The URL can be used to link to this page

Home My WebLink About204-225 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scannÎng 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. ~O y.. - d...:)..S Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 REJ'AN ~ ;S>lor Items: \Ø' Greyscale Items: DIGITAL DATA ~skettes, No. I D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Dale 1/3t/Q7 D Other:: BY: ~ 151 mf Project Proofing 11111111I111111111I BY: ~ Dale I /3//07 ~ x 30 = 100 Date: 0 151 me Scanning Preparation + BY: 11111111111111 "III Production Scanning Stage 1 Page Count from Scanned File: 7.s (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES BY ~ Date 1/31 107 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 V\1P NO BY: Maria Date: 151 11/11111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned III II 111I11111 "III BY: Maria Date: 151 Comments about this file: Quality Checked III "111111I" 1111I 1 0/6/2005 Well History File Cover Page.doc UNDER EVALUATION: Producer 114A (PTD #2042250) Sustained IA Case Pressure Abo... Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com) 7f/4(i Sent: Wednesday, July 13, 2011 9:48 PM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Producer 11 -06A (PTD #2042250) Sustained IA Casing Pressure Above MOASP Hi Jim, On 6/26/2011 the Drillsite Operator found the IA pressure at 2000 psi during his daily wellhead pressure readings and called the pressure into the Well Integrity Engineer. On 6/27/2011, a Downhole Diagnostics technician was sent out to the well to monitor and bleed the annulus pressure. A calibrated gauge was put on the well at that time and IA pressure was found to be 2180 psi confirming sustained casing pressure above MOASP. Prior to leaving location, the Downhole Diagnostics technician bled the IA ✓" pressure down to 1000 psi. Please let me know if you have any further questions. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator UL 1 ti 201'1 BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, July 11, 2011 4:47 PM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer 11 -06A (PTD #2042250) Sustained IA Casing Pressure Above MOASP Please clarify when IA pressure exceeded 2000psi Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, June 29, 2011 4 :41 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bommarito, Olivia 0 Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 11 -06A (PTD #2042250) Sustained IA Casing Pressure Above MOASP 7/14/2011 UNDER EVALUATION: Producer 114A (PTD #2042250) Sustained IA CasoPressure Abo... Page 2 of 2 All, Producer 11 -06A (PTD #2042250) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA /OOA equal to SSV/2180/200/200 on 6/27/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: TIFL once well is online 2. WIE: Evaluate for gas lift valve changeout. A TIO plot and wellbore schematic have been included for reference. «Producer 11 -06A (PTD # 2042250) TIO Plot.doc» «Producer 11 -06A (PTD # 2042250) wellbore schematic.pdf» 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 7/14/2011 OPERABLE: Producer 11 - 06A (PTD 4042250) Passing TIFL - Verified tubinItegrity Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, July 08, 2011 9:24 AM I �� fi To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bommarito, Olivia 0 Cc: Clingingsmith, Mike J (Swift); Walker, Greg (D &C) Subject: OPERABLE: Producer 11 -06A (PTD #2042250) Passing TIFL - Verified tubing integrity All, Producer 11 -06A (PTD #2042250) passed a TIFL on 07/07/11 after the IA pressure was reported to have sustained casing pressure. The passing test verifies tubing integrity. The well has been reclassified as ✓ Operable and may continue on production. Thank you, Torin Roschinger (filling in for Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, June 29, 2011 4:41 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bommarito, Olivia 0 Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 11 -06A (PTD #2042250) Sustained IA Casing Pressure Above MOASP All, Producer 11 -06A (PTD #2042250) has confirl. - • • - • IA casin• •ressure above MOASP. The wellhead pressures were tubing /IA/OA/OOA equal to SSV/2180/200/200 on 6 011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: TIFL once well is online 2. WIE: Evaluate for gas lift valve changeout. 7/12/2011 OPERABLE: Producer 11 -06A (PTD #2042250) Passing TIFL - Verified tubin tegrity Page 2 of 2 A TIO plot and wellbore schematic have be included for reference. « File: Producer 11 -06A (PTD # 2042250) TIO Plot.doc » 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 7/12/2011 PBU 11 -06A PTD # 2042250 6/29/2011 TIO Pressures Plot Well: 11 -o6/r 4.000 • :3,0IJ0 —— Tbg —�- IA 2,000 -A— OA �• •�••�� 00A 000A —0n 1,000 04/09/11 04/23/11 05/07/11 05/21/11 06/04/11 06/18/11 TREE = FMC GEN 2 WELLHEAD = CILV? SAFETY NO: * * *4 -1/2" CHROME TBG* ** ACTUATOR = BAKER C 11 - ®6 A KB. ELEV = 62' iii BF. ELEV = 31' KOP = -__.w 3200' 14 6 V 14 _ Max Angle T @ 10878' ► � 1.4 2067' H4 -112" HES X NIP, ID = 3.813" Datum MD = 10817' r� 1• Datum TV D - 8700 SS 6, 6 04 1.4, GAS LIFT MANDRELS 4 -1/2" TBG, 12.6 #, 13CR80 , .0152 bpf, ID = 3.958" I- 1029' 14 . ST MD TVD DEV TYPE VLV LATCH PORT DATE al 1 .' V 4 3471 3460 19 KBG-2-1R DOME BK 16 08/04/07 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2515' } �" y + +' 3 6057 5591 47 KBG -2 -1R DOME BK 16 08/04/07 17" TIEBACK CSG, 26 #, L -80 TCII, ID = 6.276" 2768' A 1� / ' 2 7952 6889 44 KBG -2 -1R DOME BK 16 08/04/07 1 ' �i 1 _9037 7690 42 KBG-2-1R SO BK _ 24 07/31/09 7" TIEBACK CSG, 26 #, L -80 BTC, ID = 6.276" I 5992' ■, 5986' 7" BKR SEAL ASSY, ID = 6.276" I TOP OF 7" SCAB LNR H 5983' i' 1 i f ' 5983' BAKER ZXP PKR u 4P- z 1∎ ►i S ' �� ►� 9074' 1--14 -1/2" HES X NIP, ID = 3.813" 41 �A 9104' H7" x 4-1/2" BKR S -3 PKR, ID = 3.830" I 1! •2 9138' J-- I4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, HY2CR95 VAM 9209' �� •!�� 9203' J --I TBG STUB (01/25/06) TOP , .0152 bpf, ID = 3.958" /. * ` * P. 9209' 7" X 4 -1/2" UNIQUE MACHINE OVERSHOT I , � 1 �� 9243' H7" X 4 -1/2" BAKER S -3 PKR, ID = 3.875" I Minimum ID =1.92" @ 932$" ∎! ig I 9308' H4 -1/2" HES X NIP, ID = 3.813" I 3 -1/2" X 2-3/8" XO .1 ,... _, - ■• 11 4 , 9322' 4.4 "'9322' H TOP OF CMT (2 -3/8 LNR) H3.70" BKR DEPLOY SLV, ID = 3.00" (12/28/04) I 0 r / 0 ' , I 9328' H3-1/2" X 2 -3/8" XO, ID = 1.92" I I. 16 4 14 9340' H3.70" DEPLOYMENT SLV (BEHIND PIPE) I 4 -1/2" TBG, 12.6 #, 13 - R, .0152 bpf, ID = 3.958" I- 9369' ry bi 9369' I- I4 -1/2" UNIQUE OVERSHOT (BEHIND PIPE) c . F 4 ors 9406' H7" X 4 -112" BAKER S -3 PKR (BEHIND PIPE) I 1 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9441' '' , 4 14 6 � N 7" LNR- TIEBACK, 29 #, L -80, .0371 bpf, ID = 6.184" H 9525' I 6 r L 9524' H 7" BAKER LNR HGR (BEHIND PIPE) 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I- 9849' 4 p.44 1 4 1 'ffl 9700' I-I CALC TOP OF CEMENT (BEHIND PIPE) I a. WFD WHIPSTOCK & ANCHOR (11/23104 10068' „ 4 1 IRA TAG I-I 100 . �t4 ! I3 -1/2" LNR, 9.3 #, 13CR80 (01/27/04), ID = 2.992" I- 10371' � .4 v. MILLOUT WINDOW (11 -06A) 10067' - 10073' ••• i • PERFORATION SUMMARY eft # REF LOG: ?' ?? BHCS ON 01/22/82 ? ?? 0.j . + +• ANGLE AT TOP PERF: 81 @ 10780' 0.4+0 Note: Refer to Production DB for historical perf data l Oi ` t�11�1 : SIZE SPF INTERVAL Opn /Sqz DATE Af + iAA• � a l 1- 9/16" 6 10780 - 10800 0 02/13/05 ` 1- 9/16" 6 10830 - 10850 0 02/13/05 'frfct� ♦l " 1- 9/16" 6 10880 - 10900 0 02/13/05 .�.�.1�� * +�� 1- 9/16" 6 10986 - 11120 0 12/28/04 � + 1- 9/16" 6 11142 - 11254 0 12/28/04 1- 9/16" 6 11284 - 11374 0 12/28/04 7" LNR, 29 #, L -80 H 10557' I 1- 9/16" 6 11470 - 11490 0 12/28/04 1- 9/16" 6 11520 - 11530 0 12/28/04 1- 9/16" 6 11606 - 11634 0 12/28/04 IPBTDH 11684' <r. 1- 9/16" 6 11650 - 11665 0 12/28/04 2 -3/8" LNR, 4.7 #, L -80, .0039 bpf, ID = 1.995" I-i 11720' I DATE REV BY _ COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/30/82 ORIGINAL COMPLETION 05/21/06 DAC /TLH DRLG DRAFT CORRECTIONS WELL: 11 -06A 08/28/97 RWO 06/05/06 KSB /PAG GLV C/O PERMIT No: 2042250 12/31/01 DAC /KK RWO 08/07/07 SWC /SV GLV C/O API No: 50- 029 - 20674 -01 01/24/04 JAF/TLP CTU #9 LNR 09/09/09 CJN /TLH GLV C/O (07/31/09) SEC 33, T11 N, R15E, 3977.22' FEL & 3381.92' FNL 12/28/04 DH CTD SIDETRACK (11 -06A) 05/09/06 D16 RWO _ _ BP Exploration (Alaska) . • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 " Anchorage, Alaska 99519 -6612 December 21, 2010 .ac Mr. Tom Maunder ,a N :i : Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ��'� r?b' x^ < Fors. lion Anchorage, Alaska 99501 Of fl .- Subject: Corrosion Inhibitor Treatments of GPB DS 11 © - Dear Mr. Maunder, ' ! 06 A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12 /21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 r ) 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 _ NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000_ NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 OPERABLE: 11-06A (PTD #20~ 50) Tubing integrity restored O Page 1 of 2 -~ Schwartz, Guy L (DOA) ~ 3 From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, August 03, 2009 1:19 PM To: Regg, James B(DOA); Maunder, 7homas E(DOA); Schwartz, Guy L(DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Chiwis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABL~: 11-06A (PTD #2042250) Tubing integrity restored a~~, Well 11-06A (PTD #2042250) passed a TIFL after changing out the orifice gas lift valve proving tubing integrity has been restored. The well has been reclassified as Operable. Please let us know if you have any questions, Thank you, Anna ~u6e, ~.~. (alt Torin Roschinger) Wetl Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 , ~, yr~ 4 •. x,r .~'sl+~t~~§~,'~ r ~-=tj~~~ . c'.~,11~:~ Fram: NSU, ADW Well Integrity Engineer Sent: Tuesday, July 28, 2009 3:03 PM To: 'jim.regg~lalaska.gov'; 'tom.maunder@alaska.gov'; 'Schwartz, Guy l(DOA)'; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FSS/2/COTU/5eawater); NSU, ADW Well Qperations Supervisor; Engel, Harry R; 6P6, Wells Opt Eng; GPB, EOC Specialists Cc: Chiwis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subgect: UIVDER EVALUATION: 11-06A (PTp #2042250) TxIA Communication All, Well 11-06A (PTD #2042250) has been found with sustained casing pressure on the IA. TMe TIOs were 2360/2160/210118~ psi on 07/26/09 and a subsequent TIFL failed. The well has been classified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: T1FL - FAILED 2. S: Change out OGLV 3. D: Re-TIFL A TIO Plot and wellbore schematic have been provided for reference. « File: 11-06A TIO Plot.doc» « File: 11-06A.pdf» Please call with any questions or concems. Thank you, 8/3/2Q09 OPERABLE: 11-06A (PTD #20~ 50) Tubing integrity restored • Page 2 of 2 ?'orin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 CeA (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/3/2009 . 11-06A (PTD #2042250) TIO Plot • ........................................ ........ . ................ 3,0~1 ~- Tbg ^ IA 2,000 ~ ^ -~- OA ~ ~ ^ ~ ~ ^ '~ OOA ~ ~ ~ i~' OOOA 1,000 ~~ _~ - - ~ ~~ ~ ~ ~~ ~ ~ On TREE = FMC GEN 2 WELLHEAD = CM/? ACTUATOR= BAKERC KB. ElEV - 62 BF. ElEV = - 31~ KOP = 3200' Max Angle = 93 @ 10878' Datum !v~ = 10817' Datum ND = 8700' SS 4-1/2" TBG, 12.6#, 13CR80 ,.0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 7" TIEBACK CSG, 26#, L-80 TGI, ID = 6.276" ~ 7" TIEBACK CSG, 26#, L-80 BTC, ID = 6.276" ~ TOP OF 7" SCAB LNR I-~ 4-1/2" TBG, 12.6#, HY2CR95 VAM TOP , .0152 bpf, ID = 3.958" ~ 1029' 2515' 2768' 5992' 5983' I 9209' 1 Minimum ID =1.92" @ 9328" 3-1 /2" X 2-3/8" XO 4-1l2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" H 9369' SAFE~OTES: "*"4-1/2° CHROME TBG*** 11-0 6A AFE 2067' H4-1/2" HES X NIP, ID = 3.813" GAS LIFf MANDRFI.S ST MD ND DEY TYPE VlV LATCH PORT DATE 4 3471 3460 19 KBG2-1 R DOME BK 16 08/04/07 3 6057 5591 47 KBG-2-1R DOME BK 16 08/04/07 2 79b2 6889 44 KBG2-1 R DOME BK 16 08/04/07 1 9037 7690 42 KBG-2-1 R SO BK 24 OSl04107 5986' 7" BKR SEAL ASSY, ID = 6.276" 5983' BAKER ZXP PKR 9074' 4-1/2" HES X NIP, ID = 3.813" 9104' 7" x 4-112" BKR S-3 PKR, ID = 3.830" 9138' 4-1/2" HES X NIP, ~= 3.813" 9203' - ~G STUB (01/25/06) 9209' 7" X 4-1i2" UNIQUE fviACHINE OVERSHOT 9243' 7" X 4-1 /2" BAKER S-3 PKR, ~= 3.875" 9308' 4-1 /2" HES X NIP, ID = 3.81~ ~9322' TOP OF CMf (2-3/8 LNR) 9322' 3.70" BKR DEPLOY SLV, ID = 3.00" (12l281( 9328' 3-1/2" X 2-3l8" XO, ID = 1.92"~ 9340' 3.70" DEPLOYMENT SLV (BEHIND PIP~ 9369' 4-1/2"UNIQUEOVERSHOT (661INDPIPE~ 9406' 7" X 4-1l2" BAKER S-3 PKR (B~iiND PIPE~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" LNR-TIEBACK, 29#, L-80, .0371 bpf, ID = 6.184" 9-5/8" CSG, 47#, L-80, ID = 8.681" WFD WHIPSTOCK & ANCHOR (11l23/04) R,4 TA G 3-1/2" LNR, 9.3#, 13CR80 (01127/04), ID=2.992" ~ 9441' ~ 9525' 9849' 10068' 10072' 10371' PERFORATION SUMMARY REF LOG; '?:''7 BHCS ON Q1/22/82 ??? A NGLE AT TOP PERF: 81 @ 10780' Note: Refer to Production DB for historical perf data SIZE SPF ~VVTERVAL Opn/Sqz DATE 1-9/16" 6 10780 - 10800 O 02/13/05 1-9l16" 6 1083~ - 10850 O 02/13/05 1-9l16" 6 10880 - 10900 O 02/13/05 1-9l16" 6 10986 - 11120 O 12l28/04 9-9/i6" 6 14142-49254 O 12l28/04 1-9/16" 6 11284 - 11374 O 12I28/04 1-9/16" 6 11470 - 11490 O 12/28/04 1-9/16" 6 11520 - 11530 O 12/28/04 1-9/16" 6 11606 - 11634 O 12/28/04 1-9/16" 6 11650 - 11665 O 12/28/04 9524' -~7" BAKER LNR HGR (B~i1ND PIP~ 9700' CALG TOP OF CE7VIENT (BOiIND Pll MILLOUT WINDOW (11-06A) 10067' -10073' PBTD 11684' 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" 11720' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/30/82 ORIGINAL COAAPIETiON 05/21/06 DAGTLH DRLG DRAFT CARRECTIONS 08/28/97 RWO 06l05/06 KSB/PAG GLV C/O 12l31101 DAC/KK RWO 08/07/07 SWGSV GLV GO 01/24/04 JAF/TLP CTU #9 LNR 12l28/04 DH CTD SIDETRACK (11-O6A) OS/09I06 D16 RVUO 7° LNR 29#, L-80 t-~{ 9 0557' PRUDHOE BAY UNtT WELL: 11-06A PERMff No: R1042250 API No: 50-029-20674-01 SEC 33, T11 N, R15E, 3977.22' FE1 & 3381.92' FNL BP Exploretion (Alaska) • • ~~: ;~ _ . MICROFILMED 03/01/20x8 DO NOT PLACE ~~- ~ ~~ •. ~. ANY NEW MATERIAL UNDER THtS PAGE F:1LaserFiche\CvrPgs_Inserts~Miicrofilm Marker.rbc )... ì J rvv.. ,t ~ tI 7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042250 Well Name/No. PRUDHOE BAY UNIT 11-06A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20674-01-00 MD 11720 TVD 8780 Completion Date 12/27/2004 Completion Status 1-01L Current Status 1-01L UIC N ~...