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Home My WebLink About206-102linage Prajecfi 1~Vell Hi~tary File hover Page xl-ty~ This page identifies those items that were not scanned during the initial productian scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~/ ~ - / ~ ~ Well History File Identifier Organizing (done) ,.o,ced iuiuuiuiiiiuu Re.~,~~.~ea iuuiiiiuuiiuu RE CAN C for Items: Greyscale Items: ^ Poor Quality Originals: J ^ Other: NOTES: DfGITAL DATA Diskettes, No. ~~., ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: [ Maria ~ Date: l ~ ~c~-.e',L~l~ lsl Project Proofing III {11111 I I III I I III BY: Maria Date: ~`' ~"j /s/ ~~ Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: ~ Maria Date: ~/~ ,,~~ /s/ ~~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include, co/ve'r sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: //~ ~ /s/ ,~/~ ' `~ Sta e 1 If NO in sta e 1 a e s discre ancies were found: YES NO g g .pg() p BY: Maria Date: lsl ` ` Scanning is complete at this point unless rescanning is required. III II'I II I II II I I III ReScanned II! (I'lIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIlIII III III II 10/6/2005 Well History File Cover Page.doc Pm Jc) *, IOzo Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] 77. 61i5/1y Sent: Saturday, August 11, 2012 6:29 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: Producer 06 -13A (PTD # 2061020) MIT -IA Passed All, Producer 06 -13A (PTD #2061020) passed an MIT -IA after dummy gas lift valves were set confirming competent barriers to formation. The well is reclassified as Operable. Thank you, Mehreen Vazir SCANNED MAY 0 7 2013 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Friday, July 06, 2012 1:36 PM To: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops ead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Tea Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, • •S PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer; Wills hane M; Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael J Subject: NOT OPERABLE: Producer 06 -13A (PTD # 2061020) Sustained Casino •ressure Above MOASP During Pro - Ration All, Producer 06 -13A (PTD # 2061020) has confirmed sustained IA cas g pressure above MOASP during pro- ration. The wellhead pressures were tubing /IA/OA equal to 2100/2100/50 on ►. /04/2012. A TIFL failed on 07/05/2012. The well has been reclassified as Not Operable until further diagnostics can •e performed post pro- ration. Plan forward (Post pro- ration) 1. DHD: Monitor well for IA repressurization and bl - -d accordingly 2. WIC: Reclassify well as Under Evaluation post TAR 3. Slickline: Change out screened orifice v. e 4. DHD: Re -TIFL 5. WIE: Pending TIFL, evaluate fu er gas lift diagnostics A TIO plot and wellbore schemati ave been included for reference. 1 OPERABLE: 06 - 13A (PTD #ZdC 101 !0) Tubin tegrity Restored • Page 1 of 3 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] r /lz j Sent: Friday, October 21, 2011 1:49 PM r ' 1 e To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Stechauner, Bernhard Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J; Clingingsmith, Mike J (Swift) 206 i0z0 Subject: OPERABLE: 06 -13A (PTD #2091-920) Tubing Integrity Restored Attachments: 06 -13A TIO 10- 13 -11. doc; 06 -13A. pdf All, Producer 06 -13A (PTD #2061020) passed a TIFL on 10/19/2011 after isolating the gas lift supply line from the well. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator :z s, n Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, October 13, 2011 8:35 PM To: 'Maunder, Thomas E (DOA) ; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew; Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: 06 -13A (PTD #2001020) TIFL Failed All, Producer 06 -13A (PTD #2061020) failed a TIFL on 10/13/2011. The well is currently Under Evaluation for IA pressure over MOASP during the pro- ration. The plan forward is: 1. Slickline: Set dummy gas lift valves 2. Fullbore: MIT -IA A TIO plot and wellbore schematic are included for reference: «06 -13A TIO 10- 13 -11. doc» «06 -13A. pdf» Please call if you have any questions. 11/2/2011 OPERABLE: 06 -13A (PTD #2001020) Tubin1tegrity Restored • Page 2 of 3 Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, September 26, 2011 11:37 AM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: AK, D &C Well Integrity Coordinator; King, Whitney Subject: UNDER EVALUATION: 06 -13A (PTD #2001020) Evaluate for High IA Pressure During TAR All, Producer 06 -13A (PTD #2061020) had sustained IA pressure above the MOASP during the TAR. The well is now ready to be brought online to perform a TIFL. In the event the TIFL fails, a follow -up e-mail will be sent with a plan forward. The well is reclassified as Under Evaluation and may be returned to production. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, August 18, 2011 11:46 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) ; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard; Bommarito, Olivia 0; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA on 08/16/2011 during the shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 06 -13A (PTD #2061020) 14 -10 (PTD #1801300) 11/2/2011 OPERABLE: 06 -13A (PTD #2001020) Tubin•egrity Restored • Page 3 of 3 The following producer was found to have sustained casing pressure on the OA on 08/15/2011 during the shut down for turnaround activity. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 14-40A (PTD #2011350) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 11/2/2011 PBU 06 -13A PTD #2061020 10/21/2011 TIO Pressure Plot Wet 06-13 4.000 - '.... 3.000 - • ••• •_••- • -.._ -. _ -• .. l— OA Ua i 2.000 00 OOA - 000A On 1,000 r -• -•• • 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10/01/11 10/08/11 • TREE= 4- 1/16" CM/ WELLHEAD = FMC GEN 2 SAFETY NOTES: * ** OME TBG & LNR * ** ACTUATOR = AXELSON V KB. ELEV = 68' ' BF. ELEV = ? KOP = ^ 2800' •# �' 2042' H 9 -5/8" HOWCO ES CEMENTER Max Angle = 93 @ 10155' • • � . Datum MD = 10283' IF t Datum 'TV D= 8702' SS 2198' I-14-1/2" HES X NIP, ID = 3.813" I I9 -5/8" TBG, 40 #, L -80, TCII, ID = 8.835" H 2052' ' GAS LIFT MANDRELS ST MD TV D - DEV TYPE VLV LATCH PORT DATE 5 3060 3056 14 KGB2 DOME BK 16 08/10/09 4 4926 4740 26 KGB2 SO BK 20 08/10/09 113 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2672' I-A & 3 6338 5982 32 KGB2 DMY BK 0 12/08/06 2 7790 7215 32 KGB2 DMY BK 0 12/08/06 Minimum ID ® 3.725" @ 9842' 1 9413 8346 52 KGB2 DMY BK 0 12/08/06 4-1/2" HES XN NIP le 4001' 1 9 -5/8" X 7" BKR ZXP LTP w / TIEBACK SLV, ID = 6.280" • • • 4025' H9-5/8" X 7" BKR FLEX LOCK HGR, ID = 6.320" J • I L. .j • �� M ILLOUT WINDOW (06 -13A) 4909' - 4915' • ♦' I9 -5/8" WHIPSTOCK (11/11/06) H 4916' I ��' 19-5/8" EZSV (11/05/06) J 4926' 4 ' 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I-I 9937' a O""I 6843' I-17" HES ES CEMENTER ID = 6.187" MTV 6,7o f5; I OV _0I ,--- -I 9776' 1-14-1/2" HES X NIP, ID = 3.813" I 1 PERFORATION SUMMARY 1 14 ' ��+1 gg 9797' I-17" X 4 -1/2" BKR S -3 PKR, ID = 3,870" ( REF LOG: ?? �.. . ANGLE AT TOP PERF: 62 @ 10009' 94 •••••• - e 11 9821' H4 -1/2" HES X NIP, ID = 3.813" I Note: Refer to Production DB for historical perf data - - -=-- SIZE 1 SPF INTERVAL Opn /Sqz DATE SLOTTED 10009 - 10489 O 12/05/06 1 9842' 1-14-1/2" HES XN NIP, ID = 3.725'' I SLOTTED 10572 - 12498 0 12/05/06 1 9851' I-- 7" X 5" BKR HRD ZXP LTP w / 111 I / TIEBACK SLV, ID = 4.430" I4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I 9854' $854 I- I4 -1i2" WLEG, ID = 3.958" \\I 9871' HBKR 7" x 5" HMC LNE HGR, ID = 4.250 "I ] 17" CSG, 26 #, L -80, BTC-M, ID = 6.276" H 10007' I--4 9880' H5" X 4-1/2" XO, ID = 3.990" 4 -1/2" SLD LNR, 12.6 #, L -80, IBT, .0152 bpf, ID = 3.958 " I-I 10010' I4 -1/2" SLTD LNR, 12.6 #, L -80, IBT, .0152 bpf, ID = 3.958" H 10489' I- I4 -1 /2" SLD LNR, 12.6 #, L -80, IBT, .0152 bpf, ID = 3.958" I-I 10573' I- 14-1/2" SLID LNR, 12.6 #, L -80, IBT, .0152 bpf, ID = 3.958" H 12500' F--4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/80 ORIGINAL COMPLETION 09/09/09 JLJ /TLH GLV C /Os (08/07 & 08/10/09) WELL: 06 -13A 11/20/91 LAST WORKOVER PERMIT No: 2061020 12/12/06 N2ES SIDETRACK "A" API No: 50- 029 - 20457 -01 12/24/06 JCM/PAG GLV C/O SEC 2, T1 ON, R14E, 4499.3' FEL & 1080.52' FNL 01/10/07 NM/PJC DRLG DRAFT CORRECTIONS 06/21/07 PJC CORRECTIONS ® BP Exploration (Alaska) UNDER EVALUATION: 06 -13A (PTD':,. ! i 1 0) TIFL Failed Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] rZ ., 1 0, 1411 I Sent: Thursday, October 13, 2011 8:35 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew; Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: 06 -13A (PTD #2001020) TIFL Failed Attachments: 06 -13A TIO 10- 13- 11.doc; 06- 13A.pdf All, ✓ /ON Producer 06 -13A (PTD #2061020) failed a TIFL on 10/13/2011. The well is currently Under Evaluation for IA pressure over MOASP during the pro- ration. The plan forward is: 1. Slickline: Set dummy gas lift valves 2. Fullbore: MIT -IA A TIO plot and wellbore schematic are included for reference: «06 -13A TIO 10- 13- 11.doc» «06 -13A. pdf» Please call if you have any questions. '/r0 Thank you, Mehreen Vazir (Alternate; Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 • Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, September 26, 2011 11:37 AM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: AK, D &C Well Integrity Coordinator; King, Whitney Subject: UNDER EVALUATION: 06 -13A (PTD #2001020) Evaluate for High IA Pressure During TAR All, Producer 06 -13A (PTD #2061020) had sustained IA pressure above the MOASP during the TAR. The well is now ready to be brought online to perform a TIFL. In the event the TIFL fails, a follow -up e-mail will be sent with a plan forward. The well is reclassified as Under Evaluation and may be returned to production. 10/14/2011 UNDER EVALUATION: 06 -13A (PTD #20040) TIFL Failed • Page 2 of 2 Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, August 18, 2011 11:46 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard; Bommarito, Olivia 0; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA on 08/16/2011 during the shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 06 -13A (PTD #2061020) 14 -10 (PTD #1801300) The following producer was found to have sustained casing pressure on the OA on 08/15/2011 during the shut down for turnaround activity. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 14 -40A (PTD #2011350) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator @BP.com 10/14/2011 PBU 06 -13A PTD #2061020 10/13/2011 TIO Pressures Plot Wet 06-13 4,000 - 3,000 - • — 10— NJ —1•— W 2,000 - - • • • BOA • •• •r ...r..r • — 410— 000A + • • 1,000 • 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10/01/11 10/08/11 • TREE= 4-1/16" CM/ WELLHEAD = FMC GEN 2 SAFETY NOTES: *** OME TBG & LNR*** ACTUATOR = AXELSON oei 3A KB. ELEV = 68' , BF. ELEV „ = ? ■• < • ■ 10 = 286o. 4.:1 n . V 2042' H 9-5/8" HOWCO ES CEMENTER 1 Max Angle = 93 @ 1015.6' .. ..0 4 .... ..,. ...... Datum MD = 10283' r . Datum TVD = 8702 SS I I 1 2198' H 4-1 /2" HES X NIP, 0 = 3.813" I 19-5/8" TBG, 40#, L-80, TCII, ID = 8.835" H 2052' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3060 3056 14 KGB2 DOME BK 16 08/10/09 4 4926 4740 26 KGB2 SO BK 20 08/10/09 ., 1 13-3/8" CSG, 72#, N-80, ID = 12.347" I-1 2672' PA 3 6338 5982 32 KGB2 DMY BK 0 12/08/06 2 7790 7215 32 KGB2 DMY BK 0 12/08/06 Minimum ID = 3.725" @ 9842' 1 9413 8346 52 KGB2 DMY BK 0 12/08/06 4-1/2" HES XN NIP 4001' I- 9-5/8" X 7" BKR ZXP LTP 44 i" W / TIEBACK SLV, ID = 6.280" • r I • • / I I 1 * 4025' H 9-5/8" X 7" BKR FLEX LOCK HGR, ID = 6.320" • I • • I • • I I • • I * I • • MILLOUT WINDOW (06-13A) 4909' - 4915' '4 19-5/ HPS WTOCK (11/11/06) I 4916' -•-•,. ,-,-,,- , , -■'., 'k 1.-,:- - - - -.■'' I 9-5/8" EZSV (11/05/06) H • 9-5/8" CSG, 47#, L-80, ID = 8.681" D-I 6843' H 7" HES ES CEMENTER, ID = 6.187" 1 1 H 9937' ..... ,..., Ir --1 9776' H 4-1/2" HES X NIP, ID = 3.813" I PERFORATION SUMMARY 11. NI g-L. 9797' I-17" X 4-1/2" BKR S-3 PKR, ID = 3.870" 0 . REF LOG: ?? t 4 7. ANGLE AT TOP PERE: 62 @ 10009' ktitkV9 1 1 i--.1 9821' H 4-1 / 2" HES X NIP, ID = 3.813" 1 Note: Refer to Production DB for historical perf data SIZE I SPF INTERVAL Opn/Sqz DATE SLOTTED 10009 - 10489 0 12/05/06 1 ---1 9842' 1-14-1/2" HES XN NIP, ID = 3.725" 1 SLOTTED 10572 - 12498 0 12/05/06 9851' j- 7" X 5" BKR HRD ZXP LTP w / TIEBACK SLV, ID = 4.430" 14-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 1 9854' 9854' - HI 4-1/2" WLEG, ID = 3.958" I 9871' H BKR 7" x 5" HMC LNE HGR, ID = 4.250"1 17" CSG, 26#, L-80, BTC-M, D = 6.276" N 10007' 1 9880' 1-15" X 4-1/2" X0, ID = 3.990" I 14-1/2" SLD LNR. 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" 1--1 10010' 1 ----- 1 14-1/2" SLTD LNR, 12.6#, L-80, IBT, ,0152 bpf, ID = 3,958" 1 10489' I--- 14-1/2" SLD LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" H 10573' 1- 1 I 4- 1 /2" SLTD LNR, 12.6#, L-80, IBT. .0152 bpf, ID = 3.958" H 12500' 1 -411--1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/80 ORIGINAL COMPLETION 09/09/09 JLJ/TLH GLV C/Os (08/07 & 08/10/09) WELL: 06-13A 11/20/91 LAST WORKOVER PERMIT No: 2061020 12/12/06 N2ES SIDETRACK "A" API No: 50-029-20457-01 12/24/06 JCM/PAG GLV C/O SEC 2, T1ON, R14E, 4499.3' FEL & 1080.52' FNL 01/10/07 NM/PJC DRLG DRAFT CORRECTIONS 06/21/07 PJC CORRECTIONS BP Exploration (Alaska) - - , Producers with Sustained Casing PresssDuring TAR • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] ( Ce t r2 Sent: Thursday, August 18, 2011 11:46 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard; Bommarito, Olivia 0; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA on 08/16/2011 during the shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. . •.- A PTD #2061020) ✓ ) 14 -10 (PTD #1801300) The following producer was found to have sustained casing pressure on the OA on 08/15/2011 during the shut down for turnaround activity. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 14 -40A (PTD #2011350) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator ; ( =" I<! zo)r BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator @BP.com 8/26/2011 • ,; ,, ~M ~~, x _ ~ _ ~h Y~~~~. ~ 1 `t +'~ 4 3 ,r. ~'~ ~,~ ~. ~~ w ,~., ~:~. ~»~ ~, _,r,;:` MiCROFLLMED 6/30/2010 DO NOT PLAC E ANY NEW MATERIAL. UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~. Mr. Tom Maunder g~;~,v~, Jule ~ fir; ~~~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ~ ~ ~,... Anchorage, Alaska 99501 nn (7 O~ //°° l Subject: Corrosion Inhibitor Treatments of GPB DS 06 QV ~ Y3~ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ r BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al os-01 1750490 50029201720000 NA Sealed NA 06-02 1770780 50029202s20o00 NA Sealed NA o6-03A 1951520 500292o1asoloo NA Sealed NA os-oaA 2001020 50029201790100 NA Sealed NA os-o5 1780200 50029202980000 NA Sealed NA os-066 2050980 50029202010200 NA Sealed NA 06-07 1780210 50029202990000 NA Sealed NA os-osA 1951950 50029203000100 NA Sealed NA 06-09 1790730 50o292oaoooooo NA Sealed NA os-10A 1981960 50029204020100 NA Sealed NA 06-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50o292oa57o1oo NA Sealed NA 06-148 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA os-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-216 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 500292oso6o100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 o6-24A 2000960 50029208220100 NA Sealed NA OPERABLE: 06-13A (PTD #206~ 0) Tubing Integrity Restored • Page 1 of 2 ~-`~-D9 Schwartz, Guy L (DOA) From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, August 08, 2009 10:50 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwarfz, Guy L(DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Settenright, Ana Maria Cc: Sala, Jaycen (CM2MHill); NSU, ADW Weli Integrity Engineer Subject: OPERABLE: 06-13A (PTD #2061020) Tubing Integrity Restored All, Well 06-13A (PTD #2061020) passed a MITIA after setting dummy gas lift valv~s proving tubing integrity has been restored. The well has been reclassified as Operable. Once a generic kick-off gas lift design has been set, the weil may be returned to production. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ; Y~~. r .~.~ ~ ~_ '~(}u3`; From: NSU, ADW WeA lntegrity Engineer Sent: Tuesday, August 04, 2009 5:48 PM To: Regg, )ames B(DOA); 'Maur~der, Thomas E(DOA)'; Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; GPB, Area Mgr Central (GCl/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, F53 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor, GPB, Wells Opt Eng; GPB, EOC Specialists; Seltenright, Ana Maria Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Sala, Jaycen (CH2MHill) Subject: UNDER EVALUATION: 06-13A (PTD #2061020) Sustained Casing Pr~sure due ta TxIA Comm All, Well 06-13A (PTD #2061020) has been found to have sustained casing pressure due to TxIA communication. A TIFL was conducted on 8/3/09 and initially passed. The wellhead pressure were tubing/IA/OA equal to 2080/2030/10 at the start of the TIFL. Although the IA fluid level remained the same, overnight the IA pressure increased 750 psi. The well has been reclassified as Under Evaluation and may remain online while further diagnostic testing is completed. The plan forward includes: 1. D: TIFL - FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi A TIO Plot and wellbore schematic have been included for reference. Ple~se let us know if you have any questions. 8/10/2009 OPERABLE: 06-13A (PTD #2061020) Tubing Integrity Restored • Page 2 of 2 ~ Thank you, Anna l~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 8/10/2009 LTNDER EVALUATION: 06-13~TD #2061020) Sustained Casing Pres~u~e due to TxI... Page 1 of 1 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, August 04, 2009 5:48 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA}; GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Weils Opt Eng; GPB, EOC Specialists; Seltenright, Ana Maria Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Sala, Jaycen (CH2MHiii) Subject: UNDER EVALUATION: 06-13A (PTD #2061020) Sustained Casing Pressure due to TxIA Comm Attachments: 06-13A TIO plot.doc; 06-13A.pdf AI I, / Well 06-13A (PTD #2061020) has been found to have sustained casing pressure due to TxIA communication. A TIFL was conducted on 8/3/09 and initially passed. The wellhead pressure were tubing/IA/OA equal to - 2080/2030/10 at the start of the TIFL. Although the IA fluid level remained the same, overniaht the IA pressure increased 75 si. The well has been reclassified as Under Evaluation and may remain oniine while further diagnostic testing is completed. The plan forward includes: 1. D: TIFL - FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi ,,,'~ ,d~~~` `~ ~~~ ~~~~~-~~-' A TIO Piot and wellbore schematic have been included for reference. «06-13A TIO plot.doc» «06-13A.pdf» ,i Please let us know if you have any questions. Thank you, Anna ~u6e, ~.~. ~alt Torin Roschinger) Well tntegrity Coordinator GPB Welis Group Phone; (907) 659-51 t~2 Pager: (907) 859-5100 x1154 8/31 /2009 PBU 06-13A PTD #2061020 8/4/2009 TIO Pressures ~ 3,000 2 ~0 i^ •r ~~ • i ~ r .ooo ^ i ^ ~i r s~ ~ ~i ~ ~ * r ' ^^~ar r^^^;^ ^~~E~t~~~~~~~~~~~~~~*~~~t~~~~~~-i~~~~~u~f--~~ r ^~~~~r -~- Tby ^ IA -~ OA f~~~^ OOA OOOA ~ Dn 1,_~i_a_L a ~ t ~ a r~ a i ~ ~ ~ ~ i~.i~.* it ~.iiila a.~..a a ~ ~ ~. . ~ ~~+ ~', ~.. . .._~_.~_~k a ~ a. ~ ~ ~ ~ a a ~ • .:~.. ~i~..4...; ~ ...~., ~ - ,~.,c ~~.,; . - .__. „ - ,. .~..,, -.,Li~<~~i-._ ..... :~~~~.~r~:~ TREE= 4-1i16" CIW WELLHEAD = FNiC GEN 2) ACTUATOR = AXELSON~ KB. ELEV = 68~ ' BF. ELEV = ?. ' KOP = 2800'' I Max Angle = me~, .~ ' Datum MD = 93 @ 10155'' .~,~.~ ,,.~.,~..~ 10283' Datum ND - 5702'SS ~ SAF~OTES: ~"CHROME TBG & LNR*** ~~-~ ~~ 2042' 9-5/$" HOWCO ES CEMENTER 9-5/8" TBG, 40#, L-80, TCII, ID = 8.835" ~-{ 2052~ 13-3J8" CSG, 72#, N-80, ID = 12.347" ~-i 267: Minimum ID = 3.725" @ 9842' 4-1/2" HES XN NIP 9-5(8" WHIPSTOCK (11i11l06) (-j 4916~ 9-5l8" EZSV (11105106} ~--~ 4926' 9-5/8" CSG, 47#, L-80, ID = 8.681" (-°i 9937' PERFOR4110N SUMMARY REF LOG: ?? ANGLE AT TOP PERF: 62 @ 10009' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOT7ED 10009 - 10489 O 12(05/06 SLOTTED 10572 - 12498 q 12(05/06 ' ' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 9854' ~7" CSG, 26#, L-80, BTGM, ID = 6.276" 4-1/2" SLD LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" 4-112" SLTD ~NR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.95$" 4-1l2" SLD LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" 10( OU7' I 10d10' 1 4-1/2" S~TD LNR, 12.6#; ~-80, IBT, .0152 bpf, ID = 3.958" i~r 5uu -~ ~ ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/80 ORIGINAL CC}MPI.ETIdN ~~_~_ 11/20i91 LAS7 WORKOVER ,,,,,,,,,,,,,,,.,. _.,,.,,...,, _,..,.,, _ _,,,,,,,,,,.,... ~ 12/12/Ofi N2ES SIDEI"RACK "A" 12/24/06 JCNUPAG GLV C/O 01I10/07 NNUPJC DRLG DRAFT CdRRECTIdNS 06/21l07 PJC CORREG710NS ~ 7„ HES ES CEMENTER, ID = 6.187" ~ ~77~' --~ 4-1 /2" HES X NIP, ID = 3.813" ~ g7J7' 7" X 4-1(2" BKR S-3 PKR, ID = 3.870" ~$2~' 4-1(2" HES X NlP, ID = 3.813" ~$4~~ 4-1/2" HES XN NIP, ID = 3.725" g$$'~' ~ 7" X S" BKR HRD ZXP LTP w!( TIEBACK SLV, ID = 4.430" J$~j4' 4-1/2" WLEG, ID = 3.958" g871' BKR 7" x 5" HMC ~NE HGR, ID = 4.250" ~8$0~ 5" X 4-1I2" XfJ, ID = 3.990„ PftUDHOE BAY UNIT WELL: 06-13R PERMIT No: ~ZOfi1020 API No: 50-029-20457-01 5EC 2, T1 dN, R14E, 4499.3' FEL & 1080.52' FNL BP F~cploration (Alaska) 2198' ~4-1l2" HES X tVIP, ID = 3.813" GAS LIFT MANDRELS ST Mb ND dEV TYPE VLV LATCH PORT DATE 5 30fi0 3056 14 KG82 OOME BK 16 12/24(06 4 4926 4740 26 KG82 SO BK 20 12l24/06 3 6338 5982 32 KGB2 DMY BK 0 12/08/06 2 7790 7215 32 KGB2 DMY BK 0 12/08/O6 1 9413 8346 52 KGB2 DMY BK 0 12(08t06 9-5/8" X 7°' BKF2 ZXP LTP ~ w J TIEBACK SLV, ID = 6.280" ~ 9-5/8" X 7" BKR F~EX LQCK HGR, ID = 6.320" M ILIOUT WENDOW (06-13A) 4909' - 4915' ~ J ~. ~~q DATA SUBMITTAL COMPLIANCE REPORT 11 /7/2008 Permit to Drill 2061020 Well Name/No. PRUDHOE BAY UNIT 06-13A MD 12500 TVD 8684 REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name o Cement g ~. u,..u.,.,, , ~D D Asc Directional Survey 4~D D Asc Directional Survey i C Las 15544 Induction/Resistivity t I(~/t~D C Las 15545 Induction/Resistivity C Lis 16223 Induction/Resistivity ~lfFpt LIS Verification "' R t LIS V if ti p ica er on I ~D C Lis i 16224 Induction/Resistivity C Pds 16888 See Notes (~og Induction/Resistivity Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20457-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Completion Date 12!9/2006 Samples No Directional Survey Yes Log Log Run Scale Media No (data taken from Lags Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments Mud Log No MWD / DIR / RES / PWD / ABI / Azimuthal density /DEN / NEU 5 Col 1 50 4900 Case 12/13/2006 USIT, CCL, GR 5-Nov-2006 10220 12500 Open 1/29/2007 4899 11272 Open 1/29/2007 PB 1 10107 10512 Open 10/12/2007 DRHO, FCNL, GR, NCNL, NPHI, RHOB, RPD, RPS w/EMF graphics Field Data 10115 10517 Open 10/12/2007 DRHO, RPM, FNCL, GR, NCNL, PB1 NPHI, RHOB, RPD, RPS w/EMF graphics Field Data 4638 12489 Open 5/7/2008 GR, RPD, RPS, FET, RPM, RPX, ROP, NPHI, FCNT, NCNT, RHOB, DRHO 4638 124$9 Open 5/7/2008 LIS Veri, GR, RPD, RPS, FET, RPM, RPX, ROP, NPHI, FCNT, NCNT, RHOB,DRHO 4638 11207 Open 5/7/2008 PB1 LIS Veri, GR,RPS, FET, RPD, RPX, RPM, ROP, FCNT, NPHI, NCNT, DRHO, PEF, RHOB 4638 11207 Open 5/7/2008 PB1 GR,RPS, FET, RPD, RPX, RPM, ROP, FCNT, NPHI, NCNT, DRHO, PEF, RHOB 0 0 Open 9/16/2008 MD and TVD of EWR logs and P61 in PDS graphics 25 Col 4909 12500 Open 9/16/2008 MD ROP, DGR, EWR, CTN, ALD 4-Dec-2006 t DATA SUBMITTAL COMPLIANCE REPORT 11 /7/2008 Permit to Drill 2061020 Well Name/No. PRUDHOE BAY UNIT 06-13A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20457-01-00 MD 12500 TVD 8684 Completion Date 12/9/2006 Completion Status 1-OIL Current Status 1-OIL UIC N og Induction/Resistivity 25 Col 4724 8684 Open 9/16/2008 TVD, DGR, EWR, CTN, ' ALD 4-Dec-2006 /Log Induction/Resistivity 25 Col 4909 11272 Open 9/16/2008 P61 MD ROP, DGR, t~ED C Pds 16985 Production Production Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Comments: Compliance Reviewed By: EWR, CTN, ALD 4-Dec- 2006 9707 12322 Case 10/1/2008 Mem PPL, GR, CCL, Temp, Pres, Spin, Deft 5- Sep-2008 5 Blu 9707 12322 Case 10/1/2008 Mem PPL, GR, CCL, Temp, Pres, Spin, Deft 5- Sep-2008 ~, Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y / N Formation Tops Y / N Date: r~ L_J os/2s/os ~~~ $Cbw~ll~~l'~~I' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Joh # N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I nn nn ..iin n_._ 17-12 11978484 PRODUCTION PROFILE - 09/19/08 1~ 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09/08/08 1 1 18-05A 11999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT _ '3 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- ~(] 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG ~ _ ( 09/06/08 1 i 13-14 11978482 PROD PROFILE ~ - ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE 2 _ C/~ ~ 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02108 1 1 L-216 11970842 INJECTION PROFILE - ~ _ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE Q 09/09/08 1 1 L-205L4 40016965 OH MWD/LWD EDIT 06/26!08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) DI CACC wn VLlnun ~-.. ~.~ ey~ i..-...~ .... ...... ...... ...- ---.._...-•- ---- ----- -- -- -- . --.•~-•-~.-..~..~~.-...~...-v . v• v.w.~..~v .+nv nc~Vnl~I~~ti vIYG VVI'1 CN1i171V: BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: °1~~.1 ~, ,~!)ci~'w Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9~-2 8 - ATTN: Beth PPP Received by, • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 06-13A+PB1 August 27, 2008 AK-MW-4723 502 06-13A+PB1: 2" x 5" MD TC Logs: 1 Color Log 50-029-20457-01,70 2" x 5" TVD TC Logs: 1 Color Log 50-029-20457-01 No TVD for PB1 Digital Log Images: = 1 CD Rom 50-029-20457-01,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 rAnchorage, Alaska 99508 f ~~ _. ~~ ~~~~ r '/ Date: ;y ~, Signed: ~, i X0(0 -l0~ ~ /(~,$~ 3 ~ • WELL LOG TRANSMITTAL To: State of Alaska Apri124, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 06-13A AK-MW-4723502 1 LDWG formatted CD rom with verification listing. API#: 50-029-20457-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,..,; r~~ Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~0(0 ~~9a ~ ~ (023 • • WELL LOG TRANSMITTAL To: State of Alaska April 24, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 06-13APB1 AK-MW-4723502 1 LDWG formatted CD rom with verification listing. API#: 50-029-20457-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMTTTAL LETTER TO THE ATTENTION OF: n Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 -~ - .