-05(172-024).-----------------------------------.------------ 19 Su-rfacecasingproiects all known USDWs-_----_-----------_- ---_-----NA____ --Allaqu(fers exempted,AEO1.-._____-__-________________________-__.-_---- 20 CMTvoladeguate-to circulate onconduotor8surf-csg-___---------- --------- NA_-__-- --Surface casing set in J-05.__---_--_-_-__-_---_------_-_------_--------.-_-__ 21 CMTvoladeguatetotie-iniongstringtosurfosg_--_______________ _________NA_---_- -_Production_casingset in-JrOSB_(200-1113)._____________-__---__-___-___-______---_ 22 CMTwillcoyerallk~own-ProductiyehQrizons____-_-_____--_-__ ---_-_-__NA---_- --Open-hole completion planaed,___-__-______-______________________--_---- 23 Casing designs adequate for G,_T, B &_permafrost - - - - - - - - - - ~'- - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - _ - - - _ - - - - . - _ - -Yes - - _ - - _ Rig equipped with steel pits, No reserve pit planned._ All wasfeto approved disposal well(s). _ - - - _ - - - - - - _ 25 Ifa_re-drill,hasa10~403forabandonmentbeenapproved--------__ _-----_--_N.A_-.__- -_---_--_-------.-_----------------------------------------------- 26 Adequate wellbore separationproposed- _ - - - - - - - - - - - - - - - - - - - - _ - - _ - _ Yes - _ . _ _ Proximity analysis performed_ G_lose aP_proaches arein zQne_ - - - _ - - _ - . - - - - - - - - - - - - - - - _ 27 If divertar_r@quired,daesitmeetregulations______________________ _________ NA______ __BpPstack_willalteadY_beinplace,____-__________-_--_-_--__-______--____---_- Appr Date 28 Driping fluidprogram schematic-& equip list adequate - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ Maximum expected fo[mation pressure 6,8_EMW.- MW planned $.$ ppg. - - - - - - - - _ - - - - - - . - _ - - - _ - TEM 11110/2008 29 BO-P1=s,_doihey meetregulaiion- ------- --- -- - ------- Yes - - --- ---- - -- - - --------- - --- -- -- - 30 BOPE_press rating appropriate; test to_(put prig in-commenis)- - - - - - - - - - - - - - - - - - - Yes - _ - - - _ - MASP calculated at 215$psi_ 3500_psi_BOP testplanned, _ - - - _ - - - _ - - - - - . - _ - - - - - 31 Chokemanrfolds~mpliesw/API RP-53 (May$4)- - --- ----- Yes - -- ----- --- - --- -- -- ---------- - ----- -- -- - (((JJJ `~~~ 32 Work will occur without operr~ton shutdown- - - - - - - - - - - - - -Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - _ - - - _ - - - Yes _ - - - - _ _ li2$ is reported_at,l pad..Mud should preclude H2S on rig. -Rig has_ sensors and alarms, - - - - _ - - _ - _ - - 34 Mechanical_cgndBionofwellswithinA9RyeriFied(Forservicewellontya_____ _________NA______ ---_-_______-.---. _.--__________________-----------_--_--_-.-_---_-- Geology 35 Permitcanbeissuedwlohydrogen_sulfidemeasu[es---___.------_ -__-.-__No_-_--_ _MaxlevelH2$on_Jpadisl_10ppmonwellJ-26,__-----------------------_----_------ 36 Data.presentedonJ~fentialaverpressurezones------------------- ----------NA----- ------------------------------------------------------------------- Appr Date 37 SeismicanarysisQfshallowgas_zo[~s____________________--- ---_.-___ NA_---_- -___--_ ACS 111512008 38 Seakedcondit(onsurvey_(ifof(-shore)------------------------ ------_-- NA____- __.___-- 39 ContaGtnamelphoneforweekty.progressreports(exploratoryonry]--_-_-- ---____-_Yes-___- -_SeanMcLaughlin--_5$4-43&7.-__._-------------------------------------------- Geologic Commissioner. Engineering Public Date: Date Com issioner: i crier Date ~~~~-~.~ vg /t-i3-o8 • 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. • **** REEL HEADER **** MWD 09/04/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/02/30 2429264 O1 3.0" CTK *** LIS COMMENT RECORD *** ~~~~~~!~!~~~~~~!!!! Remark File Version 1.000 !!!!!!!!~!!!!!!~~!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9653.0000: Starting Depth STOP.FT 12069.