~~_._---~-,.._-~-----"---,.~-~_.~-~-~----- ~""------'._."-----~-'--'-----~--'--------_.~--- ----'.---. --"'-~--~-"'-'-------------~ - -~----~_."~---~-"~~-.~~".~-----------~---~--- ---------"'----._-~---,.--~-~--------~-_._._--------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -~-,-~._~-~~~._~,~-".~-._--_._----,-,--~._---_.~ ._-~-~----~-----_.- ~-"~~.'--- -~._-,~,--_._~--- ___________________._________ .__~__"M._ .~-,----------_._--_._--- DATA INFORMATION Types Electric or Other Logs Run: MWD / GR / ROP, Memory Induction, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type ~ F D Li, ~ C Lis ~ ~b C J:: I IC8 0 rei!!! t8§ Electr Digital Dataset Med/Frmt Number D Asc Name Directional Survey Log Log Run Scale Media No Interval OH/ . Start Stop CH Received Comments 10000 11720 1/27/2005 IIFR l 9852 11696 Open 7/7/2005 GR ROP 9187 11673 Case 1/19/2005 COMPENSATED I NEUTRON, MEMROY GR, i CCL, CNL I 13208 Gamma Ray Neutron 5 Blu 13202 Induction/Resistivity 13202 Induction/Resistivity 13208 LIS Verification 13462 Neutron \ I I I i I 4-5, 7-8 10067 11720 5/10/2006 ROP NGP 14-Dec-2004 I 4-5,7-8 10067 11720 5/10/2006 NGP 14-Dec-2004 : ..____ ._>~~~_1 0088 Ope~!10/20~ GR, ROP ._______1 9650 11720 7/14/2005 11720 Open Open Open 7/14/2005 25 Blu 9650 9852 9197 11696 7/7/2005 1/17/2006 GR ROP 11680 GRCH-CNT 13..ee tJ¿tJtlðl, w",~~.~dA -> 4' 311661.1.83:5 1;IMð6ð . MEMô~',' er~L 114 eÄRRICR ME:M LCC "-:ODl,/QI J L . >1:¡~'>-Þ'J8Ii1trel'l \)J'-'..~ (~(..,\, £..Dlt.- 3,88 11835 1/17Æ8eG MCMORY Ol4tfN 'OARRIC¡:tMCM LCC ~~é)CL'or4L . ~L ~ ::j:::~ ~::::;::::;:: ~ _ _ _ _ Well Cores/Samples Information: - ----"'.".-------., ---- Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2042250 MD 11720 TVD 8780 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? 'y I N - Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. PRUDHOE BAY UNIT 11-0GA Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20674-01-00 Completion Date 12/27/2004 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? ~N E:P/N Formation Tops Comments: ~"-----_." ---------" Compliance Reviewed By: ----~~======-----=--~---=----~ ~ :r¢ - ~ ----=-~--= Date: -- _ --~ ~ 'I . . . . SARAH PALIN, GOVERNOR ALA.5 KA, () [L A~'\J D G "-\5 CON5ERVA TION COl\ILV1I5S10N jjJ \\.7'" -\VE:\LE, SLlTE IUU -\.'I,CHOR-\G£.\LASIC\ 99501-3539 PH(}'I,E (90") P9-1~J3 F\X (907) 2'6-75423 December 8, 2006 CERTIFIED MAIL - RETURN RECEIPT REQUESTED 7005 1160 0001 5753 9471 Mr. Bruce J. Williams GPB Maintenance and Reliability Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~ MA'f 1 6 2001 Subject: Defeated SVS at PBU 11-06A Dear Mr. Williams: .. ..j,. " ~.' ~,~,...,~...."':"-.J.""'" .. The Alaska Oil and Gas Conservation Commission has received and reviewed the explanation ÍÌ"om BP Exploration Alaska, Inc. ("BPXA") regarding the defeated surface safety valve ("SSV") on Prudhoe Bay Unit Well 1l-06A. That explanation was provided to the Commission's letter dated November 2, 2006 and provides an overview of corrective actions that will be implemented to prevent this scenario from recurring. One of the actions items identified by BPXA is an audit of all Greater Prudhoe Bay drill sites and well pads leading to a plan that will complete the ongoing effort to change-out needle valves on well safety valve systems to quarter turn valves. The Commission appreciates BPXA's commitment to eliminate the occurrence of defeated safety valve systems through this tangible and practical effort. The results of BPXA' s audit and the schedule to complete the installation of quarter turn valves should be provided to the Commission by April 2007. The Commission is satisfied with BPXA's response to this violation and does not intend to pursue enforcement action regarding the Prudhoe Bay Unit 11-06A defeated surface safety valve. Sincerely, C&4zhup p¿~ aL Y f r ut=rSlt::r Commissioner cc: AOGCC Inspectors (via email) do'/-¿)&6- . . .- SARAH PALIN, GOVERNOR AlASKA. OIL AND GAS CONSERVATION COlVIl\HSSION 33J W. 7" A VE'IlE, SLITE 100 \'ICHOR-\GE, .\LASKA 99501-3539 PHOI\E (907) 279-1433 FAX (907) ! 76- 75423 December 8, 2006 Mr. Bruce 1. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P_G. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Williams: Attached please find the September 2006 Facility Report of Produced Gas Disposition, Form 10- 422 ("Gas Disposition Report") for the Lisburne Production Center ("LPC"). BP Exploration (Alaska) Inc. ("BPXA") provided the Gas Disposition Report signed October 18, 2006. The Commission has classified as waste 8,132 Mcf of gas, the volume vented and flared as a result of a leak on the high-pressure gas reinjection line within the Lisburne L2 manifold building. This leak resulted in the shut down of the LPC ÍÌ"om September 28 until restart September 30, 2006. The volume is listed on the Gas Disposition Report as flared or vented more than 1 hour. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, /. ~oer~ E~~rl~ner Attachment Department of Revenue 550 W. 7lh Avenue ,~chorage,AJ( 99501 Attention: Rodney Stevens (Suite 500) Attention: Jim Stouffer (Suite 800) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACiliTY REPORT OF PRODUCED GAS DISPOSITION I l'dCllily l~lIllIli,,' 1~;~c~:~~:7~NE PROD (GPMA) 3. Field I; Ope r¡>l0I I~ Month/Yeal 01 DlspO"'llol\ 0290000009 PBU - GPMA BP September -2006 Disposition Volume MCF 20 For production from multiple pools, list contribution of each pool as a pel celli of -- Total Volume G Sú!u 85,466 Pool Name Pool Code Percent Reo lectl:~U 7,159,937 Ltsburne 640144 42.3% 7 Niakuk & West Niakuk 640148 1.2% r Idled ù¡ vented \ 11UU1 Uf ft:~~ 488 North Prudhoe Bay State 640152 0.0% tJ PI. Mcintyre 640180 54.9% f':ldll~d UI v8r1kU ¡HUll; Old!] 1 huUt (::>8t: Il\stl) 8,132 Raven - Ivishak-Sag River 640147 1.6% ~ West Beach 640186 0.0% f----~- IU ¡..JIIIH .jlìl! f-'urYL- 12,579 11 U~;-::lI hJ¡ ItdSf.: l)µe¿;.tllu'l~ (specìy 111 F~elnarks) 779,811 12 01l1t-:1 (~t:e IIlSIIULIIUf!::i) 760,146 ,)'"" " ~ Authorization> 1 hr MCF Safely 13 TOTAL VOLUME (ITEMS 6-12) 8,806,559 MCF Lease Use 14 r~UI Cia,; Equlvalellt 85,466 Conservation MCF 1~ Purclrds"d UdS 0 Waste Sr~, ¡ -:;,¿- MCF It.> !¡dllSlturt:(1l1ulIl 2,261,910 I()jtA"Îf:~1.L~__ /2 ~S-fk; -- 0 Dale II rldlJSlel'll-:O to (Fxpn:1:-";::; dS éJ negative If) em' IU H<::JJldlhs Block II 1-:",,1 Cas ~ 0-10,1130 IIISLI "lid Assist Gas ~ tOi), I ~ I mscl; Bluck 12 LJlI Gas UII Field; L3lock 16 Ml alllJ Fuel Cas h0W Pmdhu" 1----. Illeleliy [erlily Uì~üreUUrlrg IS tl~" :;¿:zct 10Ule liesl orlJlY kllowledge Manager, State Produclion Taxe~ Note: All volumes must be Srglldlure J /:7~7 ~/ rltle and Royalty corrected to pressure of 14.65 psia i / I ( /í)-/f -')~J and to a temperature of 600 F. !-'llIrted Ndl"e ~nard W. t-Iany PlrOlle (907)564-5U20 Dalto Authoritv 20 AAC25.235. F ürm 10-422 Fiev 1/2004 Submit If\ Duµl¡cale . ,JC~j!- . DATIE TIME VOLUME (MSCF) ~/171?()UIj ()/:jt>l~O~mJ 466 Total Ftare ,= I Hour 46b ~/¿~/¿OUü 'JiJOI?OOb O~:.J~ 1 ¿::>b o:n¿·?O~)j b,~2b b~4 BP EXPLORATION ALASKA, INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY, LISBURNE LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE 22E036SDV failed 10 open Unplanned Inslrurnenlalion repaired Ihe problem lmeryel\cy s/\uldown due to yas release at dnll Site L;) Planl resIart after emergency shutdown Unplalllled Unplanned DeplessUled RGllllle Proceed with startup . Total Flare> J Hour /,620 Volume Flared 8,086 . IVleasured Safety Pilot 11,909 Continuous Assist 103,119 TOTAL FLARED 123,114 DATE TIME 0/111:'000 08:) 1 -0909 VOLUME (MSCF) o Tolal Flare <= 1 Hour 0 U!J/¿9/0() 0\.J/3UiUU O!;)t>!;) 12t>U 0332205:1 Volume Flared Tolal Flale ;. 1 Hour 0 -- Measured Safety Pilot Continuous Assist TOTAL FLARED BP EXPLORATION ALASKA, INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY, POINT MCINTYRE LISBURNE PRODUCTION CENTER GAS flARING INCIDENTS Sep-06 DESCRIPTION OF INCIDENTS & CAUSE 22E036SDV failed to open o o Emergency stlUldown due to gas release at dllll site 1_:) Plant restart after emergency shutdown o o o o PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE Ullplanned Unµlanned Unplanned InSliumentalion repalled the problem . Depressured RGllllle Proæed with startup . DATE TIME 0/1 / ;:!(JU(j U8S 1 ·U90!) VOLUME (MSCF) U T,otal Flare <~ 1 HoUl 0 UU/2!3/00 o (J/:J 0100 08S81 ¿,S0 03:32-205:3 -- V olullle Flared lolal Flale;.. HoUl 0 Measured Safely Pilot Continuous Assist TOTAL FLARED -- BP EXPLORATION ALASKA,INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY. WEST BEACH LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DESCRIPTION OF INCIDENTS & CAUSE 22E036SDV failed to open o U Elllergellcy sllutdown due to gas release al drill Slle L-{, Plant restart at1er emergency shutdown o o o o PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE Unplanned Ullplanned Unplanned IlIstJurnematioll repaired tile problelll DepressUled RGIIII1è Proceed with startup . . BP EXPLORATION ALASKA, lNG, CONSERVATION ORDER NO. 219 PRUDHOE BAY, NORTH PRUDHOE BAY LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DATE TIME VOLUME (MSCF) DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE ~J 1 71200b OtJ51 -0909 o 22E036SDV failed to open Unplanned Instrumentation leJalred the probkm . Total Flare <=- HoUl 0 09/2\)/00 OW:.JO/Otj 0~tJ~12:"(j 0332-2053 lJ o Emergency shuldown due 10 gas release at drill Sit" L2 Plant restart after emergency shutdown Ullplanlled Unplanned DeJressured RGI line Ploœed with startuJ rolal Flare> 1 HoUl 0 Volume Flared 0 . IVJeasured Safety Pilot 0 Continuous Assist 0 TOT At FLARED 0 DATE TIME VOLUME (Mscf) 9/17/2006 Ol:Jb1-0909 4 -- Toral Flare <-" HoUl 4 --- U81¿810b 09/JU/U0 08:'>9-1 ¿b6 Ujj¿:¿05J tJ9 o BP EXPLORATION ALASKA, INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY, NIAKUK LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE 22E036SDV failed 10 open Unplanned Instrumentallon repaired tile problelll . Depre5sured RGIII"'" Ploceed with 51anup Tolal Flare> 1 HoUl 59 Volunu! Flared 63 . Measured Safety Pilot 122 Continuous Assist 1,165 TOTAL FLARED 1,350 t::fllelgellCY stlutdown due to gas release at dllll site L~¡ Plant res Ian ¡¡tter emergency shutdown UnplWllled Unplanned DATE VOLUME (Mset) TIME 9117/2006 OtJ", 1 ·0909 6 ---- h)lal Flale <= 1 HoUl ô --- 091;!WOb 09130/0b 09L>91;!",b 03322053 73 o BP EXPLORATION ALASKA, INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY, WESTERN NIAKUK LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DESCRIPTION OF INCIDI::NTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE 22E036SDV faded to open Unplanned Instrumentation repaired the problem I:::lnelyency shutdown due 10 gas release at dnl! site L-¿ Plan 1 restart atler emergency shutdown Unplalllled Unplanned . Depressured RGllllle Proceeli Wlttl startup Tolal Flare;. 1 HoUl f3 Volume Flared 79 . Measured Safety Pilot 151 Continuous Assist 1,426 TOT AL FLARED 1,656 DATE VOLUME (Mscf) TIME !J1l//200li ÚI:Jto 109ü!J 12 Tolal Flare <= Hour 12 09/29/06 09/JO/06 OYS9-125li 0332-2053 380 o BP EXPLORATION ALASKA, INC, CONSERVATION ORDER NO. 219 PRUDHOE BAY, RAVEN LISBURNE PRODUCTION CENTER GAS FLARING INCIDENTS Sep-06 DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE 22EOJGSDV failed to open Unplanned Instrumentation repaired the problem . Depressured RGlline Proceed with startup fotal flare? 1 HoUl JlJu Volume Flared 392 . Measured Safety Pilot 397 Continuous Assist 3,471 TOTAL FLARED 4,260 Emergency shutdown due to gas release at drill site L-¿ Plant restart after emergency shutdown Unplanned Unplanned . . REPORT NO: 06-0556 BPXA FLARE REPORT PRUDHOE BAY FACiliTY: lPC DATE: 29 Sep 2006 SYSTEM 1. Other TIME OF FLARING Start Stop Duration Intermittent 09:59 12:56 2Hrs 57Mins _~ Black Smoke Planned VOLUME ~1 7tf;~. MSCF TOTAL VOLUME 1t.