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JLC 4/10/2023 RBDMS JSB 041123 • S „f612._ ii(zSI(c„ State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: PBF well 15-18A Date: 11/21/16 PTD: 2080830 Operator: BPXA Type Inspection: Safety valve Operator Rep: Justice English Inspector: Jeff Jones Position: Lead Operator Op. Phone: 659-8341 Correct by(date): 12/21/16 Op. Email: akopsfs3dsopslead@bp.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected The well house roof doors are open or missing allowing snow and ice to build up inside. o oR-b57f5ZS wt \ eizz���. Attachments: CZ- ,1`OperatorRep Signatures: AOGCC Inspector *After signing,a co,/of this fo /is to be I with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. SCANNE® JUN 2 7 2.01?, Revised 2/2016 • • 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. ('~ ~ - ~ ~ 3 Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ~s„a iuuimuiiiiim DIGITAL DATA Diskettes, No. 1 ^ Other, No/Type: o ~,.~~~e~~ iiiiiuiisiumu ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~s~ Pro "ect Proofin II I II'I II I I III I ~ III I g BY: Maria Date: ` ~s~ - D + =TOTAL PAGES Scanning Preparation ~_ x 30 - / (Count does not include cover sheet) BY: Maria Date: ~ ' / / /'/~ ~s~ _ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: _ Maria Date: ~ ~' /~ ~s~ r V I Stage 1 If NO in stage 1, page(s) discrepanci s were found: YES NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II II II III II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked it I II'lll III II') III 10/6/2005 Well History File Cover Page.doc • • 0 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 � � ©g3 January 6, 2012 a "' '4:::::- VT:: I Mr. Tom Maunder ✓ @ � aun ..;esnIi 1SS ° Alaska Oil and Gas Conservation Commission N� +.. ^,w;C ^� 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 5LA * *ED FEB 2 7 ZO Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 907 - 659 -5102. Sincerely, c--- - d - O Mehreen Vazir BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-15 Date: 11/09/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 15-015 2042570 50029206960200 15-02B 2060720 50029206970200 15-03 1820300 50029207220000 15-04B 2071380 50029207260200 , 15-05A 1950340 50029207310100 15-06A 1982540 50029207420100 15-07C 2030970 50029211660300 15-08C 2050050 50029211800300 15-09A 1931380 50029212010100 15 -10A 1880850 50029205010100 15-11B 2041460 50029206530200 15-12B 2060870 50029206650200 15-13A 1991240 50029206450100 15-14A 2042220 50029206820100 15-15C 2081820 50029206910300 15-16B 2011920 50029211150100 15-17 1840890 50029211260000 2080830 50029222740100 0.4 NA 0.4 NA 5.1 11/9/2011 Additional treatment 15 -19A 1990990 50029218290100 Dust Cover NA NA NA 10.2 11/9/2011 15-20C 2050930 50029211330300 15-21A 1990290 50029205030100 15 -22 1800970 50029205090000 15 -23A 2031110 50029222250100 15-24 1911280 50029222230000 15-25B 2080240 50029218420200 15-26B 2041590 50029222350200 15-27 , 1920060 50029222430000 15-28A 2031240 50029222470100 15-29B 2090380 50029222590200 0.1 NA 0.1 NA 3.4 11/9/2011 Additional treatment 15-30A 2020890 50029222820100 15-316 2050860 50029222850200 15-32A 2011840 50029224620100 15-338 2031940 50029224480200 15-34A 2001370 50029224740100 15-35 1940880 50029224880000 15-366 2060730 50029224800200 15-376 2040190 50029224850200 15-38A 2030160 50029224960100 Dust Cover NA NA NA 3.4 11/5/2011 15-39A 2060860 50029225030100 0.3 NA 0.3 NA 3.4 11/5/2011 Additional treatment 15-40A 1980980 50029225110100 15-41B 2011460 50029224920200 15-42B 2090730 50029226240200 15-43 1960830 50029226760000 4 NA 4 NA 30.6 11/9/2011 15-44 1961100 50029226830000 15-456 2071790 50029226710200 15-46 2041030 50029226650000 15-47 1951740 50029226170000 15-48B 2051660 50029226350200 15-49B 2090640 50029226510200 • STATE OF ALASKA ALASKA�AND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 4 208 -0830 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 22274 -01 -00 8. Property Designation (Lease Number) : s 9. Well Name and Number: ADLO- 028304 i PBU 15 -18A 10. Field /Pool(s): r PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14187 feet Plugs (measured) 12720, 12768 feet true vertical 8820.98 feet Junk (measured) None feet Effective Depth measured 14141 feet Packer (measured) 11221 feet true vertical 8817.31 feet (true vertical) 8472 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94.5# H-40 35 - 115 35 - 115 Surface 3870' 13 -3/8" 68# L -80 34 - 3904 34 - 3501 4930 2270 Production 10899' 9 -5/8" 47# L -80 33 - 10932 33 - 8311 6870 4760 Liner 829' 7" 26# L -80 10602 - 11431 8108 - 8579 7240 5410 Liner 2953' 2 -3/8" 4.6# L -80 11226 - 14179 8475 - 8820 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 32 - 34 32 - 34 3 -1/2" 9.2# 13Cr80 34 - 11431 34 - 8579 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker KB To Packer 11221 8472 .k MO AUG 2 2 201 RECEIVE 12. Stimulation or cement squeeze summary: AUG 17 2011 Intervals treated (measured): Ni sh Treatment descriptions including volumes used and final pressure: . - & G aa C. Gi . Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 457 24,155 3 973 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na Lastufk Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 8/16/2011 P AUG 1 8 20i 0 I �� Submit Original Only Form 10 -404 Revised 10/201 � 9� Y 15 -18A 208 -083 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15 -18A 6/24/08 PER 12,800. 13,490. 8,814.14 8,806.23 15 -18A 6/24/08 PER 13,560. 14,100. 8,809.55 8,815.04 15 -18A 10/31/08 BPS 2,107. 14,100. 2,083.59 8,815.04 15 -18A 11/7/08 BPP 2,107. 14,100. 2,083.59 8,815.04 15 -18A 7/22/11 BPS 12,768. 14,100. 8,815.7 8,815.04 15 -18A 7/23/11 APF 12,550. 12,575. 8,816.16 8,815.81 15 -18A 7/24/11 APF 12,345. 12,370. 8,816.07 8,815.17 15 -18A 7/24/11 APF 12,370. 12,395. 8,815.17 8,814.67 15 -18A 7/24/11 BPS 12,720. 12,768. 8,818.04 8,815.7 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED 1 FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 15 -18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY , in 7 *.": 7/22/2011; CTU #8 with 1.5" coil. POH with PDS logging tools. M/U bowspring centralizer. RIH with PDS memory 'logging tools. RIH clean to 12800'. Flag coil at 12700'. Log up to 11000'. POH. !Lay out logging tools. Correction of +6 1/2'. RIH & set Hal MAP 2 3/8" CIBP C� 112750'. POOH RD Hal setting tools, cut 125' pipe, MU CTC /MHA. MU 1st 25' gun 'set. RIH with SWS 1.56" PJ perf guns. Tag CIBP and correct depth to 12750'. Pick I up and perf 12550 - 12575'. POH with fired perf guns. * **Job in Progress *** 7/23/2011; CTU #8, 1.5" coil, ** *Continued from WSR of 07/22/11***. ;Continued POH with first set of perf guns. PJSM. Lay out 25' fired guns. M/U new I firing head and 25' of 1.56" PJ perf guns. RIH with perf guns. Tag plug, discrepency E of 17', more than 10' from last run is of spec from SLB recommended guide line. Discussed w /SWS FSM & Coord, POOH for re- logging memory run. CONDUCT HERD, MAN DOWN ON FB TANK.Cut 75' pipe, rehead, MU SWS memory logging tool assembly, 1.7" x 15.75' & RIH. Tag CIBP at 10759' up depth. Flag coil at ; 12709'. Log up to 11300'. POH. Lay out logging tools. Download data. Determine iCIBP had moved downhole to 12768' after first perf gun was fired. Decide to set 'another CIBP at 12720' for pressure isolation. PJSM. M/U Halco setting tool and CIBP. ** *Job in Progress * ** 7/24/2011 CTU #8, 1.5" coil, ** *Continued from WSR of 07/23/11*** M/U Halco CIBP BHA. RIH. Correct depth to flag. Set CIBP, top at 12720' corrected :depth. Stack 3K down on plug, 2 times. Plug holding. POH. MU 1.56" x 25'guns for I #2 set of perf. RIH. Perf from 12370'- 12395' 6SPF. POOH. MU last 25' set of guns, 1.56" x 6 spf. RIH. Tag CIBP and correct depth. Pick up and perforate from 12,345 - 12,370'. POH to surface. Freeze protect 3 -1/2" tubing to 2500' with 50/50 i meth. ***Job in Progress * ** 7/24/201 1 j CTU #8, 1.5" coil, ** *Continued from WSR of 07/23/11*** M/U Halco CIBP BHA. RIH. Correct depth to flag. Set CIBP, top at 12720' corrected depth. Stack 3K down on plug, 2 times. Plug holding. POH. MU 1.56" x 25'guns for' #2 set of perf. RIH. Perf from 12370'- 12395' ASPF. POOH. MU last 25' set of {guns, 1.56" x 6 spf. RIH. Tag CIBP and correct depth. Pick up and perforate frnm 12,345 - 12,370'. POH to surface. Freeze protect 3 -1/2" tubing to 2500' with 50/50 meth. ** *Job in Progress * ** • • 7/25/2011 CTU #8, 1.5" Coil, * **Continued from WSR of 07/24/11 * ** PJSM. Lay out 25 ' fired perf guns. Cut off 150' coil. M/U CTC and pull test. N/D BOPE and N/U tree cap and press test. Rig down CTU. ! Job Summary: 1. Halco CIBP set at 12,720'. 2. Halco CIBP wedged at 12,768'. It moved down hole and stopped at a 2 -3/8" liner connection. Stacked 3K down on it with coil. 3. Perforated intervals: 12,345 - 12370', 12370 - 12395', 12,550 - 12,575'. Total of 75', 1.56" PJ perfs at 6 SPF. Move CTU #8 to DS 15 -30B. «« Job Complete »» FLUIDS PUMPED BBLS 72 1 %KCL 321 1% KCL W/ SAFE LUBE 22 50/50 METH 415 TOTAL TREE= CIW W ID ELLHEAD = FMC 1 H EAD 8A SAFETY * * *3 12" CHROME TBG * ** 16 SLIP ACTUATOR = BAKER C PIECES & R RING FROM MIS -SET CIBP MAY BE IN KB. ELEV = 67' GLMs. WELL ANGLE> 70° @ 11799'. BF.ELEV= I - I KOP= ? Max Angle = 96° @ 13634' 4 -1/2" TBG, 12.6 #, L -80 — 34' Datum MD = Ni .0152 bpf, ID = 3.958" 34' — I4 -1/2" X 3 -1/2" XO, ID = 2.992" 1 Datum ND = 8800' SS Q I 2143' 113 - 1/2" CAMCO TRDP SSSV NIP (LOCKED OUT TRSV), ID = 2.81" 13 -3/$" CSG, 68 #, K -55/ L -80, ID = 12.415" H 3904' I-411 ■ ■ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =1.81" 11221' 5 3501 3224 44 FMHO DOME RK 16 07/08/08 4 6788 5503 47 FMHO SO RK 20 07/08/08 3 -1/2" KB LINER TOP PACKER 'e "i Wi ►'�' +'� 3 8983 7017 46 FMHO DMY RK 0 08/02/92 11111 2 10424 7992 49 FMHO DMY RK 0 02/06/04 TOP OF 7" LNR H 10602' � �1��x 1 10516 8052 49 FMHO D RK 0 08/02/92 I CSG, 47 #, L -80, ID = 8.681" 10932' ,v, 1v, 10500' — I TOP OF CEMENT 1 y 9-5/8" ��� -� i111 ; 11221' 113 -1/2" KB LTP, ID = 1.81" I 1 11 11 11226' H2-3/8" BTT DEPLOYMENT SLV, ID = 2.250" 1 !�� 1 1 1 1 i , 11362' 113 -1/2" PKR SWN NIP, ID = 2.75" I � 1 •11, 111 1�1 1 4, MILLOUT WINDOW (15 -18A) 11426' - 11431' I3 -1/2" BKR WHIPSTOCK (06/21/08) I-1 11426' 1 �� . A 1 RA PIP TAG (06/21/08) I - 1 11432' C � ∎ 13-1/2" BKR WHIPSTOCK (05!30108) I — { 11520' •A•4 ∎0 12720' 1 1111 2 -3/8" HALCO SP (07/24/11) IRA PIP TAG (05/30/08) 11525' : ► 1/ 11� + I 12768' 2 -3/8" NALCO 13 -1/2" HES CIBP (05/30/08) I 11550' . = 4 •••1 44, , CIBP (07/24/11) It �/ � 1 12350 1 '11 �` 3 -1/2" TBG, 9.2 #, 13CR -80, .0087 bpf, ID= 2.992" 12350' • 1 o ► 1 1 1 1 ►1� '`1 11 11 I PBTD I -I 14141' 4 1 w. 4 PERFORATION SUMMARY 1 1 1 1 1 2 -3/8" LNR, 4.6 #, L -80 STL, --I 14179' REF LOG: Memory CCL /GR/CNL on 07/23/11 01• 1 1 1 1 .0039 bpf, ID = 1.995" ANGLE AT TOP PERF: 93° @ 12345' f1� �1 Note: Refer to Production DB for historical perf data �� oi l 12340' H7" X 3 -1/2" TM/ SS HORIZONTAL PKR I 3 SIZE SPF INTERVAL Opn /Sqz DATE 1 1.56" 6 12345 - 12395 0 07/24/11 12350' H 3 -1/2" TIW 6 -UNIT OVERSHOT SEAL ASSY I 1.56" 6 12550 - 12575 0 07/24/11 1.56" 6 12800 - 13490 C 06/24/08 I 12369' H4 -1/2" PORTED JOINT (34.85') I 1.56" 6 13560 - 14100 C 06/24/08 ' 1 , 13501' — FISH - BKR CIBP MILLED @ 12296' & PUSHED BTM (07/16/07) 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I—I 12612' 7777 I I 16 SLIP PIECES & RET RING LOST FROM MIS -SET CIBP (POSSIBLY IN GLMs) 4-1/2" LNR - SLO I ILL), 12.2 #, L -80, — 13514' 1 0152 bpf, ID = 3.958" 411/ 13_503' CT M D 11 MILLED CIBP - PUSHED DOWN I FROM 12210' - 4/28/03 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I — I 13538' I MO: 13533' I — FISH - 13.1' SETTING TOOL ATTACHED TO CHOKE PKR DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08103/92 ORIGINAL COMPLETION 06/03/10 MBM/PJC SET LT PKR (05/30/10) WELL: 15 -18A 06/27/08 NORDIC 1 CTD SIDETRACK 04/23/11 RCT /PJC MIN ID/ KB PKR CORRECTION PERMIT No:''2080830 07/14/08 JLJ /SV PULLED FISH (07/09/08) 07/28/11 RRW/ PJC CIBP/ ADPERFS (07/24/11) API No: 50 -029- 22274 -01 -00 07/18/08 JLJ /JMD GLV C/0 (07/08/08) SEC 22, T11 N, R14E, 618' FNL & 117' FWL 09/16/09 SM/JMD DRLG DRAFT CORRECTIONS 12/10/09 NS /JMD PERF AND MIN ID CORRECTIONS BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080830 Well Name/No. PRUDHOE BAY UNIT 15-18A Operator BP EXPLORATION (ALASKEy INC API No. 50-029-22274-01-00 MD 14187 TVD 8821 Completion Date 6/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes DATAINFORMATDN Types Electric or Other Logs Run: MWD DIR / GR, MCNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED Asc Directional Survey 0 14187 Open 6/30/2008 t Directional Survey 0 14187 Open 6/30/2008 og Neutron 2 Blu 10594 14129 Open 8/26/2008 MCNL, Mem Lee CCL, GR 24-Jun-2008 D C Lis 16805~eutron 10574 14134 Open 8/26/2008 LIS Veri, GR, CNT t LEIS Verification 10891 14187 Open 9/11!2008 LIS Veri, GR, ROP C 16881 "Gamma Ray 10891 14187 Open 9/11/2008 LIS Veri, GR, ROP ""open under word pad""` og Gamma Ray 25 Blu 11426 14187 Open 9/11/2008 MD GR 22-Jun-2008 Gamma Ray 25"S~BIu 11426 14187 Open 9/11/2008 TVD GR 22-Jun-2008 og See~AJetes- (.: eti~~~^--- ~ ~ ~ Col 10880 14160 Open 9/11/2008 Depth Shift Monitor Plot C Las 17280'~Gamma Ray 10891 14187 Open GR, ROP FIELD DATA og Production 5 Col 10475 14110 Case 10/26/2009 Mem PPL, PSP, GR, CCL, Pres, Temp, Gradio, Spin .