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201-090
New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, August 09, 20112:01 PM To: 'Lastufka, Joseph N (Wipro)' Cc: McMains, Stephen E (DOA) Subject: DS 18-04B (PTD 201-09�nd DS 9-44 (PTD 190-126) Joe, We received "Suspended well inspection" forms 10-404s for DS 18-04B and DS 0944 recently. These wells are actually P & A `d already (we received the 407s too) and can't be classified as suspended. The sidetracks that were started and then operationally shut down with sundries are all the paperwork that is needed. Once the sidetrack is started (window cut) the motherbore is officially P & A'd. Please call me with any questions.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) AUG 15 2011- fB/y 11:7- j i 00ZC) P u -OL( C LUCti CL 6k)eC� 1 ��Ck" brl 67/10 111 ao C0OT 6�L'7f►�illil STATE OF ALASKA ALASKA C.._ AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ^kim Other v REPORT OF 0F4` 1. 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ ❑ Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ waiver[] Time Extension ❑ INSPECTIO Change Approved Program ❑ Operat. Shutdown[:] Perforate ❑ Re-enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: S. Permit to Drill Number: Name: Development ❑r Exploratory ❑ Stratigraphic❑ Service ❑ „ 201-0900 3. Address: P.O. Box 196612 5. API Number: Anchorage, AK 99519-6612 " 50-029-20875-02-00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO-028307 PBU 18-04B 4b--C)1AC N, 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL OL 11. Present Well Condition Summary: yd Total Depth measured 10607 feet N Plugs (measured) 9575 feet true vertical 9002.08 feet Q1 Junk (measured) None feet Effective Depth measured 9980 feet / Packer (measured) 8541 9551 9685 feet true vertical 8410.51 feet (true vertical) 7208 8066 8173 feet Casing Length Size MD `\ TVD Burst Collapse Structural V Conductor 80' 20" 91.5# H-40 107 �'( 27 - 107 1490 470 Surface 2603' 13-3/8" 72# L-80 - 2629 26 - 2593 4930 2670 1:b Production 8709' 9-5/8" 47# L-80 ,(\ 5 - 87t4V 25 - 7385 6870 4760 Liner 1341' 7" 26# L-80 / r ,/\ 8541 - 9882 7208 - 8331 7240 5410 Liner 909' 4-1/2" 12.6# L -8d, 968 10594 8173 8990 8430 7500 Liner \/ Perforation depth: Measured depth: SEE True Vertical depth: — — — Tubing: (size, grade, measured and true vertical d th) 4-1/2" 12.6# 13Cr80 24-9608 24-8111 Packers and SSSV (type, measured and true v nical depth) 7" Baker ZXP Packer 8541 7208 4-1/2" Baker S-3 Perm Packer 9551 8066 4-1/2" Baker ZXP Packer 968a5r� 8173 pppp������'cc "T "�VE d ' 12. Stimulation or cement squeeze summary: JULZOl1 v U Intervals treated (measured): Treatment descriptions including volumes used and final pressure: fila4a GN �& GAA C01'4. r$i-diillSStU11 a�D 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ .. SUSP❑� SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: i 6 20�-2�'�a-� NA Contact Joe Lastufka `; Pa r1 AUG a � 6+ M� B I4 Jl - Printed Name Joe Lastufka Title Petrotechnical Data Technologist Signature Phone 564-4091 Date 7/28/2011 Form 10-404 Revised 10/2010 RSDMS JUL 2 9 2011 RSDMS JUL 2 9 2011 L,. 9 b , f (- y_� Submit Original Only ,7 w Ph 1Nlp 18 -04B 201 -090 PERF ATTACHMENT . Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18 -04B 8/14/01 PER 10,465.3 10,485.3 8,869.73 8,888.36 18 -04B 8/15/01 PER 10,426. 10,456. 8,833.24 8,861.09 18 -04B 9/23/01 FIL 10,479. 10,485.3 8,882.49 8,888.36 18 -04B 9/25/01 APF 10,410. 10,450. 8,818.37 8,855.52 18 -04B 9/25/01 FIL 10,471. 10,479. 8,875.04 8,882.49 18 -04B 10/3/01 FIL 10,455. 10,471. 8,860.16 8,875.04 18 -04B 1/22/02 APF 10,383. 10,410. 8,792.96 8,818.37 18 -04B 4/2/11 BPS 9,575. 10,675. 8,084.72 9,065.68 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED 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 • • . Prudhoe Bay Unit Well 18 -04B / 18 -04C, PTD 2010900 / 2110020 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU 18 -04B / 18 -04C on 7/10/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Bob Noble witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 1 /4 mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • Sidetrack operations in PBU 18 -04C (PTD 2110020) were temporarily shutdown after encountering drilling problems. The Operations Shutdown was approved 3/30/11 (Sundry 311 -069). • Since the sidetrack PBU 18 -04C has not been completed, parent well 18 -04B is still considered suspended with a date of 02/23/11. r . - • PBU 18 -04B / 18 -004C is l ocated on a pad with active producing wells and/or S service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. s r re • The well is secured with a tubing tail plug. • The well is mechanically sound as proven by a pressure test to 2500 #. AWO 7/13/2011 Suspended Weite Inspection Form • Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 18 -04B / 18 -04C Field /Pool: PRUDHOE BAY Permit # (PTD): 2010900 / 2110020 API Number: 500292087502 / 500292087503 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 2/23/2011 Surface Location: Section: 24 Twsp: 11N Range: 14E Nearest active pad or road: Prudhoe Bay Drillsite #18 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Welibore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Dry Location cleanup needed: No Pits condition: Clean gravel Surrounding area condition: Clean Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: No Access road condition: Good Photographs taken (# and description): 2: front of wellhouse, back of wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: McEvoy wellhead, Grey master valve, McEvoy tree. No flowline. Cellar description, condition, fluids: Clean gravel Rat Hole: No Wellhouse or protective barriers: no barriers Well identification sign: Tubing Pressure (or casing if no tubing): No scaffolding Annulus pressures: IA: 0 psi OA: 0 psi Wellhead Photos taken (# and description): 2: wellhead, tree Work Required: Remove integral on IA, intall well information sign outside of wellhouse Operator Rep (name and signature): AOGCC Inspector: Bob Noble Other Observers: Michael Clingingsmith Inspection Date: 7/10/2011 AOGCC Notice Date: Time of arrival: 1:00 AM Time of Departure: 1:35 AM Site access method: Truck TREE _ McEVOY • 18-04C WELLHEAD = McEVOY SAFETY N WELL ANGLE> 70 @ 10120' * ** ACTUATOR = AXELSON SUSPENDED 4-1/2" CH E TBG*** KB. ELEV 45.1' BF. ELEV = 19.21' KOP= 2100' Max Angle = 75° © 10187' 1 2185' H4 -1/2" CAMCO BAL-0 SSSVN, ID = 3.813" I Datum MD = 11113' u Datum TVD = 8800' SS 120" CONDUCTOR 1-1 120' GAS LIFT MANDRELS 113-3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" I-1 2629' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 Minimum ID = 3.80" @ 9595' ( Li 1 2 8112 6830 31 MMGM DMY RK 0 04/06/02 4 -1/2" MILLED OTIS XN NIP 1 9514 8116 38 KBG -2 DMY BK 0 04/06/02 8541' H9-5/8" X 7" BKR ZXP PKR/TIEBACK, ID = 6.313" I 8555' H 9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.313" I (TOPOFWHIPSTOCK H 8741' I 19 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" ^8734 9 -5/8" MILLOUT WINDOW (18 -04B) 8718' - 8734' PERFORATION SUMMARY 1 ( 9541' H4 -1/2" OTIS X NIP, ID = 3.813" I REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 @ 10383' Note: Refer to Production DB for historical perf data Z 9551' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10383 - 10410 C 01/22/02 3 -3/8" 6 10410 - 10450 C 09/25/01 ' I 9575' H4 -1/2" OTIS X NIP, ID = 3.813" I 2 -7/8" 4 10426 -10456 C 08/14/01 2 -/78" 4 10465 - 10485 C 08/14/01 95 75' 4 -1/2 " PX PLUG (04/02/11 ) 1 1 9595' H4 -1/2" OTIS XN NIP, MILL TO 3.80" (02/05/11) I i _ I 9608' H4-1/2" WLEG, ID = 3.958" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM ACE, --I 9606' 1 .0152 bpf, ID = 3.958" ( 9685' 7" X 4 -1/2" BKR ZXP PKR w/ 7.40' TIEBACK & HMC LNR HGR, ID = 4.39" $7" LNR, 26"/L-80 BTC, .0383 bpf, ID = 6.276" H 9882' 3.80" MILLOUT WINDOW (18 -04C) 9983' - 9990' 114 -1/2" PKR WHIPSTOCK (02/22/11) H 9980' 14-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" '--I -9990' 1 ....., ••• .•••4 ........ 14 -1/2" OPEN HOLE H 10675' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 ORIGINAL COMPLETION WELL: 18 -04B 05/18/98 N4/3 ES RWO PERMIT No: / t010900 07/17/01 N7ES SIDETRACK (18 -04B) API No: 50- 029 - 20875 -02 03/02/11 NORDIC 1 CTD SUSPENDED (18 -04C) SEC 24, T11 N, R14E, 1067' FNL & 191' FEL 03/08/11 PJC CSG/ TBG CORRECTIONS 04/01/11 MR/PJC SUSPENDED FINAL 04/04/11 WEC/PJC SET PX PLUG (04/02/11) BP Exploration (Alaska) 1 -18 ' �. • y26, 2010 Approximate Scale: 1" =300' 2010- 19c -5 -21 AznO- METRIC ,' 9 T i t , 1 t IIIP 1 e i , 4 01,40- . ; ' p w:- A J ,.;✓ fr' r• / f / 1 k �j " % �� • Enter /Exit // / ( � e / / / / \\ / / 911' \ 234' ''.(/ \\ n i b \ \ \ \ �\ \ 244'. it 9 I ■ 18 I I 7 + I 1 I 23 • 6 • I I I • 16 27 • • 26 00 5 • 1 N. 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'' + t J t i .. • 4 , Y • I ' ., • • — • « . • r-L- .. q . ,,, .... • . . , • ° j . t f r ' Ps r r 1'. t �< s r r C I F M1 r ' t I • • , ° r a ' 2 , ` # I :y ». y r ( t , r , If 1 ,- , ', , ' e J t f , a r ' I • x *{ e9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CO p1 Lo` eunG\ 4IeA Suspended Well Inspection Report 7 M 11-�oZ � I� 5 IG o Date Inspected: 07/10/11 Inspector: Bob Noble Type of Inspection: Well Name: —2BW@-848- FgU 18-OLyI C PTD No.: 4910900— 7 (I —oD 2, Location Verified? Yes If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 02/23/11 Sundry No.: Well Completion Rpt Well Pressures (psi): Tubing N/A IA 430 OA 0 of nq Surface Up Actions Photo (1) fuLLr� S i`� i� 0* -W e fi`Me �Y2Qo'rt • RSL Operator: gp j_ `,,((I)),, -/'� Oper. Rep: Mike Clingingsmith `v I V �) �C Oper. Phone: 659-5766 Oper. Email: L4 11 Dale AOGCC Notified: 07/09/11 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Photos Taken? Yes is of spills. k?Wcd' 'W T)Fi 1 Er L��l" `�.(SCclM'YILT cook -d +0 Supry BY: PLB 08/2010 2011-0710 Suspend_PBU 18-04B—bn.als C Suspended Well Inspection - PBU 18-04XC PTD 4*e960 211 -M Z Photo by AOGCC Inspector B. Noble P4 A dVl 212-3111, W Iyop,-L" iS I13 -d C . PBU-I�Suspended Well Inspection 7-10-11 bn O-Oq c- . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 2QAAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: V 12. Permit to Drill Number. BP Exploration (Alaska) Inc. 2/23/2011 201 - 090 311 - 003 3. Address: 6_ Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 07/02/2001 50 029 - 20875 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number. Surface: 07/13/2001 PBU 18-04B 1067' FNL, 191' FEL, SEC. 24, T11 N, R14E, UM 8. KB (ft above MSL): 45.1' 15. Field / Pool(s): Top of Productive Horizon: 3809' FNL, 3662' FEL, SEC. 24, T11 N, R14E, UM GI (ft above MSL): 16.1' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth ( MD+TVD): Oil Pool 3733' FNL, 3715 FEL, SEC. 24, T11 N, R14E, UM 9980' 8411' 4b_ Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x- 691572 y - 5960796 Zone- ASP4 10607' 9002' ADL 028307 TPI: x- 688172 y- 5957968 Zone- ASP4 11. SSSV Depth ( MD+TVD): 17. Land Use Permit: Total Depth: x- 688117 y- 5958043 Zone- ASP4 N/A 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): 18. Directional Survey: ❑ Yes El No N/A ft MSL 1900' (Approx.) (Submit electronic and printed information per 20 AAC 25.050) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/ TVD: MWD / GR /RES /PWD 8718' 7370' 23. CASING, LINER AND CEMENTING RECORD SErnNG DEPTH Ao SErrwG DE ru No Has AMOUNT CASING Wr. PER Fr. GRADE To Borrow Toe Banal SIZE CEP ENrING RECORD POLLED 20' 91.5# H-40 Surface 80' - • 80' 30" 1850 # Poleset 13 -3/8" 72# L-80 Surface 2629' §u - • . 2593' 17 -1/2" 2240 sx Fondu. 400 sx Permafrost 'C' a; 47# ; -I ter-P: ; 71; - �_ 7 71 1 _ - 1/4" "fPr DIFTTI3C :/ r1�=IMIC T 26# L-80 8541' 9882' 7208' 8331' 8-12" 287 sx Class 'G' 4-12' 12.6# L-80 9685' 10594' 8173' 899(Y 6-1/8" 250 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open - (MD+1VD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD / TVD) 4-12", 12.6#, 13Cr80 9608' 9551' / 8066' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. �_Y f' �,` DEPTH INTERVAL (MDD AMOUNT AND KIND OF MATERIAL USED �1 9980' Set Whipstock RECEIVE6 MAR3 2011 27. PRODUCTION TEST � �d & 43as L�lil>i. GOIO'111SSIl Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Pro lion N/A .tf Cflo . e Date of Test Hours Tested: Production For Oi -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RA Test Period Flow Tubing Casing Press: Calculated On..-BBL: GAS -MCF: WATER -BBL: OIL GRAVITY API (CORR): Press- 24-Hour Rate 28_ CORE DATA Conventional Core(s) Acquired? ❑ Yes No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS APR 0 Zen A/ - Form 10-407 Revised 12/2009 CONTINUED ON REVERSE A) I I . /3./1 ,00400,. � /ub it Original Only 29_ • GEOLOGIC MARKERS (List all formations and markers encountered): 39 FORMATION TESTS NAME MD ND Wel Tested? ® Yes ® No Permafrost Top If yes, Kist intervals and formations tested, briefly siummuizilig test Permafrost Base results_ Altadr separate sheets to this rm fo, 4 needed, and submit detailed test information per 20 AAC 25.071_ Sag River 9836" 8293 None Shubfic 9876' 8326' Saderodh9 9947" 833 84 Zone 3 10106° 8521' Zone 2 10180' 8597 Zone 1B 10400' 8809' Zone lA 10447' 8853' Base of Saderoodhit 10487' 889(7 Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Dring Reports, Well Schema is Diagram 32_ I hereby certify that the - is true and correct to the best of my knowledge. hl� • Signed: Terris Hubble The: Drug Tectertatigitt Date: 03/3.0// PBU 18 201 - 090 311 -003 PleParedByNametlrvmber_ Temie Hubble, 564 -4628 Well Number Permk No ! A p p r o v a l No W►9 = w ' Ross, 564 -5782 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska Submnk a well schematic diagran with each 10-407 well completion report aid 10-404 well sundry report when the downhale well design is changed_ Item 1a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas I jection, Sat Water Disposal, Water Supply for Injection. Observation, or Other. Multiple completion is defned as a well producing from more than one pool with production from each pool completely segregated_ Each segregated pool is a completion. Item 4b: WI (Top of Producing Interval)_ Item 8: The Kerr 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 attadmenrts_ Item 13: The API number reported to AOGCC most be 14 digits (ex 50-029- 20123 - 0000)_ Item 20: Report true vertical thickness of permafrost in Box 20_ Provide 113 and TVD for the top and base of permafrost in Box 29 Item 23: Attached supplemental records for this well should show the details of any =Aide stage cementing and the location of the cementing tool_ item 24: If this well is completed for separate production from more than one interval (mn6ple completion), so state in t em 1, and in bon 23 show the producing intervals for only the interval reported in tern 26_ (Srirnk a separate form for each additional iderval to be separately produced, showing the data pertnent to such interval)_ Item 27: Method of Operation: Flowing, Gas LAY Rod Pimp, Hydraric Pump, Sutbrnerstfe, Water Injection, Gas Injection, Shut -In, or Other (explain)_ Item 28: Provide a fisting of intervals cored and the corresponding formations, and a brief description in this boa Sabra/ detailed desaiption and analytical laboratory nformation requited by 20 AAC 25_071_ Item 30: Provide a fisting of intervals tested and the corresponding formation, and a brief summary in this box Submit detailed test and analytical laboratory information requited by 20 AAC 25.071_ Form 10-407 Revised 122009 Submit Oricjnal Only 18 -04B, Well History (Pre Rig Sidetrack) Date Summary 1/30/2011 WELL SHUT IN ON ARRIVAL. DRIFT TBG W/ 20' x 3.70" DMY WHIPSTOCK, DIFFICULTY RIH AND STOP @ 1823' SLM. TAG XN NIPPLE W/ 3.80" GAUGE RING @ 9573' SLM / 9595' MD. 1/31/2011 ATTEMPT TO DRIFT W/ 20' x 3.70" WHIPSTOCK, UNABLE TO PASS 9160' SLM. DRIFT & TAG BTM W/ 10' x 3.70" WHIPSTOCK AT 10,441' SLM. DID NOT S /D. ATTEMPT TO DRIFT W/ BAKER DMY WHPSTK (19.67' x 3.70), UNABLE TO PASS 8753' SLM. 2/1/2011 BRUSH & FLUSH DOWN TO 10,150' SLM W/ BLB AND 3.625" GAUGE RING. ATTEMPT TO DRIFT W/ 19.67' x 3.70" BKR DRIFT & UNABLE TO PASS 8978' SLM. WELL TURNED OVER TO DSO. 2/4/2011 Job Scope: Mill out XN nipple to 3.80" with LH BHA. MIRU CTU. N/U BOPE. M/U 3.80" LH Baker Milling BHA. RIH to 7000'. 2/5/2011 Job Scope: Mill out XN nipple to 3.80" and drift well for whipstock. Continue RIH with LH milling BHA to XN nipple at 9595'. Tag XN. Pick up and ease down and mill out XN nipple. Ream XN up /down 4 times. Run thru XN clean with no pump. RIH to 10200' with milliing BHA. POH clean to surface. M/U Baker 20' x 3.63" dmy whipstock drift with two 3.70" gauge rings, RIH to 10200'. did not see any restrications. Pooh. Freeze protect tbg w/ 38 bbls 60/40 meth. Job Complete. 2/7/2011 T /I /0= 280/0/0 Bled tree to 0 psi. Torqued studs to specs excluding THA x Master. Pressure tested down on Swab Low /300 psi. High /3500 psi. Pass. Page 1 of 1 North America - ALASKA - BP Page 1 eta Operation Summary Report Common Well Name: 18 -04 — AFE No Event Type: RE- ENTER- ONSHORE (RON) j Start Date: 2/14/2011 End Date: 3/2/2011 1X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay I Site: PB DS 18 Rig Name /No.: NORDIC 1 , Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA ; UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/14/2011 00:00 - 00:30 0.50 MOB P PRE PJSM TO PUMP 50 BBLS FRESH WATER,15 BBLS INHIBITED WATER, 10 BBLS 60/40 METHANOL THROUGH REEL AND BLOW DOWN REEL WITH N2. 00:30 - 02:30 2.00 MOB P 1 PRE PUMP 50 BBLS FRESH WATER, 15 BBLS INHIBITED WATER, 10 BBLS 60/40 METHANOL THROUGH REEL. 02:30 - 04:00 1.50 MOB P PRE BLOW DOWN REEL WITH N2 TO TIGER TANK. 04:00 - 04:10 0.17 MOB P i PRE POP INJECTOR OFF WELL AND STAND BACK. �__ -- _,_ SUCK OUT TREE. 04:10 - 04:30 0.33 MOB P PRE PREP COIL FOR REEL SWAP. T 04:30 - 07:00 2.50 MOB P PRE CHANGE OUT BRASS AND PACKOFF. 07:00 - 08:00 1.00 MOB P J PRE (PULL BACK COIL AND SECURE TO REEL. h- 08:00 - 21:20 13.33 MOB N WAIT PRE PHASE 3 CONDITIONS, HALT OPERATIONS. -- 21:20 - 00:00 2.67 MOB N WAIT r PRE PHASE 2 LEVEL 3' ON ALL ROADS AND PADS. CALLED IMT AT 659 -5648 AND THIER I, COMANDER SAID NO ONE COULD GO BACK TO WORK. 2/15/2011 00:00 04:50 4.83 MOB I N WAIT PRE PHASE 2 LEVEL 3 ON ALL ROADS AND PADS. CALLED IMT AT 659 -5648 AND THIER ICOMANDER SAID NO ONE COULD GO BACK 04:50 MOB P PRE TO WORK. - — — 2/16/2011 00:00 - 02:00 2.00 MOB P PRE I ND BOP'S. NU TREE CAP. 02:00 - 03 :00 1.00 MOB P PRE 1 PT TREE CAP, NO VISIBLE LEAKS. I TEST BLEEDS OFF 200 PSI IN 15 MINUTES. 