}-;g. MSCF First Determination of Cause: 1. emerency shutdown due to gas release at driil site L-2 Action Taken to Stop Flaring: 1 Oepressured RGI line 'N ",rj"escJa,/ Octot::er 18 2006 Page 1 Df 1 . . REPORT NO: 06-0561 :....,..,. )0.,/ ~,.< «§§$1t' , .'*""..............:.'...,..................... . .'. ~:.:\,. . -'$""'" ~~~% BPXA FLARE REPORT PRUDHOE SAY FACILITY: LPC DATE: 30 Sep 2006 TIME OF FLARING Slack SYSTEM Start Stop Duration ! ntermittent Smoke Planned VOLUME Flare/Relief Valve 03:32 03:33 o Hrs 1 f'v1ins 4 MSCF 2 Flare/Relief Valve 03:48 03'49 o Hrs 1 tv1ins 23 MSCF 3 Flare/Relief Valve 16:26 16:27 o Hrs 1 rv11ns 10 MSCF 4 Flare/Relief Valve 1636 1637 o Hrs 1 Mins 7 MSCF 5 Flare/Relief Valve 1819 1820 o Hrs 1 Mins 13 MSCF Ô Flare/Relief Valve 1824 18.35 o Hrs 11 ",1ins 98 MSCF 7 Flare/Relief Valve 1838 1841 o Hr3 3 Îv1in3 5 iv1SCF 8 Flare/Relief Valve 1843 1851 o Hrs 8 Mins 10 MSCF 9 Flare/Relief Valve 1853 2002 1 Hrs 9 Mins 129 MSCF 10 Flare/Relief Valve 2045 2053 o Hrs 8 tv1in3 395 MSCF TOT AL VOLUME 694 MSCF First Determination of Cause: Plant Restart after an ESD 2 Plant Restart after an ESD 3 Restart Plant after an ESD 4 Restart Plant after an ESD 5 Restart Plant after an ESD 6 Restart Plant after an ESD i Restart Plant after an ESD 3 Restart Plant after an ESD 9 Restart Plant after an ESD \L~.~ "l;~ :}-:::[~-::<>.?! :=2 2:JrJ~~ :::>3]e 1 of 2 ~~~ :!;d. d''* ~~iq~~~ FACILITY: lPC . . REPORT NO: 06-0561 BPXA FLARE REPORT PRUDHOE ¡BAY DATE: 30 Sep 2006 Action Taken to Stop Flaring: 1 Proceed with start-up. 2 Proceed with Start-up 3 Proceed with Start-up 4 Proceed with Start-up S Proceed with Start-up 6 Proceed with Start-up 7 Proceed with Start-up 8 Proceed with Start-up. 9. Proceed with Start-up, _..<:;J::::'1~( ?I,--':¡'~ P a:J>:::? 2 ¡ ~ .. Subject: GPB Gas Flaring Incident From: "GPB, Prod Opt '1'L" <GPBProdOptTL@BP.com> Date: Sat, 30 Sep 2006 09:31 :43 -0800 To: "steve__mcmaìns@admin,state,(Û{.µsll <lstev~......~~p+~Jri~@ª' Environ Advisor East" <GPBE~yìrBn1\.dvi$() <Gary.Benson@BP,com>, "Pfeiffer,Jirn N' "john.kurzca~BP .com> .. #î~.state,ak.us'>, "GPB, Environ TV' <GPBEnvironTL@BP.com>, "OPB, ler,Anne M" <Anne.Fiedler@13P.C0l11>,"~ensQn¡ Gary A" ;éomÞ, I'GPB, GPMAArt:aMgr"<GPI3GPMATL@BP,co1h>, "Kurz, John" 10 Steve McMains /\OGCC steve _mcrnalns@adrnm,stateakus 907-/93-1241 tax 907-276-7542 . F 10111 Michael Bolkovatz, GPB Prod Optlm T earl! Leader 1\11 (;.>\temied \FJ~; venting dmJ tlaring event uccullecJ dl (jI'MA US L;¿ Oil St:pleln!x:i :¿BI t\urt: wa~; a 1dilull: ollllle IIIS)II ¡J1'f::ssun-; gas 1-f::IJlj(-:clio[) line that requimd depre~surJlI\: lhe line from LPC 10 LGI UJC was shutdown <1\ OS)UU dnd all CdS Wd~) initii:dly sent to flare Gas venting was ¡llItidk~cJ dt LCI pad to IIlcred~e Ole rate or c!eple~SUfll1~ c1W? \0 Incre<)::;III~J LEL ÇJ3S levels m Module 4902 at L2 AlllJclc, vellllllg/1ldil11g slopped at 1432 t11S whelì tile preSSUlt: 011 tll\; lJ(j~) II1Jectioll header was bled to 0 psi The totalllJII,d volume was [) 4 MMSCF and the totdl volume ven\l:(j (O-lIuu~JII Uk: 1(~:Jk ~Ji)d éit LGI) was 1 1 MMSCF if you requll(~ ::JUdltiulldllnjorrndtioll, pleéJ::iI::: dUII't 11e::Oltdlt::: \0 cdll MICr'lael Bolkov3tz CPB Production Optllì1ization rL (~)()7) 659-55Ul) . I U/2!)U()(¡7 ~x ftPé ~)cf? Rt:L;t:.\ v LU . STATE OF ALASKA" SEP 2 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION .. C Commission ~,Iti Oil & Gas ons. REPORT OF SUNDRY WELL OPERATlun~ Anchorage 1. Operations Performed: Other[&:JMILL PLUG Abandon 0 Repair WellD PluQ PerforationsD Stimulate 0 Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownO Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 204-225 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-20674-01-00 7. KB Elevation (ft): 9. Well Name and Number: 62.00 11-06A 8. Property Designation: 10. Field/Pool(s): ADL-028325 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11720 feet true vertical 8780.0 feet Plugs (measured) None Effective Depth measured 11684 feet Junk (measured) None true vertical 8781.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 34 - 114 34.0 - 114.0 1490 470 SURFACE 2482 13-3/8" 72# L-80 33 - 2515 33.0 - 2515.0 4930 2670 PRODUCTION 9817 9-5/8" 47# L-80 32 - 9849 32.0 - 8328.0 6870 4760 TIEBACK LINER 5969 7" 26# L-80 22 - 5991 22.0 5545.0 7240 5410 SCAB LINER 3550 7" 29# L-80 5983 - 9533 5539.0 - 8073.0 8160 7020 LINER 542 7" 29# L-80 9525 - 10067 8067.0 - 8506.0 8160 7020 LINER 727 3-1/2" 9.3# 13Cr80 9340 - 10067 7921.0 - 8506.0 10160 10530 LINER 2398 2-3/8" 4.7# L-80 9322 - 11720 7907.0 - 8780.0 11200 11780 Perforation depth: Measured depth: 10780-10800,10830-10850, 10880-10900, 10986-11120,11142-11254, 11284-11374, 11470-11490, 11520-11530,11606-11634,11650-11665 True vertical depth: 8757-8766,8763-8763,8762-8761,8761-8770, 8771-8772, 8772-8774, 8775-8776, 8778-8779, 8783-8783, 8783-8782 TubinQ ( size, Qrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 20 - 1029 4-1/2" 12.6# HY2CR95 @ 1029 - 9209 4-1/2" 12.6# L-80 @ 9209 - 9369 Packers & SSSV (type & measured depth): 9-5/8" Baker ZXP Packer @ 5983 7" Baker S-3 Packer @ 9243 4-1/2" HES X Nipple @ 2067 12. Stimulation or cement squeeze summary: Intervals treated (measured): R.BDMS 8Ft SEP 2 6 2006 Treatment descriptions including volumes used and final pressure: 13 Reoresentative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 693 Subsequent to operation: 1154 2,463 3392 --- 249 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A '2/_ ,D. æ-J 'd.fI Phone 564-5174 Date 9/19/06 1\ ! Form 10-404 Revised 4/2004 t..,.,ll ¡ ¡ , " . . 11-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/05/2006 T estEvent --- BOPD: 354 BWPD: 1,167 MCFPD: 4,158 AL Rate: 2,010 06/19/2006 PULLED HES FAS-DRILL FISH @ 9310' SLM RAN 3" BAILER TO TOP OF DEPLOYMENT SLEEVE @ 9311' SLM. NO RETURNS IN SB. RAN 2.25" BAILER TO 2 3/8 " X-OVER @ 9321' SLM. NO RETURNS IN SB. DRIFTED INTO 2 3/8"" LINER W/1.75" CENT & 1.5" BAILER, 9350' SLM. SB EMPTY. *** TURNED WELL OVER TO DSO *** 06/18/2006 TII/O= 500/0/0. ASSIST SLlCKLlNE. Final WHP= 50/0/0. 06/18/2006 ATTEMPT TO FISH HES FASDRILL @ 9311' SLM 06/17/2006 TII/O= 500/0/0. ASSIST SLlCKLlNE; Free up tool by pumping 59 bbls of diesel down the 06/17/2006 *** JOB CONTINUED FROM 06-16-06 WSR *** ATTEMPTED TO PULL HES FAS DRILL. TOOLS HUNG UP @ 9232' SLM, LRS PUMPED 59 BBLS DIESEL, TOOLS CAME FREE. RECOVERED 1.55" OD x 1.60" LONG PIECE OF FASDRILL CORE. 06/16/2006 ATTEMPT TO FISH HES FAS DRILL PLUG 06/15/2006 ATTEMPT TO FISH/BAIL HES FAS DRILL PLUG 06/14/2006 ****WELL SHUT IN ON ARRIVAL****(bail out plastic plug parts) RAN 10' x3" PUMP BAILER W/3.70" MODIFIED FLAPPER BOTTOM, SD @ 9316' SLM, RECOVERED 10 CUPS OF DEBRIS FROM FASDRILL PACKER. 06/14/2006 Continue pushing plug to 9317' CTM, PU and hung up @ 9292' worked pipe and came free. POOH Found two crowns form HES composite plug between motor and MHA. RD CTU, Left well shut in. Slickline will attempt to break up plug *** Job Complete*** 06/13/2006 CTU #5, Mill FastDrill; MIRU CTU #5. RIH with 3.13" PDM and 3.125" Venturi Junk Basket w/ Cut-Rite shoe. Tagged plug/fill at 9298' ctmd. Venturied and rotated on plug for 40 min. POOH. RIH w. 3.13" PDM and 3.125" Venturi Junk Basker w/Cut-Rite shoe ID of 2.0" Tag and mill till plug moves down hole. 06/07/2006 TII/O/OO= 280/750/0/10. Temp= Warm. IA FL (for GLE). IA FL @ 5988' (105 bbls) above sta# 3 s/o. Gas lift rate @ 2.08 mmscfd. FLUIDS PUMPED BBLS 4 PT Surface Equipment 31 50/50 Methanol Water 59 Diesel 290 1 % KCL with Safe-Lube 176 1 % Extra Slick KCL Water with Safe-Lube 20 1.5# Biozan 580 TOTAL Page 1 TREE = FMC GEN 2 WB..LHEAD = CWV? 11-06A SAFETY NOTES: ***4-1/2" CHROME TBG*** ACTUA TOR = BAKERC KB. B..EV = 62' BF. B..EV = 31' KOP= 3200' V , Max Angle = 93 @ 10878' Datum MD = 10817' '" . 2067' 4-1/2"HESXNIP,ID=3.813" I Datum 1VD = 8700' SS /'" I GAS LIFT MANDRB..S 4-1/2" TBG, 12.6#, 13CR80 , .0152 bpf, ID = 3.958" 1029' ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 113-3/8" CSG, 72#. L-80, ID = 12.347" I 2515' Y . 4 3471 3460 19 KBG-2-1R DOME BK 16 06/05/06 17" TIEBACK CSG, 26#, L-80 Tell, ID = 6.276" I L 3 6057 5591 47 KBG-2-1R SO BK 20 05/09/06 2768' 2 7952 6889 44 KBG-2-1R DMY BK 0 05/09/06 1 9037 7690 42 KBG-2-1R DMY BK 0 05/09/06 17" TIEBACK CSG, 26#, L-80 BTC, ID = 6.276" I 5992' , IIIfi 5986' 7" BKR SEAL ASSY, ID - 6.276" I TOP OF 7" SCAB LNR I .. 5983' ~ ............. 5983' BAKER ZXP A<R I I 9074' 4-1/2"HESXNIP, 10=3.813" I 9104' 7" x 4-1/2" BKR 8-3 A<R, ID = 3.830" I . 9138' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, HY2CR95 VAM 9209' 9203' -iTBG STUB (01/25/06) I .... TOP, .0152 bpf, ID = 3.958" -- 9209' - 7" X 4-1/2" UNIQUE MA CHINE OV ERSHOT I :8 ð 9243' -i 7" X 4-1/2" BAKER S-3 A<R, ID = 3.875" I Minimum ID = 1.92" @ 9328" I I 9308' H4-1/2" HES X NIP, ID = 3.813" I 3-1/2" X 2-3/8" XO . -..¡ -9322' -iTOPOFCMT(2-3/8LNR) I ~ ~ 9322' -13.70" BKR DEPLOY SLV, ID = 3.00" (12/28/04) I ::::: 9328' -i3-1/2" x 2-3/8" XO, ID = 1.92" I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I- 9340' -i 3.70" DEPLOYMENT SL V (BB-IIND PIPE) I 9369' 9369' -i4-1/2" UNIQUE OVERSHOT (BEHIND PIPE) I ~ :8 ~ -i7" X 4-1/2" BAKER S-3 A<R (BB-IIND PIPE) I = 9406' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9441' J.......~ r-- ...... H 7" BAKER LNR HGR (BEHIND PIPE) I I-~ I 9524' 7" LNR-TIEBACK, 29#, L-80, .0371 bpf, ID = 6.184" 9525' , I 9-5/8" CSG, 47#, L-80, ID = 8.681" 9849' ~ ~ 9700' H CALC TOP OF CEMENT (BEHIND PIPE) I 1 WFD WHIPSTOCK & ANCHOR (11/23/04) ~ ~ 10068' - ~ IRA TAG 10072' ) ~~ 13-1/2" LNR, 9.3#, 13CR80 (01/27/04), ID = 2.992" 10371' ~ I M ILLOUT WINDOW I ~ ~ (11-06A) 10067' . 10073' ÆRFORA TION SUMMARY .. REF LOG: ??? SHCS ON 01/22/82 ??? .¡. ,. ANGLEATTOPÆRF: 81 @ 10780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 11(I 1-9/16" 6 10780 - 10800 0 02/13/05 1-9/16" 6 10830 - 10850 0 02/13/05 1-9/16" 6 10880 - 10900 0 02/13/05 1-9/16" 6 10986 - 11120 0 12/28/04 1-9/16" 6 11142 - 11254 0 12/28/04 I 7" LNR, 29#, L-80 H I 1-9/16" 6 11284 - 11374 0 12/28/04 10557' 1-9/16" 6 11470 - 11490 0 12/28/04 1-9/16" 6 11520 - 11530 0 12/28/04 1-9/16" 6 11606 - 11634 0 12/28/04 IFBTDI 11684' I- 1-9/16" 6 11650 - 11665 0 12/28/04 12-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" H 11720' I 'V DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 01/30/82 ORIGINAL COM PLETION OS/21/06 DAClTLH DRLG DRAFT CORRECTIONS WB..L: 11-06A 08/28/97 RWO 06/05/06 KSB/PAG GL V C/O ÆRMIT No: '2042250 12/31/01 DAC/KK RWO API No: 50-029-20674-01 01/24/04 JAF/TLP CTU #9 LNR SEe 33, T11 N, R15E, 3977.22' FB.. & 3381.92' FNL 12/28/04 DH CTD SIDETRACK (11-06A) 05/09/06 D16 RWO BP Exploration (Alaska) ..51¿r~ _ STATE OF ALASKA a ALASKWJIL AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONS , 1. Operations Performed: o Abandon IBI Repair Well o Plug Perforations o Stimulate o Other o Alter Casing IBI Pull Tubing o Perforate New Pool o Waiver o Re-Enter Suspended Well o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. IBI Development 0 Exploratory 204-225 J. AOOress: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20674-01-00 7. KB Elevation (ft): 62' 9. Well Name and Number: PBU 11-06A 8. Property Designation: 10. Field / Pool(s): ADL 028325 Prudhoe Bay Field I Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11720 feet true vertical 8780 feet Plugs (measured) None Effective depth: measured 11684 feet Junk (measured) None true vertical 8781 feet Casing Length Size MD TVD Burst Collapse Structural - Conductor 80' 20" 80' 80' 1530 520 Surface 2453' 13-3/8" 2515' 2515' 5380 2670 Intermediate 9787' 9-5/8" 9849' 8328' 6870 4760 Production Liner 4574' 7" 5983' - 10067' 5555' - 8506' 8160 7020 Scab Liner 1031' 3-1/2" 9340' - 10067' 7921' - 8506' 10160 10530 Liner 2398' 2-3/8" 9322' - 11720' 7907' - 8780' 11200 11780 Liner Tieback 5969' 7" 22' - 5991' 22' - 5545' 7240 5410 Perforation Depth MD (ft): 10780' - 11665' Perforation Depth TVD (ft): 8757' - 8782' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr / L-80 9441' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 7" x 4-1/2" Baker 'S-3' 9406'; 9243'; 9104' packer; 7" x 4-1/2" Baker 'S-3' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft MAY .3 () 2006 Treatment description including volumes used and final pressure: Cut tubing at 9225' and pulled. Ran 7" Tieback from surface to 5991'. Cemented with 65 Bbls (132 sx LiteCrete and 100 Bbls (484 sx Class 'G'. Cleaned out to shoe, then ran tubing new tubing to 9209'. 13. Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: IBI Daily Report of Well Operations o Exploratory IBI Development o Service IBI Well Schematic Diagram 16. Well Status after proposed work: IBI Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt Contact Paul Chan, 564-5254 306-010 Printed Name Terrie Hubble Title Technical Assistant Signature ~ M\1 ~ H..i ~ Phone Date OSfi 6/0{¿, Prepared By Name/Number: 564-4628 Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 OR\G\NAL Submit Original Only 11-06A . . 