~ ~~ 1-Jul-2009 D C Pds 18824ciProduction 10475 14110 Case 10/26/2009 Mem PPL, PSP, GR, CCL, Pres, Temp, Gradio, Spin 1-Jul-2009 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080830 Well Name/No. PRUDHOE BAY UNIT 15-18A Operator BP EXPLORATION (ALASK/y INC API No. 50-029-22274-01-00 MD 14187 TVD 8821 Completion Date 6/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Wetl Cored? ' `"~J Chips Received? Y /~1_ Analysis ~ Received? Comments: Daily History Received? ~N Formation Tops ~ N C~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, ~3 a~$5°,~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, • Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 na+o• n~msl~n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01B 2042570 50029206960200 NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7!2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-418 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-48B 2051660 50029226350200 NA 1.2 NA 10.2 10!8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 10/ 1 fi/09 Sehlum6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 ATTN: Beth Well Job M NO.5418 Company: State of Alaska Alaska OII & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD P1-25 W-O1A 12-O6A AP3O-00063 B2NJ-00026 AZCM-00043 INJECTION PROFILE MEMORY GLS LDL - 10/0209 10/02/09 10/03/09 1 1 1 1 1 1 W-36 E-35A 12-34 AV1H-00028 B2NJ-00027 AYS4-00104 PROD PROFILE W/GL MEM CEMENT BOND LOG INJECTION PROFILE 09/29!09 10/03/09 10/11/09 1 1 1 1 1 1 Z-07A AYS4-00101 PRODUCTION PROFILE 10/08/09 1 1 15-18A B2WY-00015 MEM PROD PROFILE 07/01/09 t 1 OS-18A B04C-00069 SCMT 07/30/09 1 1 U-05A B14B-00068 USIT 08/17/09 1 1 P-07A AWJI-00051 MEM P PROFILE ~ 10/09/09 1 1 09-03 AZCM-00044 PRODUCTION LOG 10/10/09 1 1 1.45/0.26 82NJ-00032 MEM LDL 10/10/09 1 1 5-134 V-105 AWLS-00039 B3S0-00026 USIT (PROF 09/28/09 10/03/09 1 1 1 1 BP Exploration (Alaska) Inc. Petrotechnical Dala Center LR2-1 900 E. Benson Blvd. /~1a4e ~~~ Alaska Data 8 Consulting Services 2525 Gambell Street, SuBe 400 Anchorage, AK 99503-2A3A /~ BAKER N~J6F/ES Saker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'1'lUN (ALASKA) 1NC CUUN'1'Y NURl'H SLUYE BOROUGH WELL NAME 15-18A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 9/10/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2026713 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 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 Completed Bv: o`~ ~" ,~~ ~° '/ Page I of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7t" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 15-18A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 2026713 Sent by: Catrina G idry Date: 09/10/®~ Received by: -~~' Date: ~ ` ~~ '~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ FS ~n~~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 08/25/08 ~~ 3 ~% ., f ~AS~a ~t~~ N0.4826 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 A-02 12086677 RST ~ - ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 A-13 12086676 RST (~ ~f 07/23/08 1 1 G-02A 11968945 RST $- ~ 06/08/08 1 1 B-19A 12017500 RST / Q~ 06/14/08 1 1 15-i8A 12005216 MCNL ~~ '- 06/24/08 1 1 C-02 11982437 RST / Q 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - / 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT a0 07/23/08 1 1 V-207 11999031 MDT QUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) - Q 07/28/08 1 1 B-18 11978471 USIT _~ /(p ~ ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 07/21/08 1 1 13-29L7 11962614 LDL (~ a -d ~ 07/30/08 1 1 13-29L1 11966271 USIT - f 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 ~- w ~ -at PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACR TO: BP Exploration (Alaska) Ina ~, ~,,,~ ~. Petrotechnical Data Center LR2-1 ~ ~~ -~, ww~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~.~~ `~ ~ 1[l~~i li'„ ;., Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: C~U STATE OF ALASKA ALASKA~IL AND GAS CONSERVATION COM SSION ` WELL COMPLETION OR RECOMPLETION REPORT AND LOG .JUi~ ~ ~ ZOJB 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.,05 zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: -'~ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. ~, Z4 • D$ 12. Permit to Drill Number 208-083 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded q• 6/17/2008 ~ 13. API Number 50-029-22274-01-00 • 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 6/21/2008 14. Well Name and Number: PBU 15-18A , FNL, 11T FWL, SEC. 22, T11N, R14E, UM 618 Top of Productive Horizon: 4817' FSL, 4316' FEL, SEC. 16, T11 N, R14E, UM 8. KB (ft above MSL): 67' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1020' FSL, 729' FEL, SEC. 08, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 14141' 8817' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676034 ` y- 5960865 • Zone- ASP4 10. Total Depth (MD+TVD) 14187' 8821' 16. Property Designation: ADL 028304 TPI: x- 671464 y- 5966196 Zone- ASP4 th: x- 669733 • - 5967640 • Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): kdP //~ ~f28 ;y~j MWD DIR / GR, MCNL / GR / CCL 7? ?yam f ~ 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 20" 94.5# H-40 Surface 115' Surface 115' 30" 13-3/8" 68# L-80 35' 3904' 35' 3501' 16" 2846 cu ft Coldset II 460 cu ft'G' 9-5/8" 47# L-80 35' 10932' 35' 8311' 12-1 /4" 3005 cu ft Class 'G' 7" 26# L-80 1060 ' 4 8108' 8576' 8-1/2" 572 cu ft Class'G' 2-3/8" 4.6# L-80 11226' 14179' 8475' 8820' 3" 65 cu ft Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. Tui3wG RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; p 56" Gun Diameter 6 spf 1 4-1/2", 12.6#, L-80 x 11426' (Below Window) 12340' , . MD TVD MD TVD 3-1/2", 9.2#, 13Cr80 12800' - 13490' 8814' - 88[16' 13560' - 14100' 8810' - 8815' 2rj, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 18 Bbls of Diesel 26. PRODUCTION TEST Date First Production: July 26, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 7/25/2008 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 843 GAS-MCF: 2,046 WATER-BBL: 2 CHOKE SIZE: 176 GAS-OIL RATIO: 2,428 Flow Tubing Press. 480 Casing Press: 1,500 CALCULATeD 24-HOUR RATE OIL-BBL: 2,528 GAS-MCF: 6,139 WATER-BBL: 6 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. COMPLETION None ~ ~~ ~ ~~ SEP ~ 91D08 Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 3 G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME 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. 23S6 /Zone 2B 11454' 8591' None 22TS 11532' 8647' 21 TS /Zone 2A 11618' 8720' Zone 1 B 11686' 8769' TDF /Zone 1A 11740' 8798' Formation at Total Depth (Name): TDF /Zone 1A 11740' 8798' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~f O~~ / `~~ ~ Signed Terrie Hubble Title Drilling Technologist Date PBU 15-18A 208-083 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. . Form 10-407 Revised 02/2007 Submit Original Only ~ ~ BP EXPLORATION Page 1 of 13 ~ Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task !, Code ! NPT 6/12/2008 00:00 - 03:00 3.00 MOB P 03:00 - 08:30 5.50 BOPSU P 08:30 - 13:00 4.50 BOPSU P 13:00 - 14:30 1.50 BOPSU P 14:30 - 18:20 3.83 STWHIP P 18:20 - 18:35 0.25 STWHIP P 18:35 - 19:30 0.92 STWHIP P 19:30 - 21:00 1.50 STWHIP P 21:00 - 21:10 0.17 STWHIP P 21:10 - 21:25 0.25 STWHIP P 21:25 - 22:10 0.75 STWHIP P 22:10 - 00:00 1.83 STWHIP P 6/13/2008 00:00 - 00:30 0.50 STWHIP P 00:30 - 01:10 0.67 STWHIP P 01:10 - 01:25 0.25 STWHIP P 01:25 - 19:00 17.58 STWHIP P Spud Date: 7/5/1992 Start: 6/5/2008 End: 6/7/2008 Rig Release: 6/27/2008 Rig Number: Phase Description of Operations PRE Moving rig from K-20C to 15-18. PRE Accept Rig at 0300. Back rig over well and set down. Start N/U BOPs and secure stack with chains. M/U 1502 line to flowback tank. PRE Test BOP witnessed by AOGCC representative Bob Noble. One failure .PVT audibale alarm required resetting. PRE RU lubricator PT 250 psi low and 1000 psi hi. Pull BPV well dead. WEXIT Pull CT thru injector. Pump forward. PT inner reel valve 250 psi low and 3500 psi hi. Pump forward. Cut 18 ' CT to find wire. Install boot. Pump slack and cut coil. WEXIT SAFETY MEETING. Discuss procedures and hazards for cutting CT using hydraulic cutter. WEXIT Find cable after cutting 333 ft of CT. Continue cutting a total of 1,182 ft of CT for Coil fatigue management. WEXIT Install SLB CT connector. Pull test to 35 Klbs, good. Install BHI cable head and test continuity and resistance, good. WEXIT Pressure test CT connector to 4,500 psi, good. WEXIT SAFETY MEETING. Discuss hazards and crew positions for running BHA #1. WEXIT M/U BHA #1 - 2.74" Speed Mill + String mill, BOT Xtreme motor, 13 ft Wt bars, 2 jts 2-1/4" CSH, 2-3/8" CoilTrack. BHA OAL = 122.54 ft. Pump 1 reel volume forward. WEXIT M/U CT riser and electric test tool at surface. RIH. WEXIT Continue RIH. WEXIT Log GR down from 11,285 ft. Correct -23 ft. WEXIT Continue RIH. Weight check at 11,450 ft is 40 Klbs. D to whi stock at 11 485 ft. Pick up and start pumping at 1.31 bpm ~ 1800 psi free spin. WEXIT Pumping tag at 11,484 ft, start milling here at 1 ft/hr. 01:30 - 11,484.1 ft 1.32 bpm f~ 2050 psi. DWOB = -0.24 Klbs, CT weight = 13.2 Klbs. 02:00 - 11,484.6 ft 1.33 bpm C~3 2400 psi. DWOB = -0.73 Klbs, CT weight = 11.5 Klbs. Multiple stalls at 11,484.8 ft, then at 11,484.6 ft. 04:00 - 11,484.4 ft 1.34 bpm ~ 1900 psi. DWOB = 0.5 Klbs, CT weight = 12.7 Klbs. 05:00 - 11,484.5 ft 1.35 bpm ~ 2140 psi. DWOB = 0.4 Klbs, CT weight = 12.4 Klbs. Add 0.6% Safe-Cube to system. 06:00 - 11484.4 ft 1.37 bpm ~ 2095 psi DWOB = .04KIbs , CT weight = 12.9KIbs, FS =1940 psi ~ 11484.47 600 psi drill off. 07:00 - 11484.7ft ~ 2245 psi DWOB .29KIbs. CT weight 12.9K, ~ 11484.75 700 psi drill off. 10;30 - 11486.5 ft 1.4 bpm, C~3 2530 psi, DWOB 2KIbs, CT 11.4 Klbs 13:00 - 11488.1ft ~ 2618 psi DWOB .6K,CT weight 10.2k 13:30 -11488.25 ft ~ 2570 psi, DWOB 3.17KIbs, CT weight Printed: 7!7/2008 11:52:08 AM ~ ~ BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Confractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours ~, Task Code NPT Phase Description of Operations 6/13/2008 01:25 - 19:00 17.58 STWHIP P WEXIT 10.1 klbs Stall at 11488.1'. 16:00 - 11488.9 ft 1.4 bpm ~ 2600 psi, DWOB 3.6KIbs, CT weight 10.8KIbs 17:30 - 11489.3' ft 1.4 bpm ~ 2570 psi, DWOB 3.5KIbs, Ct weight 10.7 Klbs. 19:00 - 22:30 3.50 STWHIP P WEXIT Continue milling. 19:00 - 11,489.5 ft 1.40 bpm ~ 2560 psi. DWOB = 3.56 Klbs, CT weight = 11.2 Klbs. 20:00 - 11,489.6 ft 1.40 bpm ~ 2540 psi. DWOB = 3.49 Klbs, CT weight = 11.1 Klbs. 21:00 - 11,489.8 ft 1.40 bpm ~ 2550 psi. DWOB = 3.7 Klbs, CT weight = 10.9 Klbs. 22:00 - 11,489.8 ft 1.40 bpm ~ 2620 psi. DWOB = 3.7 Klbs, CT weight = 11.1 Klbs. 22:30 - 00:00 1.50 STWHIP P WEXIT 11,489.8 ft -Slow increase in CT pressure up to 3,200 psi and increase in DWOB to 5.5 Klbs, without moving CT. Pick up is 32 Klbs, clean. 23:00 - 11,489.4 ft 1.37 bpm ~ 2,790 psi. DWOB = 3.35 Klbs, CT weight = 12 Klbs. 6/14/2008 00:00 - 05:30 5.50 STWHIP P WEXIT Continue milling window. 00:00 - 11,489.7 ft 1.37 bpm ~ 2900 psi. DWOB = 4.3 Klbs, CT weight = 12.2 Klbs. 01:00 - 11,489.7 ft 1.36 bpm ~ 2780 psi. DWOB = 3.5 Klbs, CT weight = 12.9 Klbs. 02:00 - 11,490.1 ft 1.36 bpm ~ 2800 psi. DWOB = 3.2 Klbs, CT weight = 11.9 Klbs. Stall at 11,490.2 ft. Up weight is 31 Klbs. Stall at 11,490.15 ft. 03:00 - 11,490.1 ft 1.39 bpm ~ 2700 psi. DWOB = 2.6 Klbs, CT weight = 12.9 Klbs. 04:00 - 11,490.0 ft 1.44 bpm C~ 2520 psi. DWOB = 1 Klbs, CT weight = 13 Klbs. 05:00 - 11,490.4 ft 1.46 bpm ~ 2970 psi. DWOB = 2.6 Klbs, CT weight = 11.7 Klbs. 05:30 - 07:50 2.33 STWHIP P WEXIT Stacking weight with no drilling off, POOH to check motor and mills. Pump through EDC on the way out. 07:50 - 08:15 0.42 STWHIP P WEXIT Stand back injector and LD BHA. FISH IN HOLE. String mill and window mill left in hole. String mill failed in mandrel body connection 1/2 below pin connection on string reamer. 08:15 - 12:30 4.25 FISH N DPRB WEXIT Wait on arrival of slickline unit and fishing tools. 12:30 - 15:00 2.50 FISH N DPRB WEXIT RU slick line. 15:00 - 15:50 0.83 FISH N DPRB WEXIT RIH with 2.5 LIB. tag a 11482 WLMD. 15:50 - 16:30 0.67 FISH N DPRB WEXIT POH with LIB. Cresent mark 30 degrees of circumference. 16:30 - 18:00 1.50 FISH N DPRB WEXIT Review fishing options and LID impressiuon with wire line coordinator. PU 2-1/8 grapple overshot. 18:00 - 19:10 1.17 FISH N DPRB WEXIT RIH with slickline 2-1/8 grapple overshot, 2-1/8 wt bar, 1-7/8 oil jar, Knuckle jt, 1-7/8 spang, 2-1/8 wt bar, knuckle jt. 19:10 - 19:35 0.42 FISH N DPRB WEXIT Wt check at 11,400 ft is 615 lbs. Run up and down above fish to ensure spang operation. Tag at 11,482 ft, jar down to engage grapple. 19:35 - 21:00 1.42 FISH N DPRB WEXIT POOH. Fish is not recovered. M/U fishing string again, same as before. Plan to jar down Printed: 7/7/2008 11:52:08 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task I Code ~ NPT ' Phase 6/14/2008 19:35 - 21:00 1.42 FISH N DPRB WEXIT 21:00 - 22:45 1.75 FISH N DPRB WEXIT 22:45 - 00:00 1.25 FISH N DPRB WEXIT 6/15/2008 00:00 - 01:40 1.67 FISH N DPRB WEXIT 01:40 - 02:20 0.67 FISH N DPRB WEXIT 02:20 - 02:40 0.33 FISH N DPRB WEXIT 02:40 - 03:30 0.83 FISH N DPRB WEXIT 03:30 - 04:00 0.50 FISH N DPRB WEXIT 04:00 - 04:20 0.331 FISH N ~ DPRB WEXIT 04:20 - 04:30 0.17 FISH N DPRB WEXIT 04:30 - 05:50 1.33 STWHIP N DPRB WEXIT 05:50 - 06:30 0.67 STWHIP N DPRB WEXIT 06:30 - 07:30 1.00 STWHIP N DPRB WEXIT 07:30 - 10:00 2.50 STWHIP N DPRB WEXIT 10:00 - 10:20 0.33 STWHIP N DPRB WEXIT 10:20 - 10:40 0.33 STWHIP N DPRB WEXIT 10:40 - 10:45 0.08 STWHIP N DPRB WEXIT 10:45 - 13:00 2.25 STWHIP N DPRB WEXIT 13:00 - 14:15 1.25 STWHIP N DPRB WEXIT 14:15 - 16:25 2.17 STWHIP N DPRB WEXIT 16:25 - 18:50 2.42 STWHIP N DPRB WEXIT 18:50 - 00:00 5.17 STWHIP N DPRB WEXIT 16/16/2008 100:00 - 16:00 ~ 16.00 STWHIP P WEXIT Description of Operations more agressively this time for a better chance to engage the grapples. RIH. Jar down for 45 min. POOH. Fish is not recovered. Marks on nose of overshot, no marks on inside grapple. M/U 3rd fishing string. Added 2 wheeled bars and a knuckle joint just above the overshot. RIH with slickline fishing BHA #3. Jar down for 30 min. POOH. Fish not recovered. Heavier marks on nose of overshot but none on inside grapples. M/U slickline fishing BHA #4 -Inside spear. RIH BHA #4. Set down 11,484 ft, try repeatedly to engage spear. Some overpulls seen. POOH. Fish not recovered. No marks on spear to indicate it had engaged the fish. Marks on one side only probably from getting in between fish and ID of tubing. SAFETY MEETING. Discuss procedure and hazards for rigging down slickline. Rig down slickline unit. Load new whipstock and running tools to rig floor. Assemble whipstock BHA. Wait on SWS to install PIP tag in whipstock. PU WS and coiltrak BHA RIH to 11240. 33K Up and 12K dn. Log tie-in. correction -19'. RIH to place top of WS at 11426'. PU WT 31.2K, 14K Dn. Pressure to 1600psi. Continue to pressure to 3850 psi shear off. Set down 5K. POH. LD WS setting tools and PU milling BHA. RIH tag 11443.w pump. PU to neutral f~ 11438. Correct to 11426'. Mill 11426 , 1.5 bpm 2640psi 2550 psi FS, 19:00 - 11,426.11 ft 1.50 bpm ~ 2560 psi. DWOB = 0.02 Klbs, CT weight = 13.4 Klbs. 9 stalls getting started from this point. 20:00 - 11,426.31 ft 1.32 bpm f~ 2220 psi. DWOB = -0.02 Klbs, CT weight = 13.7 Klbs. 21:00 - 11,426.12 ft 1.32 bpm ~ 2210 psi. DWOB = 0.01 Klbs, CT weight = 12.9 Klbs. Add 1 drum of safe-tube to system. 22:00 - 11,426.16 ft 1.32 ~ 2200 psi. DWOB = 0.01 Klbs, CT weight = 12.9 Klbs. 23:00 - 11,426.31 ft 1.43 bpm ~ 2400 psi. DWOB = 0.05 Klbs, CT weight = 13.1 Klbs. Continue milling window. 