1 FAILED. CALLED GREASE CREW TO GREASE SWAB VALVE. 03:00 - 03:15 0.25 _ MOB P PRE 1 KICK WHILE TRIPPING DRILL. I 1 1 03:15 - 03:45 0.50 MOB P PRE I PT TREE CAP, NO VISIBLE LEAKS. 1 TEST BLEEDS OFF 200 PSI IN 15 MINUTES. — - I STILL FAILED. 03:45 - MOB P PRE STOP TEST TO GREASE SWAB VALVE. 2/17/2011 100 00 - 01:30 1.50 BOPSUR P PRE BOPE TEST. HYDRAULIC CHOKE FAILED. INSTANTLY I BLED OFF PRESSURE. 1 I 01'30 02:00 0.50 BOPSUR P I ', PRE PJSM TO CHANGE OUT GOOSE NECK _ _ ROLLERS AND ADJUST FOR 2 -3/8" COIL. 02:00 CHANGED OUT GOOSE NECK ROLLERS AND 03:30 1.50 BOPSUR P ADJUSTED FOR 2 -3/8" COIL. PRE I REBUILD HYDRAULIC CHOKE. C/O STEM AND 1 ' SEAT. 03:30 - 05:00 1.50 BOPSUR P PRE TEST HYDRAULIC CHOKE. PERFORM SEAT TEST. BLED OFF 200 PSI IN 5 MINUTES DURING A ' 3500 PSI TEST. 05:00 - 11:30 6.50 RIGU P 1 l PRE �I PULL CT ACROSS AND STAB. FILL CT. PERFORM SLACK MANAGEMENT (PUMPING 1 SLACK BACK INTO NEW REEL). CUT 10' CT, REBOOT ELINE. REHEAD. PULL TEST TO 1 35K LB, PRESSURE TEST TO 3500 PSI. 1 Printed 3/30/2011 11:12:48AM North America - ALASKA - BP Page 2 Operation Summary... Report,.. Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 2/14/2011 End Date: 3/2/2011 X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 1 Spud Date/Time: 12/25/1982 12:00:00AM I Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date ' From - To Hrs 1 Task Code I NPT ' NPT Depth Phase ' Description of Operations (hr) 1 (ft) i 11:30 - 12:00 0.50 1 1 BOPSUB � P I I PRE PT INNER REEL VALVE TO 250 PSI / 3750 PSI AND CHART TESTS AS PART OF BOPE TEST. 1 12:00 - 18:00 6.00 I RIGU P i PRE ! MU BAKER UQC. TEST CHECKS TO 250 PSI / 1500 PSI AND CHART - GOOD. 'SIMULTANEOUSLY, RESEAL PUMP #2. 18:00 - 19:00 1.00 BOPSUB P PRE I TEST PACKOFF. ' CALIBRATE BARTON CHART RECORDER. TEST PACKOFF TO 300 PSI AND 3500 PSI. CHART TEST. 119:00 - 19:15 0.25 RIGU P 1 I PRE I PJSM FOR PUMPING SLACK FOWARD. 19:15 20.30 1.25 RIGU P PRE I SPOT 55 BBLS METHONAL AT EOP. 1 , PUMP SLACK FOWARD AT 2.5 TO 3 BPM. PUMP 60 BBLS TOTAL. 20:30 - 21:15 0.75 BOPSUB N SFAL I PRE RESTRICTION ON HYDRAULIC CHOKE. 1 PJSM. PULL APART CHOKE. PLUNGER ON STEM PULLED OFF. I REPLACE STEM AND PLUNGER. 1 21:15 - 22:00 0.75 BOPSUB N SFAL PRE I PJSM, PERFOM BODY TEST ON HYDRAULIC ; CHOKE TO 250 PSI AND 3500 PSI . CHARTED. PERFORM [INSTANTLY. ERFO SEAT TEST. BLED OFF P I FAILED TEST. 122:00 - 00:00 2.00 BOPSUB N SFAL PRE WORK ON HYDRAULIC CHOKE. 2/18/2011 I 00:00 - 01 :30 1.50 BOPSUB N SFAL PRE REPAIR HYDRAULIC CHOKE. PJSM, TEST HYDRAULIC CHOKE BODY TO 1 I 1 250 PSI AND 3500 PSI, CHARTED, GOOD 1 TEST. 1 SEAT PERFORM CHOKE SEA TEST TO 2500 PSI, O I BLED OFF 100PSI IN 5 MINUTES, CHARTED 01:30 - 02:00 0.50 BOPSUR P PRE PJSM WITH NORDIC,SLB AND VALVE CREW. REVIEW LIFTING AND INSPECTION CERTS. REVIEW BOP SCHEMATIC, REVIEW UPDATED AND APPROVED PROCEEDURES FOR I PULLING BPV. 1 SETTING TREE TEST PLUG AND PRESSURE I TESTING TTP AND TREE FLANGE. 02:00 - 02:20 0.33 BOPSUR P PRE H2S RIG EVACUATION DRILL, MUSTER TO SAFE AREA AT SATTELITE OFFICE. GOOD RESPONSE BY ALL. ALL THIRD PARTY CONTRACTORS RESPONDED WELL. SIMOPS WERE BEING CONDUCTED, ALL WERE NOTIFIED AT THE TIME OF THE DRILL. _ IAFTERACTION REVIEW WAS HELD. 02:20 - 03:30 , 1.17 I BOPSUR P PRE R/U LUBRICATOR, 03:30 - 05:00 1.50 I BOPSUR P PRE I SET PUMP 1 TRIP LIMIT TO 1500 PSI, PRESSURE TEST LUBRICATOR AGAINST i CLOSED MASTER VALVE TO 250 PSI AND 1 3500 PSI, CHARTED FOR 5 MIN. OPEN MASTER VALVE AND PUMP AT .4 BPM, UP TO 250 PSI STABILIZED. OBSERVED NO LEAKS AT WELLHEAD. PUMP 1 BBL TOTAL, VERIFY 250 PSI UNDER I BPV. INSTALL FUSEABLE CAP ON SSV. BLEED OFF 250 PSI WHP THROUGH CHOKE. PULL BPV. UD BPV. M/U TREE TEST PLUG. TEST LUBRICATOR I I AGAINST MASTER VALVE TO 250 PSI AND 1 3500 PSI. CHART TEST. Printed 3/30/2011 11:12:48AM North America - ALASKA BP Page 3 a` " Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 2/14/2011 End Date: 3/2/2011 X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations 1 (ft) ) 05:00 09:00 4.00 i BOPSUR P PRE SET TTP. TEST TREE AGAINST TTP TO 250 1 I PSI LOW / 3500 PSI HIGH. BOTH PASSED. NOTE: TTP DOES NOT HOLD PRESSURE FROM BELOW - WHP OF 250 PSI IS NOT ISOLATED BY TTP. ;CLOSE MASTER, BLEED DOWN LUBRICATOR I(GAS) FROM 250 PSI TO ZERO, CLOSE SSV. - IUNSTAB, MU PULLING TOOL W/ 2 SHEAR IPINS,STABON. TEST LUBRICATOR AGAINST MASTER VALVE AND OPEN TO WELL. LAND PULLING TOOL AND ATTEMPT TO PULL PLUG PULLING TOOL CAME BACK SHEARED (DID NOT GET PLUG). CALL TOWN TO DISCUSS. 1 MASTER AND SSV ARE CLOSED, VALVE SHOP LUBRICATOR IS RIGGED UP. 109:00 - 20:30 11.50 BOPSUR N WAIT 1 PRE I WAIT ON ORDERS FROM TOWN REGARDING PLAN FORWARD FOR PULLING TTP. REVIEW SITUATION WITH CREW AND 1 DISCUSS CONTINGENCIES. i t — — �- — -- -— - - -- 20 :30 - 21:00 0.50 BOPSUR N SEAL PRE 1 PJSM TO RIG DOWN MOVE OFF 18 -04C AND PULL OUT OF THE WAY FOR SLICK LINE TO _ a FISH THE TREE TEST PLUG OUT OF THE 1TUBING HANGER. 21:00 - 00:00 3.00 BOPSUR N SFAL PRE SET INJECTOR ON ITS LEGS FOR RIG MOVE. I CALLED GREASE CREW TO GREASE SWAB VALVE AND MASTER VALVE. I OFF LOADED XS 2 %KCL WITH 0.6 %CFS -520 ONTO VAC TRUCK AND SENT BOTH FULL VAC TRUCKS TO PAD 3 FOR DISPOSAL. CALLED THE SERVICE COIL BULL PEN AND NO ONE IN SERVICE COIL COULD USE IT IN THE NEXT WEEK. THE MUD PLANT ONLY HAD ROOM FOR THE TWO FULL TRUCKS OF N-VIS SENT BACK TONIGHT. I TALKED WITH NORDIC TOURPUSHER AND SLB SUPERVISOR ABOUT MOVING THE RIG WITH THE COIL FULL OF FLUID. OFF LOADED THE FRESH WATER AND SENT IT FOR DISPOSAL. DID NOT TAKE ON DIESEL TODAY, TO LIGHTENING THE LOAD. 2/19/2011 00:00 - 01:30 1.50 BOPSUR N SFAL PRE TEST SV AND SSV WITH NEAT METHANOL TO 250 LOW AND 3500 PSI HIGH FOR 5 MINUTES I EACH. CHARTED AND SIGNED BY DRILLER PLACED AND WSL, 101:30 - 02:00 0.50 BOPSUR N SFAL PRE PUMP ALL FLUID OUT OF BOPE STACK. 102:00 04:15 2.25 BOPSUR N SFAL 1 - ----- -- ' PRE � RIC, noWN THE RnP� FILL TREE WITH NEAT METHANOL. NU THE 1 TREE CAP. I RIG HYDRAULIC SYSTEM WARMING UP. 04:15 05:00 0.75 BOPSUR N SFAL PRE 1 PT TREE CAP WITH NEAT METHANOL TO 250 LOW AND 3500 PSI HIGH FOR 5 MIN. CHARTED AND SIGNED BY DRILLER AND WSL, PLACED IN WELL FILE. RIG RELEASE AT 05:00 AM. Printed 3/30/2011 11:12:48AM North America - ALASKA - BP Page 4 ettr Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 2/14/2011 I End Date: 3/2/2011 'X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth,' Phase Description of Operations (hr) BOPSUR N SFAL (ft) L 05:00 05:30 0.50 PRE PJSM WITH DS 18 PAD OPERATOR, NORDIC i SUPERINTENDENT, BP SUPERINTENDENT, TWO WSL'S, SLB AND NORDIC 1 CREW. READ THROUGH THE BP PLAN FORWARD AND COVERED EVERY POINT. READ THROUGH NORDICS PROCEDURE AND MADE SURE EVERYONE KNEW WHAT WE WERE DOINGAND WHY. WE IDENTIFIED HAZARDS AND ASSIGNED SPECIFIC DUTIES. ONE HAND I WILL HOLD THE RIG WHEEL CHOCKS AND BE !READY TO THROW IN FRONT OF THE RIG WHEEL AS A POSITIVE STOP. THE PAD OPERATOR WAS TOLD THAT ALL VALVES ARE CLOSED AND ASKED IF WHERE WE PLANNED TO PUT THE RIG WAS GOOD WITH HIM. ALL PERSQNNEL INVOLVED WITH THE POSITIONING OF THE RIG WILL CARRY HAND HELD RADIOS AND PERFORM RADIO CHECKS. IF LINE OF SIGHT OR RADIO CONTACT IS LOST OR BROKEN THEN THE RIG WILL STOP. THE REASON FOR STOPPAGE WILL BE INVESTIGATED BEFORE RESUMING RIG MOVEMENT. THE RIG WILL 1 ONLY BE MOVED IN LOW SPEED RANGE. AN 'MR WILL BE HELD AFTERWARD. 05:30 - 06:00 l 0.50 BOPSUR N SFAL OF PRE PULL RIG OFF WELL AND PARK ON EDGE OF L I _ PAD OUT OF THE WAY. 06:00 - 09:00 1 3.00 ` BOPSUR N SFAL PRE MET WITH PAD OPERATOR, CONDUCTED A PAD INSPECTION AND CLOSED OUT THE WELL WORK TRANSFER PERMIT. ALSO TOLD HIM THAT THE LOTO WAS TAKEN OFF OF 18 -15 AND WE NO LONGER NEEDED IT SHUT N. 09:00 17:30 8.50 BOPSUR N SFAL - ' PRE I WAIT ON SLICKLINE TO FISH THE TREE TEST PLUG IN THE TUBING HANGER. KILL THE WELL AND SET A TUBING TAIL PLUG IN THE SUB SURFACE SAFETY VALVE PROFILE AT 12185'. 17:30 18:00 0.50 BOPSUR N SFAL PRE [ CONDUCTED AN MR WITH THE CREW FOR PULLING THE RIG OFF THE WELL AFTER THE 1 PTM. THE DAY SPOC POINTED OUT THAT THE SPOTTERS SHOULD HAVE BEEN WEARING REFLECTIVE VESTS. THE FLOOR HAND POINTED OUT THAT WITH ALL THE EXTRA SUPERVISION THAT THE HANDS WERE ASSIGNED TO DIFFERENT POSITIONS AROUND THE RIG THAN THEY ARE USED TO. 'THERE WAS ALSO SOME CONCERN ABOUT GETTING IN A HURRY SINCE THE RIG MOVE I HAPPENED DURING THE NORMAL CHANGE 1 OUT TIME, BUT NO ONE FELT RUSHED AND DID NOT MIND WORKING OVER A LITTLE TO 18:00 - 21:00 3.00 BOPSUR N SFAL PRE E CHANGE THE MOVE. I ', CHANGE AND WALK AROUND CHECKING OUR AREAS. TALKED WITH THE SLICK LINE I CREW ON 18 -04 AND LET THEM KNOW WHAT WE DID BEFORE THEY GOT HERE AND I ASKED THEM TO CALL IT THEY NEED ANYTHING, LIKE A HEATER OR NEAT (METHANOL. Printed 3/30/2011 11:12:48AM North America - ALASKA - BP Page 5 Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/14/2011 I End Date: 3/2/2011 X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 I Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) eft) 21:00 - 00:00 3.00 BOPSUR N j SFAL PRE CALLED GCI TO GET COMMUNICATION HOOKED BACK UP TO THE RIG. WAIT ON SLICKLINE TO FISH THE TREE TEST PLUG IN THE TUBING HANGER. KILL THE WELL AND SET A TUBING TAIL PLUG IN THE SUB SURFACE SAFETY VALVE PROFILE AT . 2185'. 2/20/2011 00:00 - 05:00 5.00 BOPSUR N SFAL PRE WAIT ON SLICKLINE TO FISH THE TREE TEST PLUG IN THE TUBING HANGER. KILL THE WELL WITH 8.4 PPG KCL AND SETA 4 1/2" TUBING TAIL PLUG IN THE X NIPPLE AT 9575'. PRESSURE TEST TO 250 PSI AND 3500 PSI FOR. 30 MINUTES. 05:00 - 22:00 17.00 BOPSUR N SFAL PRE ' SLICKLINE RECOVERED TREE TEST PLUG. I KILL WELL WITH 8.4 PPG KCL. i SECURE WELL WITH TUBING TAIL PLUG IN X NIPPLE AT 9575'. PERFORM MIT ON TUBING TAIL PLUG FOR 30 MINUTES AT 3500 PSI. I i SLICKLINE RDMO. 22:00 - 00:00 2.00 BOPSUR N SFAL PRE WELLS GROUP IS OFF WELL 18 -04. CALLED ' DSM TO COME REMOVE WORK PLATFORM. 2/21/2011 00:00 - 02:30 2.50 BOPSUR N SFAL PRE WELLS GROUP IS OFF WELL 18 -04. CALLED DSM TO COME REMOVE WORK PLATFORM. CONDUCTED A PAD INSPECTION WITH PAD ' OPERATOR. A NEW WELL WORK TRANSFER PERMIT WAS FILLED OUT. DISCUSSED THE PRIMARY SAFE AREA AND THE SECONDARY SAFE AREA INCASE OF AN INCIDENT. ALSO DISCUSSED SIMOPS AND THE 5 MPH SPEED LIMIT AROUND THE RIG. 02:30 - 03:00 0.50 BOPSUR N SFAL PRE PJSM TO MOVE RIG OVER 18 -04C. CONTENTS OF DISCUSSION - ENSURE THAT ALL TREE VALVES ARE CLOSED AND PRESSURE HAS BEEN BLED OFF. '- REVIEWED NORDIC'S RIG MOVE PROCEDURE. I i 1-DISCUSSED NORDIC'S PREMOVE 1 CHECKLIST. -THE RIG HYD SYSTEM WAS PROPERLY WARMED UP. - EVERYONE WAS WEARING THE PROPER PPE. 1 - IDENTIFIED THE HAZARDS. - EVERYONE HAD A RADIO AND RADIO CHECKS WERE PERFORMED. I- NORDIC SUPERINTENDENT IN CELLAR MAINTAINS LINE OF SIGHT OR RADIO CONTACT. I -IF LINE OF SIGHT OR RADIO CONTACT IS BROKEN THE RIG WILL STOP. 1 1-ALL RIG MOVEMENT WILL BE PERFORMED IN LOW RANGE. -ONE SPOTTER WILL CARRY THE WHEEL CHOCKS AND BE READY TO USE THEM. 03 :00 - 04 :00 1.00 BOPSUR N SFAL I PRE RIG MOVE. RIG ACCEPT AT 04:00. 04:00 05:00 1.00 I BOPSUR N SFAL PRE I SPOT CUTTINGS BOX. PULL TREE CAP. HARDLINE CREW RECONNECT TIGER TANK AND PT TO 4000PSI. Printed 3/30/2011 11:12:48AM North America -` ALASKA - BP Page 6s Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/14/2011 End Date: 3/2/2011 IX3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 I Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date I From - To Hrs I Task ' Code NPT ,, NPT Depth Phase Description of Operations , (hr) ! (ft) , ':05:00 - 05:30 ! 0.50 BOPSUR , N SFAL j PRE PJSM. NU BOPE. 05:30 - 22:30 17.00 BOPSUR N SFAL PRE BOPE TEST. WITNESS WAIVED BY J. CRISP P 1 W/ AOGCC. � Qv FIGHTING TO GET TEST ON SWAB VALVE. '/ I 'GREASE TREE. GREASE CHOKE MANIFOLD. 1 i_ 1 22:30 - 00:00 1.50 I BOPSUR N SFAL PRE STAND BY PHASE 2 WEATHER COULD BE i PHASE 3 ANY MINUTE. ELECT TO WAIT TO _ RU SLICKLINE. _ 2/22/2011 00:00 - 03:00 3.00 1 BOPSUR N SFAL PRE STAND BY PHASE 2 WEATHER COULD BE PHASE 3 ANY MINUTE ELECT TO WAIT TO L_ , , RU SLICKLINE. 03:00 - 03:30 0.50 BOPSUR N SFAL PRE BACK TO PHASE 1 LEVEL 2 ON ACCESS ROADS AND PADS. CALL FOR SLICKLINE. 0330 05:00 1.50 BOPSUR N SFAL PRE FILL PITS WITH 290 BBLS OF XS 2%KCL WITH 0.6 %CFS -520. EXTRA TRUCK ON LOCATION WITH 210 BBLS XS 2 %KCL WITH 0.6 %CFS -520 'FOR BULLHEAD KILL 05:00 - 10:00 5.00 RIGU N SFAL PRE PT TREE AGAINST MASTER TO 250 PSI LOW / ■ 3500 PSI HIGH FOR 5 MINUTES EACH W/ KCL - PASS. I PT TREE AGAINST TTP TO 250 PSI LOW / - 3500 PSI HIGH FOR 5 MINUTES EACH W/ KCL - PASS. STAGE SLICKLINE, CONFIRM WEIGHTS OF ITHEIR EQUIPMENT, AGREE ON LIFTING PLAN. CONFIRM CERTIFICATION OF THEIR PCE. CONFIRM LENGTHS/ODS OF THEIR TOOLSTRING, CONFIRM THEIR PULLING ! SELECTION. I I I PJSM W/ ENTIRE CREW FOR RU AND RIH W / SLICKLINE. RECOGNIZE PINCH POINTS OF WIRE AT DRUM AND SHEAVES, I ACKNOWLEDGE THE POTENTIAL FOR THE I ! I WIRE TO PART, CONSIDER THE POTENTIAL FOR DROPPED OBJECTS WHILE ! I , i UNSTABBING W/ FISH, CROWNING OUT WI ITHEIR TOOLS IF WE COME DOWN ON TUGGER, DROPPING EQUIPMENT WHILE I , LOADING ONTO RIG FLOOR, ETC. REVIEW NORDIC AND WELLS GROUP PROCEDURES I FOR RU AND RUNNING SLICKLINE. 10:00 - 11:45 1.75 RIGU N SFAL PRE i RU SLICKLINE (30' LUBRICATOR, WIRELINE RAMS, PUMP -IN SUB). 11:45 - 18:00 ! 6.25 RIGU N SFAL PRE RIH W/ SLICKLINE W/ SHROUDED JDC TO PULL PRONG. (DETAILS OF SLICKLINE WORK MAY BE FOUND IN THEIR AWGRS I REPORT). PULL AND RECOVER PRONG. I RIH W/ SLICKLINE W/ GS TO PULL AND RECOVER PLUG. PULLED PLUG ON FIRST ± —'I 'ATTEMPT. POH WITH PLUG. _ 18:00 - 19:00 1.00 RIGU N SFAL PRE 1PJSM ON RD SLICKLINE UNIT. RD UNIT. NOTE - SI WHP IS ZERO PSI. P 1 19:00 - 20:00 1.00 RIGU I PRE I PRE -SPUD MEETING WITH NEW CREW I I I COMING ONTO HITCH, DISCUSS HIGH GOR I SOP UPDATE. PJSM ON WELL KILL I , L OPERATIONS. Printed 3/30/2011 11:12:48AM North America = ALASKA - BP Page; tl Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/14/2011 1 1 End Date: 3/2/2011 X3 00Y24 -C (1,484,621.00 ) !X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay I Site: PB DS 18 , Rig Name /No.: NORDIC 1 1 Spud Date/Time: 12/25/1982 12:00:00AM 1 Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA 1 UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT NPT Depth I Phase Description of Operations hr (ft) 20:00 - 22:00 2.00 KILLW P WEXIT 1 CONDUCT WALKAROUNDS TO INSPECT FLOW LINE TO TIGER TANK, INSPECT CELLAR, CHECK VALVE FUNCTIONS. RECORD FLUID VOLUMES ON LOCATION. BEGIN WELL KILL OPERATIONS. j -PUMP 5 BBL METHANOL SPEAR FOLLOWED 1 BY 8.4 PPG KCL ' -CATCH FLUID AT 15 BBLS, INCREASE RATE TO 4.5 BPM AT 1480 PSI, ZERO COUNTERS `- BEGIN WELL KILL AT 4.5 BPM; PRESSURE INCREASE TO 1605 PSI AT 100 BBLS AWAY ,- PRESSURE REDUCED TO 1420 PSI AT END OF PUMPING 252 BBLS AWAY (1.5 TIMES L VOLUME CALCULATED AT 240 BBLS) 22:00 - 22:40 0.67 T KILLW P WEXIT FLOW CHECK WELL FOR 30 MINUTES; STATIC. COME ON WITH PUMPS, CALCULATE 9 BPH LOSS RATE._ 22:40 - 23:30 0.83 WHIP P WEXIT PJSM ON MU OF WHIPSTOCK BHA TO I COILTRACK. MU 3.70" WHIPSTOCK BHA: - WHIPSTOCK PACKER, KB WHIPSTOCK 1 TRAY, WIRELINE ADAPTER KIT, #10 J HYDRAULIC SEAT, CROSSOVERS, HOT, DGS, DPS, EDC. POWERCOMMS, SUB WEAR 4PROTECTOR, LQC, UQC, XO, CTC - CONFIRM HIGHSIDE ORIENTATION OF WHIPSTOCK TO COILTRACK MWD j 23:30 00:00 0.50 WHIP 1 P WEXIT MU INJECTOR TO LUBRICATOR. RIH WITH WHIPSTOCK BHA ON COIL AT .45 BPM WITH EDC OPEN. 2/23/2011 00:00 - 02 :15 + 2.25 WHIP P WEXIT I RIH WITH 3.70" WHIPSTOCK BHA AT .45 BPM 1 WITH OPEN EDC: WHIPSTOCK PACKER, KB WHIPSTOCK 1 TRAY, WIRELINE ADAPTER KIT, #10 J F HYDRAULIC SEAT, CROSSOVERS, HOT, DGS, DPS EDC. POWERCOMMS, SUB WEAR PROTECTOR, LQC, UQC, XO, CTC N - NO ISSUES WITH PREVIOUSLY O TED 1 TIGHT SPOTS FROM SLB DRIFT RUNS 02:15 - 03:15 1.00 WHIP P WEXIT CONDUCT TIE -IN LOG AT 9870' TO 10,100'; -15' CORRECTION. CONDUCT CCL LOG ACROSS WHIPSTOCK SETTING AREA. - AVERAGE 24 BPH LOSSES WHILE RIH, LOGGING 03:15 - 03:40 0.42 , WHIP P ,, WEXIT CONFIRM TOOL FACE ORIENTATION TO 30 DEG LEFT OF HIGH SIDE. POSITION 1 WHIPSTOCK TOP AT 9980' MD. CLOSE EDC, PRESSURE UP TO SET WHIPSTOCK. POSITIVE INDICATION OF SET AT 1960 PSI. I SET DOWN 5K TO CONFIRM SET. PU OFF OF 1 WHIPSTOCK. CONFIRM ONE - FOR -ONE RETURNS. 03:40 - 04:20 0.67 WHIP P WEXIT CONDUCT ANNULAR ISOLATION TEST. I PRESSURE TEST TO 250 PSI LOW FOR 5 MINUTES AND 2400 PSI HIGH ON CHART FOR 10 MINUTES. GOOD TEST. 04:20 - 08:00 3.67 WHIP P WEXIT I FLOW CHECK WELL. STATIC. DISPLACE 8.4 PPG KCL TO 8.6 PPG QUICKDRILL MUD. 08:00 - 09:40 1.67 WHIP P WEXIT WELL SWAPPED TO MUD. RETURNS STILL 1:1. POOH W/ SETTING ASSEMBLY. Printed 3/30/2011 11:12:48AM North America - ALASKA - BP Page a Operation Summary Report Common Well Name: 18 -04 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/14/2011 End Date: 3/2/2011 'X3- 00Y24 -C (1,484,621.00 ) X3- 00YGV -C (757,473.00 ) Project: Prudhoe Bay Site: PB DS 18 Rig Name /No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI: 500292087500 Active Datum: 9 : 04 7/29/1998 10:43 @56.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 1 (hr) (ft) 09:40 - 12:30 2.83 STWHIP i P WEXIT AT SURFACE. FLOWCHECK - GOOD. UNSTAB, LD WS SETTING ASSEMBLY. TOOL APPEARS TO HAVE FUNCTIONED PROPERLY. MU WINDOW MILLING ASSEMBLY: UQC, LQC, WEAR SUB, P &C, EDC, DPS, DGS, BLIND, XO, XO, 2 JTS 2 -3/8" PH6, XO, 2 -7/8" XTREME MOTOR (STRAIGHT), HCC DIAMOND STRING REAMER (3.80" GO, 3.79" NO -GO) AND HCC DIAMOND WINDOW MILL (3.80" GO, 3.79" NO -GO ). , 12:30 14:30 2.00 W W IH STHIP P EXIT R W/ WINDOW MILLING ASSEMBLY. DID NOT SEE XN AS RIH. 14:30 - 15:45 1.25 STWHIP I p WEXIT ' LOG TIE -IN, CORRECTION OF ( -12') DRY TAG WHIPSTOCK (PINCH POINT SAME AS TOWS) AT 9983' MD. 15 :45 - 17:10 1.42 STWHIP P WEXIT `UP WEIGHT 38800 LB. RIH WEIGHT 16800 L�r� FREESPIN2850 PSI 2.80 BPM. BEGI V R oNC MILLING WINDOW. ENGAGE AT 998 : MD. 16 :10 - TIME MILLING AT 9983.2' s / 600 LB DHWOB AND 2950 PSI AT 2.8. = 'M. ,16:20'- TIME MILLING AT • ":3.3' MD W/ 750 LB DHWOB AND 2950 PS .0 PSI MOTOR WORK) AT 2.80 BP k BI-IP/ECD/PVT: 4205 PSV 9.76 PPG / 342 r LS. RETURNS 1:1. IAP: 200 PSI. OAP: a PSI. MILL AHEAD TO 9984.5' ' I i 1 MD. 17:10 - 19:00 1 1.83 STWHIP P WEXIT IM ENT PHASE III CONDITIONS. TRAVEL RMITTED BY CONVOY ONLY WITH SUPERVISOR PERMISSION. DECISION IS TO 1 POH WITH MILLING ASSEMBLY TO SECURE WELL AND GET NON -RIG PERSONNEL BACK TO THEIR CAMPS SAFELY. 