11-06A RigW orkover Prudhoe Bay Unit 50-029-20674-01 204-225 Accept: Spud: Release: Ri: PRE-RIG WORK 01/19/06 SET 4-1/2" HES FASDRILL PLUG AT 9276'. PLUG CONFIRMED SET WITH 2000 PSI PRESSURE TEST FOR 15 MINUTES. SHOT TUBING PUNCHER FROM 9201' - 9203' WITH 1.56" HSD PJ, HMX GUN 4 SPF. 01/20/06 SHOT STRING SHOT FROM 9214' - 9226' IN PREPARATION FOR CHEMICAL CUT TUBING. 01/21/06 TII10=SSV/0/50 FLOWLINE ICE PLUG PUMPED 3 BBLS NEAT METHANOL IN ATTEMPT TO WORK ICE PLUG. ESTABLISHED ICE PLUG IS BETWEEN GROVE VALVE AND MANIFOLD BLDG. FREE FROM GROVE VALVE TO WELL HEAD. 01/22/06 THAW ICE PLUG IN FLOW LINE, PUMPED 2 BBLS NEET METHANOL UNABLE TO THAW ICE PLUG. ESTABLISHED PLUG TO BE BETWEEN GROVE VALVE AND MANIFOLD BLDG.FLOW LINE, FREE BETWEEN WELL HEAD AND GROVE VALVE. FINAL WHP'S= S1/0/50. 01/25/06 CHEMICAL CUT 4-1/2" TUBING AT 9225' WITH A 3-5/8" CUTTER. POSITIVE INDICATION OF CUT SEEN AT SURFACE. NO PROBLEMS RIH OR POOH. TURNED WELL OVER TO DSO. JOB COMPLETE. 01/28/06 TII10=200/0/0 CIRC OUT, FREEZE PROTECT AND CMIT TX IA X OA AT 3500 PSI ( INCOMPLETE) (PRE RWO) PUMPED 5 BBLS NEAT METHANOL SPEAR, 903 BBLS 1% KCL AND 150 BBLS DIESEL. LET U-TUBE FOR 1 HR, FREEZE PROTECT JUMPER LINE TO WELL # 4 WITH 12 BBLS METHANOL. PRESSURED TUBING AND IA AND OA TO 3200 PSI WHEN CALLED OFF JOB. BLED BACK 6.5 BBLS DIESEL. RDMO, TURN WELL OVER TO DSO. FWP= 0/0/1020. 01/29/06 TIIIO= ONAC/780. CMIT-TXIAXOA TO 3500 PSI [PASSED ON THE 2ND ATTEMPT] FREEZE PROTECT THE FLOWLINE WITH 30 BBLS OF NEAT METHANOL AND 88 BBLS OF 1800 DIESEL. FINAL WHP= 0/0/0. 03/21/06 TIIIO=BPV/O/O MIT OA PASSED AT 2500 PSI. (SHUT IN) (RWO SCREENING) OA PRESSURED UP W/2.6 BBLS CRUDE PUMPED. 1ST TEST OA LOST 200 PSI IN 15 MIN. 2ND TEST OA LOST 100 PSI IN 15 MIN. WI TOTAL LOSS OF 150 PSI IN 30 MIN. FINAL WHP'S=BPV/O/O. 04115/06 TIII0=BPVNAC/110. TEMP=SI. MONITOR WHPS (PRE RIG). OA FL AT SURFACE. WELLHOUSE, WELLHEAD SCAFFOLDING, AND FLOWLINE HAVE BEEN REMOVED. 04/23/06 TIIIO= ONAC/70. TEMP= SI. BLEED WHP'S TO 0 PSI (PRE-RIG) BY 4/24. WELLHOUSE, FLOWLINE, AND SCAFFOLDING HAS BEEN REMOVED. OA FL AT SURFACE. BLED OAP TO SLOP TRAILER FROM 70 PSI TO 0 PSI IN 1 HOUR. MONITORED FOR 30 MINUTES. FINAL WHP'S= ONAC/O+. 04124/06 TIII0=ONAC/13 TEMP=SI WHPS POST-BLEED (PRE-RIG). BLED OA PRESSURE INTO BUCKET IN 1 MINUTE. FINAL WHPS=ONAC/O. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOYON DOYON 16 Start: 1/21/2006 Rig Release: 5/9/2006 Rig Number: Spud Date: 12/27/1981 End: 5/9/2006 4/30/2006 05:00 - 05:30 0.50 MOB P PRE Prepared for Rig Move. 05:30 - 06:00 0.50 MOB P PRE Moved Rig Off Well END-3-27/ M-33 06:00 - 06:30 0.50 MOB P PRE Removed BOPE From Cellar Secure on Stand. 06:30 - 07:30 1.00 MOB P PRE PJSM-Lay Derrick over and install Rear Booster Tire Assembly. 07:30 - 00:00 16.50 MOB P PRE Move Rig to D.S.-11. 5/1/2006 00:00 - 02:30 2.50 MOB P PRE Moving To D.S-11-06A 02:30 - 03:30 1.00 MOB P PRE RID Booster Tire Assembly, Install BOPs in Cellar. 03:30 - 05:00 1.50 MOB P PRE PJSM, Service Crown Section, Raise Derrick, RlU Wind Walls. 05:00 - 06:30 1.50 MOB P PRE Spot Rig Over Well 11-06. 06:30 - 09:30 3.00 MOB P PRE Rig Up Floor and Ready Rig. Spot Up Auxiliary pump Unit and Connect to Rig. 09:30 - 10:00 0.50 WHSUR P DECOMP PIU DSM Lubricator and Pull BPV. Zero Psi on tbg. UD Lubricator. Rig Accepted 5/1/06 at 09:30. 10:00 - 10:30 0.50 WHSUR P DECOMP RlU Lines to Tree and Swab Cap. PT Lines to 3500 psi. 10:30 - 14:00 3.50 WHSUR P DECOMP Circulate Out Freeze Protect and Condition Well to Clean Seawater. Circulate 680 bbls. Pump rate 10.0 bpm at 1070 psi. Monitor Well after pumping. Positive pressure on both Tbg and IA. Not Reading on gauge. Swap to 500 psi gauges. Read 5 psi on both Tbg and IA. 14:00 - 16:00 2.00 WHSUR P DECOMP Circulate another 400 bbls down tbg and up IA. at 9.0 bpm and 1100 psi. Monitor Well for Flow. Bleed Down both Tbg and IA pressure. Had 10 psi on both after circulation. Monitor Well for 30 minutes after bleeding down - no flow. 16:00 - 16:30 0.50 WHSUR P DECOMP B / 0 and RI D Circulating hoses. 16:30 - 17:00 0.50 WHSUR P DECOMP Set BPV and Test to 1000 psi from Below. 17:00 - 18:30 1.50 WHSUR P DECOMP N/D Tree and Adapter. 18:30 - 21 :00 2.50 WHSUR P DECOMP PJSM N/U BOPE. 21 :00 - 21 :30 0.50 WHSUR P DECOMP RlU BOP Test Equipment. 21 :30 - 00:00 2.50 WHSUR P DECOMP Test BOPE 250 psi Low Test, 3,500 psi High Test on Annular, Pipe Rams, Blind Rams and Surface Choke Valves, Manual and HCR Choke and Kill lines, Upper and Lower IBOPs and FOSVs. John Crisp Waived Witness of Bop Test. 5/212006 00:00 - 02:30 2.50 BOPSU P DECOMP Test BOPE 250 psi Low Test, 3,500 psi High Test on Annular and Surface Choke Valves, Manual and HCR Choke and Kill lines, Upper and Lower IBOPs and FOSVs. AOGCC Representative John Crisp Waived Witness of BOP Test. BOP Test Supervised By BP WSL and Doyon Toolpusher. 02:30 - 03:30 1.00 WHSUR P DECOMP Nipple Down BOPs. Pulled 4.5" Test Joint to Test Blind Rams and Pulled Blanking Sleeve With Test Joint. Unable to Seat Blanking Sleeve From Rig Floor. Split Stack to Install Blanking Sleeve. 03:30 - 04:30 1.00 WHSUR P DECOMP Install Blanking Plug, Nipple Up BOPE. 04:30 - 05:30 1.00 WHSUR P DECOMP Continue to Test BOPE. Tested Lower Pipe Rams, Blind Rams, Koomey Test. 05:30 - 06:00 0.50 WHSUR P DECOMP RID BOP Test Equipment. 06:00 - 06:30 0.50 PULL P DECOMP P/U DSM Lubricator and Pull BPV. RID DSM Lubricator. 06:30 - 07:30 1.00 PULL P DECOMP PIU 4-1/2" Landing Joint and Make Up to FMC Tbg hanger. Pull Hanger to Floor with 165,000# to Unseat, PIU Wt - 130,000#. UD Landing Joint and Hanger. 07:30 - 09:00 1.50 PULL P DECOMP Circulate Bottoms Up with 10 bpm and 1250 psi. 09:00 - 17:30 8.50 PULL P DECOMP POOH with 4.5# 12.6# Vam Ace 13Cr80 Tubing. Used Compensator for All Jts. Apply Thread Protectors to Pin Ends, Printed: 5/1512006 3:31 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOYON DOYON 16 Start: Rig Release: Rig Number: 1/21 /2006 5/9/2006 Spud Date: 12/27/1981 End: 5/9/2006 5/212006 09:00 - 17:30 8.50 PULL P DECOMP Number and UD joints. Recovered 5 GLMs and 215 Jts Tubing. 17:30 - 18:30 1.00 PULL P DECOMP RID Tubing Handling Equipment, Load Pipe Shed wlBHA #1. 18:30 - 19:00 0.50 PULL P DECOMP Set Wear Ring. 19:00 - 19:30 0.50 PULL P DECOMP Clear and Clean Rig Floor. 19:30 - 22:00 2.50 FISH P DECOMP P/U M/U BHA. Consists of Flat Bottom Shoe, Tubing Mill, Wash Pipe Boot Basket, XO, Scraper, 2 Boot Baskets, XO, Bowen Bumper Sub, Jar, XO, 12 Drill Collars, 21 HWDP = 1051.41'. 22:00 - 00:00 2.00 FISH P DECOMP P/U 4" Drill Pipe 1x1 From Pipe Shed. f/1 ,051', tl3,160'. 5/3/2006 00:00 - 06:30 6.50 FISH P DECOMP RIH w/ Dress Off BHA on 4" DP to 9,200'. PI U DP 1 x 1 From Pipe Shed. 06:30 - 07:00 0.50 FISH P DECOMP M I U Top Drive, Established Parameters: String Weight Up 180,000#, String Weight Down 145,000#, String Weight Rotating 161,000#, 60 rpm, Torque 5,000 ft Ilbs, Pump 5 bpm, 800 psi. Washed Down, Tagged Tubing Stub at 9,221' DPM. Dressed Off Top of Tubing Stub 9,221' - 9,221.6', WOM 5,000#, Pump Rate 5 bpm, SPP Off 800 psi, SPP On 950 psi, 60 rpm, Torque Off 5,000 ft Ilbs, Torque On 8,000 ft Ilbs. PI U Off of Tubing Stub to 9,200', Shut Down Pumps and Rotary, RIH and Swallowed Tubing Stub without Pumps or Rotation. 07:00 - 08:30 1.50 FISH P DECOMP Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 13 bpm, 4,100 psi. Shut Down Pumps, Monitored Well, Static. B I 0 and BID Top Drive. L / D 1 Joint 4" DP. 08:30 - 10:00 1.50 FISH P DECOMP Held PJSM. Slipped and Cut Drilling Line. 10:00 - 13:00 3.00 FISH P DECOMP POOH w/4" DP. 13:00 - 14:00 1.00 FISH P DECOMP POOH wI BHA, Stood Back 4" HWDP, 4-3/4" DC. B I 0 and L I D Dress Off BHA Tools. 14:00 - 14:30 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor. 14:30 - 15:30 1.00 DHB P TIEB1 Held PJSM. M I U HES 7" RBP BHA: RBP Assy - Liner Entry Guide, RBP, Retrieving Tool, XO; 12 x 4-3/4" DCs, 21 Jts 4" HWDP. 15:30 - 18:00 2.50 DHB P TIEB1 RIH w/ RBP BHA on 4" DP to 6,000'. 18:00 - 18:30 0.50 DHB P TIEB1 M / U Top Drive, Established Parameters: String Weight Up 135,000#, String Weight Down127,000#, Engaged Pump 3 bpm, 110 psi. RIH to 6,045'. Set RBP @ 6,041' Tested tl1 ,000 psi, Spot 20 bbl Hi-Vis Pill @ 6 bpm 420 psi. 18:30 - 20:30 2.00 DHB P TIEB1 POOH tl6,014' Mixed 500# 20/40 Mesh Sand in Drill Pipe. Wait 1 hr. 20:30 - 21 :30 1.00 DHB P TIEB1 POOH tlS,727' Reverse Circulated Drill Pipe Volume. At 25 bbls Back Saw large Quantity of Sand Back to Surface. 21 :30 - 22:30 1.00 DHB P TIEB1 RIH tl6,036' No Sand. POOH tl6,006'. 22:30 - 00:00 1.50 DHB P TIEB1 Mixed and Pumped 500#, 20/40 Mesh Sand. Circulated at 1 bpm, 50 psi To Spot Sand on RBP. 5/4/2006 00:00 - 00:30 0.50 DHB P TIEB1 POOH to 5,727'. Waited for Sand to Fall. R / U To Reverse Circulate. 00:30 - 01 :00 0.50 DHB P TIEB1 Reverse Circulated Drill String, 9 bpm, 1,450 psi, No Sand Back on Bottoms Up. 01 :00 - 01 :30 0.50 DHB P TIEB1 B / D and R / D Circulating Equipment. RIH Tagged Sand At 6,026'. Monitored Well, Static. 01 :30 - 04:30 3.00 DHB P TIEB1 POOH wI 4" DP. 04:30 - 05:30 1.00 DHB P TIEB1 POOH wI BHA, B I 0 and LID RBP Running Tool. 05:30 - 06:00 0.50 DHB P TIEB1 Cleared and Cleaned Rig Floor. Printed: 5/15/2006 3:31:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOVON DOVON16 Start: Rig Release: Rig Number: 1 /21 /2006 5/9/2006 Spud Date: 12/27/1981 End: 5/9/2006 5/4/2006 06:00 - 06:30 0.50 FISH P TIEB1 M I U Polish Mill BHA: 7.42" Polish Mill, XO, Spacer Sub, 8.14" Top Dress Off Mill, Pup Jt, XO, 1 Jt 4" DP, XO, Pin x Pin Sub, 9-5/8" Casing Scraper, XO, XO, Bumper Sub, Oil Jars, XO, 12 x 4-3/4" DCs, 21 Jts 4" HWDP. BHA Total Length 1,086.63'. 06:30 - 08:00 1.50 FISH P TIEB1 RIH w/ Polish BHA on 4" DP to 5;975'. 08:00 - 08:30 0.50 FISH P TIEB1 M / U Top Drive, Established Parameters, String Weight Up 138,000#, String Weight Down 125,000#, String Weight Rotating 135,000#, 70 rpm, Torque 3,500 ft Ilbs, Pump Rate 5 bpm, 300 psi. Washed Down and Polished 7" Tie Back, No-Goed on Top of Tie Back wI Top Dress Off Mill at 5,982'. 08:30 - 09:30 1.00 FISH P TIEB1 Pumped and Circulated Around 40 bbl Hi-Vis Sweep. 16.5 bpm, 3,850 psi. Monitored Well, Static. B / 0 and B /0 Top Drive. 09:30 - 11 :00 1.50 FISH P TIEB1 POOH wI 4" DP. 11 :00 - 11 :30 0.50 FISH P TIEB1 POOH wI BHA, B I 0 and LID Polish Mill Tools. Good Indication on Top Mill Tattletail That Tie Back Top Dressed Off. 11 :30 - 12:00 0.50 CASE P TIEB1 Cleared and Cleaned Rig Floor. 12:00 - 13:30 1.50 BOPSU P TIEB1 Held PJSM. C/O 3-1/2" x 6" Variable Rams to 7" Solid Rams. R I U 7" Casing Handling Equipment. 13:30 - 14:30 1.00 BOPSU P TIEB1 R I U Test Equipment. Tested 7" Rams to 250 psi 13,500 psi. Each Test Held f/ 5 Minutes with No Leaks or Pressure Loss. Bled Down Pressure, Pulled Test Plug, RID Test Equipment. BID All Lines. 14:30 - 15:00 0.50 CASE P TIEB1 Held PJSM. PI U Seal Stem Assy: Seal Stem, Locator Sub, 7" Pup Jt, Float Collar. M I U Seal Stem Assy to 1 Joint 7" 26" L-80 BTC Casing, M / U Torque 8,250 ft /Ibs, Backerlocd Connection. Filled Casing and Checked Float, OK. 15:00 - 20:00 5.00 CASE P TIEB1 M I U and RIH wI 78 Joints 7" 26# L-80 BTC Casing, Average M I U Torque 8,250 ft Ilbs. Filled Casing Every 5 Joints. 20:00 - 21 :00 1.00 CASE P TIEB1 RIU To Run 7" TC-II, L-80, 26# Casing. 21 :00 - 00:00 3.00 CASE P TIEB1 MIU and RIH wI 30 Joints 7" 26# L-80, TC-II Casing. Torque Turned Each Connection. Average M I U Torque 10,000 ft-Ibs. Filled Casing Every 5 Joints. 5/5/2006 00:00 - 03:00 3.00 CASE P TIEB1 M/U and RIH wI 68 Joints 7" 26# L-80, TC-II Casing. Torque Turned Every Connection. Average M / U Torque 10,000 ft-Ibs. Filled Casing Every 5 Joints. 03:00 - 04:00 1.00 CASE P TIEB1 RIU Long Bails and M/U Circulating Head. 04:00 - 05:00 1.00 CASE P TIEB1 Circulated at 1 bpm and 50 psi Stung Into PBR. Landed Seal Assembly At 5,989'. Tested Seals To 500 psi For 5 minutes. P/U RIU on Cement Manifold. 05:00 - 06:00 1.00 CASE P TIEB1 Circulated 2 x Bottoms Up Staged Up Pumps to 10 bpm, 860 psi. 06:00 - 22:30 16.50 CASE N WAIT TIEB1 Continued to Circulate Wellbore 5 bpm, 300 psi, While Wating on Schlumberger Cementing Equipment from North Star. Schlumberger on Location at 2100 hrs, Spotted Equipment and R I U Lines. Held PJSM wI Rig Crew, Cementers, Little Red, Vac Truck Drivers, Tool Pusher and Drilling Supervisor, Reviewed HSE and Plan Forward. 22:30 - 00:00 1.50 CEMT P TIEB1 Schlumberger Batched Mixed Lead and Tail Cement. 