~~ ~ .°~ :. ~ ~--, ~,, ,~ ~t r ,~-~~ Date: ~,~"' ~ Signed: ~~ CD - ~~ c-~ ~~6~~G~ Date 10-L2-2007 Transmittal Number:92907 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) t you nave any questions, please contact Douglas llortcn at trie YDI; at Jb4-4y i s Deliver Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-01 C~~~~-_ ~a5~"3s1_ __. __. __ _ _ _ 01-08A ~C. ~f~S_ iq ,S- _~ __~__ 01-08APB1 UsC ~~_~=_/~'~lC~ _ - 03-14A w_(o p _ - __._-__ -_- 03-36A - a~ i 55~(( __ - -- _. ___ _ f-FaS ~c ~ R~P-;- ~- 05-36A r7A~ ~-n~1c~__.~. 05-36APB1 70~ _a-~.~ 15~ 06-13A . ~ ~~ - a~~ l rah'-~- -_-_~_. _...~. ~._ 06-13APB1 ~a.~.s?~__ ~LS~"~1~ .___.._._:_~._ 12-05A ~~ __~ ~ l~c~n -^ 12-05AP61 ~0~-~3 -_"t~-5Y~_.___~.._,~_.... E-15C ~ t~y9 G-26 _~~~_~~l~_s C~_3~,_ _.___, K-02D s?blo Q5(o _ -'k._t$.5"-! -__...v,_v K-02DPB1 _2.Olo.-~'~ "~l~SSa ___.._. W -213 . Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 a a • 19-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 6-13A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,220.72' MD Window /Kickoff Survey: 4,909.00' MD (if applicable) Projected Survey: 12,500.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 8 ~ ,N. o~$~ 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) r~ 19-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 6-13APB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,899.00' MD Window /Kickoff Survey: 4,909.00' MD (if applicable) Projected Survey: 11,272.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date~~,~~ 6~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) STATE OF ALASKA ~'~'" ~'~~~'~ ALASKA AND GAS CONSERVATION COMMION/~~~~ ~ I .i ~~ ~ Q 9 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~las~~ 0~# ~s ~:ons, C~tnmissior~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 2oAAC 2s., ~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Strati raphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. ~Oti~ 12/9/2006+ %~~~ 12. Permit to Drill Number 206-102 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/12/2006 ~ 13. API Number 50-029-20457-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/5/2006 14. Well Name and Number: PBU 06-13A 120 FSL, 1704 FEL, SEC. 02, T10N, R14E, UM. Top of Productive Horizon: 2240' FSL, 948' FEL, SEC. 11, T10N, R14E,UM 8. KB Elevation (tt): 67' ~ 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1084' FSL, 4295' FEL, SEC. 12, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 12500 + 8684 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685290 y- 5940701 Zone- ASP4 10. Total Depth (MD+TVD) 12500 + 8684 Ft 16. Property Designation: ADL 028311 TPI: x- 686126 y- 5937562 Zone- ASP4 Total Depth: x- 688088 y- 5936454 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) ~• 21. Logs Run: ~ ~// ~~ '~ - ~~ MWD / DIR / RES / PWD / ABI / Azimuthal density /DEN / NEU ~ ~4-,~~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 110' Surface 110' 30" 281 sx Arcticset II 13-3l8" 72# N-80 Surface 2672' Surface 2672' 17-1/2" 270 sx Fondu 400 sx AS II -5/ " 47# S- ! L-80 urfac Urfa 472 ' 1 -1/4" 11 x Class'G' 300 x AS I 7" 26# L-80 3992' 10007' 3906' 10007' 8-1/2" 681 sx lass 'G' 4-1/2" 12.6# L-80 9853' 12 8596' 8684' 6-1/8" Unc m nted SI tted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Slotted Liner 4-1/2", 12.6#, 13CR80 9854' 9797' MD TVD MD TVD 10012' - 10492' 8675' - 8701' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10575' - 12500' 8700' - $684' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: January 6, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 1 /7/2007 Hours Tested 10 PRODUCTION FOR TEST PERIOD OIL-BBL 1248 GAS-MCF 4248 WATER-BBL 78 CHOKE SIZE 78 GAS-OIL RATIO 3405 Flow Tubing Press. 275 CaSing PreSSUre 1440 CALCULATED 24-HOUR RATE OIL-BBL 2994 GAS-MCF 10195 WATER-BBL 187 OIL GRAVITV-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate s~ ry). ~, ~ GGI.1flL~t10 Submit core chips; if none, state none'. X35 ~~~, ~~~ x 10~~ ~ ~~ I . None Form 10-407 Revised 12/2003 (~ CONTINUED ON REVERSE SIDE ~ ~ ~~~ V~~~~ ~~~~~~J 28~' ' ~ GEOLOGIC MARKERS 29. TION TESTS Include and briefly summarize test results. List intervals tested, NannE MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Sag River 10017' 8677' None Top of Sag River (por) 10032' 8684' Top of Shublik 10088' 8700' Top of Shublik (Invert) 10202' 8702' Top of Sag River 10500' 8701' Top of Sag River 10570' 8700' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ii Signed Sondra S roman Title Technical Assistant Date ~ 1 " PBU 06-13A 206-102 Prepared ey NameAVumber. Sondra Stewman, 564-4750 Wel! Number Permit No. / A royal No. Drilling Engineer: Mehrdad Nadem, 564-5941 INSTRUCTIONS GeNeru-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". ITeM 29: list all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE= 4-1116" CIW WE'L~HEAD ' ' FMG ACTUATOR= AXELSON KB. ELEV = 68' BF. ELEV = ? KOP = 2804° Max Angle = 93 ~ 10155' Datum MD 10283' Datum TV D = 8702"-SS PJC DRAFT 9-5/8" TBG, 40#, L-80, TCII, ID = 8.835" 2052' O ~ -13 A SAFEI~TES: ***CHROM E TBG & LlVR""* 2042 ~-~9-518" HOWCO ES CEMENTER 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 2672' Minimum ID = 3.725" @ 9842' 4-1 /2" HES XN NiP (9-518" WHIPSTOCK (11111/06) ~-j 4916' 9-5/8" EZSV (11/05/06) 4926 L-80, ID = 8.681" 219$' - j 4-1I2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3060 3056 14 KGB2 DOME BK 16 12/24!06 4 4926 4740 26 KG62 SO BK 20 12124(06 3 6338 5982 32 KGB2 DMY BK 0 12/08/06 2 7790 7215 32 KG62 DMY BK 0 12/08/06 1 9413 8346 52 KGB2 DMY BK 0 12!08!06 400~~ 9-518" X 7" BKR ZXP LTP I w /TIEBACK SLV, ID = 6.280" 4025' 9-518" X 7" BKR FLEX LOCK HGR, ID = 6.320" M ILLOtIT WINDOW (06-13A) 4909' - 4915' ~ 7" HES ES CEMENTER, ID = 6.187" ~ 9776 ~ 4-1/2" HES X NIP, ID = 3.813" I 9797' 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 9$21' 4-112" HES X NIP, ID = 3.813" 9$42' 4-1/2" HES XN NIP, ID = 3.725" 4-112" TBG, 12.6#, 13CR-80 VAM TOP 9$54' 9$51 ~ 7" X 5" BKR HRD ZXP LTP w / .0152 bpf, ID = 3.958" TIEBACK SLV, ID = 4.430" 9854 4-1/2" WLEG, ID = 3.958" 9871 RS PACKOFF SEAL NIP w / 7" CSG, 26#, L-80, BTGM, ID = 6.276" 10007 BKR 7" X 5" HMC LNR HGR, ID = 4.250" 9$$~ 5" X 4-1/2" XO, ID = 3.990" ~ 4-112" SLD LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" ~ 4-112" SLID LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" 10489' -~ ~ - I I 4-1(2" SLD LNR, 12.6#, L-80, IBT, .0152 bpf, ID - 3.958" 10573' I I 4-1/2" SLTD LNR, 12.6#, L-80, IBT, .0152 bpf, ID = 3.958" 12500' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE DATE REV BY COMMENTS DATE REV BY COMMENTS 06103!80 ORIGINAL COMPLETION 11/20/91 LAST WORKOVER 12112/06 N2ES SIDETRACK "A" 12116f06 ?/PJC DRLG DRAFT CORRECTIONS 12/24/06 JCNUPAG GLV C/O PRUDHOE BAY UNff WELL: 06-13A PERMIT No: 2061020 API No: 50-029-20457-01 SEC 2, T10N, R14E, 4499.3' FEL & 1080.52' FNL BP Exploration (Alaska). BP EXPLORATION Operations Summary Report. Legal Well Name: 06-13 Common Well Name: 06-13 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT 11/2/2006 100:00 - 05:00 5.00 MOB P 05:00 - 10:00 I 5.00 I MOB I P 10:00 - 21:00 ! 11.001 MOB I P 21:00 - 00:00 I 3.001 MOB I P 11/3/2006 100:00 - 01:30 I 1.501 MOB P 01:30 - 07:30 I 6.001 RIGU I P 07:30 - 08:30 1.00 RIGU P 08:30 - 11:00 2.50 WHSUR. P 11:00 - 15:30 I 4.50 I W HSU R I P 15:30 - 18:30 I 3.00 WHSUR P 18:30 - 21:00 2.50 WHSUR P 21:00 - 00:00 3.00 BOPSU P 11/4/2006 100:00 - 06:30 6.501 BOPSUFt P 06:30 - 07:30 1.00 BOPSUFj P 07:30 - 09:30 2.00 PULL P 09:30 - 10:30 1.00 PULL P 10:30 - 14:00 3.50 PULL P 14:00 - 16:00 2.00 PULL I P 16:00 - 20:00 4.00 PULL P 20:00 - 20:30 0.50 PULL P 20:30 - 00:00 3.50 PULL P 11/5/2006 00:00 - 02:00 2.00 PULL P Start: 11 /1 /2006 Rig Release: 12/9/2006 Rig Number: Page 1 of 17 Spud Date: 5/15/1980 End: 11 /23/2006 Phase ' Description of Operations PRE Remove hydraulic service loop from topdrive. Change out flat tire on camp. Prep for rig move. Pull pit complex away from sub. Move camp and stage down the pad. Move truck shop and welding shop. PRE Move sub off of well E-11 B. Rig down cattle chute. PJSM. Lay derrick over. PRE Move rig onto K Pad road and transport to DS 06-13A. Lay herculite and spot sub over well. PRE Transport pits and camp from E Pad to DS 06-13A. Begin berming. Lay walkways and install floor boards around well head. PRE PJSM. Inspect derrick, raise and pin. Raise and pin cattle chute. Bridle down. Pin blocks. PRE Remove jeep from pits. Lay herculite for pits and cuttings tank. Spot pits, cuttings tank and camp. Hookup interconnect. Spot welding shop, truck shop and out buildings. Hang off bridle lines. PRE Hold pre-spud/HSE meeting with company man, toolpusher and rig personnel. Rig accepted at 0730 hrs. DECOMP PJSM. PU DSM lubricator. Wait on pad operator to remove lock on master valve. Pull BPV and rig down lubricator. Tubing on vaccum. IA and OA both at 0 psi. DECOMP PJSM. RU circulating lines to annulus and top of tree. Test lines to 3500 psi. Line up and reverse circulate diesel freeze protect out of tubing. Pump down tubing and displace diesel with clean seawater. Monitor welt. Static. Blow down lines. DECOMP Attempt to set BPV- no go. Troubleshoot problem. Master valve gate appears to be damaged or broken. Work obstruction into valve cavity. Set BPV. Test from below to 1000 psi for 10 minutes and record on chart. Test OK. Blow down and rig down circulating lines. DECOMP Nipple down tree and adapter flange. MU blanking plug to hanger with 9.5 right hand turns. DECOMP Nipple up BOP stack. Grease choke manifold and BOP valves. Install flow riser and turnbuckles. Install mousehole. DECOMP Finish NU. Test ROPE to 250 psi low, 3500 psi high. Test Hydil to 250 psi low, 3500 psi high. Test witness waived by Lou Grimaldi with AOGCC. DECOMP Rig down test joint. Blow down choke and top drive. DECOMP Pull blanking plug. Rig up lubricator and pull BPV. Rig down lubricator. DECOMP Remove ice from derrick. DECOMP Rig up to pull hanger. MU landing joint. Back out lockdown screws. PuII hanger to floor. Remove control line. LD hanger. Monitor well. OK DECOMP PJSM. Rig up to lay down tubing. Rig up control line spooling unit. DECOMP POOH laying down 5-1/2" and 4-1/2" tubing from cut at 5085' with control line to SSSV. DECOMP Lay down SSSV. Rig down control line spooling unit. Recover all 56 SS bands. DECOMP Continue POOH and LD 4-1/4" tubing. DECOMP Continued POOH laying down 4-1/2" and 3-1/2" chrome tubing. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 2 of 1 ~ Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date 'From - To ~ Hours Task ~ Code ~ NPT Phase 11/5/2006 00:00 - 02:00 2.00 PULL P 02:00 - 03:30 1.50 PULL P 03:30 - 11:30 8.00 DHB P 11:30 - 13:30 I 2.001 BOPSUF~P 13:30 - 15:30 2.00 STCTPL P 15:30 - 19:00 3.50 BOPSU P 19:00 - 20:00 1.00 STCTPL P 20:00 - 00:00 4.00 STCTPL P 11/6/2006 ~ 00:00 - 03:30 ~ 3.50 ~ CASE ~ P 03:30 - 04:30 1.00 CASE P 04:30 - 05:00 0.50 CASE P 05:00 - 12:00 7.00 BOPSU P 12:00 - 13:30 1.501 BOPSUp P 13:30 - 15:00 1.50 (BOPSUFj P 15:00 - 16:00 I 1.00 I FISH I P 16:00 - 17:00 I 1.001 FISH I P 17:00 - 00:00 I 7.001 FISH I P 11/7/2006 00:00 - 00:30 0.50 FISH P 00:30 - 02:30 2.00 FISH P 02:30 - 04:30 2.00 FISH P 04:30 - 06:00 1.50 FISH P 06:00 - 10:00 I 4.001 FISH I P Description of Operations DECOMP Tubing cut joint 23.30. DECOMP Rig down and lay down tubing handling equipment. Clear floor. DECOMP PJSM. Rig up E-line to run GR/JB. Guage ring at 8.5" OD. Run GR/JB to 5050'. Recover 2 more SS bands for 58 total, POOH. RIH set EZSV at 4926', POOH. RIH with USIT and log from 4900'. DECOMP Test casing to 3500 psi for 30 minutes - OK. Test 9-5/8" x 13-3/8" annulus to 2000 psi for 30 minutes. Record on chart. Test OK. DECOMP PJSM. RIH with string shot on wireline to 2044' across 9-5/8" casing collar. Fire string shot. POOH. Rig down wireline. DECOMP Rig up and test BOPE with 4" test joint to 250 psi low, 3500 psi high. Test 4" TIW, annulur preventer, upper and lower rams. Record on chart. Test OK. Rig down test equipment. Blow down lines. Install wear bushing. DECOMP PU and MU Multi String Cutter BHA. DECOMP PU and RIH with 4" DP to 2167'. Install blower hose. Break circulation. Establish perameters. Up weight 60k, down 60k, RT 60k with 2-3 torque. Pump at 73 gpm with 125 psi and 210 gpm with 980 psi. Locate casing collar. Verify and pull up to 2032'. Cut 9-5/8" casing as per Baker Rep. Shut annular preventer. Open annulus valve to cuttings tank. Establish circulation. Pump 2 bbls. Shut down pump and close annular valve. Rig up Little Red Services and test lines to 3500 psi. DECOMP Continue to circulate out Arctic Pac with 150 bbls 150 degree diesel, followed by 290 bbls 120 degree seawater until clean. Blow down lines. Remove blower hose. DECOMP POOH with 4" DP and casing cutter. DECOMP Lay down 9-5/8" casing cutter and XO's. Cutter in good shape. DECOMP Pull wear ring. Break BOP stack and change out tubing spool. Pull 9-5/8" packoff. Change top rams to 9-5/8". DECOMP Tighten top ram doors. Check and tighten tubing spool gland nuts. DECOMP Test tubing spool flanges to 1500 psi for 5 minutes and record on chart. Test - OK. Install upper test plug. Test TIW and upper ram door seal to 250 psi low, 3500 psi high for 5 minutes. Record on chart - OK. Bleed pressure. Rig down test equipment. Blow down lines. DECOMP PU and MU spear assembly. Bull nose, spear packoff, 9-5/8" spear, extension, sub and XO. DECOMP Pull 9-5/8" hanger to floor. Lay down spear assembly. Monitor well, static. Back out hanger and pup. Lay down. DECOMP Rig up casing equipment. POOH and lay down 9-5/8" casing from 2032'. DECOMP POOH. Lay down 9-5/8" casing. Recovered 12 centralizers. DECOMP Rig down 9-5/8" casing equipment. Clear floor. PU and breakdown spear. Clean floor. Install wear ring. DECOMP PU washouUscraper BHA and run in hole to 312'. DECOMP RIH for washout/scraper run and 9.8 ppg displacement. Rotation required to get into 9 5/8" stump. DECOMP Run in hole from 2344' to 2877'. Make up crossover 13 3/8" casing scraper, bumper sub, and jars. Continue to run in hole and tag up 13 3/8" scraper at 2032', bit ~ 4898'. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11 /1 /2006 End: 11 /23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To '~ Hours ~ Task ~ Code ( NPT '! Phase Description of Operations 11/7/2006 10:00 - 11:00 1.00 FISH P DECOMP Displace welt to 9.8 brine,pump 40 bbls hi-vis sweep followed by 9.8 brine X415 gpm 800 psi. 11:00 - 14:30 3.50 FISH P DECOMP POOH from 4899' to 2900'. Lay down crossover, jars,bumper sub,bit sub, and casing scraper to 2877'. 14:30 - 17:30 3.00 FISH P DECOMP POOH from 2877' to 279'. Stand back drill collars,lay down crossover and bit.Clear and clean ftoor,pick up tools for next BHA. 17:30 - 20:00 2.50 FISH P DECOMP Make up BHA #4 - 11 3/4" washpipe and shoe,drive sub,double pin sub,2 boot baskets,bit sub,bumper sub,oil jar,9 drill collars,and crossover. Run in hole to 341'. 20:00 - 21:00 1.00 FISH P DECOMP Run in hole 341' to 1942'. Install blower hose,pick up single from pipe shed. 21:00 - 23:00 2.00 FISH P DECOMP Establish parameters,up wt. 80k,down wt. 80k,rotating wt. 80k. 1 k free torque at 40 RPM.169 GPM X95 psi. Wash down over stump 2032' to 2060'. Increase pump to 264 GPM 2230 psi,pump hi-vis sweep and circulate until clean. 23:00 - 00:00 1.00 FISH P DECOMP Monitor well. Pump dry job,POOH from 2060' to 435'. 11/8/2006 00:00 - 02:30 2.50 FISH P DECOMP Handle BHA /Lay down washpipe. 02:30 - 03:30 1.00 FISH P DECOMP Clear and clean floor. 03:30 - 07:00 3.50 FISH P DECOMP PJSM Make up BHA #5 with back-off tool. 07:00 - 09:00 2.00 FISH P DECOMP RIH with BHA #5,fill first stand with diesel,fill every 5 stands with 9.8 ppg brine. 09:00 - 12:00 3.00 FISH P DECOMP PJSM. Space out and back off casing stub. - Set lower slips at 2069' MD. Set upper slips at 2042' MD. - Cut at 2032' MD, collar at 2052' MD. - Connection broke with 3300 psi (33,000 ftlbs). - Cycle backoff tool for 6-1/8 turns. - Pickup to release 12:00 - 13:30 1.50 FISH P DECOMP Circulate bottoms up 156 SPM / 380 GPM @ 410 psi. POOH with BHA #5. 13:30 - 14:30 1.00 FISH P DECOMP Slip and cut drilling line.lnspect brake system,check traction motor brushes,and weight indicator gap. 14:00 - 15:00 1.00 FISH P DECOMP Rig service,seroice topdrive,crown,drawworks,clutches and Elmago spline. 15:00 - 16:30 1.50 FISH P DECOMP POOH from 1924' to 324'. 16:30 - 18:00 1.50 FISH P DECOMP POOH from 324",lay down back-off tool,stand back drill collars. 18:00 - 19:00 1.00 FISH P DECOMP Clear and clean floor. PJSM make up spear assembly. 19:00 - 20:00 1.00 FISH P DECOMP Make up BHA #6, Bullnose,spear,extension,stop sub,and crossover to 11'. 20:00 - 21:00 1.00 FISH P DECOMP Run in hole from 11' to 2032'. Up wt 60k, down wt. 60k. Set down 5k to engage spear then pull up 15k to confirm. Back out with 12 turns to left. Monitor well. 21:00 - 22:00 1.00 FISH P DECOMP POOH with fish from 2032', 22:00 - 23:00 1.00 FISH P DECOMP Break out fish from spear assembly and lay down. Casing stump 19.15'. 23:00 - 00:00 1.00 FISH P DECOMP Clear and clean floor. Install long bales. 11/9/2006 00:00 - 00:30 0.50 CASE P DECOMP Pull wear ring. 00:30 - 03:00 2.50 CASE P DECOMP Pick up casing tools to rig floor and rig up to run casing. 03:00 - 08:30 5.50 CASE P DECOMP PJSM. Run 9 5/8"40#, L-80, TC11 casing. Torque turn TC11 connections to 12,600 ft/Ibs. 08:30 - 10:00 1.50 CASE P DECOMP Make up crossover and tag connection 38 feet in on jt #52. Verify spaceout. Makeup top drive. Screw in 11 turns to 11 k ftlbs. Pickup 100k Ibs over (200k total). Pressure test to 1500 Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 ' Event Name: REENTER+COMPLETE Start: 11/1/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task Code NPT ~ Phase 11/9/2006 08:30 - 10:00 1.50 CASE ~P 10:00 - 10:30 0.50 REMCM P 10:30 - 12:30 2.00 REMCM P 12:30 - 13:30 1.00 R 13:30 - 14:30 1.00 R 14:30 - 15:30 1.00 R 15:30 - 18:30 3.00 R 18:30 - 21:30 3.00 21:30 - 22:30 1.00 22:30 - 00:00 1.50 11/10/2006 00:00 - 00:30 0.50 R 00:30 - 01:00 0.50 R 01:00 - 04:00 3.00 R 04:00 - 04:30 0.50 R 04:30 - 07:00 I 2.50 I R 07:00 - 08:30 1.50 REMCM P 08:30 - 10:30 2.00 REMCM P 10:30 - 11:30 1.00 REMCM P 11:30 - 15:00 3.50 REMCM P 15:00 - 15:30 0.50 REMCM P 15:30 - 19:30 4.00 STWHIP P Page 4 of 17 Spud Date: 5/15/1980 End: 11 /23/2006 Description of Operations DECOMP psi for 10 minutes. Bleed pressure. DECOMP PJSM for cement job. DECOMP Rig up and test cement lines to 4500 psi. Open ES cementer at 2700 psi. Pump 25 bbls viscous brine at 300 psi. Pump 135 bbls 15.8 ppg cement at 5.5 bpm, 1150 psi. Drop the plug (verify with tattle tail). Pump 159 bbls displacement with brine. - Caught cement at 82 bbls away (7.5 bpm, 950 psi) - Cement returns at surface 119 bbls away (4.7 bpm, 850 psi) - Bumped plug at 159 bbls away Pressure up to 2050 psi. Hold 2 minutes. Bleed off pressure. Bleed back 1 bbls. DECOMP Flush BOP and lines with cement retarder. Blow down lines,drain BOP. Rig down cement head and lines,clear floor. DECOMP Suck out top of 9 5/8" casing with super sucker in preperation for cut. Prepare to nipple down,lay down mouse hole, remove turnbuckles. DECOMP Break flange below tubing spool,pick up BOP stack. Set emergency slips with 100k as per FMC. DECOMP Rig up WACHS cutter,cut 9 5/8" casing. Lay down cut-off and set BOP on stand. Install 9 5/8" packoff. Change out elevators and bales. DECOMP Nipple up BOP stack,install turnbuckles and riser. Test packoff to 2500 psi. for 15 minutes. DECOMP Change top pipe rams to 3 1/2" x 6" variables. DECOMP Rig up to test top rams,set test plug,fill BOP stack. Test varible rams to 250 psi low and 3500 psi high for 5 minutes and record on chart. Test witnessed by BP rep. Blair Neufeld (WSL). Bleed pressure,pull test plug,rig down test equipment and blow down Iines.Set wear bushing and run in 41ock down screws. DECOMP Clean and clear floor. DECOMP Pick up and make up BHA #7 with 8 1/2" bit, boot baskets,jars,and 9 drill collars. DECOMP Run in hole picking up 21 HWDP from pipe shed. DECOMP Rig up blower hose. Tag cement at 2038'. Break circulation, tag ES cementer at 2040'. DECOMP Drill cement and ES cementer. 80 RPM,2500 ft/Ibs torque,355 GPM C~3 460 psi. Up wt. 90k,down wt. 90k, Rotating wt. 90k. 9.8 ppg brine. Test casing to 3500 psi,hold for 5 minutes and chart. Drill baffle plate. DECOMP Circulate 25 bbls sweep around. Continue to RIH to the EZSV. Tag at 4929' MD. DECOMP Rig up test equipment. CBU. Test casing to 3500 psi for 30 minutes, good test. DECOMP Circulate 9.0 ppg milling fluid, surface to surface. DECOMP Pump dry job. POOH. Hole taking proper fill. --Well Control Drill DECOMP Lay down BHA #7. W EXIT Pick up whipstock and mill assembly. -Shallow hole test MWD, OK. - Orient Whipstock to MWD Printed: 12/11/2006 7:42:34 PM BP EXPLORATION Operations Summary Report Page 5 of 17 Legal Well Name: 0 6-13 Common W ell Name: 0 6-13 Spud Date: 5/15/1980 Event Nam e: REENTE R+COM PLET E Start : 11/1/2006 End: 11/23/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/9/2006 Rig Name: NABOB S 2ES Rig Number: Date From - To Hours ~ Task ' Code NPT ! Phase Description of Operations 11/10/2006 19:30 - 00:00 4.50 STWHIP P WEXIT Run in hole from 111' to 2921', fill pipe and check MWD with 430 GPM C~3 850 psi. Run in hole from 2921' to 4880'. Up wt. 140k,down wt. 125k. 11/11/2006 00:00 - 01:00 1.00 STWHIP P WEXIT Orient Whipstock to 60 right of highside and attempt to set whipstock with bottom trip anchor. Set down 25k, pulled up 10k over then pulled free Set down 35k, pulled up 10k over then pulled free. Set down 25k, pulled up 10k over then pulled free. Pulled whipstock out to avoid shearing brass bolt before slips set properly. 01:00 - 04:00 3.00 STWHIP N DFAL WEXIT POOH for whipstock,slips on tool showed steady 5k drag in 9 5/8" 47# casing but no grabbing in casing collars. Pulled freely in 9 5/8" 40# casing. 04:00 - 06:00 2.00 STWHIP N DFAL WEXIT Rack back HWDP,drill collars, and MWD. PJSM. Pick up joint of 9 5/8" casing and run over top of BHA. Lower casing joint into BOP stack and set down on wear ring, close bag. Pull BHA through BOP inside 9 5/8" casing joint to avoid setting slips in BOP stack. Mills were retrieved, no whipstock. 06:00 - 08:30 2.50 STWHIP N DFAL WEXIT Pick up BHA #9: Hook, jars, MWD. 08:30 - 11:00 2.50 STWHIP N DFAL WEXIT RIH with 4" DP. - Hole taking proper fill. - PU 135k, SO 130k 11:00 - 12:00 1.00 STWHIP N DFAL WEXIT Orient hook. RIH, tag whipstock. Pickup 40k over. Slack off. Repeat same x 2. Release hook. -Whipstock tagged at 4916' MD. - Orientation at 75 deg ROHS. 12:00 - 15:00 3.00 STWHIP N DFAL WEXIT POOH with BHA #9. - Hole taking proper fill. 15:00 - 16:00 1.00 STWHIP N DFAL WEXIT LD BHA #9. PU BHA #10. 16:00 - 20:00 4.00 STWHIP N DFAL WEXIT RIH with window milling BHA #10, picking up singles. - Hole taking pro 20:00 - 00:00 4.00 STW HIP N DFAL WEXIT Mill window frorrY 909' to 491 ' `-- Up wt. 140k,down wt. 125k, rotating wt. 135k, torque off bottom 3500,on bottom 7k. 500 gpm ~ 1380 psi. Mud weight in and out 9.1 ppg. Recovered 125 Ibs 'lling operations. 11/12/2006 00:00 - 03:00 3.00 STWHIP P WEXIT Mill window fro 4915' to 4926' ill formation from 4926' to 4938'. Up wt. 145k,down wt. 125k,rotating wt. 135k, torque off bottom 3500,torque on bottom 7k. 500 GPM C~ 1380 psi. Mud weight in and out 9.1 ppg. Recovered an additional 135 Ibs of metal for. a total of 2601bs. 03:00 - 03:30 0.50 STWHIP P WEXIT Circulate sweep, work window with mills. Some drag noted at 4913' but was smoothed out with mills. 03:30 - 04:00 0.50 STWHIP P WEXIT Perform FIT to 12.1 EMW. 28 strokes to bring pressure up to 740 psi. Pressure increased in straight line (did not break down formation)but bled off from 740 psi to 240 psi over 10 minutes. 04:00 - 05:00 1.00 STWHIP P WEXIT Perform MADD pass logging with MWD from 4880' to 4700' at 250Whr. Pump dry job,blow down top drive. 05:00 - 07:30 2.50 STWHIP P WEXIT POOH from 4700'. 07:30 - 09:00 1.50 STWHIP P WEXIT LD milling BHA #10. - Download and Upload MWD - Upper mill in gauge, 8-1/2". 