1- POH WITH MILLING BHA - CONDUCT KICK WHILE TRIPPING DRILL WHILE POH 19:00 - 20:00 1.00 STWHIP P WEXIT PJSM ON LD MILLING BHA - LD BHA; MILL GAUGED AT 3.80" GO AND 1 3.79" NO -GO - FILL HOLE. FLOW CHECK, WELL STATIC - INSTALL NIGHTCAP, CLOSE VALVES TO SECURE WELL 20:00 - 00:00 4.00 STWHIP N WAIT WEXIT 1 WAIT ON WEATHER 1- WINDS STEADY AT 36 -40 MPH, GUSTING TO 150 +MPH - CALLS TO SECURITY DEFERRED TO HEAVY EQUIPMENT OPERATIONS MANAGER (WHO MAKES DECISION ON PHASE LEVELS); CONSIDERED "HEAVY PHASE II" - OFFICIAL PHASE CONDITIONS PHASE II, LEVEL II ON ACCESS ROADS AND PADS 1- HEAVY EQUIPMENT IS MOVING; ALL OTHER TRUCKS ARE TRAVELING IN CONVOY ONLY IF REALLY NEEDED Printed 3/30/2011 11:12:48AM NELLHEAD F ` MCEVOY 1 S -0 SAFETY CHROME TBG*** ANGLE > 70 @ 10120' * ** \CTUATC)R = AXELSON CB. ELEV = 45.1' SUSPENDED 3F. ELEV = 19.21' 2185' H4-1/2" CAMCO BAL -O SSSVN, ID = 3.813" vlaxAngle 75° @ 10187' I I� )atum MD = 11113' )atum TVD = 8800' SS GAS LIFT MANDRELS PJC 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2629' DRAFT, ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3168 3055 35 MMGM DMY RK 0 03/29/C 3 5993 5193 40 MMGM DMY RK 0 03/29/C Minimum ID = 3.80" @ 9595' t 2 8112 6830 31 MMGM DMY RK 0 04/06/C 4 -1/2" MILLED OTIS XN NIP 1 9514 8116 38 KBG -2 DMY BK 0 04/06/C 8541' I--I 9 -5/8" X 7" BKR ZXP PKR/TIEBACK, ID = 6.313" 8555' H9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.313" I TOP OF WHIPSTOCK H 8741' IN 19-5/8" CSG, 47 #, L -80, ID = 8.681" I-I -8734 9 -5/8" MILLOUT WINDOW (18 -04B) 8718' - 8734' FR- PERFORATION SUMMARY I I 9541' H4-1/2" OTIS X NIP, ID = 3.813" I REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 @ 10383' Note: Refer to Production DB for historical perf data I 9551' H7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 2 r SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10383 - 10410 C 01/22/02 3 -3/8" 6 10410 - 10450 C 09/25/01 I 9575' 1-14-1/2" OTIS X NIP, ID = 3.813" I 2 -7/8" 4 10426 - 10456 C 08/14/01 2 -/78" 4 10465 - 10485 C 08/14/01 ' 9595' H4 -1/2" OTIS XN NIP, MILL TO 3.80" (02/05/11) I 9608' H4-1/2" W L EG, ID = 3.958" I 14-1/2" TBG, 12.6 #, 13CR, .0152 bpf, ID = 3.958" H 9606' f I 9685' I- 7" X 4 -1 /2" BKR ZXP PKR w / 7.40' TIEBACK & HMC LNR HGR, ID = 4.39" 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I 9882' — 3.80" MILLOUT WINDOW (18 -04C) 9983' - 9990' 4 -1/2" PKR WHIPSTOCK (02/22/11) H 9980' I4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I--I -9990' 4 0 ,r - Crs'c- . 'e $, .;. ;.; 14-1/2" OPEN HOLE I 10675' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION WELL: 18 -04B 05/18/98 RWO PERMIT No:'2010900 07/17/01 N7ES SIDETRACK (18 -04B) API No: 50- 029 - 20875 -02 03/02/11 NORDIC 1 CTD SUSPENDED (18 -04C) SEC 24, T11 N, R14E, 1067' FNL & 191' FEL 03/07/11 PJC DRLG DRAFT CORRECTIONS 1 BP Exploration (Alaska) • • t ti[F A[LnnA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. MOWED JAN 1 3 2 D )) t P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -04B Sundry Number: 311 -003 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the • next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ) ( day of January, 2011. Encl. STATE OF ALASKA 00/1( ALASKA LAND GAS CONSERVATION COMMISSI! I� it' „ II * ,, �� ` APPLICATION FOR SUNDRY APPROVAL yr I � �I r II 20 AAC 25.280 1. Type of Request: ❑ Abandon Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. _i Development • ❑ Exploratory 201 -090 3. Address: ❑ Service ❑ Stratigraphic 6. API Nun2070 ?, ' P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029-20077 -02 -00 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-04B ' Spacing Exception Required? ❑ Yes No 9. Property Designation: 10. Field / Pool(s): - ADL 028307 • Prudhoe Bay Field / Prudhoe Bay Oil Pool 11 - PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10607' ,. 9002' ' 10506' 8908' None None Casing Length Size 1 MD _ TVD Burst Collapse Structural Conductor 80' 20” 80' 80' Surface 2629' 13 - 3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9 -5/8" 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541' - 9882' 7208' - 8331' 7240 5410 Liner 909' 4 -1/2" 9685' - 10594' 8173' - 8990' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10383' - 10485' 8793' - 8888' 4 -1/2 ", 12.6# 13Cr -80 9608' Packers and SSSV Type: 7" x 4 -1/2" BKR S -3 Packer Packers and SSSV 9551' / 8066' 7" x 4 - 1/2" BKR ZXP Packer MD (ft) and TVD (ft): 9685' / 8173' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG • 0 Suspended 17. I hereby certify that the f• -going is true and correct to the best of my knowledge. Contact Matthew Ross, 564 -5782 Printed Name Jo jr fir; I Title Engineering Team Leader tiiir Prepared By Name/Number. Signature / Phone 564 -4711 Date % E lizabeth Barker, 564-4628 iol Commission Use Only Conditions o approval: N tify Commission so that a representative may witness ( — f 0O Sundry Number 0 ❑ Plug Integrity Er BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ,t,3 r s` 6ve 7cs1 ,� ,- r � Other: S f' r'`"'. , . m. d 4., ` i.,. # -. Z606 (SC. Arm t k &.rK ,l e_bl 4 4opro VC.0 / `e-` a 0 !� � Ar 20 AkC- ZsI1 -C1- Subsequent Form Required: i 'a ? �` 2 ` '�' uQf$= Cfi - . ;i$SI0 !�f1t:f3llfag£ APPROVED BY / / Approved By COMMISSIONER THE COMMISSION Date 1// 6 Form 10-403 Revi ed IW�7 B /@ JAN 1 1 3 2 01 ,. /J /74/ Submit In uplicate R L ORIGINAL `'�- ,e" 44 • • To: Alaska Oil & Gas Conservation Commission From Matthew Ross b p CTD Engineer 0 Date: December 28, 2010 Re: 18 -04B Sundry Approval Sundry approval is requested to plug the 18 -04B perforations as part of drilling the 18 -04C coiled tubing sidetrack. History of 18 -04B. 18 -04B is a 2001 rotary sidetrack targeting a structurally low block within the Midfield Graben. It was completed as high angle well in Zone 1B /1A. The well struggled to flow at —800 bopd at 3100 GOR from Zone 1 and required frequent Hot Oil Treatments. The oil rate steadily declined until Jan 2002 when 27' of Zone 2A were perforated. The well tested strong at —3000 bopd but declined to 1000 bopd at 30,000 GOR in a few months. From mid 2002 to 2007, it cycled with slowly declining recharge and ontime. The well was shut -in for high GOR in Jan 2008 when it POP'ed and tested at 89,000 GOR after a 4 month shut -in period. There have been subsequent attempts to POP the well without success, and it remains SI. LAST WELLTEST (12/31/07): 0 bopd, 36 MMscfd, 0% WC at >100,000 GOR 18 -04B is currently shut -in for high GOR with no remaining wellwork options. Reason for sidetrack. 18 - 04B is currently SI for high GOR with no remaining wellwork options. The proposed sidetrack will provide additional offtake in a Midfield Graben fault block located in Southern DS 18. Proposed plan for 18 -04C is to drill a thru- tubing sidetrack with a Coiled Tubing Drilling rig on or around January 25, 2011. The existing perforations will be isolated by the primary cement job. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work: (scheduled to begin January 15, 2011). 1. S Dummy WS drift to 10,150' MD. live l� A'1 of � 0 2. F Load & kill well prior to setting WS. Freeze protect well to 2000' MD. freivC1-r`o f 12ecemipf 2007 3. E Concurrently set 4 -1/2" Packer WS at 9980' MD. ✓ 1- co • 4. F Pressure test packer WS to 2400psi. ( f lOd T1 25 "_0 5. V PT MV, SV, WV. far 25 0(4 ,p,1 hvl h.,' / q 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. f (S G( sL 6)R. 6 0 g m4ke5` 8. V Set TWC —24hr prior to rig arrival. / g j � � 7"( /5 bail A 0r �`, e • ! �, — P wQ lei Pit-nick ,d't- k 5''ove Rig Work: (scheduled to begin on January 25, 2011) P , 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 1 m f T o ve rec(vi, F41 2. Mill XN profile at 9595' MD. � a'recr 6o r4e 3. Mill 3.80" window at 9980' MD and 10' of rathole. • .6 4. Drill Build: 4.25" OH, 421' (40° /100). 5. Drill Lateral: 4.25" OH, 704' (12° /100). 6. Run 3- 3/16" solid cemented completion leaving TOL at 9950' MD. 7. Pump primary cement leaving TOC at 9950' MD, 11 bbls of 15.8 ppg liner cmt planned. 8. Cleanout run. 9. Run MCNL /GR/CCL log. 10. Perforate 100'. . • 11. Run 4 -1/2" liner top packer and test liner lap to 2,400 psi. 12. Freeze protect well, set BPV and RDMO. Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Run generic GLV's. Matthew Ross CTD Engineer 564 -5782 CC: Well File Sondra Stewman /Terrie Hubble • TREE= McEVOY • WELLHEAD= McEVOY I SAFETY AS: 4 -1/2" CHROME TBG I ACTUATOR = AXELSON 1 8-04 B KB. ELEV = 45.1' BF. ELEV = 19.21' KOP = 2100' Max Angle = 43 © 3900' I 2185' H 4 -1/2" CAMCO BAL -O SSSVN, ID = 3.813" I Datum MD = 10439' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2629' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 9595' 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 4 -1/2" OTIS XN NIPPLE 2 8112 6830 32 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG -2 DMY BK 0 04/06/02 I 8541' H9-5/8" X 7" BKR ZXP PKR/TIEBACK, ID = 6.313" I 1 8 555 ' - I 9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.313" I 9 -5/8" MILLOUT WINDOW 8718' - 8734' TOP OF WHIPSTOCK H 8741' I PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 9541' H4 -1/2" OTIS X NIP, ID = 3.813" I ANGLE AT TOP PERF: 18 @ 10383' 9551' H7" X 4-1/2" BKR S -3 PKR, ID = 3.875" I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE •� 9575' I-I -1/2" OTIS X NIP, ID = 3.813" I 3 -3/8" 6 10383 - 10410 0 01/22/02 III 9595 I -14 -1/2" OTIS XN NIP, ID = 3.725" I 3 -3/8" 6 10410 - 10450 0 09/25/01 IIIIII.' N I' 2 -7/8" 4 10426 - 10456 0 08/14/01 I 9608' 1-14-112" WLEG, ID = 3.958" I 2 -178" 4 10465 - 10485 0 08/14/01 444444414'1' ik . 1 v 9685' I- 7" X 4-1/2" BKR 000004 ZXP PKR, ID = 4.39" • • • • • • • • • • • • • • • • • • • • • • 9882' ( — 7" LNR, 26 #, L -80, 0.000.4 .0383 bpf, ID = 6.276" I9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-I 9729' I4 -1/2" TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" hL 9606' I \ I PBTD H 10505' 4-1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" H 10594' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION 06/13/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18 -04B 05/18/98 LAST WORKOVER 09/13/03 CMO/TLP DATUM M D & PERF ANGLE PERMIT No: I 010900 07/17/01 RIG SIDETRACK 02/14/04 LWB /TLH GLV TVD CORRECTION API No: 50- 029 - 20875 -02 07/21/01 CI-I/TP CORRECTIONS 04/01/08 SWC/SV GLV C/0 SEC 24, T11N, R14E, 1067' FNL & 191' FEL 08/14/01 ? /KAK PERFS 09/25/01 JLM/KK PERFS & GLV CHANGES 01/22/02 CWS /KK ADPERFS BP Exploration (Alaska) IKEE= Mc EVOY WELLHEAD McEVOY -04C SAFETY N : 4 -1/2" CHROME TBG i ACTUATOR = AXELSON KB. ELEV = 45.1' posed CTD Sidetrack BF. ELEV = —. -- 19.21' KOP = 2100' Max Angle = 43 Q 3900' [ 2185' H4 -1/2" CAMCO BAL - O SSSVN, ID = 3.813" Datum MD = 10439' 0 Datum 1 VD = 8800' SS 113 - 3/8" CSG, 72 #, L - 80, ID = 12.347" — 1 2629' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3168 3055 35 MMGM DMY RK 0 03/29/08 Minimum ID = 3.725" 9595' 3 5993 5193 40 MMGM DMY RK 0 03/29/08 4-1/2" OTIS XN NIPPLE 2 8112 6830 32 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 r t l,4 I 8541' H9 -5/8" X 7" BKR ZXP PKR/TIEBACK, ID = 6.313" I 8555' 1H9 -5/8" X 7" BKR HMC LNR HGR, ID = 6.313" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9729' 9-5/8" MILLOUT WINDOW 8718' - 8734' ..,, / . . 40 + I 9541' H4 OTIS X NIP, ID = 3.813" SO ' I 9551' I X 4 -1/2" BKR S -3 PKR, ID = 3.875" I .fr e 9575' H4 - 1/2" OTIS X NIP, ID= 3.813" I I 9595' — 14 - 1/2" OTIS XN NIP, ID =3,8" 4-1/2" TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" H 9606' 9608' H4-1/2" WLEG, ID = 3.958" I 9685' 17" X 4 -1/2" BKR ZXP PKR, ID = 4.39" PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 @ 10383' I 9882' IH 7" LNR, 26#, L - 80, 0.0383bpf, ID = 6.276" I Note: Refer to Production DB for historical pert data ' _, _, SIZE SPF INTERVAL Opn /Sqz DATE -� 4.5 KB LTP -9940 3-3/8" 6 10383 - 10410 C 01122/02 ( 9950' H TOP OF LINER I 3-3/8" 6 10410 - 10450 C 09/25/01 2 -7/8" 4 10426 - 10456 C 08/14/01 I 14 1/2" pkr w hipstock H 9980' 2 -178" 4 10465 - 10485 C 08/14/01 :_ PBTD —I 10505' iiii00 ■■■ 4 LNR, 12.6 #, L - 80, .0152 bpf, ID = 3.958" H 10594' I✓ 1 3 - 3/16" LNR cmtd ( I 11105' I DATE REV BY COMMENTS " DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION 06/13/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18-04 : 05/18/98 LAST WORKOVER 09 /13/03 CMO/TLP DATUM M D & FERF ANGLE PERMT No: 07/17/01 RIG SIDETRACK 02/14/04 LWB/TLH GLV TVD CORRECTION API No: 50- 029 - 20875 -0' : 0721 /01 CH/TP CORRECTIONS 04/01/08 SWC/SV GLV GO SEC 24, T11 N, R14E, 1067' FNL & 191' FEL 08/14 /01 ?/KAK PERFS 11/05/10 MSE PROPOSED CTD SIDETRACK _ 09/25/01 JLM/KK PERFS & GLV CHANGES 0122102 CWS/KK ADPERFS BP Exploration (Alaska) NORDIC - CALISTA RIG I CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM , V12 I V14 7 -1116" 5000 psi BOP's 1 0 = 7 .06" ®" V15 Vii 17 1116 . '5000 pal, RX<6 Transducers 0 111111'1 POOR 1 V V2 I V1 V 16 � - ro ' mB n DEGASSER SER Hole : tee' BOP aneement for gala" RIM :: ubing ril. 7 1116" 5000 Pai, .46 11 MM. ' V17 � I IC r 1K OK Ill; i To Poor Boy Gas Buster e� ON 11" ' p s i 3.00" 5000 pal OCR 1 , .'- , ■ /fr. 21116 "5000 pal CHECK I VALVE Manual Choke Ilti — INA 71lls Cameron FOV Gate Valve x 5000 pal M Ma riaillIEM MEOH /Diesel r, r e, .-- A FP Line CoFlex Hose Micro Motion 111 � 114 Tum Hak:o SWACO 10WOG To Production Tree or Cross Over • A Il T CoFlex Hose CV11 0 „ Bleed Off ' Cement Line In CV Ground Level Tie -in a� -I CV3 CV2 r--- T Stand Pipe =� Awn _� _ � — __ ^_ _ _... _.. _ AI .7. Manual Choke pressure Transducers IR �.. _ = ins - . _� — _ Ilia — — III CV9 Motion 1� InI111M-' II CV17 11_10 COB 11 Tiger Tank Mud Pump 2 O _ _ Baker MP 1 d MP 2 0; 11'. Choke . In From • • CV14 to Pits Rig Floor ir Mud Pump X1 41 V16 Reverse Ci i • i Cir CTw le ••' ill - O A - • • To Manifold CV15 1- Jun-2010 Roeorce Correlation line I rT while nON CoFlex Hose e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFíche\CvrPgs _Inserts\Microfihn _ Marker. doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well icr5fk¿ 0.5. 07-03A :203 -{1.1K-10B ~qÍ;;-CJ.{7 0.5. 02-15A Î-17-l.1?J-- 0.5. 18-13A 703.l'/l- G-12B 1ot- ;2,2.( ~D.S. 05-26A ,7 v:3_\\tf-15-04A TqÇ-ð3b 18-02A '71)/_O~.,¿18-04B n5-015 L 1-01 :'3'8-1y¡-L5-17 Ji{1 _., if'~H-18 . ,/; -t~#~ 2-62/Q-17 I 0(:; ~, L5-15 ~ L5-15 _~q; L5-15 \ L5-15 iðO-D.;r'E-17 }ö- ty.{ - G-15A Job # 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST RST US IT USIT RST RST RST RST RST RST RST RST SCANNED JUN 1 7 2005 Log Description Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/04 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: .~~~~ Blueline b{OI- 090 02/28/05 NO. 3354 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints --' CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / -' 1 V 1 1 1 1 1 1 1 1 1 1 1 1 1 1 J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnChorag~, AK 99503-238 . . /' ATTN: Beth - / / Receive . . . r.¿tlv---. tac.M/...a~ Ó Permit to Drill 2010900 DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. PRUDHOE BAY UNIT 18-04B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20875-02-00 MD 10607 ~'- TVD 9002 .-- Completion Dat 8/15/2001 ~' Completion Statu 1-OIL Current Status 1-OIL UIC N ........................................................................... :~_-£'T~. - -. T£`~:~--::~.~:~:`~`~::~L`~-~`:~-L~-Z-`--`.~`:~¥Z~27~L7~2`--`~`~`-~7~ ................... .... ~'~ REQUIRED INFORMATION MudLog N._~o__ Sample N_.9o _D_!re_c.t_i~n_a_l_~_u~e__y- .... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) ED ED J3-------'" 1 8614 10554 Open 2~7~2002 10609 ~' Directional Survey FINAL ch 8/2/2001 ED ,~ Directional Survey FINAL ch 8/2/2001 ED ~' Ver LIS Verification 1 8614 10407 Open 2/7/2002 10608 ED ,G-'"~Pdf Cn See Notes 1 8621 10607 Case 12/6/2002 11359 Ver LIS Verification Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments Directional Survey FINAL ch 8/2/2001 ED G-----' RS Reservoir Saturation 1 9640 10476 Case 4/9/2002 10718 R,.I~.--'"' Directional Survey FINAL ch 8/2/2001 Directional Survey Digital Data PB1 Directional Survey Paper Copy Directional Survey Digital Data PB1 Digital Well Log data including PB1 Directional Survey Paper Copy Well C~-~~-rmati(:;~', Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / b Daily History Received? ~_..~/N Chips Received? ~ Formation Tops ~( N Analysis R~.nRiv~.d ? Permit to Drill 2010900 MD 10607 TVD DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. PRUDHOE BAY UNIT 18-04B Operator BP EXPLORATION (ALASKA) INC 9002 Completion Dat 8/15/2001 Completion Statu 1-OIL APl No. 50-029-20875-02-00 Current Status 1-OIL UIC N Compliance Reviewed By: l,",....x5 ? To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 18-04B & 18-04B PB 1 June 11, 2002 AK-MW-Ill08 18-04B: Digital Log Images: 50-029-20875-02 18-04B PBI: Digital Log Images: 50-029-20875-70 1 CD Rom 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED ,COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION' OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical iData Cemer, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed: RECEIVED DEC 0 6 2O07. 04~03~02 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AI'rN: Sherrie NO. 1950 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD K-20A /(~-' ! 50 22123 MCNL 03/09/02 ] 1 D.S, 18-04B 21361 RST-SlGMA 08/04/01 1 ] I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnicd Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 A1ZN: Sherrie STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratow.__ Stratigraphic_ Service__ 4. Location of well at surface 1067' FNL, 191' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 3792' FNL, 3669' FEL, Sec. 24, T11N, R14E, UM At effective depth 1517' FSL, 1585' FWL, Sec. 24, T11N, R14E, UM At total depth 3733' FNL, 3715' FEL, Sec. 24, T11N, R14E, UM (asp's 691572, 5960796) (asp's 688164, 5957984) (asp's 688139, 5958014) (asp's 688117, 5958042) 6. Datum elevation (DF or KB feet) RKB 45 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-04B 9. Permit number / approval number 201-0900 10. APl number 50-029-L;:~)7-7-~ 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2602' Intermediate 8691' Liner 1341' Sidetrack Liner 909' 10607 feet Plugs (measured) 9002 feet 10506 feet Junk (measured) 8908 feet Size Cemented Measured Depth True Vertical Depth 20" 1850# Poleset 107' 107' 2240 sx Fondu & 400 sx 13-3/8" 2629' 2593' PFC 500 sx Class 'G' & 300 9-5/8" 8718' 7370' sx PFC 7" 287 sx Class 'G' 8541' - 9882' 7208' - 8331' 4-1/2" 250 sx Class 'G'w/Latex 9685' - 10594' 8173' - 8990' Perforation depth: measured Open Perfs 10383' - 10456', 10465' - 10485' Tubing (size, grade, and measured depth) I Packers & SSSV (type & measured depth) true vertical Open Perfs 8793'- 8861' 8869'- 8888' ' 4-1/2", 12.6ff, 13CR TBG ~ 9551'. 4-1/2", 12.6~ Tubing Tail ~ 9608'. 9-5/8" x7" Baker ZXP PKR ~ 8541'. 7" x 4-1/2" BKR S-3 PKR 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/12/2002 Subsequent to operation 01/25/2002 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 7O3 3083 8 443 3366 11557 38 492 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~.~)~ Title: T e ch i cai Assistant Form 10-404 Rev 06/15/88 · Date February 22, 2002 18-04B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/14/2002 01/17/2002 01/20/2002 01/21/2002 01/22/2002 PERF(ADD-PERF): PULL SSSV / DRIFT TBG PERF(ADD-PERF): HOT IA TO THAW TBG PERF(ADD-PERF): BRUSH / BROACH; DRIFT/TAG PERF(ADD-PERF): BRUSH / BROACH; DRIFT/TAG PERF(ADD-PERF): PERFORATING 01/14/02 EVENT SUMMARY PULL 4.5" WRDP SERIAL # HDS-1111 / BRUSH AND FLUSH TBG / DRIFTTBG TO 2318'SLM W/3.80 GAUGE RING. LRS WAS PUMPING .5 BPM @ 1200 PSI. PUMP PRESSURED UP TO 3000 PSI. HELD 3000 PSI, CO. REP WANTED TO FLOW WELL/WELL WILL NOT FLOW W/O LIFT GAS. IA FROZEN. UNABLE TO FLOW WELL. FINAL TBG PRESSURE 1250 PSI. POSS CTU CLEAN OUT. 01/17/02 HOT OIL IA WITH 270 BBLS OF 190' F CRUDE TO THAW PARAFFIN PLUG IN TBG. HOT OIL TBG WITH 115 BBLS OF 190' F CRUDE. FREEZE PROTECT FLOWLINE WITH 5 BBLS OF METH, AND 62 BBLS OF CRUDE. 01/2O/O2 CUT PARAFFIN RUNNING BRUSH GAUGE RINGS W/LRS PUMPING. TODAYS LAST RUN-3.50" GAUGE TO 3300'. FALLING VERY SLOW. POOH TO CHANGE TO SMALLER GAUGE. JOB IN PROGRESS. 01/21/02 CONTINUED CUTTING PARAFFIN W/GAUGE RINGS-3.40", 3.50", 3.61". RAN BRAIDED LINE BRUSH W/3.80" GAUGE. HIT PARAFFIN @ 3100'. WORK TO 3400' WLM. DECISION MADE TO RUN 3-3/8" DUMMY GUN. RAN 3 3/8 X 15' DUMMY GUN W/SAMPLE BAILER, TAGGED SOFT BOTTOM @ 10,484' CORRECTED(USED 27' CORRECTION FROM BF/KB), RELEASE EQUIP, RETURN WELL TO DSO, LEFT WELL S/I. 01/22/02 PERFORATED 10383-10410' WITH 3 3/8" POWERJET 6 SPF. DID NOT TAG TD. STICKY HOLE CONDITIONS. **** TURNED WELL BACK TO OPERATIONS TO POP AND TEST **** FLUIDS PUMPED BBLS 15 METHANOL 1389 CRUDE 18 XYLENE 1422 TOTAL ADD PERFS 01/22/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" PJ 6SPF, 60 DEG PHASING, RANDOM ORIENTATION. 10383' - 10410' Page 1 WELL LOG TRANSMITTAL To: State of Alaska February 05, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 18-04B PB 1, AK-MM-11108 1 LDWG formatted Disc with verification listing. API#: 50-029-20875-70 PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNINI'G A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP iExploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ECEIVED FEB 0 -:' 2002 Alas~Oil &Oas Cons, Comm'~ WELL LOG TRANSMITTAL To: State of Alaska February 05, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 18-04B, AK-MM-11108 1 LDWG formatted Disc with verification listing. API#: 50-029-20875-02 -- -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 9951. 8 BP iExploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 o RECEIVED FEB 0 ? 2002 gl Oil&OB COm. Comm n ' STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL r~] GAS r-~ SUSPENDED E] ABANDONED ~] SERVICE C ' 2. Name of Operator ,t,f~l,,t~hll~lll~ 7. Permit Number BP Exploration (Alaska), Inc. ~ ~ 201-090 3. Address ;~[, 8. APlNumberp. o~,7,.,.,~ ~ P. O. Box 196612 Anchorage, AK 99519-6612 ;. 50-029-~e~7-~. 4. Location of well at surface ~" ~' ~--;~"~ 9. Unit or Lease Name 1067' FNL, 191' FEL, Sec. 24, T11N, R14E, UM (asp's 691572, 5960796) .~' i'~"."ii',"L"!"i ..' ' Prudhoe Bay Unit At Top Producing Interval ,.~ 10. Well Number 3792' FNL, 3669' FEL, SEC 24, T11 N, R14E, UM (asp's 688164, 5957984) ....~''::~Z''~'-'' ~.. / 18-04B At Total Depth ¢:':" ""' .~ 11. Field and Pool 3733' FNL, 3715' FEL, SEC 24, T11N, R14E, UM (asp's 688117, 5958042) ~.i'~i~. ' ii .... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 45.1 feetI ADL 28307 Prudhoe Bay Oil Pool 12. Date Spuddedjuly 2, 2001 13. Date T.D.July Reached13, 2001 14. ,~ u~OO l~p~,,,Date,~'-~ ~'.-'.~'f--]'~ 2_~. / ~'/-,,C°mp' Susp. Or Aband.II 15.N/AWater Depth,feet MSLif offshore 16. No. of Completions1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10607' MD/9002' TVD 10506' MD/8908' TVD YES [~] No E]I 2185' feetMD 1900' (approx) 22. Type Electric or Other Logs Run MWD / GR / Res / PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO'I-TOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 1850# Poleset 13-3/8" 72# L-80 Surface 2629' 17-1/2" 2240 Sx Fondu & 400 Sx PFC 9-5/8" 47# L-80 Surface 8718' 12-1/4" 500 sx Class G & 300 Sx PFC 7" 26# L-80 8541' 9882' 8-1/2" 287 Sx 15.8 ppg Class G 4-1/2" 12.6# L-80 9685' 10594' 6-1/8" 250 Sx 15.6 ppg Class G w/Latex 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (2-7/8" carriers, 4 SPF, 60° phasing, & underbalanced press) 4-1/2" 12.6# 13CR-80 9608' 8541 t' 10426' - 10456' MD; 8833' - 8861' TVD (Zone 1B/lA) 9685' 10465' - 10485' MD; 8869' - 8888' TVD (Zone lA) 9551' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 17, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 8/20/2001 3.6 Test Period >I 10500 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -317 psi 24-Hour Rate > 318 3339 13 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved May 23, 2001 (Permit #201-090) RECEIVED AUG 3 0 ZOO1 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGIN. Al.. Submit in duplicate Alaska 0i'l & Gas Cons. Commission Anchorage 29. ~. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sag River Sand 9836' 8293' Top of Shublik A 9876' 8326' Top of Sadlerochit 9947' 8384' Top of Zone 3 10106' 8521' Top of Zone 2 10180' 8593' Top of Zone lB 10400' 8809' Top of Zone lA 10447' 8853' Base of Sadlerochit 10487' 8890' 31. LIST OF ATTACHMENTS Summary of 18-04B CT Sidetrack Drilling Operations, Well Schematic, & End of Well Survey (including one plugback). 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~,,~.., ~ ;~li~ Title AD&W Drillin.q En.qineer Date Au.qust 30, 2001 Bill Isaacson Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Oth er-explain. R E C E Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL, Alaska 0il & Gas Cons. Con~missiorl Anchorage TREE = Mc EV OY 7A/ELL HEAD = Mc EVOY :~A CTUATOR = AXELSON KB. ELEV = 46.60' 3F. ELEV: 19121' KOP = 2100' Max Angle = 43 @ 3900' Datum MD = 10430' Datum TVD = 8800 SS 113-3/8" CSG, 72#, L-80, ID = 12.347" Id 2629' IMinimum ID = 3.725" @ 9595' 4-1/2" OTIS XN NIPPLE 18-04B NOTES: 4-1/2" CHROMETBG 2185' l~4-1/2" CAMCOBAL-OSSSVN, ID= 3.813" GAS LIFT MANDRELS PERFORATION SUMMARY REF LOG: ANGLE AT TOP PEP, F: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10426- 10456 O 08/14/01 2-/78" 4 10465 - 10485 O 08/14/01 8541' 8555' Id 9-5/8" X 7" BKR ZXP PKRFFIEBACK, ID = 6.313" I Id 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.313" 9-5~8" MILLOUT WINDOW 8718'- 8734' ]WHIPSTOCK Id 8741' IEzsv I-I 74s' 9551' Id7" X 4-1/2" BKR S-3 PKR, ID= 3.875" 9575' I-~4-1/2" OTISX NIP, 1D=3.813"I 9595' 1-14-1/2" OTIS XN NIP, ID = 3.725" 9608' I-~4-1/2" WLEG, ID= 3.958"I 9685' I-~7"x4-1/2" BKR I / zxP F R, ID = 4.39" I 9882' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 19-5/8" CSG, 47#, L-80, ID = 8.681" Id 9729' 14-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" 10506' 9606' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 10594' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/27/83 ORIGINAL COMPLETION 08/03/01 TNFFP ADD GLM DATA SIS- CONVERTED TO CANVAS 08/14/01 ?/KAK PERFS 05/18/98 LA ST WORKOV ER 07/17/01 RIG SIDETRACK 07/21/01 CH/'FP CORRECTIONS PRUDHOE BAY UNIT WELL: 18-04B PERMIT No: 201-090 APl No: 50-029-20875-02 BP Exploration (Alaska) BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: 18-04 Common Well Name: 18-04B Event Name: REENTER+COMPLETE Start Date: 6/25/2001 End Date: DATE TMD 24 HOUR SUMMARY 6/25/2001 (ft) Move rig off "W" pad, down access rd, onto Spine Rd. 6/26/2001 (ft) Moving rig f/W-pad, 19.2 miles, immoble w/flat tire, repair same 6/27/2001 (ft) Mobilize rig from VV pad to drill site 18 6/28/2001 (ft) Con't rig up Nabors Rig 7 ES. Accept rig @ 22:00 Hrs 28 June 2001. 6/29/2001 (ft) Displace hole to SW, reset BPV & test. N/U & test BOPE. 6/30/2001 (ft) Complete BOP test, POH & L/D 4 1/2" tbg. 7/1/2001 8,745.0 (ft) Dummy run w/mill ass'y & POH. Set EZSV. RIH w/mill ass'y. 7/2/2001 8,744.0 (ft) Con't RIH & set whipstock. Mill window. 7/3/2001 8,810.0 (ft) Mill window & run FIT. POH f/BHA # 3. RIH & dir drill 8 1/2 7/4/2001 8,853.0 (ft) Drill to 8842' & POH. X-O MWD ass'y & RIH. Drill to 8853 & POH for MWD 7/5/2001 9,510.0 (ft) RIH to 8853' & return to directional drilling operations. 7/6/2001 9,882.0 (ft) Directional drill 8 1/2" hole to 9882'. POH & run 7" csg. 7/7/2001 9,882.0 (ft) Run & cement 7" liner & circ hole clean. POH & test BOPE. 7/8/2001 10,061.0 (ft) Test all BOPE, P/U BHA # 5, RIH & dir drill 6 1/8" hole. 7/9/2001 10,457.0 (ft) Directional drill 6 1/8" hole to 10,457'. POH to plug back open hole. 7/10/2001 9,967.0 (ft) RIH. Cmt KO plug. POH. Cut & Slip. M/U BHA. RIH. Sidetrack. Drill. 7/11/2001 10,221.0 (ft) Drill 6-1/8" hole. 7/12/2001 10,552.0 (ft) RIH w/new BHA, drill ahead pumping LCM, monitor losses. 7/13/2001 10,607.0 (ft) Drill to TD, LCM sweep, ST, RIH, ST sqz LCM, LD BHA, Inr 7/14/2001 10,607.0 (ft) Run & cmt liner, LD DP 7/15/2001 10,607.0 (ft) LD DP, run cmpl assembly. 7/16/2001 10,607.0 (ft) Land tbg, set pkr, test tbg/csg, BPV failure, pull dummy in SSSV 7/17/2001 10,607.0 (ft) Test BPV, ND/NU, freeze prot., test tree, RD, move to D-18A Printed: 8/29/2001 9:48:59AM 18-04B DESCRIPTION OF WORK COMPLETED RIG SIDETRACK DRILLING OPERATIONS SUMMARY SUPPLEMENT Date Event Summary 7/21/2001: 7/22/2001: 7/24/2001: 7/31/2001: 8/03/2001: 8/04/2001: 8/13/2001: 8/14/2001 - 8/15/2001: Pulled ball & rod / RHC plug from XN nipple. Pulled Dumied GLV's - installed new GLV design. RIH w/bailer & tagged BTM @ 9675'. Made 3 runs w/pump bailer to 9656'. Bailed 3 gallons of mud & cuttings. RIH w/CT & tagged fill @ 9690'. FCO'd to 10505' CTM. RIH w/dummy gun & tagged PBTD @ 10494'. Ran RST Log. Jetted ice w/50/50 Methanol Water to 6100'. Switched to N2 while POOH. MIRU ELU. PT'd equip. RIH w/perforating guns & tagged PBTD @ 10490'. Shot (in two runs) 50' of initial perforating from: 10426' - 10456' MD 10465' - 10485' MD Used 2-7/8" PJ carriers & all shots @ 4 SPF, 60° phasing, random orientation, & underbalanced press. POOH w/guns - ASF. RD ELU. Placed well on initial production & obtained a representative well test. Sidetrack Summary Page I BP EXPLORATION Page 1 of 8 Operations Summa Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/25/2001 20:30 - 00:00 3.50 MOB PRE PJSM. Move Rig down "W" Pad access rd and onto Spine Rd. (camp and Pits to follow.) ~6/26/2001 00:00 - 11:00 11.00 MOB P PRE Turnkey rig move, moving rig down Spine Rd to K-pad road, 19.2 miles f/W-pad, one minor road problem at S-curve by Frontier pad 11:00 - 00:00 13.00 MOB N RREP PRE PJSM, replaced blown rear tire on driller's side of Sub 6/27/2001 00:00 - 06:00 6.00 MOB P PRE Con't - Move rig to DS - 18. 06:00 - 12:00 6.00 MOB P PRE PJSM. Set down choke base & landings. P/U top drive unit from carriage & spot on floor. P/U BOP & install HCR. 12:00 - 13:00 1.00 MOB P PRE Toolpusher meeting. 13:00 - 19:30 6.50 MOB P PRE Con't - Rig up BOPE. Move camp & shop. 19:30 - 20:30 1.00 MOB P PRE Derrick inspection. 20:30 - 23:00 2.50 MOB P PRE R/U drilling line. Change out bridle line sheaves. 23:00 - 00:00 1.00 MOB P PRE Spot rig over well. 6/28/2001 00:00 - 02:00 2.00 MOB P PRE Con't - Spot rig over well on double set of rig mats. Trouble shoot # 3 drive motor. Clean rig. Switch to Rig summer Maintenance AFE f/02:00 - 22:00 hours on 6/28/01 22:00 - 23:00 1.00 RIGU P PRE Rig accepted @ 22:00 Hrs 28 June 2001. Install 2nd annular valve. Clear floor & rig up for pressure test. 23:00 - 23:30 0.50 RIGU P PRE Pre spud meeting. 23:30 - 00:00 0.50 RIGU P PRE Rig up hose's for flare line & to cuttings tank. 6/29/2001 00:00 - 01:00 1.00 RIGU P PRE R/U DSM lubricator & pull BPV. R/D lubricator. 01:00 - 03:00 2.00 RIGU P PRE R/U surface equipment. Pressure test to 250 psi (Iow) & 5000 psi (high) - OK. Note - This was a test of the rebuilt mud pumping system. 03:00 - 07:00 4.00 RIGU P PRE Circulate out freeze protection. 07:00 - 09:30 2.50 RIGU P PRE Set BPV & pressure test to 900 psi - OK. 09:30 - 11:30 2.00 RIGU P PRE PJSM. N/D prOduction tree. 11:30 - 20:00 8.50 RIGU P PRE N/U BOP stack & install kill lines, choke line, & rams blocks (3 sets). 20:00 - 21:00 1.00 RIGU P PRE P/U & M/U test joint. 21:00 - 00:00 3.00 RIGU P PRE Pressure test BOP, et al, to BP requirements (low = 250 psi & high = 4000 psi). All BOP components pressure tested OK. Note - AOGCC represenative, Mr. John Crisp, waived witnessing the BOP testing & gave written variance to the pressure test. The variance being to test the two lower sets of rams after POH with tubing. All written correspondence is on file. 6/30/2001 00:00 - 04:00 4.00 RIGU P PRE Con't ~ Pressure test BOP, et al, to BP requirements (Iow = 250 psi & high = 4000 psi). All BOP components pressure tested OK. Note -AOGCC represenative, Mr. John Crisp, waived witnessing the BOP testing & gave written variance to the pressure test. The variance being to test the two lower sets of rams after POH with tubing. All written correspondence is on file. 04:00 - 04:30 0.50 RIGU P PRE Rig down & lay down test joint. 04:30 - 05:30 1.00 RIGU P PRE Level sub base. 05:30 - 06:30 1.00 RIGU P PRE PJU DSM lubricator & pull BPV. 06:30 - 09:30 3.00 RIGU P PRE Adjust brakes, re-position hydraulic hoses for handler link on top drive unit. 09:30 - 11:30 2.00 RIGU P PRE P/U & M/U 4 1/2" tbg spear, RIH & engauge. Back out lock down screws & pull tbg hanger & tbg free (210 k). Release Printed: 7/23/2001 11:1 O: 16 AM Page 2 of 8 BP EXPLORATION Operations Summa Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/30/2001 09:30 - 11:30 2.00 RIGU 3 PRE spear & L/D same. 11:30 - 12:30 1.00 RIGU 3 PRE POH & break out & L/D tbg hangr. Note NORM inspector on location. 12:30 - 13:30 1.00 RIGU 3 PRE R/U 4 1/2 tbg handling eqipment & tools, & R/U control line spool. 13:30 - 23:30 10.00 RIGU 3 PRE POH laying down 4 1/2" 12.6# L-80 BTC tbg. Recovered 224 jts 4 1/2" tbg (52 jts tbg, camco SSSV, 165 jts tbg, 1 pseudo-cut jt tbg, 6 jts tbg, & PBR) & 30 SS bands. 23:30 - 00:00 0.50 RIGU P PRE M/U test joint & set test plug. 7/1/2001 00:00 - 02:00 2.00 RIGU P PRE Con't ~ Set test plug & presure test lower rams (pipe & blind) to 250 psi Iow & 4000 psi high. Pressure test - OK. Pull test plug & set wear bushing. 02:00 - 05:00 3.00 RIGU P PRE Pick up BHA # 1 & RIH on gauge ring run. 05:00 - 06:30 1.50 RIGU P PRE Slip & out drilling line (100'). 06:30 - 13:30 7.00 RIGU P PRE Con't ~ RIH w/BHA # 1 on gauge ring run to 8892'. No hole problems. 13:30 - 17:00 3.50 RIGU P PRE POH & stand back drill string & BHA # 1. 17:00 - 20:00 3.00 RIGU P PRE PJSM. R/U Schlumberger. RIH w/Baker EZSV on e line. Correlate to cased hole log dated 22 Jan 1983. Set EZSV w/ top @ 8745'. 20:00 - 21:00 1.00 RIGU P PRE Rig down Schlumberger. 21:00 - 21:30 0.50 RIGU P PRE PJSM. Pressure test 9 5/8" Csg to 4000 psi for 15 minutes - OK. Note - Pressure test charted & chart is on file. 21:30 - 00:00 2.50 RIGU P PRE PJSM. M/U BHA # 2 & RIH to 122'. 7/2/2001 00:00 - 01:00 1.00 STWHIP P INT1 Load MWD. 01:00-03:00 2.00 STWHIP P INT1 RIHw/BHA#2f/122'to 1056' & shallow test MWD tools. 03:00 - 09:00 6.00 STWHIP P INT1 Con't RIH to 8741'. (stg wt = 195 k up & 160 k dn). Note - Work thrU tight spots @ 5432' & 5612' that took 10 k weight. 09:00 - 10:30 1.50 STVVHIPI P INT1 Orient whipstock 52 Deg left, set trip anchor w/15 k dn. Pull 10 k over to verify setting. Shear pins w/40 k dn weight. Whipstock @ 8741'. Note - 4' difference between wire line depth & drill pipe measurement. 10:30 - 13:00 2.50 STWHIP P INT1 Displace well to 10.7 ppg milling fluid. 13:00 - 00:00 11.00, DRILL P INT1 Mill 8 1/2" window. Top of window @ 8718', bottom of window at 8734', and mill to 8744'. (stg wt = 198 k up, 165 k dn, & 170 rot). 7/3/2001 00:00 - 03:30 3.50 DRILL P INT1 Con't ~ mill 8 1/2" window f/8744' to 8749'. Work thru window w/pumps on & off with no difficulty (top of window @ 8718' & bottom of window @ 8734') Recover est 168 # of metal from window milling operations. 03:30 - 05:00 1.50 DRILL P INT1 Pump Iow vis sweep & circulate hole clean. POH to 8664'. 05:00 - 05:30 0.50 DRILL P INT1 Perform FIT to EMW of 12.5 ppg - OK. Note - FIT test charted & chart is on file. 05:30 - 09:30 4.00 DRILL P INT1 PJSM. Monitor well - static. Pump dry job & POH. L/D BHA # 2 & mill ass'y. 09:30 - 11:00 1.50 DRILL P INT1 Clear floor & Pull wear bushing. Flush BOP stack & function test rams - OK. Reset wear bushing. 11:00 - 15:00 4.00 DRILL P INT1 P/U & M/U BHA # 3 & upload MWD tool. RIH to 908' & shallow test MWD tools - OK. 15:00 - 16:30 1.50 DRILL P INT1 PJSM. RIH picking up singles of 4" DP f/908" to 3333'. 16:30 - 18:30 2.00 DRILL P INT1 PJSM. Slip & cut drilling line. Service top drive unit & check for loose nuts & bolts after summer maintaince. Printed: 7/2312001 11:10:16AM BP EXPLORATION Page 3 of 8 Operations Summar Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of OPerations 7/3/2001 18:30 - 20:30 2.00 DRILL P INT1 Con't ~ RIH f/3333' to 8656'. Orient directional tools to 52 Deg LHS. 20:30 - 21:00 0.50 DRILL P INT1 Ream hole f/8738' to 8749'. No problems going thru window. 