00:00 - 11,426.46 ft 1.49 bpm ~ 2530 psi. DWOB = 0.12 Klbs, CT weight = 13.0 Klbs. 01:00 - 11,426.63 ft 1.46 bpm ~ 2480 psi. DWOB = 0.23 Klbs, CT weight = 12.8 Klbs: 02:00 - 11,426.96 ft 1.42 bpm ~ 2430 psi. DWOB = 0.56 Klbs, CT weight = 13.3 Klbs. Printetl: 7(7/2008 11:52:Ut3 AM i~. BP EXPLORATION Operations Summary Report Legal Well Name: 15-18 Page 4 of 13 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase ', Description of Operations 6/16/2008 00:00 - 16:00 16.00 STWHIP P WEXIT 03:00 - 11,427.35 ft 1.41 bpm ~ 2500 psi. DWOB = 0.92 Klbs, CT weight = 12.3 Klbs. 04:00 - 11,427.87 ft 1.41 bpm C«~ 2470 psi. DWOB = 1.09 Klbs, CT weight = 11.4 Klbs. 05:00 - 11,428.35 ft 1.41 bpm ~ 2640 psi. DWOB = 2.99 Klbs, CT weight = 10.4 Klbs. 06:00 - 11,429.15 ft 1.42 bpm ~ 2650 psi. DWOB = 3.13 Klbs, CT weight = 10.4 Klbs. 07:00 - 11,429.70 ft 1.42 bpm ~ 2660 psi. DWOB = 3.32 Klbs, CT weight = 10.9 Klbs. 08:00 - 11,430.00 ft 1.42 bpm ~ 2580 psi. DWOB = 3.09 Klbs, CT weight = 10.2 Klbs. 09:00 - 11,430.30 ft 1.42 bpm C~1 2560 psi. DWOB = 3.10 Klbs, CT weight = 9.9 Klbs. 10:00 - 11,430.55 ft 1.42 bpm C~ 2560 psi. DWOB = 3.33 Klbs, CT weight = 10.1 Klbs. 11:00 - 11,430.90 ft 1.42 bpm @ 2580 psi. DWOB = 3.63 Klbs, CT weight = 9.8 Klbs. 11:30 - 11,430.95 ft witnessed pressure spike MW increased 50 psi (Thru 3.5") 12:00 - 11,431.20 ft 1.42 bpm ~ 2600 psi. DWOB = 4.11 Klbs, CT weight = 9.3 Klbs. 14:00 - 11431.8 ft 1.42 bpm ~ 2560 psi DWOB =3.74 Klbs , CT weight 9.7 K Ibs 15:00 - 11432.1 ft 1.30 bpm ~ 2988 psi FS2688 psi , DWOB 4.2KIbs CT weight 9.4 Klbs 16:00 - 11432.2 ft 1.30 bpm (~ 2988 psi FS2688 psi , DWOB 4.2KIbs CT weight 9.4 Klbs. No progress in the last hour decided to take a look. 16:00 - 18:15 2.25 STWHIP P WEXIT POH to look at mill. 18:15 - 18:45 0.50 STWHIP P WEXIT Lay down motor, mill, and string reamer from BHA #3. Mill has significant wear on the shoulder and indications on the nose of crossing the center line of the 3-1/2" casing. Came out 2.71" N-G, with no apparent damage to mill. String reamer also shows significant wear and has lost most of its cutting structure, 2.72" N-G. No apparent damage to string reamer. 18:45 - 19:30 0.75 STWHIP P WEXIT P/U new mill, string reamer and motor. Mill and string reamer are 2.73" N-G. 19:30 - 21:40 2.17 STWHIP P WEXIT RIH BHA #4 -New 2.73" Diamond Speed Mill + String Reamer, 2-1/8" BOT Xtreme mud motor, 2 jts 2-1/16" CSH, 3 weight bars, 2-3/8" CoilTrack. 21:40 - 22:00 0.33 STWHIP P WEXIT Log GR down from 11,314 ft. Correct -20 ft. 22:00 - 22:15 0.25 STWHIP P WEXIT RIH to find bottom. 22:15 - 00:00 1.75 STWHIP P WEXIT Start milling from 11,428.1 ft with free spin 2950 psi ~ 1.45 bpm. Several stalls getting started. 23:00 - 11,428.13 ft 1.45 bpm ~ 2970 psi. DWOB = 0.20 Klbs, CT weight = 13 Klbs. 6/17/2008 00:00 - 08:30 8.50 STWHIP P WEXIT Continue milling window. 00:00 - 11,428.19 ft 1.38 bpm ~ 2800 psi. DWOB = 0.24 Klbs, CT weight = 12.9 Klbs. 01:00 - 11,428.33 ft 1.39 bpm C~ 2840 psi. DWOB = 0.69 Klbs, CT weight = 12.1 Klbs. Printed: 7/7/2008 11:52:08 AM ~' BP EXPLORATION Page 5 of 13 Operations Summary Report ~~ ~~ Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To I Hours Task I! Code ~ NPT Phase Description of Operations 6/17/2008 00:00 - 08:30 8.50 STWHIP P WEXIT 02:00 - 11,428.77 ft 1.40 bpm (~ 3030 psi. DWOB = 2.15 Klbs, CT weight = 10.3 Klbs. 03:00 - 11,429.20 ft 1.39 bpm ~ 2940 psi. DWOB = 2.43 Klbs, CT weight = 9.6 Klbs. 04:00 - 11,429.41 ft 1.39 bpm ~ 2980 psi. DWOB = 2.91 Klbs, CT weight = 9.8 Klbs. 05:00 - 11,429.75 ft 1.39 bpm ~ 3100 psi. DWOB = 3.81 Klbs, CT weight = 9.8 Klbs. 06:00 - 11,429.80 ft 1.40 bpm C~3 3350 psi. DWOB = 3.71 Klbs, CT weight = 9.8 Klbs. 06:40 - 11429.85 ft from 4K to 1.9K WOB fell off ROP Milling off as expected. 07:00 - 11430.50 ft 1.49 bpm ~ 3240 psi DWOB = 2.19KIbs, CT weight = 10.4 Klbs 08::20 - 11431.50 ft 1.48 bpm ~ 2988 psi DWOB .6KIbs, CT weight = 10.9 Klbs. Geo confirms formation in sam le. 08:30 - 10:30 2.00 STWHIP P WEXIT Mill rat hole 1.49 BPM ~ 3100 psi. WOB 2.iK ROP 5-10 fph. mill to 11,441ft. 10:30 - 12:30 2.00 STWHIP P WEXIT Ream window 1.48 bpm ~ 2944 psi. Make three passes. Window 11425.7 -11431.0 Ft .Md. Dry pass OK. 12:30 - 14:45 2.25 STWHIP P WEXIT Swap to Flo Pro as POH 1.25 bpm ~ 2640 psi. ~ Test IA to 3000 psi lost 150 psi first 30 minutes and an '~~ addtional 40 psi in the second 30 min Good Test IA Passed. Test reported in AWGERS by Little Red. 14:45 - 16:20 1.58 STWHIP P WEXIT LD milling BHA. Window mill gauged 2.73 Go and 2.72 NO Go. String Mill gauged 2.74 Go and 2.73 NO Go. 16:20 - 18:10 1.83 DRILL P PROD1 RIH BHA #5 - 3" bicenter bit, WTD CTD motor, HOT, DGS, DPS, EDC, P&C, Wear sub, LOC, UOC, and CTC. 18:10 - 19:15 1.08 DRILL P PRODi Log from 10930 - 11040' at 140 fUhr. minus 14' correction 19:15 - 19:30 0.25 DRILL P PROD1 RIH. Pumps off through window. Tag bottom at 11443.5'. 19:30 - 21:30 2.00 DRILL P PROD1 Drill to 11459', 1.5 iN1.5 out bpm ~ 3680 psi, 3600 psi FS, 0.9k WOB, 20-12 fph, IA = 134 psi, OA = 111 psi 21:30 - 00:00 2.50 DRILL P PROD1 Drill to 11490', 1.5 in/1.5 out bpm ~ 3810-3700 psi, 3600 psi FS, 1.22k-0.95k WOB,10 fph, IA = 230 psi, OA = 178 psi 6/18/2008 00:00 - 03:30 3.50 DRILL P PROD1 Drill to 11516' at 1.5/1.5 bpm in/out, 3820-3720psi, 3650psi FS, 1.13-0.73 WOB, 18-5 fph, 314 psi IA, 276 psi OA. 03:30 - 06:00 2.50 DRILL P PROD1 Drill to 11545' at 1.4/1.4 bpm, 3600 psi, 3360 psi FS, WOB, 35-15 fph, 370 psi IA, 340 psi OA. 06:00 - 06:26 0.43 DRILL P PROD1 Wiper to window. 06:26 - 13:00 6.57 DRILL P PROD1 Drill 1.43/1.43bpm 03600 psi, & 3450 psi FS, WOB 1.47K, 10.7 ECD ROP 23-40. 13:00 - 13:40 0.67 DRILL P PROD1 Drill 1.45/1.444 bpm ~ 3820 psi, WOB 1k, 10.8 ECD,ROP 31, Drill to 11700'. 13:40 - 14:00 0.33 DRILL P PROD1 Wiper to window. 14:00 - 16:00 2.00 DRILL P PROD1 Drill 1.46 / 1.46 bpm X3850 psi. 3600 FS, DWOB .4K,ECD 10.9, ROP 36, Drill to 11752'. 16:00 - 18:00 2.00 DRILL P PROD1 Drill 1.48 / 1.48 bpm X3900 psi. 3600 FS, DWOB 10.6K,ECD 10.8, ROP 32-70. Drill to 11850'. 18:00 - 18:30 0.50 DRILL P PRODi Wiper to window. 18:30 - 19:00 0.50 DRILL P PROD1 Drill to 11886' at1.51/1.48 bpm ~ 4380 psi, 3900 psi FS, Printed: 7/7/2008 11:52:08 AM i BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/18/2008 18:30 - 19:00 0.50 DRILL P PROD1 DWOB 2.43k, ECD 11.0, ROP 93 fph, IA 498 psi, OA 413 psi. 19:00 - 21:15 2.25 DRILL P PROD1 POH to surface. 21:15 - 21:35 0.33 DRILL P PROD1 SAFETY MEETING covering procedure, hazards, and 21:35 - 22:15 0.671 DRILL P PRODi 22:15 - 22:35 0.331 BOPSUp P PRODi 22:35 - 00:00 1.42 DRILL P PROD1 6/19/2008 00:00 - 01:10 1.17 DRILL P PROD1 01:10 - 01:30 0.33 DRILL P PROD1 01:30 - 03:45 2.25 DRILL P PROD1 03:45 - 04:15 0.50 DRILL P PRODi 04:15 - 04:40 0.42 DRILL P PRODi 04:40 - 06:00 1.33 DRILL P PROD1 06:00 - 09:00 3.001 DRILL P PROD1 09:00 - 09:50 0.83 DRILL P PROD1 09:50 - 11:50 2.00 DRILL P PROD1 11:50 - 12:40 0.83 DRILL P PRODi 12:40 - 16:25 3.75 DRILL P PROD1 16:25 - 17:10 0.75 DRILL P PROD1 17:10 - 17:20 0.17 DRILL P PROD1 17:20 - 17:40 0.33 DRILL P PROD1 17:40 - 21:05 3.42 DRILL P PROD1 21:05 - 22:10 1.08 DRILL P PROD1 22:10 - 00:00 1.83 DRILL P PROD1 ~ 6/20/2008 ~ 00:00 - 00:50 ~ 0.83 ~ DRILL ~ P ~ ~ PROD1 00:50 - 02:05 1.25 DRILL P PROD1 02:05 - 04:15 2.17 DRILL P PROD1 04:15 - 05:08 0.88 DRILL P PROD1 05:08 - 05:20 0.20 DRILL P PROD1 05:20 - 05:50 0.50 DRILL P PROD1 05:50 - 09:25 3.58 DRILL P PROD1 09:25 - 10:45 1.33 DRILL P PRODi 10:45 - 13:20 2.58 DRILL P PROD1 mitigations to LD build BHA and PU lateral drlg BHA, cut coil and rehead, plus function test the BOPE. Standback injector, blowdown BHA, LD build BHA, BO motor & bit. Function Test BOPE--annular preventer, blind/shear, upper 2" combis, 2-3/8" combi, lower 2" combi, and HCR valve. Cut 106' of coil, install & pull test CTC, and rehead cable. RU CT Inspect, Finish rehead cable, PT UOC &CTC to 4500 psi. PU lateral drilling BHA, stab injector. RIH to 11407' w/ lateral drilling BHA #5 - 3" HCC bicenter bit, WTD CTD motor, HOT, DGS, DPS, EDC, P&C, Wear sub, LOC, UOC, and CTC. RD CT Inspect RIH to 11436' and tie in. Minus 18 ft correction. Drill to 11920' w/ 1.52 bpm in/1.50 bpm out, 4100 psi, FS 3750 psi, DWOB ,ECD 11.0, IA = 236, OA = 123. Drill 1.5/1.51 bpm C~ 3950 psi DWOB 2K, CT weight 7K.ECD 10.9ppg. Drill to 12050'. Swap to new Flo Pro. Wiper to window. Drill 1.55/1.53 bpm @ 3950 psi 3500 psi FS, DWOB 2.45K, CT weight 10K.ECD 10.6 ppg. Drill to 12180 Wiper to window. Drill 1.57/1.55 bpm ~ 3950 psi 3650 psi FS, DWOB 2.05 K, CT weight 8.3 K.ECD 10.6 ppg. Drill to 12350 W iper to window. Log tie-in +3 correction. Continue wiper to TD. Drill to 12500' at 1.47/1.44 bpm ~ 3500 ps, FS 3280 psi, DWOB 1.13k-1.53k, CT weight 10.7k-8..5k, ROP 80-20 fph, ECD 10.7 ppg, IA 486, OA 323. Wiper to window. Drill to 12600' at 1.51/1.48 bpm C~3 3750 ps, FS 3490 psi, DWOB 2.11 k, CT weight 9.7k, ROP 42fph, ECD 10.8 ppg, IA 510, OA 339. Drill to 12650' at 1.40/1.36 bpm ~ 3509 psi, FS 3200 psi, WOB 1.14k, ECD 10.75 ppg, ROP 95 fph, CT WT 9.5k, IA 525 psi, OA 350 psi. Wiper trip to window. Drill to 12800' at 1.41/1.36 bpm ~ 3490 psi, FS 3200 psi, WOB 1.19k-0.78k, ECD 10.78-10.84 ppg, ROP 124 fph, CT WT 10.5k-8.Ok, IA 530 psi, OA 345 psi. Wiper trip to window. Log tie-in. +4 ft correction. Continue wiper trip to TD. Drill to 12950' at 1.5/1.49 bpm ~ 3490 psi, FS 3200 psi, WOB 1.19k-0.78k, ECD 10.9-10.84 ppg, ROP 60-100 fph, CT WT 10.5k-8.Ok, IA 580 psi, OA 345 psi. Wiper to window. Drill to 13100, 1.49/1.44 bpm ~ 3780 psi, FS 3450 psi, WOB PfintBtl: //7/"LUUtl 11:SL:Utl AM i • BP EXPLORATION Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 6/5/2008 Rig Release: 6/27/2008 Rig Number: Date From - To 'Hours Task Code NPT Phase 6/20/2008 10:45 - 13:20 2.58 DRILL P PROD1 13:20 - 14:30 1.17 DRILL P PROD1 14:30 - 15:40 1.17 DRILL P PROD1 15:40 - 16:45 1.08 DRILL P PROD1 16:45 - 16:55 0.17 DRILL P PROD1 16:55 - 17:35 0.67 DRILL P PROD1 17:35 - 18:50 1.25 DRILL P PROD1 18:50 - 20:05 1.25 DRILL P PROD1 20:05 - 22:30 2.42 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 6/21/2008 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 01:10 0.17 DRILL P PROD1 01:10 - 02:45 I 1.581 DRILL I P I I PROD1 02:45 - 04:45 2.00 DRILL P PROD1 04:45 - 05:05 0.33 DRILL P PROD1 05:05 - 05:50 0.75 DRILL P PRODi 05:50 - 07:00 1.17 DRILL P PRODi 07:00 - 09:30 2.50 DRILL P PROD1 09:30 - 10:50 1.33 DRILL P PROD1 10:50 - 13:15 2.42 DRILL P PROD1 13:15 - 14:45 1.50 DRILL P PROD1 14:45 - 16:00 1.25 DRILL P PROD1 16:00 - 16:30 0.50 DRILL P PROD1 16:30 - 17:20 0.83 DRILL P PROD1 17:20 - 18:00 0.67 DRILL P PROD1 18:00 - 19:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 19:30 - 20:00 0.501 DRILL P I PROD1 Page7of13~ Spud Date: 7/5/1992 End: 6/7/2008 Description of Operations 1.19k-0.78k, ECD 10.9 ppg, ROP 60-100 fph, CT WT 10.2k-8.Ok, IA 582 psi, OA 359 psi. Wiper to window. Swap to new FloPro. Drill to 13250' , 1.53/1.5 bpm ~ 3700 psi, FS 3350 psi, WOB 1.3k, ECD 10.8 ppg, ROP 100-150 fph, CT WT 8.3, IA 612 psi, OA 381 psi. Wiper to window. Log tie-in. Correction +5'. Wiper to TD. Drill to13400', 1.49/1.44 bpm ~ 3560 psi, WOB 1.6k-1.23k, ECD 10.4-10.6 ppg, ROP 150-165 fph, CT WT 8.8k-5.3k, IA 508psi, OA 291 psi. Wiper to window. Drill to13509', 1.46/1.39 bpm ~ 3450 psi, FS 3050psi, WOB 1.37k, ECD 10.5 ppg, ROP 170 fph, CT WT 7.8k, IA 508psi, OA 291 psi. Trouble spot at 13494' stacking weight w/ no motor work. FS increased to 3160psi. Worked pipe. Purposely stalled motor. FS decreased back to 3020psi. Drilled 10' then stalled. 500' wiper trip. Back on bottom w/ same problem of stacking weight w/ no motor work. POH to change bit & motor. POH. POH to surface. SAFETY MEETING discussing job assignments, procedures, hazards, and safe work practices for BHA change. Stand back injector, LD BHA, BO motor & bit, redress LOC, PU new motor & new bit, PU agitator, PU BHA, stab injector. RIH BHA #7 w/ 3" HYC bit, WTD CTD motor, Agitator, FVS R1 float, HOT, DGS, DPS, EDC, P&C, Wear sub, LOC, UOC, and CTC. Log tie-in. -18 ft correction. RIH to bottom. Drill to 13646' , 1.34/1.29 bpm ~ 3790 psi, FS 3500psi, WOB 1.63k, ECD 10.66 ppg, ROP 50fph, CT WT 9.Ok, IA 308 psi, OA 117 psi, PVT 292bb1. W iper to window. Drill to 13'800 , 1.40/1.33 bpm X4110 psi, FS 3700psi, WOB .88-1.4 k, ECD 10.66 ppg, ROP 100fph, CT WT.2k, IA 505 psi, OA 259 psi, PVT 273bb1. Wiper to window. Drill to 13'947 , 1.37/1.30 bpm @4050 psi, FS 3700psi, WOB .88-1.4 k, ECD 10.86 ppg, ROP 150+fph, CT WT-2k, IA 545 psi, OA 306 psi, PVT 251 bbl. Wiper to window. Log tie-in +9' correction. Wiper to bottom. swap to new Flo Pro. Drill to 14000 , 1.32/1.25 bpm X4010 psi, FS 3700psi, WOB 1.5 k, ECD 10.91 ppg, ROP 150+fph, CT WT+2k, IA 516 psi, OA 290 psi, Drill to 14094', 1.37/1.30 bpm X3600 psi, FS 3150psi, WOB 1.15 k, ECD 10.4 ppg, ROP 100+fph, CT WT 2.8k-3.2k, IA 516 psi, OA 290 psi. Wiper to window. Printetl: 7/7/2009 11:52:08 AM • BP EXPLORATION Operations Summary Report Page 8 of 13 ~ Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code ~ NPT ' Phase Description of Operations 6/21/2008 20:00 - 20:35 0.58 DRILL N SFAL PROD1 CT Injector Maitenance--stop and replace 12 cotter pins & 3 peanuts on the injector chain. 20:35 - 22:35 2.00 DRILL P PROD1 Wiper to window. 22:35 - 23:30 0.92 DRILL P PROD1 Drill to 14186', 1.32/1.22 bpm ~ 3600psi, FS 3100psi, WOB 0.99k, ECD 10.3ppg, ROP 100+fph, CT WT 5.3k, IA 464 psi, OA 240 psi, PVT 319. 23:30 - 00:00 0.50 DRILL N STUC PRODi Diffentially stuck on bottom. Coil Wt is 39k. Overpulled to 64k; still stuck. Called for crude. Pull 44k and circulate hole clean. Down on the pumps and relax pipe. 6/22/2008 00:00 - 06:15 6.25 DRILL N STUC PROD1 Differentially stuck & waiting on crude. Bit depth 14151'. Coil 06:15 - 07:50 1.58 DRILL P 07:50 - 08:00 0.17 DRILL P 08:00 - 09:05 1.08 DRILL P 09:05 - 13:00 3.92 DRILL P 13:00 - 13:45 0.75 DRILL P 13:45 - 15:10 1.42 CASE P 15:10 - 21:00 5.83 CASE P 21:00 - 21:45 0.75 CASE P 21:45 - 22:00 0.25 CASE P 22:00 - 00:00 2.00 CASE P 6/23/2008 00:00 - 02:00 2.00 ~ CASE ~ P 02:00 - 04:20 2.33 CASE P 04:20 - 05:05 0.75 CASE P 05:05 - 07:00 1.92 CASE P 07:00 - 10:15 3.25 CEMT P weight 39k, pull to 71 k. Relax pipe. Truck picking up crude has mechanical problems, another truck has been dispatched. Crude on site at 04:20. S of 10bb1 crude, Pull 70k. Relax pipe for 40 minutes. Work pipe pull 60k Pump 5bbl. Relax 15min. Pull 44k, worked. pipe free. PROD1 Wiper to window. PROD1 Log tie -in. correction +19.5' PROD1 Wiper to TD. Tag at 14187. Circulate liner pill to TD 1 bpm ~ 2850 psi. PROD1 POH spotting liner pill. POH to window. Repair injection chain replace one peanut. Continue to POH. PROD1 LD BHA. HyCalog bit graded 1,1 RUNPRD Circulate mud from reel. Blow down reel with N2. RUNPRD Pull back and secure. CT to reel. Exchange reels, Insert grapple & Pull test. Pull cementing CT across. Weld on CTC. Pull Test CTC, PT hardline to 4000psi, fill coil, pump volume dart--41.7bb1 coil vol. RUNPRD RU elevators. Pull up BTT tools to rig floor. Filled hole; well is taking fluid. RUNPRD SAFETY MEETING discussing procedures, hazards, and safe work practices for PU liner. RUNPRD PU Guide shoe, float collar, 1 jnt 4.6ppf L-80 ST-L solid liner w/ cementralizer, float collar, pup jnt, landing collar, 47 jnts 4.6 ppf L-80 ST-L liner w/ cementralizers. Torque connections to 1100# and drift first 5 jnts of liner. RUNPRD PU 45 jnts 4.6# L-80 ST-L Liner w/ cementralizers (92 ints total and BOT Liner Deployment Sleeve. Total Liner Assembly Length = 2955.22'. Stab injector. RUNPRD RIH w/ Liner Assembly. Work pipe from 14104' down to 14217'. RUNPRD Launch 5/8" steel ball. Pump at 0.4bpm; do not hear ball. Increase to 1.25bpm; ball is moving. Ball on seat at 39bb1, sheared at 4200psi. Release from liner verified by 24k PU wt versus 34k while running liner. RUNPRD Displace well to 2% KCL Double Slick 2.14 / 1.8 BPM C~ 3245 psi. RUNPRD RU cementers. Hold PJSM .Batch up cement. Flood lines with KCL & PT to 6000 psi. Zero in MM at 15.9 density. Pump 11.6 bbls (Calculated + 1.5bb1 for losses.) ~ 2 bpm. Displace with 34 bbl Bio and KCL bbl pumped in /out rates Pressure Printetl: 7/7/2008 11:5L:OS AM ~ ~ BP EXPLORATION Page 9 of 13 Operations. Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task '~ Code ~ NPT ' Phase Description of Operations __ 6/23/2008 07:00 - 10:15 3.25 CEMT P RUNPRD 11.6 4277 Cement 15.9 pp9 Launch dart and clear cement from inner reel valve to 30 2.0/1.63 3460 35 2.02/1.63 3350 40 2.01/1.61 -3307 44 1.9/1.57 3311 swap displacement to KCL 49 1.0/.84 978 50 .91 /.61 872 52 .89/.54 959 53 .88/.48 1003 53.6 Shear liner wioer olua ~ 4400 psi. Zero out MM 58 1.43/1.1 4058 60 1.43/1.14 4058 61 1.28/1.05 3988 62 1.16/.97 4178 interface at window. 63 .83/.68 3779 65.5 bump plug (calculated 64.8) Total return thru out MM 9 bbls 2.9 bbls lost t TOP OF CEMENT at WINDOW. Check floats OK. Unsling circ 2 bbl 10:15 - 12:00 1.75 CEMT P RUNPRD POH. Filling displacement. 12:00 - 13:30 1.50 CEMT P RUNPRD LD liner running tools. PU the cleanout assy. 13:30 - 16:15 2.75 CEMT P RUNPRD RIH with 49 stands of 1"CSH. 16:15 - 20:10 3.92 EVAL P LOWERI RIH Clean ut BHA weld on CTC, dual flapper check valve, lockable swivel, hyd disconnect, XO, 49 stands 1"CSH, XO, hyd disconnect, circ sub, baker motor, and HCC diamond parabolic mill. Total Length = 3052.11' 20:10 - 23:00 2.83 EVAL P LOW ERi POH to surface. 23:00 - 23:10 0.17 EVAL P LOWERI SAFETY MEETING discussing hazards, safe work practices, and procedure to standback CSH and RD cleanout tools. 23:10 - 00:00 0.83 EVAL P LOWERI standback injector and CSH. 6/24/2008 00:00 - 01:15 1.25 EVAL P LOWERI standback remaining CSH. UD cement milling tools. 01:15 - 02:00 0.75 BOPSU P LOW ER1 MU swizzle stick, stab injector, jet the stack, and function rams. 02:00 - 02:15 I 0.25 I EVAL I P 02:15 - 04:30 2.25 EVAL P 04:30 - 06:00 1.50 EVAL P 06:00 - 08:00 2.00 EVAL P 08:00 - 09:00 1.00 EVAL P 09:00 - 10:20 1.33 EVAL P LOWERI SAFETY MEETING discussing radiation safety, procedure to MU logging BHA, and hazards w/ PU CSH. LOWERi PU MCNL to in tools and 49 stands of CSH. LOWERI RIH logging BHA #10 w/ CTC, dual flapper check valve, lockable swivel, 3/4" ball hydraulic disconnect , XO, 49 stands 1"CSH, XO, 5/8" ball hydraulic disconnect, XO, and MCNL tool. LOWERI Log down from 10600 at 30 fpm.Tag lightly at 14166. LOWERI Log from TD to 10600' @ 60 fpm. LOWERI POH Printetl: 7/7/2008 11:52:08 AM ~ ~ BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~~ From - To Hours Task Code NPT 6/24/2008 10:20 - 13:45 3.42 EVAL P 13:45 - 13:50 0.08 EVAL P 13:50 - 14:50 1.00 CEMT P 14:50 - 15:20 0.50 PERFOB~ P 15:20 - 18:00 2.67 PERFO P 18:00 - 18:10 0.17 PERFO~ P 18:10 - 19:30 1.33 PERFO P 19:30 - 21:30 2.00 PERFO P 21:30 - 22:30 I 1.00 P Spud Date: 7/5/1992 Start: 6/5/2008 End: 6/7/2008 Rig Release: 6/27/2008 Rig Number: Phase ', Description of Operations LOWERI Stand back CSH LOWERI PJSM with logger RUNPRD Liner lap test 14:18 - 2040 psi 14:23 - 1967 PSI 14:28 - 1915 PSI 14:33 - 1857 PSI 14:38 - 1802 PSI 14:43 - 1750 PSI 14:45 - 1740 PSI 14:48-1710 PSI Failed Test Lost 330 si in 30 min LOWERI PJSM for running pert guns LOWERI MU 1.56" Perf Gun BHA #11 w/ 62 Guns and blanks (over all length is 1326'). LOWERI PJSM RU to run 1" stds of CSH, RIH with 27 stds of 1" CSH LOWERI RU and RIH 27 stds of 1"CSH LOWERI RI CTC, dual flapper check valve, lockable swivel, 3/4" ball hyd disconnect, XO, 54 jnts 1" CSH, XO, 5/8" ball hyd disconnect, and 62 1 56" oer auns & firinq,h~ad , BHA total length = 3005.10' LOWERI Tag bottom 14169'. Confirm tag at 14169'. PU until weight breaks over at 14163'. Correct depth to PBTD 14141'. Zero totalizers. Launch ball. Pull up to 14102'. Ball confirmed launched. Pump 1.3bpm C~ 3700psi. Decrease to 0.65bpm ~ 1179psi at 31 bbl. Ball on seat 36.9bb1 (43.3bb1 calculated), pressure slowly climbing, POH slowly. MM outrate also 22:30 - 22:40 I 0.171 P 22:40 - 00:00 I 1.33 I P P LOWERI POH 45fpm, 0.7bpm ~ 2850psi. Slow to 12fpm, 0.60bpm ~ 670psi. Low level gas detection alarm at surface, w/ gas dispersing quickly. Out MM erratic between 3ppg to 6ppg. Shut in choke at 12000'. POH 50fpm pumping 0.50bpm ~ 480psi. Decrease to 0.20bpm C~ 315psi. Shut in pressure gradually increased to 200psi. PU to above liner at 11000'. P LOW ER1 Shut down pumps, open choke, and flow check for 15 minutes. Initial fluid flow that dropped to zero after one minute. 6/25/2008 ~ 00:00 - 01:30 ~ 1.50 ~ PERFOB~ P 01:30 - 01:50 0.33 PERFO P 01:50 - 02:00 0.17 PERFO P 02:00 - 04:20 2.33 PERFO P 04:20 - 04:30 0.17 PERFO P 04:30 - 09:00 4.501 PERFOB~ P LOWERi POH pumping at 0.8bpm C~3 960psi. Out MM jumping between 3ppg & 6ppg. LOWERI Flowcheck at 400'. No flow. LOWERi SAFETY MEETING discussing UD CSH. LOWERI UD 54jnts 1"CSH LOWERI SAFETY MEETING discussing hazards, procedures, and safe work practices to UD perf guns. LOWERI UD 62 perf guns, RD, cleared floor, offload perf guns from Printed: 7/7/2008 1 L'S2:08 AM ~ ~ BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 6/25/2008 04:30 - 09:00 4.50 PERFO P LOW ER1 PERFORATED INTERVALS: 2", SWS PJ, 6 SPF 12800' -13490', 13560 - 14100', TOTAL PERF INTERVAL = 1,230'. 09:00 - 09:05 0.08 CASE P RUNPRD PJSM on handling and running LTP 09:05 - 09:30 0.42 CASE P RUNPRD Ml I Liner Too Pkr BHA # 12 09:30 - 13:00 3.50 CASE P RUNPRD RIH with LTP Assy to 11180', Up Wt at 11180' without the pumps, 51 k, broke back abruptly to 35k with 1800 psi of spike pressure continued PU to 42k, broke back to 40k, then slacked off with 8-9k, then PU with Up Wt of 29.6k, pressure fell off to Opsi, S/O wt of 16.5k, stung into deployment sleeve at 10225', attempt to test backside to 1000psi, communicating up CT with 13:00 - 16:05 3.08 CASE P RUNPRD POH to BHA #12 from 11225' to 10575', UP wt 29.6k, attempt to circ while POH at minimum rate, pressure increasing to 700psi, Up Wt increased to 38k, shut down pumps, lined up to circ across well, continued POH to 10532' with up drag of 20-25k, S/O wt at 14-15k, worked back and forth, freed up, POH, resumed UP Wt of 29.5k, POH at 50-60fpm. Note: GLM at 10516', slight bobble at GLM at 8983', no other problems with other GLMs, Tagged up on SSSV at 2152'. Found 2 peanut plates that had fallen off the back side of the injection chain at separate intervals while POH, the cotter pins had sheared. Replaced the peanut plates and cotter pins 16:05 - 16:15 0.17 CASE N DFAL RUNPRD Att m t to work ast SSSV at 2151' after fo rth tt t through SSSV. stuck in SSSV at 2151', unable to work CT up 16:15 - 16:25 0.17 CASE N DFAL RUNPRD PJSM with rig personnel to discuss operational procedure for working CT free. 16:25 - 17:20 0.92 CASE N DFAL RUNPRD Secured rig floor, RU, bullhead down backside of CT to 700psi, working CT several times with 50k over pull, no movement, bleed off trapped pressure from CT 400psi, attempt to work pipe free with several overpulls of 50k, no movement, Line up to pump down backside taking returns up CT with 700psi, Dulled free after several attempts with 50k overpulls 7:20 - 17:55 17:55 - 21:15 .58 3.33 ASE CASE N N FAL DFAL UNPRD RUNPRD Peanut plate had fallen off the frontside of the injection chain while POH at 1849' ,the cotter pin had sheared. Replaced the peanut plate and cotter pin POH to LTP assy, BHA #12 LTP parted at the inner mandrel and the outer slip housing. Consulted with ANC office, Wells Group, and Baker for plan forward. Replaced cotter pins on the injector chains and circulated two coil volumes through the rig floor circulating hole at 1.4bpm to flush out any junk sucked up while taking returns through CT. 21:15 - 21:30 0.25 CASE N DFAL RUNPRD SAFETY MEETING discussing RU of slickline lubricator and fishing job details, radio communication, and emphasizing safe work practices. 21:30 - 00:00 2.50 CASE N DFAL RUNPRD PU slickline tools and lubricator to rig floor. RU lubricator and slickline unit. Discuss fishing plan w/ BTT, slickline, Wells Group, and ANC office. Printed: 7/7/2008 11:52:08 AM ~ • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task !Code ' NPT I Phase 6/26/2008 00:00 - 00:15 0.25 CASE N DFAL RUNPRD 00:15 - 06:00 5.75 FISH N DFAL RUNPRD Description of Operations Pressure test slickline lubricator to 500psi. RIH w/ slickline. Overall Fish Length = 7.91' (LTP seal assembly, fishing neck, & slip case) 1st run--2.84" No Go & 2.25" magnet w/ covering sleeve. Sat down on top of SSSV at 2118' slickline MD. SSSV is clear. Magnet returned metal shavings to surface. 2nd run--2.70" OD Lead Impression Block. Lightly tagged at 2144' slicklihe MD. No usable impression. 3rd run--2.70" OD Lead Impression Block. Tagged at 2146' slickline MD. Clear cresent shape indicating top of parted 4th run--2.84" No go. Confirmed No Go in SSSV at 2134' slickline MD. 5th run--2.5" No Go w/ 2.375" Magnet. Returned metal shavings and 2" sliver of sealing element. 6th run--Tattle-tail. Confirmed spear will release from fish. 06:00 - 06:20 0.33 FISH N 06:20 - 08:45 2.42 FISH N 08:45 - 09:30 0.75 FISH N 09:30 - 11:15 1.75 FISH N 11:15 - 12:45 12:45 - 15:35 1.50 FISH N 2.83 FISH N 15:35 - 16:30 16:30 - 16:45 16:45 - 17:15 17:15 - 17:45 17:45 - 17:55 17:55 - 19:00 19:00 - 19:30 0.92 FISH N 0.25 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 0.17 WHSUR P 1.08 WHSUR P 0.501 WHSURIP DFAL RUNPRD DFAL RUNPRD DFAL IRUNPRD DFAL IRUNPRD DFAL RUNPRD DFAL RUNPRD DFAL RUNPRD POST POST POST POST POST POST Further review of the slickline depth shows the fish is in the bottom of the SSSV. Discussed operations w/ ANC Office and will run releaseable spear next. PJSM for fishing with slickline MU slickline 1.79" OD releasable spear with 1.43" OD center core and 1.68" nogo, engaged fish at 2144', Came free on second pull, POOH, looked like grapple was all the way in, but came free. Re-pinned the GS and clean the grapple top. No recovery MU slickline 1.79" OD releasable spear with 1.43" OD center core and 1.68" nogo, start jarring down to engage spear at 2144', jarred up twice, pulled free POH LD 1.43" OD center MU slickline 1.89" OD releasable spear with 1.47" OD center core and 1.89" nogo, Stab lubr, test to 500 psi, RIH with slickline to 2145', engaged fish jarred up .Unsuccessful. no ~n~, Consult with Anchorage for plan forward. Wait on slickline tools MU slickline 2.7" OD blind box, 16' of 1.875" Stem, Stab lubr, test to 500 psi, RIH with blind box, Jarring down with over 500 Fish left in the 3-1/2" tubing at 2144' (SSSV) slickline MD. Fish is the bottom half of a 35 Hyd. KB Packer, 7.91' long, consisting of the seal assembly, fishing neck, and slip cage. Three packer slips and two sealing elements are in the well at unknown depths below the packer. POH, LD slickline, offload tools and equipment from rig floor MU BHA #13 with nozzle RIH to 2100' POH. freeze protect well with 18 bbls of diesel to surface PJSM on pickling and N2 blowdown procedures. Pickle 2" CT with 50 bbl water pill, 10bbls of inhibited water w/ KI-3882, 10bbls of McOH water. Wait on N2 Crew. Nrinred: nnzoutf n:oz:ue Nnn ~ ~ BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 15-18 Common Well Name: 15-18 Spud Date: 7/5/1992 Event Name: REENTER+COMPLETE Start: 6/5/2008 End: 6/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/27/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations 6/26/2008 19:30 - 19:40 0.17 WHSUR P POST SAFETY MEETING discussing hazards, procedures, and safe work practices to blow down coil with N2. 19:40 - 20:45 1.08 WHSUR P POST Blow down coil with N2. Bleed off to tiger tank. Standback injector. 20:45 - 21:10 0.42 WHSUR P POST Install BPV. ~ 21:10 - 21:20 0.17 WHSUR P POST SAFETY MEETING discussing hazards and procedures to pull coil back to reel and RD hardline. 21:20 - 22:00 0.67 WHSUR P POST RU tugger, install internal grapple, pull test grapple, pull coil across. 22:00 - 00:00 2.00 WHSUR P POST RD hardline in reelhouse & stack inside reel. Cleanout shaker. 6/27/2008 00:00 - 00:25 0.42 WHSUR P POST Finish RD hardline and spot truck under reelhouse. Start cleaning out pits. 00:25 - 00:35 0.17 WHSUR P POST SAFETY MEETING discussing communication, personnel position, and hazards of lowering the reel. 00:35 - 01:15 0.67 WHSUR P POST Lower reel to lowboy trailer. 01:15 - 01:25 0.17 WHSUR P POST SAFETY MEETING discussing procedures and safety aspects of RD injector into its components. 01:25 - 06:00 4.58 WHSUR P POST RD gooseneck to catwalk. Breakdown injector and set on rig floor. Clean up and lower stripper down beaver slide. Move injector to catwalk. 