09:00 - 11:00 2.00 STWHIP P WEXIT Flush stack. Printed: 12/71/2006 7:42:34 PM BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date Frl om - To Hours Task Code. NPT 11/12/2006 11:00 - 13:30 2.501 WHIP I P 13:30 - 16:30 3.00 WHIP P WEXIT 16:30 - 17:30 1.00 WHIP P WEXIT 17:30 - 18:00 0.50 STWHIP P WEXIT 18:00 - 19:00 1.00 STWHIP P WEXIT 19:00 - 19:30 0.50 EVAL P WEXIT 19:30 - 00:00 4.50 DRILL P LNR1 11/13/2006 ~ 00:00 - 11:30 I 11.501 DRILL P LNR1 11:30 - 12:00 0.50 DRILL N RREP LNR1 12:00 - 00:00 12.00 DRILL P LNR7 11/14/2006 100:00 - 06:00 I 6.001 DRILL I P I I LNRi Description of Operations PJSM (both crews). Pick up 8-1/2" drilling BHA #11. - HCM506Z, 7" slow speed motor, Dir/GR/RES/PWD - Shallow hole test MWD RIH to window with drilling BHA #11. Slip and cut 78' of drilling line. Service top drive. Orient toolface 75 degrees right of high side and lower down into window with pumps off. At 4924' BHA took 25k weight,set down twice. Turned assembly 30 degrees right and sat down 20k twice. Turned 30 more degrees right for total of 140 degrees right of highside and slid through window with only 5 k hang up at 4924'. It is likely that the offset in the motor caused the bit to catch the top side of the window. MAD pass logging with MWD from 4928' to 4938'. Drill 8 1/2" hole from 4928' to 5156'. Up wt. 130k,down wt. 120k,rotating wt. 125k. 500 GPM f~ 1750 psi off bottom and 1870 psi on bottom. Torque off bottom 4k and on bottom 4-5k @80 RPM. Mud wt. in and out 9.1 ppg and ECD's running from 9.55 to 9.7 PPg• Yield point 27 ~21:OOhrs with moderate to heavy cuttings load on shakers,primarily sand. AST=2.6 hrs ART = .5 hrs Drill 8 1/2" hole from 5.156' to 5867'. Up wt. 135k,down wt. 125k,rotating wt. 127k. 500 GPM ~ 1790 psi off bottom and 1918 psi on bottom. Torque off bottom 4k and on bottom 4-5k X80 RPM. Mud wt. in 9.1 ppg and out 9.2ppg, ECD's running from 9.60 to 9.70 PPg• Moderate to heavy cuttings load on shakers,sand and clay. Water running at 18 bbl/hr and mud cleaner running to control drilled solids. Repair pump #2 rheostat. Drill 8 1/2" hole from 5867' to 6721'. Up wt. 160k,down wt. 130k,rotating wt. 145k. 500 GPM ~ 1950 psi off bottom and 2230 psi on bottom. Torque off bottom 6k and on bottom 7k X80 RPM, WOB 10-15k Mud wt. in 9.1 ppg and out 9.2ppg, ECD's running from 9.50 to 9.70 ppg. ECD's on average were lower in the afternoon as ROP decreased. Moderate to heavy cuttings load on shakers,sand and clay with several large "fist size" lumps of coal .See remarks for locations of coal seams. Water running at 18 bbl/hr and mud cleaner running to control drilled solids. Drill 8 1/2" hole from 6721' to 7260'. Up wt. 170k,down wt. 135k,rotating wt. 150k. 500 GPM C~ 2000 psi off bottom and 2270 psi on bottom. Torque off bottom 6k and on bottom 7k Q80 RPM, WOB 10-15k Mud wt. in 9.1 ppg heavy and out 9.2 ppg heavy, ECD's running from 9.67 to 9.80 ppg. ECD's have increased overnight but that Phase WEXIT Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9!2006 Rig Name: NABOBS 2ES Rig Number: Date ;From - To Hours it Task ~ Code ( NP~T ' Phase 11/14/2006 1~ 00:00 - 06:00 6.001 DRILL ~ P I I LNR1 06:00 - 17:30 I 11.501 DRILL I P I I LNR1 17:30 - 19:30 I 2.00 ~ DRILL I P ~ ~ LNR1 19:30 - 21:30 ~ 2.00 ~ DRILL P I I LNR1 21:30 - 23:30 I 2.001 DRILL I P I I LNR1 23:30 - 00:00 0.50 DRILL P LNR1 11/15/2006 00:00 - 02:00 2.00 DRILL P LNR1 02:00 - 04:30 2.50 DRILL P LNR1 04:30 - 07:00 2.50 BOPSU P LNR1 07:00 - 08:30 I 1.501 BOPSUR P I I LNR1 08:30 - 15:00 I 6.501 BOPSUR P I I LNR1 15:00 - 15:30 0.50 BOPSUF~P LNR1 15:30 - 17:30 2.00 DRILL I P LNR1 17:30 - 19:00 I 1.50 DRILL ~ P LNR1 19:00 - 20:00 1.00 DRILL P LNR1 20:00 - 22:00 2.00 DRILL P LNR1 22:00 - 23:00 1.00 DRILL P LNR1 23:00 - 00:00 1.00 DRILL P LNR1 11/16/2006 100:00 - 02:00 I 2.001 DRILL I P I I LNR1 Description of Operations is due to the mud weight increasing. Moderate to heavy cuttings load on shakers primarily clay/shale with some sand and periodic pebble size coal. Drilling in Coleville, top at 6767'. Water running at 18 bbl/hr and mud cleaner and centrifuge running to control drilled solids. Drill 8 1/2" hole from 7260' to 8028'. Up wt. 185k,down wt. 140k,rotating wt. 160k. 500 GPM ~ 2380 psi off bottom and 2620 psi on bottom. Torque off bottom 8k and on bottom 10k X80 RPM, WOB 10-15k Mud wt. in 9.2ppg heavy and out 9.2 ppg heavy, ECD's running from 9.67 to 9.80 ppg. Moderate to heavy cuttings load on shakers primarily clay/silt with periodic pebble size coal. Drilling in Coleville, top at 6767'. Water running at 18 bbl/hr and mud cleaner and centrifuge running to control drilled solids. Circulate 35 bbl hi-vis sweep around. Shaker load cleans up after an additional bottoms up once sweep is back to surface. POOH from 8028' to 4842'. Rack back 5 stands,pump dry job,blow down topdrive. Hole in good condition with no tight spots and took proper amount of fill. No overpull through window. Service top drive, change saver sub from 4" HT40 to 4 1/2" IF. Change out gripper dies and stabbing guide. POOH to test rams with 5" from 4842 to 3998. POOH from 3998' to 823'. Hole took correct amount of fill. Rack back HWDP,collars , MWD and motor. Download MWD Pull wear ring,install test plug. Test pipe rams,hydril,TlW and dart with 5" test joint, 250 psi low and 3500 psi high. Test saver sub to 250 psi tow and 3500 psi high. Record and chart. Test witnessed by BP rep. Blair Neufeld (WSL).Pull test plug,install wear ring. PJSM Pick up motor and MWD, insert pulsar into collar. Begin upload, stop and rack back in derrick. Pull wear ring,install test plug,rig up 4" test equipment.Test BOP and all related valves to 250 psi low and 3500 psi high. Test witness waived by AOGCC rep Jeff Jones. Test witnessed by BP rep Dick Maskell (WSL). Blow down choke and top drive, install wear ring. Run in hole with BHA,upload and shallow test MWD 500 gpm @ 760 psi. Run in hole with 5" drill pipe from pipeshed 823' to 3090'. POOH from 3090' to 823' standing back 5" drill pipe in derrick. Run in hole from 823' to 4842', fill pipe ~ 2691' 500 gpm ~ 1300 psi. Cut and slip 55' of drilling line.lnstall blower hose. Orient 75 degrees right of highside to exit window. 500 gpm fp1 1800psi. Work BHA through window. Assembly hung up at 4923' and 4925',BHA was rotated 30 degrees at a time and worked down for 3 complete 360 degree turns. Finally went through window oriented @ 100 degrees right of highside. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Event Name: REENTER+COMPLETE Start: 11/1/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours '~ Task ~ Code NPT Phase 11/16/2006 ~ 02:00 - 02:30 ~ 0.50 ~ DRILL P ~ LNR1 02:30 - 04:30 I 2.001 DRILL I P I I LNR1 04:30 - 05:00 I 0.501 DRILL I P ( I LNR1 05:00 - 12:00 I 7.001 DRILL I P I I LNR1 12:00 - I 0.001 DRILL I P I I LNR1 11/17/2006 100:00 - 12:00 I 12.001 DRILL I ILNR1 12:00 - 00:00 I 12.001 DRILL I I I LNR1 11/18/2006 100:00 - 12:00 I 12.001 DRILL I P I I LNR1 Page 8 of i r Spud Date: 5/15/1980 End: 11 /23/2006 Description of Operations Run in hole from 4930' to 5964' with 4" drillpipe from derrick.Hole in good condition with no hanging up through coal seams in Ugnu.Change out handling equipment. Run in hole picking up 5" drillpipe from pipeshed from 5964' to 7944'. Hole in good condition, no fill on bottom. Break circulation, pump at 400 gpm ~ 1800 psi. ECD 10.33ppg,circulate to shear mud. Thick mud and heavy cuttings load seen on bottoms up,clay,sand and silt. Drill 8 1/2" hole from 8028' to 8320'. Up wt. 215k,down wt. 140k,rotating wt. 170k. 500 GPM ~ 3130 psi off bottom and 3350 psi on bottom. Torque off bottom 9k and on bottom 10k X80 RPM, WOB 10-15k Mud wt. in 11.6 ppg and out 11.6 ppg. Moderate cuttings load on shakers primarily clay/silt with some sand. Started weight up with spike fluid @ 8028' and completed over 3 circulations. Drill 8 1/2" hole from 8320' to 8580'. Up wt. 215k,down wt. 140k,rotating wt. 170k. 500 GPM ~ 3130 psi off bottom and 3350 psi on bottom. Torque off bottom 9k and on bottom 10k C~80 RPM, WOB 10-25k Mud wt. in 11.6 ppg and out 11.6 ppg.Water running at 8 BPH. Light cuttings load on shakers primarily silt/sand. Drill 8 1/2" hole from 8580' to 8908'. Up wt. 215k,down wt. 140k,rotating wt. 175k. 500 GPM ~ 3330 psi off bottom and 3510 psi on bottom. Torque off bottom 9k and on bottom 10k X80 RPM, WOB 10-25k Mud wt. in 11.6 ppg and out 11.6 ppg. Light to moderate cuttings load on shakers primarily silt/shale. Directional work for 53 deg tangent complete some moderate difficulty with sliding,hanging up,stalling. ECD averaging 12.2 PP9 Drill 8 1/2" hole from 8908' to 9303'. Up wt. 215k,down wt. 150k,rotating wt. 175k. 500 GPM C~ 3440 psi off bottom and 3620 psi on bottom. Torque off bottom 8k and on bottom 9k X80 RPM, WOB 10-27k Mud wt. in 11.6 ppg and out 11.6 ppg. Light to moderate cuttings load on shakers primarily silt/shale with no signs of sloughing. Assembly has a dropping tendency requiring some sliding to correct. Water running at 10 to 12 BPH. Drill 8 1/2" hole from 9303' to 9645'. Up wt. 220k,down wt. 145k,rotating wt. 180k. 500 GPM ~ 3450 psi off bottom and 3650 psi on bottom. Torque off bottom 11k and on bottom 10k C~80 RPM, WOB 10-27k Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Operations Summary Report Page 9 of 17 Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABORS 2ES Rig Number: Date ~ From - To ~ Hours j Task .Code NPT ', Phase 11/18/2006 ~ 00:00 - 12:00 ~ 12.001 DRILL P I I LNR1 12:00 - 15:00 I 3.001 DRILL I P I I LNR1 15:00 - 16:00 I 1.00 DRILL N I DFAL LNR1 16:00 - 17:30 I 1.501 DRILL I N I DFAL I LNR1 17:30 - 19:30 2.00 DRILL N DFAL LNR1 19:30 - 21:30 2.00 DRILL N DFAL LNR1 21:30 - 22:00 0.50 DRILL N DFAL LNR1 22:00 - 00:00 2.00 DRILL N DFAL LNR1 11/19/2006 100:00 - 05:00 I 5.001 DRILL I N I DFAL I LNR1 05:00 - 09:00 I 4.001 DRILL (N I DFAL I LNR1 09:00 - 18:00 I 9.001 DRILL I P I I LNR1 n 18:00 - 20:00 I 2.001 DRILL I P I I LNR1 20:00 - 21:30 I 1.501 DRILL I P I I LNR1 Description of Operations Mud wt. in 11.6 ppg and out 11.6 ppg, ECD running approximately 12.25ppg. Light to moderate cuttings load on shakers primarily silUshale some small shale slivers but none that indicate sloughing. Assembly has a dropping tendency requiring some sliding to correct. Water running at 12 BPH. Drill 8 1/2" hole from 9345' to 9675'. Up wt. 220k,down wt. 145k,rotating wt. 180k. 500 GPM ~ 3450 psi off bottom and 3650 psi on bottom. Torque off bottom 11k and on bottom 10k X80 RPM, WOB 10-27k Mud wt. in 11.6 ppg and out 11.6 ppg, ECD running approximately 12.25ppg. Light to moderate cuttings load on shakers primarily silUshale some small shale slivers but none that indicate sloughing. Assembly has a dropping tendency requiring some sliding to correct. Water running at 12 BPH. Trouble shoot MWD. Circulate nut plug,attempt to get pulses. Prepare to pull out of hole for MWD failure. Circulate bottoms up 500 gpm ~ 3350 psi.Monitor well,pump dry job,blow down top drive. POOH from 9675' to 5964',change out handling equipment. POOH from 5964' to 823',change out handling equipment. POOH from 823' to MWD. Download and trouble shoot MWD. Break bit,lay down motor, pull pulser and -ay down DM collar. Make up BHA,Change out, pulser,DM collar, motor, and bit. Upload and surface test MWD. Run in collars,HWDP and jars to 823'. Re-test MWD. Run in hole,fill pipe every 30 stands. Orient to pass through window @ 4926'.Passed through window oriented at 70 degrees right of highside and 20 to 25k down weight. Install blower hose. Wash down last stand to bottom and tag up at 9675' Work minor tight spots on trip 8140',8300' and 8520', 25-30k weight taken to work through. Drill 8 1/2" hole from 9675' to 10,007'. Up wt. 230k,down wt. 145k,rotating wt. 180k. 500 GPM ~ 3550 psi off bottom and 3750 psi on bottom. Torque off bottom 10k and on bottom 11k X80 RPM, WOB 10-20k Mud wf. in 11.6 ppg and out 11.6 ppg, ECD running approximately 12.25ppg. Light to moderate cuttings load on shakers primarily silUshale some small shale slivers but none that indicate sloughing. Assembly has a dropping tendency requiring some sliding to correct. Water running at 12 BPH. Circulate bottoms up sample for geologist,500 gpm @ 3475 psi.Attempt to get bottom hole survey with MWD. Circulate Hi-Vis sweep around, 500 gpm @ 3450 psi. Some Printed: 12/11/2006 1:42:34 PM BP EXPLORATION. Page 10 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i Name: 0 ell Name: 0 e: Name: From - To 6-13 6-13 REENTE NABOBS NABOBS Hours ~, R+COM ALASK 2ES Task PLET A DRI Code E LLING NPT ' Start I Rig Rig Phase Spud Date: 5/15/1980 : 11/1/2006 End: 11/23/2006 Release: 12/9/2006 Number: Description of Operations 11/19/2006 20:00 - 21:30 1.50 DRILL P LNR1 increase in cuttings when sweep returns to surface. Monitor well. 21:30 - 22:00 0.50 DRILL P LNR1 Short trip 7 stands from 10,007' to 9361'. Hole in good condition with no tight spots. 22:00 - 23:30 1.50 DRILL P LNRi Circulate Hi-Vis sweep around,500 gpm ~ 3400 psi. Noticable increase in cuttings on bottoms up, and less noticiable with sweep back to surface. Overall cuttings load on shaker, light. Monitor well, drop 2 7/8" rabbit. 23:30 - 00:00 0.50 DRILL P LNR1 POOH from 10,007' to 8600'. Pump dry job, blow down top drive. 11/20/2006 00:00 - 04:00 4.00 DRILL P LNR1 POOH from 8700' to 823'. Hole in good condition with no overpull and took proper amount of fill.Retrieve rabbit at top of 4". 04:00 - 05:30 1.50 DRILL P LNR1 Lay down 5" HWDP 05:30 - 09:00 3.50 DRILL P LNR1 Download MWD and lay down collars, MWD,bit and motor. Clean and clear floor. 09:00 - 10:00 1.00 DRILL P LNR1 PJSM Change out upper rams to 7". 10:00 - 12:00 2.00 BOPSU P LNR1 PJSM Pick up and make up 7"test joint. Pull wear ring,install test plug. Test rams and doors to 3500 psi. Pull test plug and install wear ring. Break and lay down test joint. 12:00 - 13:00 1.00 CASE P LNR1 Rig up 7" casing handling equipment. 13:00 - 14:00 1.00 CASE P LNR1 PJSM with all personnel. Make up 7" float equipment, check floats. 14:00 - 21:00 7.00 CASE P LNR1 Make up 7" 26# L-80 BTC-M liner. OPT torque 9000 ft/Ibs.Not gaining back all displacement until packer is put in the hole then no displacement coming back. 21:00 - 23:00 2.00 CASE P LNR1 Attempt to break circulation to circulate liner volume but all fluid lost to formation. Move pipe up and hole swabs, stop or move down all fluid being pumped lost. Decided pull back and lay down 8" packer, rig up floor and pipe shed for laying down. 23:00 - 00:00 1.00 CASE N DPRB LNR1 Lay down 7" liner from 4870' to 4470'. Liner is swabbing fluid from inside of liner, fill liner every 2 joints while pulling. Total losses while running to midnight 147 bbl. 11/21/2006 00:00 - 04:30 4.50 CASE N DPRB LNR1 POOH with 7" 26# L-80 liner. Pipe swabbing POH, fill hole through liner. Took proper displacement. Lay down casing packer. 04:30 - 05:00 0.50 CASE N DPRB LNR1 Attempt to get circulation, pump at 2-3 BPM, returns when picking up but no returns when stopped or running down. Well starts to improve getting some returns at 3 BPM when stationary then reverts to no returns when stationary. No static losses. 05:00 - 09:00 4.00 CASE P LNRi PJSM Blow down top drive. Run in hole with 7" 26# L-80 liner without packer to 4870'. 09:00 - 09:30 0.50 CASE P LNR1 Make up XO and top drive. Attempt to circulate at 1.5 bpm at 280 psi. No returns. Move pipe up hole establish circualtion with max rate of 4 bpm with 330 psi. No static losses. Break out top drive and blow down. 09:30 - 12:00 2.50 CASE P LNRi Continue to run into open hole to 6024'. Up weight 125k down 115k at window. 12:00 - 13:00 1.00 CASE P LNR1 Change out handling equipment. Make up hanger. Mix and add PAL mix. Let set for 30 minutes. Up weight 160k down 125k. 13:00 - 13:30 0.50 CASE P LNR1 Break circulation at 2 bpm with 320 psi. Returns only on up stroke. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 11 of ~ 7 Operations Summary Report Legal Well Name: 0 6-13 Common W ell Name: 0 6-13 Spud Date: 5/15/1980 Event Nam e: REENTE R+COM PLET E Start :: 11/1/2006 End: 11/23/2006 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 12/9/2006 Rig Name: NABOR S 2ES Rig Number: Date From - To Hours ' Task ' Code j NPT Phase Description of Operations 11/21/2006 13:30 - 17:00 3.50 CASE P LNR1 RIH with liner on 5" DP to 9988'. Fill every 5 stands. Break circulation every 10 stands. When circulating, returns on up stroke and slight fluid movement when stationary -breathing? or minor returns. Well was giving back a little fluid when pumping stopped. 17:00 - 17:30 0.50 CASE P LNRi Make up cement head and single. Tag bottom at 10007'. Attempt to PU. Pull to 350k with no movement. 17:30 - 22:00 4.50 CASE P LNR1 Break circulation at 1 bpm with 600 psi. Stage up to 3 bpm with losses of 1.5 bpm. Lower pump rate to 2 bpm at 450 psi with losses at 1 bpm. Attempt to move string with 325k. No movement. Circulate while waiting on cementers. After bottoms up full returns established at 5 bpm. Slow pumps to 3 bpm with full returns. 22:00 - 23:30 1.50 CEMT P LNR1 PJSM. Rig up cementers and batch mix cement. Blow air through lines. 23:30 - 23:45 0.25 CEMT P LNR1 Pump 3 bbls water. Pressure test lines to 4000 psi. 23:45 - 00:00 0.25 CEMT P LNR1 Start 11.8 ppg Mudpush with 1 ppb cemnet. Pumping at 4 bpm with 581 psi. Pump 40 bbls 11.8 ppg Mudpush II. 11/22/2006 00:00 - 00:15 0.25 CEMT P LNR1 Start 12.0 ppg LiteCrete GasBlok lead slurry with 1 ppb Cemnet LCM. At 5 bbls away pumping at 3.8 bpm pressure at 650 psi. Pump 80 bbls away at 5 bpm with 719 psi. Pump total lead of 85 bbls. 00:15 - 00:25 0.17 CEMT P LNR1 Switch over to 15.8 ppg Class G GasBlok tail slurry with 2 ppb Cemnet LCM except in last 10 bbls. Pump 5 bbls away at 5 bpm with 696 psi. Pump 15 bbls away at 3.8 bpm with 320 psi. Pump a total of 20 bbls tail slurry. 00:25 - 01:40 1.25 CEMT P LNR1 Drop dart and verify release. Pump 5 bbls water and follow with 11.6 ppg LSND mud. Pump 10 bbls away at 5 bpm with 380 psi, 60 bbls away at 5 bpm with 613 psi. Slow to 3 bpm with 350 psi and latch up with 67.7 bbls. Pressure spike to 2850 psi on latch up. Mud push rounding corner at 150 bbls away pumping at 5 bpm with 705 psi. Slow pumps to 3 bbls per minute at 170 to 180 bbls away as plug goes by ES Cementer. With 200 bbls away at 5 bpm pressure at 950 psi. Back off to 4 bpm to keep pressure at or below 1000 psi. Pump away 225 bbls at 3.7 bpm with 1000 psi, 250 bbls away at 3.2 bpm with 1002 psi, With 280 bbls away back off to 2.2 bpm with 993 psi. Bump plug at 296 bbls away with 1913 psi to verify. CIP at 0138 hrs. 01:40 - 02:00 0.33 CEMT P LNR1 Pressure up to 2000 psi to set hanger. Slack off 50k to verify. Bleed pressure, 2 bbls back, float holding. Pressure up to 2500 psi to release running tool. Pull up 2' with 150k. Release verified. Increase pressure to 3450 psi and shear ES Cementer open. Confirm circulation. Switch over to rig pumps to circulate out cement. Losses during cement job at 9 bbls. 02:00 - 12:30 10.50 CEMT P LNR1 Circulate out excess cement. Circulate while waiting on cement compresive strength of 500 psi. Initially appear to be pumping cement away when circ at 5 bpm. Slow rate to as low as 1.5 bpm to circ out excess cement. Got back approx 25 bbls 12.0 ppg cement -estimate losses at 20-30 bbls when circulating out excess cement. Circulate at 2 bpm with 330 psi. Increase to 5 bpm with 750 psi. No losses. 12:30 - 14:00 1.50 CEMT P LNR1 PJSM. Batch mix cement. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours ' Task ~ Gode ( PJPT Phase 11/22/2006 114:00 - 14:15 0.251 CEMT ~ P ~ LNR1 14:15 - 14:35 I 0.331 CEMT I P I LNR1 14:35 - 15:15 I 0.671 CEMT I P I I LNRi 15:15 - 16:30 I 1.251 CEMT I P I I LNR1 16:30 - 18:00 I 1.501 CEMT I P I I LNR1 18:00 - 19:30 I 1.501 CEMT I P I I LNR1 19:30 - 21:30 2.00 CEMT P LNR1 21:30 - 00:00 2.50 CEMT N SFAL LNR1 11/23/2006 00:00 - 01:00 1.00 CEMT N SFAL LNR1 01:00 - 05:00 4.00 CEMT P LNR1 L 05:00 - 07:00 I 2.001 BOPSUFi P I I PROD1 07:00 - 08:30 1.50 BOPSU~ P PROD1 08:30 - 09:30 1.00 BOPSU P PROD1 09:30 - 11:30 I 2.001 BOPSUR P I I PROD1 11:30 - 13:30 2.001 DRILL P I PROD1 13:30 - 19:00 I 5.501 DRILL I P I I PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 20:30 1.00 DRILL P PROD1 20:30 - 22:30 I 2.001 DRILL I P I I PROD1 22:30 - 00:00 I 1.501 DRILL I P I I PROD1 Description of Operations Pump 5 bbls water. Test lines to 4000 psi. Pump 42 bbls 12.0 ppg mudpush at 4 bpm with 500 psi. Switch to cement slurry. Pump 12.0 ppg LiteCrete at 4.6 bpm with 650 psi. Pump 30 bbls away at 5 bpm with 630 psi, 60 bbls away at 5 bpm with 560 psi. Total cement pumped 84.5 bbls. Release dart and kick out with 5 bbls water. Displace with mud, start with 5 bpm at 520 psi. Slow to 2 bpm at 62 bbls away. PU LW P at 66.4 bbls away. Shear at 1700 psi. Increase rate to 5 bpm with 550 psi. At 100 bbls away rate at 5 bpm with 850 psi, 140 bbls away slow to 3.5 bpm with 850 psi. W ith 160 bbls away at 880 psi, 170 bbls away slow to 2 bpm with 740 psi. Land at 175.2 bbls away. CIP at 1515 hrs. Pressure up to 2400 psi and close ES Cementer. Verified when hose jumped. Bleed off pressure, get back 1.5 bbls. No flowback -close verified. PU and set LTP. Pressure up to 1000 psi. PU and unsting from liner. Girculate at max rate. Got back 20 bbls mudpush and cement. Max weight out 12.4 ppg. Pump dry job. Lay down cement head and 2 singles of DP. Flush mud manifold. Break down surface equipment. Clear floor. Cut and slip drilling line. Cut 91' of line. Service drawworks. Inspect traction motor. Service top drive. POOH laying down 5" DP to 2300'. Change out spinners on Iron Roughneck. Blown seal. PJSM. Install Iron Roughneck spinner assembly and test. PJSM. POOH laying down 5" DP, and 10' pup. Break and LD running tool. 100% of tool recovered. Wire strip and clean last 30 joints of DP, covered in cement. First 10 covered in soft mush. Last 20 covered in hard cement. RIH with 3 stands of 5" DP from derrick. POOH and lay down. Clear and clean floor. Rotory table and BOP stack packed off with cement. Clean out table. PU and MU flushing tool. Flush out stack. Break and lay down tool. Blow through choke and kill lines. Slowdown top drive. PJSM. Drain stack. Close blinds. Change out top rams to 3-1/2" X 6" variable. PJSM. Change out top drive saver sub and stabbing guide. Service ram and adjust gripper foot. PJSM. Make up 4" test joint. Pull wear ring and install test plug. Test top rams and door seals to 250 psi low, 3500 psi high. Pull test plug. Install wear ring. Break and lay down test joint. PJSM. PU 4-3/4" DC. Change out to 3-1/2" handling equipment. MU bit sub, bit. and run in with BHA to 281'. PU 4" DP and run in hole to 4009'. Circulate BU every 2000'. RIH from derrick to 6810'. Fill pipe. Install blower hose. Tag at 6838'. Drill cement plugs and ES Cementer to 6845'. Circulate and condition mud due to aeration and loss of pressure. Drill ES Cementer at 6845'. Pump at 240 gpm with 14-15k WOB. Drill with 60 rpm. Up weight 130k down 105k. Push down hole to 7000'. Blow down top drive. RIH to 9716'. Break circulation and wash down to 9811'. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: 0 6-13 Common W ell Name: 0 6-13 Spud Date: 5/15/1980 Event Nam e: REENTE R+COM PLET E Start : 11/1/2006 End: 11/23/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/9/2006 Rig Name: NABOB S 2ES Rig Number: Date ~ , From - To Hours ' Task i Code; NPT ~ Phase ; Descri tion of O erations P P 11/24/2006 00:00 - 01:30 1.50 DRILL P PROD1 Wash and drill cement to 9876'. Circulate and condition flocculated mud at 500 gpm with 3550 psi. Rotate at 60 rpm with 9.5k torque. RT weight 132k. 01:30 - 02:30 1.00 DRILL P PROD1 Line up and test liner and casing to 3500 psi for 30 minutes. Record on chart. 02:30 - 08:00 5.50 DRILL P PRODi Drill out cement and float equipment to 10004'. Pump at 275-375 gpm with 1400-2200 psi. Rotate at 45-75 rpm with 9k torque and 8-13k WOB. Up weight 195k, down 110k, RT 145k. 08:00 - 10:30 2.50 DRILL P PROD1 PJSM. Displace well to 8.4 ppg FloPro. Pump 150 bbls water, 50 bbl Hi-vis sweep, chase with new mud. Clean under shakers and troughs. Pump dry job. Break down surface equipment. 10:30 - 14:30 4.00 DRILL P PROD1 POOH to 281'. 14:30 - 18:00 3.50 DRILL P PROD1 Stand back HWDP and jars. LD 4-3/4" drill collars, bit sub, float sub and bit. PJSM. Pick up motor, 6-1/8" bit, float sub and MWD tools. Scribe and upload. PU flex collars. Surface test MWD. Run HWDP, jars and XO to 359'. 18:00 - 20:30 2.50 DRILL P PROD1 RIH to 3157. 20:30 - 22:30 2.00 DRILL P PROD1 PJSM. Run BOP drill and stripping drill. Run in 5 stands for exercise. Blow down kill line and choke manifold. POOH and retrieve IBOP valves. 22:30 - 00:00 1.50 DRILL P PROD1 Continue to RIH to 5955' filling every 30 stands. 11/25/2006 00:00 - 03:00 3.00 DRILL P PRODi RIH to 9889'. Install blower hose. SPR Pump #1 30 spm/510 psi, 45/620. Pump #2 30/500, 45/610. Wash down and tag at 10004'. Pump at 260 gpm with 1340 psi. 03:00 - 06:30 3.50 DRILL P PROD1 Line up 90 right and drill out shoe. Drill 21' of new formation to 10028' for FIT. Up weight 175k, down 140k. Pump Hi-vis sweep surface to surface at 260 gpm with 1460 psi. 06:30 - 08:30 2.00 DRILL P PROD1 Pump Hi-vis sweep surface to surface at 260 gpm with 1460 psi. 08:30 - 09:00 0.50 DRILL P PROD1 Perform FIT to 10.0 ppg EMW. Could not get full 10 ppg FIT. Leaked off at 9.84 ppg EMW. 09:00 - 10:30 1.50 DRILL N WAIT PROD1 Wait on reply from Anch for OK to drill ahead. Reciprocate and roll pumps. 10:30 - 21:00 10.50 DRILL P PROD1 Drill ahead to 10150' MD, 8703' TVD. Up weight 190k, down 140k. Pump at 250 gpm with 1680 psi on bottom, 1525 psi off bottom. WOB 15-30k. Finish build at 91.4 deg inc in Shublik - top at 10088' MD/8694' TVD. 21:00 - 22:30 1.50 DRILL P PROD1 Circulate BU. Drop dart. Remove blower hose. Install air slips. Pump dry job and blow down top drive. 22:30 - 00:00 1.50 DRILL P PROD1 POH to 6888'. Up weight 195k. No problems. 11/26/2006 00:00 - 04:00 4.00 DRILL P PROD1 POOH to 359'. Monitor well at BHA. 04:00 - 06:30 2.50 DRILL P PROD1 Stand back HWDP and flex collars. Down load MWD. Flush TM/DMI motor. Break out bottom hole tools. 06:30 - 11:00 4.50 DRILL P PROD1 PJSM. Pick up motor, bit, float sub stabilizer, DM collar, Gamma and TM collar. Upload MWD. Surface test MWD at 240 gpm with 756 psi. PJSM. Load nukes and RIH. 11:00 - 15:00 4.00 DRILL P PROD1 RIH from 390' to 10150'. Install blower hose. Pull air slips at 9988'. 15:00 - 00:00 9.00 DRILL P PROD1 Drill ahead to 10327'. Up weight 183k, down 135k, RT 163k. WOB 3-12k. RPM at 55 with 6-7k torque on and off bottom. Pump at 255 gpm with 1850 psi on and 1540 psi off bottom. SPR's 30/530, 45/610 both pumps with a depth of 10150' at 1600 hrs. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date !From - To ~ Hours ~~ Task ! Code ~ NPT 11/27/2006 ~ 00:00 - 12:00 12.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 11/28/2006 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 14:30 I 2.501 DRILL I P 14:30 - 15:30 I 1.001 DRILL I P 15:30 - 00:00 I 8.501 DRILL I N I SFAL 11/29/2006 100:00 - 12:00 12.001 DRILL N I SFAL 12:00 - 17:00 I 5.001 DRILL I N I SFAL 17:00 - 18:00 1.00 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 00:00 I 5.001 BOPSUR P 11/30/2006 00:00 - 03:00 3.00 BOPSUf~ P 03:00 - 06:00 3.00 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:30 2.00 DRILL P Phase ~ Description of Operations PROD1 Drill ahead to 10600' MD. Losses at 81 bbls per hour. Static loss at -30 bph. Up weight 185k, down 135k, RT 155k. Torque on bottom 6-7k, off bottom 4-5k. WOB 3-7k. PSI on bottom 1560, off bottom 1430 at 252 gpm. SPR's at 10575', #1 30/630, 45/740. #2 30/590,45/700. PROD1 Drill ahead to 10956' MD. Up weight 185k, down 130k, RT 130k. Pressure 1650 psi on bottom, 1480 psi off bottom at 255 gpm. WOB 3-12k. Torque 6-7k on bottom, 5-6k off bottom at 60 rpm. SPR #1 30/460, 45/650. #2 30/440, 45/630 at 10852', 2130 hours. PROD1 Directional drilled ahead to 11215' MD. Up weight 185k, down 130k, RT 160k. PROD1 Drill ahead to 11272' MD, 8693' TVD. Up weight 185k, down 130k, RT 160k. WOB 3-12k. Pump at 255 gpm with 1620 psi on bottom and 1420 psi off bottom. Torque 6-7k on bottom, 5-6k off bottom at 55 rpm. SPR both pumps, 30/480, 45/600 at 11262', 1330 hours. PROD1 Inspect low air output from top drive blower. Found blower motor seized. PROD1 PJSM. POOH to 9919' into 7" shoe. Up 200k, max up 240k at 10225'. Circulate over top of hole. Change out top drive blower motor. Static losses at 15 bph. Lost 2397 bbls this time period for a total of 4435 bbls. PROD1 Repairing top drive blower motor. Install new motor and squirrel cage. Check rotation of motor. Purge hose and function test. Alarm indicated low air flow. Lock out, tag out. Trouble shoot. Circulating over top of hole with 25 bph static losses. PROD1 PJSM. Trouble shoot and repair low air flow to top drive. Remove blower hose upper end. Test air flow directly off blower housing, low flow. Remove blower duct outlet hard line. Visually verify no debris in duct and check blower rotation. Motor turning backwards. Reassemble duct. Reverse motor rotation and test. Tested OK. Remove, clean and replace blower exhaust screens. Re-install blower and test top drive. Everything checks out. PROD1 Grease and service top drive. PROD1 PJSM. Pick up and run RTTS. Set at 87' with drill string hung off. Test packer to 500 psi - OK. PROD1 PJSM. Pick up and make up test joint. Pull wear ring. Instatl test plug fill stack and choke. Test BOPE to 250 psi low, 3500 psi high. Test witnessed by John Crisp with AOGCC. PROD1 Test BOPE to 250 psi low, 3500 psi high. Test witnessed by John Crisp with AOGCC. PROD1 Clear and clean floor. RIH and screw into RTTS. Close bag, open kill line. Pull RTTS loose with no overpull. Check for pressure. No pressure. Fill DP. Still no pressure. Open bag. Fill DP and pump over top with kill line. Hole took 70 bbls to fill. Pull RTTS to floor, break out and lay down. Clear floor and prepare to RIH. PROD1 RIH to 10530'. Taking weight. Break circulation. PROD1 Ream tight hole from 10530' to 10550'. Pipe became stuck. Hole packing off. Pull to 310k, jar and work pipe free. Regain circulation. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page ~ 5 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING 1 Rig Name: NABOBS 2ES Date l Prom - To Hours Task ', Code NPT 11/30/2006 08:30 - 10:30 2.00 DRILL P PRODi 10:30 - 14:30 4.00 DRILL P PROD1 14:30 - 16:00 1.50 DRILL N DFAL PROD1 16:00 - 21:30 5.50 DRILL N DFAL PROD1 21:30 - 00:00 2.50 DRILL N DFAL PROD1 12/1/2006 00:00 - 02:00 2.00 DRILL N DFAL PROD? 02:00 - 05:00 3.00 DRILL N DFAL PROD1 05:00 - 06:30 1.50 DRILL N DFAL PROD1 06:30 - 10:30 4.00 DRILL N DFAL PROD1 10:30 - 12:00 1.50 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 13:00 0.50 DRILL N DFAL PROD1 13:00 - 00:00 11.00 DRILL N PROD1 12/2/2006 00:00 - 12:00 12.00 DRILL P PROD1 12:00 - 16:30 4.50 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 00:00 6.00 DRILL P PROD1 12/3/2006 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 05:30 3.50 DRILL P PROD1 05:30 - 07:00 1.50 DRILL P PRODi 07:00 - 08:00 1.00 DRILL P PROD1 Spud Date: 5/15/1980 Start: 11 /1 /2006 End: 11 /23/2006 Rig Release: 12/9/2006 Rig Number: Phase ~ Description of Operations Circulate bottoms up. Rotate and reciprocate at 250 gpm with 1400 psi, 80 rpm with 6-7k torque. Up weight 185k, down 140k, RT 160k. Retrieve and analyze samples from bottoms up. Log MAD pass from 10500' to 10225'. Pump at 250 gpm with 1400 psi. Torque at 6-7k with 60 rpm. Up weight 185k, down 140k, RT 160k. POOH at 100' per hour. No problems. Attempt to gain survey data. Unable to switch modes. Try various pump rates and bleed offs. Do data. SPR both pumps, 30/480, 45/630 at 10230', 1500 hours. Mix and pump dry job. Remove blower hose. POOH to 389'. Up weight 200k with max pull at 220k pulling BHA through shoe. PJSM. Flush MWD tools. Remove nukes. Download MWD. POOH with BHA. Drain motor, break out bit. Bit in good shape. Lay down motor. Motor appears to have bad bearings. Clear and clean floor. Make up BHA. Rerun bit. Run new motor and MWD. Batteries were dead in MWD. PJSM. Run nukes. RIH to 390' surface test MW D at 250 gpm with 785 psi - OK. Blow down topdrive. RIH to 9921' filling pipe every 3000'. Test MWD. Pull air slips. PJSM. Cut and slip 100' of drilling line. Inspect drawworks, traction motor brushes and brakes. Adjust brakes. Lube Elmago splines. Service topdrive and crown. Install blower hose. RIH to 10230'. Lay down single. Orient to 180 degrees and trough low side for open hole sidetrack. Start trough at 10204'. Exit point at 10225' MD, 8702' TVD. Slide drill to 10280'. Up weight 200k, down 125k. Pump at 275 gpm with 1610 psi on bottom, 1490 off bottom. WOB 5-7k. Drill ahead to 10525'. Up weight 185k, down 135k, RT 158k. WOB 3-10k. Torque 6-7k on bottom, 5-6k off bottom at 55 rpm. Pump at 272 gpm with 1900 psi on bottom, 1570 psi off bottom. SPR's at 10425'/0600 hours both pumps, 30/470, 45/600. Drill ahead to 10700'. Up weight 180k, down 135k, RT 155k. Torque 5-6k off bottom, 6-7k on bottom at 55 rpm. WOB 5-10k. Pump at 272 gpm with 1630 psi off bottom, 1900 psi on bottom. SPR's both pumps at 10600'/1500 hours, 30/480, 45/600. Pump Hi-vis beaded sweep surface to surface until clean, rotating and reciprocating. Shut down and monitor well. POOH to 9921' inside shoe. Safety stand down meeting with Mike Schultz, Dan Hebert, rig reps and crew. Hold PJSM. RIH to 10700'. Tight at 10520' to 10570'. Pull 50k over. Reamed from 10520' to 10570'. Drill ahead to 10809' MD, 8702' TVD. Up weight 180k, down 135k, RT 155k. Pump at 270 gpm with 1600 psi on bottom, 1900 psi off bottom. SPR's 30/540, 45/660 at 10700', 0215 hours. Losses of 48 bph. Total losses from 0000 to 0600, 286 bbls. Circulate 25 bbl Hi-vis sweep surface to surface until clean. Monitor well. POOH to 9921' into 7" shoe. No problems. Blow Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: 06-13 Common Well Name: 06-13 Spud Date: 5/15/1980 Event Name: REENTER+COMPLETE Start: 11/1/2006 End: 11/23/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task Code' NPT ~ Phase Description of Operations 12/3/2006 07:00 - 08:00 1.00 DRILL P 08:00 - 12:00 4.00 DRILL P 12:00 - 14:00 I 2.001 DRILL I P 14:00 - 00:00 10.00 ~ DRILL P 12/4/2006 100:00 - 12:00 I 12.00 DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 12/5/2006 100:00 - 01:30 I 1.501 DRILL I P 01:30 - 03:30 2.00 DRILL P 03:30 - 04:30 1.00 DRILL P 04:30 - 07:30 I 3.001 DRILL I P 07:30 - 09:00 1.50 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 12:00 2.00 DRILL P 12:00 - 15:00 3.00 DRILL P 15:00 - 17:00 2.00 DRILL P 17:00 - 18:30 1.50 DRILL P 18:30 - 22:30 4.00 DRILL P 22:30 - 00:00 1.50 DRILL P 12/6/2006 100:00 - 03:30 I 3.501 DRILL I P 03:30 - 04:00 0.50 CASE P 04:00 - 05:00 1.00 CASE P 05:00 - 09:00 4.00 CASE P 09:00 - 10:00 1.00 CASE P 10:00 - 15:30 5.50 CASE P PROD1 top drive down. PROD1 Held safety stand down meeting with Mike Schultz, Dan Hebert, rig reps and crew. PROD1 RIH to 10203'. Fill pipe and break circulation. Orient tool face and wash down to 10296' with no problems. RIH to 10761', no problems. Up weight 185k, down weight 135k. Wash to 10809'. PRODi Drill ahead to 11136' MD, 8699' TVD. Up weight 185k, down 135k, RT 155k. Torque 6k off bottom, 7k on bottom at 55 rpm. Pump at 272 gpm with 1500 psi off bottom, 1750 psi on bottom. SPR's both pumps, 30/540, 45/660 at 10800', 1400 hours. PROD1 Directional drill ahead to 11574' MD, 8693' TVD. Up weight 185k, down 135k, RT 155k. WOB 5-10k. Torque off bottom 5-6k, on bottom 6-7k at 60 rpm. Pump at 272 gpm with 1560 psi off bottom, 1870 psi on bottom. PROD1 Drill ahead to 12309' MD. Up weight 185k, down 130k, RT 155k. WOB 5-15k. Torque off bottom 5-6k, on bottom 6-7k at 80 rpm. Pump at 272 gpm with 1710 psi off bottom, 2000 psi on bottom. PROD1 Drill ahead to TD of 12500' MD, 8684' TVD. Town Geologist called TD at 0130 hours after consultation with town personnel. Up weight 185k, down 135k, RT 155k. WOB 12k. Torque off bottom 5-6k, on bottom 6-7k at 60 rpm. Pump at 272 gpm with 1680 psi off bottom, 2200 psi on bottom. SPR's both pumps, 30/500, 45/600 at 12500', 0300 hours. PROD1 Monitor well. Circulate 1 1/2 x BU. Pump sweep and circulate hole clean. Monitor well. PROD1 Short trip from 12,500' to 12,162'(swabbing). Pumped out from 12,349' to 12,256'. Run back to bottom. PROD1 Pump 40 bbl. Hi-Vis sweep around, until hole cleans up. Monitor well. PROD1 Short trip from 12,500' to 9,921'. Blow down topdrive. PROD1 Service topdrive and rig. PROD1 Run in hole to 12,500'. PROD1 Fill pipe,break circulation. Stage up pump, circulate and condition hole while rotating and reciprocating. Pump Hi-Vis sweep and continue to circulate until shakers clean up. PROD1 Monitor well. POOH from 12,500' to 9921',no problems. Monitor well at shoe and remove blower hose. PROD1 Drop dart to open circulating sub and pump bottoms up at 450 GPM,1250 psi. Pump dry job. PROD1 POOH from 9921' to BHA ~ 390'. PROD1 Change out handling equipment. Lay down HWDP and 2 flex non mag collars. Flush BHA with water. PROD1 PJSM. Remove radioactive sources, download MWD and lay out BHA RUNPRD Clear and clean rig floor. RUNPRD Rig up to run 4 1/2" 12.6# L-80 slotted liner. RUNPRD Run 4 1/2" ,12.6#,L-80,IBT-M, liner. RUNPRD Change out handling equipment . Up wt 55k, down wt 55k. RUNPRD Run in hole with liner on 4" drill pipe from 2654' to 9981'. Fill pipe and break circulation,125 GPM ~ 360 psi. Up wt. 170k down wt, 135k. Printed: 12/11/2006 1:42:34 PM BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: 0 6-13 Common W ell Name: 0 6-13 Spud Date: 5/15/1980 Event Nam e: REENTE R+COM PLET E Start : 11/1/2006 End: 11/23/2006 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 12/9/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To -- - Hours -- Task - --- Code I----- NPT ' Phase Description of Operations - _ -- 12/6/2006 15:30 - 16:30 1.00 CASE P RUNPRD Run in hole from 9981' to 12,500'. Tag bottom ~ 12,500 and verify tag. Up wt. 190k,down wt. 140k. 16:30 - 17:30 1.00 CASE P RUNPRD Drop ball, and pump at 4 BPM for 1/2 the drill pipe volume. Slow pump to 2 BPM to land ball on seat. Set packer and release hanger as per Baker Rep, with 4000 psi. Test annulus to 1500 psi,bleed off pressure. 17:30 - 20:00 2.50 CASE P RUNPRD Pull up to un-sting from hanger,displace well to clean seawater (530 bbls.) Safety meeting with Nabors drilling rep Dave Hebert. 20:00 - 00:00 4.00 CASE P RUNPRD Monitor well. Blow down topdrive,POOH laying down drill pipe from 9870' to 5875'. 12/7/2006 00:00 - 04:00 4.00 CASE P RUNPRD POOH laying down drill pipe from 5875' to surface. 04:00 - 05:30 1.50 CASE P RUNPRD Change out handling equipment,lay down liner running tool. Change handling equipment, run in hole 37 stands from derrick to 3452'. 05:30 - 07:00 1.50 CASE P RUNPRD Slip and cut drilling line,service rig. 07:00 - 10:30 3.50 CASE P RUNPRD POOH laying down drill pipe from 3452' to surface. 10:30 - 12:00 1.50 CASE P RUNPRD Clear and clean rig floor. Pull wear ring and remove saver sub. 12:00 - 16:30 4.50 BUNCO RUNCMP PJSM. Change out bales,pick up casing tools and rig up to run 4 1/2",12.6#, 13CR-80, Vam-top tubing.Average static losses 50 BPH. 16:30 - 00:00 7.50 BUNCO RUNCMP Run 4 1/2",12.6#,13CR-80,Vam-Top tubing to 2675'. Torque turn connections, and Baker Lok connections below the packer.Average dynamic losses 50 BPH. 12/8/2006 00:00 - 12:00 12.00 BUNCO RUNCMP Run 4 1/2",12.6#,13CR-80,Vam-Top tubing to 9858'. Torque turn connections.Average dynamic losses 50 BPH. Tag up at 9858' and pull up for space out measurement. Up wt. 135k,down wt. 110k. 12:00 - 14:00 2.00 BUNCO RUNCMP Pick up and make up space out pups (7.74',9.91',9.97').Make up joint #228, hanger, and landing joint as per Baker and FMC reps. Run in lock down screws. 14:00 - 17:30 3.50 BUNCO RUNCMP Rig up circulating lines to reverse circulate in corrosion inhibitor. Circulate at 38 BPM ~ 160 psi,150 bbls clean seawater. Change out bales,install saver sub,clear floor. 17:30 - 19:00 1.50 BUNCO RUNCMP Drop ball,set packer,test tubing to 3500 psi for 30 minutes,record on chart. Bleed tubing to 1500 psi and pressure up annulus to 3500 psi,hold for 30 minutes,record on chart. Bleed off tubing to shear DCK valve (sheared). 19:00 - 20:00 1.00 BOPSU P RUNCMP Dry rod TWC and test to 1000 psi from below. 20:00 - 22:30 2.50 BOPSU P RUNCMP Blow down all surface equipment. Pull riser and mouse hole. Nipple down BOP. 22:30 - 00:00 1.50 BOPSU P RUNCMP Nipple up adaptor flange and tree. 12/9/2006 00:00 - 02:00 2.00 BOPSU P RUNCMP Test adaptor to 5000 psi. Complete nipple up of tree. Test tree to 5000 psi. 02:00 - 03:00 1.00 BOPSU P RUNCMP Rig up DSM lubricator and pull TWC. Rig down lubricator. 03:00 - 04:30 1.50 BOPSU P RUNCMP Rig up circulating hoses from top of tree to cuttings tank. Rig up U tube hoses to Little Red Hot Oil Services. 04:30 - 05:30 1.00 BOPSU P RUNCMP Circulate 155 bbl Diesel down annulus 2 1/2 BPM 0900 psi. 05:30 - 09:00 3.50 BOPSU P RUNCMP U-Tube annulus x tubing. Dry rod BPV and test from below to 1000 psi. Suck back circulating lines and rig down Little Red Hot Oil Services. Rig down circulating lines,remove secondary annulus valve. Secure well,Rig Released at 09:00 12/9/2006 Printed: 12/11/2006 1:42:34 PM ~alliburton Company Survey Report Company: BP AI710C0 Ih~te: 12%19/2006 fimc: 11 :27:43 Na~;c: 1 Ficl~l: Prudhoe Bay Co-ordinare(NE:) Kef ercncc: Well: 06-13, True N orth Sic: PB DS 06 Vertical (TVD) Kefer cncc: 6-13A: 67.0 ~~'cll: 06 .3 Section (VS) Kefercncc: Well (O.OON,O.OOE, 100.OOAzi) ui Il~i:~th: U6 '~3A Surccy Calculation M ethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED ST ATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 06-13 Slot Name: 06-13 Well Position: +N/-S -1193.99 ft Northing : 5940701.40 ft Latitude: 70 14 34.785 N +E/-W 586.24 ft Easting : 685290.16 ft Longitude: 148 30 12.181 W Position Uncertainty: 0.00 ft Wellpath: 06-13A Drilled From: 06-13A PBi 500292045701 Tie-on Depth: 10220.72 ft Current Datum: 6-13A: Height 67.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2006 Declination: 24.24 deg Field Strength: 57657 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 100.00 Survey Program for Definitive Wellpath Date: 12/19/2006 Validated: N o Version: 2 Actual From To Survey Toolcode Tool Name ft ft 99.00 4899.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 4909.00 10220.72 06-13A PB1 II FR+MS+Sag (4909.0 MWD+IFR+MS MWD +IFR + Multi Station 10225.00 12452.73 06-13A IIFR+MS+Sag (10225.00-1 MWD+IFR+MS MWD +IFR + Multi Station Survey ~tll incl Azim TVD Sys TVD N1S PJ11' MapN MapE Tool ft deg deg ft ft ft ft ft ft 30.00 0.00 0.00 30.00 -37.00 0.00 0.00 5940701.40 685290.16 TIE LINE 99.00 0.00 0.00 99.00 32.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 199.00 0.00 0.00 199.00 132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 299.00 0.00 0.00 299.00 232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 399.00 0.00 0.00 399.00 332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 499.00 0.00 0.00 499.00 432.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 599.00 0.00 0.00 599.00 532.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 699.00 0.00 0.00 699.00 632.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 799.00 0.00 0.00 799.00 732.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 899.00 0.00 0.00 899.00 832.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 999.00 0.00 0.00 999.00 932.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1099.00 0.00 0.00 1099.00 1032.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1199.00 0.00 0.00 1199.00 1132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1299.00 0.00 0.00 1299.00 1232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1399.00 0.00 0.00 1399.00 1332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1499.00 0.00 0.00 1499.00 1432.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1599.00 0.00 0.00 1599.00 1532.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1699.00 0.00 0.00 1699.00 1632.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1799.00 0.00 0.00 1799.00 1732.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1899.00 0.00 0.00 1899.00 1832.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1999.00 0.00 0.00 1999.00 1932.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2099.00 0.00 0.00 2099.00 2032.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2199.00 0.00 0.00 2199.00 2132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2299.00 0.00 0.00 2299.00 2232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2399.00 0.00 0.00 2399.00 2332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2499.00 1.00 144.70 2498.99 2431.99 -0.71 0.50 5940700.70 685290.68 CB-GYRO-MS 2599.00 0.00 0.00 2598.99 2531.99 -1.42 1.01 5940700.00 685291.20 CB-GYRO-MS 2699.00 1.00 131.43 2698.98 2631.98 -2.00 1.66 5940699.44 685291.87 CB-GYRO-MS ~alliburton Company Survey Report ('ompan~: BP Amoco Date: 12'19;2006 fine: 11 :2i:43 P,~~e: 2 field: Pr udhoe Bay Co-ord inare~Nh) Kcference: Well: 06-i3, True N orth Site: PB DS 06 ~%crtical (TAT)) Refer ence 6-1 3A: 67.0 1~`cll: 06 -13 Section (VS) itefcren ce: Well (O.OON,O.OOE,1 00.OOAzi) ~1'clipath: 06 -13A Survey Calculation D lcthod: Mi nimum Curvature Db: Oracle Survey JIll Intl Azim I'~~U SFS TVU N/S li/N' -- AIapN - ,\9apE I'uol ft deg deg ft ft ft ft ft ft 2799.00 2.75 111.88 2798.93 2731.93 -3.47 4.54 5940698.04 685294.79 CB-GYRO-MS 2899.00 7.00 99.42 2898.55 2831.55 -5.37 12.78 5940696.35 685303.07 CB-GYRO-MS 2999.00 11.00 100.98 2997.29 2930.29 -8.18 28.17 5940693.91 685318.52 CB-GYRO-MS 3099.00 15.25 99.63 3094.66 3027.66 -12.20 50.51 5940690.45 685340.95 CB-GYRO-MS 3199.00 19.75 100.28 3190.01 3123.01 -17.42 80.12 5940685.96 685370.68 CB-GYRO-MS 3299.00 21.75 98.92 3283.52 3216.52 -23.31 115.05 5940680.93 685405.74 CB-GYRO-MS 3399.00 23.00 99.40 3375.99 3308.99 -29.37 152.63 5940675.79 685443.45 CB-GYRO-MS 3499.00 24.75 99.15 3467.43 3400.43 -35.89 192.57 5940670.26 685483.54 CB-GYRO-MS 3599.00 26.00 101.60 3557.78 3490.78 -43.63 234.71 5940663.56 685525.86 CB-GYRO-MS 3699.00 27.75 103.12 3646.98 3579.98 -53.32 278.86 5940654.95 685570.23 CB-GYRO-MS 3799.00 28.00 103.67 3735.37 3668.37 -64.15 324.34 5940645.24 685615.96 CB-GYRO-MS 3899.00 28.00 104.20 3823.67 3756.67 -75.46 369.91 5940635.06 685661.79 CB-GYRO-MS 3999.00 28.00 103.85 3911.96 3844.96 -86.84 415.45 5940624.81 685707.60 CB-GYRO-MS 4099.00 28.00 104.37 4000.26 3933.26 -98.28 460.99 5940614.49 685753.39 CB-GYRO-MS 4199.00 27.00 104.90 4088.96 4021.96 -109.94 505.66 5940603.93 685798.34 CB-GYRO-MS 4299.00 27.00 104.55 4178.06 4111.06 -121.48 549.57 5940593.47 685842.52 CB-GYRO-MS 4399.00 26.75 106.00 4267.26 4200.26 -133.39 593.17 5940582.64 685886.40 CB-GYRO-MS 4499.00 26.50 105.45 4356.65 4289.65 -145.54 636.31 5940571.56 685929.82 CB-GYRO-MS 4599.00 26.25 106.90 4446.25 4379.25 -157.91 678.98 5940560.24 685972.77 CB-GYRO-MS 4699.00 26.00 106.57 4536.03 4469.03 -170.59 721.14 5940548.60 686015.23 CB-GYRO-MS 4799.00 26.00 107.12 4625.91 4558.91 -183.29 763.10 5940536.93 686057.49 CB-GYRO-MS 4899.00 25.75 107.67 4715.88 4648.88 -196.34 804.74 5940524.92 686099.44 CB-GYRO-MS 4909.00 25.73 107.80 4724.89 4657.89 -197.66 808.88 5940523.70 686103.61 MWD+IFR+MS 4926.00 26.32 112.25 4740.17 4673.17 -200.21 815.88 5940521.31 686110.67 MWD+IFR+MS 5018.20 26.47 130.45 4822.89 4755.89 -221.32 850.49 5940501.07 686145.79 MWD+IFR+MS 5111.23 25.53 148.80 4906.64 4839.64 -251.97 876.70 5940471.07 686172.74 MWD+IFR+MS 5172.85 25.77 160.98 4962.23 4895.23 -276.01 887.95 5940447.32 686184.57 MWD+IFR+MS 5266.10 25.27 162.71 5046.38 4979.38 -314.18 900.47 5940409.47 686198.03 MWD+IFR+MS 5359.98 24.91 162.04 5131.41 5064.41 -352.12 912.53 5940371.84 686211.01 MWD+IFR+MS 5452.77 24.29 166.91 5215.78 5148.78 -389.30 922.88 5940334.93 686222.27 MWD+IFR+MS 5545.19 24.44 174.85 5299.99 5232.99 -426.87 928.90 5940297.52 686229.21 MWD+IFR+MS 5638.48 25.39 180.47 5384.61 5317.61 -466.09 930.47 5940258.35 686231.75 MWD+IFR+MS 5731.62 27.48 184.11 5468.02 5401.02 -507.50 928.76 5940216.91 686231.06 MWD+IFR+MS 5826.03 30.11 190.05 5550.76 5483.76 -552.56 923.07 5940171.73 686226.47 MWD+IFR+MS 5920.10 32.89 193.53 5630.97 5563.97 -600.64 912.97 5940123.42 686217.56 MWD+IFR+MS 6015.83 33.15 195.16 5711.24 5644.24 -651.18 900.04 5940072.58 686205.88 MWD+IFR+MS 6110.17 32.93 194.15 5790.32 5723.32 -700.94 887.03 5940022.52 686194.10 MWD+IFR+MS 6205.14 32.90 194.89 5870.05 5803.05 -750.90 874.09 5939972.26 686182.39 MWD+IFR+MS 6300.04 32.39 203.76 5950.00 5883.00 -799.10 857.22 5939923.66 686166.71 MWD+IFR+MS 6394.80 32.28 204.99 6030.07 5963.07 -845.26 836.30 5939877.00 686146.94 MWD+IFR+MS 6489.66 31.68 204.78 6110.53 6043.53 -890.84 815.16 5939830.93 686126.92 MWD+IFR+MS 6584.43 31.56 204.01 6191.23 6124.23 -936.08 794.64 5939785.19 686107.52 MWD+IFR+MS 6679.13 31.38 203.99 6272.00 6205.00 -981.25 774.53 5939739.55 686088.53 MWD+IFR+MS 6773.06 31.16 203.89 6352.29 6285.29 -1025.81 754.75 5939694.51 686069.85 MWD+IFR+MS 6866.78 30.72 204.06 6432.67 6365.67 -1069.84 735.17 5939650.02 686051.36 MWD+IFR+MS 6958.76 31.65 200.60 6511.37 6444.37 -1113.88 717.10 5939605.55 686034.38 MWD+IFR+MS 7052.29 31.77 199.30 6590.94 6523.94 -1160.09 700.32 5939558.94 686018.75 MWD+IFR+MS 7145.48 32.54 195.54 6669.84 6602.84 -1207.40 685.50 5939511.29 686005.09 MWD+IFR+MS 7238.53 32.45 194.22 6748.32 6681.32 -1255.71 672.66 5939462.68 685993.44 MWD+IFR+MS 7331.59 31.45 193.90 6827.28 6760.28 -1303.48 660.70 5939414.63 685982.66 MWD+IFR+MS 7424.61 32.46 194.49 6906.21 6839.21 -1351.20 648.62 5939366.63 685971.76 MWD+IFR+MS 7517.34 31.91 194.34 6984.69 6917.69 -1399.04 636.32 5939318.51 685960.64 MWD+IFR+MS ~alliburton Company Survey Report Cumpan~: BP faI1l000 Date: 12'19/2006 Time: 11:27:43 Pale: 3 !, field: Pru dliue Bay Co-ord inatelNE) Refercncr. W elt 06-i3, True N orth ~ Site: PB DS 06 Vertica l ('fVlll Refer ence: 6- 13A: 67.0 ~~ ':~'cll: 06- 13 Section ('v S) Reference: W ell (O.OON,O.OOE, 100.OOAzi) A1'clipath: 06-13A Survc~~ Calculation'V Ie(hod: Mi nimum Curvature Db: Oracle Survcv SID IncJ Azim "fell Scs T~'D N/S I~;/~V i,iapN \IapE Tool ft deg deg ft ft ft it ft ft 7611.53 32.51 194.16 7064.38 6997.38 -1447.70 623.97 5939269.56 685949.49 MWD+IFR+MS 7704.82 33.19 191.88 7142.76 7075.76 -1497.00 612.58 5939220.00 685939.31 MWD+IFR+MS 7799.06 32.30 191.99 7222.02 7155.02 -1546.87 602.04 5939169.89 685930.00 MWD+IFR+MS 7892.35 31.37 191.71 7301.27 7234.27 -1595.03 591.93 5939121.50 685921.08 MWD+IFR+MS 7986.65 32.76 192.15 7381.19 7314.19 -1644.01 581.58 5939072.28 685911.94 MWD+IFR+MS 8041.90 33.95 191.78 7427.34 7360.34 -1673.73 575.28 5939042.42 685906.37 MWD+IFR+MS 8090.34 34.87 191.00 7467.30 7400.30 -1700.56 569.88 5939015.46 685901.63 MWD+IFR+MS 8183.96 36.06 188.28 7543.55 7476.55 -1754.10 560.80 5938961.72 685893.88 MWD+IFR+MS 8279.32 38.52 185.72 7619.42 7552.42 -1811.44 553.80 5938904.23 685888.28 MWD+IFR+MS 8372.94 39.31 184.26 7692.26 7625.26 -1870.02 548.69 5938845.55 685884.62 MWD+IFR+MS 8467.69 41.80 180.57 7764.26 7697.26 -1931.54 546.15 5938783.98 685883.59 MWD+IFR+MS 8562.20 45.27 177.66 7832.77 7765.77 -1996.61 547.20 5938718.97 685886.24 MWD+IFR+MS 8656.58 49.91 174.06 7896.42 7829.42 -2066.06 552.31 5938649.66 685893.06 MWD+IFR+MS 8750.58 52.35 170.82 7955.41 7888.41 -2138.59 561.97 5938577.40 685904.50 MWD+IFR+MS 8846.23 55.37 169.05 8011.82 7944.82 -2214.62 575.49 5938501.73 685919.88 MWD+IFR+MS 8941.57 54.84 168.54 8066.36 7999.36 -2291.33 590.69 5938425.42 685936.96 MWD+IFR+MS 9036.61 53.85 168.08 8121.76 8054.76 -2366.95 606.33 5938350.21 685954.45 MWD+IFR+MS 9130.03 52.80 167.10 8177.56 8110.56 -2440.13 622.43 5938277.46 685972.34 MWD+IFR+MS 9224.89 54.62 168.73 8233.70 8166.70 -2514.89 638.42 5938203.12 685990.17 MWD+IFR+MS 9318.89 53.63 168.24 8288.79 8221.79 -2589.52 653.63 5938128.89 686007.20 MWD+IFR+MS 9414.79 52.29 168.37 8346.55 8279.55 -2664.48 669.14 5938054.34 686024.55 MWD+IFR+MS 9507.91 52.96 169.59 8403.08 8336.08 -2737.11 683.29 5937982.08 686040.48 MWD+IFR+MS 9603.23 52.36 169.57 8460.90 8393.90 -2811.65 696.99 5937907.91 686056.01 MWD+IFR+MS 9697.02 56.81 170.31 8515.23 8448.23 -2886.89 710.33 5937833.02 686071.19 MWD+IFR+MS 9792.28 59.62 169.80 8565.41 8498.41 -2966.64 724.32 5937753.64 686087.13 MWD+IFR+MS 9886.82 59.71 169.55 8613.15 8546.15 -3046.91 738.94 5937673.76 686103.73 MWD+IFR+MS 10004.44 60.72 170.52 8671.58 8604.58 -3147.45 756.60 5937573.69 686123.85 MWD+IFR+MS 10035.20 67.13 170.49 8685.09 8618.09 -3174.69 761.16 5937546.57 686129.07 MWD+IFR+MS 10069.18 75.20 171.21 8696.06 8629.06 -3206.42 766.26 5937514.98 686134.96 MWD+IFR+MS 10100.68 82.58 171.15 8702.12 8635.12 -3236.94 771.00 5937484.59 686140.44 MWD+IFR+MS 10127.10 88.57 171.30 8704.16 8637.16 -3262.96 775.01 5937458.68 686145.10 MWD+IFR+MS 10154.91 93.43 171.60 8703.67 8636.67 -3290.45 779.15 5937431.30 686149.90 MWD+IFR+MS 10189.76 90.73 172.68 8702.41 8635.41 -3324.94 783.91 5937396.93 686155.51 MWD+IFR+MS 10220.72 90.29 172.62 8702.13 8635.13 -3355.65 787.87 5937366.34 686160.23 MWD+IFR+MS 10225.00 90.62 172.37 8702.10 8635.10 -3359.89 788.43 5937362.11 686160.89 MWD+IFR+MS 10247.74 89.80 170.99 8702.02 8635.02 -3382.39 791.72 5937339.70 686164.73 MWD+IFR+MS 10280.36 90.11 167.76 8702.04 8635.04 -3414.45 797.73 5937307.80 686171.53 MWD+IFR+MS 10313.13 90.79 165.53 8701.78 8634.78 -3446.33 805.30 5937276.12 686179.88 MWD+IFR+MS 10341.22 90.63 162.62 8701.44 8634.44 -3473.34 813.01 5937249.31 686188.25 MWD+IFR+MS 10375.49 89.66 159.32 8701.35 8634.35 -3505.73 824.18 5937217.20 686200.21 MWD+IFR+MS 10405.50 90.09 156.39 8701.41 8634.41 -3533.52 835.49 5937189.70 686212.20 MWD+IFR+MS 10435.23 90.21 154.40 8701.34 8634.34 -3560.55 847.87 5937162.98 686225.24 MWD+IFR+MS 10467.84 90.64 151.12 8701.09 8634.09 -3589.54 862.79 5937134.37 686240.87 MWD+IFR+MS 10497.88 90.38 146.78 8700.83 8633.83 -3615.27 878.28 5937109.03 686256.99 MWD+IFR+MS 10528.19 90.40 143.14 8700.62 8633.62 -3640.08 895.68 5937084.66 686274.99 MWD+IFR+MS 10557.52 90.89 141.41 8700.29 8633.29 -3663.28 913.62 5937061.91 686293.50 MWD+IFR+MS 10619.58 90.09 138.08 8699.76 8632.76 -3710.63 953.72 5937015.56 686334.74 MWD+IFR+MS 10684.43 90.09 137.98 8699.66 8632.66 -3758.84 997.09 5936968.43 686379.28 MWD+IFR+MS 10712.51 89.46 136.92 8699.77 8632.77 -3779.53 1016.08 5936948.22 686398.77 MWD+IFR+MS 10746.04 88.98 135.61 8700.22 8633.22 -3803.75 1039.25 5936924.57 686422.53 MWD+IFR+MS 10775.69 89.40 133.06 8700.64 8633.64 -3824.47 1060.46 5936904.38 686444.24 MWD+IFR+MS 10806.26 89.65 131.61 8700.90 8633.90 -3845.06 1083.05 5936884.36 686467.33 MWD+IFR+MS 10838.50 90.58 129.18 8700.83 8633.83 -3865.95 1107.60 5936864.08 686492.39 MWD+IFR+MS ~alliburton Company Survey Report Company: BP Amoro Field: Pru dhoe Bay Silc: PB DS 06 ~~'ell: 06- 13 ~ ~T'cllpath: 06- 13A Sune~ -- \ID Intl ft deg 10869.46 90.69 10900.50 90.96 10931.67 90.77 10962.26 90.83 10994.28 90.28 11025.33 90.21 11056.42 90.52 11086.97 90.58 11121.63 91.25 11151.76 90.57 11182.07 90.10 11214.14 90.20 11246.40 91.51 11276.10 90.76 11369.03 89.95 11462.76 90.94 11556.47 90.39 11650.47 90.51 11743.43 90.14 11836.78 90.58 11928.98 91.25 12021.44 90.16 12115.77 91.63 12206.59 91.00 12300.43 90.35 12393.30 90.15 12452.73 89.72 12500.00 89.72 Date: 1 2.'19/2006 Time: ' 1 :27:43 Pa~c: -1 Co-ordiuatetNF) kefere~nce: Uvell: 06- i 3, True North Vertical ('TVD1 Reference: 6-13A: 67.0 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Sunny Calculation ~[cthorl: Minimum Curvature Db: Oracle Azim deg fVll ft Sys "f~'U ft \/S ft 1?