21:00 - 00:00 3.00 DRILL P INT1 Directional drill 8 1/2" hole w/1.50 Deg mtr f/8749' to 8810'. MWD = DIR, PWD, EWR, & GR. (stg wt = 190 k up, 145 k dn, & 170 k rot) ART = .25 Hrs & AST = 1.5 Hrs. 7/4/2001 '00:00 - 01:30 1.50 DRILL P INT1 Con't ,.. Directional drill 8 1/2" hole w/1.50 Deg mtr f/8810' to 8842'. MWD = DIR, PWD, EWR, & GR. (stg wt = 185 k up, 145 k dh, & 160 k rot) ART = 0 Hrs & AST = 1.0 Hrs. 01:30 - 04:00 2.50 DRILL N DFAL INT1 Monitor well - static. Pump dry job & POH for MWD tool failure f/8842' to 909'. 04:00 - 07:30 3.50 DRILL N DFAL INT1 Stand back BHA, down load MWD, & change out MWD componants [RLL, DM, & pulsar]. Orient motor & upload MWD. 07:30 - 08:30 1.00 DRILL N DFAL INT1 RIH to 908' & shallow test MWD tools - OK. 08:30 - 12:00 3.50 DRILL N DFAL INT1 Con't RIH f/908' to 8842'. No problem going thru whipstock. Trouble shoot MWD tools. (stg wt = 180 k up, 145 k dn, & 160 k rot). 12:00 - 13:00 1.00 DRILL P INT1 Con't ~ Directional drill 8 1/2" hole w/1.50 Deg mtr f/8842' to 8853'. MWD = DIR, PWD, EWR, & GR. (stg wt = 180 k up, 145 k dn, & 160 k rot) ART = .25 Hrs & AST = 0 Hrs. MWD tool not plusing. Monitor well - static. 13:00 - 13:30 0.50 DRILL N DFAL 'INT1 POH for MWD tool failure f/8853' to 8190'. Surge MWD tool & pump dry job. 13:30 - 17:00 3.50 DRILL N DFAL INT1 POH & stand back BHA. 17:00 - 21:00 4.00 DRILL N DFAL INT1 Down load MWD & change out pulsar. Upload MWD. 21:00 - 21:30 0.50 DRILL N DFAL INT1 RIH to 908' & shallow test MWD tools - OK. 21:30 - 00:00 2.50 DRILL N DFAL INT1 Con't ~ RIH to 6975'. Fill pipe & function test MWD tools @ 3240' & 5671'. 7/5/2001 00:00 - 01:30 1.50 DRILL N DFAL INT1 Con't ~ RIH w/MWD & directional drilling ass'y to 8853'. No problems & no fill on bottom. 01:30 - 00:00 22.50 DRILL P INT1 Directional drill 8 1/2" hole w/1.50 Deg mtr f/ 8853' to 9510'. MWD - DIR, PWD, EWR, & GR. (stg wt - 190 k up, 145 k dn, & 165 k rot) ART = 4.50 Hrs & AST = 11.0 Hrs. 7/6/2001 00:00 - 12:30 12.50 DRILL P INT1 Con't ~ Directional drill 8 1/2" hole w/1.50 Deg mtrf/ 9510' to 9873'. MWD = DIR, PWD, EWR, & GR. (stg wt = 195 k up, 145 k dn, & 170 k rot) ART = 10.50 Hrs & AST = 0 Hrs. 12:30 - 13:30 1.00 DRILL P INT1 Circulate bottoms up for samples, as per geologist. 13:30 - 14:00 0.50 DRILL P INT1 Con't .,. Directional drill 8 1/2" hole w/1.50 Deg mtr f/ 9873' to 9882'. MWD = DIR, PWD, EWR, & GR. (stg wt = 195 k up, 145 k dn, & 170 k rot) ART = 0.25 Hrs & AST = 0 Hrs. 14:00 - 15:30 1.50 DRILL P INT1 Circulate hole clean. 15:30 - 16:00 0.50 DRILL P INT1 Short trip f/TD @ 9883' into 9 5~8" csg @ 8657' w/no problems. 16:00 - 17:30 1.50 DRILL P INT1 Slip & cut drilling line, check brakes, & linkage. 17:30 - 18:00 0.50 DRILL P INT1 RIH f/8657' to TD @ 9882'. No problems. 18:00 - 20:00 2.00 DRILL P INT1 Circulate hole clean & spot liner running pill. Drop ESS. Monitor well - static. 20:00 - 00:00 4.00 DRILL P INT1 POH standing back drill string & laying down BHA. 7/7/2001 00:00 - 03:00 3.00 DRILL P INT1 Con't ~ POH & L/D BHA & MWD tools. 03:00 - 03:30 0.50 CASE P INT1 Clean floor & secure all tools. 03:30 - 04:30 1.00 CASE P INT1 PJSM. Rig up floor & csg tools to run 7" csg. Printed: 7/23/2001 11:10:16 AM BP EXPLORATION Page 4 of 8 Operations Summa Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/7/2001 104:30 - 08:30 4.00 CASE P INT1 P/U & M/U 32 jts 7" 26#, L-80, BTCM csg & RIH to 1400' & circulate liner volume. 08:30 - 14:00 5.50 CASE P INT1 Con't RIH w/4" drill pipe to 8651', filling drill pipe every 10 stands. 14:00 - 15:00 1.00 CASE P INT1 P/U & M/U cement head on DP single. Circulate one DP volume @ 6 Bbl/Min w/930 psi. (stg wt = 170 k up & 130 k dn). 15:00 - 15:30 0.50 CASE P INT1 Con't to RIH to TD @ 9882' with no problems. 15:30 - 16:00 0.50 CASE P INT1 Circulate @ 8 Bbl/Min w/1830 psi with full returns. (stg wt = 190 k up & 125 k dn) 16:00 - 18:00 2.00 CEMT P ~ INT1 PJSM. R/U Halliburton. Pump 5 Bbls H20 & pressure test pumps & lines to 4000 psi - OK. Pump 35 Bbl of 11.7 ppg spacer followed by 51 Bbls of 15.8 ppg cement. Displace w/ 133 Bbl mud & bump plug to 3800 psi & set hanger, & check floats - OK. Cement in place @ 17:40 Hrs. Rotate off hanger ass'y & shear dogs. Pressure up to 800 psi & pull out of hanger. Set 70 k down to set packer. Confirm packer setting. Float shoe @ 9880.35', float collar @ 9838.24', landing collar @ 9797.24', & liner top @ 8541.34'. 18:00 - 19:30 1.50 CEMT P INT1 Circulate hole clean. Circulate @ 10 Bbl/Min @ 2180 psi. Recovered 2 Bbl of cement contaminated mud. 19:30 - 23:00 3.50 CEMT P INT1 L/D cement head, RJD Halliburton, & pump dry job. POH & L/D running tool. Note - Pressure test Choke manifold, et al, on trip out. ^OGCC, Mr. John Spaulding, waived witnessing BOP test. 23:00 - 00:00 1.00 BOPSUI;.P INT1 Pull wear bushing & set test plug. Pressure test BOP stack, et al, as per BP standards (Iow of 250 psi for 5 min & high of 3500 psi for 10 min). BOP testing in progress at midnight. 7/8/2001 00:00 - 03:00 3.00 BOPSUF.P INT1 Complete pressure testing of all BOPE. BOPE pressure tested as per BP requirements (Iow of 250 psi for 5 min & high of 3500 psi for 10 min). All pressures charted & chart is on file. Note - AOGCC represenative, Mr. John Spaulding, was notified prior to the BPOE test & waived witnessing the pressure testing. 03:00 - 03:30 0.50 BOPSUF;.P INT1 R/D test equipment & secure all tools. Recover test plug & reset wear bushing. 03:30 - 04:00 0.50 BOPSUF.P INT1 Close blind rams & pressure test casing to 3500 psi for 30 min. Pressure test was charted & chart is on file. 04:00 - 08:00 4.00 DRILL P INT1 PJSM. P/U & M/U directional BHA # 5 & RIH picking up 17 its of HWDP to 815'. Shallow test MWD & motor - OK. 08:00 - 13:30 5.50 DRILL P INT1 Con't RIH w/4" drill pipe to 9786'. Break circulation & tag landing collar @ 9797'. (stg wt = 190 k up, 145 k tin, & 165 k rot). 13:30 - 15:00 1.50 DRILL P INT1 Drill shoe track f/9797' to 9882'. 15:00 - 16:00 1.00 DRILL P PROD1 Directional drill 6 1/8" hole w/1.15 Deg mtr f/ 9882' to 9902'. MWD = DIR, & GR. (stg wt = 190 k up, 145 k dn, & 165 k rot) ART = 1.00 Hrs & AST = 0.0 Hrs. Note - This 20' section of hole was drilled w/9.4 ppg mud & no losses were observed. 16:00 - 19:00 3.00 DRILL P PROD1 Monitor well - static. Displace wellbore to 8.4 ppg Quickdril mud system. 19:00 - 00:00 5.00 DRILL P PROD1 Directional drill 6 1/8" hole w/1.15 Deg mtr f/ 9902' to 10,061'. MWD = DIR, & GR. (stg wt = 185 k up, 150 k dn,& 165 k rot) ART = 0.25 Hrs & AST =2.50 Hrs. 7/9/2001 00:00 - 02:30 2.50 DRILL P PROD1 Directional drill 6 1/8" hole w/1.15 Deg mtr f/10,061' to Printed: 7/23/2001 11:10:16 AM BP EXPLORATION Page 5 of 8 Operations Summa Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: I Date From - To Hours Activity~ Code NPT Phase Description of Operations , , , 7/9/2001 00:00 - 02:30 2.50 DRILL P PROD1 10,206'. MWD = DIR, & GR. (stg wt = 185 k up, 150 k dn, & 165 k rot) ART = 1.50 Hrs & AST =0.0 Hrs. Lost partial returns @ 10,206'. 02:30 - 04:30 2.00 DRILL P PROD1 POH to 10,156 & monitor well. Mix & pump LCM pill. Spot pill across lost circulation interval 04:30 - 05:00 0.50 DRILL P PROD1 Monitor well - static. Note - Circulation losses = 40 Bbl. 05:00 - 13:30 8.50 DRILL P PROD1 Directional drill 6 1/8" hole w/1.15 Deg mtr fl 10,206' to 10457'. MWD = DIR, & GR. (stg wt = 200 k up, 150 k dn, & 170 k rot) ART = 4.50 Hrs & AST =0.50 Hrs. 13:30 - 15:30 2.00 DRILL C PROD1 Mix & pump high vis pill & circulate hole clean. 15:30 - 20:00 4.50 DRILL C PROD1 POH & lay down MWD / Diectional tools. Note - Trip out of hole is to plug back 6 1/8" open hole section. Fluid loss rate = 12 BPH. 20:00 - 20:30 0.50 DRILL C PROD1 Clear floor & secure all tools. 20:30 - 00:00 3.50 DRILL C PROD1 P/U & M/U 4" mule shoe& RIH on 4' drill pipe to 9031'.Note - Total fluid loss for 24 hr = 73 Bbl. 7/10/2001 00:00 - 01:00 1.00 STKOH C PROD1 RIH W/4" muleshoe to 10,457'. 01:00 - 02:00 1.00 STKOH C PROD1 Circulate while hold PJSM. 02:00 - 03:00 1.00 STKOH C PROD1 Mixed and pumped 35 bb115.8 ppg cmt kickoff plug. CIP 0245 hrs, 71912001. 03:00 - 03:30 0.50 STKOH C PROD1 R/D cement line and pulled 8 stds DP to 9707'. 03:30 - 04:30 1.00 STKOH C PROD1 Circulate. Had trace of cement in returns. 04:30 - 06:30 2.00 STKOH C PROD1 POH f/9707' - 5000'. 06:30 - 09:00 2.50 STKOH C PROD1 Cut and slip drilling line. Service top drive. 09:00 - 11:30 2.50 STKOH C PROD1 POH. L/D muleshoe. 11:30 - 14:00 2.50 STKOH C PROD1 M/U 6-1/8" sidetrack BHA. 14:00 - 17:30 3.50 STKOH C PROD1 RIH to 9709'. 17:30 - 18:30 1.00 STKOH C PROD1 Wash f/9709'- 9821'. Tagged hard cmt @ 9821'. Drilled medium cmt to 9882'. 18:30 - 22:00 3.50 STKOH C PROD1 Time drill to 9913', sidetrack well. 22:00 - 00:00 2.00 STKOH C PROD1 Drill 6-1/8" hole, sliding for change in well location. ART=O, AST=4.5 hrs 7/11/2001 00:00 - 04:30 4.50 STKOH C PROD1 Drill to 10,122'. Lost 2 bbl and shut down drilling. Refill, monitor hole and mix LCM pill. 04:30 - 05:30 1.00 STKOH C PROD1 Pumped 30 bbl, 20 ppb LCM pill (Barofibre + Liq Cs9). Est. static loss rate = 18 bbl/hr. 05:30 - 06:30 1.00 STKOH C PROD1 Pump 2nd 30 bbl, 20 ppb pill (Barofibre + LC). Lost 44 bbl while spotting at 45 SPM and 650 psi. 06:30 - 07:00 0.50 STKOH C PROD1 Soak pill. Est. losses cont. at 18 bbl/hr. 07:00 - 07:30 0.50 STKOH C PROD1 Drill ahead at 95 SPM, 1600 psi. Est. dynamic losses at 90 bbl/hr. 07:30 - 08:30 1.00 STKOH C PROD1 Drill to 10,133'w/3 bbl/min losses. 08:30 - 11:30 3.00 STKOH C PROD1 Drill to 10,221' (attempt to drill past fault zone) with cont. avg loss rate of 180 bbl/hr. ART= 0 AST=5.5 hr 11:30 - 18:30 7.00 STKOH C PROD1 POOH to 7" shoe. Monitor well w/static losses of 60 bbl/hr. Drop ball to open PBL ¢irc sub. Monitor well and mix LCM. Pump 50 bbl pill (80 ppb, OM-seal). Cont. to move pipe - 200K up, 130K dwn. (bit at 9,842', PBL at 9,684'). Spot pill, close Rams and squeeze 25 bbl away. Monitor well - hole static. Circ Printed: 7/23/2001 11:10:16 AM BP EXPLORATION Page 6 of 8 Operations Summa Report Legal Well Name: '18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 7ES Rig Number: , Date From - To Hours ActivityCode NPT Phase Description of Operations , 7/11/2001 11:30 - 18:30 7.00 STKOH C PROD1 DP to ensure LCM clear. Drop ball to close PBL. Stage up to 1900 psi on pumps. Cont. to move pipe - 200K up, 130K dwn. Chk MWD, est 500 psi loss, drop 2nd ball to close PBL. Press. up to 2,200 psi and held. Fluid level static in annulus. String apparently plugged. 18:30 - 22:30 4.00 STKOH X DFAL PROD1 POOH to 9,100', press, up DP to 3,200 psi, no circ. Cont. POOH to 815' w/wet string. Vinyl ball (opening) was unseated and against one port. Steel balls (closing) were wedged against Vynal ball. PBL ports were approx. 3/4 open. BH^ was clear of LCM below PBL. 22:30- 00:00 1.50 STKOH X DFAL PROD1 Clean floor and LD PBL. 7/12/2001 00:00 - 01:30 1.50 STKOH X DFAL PROD1 MU BHA. RIH at moderate speed, filling pipe. Test MWD at 908' - ok. 01:30 - 06:00 4.50 STKOH X DFAL PROD1 RIH to 9,873' checking fluid level in well. 06:00 - 06:30 0.50 STKOH C PROD1 Circ DP vol @ 45 SPM. Chk shot MWD. 06:30 - 07:30 1.00 STKOH C PROD1 Wash to btm, est. loss rate = 80 bbl/hr. Orient MWD. 07:30 - 17:00 9.50 STKOH C PROD1 PJSM, ck Crown Saver. Drill to 10,475'. Avg dynamic loss rate while drlg = 96 bbl/hr. 17:00 - 19:00 2.00 STKOH C PROD1 Pump 120 bbl of 9.1 ppg BaradriI-N, w/30 Ib/bbl Ca Baracarb. Allow to soak, while moving pipe. Monitor well. Static loss rate 76-92 bbl/hr. 19:00 - 00:00 5.00 STKOH C PROD1 Cont. drlg to 10,552' pumping 25 bbl sweeps every 1/2 hr of 10 ppb OM-seal + 10 ppb Barofibre. Add water while drlg and 5 sx LCM to system between sweeps. Est. avg loss rate 80 bbl/hr, decreasing in shale section. Daily ART = 5-3/4 hr, AST = 3-3/4 hr 7/13/2001 00:00 - 03:00 3.00 STKOH C PROD1 Drill 6-1/8" hole to TD of 10,607'. 03:00 - 05:00 2.00 CASE P COMP Circ 25 bbl - 20 ppb hi-vis, LCM sweep at 95 SPM and 1,400 psi While reciprocating pipe. Pipe up=255K, Dwn=130K. 05:00 - 06:00 1.00 CASE P COMP ST to 9,842', inside 7" csg, no problems, Pipe up=275-285K. Monitor well, avg. static loss = 50 bbl/hr. 06:00 - 07:00 1.00 CASE P COMP RIH to TD. 07:00 - 09:00 2.00 CASE N DFAL COMP Dropped and pumped opening vinyl ball for PBL circ. tool. Tool did not open. Drop/pump second vinyl ball, tool did not open. 09:00 - 09:30 0.50 CASE N DFAL COMP POOH to 9,855', inside 7" csg.-no probs. 09:30 - 10:30 1.00 CASE N DFAL COMP Drop Red ball and pump calc. displac, at 5 bbl/min and 1150 psi. - No press, change. Tool not open. 10:30 - 12:00 1.50 CASE P COMP Pump 60 bbl- 35 ppb OM-seal pill thru BHA at 3 bbl/min, 416 psi. Lost 31 bbl while spotting pill. 12:00 - 13:30 1.50 CASE P COMP Monitor well - static loss rate = 28 bbl/hr. Close Rams sqz 26 bbls at 1/2 bbl/min. Monitor well- static loss rate = 4 bbl/hr. 13:30 - 21:30 8.00 CASE P COMP Drop rabbit, POOH, LD BHA. 21:30 - 22:00 0.50 CASE P COMP Clear rig floor. 22:00 - 00:00 2.00 CASE P COMP PU / MU csg equip. PJSM. PU and run shoe jr, thread lock float equip., test floats- okay. 7/14/2001 00:00 - 02:30 2.50 CASE P COMP PJSM. Cont. to run 21 jts 4-1/2", 12.6 Ib/ft, L-80, IBT-M liner and accessories. 02:30 - 03:30 1.00 CASE P COMP Circ. liner volume. 03:30 - 10:00 6.50 CASE P COMP RIH w/liner to 9,833, filling 4" DP every 10 stds. 10:00 - 11:00 1.00 CASE P COMP Circ. liner + DP vol. 11:00 - 11:30 0.50 CASE P COMP Cont. RIH to 10,584'. 11:30 - 12:00 0.50 CASE P COMP Cont. RIH to 10,590', tight hole. 12:00 - 14:00 2.00 CASE P COMP Wash liner to btm from 10,590' - 10,607' TD. PU and Printed: 7/23/2001 11:10:16 AM BP EXPLORATION Page7 of 8 . Operations Summa Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: N^BORS 7ES Rig Number: Date From .To Hours ActiVity Code NPT Phase DescriPtion of Operations 7/14/2001 12:00 - 14:00 2.00 CASE P COMP reciprocate, circ. @ 2 bbl/min w/300 psi. RU cementers. 14:00 - 15:30 1.50 CEMT P COMP PJSM. Pump 5 bbl and test lines to 5,000 psi - okay. Pump 250 sx 15.6 ppg Class "G" + Latex, + adds. @ 5 bpm. Cement at shoe after 60 bbls pumped. Lost circ. at 83 bls pumped (pump press.= 2,700 psi). Decr. rate to 1 bpm, no retrns. Cont. pump at 2 bpm, bump plug. Press. up to 3,500 and set hngr. Press. up to 4,500 psi and set pkr. Chk floats - ok. PU and release from pkr. 15:30 - 18:00 2.50 CEMT P COMP Displace DP w/clean sea water and had 2 bbl of cmt returned. 18:00 - 22:30 4.50 CEMT P COMP POOH and LD DP to 4,596'. 22:30 - 00:00 1.50 CEMT P COMP Cut and slip DL (110'), service TD. 7/15/2001 00:00 - 04:00 4.00 RUNCOItP COMP Cont. POOH and LD 4" DP. 04:00 - 04:30 0.50 RUNCOItI:' COMP RU and pull Wear Bushing. 04:30 - 05:00 0.50 RUNCOItl:' COMP Press. test casing to 3,500 psi f/30 rain - ok. 05:00 - 09:30 4.50 RUNCOItl:) COMP PJSM. Run 4-1/2", 12.6 lb/fi, 13CR, L-80, VAM ACE tbg. Check and run S-3 pkr. 09:30 - 10:30 1.00 RUNCOItP COMP Adjust brakes on drawworks. 10:30 - 21:00 10.50 RUNCOItP COMP Cont. running 4-1/2", 12.6 lb/fi, 13CR tbg 21:00 - 22:30 1.50 RUNCO~I:) COMP PJSM. RU/MU control line spools and sheaves. MU lines to SSSV and test to 5,000 psi f/15 min. - ok. 22:30 - 00:00 1.50 RUNCOI~I~ COMP Cont. running 4-1/2", 12.6 lb/fi, 13CR tbg and control lines to 8,133'. 7/16/2001 00:00 - 03:30 3.50 RUNCOItl~ COMP PJSM. Cont. RIH w/4-1/2", 12.6 lb/fi, 13CR, NSCT tbg to 9,607'. (MU torque = 3620 fi-lb) 03:30 - 04:30 1.00 RUNCOItl:) COMP RD tbg equip., RU TIW to TD, chg out elevators, MU Control lines to tbg hngr. 04:30 - 06:00 1.50 RUNCOItP COMP Land tbg @ 9,607' and torque LDS to 500 fi-lb. 06:00 - 09:30 3.50 RUNCOItP COMP Circ. and pump inhibitor. 09:30 - 11:00 1.50 RUNCOItP COMP RU and press, tbg to 3,500 psi and set S-3 pkr. Hold press, f/ 30 min -ok. Bleed tbg press, to 1500 psi. Press. up annulus to 3,500 psi and hold for 30 min. - ok. Bleed off tbg press, and shear RP. RD landing joint. 11:00 - 14:30 3.50 WHSUR N DFAL COMP Install BP¥. Pull BPV due to failure to set as indicated by indicator pins. BPV did not set after multiple attempts. Lost two "O" rings after 1st two attempts. 14:30 - 15:00 0.50 WHSUR N DFAL COMP RU and pump to wash profile area. Recovered one "O" ring. 15:00 - 16:30 1.50 WHSUR N DFAL COMP Make multipe attempts to set BPV w/o success. 16:30 - 17:00 0.50 WHSUR N , DFAL COMP RU and pump to wash profile area. 17:00 - 19:00 2.00 WHSUR N DFAL COMP Make multipe attempts to set BPV w/o success. 19:00 - 20:30 1.50 WHSUR N DF^L COMP Maint. of mud pumps, while waiting on WL. 20:30 - 22:00 1.50 WHSUR N DFAL COMP RU WL. Brush profile area. Attempt to set BPV. No success. 22:00 - 23:30 1.50 WHSUR N DFAL COMP RIH w/ WL and retreive dummy valve from SSSV. Have bullnose on BPV machined down to proper taper/OD. 23:30 - 00:00 0.50 WHSUR P COMP RD WL, set BPV. 7/17/2001 00:00 - 01:00 1.00 WHSUR P COMP PTSM, PJSM. Test BPV to 2,500 psi - ok. 01:00 - 05:00 4.00 WHSUR P COMP N/D BOP stack & N/U Tubing adaptor & Xmas tree. 05:00 - 05:30 0.50 WHSUR P COMP Pressure test adaptor & Xmas tree to 5000 psi- OK. 05:30 - 06:30 1.00 WHSUR P COMP PJSM w/DSM personnel. R/U lubricator, pull BPV, & R/D lubricator. 06:00 - 06:30 0.50 WHSUR P COMP R/U to U-tube diesel and freeze protect. 06:30 - 07:30 1.00 WHSUR P COMP PJSM. R/U Hot Oil service. Freeze protect w/155 Bbls diesel. 07:30 - 09:30 .2.00 WHSUR P COMP U-tube diesel & blow down lines. 09:30 - 10:30 1.00 WHSUR P COMP Installed BPV and tested to 2500 psi. Printed: 7/23/2001 11:10:16 AM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: 18-04 Common Well Name: 18-04B Spud Date: 12/25/1982 Event Name: REENTER+COMPLETE Start: 6/25/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 ,Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/17/2001 09:30- 10:30 1.00 WHSUR ~ COMP RIG RELEASED for move to D-18A @ 1030 hrs 7/17/2001. Printed: 7/23/2001 11:10:16AM 31-Ju1-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Wel 18-04B ~© 1- O~0 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,804.14' MD 9,882.00' MD 10,607.