06:00 - 06:45 0.75 WHSUR P POST PJSM for ND BOP's and lifting injector 06:45 - 10:00 3.25 WHSUR P POST Lift injector and gooseneck down from catwalk. ND BOP's, install tree cap and Pressure test RELEASE RIG 12:00 on 6/27/08 Total Time from Accept to Release = 15 Davs 9 hours Printed: 7/7/2008 11:52:08 AM by ~ BP Alaska ~~ Baker Hu hes INTE Surve Re ort g Q Y P lNTEQ Company: $P Amoco Date: 6/23/2008 Time: 08:17:54 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: W eIL 15-18, True North. Site: PB DS t5 Vertical (TVD) Reference: 28:18 7/5/1992 00:00 67.0 Went 15-18 Section(VS)Refereuce: Wefl'(O.OON,O.OOE,318.38Azi) Wellpath: 15-18A Survey Calculation Method: Minimum Curvature' Db: Oracie Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-18 Slot Name: 18 15-18 Well Position: +N/-S 2033.93 ft Northing: 5960865.55 ft Latitude: 70 17 55.240 N +E/-W -215.32 ft Easting : 676034.04 ft • Longitude: 148 34 27.490 W Position Uncertainty: 0.00 ft Wellpath: 15-18A Drilled From: 15-18 500292227401 Tie-on Depth: 11355.86 ft Current Datum: 28:18 7/5/1992 00:00 Height 67.00 ft ' Above System Datum: Mean Sea Level Magnetic Data: 4/25/2008 Declination: 23.32 deg Field Strength: 57676 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.00 0.00 0.00 318.38 Survey Program for Definitive Wellpath Date: 4/25/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 437.98 11355.86 1 : MW D -Standard (437.98-135 MW D MW D -Standard 11426.00 14187.00 MW D (11426.00-14187.00) MW D MW D -Standard Annotation MD TVD ft ft 11355.86 8541.91 TIP 11426.00 8576.27 KOP 14187.00 8820.98 TD Survey: MW D Start Date: 6/19/2008 Company: Baker Hughes INTEQ Engineer: BP Tool: MW D;MW D -Standard Tied-to: From: Definitive Path Survey MD Incl- Azim TVD Sys TVD N/S E/W 1VIapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ' ft deg/100ft 11355.86 59.82 326.09 8541.91 8474.91 5294.82 -4239.90 5966059.26 671671.56 6774.33 0.00 MW D 11426.00 61.52 326.62 8576.27 8509.27 5345.73 -4273.77 5966109.36 671636.50 6834.89 2.51 MW D 11457.84 54.66 325.52 8593.09 8526.09 5368.14 -4288.84 5966131.41 671620.91 6861.66 21.74 MW D 11495.10 43.08 323.86 8617.56 8550.56 5391.03 -4305.00 5966153.91 671604.22 6889.50 31.26 MW D 11525.32 34.18 320.89 8641.14 8574.14 5405.98 -4316.47 5966168.59 671592.40 6908.29 30.08 MW D 11555.34 28.05 311.79 8666.85 8599.85 5417.24 -4327.07 5966179.60 671581.55 6923.75 25.69 MW D 11586.42 31.46 296.94 8693.86 8626.86 5425.80 -4339.77 5966187.86 671568.65 6938.58 26.05 MW D 11616.34 36.30 286.54 8718.72 8651.72 5431.87 -4355.24 5966193.56 671553.04 6953.40 25.19 MW D 11647.84 43.32 279.32 8742.91 8675.91 5436.28 -4374.88 5966197.51 671533.31 6969.74 26.65 MW D 11677.20 49.69 273.41 8763.12 8696.12 5438.58 -4396.02 5966199.32 671512.12 6985.50 26.14 MW D 11707.76 55.24 266.85 8781.74 8714.74 5438.58 -4420.22 5966198.75 671487.92 7001.57 24.88 MW D BP Alaska by Baker Hughes INTEQ Survey Report BAI~R Nua~s INTEQ Company:. BP Amoco Date: 6/23/2008 Time: 08:17:54 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-18, T rue North Site:: PB DS 15 Vertical (TVD) Reference: 28 : t8 7/5/1 992 00:00 67 .0 Well: 15- 18 Section (VS) Reference: Well (0.001V,O. OOE,318:38Azi) WeRpaths 15- 18A Survey Calculation Method: Minimum Curvature Db: Oracle Survey Mb Incl Azm TVD 5ysTVD N1S F./W MapN MapE VS ` DLS Tool ff deg deg ft ft ft ft ft ft ft deg/100ft 11737.74 61.84 261.46 8797.39 8730.39 5435.94 -4445.63 5966195.51 671462.59 7016.47 26.82 MW D 11768.88 67.36 254.67 8810.75 8743.75 5430.09 -4473.11 5966189.03 671435.25 7030.35 26.49 MW D 11799.06 72.76 258.68 8821.05 8754.05 5423.57 -4500.71 5966181.86 671407.82 7043.80 21.82 MW D 11829.48 79.91 263.47 8828.23 8761.23 5419.01 -4529.88 5966176.62 671378.76 7059.77 28.04 MW D 11856.80 86.25 268.09 8831.52 8764.52 5417.03 -4556.91 5966174.00 671351.79 7076.24 28.64 MW D 11888.05 91.72 276.03 8832.08 8765.08 5418.15 -4588.10 5966174.39 671320.59 7097.79 30.84 MW D 11920.37 92.21 282.04 8830.97 8763.97 5423.22 -4619.98 5966178.71 671288.59 7122.76 18.65 MW D 11950.75 91.07 286.15 8830.10 8763.10 5430.61 -4649.43 5966185.42 671258.98 7147.84 14.03 MWD 11980.91 92.76 291.66 8829.09 8762.09 5440.37 -4677.93 5966194.51 671230.26 7174.07 19.10 MWD 12009.97 90.86 294.92 8828.17 8761.17 5451.86 -4704.61 5966205.36 671203.32 7200.37 12.98 MWD 12042.81 91.14 300.21 8827.60 8760.60 5467.05 -4733.70 5966219.86 671173.88 7231.05 16.13 MWD 12070.71 93.50 305.93 8826.47 8759.47 5482.25 -4757.05 5966234.51 671150.18 7257.92 22.16 MWD 12100.85 92.49 310.31 8824.89 8757.89 5500.82 -4780.73 5966252.53 671126.08 7287.53 14.89 MWD 12131.77 92.43 315.43 8823.56 8756.56 5521.83 -4803.36 5966273.00 671102.97 7318.27 16.54 MWD 12160.95 92.00 319.99 8822.44 8755.44 5543.40 -4822.97 5966294.10 671082.85 7347.42 15.68 MWD 12190.87 91.72 323.78 8821.46 8754.46 5566.92 -4841.43 5966317.18 671063.85 7377.26 12.69 MWD 12225.51 90.65 330.66 8820.75 8753.75 5596.02 -4860.17 5966345.83 671044.44 7411.46 20.10 MWD 12259.47 89.78 330.25 8820.62 8753.62 5625.57 -4876.91 5966374.97 671027.01 7444.67 2.83 MWD 12293.29 93.47 327.52 8819.66 8752.66 5654.50 -4894.38 5966403.49 671008.87 7477.90 13.57 MW D 12332.53 94.53 322.39 8816.92 8749.92 5686.54 -4916.85 5966434.99 670985.66 7516.78 13.32 MW D 12361.31 91.57 320.01 8815.39 8748.39 5708.93 -4934.85 5966456.95 670967.14 7545.48 13.19 MW D 12390.99 90.95 316.26 8814.74 8747.74 5731.02 -4954.65 5966478.58 670946.83 7575.14 12.80 MW D 12423.79 90.98 311.15 8814.18 8747.18 5753.68 -4978.35 5966500.67 670922.60 7607.82 15.58 MW D 12455.11 90.61 308.39 8813.75 8746.75 5773.71 -5002.42 5966520.13 670898.07 7638.78 8.89 MW D 12487.07 86.65 305.32 8814.51 8747.51 5792.87 -5027.98 5966538.68 670872.08 7670.07 15.67 MW D 12518.53 87.94 301.74 8816.00 8749.00 5810.22 -5054.17 5966555.41 670845.49 7700.44 12.08 MW D 12548.79 91.32 298.42 8816.19 8749.19 5825.38 -5080.35 5966569.96 670818.96 7729.16 15.66 MW D 12580.97 90.12 294.02 8815.79 8748.79 5839.60 -5109.20 5966583.49 670789.78 7758.96 14.17 MWD 12612.15 90.28 289.73 8815.68 8748.68 5851.21 -5138.13 5966594.42 670760.59 7786.85 13.77 MW D 12642.87 88.19 286.00 8816.09 8749.09 5860.63 -5167.36 5966603.16 670731.15 7813.31 13.92 MWD 12672.61 87.24 281.36 8817.28 8750.28 5867.66 -5196.23 5966609.50 670702.13 7837.73 15.91 MWD 12703.47 89.54 277.12 8818.15 8751.15 5872.61 -5226.67 5966613.74 670671.59 7861.65 15.63 MWD 12733.93 92.64 275.54 8817.57 8750.57 5875.97 -5256.93 5966616.39 670641.25 7884.26 11.42 MWD 12764.83 93.59 280.26 8815.89 8748.89 5880.21 -5287.48 5966619.91 670610.61 7907.72 15.56 MWD 12796.89 92.24 284.52 8814.26 8747.26 5887.07 -5318.75 5966626.04 670579.20 7933.62 13.92 MWD 12833.29 91.69 289.77 8813.01 8746.01 5897.80 -5353.50 5966635.95 670544.21 7964.71 14.49 MWD 12863.75 90.00 292.89 8812.56 8745.56 5908.87 -5381.86 5966646.36 670515.59 7991.83 11.65 MWD 12897.43 90.86 298.95 8812.30 8745.30 5923.59 -5412.14 5966660.36 670484.98 8022.94 18.17 MWD 12929.07 90.86 303.97 8811.83 8744.83 5940.09 -5439.12 5966676.22 670457.63 8053.20 15.86 MW D 12963.01 92.12 309.76 8810.95 8743.95 5960.44 -5466.25 5966695.93 670430.03 8086.43 17.45 MW D 12993.95 91.44 314.61 8809.98 8742.98 5981.20 -5489.16 5966716.14 670406.64 8117.16 15.82 MW D 13027.17 92.27 311.53 8808.91 8741.91 6003.87 -5513.41 5966738.24 670381.87 8150.22 9.60 MW D 13059.53 92.33 307.49 8807.61 8740.61 6024.44 -5538.35 5966758.22 670356.45 8182.16 12.48 MW D 13090.65 91.23 302.86 8806.64 8739.64 6042.35 -5563.77 5966775.53 670330.62 8212.43 15.28 MW D 13122.05 90.80 297.89 8806.09 8739.09 6058.22 -5590.84 5966790.76 670303.18 8242.28 15.88 MW D 13153.80 90.64 295.89 8805.69 8738.69 6072.58 -5619.16 5966804.45 670274.54 8271.82 6.32 MWD 13183.47 89.39 299.36 8805.68 8738.68 6086.33 -5645.44 5966817.58 670247.95 8299.56 12.43 MWD 13215.73 90.58 305.01 8805.69 8738.69 6103.51 -5672.73 5966834.11 670220.26 8330.52 17.90 MWD 13247.15 90.52 310.03 8805.38 8738.38 6122.64 -5697.64 5966852.65 670194.91 8361.37 15.98 MW D 13279.34 89.78 315.26 8805.30 8738.30 6144.44 -5721.31 5966873.89 670170.74 8393.39 16.41 MW D 13310.84 89.57 319.66 8805.48 8738.48 6167.64 -5742.60 5966896.59 670148.91 8424.87 13.98 MW D 13341.71 91.04 324.65 8805.32 8738.32 6192.01 -5761.54 5966920.50 670129.41 8455.67 16.85 MWD 13372.12 90.80 328.94 8804.83 8737.83 6217.44 -5778.18 5966945.54 670112.18 8485.74 14.13 MWD BP Alaska by Baker Hughes INTEQ Survey Report sw~ ~r Nuys INTEQ Company: BP Amoco Date:. 6/23/2008 Time: 08:17:54 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-18, True North 'Site: PB DS 15 Vertical (TVI)) Reference: 28:18.7/5/1992'00:00 67.0 Well: 15-18 Section (VS) Reference: Well (O:OON,0 00E,318.38Azi) Wellpathd 45-18A Survey Calculation Method: Minimum Curvature Db: OraCle Survey MD Inca Azim TVD Sys TVD N/S F./W MapN MapE ?" VS ' DIS Tool ft deg deg ft ft ft ft fT ft ft degl100ft 13401.64 90.92 333.48 8804.38 8737.38 6243.31 -5792.40 5966971.06 670097.36 8514.51 15.38 MW D 13438.18 89.05 337.63 8804.39 8737.39 6276.56 -5807.51 5967003.95 670081.47 8549.41 12.46 MW D 13472.02 87.33 342.29 8805.46 8738.46 6308.33 -5819.10 5967035.43 670069.15 8580.86 14.67 MW D 13503.90 88.12 346.95 8806.73 8739.73 6339.03 -5827.55 5967065.93 670059.98 8609.42 14.81 MW D 13533.89 87.05 349.98 8807.99 8740.99 6368.39 -5833.54 5967095.13 670053.31 8635.35 10.71 MWD 13565.16 85.90 352.21 8809.92 8742.92 6399.22 -5838.37 5967125.84 670047.76 8661.60 8.01 MWD 13598.28 91.11 352.39 8810.78 8743.78 6432.02 -5842.80 5967158.53 670042.55 8689.07 15.74 MW D 13633.70 95.89 350.59 8808.62 8741.62 6466.97 -5848.03 5967193.35 670036.51 8718.67 14.42 MW D 13671.57 94.87 346.27 8805.06 8738.06 6503.90 -5855.59 5967230.08 670028.09 8751.30 11.67 MW D 13702.81 91.88 343.61 8803.23 8736.23 6534.01 -5863.70 5967259.99 670019.28 8779.19 12.80 MW D 13733.24 90.31 340.85 8802.64 8735.64 6562.98 -5872.98 5967288.73 670009.32 8807.02 10.43 MW D 13763.72 90.09 335.06 8802.54 8735.54 6591.22 -5884.42 5967316.70 669997.23 8835.72 19.01 MW D 13796.38 88.10 332.65 8803.05 8736.05 6620.53 -5898.80 5967345.66 669982.16 8867.19 9.57 MWD 13830.91 86.41 331.21 8804.71 8737.71 6650.96 -5915.03 5967375.70 669965.22 8900.72 6.43 MWD 13864.48 86.94 327.11 8806.65 8739.65 6679.73 -5932.21 5967404.06 669947.38 8933.64 12.29 MWD 13895.00 88.41 323.38 8807.89 8740.89 6704.78 -5949.59 5967428.69 669929.42 8963.91 13.13 MW D 13926.48 89.69 320.19 8808.42 8741.42 6729.50 -5969.06 5967452.95 669909.37 8995.32 10.92 MW D 13959.02 89.20 317.24 8808.73 8741.73 6753.95 -5990.52 5967476.89 669887.34 9027.86 9.19 MW D 13992.40 86.78 314.56 8809.90 8742.90 6777.90 -6013.74 5967500.29 669863.58 9061.18 10.81 MW D 14023.32 86.26 310.66 8811.78 8744.78 6798.79 -6036.45 5967520.64 669840.39 9091.88 12.70 MWD 14052.32 87.58 310.83 8813.34 8746.34 6817.69 -6058.38 5967539.02 669818.01 9120.58 4.59 MWD 14084.58 88.28 314.95 8814.50 8747.50 6839.63 -6082.00 5967560.40 669793.89 9152.66 12.95 MWD 14114.02 87.21 319.00 8815.66 8748.66 6861.13 -6102.07 5967581.42 669773.33 9182.06 14.22 MW D 14148.34 85.39 323.46 8817.88 8750.88 6887.82 -6123.51 5967607.60 669751.27 9216.26 14.01 MW D 14187.00 85.39 323.46 8820.98 8753.98 6918.78 -6146.45 5967638.02 669727.61 • 9254.64 0.00 MW D 1LHEAD = MCEVOY • TUATOR = Otis . ELEV = 67' ELEV= JR~~ ~~F-~ ~p = x Angle = 96° @ 13634' 4-1/2" TBG, 12.6#, L-80 34' tum MD = 14759' .0152 bpf, ID = 3.958" tum TVD = 8800' SS 13-3/8" CSG, 68#, K-55/ L-80, ID = 12.415" 3904' Fish -- 2 slips and 2 sealing elements from Packer. H ?????' TOP OF 7" LNR ~~ 10602' 9-518" CSG, 47#, L-80, ID = 8.681" ~~ 10932' Minimum ID =1.995" @ 11232' 2-3/8" STL PUP Top of 2-3/8" LNR Deployment 11226' Sleeve w / 3" GS profile. ID=2.25" TOP OF 3 1/2"whipstock -i 11426' TOP OF 3 1/2"whipstock 11520' CIBP 11550' 3-1/2" TBG, 9.2#, 13-CR-80, .0087 bpf, ID = 2.992" 12350' PERFORATION SUMMARY REF LOG: Memory CCL/GR/CNL on 06/24/08 ANGLE AT TOP PERF: 92°@ 12800' Note: Refer to Production DB for historical perf data 1.56" 16 I 13560 - 1400 I O (06/24/08 v ~ POS~' CHOKE PKR LDL,3/12/98 POSSIBLY PKR 15 -18 A , LEAK. CMT TOP IN IA @ 10500', CMT TOP INSIDE TBG POST MILLING @ 12205'. 3-12" CHROME TBG. 16 SLIP PIECES & RET RING FROM MIS-SET CIBP MAY BE IN GLMs. 34' 4-112" X 3-1 /2" XO 2143' 3-1/2" CAMCO TRDP SSSV NIP ® " (LOCKED OUT TRSV ), ID = 2.81 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAl 5 3501 3223 44 FMHO DOME RK 16 07/26 4 6788 5503 47 FMHO SO RK 20 07/26 3 8983 7017 46 FMHO DMY RK 0 08!02 2 10424 7992 49 FMHO DMY RK 0 02/06 ~ 1 10516 8052 49 FMHO DMY RK 0 08/02 10500' I-I TOP OF CEMENT 11362' ~ 3-1/2" PARKER SWN NIP, ID = 2.75" 11426' Top of w indow 11431' Bottom of w indow PBTD 14141' 2-3/8" LNR, 4.6#, L-80, STL w / cementralizers, ID = 1.995" ~-{ 141 i 12340' ~~ 7" X 3-1/2" TM/ SS HORIZONTAL PKR 12350' -' 3-1/2" TMJ 6-UNIT OVERSHOT SEAL ASSY 12369' ~-{ 4-1/2" PORTED JOINT (34.85') 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 1261 Z' 13501' FISH - BKR CIBP MILLED @ 12296' g, PUSHED BTM (07/16107) ~I 4-1/2" LNR -SLOTTED, 12.2#, L-80, 12630-13514 I I ????? 16 SLIP PIECES & RET RING LOST FROM .0152 bpf, ID = 3.958" ~ ~ ~ MIS-SET CIBP (POSSIBLY IN GLMs) ~I 13503' CTMD MILLED CIBP -PUSHED DOWN FROM 12210' - 4/28/03 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13538' 13533' FISH - 13.1' SETTING TOOL ATTACHED TO CHOKE PKR DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNtT D8/03/92 ORIGINAL COMPLETION WELL: 15-18A D6/27108 NORDIC1 CTD SIDETRACK PERMIT No: 2080830 X7/14/08 JLJ/SV PULLED FISH (07/09/08) API No: 50-029-22274-01 SEC 22, T11 N, R14E, 76.05' FEL & 4158.64' FNI BP Exploration (Alaska! Digital Well File + Well: 15-18 Well History Well Date Summary 15-18A 6/26/2008 T/I/O =0/0/0 Set 4-1/16" CIW "H" BPV # END 404 with T-Bar from rig floor so Nordic 1 could move off weII..R.K.6=25.25...no problems 15-18A 6/26/2008 ****CONT JOB FROM 6-25-08 /ASSISTING NORIC #1 ***(rig support) RUN MULTIPLE TOOLS TO 3 1/2" BAKER KB LTP PACKER C~ 2144' SLM. RAN 3 1/2" CENTER SPEAR WOULD NOT LATCH KEEP SLIPPING OUT RAN 2.70" BLIND BOX, SD ~ 2144' SLM PACKER NEVER MOVED ***WELL TURNED OVER TO RIG*** 15-18A 6/28/2008 T/I/O =0/0/0 dulled 4-1/16" CIW "H" BPV # END 404 ~ 102" 1-2ext.used...post rig ...no problems 15-18A 7/3/2008 T/I/O=Vac/140/60. Temp=Sl. T FL (CTD). No A/L. TBG FL @ 510'. Depressed TBG FL with aas from 15- 49 from 510' to 3251'. Left 2080 psi on TBG. Final WHPs=2080/140/60. 15-18A 7/4/2008 ***WELL SI ON ARRIVAL*** INITIAL T/I/O = 1900/0/0. J3ECORD VIDEO OF TP FIRH t ODC n IN SSRV AT 9190' FINAL T/I/O = 1650/0/0. SWAB CLOSED, CASING VALVES OPEN TO GAUGES, SSV CLOSED WELL SI ON DEPARTURE. MASTER VALVE CLOSED PER DSO. ***JOB COMPLETE*** 15-18A 7/6/2008 ***WELL SHUT IN ON ARRIVAL*** RAN 3-1 /2" BLB, 2.25" SCALE BUCKET TO 2,130' SLM. RECOVERED 1 TBSP OF HYDRATES. ***WELL LEFT S/I ON DEPARTURE, TURNED OVER TO DSO*** 15-18A 7/7/2008 **** WELL SHUT IN **** (fish pkr) RETRIEVED - 1 CUP GREEN CEMENT/SCHMOO ON FISH C~3 2126' SLM 2.50" TAPERED LIB INDICATES SLIP CARRIER ID - 1.55 ID ~ 2126' SLM RAN 2.50" B.BELL, 3' STM, 1.90' SWAGE, B.NOSE, WORK RESTRICTION @ 2122' SLM 2.0" TAPERED LIB INDICATES WORKING SLIP CARRIER ID OUT ~ 2122' SLM CURRENTLY WORKING RESTRICTION W/ 2.50" B.BELL, 1.90" SWAGE ~ 2122' SLM ,JARRING DOWN ON KB LINER TOP PAC:KFR~ ***CONTINUED WSR ON 07-08-08*** 15-18A 7/8/2008 T/I/0=1300/125/0 Assist SLB with tubing load Pumped 10 bbls 60/40 meth followed by 22 bbls crude before TBG pressured up to 2950 psi. Pumped 8 bbls to pressure up Tubing for S/L to pull GLV. **Annulus casing valves open to gauges, S/L in control of well on departure** FWHP's= 1500/1100/0 15-18A 7/8/2008 ***CONTINUED WSR FROM 07-07-08*** (fish pkr) JAR DOWN ON FISH W/ 2.50" B.BELL, 1.90" SWAGE C~? 2121' SLM (-3HRS JARRING) TAG TRSSSV W/ 2.84" NO-GO @ 2107' SLM WORK FISH FREE W/ BAITED TAPERED B.BOX. PUSH DOWN HOLE RATTLE GLM'S W/ KJ,KJ, 2.31" G.RING, TAG FISH & 10.548' WLM. SET SSC/S ~ 6,857' WLM PULL 1.5" DGLV'S FROM STA#4 ~ 6788' MD & #5 ~ 3501' MD SET 1.5" (RK) LGLV (16/24" PORTS, 1500# TRO) IN STA#5 ~ 3501' MD CURRENTLY RIH W/ S/O FOR STA#4 ***CONTINUED WSR ON 07-09-08*** 15-18A 7/9/2008 ***CONTINUED WSR FROM 07-08-08*** (fish pkr / g/I for rate) SET 1.5" (RK) S/O (20/64" PORTS) IN STA#4 ~ 6788' MD PULL M/T SSCS ~ 6857' SLM PULL "35 HYD KB PACKER" FROM 10.608' SLM RAN KOT W/ LIB TO STA # 2, INCONCLUSIVE, COULD NOT SIT DOWN RAN 2.30 MAGNET THROUGH STA'S 2,3,4,& 5, NO SLIP RECOVERY RAN 2.50 LIB TO LINER TOP C~3 11,198' WLM (11,226' CTM), R TOP DRIFT LINER W/ 1.87" SWADGE, S.BAILER,S/D ~ 11,207' SLM (RUBBER, METAL) DRIFT LNR W/ 1.50" S.BAILER, WORK DEBRIS FROM 11,212' TO 11.744' SLM **** WELL LEFT SHUT IN, DSO NOTIFIED **** 15-18A 7/21/2008 ASRC unit #2, standby for CTU to complete pert job **Job in progress** 15-18A 7/22/2008 ASRC Test Unit #2, S/B for CTU, R/U, Divert well thru test sep, ***Job in progress*** 15-18A 7/23/2008 ASRC Test Unit #2, Continue to stabilize monitor well, adjust G/L rate, ***Job in progress*** 15-18A 7/24/2008 ASRC Test Unit #2, Continue to monitor stabilize well, ***Job in progress*** 15-18A 7/25/2008 ASRC Test Unit #2, stabilize, Start test, ***Job in progress*** 15-18A 7/26/2008 ASRC Test Unit #2, Complete 8 hour test, RDMO, ***Job complete*** Print Date: 7/28/2008 http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer. aspx Page 1 of 1 Page 1 of 1 7/28/2008 • • ri.