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: J-05CL1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 38.779"N 148 deg 50' 21.840"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 30 Jan 2009 API API NUMBER: 500292012060 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 09 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 65.84 DMF DF EKB .F 0 EDF .F 65.84 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks 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 Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~o~ _~~a ~~~~- (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 log 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 depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the PDC (Primary Depth Control) log for J-05CL1. (8) The sidetrack was drilled as an OHST from J-05C at 10102 feet MD (8612.5 feet TVDSS). (9) Tied to J-05C at 10088 feet MD (8612.7 feet TVDSS). (10) Run 1 was used to drill J-05C. (11) Resistivity data from 10115 feet to 10540 feet MD (8612.6 ft. to 8610.1 ft. TVDSS) was logged on .run 4, 10.7 hours after drilling. (12) The interval from 11700 feet to 11740 feet MD (8633.9 ft to 8638.5 ft TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> 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 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 76 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 depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the Primary Depth Control (PDC) for well J-05CL1. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes • Logging direction is down (value= 255) Optical Log 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 Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 116 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9653.000000 Tape File End Depth = 11740.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 129 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 U *** LIS COMMENT RECORD *** ~~~~~~~~~~~~~~~~~!! Remark File Version 1.000 The data presented here is final and depth shifting has been waived by Roger Sels with BP Exploration (Alaska), Inc. The MWD data is the Primary Depth Control (PDC) for well J-05CL1. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log 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-ty pe is: 1 FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 40 Tape File Start Depth = 10998.500000 Tape File End Depth = 11710.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 53 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!~!!!!!!!!~~!~!!~! Remark File Version 1.000 This file contains the raw-unedited field MADPass data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log 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: 1 FRAME SPACE _ 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 x.250 * F Code Samples Units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 80 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 10998.250000 Tape File End Depth = 11709.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 93 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log 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: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 232 Tape File Start Depth = 9653.000000 Tape File End Depth = 11740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 245 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/02/30 2429264 01 **** REEL TRAILER **** MWD 09/04/14 BHI Ol Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes r1 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9653.0000 80.5000 -999.2500 -999.2500 -999.2500 -999.?_500 -999.2500 9653.5000 80.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 61.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 83.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9900.0000 95.