/~1' ft \iapA ft ~~lapt: ft "foul 127.40 8700.49 8633.49 -3885.13 1131.90 5936845.50 686517.15 MWD+IFR+MS 125.22 8700.04 8633.04 -3903.51 1156.91 5936827.75 686542.60 MWD+IFR+MS 124.04 8699.57 8632.57 -3921.22 1182.56 5936810.67 686568.67 MWD+IFR+MS 122.31 8699.14 8632.14 -3937.96 1208.16 5936794.57 686594.67 MWD+IFR+MS 120.38 8698.83 8631.83 -3954.61 1235.50 5936778.59 686622.42 MWD+IFR+MS 117.98 8698.70 8631.70 -3969.75 1262.61 5936764.13 686649.89 MWD+IFR+MS 116.91 8698.50 8631.50 -3984.08 1290.20 5936750.48 686677.82 MWD+IFR+MS 114.27 8698.21 8631.21 -3997.27 1317.75 5936737.97 686705.68 MWD+IFR+MS 112.45 8697.66 8630.66 -4011.01 1349.56 5936725.02 686737.82 MWD+IFR+MS 110.76 8697.18 8630.18 -4022.10 1377.57 5936714.62 686766.09 MWD+IFR+MS 109.86 8697.00 8630.00 -4032.62 1405.99 5936704.80 686794.77 MWD+IFR+MS 107.85 8696.92 8629.92 -4042.99 1436.34 5936695.19 686825.36 MWD+IFR+MS 106.77 8696.44 8629.44 -4052.58 1467.14 5936686.35 686856.38 MWD+IFR+MS 104.20 8695.85 8628.85 -4060.51 1495.75 5936679.13 686885.17 MWD+IFR+MS 102.71 8695.27 8628.27 -4082.13 1586.12 5936659.74 686976.05 MWD+IFR+MS 104.38 8694.54 8627.54 -4104.08 1677.24 5936640.03 687067.67 MWD+IFR+MS 104.44 8693.46 8626.46 -4127.40 1767.99 5936618.95 687158.97 MWD+IFR+MS 104.24 8692.72 8625.72 -4150.68 1859.06 5936597.92 687250.57 MWD+IFR+MS 102.69 8692.19 8625.19 -4172.33 1949.46 5936578.51 687341.47 MWD+IFR+MS 102.78 8691.60 8624.60 -4192.91 2040.51 5936560.17 687433.00 MWD+IFR+MS 102.53 8690.13 8623.13 -4213.10 2130.46 5936542.19 687523.41 MWD+IFR+MS 100.71 8688.99 8621.99 -4231.72 2221.02 5936525.81 687614.39 .MWD+IFR+MS 99.81 8687.52 8620.52 -4248.52 2313.82 5936511.29 687707.57 MWD+IFR+MS 99.92 8685.44 8618.44 -4264.08 2403.28 5936497.94 687797.38 MWD+IFR+MS 100.31 8684.33 8617.33 -4280.56 2495.65 5936483.74 687890.12 MWD+IFR+MS 99.78 8683.93 8616.93 -4296.76 2587.10 5936469.80 687981.93 MWD+IFR+MS 99.64 8683.99 8616.99 -4306.78 2645.67 5936461.22 688040.74 MWD+IFR+MS 99.64 8684.22 8617.22 -4314.70 2692.28 5936454.45 688087.51 PROJECTED to TD ~alliburton Company Survey Report C"umpan}: BP AI710C0 Datc: 12:19/2006 Time: 1 1:25:09 Pa;;e: I Field_ Prudhoe B2y Co-ordinatciNi'1 Rcfcrcncr. Well: 06-13. Trull North tide: PB DS 06 Vertical 1"C~'lli Rd'cr cncc 6-13A PB1: 67.0 Well: 06-13 .Section (VS) Reference: Well (O.OON,O.OOE, 100.OOAzi) I ~i'ellpath: 06-13A PB1 Survey Calculation A feUwd: Minimum Curvature Db: Oracle Field: Prudhoe Bay - -- -_ North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2006 Well: 06-13 Slot Name: 06-13 Well Position: +N/-S -1193.99 ft Northing: 5940701.40 ft Latitude: 70 14 34.785 N +E/-W 586.24 ft Easting : 685290.16 ft Longitude: 148 30 12.181 W Position Uncertainty: 0.00 ft Wellpath: 06-13A PBi Drilled From: 06-13 500292045770 Tie-on Depth: 4899.00 ft Current Datum: 6-13A PBt : Height 67.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2006 Declination: 24.24 deg Field Strength: 57657 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 100.00 Survey Program for Definitive Wellpath Date: 4/3/2006 Validated: N o Version: 12 Actual From To Survey Toolcode Tool Name ft ft 99.00 4899.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 4909.00 11214.72 06-13A PB1 II FR+MS+S ag (4909.0 MW D+IFR+MS MW D +IFR + Multi Station Survey ~1U Intl Azim I'~1) Sys'l'VU N/S E/V1' MapN MapE Tool it deg deg ft ft ft ft ft ft 30.00 0.00 --- - - 0.00 - 30.00 -37.00 - 0.00 0.00 5940701.40 685290.16 TIE LINE 99.00 0.00 0.00 99.00 32.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 199.00 0.00 0.00 199.00 132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 299.00 0.00 0.00 299.00 232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 399.00 0.00 0.00 399.00 332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 499.00 0.00 0.00 499.00 432.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 599.00 0.00 0.00 599.00 532.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 699.00 0.00 0.00 699.00 632.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 799.00 0.00 0.00 799.00 732.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 899.00 0.00 0.00 899.00 832.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 999.00 0.00 0.00 999.00 932.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1099.00 0.00 0.00 1099.00 1032.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1199.00 0.00 0.00 1199.00 1132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1299.00 0.00 0.00 1299.00 1232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1399.00 0.00 0.00 1399.00 1332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1499.00 0.00 0.00 1499.00 1432.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1599.00 0.00 0.00 1599.00 1532.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1699.00 0.00 0.00 1699.00 1632.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1799.00 0.00 0.00 1799.00 1732.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1899.00 0.00 0.00 1899.00 1832.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 1999.00 0.00 0.00 1999.00 1932.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2099.00 0.00 0.00 2099.00 2032.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2199.00 0.00 0.00 2199.00 2132.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2299.00 0.00 0.00 2299.00 2232.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2399.00 0.00 0.00 2399.00 2332.00 0.00 0.00 5940701.40 685290.16 CB-GYRO-MS 2499.00 1.00 144.70 2498.99 2431.99 -0.71 0.50 5940700.70 685290.68 CB-GYRO-MS 2599.00 0.00 0.00 2598.99 2531.99 -1.42 1.01 5940700.00 685291.20 CB-GYRO-MS 2699.00 1.00 131.43 2698.98 2631.98 -2.00 1.66 5940699.44 685291.87 CB-GYRO-MS 2799.00 2.75 111.88 2798.93 2731.93 -3.47 4.54 5940698.04 685294.79 CB-GYRO-MS ~alliburton Company Survey Report Company: BP AmOCO Meld: Prudhoe Bay Site P6 DS 06 Wcll: 06 13 yVcllpath: Oi3 ''-3A PB1 Sure°cv __ bID Intl ft deg im deg 'll ft sT~"D ft Date: 12!19.2006 Time: '11 :25:09 P.~~e: 2 Co-ordinate(NE) Reference: W211: 06-13. True North Vertical (TVD) Reference: 6-13A PB1 : 67.0 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Survey Calculation Method: Minimum Curvature llb: Oracle N/S F,/iV MapN \IapG Tool ft ft ft ft 2899.00 7.00 99.42 2898.55 2831.55 -5.37 12.78 5940696.35 685303.07 CB-GYRO-MS 2999.00 11.00 100.98 2997.29 2930.29 -8.18 28.17 5940693.91 685318.52 CB-GYRO-MS 3099.00 15.25 99.63 3094.66 3027.66 -12.20 50.51 5940690.45 685340.95 CB-GYRO-MS 3199.00 19.75 100.28 3190.01 3123.01 -17.42 80.12 5940685.96 685370.68 CB-GYRO-MS 3299.00 21.75 98.92 3283.52 3216.52 -23.31 115.05 5940680.93 685405.74 CB-GYRO-MS 3399.00 23.00 99.40 3375.99 3308.99 -29.37 152.63 5940675.79 685443.45 CB-GYRO-MS 3499.00 24.75 99.15 3467.43 3400.43 -35.89 192.57 5940670.26 685483.54 CB-GYRO-MS 3599.00 26.00 101.60 3557.78 3490.78 -43.63 234.71 5940663.56 685525.86 CB-GYRO-MS 3699.00 27.75 103.12 3646.98 3579.98 -53.32 278.86 5940654.95 685570.23 CB-GYRO-MS 3799.00 28.00 1.03.67 3735.37 3668.37 -64.15 324.34 5940645.24 685615.96 CB-GYRO-MS 3899.00 28.00 104.20 3823.67 3756.67 -75.46 369.91 5940635.06 685661.79 CB-GYRO-MS 3999.00 28.00 103.85 3911.96 3844.96 -86.84 415.45 5940624.81 685707.60 CB-GYRO-MS 4099.00 28.00 104.37 4000.26 3933.26 -98.28 460.99 5940614.49 685753.39 CB-GYRO-MS 4199.00 27.00 104.90 4088.96 4021.96 -109.94 505.66 5940603.93 685798.34 CB-GYRO-MS 4299.00 27.00 104.55 4178.06 4111.06 -121.48 549.57 5940593.47 685842.52 CB-GYRO-MS 4399.00 26.75 106.00 4267.26 4200.26 -133.39 593.17 5940582.64 685886.40 CB-GYRO-MS 4499.00 26.50 105.45 4356.65 4289.65 -145.54 636.31 5940571.56 685929.82 CB-GYRO-MS 4599.00 26.25 106.90 4446.25 4379.25 -157.91 678.98 5940560.24 685972.77 CB-GYRO-MS 4699.00 26.00 106.57 4536.03 4469.03 -170.59 721.14 5940548.60 686015.23 CB-GYRO-MS 4799.00 26.00 107.12 4625.91 4558.91 -183.29 763.10 5940536.93 686057.49 CB-GYRO-MS 4899.00 25.75 107.67 4715.88 4648.88 -196.34 804.74 5940524.92 686099.44 CB-GYRO-MS 4909.00 25.73 107.80 4724.89 4657.89 -197.66 808.88 5940523.70 686103.61 MWD+IFR+MS 4926.00 26.32 112.25 4740.17 4673.17 -200.21 815.88 5940521.31 686110.67 MWD+IFR+MS 5018.20 26.47 130.45 4822.89 4755.89 -221.32 850.49 5940501.07 686145.79 MWD+IFR+MS 5111.23 25.53 148.80 4906.64 4839.64 -251.97 876.70 5940471.07 686172.74 MWD+IFR+MS 5172.85 25.77 160.98 4962.23 4895.23 -276.01 887.95 5940447.32 686184.57 MWD+IFR+MS 5266.10 25.27 162.71 5046.38 4979.38 -314.18 900.47 5940409.47 686198.03 MWD+IFR+MS 5359.98 24.91 162.04 5131.41 5064.41 -352.12 912.53 5940371.84 686211.01 MWD+IFR+MS 5452.77 24.29 166.91 5215.78 5148.78 -389.30 922.88 5940334.93 686222.27 MWD+IFR+MS 5545.19 24.44 174.85 5299.99 5232.99 -426.87 928.90 5940297.52 686229.21 MWD+IFR+MS 5638.48 25.39 180.47 5384.61 5317.61 -466.09 930.47 5940258.35 686231.75 MWD+IFR+MS 5731.62 27.48 184.11 5468.02 5401.02 -507.50 928.76 5940216.91 686231.06 MWD+IFR+MS 5826.03 30.11 190.05 5550.76 5483.76 -552.56 923.07 5940171.73 686226.47 MWD+IFR+MS 5920.10 32.89 193.53 5630.97 5563.97 -600.64 912.97 5940123.42 686217.56 MWD+IFR+MS 6015.83 33.15 195.16 5711.24 5644.24 -651.18 900.04 5940072.58 686205.88 MWD+IFR+MS 6110.17 32.93 194.15 5790.32 5723.32 -700.94 887.03 5940022.52 686194.10 MWD+IFR+MS 6205.14 32.90 194.89 5870.05 5803.05 -750.90 874.09 5939972.26 686182.39 MWD+IFR+MS 6300.04 32.39 203.76 5950.00 5883.00 -799.10 857.22 5939923.66 686166.71 MWD+IFR+MS 6394.80 32.28 204.99 6030.07 5963.07 -845.26 836.30 5939877.00 686146.94 MWD+IFR+MS 6489.66 31.68 204.78 6110.53 6043.53 -890.84 815.16 5939830.93 686126.92 MWD+IFR+MS 6584.43 31.56 204.01 6191.23 6124.23 -936.08 794.64 5939785.19 686107.52 MWD+IFR+MS 6679.13 31.38 203.99 6272.00 6205.00 -981.25 774.53 5939739.55 686088.53 MWD+IFR+MS 6773.06 31.16 203.89 6352.29 6285.29 -1025.81 754.75 5939694.51 686069.85 MWD+IFR+MS 6866.78 30.72 204.06 6432.67 6365.67 -1069.84 735.17 5939650.02 686051.36 MWD+IFR+MS 6958.76 31.65 200.60 6511.37 6444.37 -1113.88 717.10 5939605.55 686034.38 MWD+IFR+MS 7052.29 31.77 199.30 6590.94 6523.94 -1160.09 700.32 5939558.94 686018.75 MWD+IFR+MS 7145.48 32.54 195.54 6669.84 6602.84 -1207.40 685.50 5939511.29 686005.09 MWD+IFR+MS 7238.53 32.45 194.22 6748.32 6681.32 -1255.71 672.66 5939462.68 685993.44 MWD+IFR+MS 7331.59 31.45 193.90 6827.28 6760.28 -1303.48 660.70 5939414.63 685982.66 MWD+IFR+MS 7424.61 32.46 194.49 6906.21 6839.21 -1351.20 648.62 5939366.63 685971.76 MWD+IFR+MS 7517.34 31.91 194.34 6984.69 6917.69 -1399.04 636.32 5939318.51 685960.64 MWD+IFR+MS 7611.53 32.51 194.16 7064.38 6997.38 -1447.70 623.97 5939269.56 685949.49 MWD+IFR+MS ~alliburton Company • Survey Report Cumpanr: BP AmoCO f'idd: Prudhoe Bay tiitc PB DS 06 11'ell: 06-13 11~ellpath: 06-13A PB1 Uatc 12.'192006 Tinu~: 11 :;?5:09 Pagc: 3 Co-ordinacelNE) Keference: Well: 06-13. True North Vertical (TVD) Reference: 6-13A PE1 : 6, ~ Section (4S}Reference: Well (O.OON,O.OOE,t00.00Azi) Sure°ey~ Calculatinu Method: Minimum Curvature llb: Oracle Survcv MD Incl Acim T~'D Sys 'f~~D ~/S S/~ti' MapN MapE Tool ft deg deg ft ft ft ft ft ft 7704.82 33.19 191.88 7142.76 7075.76 -1497.00 612.58 5939220.00 685939.31 MWD+IFR+MS 7799.06 32.30 191.99 7222.02 7155.02 -1546.87 602.04 5939169.89 685930.00 MWD+IFR+MS 7892.35 31.37 191.71 7301.27 7234.27 -1595.03 591.93 5939121.50 685921.08 MWD+IFR+MS 7986.65 32.76 192.15 7381.19 7314.19 -1644.01 581.58 5939072.28 685911.94 MWD+IFR+MS 8041.90 33.95 191.78 7427.34 7360.34 -1673.73 575.28 5939042.42 685906.37 MWD+IFR+MS 8090.34 34.87 191.00 7467.30 7400.30 -1700.56 569.88 5939015.46 685901.63 MWD+IFR+MS 8183.96 36.06 188.28 7543.55 7476.55 -1754.10 560.80 5938961.72 685893.88 MWD+IFR+MS 8279.32 38.52 185.72 7619.42 7552.42 -1811.44 553.80 5938904.23 685888.28 MWD+IFR+MS 8372.94 39.31 184.26 7692.26 7625.26 -1870.02 548.69 5938845.55 685884.62 MWD+IFR+MS 8467.69 41.80 180.57 7764.26 7697.26 -1931.54 546.15 5938783.98 685883.59 MWD+IFR+MS 8562.20 45.27 177.66 7832.77 7765.77 -1996.61 547.20 5938718.97 685886.24 MWD+IFR+MS 8656.58 49.91 174.06 7896.42 7829.42 -2066.06 552.31 5938649.66 685893.06 MWD+IFR+MS 8750.58 52.35 170.82 7955.41 7888.41 -2138.59 561.97 5938577.40 685904.50 MWD+IFR+MS 8846.23 55.37 169.05 8011.82 7944.82 -2214.62 575.49 5938501.73 685919.88 MWD+IFR+MS 8941.57 54.84 168.54 8066.36 7999.36 -2291.33 590.69 5938425.42 685936.96 MWD+IFR+MS 9036.61 53.85 168.08 8121.76 8054.76 -2366.95 606.33 5938350.21 685954.45 MWD+IFR+MS 9130.03 52.80 167.10 8177.56 8110.56 -2440.13 622.43 5938277.46 685972.34 MWD+IFR+MS 9224.89 54.62 168.73 8233.70 8166.70 -2514.89 638.42 5938203.12 685990.17 MWD+IFR+MS 9318.89 53.63 168.24 8288.79 8221.79 -2589.52 653.63 5938128.89 686007.20 MWD+IFR+MS 9414.79 52.29 168.37 8346.55 8279.55 -2664.48 669.14 5938054.34 686024.55 MWD+IFR+MS 9507.91 52.96 169.59 8403.08 8336.08 -2737.11 683.29 5937982.08 686040.48 MWD+IFR+MS 9603.23 52.36 169.57 8460.90 8393.90 -2811.65 696.99 5937907.91 686056.01 MWD+IFR+MS 9697.02 56.81 170.31 8515.23 8448.23 -2886.89 710.33 5937833.02 686071.19 MWD+IFR+MS 9792.28 59.62 169.80 8565.41 8498.41 -2966.64 724.32 5937753.64 686087.13 MWD+IFR+MS 9886.82 59.71 169.55 8613.15 8546.15 -3046.91 738.94 5937673.76 686103.73 MWD+IFR+MS 10004.44 60.72 170.52 8671.58 8604.58 -3147.45 756.60 5937573.69 686123.85 MWD+IFR+MS 10035.20 67.13 170.49 8685.09 8618.09 -3174.69 761.16 5937546.57 686129.07 MWD+IFR+MS 10069.18 75.20 171.21 8696.06 8629.06 -3206.42 766.26 5937514.98 686134.96 MWD+IFR+MS 10100.68 82.58 171.15 8702.12 8635.12 -3236.94 771.00 5937484.59 686140.44 MWD+IFR+MS 10127.10 88.57 171.30 8704.16 8637.16 -3262.96 775.01 5937458.68 686145.10 MWD+IFR+MS 10154.91 93.43 171.60 8703.67 8636.67 -3290.45 779.15 5937431.30 686149.90 MWD+IFR+MS 10189.76 90.73 172.68 8702.41 8635.41 -3324.94 783.91 5937396.93 686155.51 MWD+IFR+MS 10220.72 90.29 172.62 8702.13 8635.13 -3355.65 787.87 5937366.34 686160.23 MWD+IFR+MS 10248.58 92.46 170.99 8701.46 8634.46 -3383.21 791.84 5937338.88 686164.87 MWD+IFR+MS 10278.49 92.28 170.62 8700.23 8633.23 -3412.71 796.61 5937309.51 686170.37 MWD+IFR+MS 10309.88 92.03 169.64 8699.05 8632.05 -3443.62 801.99 5937278.75 686176.50 MWD+IFR+MS 10341.02 91.78 167.92 8698.01 8631.01 -3474.14 808.05 5937248.38 686183.31 MWD+IFR+MS 10372.90 91.35 165.57 8697.14 8630.14 -3505.16 815.35 5937217.55 686191.37 MWD+IFR+MS 10403.40 90.49 163.06 8696.65 8629.65 -3534.52 823.60 5937188.41 686200.34 MWD+IFR+MS 10435.07 90.30 160.66 8696.43 8629.43 -3564.61 833.46 5937158.57 686210.93 MWD+IFR+MS 10466.41 90.73 159.01 8696.15 8629.15 -3594.03 844.26 5937129.43 686222.45 MWD+IFR+MS 10495.84 90.54 157.08 8695.83 8628.83 -3621.32 855.26 5937102.42 686234.12 MWD+IFR+MS 10526.66 90.60 154.68 8695.52 8628.52 -3649.45 867.85 5937074.61 686247.40 MWD+IFR+MS 10561.52 88.80 149.33 8695.70 8628.70 -3680.21 884.21 5937044.26 686264.51 MWD+IFR+MS 10588.13 87.45 146.45 8696.57 8629.57 -3702.74 898.34 5937022.09 686279.19 MWD+IFR+MS 10620.10 86.11 142.52 8698.37 8631.37 -3728.72 916.88 5936996.58 686298.36 MWD+IFR+MS 10651.80 84.49 139.05 8700.97 8633.97 -3753.19 936.85 5936972.60 686318.93 MWD+IFR+MS 10683.57 86.35 135.88 8703.50 8636.50 -3776.52 958.26 5936949.81 686340.90 MWD+IFR+MS 10713.47 88.69 134.04 8704.80 8637.80 -3797.63 979.39 5936929.23 686362.54 MWD+IFR+MS 10746.53 88.53 131.17 8705.60 8638.60 -3820.00 1003.72 5936907.46 686387.41 MWD+IFR+MS 10778.32 88.57 129.88 8706.40 8639.40 -3840.65 1027.87 5936887.41 686412.06 MWD+IFR+MS 10806.99 89.19 128.16 8706.97 8639.97 -3858.69 1050.14 5936869.92 686434.77 MWD+IFR+MS 10840.40 89.61 125.53 8707.31 8640.31 -3878.72 1076.88 5936850.56 686461.98 MWD+IFR+MS • ~alliburton Company Survey Report Cumpan}: BP An,~Co N'icid: Prudhoe Bay Site: PB DS 06 ~Vcll: 06-13 ~i'cllpaith: 06-13A PB1 Snrve~ - - ', n1U lncl Azim -- l'~'D Scs'f~'ll ft deg deg ft ft 10900.39 90.72 126.74 8707.14 8640.14 10962.25 91.04 126.34 8706.19 8639.19 10994.20 91.66 124.00 8705.44 8638.44 11025.31 91.83 120.58 8704.49 8637.49 11055.95 90.66 118.26 8703.83 8636.83 11087.47 90.49 117.75 8703.51 8636.51 11118.23 90.92 116.10 8703.13 8636.13 11152.94 94.12 113.55 8701.60 8634.60 11181.96 94.00 110.81 8699.55 8632.55 11214.72 94.12 105.96 8697.23 8630.23 11272.00 94.12 105.96 8693.11 8626.11 llatc: 1 2i 19'2006 firoc 1 ? :25:09 Pa;;c: ~ Co-ordinate(NEI Keference: vVeil: 06-13, True North Vertical (T4~) ReCerence: 6-13A PB1 : 67.0 Section (VS) Reference: Well (O.OON,O.OOE,100.OOAzi) Surve~~ Calculation Aicthod: Minimum Curvature DU: Oracle - _ __ ---~ N/S _ L/~~ DIapN :Vapl? Tool ft ft ft ft -3914.10 1125.32 5936816.39 686511.28 MWD+IFR+MS -3950.92 1175.02 5936780.79 686561.87 MWD+IFR+MS -3969.32 1201.13 5936763.05 686588.42 MWD+IFR+MS -3985.93 1227.41 5936747.09 686615.10 MWD+IFR+MS -4000.97 1254.09 5936732.70 686642.14 MWD+IFR+MS -4015.77 1281.92 5936718.59 686670.32 MWD+IFR+MS -4029.70 1309.34 5936705.35 686698.08 MWD+IFR+MS -4044.26 1340.80 5936691.57 686729.89 MWD+IFR+MS -4055.19 1367.61 5936681.30 686756.95 MWD+IFR+MS -4065.49 1398.61 5936671.77 686788.19 MWD+IFR+MS -4081.20 1453.54 5936657.41 686843.49 PROJECTED to TD Printed: 12/11/2006 1:42:28 PM 12/11/06 • Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4070 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Date BL Color CD V-211 40011168 OH EDIT OF MWD/LWD 11N7/04 2 1 5-213A DS 09-13 40011201 11491394 OH EDIT OFMWD/LWD MEM PROD PROFILE 12/11/04 17/24/06 2 2 1 14-30A DS 09-36C 11485775 1149225 MEM PROD PROFILE INJECTION PROFILE 11121/06 11/23/06 2 2 W-12A Y-29A 11418301 11485776 MEM PROD PROFILE MEM PROD PROFILE 09110/06 11/25/06 2 2 NK-43 6-13A 11414407 11212699 PROD PROFILE W/DEFT USIT 10/28/08 71/05/06 2 1 14-30A 11485775 SCMT 11122/06 1 OS 02-39L1 11491395 SCMT 11125/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. 1 v-"'*0 ~ -.~ t_ _ , ~ ~ '" ° ` Petrotechnical Data Center LR2-1 ` ( ' W ,r, _ ~ 900 E Benson Blvd. (~~ a ~ r ~?_-,~ ,1 ~t^' Anchorage AK 99508-4254 -. -" Dale Delivered: ., ~ ~ k ~j9~~~ . `~ tR n' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-283 ATTN: Beth ~~~ Received by: ~C~Cn - ~b~ • ~ 11 i ~ ~ ', ''~ ' ~ ~ ~ ~~, ~, ~~ ~~ j~~ ~~'a ~ ~ ' 3a ~ ,~"° ,~ ~ FRANK H. MURKOWSKI, GOVERNOR _.~~ ~r ~ ~+ ~-+~1t~~rrm~ ~~ ~ ~ '7 333 W. 7"' AVENUE, SUITE 100 COI~SERQATI011T CU1~II1'I15SI011T ~ ANCHORAGE, ALASKA 99501-3539 a PHONE (907) 279-1433 Dave Wesley FAx (so7> 27s-7542 Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-13A BP Exploration (Alaska) Inc. Permit No: 206-102 Surface Location: 120' FSL, 1704 FEL, SEC. 02, TlON, R14E, UM Bottomhole Location: 4581' FNL, 1762' FWL, SEC. 12, T10N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining. additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been .issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in .accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, - l/ s ~_ .., Dan T. Seamount Commissioner i DATED this ay of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ., ~ j ~ ~~ ~~ STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 JUL 1 3 2006 Alaska Oil & Gas Cons. Commission Anchoraae 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service / ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: ) PBU 06-13A ~~IS(°` 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13412 TVD 8690 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028311 Pool FSL, 1704 FEL, SEC. 02, T10N, R14E, UM 120 Top of Productive Horizon: 3330' FNL, 907' FEL, SEC. 11, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 1, 2006 Total Depth: 4581' FNL, 1762' FWL, SEC. 12, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 15,748' 4b. Location of Well (State Base Plane Coordinates): Surface: x-685290 y- 5940701 Zone-ASP4 10. KB Elevation Plan (Height above GL): 68 feet 15. Distance to Nearest Well Within Pool: 217' 16. Deviated Wells: Kickoff Depth: 4900 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC .035) . Downhole: 3300 Surface: 439 18. Casin Pro ram: S cifications To - Baffin De th - Bo om Qu nt' of nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data Tieback 9-5/8" 47# L-80 BTC-M 2000' Surface Surface 2000' 2000' 297 sx Class'G' ~ Tieback 7" 26# L-80 TCII 3672' Surface Surface 3627' 3590' See Below Tieback 7" 26# L-80 BTC-M 1123' 3627' 3590' 4750' 4688' 198 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 5226' 47 0' 4688' 976" 673' 163 sx LiteCrete, 169 sx'G', 179 sx LiteCrete 6-1/8 4-112" 12.6# L-80 IBT-M 3585' 9826' 858 ' 13411' 8690' Uncemented Slotted Liner 1 g. PRESE NT. WELC CONDITION S UMMARY {To b~ completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9968 Total Depth TVD (ft): 9360 Plugs (measured): 9066 Effective Depth MD (ft): 9891 Effective Depth TVD (ft): 9285 Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 20" 281 sx Arcticset II 110' 110' Surface 2672' 13-3l8" 2700 sx Fondu 400 sx Arcticset II 2 72' 2672' Intermediate Production 9937' 9-5/8" 1100 sx Class'G' 300 sx Arcticset I 9937' 9330' Liner 586 sx Class'G' 175 sx Class'G' Scab Liner 4863' 7" 586 sx Class'G' 175 sx Class'G' 5004' - 9867' 4811' - 9262' Perforation Depth MD (ft): 9447' - 9538' Perforation Depth TVD (ft): 8854' - 8942' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: _ 22. I hereby certify that the foregoing is true and correct. Printed Name D ve Wesley Si nature /~ Contact Mehrdad Nadem, 564-5941 Title Senior Drilling Engineer Prepared By Name/Number: Phone 564-5153 Date 7 ~~~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: © - O ' API Number: 50-029-20457-01-00 Permit Approval See cover letter for Dat : other re uir menu Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No t ,~ S .~- ~ ~ ~ E f -~ 3 S~ (7 r ~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No O~her: ~Q~/.,,~ ~ ~ jro dG~ . rrr S w aT.v~ ~o Z o /~A"C 25 . v 3 S r! ~~ (. l~ / ~,.~. ~-2./l.~e P~O~ ~ ° S~' l ~ ~ a'~''I~ ~~/ ~~ ~~ / ^ APPROVED BY THE COMMISSION ,COMMISSIONER Fnrm 1r1~n1 RP~~~P~ 1~nnn~ Submit In DuQlicate • To: Winton Aubert, Petroleum Engineer ~-.~ r Alaska Oil & Gas Conservation Commission = ~ ~ ~ ; From: Mehrdad Nadem, Drilling Engineer ~:_ _ _ Date: July 12, 2006 Re: 6-13A Sidetrack Permit to Drill The sidetrack, 6-13A, is scheduled to be drilled by Nabors Rig 2ES during the first week of August. The plan is to exit the parent 06-13 wellbore at 4,900' MD. A whipstock will be run and an 8-1/2" window will be milled in the 9-5/8" casing. An 8-1/2" hole will be drilled to the Top of the Sag River formation. A 7" liner will then be run and cemented. A 7" tieback will be run, and will be cemented to 3,172' MD which is 500' below the 13-3/8" casing shoe. The 6- 1/8" wellbore then builds to horizontal in the Sag River formation. The planned well runs horizontally in this formation for approximately 3,047' after landing. A slotted 4-1/2" production liner will be run in the horizontal section. Planned Well Summary Well 6-13A Well Horizontal Target Sag River T e Sidetrack Ob'ective AFE Number: PBD4P2531 API Number: 50-029-20457-01 Surface Northin Eastin Offsets TRS Location 5,940,701.77 685,289.85 120' FSL / 1,704' FEL 10N, 14E, 2 T t Northin Eastin Offsets TRS arge L ti 5,937,272.32 686,174.67 3,330; FNL / 907; FEL 10N, 14E, 11 oca ons 5,936,704.82 686,688.74 3,910 FNL / 408 FEL 10N, 14E, 11 Bottom Northin Eastin Offsets TRS Location 5,936,088.40 688,874.42 4,581' FNL / 1,762' FWL 10N, 14E, 12 Planned KOP: 4,900 and / 4,716' tvd Planned TD: 13411 and / 8,690' tvd Ri Nabors ES CBE: 35.3' RTE: 68' 6-13A Sidetrack Page 1 • Directional Program • A roved Well Ian: Wp09 Exit oint: 4,900' and / 4,716' tvd Maximum Hole Inclination: 93.64° in the lanned 6 1/8" reduction section. Proximit Issues: All wells ass major risk criteria ass resurvey usin tool codes. Survey Program: Standard MWD/IFR/MS. Nearest Well within ool: Well 6-11 at 217 ft. Nearest Pro a Line 15,748' Logging Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/Res/PWD throu hout the interval 6 1/8" production: Real time MWD Dir/GR/Res in the build Real time MWD Dir/GR/Res/ABI/ Azimuthal density/pen/Neu in the lateral. MAD pass build for Den/Neu. Cased Hole: USIT will be run from surface to 2,000'. O en Hole: None lanned Mud Proaram Hole Section /operation: Mill window in the 9 5/8" casing at 6,100 and Type Densit ( g) MBT PV YP API FL H LSND 9.0 <12 15-22 30-40 <6.0 9.0 - 10.0 Hole Section /operation: Drillin 8 1/2" interval from 8600' and to section TD Type Densi g MBT PV YP API FL H LSND 9.0- 1.3 oa <15 15-22 20-24 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 6 1/8" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >20,000 8 - 12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. i Grade Connection Length Top and / tvd Bottom and / tvd N/A 9-5/8" 47# L-80 BTC-M 2,000' Surface -2,000' N/A 7 " 26.0# L-80 TCII 3,672' Surface 3,627' / 3,590' N/A 7 " 26.0# L-80 BTC-M 1,123' 3,627' / 3,590' 4,750' / 4,688' 8 1/2" 7" 26.0# L-80 BTC-M 5,226' 4,750' / 4,688' 9,976' / 8,673' 6 1/8" 4'/z" -Slotted 12.6# L-80 IBT-M 3,585' 9,826' / 8,580' 13,411' / 8,690' Tubin 4 ~/z" 12.6# 13Cr Vam To 9,826' Surface 9,826' / 8,580' 6-13A Sidetrack Page 2 Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casin window 20' new formation be and FIT 11.8 EMW 7" tieback Baffle collar to surface 30 min recorded 3,500 si surface 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Cementing Program Casing String: 9-5/8", 47#, L-80, BTC-M Lead slurry: None Planned. Slurry Design Basis: Tail slurry: 2,000' 11.5 ppg Class G in the 13-3/8" x 9 5/8" annulus with 10- bbl excess. Pre-Flush Heated Seawater Fl id l S /V S acer None Planned u equence ume: s o Lead Slurr None Planned Tail Slurr 126 bbls / 708 ft / 297 xs class G, 11.5 ; 2.38 ft /sk. L/ Casing String: 7", 26#, L-80, BTC-M x TC-II Tieback Slurry Design Basis: Lead slurry: None planned. Tail slurr :1,578' 9-5/8" X 7" annulus to 3,172' MD with 0% excess. Pre-Flush None Planned Freeze Prot 82 bbls of diesel Fluids Sequence /Volume: S acer 5 bbls water Lead Slurr None tanned Tail Slur 41 bbl / 230 cf / 98 xs Class `G', 15.8 ; 1.16 cf/sk. Casin Strin 7", 26#, L-80, BTC-M intermediate liner -First Sta e Slurry Design Basis: Lead slurry: 2,177' of 7" X 8-1/2" annulus with 40% excess. Tail slurry: 1000' of 7" X 8-1/2" annulus with 40% excess, plus 80' of 7", 26# shoe track. Pre-Flush None tanned Fl id /V l S S acer 45 bbls Mud PUSH at 11 u s equence o ume: Lead Slur 69 bbls / 387 cf / 63 sxs Lite Crete, 11.5 ; 2.38 cf/sk Tail Slur 35 bbls / 197 cf ;169 sxs Class `G', 15.8 ; 1.16 cf/sk. Casin Strin 7", 26#, L-80, BTC-M intermediate liner -Second Sta e Slurry Design Basis: Lead slurry: 1,900' of 7" x 8-1/2" annulus with 40% excess, plus 150' of 7" x 9-5/8" liner lap, plus 200' of 9-5/8" x 4" drill pipe annulus. Pre-Flush None tanned Fl id /V l S S acer 45 bbls Mud PUS at 11 equence ume: u s o Lead Slur 76 bbls / 427 cf 179-sxs Lite Crete, 11.5 ; 2.38 cf/sk Tail Slur None Planned ~ .f Casin Strin 41/2", 12.6#, L-80, slotted roduction liner Slur Desi n Basis: Lead slur :None tanned 6-13A Sidetrack Page 3 • ~ Tail slur :None tanned Pre-Flush Not a licable S acer Fl id /V l S Not a licable u s equence o ume: Lead Slur Not a licable Tail Slur Not a licable 6-13A Sidetrack Page 4 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum anticipated BHP: 3,3 ' at 8,609' TVD. Maximum surface pressure: ,43 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Inf' Ite with 11.8 ppg EMW FIT Planned BOPE test pressure: 250 psi low / 3,500 psi high i 7 day test cycle (Pre drilling phase) 14 day test cycle (Drilling operations) BOPE configuration for 9-5/8" i /,; C/O to 9-5/8" rams before cutting the existing 9-5/8' casing. cas ng. BOPE configuration for 7" C/O to 7" pipe rams before running the 7" liner and the 7" tieback. f' drilling liner. Well Interval: 6 1/8" production interval Maximum anticipated BHP: 3,135 psi at 8,699' TVD. Maximum surface pressure: 2 SI (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: nfinit "with 10.0 pp EMW FIT. Planned BOPE test pressure: si low / 3,500 psi hi h - 14 day test cycle Drilling o erations Planned completion fluid: 8.4 pp seawater / 7.1 pp Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 6-13A Sidetrack Page 5 • • Geologic Prognosis Commercial Est. Formation Hydrocarbon Est. Pore Tops Uncertainty Bearing Press. Formation (TVDss) (eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells SV4 -2669 10' SV3 -3350 10' SV3 -3699 10' SVl -4116 10' UG4 -4497 10' UG3 -4650 10' KOP@4,901MD -4718 UGl -5620 10' WS2 -5830 10' WS1 -6057 10' CM3 -6317 10' CM2 -6809 20' No CM 1 -7470 20' No THRZ -7880 20' No BHRZ -8050 20' No TJC -8210 20' No TJB -8390 20' No TJA -8510 20' No TSGR -8605 20' Yes PTD@13,343' MD -8620 TSHA -8634 20' Yes TSGR and TSHA in hori sec (due to di) -8610 to 8636 20' TD Criteria: Approx 2900' Sag horizontal. Need minimum of 1500' reservoir sand to TD. 6-13A Sidetrack Page 6 • • Fault Prognosis The 06-13A wellplan will not intersect any mapped faults. Fault #1 is a large (~40 ft), NW-SE trending, down to the S fault to the SW of the landing and heel portion of the well. Fault #2 is a ~ 15-20 ft, N-S trending, down to the W fault which dies out N of the horizontal section of the well. The tip point of Fault #2 is N of 11,700 MD in the well plan. Previous Sag wells in the area have had serious Lost Circulation issues. Well 06-68 (2500 ft W) lost as much as 350 BPH, and 13-026L 1 (~ 1000 ft E) lost 2000 & 5000 BBL (in two places). These LC events were in the Sag and were not associated with obvious faults. Well Type Loss (bbl) MD SSTVD Formation X Y 06-068 rig 3508PH 12325 8635 SAG RIVER 682333 5937200 06-068 rig 10088H 11610 8633 SAG RIVER 683042 5937200 13-026L1 coil 830 10434? 