5/6/2006 00:00 - 00:30 0.50 CASE P TIEB1 Shut Down Pumping, Lined up And Tested Little Reds Lines to 3,500 psi. Switched to SLB Cementer Pumped 5 bbls Water,S bpm, 420 psi.Shut in Manifold and Pressure Tested Lines to 4,500 psi. Printed: 5/15/2006 3:31 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOYON DOYON 16 Start: 1/21/2006 Rig Release: 5/9/2006 Rig Number: Spud Date: 12/27/1981 End: 5/9/2006 5/6/2006 00:30 - 01 :00 0.50 CASE P TIEB1 Lined Up On Little Reds and Pumped 45 bbls Diesel At 4 bpm, and 400 psi. 01 :00 - 02:00 1.00 CASE P TIEB1 Switched to Schlumberger, Dropped Bottom Plug, Pumped 65 bbls (133 sks) 11.5 ppg Lite Crete Cement w/ 0.500 %bwoc Dispersant, 0.030 %bwoc Retarder, 0.200 %bwoc Antiloam, 1.50 gall sk GASBLOK, Followed by 95 bbls (460 sxs) 15.8 ppg Premium Class G Cement w/ 0.300 %bwoc Dispersant, 0.050 %bwoc Retarder, 0.200 %bwoc Antiloam. Pumped Cement at the Following Rates: Lead Cement Pumped Rate Pressure 5.00 bbls 5.00 bpm 915 psi 25.00 bbls 6.00 bpm 1,079 psi 50.00 bbls 6.00 bpm 933 psi 65.00 bbls 2.50 bpm 280 psi Tail Cement Pumped Rate Pressure 25.00 bbls 4.00 bpm 960 psi 50.00 bbls 5.00 bpm 736 psi 75.00 bbls 5.00 bpm 800psi 90.00 bbls 5.00 bpm 805 psi 95.00 bbls 2.00 bpm 791 psi Dropped Top Wiper Plug, Pumped 5.0 bbls Water 4.50 bpm, 200 psi. Switched to Rig Pumps and Displaced Cement with 225 bbls 01 Seawater at the Following Rates: Pumped Rate Pressure 25.00 bbls 8.00 bpm 431 psi 50.00 bbls 8.00 bpm 355 psi 75.00 bbls 8.00 bpm 355 psi 100.00 bbls 8.00 bpm 356 psi 125.00 bbls 8.00 bpm 460 psi Caught Cement w/135.0 bbls Pumped 150.00 bbls 8.00 bpm 1,020 psi 175.00 bbls 8.00 bpm 1,650 psi 200.00 bbls 8.00 bpm 2,150 psi 225.00 bbls 3.00 bpm 2,300 psi Bumped Plug w/ 230.00 bbls Total Displacement Pumped. Pressured up to 2,800 psi to Bump Plug, Held 1/ 5 Minutes. RIH and Landed Out Seal Assy on Top 01 Tie Back PBR. Bled Down Pressure and Checked Seals, Seals Held. Cement In Place at 02:00 hrs. 5 bbls Cement Back to Surface. 02:00 - 02:30 0.50 CEMT P TIEB1 Flushed BOP Stack w/ Retarder / Citric Acid Mix Followed by 25 bbls Seawater. B / 0 Surface Lines. 02:30 - 03:30 1.00 BOPSU P TIEB1 Pumped Out BOP Stack, B / 0 and L / D Cement Manifold, Pumped Out 7" Casing, N I D Stack and Riser. P / U and Split BOP Stack. 03:30 - 04:30 1.00 CASE P TIEB1 Set Emergency Slips With 160,000#, Prep To Make Casing Cut. 04:30 - 06:30 2.00 CASE P TIEB1 R I U Wachs Cutter, Cut and Dressed Off 7" Casing per FMC Rep. 06:30 - 07:30 1.00 CASE P TIEB1 L / D Cut Joint, Set Back BOP Stack on Pedestal. 07:30 - 08:30 1.00 WHSUR P TIEB1 N I U New 13-5/8" x 13-5/8" 5M Tubing Spool wI 7" Packoff. Tested Packoff and Seals to 3,500 psi, OK. Printed: 5/15/2006 3:31:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOYON DOYON 16 Start: Rig Release: Rig Number: Spud Date: 12/27/1981 End: 5/9/2006 1 /21 /2006 5/9/2006 N / U BOP Stack, C/O 7" Solid Rams f/3-1/2" x 6" Variable Rams. 09:30 - 1 0:30 1.00 TIEB1 M / U Test Plug and Test Joint, RIH and Set in Wellhead. R / U Test Equipment. Tested 3-1/2" x 6" Variable Rams, 250 psi / 3,500 psi. All Tests Held fl 5 Minutes w/ No Leaks or Pressure Loss. RID Test Equipment, Pulled Test Joint and Test Plug, Ran and Set Wear Bushing. Tests Witnessed by BP Drilling Supervisor and Doyon Tool Pusher. 10:30 - 11 :30 1.00 BOPSU P TIEB1 Installed Riser, Brought BHA Components to Rig Floor. 11 :30 - 12:30 1.00 DRILL P TIEB1 M I U Drill Out BHA: 6" HTC ATJ-4 Bit, 2 x 4-3/4" Boot Baskets, Bit Sub wI Float, Bumper Sub, Jars, XO, 12 x 4-3/4" DC's, 21 Joints 4" HWDP. BHA Total Length: 1,041.08' 12:30 - 14:30 2.00 DRILL P TIEB1 RIH w/ BHA on 4" DP to 5,939'. Tagged Up at 5,939. 14:30 - 15:00 0.50 DRILL P TIEB1 M I U Top Drive, Established Parameters: String Weight Up 144,000#, String Weight Down 124,000#, String Weight Rotating 130,000#, 70 rpm, Torque 4,500 ft /Ibs, Pump 6 bpm, 550 psi. 15:00 - 15:30 0.50 DRILL P TIEB1 Washed and Reamed Soft Cement 5,939' - 5,959', Pump Rate 6 bpm, 550 psi, 70 rpm. Drilled Hard Cement and Float Equipment 5,959' - 6,015', WOB 15,000#, 70 rpm, Torque 5,000 ft Ilbs, Pump Rate 10 bpm, 1,650 psi. 15:30 - 16:30 1.00 DRILL P TIEB1 Shut Down Pumps, P / U to 5,990', RIH, Dry Tagged Sand at 6,024'. PI U to 6,015', Engaged Pumps 14 bpm, 3,500 psi, Wash Down from 6,024' - 6,028'. PI U to 5,950', Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 14 bpm, 3,500 psi. Shut Down Pump, Monitored Well, Static. B / 0 and BID Top Drive. 16:30 - 18:30 2.00 DRILL P TIEB1 POOH wI 4" DP. 18:30 - 19:00 0.50 DRILL P TIEB1 Clear and Clean Rig Floor. 19:00 - 19:30 0.50 DRILL P TIEB1 M/U Reverse Circ BHA, Consist of Flat Mill, Pin Bushing, XO, Reverse Circ Junk Basket, TSS Top Sub, XO, Casing Scraper, XO, Bowen LBS, Bowen Super II Jar, Circ Sub, XO, 12 Drill Collars, 21 jts HWDP. BHA =1048.45'. 19:30 - 21 :00 1.50 DRILL P TIEB1 RIH t/6,031' Obtain Drilling Parameters. Up Weight = 150,000 #, Down Weight = 120,000#, Rotating Weight = 130,000#, 30 rpm, Torque =3,000 ft-Ibs. 21 :00 - 22:00 1.00 DRILL P TIEB1 Dropped Ball Reverse Circulated at 4 bpm, 417 psi, Ball on Seat 2,025 psi, Washed to 6,034', POOH to 6,004' Dropped Ball to Open Circ Sub Pumped Ball at 3 bpm with 300 psi 150 stks ball seated and sheared at 2,100 psi, Incresed pump Rate to 13 bpm, With 2671 psi, Rotated 20 rpm, 3,000 ft-Ibs Torque, Rubber and Sand Back on Bottoms Up. 22:00 - 23:00 1.00 DRILL P TIEB1 Pumped 20 bbl Spacer Displaced Well to Clean Sea Water, 8 bpm With 1,350 psi. 23:00 - 00:00 1.00 DRILL P TIEB1 Monitor Well, BID POOH to 3,636'. 5m2006 00:00 - 01 :00 1.00 DRILL P TIEB1 POOH w/ 4" DP f/ 3,636. 01 :00 - 02:30 1.50 DRILL P TIEB1 B / 0 and L /0 HWDP, DC and Reverse Circulating Junk Basket Assy. Contents of Junk Basket; One Large Piece Cement and Two Smaller Ones. 02:30 - 03:30 1.00 FISH P TlEB1 R / U Test Equipment, Closed Blind Rams, Tested Casing to 3,500 psi fl 30 Minutes, OK. 03:30 - 04:00 0.50 FISH P TIEB1 M / U RBP Retrieving Tool. 04:00 - 06:30 2.50 FISH P TIEB1 RIH w/ RBP Retrieving Tool on 4" DP to 5,972'. Printed: 5/15/2006 3:31 :43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11-06A WORKOVER DOYON DOYON 16 Start: 1/21/2006 Rig Release: 5/9/2006 Rig Number: Spud Date: 12/27/1981 End: 5/9/2006 5/7/2006 06:30 - 09:00 2.50 FISH P TIEB1 M I U Top Drive, Established Parameters, String Weight Up 125,000#, String Weight Down 112,000#. RIH Dry Tagged Sand at 6,036', PI U to 6, 034'. Closed Annular, Engaged Pumps 8 bpm, 1,550 psi, Reversed Circulated Sand Off of RBP from 6,036' to 6,041'. Reverse Circulated 2 x Bottoms Up. Reduced Pump Rate to 5 bpm, 800 psi, Continued to Reverse Circulate, RIH, Latched RBP Stacked 10,000# on Plug. P / U w/ 25,000# Overpull. Shut Down Pump, Bled Off Pressure and Opened Annular. Released 7" RBP, P / U 15' to Ensure RBP Released, RIH 15', RBP Fully Released. Closed Annular, Reverse Circulated 2 x Bottoms Up, 8 bpm, 1,550 psi. Shut Down Pump, Bled Off Pressure, Opened Annular, Monitored Well, Static. B / 0 All Lines. 09:00 - 14:00 5.00 FISH P TIEB1 POOH, B / 0 and L / D 4" DP. 14:00 - 16:30 2.50 FISH P TIEB1 RIH w/ 4" DP from Derrick, POOH, B / 0 and LID Same. 16:30 - 17:00 0.50 FISH P TIEB1 Cleared and Cleaned Rig Floor. Pulled Wear Bushing. 17:00 - 18:00 1.00 RUNCO RUNCMP Held PJSM, R I U 4-1/2" HY2CR-95 Vam TOP Handling Equipment wI Compensator and Torque Turn Equipment. 18:00 - 00:00 6.00 RUNCO RUNCMP Held PJSM, Ran 4.5", 11.6#, HY2CR-95 Tubing to 2,645', P / U Every Joint wI Compensator, Torque Turned All Connections. Used Jet Lube Seal Gaurd Thread Compound. Average Make Up Torque 4,260 ft-Ibs. 5/8/2006 00:00 - 07:30 7.50 RUNCO RUNCMP Ran Total of 194 Joints 4-1/2",11.6#, HY2CR-95 Tubing, PI U Every Joint w/ Compensator, Torque Turned All Connections. Used Jet Lube Seal Gaurd Thread Compound. Average Make Up Torque 4,260 ft-Ibs. Gallled Pin on Jt. #64 LID Jt, Replaced Box on Jt #63. 07:30 - 09:30 2.00 RUNCO RUNCMP Ran 25 Joints 4-1/2",12.6#, 13CR80 Tubing, P / U Every Joint w/ Compensator, Torque Turned All Connections. Used Jet Lube Seal Gaurd Thread Compound. Average Make Up Torque 4,440 ft-Ibs. String Weight Up 145,000#, String Weight Down 112,000#. 09:30 - 11 :30 2.00 RUNCO RUNCMP PI U Joint #220, RIH, Swallowed Tubing Stub wI 0 / S, Observed Pins in 0 I S Shear w/1 0,000# Weight, Continued in Hole Stacked 15,000# on Tubing Stub, PI U and Repeated x 3 to Ensure Proper Space Out. 11 :30 - 12:30 1.00 RUNCO RUNCMP LID Jt #220, M / U Tubing Hanger and Landing Jt. Landed Hanger in Tubing Head. Tubing Spaced Out wI Unique Overshot 5.00' Over Tubing Stub. RILDS on Tubing Hanger. 12:30 - 13:30 1.00 RUNCO RUNCMP PJSM w/ Rig Crew, Vac Truck Drivers, Tool Pusher and Drilling Supervisor. R I U Circulating Head and Lines to Landing Joint and 7" x 4-1/2" IA to Reverse Circulate. 13:30 - 15:00 1.50 RUNCO RUNCMP Pumped 200 bbls 140 deg Seawater w/ Corrosion Inhibitor and Chased w/40 bbls Seawater. Pumped Down 7" x 4-1/2" Annulus, Took Returns Up Tubing. Pump Rate 3 bpm, 350 psi. 15:00 - 17:00 2.00 RUNCO RUNCMP PJSM wI Rig Crew, Baker Rep, Tool Pusher and Drilling Supervisor on Setting Packer and Testing Tubing. Broke Out Head Pin, Dropped BallI Rod Assy. Allowed Ball/ Rod Assy to Fall On Seat. M I U Head Pin, Pressured Up on Tubing to 2,500 psi to Set Packer, Increased Pressure to 3,500 psi, Pressure Tested Tubing f/30 minutes, OK. Bled Down Tubing Pressue to 2,000 psi. Pressure Tested IA to 3,500 psi, OK. Bled Down Tubing, OCR Valve Sheared at 3,000 psi Printed: 5/1512006 3:31:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06A 11 -06A WORKOVER DOYON DOYON 16 Start: 1/21/2006 Rig Release: 5/9/2006 Rig Number: Spud Date: 12/27/1981 End: 5/9/2006 Differential, Bled Down All Pressures, Lined Up, Pumped Down Tubing at 3.5 bpm, 1,170 psi, Took Returns Up IA. 17:00 - 18:00 1.00 RUNCMP B/O and UD Landing Jt. Ran and Set TWC. Tested from Below to 1,000 psi, OK. 18:00 - 19:00 1.00 RUNCMP Nipple Down BOPE. 19:00 - 21 :00 2.00 RUNCMP Nipple Up Adapter Flange and Tree. FMC Tested Void and Neck Seal to 5,000 psi. 21 :00 - 23:00 2.00 RUNCMP Tested Adapter Flange and Production Tree to 5,000 psi. OK. BP Drilling Supervisor and Drill Site Operator Witnessed Make up and Pressure Tests Adapter Flange and Production Tree. 23:00 - 23:30 0.50 RUNCMP RIU Drill Site Maintenance Pull Two Way Check. 23:30 - 00:00 0.50 RUNCMP RIU Little Red Services, Freeze Protect Well With 100 bbls Diesel. At 3 bpm with 1,320 psi. 5/9/2006 00:00 - 01 :30 1.50 RUNCMP Pumped 100 bbls, Diesel FP down 4-1/2" x 7" Annulus, 3 bpm, 1,320 psi. Shut Down Pump, Lined Up and U- Tubed Diesel. R I D Littles Red Equipment. 01 :30 - 02:00 0.50 RUNCMP Set BPV and Tested to 1,000 psi fl 5 Minutes. 02:00 - 03:00 1.00 RUNCMP B / 0 and RID All Surface Lines, Secured Well. Released Rig 0300 hrs 5/9/2006. Printed: 5/1512006 3:31 :43 PM . -:3~f . ~ðt{-a{) j- I', WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 April 27, 2006 RE: MWD Formation Evaluation Logs 11-06A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 1l-06A: LAS Data & Digital Log Images: 50-029-20674-01 1 CD Rom BDq -;);)$- 5'/(~Of.ø C þJß-- t 3 'if'\ I . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Chan Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay, 11-05A Sundry Number: 306-010 Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisiL day of January, 2006 Encl. l ~ ¡... It _I I¡.J r.:,fr l 11 'z..ooe, . STATE OF ALASKA I/cr:s 'l/h RECEIVED ALASKA OIL AND GAS CONSERVATION COMM SSION APPLICATION FOR SUNDRY APPROVAL JAN 11 ?On~ 20 AAC 25.280 AJuta Oi & Gas Cow;, C('~~ . . 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Other - .'." . Alter Casing I iii Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program iii Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well CI~: 5. Permit To Drill Number BP Exploration (Alaska) Inc. IHI Development o Exploratory 204-225 / 3. Address: o Stratigraphic o Service 6. API Number: /' P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20674-01-00 7. KB Elevation (ft): 62' 9. Well Name and Number: / PBU 11-06A 8. Property Designation: 10. Field I Pool(s): ADL 028325 Prudhoe Bay Field I Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY . ... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11720 8780 11684 8781 None None CasinQ LenQth Size MD ./ TVD Burst Collapse Structural 80' 20· 80' 80' 1530 520 2453' 13-3/8" 2515' 2515' 5380 2670 9787' 9-5/8" 9849' 8328' 6870 4760 linAr 4574' 7" 5983' - 1 0067' 5555' - 8506' 8160 7020 Scab Liner 1031' 3-1/2" 9340' - 10067' 7921' - 8506' 10160 10530 Liner 2398' 2-3/8" 9322' - 11720' 7907' - 8780' 11200 11780 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 10780' - 11665' / 8757' - 8782' 4-1/2", 12.6# 13Cr I L-80 9441' Packers and SSSV Type: 7· x 4-1/2" Baker 'S-3' packer; 7· x 4-1/2· Baker 'S-3' Packers and SSSV MD (ft): 9406'; 9243' / packer 12. Attachments: 13. Well Class after proposed work: / IHI Description Summary of Proposal o BOP Sketch o Exploratory IHI Development o Service o Detailed Operations Program '--.. 14. Estimated Date for Januarh3, ,?Ó06 15. Well Status after proposed work: Commencing Operations: IHI Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Date,," o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby "ortil\, th"'t the fOreg~i1 is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 printed'r~ ~ ~n /' Title Drilling Engineer Prepared By Name/Number: Sianatur J( ( '-........ Phone 564-5254 Date \ I 0 I r::Io Terrie Hubble, 564-4628 \.. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ., Sundry Number:30(Q - 0\ 0 o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: \ -ec;. t ßof?G- ~ÇOO . y?~. ~"b~"·rfJdP)/IA . RBDMS 8Ft JAN1.2 2006 /-/I,tJ6 Ap~ovev ~ L /IIA APPROVED BY COMMISSIONER THE COMMISSION Date Form 10-403 ~ed 07/2ðQ¥' ORIBINAL Submit In Duplicate . . G 11-06A proposed Ria Workover Procedure 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and lD 4-1/2" tubing string to the cut at -9200' MD. // 3. RIH with bit x scraper to Tal at 5983' MD. 4. Run and cement 7" 26#/ft tieback liner. / 5. Cleanout 7" liner. 6. Run 4-1/2" 13Cr80 premium connection completion with stacker packer completion. Set packer at -9100' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. NO BOPE. NU and test tree. RDMO. / / TREE = WELLHEAQ = ACTUATOR = KB. ELEV = . FMC GEN 2 erN BAKER C 62' KOP= Max Angle = Datum MO = DatumlVD= 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 2515' ¡TOP OF 7" SCAB LNR I 5983' Minimum ID = 1.92" @ 9328" 3-1/2" X 2-3/8" XO 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" r- I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" r- 17" LNR-TIEBACK, 29#, L-80, .0371 bpf, 10 = 6.184" H 19-5/8" CSG, 47#, L-80, 10 = 8.681" r I WFD WHIPSTOCK & ANCHOR (11/23/04) r- IRA TAGr- 13-1/2" LNR, 9.3#, 13CR80 (01/27/04),10 = 2.992" r- PERFORA TION SUMMARY BrieS ON ANGLEATTOPÆRF: 81 @ 10780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 1-9/16" 6 10780 - 10800 0 02/13/05 1-9/16" 6 10830 - 10850 0 02/13/05 1-9/16" 6 10880 - 10900 0 02/13/05 1-9/16" 6 10986 - 11120 0 12/28/04 1-9/16" 6 11142-11254 0 12/28/04 1-9/16" 6 11284 - 11374 0 12/28/04 1-9/16" 6 11470 - 11490 0 12/28/04 1-9/16" 6 11520 - 11530 0 12/28/04 1-9/16" 6 11606 - 11634 0 12/28/04 1-9/16" 6 11650-11665 0 12/28/04 DATE 01/30/82 08/28/97 12/31/01 01/24/04 12/28/04 02/07/03 REV COMMENTS ORIGINAL COM PLErION RWO DAC/KK RWO JAF/TLP CTU #9 LNR DH CTDSIDErRACK(11-06A) JMP/KK WAIVER SAFETY NOTE 11-06A S.NOTES: **IAx OACOMM. OPERATING P RE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (02/07/03 WAlVER)** 9-5/8" LEAK @ 6340' ('97) **4-1/2" CHROME TBG** 2082' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS DEV TYPE VLV LATCH 13 MMG-M DMY RK 36 MMG-M DMY RK 46 KBG-2 DMY BK 48 KBG-2 DMY BK 40 KBG-2 DMY BK ST MD lVD 1 3320 3315 2 5025 4841 3 6019 5564 4 6379 5808 5 9216 7825 PORT DA TE o 07/24/05 o 07/24/05 o 12/31/01 o 12/31/01 o 12/31/01 5983' ~ BAKER ZXP PKR I 9243' 9308' -9322' 9322' 9328' -17" X 4-1/2" BAKER S-3 PKR, 10 = 3.875" I -14-1/2" HES X NIPW/ RHC SLV, ID = 3.813" ~TOPOF CMT (2-3/8 LNR) I ~3.70" BKRDEPLOY SLV, ID=3.00" (12/28/04) 1-13-1/2" X 2-3/8" XO, ID = 1.92" I -13.70" DEPLOYMENT SL V (BEHIND PIPE) I 9369' -4-1/2" UNIQUE OVERSHOT (BEHIND PIPE) -17" X 4-1/2" BAKER S-3 PKR (BEHIND PIPE). 9524' 9700' -17" BAKER LNR HGR (BEHIND PIPE) I - CALC TOP OF CEl'vIENT (BEHIND PIPE) MILLOUT WINDOW (11-06A) 10067' - 10073' 10557' I I PBTD I 12-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" H DA TE REV BY COMMENTS 07/22/03 JCM/TLH GLV C/O 10/18/05 SGS/TLH DRLG DRAFT CORRECTIONS PRUDHOE BA Y UNIT WELL: 11-06A PERMIT No: "'2042250 API No: 50-029-20674-01 SEC33, T11N, R15E, 3977.22' FEL & 3381.92' FNL BP Exploration (Alaska) 11-.A Proposed Comttetion ~ TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD - DatumlVD = FMC GEN 2 CrN BAKER C 62' 31' 3200' 93 @ 10878' 10817' 8700' SS 113-3/8" CSG, 72#, L-80, 10= 12.347" 2515' I 7" TIEBACK, 26#, L-80, CEMENTED TO SURFACE H 5983' ITOPOF 7" SCAB LNR I 5983' Minimum ID = 1.92" @ 9328" 3-1/2" X 2-3/8" XO 14-1/2" TBG, 12.6#, 13-CR. .0152 bpf, 10 = 3.958" r 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" r 17" LNR-TIEBACK, 29#, L-80, .0371 bpf, ID = 6.184" H 1 9-5/8" CSG, 47#, L-80, ID = 8.681" r IWFD WHIPSTOCK & ANCHOR (11/23/04) r IRA TAGr 3-1/2" LNR, 9.3#, 13CR80 (01/27/04),10 = 2.992" ÆRFORATION SUMMARY REF LOC; 7?? SHCS ON C1/?.2/82 ??? ANGLEATTOPÆRF: 81 @ 10780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-9/16" 6 10780 - 10800 0 02/13/05 1-9/16" 6 10830 - 10850 0 02/13/05 1-9/16" 6 10880 - 10900 0 02/13/05 1-9/16" 6 10986 - 11120 0 12/28/04 1-9/16" 6 11142 - 11254 0 12/28/04 1-9/16" 6 11284 - 11374 0 12/28/04 1-9/16" 6 11470 - 11490 0 12/28/04 1-9/16" 6 11520 - 11530 0 12/28/04 1-9/16" 6 11606 - 11634 0 12/28/04 1-9/16" 6 11650 - 11665 0 12/28/04 DATE 01/30/82 08/28/97 12/31/01 01/24/04 12/28/04 02/07/03 REV BY COMMENTS ORIGINAL COMPLETION RWO DAC/KK RWO JAF/TLP CTU #9 LNR DH CTD SIDETRACK (11-06A) JMP/KK WAIVER SAFETY NOTE -2100 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 2 3 4 5983' -1BAKERZXPPKR I -14-1/2" HES X NIP, 10 = 3.813" -17" X 4-1/2" BAKER S-3 PKR, 10 = 3.875" 4-1/2" HES X NIP, 10 = 3.813" 4-1/2" UNIQUE OVERSHOT 7" X 4-1/2" BAKER S-3 PKR, 10 = 3.875" -14-1/2" HES X NIPW/ RHC SLY, 10 = 3.813" -1 TOP OF CMT (2-3/8 LNR) I -13.70" BKR DEPLOY SLY, ID = 3.00" (12/28/04) H 3-1/2" X 2-3/8" XO, ID = 1.92" I -13.70" DEPLOYMENT SLY (BEHIND PIPE) I -9100 -9200 9243' 9369' 9524' 9700' 10557' I -14-1/2" UNIQUE OVERSHOT (BEHIND PIPE) -17" X 4-1/2" BAKER S-3 PKR (BB-IIND PIPE) -17" BAKER LNR HGR (BB-IIND PIPE) I -1 CALC TOP OF CEMENT (BEHIND PIPE) MILLOUT WINDOW (11-06A) 10067' - 10073' IPBTD 12-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" H DA TE REV BY COMMENTS 07/22/03 JCrvttTLH GLV C/O 10/18/05 SGSITLH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 11-06A ÆRMIT No: 72042250 API No: 50-029-20674-01 SEC 33, T11 N, R15E. 3977.22' FEL & 3381.92' FNL BP Exploration (Alaska) SchlUlobepgep NO. 3654 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECE'VED JAN 0 9 Z006 ~OIt&Gaseons. eomm\SSiOO Ancttofage Field: Prudhoe Bay, Milne pt. Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# Loa Description Date BL Color CD 11-0GA ^"^A -~,;;)-r 10928610 MCNL (Prints & Film sent 01/18/05) 12/24/04 1 L3-05 11058540 RST 11/10/05 1 1 G-11A 11084277 RST 07/12/05 1 1 L3-11 11072883 RST 08/09/05 1 1 L2-32 11136742 RST 11108/05 1 1 E-33A 11075912 MCNL 08/23/05 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A~B.~ R~'edb,· . . . I() Date Delivered: 01/06/06 . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I July 7,2005 RE: MWD Formation Evaluation Logs: 11-06~ AK-MW-3444751 1 LDWG formatted Disc with verification listing. API#: 50-029-20674-01 IJ~D? PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITfAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: / -L¡t~ j- Signed: /J/-J IJ/L¡ ) {; ~( - Á Á C (.'/t - · STATE OF ALASKA . Rrne~æ,..~V-- ALASK~IL AND GAS CONSERVATION COrZSSION c:: cED REPORT OF SUNDRY WELL OPERATIONSPR 1 9 2005 1. Operations Performed: Stimulate [jlaska Oil & Gas ßJn.rlCìmmission Abandon D Repair Well 0 PluQ Perforations 0 Alter CasingD Pull TubingD Perforate New Pool D WaiverD TinAndtOf\Sge D Change Approved Program D Operation Shutdown 0 Perforate ŒJ Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 204·2250 3. Address: P.O. Box 196612 6. API Numbe Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-20674-01-00 7. KB Elevation (It): 9. Well Name and Number: 62.00 11-o6A 8. Property Designation: 10. Field/Pool(s): ADL-028325 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11720 feet true vertical 8780.3 feet Plugs (measured) None Effective Depth measured 11684 feet Junk (measured) None true vertical 8781.3 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 32 - 112 32.0 - 112.0 1490 470 Liner 4084 7" 29# L-80 5983 - 10067 5539.4 - 8505.7 8160 7020 Liner 745 3-1/2" 9.2# 13Cr80 9322 - 10067 7907.3 - 8505.7 10160 10530 Production 8860 9-5/8" 47# L-80 31 - 8891 31.0 - 7582.3 6870 4760 Production 958 9-5/8" 47# SOO-95 8891 - 9849 7582.3 - 8328.4 8150 5080 Surface 2484 13-3/8" 72# L-80 31 - 2515 31.0 - 2514.9 4930 2670 Perforation depth: Measured depth: 10780 - 10880, 10880 - 10900, 10986 - 11120, 11142 - 11254, 11284 - 11374, 11470 - 11490, 11520 - 11530 11606 - 11634, 11650 - 11665 True vertical depth: 8757.06 - 8762.01, 8762.01 - 8761.21, 8761.26 - 8770.49, 8771.07 - 8773.05, 8772.09 - 8773.91, 8775.46 - 8776.33 8777.98 - 8778.56, 8783.23 - 8783.43, 8782.7 - 8781.95 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 21 - 9369 4-1/2" 12.6# L-80 @ 9369 - 9441 Packers & SSSV (type & measured depth): 7" Baker ZXP Top Packer @ 5983 4-112" Baker 5-3 Perm Packer @ 9243 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 341 2.2 4453 1500 216 Subsequent to operation: 1118 4.5 4614 1650 222 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI Service 0 Copies of Logs and Surveys run _ 16. Well Status alter proposed work: Daily Report of Well Operations_ ! OilŒ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron be Production Technical Assistant ¡ Signature ß1/.- ~_........ C r. r;-~ ì ~.'\ I hone 564-4657 Date 4/13/05 a _. I Form 10-404 Revised 4/2004 K17m~ L( I)~ . . 11-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/09/05 ***WELL FLOWING UPON ARRIVAL***(PRE CTU ADPERF). DRIFT W/ 1.67 DUMMY GUN (12' 10" OAL) TO 10,050' SLM. STOP DUE TO DEV.***NOTIFY DSO WELL IS READY TO POP*** 02/11/05 MIRU CTU 9 PDS LOG CCUGR 11,160 (STACK OUT DEPTH) TO 10,700' GIH WITH 1ST PERF GUN RUN. DROP BALL -FIRE GUN # 1 FOR PERF INT 10880-10900' POH - GUN DIDN'T FIRE. 02/12/05 RE-RUN GUN. PERFORATE 10880'-10900' 6 SPF. 02/13/05 **** CONTINUED FROM 2/12/05 WSR **** LD LOG TOOL - VERIFY GOOD DATA- MU/RIH WITH GUN # 2 -(1.56" HSD GUN-6 SPF-1606 POWERJET,HMX) GUNS FIRED PERFORATE INTERVAL 10,830-10850' POH WITH GUN #2 - ALL SHOTS FIRED - MU / GIH WITH GUN RUN #3. SET ON PERF DEPTH 10780-10800' POH WITH GUN # 3 - ALL SHOTS FIRED. FREEZE PROTECT SURFACE EQUIPMENT AND LINES - RDMO **** JOB COMPLETE **** FLUIDS PUMPED BBLS 68 1 % KCL 469 60/40 Methonal 537 TOTAL Page 1 TREE I/'./ELlHEAO = AèñJÂTOFr;~' KB. ELEV = BF. ELEV = KOP= ~~~~"Q!~~,,~ Datum MD = Datum lVD = FMC GEN 2 CM! BA'Rffic 62 31 3200' ~9~<g),,§,~9,9' 10396' 8700'SS . FROM - 0 RAFT 113-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID = 1.92" @ 9327' 3-1/2" X 2-3/8" XO I TOP OF 7" SCAB LNR I 5983' Top of 2 3/8" Hner. top of Cement 1- 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" r TOP OF 7" LNR 7" LNR- TIEBACK, 29#, L-80, .0371 bpf, 10 = 6.184" 19-5/8" CSG, 47#, L-80 & SOO-OS, ID = 8.681" IMechanicai VVhipstock r 3-'1/2" LNR, 9.3#. 13-Cr, 0.0087 bpf, ID = 2.992" 10371' ÆRFORA TION SUMMARY REF LOG BHCS ON 01/22/82 ANGLE AT TOP ÆRF: XX @ 10780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1.56" 6 10780 - 10800 0 02/13/05 1.56" 6 10830 - 10850 0 02/13/05 1.56" 6 10880 - 10900 0 02/13/05 1.56" 6 10986 - 11120 0 12/28/04 1.56" 6 11142 - 11254 0 12/28/04 1.56" 6 11284 - 11374 0 12/28/04 1.56" 6 11470-11490 0 12/28/04 1,56" 6 11520 - 11530 0 12/28/04 1.56" 6 11606 - 11634 0 12/28/04 1.56" 6 11650 - 11665 0 12/28/04 I 7" LNR, 29#, L-80, BTC, 0.0371 bpf, 10 6,184" TO 10558' 1 0557' DATE 01/30/82 08/28/97 12/31/01 12/28/04 12/08/01 02/07/03 01/28/04 REV BY COMMENTS ORIGINAL COMPLETION WORKOVER DAC/KK LAST WORKOVER CTD SIDETRACK (11-06A) TMNlTLH TUBING CUT JMP/KK WAIVER SAFETY NOTE JAFITLP MIN 10, DEPLOY SLY, X NIP, CMT DA TE REV BY COMMENTS 02/06/04 BJMcNlK FISH 09/10/04 JGMlTLP CT GS TO LA TCH 09/30/04 KCFITLP FISH 11/30/04 MSE ADD DRLG DETAILS 03/06/05 JLGITLH GLV C/O & ADÆRF (02/12/05) PRUDHOE BA Y UNfT WELL: 11-06/1. ÆRMfT No: API No: 50-029-20674-01 SEC 33, T11 N, R15E, 3977.22' FEL & 3381.92' FNL 11-06' S~ NOTES: CHROME TBG. **IA x OA COMM. OP"-ING PRESSURE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (02107/03 WAlVER)** **3-1/2" LNR & 4-1/2" CHROME TBG** Proposed CTD Sidetrack 2082' 4-1/2" HES X NIP, 10 = 3.813" ST MD lVD 5 3319 3300 4 5025 4825 3 6018 5564 2 6378 5820 1 9215 7820 GAS LIFT MANDRELS DEV TYÆ VLV LATCH KBG-2 DOME RK KBG2 SO RK KBG-2 DMY BK MMG-M DMY BK Iv1MG-M DOME BK PORT DATE 16 01/03/05 20 01/03/05 o 12/31/01 o 12/31/01 o 12/31/01 -l BAKER ZXP PKR I -l 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" -l 4-1/2" HES X NIPW/ RHC SLY, 10 = 3.813" I H 3-1/2" X 2-3i8" XO, ID = 192" (ÆR C/l.O 1/6/05) 3-1 i2" DEPLOY SLV. ID '" 3 00" (ÆR CA 0 1 !G/Ob) ( , ~;:::~'f c '1 ,¿] ,:::;) ¡ /, >~¡¡ ;= ; '-.