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 0,0! Alalka Oil & Gas C,,~s. C0mmiaN0n DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~ 8, Slot ~8-04 ~8-04B Job No. AKIVIMf f f08, Surveyed: '/3 July, 2001 S UR VEY REPORT 1 August, 200'1 Your Ref: AP1.600292087502 Surface Coordinates: 5960796.07 N, 69f57f.58 E (70° f7' 50.8f92" N, Kelly Bushing: 45. lOft above Mean Sea Level 148° 26' 54.7241" HO A l-MIIIburton Gomplny Survey Ref: svy10914 Sperry-Sun Drilling Services Survey Report for 18-04B Your Reft API-500292087502 Job No. AKMM11108, Surveyed: 13 July, 2001 DEFINITIVE North Slope Alaska Measured Depth (ft) Incl. Azim. 9804.14 37.040 177.670 9882.00 33.580 178.390 9912.84 37.620 173.110 9947.85 36.610 165.070 9977.04 34.570 159.710 Sub-Sea Depth (ft) 8222.68 8286.21 8311.29 8339.22 8362.96 Vertical Depth Ct) 8267.78 8331.31 8356.39 8384.32 8408.06 10010.04 31.900 153.700 8390.57 8435.67 10041.16 28.840 145.770 8417.43 8462.53 10071.13 25.520 140.280 8444.09 8489.19 10101.18 21.020 139.020 8471.69 8516.79 10135.14 16.000 135.610 8503.88 8548.98 10165.13 13.240 12~.600 8532.90 8578.00 10196,96 9.010 114.680 8564.13 8609.23 10230.92 4.430 99.840 8597.85 8642.95 10261.26 1.500 32.180 8628.15 8673.25 10289.83 4.500 334.560 8656.69 8701.79 10324.90 9.270 322.410 8691.49 10355.32 14.010 318.740 8721.28 10383.79 18.440 320.020 8748.61 10415.28 21.730 320.590 8778.18 10444.65 21.910 320.540 8805.45 8736.59 8766.38 8793.71 8823.28 8850.55 10477.18 21.340 320.800 8835.69 8880.79 10550.77 20.720 325.300 8904.38 8949.48 10607.00 20.720 325.300 8956.97 9002.07 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) 2576.69 S 3529.25W 5958130.25 N 688109.16 E 2621.66 S 3527.69W 5958085.34N 688111.86 E 2639.54S 3526.32W 5958067.50N 688113.69 E 2660.25 S 3522.35W 5958046.89 N 688118,19 E 2676.44 S 3517.23W 5958030.85 N 688123.72 E 2693.04 S 3510.12 W 5958014.43 N 688131.25 E 2706.63 S 3502.25 W 5958001.05 N 688139.46 E 2717.57 S 3494.05 W 5957990.31 N 688147.94 E 2726.63 S 3486.38 W 5957981.46 N 688155.84 E 2734.57 S 3479.11 W 5957973.70 N 688163.31 E 2739.62 $ 3473.49 W 5957968.7-9 N 688169.05 E 2742.89 S 3468.34 W 5957965.66 N 688174.29 E 2744.23 S 3464.62 W 5957964.42 N 688178.03 E 2744.09 S 3463.26 W 5957964.59 N 688179.40 E 2742.76 $ 3463.54 W 5957965.91 N 688179.08 E 2739.28 S 3465.86 W 5957969.33 N 688176.68 E 2734.57 $ 3469.78 W 5957973.95 N 688172.63 E 2728.52 $ 3474.95 W 5957979.86 N 688167.31 E 2720.20 S 3481.85 W 5957988.00 N 688160.20 E 2711.77 S 3488.79 W 5957996.25 N 688153.05 E 2702.50 S 3496.38 W 5958005.33 N 688145.22 E 2681.41 S 3512.26 W 5958026.00 N 688128.81 E 2665.06 S 3523.59 W 5958042.06 N 688117.07 E Alaska Drilling & Wells PBU_EOA DS 18 Dogleg Vertical Rate Section Comment (°llOOft) 1280.74 Tie On Point 4.476 1323.74 Window Point 16.450 1341.09 14.146 1361.96 12.764 1378.93 12.841 1396.94 16.189 1412.36 13.873 1425.38 15.066 1436.45 15.116 1446.34 11.388 1452.95 15.346 1457.72 14.314 1460.19 13,517 1460.51 13.676 1459.16 14.147 1455.12 15.763 1449.38 15.610 1441.98 10.466 1431.85 0.616 1421.62 1.777 1410.37 2.350 1385.26 0.000 1366.10 Projected Survey I August, 2001.15:38 Page 2 of 4 Dr#lOuest 2.00.08.005 Sperry-Sun Drifting Services Survey Report for 18-04B Your Ref: AP1-500292087502 Job No. AKMMff108, Surveyed: 13 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 18 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.762° (30-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well Reference and calculated along an Azimuth of 160.910° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10607.00ft., The Bottom Hole Displacement is 4417.94ft., in the Direction of 232.898° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment 9804.14 8267.78 2576.69 S 3529.25 W Tie On Point 9882.00 8331.31 2621.66 S 3527.69 W Window Point 10607.00 9002.07 2665.06 S 3523.59 W Projected Survey 1 August, 2001.15:38 Page 3 of 4 Dt#1Quest 2.00.08.005 Sperry-Sun Drifting Services Survey Report for 18.04B Your Ref: AP!-500292087502 Job No. AKMM11108, Surveyed: 13 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 18 Survey tool program for 18-04B From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8989.10 7605.12 8989.10 7605.12 10607.00 9002.07 Survey Tool Description AK-1 BP_HG (18-04 Oyrodata) MWD Magnetic (18-04B PB1 ) 1 August. 2001 - 15:38 Page 4 of 4 DdllQ~e.qt 2.00.08.005 31-Jul-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Wel 18-04B PB1 ~_-0/'-(.~ ~) Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,689.10' MD 8,718.00' MD 10,457.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFINITI"/£ North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~8, Slot ~8-04 18-04B PB1 Job No. AKIVIMf ff08, Surveyed: 9 July, 2001 S UR VEY REPORT August, 2001 Your Reft API-500292087570 Surface Coordinates: 5960796.07 N, 69f57f. S8 E (70* f7' 50.8f92" N, f48° 26' 54.7241" W) Kelly Bushing: 45. fort above Mean Sea Level A H~lllburtofl Company Survey Ref: sw10913 North Slope Alaska Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) 8689.10 21.600 248.840 7298.24 8718.00 21.060 249.210 7325.16 8747.67 22.890 243.860 7352.68 8777.34 24.890 239.280 7379.81 8807.93 27.070 235.260 7407.31 8838.37 29.300 234.210 7434.14 8867.44 30.820 231.530 7459.30 8898.00 32.790 227.4,50 7485.27 8928.39 35.300 226.080 7510.45 8959.80 35560 225.060 7536.05 8989.10 34.628 219.614 7560.02 8994.99 34.470 218.490 7564.88 9024.94 34.850 212.490 7589.52 9054.95 33.740 208.580 7614.31 9088.54 32.110 201.350 7642.52 Vertical Depth (ft) 7343.34 7370.26 7397.78 7424.91 7452.41 Sperry-Sun Drilling Services Survey Report for fS.04B PBf Your Ref: AP1-500292087570 Job No. AKMMf1108, Surveyed: 9 July, 2001 7479.24 7504.40 7530.37 7555.55 7581.15 7605.12 7609.98 7634.62 7659.41 7687.62 9119.02 32.090 198.380 7668.34 7713.44 9145.30 31.810 196.110 7690.64 7735.74 9181.76 32.340 188.890 7721.55 7766.65 9210.89 32.400 183.370 7746.15 7791.25 9240.88 31.780 181.490 7771.56 7816.66 9274.83 31,240 181.230 7800.51 7845.61 9305.78 32.540 178.520 7826.79 7871.89 9335.33 33.710 176.510 7851.53 7896.63 9368.82 37.220 172.620 7878.81 7923.91 9399.29 40.020 170.450 7902.62 7947.72 Local Coordin~tes Global Coordinates Northings Eastlngs Northings Eastings fit) (ft) (ft) (ft) 2030.01 S 3399,69 W 5958680.06 N 688224.75 E 2033.77 S 3409.50 W 5958676.05 N 688215.03 E 2038.20 S 3419.67 W 5958671.36 N 688204.98 E 2043.94 S 3430.22 W 5958665.36 N 688194.58 E 2051.19 $ 3441.47 W 5958657.82 N 688183.51 E 2059.50 S 3453.21 W 5958649,22 N 688171.99 E 2068.29 S 3464.81 W 5958640.13 N 688160.62 E 2078.76 S 3477~04 W 5958629.35 N 688148.66 E 2090.42 S 3489,43 W 5958617.38 N 688136.57 E 2103.16 S 3502.43 W 5958604.31 N 688123,90 E 2115.60 S 3513.77 W 5958591.59 N 688112.88 E 2118.19 S 3515.87 W 5958588.94 N 688110.84 E 2132.05 S 3525.75 W 5958574.84 N 688101.32 E 2148.60 S 3534.34 W 5958560.07 N 688093.10 E 2163.11 S 3542.06 W 5958543.37 N 688085.81 E 2178.34 S 3547,56 W 5958528.00 N 688080.70 E 2191.62 S 3551.68 W 5958514,62 N 688076.92 E 2210.50 S 3555.86 W 5958495.65 N 688073.22 E 2225.99 S 3557.52 W 5958480.12 N 688071.96 E 2241.90 S 3558.20 W 5958464.19 N 688071.68 E 2259.64 S 3558.62 W 5958446.45 N 688071.71 E 2275.99 S 3558,58 W 5958430.11 N 688072.17 E 2292.12 S 3557.68 W 5958414.00 N 688073.29 E 2311.45 S 3556.01 W 5958394.73 N 688075.65 E 2330.25 S 3553.20 W 5958376.00-N 688078.94 E DEFINITIVE Alaska Drilling & Wells PBU_EOA DS 18 Dogleg Vertical Rate Section (°/'~OOft) 3918.29 1.926 3928.28 9.136 3938.96 9.189 3950.77 9.158 3964.08 Comment Tie On Point Window Point 7.505 3978.42 6.975 3992.97 9.540 4009.06 8.636 4026.03 2.056 4044.16 11.147 4060.80 11.147 4064.07 11.460 4080.48 8.219 4096.33 12.658 4112.74 MWD Magnetic 5.178 4126.61 4.693 4138.19 10.610 4153.34 10.145 4164.41 3.920 4174.98 1.640 4186.50 6.247 4196.78 5.430 4206.42 12.456 4217.17 10.207 4226.85 1 August, 2001 - 15:33 Page 2 of 4 DrillQ~est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for fS.04B PBf Your Ref: AP1.500292087570 Job No. AKMMf f f 08, Surveyed: 9 July, 2001 North Slope Alaska Meaaured Sub-Sea Vertical Local Coordinatea Global Coordin~tea Depth Incl. Azim. Depth Depth Northings Eaatlnga Northinga Eastings Ct) Ct) Ct) (~t) (it) (ft) (~t) 9427.62 39.960 170.160 7924.32 7969.42 2348.20 S 3550.13 W 5958358.14 N 688082.46 E 9462.46 39,210 171.500 7951.17 7996.27 2370.12 S 3546.59 W 5958336,32 N 688086.56 E 9493.12 38.610 172.750 7975.03 8020,13 2389.19 S 3543,95 W 5958317.32 N 688089.68 E 9522.36 38.090 173.810 7997.96 8043.06 2407.21 $ 3541.83 W 5958299.36 N 688092.26 E 9557.04 37.520 174.030 8025.36 8070.46 2428.35 S 3539.58 W 5958278.29 N 688095.05 E 9587.62 37.220 174.260 8049.66 8094.76 2446.81 S 3537.68 W 5958259.88 N 688097.42 E 9615.97 36.950 175.240 8072.28 8117.38 2463.83 S 3538.12 W 5958242.90 N 688099.42 E 9709.35 36.880 176.570 8146.94 8192.04 2519.77 S 3532.11 W 5958187.08 N 688104.85 E 9804.14 37.040 177.670 8222.68 8267.78 2576.69 S 3529,25 W 5958130.25 N 688109.16 E 9852.00 34.910 178.100 8261.41 8306.51 2604.79 S 3528,21 W 5958102.19 N 688110,91 E 9900.00 32.780 178.580 8301.28 8346.38 2631.51 S 3527.43 W 5958075.50 N 688112.37 E 9948.86 30.620 179.140 8342.85 8387.95 2657.17 S 3526.92 W 5958049.85 N 688113.54 E 10007.90 24.700 174.840 8395.12 8440.22 2684.52 $ 3525.58 W 5958022.55 N 688115.57 E 10102.15 20.070 171.540 8482,25 8527.35 2720.15 S 3521.43 W 5957987.04 N 688120.63 E 10194.87 19.280 170.480 8569.56 8614.66 2750.98 S 3516.68 W 5957956.34 N 688126.29 E 10288.56 18.100 171.080 8658.30 8703.40 2780.62 S 3511.74 W 5957926.84 N 688131.86 E 10382.29 17.270 171.920 8747.60 8792.70 2808.78 S 3507.53 W 5957898.80 N 688136.79 E 10407.36 17.140 172.970 8771.55 8816.65 2816.13 S 3506.55 W 5957891.47 N 688137.95 E 10457,00 17.140 172.970 8818.99 8864.09 2830.65 S 3504.76 W 5957877.00 N 688140.11 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.762° (30-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an AzimUth of 230.870° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10457.00ft., The Bottom Hole Displacement is 4505.1 Oft., in the Direction of 231.074° (True). 1 August, 2001.15:33 Page 3 o1'4 Dogleg Rate (°llOOft) 0.691 3.262 3.223 2.867 1.689 1.082 2.292 0.859 0.718 4.482 4.472 4.462 10.576 5.088 0.935 1.276 0.926 1.343 0.000 Alaska Drilling & Wells PBU_EOA DS 18 Vertical Section Comment 4235.80 4246.89 4256.88 4266.6O 4278.19 4288.38 4297.90 4330.10 4363.80 4380,72 4396.98 4412.78 4429.00 4448.27 4463.95 4478.91 4493.41 4497.30 450507 Projected Survey DrillCluost 2.00.08.005 Sperry-Sun Drilling Services Survey Report for fS.04B PBf Your Ref: AP1-500292087570 Job No. AKMMf f f 08, Surveyed: 9 July, 2001 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 18 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8689.1o 7343.34 2030.01 s 3399.69 W Tie On Point 8718.00 7370.26 2033.77 S 3409.50 W Window Point 10457.00 8864.09 2830.65 S 3504.76 W Projected Survey Survey tool program for 18-04B PBf From To Measured Vertical Measured Vertical Depth Depth Depth Depth fit) fit) (ft) fit) 0.00 0.00 8989.10 7605.12 8989.10 7605.'12 10457.00 8864.09 Survey Tool Description AK-1 BP_HG (18-04 Gyrodata) MWD Magnetic (18-04B PB1) 1 August, 2001 - 15:33 Page 4 of 4 DrtllQuest 2.00.0R.005 ~KA OIL A~D GAS CONSERVA~ION C0PlPl~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 18-04B BP Exploration (Alaska) Inc. Permit No: 201-090 Sur Loc: 1067' SNL, 191' WEL, SEC. 24, TllN, R14E, UM Btmhole Loc. 1371' NSL, 3683' WEL, SEC. 24, T1 IN, R14E, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill dOes not exempt you from obtaining additiOnal Permits required by law from other governmental agencies, and does not authorize conducting drilling operations until' all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager, at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~3/~day of May, 2001 jjc/Enclosures CC: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAsKAi'..,L AND GAS CONSERVATION COMI~,oSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill 6il Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 49.6' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028307 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1067' SNL, 191' WEL, SEC. 24, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1403' NSL, 3686' WEL, SEC. 24, T11N, R14E, UM 18-04B Number 2S100302630-277 At total depth 9. Approximate spud date 1371' NSL, 3683' WEL, SEC. 24, T11N, R14E, UM 05/29/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028308, 1371' MDI No Close Approach 2560 10542' MD / 8974' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8735' MD Maximum Hole Angle 48 ° Maximum surface 3488 psig, At total depth (TVD) 8255' / 3200 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 8-1/2" 7" 26# L-80 IBT-M 1248' 8585' 6722' 9833' 8305' ;)46 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 942' 9600' 8091' 10542' 8974' 135 sx Class'G' '- 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11232 feet Plugs (measured) PBTD Tagged at 11148' (10/98) true vertical 8878 feet Effective depth: measured 11148 feet Junk (measured) Fish (See Diagram) in tubing true vertical 8869 feet Casing Length Size Cemented MD 'I-V[~ Structural Conductor 80' 20" 1850# Poleset 80' 80' Surface 2573' 13-3/8" 2240 sx Fondu, 400 sx Permafrost 'C' 2629' 2596' Intermediate Production 9673' 9-5/8" 500 sx Class 'G', 300 sx Permafrost 9729' 8349' Liner 654' 7" 288 sx Class 'G' 9423' - 10077' 8047' - 8694' Liner 1928' 2-7/8" 64 sx Class 'G' 9299' - 11227' 7925' - 8878' Perforation depth: measured 10485' - 10795', 10885' - 11150' true vertical 8798' - 8851', 8852' - 8869' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Scott, Kolstad, 564-5347 Prepared By Name/Nurnbec Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone c.__----~.,_,_-.~.~. ~ Title Senior Drilling Engineer Date ' .i'.'"::":':.".:.' .:'.'.:;:; ;:';:" "' ?;'.':.;':";~: ..: i:"'": :'.'.:. ::..::.:': ':;.":.': :;'i':..:;.':.:'.:'''~' ..:'":'"":; ? ::~' "..?':':.'.!i!:::'!'':',:.'?!.':':.?:.' ":'?:?¢~.lS.~i:On...':' ~eO, nit:,.; :.:.:. ;;':'.::i::::'.::.i'.;.:..;!.i:"' '.::;.:i.:.:... ;.:::::ii::.:. ;.:..,;.: ,.i.'.,. :::. :::.:.....;: ?i!:.::;"i.;..';. ::' ':"":=.':.:i.: ::: :i' !..;: ?'.::' :' '..';, ;' .~:. ::.:;.:.:. :..::; :.:: :'::.:..: :: Permit Number I APl Number I Approval Date I See cover letter =¢?- o I I ,5. ¢,. / I for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required ,~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K []4K [] 5K [] 1OK [] 15K [] 3.5K psi for CTU · Dy oroer Of ,Approved By '"'~ ?'avlor Seamount . . Commissioner the commission Date ,~---/. ~ ""~-~ / Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: 118-04B Drill and Complete Plan Summary I Type of Well (service / producer /injector): I Producer Surface Location: Target Location: Ivishak Sands Bottom Hole Location- X = 691,571.58 Y = 5,960,796.07 4,212' FSL 191' FEL T 11N, R 14E, S 24 Umiat X = 688,150 Y = 5,957,900 1,403' FSL 3,686' FELT 11N, R14 E, S24 Umiat X = 688,153.98 Y = 5,957,868.13 1,371' FSL 3,683' FELT 11N, R 14E, S24 Umiat I AFE Number: 14J0474 I Estimated Start Date: 1 5/29/2001 I MD: I~ 0,542' I ITVD: 18,974' I I Rig: I Nabors9ES I Operating days to complete: I 18.6 I GL/MSL: 21.1' I IRKB: 149.6' I Well Design (conventional, slimhole, etc.): I Conventional Sidetrack I Objective: I Ivishak Zone 1 Mud Program: 8 1/2" Intermediate hole: Freshwater LSND Interval Density Viscosity YP PV Tauo pH HTHP (ppg) (seconds) (Ib/100ft2) Filtrate Milling 10.6 40 - 60 30 - 35 10 - 15 4 - 8 8.5 - 9.5 KOP to ,,9~K'-,9':6"40 - 55 20 - 27 10 - 15 3 - 7 8.5 - 9.5 < 10 cc TSGR I,O,(.o 6-1/8" Production hole: QuickDril N Interval Density Viscosity YP PV Tau0 pH (ppg) (seconds) (lb/100ft2) Sag River 8.3 - 8.5 45 - 55 20 - 25 5 - 8 4 - 8 8.5 - 9.0 to TD Directional'. KOP: I-8,735' MD Maximum Hole Angle: 48° Close Approach Wells: All wells pass close approach guidelines 18-04B Permit to Drill Page 1 Logging Program: Intermediate Hole Production Hole Drilling: MWD / GR / Res / PWD Open Hole: None Cased Hole: None Drilling: MWD / GR Open Hole: None Cased Hole: None Formation Markers: Formation Tops MDbkb TVDss Comments UG1 5,445' WS2 5,980' WS1 6,180' CM3 6,42O' CM2 6,860' KOP 8,735' 7,329' KOP at base of CM2. CMl 8,822' 7,410' 25' vertical uncertainty HRZ 9,385' 7,860' 25' vertical uncertainty Put River Sands 9,681' 8,115' 25' vertical uncertainty 4,100 - 4,300 psi. Possible gas LCU / Kingak 9,730' 8,160' 25' vertical uncertainty SGR 9,833' 8,255' 3,200 psi, 25' vertical uncertainty SHB 9,887' 8,305' 3,200 psi, 25' vertical uncertainty SAD / Zone 4 9,946' 8,360' 3,200 psi, 25' vertical uncertainty Zone 3 10,073' 8,480' 3,200 psi, 25' vertical uncertainty Zone 2 10,173' 8,575' 3,200 psi, 25' vertical uncertainty Zone 1 10,379' 8,770' 3,200 psi, 25' vertical uncertainty Base Sadlerochit 10,442' 8,830' 3,200 psi, 25' vertical uncertainty TD 10,542' 9,944' Casin!/Tubinq Proqram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/I'VD MD/TVD bkb 8 Y2" 7" 26# L-80 IBTM 1,248' 8,585'/6,722' 9,833'/8,305' 6-1/8" 4 Y2" 12.6# L-80 IBTM 942' 9,600' / 8,091' 10,542'/ 8,974' Tubing 4 Y~" 12.6# 13 Cr- Vam 9,600' Surface 9,600'/8,091' 80 Ace 18-04B Permit to Drill Page 2 Cement Calculations: Casin(. Size 17" Liner Basis: Lead: None Lead TOC: N/A I Total Cement Volume: Tail: Based on fully cemented liner with 150' liner lap, 30% excess in the open hole, 82' shoe track, and 200' of cement in the 4" DP x 9 5/8" annulus. Tail TOC: at the top of the liner: 8,585' MD, 6,722' TVDbkb Tail 51 bbls / 287 ifa/246 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. Casin.c Basis: Size 14 Liner Lead: None Lead TOC: N/A Tail: Based on a fully cemented liner with 50% excess, 82' shoe track, and 200' of cement in the DP x 7" annulus. Tail TOC: 9,600' MD, 8,091' TVDbkb I Total Cement Volume: I Lead Tail J N/A J28 bbls / 157 ftc/135 sks of Dowell Premium 'G' with latex at 15.8 ppg and 1.17 of/sk. Well Control: For intermediate and production hole drilling, well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3;590 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Max. anticipated BHP (PTR): · Max. surface pressure (PTR): · Max. anticipated BHP (SGR): · Max. surface pressure (SGR): · Planned BOPtest pressure: · Planned completion fluid: 4,300 psi (10.2 ppg) @ 8,115' TVDss- Put River Sands 3,488 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) 3,200 psi (7.5 ppg) @ 8,255' TVDss - Sag River Sands 2,375 psi @ surface 3,500 psi ~ 0 ~ (~ l%" ~-,,o\ ~ \t-,,'~ e.