8668 690050 5935090 13-02BL 1 coil 5000 10755 8663 SAG RIVER 690305 5935278 13-028L1 coil 2000 11960 8637 SAG RIVER 689718 5936030 13-19 rig 55 8341 7593 Above SAG RIVER 687279 5935400 13-19 rig 81 8998 8198 Above SAG RIVER 687322 5935651 13-20 rig 100. 7735 6778 Above SAG RIVER 688789 5934840 13-20 ri 54 9305 8121 Above SAG RIVER 689315 5935451 6-13A Sidetrack Page 7 r • .Operations Summary Current Condition: / SI since Apri12005. / 4-1/2'; 12.6#, L-80 x 5-1/2'; 17#, 13-CR-80 tubing, cross over at 35' MD. / 3-1/2'; 9.3#, L-80 x 4-1/2'; 12.6#, 13-CR-80 tubing, WLEG Q 4,887' MD. / 7"X 3-1/2" OTIS BWN permanent packer at 8,950' MD. / 3-1/2" `PXN' tubing tail plug set at 9,047' (SLM). Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Rig Work: 1. Rig up slick line, and lock open the TRSV at 2,213'. 2. Rig up slick line, RIH, and remove PXN TTP from 9,062'. Drift through 3-1/2" tubing tail, record PBTD. 3. Replace all nine gas lift valves with dummy valves. 4. Fluid pack the tubing and inner annulus. 5. RIH with coil tubing, P&A we1106-13 with 52 bbls of cement to 7,000' MD in the tailpipe. Cement calculations: • 7" liner 9,867'-9,062'=805' (~31 bbls) ID=6.276" • 3-1/2" 9,062'-7,000'=2,062' (~18 bbls) ID=2.992" • Total cement volume of 52 bbls, including 3 bbls for squeezing. 6. RIH with a-line, RIH and cut the 4-1/2" tubing with a jet cutter at 5,100 MD. 7. Pressure test the TxIA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi. 8. Circulate the well to seawater through the cut, freeze protect the IA to 2,200'. 9. Bleed OA, IA & tubing to zero. Test 9-5/8" pack off to 3,500' psi and tubing hanger seals to 5,000 psi. Function all lockdown screws. Repair or replace as needed. 10. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger, secure the well. 11. Remove the well house, level the pad. Please provide total well preparation cost on the handoverform. Rig Operations: 1. MI / RU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection fluids, and displace to seawater __ 3. Set TWC. Nipple down tree and adaptor. Nipple up and test BOPE to ,500 psi. Pull TWC. 4. Rig up, Back out lockdown screws, pull hanger. 5. Pull the 4-1/2" tubing from the pre-rig cut at 5,100' and above. 6. P/U drill pipe- PU mills assembly. RIH picking up DP, and circulate the well bore. 7. RU e-line, run USTT. 8. Rig up a-line, MU a 9-5/8" CIBP on DP, RIH and set at 4,925' MD, test. 9. Determine the depth of the 9-5/8" cut based on USIT interpretation. 10. Change out to 9-5/8" rams, and test. 6-13A Sidetrack Page 8 .~ 11. MU a Baker 9-5/8" cutting assembly. RIH picking up DP. Cut the 9-5/8" casing per Baker representative instructions. Cut ~4' above a casing collar. POOH, L/D assembly. 12. BOLDS, RU/MLT casing spear assembly, and unseat the 9-5/8". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9- 5/8" casing from the cut. 13. MU Wash over assembly, and 13-3/8" casing scraper. 14. RIH, Clean out the 13-3/8" casing, and the 9-5/8" casing stub, POOH, L/D the assembly. 15. RU BKR back-off assembly, RIH, and back off the 9-5/8"casing joint. POOH, L/D assembly. 16. MU casing spear assembly, RIH, recover cut stub. POOH. 17. MU 9-5/8" casing with a TAM port. Run the 9-5-8" casing to surface, and test. 18. Pull tension, split stack, set slips. 19. Cut the 9-5/8" casing with a WACHS cutter, set back the stack. 20. Install pack off, and test. 21. Install spool, Nipple up BOPE, and test. 22. RU 9-5/8" cementer and RIH with TAM Tool. 23. Open TAM collars, circulate. 24. Cement the 9-5/8" to the surface. Close Tam Collar and confirm. 25. POOH, L/D TAM tool. Rig down the cementer, 26 MU 9-5/8" milling Assembly. RIH to CIBP, POOH, L/D Milling Assembly. 27. RU, MU 9-5/8" whipstock assembly with bottom trip anchor with an 8-1/2" window milling assembly. BHA will contain a UBHO sub for whipstock orientation. Swap mud to 9.5 ppg ~ ~- LSND based milling fluid. ~ 28. RIH to CIBP, orient and set the whipstock. y 29. Mill window on 9-5/8"casing at 4,900' MD plus 20' from mid window. ~ 30. CBU, perform FIT to 11.8 ppg. ~- 31. POOH, L/D milling assembly. 32. MU 8-1/2" drilling assembly-BHA with Dir/GR/RES/PWD. 33. RIH to window. ~ 34. Drill ahead 5,076' per directional plan to Top of Sag at 9,976' MD. Circulate bottom up, ~}- short trip- circulate and condition the hole for 7" liner run. 35. POOH, L/D the BHA. ~ 36. Change out to 7" rams, and test. -' 37. Rig up, MU 131 joints of 7" liner. ~- 38. RIH to botto ri' rill pipe. Circulate and condition the hole. ` ~ 39. Cement the ntire "liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at -~ 4,750' MD., enting will be done in two stages. Set the hanger and packer, displace ~-' cement with mud. 40. Circulate bottom up, POOH, L/D liner running took. (LRT). 41. Make up 4,750' of 7" liner tieback. / 42. Sting in and establish s , P to expose ports. 43. Cement the tieback to ,17 MD, bury the seal. The top of the 9-5/8" by 7" annulus will be freeze protected to th ,,~ rface. 44. Split stack, set slips. 45. Cut casing, set back stack. 46. Install pack-off and test. 47. Nipple up spool and BOPE stack, test. /~ 48. Change out rams to variable and test. 49. Pick up drill pipe and stand back. 6-13A Sidetrack Page 9 • • 50. Test casing and liner. Record the test. 51. MU clean out assembly. 52. RIH to liner float equipment. 53. Drill out tieback float equipment. 54. RIH to drilling liner float equipment, test for 30 minutes, and record. Then drill out of cement /' and float equipment to shoe. 55. Displace to 8.5 flo pro fluid. 56. POOH for directional drilling BHA. 57. Make up 6-1/8" directifarial drilling BHA. RIH to shoe. Drill out of shoe plus 20' of new ~- formation, and FTT to ~ 0.~. 58. Drill ahead 360'in the-build section. This segment contains doglegs as high as 4°~~100'. 59. Circulate bottom up, POOH for horizontal assembly. 60. Make up 6-1/8" horizontal drilling assembly. Azimuthal density logging tool will be added to the BHA which includes Dir/GR/ABURes and stratasteer geosteering. 61. Strata steer, drill 3,076' per directional plan to TD at 13,412'. 62. Circulate bottom up, short trip, circulate and condition the hole for 4-1/2" slotted liner run. 63. POOH, L/D BHA and excess drill pipe. ~~ 64. Make up 3,435' of 4-1/2", 12.6#, L-80 slotted liner, plus 150' of 4-1/2" 12.6#, L-80, IBT-M for overlap into the 7" liner. 65. RIH to bottom. Set liner hanger and packer. j 66. Release and displace to clean seawater. 67. POOH, L/D drill pipe, Liner running tool. 68. Make up 9,826' of 4-1/2" chrome tubing. Space and land the completion tubing into the 4- 1/2" liner top, RII.DS. 69. Reverse circulate to seawater and corrosion inhibitor. 70. Drop ball and rod, set packer. ~~ 71. Test tubing and annulus separately to 3500 psi each, record the tests. 72. Install and test TWC. 73. Nipple down BOPE. 74. Nipple up adaptor flange and tree, and test the tree to 5,000 psi. Pull the TWC. 75. Reverse in diesel freeze protect to 2,200'-U-tube. Install BPV. 76. Secure Well, Release the rig. Post-Rig Work: 1. Install wellhouse and flowlines. New S-riser will be manufactured. 2. MIRU slick line. Pull the ball and rod / RHC plug from `XN' nipple. 3. Install gas lift valves. 6-13A Sidetrack Page 10 • • Phase 1: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 48 $357,121 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. :• "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto 06-13. Wells 06-12 and 06-14 are adjacent to 06-13. The distance between each of these wells are greater than 90'. However, care should be taken while moving in on the well. Spotters should be employed at all times. - During MI/RU operations, the 06-13 well bore will be secured with the following barriers: o Tubing: cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: 300 Sacks of cement down squeeze, and passing MITOA. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 06-13 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: 300 Sacks of cement down squeeze, and passing MITOA. - DS-D6 is a high Peve! H2S drill site. Use extra caution while working at this drill site. Standard Opera`~irig Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: WPII Name N2C i.PVOI ilatP of RParlino #1 Closest SHL Well H2S Level 06-14 70 m 01/16/02 #2 Closest SHL Well H2S Level 06-12 30 m 02/22/02 #1 Closest BHL Well H2S Level 06-04 200 m 05/23/03 #2 Closest BHL Well H2S Level 06-19 10 m 09/03/05 Max. Recorded H2S on Pad/Facility 06-13 250 ~ m 01/09/04 ~. ;,r'' - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 92 $591,516.00 includin 9-5/8" rerun 6-13A Sidetrack Page 11 • • Reference RP • "De-completions" RP • "De-completions" RP • "Casing Cut and Pull with Baker Back Off Tool" RP • "Surface Casing Port Collar" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a FMC GEN 2-13-5/8" 5000 psi CIW with 7-1/6 x 6-3/8" bore tree. Verify with FMC that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 4-1 /2" AVA TRSV SSSV at 2,213', No records could be located showing the presence or lack of control bands. Please have equipment available to pull control bands, if found during decompletion. - USIT log will be run after tubing has been pulled to identify top of cement for cut and pull operations. - A FasDrill plug will be run to below top of cement. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 38 $338,874.00 `Reference RP • "Whip stock Sidetracks" RP • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 108 $539,636.00 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management" RP • "Leak-off and Formation Integrity Tests" SOP 6-13A Sidetrack Page 12 • Issues and Potential Hazards - For this well, the Kingak will require a mud weight of 11.3 ppg. Maintain mud weight at 11.3 ppg to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.5 ppg pore pressure, a fracture gradient of 11.,8°pp~ at the 9 5/8" casing window, and 11.3 ppg mud in the hole, the kick tolerance is it'ifinite.! - f The ove kick tolerance is based on an FIT of 11.8 ppg EMW; if this is not reached contact the ODE. - 06-13A well plan will not intersect any mapped fault. Fault#1 is a large ~40', NW-SE trending, down to S fault to the SW of the landing and heel portion of the well. Phase 6: Run and Cement 7" Intermediate Casing and Tieback Planned Phase Time Planned Phase Cost 48 $730,782.00 Reference RP Reference RP • "Intermediate Casing and Cementing Guidelines" RP ~.• "Shale Drilling, Kingak and HRZ" RP ~.• Schlumberger Cementing Program Issues and Potential Hazards - The design for the liner is to run a 7", 26#, L-80, BTC-M solid liner. - Sufficient 7" liner will be run to extend 150' back up into the 9-5/8" casing. - A tieback will be run to surface and cemented to 3,172' MD. Two different connections will be run (BTC-M and TC-II) in the tie-back. - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 189 $1,116,282 Reference RP Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP • Schlumberger Cementing Program 6-13A Sidetrack Page 13 • ~ Issues and Potential Hazards - Fault #2 is a ~15-20 ft, N-S trending, down to the W fault which dies out N of the horizontal section of the well. The tip point of Fault #2 is N of 11,700 MD in the well plan. Previous Sag wells in the area have had serious Lost Circulation issues. May not be able to reach TD due to severe losses. May use fault isolation with MPAS packers. If significant LCM is required to control losses, a 4-1/2" cemented and perforated liner may be installed. Phase 9: Run 4'/i" Production Liner Planned Phase Time Planned Phase Cost 30 hours $234,457.00 Reference RP ~o ""Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4 '/~", 12.6#, L-80 slotted liner throughout the production interval. - Sufficient 4-'/z" liner will be run to extend -150' back up into the 7" liner shoe. - Ensure the 4'/z" liner top packer is set prior to POOH. Phase 12: Run 4'/i", 12.6#, 13Cr, VamTop Completion Planned Phase Time - Planned Phase Cost 25 hours $657,887.00 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP • "Handling and Running 13 Chrome" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 Asia at 100° F. - The completion design will be a 4~h", 12.6#, 13Cr, VamTop production tubing string with 7" x 4- 1/2" Baker S-3 packer with 5 GLM's. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 18 hours $54,668 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off DS-06. As always, care should be taken while moving onto the well. Spotters should be employed at all times. 6-13A Sidetrack Page 14 LHEA D.= FMC CTLIATOR = AXELSON . ELEV = 68' F. ELEV = ~~~ ~ OP = 2900' Angle = 30 ~ 5900' tum MD = 9461' tum TVD = 8800' SS ~ 06-73' 5-102" TBG, 17#, 13-CR-80, .0232 bpf, ID = 4.892" 35' TOP OF 4-1/2" TBG 35' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2672' Minimum ID = 2.750" ~ 9066' 3-1 /2" PARKER SWN NIPPLE 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ( 4887' TOP OF 3-1 /2" TBG 4887' TOP OF T' LNR 5004' PERFORATION SUMMARY REF LOG: BHCS ON 05/29(80 ANGLEAT TOP PERF: 15 ~ 9421' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-318" 4 9421 - 9427 S 09/30/91 2-318" 4 9439 - 9443 S 09/30/91 2-118" 4 9447 - 9460 S 11/09/98 2-114" 6 9447 - 9462 C 01 /04105 2-1 /8" 4 9470 - 9490 C 01 /12/99 2-118" 6 9490 -9538 C 06/25!93 4" 4 9550 - 9570 S 09/30/91 2-318" 4 9591 - 9611 S 09/30/91 ~ 3-112" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" ~-~ 9077' 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" ~ 9867' PBTD 9891' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9937' SA~ NOTES: '""'CHROME TBG &LNR""" 35' S-1/2" X 4-1/2" XO 2213' 1~4-1/2" AVA TRSV SSSV NIP, ID = 3.81" GAS LIFT MANDRELS ST NID TVD DEV TYPE VLV LATCH PORT DATE 2913 2912 7 TGPDX DMY RK 0 11120/91 2 3635 3590 26 TGPDX DOME RK 16 11/27/98 3 4790 4618 26 TGPDX DMY RK 0 11/20/91 4 5763 5487 29 TGPDX SO RK 20 11/27/98 5 6866 6450 28 TGPDX DMY RK 0 06/15/93 6 7585 7099 24 TGPDX DM1' RK 0 03/01(92 7 8047 7523 23 TGPDX DMY RK 0 11/20/91 8 8508 7952 20 TGPDX DMY RK 0 11 /20!91 9 8876 8303 17 TGPDX EKED RK 0 06/15/93 4887' I-i4-1/2" X 3-1/2" XO 8950' ~-I7" X 3-1/2" OTIS BWN PERMANENT PKR 9066• ~-~3-1/Z" PARKER SWN NIP, ID=2.75" 9066' 3-112" PXN TTP (07/13/05) 9077' ~3-112" OTIS S/O SUB WLEG 9078' 3-1/2" TBG TAIL 9062' ELMD TT LOGGED 02/13/92 DATE REV BY COMMENTS DATE REV BY COMMENTS 063/80 OPoGINAL COMPLETION 07/25/05 RPH/PJC WAVER CANCELLED 11/20/91 LAST WORKOV ER 09/23/05 KSB/TLH PXN TTP SET (07/13105) 09113/01 RN/TP CORRECTIONS (]9/13/01 JMlTLH SET PLUG 04105/03 KB/KAK PERF CORRECTIONS 01/04105 JRA/TLP ADD PERF PRUDHOE BAY UNIT WELL: 06-13 PERMIT No: 1800300 API No: 50-029-20457-~ SEC 2, T10N, R14E, 4499.3' FEL 8 1080.52' FNL BP Exploration (Alaska) 0 6 -l 3 A SAFEfY NOTES: •--CHROME TBG s LNR*•• -2,200' -4-1 /2"BKR LandngN~pb 2,672' -133/d"CSG,72#,N-80,D=12347" 3,172' -TOC -~ -4750 7" 26#, L80 TC IIm BTC M -4,750 7"SealAssemb7y 4,750 9/$'x7"w/10'TBS HGR _4,900' - KO P -4,920' 9~/$" BKR W h~smck _4,925' - 9~/$"HES C]BP I Gas Lift Mandrels TREE = FMC GEN 2 WELLHEAD=_ ___F_MC ~ ACTUATOR = AXELSON KB. ELEV = ~~ 68' BF. ELEV = ~ ? KOP = _ ~_ 290_0' Max _Angle = 30 ~ 5900' Datum MD = _ 94_61' Datum ND = 8800' SS ST MD ND Mandrel Size 5 3,076 3,000 4.5" x 1.0" GLM where possible 4 5,012 4,750 4.5" x 1.0" GLM where possible 3 6,401 6,000 4.5" x 1.0" GLM where possible 2 7,740 7,200 4.5" x 1.0" GLM where possible 1 9,343 8,350 a.5" x 1.0" GLM where possible ~\ 9,826' 4-1 /2" 13CR-80 VAM Top TBG 9,788' HES 4-1/2"N N~pb,D=3813" 9,808' HES 4-1/2"XN N~pb,D=3.725" 9,828' 4-1/2"W LEG +~ 9,828' 7"x5"ZXP w/10'TBS Hanger 9,978' 7"CSG ,26#, -SO eTC~ l 5,100' 4-1 /2"TBG JET CUT 7,000' TOC PBTD 13,411' 4-1/2", 12.6# Sbtted LNR 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" 9867' PBTD 9,891' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9937' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03!80 ORIGINAL COMPLETION 07/25/05 RPWPJC WAIVER CANCELLED 11/20/91 LAST YVORKOVER 09!23/05 KSB/TLH PXN TTP SET (07/13/05) 09/13!01 RN(TP CORRECTIONS 09/13!01 JMrTLH SET PLUG 04/05/03 KBlKAK PERF CORRECTIONS 01104!05 JRAiTL? 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Kula. avr•J Nwiw -N ~ti -1':-k N,uthlnX I~.nyluE LnI1Nlb L,mginwk tilnt Ib-IJ ~I IV7'W 5X1+?J svJlliUl.lU td5~.N1 In ]ll'IJ'iJ.]XSN IJ%°JII'I_'-I %I N N,\ f ( ~ Slur( Uir 12,100' :.490 MD, 4716.88'TVD TARGET DETAILS I ~ ~ ~ ~ ~ ~ Namc TVD +Nr-S +E;'-W Northing Fasting Shape 35011 ~ .Stan Uir 4. I OU' : 92U' MU, 4734.88'TVD~ 06-13A T3 5690.00 -47110.0(1 3470.110 5936088.40 688874.42 Point 4110(1 ~ Find Uir :589 .I l' MD, 5612.81' TVD. U6-13A TI 8703.110 -34511.011 800.00 5937272.32 656174.67 Poinl 4500 06-13A Poly 87113.00 -3534.56 32Q47 5937176.00 G85697A(1 Pulygun ' - ~ ., ~ 116-13A T2 8703.00 -4030.011 1300.00 5936704.82 686688.74 Point I ~ ~ SSIIU ' UO 0000 ~ ~ ' I SECTION DETAILS _ I 400 Sec MD Inc A~i TVU +N;-S +Ei-W DLeg TFace VSec Target I .7000 ~ I 49UIZ011 25.75 IU7.67 4716.88 -196.34 SU4.74 4011 0.00 804.74 ' ' UOU ' ' ' ' ~ 2 49?11.011 26.06 113.12 4734.88 -199.38 812.93 12.00 85Ab 812.93 ~ - ~ 7500 3 5891.11 32.56 197.28 5612.81 -548.18 935.61 4.00 1211.62 935.61 I ~ ~~ $000 4 81179.45 32.86 197.28 745 L110 -1652.00 583.011 0.110 (IA0 553 AO 550 S 8750.41 53,1111 170.46 7943.75 -2128?3 573.14 4.110 -52.93 573.14 - - S ) O(i ~ ~ 6 980 L47 53.00 170.46 8576.31 _95(,.114 712.19 U.UO OAO 71_.19 - - _ - _ _ - - _ y _ 00 7 9976.77 60.00 170.00 8673.011 -31110.110 737.00 4.00 -3.30 737.11(1 ' ~ 5 99yG.77 GU.110 1711.1111 8683.00 -3112116 740.01 0.00 0.00 74(1.01 9 10136.93 93.64 IG9.71 8714.50 -3249.47 763.72 24.1111 -11.52 7(,3.72 ~ I 00 Smn Dlr 4. IUO'.: 79.45' MD. 745 I'TVD . l0 10395.46 93.64 169.71 5704A5 -3405,14 791.97 0.00 Q.00 791.97 07 911 II 111341 110 170 00 87113 (1(1 -345(100 SUQ 00 8 00 175 511 800 011 OG-13A TI 1 ; . . . . . . . . 12 111919.58 911.00 123.72 87119.00 -31)21.35 1107.74 S.llll -90.110 1107.74 - 13 110113.93 90.011 123.72 8703.011 -31)68.17 1177.1)(1 O.OU 0.00 1177.90 EnilDir~:8750A1' D.7943.75'TVD ~ 14 11141.12 911.011 IIU.00 8703AU -4030.0(1 13(10.1)0 10.1111 -911.00 13011.011 06-13AT2 17 OU ' i I S I I I G9.) I 911.33 1117. l4 8702.92 -4039.17 1327.28 111.0(1 -83.41 1327.28 - - : ~ - - - ~ ~ ~ IG 13412?5 90.33 107.14 8690.011 -471111.(10 34711.(10 OAU (1.11(1 34711.011 lIG-13A "f3 1 CASING DETAILS _ ~ Sta1K Dir 41(10' : N8 1.47 MD, 8576.31"T4'D ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ '~ ~ ~ ~ Nu. TVD MD Namc Sizc ~ I ~ 8 0 0 - ~ '~ ~ 1 SG73A0 9976.77 7" 7.(11111 - 1 '~ 1 nd Dir `. 9976. 1# .. ' MD. SG73' TVD I ~ 2 8690.01 13411.00 4 1 P_" 4.5011 i ~ , ~ ~ ~ ' - - r - - FORMATION TUP DETAILS _...- - - --- - - -- - - _ ' - r- _ - ~ ~ ~ 'Start Dlr 2J!II )' :; 9996.77 MD, 8¢83'TV ! No. TVDPadI MDPath Formation -- _ End Uir :101 93'lNU G 871~ 5' Tyq I 4718.00 4901.24 UG3 I 7 ! $ ( , , . , - - _, '_ 5325A0 5566.26 UGI 1 i S ' ' ? 3 5898.00 G23o.G2 W'S2 mn D r, 5; UO ..1UZ95.46 M1J. 8704. ~'TVU. - - 4 GI_5.(10 65(10.86 WSI ' li -. 1. { - -- S 6385A0 6810.39 C M3 G 68 77.00 7396.1' CM2 - - ~ 'Ild Dir : 10919.58' MU. (13' TVD - 1- - 7 7538.00 8184.6_ C'M I . . ~ _ 8 7y48.0(1 8757A8 THRL _ _ . Q G- 13A f o ~ 1 .._ i .SlanDif IU; I(1( :11003.93' MU. 87(13'TV I 9 8118.00 9039.95 BHRZ . - ,_ ' : ' 10 8278.0(1 93115.81 TJC' ) End Uir :'1116W.91 MU. 7(12.92 ?VD - -'---,, II 5458.1111 96114.89 T1B -~- 12 8578.00 9804.29 T1A ~ ~ ~ 13 8673.011 9976.77 TSGR . -_ t -' - n<.a,TI - -'--} Tolal'D nth:'1341225'MD.86\Itl' VD' 14 8702.0(1 1111142.67 TSHA -8UU 0 800 1600 2400 Wcsll-), C-astl+) [SWIL'in] • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5!3/2006 Time: 13:58:02 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference:. . Well: 06-13, True North Site: PB DS O6 Vertical (TVD)12eference: 20:13 5/15/1980 00:00 $8.0 Well: 06-13 Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 06-13A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 06-13A wp09 Date Composed: 4/3/2006 Version: 54 Principal: Yes Tied-to: From: Definitive Path Fietd: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 06 TR-10-14 UNITED STATES :North S lope Site Position: Northing: 5941880.59 ft Latitude: 70 14 46.529 N From: Map Easting: 684674.88 ft Longitude: 148 30 29.224 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.40 deg Well: 06-13 Slot Name: 06-13 Well Position: +N/-S -1193.99 ft Northing: 5940701.40 ft Latitude: 70 14 34.785 N +E/-W 586.24 ft Easting : 685290.1 6 ft Longitude: 148 30 12.181 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9976.77 8673.00 7.000 8.500 7" 13411.00 8690.01 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 0.00 SV3 0.00 0.00 0.00 SV2 0.00 0.00 0.00 SV1 0.00 0.00 0.00 UG4 0.00 0.00 4901.24 4718.00 UG3 0.00 0.00 5566.26 5328.00 UG1 0.00 0.00 6230.62 5898.00 WS2 0.00 0.00 6500.86 6125.00 WS1 0.00 0.00 6810.39 6385.00 CM3 0.00 0.00 7396.11 6877.00 CM2 0.00 0.00 8184.62 7538.00 CM1 0.00 0.00 8757.48 7948.00 THRZ 0.00 0.00 9039.95 8118.00 BHRZ 0.00 0.00 9305.81 8278.00 TJC 0.00 0.00 9604.89 8458.00 TJB 0.00 0.00 9804.29 8578.00 TJA 0.00 0.00 9976.77 8673.00 TSGR 0.00 0.00 10042.67 8702.00 TSHA 0.00 0.00 Targets Map Map <-___ Latitude --> z- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 06-13A T3 8690.00 -4700.00 3470.00 5936088.40 688874. 42 70 13 48.553 N 148 28 31.363 W 06-13A T1 8703.00 -3450.00 800.00 5937272.32 686174. 67 70 14 0.854 N 148 29 48.934 W 06-13A Poly 8703.00 -3534.56 320.47 5937176.00 685697. 40 70 14 0.023 N 148 30 2.868 W -Polygon 1 8703.00 -5019.15 3658.49 5935774.00 689070. 70 70 13 45.413 N 148 28 25.891 W -Polygon 2 8703.00 -4257.63 4014.64 5936544.00 689408. 00 70 13 52.901 N 148 28 15.532 W ,~ Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/3/2006 Time: 13:58:02 Page: 2 Field: .Prudhoe Bay Co-ordinate(NE}Reference: Well: 06-13, True North Site: PB DS O6 Vertical (TVD) Reference:. 20:13 5/15/1980 00:00 68.0 Well; 06-13 Section (VS) Reference: Well. (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 06-13A Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-_- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec. Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 3 8703.00 -3118.62 573.19 5937598 .00 685939.80 70 14 4.114 N 148 29 55.524 W -Polygon 4 8703.00 -3534.56 320.47 5937176 .00 685697.40 70 14 0.023 N 148 30 2.868 W -Polygon 5 8703.00 -3952.49 637.01 5936766 .00 686024.10 70 13 55.912 N 148 29 53.671 W -Polygon 6 8703.00 -5019.15 3658.49 5935774 .00 689070.70 70 13 45.413 N 148 28 25.891 W 06-13A T2 8703.00 -4030.00 1300.00 5936704 .82 686688.74 70 13 55.149 N 148 29 34.407 W Plan Section Information MD ft Incl .deg Azim deg TVD ft +N/-S ft +E/-W ft DLS deg/100ft Build deg/100ft Turn deg/1OOft TFO deg Target 4900.00 25. 75 107.67 4716. 88 -196.34 804.74 0.00 0.00 0.00 0.00 4920.00 26. 06 113.12 4734. 88 -199.38 812.93 12.00 1.56 27.24 85.00 5891.11 32. 86 197.28 5612. 81 -548.18 935.61 4.00 0.70 8.67 120.62 8079.45 32. 86 197.28 7451. 00 -1682.00 583.00 0.00 0.00 0.00 0.00 8750.41 53. 00 170.46 7943. 75 -2128.23 573.14 4.00 3.00 -4.00 -52.93 9801.47 53. 00 170.46 8576. 31 -2956.04 712.19 0.00 0.00 0.00 0.00 9976.77 60. 00 170.00 8673. 00 -3100.00 737.00 4.00 3.99 -0.27 -3.30 9996.77 60. 00 170.00 8683. 00 -3117.06 740.01 0.00 0.00 0.00 0.00 10136.93 93. 