<' " ;--? ~:::,- IS> ,r\ I "')6 clJ1 T' BAKER liNER HANGER I CALCTOC I 11720' I I PSTD H fish cut and retrieved below 10200' FISH - 20' BHA (JARS, MOTOR, MILL) 5/8" STEEL DISCONNECT BALL IN CT BP Exploration (Alaska) · STATE OF ALASKA. RECEIVI!O ALASKA OIL AND GAS CONSERVATION CO~SSION . ".20òS REPORT OF SUNDRY WELL OPERATIONSAPRt ~ - 1. Operations Performed: Stimulate D Alaska Oil & \j8S \,tuna. Abandon D Repair WellO Pluç¡ PerforationslKl Arfèttöfijè Alter Casing D Pull TubingO Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operation Shutdown 0 Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 204-2210 3. Address: P.O. Box 196612 6. API Numbe Anchorage, Ak 99519-6612 Stratigraphic D Service ŒI 50-029-23233-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.90 MPB-27 8. Property Designation: 10. Field/Pool(s): ADL-047438 Kuparuk River Field I Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 8480 feet true vertical 4544.7 feet Plugs (measured) None Effective Depth measured 8480 feet Junk (measured) None true vertical 4544.7 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 94# H-40 35 - 114 35.0 - 114.0 1530 520 Liner 1009 4-1/2" 12.6# L-80 7471 - 8480 4489.7 - 4544.7 8430 7500 Production 7581 7" 26# L-80 33 - 7614 33.0 - 4520.5 7240 5410 Surface 3558 9-5/8" 40# L -80 35 - 3593 35.0 - 2862.7 5750 3090 Perforation depth: Measured depth: 7298 - 7308 True vertical depth: 4427.97 - 4431.52 Tubinç¡ ( size, ç¡rade, and measured depth): 4-112" 12.6# L-80 @ 31 - 7468 3-112" 9.3# L-80 @ 7468 - 7512 Packers & SSSV (type & measured depth): 4-112" Baker ZXP Packer @ 7483 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl I Gas-Met I Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: No Prior Injection Subsequent to operation: Well Shut-in 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ Oil 0 GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature l1ILA .A C~;b-~ Phone 564-4657 Date 4/15/05 ~ Form 10-404 Revised 4/2004 tJ I···' j f 11\1 /~ L ~ ,ß))/v15 if (~~5 Ii - . . MPB-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/10105 *** WELL SI ON ARRIVAL ***. ATTEMPT TO PULL JET PUMP, COULD NOT PASS 3000' SLM. DRIFT WI GAUGE RING & BRUSH.. PULL JET PUMP (BP-1077, 4C).. PULL DV & SET ORIFICE VALVE. DRIFT TO 7400' SLM WI 3.70" CENT.. *** WELL LEFT SI *** 02/12/05 Set CIBP @ 7400' 02/14/05 Perforate 7298'-7308' 6 SPF FLUIDS PUMPED BBLS : o TOTAL No Fluids Pumped Page 1 Tree: Cameron 41/16.' Wellhead: FMC 11" x M, Gen. 5 wI 11" x 4.5" FMC Tbg. Hnr. w/4.5 TC-11 Top & Btm." 4" CIW 'H' BPV profile 20" 92 ppf, H-40 I 80' KOP @ 300' Max. hole angle = 64 to 70 deg. fl 2900' to 7,500' Hole angle through perfs = 90 deg. 95/8",40 ppf, L-80 Btrc. I 3,593' I 4.5" 12.6 ppf, L-80 IBT-M tubing (cap. = 0.0152 bpf, drift = 3.958") 7" 26 ppf, L-80, btc production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) Short Joint 7,115 -7,125' 7" "RA Tag" Installed in cOUPling 7,115' Tubing and Casing perforated at 7298' MD - 4428' TVD 7308' MD - 4432' TVD I ~akêVCIB~ 7400'1 Perforation Summary Ref log: Size SPF Interval (TVD) Weatherford Float Collar I 7,527' Weatherford Float Shoe I 7,614' MPU B-27i DATE 12/07/04 REV. BY COMMENTS MDO Drilled and completed by Doyon-14 .. . KB. elev. : 57.3?' . GL. elev.- 23.3 . DF. elev. = 56.9' 4.5"x1" Cameo KGB-2 GLM I 2,762' I NOTE: Minimum id 2.90" @ 7,468' I 7,186' I I 7,251' I I 7,479' I 7,500 - 7,512 7,471' 7,483' 7,490' Baker 80-40 Seal bore ex!. 5" 7,498' - 7,517' 4.5" "XD" Duro slv. 4.5" HES XN-Nipple (3.725") Baker No-Go Locator 4" Bonded seal assy. Baker Tie back sleeve 7"x5" Baker'zxp Liner top Baker HMC liner hgr. w/dg slips HES 4.5" "V" Float shoe I 8480' I 20 joints of slotted liner 7,605' - 8,425' MILNE POINT UNIT WELL B-27i API NO: 50-029-23233-00 01/18/05 Schlumberger NO. 3307 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay (((. '].0'-0 1f2-o j ft5 "/~ '?Ð"'.ZtS ! 'fr...(rð Color . Well Job# Log Description Date Blueline Prints CD 3 D-11A 10928608 MEM PROD/INJECTION PROFILE 12/16/04 1 IU DS 07-30A 10715445 MEM PROF & IPROF 12/09/04 1 1/ DS 14-09B 10964105 LEAK DETECTION 12/23/04 1 .2, P2-56 10830819 RST 06/20/04 1 1 DS 11-06A 10928610 MCNL (PRINT ONLY-NO CD) 12/24/04 1 E-21A 10670030 MCNL (PRINT ONLY-NO CD) 08/22/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 "",horn,,, AK 99~ ATTN: Beth ~ Received by: 1 ~ .. __ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO.SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 370' SNL, 57' WEL, SEC. 33, T11 N, R15E, UM Top of Productive Horizon: 2174' NSL, 3463' WEL, SEC. 28, T11N, R15E, UM Total Depth: 1725' NSL, 2704' WEL, SEC. 28, T11 N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 7075Q~ y- 595~_353 Zone- ASP4 TPI: x- 704026 y- 5953803 Zone- ASP4 Total Depth: x- 704799 y- 5953375 Zone- ASP4 --- ---- -- --- - --- -- 18. Directional Survey IBI Yes 0 No One Other 5. Date Comp., Susp., or Aband. 12/27/2004 6. Date Spudded 12/16/2004 7. Date T.D. Reached 12/22/2004 8. KB Elevation (ft): 62' 9. Plug Back Depth (MD+ TVD) 11684 + 8781 10. Total Depth (MD+ TVD) 11720 + 8780 11. Depth where SSSV set (Nipple) 2082' MD 19. Water depth, if offshore NI A MSL 21. Logs Run: MWD I GR I ROP, Memory Induction, MGR I CCL I CNL 22. CASING, LINER AND ( EMENTING RECORD HOLE SIZE 30" 17-1/2" 12-1/4" 8-112" NIA CASING . SETTING JEPTH MD SETTING DEPTH TVD SIZE W'T; PEA FT. GRADE lOP I tsOTTOM Top BoTTOM 20" 94# H-40 Surface 80' Surface 80' 13-318" 72# L-80 Surface 2515' Surface 2515' 9-5/8" 47# L-80 I SOO-95 Surface 9849' Surface 8328' 7" 29# L-80 5983' 10067' 5555' 8506' 3-1/2" 9.3# 13Cr80 9340' 10067' 7921' 8506' 2-318" 4.7# L -80 9322' 11720' 7907' 8780' 23. Perforations open to Production (MD + TVD of Top and 24. Bottom Interval, Size and Number; if none, state "none"): 1.56" Gun Diameter, 6 spf MD TVD 10986' - 11120' 8761' - 8770' 11142' - 11254' 8771' - 8773' 11284'-11374' 8772'-8774' 11470' - 11490' 8775' - 8776' 11520' - 11530' 8778' - 8779' 11606' - 11634' 8783' - 8783' 11650' - 11665' 8783' - 8782' MD 27. 3" . SIZE 4-112",12.6#, 13Cr & L-80 TVD 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-225 13. API Number 50- 029-20674-01-00 14. Well Name and Number: ~BUTf-06A 15. Fiel9J'Pool(s): Hl'Ódhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028325 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ..... ~~~:~ 1250 sx Permafrost 'C' 12300 sx Fondu, 400 sx PF 'C' 500 sx Class 'G' 350 sx Class 'G', 109 sx Class 'G' Scab Liner - 106 sx Class 'G' (Approx.) 50 sx Class 'G' llJälNG DEPTH SET (MD) 9441' ..... PACKER SET (MD) 9406' & 9243' 25. ACID,FAAC'Tl,JAI;.CEMEI'fr $QU¡:EZE.ETC, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected wI 33 Bbls of MeOH GAs-McF 200 WATER-BsL 741 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 4, 2005 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BsL 1/11/2005 4.1 TEST PERIOD + 31 Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 20ï 1,379 24-HoUR RATE 183 GAs-McF 1,171 CORE DATA Brief d.e. S. c',' .r..iP.. t. iO. n. ..Of...lithoI09y, porosity, fractures, apparent dips and presence of oil, gas or water (att~. '...... "sn;~t~~~!. necessary). sUbryitcore chip~;if none, state "none". r(~E':C;E: ~ ì;." t~' None I ,%',C:; ~ ~ .., ~, ~ . , 1'EP",~':1 ¡ ._.QL-.. ¡ \...,.;..,.._~. '_.....----~ WATER-BsL 4,340 RBDMS BFL JAN 2 4 2005 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO 89.53 6,406 OIL GRAVITY-API (CORR) , !\ !\' ~ ¿' J¡L\!~ 1 '';} ~F , 28. GEOLOGIC MARK NAME MD 27P I Base CGL 10113' 25P 10229' 24N 10255' 23N 10321' 23P 10339' 22P 10364' Zone 1 B 10660' 14N 10752' 14P 10780' 13N 11553' 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8539' None 8606' 8621' 8657' 8666' 8679' 8739' 8752' 8757' 8780' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant PBU 11-06A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 204-225 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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 26: 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 1 0-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: nom 12/12/2004 115:00-18:00 r I 118:00 : 22:00 i 22:00 - 23:00 123:00 - 23:15 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/1/2004 12/27/2004 N1 Spud Date: 12/27/1981 End: , 123:15 - 00:00 12/13/2004 j 00:00 - 04:00 1 I I 104:00 - 11 :00 ! 11 :00 - 12:00 112:00 - 18:30 I r I 118:30 - 18:45 ! 18:45 - 19:00 119:00 - 21:00 i 21 :00 - 22:30 122:30 - 00:00 12/14/2004 i 00:00 - 05:30 ! ¡ 105:30 - 06:30 106:30 - 08:30 108:30 - 09:30 'I 109:30 - 10:00 10:00 - 12:00 , i 1 112:00 - 14:15 114:15 - 17:30 i i I 1 i I 117:30 - 21 :18 121:18 - 23:20 23:20 - 00:00 12/15/2004 00:00 - 00:30 3.00 MOB P PRE 4.00 MOB P PRE 1.00 MOB P PRE 0.25 MOB P PRE 0.75 MOB P PRE 4.00 MOB P PRE 7.00 MOB N WAIT PRE 1.00 MOB P PRE 6.50 MOB P PRE 0.25 MOB P PRE 0.25 MOB P PRE 2.00 BOPSU P PRE 1.50 RIGU P PRE 1.50 RIGU P PRE 5.50 BOPSU P PRE 1.00 RIGU P PRE 2.00 RIGU P PRE 1.00 STWHIP P WEXIT 0.50 STWHIP P WEXIT 2.00 STWHIP N WAIT WEXIT 2.25 STWHIP P WEXIT 3.25 STWHIP P WEXIT 3.80 STWHIP P WEXIT 2.03 STWHIP P WEXIT 0.67 STWHIP P WEXIT 0.50 STWHIP P WEXIT Secure reel in reel house for reel swap. Change out choke hose in rig cellar. Lay down windwall and mast. Move rig off well. SAFETY MEETING. Review rig move procedure, hazards and mitigation with Nordic, SWS, Security, Tool service and BP personnel. Derrick Down rig move to OS 11-06A. Move rig to FS-2. Was not able to shut down power on substation because the backup generators were to cold to start. Wait for power to be shut down. 7 hrs standby. Move rig to OS 11. Raise windwalls and derrick. Pick up injecter head out of pipe bay. Swap CT reels with Peak crane. SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. Back rig over well. RIG ACCEPTED AT 1900 hrs 12-13-2004 Nipple up BOPE to tree. Position trailers, and tiger tank berm. Positon tiger tank and cuttings tank. R/U hardline and pressure test. Stab new 2" coil into injecter head. Grease tree and rig valves with grease crew. Pressure I Funtion test BOPE. Witness waived by AOGCC. Sent test report to AOGCC. Fill rig pits with Biozan water. Weld on CT connecter. Pull test. Prep floor. Service power pack, Load Weatherford tool. PT hard line. Fill coil and pump dart. Dart landed at 40.2 bbl. PT inner reel valve. MU BHA #1 mill and straight motor. Wait on arrival of Schlumberger UTEM [Universal tubing integrity monitor], Stab onto well and circulate. Install, Calibrate UTEM and check. RIH with WFD 2.80" milling BHA with straight motor. Tag WFD whipstock at 10,067.5'. Correct to 10,067.0'. Whipstock TF at 19R. Milling 2.80" window thru 3.5", 9.3#, 13-CR Liner. 1.8/1.8 bpm, 1700-2000 psi, 1500# WOB, 4 stalls to get started. Very slow milling. Not sliding well. Milling with 2% KCL with 1 PPB Biozan to start. Increased it to 1.5 PPB Biozan to get better slide with chrome tubing. Milled to 10068'. Milling 2.80" window, 1.8 bpm, 2000 - 2200 psi, 3K# WOB, Slow milling. Milling 3-1/2" liner exit Qp = 1.84 bpm at 2743 psi on bottom WOB = 3 to 4 k Milled 6 ft from WS pinch point. Reaming window area from 10,067 ft to 10,073 ft Reaming window area 10,067 ft to 10,073 ft Dry ran through window, clean, Painted flag at 9,990 ft EOP Printed: 12/31/2004 9:22:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -06 11 -06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 12/1/2004 12/27/2004 N1 Spud Date: 12/27/1981 End: Start: Rig Release: Rig Number: 03: 15 - 05:30 05:30 - 05:40 05:40 - 06:15 06:15 - 10:00 10:00 - 11 :30 11 :30 - 12:30 12:30-15:15 15:15 - 17:00 17:00 - 19:00 19:00 - 19:50 19:50 - 21 :20 21 :20 - 22:00 22:00 - 22:15 22:15 - 00:00 12/16/2004 00:00 - 00:15 00:15 - 00:45 00:45 - 01 :00 01 :00 - 01 :30 01 :30 - 01 :35 01 :35 - 02:30 02:30 - 03:45 03:45 - 04:15 2.25 STWHIP P 0.17 STWHIP P 0.58 STWHIP P 3.75 STWHIP P POOH to PU BHA # 2 Stood back injector. LD 2" CSH and BHA, Gauged mills DSM gauged at 2.8" PU 2.5 deg motor w/ 2.8" Flat Radius Mill, Sperry' MOP I MWD package and MHA WEXIT RIH, SHT, Orientor test at 3100 ft, OK Corrected -1 ft at EOP flag WEXIT PT liner to 500 psi. pressure up to 600 psi and pressure dropped to 150 psi in 2-3 minutes. Test failed, gave you one WEXIT Orient TF WEXIT Milling 2.80" window thru 7", 29#, L-80 Liner. 1.8/1.8 bpm, 2800 - 3000 psi, 40R TF, 600# WOB, Mill as per milling schedule. Milled to 10,074.7'. TF was walking to the left. Picked up to orient TF and MWD failed. Could not get working again, no signal. DFAL WEXIT POH for failed MWD. High G totals while milling with bent motor, indicating high amount of vibration. DFAL WEXIT C/O MWD probe and check mill / motor I orienter. DFAL WEXIT RIH, SHT at 3100', OK. Orienter got 2 for 2 clicks. RIH and correct to flag [-4.6']. RIH with highside TF. Tag bottom, pick up to orient, Pulser quit again. Not able to get started again. POH for MWD failure. Same problem as last time. Sperry looking at all posibilities. C/O Sperry Probe again. C/O motor. Re-run Mill. Cut off 100 ft of coil and weld on CTC every 3 trips per SWS policy for chrome tubing. Welded on CTC, Pull tested to 35k and PT to 3200 psi PU new 2.5 deg motor and RR mill. Scribed HS RIH. Changed out O-ring on lubricator SHT at 3300 ft and 3800 ft. Unable to get orienter to work Unable to get it to work POOH to change orienter Change our orienter RIH Tested orienter at 3300 ft OK, RIH RIH Orient TF to 20R RIH tagged at 1074.7 ft Off NPT time at 0100 hrs 12-16-2004 (15 hrs NPT) Orienting to get resultant TF at HS or RHS Milling window Qp = 1.8 BPM at 3000 I 3200 psi TF @ 28R WOB = 13481b Lost Gen #1, PUH and reset, RIH and try to re-establish TF TF rotated to 110 R, PU and trying to orient TF Finally Milling window with 100 psi motor work Qp = 1.8 BPM at 3100 13411 psi TF @ 22R WOB = 1800 Ib to 2200 Ib Lost Pp, WOB and TF rolled R. PUH = 31.5k WEXIT SD pump, RIH dry tagged 10074.5 ft, PUH and orient TF to HS RIH and tagged at 10,078 ft PUH and RIH with pump TF 39R Tagged at 10077.1 ft. Had some motor work and WOB then fell off, like we are in formation. Cir bottoms up i I I 1.501' STWHIP N 1.00 I STWHIP N 2.751 STWHIP N 1.75 STWHIP N DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT WEXIT WEXIT WEXIT WEXIT 2.00 STWHIP N 0.83 STWHIP N 1.501 STWHIP N 0.67 STWHIP N 0.25 STWHIP N 1.75 STWHIP N 0.25 STWHIP N 0.50 STWHIP N 0.25 STWHIP N 0.50 STWHIP P 0.08 STWHIP P 0.92 STWHIP P 1.25 STWHIP P 0.50 STWHIP P Printed: 12/31/2004 9:22:20 AM BP Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/1/2004 12/27/2004 N1 Spud Date: 12/27/1981 End: I 0.33 STWHIPI P Drilled down to 10,078.3 ft, PUH, clean, Drilled down to 10,079 I ft 04:35 - 04:45 STWHIPI P WEXIT PUH to Tie-in @ 9874 ft 04:45 - 05:15 0.50 STWHIPi P WEXIT Logging + 1 ft correction 05:15 - 05:40 0.42 STWHIPI P WEXIT RIH, washed down to 10,080 ft. Drilled down to 10,082 ft, with ! 