~,,~ ¢,,,~, sea water / 2,200' of 6.8 ppg Diesel 18-04B Permit to Drill Page 3 Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · Drill Site 18 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H2S recently measured on DS 18: Closest surface location measured recently: Recent data from nearest BHL: 16 ppm from 18-02, 5/8/99. 14 ppm from 18-19, 5/7/99. 4 ppm from 18-29, 12/2/96. DRILLING CLOSE APPROACH: · All wells pass BP close approach guidelines. Disposal' · · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. 18-04B Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slickline, drift and tag. 2. RU coil tubing and P&A perforations. 3. Liquid pack the tubing and 9-5/8" x 4 Y2" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing to 3000 psi for 30 minutes. 4. RU E-line. Cut the 4 1/2,, tubing at _ 9,000' in the middle of a joint. 5. Test the FMC 9-5/8" packoff and tubing hanger seals. 6. Bleed casing and annulus pressures to zero. 7. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q 1. 2. 3. 4. 5. Operations: MIRU Nabors 9ES. Circulate out freeze protection and displace well to sea water. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull 4 Y2" tubing from cut. MU window milling BHA and drift down to the BP setting depth. Set BP on E-line (set as needed to avoid cutting casing collar). 6. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 9 5/8" casing at _ 8,750' MD. POOH. 7. Kick-off and drill the 8 Y~" section to the top of the Sag River as per the directional plan. 8. Run and cement a 7", 26#, L-80 liner. 9. Pick up 6 1/8" drilling BHA. Pressure test liner. RIH and drill out float equipment. Displace well to QuickDril. 10. Drill 20' of new formation and perform FIT to 8.5 ppg EMW. 11. Drill 6 1/8" hole to 100' below the base of zone 1. 12. Run and cement a 4 Y2", 12.6#, L-80 solid production liner to TD. Leave perf pill in liner, displace well to clean sea water above liner top. POOH. 13. Test the 4-1/2", 7", and 9 5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 14. Run 4-1/2", 12.6#, 13Cr gas lift completion tying into the 4-1/2" liner top. 15. Set packer and test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. Shear RP valve. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to 2,200'. 18. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 2. Run CNL. 3. Install gas lift valves. 4. Perforate. 18-04B Permit to Drill Page 5 Job 1- MIRU Hazards and Contingencies ~ Well 18-03 and 18-05 are located 120.52' and 120' from 18-04 respectively. These wells should not require the well houses to be removed and therefore will not need to be shut in. Reference RPs · :- "Drilling/Work over Close Proximity Surface and Subsurface Wells Procedure" Operational Specifics Job 2' Decomplete Well Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 3: Run Whipstock Hazards and Contingencies ~ Cement is expected behind the casing at the window depth. The estimated top of cement outside the 9 5/8" casing is 8,322' based on 30% washout in the 12 ~,~" original hole. Reference RPs Operational Specifics Job 4: Drillinq Intermediate Hazards and Contingencies > The 18-04B well path will drill through the Put River formation that is expected to be at or near the virgin reservoir pressure of 4,100 - 4,300 psi (10.2 ppg EMW). Gas could be present in the Put River sands. Gas cut mud is possible in the Put River formation. This pressure will be controlled with the appropriate mud weight. 18-04B Permit to Drill Page 6 One fault crossing is expected in the Kingak Shale. No lost circulation is expected. The 18-04B well path will drill full sections of the HRZ and some Kingak shale. Both of these formations have been troublesome and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. The kick tolerance for the 8 Y2" section would be infinite assuming an influx from the Put River formation at -9,681' MD. This is a worst case scenario based on a 10.2 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 9 5/8" window, and 10.6 ppg mud in the hole. Reference RPs Operational Specifics Job 5: Install 7" Intermediate Liner Hazards and Contingencies ~ Long shale intervals will be exposed while running the liner. 10.6 ppg mud weight and fluid loss additives will be used to control well bore stability. Differential sticking could be a problem in the Put River if the pipe is left stationary for long periods. Minimize the time the pipe is left stationary while running the liner. Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight to set the packer. Check with Baker for the maximum down weight. If the stinger is pulled out of the liner top prior to setting the packer, POOH to remove the stinger prior to setting the packer. Reference RPs Operational Specifics Job 6: Drillinq Production Hole Hazards and Contingencies ~ The 18-04B target is a graben (down thrown) fault block surrounded on all sides by faults. Fault throws around the target area vary from 20' to 30'. No fault crossings are anticipated, however there could be sub-seismic or unmapped faults that could cause lost circulation. These sub-seismic faults should be expected throughout the section particularly while drilling through the Shublik. Other DS 18 offset wells experienced lost circulation in the area. To be prepared for any potential lost circulation, a copy of the 18-04B Permit to Drill Page 7 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling the production interval. Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the Sag River or Ivishak Sands. The kick tolerance for the 6 1/8" production section would be infinite assuming an influx from the Shublik formation at -9,887' MD. This is a worst case scenario based on a 7.5 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" shoe, and 8.5 ppg mud in the hole. Reference RPs Operational Specifics Job 7: Install 4 ~2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem in the Sag River and Ivishak sands. Minimize the time the pipe is left stationary while running the liner. Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight to set the packer. Check with Baker for the maximum down weight. If the stinger is pulled out of the liner top prior to setting the packer, POOH to remove the stinger prior to setting the packer. Reference RPs Operational Specifics Job 8: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs Operational Specifics 18-04B Permit to Drill Page 8 Job 9: ND/NU/Release Riq Hazards and Contingencies ~ See hazards related to the MIRU in Job 1. Reference RPs Operational Specifics 18-04B Permit to Drill Page 9 TREE= MCEVOY GEN 3 WELLHEAD= MCEVOY ACTUATOR= AXELSON KB. ELEV = 49' BE ELEV = ? KOP = 2100' Max Angle = 92 @ 10505' Datum MD = 10986' Datum TVD= 8800' SS 18-04A SAFETY NOTES: WAIVEREDWELL- NOAC PROBLEMS. 2204' ~--~ 4'1/2" CAMCO BAL-O'SSSV NIP'lID = 3.813" 13-3/8" CSG, 72/I, L-80, ID =12.347" H 2629' IMinimum 13 = 2.372"@ 9303' "PT" LANDING NIPPLE I TOPOF 2-7/8" LNP, H 9303' FISH- 1-1/4"X E' PLUGBODY MN ID= I I .527" 8/18/99 9303' H XO3-1/Z'X2-7/8"I 9351' H 4'1/2 BAKER PBR ASSY (BEHIND LINER) I I TOPOF 7"LNR H 9423' I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" H 9477' I 9-5/8" CSG, 47#, L-80, ID= 8.681" H 9729' 9368' 9464' 9476' 9477' I 9453' 9-5/8" X 4-1/2" BAKER SAB PKR(BEHIND LNR) I -I 4-1/Z' CAMCO DB-6 LANDING NIP I I (BEHND LNR), ID = 3.687" 4-1/2" BAKER SHEAROUTSUB (BEHNDLNR) 4-11Z' TUBING TAIL (BEHIND LINER) ELIVlD 03/17/88 PERFORATION SUMMARY REF LOG: BHS ON 01123/83 ANGLEATTOP PERF: 91 @ 10485' Note: Refer to R'oductJon DB for historical perf data SIZE SPF INTERv'AL OprVSqz DATE 2 10485-10795 O 05/16/98 2 10885-11150 O 05/16/98 i MILLOUT WINDOW 10075-10082 I I 11202' H 2-7/8" BAKER FLOAT SHOE 7"LNR, 29#, L-80,0.0371 bpf, ID=6.184" H 10334' I 2-7/8" LNR, 6.5#, FL4S, 0.00579 bpf, ID = 2.441" H 11225' H DATE REV BY COMIVENTS 01/27/83 ORIGINAL corvPLEFION 05/18/98 LAST WORKOVER 01/02/01 SIS-Isl CONVERTED TO CANVAS 02/07/01 SIS-LG REVISION 05/02/01 RN/KAK CORRECTIONS PRLDHOE BAY UNIT WELL: 18-04a PERMIT No: 98-028 APl No: 50-029-20875-01 SEC 24,TIIN, R14E 4876.21 FEL 3020.7 FNL 13P Exploration (Alas ka) 'Ompletion ' GL Elevation = 22.1 Nabors 9ES RKB = 50.6' 13 3/8", 72 #/ft, L-80 2629' I LinerTop at I +/-8,600' I 4-1/2" 'BaI-O' Wireline retrievable SSSV 2200' 4-1/2" 12.6# 13 Cr-80, New Vam Tubing 4-1/2" x 1-1/2' (lowermost = 1") Camco 'MMG' Gas Lift Mandrels with handling pups installed above and below. GAS LIFT MANDRELS ' IVD ! Size Valve Type -- , I ' r 1-1/2- RP Shear 2 ' 1-1/2" DV 3 ' 1-1/2" DV ' 1" DV 4 (or 1 jt above packer) I I BAKER 9 5/8" x 7" ZXP Liner Top Packer and Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +/- 8,763' MD Bridge Plug set at +~-8,784' MD 4-1/2" 'X' Landing Nipple 7" x 5" Baker 'S-3' Packer 4-1/2" 'X' Landing Nipple 4-1/2" 'XN' Landing Nipple, 3.75" ID 4-1/2" Liner top packer 10,640, and hanger 7" 26#/ft L-80 BTCM 19,835, 9-5/8", 47 #/ft, L80, BTC I 9,729' I TOC at +/-10,385' MD Top Perforation at +/-10,485' MD PRUDHOE BAY UNIT WELL: 18-04B APl #: 50-029-20875-02 4-1/2' 12.6 #/ft, L-80, IBT-M 11o,482' I Date Revised by Comments 05/07/01 SRK Proposed completion DS18-04B Proposed Well Profile - Geodetic Report Schlumberger Report Date: May 8, 2001 Client: Alaska Drilling & Wells Reid: Prudhoe Bay Unit - EOA (Drill Sites) Structure I Slot: DS-18/18-04,orohole:Well: 18-04B18-04F®aSi itY UWlIAPI#: 500292087502 Survey Name I Date: 18-04B (P4) / May 8, 2001 Tort I AHD I DDI I EnD ratio:166.153° / 4795.32 ff / 5.971 / 0.534 Grid Coordinate Sy,tem: NAD27 Alaska State Planes, Zone 4, US Feet Location Lat/Long: N 70 17 50.819, W 148 26 54.724 Location Grid N/E Y/X: N 5960796.070 flUS, E 691571.580 flUS Grid Convergence Angle: +1.46067647° Grid Scale Factor: 0.99994169 Survey I DLS Computation Method~Minimum Curvature / Lubinski Vertical Section Azimuth: 188.330° Udy Vertical Section Odgln:N 0.000 ft, E 0.000 ft TVD Reference Datum: KB 'I'VD Reference Elevation: 49.6 ft relative to MSL Magnetic Declination: 26.812° Total Field Strength: 57490.978 nT Magnetic Dip: 80.810° Declination Date: May 07, 2001 Magnetic Declination ModeI:BGGM 2000 North Reference: True Nodh Total Corr Mag North -> True North~26.812° Local Coordinatea Referenced To.Well Head Station ID Tie In Survey Top Of Window Base Whipstock KOP Crv 8/100 I MD I Inc' I Azim I TVD I VSoc I N/'S I E~W I DLs 8693.60 21.00 248.00 7340.36 2541.75 -2074.06 -3379.24 0.00 8735.00 20.27 248.79 7379.10 2549.03 -2079.44 -3392.80 1.88 8751.00 21.30 244.21 7394.06 2552.03 -2081.70 -3398.00 12.00 8763.00 21.30 244.21' 7405.24 2554.47 -2083.60 -3401.93 0.00 Grid Coo~inates Northing I Ea,ting (~us) (~us) 5958636.67 688246.51 5958630.95 688233.09 5958628156 688227.95 5958626.56 688224.07 Geographic Coordinates Latitude I Longitude N 70 17 30.413 W148 28 33.200 N 70 17 30.360 W148 28 33.595 N 70 17 30.338 W148 28 33.746 N 70 17 30.320 W148 28 33.861 CMl 8800.00 22.11 236.50 7439.63 2562.88 -2090.37 -3413.79 8.00 5958619.49 688212.39 8821.60 22.74 232.29 7459.60 2568.60 -2095.17 -3420.48 8.00 5958614.52 688205.82 8900.00 25.85 218.99 7531.10 2594.24 -2117.74 -3443.24 8.00 5958591.38 688183.65 9000.00 31.14 206.34 7619.04 2637.65 -2157.92 -3468.47 8.00 5958550.57 688159.45 9100.00 37.32 197.28 7701.73 2692.27 -2210.12 -3488.98 8.00 5958497.87 688140.28 N 70 17 30.253 W148 28 34.206 N 70 17 30.206 W148 28 34.401 N 70 17 29.984 W148 28 35.064 N 70 17 29.588 W148 28 35.799 N 70 17 29.075 W148 28 36.396 End Crv Crv 7/100 Top HRZ 9200.00 44.02 190.55 7777.57 2757.04 -2273.33 -3504.37 8.00 5958434.29 688126.51 9256.38 47.94 187.45 7816.74 2797.56 -2313.36 -3510.67 8.00 5958394.12 688121.23 9262.07 47.94 187.45 7820.56 2801.78 -2317.55 -3511.22 0.00 5958389.91 688120.79 9300.00 45.35 186.69 7846.59 2829.35 -2344.92 -3514.62 7.00 5958362.47 688118.08 9385.40 39.52 184.71 7909.60 2886.88 -2402.21 -3520.39 7.00 5958305.05 688113.78 N 70 17 28.453 W148 28 36.843 N 70 17 28.059 W148 28 37.026 N 70 17 28.018 W148 28 37.042 N 70 17 27.749 W148 28 37.141 N 70 17 27.185 W148 28 37.308 9400.00 38.53 184.32 7920.95 2896.06 -2411.38 -3521.12 7.00 5958295.87 688113.28 N 70 17 27.095 W148 28 37.329 18--04B (P4) report.xls Page 1 of 2 5/8/2001-12:16 PM Grid Coordinatee Geo~lraphlc Coordinatee I Station ID I MD I Incl I A~im I TVD I VSec I N/-S I E/-W I OLS No~lng I Eaetlng LatitudeI Longitude 9500.00 31.77 181.12 8002.67 2953.31 -2468.83 -3523.98 7.00 5958238.37 688111.89 N 70 17 26.530 W148 28 37.412 9600.00 25.13 176,42 8090,55 3000.27 -2516,40 -3523.17 7.00 5958190.84 688113.91 N 70 17 26,062 W148 28 37.388 End C~ 9632,80 23.00 174,34 8120.50 3013,30 -2529.73 -3522,10 7.00 5958177,54 688115.32 N 70 17 25.931 W148 28 37.356 TPTR 9680.71 23.00 174,34 8164,60 3031.47 -2548.36 -3520.26 0.00 5958158.96 688117.63 N 70 17 25.748 W148 28 37.303 LCU / Kingak 9729.59 23.00 174.34 8209.60 3050.00 -2567.37 -3518.37 0.00 5958140.01 688120.01 N 70 17 25.561 W148 28 37.247 Top Sag 9832,79 23,00 174.34 8304.59 3089.13 -2607.49 -3514,40 0.00 5958100.01 688125.00 N 70 17 25.167 W148 28 37.131 Tgtl/7"Csg Pt 9832,80 23.00 174.34 8304,60 3089,13 -2607,49 -3514.40 0,00 5958100.01 688125.00 N 70 17 25.167 W148 28 37,131 Drp 4/100 9862.80 23.00 174.34 8332,22 3100.51 -2619.16 -3513.24 0.00 5958088.37 688126.45 N 70 17 25,052 W148 28 37.097 Top Shublik 9887.03 22.03 174.34 8354.60 3109.51 -2628,39 -3512.33 4.00 5958079.17 688127.60 N 70 17 24.961 W148 28 37.070 9900.00 21.51 174.34 8366.65 3114.18 -2633.18 -3511.85 4.00 5958074.39 688128.20 N 70 17 24.914 W148 28 37.056 Top Sad/Z4 9945.89 19.68 174.34 8409.60 3129.84 -2649.24 -3510.26 4.00 5958058.38 688130.20 N 70 17 24.756 W148 28 37.010 End Drp 9969.40 18.74 174.33 8431.81 3137.35 -2656.94 -3509.50 4.00 5958050.70 688131.16 N 70 17 24.680 W148 28 36.988 Top Z3 10072.67 18.74 174.33 8529.60 3169.53 -2689.95 -3506.22 0.00 5958017.79 688135.28 N 70 17 24.356 W148 28 36.891 Top Z2 10172.98 18.74 174.33 8624.60 3200.80 -2722.01 -3503.04 0.00 5957985.82 688139.27 N 70 17 24.040 W148 28 36.798 Top Z1B 10378.90 18.74 174.33 8819,60 3264.97 -2787.83 -3496.51 0,00 5957920,19 688147,48 N 70 17 23,393 W148 28 36.607 Base Sad 10442.24 18,74 174.33 8879,59 3284.71 -2808.08 -3494.50 0,00 5957900,00 688150.00 N 70 17 23.194 W148 28 36.548 Tgt2 10442.25 18.74 174.33 8879.60 3284.72 -2808,08 -3494.50 0,00 5957900,00 688150.00 N 70 17 23.194 W148 28 36.548 TD/4-1/2"Lnr Pt 10542.25 18.74 174.33 8974.30 3315,88 -2840,04 -3491.33 0,00 5957868,13 688153.99 N 70 17 22,880 W148 28 36.456 Le.qal Description: Surface: Tie-In: Tgt 1 : Tgt 2: BHL: 4212 FSL 191 FEL S24 T11N R14E UM 2137 FSL 3571 FEL S24 T11N R14E UM 1603 FSL 3706 FEL S24 T11N R14E UM 1403 FSL 3686 FEL S24 T11N R14E UM 1371 FSL 3683 FEL S24 T11N R14E UM Nodhin~ (Y)[ffUS1 Eastin~ CXi[ffUSl 5960796.07 691571.58 5958636.67 688246.51 5958100.00 688125.00 5957900.00 688150.00 5957868.13 688153.98 18--04B (P4) report.xls Page 2 of 2 5/8/2001-12:16 PM Client: Alaska Drillirg & Wells Well: 18-04B (P4) Field: Prudhoe Bay Unit - Structure: DS-18 Sectic~ A~: 188.33 dag Date: May 08, 2001 Schlumberger O >> Top Of Wlndow 0735MD 7379TVD ~ [ i Base Whip,rock 0751 MD 7394TVD ~.,,~'~ { 21.30' 244,21' az 2552 del arture ~ - --~, .......... ~ ....... j ...... _ ........ KOP Crv 8/100 8763 MD 7405 'fVD / %k Eni Crv 9256 MD 7817 TVD 2130" 24421°az 2'54departure I 47.!;~4" 187.45°az 2798departure ....... ~-~ ~'~"~,~ D'~) .......................... ..... .......... '""~ .................................................................... .......................... [ '~ J _ End Crv 9633 MD 8120 'fro ~ ,.-.-¢,,~ ~.~. ~.,.~,..,- ~ ~ J r~, _ Tgt '11 ?' :ag Pt 9833 MD 8305 -- --I~TT~ ,.~f~3T~ViL~(~O tV,..~- ..... i ........ J ~.-- -- ~23'~° 4~'34~az"~089~ep~ - m~,~m ~ .... i ........ k%~ ........... i j A%)z~k _ D~4/100 9863MD 8332TVD -- "?jp~"~.~ ~..~ ..... i ....... "~,,'~.._...--,~'-=""'"--~ 23~9~'"'174.'3~az'310'l'depaftur~' ! i % Tgt2 10442MD 88;0T : I ! j ~, / 18.74° 174.33' az ; i i TD ' 4-1'2" Lnr Pt ; i j 10542 MD 8974 'rVD I 18.74° 174,33° az j i i 3316 departure i ........................................................ ~ ................................................................................................................................................... EDO 2000 2 ~ .~ ~q~ 7000- 7500. 8000: 8500. 9000. 9500. Vertical Section Departure at 188.33 deg from (0.0, 0.0). (1 in = 500 feet) Client: Alask~ Drilling & Wells Well: 18-04B (P4) Field: Prudhoe Bay Unit - 5~A Structure: DS-18 Scale: 1 in = 500 ft E~te: 08-May-2001 Schlumberger A A A 0 V V V -30001 True North Mag Dec ( E 26.81° ) Base Whlpsto~:k 8751 MD 7394 TVD 21.30° 244.21' az 2082 S 3398 W KOP Crv 8/100 87~ MD 7405 TVD 21.30° 244.21° az L:084 S 3402 W 18.04 Tie In Sun/ey ~ 7340 3VD 21,00° 248.00° = 2074 S 3379 W 7379 'IVD 20.27° 248.79° az 3393 W = End CW 9256 MD 7817 TVD 47.94° 187,45° az 2313 S ~Crv 71100 9262 MD 7821 TVD i~47,94° 18L45°az 2318S I W E.dc. 812o~ Fadlt Line at 8300 T DBKB ......... Tgt2 1 2MD 8880'IA/D / i J J~- TD 1 4-112" Lnr Pt i 2840 S 3491 W -3200 .3~J00~ <<< WEST EAST >>> 04/lC2/01 001881~9I H 1 881 29 i' l'i' VEN[N3R ALASKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 041801 CKO41801D 100. O0 100. O0 PYMT ;OMMENTS: Peri,it to Drill l:ee HANDL NO INST: S/H- Terrie Hub)le X4&28 rilE A~ACHED CHECK IS IN PAYME~ FOR ~MS DE~RIBED A~VE. i(O]f'-ll -*m 1 OO. O0 1OO. OO ,4NCHOR'C~O.E AK~ :.~'50.1 · . CONSOLIDATED COMMERCIAL::',~CCOUNT,'. · . NOT. YALI[~',,~F'rER 120'DAYS ,;ii , , WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION :~.R D,STE/ INIT CLASS ENGINEERING WELL NAMF_~Z,f/g'~ PROGRAM: exp 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOLAREA Y N Y N Y N Y N Y N Y N Y N. Y N Y N Y N Y N Y N N Y Y Y dev ~ redrll ~ serv. wellbore seg 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ....... ; ..... 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ann. disposal para req UNIT# ON/OFF SHORE NJ N N N 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. JJ GEOLOGY 30. P~rmit can be issued wlo hydrogen sulfide measures ...... Y N I1~----" ' 31. Data presented on potential oVerpressure zones ....... Y ~/' .h /./7 ' 32. seismic analysis of shallow gas zones ........ ..... Y//N R D,~TF_/ 33. Seabed condition survey (if off-shore), ............ . //Y N ' ' ~ ~.~.//?/,~? 