64 169.71 8714. 50 -3249.47 763.72 24.00 24.00 -0.20 -0.52 10295.46 93. 64 169.71 8704. 45 -3405.14 791.97 0.00 0.00 0.00 0.00 10341.07 90. 00 170.00 8703. 00 -3450.00 800.00 8.00 -7.98 0.63 175.50 06-13A T1 10919.58 90. 00 123.72 8703. 00 -3921.35 1107.74 8.00 0.00 -8.00 -90.00 11003.93 90. 00 123.72 8703. 00 -3968.17 1177.90 0.00 0.00 0.00 0.00 11141.12 90. 00 110.00 8703. 00 -4030.00 1300.00 10.00 0.00 -10.00 -90.00 06-13A T2 11169.91 90. 33 107.14 8702. 92 -4039.17 1327.28 10.00 1.15 -9.93 -83.41 13412.25 90. 33 107.14 8690. 00 -4700.00 3470.00 0.00 0.00 0.00 0.00 06-13A T3 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo. ft deg deg ft ft ft ft ft deg/i00ft ft ft 4900.00 25.75 107.67 4716.88 4648.88 804.74 -196.34 804.74 0.00 5940524.92 686099.44 Start Dir 1: 4901.24 25.76 108.01 4718.00 4650.00 805.26 -196.50 805.26 12.00 5940524.76 686099.95 UG3 4920.00 26.06 113.12 4734.88 4666.88 812.93 -199.38 812.93 12.00 5940522.07 686107.69 Start Dir 4/ 5000.00 24.58 119.75 4807.21 4739.21 843.54 -214.54 843.54 4.00 5940507.67 686138.67 MWD+IFR 5100.00 23.18 129.02 4898.68 4830.68 876.89 -237.26 876.89 4.00 5940485.78 686172.57 MWD+IFR 5200.00 22.38 139.16 4990.91 4922.91 904.65 -264.06 904.65 4.00 5940459.67 686200.97 MWD+IFR 5300.00 22.25 149.70 5083.46 5015.46 926.66 -294.82 926.66 4.00 5940429.46 686223.73 MWD+IFR 5400.00 22.79 160.06 5175.87 5107.87 942.82 -329.39 942.82 4.00 5940395.31 686240.73 MWD+IFR 5500.00 23.96 169.71 5267.70 5199.70 953.05 -367.59 953.05 4.00 5940357.37 686251.90 MWD+IFR 5566.26 25.04 175.55 5328.00 5260.00 956.54 -394.82 956.54 4.00 5940330.24 686256.06 UG1 5600.00 25.68 178.33 5358.49 5290.49 957.31 -409.24 957.31 4.00 5940315.84 686257.18 MWD+IFR 5700.00 27.83 185.83 5447.80 5379.80 955.57 -454.14 955.57 4.00 5940270.91 686256.54 MWD+IFR 5800.00 30.34 192.25 5535.20 5467.20 947.84 -502.07 947.84 4.00 5940222.81 686249.99 MWD+IFR 5891.11 32.86 197.28 5612.81 5544.81 935.61 -548.18 935.61 4.00 5940176.42 686238.91 End Dir : c 5900.00 32.86 197.28 5620.28 5552.28 934.18 -552.78 934.18 0.00 5940171.78 686237.59 MWD+IFR 6000.00 32.86 197.28 5704.28 5636.28 918.07 -604.60 918.07 0.00 5940119.59 686222.75 MWD+IFR 6100.00 32.86 197.28 5788.28 5720.28 901.95 -656.41 901.95 0.00 5940067.40 686207.92 MWD+IFR 6200.00 32.86 197.28 5872.28 5804.28 885.84 -708.22 885.84 0.00 5940015.21 686193.09 MWD+IFR 6230.62 32.86 197.28 5898.00 5830.00 880.91 -724.09 880.91 0.00 5939999.23 686188.54 WS2 6300.00 32.86 197.28 5956.28 5888.28 869.73 -760.03 869.73 0.00 5939963.02 686178.25 MWD+IFR 6400.00 32.86 197.28 6040.28 5972.28 853.61 -811.84 853.61 0.00 5939910.83 686163.42 MWD+IFR 6500.00 32.86 197.28 6124.28 6056.28 837.50 -863.66 837.50 0.00 5939858.64 686148.59 MWD+IFR 6500.86 32.86 197.28 6125.00 6057.00 837.36 -864.10 837.36 0.00 5939858.19 686148.46 WS1 6600.00 32.86 197.28 6208.27 6140.27 821.39 -915.47 821.39 0.00 5939806.45 686133.75 MWD+IFR 6700.00 32.86 197.28 6292.27 6224.27 805.27 -967.28 805.27 0,00 5939754.27 686118.92 MWD+IFR • • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/3/2006 Time:. 13:58:02 Page: .. 3 Field: Prudhoe Bay Co-ordinate(NE) Reference:. Well: 06-13, True North Site: PB DS 06 Vertical (TVD} Reference: 20 :135115/1 980 00:0068:0 Well: 06-13 Section (VS) Reference: Well (O:OON;O.OOE,90.OOAzi) Wellpath: Plan 06-13A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg .deg ft ft ft ft ft deg/100ft ft ft 6800. 00 32. 86 197.28 6376. 27 6308 .27 789 .16 -1019 .09 789. 16 0.00 5939702. 08 686104. 08 MWD+IFR 6810. 39 32 .86 197.28 6385 .00 6317 .00 787 .49 -1024 .47 787. 49 0.00 5939696. 65 686102. 54 CM3 6900. 00 32 .86 197.28 6460 .27 6392 .27 773 .05 -1070 .90 773. 05 0.00 5939649. 89 686089. 25 MWD+IFR 7000. 00 32 .86 197.28 6544 .27 6476 .27 756 .93 -1122 .72 756. 93 0.00 5939597. 70 686074. 42 MWD+IFR 7100. 00 32 .86 197.28 6628 .27 6560 .27 740 .82 -1174 .53 740 .82 0.00 5939545. 51 686059. 58 MWD+IFR 7200. 00 32 .86 197.28 6712 .27 6644 .27 724 .71 -1226 .34 724 .71 0.00 5939493. 32 686044. 75 MWD+IFR 7300. 00 32 .86 197.28 6796 .27 6728 .27 708 .59 -1278 .15 708 .59 0.00 5939441 .13 686029. 91 MWD+IFR 7396. 11 32 .86 197.28 6877 .00 6809 .00 693 .11 -1327 .95 693 .11 0.00 5939390. 97 686015. 66 CM2 7400. 00 32 .86 197.28 6880 .27 6812 .27 692 .48 -1329 .96 692 .48 0.00 5939388 .94 686015. 08 MWD+IFR 7500. 00 32 .86 197.28 6964 .27 6896 .27 676 .37 -1381 .78 676 .37 0.00 5939336 .75 686000. 25 MWD+IFR 7600. 00 32 .86 197.28 7048 .27 6980 .27 660 .25 -1433 .59 660 .25 0.00 5939284 .56 685985. 41 MWD+IFR 7700. 00 32. 86 197.28 7132 .27 7064 .27 644 .14 -1485 .40 644 .14 0.00 5939232 .37 685970. 58 MWD+IFR 7800. 00 32 .86 197.28 7216 .27 7148 .27 628 .03 -1537 .21 628. 03 0.00 5939180. 18 685955. 75 MWD+IFR 7900. 00 32 .86 197.28 7300 .26 7232 .26 611 .91 -1589 .02 611. 91 0.00 5939127. 99 685940. 91 MWD+IFR 8000. 00 32 .86 197.28 7384 .26 7316 .26 595 .80 -1640 .84 595. 80 0.00 5939075. 80 685926. 08 MWD+IFR 8079. 45 32 .86 197.28 7451 .00 7383 .00 583 .00 -1682 .00 583. 00 0.00 5939034. 34 685914. 29 Start Dir 4/ 8100. 00 33 .36 196.08 7468 .21 7400 .21 579 .78 -1692 .75 579. 78 4.00 5939023. 51 685911. 34 MWD+IFR 8184. 62 35 .54 191.50 7538 .00 7470 .00 568 .43 -1739 .22 568. 43 4.00 5938976. 78 685901. 13 CM1 8200. 00 35 .95 190.72 7550 .48 7482 .48 566 .70 -1748 .04 566 .70 4.00 5938967. 93 685899. 62 MWD+IFR 8300. 00 38 .75 186.00 7629 .99 7561 .99 557 .96 -1808 .03 557 .96 4.00 5938907. 74 685892. 36 MWD+IFR 8400. 00 41 .72 181.84 7706 .34 7638 .34 553 .62 -1872 .44 553 .62 4.00 5938843 .25 685889. 60 MWD+IFR 8500. 00 44 .82 178.15 7779 .16 7711 .16 553 .69 -1940 .94 553 .69 4.00 5938774 .77 685891. 35 MWD+IFR 8600. 00 48 .02 174.85 7848 .10 7780 .10 558 .16 -2013 .21 558 .16 4.00 5938702 .64 685897. 60 MWD+IFR 8700. 00 51 .31 171.87 7912 .82 7844 .82 567 .02 -2088 .90 567 .02 4.00 5938627 .20 685908. 32 MWD+IFR 8750. 41 53 .00 170.46 7943 .75 7875 .75 573 .14 -2128 .23 573 .14 4.00 5938588 .03 685915. 41 End Dir 8757. 48 53 .00 170.46 7948 .00 7880 .00 574 .08 -2133 .80 574 .08 0.00 5938582 .49 685916. 48 THRZ 8800. 00 53 .00 170.46 7973 .59 7905 .59 579 .70 -2167 .29 579 .70 0.00 5938549 .15 685922. 93 MWD+IFR 8900. 00 53 .00 170.46 8033 .77 7965 .77 592 .93 -2246 .05 592 .93 0.00 5938470 .74 685938. 09 MWD+IFR 9000. 00 53 .00 170.46 8093 .96 8025 .96 606 .16 -2324 .81 606 .16 0.00 5938392 .34 685953. 25 MWD+IFR 9039. 95 53 .00 170.46 8118 .00 8050 .00 611 .45 -2356 .27 611 .45 0.00 5938361 .02 685959. 30 BHRZ 9100. 00 53 .00 170.46 8154 .14 8086 .14 619 .39 -2403 .56 619. 39 0.00 5938313. 93 685968. 41 MWD+IFR 9200. 00 53 .00 170.46 8214 .32 8146 .32 632 .62 -2482 .32 632. 62 0.00 5938235. 53 685983. 57 MWD+IFR 9300. 00 53 .00 170.46 8274 .51 8206 .51 645 .85 -2561 .08 645 .85 0.00 5938157. 12 685998. 73 MWD+IFR 9305. 81 53 .00 170.46 8278 .00 8210 .00 646 .62 -2565 .66 646 .62 0.00 5938152. 57 685999. 61 TJC 9400. 00 53 .00 170.46 8334 .69 8266 .69 659 .08 -2639 .84 659 .08 0.00 5938078 .72 686013. 89 MWD+IFR 9500. 00 53 .00 170.46 8394 .87 8326 .87 672 .31 -2718 .60 672 .31 0.00 5938000 .31 686029. 05 MWD+IFR 9600. 00 53 .00 170.46 8455 .05 8387 .05 685 .54 -2797 .36 685 .54 0.00 5937921 .91 686044. 21 MWD+IFR 9604. 89 53 .00 170.46 8458 .00 8390 .00 686 .19 -2801 .21 686 .19 0.00 5937918 .07 686044. 95 TJB 9700. 00 53 .00 170.46 8515 .24 8447 .24 698 .77 -2876 .12 698 .77 0,00 5937843 .50 686059. 37 MWD+IFR 9800. 00 53 .00 170.46 8575 .42 8507 .42 712 .00 -2954 .88 712 .00 0.00 5937765 .10 686074. 53 MWD+IFR 9801. 47 53 .00 170.46 8576 .31 8508 .31 712 .19 -2956 .04 712 .19 0.00 5937763 .94 686074. 76 Start Dir 4/ 9804. 29 53 .11 170.46 8578 .00 8510 .00 712 .57 -2958 .26 712 .57 4.00 5937761 .73 686075. 18 TJA 9900. 00 56 .93 170.19 8632 .86 8564 .86 725 .75 -3035 .55 725 .75 4.00 5937684 .79 686090. 26 MWD+IFR 9976. 77 60 .00 170.00 8673 .00 8605 .00 737 .00 -3100 .00 737 .00 4.00 5937620 .64 686103. 09 7" 9996. 77 60 .00 170.00 8683 .00 8615 .00 740 .01 -3117 .06 740 .01 0.00 5937603 .66 686106. 52 Start Dir 2 10000. 00 60 .78 169.99 8684 ,60 8616 .60 740 .50 -3119 .83 740 .50 24.00 5937600 .91 686107. 07 MWD+IFR 10042. 67 71. 02 169.90 8702 .00 8634 .00 747 .29 -3158 .12 747 .29 24.00 5937562 .79 686114. 81 TSHA 10100. 00 84. 77 169.78 8713 .99 8645 .99 757 .16 -3213 .17 757 .16 24.00 5937508 .01 686126. 02 MWD+IFR 10136. 93 93. 64 169.71 8714 .50 8646 .50 763 .72 -3249 .47 763 .72 24.00 5937471 .89 686133. 48 End Dir : 1 10200. 00 93. 64 169.71 8710 .50 8642 .50 774 .96 -3311 .40 774 .96 0.00 5937410 .25 686146. 23 MWD+IFR 10295. 46 93 .64 169.71 8704 .45 8636 .45 791 .97 -3405 .14 791 .97 0.00 5937316 .96 686165. 54 Start Dir 8/ 10300. 00 93 .28 169.74 8704 .17 8636 .17 792 .78 -3409 .60 792 .78 8.00 5937312 .53 686166. 46 MWD+IFR 10341. 07 90 .00 170.00 8703 .00 8635 .00 800 .00 -3450 .00 800 .00 8.00 5937272 .32 686174. 67 06-13A T1 lent S S S S S S S S S S S S S S S S S S S S 0 S S S S S S S S S S S S S S 3 S S • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/3/2006 Timer 13:58:02 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 06-13, True North. Site: PB DS 06 Vertical (TVD) Reference: 20 ; 13 5/15/1980 00:00 68.0 Well: 06-13 Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 06-13A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN ft deg deg ft ft ft ft ft deg/100ft ft 10400 .00 90. 00 165.29 8703. 00 8635. 00 812. 61 -3507. 55 812. 61 8.00 5937215.10 10500 .00 90. 00 157.29 8703. 00 8635. 00 844. 66 -3602. 19 844. 66 8.00 5937121.28 10600 .00 90. 00 149.29 8703. 00 8635. 00 889. 58 -3691. 44 889. 58 8.00 5937033.17 10700 .00 90. 00 141.29 8703. 00 8635. 00 946. 49 -3773. 57 946. 49 8.00 5936952.46 10800 .00 90. 00 133.29 8703. 00 8635. 00 1014. 27 -3846. 99 1014. 27 8.00 5936880.74 10900 .00 90. 00 125.29 8703. 00 8635 .00 1091. 60 -3910. 26 1091. 60 8.00 5936819.40 10919 .58 90. 00 123.72 8703. 00 8635. 00 1107 .74 -3921. 35 1107. 74 8.00 5936808.71 11000 .00 90. 00 123.72 8703. 00 8635 .00 1174. 63 -3965. 99 1174. 63 0.00 5936765.73 11003 .93 90. 00 123.72 8703. 00 8635 .00 1177. 90 -3968. 17 1177. 90 0.00 5936763.63 11100 .00 90. 00 114.11 8703. 00 8635 .00 1261 .90 -4014. 56 1261. 90 10.00 5936719.31 11141 .12 90. 00 110.00 8703. 00 8635 .00 1300 .00 -4030. 00 1300. 00 10.00 5936704.82 11169 .91 90. 33 107.14 8702. 92 8634. 92 1327 .28 -4039. 17 1327. 28 10.00 5936696.32 11200 .00 90. 33 107.14 8702. 74 8634.74 1356 .04 -4048. 04 1356. 04 0.00 5936688.16 11300 .00 90. 33 107.14 8702. 17 8634 .17 1451 .60 -4077. 51 1451. 60 0.00 5936661. 05 11400 .00 90. 33 107.14 8701. 59 8633 .59 1547 .15 -4106 .98 1547. 15 0.00 5936633. 94 11500 .00 90. 33 107.14 8701. 02 8633 .02 1642 .71 -4136 .45 1642. 71 0.00 5936606. 83 11600 .00 90. 33 107.14 8700. 44 8632 .44 1738 .27 -4165. 92 1738. 27 0.00 5936579. 72 11700 .00 90. 33 107.14 8699. 86 8631 .86 1833 .82 -4195 .39 1833. 82 0.00 5936552. 61 11800 .00 90. 33 107.14 8699. 29 8631 .29 1929 .38 -4224 .86 1929. 38 0.00 5936525. 50 11900 .00 90. 33 107.14 8698. 71 8630 .71 2024 .94 -4254 .33 2024. 94 0.00 5936498. 39 12000 .00 90. 33 107.14 8698. 14 8630 .14 2120 .49 -4283. 80 2120. 49 0.00 5936471. 27 12100 .00 90. 33 107.14 8697. 56 8629 .56 2216 .05 -4313 .27 2216. 05 0.00 5936444. 16 12200 .00 90. 33 107.14 8696. 98 8628 .98 2311 .61 -4342 .75 2311. 61 0.00 5936417. 05 12300 .00 90. 33 107.14 8696. 41 8628 .41 2407 .17 -4372 .22 2407. 17 0.00 5936389. 94 12400 .00 90. 33 107.14 8695. 83 8627 .83 2502 .72 -4401 .69 2502. 72 0.00 5936362. 83 12500 .00 90. 33 107.14 8695. 26 8627 .26 2598 .28 -4431 .16 2598. 28 0.00 5936335. 72 12600 .00 90. 33 107.14 8694. 68 8626 .68 2693 .84 -4460 .63 2693. 84 0.00 5936308. 61 12700 .00 90. 33 107.14 8694. 10 8626 .10 2789 .39 -4490 .10 2789. 39 0.00 5936281. 50 12800 .00 90. 33 107.14 8693. 53 8625 .53 2884 .95 -4519 .57 2884. 95 0.00 5936254. 38 12900 .00 90. 33 107.14 8692. 95 8624 .95 2980 .51 -4549 .04 2980. 51 0.00 5936227. 27 13000 .00 90. 33 107.14 8692. 37 8624 .37 3076 .06 -4578 .51 3076. 07 0.00 5936200. 16 13100 .00 90. 33 107.14 8691. 80 8623 .80 3171 .62 -4607 .98 3171. 62 0.00 5936173. 05 13200 .00 90. 33 107.14 8691. 22 8623 .22 3267 .18 X637 .45 3267. 18 0.00 5936145. 94 13300 .00 90. 33 107.14 8690. 65 8622 .65 3362 .74 -4666 .92 3362. 74 0.00 5936118. 83 13400 .00 90. 33 107.14 8690. 07 8622 .07 3458 .29 -4696 .39 3458. 29 0.00 5936091. 72 13411 .00 90. 33 107.14 8690. 01 8622. 01 3468 .80 -4699 .64 3468. 80 0.00 5936088. 73 13412 .00 90. 33 107.14 8690. 00 8622. 00 3469 .76 -4699 .93 3469. 76 0.00 5936088. 46 13412 .25 90. 33 107.14 8690. 00 8622 .00 3470 .00 -4700 .00 3470. 00 0.00 5936088. 40 MapE TooUCo r ft 686188.69 MWD+IFR 686223.06 MWD+IFR 686270.16 MWD+IFR 686329.06 MWD+IFR 686398.62 MWD+IFR 686477.48 MWD+IFR 686493.89 End Dir : 1 1 686561.85 MWD+IFR 686565.17 Start Dir 1 0 686650.28 MWD+IFR 686688.74 06-13A T2 686716.24 End Dir : 11 6 686745.21 MWD+IFR 686841.46 MWD+IFR 686937.70 MWD+IFR 687033.95 MWD+IFR 687130.20 MWD+IFR 687226.44 MWD+IFR 687322.69 MWD+IFR 687418.94 MWD+IFR 687515.18 MWD+IFR 687611.43 MWD+IFR 687707.68 MWD+IFR 687803.92 MWD+IFR 687900.17 MWD+IFR 687996.42 MWD+IFR 688092.66 MWD+IFR 688188.91 MWD+IFR 688285.16 MWD+IFR 688381.40 MWD+IFR 688477.65 MWD+IFR 688573.90 MWD+IFR 688670.14 MWD+IFR , 688766.39 MWD+IFR , 688862.64 MWD+IFR ; 688873.22 4 1 /2" 688874.19 Total Dept : 1 688874.42 06-13A T3 Terri Hubble. BP Exploration AK Inc. PO Box 1.96612 MB 7-5 Anchorage, AK 99.519 PAY TO THE .ORDER OF Sri , i .. • 89-6/1252 288 "Mastercard Check" DATE ~' -I ~ ~ Q ~D First National Bank Alaska A~~ Anchorage, AK 99501 MEMO +:125200.060:99146227L55.611• 02gg • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ Q ~ ~~ PTD# 2 Cam-- /c~ 2~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-OIv'S TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing we I1 (If last two digits in permit No. API No. 50- - - API number are , ~ ' between 60-69) i Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full. compliance with 20 AAC EXCEPTION 2S.OS5. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Co many Name) must contact the Commission to obtain advance approval of such water well testing pro ram. Rev: 1 /25/06 C:\jody\transmitta( checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY; PRUDHOE OIL -640150. __ _ Well Name: PRUDHOE BAY. UNIT 06-13A___ _ Program DEV._ __ ________. Well bore seg PTD#:2061020 C ompany BP EXPLORATION_~ALASItA)_INC _ _ _ _ Initial Classlfype _ _DEV 11-O1L GeoArea 894 ___ Unit 11650____ __ OnlOff Shore On _ ___, Annular Disposal Administration 1 Permitfee attached. Yes _ 2 Lease numberappropriate_ Yes 3 Unique well. name and number Yes _ _ '4 Well located in a defined pool Yes _ 5 Well located proper distance from drilling unit boundary Yes _ 6 Well located proper distance from other wells Yes 7 sufficient acreage available in drilling unit. _ Yes _ 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 1 U operator has_approprate bond iA farce _ . _ _ Yes _ 11 Permit can be issued without conservation order Yes 12 F;;rmit can be issued without administrative. approval Yes Appr Date 13 Can permit be approved before 15-day wait Yes RPC 7/1312006 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For. NA 15 All wells within 114 mile area of review identified (For service well only) NA 1 fi Pre-produced injector; duration ofpre-production less. than 3 months (For service well only) NA_ _ 17 Nonconven. gas conforms t~ AS31,05,030Q,1.A),(j.2.A-D) NA __ 18 __ ___ Conductor string_provided NA - __ Engineering 19 Surface casing. protects all. known USDWs NA 20 CMT vol adequate to circulate on conductor_& surf_csg NA _ _ _ 21 CMT vo(adequate to tie-i_n long string tosurf csg NA 22 CMT will hover all known productive horizors No_ Slotted. 23 Casing designs adequate for C, T B &_permafrost Yes 24 Adequate tankage. or reserve pit .Yes .Nabors 2ES. 25 If a re-drill, has. a 10.403 for abandonment been approved Yes _ 6/1512006, 26 Adequate wellbore separation proposed.. Yes _ _ 27 If dverter required, does it meet regulations. NA _ Sidetrack. 28 Drilling fluid- program schematic & equip list adequate. Yes Max MW 11.3 ppg. Appr Date 29 BOPEs, do they meetregulatior, Yea WGA 7!1412006 '30 BOPE press rating appropriate; test to (put psig in .comments) _ Yes Test to 3500 psi. MSP 2439 psi. 31 Choke manifold complies wlAPl_RP-53 (fvlay 84)_ _ _ _ _ _ _ _ _ _ .. _ Yes _ _ '32 Work will occur without operation shutdown _ _ Yes _ 33 Is presence of H2S gas. probable.. _ _ _ Yes 250 ppm max on pad. 'B4 Mechanical. condition of wells within AOR verified ~Fpr service well on_ty) NA_ _ -- -- 35 Permitcan be issued wlo hydrogen sulfide measures _ _ No_ _ - -- -- --- Geology i36 Data,presented on potential overpressure zones NA_ _ 37 Seismic analysis. of shallow gas zones.. _ _ _ NA_ . . Appr Date '38 Seabed condition survey_(ifoff-shore) _ . _ . _ _ ._ _ _ _ _ _ NA _ _ _ . RPC 7113!2006 '',39 Contact namelphone for weekly progress reports [exploratory ontyJ _ _ _ NA_ _ a Geologic Engineering Public Commissioner: Date: issione Date Commissioner Date 7 ~~-0~ 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 Nistory file and to simplify fiinding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize ibis category of information. 6-13a.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Mon Apr 21 14:14:17 2008 Reel Header Service name .............LISTPE Date . ...................08/04/21 Ori 9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/04/21 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Pruhoe Bay unit MWD/MAD LOGS WELL NAME: 06-13A API NUMBER: 500292045701 OPERATOR: BP Exploration (Alaska) Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-APR-08 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: w-0004723502 w-0004723502 w-0004723502 LOGGING ENGINEER: B. TRANI B. TRANI M. LEAFSTEDT OPERATOR WITNESS: B. NEWFELD B. NEWFELD D. MASKELL MWD RUN 6 MWD RUN 7 MWD RUN 8 JOB NUMBER: w-0004723502 w-0004723502 w-0004723502 LOGGING ENGINEER: M. LEAFSTEDT M. LEAFSTEDT B. TRANI OPERATOR WITNESS: D. MASKEL D. MASKEL D. MASKEL MWD RUN 9 JOB NUMBER: w-0004723502 LOGGING ENGINEER: B. TRANI OPERATOR WITNESS: J. RALL SURFACE LOCATION SECTION: 2 Page 1 ~c~-~oa ~~~23 • • 6-13a.tapx TOWNSHIP: lON RANGE: 14E FNL: FSL: 120 FEL: 1704 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 67.00 GROUND LEVEL: 38.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1sT STRING 8.500 9.625 4909.0 2ND STRING 6.125 7.000 10007.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE, AN OPENHOLE SIDETRACK, EXITS 6-13A PB1 AT 10225'MD/8702'TVD. THE 6-13A PB1 WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 4909'MD/4725'TVD, IN THE 6-13 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 3. MWD RUN 3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS. NO PROGRESS WAS MADE ON MWD RUNS 1 & 2. 4. MWD RUNS 4-9 COMPRISED DIRECTIONAL, DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUNS 4-6 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 8 & 9 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AT-BIT INCLINATION (ABI). RUN 7 ALSO INCLUDED ABI. UPHOLE SGRC TIE-IN DATA WERE MERGED WITH MWD RUN 3 DATA. MAD DATA WERE ACQUIRED OVER PART OF THE RUN 8 INTERVAL WHILE POOH AFTER COMPLETING RUN 8. THESE MAD DATA ARE PRESENTED IN THE 6-13A PB1 DATASET. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN 6-13 ON 29 MAY 1980. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 8 FEBRUARY 2008, AS AUTHORIZED BY Page 2 PRIYA MARAJ (BP). 6-13a.tapx 6. MWD RUNS 1-9 REPRESENT WELL 6-13A WITH API# 50-029-20457-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12500'MD/8684'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED .PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4-8.45 PPG MUD SALINITY: 4000-7400 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH Page 3 6-13a.tapx GR 4638.0 12423.0 RPD 4884.5 12430.0 RPS 4884.5 12430.0 FET 4884.5 12430.0 RPM 4884.5 12430.0 RPX 4884.5 12430.0 ROP 4903.5 12489.5 NPHI 10052.5 12394.5 FCNT 10052.5 12394.5 NCNT 10052.5 12394.5 RHOS 10067.0 12410.0 DRHO 10067.0 12410.0 PEF 10067.0 12410.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4638.0 4645.0 4638.5 4645.5 4644.5 4651.0 4649.0 4655.5 4654.5 4662.0 4661.5 4668.5 4677.0 4682.0 4687.0 4691.5 4689.5 4693.5 4699.0 4702.5 4714.5 4717.5 4725.0 4728.0 4739.0 4742.0 4753.0 4753.5 4754.0 4755.0 4761.0 4761.0 4762.5 4763.0 4765.0 4766.5 4782.5 4785.5 4786.0 4789.5 4789.0 4792.0 4792.5 4797.5 4803.0 4806.5 4812.0 4815.5 4815.0 4817.0 4819.0 4824.5 4826.5 4831.5 4827.5 4833.5 4837.5 4841.5 4845.5 4847.5 4848.0 4849.5 4860.5 4863.5 4886.5 4892.0 4890.0 4895.5 4895.5 4901.5 4899.5 4906.0 4904.5 4910.5 12489.5 12495.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MwD 3 4645.0 MWD 4 4938.0 Page 4 MERGE BASE 4938.0 8028.0 MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 REMARKS: MERGED MAIN PASS. 6-13a.tapx 8028.0 9675.0 9675.0 10007.0 10007.0 10150.0 10150.0 10225.0 10225.0 12495.5 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 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4638 12489.5 8563.75 15704 4638 12489.5 FCNT MWD CNTS 242.36 2378.57 740.285 4685 10052.5 12394.5 NCNT MWD CNTS 19723.7 48043.1 31646.1 4685 10052.5 12394.5 RHOB MWD G/CM 1.837 3.378 2.40512 4687 10067 12410 DRHO MWD G/CM -0.363 1.124 0.103366 4687 10067 12410 RPD MWD OHMM 0.22 2000 20.4691 15092 4884.5 12430 RPM MWD OHMM 0.44 2000 16.4915 15092 4884.5 12430 RPS MWD OHMM 0.63 1823.28 9.27323 15092 4884.5 12430 RPX MWD OHMM 0.63 1823.2 9.36967 15092 4884.5 12430 FET MWD HOUR 0.27 138.93 3.18982 15092 4884.5 12430 GR MWD API 10.17 576.35 99.8309 15571 4638 12423 PEF MWD BARN 1.32 6.97 2.32851 4687 10067 12410 ROP MWD FPH 0.34 338.95 88.2589 15158 4903.5 12489.5 NPHI MWD Pu-s 8.62 39.68 22.0842 4685 10052.5 12394.5 First Reading For Entire File..........4638 Last Reading For Entire File...........12489.5 File Trailer Page 5 ~ ~ 6-13a.tapx Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4645.0 4882.0 OP 4909.5 4938.0 $ LOG HEADER DATA DATE LOGGED: 12-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4938.0 TOP LOG INTERVAL (FT): 4909.0 BOTTOM LOG INTERVAL (FT): 4938.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): .0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 75.0 MUD PH: 9.5 Page 6 ~ ~ 6-13a.tapx MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 89.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4645 4938 4791.5 587 4645 4938 GR MWD030 API 12.27 82.92 47.0469 475 4645 4882 ROP MWD030 FT/H 0.34 57.55 13.9645 58 4909.5 4938 First Reading For Entire File..........4645 Last Reading For Entire File...........4938 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Page 7 6-13a.tapx service name... .......STSL26.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4882.5 7981.5 RPD 4890.0 7974.0 RPX 4890.0 7974.0 RPM 4890.0 7974.0 RPS 4890.0 7974.0 FET 4890.0 7974.0 ROP 4938.5 8028.0 LOG HEADER DATA DATE LOGGED: 14-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8028.0 TOP LOG INTERVAL (FT): 4938.0 BOTTOM LOG INTERVAL (FT): 8028.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.3 MAXIMUM ANGLE: 32.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4926.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 55.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.850 71.0 MUD AT MAX CIRCULATING TER MPERATURE: 1.150 118.0 MUD FILTRATE AT MT: 1.500 71.0 MUD CAKE AT MT: .820 71.0 Page 8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 6-13a.tapx 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 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 RoP MwD040 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 4882.5 8028 6455.25 6292 4882.5 8028 RPD MWD040 OHMM 0.22 2000 8.35913 6169 4890 7974 RPM MWD040 OHMM 0.77 2000 4.62631 6169 4890 7974 RPS MWD040 OHMM 0.78 1823.28 4.06164 6169 4890 7974 RPX MWD040 OHMM 0.76 1823.2 3.52866 6169 4890 7974 FET MWD040 HOUR 0.27 23.43 1.078 6169 4890 7974 GR MWD040 API 10.17 186.24 85.3363 6199 4882.5 7981.5 ROP MWD040 FT/H 5.44 338.95 122.099 6180 4938.5 8028 First Reading For Entire File..........4882.5 Last Reading For Entire File...........8028 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Page 9 Physical EOF 6-13a.tapx File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 7974.5 9620.5 RPD 7974.5 9620.5 FET 7974.5 9620.5 RPX 7974.5 9620.5 RPS 7974.5 9620.5 GR 7982.0 9628.5 ROP 8028.5 9675.0 LOG HEADER DATA DATE LOGGED: 18-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9675.0 TOP LOG INTERVAL (FT): 8028.0 BOTTOM LOG INTERVAL (FT): 9675.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.0 MAXIMUM ANGLE: 55.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4926.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 11.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1850 FLUID LOSS (C3): 3.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .855 81.0 Page 10 6-13a.tapx MUD AT MAX CIRCULATING TERMPERATURE: . 470 154.4 MUD FILTRATE AT MT: . 702 81.0 MUD CAKE AT MT: 1. 328 68.0 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. .. .. .. ..... Datum specification Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7974.5 9675 8824.75 3402 7974.5 9675 RPD MWD050 OHMM 0.67 8.07 3.23778 3293 7974.5 9620.5 RPM MWD050 OHMM 0.6 9.55 3.20756 3293 7974.5 9620.5 RPS MWD050 OHMM 0.63 8.74 2.87909 3293 7974.5 9620.5 RPX MWD050 OHMM 0.63 10.57 2.77762 3293 7974.5 9620.5 FET MWD050 HOUR 0.9 37.04 3.02456 3293 7974.5 9620.5 GR MWD050 API 62.73 430.32 164.904 3294 7982 9628.5 ROP MWD050 FT/H 0.63 230.37 45.9442 3294 8028.5 9675 First Reading For Entire File..........7974.5 Last Reading For Entire File...........9675 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Page 11 6-13a.tapx Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 9621.0 9952.5 RPM 9621.0 9952.5 RPS 9621.0 9952.5 RPD 9621.0 9952.5 FET 9621.0 9952.5 GR 9629.0 9960.5 ROP 9675.5 10007.0 LOG HEADER DATA DATE LOGGED: 19-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10007.0 TOP LOG INTERVAL (FT): 9675.0 BOTTOM LOG INTERVAL (FT): 10007.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.7 MAXIMUM ANGLE: 59.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4926.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 11.