~ M, I 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: June 26, 2008 Please find enclosed directional survey data for the following wells: K 04CPB1 K-04CPB2 K-04C G15B K 20CPB1 K 20C / 15-18A E/ 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: _C~~~ ,State of Alaska AOGCC DATE: ~oa„~,,~ '~h'~ Cc: State of Alaska, AOGCC r I~ ALAS1~iA OIL AHD GA,S COHSERQA7`IOH COrIIKISSIOI~T Mary Endacott CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-18A BP Exploration Alaska Inc. Permit No: 208-083 Surface Location: 618' FNL, 117' FWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 1057' FSL, 769' FEL, SEC. 08, T11N, R14E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel . Seamount, Jr. ~ Chair n DATED this ~ day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ~~ MAY 2 Q 2008 ALASII~IL AND GAS CONSERVATION COMMI~JN PERMIT TO DRILL ~ Alaska Qii & Gas Cons. Commission 20 AAC 25.005 ~ ~ Anchorage 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 1 c. Specify if well 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 15-18A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14200' TVD 8741'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028304 Pool FNL, 117 FWL, SEC. 22, T11N, R14E, UM 618 Top of Productive Horizon: 4416' FSL, 3948' FEL, SEC. 16, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 18, 2008 Total Depth: 1057' FSL, 769' FEL, SEC. 08,~T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-676034 y-5960865 Zone-ASP4 10. KB Elevation (Height above GL): 67' feet 15. Distance to Nearest Well Within Pool: 770' 16. Deviated Wells: Kickoff Depth: 11540 feet Maximum Hole An le: 92 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3260 Surface: 2391 1 Casin Pr ram: S ficatio n To - e in De th - Bo ftom Quanti of Cem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 2960' 11240' 8415'ss 14200' 8741'ss 73 cu ft Class'G' 19. PRESE NTWELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 13538' Total Depth TVD (ft): 8809' Plugs (measured): None Effective Depth MD (ft): 13538' Effective Depth TVD (ft): 8809' Junk (measured): 13501' Casing Length ize ement Volume - MD TVD Conductor /Structural 115' 20" 11 115' Surface 3869' 13-3/8" 2846 cu ft CS II 460 cu ft Class'G' 3904' 3501' Intermediate 10897 9-5/8" 3005 cu ft Class'G' 10932' 8311' Pr i n Liner 2009' 7" 572 cu ft Class 'G' 10603' - 12612' 8108' - 8838' Liner 1198' 4-1/2" Uncemented Slotted Liner 12340' - 13 38' 8827' - 8809' Perforation Depth MD (ft): 12177' - 13514' Perforation Depth TVD (ft): 8804' - 8809' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mary Endacott, 564-4388 Printed Name Mary dacott , Title CT Drilling Engineer Prepared By Name/Number: Si nature ~~ ~ Phone 564-4388 Date 5 ~ Q ~ Terrie Hubble, 564-4628 - Commission Use Onl Permit To Drill Number: D~'O~'',30 API Number: 50-029-22274-01-00 Permit Ap royal Date: `d.' See cover letter for other re uirements Conditions of Approval: r If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ~/J Samples Req'd: ^ es dNo Mud Log Req'd: ^ Yes dNo HZS Measures: Yes ^ No Directional Survey Req'd: dyes ^ No Other: ~~ O \ ~ ~ ~~ -~t-E~~ Date APPROVED BY T COMMIA STONER Form 10-40'I~ Revised 12%2005 ~ I Submit In Duplicate by CTD Sidetrack Summary BPXA Prudhoe Bay DS 15-18A CTD Sidetrack May 19, 2008 Pre-Rig Work: 1. MIT-IA 2. Bleed production flow lines and GL lines down to zero and blind flange. 3. PT MV, SV, WV. 4. Remove wellhouse, level pad. ~~~" ~~ Rig Sidetrack Operations: (Scheduled to begin on June 18, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Set 3-1/2" packer whipstock with top at 11540'. ~4 - 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Mill 2.75"" window through 3 z an PT IA (KOP above production packer). Drill build section with 2.70" x 3.0" bicenter bit, and land well. Drill lateral section to 14,200'. Run and cement a 2-3/8" L-80 liner string, abandoning perfs in parent wellbore. Make a cleanout run with mill and motor. Make a logging run with a SWS GR-CNL logging tool. Perforate well. Run liner top packer. Circulate well to KWF brine. FP well to 2000' with diesel. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well h« ~.~~ 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: 3.0" (bi-center bits used) Casing Program: fully cemented liner • 2-3/8", L-80 4.70# STL 11,240' - 14,200' • A minimum of 13 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and TD C«~ 14,200, with 40% excess in the open hole interval) • TOC planned at top of liner Existing casing/tubing Information 13-3/8", K-55/L-80 68#, Burst 3450, collapse 1950 psi 9-5/8", L-80, 47# Burst 6870, collapse 4750 7", L-80 26#, Burst 7240, collapse 5410 psi 3-1/2", 13-Cr 9.2#, Burst 10,160, collapse 10,530 psi 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 92 deg at 12,750'. • Magnetic and inclination surreys will be taken every 30 tt. No gyro will be run. • Distance to nearest property - 20,000 ft. • Distance to nearest well within pool - 770 ft. (15-33A @ 12,175') Logging • MW D directional, Gamma Ray will be run over all of the open hole section. • Cased hole MCNUGR/CCL will be run. ~n~~rv~`C' Hazards R"} ~~~gt c~~S~toh~ P~ h. C~~~~d-' • There is one close approach to existing well C-18A; it is usually shut in due to high GOR. sl~~~;~ • The maximum recorded H2S level on DS 15 was 40 ppm on well 15-20C. • Two fault crossings, risk of lost circulation low. Reservoir Pressure • The reservoir pressure on 15-18 is expected to be 3,260psi at 8,800' TVDSS. (7.15 ppg equivalent) • The greatest reservoir pressure on DS 15 is 3,653 psi at 8,800' TVDSS on well 15-11. (7.98 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,391 psi. M.S.Endacott CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE _ ' WELLHEAD = MCEVOY ACTUATOR = Otis KB. ELEV _ _ 67 BF. ELEV KOP = Max Angle = 93 @ 12724' Datum MD = NA Datum TV D = 8800' SS • 4-1/2" TBG, 12.6#, L-80 .0152 bpf, ID = 3.958" 13-3/8" CSG, 68#, K-55/ L-80, ID = 12.415" I 34' I I 3904' I TOP OF 7" LNR I-I 10602' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-I 10932' Minimum ID = 2.75" @ 11362' 3-1 /2" PARKER SWN NIPPLE S TES: OBSTRUCTION NOTED 11 /01197. 15 ~ ~ 8 POSS CHOKE PKR, LDL 3/12198 POSSIBLY PKR LEAK. CMT TOP IN IA @ 10500', CMT TOP INSIDE TBG POST MILLING @ 12205'. 3-12" CHROME TBG. 16 SLIP PIECES & RET RING FROM MIS-SET CIBP MAY BE IN GLMs. 34' 4-1 /2" X 3-1 /2" XO 2143' 3-112" CAMCO TRDP SSSV NIP (LOCKED OUT TRSV), ID = 2.81" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3500 3223 44 FMHO DOME RK 16 07/26/04 2 6788 5503 47 FMHO SO RK 20 07/26/04 3 8983 7016 46 FMHO DMY RK 0 4 10424 7992 49 FMHO DMY RK 0 02/06/04 5 10516 8052 49 FMHO DMY RK 0 10500' - j TOP OF CEMENT 11362' ~ 3-1/2" PARKER SWN NIP, ID = 2.75" 12340' I--i 7" X 3-1/2" TMJ SS HORIZONTAL PKR 13-1/2" TBG, 9.2#, 13-CR-80, .0087 bpf, ID = 2.992" I TOP OF4-1/2" LNR 12350' 1r 2340' ~ PERFORATION SUMMARY REF LOG: GR(CCL ON 08/10/92 ANGLE AT TOP PERF: 81 @ 12177' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12177 - 12191 O 10/09/99 2-1/8" 4 12428 - 12448 C 09/11/93 2-1/8" 4 12458 - 12478 C 09/11/93 2-1/8" 4 12512 - 12532 C 09/11/93 2-1/8" 4 12592 - 12612 C 09/11/93 2-1/8" SL 12630 - 13514 C 08/02/92 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12612' I 3-1/2" TM/ 6-UNIT OVERSHOT SEAL ASSY I 12369' I-I 4-1/2" PORTED JOINT (34.85') TOP OF 4-1/2" LNR -SLOTTED 12630' j I 13501' FISH - BKR CIBP MILLED @ 12296' & PUSHED BTM (07/16/07) I ~ ????? 16 SLIP PIECES & RET RING LOST FROM I I ~ MIS-SET CIBP (POSSIBLY IN GLMs) 4-1/2" LNR-SLOTTED, 12.2#, L-80, 13514' - I .0152 bpf, ID = 3.958" 13503' CTMD MILLED CIBP-PUSHED DOWN FROM 12210' - 4/28/03 13533' FISH - 13.1' SETTING TOOL 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13538' ATTACHED TO CHOKE PKR DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/03/92 ORIGINAL COMPLETION 07/26/04 SS/KAK GLV GO WELL: 15-18 01/23/04 JK/KAK GLV UPDATES/CORRECTIONS 05/29/06 DFR/DTM CSG CORRECTION (11/24/04) PERMfT No: 1920600 02/06/04 GJB/TLP GLV C/O 07/21/07 RWL/PJC SET CIBP & PUSH BTM (07/16/07 ) API No: 50-029-22274-00 02/06/04 GJB/TLP GLV C/O SEC 22, T11 N, R14E, 76.05' FEL & 4158.64' FNL 06/07/04 BJMcL/K WTHRFD CIBP IN XO 06/15/04 SRB/KAK PULUSET CIBP; FISH BP Exploration (Alaska) WELLHEAD= MCEVOY ACTUATOR = Otis KB. ELEV = 67' BF. ELEV = KOP = ? Max Angle = 93 @ 12724' Datum MD = NA Datum TV D = 8800' SS 1 ~ 15 -18 A SAFETY NOTES: OBSTRUCTION NOTED 11 /01 /97. POS~ CHOKE PKR, LDL 3/12/98 POSSIBLY PKR Proposed CTD Sidetrack LEAK' T TOP IN IA@ 10500', CMT TOP INSIDE TBG POST MILLING @ 12205'. 3-12" CHROME TBG. 16 SLIP PIECES & RET RING FROM MISSET CIBP 4-1/2" TBG, 12.6#, L-80 34' MAY BE IN GLMs. .0152 bpf, ID = 3.958" 34' 4-1/2" X 3-1/2" XO © 2143' 3-1/2" CAMCO TRDP SSSV NIP (LOCKED OUT TRSV), ID = 2.81" -55/ L-80, ID = 12.415" 3904' GAS LIFT MANDRELS TOP OF 7" LNR ~ 10602' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10932' Minimum ID =XXX" @XXX' TOP OF 2-318" Liner 11240' TOP OF 3 1/2"whipstock 11540' 3-1/2" TBG, 9.2#, 13-CR-80, .0087 bpf, ID = 2.992" ~ 12350' PERFORATION SUMMARY REF LOG: GR/CCL ON 08/10/92 ANGLEATTOPPERF:81 @ 12177' Note: Refer to PI'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12177 - 12191 O 10!09!99 2-1 /8" 4 12428 - 12448 C 09111 /93 2-1/8" 4 12458 - 12478 C 09/11/93 2-1/8" 4 12512 - 12532 C 09/11/93 2-1/8" 4 12592 - 12612 C 09/11/93 2-1/8" SL 12630-13514 C 08/02/92 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12612' I I I I 4-1/2" LNR- SLOTTED, 12.2#, L-80, 12630-13514 I I .0152 bpf, ID = 3.958" I ~ I I I ~I I I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-{ 13538' ST MD TVD DEV TYPE VLV LATCH PORT DA T' 1 3500 3223 44 FMHO DOME RK 16 07/26; 2 6788 5503 47 FMHO SO RK 20 ~7 26/04 3 8983 7016 46 FMHO DMY RK 0 4 10424 7992 49 FMHO DMY RK 0 07. 06x04 5 10516 8052 49 FMHO DMY RK 0 10500' ~~ TOP OF CEMENT 11230' ~1 BAKER KB LTP ID = 1.75" 11362' ~-~ 3-1/2" PARKER SWN NIP, ID =milled to 2.80" 2-3/8" L-80 LINER, Cemented & Pertorated 14200' 12340' 7" X 3-1/2" TM! SS HORIZONTAL PKR 12350' ~~ 3-1/2" TM/ 6-UNIT OVERSHOT SEAL ASSY 4-1/2" PORTED JOINT (34.85') 13501' FISH - BKR CIBP MILLED @ 12296' & PUSHED BTM (07/16/07) ????? 16 SLIP PIECES & RET RING LOST FROM MIS-SET CIBP (POSSIBLY IN GLMs) 13503' CTMD MILLED CIBP-PUSHED DOWN FROM 12210' - 4/28/03 13533' FISH - 13.1' SETTING TOOL ATTACHED TO CHOKE PKR DATE ~ 08/03/92 ~ ~ ORIGINAL COMPLETION 107/26/04 I SS/KAK ~ GLV GO ~ 01/23/04 JK/KAK GLV UPDATES/CORRECTIONS 05/29/06 DFR/DTM CSG CORRECTION (11/24/04) 02/06/04 GJB/TLP GLV GO 04/23/08 MSE PROPOSED CTD SIDETRACK 06/07/04 BJMcL/K WINKED CIBP IN XO 06/15/04 SRB/KAK PULL/SET CIBP; FISH PRUDHOE BAY UNIT WELL: 15-18A PERMIT No: API No: 50-029-22274-01 SEC 22, T11 N, R14E, 76.05' FEL & 4158.64' FNL BP Exploration (Alaska) bP • BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ ~ Company: BP Amoco Date:. 5/8/2008 Time: -- 08:28:11 Page: 1 i Field: Prudhoe Bay Co-ordinate(NE} References WeIL 15-18, True North , Site: PB DS 15 Vertical (TVD) Reference: 28 :18 7/5/1992 00:00 67.0 Well: 15-18 Section (VS) Reference: Well (O.OON,O.OOE,320.OOAzi) ~; Wellpath: Plan 6, 15-18A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay _-~-__-- - -_- - North Slope UNITED STATES I Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 i, Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 li Site: PB DS 15 --- --- ------ ---- --- TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837 .36 ft Latitude: 70 17 35.236 N '~, From: Map Easting: 676296 .98 ft Longitude: 148 34 21.213 W ~I Position Uncertainty: 0.00 ft North Reference: True ~, Ground Level: 0.00 ft Grid Convergence: 1.34 deg ~' Well: 15-18 Slot Name: 18 15-18 ~ Well Position: +N/-S 2033.93 ft Northing: 5960865 .55 ft Latitude: 70 17 55.240 N +E/-W -215.32 ft Easting : 676034 .04 ft Longitude: 148 34 27.490 W Position Uncertainty: 0.00 ft I Wellpath: Plan 6, 15-18A 500292227401 Drilled From: 15-18 Tie-on Depth: 11448.05 ft Current Datum: 28:18 7/5/1992 00:00 H eight 67 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/25/2008 Declination: 23.32 deg Field Strength: 57676 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ --- -- ft ft ft deg - --- --- ~ 36.00 - - 0.00 --- ---- 0.00 320.00 - ---- Plan: Plan #6 Date Composed: 4/25/2008 ', ~I copy Mary's plan 6 Version: 8 ~, Principal: Yes Tied-to: From: Definitive Path Targets - - Map Map <-- Latitude ---> <-- Longitude -> Name Descriptiod- TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir.:.: ft ft ft ft ft J 15-18A Polygon 67.00 5400.09 -4432.06 5966160.00 671477.00 70 18 48.337 N 148 36 36.782 W ~~ -Polygon 1 67.00 5400.09 -4432.06 5966160.00 671477.00 70 18 48.337 N 148 36 36.782 W -Polygon 2 67.00 5593.71 -4583.57 5966350.00 671321.00 70 18 50.240 N 148 36 41.206 W ~I -Polygon 3 ~ 67.00 6156.47 -5376.66 5966894.00 670515.00 70 18 55.770 N 148 37 4.354 W I -Polygon 4 67.00 6813.31 -5872.44 5967539.00 670004.00 70 19 2.226 N 148 37 18.834 W '' li -Polygon 5 67.00 7457.40 -6080.42 5968178.00 669781.00 70 19 8.559 N 148 37 24.917 W •. -Polygon 6 67.00 7324.64 -6476.67 5968036.00 669388.00 70 19 7.250 N 148 37 36.476 W -Polygon 7 67.00 6284.75 -6154.92 5967004.00 669734.00 70 18 57.025 N 148 37 27.063 W -Polygon 8 67.00 5982.05 -5787.88 5966710.00 670108.00 70 18 54.051 N 148 37 16.348 W -Polygon 9 67.00 5244.23 -4653.78 5965999.00 671259.00 70 18 46.803 N 148 36 43.248 W i 15-18A Fault 1 67.00 5479.31 -5123.43 5966222.99 670784.00 70 18 49.112 N 148 36 56.953 W -Polygon 1 67.00 5479.31 -5123.43 5966222.99 670784.00 70 18 49.112 N 148 36 56.953 W -Polygon 2 67.00 -636.75 -3843.26 5960138.99 672207.00 70 17 48.968 N 148 36 19.516 W '; 15-18A Fault 2 67.00 7348.81 -5800.87 5968075.99 670062.99 70 19 7.493 N 148 37 16.758 W ; -Polygon 1 67.00 7348.81 -5800.87 5968075.99 670062.99 70 19 7.493 N 148 37 16.758 W -Polygon 2 67.00 6511.49 -5628.43 5967242.99 670254.99 70 18 59.259 N 148 37 11.707 W ', -Polygon 3 67.00 5559.50 -5471.68 5966294.99 670433.99 70 18 49.898 N 148 37 7.114 W -Polygon 4 67.00 6511.49 -5628.43 5967242.99 670254.99 70 18 59.259 N 148 37 11.707 W i 15-18A Fault 3 67.00 7374.83 -6740.58 5968079.99 669122.99 70 19 7.741 N 148 37 44.179 W ~! -Polygon 1 67.00 7374.83 -6740.58 5968079.99 669122.99 70 19 7.741 N 148 37 44.179 W ' -Polygon 2 67.00 6602.47 -6565.62 5967311.99 669315.99 70 19 0.147 N 148 37 39.053 W -Polygon 3 67.00 6277.35 -6565.23 5966986.99 669323.99 70 18 56.949 N 148 37 39.034 W -Polygon 4 i 67.00 6602.47 -6565.62 5967311.99 669315.99 70 19 0.147 N 148 37 39.053 W ', 15-18A Fault 4 67.00 6277.35 -6565.23 5966986.99 669323.99 70 18 56.949 N 148 37 39.034 W ~!. bP ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ ~1 Company: ' BP Amoco Date: 5/8!2008 Time: 08:28:11 Page: 2 ~ Field: Prudhoe.Bay Co-ordinate(NE) Reference: "' Well: 15-18; True North ~ Site: PB DS'15 Vertical (1'VD) Reference:' 28 :18 7/5/1992 00:00 67.0 We[l: 15-T8 Section (VS) Reference: Well (Q.QON,O.OOE,320 .OQAzi) i Wellpath: ' Plan 6, 15-18A --- Survey Calculation Method: `' Minimum Curvature _ .. Db:, Oracle -- 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 -Polygon 1 67.00 6277.35 -6565.23 5966986.99 669323.99 70 18 56.949 N 148 37 39.034 W , -Polygon 2 67.00 6027.5 3 -6106.93 5966747.99 669787.99 70 18 54.496 N 148 37 25.657 W -Polygon 3 67.00 5587.68 -5906.16 5966312.99 669998.99 70 18 50.172 N 148 37 19.789 W -Polygon 4 67.00 6027.5 3 -6106.93 5966747.99 669787.99 70 18 54.496 N 148 37 25.657 W ', 15-18A Target 2 8807.00 6956.64 -6183.19 5967674.99 669689.99 70 19 3.633 N 148 37 27.904 W 1 15-18A Target 1 8832.00 5505.50 -4661.66 5966259.99 671245.00 70 18 49.372 N 148 36 43.482 W Annotation '~ - -- MD - TVD I ft ft 1 11448.05 8586.70 TIP 1 11540.00 8627.95 KOP '; 11560.00 8636.80 End of 9 Deg/100' DLS 1 11630.00 8675.56 4 1 11880.00 8813.05 5 ~ 11978.61 8831.49 6 12228.61 8829.55 End of 22 Deg/100' DL S ~ 12328.61 8827.95 8 , 12428.61 8826.02 9 12558.61 8822.58 10 ~ ~ 12758.61 8815.68 11 ~~ 12928.61 8810.71 12 13178.61 8807.75 13 13378.61 8807.48 14 13528.61 8807.30 15 13778.61 8807:01 16 14028.61 8807.88 17 14178.61 8808.22 18 14200.00 8808_15 TD _ _ ~~ Plan Section Informati on MD - Inc! > - Azim TVD +N/-S +E/-W DLS Build Tura ---- TFO Targef ~ ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ~--- _ _ - - 1, 11448.05 62.05 326.78 8586.70 5361.96 _ _ -4284.44 0.00 0.00 0.00 0.00 !, 11540.00 64.63 326.73 8627.95 5430.68 -4329.49 2.81 2.81 -0.05 359.00 111560.00 62.86 326.38 8636.80 5445.65 -4339.37 9.00 -8.86 -1.76 190.00 i ~I11630.00 49.87 316.38 8675.56 5491.23 -4375.30 22.00 -18.55 -14.29 210.00 ~~I ~ 11880.00 68.31 254.54 8813.05 5532.70 -4568.23 22.00 7.37 -24.73 270.00 111978.61 90.00 254.54 8831.49 5507.05 -4661.02 22.00 22.00 0.00 0.00 112228.61 90.82 309.54 8829.55 5557.21 -4896.23 22.00 0.33 22.00 89.00 '112328.61 91.01 321.54 8827.95 5628.44 -4966.14 12.00 0.19 12.00 89.00 112428.61 91.19 309.54 8826.02 5699.67 -5036.04 12.00 0.19 -12.00 271.00 ~! 12558.61 91.82 325.13 8822.58 5794.94 -5123.84 12.00 0.48 11.99 87.50 12758.61 1 92.07 301.12 8815.68 5930.58 -5268.66 12.00 0.12 -12.01 271.00 ~ 12928.61 91.25 280.73 8810.71 5990.93 -5426.55 12.00 -0.49 -12.00 268.00 13178.61 90.08 310.71 8807.75 6098.17 -5649.20 12.00 -0.47 11.99 92.00 ~ 13378.61 90.07 334.71 8807.48 6256.12 -5769.50 12.00 0.00 12.00 90.00 13528.61 90.07 316.71 8807.30 6379.54 -5853.67 12.00 0.00 -12.00 270.00 113778.61 90.06 346.71 8807.01 6597.16 -5970.81 12.00 0.00 12.00 90.00 14028.61 89.55 316.71 8807.88 6814.79 -6087.95 12.00 -0.20 -12.00 269.00 14178.61 90.19 334.70 8808.22 6938.20 -6172.13 12.00 0.43 11.99 88.00 14200.00 90.19 337.27 8808.15 6957.74 -6180.83 12.00 0.00 12.00 90.00 - - . by ~ BP Alaska Baker Hu hes INTEQ Plannin Report g g INTEQ ~i Company; BP Amoco Date: 518/2008 Time: 08:28:11 Page: 3 j Field: Prudhoe: Bay Co-ordinate(NE) Reference: We{I: T5-18, True North 'i Site: PB DS 15 Vertlcai (TVD) Reference: 28: 18 7/5/1992 00:00 67.0 Well: 15-18 Section (VS}Reference: Well (O.OON,O.OOE,320.OOAzi) Wellpathc Pla n 6, 15-18A Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~i MD Incl Azim SSTVD N/S: E!W MapN MapE DLS VS TFO Tool ~ ft 'deg `deg ft ft ft `ft 'ft degl100ft ft deg 1 08441 S 62.05 326.78 8519.70 5361.96 -4284.44 5966125.34 671625.45 0.00 6861.49 0.00 MWD 'I 11500.00 63.51 326.75 8543.46 5400.60 -4309.76 5966163.37 671599.24 2.81 6907.36 359.00 MWD I, 11540.00 64.63 326.73 8560.95 5430.68 -4329.49 5966192.98 671578.81 2.81 6943.08 359.01 MWD j 11560.00 62.86 326.38 8569.80 5445.65 -4339.37 5966207.71 671568.58 9.00 6960.90 190.00 MWD !I 11600.00 55.34 321.04 8590.34 5473.32 -4359.61 5966234.89 671547.70 22.00 6995.11 210.00 MWD I 11630.00 49.87 316.38 8608.56 5491.23 -4375.30 5966252.44 671531.60 22.00 7018.91 212.75 I MWD 'i 11700.00 51.59 296.57 8653.13 5523.06 -4418.55 5966283.24 671487.62 22.00 7071.10 270.00 MWD 11800.00 59.20 271.38 8710.50 5541.85 -4497.50 5966300.18 671408.26 22.00 7136.24 282.62 MWD ~ 11864.31 66.37 257.64 8740.00 5536.18 -4554.18 5966293.18 671351.73 22.00 7168.33 297.11 15-18AI ~I 11880.00 68.31 254.54 8746.05 5532.70 -4568.23 5966289.37 671337.76 22.00 7174.70 303.43 MWD 11900.00 72.71 254.54 8752.72 5527.68 -4586.39 5966283.93 671319.72 22.00 7182.53 0.00 MWD 11978.61 90.00 254.54 8764.49 5507.05 -4661.02 5966261.55 671245.61 22.00 7214.69 0.00 MWD 12000.00 90.08 259.25 8764.48 5502.20 -4681.84 5966256.22 671224.90 22.00 7224.36 89.00 MWD 12100.00 90.45 281.25 8764.01 5502.63 -4781.23 5966254.32 671125.54 22.00 7288.57 89.00 MWD 12200.00 90.75 303.24 8762.95 5540.25 -4873.21 5966289.77 671032.71 22.00 7376.52 89.11 MWD 12228.61 90.82 309.54 8762.55 5557.21 -4896.23 5966306.19 671009.30 22.00 7404.31 89.34 MWD 12300.00 90.96 318.11 8761.44 5606.59 -4947.68 5966354.35 670956.71 12.00 7475.21 89.00 MWD 12328.61 91.01 321.54 8760.95 5628.44 -4966.14 5966375.76 670937.75 12.00 7503.81 89.13 MWD 12400.00 91.15 312.97 8759.61 5680.81 -5014.54 5966426.98 670888.14 12.00 7575.04 271.00 MWD 12428.61 91.19 309.54 8759.02 5699.67 -5036.04 5966445.33 670866.20 12.00 7603.31 270.84 MWD 12500.00 91.55 318.10 8757.31 5749.04 -5087.48 5966493.48 670813.62 12.00 7674.19 87.50 MWD I~, 12558.61 91.82 325.13 8755.58 5794.94 -5123.84 5966538.50 670776.20 12.00 7732.72 87.71 MWD ~, i 12600.00 91.90 320.16 8754.23 5827.81 -5148.93 5966570.78 670750.35 12.00 7774.03 271.00 MWD ~!, 12700.00 92.04 308.16 8750.78 5897.31 -5220.50 5966638.57 670677.18 12.00 7873.27 270.84 MWD ', 12758.61 92.07 301.12 8748.68 5930.58 -5268.66 5966670.70 670628.25 12.00 7929.71 270.42 MWD ' 12800.00 91.89 296.15 8747.25 5950.39 -5304.95 5966689.66 670591.51 12.00 7968.22 268.00 MWD 12900.00 91.40 284.16 8744.37 5984.77 -5398.62 5966721.84 670497.07 12.00 8054.76 267.83 MWD i 12928.61 91.25 280.73 8743.71 5990.93 -5426.55 5966727.34 670469.00 12.00 8077.44 267.48 MWD ', 13000.00 90.93 289.29 8742.35 6009.40 -5495.42 5966744.19 670399.72 12.00 8135.85 92.00 MWD ', ~, 13100.00 90.46 301.28 8741.12 6052.03 -5585.67 5966784.69 670308.50 12.00 8226.52 92.16 MWD. ICI 13178.61 90.08 310.71 8740.75 6098.17 -5649.20 5966829.33 670243.91 12.00 8302.71 92.31 MWD 'I 13200.00 90.08 313.27 8740.72 6112.48 -5665.10 5966843.26 670227.69 12.00 8323.89 90.00 MWD i i ~ 13300.00 90.08 325.27 8740.58 6188.13 -5730.22 5966917.36 670160.81 12.00 8423.70 90.00 MWD ~ t 13378.61 90.07 334.71 8740.48 6256.12 -5769.50 5966984.41 670119.96 12.00 8501.03 90.02 MWD I ~ 13400.00 90.07 332.14 8740.45 6275.25 -5779.07 5967003.30 670109.94 12.00 8521.83 270.00 MWD I 13500.00 90.07 320.14 8740.33 6358.14 -5834.68 5967084.86 670052.40 12.00 8621.08 270.00 MWD 13528.61 90.07 316.71 8740.30 6379.54 -5853.67 5967105.81 670032.93 12.00 8649.67 269.98 MWD 13600.00 90.07 325.27 8740.21 6434.96 -5898.56 5967160.16 669986.75 12.00 8720.98 90.00 MWD 13700.00 90.06 337.27 8740.10 6522.49 -5946.54 5967246.54 669936.74 12.00 8818.88 90.01 MWD 13778.61 90.06 346.71 8740.01 6597.16 -5970.81 5967320.62 669910.72 12.00 8891.68 90.02 MWD 13800.00 90.01 344.14 8740.00 6617.86 -5976.20 5967341.18 669904.85 12.00 8911.00 269.00 MWD 13900.00 89.81 332.14 8740.15 6710.50 -6013.36 5967432.92 669865.53 12.00 9005.86 269.00 MWD 14000.00 89.61 320.14 8740.67 6793.39 -6068.97 5967514.48 669808.00 12.00 9105.10 269.02 MWD 14028.61 89.55 316.71 8740.88 6814.79 -6087.95 5967535.43 669788.52 12.00 9133.69 269.08 MWD 14100.00 89.85 325.27 8741.25 6870.21 -6132.85 5967589.78 669742.34 12.00 9205.01 88.00 MWD I ~ 14178.61 90.19 334.70 8741.22 6938.20 -6172.13 5967656.83 669701.49 12.00 9282.34 87.96 MWD 14200.00 90.19 337.27 8741.15 6957.74 -6180.83 5967676.15 669692.33 12.00 9302.90 90.00 MWD j BP Al k ~/.i LEGEND - ,5-,eh~,e) n'~ ~r° ~~ , I a ' ~> ro ~ as a Plan 8, , S, 8A Plan e6 ^"° T BAKiR ~ K n°°° t3 a1EaaPaTYaETr.a M,~ by sa °~ ~~ °,,au nla,., e~r2~Tw, NTEQ n~,°,~t ~e',ai~i~r°`;ae~s'° _ N.a° .. T,.aa„a. rc,e ala: a.t. mwar: :.. ,. ns~t»z oo:aa ai.oat r.a.aeaa ox': °~9 Ft.nl~a aaa. ram , 32a.ea• a.ea e.ae ~.~ _ REFERENCE NFORMAi ON ~ :. ,•, I I . .T. ~.. ~~~ Coar^na~ 1 { W ce 5 e. true Nonn ~ ~ 7 ... ~ Tr i4 ~ ~ r { I - + t * ~ -~ - y~® 1~ II g `` S E'a 5 i ~- I f 15-18A Fault 3 ~ -' - r I, ~ .. ~ i "1' * ~ ,_ _ '~l °,ra are n> on MEa c wal.o Mrmm t 15.18A Fault 2 ~' f 1 } ~ T 1 - ~t .ona.rtr. r I 1 ~ ~ ~ 1 I W r trrr d _ n r aar u _ rr ~ ~ I f - - 'iLL 11- C an r 1 BA Ta all ~ ~ ~ ~ - { I . v u r~ ~ ~~ ~n rr i iiu~r ~ ar r a oraaa ~ rr nu aim. » " r I ~ i _ ~ \ ,r r ~ ~ a _ -. _ , _ ~ i '. ~ _ i iii r i i Saar aaa u aaaaar i :~ ~ a'rr ~ a~m.asi a'r°r°« °.. u ,..,.. rar I ' J - - f ,. r~ r 19 .. 17 ~ ~ ~ r t { - f 1 L _ _ _ _r ~ . ~., 1. a tsrsr nu t~ anam rar sear mr Naar nrrur nor aorta nrr anar racer .r.a....r e...r... ..r ~.,. a.. :~ arm I I - r ~ { -+ " 11 I t { - ~ t ' ~ - - - _ 1 . :,:a°a..^ nr~yta"`.an". o.°.an. '~° ~ :u ~ ~, aar armor n n°i'r v ° t0 ! 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I ~- I ~ ~ ~'r ~ ~ i J ~ ~ 1 O 15 1e 1T 1e Plan6 51eA _{ ~ t F I 1 t 11 12 13 i / / e - _._ } - ~ t __ aaoo i . _ :j r ~ {. \ ~_-_ i -._' , _t -i. ~ ~ '~ ... ; : tste tst ~ ~ ~ ~. _ J f I ~ - ' I ~ ~ ~ l.. --_ ~ i l ^ ~ ~ e te 161eA Tar at 2 . 16tH Tar at 1 Ena M 22 0. /aee' al ' ~ . .~.. _ _ ~ 1~_ 1 - . L _, I 1 _ - i ~ { t ~ I I ~ t i ~- ~'` ` , - t F ~I I ~ ~ t - + I + T . . ° T I 1 •_ I ~ l ~ `~ _ , . J 1 _ `T , I. , { iI i _ _ {? r i t }+_~ ~ .. _~ .. } :~. _. _~. _ - -_ ---- r1 rr `` ' ~. r r f $ I r _ IL I - 11 - : ( l - ~+ ~ .:. + ~ 1 . f ~ . ; ~ ~11 T t f ~ :: ~ ~? # ~~1 1 I . I....-~ a . ~ ~ ~Z _.. ~f~h ~ ~~ I ~ ~t t t _ t? f ~ J ~~ , . -'-I- ~ 7- _ ~ Ir 1 ~ - I 4 . i +i _ ~ ~t , L Y ~ t ~ .. ._ _ ... r I .. ' r - 1 T .. i ~ ~' a,W ~ ~ ~ a~ ~ ~m ~ a~ ,~ „m ,~ „~a ,.W „W sn„ -~ ,,~~ s .:. ,,., r ,; „~ Vertical Section at 320.00' [t OOttlinJ , ,. ,. y,r, way a,~.n ~W s,an ~ s • Rig Floor to Top of Well DS 15-258 2.25 9.23 •_ 5.00 f 71/16" 5000 psi, RX-46 Bl~nc St-aar; 12.65 •~~ T~,- -• 1~ 2" YComr..i~; ~1 ~ 7 1116" X 3 1r6" Flanged Adapter Swab Valve SSV Master Valve ~a~ 2s.sa Lock Down Screws 31.00 ~ Ground Level Alaska Department of Natural Resources Land Administration System Page 1 of~ ~. • rrf~r`,i~.9kd fv~l~~,l~c~ ~;;Lt ~~..r~rc ~St~t,~~ 1~1~',ts 1,Lcorct~r'sSearch SfateCabins (~~lEi"~~~~DUP€~S ~~ ~4laska DNR Case Summary File Type A~~_ _ File Number: 28304 ... ~ Printable Case File Summary See Township, Range, Section and Acreage? C Yes ~ No ~. New Search I l_.AS Menu ]Case Abstract ]Case Detail ]Land Abstract File: ADL 2530-I '''`'=' Search for Status Plat Updates 1s ~,I~O~, ] %~OUS Custome~~ 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Ccase Type: 7s4. OIL & GAS LEASE COMP DNR Uf~7it: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 3 5 ISSUED Starts Date: 09/ 14/ 1965 Total Acres: 2469.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~!~ NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED ~1fei~~dian: 1~ Township: 011N Runge: 014E Sectiorr.~ 0~ Sec~inn _lcres: 640 Search Plats ;1leri~li~u~: ~_' %utivnship: O11N Runge: OI-~i. S'eclrr~n.~ U6 Secltun ~Ic~~~e~~: 593 llericli~nt: l_~ ~ntivnship. O1 IN Ran,~re.~ 011 ~: Sc~c~i~ut.~ 117 S~c~ctir~rr :~u~es: `~)6 lleridrun: i lnivrzsl2ip: OIlN Runge: 014E Section: f)~ Sec~tiorl.Icres: 640 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION'S Cl~1-125 IIN 1,~E UMS,6,~ 7, 8 2=169.00 U- 3- 7 Et"td cif Case SilltT#tlar~/ Last updated on 05/2112008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28304&... 5/21 /2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~L/ /~ ',D PTD# o~O~O~~D Development; Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~,P6/Dh/OE ~Ay POOL: /~.e!//,JL~OE ~,4Y Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any pxotest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of welt) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ,~Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 111 l/2008 WELL PERMIT C HECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT 15.18A Program DEV Well bore seg PTD#:2080830 Co mpany BP EXPLORATIO~ALASKA~ INC Initial ClasslType DEV I P END GeoArea 890 Unh 11650 OnlOff Shore On Annular Disposal Administration 1 Permitfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - ----------------- - - - KA- - - - - - 2 l.easenumberappropriate-- -- - -- - - -- - -- - - -- -Yes-- -- - - -- - -- -- -- -- - -- -- - - - - --- -- -- 3 Unique well_name aAd numbe[ - - - - - - - - - - - - - Yes - - - - -- - - - -- - - - - - - - - - - - - - - - - - 4 WelUocatedin-a-definedp941 ------ -- - --- - -- --- --- Yes-- -- - - - - - - -- -- - ---- - - - -- - -- -- 5 WelUocatedproperdistanoeftomdrillingunit_boundary------------------ -- --Yes------- ---------------- - -- - --- -- -- - - - -- -- - 6 Welliocated proper distanoefrorn oiherwells- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage ayailat)le in drilling unit- - - - - - - - - - - - - - Yes - - - - 2560 Aores•- - - - - - - - - - - - - - - - - - - - - - 8 If deviated, is_ wellbore plat-included - - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Ope[atoronlyaffeeiedDa~ty- ------ -- --- -- - -- -- --- - Yes-- -- - - --- -- - -- - -- --- - -- -- --- - -- - --- -- 10 Qperatorhas-appropriasebopdinforoe___----------------------- -----Y~------- @IankekBond#6194193•--_---------------------- - - - - - -- -- 11 Pe[mitcahbeissuedwithQUiGOnservationorder----------------------- -----Yes------- ----------------- --- -- -- - - - -- -- -- - -- - -- - --- - Appr Date 12 Permitcahbeissuedwithoutadministrasive-approval------------------- -----Yes------- -------------------- -- -- - -- --- -- - -- -- - -- -- - - --- -- -- 13 Canparmitbt;apRrovedbBf9rE15•daY-wait---- -- - - - - -- -- Yes------ -- -- -- -- -- -- -- --- -- -- -- -- -- - --- - -- --- ACS 5121/2008 14 Well located within area and trataauthorized by_Ihjeotian Ordet# (put1O# in_comments)_(FVr- NA_ _ _ _ _ _ _ _ ---- _ _ _ . - _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ - - - - - - - - - - - - - - - - - - 15 AA wellswfthin114mileareaofrevtew>dehts8ed(Forsenncewellonly)__________ _____ NA_____- -- - - --_.--------------- - ~- ----- -- -- - -- -- -~ 16 P-re-pr9duced injector, durati~ of pre-production less than 3 months(For-service wel( Qnly) - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 NonCOnven,gas_canformstoAS31,05U30Q.1.A).(1.2.A-D) - -- - - --- ---KA--- -- - -- - - - -- -- - - -- -------- -- ------------- Engineering 18 Cohductorstring-t?rov_ided----------------------- -- -- -- - -- -- -~A------- C4nduciorset_inDS15-18(192-960.