34. Contact name/phone for weekly progress reports [exploratory o~] Y N I1~ D~-~'OSAL--~. ~---~'~ pr~~ ~ t'~p~-~ ' ' APPR DATE (A) will contain waste in a sUitable receiving zone; ....... GEOLQGY: y N¸ (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the Well used for disposal; Y' N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will n. ot circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING:. ' UICIAnnular COMMISSION: Comments/Instructions: ,, Z -.I -I- c:~nsoffice\wordian~diana~checklist (rev. 11101//00) 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 APPEN. DIXi .. No'special'effort has been made to chronologically.' . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Feb 05 22:03:35 2002 1804B.tapx Reel Header Service name ............. LISTPE Date ..................... 02/02/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/02/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-ii108 C. ASUCHAK R. BORDES 18-04B 500292087502 BP Exploration (Alaska), Inc. Sperry Sun 29-JAN-02 MWD RUN 3 MWD RUN 4 AK-MM-Ii108 AK-MM-ii108 C. ASUCHAK C. ASUCHAK R. BORDES M. ANTHONY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 AK-MM-II108 R. KRELL J. RALL MWD RUN 6 MWD RUN 7 AK-MM-iI108 AK-MM-Ii108 R. KRELL R. KRELL J. RALL J. RALL 24 lin 14E 1067 191 .00 45.10 16.10 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8718.0 8.500 7.000 9882.0 Page 1 RENLARKS: 1804B.tapx 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY FOR SETTING WHIPSTOCK AND IS NOT PRESENTED. 3. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. MWD RUNS 5 - 7 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5. DATA FOR MWD RUN 2 IS NOT PRESENTED DUE TO A TOOL FAILURE. THE DATA WAS COLLECTED DURING THE TRIP IN ON MWD RUN 300. 6. MWD RUN 5 DRILLED WELL 18-04BPB1 AND ONLY THE SGRD DATA BEHIND CASING IS PRESENTED FOR THIS RUN ON WELL 18-04B. 7. GAMMA RAY (SGRC) LOGGED BEHIND CASING TO 8718' MD, 7370' TVD. 8. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 9843' MD, 8300'TVD TO 9882' MD, 8331' TVD. DIGITAL AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF PARENT WELL 18-04 OF 1/22/83 WITH KBE = 56.0' A.M.S.L.. THIS WELL KICKS OFF FROM 18-04 AT 8718' MD, 7370' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 10. MWD RUNS 2 - 7 REPRESENT WELL 18-04B WITH API # 50-029-20875-02. THIS WELL REACHED A TOTAL DEPTH OF 10607' MD, 9002' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SGRD = SMOOTHED GAMMA RAY SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY DEEP SPACING SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Page 2 1804B.tapx Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8614 0 10554.0 RPD 8705 5 9840.0 RPM 8705 5 9840.0 RPS 8705 5 9840.0 RPX 8705 5 9840.0 ROP 8752 0 10608.5 FET 8753 0 9840.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8614.0 8617 8620 8625 8635 8639 8642 8647 8654 8657 8662 8665 8668 8672 8677 8680 8692 8698 8708 8720 10608 $ 5 5 0 5 5 5 0 0 5 5 5 5 5 5 .5 .5 .0 .0 .5 .5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: GR 8621 0 8624 5 8628 5 8630 5 8640 5 8644 0 8647 0 8650 5 8656 0 8659 0 8665 0 8669 0 8672 0 8674 0 8678 0 8681 0 8693 5 8697 0 8711 5 8717 0 10605 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 8748.5 8842.5 3 8843.0 8855.0 4 8855.5 9882.0 5 9882.0 9882.0 6 9882.5 10224.5 7 10225.0 10605.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 Page 3 FET MWD HR 4 1 68 1804B.tapx 28 8 Name Service Unit Min Max DEPT FT 8614 10608.5 ROP MWD FT/H 3.65 864.43 GR MWD API 13.82 839.37 RPX MWD OHMM 1.07 2000 RPS MWD OHMM 1.04 2000 RPM MWD OHMM 1 2000 RPD MWD OHMM 0.1 2000 FET MWD HR 0.84 25.72 Mean 9611.25 47.9526 122.305 6.15552 6.10697 6.29104 15.7984 3.05229 First Reading For Entire File .......... 8614 Last Reading For Entire File ........... 10608.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Nsam 3990 3714 3881 2270 2270 2270 2270 2175 First Reading 8614 8752 8614 8705.5 8705.5 8705.5 8705.5 8753 Last Reading 10608.5 10608.5 10554 9840 9840 9840 9840 9840 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8748.5 8842.5 $ # LOG HEADER DATA DATE LOGGED: 04-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER {FT): 8843.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.6 MAXIMUM ANGLE: 21.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02070HWRG6 NGP NATURAL GAMMA PROBE PB02070HWRG6 $ Page 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT FlAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1804B.tapx 8.500 LSND 10.70 49.0 9.4 800 3.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 .0 124.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 8748.5 8842.5 8795.5 189 ROP MWD020 FT/H 9.38 153.07 48.1063 189 First Reading For Entire File .......... 8748.5 Last Reading For Entire File ........... 8842.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 8748.5 8748.5 Last Reading 8842.5 8842.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Page 5 1804B.tapx Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8621.0 8817.0 RPM 8708.0 8810.0 RPD 8708.0 8810.0 RPS 8708.0 8810.0 RPX 8708.0 8810.0 FET 8749.5 8810.0 ROP 8843.0 8855.0 $ LOG HEADER DATA DATE LOGGED: 04-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8853.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM .ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02069HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02069HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.70 MUD VISCOSITY S): 49.0 MUD PH: 9.4 MUD CHLORIDES PPM): 800 FLUID LOSS (C3 : 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 125.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Page 6 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 1804B.tapx Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8621 8855 ROP MWD030 FT/H 18.95 76.06 GR MWD030 API 39.03 124.47 RPX MWD030 OHMM 1.14 2000 RPS MWD030 OHMM 1.12 2000 RPM MWD030 OHMM 1.2 2000 RPD MWD030 OHMM 0.1 2000 FET MWD030 HR 12.21 13.73 First Reading For Entire'File .......... 8621 Last Reading For Entire File ........... 8855 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean 8738 43.6336 76.0892 31.1877 31.36 32.4758 94.4191 12.7962 Nsam 469 25 393 205 205 205 205 122 First Reading 8621 8843 8621 8708 8708 8708 8708 8749.5 Last Reading 8855 8855 8817 8810 8810 8810 8810 8810 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 8810.5 RPD 8810.5 RPM 8810.5 RPS 8810.5 STOP DEPTH 9836.5 9836.5 9836.5 9836.5 Page 7 RPX 8810.5 GR 8817.5 ROP 8855.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9836.5 9843.5 9882.0 1804B.tapx 06-JUL-01 Insite 4.05 66.16 Memory 9882.0 21.1 40.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02069HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02069HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 9882.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.70 MUD VISCOSITY (S): 42.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .690 MUD AT MAX CIRCULATING TERMPERATURE: .330 MUD FILTRATE AT MT: 1.600 MUD CAKE AT MT: 1.700 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Units Size Nsam Rep Code Offset Channel Name Service Order 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Page 8 DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HR 4 1 68 71.0 156.0 69.0 74.0 1804B.tapx Name Service Unit Min DEPT FT 8810.5 ROP MWD040 FT/H 5.01 GR MWD040 API 55.85 RPX MWD040 OHMM 1.07 RPS MWD040 OHMM 1.04 RPM MWD040 OHMM 1 RPD MWD040 OHMM 1.05 FET MWD040 HR 0.84 Max 9882 864 43 391 66 46 88 44 07 35 76 25 26 25 72 First Reading For Entire File .......... 8810.5 Last Reading For Entire File ........... 9882 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 9346.25 50.4301 175.173 3.19208 3.11187 3.09707 3.16904 2.47325 Nsam 2144 2054 2053 2053 2053 2053 2053 2053 First Reading 8810.5 8855.5 8817.5 8810.5 8810.5 8810.5 8810.5 8810.5 Last Reading 9882 9882 9843.5 9836.5 9836.5 9836.5 9836.5 9836.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9844.0 9882.0 $ LOG HEADER DATA DATE LOGGED: 09-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9882.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.1 MAXIMUM ANGLE: 30.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA TOOL NUMBER 015 Page 9 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1804B.tapx 6.125 Quikdril-n 8.4O 43.0 9.0 7OO 15.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD050 API 4 1 68 4 2 .0 116.4 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9844 9882 9863 77 GR MWD050 API 35.04 124.03 61.5587 77 First Reading For Entire File .......... 9844 Last Reading For Entire File ........... 9882 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Reading 9844 9844 Last Reading 9882 9882 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 Page 10 1804B.tapx File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9882 . 5 10170.0 ROP 9882 . 5 10224 . 5 $ LOG HEADER DATA DATE LOGGED: Il-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10225.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 13.3 MAXIMUM ANGLE: 37.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 015 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Quikdril-n MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S) : 45.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3): 15.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Page 11 1804B.tapx Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEFT FT 9882.5 10224.5 10053.5 685 ROP MWD060 FT/H 3.65 297.42 45.8621 685 GR MWD060 API 14.36 839.37 75.8093 576 First Reading For Entire File .......... 9882.5 Last Reading For Entire File ........... 10224.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 First Reading 9882.5 9882.5 9882.5 Last Reading 10224.5 10224.5 10170 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10170.5 10550.5 ROP 10225.0 10605.0 $ # LOG HEADER DATA DATE LOGGED: 13-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE {MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10607.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 1.5 MAXIMUM ANGLE: 37.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 010 $ Page 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 1804B.tapx 6.125 BOREHOLE CONDITIONS MUD TYPE: Quikdril-n MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3): 15.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 .0 116.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10170.5 10605 10387.8 870 ROP MWD070 FT/H 6.24 155.58 43.251 761 GR MWD070 API 13.82 151.63 46.6381 761 First Reading For Entire File .......... 10170.5 Last Reading For Entire File ........... 10605 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 First Reading 10170.5 10225 10170.5 Last Reading 10605 10605 10550.5 Physical EOF Tape Trailer Service name ............. LISTPE Page 13 1804B.tapx Date ..................... 02/02/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 02/02/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 14 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jan 29 12:59:44 2002 1804BPBl.tapx Reel Header Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-iI108 C. ASUCHAK R. BORDES 18-04BPB1 500292087570 BP Exploration (Alaska), Inc. Sperry Sun 29-JAN-02 MWD RUN 3 MWD RUN 4 AK-MM-ii108 AK-MM-ii108 C. ASUCHAK C. ASUCHAK R. BORDES M. ANTHONY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 5 AK-MM-ii108 R. KRELL RALL/ANTHONY 24 lin 14E 1067 191 .00 45.10 16.10 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8718.0 8.500 7.000 9882.0 Page 1 REMARKS: 1804BPBl.tapx ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY FOR SETTING WHIPSTOCK AND IS NOT PRESENTED. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MWD RUN 5 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5o DATA FOR MWD RUN 2 IS NOT PRESENTED DUE TO A TOOL FAILURE. THE DATA WAS COLLECTED DURING THE TRIP IN ON MWD RUN 300. 6. GAMMA RAY (SGRC) LOGGED BEHIND CASING TO 8718' MD, 7370' TVD. 7. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 9843' MD, 8300'TVD TO 9882' MD, 8331' TVD. DIGITAL AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF PARENT WELL 18-04 OF 1/22/83 WITH KBE = 56.0' A.M.S.L.. 18-04BPB1 IS TIED INTO 18-04B AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM 18-04 AT 8718' MD, 7370' TVD (TOP OF WHIPSTOCK). THIS WELL KICKS OFF FROM 18-04B AT 9882' MD, 8331' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 2 - 5 REPRESENT WELL 18-04BPB1 WITH API # 50-029-20875-70. THIS WELL REACHED A TOTAL DEPTH OF 10457' MD, 8864' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SGRD = SMOOTHED GAMMA RAY SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. Page 2 DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 8614.0 RPD 8705.5 RPM 8705.5 RPS 8705.5 RPX 8705.5 ROP 8752.0 FET 8753.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 1804BPBl.tapx STOP DEPTH 10407 0 9840 0 9840 0 9840 0 9840 0 10460 5 9840 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 8748.5 8842.5 3 8843.0 8855.0 4 8855.5 9882.0 5 9882.5 10460.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 8614 10460.5 ROP MWD FT/H -3.82 864.43 GR MWD API 13.37 913.36 RPX MWD OHMM 1.07 2000 RPS MWD OHMM 1.04 2000 RPM MWD OHMM 1 2000 RPD MWD OHMM 0.1 2000 FET MWD HR 0.84 25.72 Mean 9537.25 58.5982 129.319 6.15552 6.10697 6.29104 15.7984 3.05229 First Reading .For Entire File .......... 8614 Last Reading For Entire File ........... 10460.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Page 3 Nsam 3694 3418 3587 2270 2270 2270 2270 2175 First Reading 8614 8752 8614 8705.5 8705.5 8705.5 8705.5 8753 Last Reading 10460.5 10460.5 10407 9840 9840 9840 9840 9840 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 1804BPBl.tapx Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8748.5 8842.5 $ # LOG HEADER DATA DATE LOGGED: 04-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8843.0 TOP LOG INTERVAL {FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.6 MAXIMUM ANGLE: 21.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02070HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02070HWRG6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.70 MUD VISCOSITY (S) : 49.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 124.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 4 1804BPBl.tapx EWR FREQUENCY (HZ): # REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 8748.5 8842.5 8795.5 189 ROP MWD020 FT/H 9.38 153.07 48.1063 189 First Reading For Entire File .......... 8748.5 Last Reading For Entire File ........... 8842.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 8748.5 8748.5 Last Reading 8842.5 8842.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRC SEXP SEDP SESP SEMP SFXE SROP $ 3 .5000 START DEPTH 8621.0 8708 0 8708 0 8708 0 8708 0 8749 5 8843 0 STOP DEPTH 8817 0 8810 0 8810 0 8810 0 8810 0 8810 0 8855 0 Page 5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD ?H: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1804BPBl.tapx 04-JUL-01 Insite 4.05 66.16 Memory 8853.0 .0 .0 TOOL NUMBER PB02069HWRG6 PB02069HWRG6 8.500 LSND 10.70 49.0 9.4 8OO 3.8 .000 .0 .000 125.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max Mean Nsam Page 6 First Reading Last Reading DEPT FT 8621 8855 ROP MWD030 FT/H 18.95 76.06 GR MWD030 API 39.03 124.47 RPX MWD030 OHMM 1.14 2000 RPS MWD030 OHMM 1.12 2000 RPM MWD030 OHMM 1.2 2000 RPD MWD030 OHMM 0.1 2000 FET MWD030 HR 12.21 13.73 First Reading For Entire File .......... 8621 Last Reading For Entire File ........... 8855 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 1804BPBl.tapx 8738 469 8621 8855 43.6336 25 8843 8855 76.0892 393 8621 8817 31.1877 205 8708 8810 31.36 205 8708 8810 32.4758 205 8708 8810 94.4191 205 8708 8810 12.7962 122 8749.5 8810 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8810 5 9836 5 RPD 8810 5 9836 5 RPM 8810 5 9836 5 RPS 8810 5 9836 5 RPX 8810 5 9836 5 GR 8817 5 9843 5 ROP 8855 5 9882 0 $ LOG HEADER DATA DATE LOGGED: 06-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT}: 9882.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.1 MAXIMUM ANGLE: 40.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02069HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB02069HWRG6 $ Page 7 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1804BPBl.tapx 8.500 9882.0 LSND 10.70 42.0 9.5 8OO 3.3 .690 .330 1.600 1.700 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 71.0 156.0 69.0 74.0 Name Service Unit Min DEPT FT 8810.5 ROP MWD040 FT/H 5.01 GR MWD040 API 55.85 RPX MWD040 OHMM 1.07 RPS MWD040 OHMM 1.04 RPM MWD040 OHMM 1 RPD MWD040 OHMM 1.05 FET MWD040 HR 0.84 Max 9882 864.43 391 66 46 88 44 07 35 76 25 26 25 72 First Reading For Entire File .......... 8810.5 Last Reading For Entire File ........... 9882 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Mean 9346.25 50.4301 175.173 3.19208 3.11187 3.09707 3.16904 2.47325 Nsam 2144 2054 2053 2053 2053 2053 2053 2053 Page 8 First Reading 8810 5 8855 5 8817 5 8810 5 8810 5 8810 5 8810 5 8810 5 Last Reading 9882 9882 9843 5 9836 5 9836 5 9836 5 9836 5 9836 5 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 1804BPBl.tapx Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9844.0 10407.0 ROP 9882.5 10460.5 $ # LOG HEADER DATA DATE LOGGED: 09-JUL-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 3.3 DATA TYPE {MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10457.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL {FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.1 MAXIMUM ANGLE: 30.6 # TOOL STRING {TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 015 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Quikdril-n MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S) : 43.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 15.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 9 REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 1804BPBl.tapx Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9844 10460.5 10152.3 1234 ROP MWD050 FT/H -3.82 246.01 75.054 1157 GR MWD050 API 13.37 913.36 65.6682 1127 First Reading For Entire File .......... 9844 Last Reading For Entire File ........... 10460.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Last Reading Reading 9844 10460.5 9882.5 10460.5 9844 10407 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF Page 10 End Of LIS File 1804BPBl.tapx Page 11