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1600 Page 12 6-13a.tapx FLUID LOSS (C3): 3.8 RESIST IVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .860 81.0 MUD AT MAX CIRCULATING TERMPERATURE: .420 171.0 MUD FILTRATE AT MT: .700 81.0 MUD CAKE AT MT: 1.330 68.0 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 Log~iny 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 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9621 10007 9814 773 9621 10007 RPD MWD060 OHMM 2.44 10.6 4.36364 664 9621 9952.5 RPM MWD060 OHMM 2.46 11.16 4.4448 664 9621 9952.5 RPS MWD060 OHMM 2.22 6.64 3.51083 664 9621 9952.5 RPX MWD060 OHMM 2.16 6.27 3.20373 664 9621 9952.5 FET MWD060 HOUR 0.72 23.49 4.87113 664 9621 9952.5 GR MwD060 API 75.42 156.78 129.828 664 9629 9960.5 ROP MWD060 FT/H 0.76 174.54 67.2928 664 9675.5 10007 First Reading For Entire File..........9621 Last Reading For Entire File...........10007 File Trailer service name... .......STSLIg.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Page 13 ~ ~ 6-13a.tapx Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER; 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 9953.0 10097.0 FET 9953.0 10097.0 RPx 9953.0 10097.0 RPD 9953.0 10097.0 RPM 9953.0 10097.0 GR 9961.0 10090.0 OP 10007.5 10150.0 $ LOG HEADER DATA DATE LOGGED: 25-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10150.0 TOP LOG INTERVAL (FT): 10007.0 BOTTOM LOG INTERVAL (FT): 10150.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.7 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153883 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 Page 14 • • 6-13a.tapx MUD VISCOSITY (S): 51.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 7500 FLUID LOSS (C3): 9.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .600 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .340 111.0 MUD FILTRATE AT MT: .500 60.0 MUD CAKE AT MT: .750 58.0 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 Loggin 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 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MwD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MwD070 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9953 10150 10051.5 395 9953 10150 RPD MWD070 OHMM 3.85 2000 460.342 289 9953 10097 RPM MWD070 OHMM 0.44 2000 359.266 289 9953 10097 RPS MWD070 OHMM 1.27 1632.18 30.9247 289 9953 10097 RPX MWD070 OHMM 0.94 1547.68 19.6131 289 9953 10097 FET MwD070 HOUR 3.56 138.93 55.2945 289 9953 10097 GR MwD070 API 55.79 550.57 119.02 259 9961 10090 ROP MWD070 FT/H 0.47 85.13 19.0291 286 10007.5 10150 First Reading For Entire File..........9953 Last Reading For Entire File...........10150 File Trailer Service name .............STSLI6.006 Page 15 • 6-13a.tapx Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FONT 10058.5 10225.0 NCNT 10058.5 10225.0 NPHI 10058.5 10225.0 PEF 10073.0 10225.0 RHOB 10073.0 10225.0 DRHO 10073.0 10225.0 GR 10090.5 10225.0 RPX 10097.5 10225.0 RPS 10097.5 10225.0 FET 10097.5 10225.0 RPM 10097.5 10225.0 RPD 10097.5 10225.0 ROP 10150.5 10225.0 LOG HEADER DATA DATE LOGGED: 28-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10225.0 TOP LOG INTERVAL (FT): 10150.0 BOTTOM LOG INTERVAL (FT): 10225.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.6 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153883 CTN COMP THERMAL NEUTRON 1844674407370955 Page 16 6-13a.tapx EWR4 Electromag Resis. 4 48783 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 50.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .670 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .500 100.4 MUD FILTRATE AT MT: .660 67.0 MUD CAKE AT MT: .630 71.0 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 Logyin 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 FCNT MWD080 CNTS 4 1 68 4 2 NCNT MWD080 CNTS 4 1 68 8 3 RHOB MWD080 G/CM 4 1 68 12 4 DRHO MWD080 G/CM 4 1 68 16 5 RPD MwD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPx MwD080 OHMM 4 1 68 32 9 FET MWD080 HOUR 4 1 68 36 10 GR MWD080 API 4 1 68 40 11 PEF MWD080 BARN 4 1 68 44 12 ROP MWD080 FT/H 4 1 68 48 13 NPHI MWD080 PU-s 4 1 68 52 14 First Last Page 17 6-13a.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10058.5 10225 10141.8 334 10058.5 10225 FCNT MWD080 CNTS 339.51 2378.57 1062.43 334 10058.5 10225 NCNT MWD080 CNTS 19723.7 48043.1 34423.3 334 10058.5 10225 RHOB MWD080 G/CM 2.109 3.378 2.57238 305 10073 10225 DRHO MWD080 G/CM -0.154 1.124 0.110797 305 10073 10225 RPD MWDO80 OHMM 18.45 51.85 33.5229 256 10097.5 10225 RPM MWD080 OHMM 16.64 67.57 36.1371 256 10097.5 10225 RPS MWD080 OHMM 14.12 91.68 38.6228 256 10097.5 10225 RPX MWD080 OHMM 11.58 76.33 32.0321 256 10097.5 10225 FET MWD080 HOUR 1.53 24.85 11.6131 256 10097.5 10225 GR MWD080 API 48.89 576.35 130.852 270 10090.5 10225 PEF MWD080 BARN 1.85 5.53 2.75672 305 10073 10225 ROP MWD080 FT/H 1.1 223.84 28.6523 150 10150.5 10225 NPHI MwD080 PU-s 8.62 31.61 17.943 334 10058.5 10225 First Reading For Entire File..........10058.5 Last Reading For Entire File...........10225 File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLI6.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 comment Record FILE HEADER FILE NUMBER: 8 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 10178.5 12436.0 RPM 10178.5 12436.0 RPS 10178.5 12436.0 FET 10178.5 12436.0 RPx 10178.5 12436.0 GR 10225.5 12429.0 PEF 10225.5 12416.0 RHOB 10225.5 12416.0 NCNT 10225.5 12400.5 NPHI 10225.5 12400.5 Page 18 • • 6-13a.tapx FCNT 10225.5 12400.5 DRHO 10225.5 12416.0 ROP 10233.0 12495.5 LOG HEADER DATA DATE LOGGED: 04-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12500.0 TOP LOG INTERVAL (FT): 10225.0 BOTTOM LOG INTERVAL (FT): 12500.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 91.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 164573 CTN COMP THERMAL NEUTRON 1844674407370955 EwR4 Electromag Resis. 4 162742 ALD Azimuthal Litho-Dens 10508942 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 49.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 1900 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.210 69.7 MUD AT MAX CIRCULATING TERMPERATURE: .770 114.0 MUD FILTRATE AT MT: 1.020 68.2 MUD CAKE AT MT: .570 67.8 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 Page 19 • • 6-13a.tapx Absent value .... ............. -999 Depth Units. .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 NCNT MWD090 CNTS 4 1 68 8 3 RHOB MWD090 G/CM 4 1 68 12 4 DRHO MWD090 G/CM 4 1 68 16 5 RPD MWD090 OHMM 4 1 68 20 6 RPM MWD090 OHMM 4 1 68 24 7 RPS MWD090 OHMM 4 1 68 28 8 RPX MWD090 OHMM 4 1 68 32 9 FET MWD090 HOUR 4 1 68 36 10 GR MWD090 API 4 1 68 40 11 PEF MWD090 BARN 4 1 68 44 12 ROP MWD090 FT/H 4 1 68 48 13 NPHI MWD090 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10178.5 12495.5 11337 4635 10178.5 12495.5 FCNT MWD090 CNTS 242.36 1106.18 715.556 4351 10225.5 12400.5 NCNT MWD090 CNTS 20377 37674.7 31432.9 4351 10225.5 12400.5 RHOB MwD090 G/CM 1.837 2.786 2.39348 4382 10225.5 12416 DRHO MWD090 G/CM -0.363 0.681 0.102849 4382 10225.5 12416 RPD MWD090 OHMM 11.29 42.4 22.846 4448 10178.5 12436 RPM MWD090 OHMM 9.32 39.53 21.5518 4448 10178.5 12436 RPS MWD090 OHMM 7.96 34.08 19.0438 4448 10178.5 12436 RPX MWD090 OHMM 7.49 45.49 21.3858 4448 10178.5 12436 FET MWD090 HOUR 0.29 120.16 2.80471 4448 10178.5 12436 GR MWD090 API 46.2 326.89 69.7245 4408 10225.5 12429 PEF MWD090 BARN 1.32 6.97 2.2987 4382 10225.5 12416 ROP MWD090 FT/H 0.42 295.07 83.2267 4526 10233 12495.5 NPHI MwD090 Pu-s 16.14 39.68 22.4021 4351 10225.5 12400.5 First Reading For Entire File..........10178.5 Last Reading For Entire File...........12495.5 File Trailer Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/21 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Page 20 y 6-13a.tapx Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................08/04/21 Ori 9in ...................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 21 r • i 6-13apbl.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Mon Apr 21 13:04:49 2008 Reel Header Service name .............LISTPE Date . ...................08/04/21 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/04/21 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Pruhoe Bay Unit MWD/MAD LOGS WELL NAME: 06-13A PB1 API NUMBER: 500292045770 OPERATOR: BP Exploration (Alaska) Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-APR-08 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: w-0004723502 w-0004723502 w-0004723502 LOGGING ENGINEER: B. TRANI B. TRANI M. LEAFSTEDT OPERATOR WITNESS: B. NEWFELD B. NEWFELD D. MASKELL MWD RUN 6 MWD RUN 7 MWD RUN 8 Job NUMBER: w-0004723502 w-0004723502 w-0004723502 LOGGING ENGINEER: M. LEAFSTEDT M. LEAFSTEDT B. TRANI OPERATOR WITNESS: D. MASKEL D. MASKEL D. MASKEL MAD RUN 8 JOB NUMBER: w-0004723502 LOGGING ENGINEER: B. TRANI OPERATOR WITNESS: D. MASKEL SURFACE LOCATION SECTION: 2 Page 1 6-13apbl.tapx TOWNSHIP: lON RANGE: 14E FNL: FSL: 120 FEL: 1704 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 67.00 DERRICK FLOOR: GROUND LEVEL: 38.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4909.0 2ND STRING 6.125 7.000 10007.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 4909' MD/4725'TVD,IN THE 6-13 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 3. MWD RUN 3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. NO PROGRESS WAS MADE ON MWD RUNS 1 & 2. 4. MWD RUNS 4-8 COMPRISED DIRECTIONAL, DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUNS 4-6 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 8 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AT-BIT INCLINATION (ABI). RUN 7 ALSO INCLUDED ABI. UPHOLE SGRC TIE-IN DATA WERE MERGED WITH MWD RUN 3 DATA. MAD DATA WERE ACQUIRED OVER PART OF THE RUN 8 INTERVAL WHILE POOH AFTER COMPLETING RUN 8. THESE MAD DATA ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN 6-13 ON 29 MAY 1980. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 8 FEBRUARY 2008, AS AUTHORIZED BY PRIYA MARAJ (BP). 6. MWD RUNS 1-8 REPRESENT WELL 6-13A PB1 WITH API# Page 2 ~J 6-13apbl.tapx 50-029-20457-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11272'MD/8693'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4-8.45 PPG MUD SALINITY: 4000-7400 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... ......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPS FET 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4638.0 4884.5 4884.5 STOP DEPTH 11200.0 11207.0 11207.0 Page 3 6-13apbl.tapx RPD 4884.5 11207.0 RPX 4884.5 11207.0 RPM 4884.5 11207.0 ROP 4903.5 11266.0 FCNT 10052.5 11171.5 NPHI 10052.5 11171.5 NCNT 10052.5 11171.5 DRHO 10067.0 11187.0 PEF 10067.0 11187.0 HOB 10067.0 11187.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4638.0 4645.0 4638.5 4645.5 4644.5 4651.0 4649.0 4655.5 4654.5 4662.0 4661.5 4668.5 4677.0 4682.0 4687.0 4691.5 4689.5 4693.5 4699.0 4702.5 4714.5 4717.5 4725.0 4728.0 4739.0 4742.0 4753.0 4753.5 4754.0 4755.0 4761.0 4761.0 4762.5 4763.0 4765.0 4766.5 4782.5 4785.5 4786.0 4789.5 4789.0 4792.0 4792.5 4797.5 4803.0 4806.5 4812.0 4815.5 4815.0 4817.0 4819.0 4824.5 4826.5 4831.5 4827.5 4833.5 4837.5 4841.5 4845.5 4847.5 4848.0 4849.5 4860.5 4863.5 4886.5 4892.0 4890.0 4895.5 4895.5 4901.5 4899.5 4906.0 4904.5 4910.5 11266.0 11272.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 3 4645.0 4938.0 MwD 4 4938.0 8028.0 MwD 5 8028.0 9675.0 MwD 6 9675.0 10007.0 MwD 7 10007.0 10150.0 Page 4 i MWD $ REMARKS: MERGED MAIN PASS. 6-13apbl.tapx 10150.0 11272.0 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 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4638 11266 7952 13257 4638 11266 FCNT MWD CNTS 224.97 2378.57 729.336 2239 10052.5 11171.5 NCNT MWD CNTS 18520.1 48043.1 29944.2 2239 10052.5 11171.5 RHOB MWD G/CM 2.109 3.378 2.51068 2241 10067 11187 DRHO MWD G/CM -0.236 1.124 0.0429027 2241 10067 11187 RPD MWD OHMM 0.22 2000 20.2849 12646 4884.5 11207 RPM MWD OHMM 0.44 2000 15.8104 12646 4884.5 11207 RPS MWD OHMM 0.63 1823.28 7.83744 12646 4884.5 11207 RPX MWD OHMM 0.63 1823.2 6.7291 12646 4884.5 11207 FET MWD HOUR 0.27 138.93 3.43625 12646 4884.5 11207 GR MWD API 10.17 585.88 115.105 13125 4638 11200 PEF MWD BARN 1.55 9.72 2.90899 2241 10067 11187 ROP MWD FT/H 0.34 365.47 85.5112 12726 4903.5 11266 NPHI MWD PU-S 8.62 40.92 22.0282 2239 10052.5 11171.5 First Reading For Entire File..........4638 Last Reading For Entire File...........11266 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Page 5 6-13apbl.tapx Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 10109.5 10415.0 FONT 10109.5 10415.0 NCNT 10109.5 10415.0 DRHO 10124.0 10431.0 PEF 10124.0 10431.0 RHOB 10124.0 10431.0 GR 10134.0 10446.0 RPM 10142.0 10453.0 RPX 10142.0 10453.0 RPD 10142.0 10453.0 FET 10142.0 10453.0 RPS 10142.0 10453.0 RAT 10196.0 10511.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MwD 8 1 10058.5 11272.0 REMARKS: MERGED MAD 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 Page 6 ~ « 6-13apbl.tapx FCNT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 10109.5 10511.5 10310.5 805 10109.5 10511.5 FCNT MAD CNTS 332.11 1724.21 872.252 612 10109.5 10415 NCNT MAD CNTS 22556.6 43911.6 32414.3 612 10109.5 10415 RHOB MAD G/CM 2.26 2.885 2.47847 615 10124 10431 DRHO MAD G/CM 2.26 2.885 2.47847 615 10124 10431 RPD MAD OHMM 15.82 40.65 23.4416 623 10142 10453 RPM MAD OHMM 14.57 45.13 23.8665 623 10142 10453 RPS MAD OHMM 15.37 52.7 25.0588 623 10142 10453 RPX MAD OHMM 13.68 47.26 24.0562 623 10142 10453 FET MAD HOUR 77.72 108.486 86.3298 623 10142 10453 GR MAD API 50.01 576.47 90.8773 625 10134 10446 PEF MAD BARN 1.46 6.73 2.38218 615 10124 10431 RAT MAD FT/H 0.06 2165.64 90.1815 632 10196 10511.5 NPHI MAD PU-S 11.59 32.91 19.3859 612 10109.5 10415 First Reading For Entire File..........10109.5 Last Reading For Entire File...........10511.5 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: Page 7 ~ ~ 6-13apbl.tapx 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 4645.0 4882.0 ROP 4909.5 4938.0 LOG HEADER DATA DATE LOGGED: 12-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4938.0 TOP LOG INTERVAL (FT): 4909.0 BOTTOM LOG INTERVAL (FT): 4938.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4909.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 75.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 89.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Page 8 ~ ~ 6-13apbl.tapx 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 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4645 4938 4791.5 587 4645 4938 GR MWD030 API 12.27 82.92 47.0469 475 4645 4882 ROP MWD030 FT/H 0.34 57.55 13.9645 58 4909.5 4938 First Reading For Entire File..........4645 Last Reading For Entire File...........4938 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 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 GR 4882.5 7981.5 FET 4890.0 7974.0 RPX 4890.0 7974.0 RPS 4890.0 7974.0 RPD 4890.0 7974.0 RPM 4890.0 7974.0 Page 9 6-13apbl.tapx RoP 4938.5 8028.0 LOG HEADER DATA DATE LOGGED: 14-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8028.0 TOP LOG INTERVAL (FT): 4938.0 BOTTOM LOG INTERVAL (FT): 8028.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.3 MAXIMUM ANGLE: 32.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4909.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 55.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.850 71.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.150 118.0 MUD FILTRATE AT MT: 1.500 71.0 MUD CAKE AT MT: .820 71.0 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 ......... .. ... ..... Datum specification Block sub-type...0 Page 10 • i 6-13apbl.tapx Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MwD040 OHMM 4 1 68 16 5 FET MwD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MwD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4882.5 8028 6455.25 6292 4882.5 8028 RPD MWD040 OHMM 0.22 2000 8.35913 6169 4890 7974 RPM MWD040 OHMM 0.77 2000 4.62631 6169 4890 7974 RPS MWD040 OHMM 0.78 1823.28 4.06164 6169 4890 7974 RPX MWD040 OHMM 0.76 1823.2 3.52866 6169 4890 7974 FET MWD040 HOUR 0.27 23.43 1.078 6169 4890 7974 GR MwD040 API 10.17 186.24 85.3363 6199 4882.5 7981.5 ROP MWD040 FT/H 5.44 338.95 122.099 6180 4938.5 8028 First Reading For Entire File..........4882 Last Reading For Entire File...........8028 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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 FET 7974.5 9620.5 RPM 7974.5 9620.5 RPx 7974.5 9620.5 Page 11 ~ ~ 6-13apbl.tapx RPS 7974.5 9620.5 RPD 7974.5 9620.5 GR 7982.0 9628.5 ROP 8028.5 9675.0 LOG HEADER DATA DATE LOGGED: 18-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9675.0 TOP LOG INTERVAL (FT): 8028.0 BOTTOM LOG INTERVAL (FT): 9675.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.0 MAXIMUM ANGLE: 55.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4909.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 11.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1850 FLUID LOSS (C3): 3.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .855 81.0 MUD AT MAX CIRCULATING TERMPERATURE: .470 154.4 MUD FILTRATE AT MT: .702 81.0 MUD CAKE AT MT: 1.328 68.0 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 Page 12 ~ ~ 6-13apbl.tapx Depth Units. .. .. ..... Datum Specificat ion Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7974.5 9675 8824.75 3402 7974.5 9675 RPD MWD050 OHMM 0.67 8.07 3.23778 3293 7974.5 9620.5 RPM MwD050 OHMM 0.6 9.55 3.20756 3293 7974.5 9620.5 RPS MWD050 OHMM 0.63 8.74 2.87909 3293 7974.5 9620.5 RPX MWD050 OHMM 0.63 10.57 2.77762 3293 7974.5 9620.5 FET MwD050 HOUR 0.9 37.04 3.02456 3293 7974.5 9620.5 GR MWD050 API 62.73 430.32 164.904 3294 7982 9628.5 ROP MWD050 FT/H 0.63 230.37 45.9442 3294 8028.5 9675 First Reading For Entire File..........7974.5 Last Reading For Entire File...........9675 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........5T5LIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 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 Page 13 • i 6-13apbl.tapx RPS 9621.0 9952.5 RPM 9621.0 9952.5 RPx 9621.0 9952.5 FET 9621.0 9952.5 RPD 9621.0 9952.5 GR 9629.0 9960.5 OP 9675.5 10007.0 $ LOG HEADER DATA DATE LOGGED: 19-Nov-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10007.0 TOP LOG INTERVAL (FT): 9675.0 BOTTOM LOG INTERVAL (FT): 10007.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.7 MAXIMUM ANGLE: 59.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4909.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 11.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1600 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .860 81.0 MUD AT MAX CIRCULATING TERMPERATURE: .420 171.0 MUD FILTRATE AT MT: .700 81.0 MUD CAKE AT MT: 1.330 68.0 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 Logyin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Page 14 e 6-13apbl.tapx Frame Spacing.. ..... ............60 .lIN Max frames per record .............undefined Absent value ... ...................-999 Depth Units. .. .. ..... Datum Specifica tion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MwD060 OHMM 4 1 68 16 5 FET MwD060 HOUR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MwD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9621 10007 9814 773 9621 10007 RPD MWD060 OHMM 2.44 10.6 4.36364 664 9621 9952.5 RPM MwD060 OHMM 2.46 11.16 4.4448 664 9621 9952.5 RPS MWD060 OHMM 2.22 6.64 3.51083 664 9621 9952.5 RPX MWD060 OHMM 2.16 6.27 3.20373 664 9621 9952.5 FET MwD060 HOUR 0.72 23.49 4.87113 664 9621 9952.5 GR MWD060 API 75.42 156.78 129.828 664 9629 9960.5 ROP MWD060 FT/H 0.76 174.54 67.2928 664 9675.5 10007 First Reading For Entire File..........9621 Last Reading For Entire File...........10007 File Trailer Service name... .......STSLIB.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 Fiie Ty e ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 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 Page 15 ~ ~ 6-13apbl.tapx FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9953.0 10097.0 RPS 9953.0 10097.0 RPX 9953.0 10097.0 RPM 9953.0 10097.0 FET 9953.0 10097.0 GR 9961.0 10090.0 ROP 10007.5 10150.0 LOG HEADER DATA DATE LOGGED: 25-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10150.0 TOP LOG INTERVAL (FT): 10007.0 BOTTOM LOG INTERVAL (FT): 10150.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.7 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153883 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 51.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 7500 FLUID Loss (C3): 9.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT): .600 60.0 MUD AT MAX CIRCULATING TER MPERATURE: .340 111.0 MUD FILTRATE AT MT: .500 60.0 MUD CAKE AT MT: .750 58.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ........ ..0 Data specification Block Type... ..0 Page 16 ~ ~ 6-13apbl.tapx 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 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MwD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9953 10150 10051.5 395 9953 10150 RPD MWD070 OHMM 3.85. 2000 460.342 289 9953 10097 RPM MWD070 OHMM 0.44 2000 359.266 289 9953 10097 RPS MWD070 OHMM 1.27 1632.18 30.9247 289 9953 10097 RPX MWD070 OHMM 0.94 1547.68 19.6131 289 9953 10097 FET MWD070 HOUR 3.56 138.93 55.2945 289 9953 10097 GR MWD070 API 55.79 550.57 119.02 259 9961 10090 ROP MWD070 FT/H 0.47 85.13 19.0291 286 10007.5 10150 First Reading For Entire File..........9953 Last Reading For Entire File...........10150 File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.008 Physical EoF File Header Service name... .......STSLIB.008 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Page 17 • 6-13apbl.tapx curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FONT 10058.5 11177.5 NCNT 10058.5 11177.5 NPHI 10058.5 11177.5 DRHO 10073.0 11193.0 PEF 10073.0 11193.0 RHOB 10073.0 11193.0 GR 10090.5 11206.0 RPD 10097.5 11213.0 RPM 10097.5 11213.0 FET 10097.5 11213.0 RPx 10097.5 11213.0 RPS 10097.5 11213.0 OP 10150.5 11272.0 $ LOG HEADER DATA DATE LOGGED: 28-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11272.0 TOP LOG INTERVAL (FT): 10150.0 BOTTOM LOG INTERVAL (FT): 11272.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.6 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153883 CTN COMP THERMA L NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 48783 ALD Azimuthal L itho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (5): 50.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): .670 74.0 MUD AT MAX CIRCULATING TER MPERATURE: .500 100.4 MUD FILTRATE AT MT: .660 67.0 MUD CAKE AT MT: .630 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 18 6-13apbl.tapx 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 FCNT MWD080 CNTS 4 1 68 4 2 NCNT MWD080 CNTS 4 1 68 8 3 RHOB MWD080 G/CM 4 1 68 12 4 DRHO MWD080 G/CM 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 20 6 RPM MwD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MWD080 OHMM 4 1 68 32 9 FET MWD080 HOUR 4 1 68 36 10 GR MwD080 API 4 1 68 40 11 PEF MWD080 BARN 4 1 68 44 12 ROP MWD080 FT/H 4 1 68 48 13 NPHI MWD080 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10058.5 11272 10665.3 2428 10058.5 11272 FCNT MWD080 CNTS 224.97 2378.57 729.336 2239 10058.5 11177.5 NCNT MWD080 CNTS 18520.1 48043.1 29944.2 2239 10058.5 11177.5 RHOB MWD080 G/CM 2.109 3.378 2.51068 2241 10073 11193 DRHO MWD080 G/CM -0.236 1.124 0.0429027 2241 10073 11193 RPD MWD080 OHMM 6.23 51.85 25.4553 2232 10097.5 11213 RPM MwD080 OHMM 6.44 67.57 24.749 2232 10097.5 11213 RPS MWD080 OHMM 5.85 91.68 23.7315 2232 10097.5 11213 RPX MWD080 OHMM 5.45 76.33 20.6295 2232 10097.5 11213 FET MWD080 HOUR 0.87 24.85 3.42946 2232 10097.5 11213 GR MWD080 API 48.89 585.88 133.943 2232 10090.5 11206 PEF MWD080 BARN 1.55 9.72 2.90899 2241 10073 11193 ROP MWDO80 FT/H 0.62 365.47 58.5421 2244 10150.5 11272 NPHI MwD080 PU-s 8.62 40.92 22.0282 2239 10058.5 11177.5 First Reading For Entire File..........10058.5 Last Reading For Entire File...........11272 File Trailer Service name... .......STSLIB.008 service sub Level Name... Page 19 6-13apbl.tapx version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 8 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 10115.5 10421.0 FCNT 10115.5 10421.0 NPHI 10115.5 10421.0 PEF 10130.0 10437.0 RHOB 10130.0 10437.0 DRHO 10130.0 10437.0 GR 10140.0 10452.0 RPD 10148.0 10459.0 RPS 10148.0 10459.0 RPM 10148.0 10459.0 FET 10148.0 10459.0 RPX 10148.0 10459.0 RAT 10202.0 10517.5 LOG HEADER DATA DATE LOGGED: 28-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10517.5 TOP LOG INTERVAL (FT): 10058.5 BOTTOM LOG INTERVAL (FT): 10517.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.6 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153883 CTN COMP THERMAL NEUTRON 1844674407370955 Page 20 • • 6-13apbl.tapx EWR4 Electromag Resis. 4 48783 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10007.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 50.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .670 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .500 100.4 MUD FILTRATE AT MT: .660 67.0 MUD CAKE AT MT: .630 71.0 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. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD081 CNTS 4 1 68 4 2 NCNT MAD081 CNTS 4 1 68 8 3 RHOB MAD081 G/CM 4 1 68 12 4 DRHO MAD081 G/CM 4 1 68 16 5 RPD MAD081 OHMM 4 1 68 20 6 RPM MAD081 OHMM 4 1 68 24 7 RPS MAD081 OHMM 4 1 68 28 8 RPX MAD081 OHMM 4 1 68 32 9 FET MAD081 HOUR 4 1 68 36 10 GR MAD081 API 4 1 68 40 11 PEF MAD081 BARN 4 1 68 44 12 RAT MAD081 FT/H 4 1 68 48 13 NPHI MAD081 PU-S 4 1 68 52 14 First Last Page 21 6-13apbl.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10115.5 10517.5 10316.5 805 10115.5 10517.5 FONT MAD081 CNTS 332.11 1724.21 872.252 612 10115.5 10421 NCNT MAD081 CNTS 22556.6 43911.6 32414.3 612 10115.5 10421 RHOB MAD081 G/CM 2.26 2.885 2.47847 615 10130 10437 DRHO MAD081 G/CM 2.26 2.885 2.47847 615 10130 10437 RPD MAD081 OHMM 15.82 40.65 23.4416 623 10148 10459 RPM MAD081 OHMM 14.57 45.13 23.8665 623 10148 10459 RPS MAD081 OHMM 15.37 52.7 25.0588 623 10148 10459 RPX MAD081 OHMM 13.68 47.26 24.0562 623 10148 10459 FET MAD081 HOUR 77.72 108.486 86.3298 623 10148 10459 GR MAD081 API 50.01 576.47 90.8773 625 10140 10452 PEF MAD081 BARN 1.46 6.73 2.38218 615 10130 10437 RAT MAD081 FT/H 0.06 2165.64 90.1815 632 10202 10517.5 NPHI MADO81 PU-s 11.59 32.91 19.3859 612 10115.5 10421 First Reading For Entire File..........10115.5 Last Reading For Entire File...........10517.5 File Trailer Service name... .......STSLI6.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.010 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/21 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/04/21 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF writing Library. Writing Library. Page 22 scientific Technical services Scientific Technical services End Of LIS File 6-13apbl.tapx Page 23 •