------------------------------- - --- -- - 19 Surface_casin3pr4teetsallknownUSDWS------------------- ----- ------ NA-------- No&qujfers,A1O4Q,_conclusions,----------------------- ------ - -- - - -- 20 CMT-voladequate-tocirculake anconduct9[&surf-csg__________________ ______ NA__-___ SurfaceGasingsatin15r18,--_-____.___-_-__------------------------ -- -- - 21 CMT_voladequate_t9tie-in longstrir~gtosurfosg____---_-.--------- --- -- NA- - -_ Production_casingset in_15,18._--____.___------------------- -- -- - -- -- 22 CMT willooyera)IknownlaroductivebQrizons. -- - - -- ----- -- -- --Yes-- - - - -- -- - ----- -- ----- -- -- - -- - -- -- ----- -- 23 Casing des9ns adequat#B for C, T, B &.pe[rna#[ost - - - - - - - - - Yes - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - R~9 equipped with steel pits, No reserve pii Plarlned._ All waste.tp approved disposal weU(s), - - - - - - - - - - - - - 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - 25 atOr40$for abandonmentgeenapprQVed---------------- Ifare-drill has -----Yes------- 308-165------------------------- -- ----- -- - - - -- -- -- -- 26 , _ Adequate welikore separatonproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - _ _ _ _ _ P(oximity analyis performed. -Nearestsegment is P&A_portign of_15,18and paths_diverge._ - - _ _ _ _ _ _ _ . _ _ _ 27 Ifd)verterrequired,doesitmeetregulations__-_-____--------------- ------ iJA_____-_ BQPStack_wilial[eddy-inplar~,---------------------------------- -- -- -- -- Appr Data 28 Drilling flu)d-program schematic_& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Maximum expected formation pressure 7,2_EMW.. Planned MW 6.6_ppg. _ _ . _ _ - _ _ _ _ _ _ - - _ _ _ _ _ _ _ - TEM 512112008 29 BOPEs~dotheymeetre9ulation- -- -- -- -- - - - -- -- -Yes-- -- - - - - -- -- - - -- ---- - --- ----- -~ - -- -- ~~ (~ Q~(~ 30 BQPE-press rating appropriate; test to-(put prig incomments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ MASP calculated_af 2391 psi, 3500_psi.DOP testplanned, _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ - - _ - - - - - - _ - - - - ~ ~ji 31 :Oh9ke-manifold complies w/API-RP-53 (May 84)_ - - . _ _ _ _ . _ _ _ - _ _ - - - - - - - - - - - Y~ - - - - - - - - 32 Work willgccurwiihoutoperationshutdo_w.n_________________------ --.-_-Yes------- Yes -------------- - -- -- -- -- -- ---- --- - -- - - -- H2S is present in lift gas. -Up_to 40 ppm in reservoir. -Rig equipped wish sensors and alarms. _ - _ _ _ _ _ _ _ _ _ _ 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ _ _ _ _ 34 Mechanical condition of wells within A9R verified (FOr service we0 only - - - - - - - - ' - - - - - - - NA- - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 Permit- rah be sssued wlo hydrogen suftide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - No- - - - - _ - Max H2$ level on DS 15 was 40ppm on well-15-20C._ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - - - - - . - - - - - - - - - - - - - - 36 Data_presentedonposentiat9verpressurezones________----------- - ----Yes------ ----------------------- - - -- -- -- ----- -- -- - - -- -- Apps Date 37 Seismie analysis of shallow gaszohes - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 512112008 38 Seabedconditiohsunrey_(ifoff-shore)________________._-_-___-__ _.___ NA ---- --- - - - - - - - ------- - - - - - --- - 39 Contact namelphoneforweekly-prQg_ress repo~fs [exploratory or>fy] _ _ _ - - _ _ - - - - - - _ _ _ Yes _ - - _ _ _ Mary Endacots -564.4388- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering P lic i D a e Dats: Co mis Date Commissionee Commissioner: ~f ~ ~ / ~ • • 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 08/09/09 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/06/22 2026713 O1 2.375" CTK *** LIS COMMENT RECORD *** ~!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10891.00.00: Starting Depth STOP.FT 14187.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 15-18A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 55.240"N 148 deg 34' 27.490"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 22 Jun 2008 API API NUMBER: 500292227401 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 67 DMF DF EKB .F 0 EDF .F 67 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. C~ • (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 has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 24 Jun 2008 per Doug Stoner with BP Exploration (Alaska), Inc. (8) Tied to 15-18 at 11355 feet MD (8474.9 feet TVDSS). (9) The sidetrack was drilled from 15-18 through a milled window in a 7 inch and 3 1/2 inch liner. Top of window 11426 ft.MD (8509.6 ft.TVDSS) Bottom of window 11431 ft.MD (8511.7 ft.TVDSS) (10) INTEQ runs 1 and 2 occured while setting the previous whipstock and an unsuccessful milling attempt. (11) The interval from 14153 feet to 14187 feet MD (8751.3 feet to 8754.9 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD~ (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT .DATA BASELINE, MEASURED, DISPLACEMENT 10905.3, 10902.8, ! -2.4873 10908, 10905.9, ! -2.07227 10909.9, 10908.8, ! -1.03613 10911.9, 10911.1, ! -0.829102 10916.1, 10914.2, ! -1.86523 10921.7, 10919.8, ! -1.86523 10924, 10922.5, ! -1.45117 10929.6, 10926.6, ! -2.90234 10932.2, 10929.6, ! -2.69434 10936, 10932.9, ! -3.10938 10938, 10935.6, ! -2.4873 10941.6, 10938.3, ! -3.31641 10944.1, 10942, ! -2.07324 10947.2, 10947.6, ! 0.414062 10954, 10953.4, ! -0.62207 10956.3, 10956.7, ! 0.414062 10961.7, 10961.9, ! 0.207031 10965.8, 10969.8, ! -1.03613 10968.3, 10967.5, ! -0.829102 10974.1, 10973.1, ! -1.03613 10976.7, 10976.1, ! -0.62207 10980.6, 10979, ! -1.6582 10981.7, 10980.2, ! -1.45117 10987.9, 10985.8, ! -2.07324 10994.3, 10993.1, ! -1.24414 10999.1, 10997, ! -2.07324 11429.1, 11427, ! -2.07227 11431.4, 11428.9, ! -2.4873 11433.1, 11430.6, ! -2.48828 11445.7, 11444.2, ! -1.45117 11451.3, 11449.6, ! -1.6582 11455.6, 11453.4, ! -2.28027 11461.2, 11459, ! -2.28027 11466, 11463.7, ! -2.28027 11469.3, 11467, ! -2.28027 11476, 11473.1, 11478.4, 11476.6, 11482.5, 11480.5, 11489.2, 11485.2, 11492.3, 11490, 11495.6, 11493.1, 11523.6, 11521.1, 11530, 11527.9, 11532.7, 11530.6, 11563.9, 11562.7, 11572.8, 11570.6, 11586.5, 11584.5, 11594, 11591.5, 11601.2, 11599.4, 11604.4, 11602.5, 11615.6, 11613.5, 11622.4, 11619.1, 11626.2, 11623.9, 11629.5, 11626.6, 11650, 11647.1, 11661.7, 11659.2, 11665.2, 11661.9, 11668.7, 11665.4, 11673.7, 11670.8, 11684.9, 11683, 11690, 11686.3, 11694.4, 11691.5, 11721.4, 11719, 11738.9, 11735.5, 11743.8, 11742.6, 11746.9, 11744.5, 11751.7, 11749.4, 11762.3, 11760.2, 11770.4, 11767.3, 11779.8, 11775.8, 11782.9, 11780.4, 11789.1, 11784.8, 11794.7, 11792.4, 11800.1, 11797.6, 11804.5, 11802.6, 11810.7, 11807.4, 11819, 11816.1, 11824.4, 11819.2, 11826, 11820.8, 11834.1, 11832.1, 11837.5, 11836.6, 11848, 11844.7, 11851.6, 11848.4, 11854.9, 11850.3, 11869.2, 11863.8, 11876.8, 11873.1, 11880.8, 11877.7, 11885.1, 11880.6, 11888.2, 11884.7, 11890.9, 11887.2, 11896.6, 11893.3, 11898.4, 11896.4, 11904, 11900.5, 11906.7, 11903.2, 11909.4, 11905.5, 11913.6, 11909.4, 11917.5, 11914.6, 11920.2, 11916.9, 11937, 11936.2, 11939.9, 11938, 11944, 11942.2, 11946.3, 11944.2, -2.90234 -1.86523 -2.07324 -3.93848 -2.28027 -2.4873 -2.4873 -2.07324 -2.07227 -1.24414 -2.28027 -2.07324 -2.4873 -1.86523 -1.86523 -2.07324 -3.31738 -2.28027 -2.90234 -2.90137 -2.48828 -3.31641 -3.31641 -2.90137 -1.86523 -3.73145 -2.90137 -2.4873 -3.31641 -1.24414 -2.48828 -2.28027 -2.07324 -3.10938 -3.93848 -2.4873 -4.35254 -2.28027 -2.4873 -1.86523 -3.31738 -2.90137 -5.18262 -5.18262 -2.07324 -0.829102 -3.31641 -3.10938 -4.56055 -5.38965 -3.73145 -3.10938 -4.56055 -3.52441 -3.73145 -3.31641 -2.07324 -3.52441 -3.52344 -3.93848 -4.14551 -2.90234 -3.31641 -0.829102 -1.86621 -1.86621 -2.07324 C~ 11948.6, 11947.1, 11954.6, 11951.9, 11959, 11956.3, 11962.1, 11958.5, 11971.8, 11969.7, 11978.7, 11979.2, 11981.2, 11980.8, 12000.1, 11998.4, 12032.1, 12032.1, 12035.2, 12035, 12043.3, 12039.8, 12071.1, 12068, 12078.1, 12075.4, 12085, 12082.1, 12088.7, 12085.6, 12094.9, 12091.4, 12110.5, 12108.2, 12155.6, 12153, 12162.3, 12162.5, 12165.6, 12164.8, 12171.2, 12168.1, 12174.1, 12172.4, 12178.2, 12176.2, 12183.2, 12179.9, 12192.1, 12191, 12194.3, 12192.1, 12206, 12205.5, 12208.9, 12207.2, 12212.6, 12211.3, 12215.7, 12212.8, 12218, 12215.1, 12221.3, 12219.8, 12225.2, 12223.2, 12231.5, 12230.6, 12234.1, 12234.1, 12237.9, 12237.7, 12242, 12241, 12246, 12245.1, 12249.7, 12247.6, 12252.8, 12252.2, 12256.4, 12255.2, 12261.4, 12258.3, 12264.9, 12264.1, 12275.9, 12275.3, 12279.2, 12278.4, 12281.1, 12280.9, 12285.6, 12283.4, 12291.7, 12290.6, 12294.8, 12293.1, 12302.2, 12297.5, 12303.7, 12298.9, 12310.1, 12309.3, 12317.2, 12316.8, 12397.4, 12394.3, 12417.3, 12414.2, 12423.5, 12421.2, 12425.8, 12424.4, 12434.9, 12431.6, 12446.8, 12442.3, 12465.7, 12461.6, 12468.6, 12464.5, 12483.1, 12479, 12519, 12514.6, 12530, 12524.8, 12542.8, 12538.9, 12582.8, 12578.9, 12608.5, 12604.4, -1.45117 -2.69531 -2.69434 -3.52441 -2.07227 0.414062 -0.414062 -1.6582 0 -0.208008 -3.52344 -3.10938 -2.69434 -2.90234 -3.10938 -3.52441 -2.28027 -2.69434 0.207031 -0.829102 -3.10938 -1.6582 -2.07324 -3.31641 -1.03613 -2.28027 -0.414062 -1.6582 -1.24414 -2.90234 -2.90234 -1.4502 -2.07324 -0.829102 0 -0.207031 -1.03711 -0.829102 -2.07324 -0.62207 -1.24414 -3.10938 -0.829102 -0.621094 -0.829102 -0.207031 -2.28027 -1.03613 -1.6582 -4.76758 -4.76855 -0.829102 -0.415039 -3.10938 -3.10938 -2.28027 -1.4502 -3.31641 -4.56055 -4.14551 -4.14648 -4.14648 -4.35254 -5.18262 -3.93945 -3.93848 -4.14648 12630.3, 12624.5, 12632.4, 12627, 12635.5, 12630.9, 12642.2, 12640.7, 12646.5, 12645.9, 12650.7, 12650.9, 12656.9, 12654.8, 12662.1, 12660.8, 12664.4, 12663.3, 12684, 12683.2, 12687.2, 12686.1, 12700, 12698.1, 12702.1, 12700.2, 12719.1, 12718.4, 12722, 12722.2, 12732.5, 12730.7, 12734.2, 12731.5, 12746.8, 12744.8, 12751.1, 12748.4, 12759.8, 12758, 12765.2, 12761.7, 12772.5, 12766.5, 12773.3, 12767.1, 12779.1, 12774.8, 12782.2, 12778.5, 12787.4, 12783.7, 12790.5, 12786.4, 12795.5, 12789.7, 12796.7, 12790.9, 12798.4, 12794.2, 12800.3, 12796.7, 12802.7, 12799.6, 12929.9, 12925.6, 13113.8, 13112.6, 13119.4, 13118.2, 13123.6, 13121.7, 13128.1, 13126.5, 13133.5, 13130.2, 13188, 13184.9, 13191.1, 13188.2, 13202.8, 13200.9, 13217.1, 13215, 13484.1, 13479.8, 13491.6, 13487.9, 13494.1, 13490.4, 13497.2, 13494.3, 13505.3, 13499.1, 13507.1, 13501.6, 13508.8, 13503.4, 13512.1, 13506.5, 13513, 13507.4, 13518.1, 13512.1, 13523.5, 13516.1, 13527.9, 13520, 13531.4, 13525.2, 13533.9, 13526.6, 13535.1, 13528.3, 13538.4, 13532.9, 13540.5, 13534.3, 13541.8, 13536.2, 13542.8, 13537.4, 13545.9, 13540.1, 13547.2, 13541.6, 13549.6, 13543.6, 13552.5, 13546.3, 13561.9, 13554.4, 13933.1, 13927.9, ! -5.80371 ! -5.38965 ! -4.56055 ! -1.4502 ! -0.62207 ! 0.207031 ! -2.07324 ! -1.24414 ! -1.03711 ! -0.829102 ! -1.03613 ! -1.86621 ! -1.86621 ! -0.621094 ! 0.207031 ! -1.86523 ! -2.69434 ! -2.07324 ! -2.69434 ! -1.86621 ! -3.52441 ! -6.01172 ! -6.21875 ! -4.35352 ! -3.73145 ! -3.73145 ! -4.14551 ! -5.80469 ! -5.80371 ! -4.14648 ! -3.52441 ! -3.10938 ! -4.35254 ! -1.24414 ! -1.24414 ! -1.86523 ! -1.6582 ! -3.31641 ! -3.10938 ! -2.90234 ! -1.86523 ! -2.07324 ! -4.35352 ! -3.73145 ! -3.73145 ! -2.90234 ! -6.21973 ! -5.59668 ! -5.38965 ! -5.59766 ! -5.59766 ! -6.01079 ! -7.46191 ! -7.87695 ! -6.21875 ! -7.25586 ! -6.84082 ! -5.59668 ! -6.21875 ! -5.59668 ! -5.38965 ! -5.80469 ! -5.59668 ! -6.01172 ! -6.21875 ! -7.46289 ! -5.18262 C~ 13940.7, 13935.3, ! -5.38965 13964.1, 13959, ! -5.18262 13969.1, 13962.3, ! -6.84082 14095.1, 14093.4, ! -1.6582 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 311 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 15-18A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 15-18A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!~!!!!~!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 24 Jun 2008 per Doug Stoner with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F • ONE DEPTH PER FRAME Tape depth ID: F 2 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 8 Total Data Records: 79 Tape File Start Depth = 10891.000000 Tape File End Depth = 14187.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 88 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 LJ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 15-18A.xtf LCC 150 CN BP Exploration (Alaska) WN 15-18A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 157 1 Size Length 4 4 4 4 8 Tape File Start Depth = 10891.000000 Tape File End Depth = 14187.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 166 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/06/22 2026713 O1 **** REEL TRAILER **** MWD 08/09/09 BHI O1 • Tape Subfile: 4 2 records... r: i Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 10891.0000 43.1000 -999.2500 10891.5000 41.9000 -999.2500 10900.0000 50.7000 -999.2500 11000.0000 -999.2500 -999.2500 11100.0000 -999.2500 -999.2500 11200.0000 -999.2500 -999.2500 11300.0000 -999.2500 -999.2500 11400.0000 -999.2500 -999.2500 11500.0000 21.8000 14.2000 11600.0000 66.2931 31.1602 11700.0000 29.4542 33.8784 11800.0000 88.8465 77.6606 11900.0000 70.4439 97.3754 12000.0000 82.2907 97.2495 12100.0000 92.4059 101.8144 12200.0000 76.0483 107.3352 12300.0000 71.1641 61.7691 12400.0000 44.0802 67.3003 12500.0000 112.6581 29.9176 12600.0000 110.8472 93.3390 12700.0000 81.8838 102.2990 12800.0000 60.8460 78.0440 12900.0000 30.1391 88.4114 13000.0000 34.5194 93.1224 13100.0000 35.9090 152.8638 13200.0000 43.4200 181.5040 13300.0000 33.7318 165.1600 13400.0000 31.7274 157.4360 13500.0000 97.2976 240.8900 13600.0000 34.2888 140.8831 13700.0000 33.3042 105.9969 13800.0000 35.5826 156.1845 13900.0000 58.8140 72.9276 14000.0000 40.8010 108.7689 14100.0000 72.1344 165.7203 14187.0000 -999.2500 -999.2500 Tape File Start Depth = 10891.000000 Tape File End Depth = 14187.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 10891.0000 -999.2500 -999.2500 10891.2500 41.8000 -999.2500 10900.0000 45.5000 -999.2500 11000.0000 41.3000 -999.2500 11100.0000 -999.2500 -999.2500 11200.0000 -999.2500 -999.2500 11300.0000 -999.2500 -999.2500 11400.0000 -999.2500 -999.2500 11500.0000 19.7000 16.5000 11600.0000 32.3000 26.5000 11700.0000 28.9000 33.5000 11800.0000 34.8000 78.0000 11900.0000 59.9000 1920.0000 12000.0000 91.9000 98.7000 12100.0000 85.0000 104.5000 12200.0000 67.6000 108.7000 12300.0000 118.3000 72.9000 12400.0000 41.5000 73.6000 12500.0000 113.5000 58.9000 12600.0000 95.5000 95.3000 12700.0000 92.3000 94.5000 12800.0000 69.7000 47.9000 12900.0000 27.0000 89.0000 13000.0000 36.8000 99.6000 13100.0000 33.0000 122.4000 13200.0000 33.8000 164.3000 13300.0000 35.1000 160.5000 13400.0000 31.6000 165.1000 13500.0000 44.5000 164.1000 13600.0000 31.1000 141.2000 13700.0000 31.6000 113.8000 13800.0000 36.4000 133.0000 13900.0000 43.3000 100.0000 14000.0000 40.8000 136.9000 14100.0000 71.4000 150.0000 14187.0000 -999.2500 304.8000 Tape File Start Depth = 10891.000000 Tape File End Depth = 14187.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LIS