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 71.0000 -999.2500 12.3960 12.8170 9.7690 8.0470 10200.0000 79.9000 38.8000 13.8700 15.6070 15.4810 16.0360 10300.0000 79.0000 73.7000 .13.1200 14.6950 13.6020 13.2410 10400.0000 76.5000 55.3000 13.6770 14.9440 13.6020 12.6860 10500.0000 95.4000 56.5000 13.7730 13.8870 12.6090 11.6700 10600.0000 79.9000 88.9000 14.2000 13.2170 12.3330 11.3190 10700.0000 81.4000 107.0000 14.1690 13.4000 12.3770 11.3190 10800.0000 92.3000 97.6000 13.7250 13.9880 12.6090 11.6700 10900.0000 77.4000 82.0000 13.2640 14.5830 13.2160 12.8210 11000.0000 77.9000 54.8000 13.2200 15.6070 14.5680 14.9600 11100.0000 73.6000 77.9000 13.1760 15.6860 14.7830 15.4850 11200.0000 76.6000 47.7000 12.6720 13.6570 13.8680 14.7900 11300.0000 230.1000 90.7000 17.6200 18.5810 12.8470 10.1500 11400.0000 69.7000 51.8000 16.2370 20.4180 18.8080 18.5580 11500.0000 95.9000 36.3000 16.1210 21.3900 17.6050 16.4470 11600.0000 115.2000 35.8000 9.7760 8.4260 11700.0000 165.1000 65.7000 46.6950 42.4650 11740.0000 -999.2500 31.3000 -999.2500 -999.2500 Tape File Start Depth = 9653.000000 Tape File End Depth = 11740.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 13.3510 28.5550 -999.2500 10.7810 67.0420 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 10998.5000 70.5000 53.7000 13.8800 13.8510 10999.0000 75.0000 55.2000 13.8800 13.8510 11000.0000 77.9000 54.8000 13.8800 13.8510 11100.0000 73.6000 77.9000 14.4380 14.6460 11200.0000 76.6000 47.7000 13.3550 13.8510 11300.0000 230.1000 90.7000 12.9790 10.2950 11400.0000 69.7000 51.8000 18.8290 18.5900 11500.0000 95.9000 36.3000 17.6510 16.6910 11600.0000 115.2000 35.8000 9.7760 8.4260 11700.0000 165.1000 65.7000 43.9810 40.2650 11710.0000 0.0000 0.0000 0.0000 0.0000 Tape File Start Depth = 10998.500000 Tape File End Depth = 11710.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RAD 12.8750 12.8750 12.9080 12.9590 12.4300 17.1530 15.5170 15.7700 13.2430 26.8150 0.0000 RAS 15.7320 15.7680 15.7860 15.8820 13.7910 18.6650 20.2070 20.8040 10.7890 66.0200 0.0000 • Tape Subfile 4 is type: LIS DEPTH GR ROP RPD RPS 10998.2500 71.5000 53.2000 13.8800 13.8510 10998.5000 70.5000 53.7000 13.8800 13.8510 11000.0000 77.9000 54.8000 13.8800 13.8510 11100.0000 73.6000 77.9000 14.4380 14.6460 11200.0000 76.6000 47.7000 13.3550 13.8510 11300.0000 230.1000 90.7000 12.9790 10.2950 11400.0000 69.7000 51.8000 18.8290 18.5900 11500.0000 95.9000 36.3000 17.6510 16.6910 11600.0000 115.2000 35.8000 9.7760 8.4260 11700.0000 165.1000 65.7000 43.9810 40.2650 11709.7500 -999.2500 57.6000 35.3410 32.2470 Tape File Start Depth = 10998.250000 Tape File End Depth = 11709.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet RAD 12.8750 12.8750 12.9080 12.9590 12.4300 17.1530 15.5170 15.7700 13.2430 26.8150 24.4030 RAS 15.7000 15.7320 15.7860 15.8820 13.7910 18.6650 20.2070 20.8040 10.7890 66.0200 46.7230 • Tape Subfile 5 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9653.0000 80.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9653.2500 80.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 61.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 83.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9900.0000 95.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 71.0000 -999.2500 12.3960 12.8170 9.7690 8.0470 10200.0000 79.9000 38.8000 13.8700 15.6070 15.4810 16.0360 10300.0000 79.0000 73.7000 13.1200 14.6950 13.6020 13.2410 10400.0000 76.5000 55.3000 13.6770 14.9440 13.6020 12.6860 10500.0000 95.4000 56.5000 13.7730 13.8870 12.6090 11.6700 10600.0000 79.9000 88.9000 14.2000 13.2170 12.3330 11.3190 10700.0000 81.4000 107.0000 14.1690 13.4000 12.3770 11.3190 10800.0000 92.3000 97.6000 13.7250 13.9880 12.6090 11.6700 10900.0000 77.4000 82.0000 13.2640 14.5830 13.2160 12.8210 11000.0000 77.9000 54.8000 13.2200 15.6070 14.5680 14.9600 11100.0000 73.6000 77.9000 13.1760 15.6860 14.7830 15.4850 11200.0000 76.6000 47.7000 12.6720 13.6570 13.8680 14.7900 11300.0000 230.1000 90.7000 17.6200 18.5810 12.8470 10.1500 11400.0000 69.7000 51.8000 16.2370 20.4180 18.8080 18.5580 11500.0000 95.9000 36.3000 16.1210 21.3900 17.6050 16.4470 11600.0000 115.2000 35.8000 9.7760 8.4260 11700.0000 165.1000 65.7000 46.6950 42.4650 11740.0000 -999.2500 31.3000 -999.2500 -999.2500 Tape File Start Depth = 9653.000000 Tape File End Depth = 11740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet i 13.3510 28.5550 -999.2500 10.7810 67.0420 -999.2500 Tape Subfile 6 is type: LIS