5000 Ib WOB. PUH clean 31 k. I Top of window at 10,067'. I I Bottom of window at 10,078'. I 05:40 - 07:20 1.67 STWHIP! P WEXIT Drilling formation for rathole, 1.8/1.8 bpm, 2900 - 3300 psi, I 11R, I 07:20 - 07:50 0.50 STWHIPI P WEXIT Backream window. Ream down. Swap well to new FloPro. 07:50 - 09:30 1.67 STWHIPlp WEXIT Drill formation, 1.6/1.6 bpm, 3050 - 3500 psi, 20R, 5000 I WOB, 4 fph. Drilled to 10,088'. I 09:30 - 10:30 1.00 STWHIPI P WEXIT Backream window. Ream down. Power failure while reaming down. ! Phase 2 weather. I 10:30 - 12:00 1.50 STWHIP! N RREP WEXIT Change SCR assignments, pull up 200' and test power supply. Electrician checked out SCR panel, found burned out control module, CIO and Tested OK. 12:00 - 13:00 I 1.00 STWHIP! P WEXIT Ream down thru window. Ream up clean. RIH with no pump I clean to bottom. I 13:00 - 14:30 1.50 STWHIPI P WEXIT POH for drilling build BHA. 14:30 - 15:00 0.50 DRILL Ip PROD1 SAFETY MEETING. Held Pre-Spud meeting with all I personnel, reviewed well plan and hazards. Held PJSM and I reviewed procedure, hazards and mitigation for M/U MWD build BHA. 15:00 - 15:50 0.83 DRILL Ip PROD1 M/U 1.7 deg motor and a used 2.75 x 3.0" HC BC Bit #5. M/U ! Sperry MWD tools, check orienter, M/U Baker MHA. OAL = 58.98' 15:50 - 17:45 1.92 DRILL Ip PROD1 RIH with MWD Build BHA #5. Circ at 0.2 bpm while RIH. SHT at 3100 ft. OK. RIH. 17:45 - 18:00 0.25 DRILL p PROD1 Orient TF to 25R. 18:00 - 19:00 1.00 DRILL P PROD1 Tag TO on depth at 10,088'. Drill build section in Zone 3. 1.81 1.8 bpm, 3250 - 3900 psi, 50R, 19:00 - 19:30 0.50 DRILL p PROD1 PUH to tie-in at 9920 ft No correction 19:30 - 20:00 0.50 DRILL P PROD1 RIH and orient TF to 1st Q 20:00 - 20:25 0.42 DRILL P PROD1 PUH logging RA Marker. RA Marker at 10,072 ft TOW at 10,067 ft 20:25 - 20:55 0.50 DRILL P PROD1 Drilling build section in basal of ZIII w/ TF at 70 R. TF walked R Qp= 1.50bpm Pp 2800 I 2850 psi Vp = 215 bbl 20:55 - 21:15 DRILL P PROD1 Orient TF around 21 :15 - 23:20 DRILL P PROD1 Drilling build section in Zone II w/ TF at 86 to 100 R. Adjusting TF as we go Qp = 1.8/1.91 bpm Pp 3200 / 3300 psi Vp = 217 bbl 23:20 - 23:40 DRILL P PROD1 Orient TF around to 80R 23:40 - 00:00 0.33 DRILL P PROD1 Drilling build section in Zone II wI TF at 86 to 100 R. Qp = 1.8/1.91bpm Pp 3200 / 3274 psi Vp=217bb ROP = 110 to 150 fph 12/17/2004 00:00 - 00:20 0.33 DRILL P PROD1 Drilled to 10270 ft Printed: 12/31/2004 9:22:20 AM BP Operations Page 4 ot12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/1/2004 12/27/2004 N1 Spud Date: 12/27/1981 End: 12/17/2004 00:20 - 00:35 0.25 DRILL I: PROD1 Wiper trip to WS 00:35 - 01 :20 0.75 DRILL PROD1 Drilling build section in Zone II wI TF at 86R. TF walking R I Qp = 1.8 11.91 bpm Pp 3100 I 3250 psi Vp = 216 bb ROP = 35 fph 01 :20 - 01 :45 0.42 DRILL P PROD1 Orient TF around 01 :45 - 02:45 1.00 DRILL P PROD1 Drilling build section in Zone II w/ TF at 86R. Qp = 1.8/1.91bpm Pp 3150/3300 psi Vp = 216 bb ROP = 10-35 fph Stacking 02:45 - 03:10 0.42 DRILL P PROD1 Wiper trip to WS 03:10 - 03:35 0.42 DRILL P PROD1 Drilling build section in Zone II wI TF at 86R. Qp = 1.84/1.91bpm Pp 3280 I 3600 psi Vp = 216 bbl ROP = 50-100 fph 03:35 - 03:50 0.25 DRILL P PROD1 Orient TF around to 45R 03:50 - 05:45 1.92 DRILL P PROD1 Drilling build section in Zone II wI TF at 45R to 86R . Qp = 1.8 11.91 bpm Pp 3150/3380 psi Vp=214bb ROP = 50-125 fph 05:45 - 07:45 2.00 DRILL P PROD1 Landed at 10,500 ft MD & 8,658.46 ft TVD. POOH Phase II driving conditions 07:45 - 08:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. 08:00 - 09:15 1.25 DRILL P PROD1 Adjust motor to 1.1 deg bend. CIO Sperry probe. Check orienter. MIU new HCC 2.75 x 3.0" Bi-center Bit #6. OAL = 58.9'. 09:15 - 10:15 1.00 DRILL N RREP PROD1 Maintenance on SCR panels. C/O power pack fan and fan motor. 10:15 - 10:45 0.50 DRILL P PROD1 RIH with BHA #6 to 1000'. SHT tools. Sperry pulser showing weak pulse. POH. 10:45 -11:15 0.50 DRILL N DFAL PROD1 CIO Sperrry probe. 11:15 -13:45 2.50 DRILL P PROD1 RIH with Lateral MWD BHA #7. SHT tools. OK. RIH. 13:45 - 14:15 0.50 DRILL P PROD1 Log GR tie-in above window. subtract 1 ft CTD. 14:15 - 15:30 1.25 DRILL N RREP PROD1 Park bit at 9900'. SWS mechanics checking vibration in power pack traction motor. Front bearing is wearing out and causing vibration. Noise level has increased and brass from bearing wear was seen. Not safe to run coil in openhole because we cannot move coil for several hours if traction motor fails. 15:30 - 17:00 1.50 DRILL N RREP PROD1 POH to C/O power pack traction motor. 17:00 - 17:30 0.50 DRILL N RREP PROD1 Layout BHA #7. 17:30 - 18:30 1.00 DRILL N RREP PROD1 Make ready to cut 100 ft CT. 18:30 - 18:45 0.25 DRILL N RREP PROD1 PJSM on way forward 18:45 - 20:30 1.75 DRILL N RREP PROD1 Pumped water back in CT, close SV Cut off 100 ft CT and weld on CTC Pulled tested to 30k and PT to 4000 psi. 20:30 - 00:00 3.50 DRILL N RREP PROD1 Electrician LOTO SCR and safe out PP traction motor RD PP traction motor, wind still gusting to 40 mph, ave at 20 mph 12/18/2004 00:00 - 06:00 6.00 DRILL N RREP PROD1 RD power pack traction motor and still waiting on winds. Velocity = 20 to 35 mph Printed: 12/31/2004 9:22:20 AM EXPLORATION 5 öf 12 Legal Well Name: 11 -06 Common Well Name: 11-06 Spud Date: 12/27/1981 Event Name: REENTER+COMPLETE Start: 12/1/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 12/27/2004 Rig Name: NORDIC 1 Rig Number: N1 NÞ-r·1 Phase 12/18/2004 00:00 - 06:00 6.00 DRILL N RREP PROD1 Tractor motor ready to pick with crane At 0600 hrs Wind speed is 22 mph and gust to 35 and 40 mph Forecast is the same 06:00 - 12:00 6.00 DRILL N RREP PROD1 WOW. Wind at 23-40 mph, Rig maintenance while WOW for Peak crane. 12:00 - 18:00 6.00 DRILL N RREP PROD1 WOW. Wind at 27-42 mph, Rig maintenance while WOW for Peak crane. 18:00 - 00:00 6.00 DRILL N RREP PROD1 WOW. Looking at alternative of getting traction motor in pipe shed Orginanizing pipe shed to bring in traction motor Phase II at 2030 hrs 12/19/2004 00:00 - 06:00 6.00 DRILL N RREP PROD1 WOW. Wind at 31-50 mph, Rig maintenance while WOW for Peak crane. Phase II at 0600 hrs. Rig crew built wooden catwalk across width of pipeshed to rig catwalk for sliding traction motor on. SWS team leader perpared lift plan with crews input. 06:00 - 13:00 7.00 DRILL N RREP PROD1 WOW. Wind at 24-35 MPH. SWS built steel plate platform with fork pockets for forklift. Loaded traction motor onto lifting platform at SWS shop and prep with slings to offload in rig pipeshed. Haul steel plate to cover wood catwalk. 13:00 - 13:15 0.25 DRILL N RREP PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for loading steel plate into pipe shed and loading traction motor into pipe shed with extended reach forklift. 13:15 - 14:00 0.75 DRILL N RREP PROD1 Laid 2 sheets of 4' x 8' steel plate on top of wood catwalk. Catwalk built with 12' x 12" wood beams, 4' x 20' long, very strong, covered with 2 sheets of plywood and steel plate. 14:00 - 15:00 1.00 DRILL N RREP PROD1 Lifted traction motor up and into pipeshed with extended reach Went very well. Sat traction motor on 1" steel tubes on steel plate and easily pushed traction motor across width of pipeshed onto rig catwalk. 15:00 - 16:00 1.00 DRILL N RREP PROD1 Welders finished steel ramp from rig catwalk to floor of pipeshed. Used chain and come-a-Iong to pull and hold back on traction motor while sliding down onto rig floor. Went very well. Position traction motor on power pack frame. 16:00 - 18:00 2.00 DRILL N RREP PROD1 SWS mechanics putting traction motor and hydraulic pump back together. We will need to pick the old traction motor out with a crane when the wind slows down. Tear down wood catwalk and load out with steel plate on forklift. Phase 1 weather conditions. 18:00 - 21 :45 3.75 DRILL N RREP PROD1 PJSM, wire up traction motor wI Nordic electrican 21 :45 - 22:20 0.58 DRILL N RREP PROD1 Open SV, WHP = 0 psi, filled hole with 3.5 bbl mud. Finish installato of PP and test drive. Check all phase rotations. OK. Put electrical covers on. Close doors and make ready to PU BHA 22:20 - 23:15 0.92 DRILL N RREP PROD1 PU BHA # 8. 1.1 deg bend motor wI 2.7' X 3' BC bit 23:15 - 00:00 0.75 DRILL N RREP PROD1 RIH 12/20/2004 00:00 - 01 :00 1.00 DRILL N RREP PROD1 RIH, SHT, Tested orienter at 3575 ft OK 01 :00 - 01 :45 0.75 DRILL P PROD1 End of NPT 0100 hrs 12-20-2004 Printed: 12/31/2004 9:22:20 AM Legal Well Name: 11 -06 Common Well Name: 11-06 Spud Date: 12/27/1981 Event Name: REENTER+COMPLETE Start: 12/1/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 12/27/2004 Rig Name: NORDIC 1 Rig Number: N1 Date 12/20/2004 01 :00 - 01 :45 0.75 DRILL P PROD1 Tie-in at 9871 Sag top. (corrected - 2ft ) 01 :45 - 01 :50 0.08 DRILL P PROD1 Orient TF to 1 st Ouantant 01 :50 - 02:00 0.17 DRILL P PROD1 Run in open hole at 45R TF set down at 10,261' (shale), 02:00 - 02:20 0.33 DRILL P PROD1 PUH and orient TF to 90 R. RIH to 10,291 ft and set down. PUH tight, 40k. Troubled shale area from 10,250 ft to 10,310 ft Orient TF again to 90 R. Ordered Kia Gard to bring concentration up to 14ppb 02:20 - 02:30 0.17 DRILL P PROD1 RI H and worked through at 6 fpm 11.3 bpm I 76R TF from 10,261 ft 10,285 ft. Cleaned up at 10285 ft 02:30 - 02:40 0.17 DRILL P PROD1 RIH 10,380 ft set down again at 10,326 ft 02:40 - 02:48 0.13 DRILL P PROD1 Working through 10,326 ft area. Got to 10,332 ft, taking wt and motor work Back reamed to 10250 ft Circulating temp at 45deg/50deg F 02:48 - 03:11 0.38 DRILL P PROD1 W /R 10,331 ft to 10,352 ft "set down" PUH and back reamed to 10,300 ft "clean" W /R 10.300 ft to 10,352 ft Op = 1.3 bpm & TF = 85R W/R 10.352 ft to 10360 ft" set down" Back reamed up, W/R down 10,364 ft PUH, W/R down 10,374 ft. PUH W/R to 10,400 ft 03:11 - 03:25 0.23 DRILL P PROD1 Back ream trouble shale area from 10,380 ft to 10,250 ft 150 psi motor work @ 10,328 ft 70 psi motor work @ 10,255 ft RIH 10,250 ft 10,400 ft "Clean" 03:25 - 03:35 0.17 DRILL P PROD1 RIH to 10,500 ft 03:35 - 05:00 1.42 DRILL P PROD1 Drilling TF @ 80-65R Op = 1.75/1.81 bpm, Pp = 3275/3550 psi. ROP = 90 to 130 fph 05:00 - 05:10 0.17 DRILL P PROD1 Orient TF to 11 OL 05:10 - 05:35 0.42 DRILL P PROD1 Drilling TF @ 90 to 120L Op = 1.64/1.78 bpm, Pp = 3275/3350 psi. ROP = 90 to 120 fph A finished adding 4 drums KlaGard Cone at 14 ppb 05:35 - 06:20 0.75 DRILL P PROD1 Wiper trip. Clean coming up through shale area Orient TF to R-side before RIH 06:20 - 06:40 0.33 DRILL P PROD1 Orient TF to 120R. 06:40 - 07:45 1.08 DRILL P PROD1 Drilling lateral, 1.7/1.7 bpm, 3240 - 3800 psi, 120R, 82 deg incl, 100 fph, Drilled to 10,744'. 07:45 - 08:10 0.42 DRILL P PROD1 Orient TF to 90R. 08:10 - 09:45 1.58 DRILL P PROD1 Drilling Z2 lateral, 1.7/1.7 bpm, 3380 - 3800 psi, 90R, 80 deg incl, 30 fph, Drilled to 10,775'. Had pressure increase, ports plugged and cleared. Saw I several rubber pieces from motor on shaker. Very clear it is motor rubber, pieces had lobes in them and correct thickness. Circ press gained 140 psi, so 1-2 ports are plugged. 09:45 - 10:10 0.42 DRILL P PROD1 Trying to drill, getting weak stalls on motor, no ROP. Ught tag on bottom stalls motor. We saw a lot of motor rubber on shaker. Not able to drill. 10: 1 0 - 10:30 0.33 DRILL P PROD1 Wiper trip to window. 10:30 - 12:10 1.67 DRILL N DFAL PROD1 POH to check motor and bit. 12:10 - 13:00 0.83 DRILL N DFAL PROD1 C/O motor. Re-run bit. Check orienter. Printed: 12/31/2004 9:22:20 AM EXPLORATION o ations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/20/2004 13:00 - 14:30 1.50 DRILL N 14:30 - 14:45 0.25 DRILL P 14:45-16:15 1.50 DRILL P 16:15 - 17:00 0.75 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 18:15 0.75 DRILL P 18:15 - 18:30 0.25 DRILL P 18:30 - 20:25 1.92 DRILL P i 20:25 - 21 :30 1.08 DRILL P 21 :30 - 21 :35\ 0.08 DRILL P 21 :35 - 21 :45 0.17 DRILL P 21:45 - 23:15 1.50 DRILL P 11 -06 11 -06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 23:15 - 23:26 23:26 - 23:30 0.18 DRILL P 0.07 DRILL P PROD1 PROD1 23:30 - 00:00 0.50 DRILL P PROD1 12/21/2004 00:00 - 00:35 0.58 DRILL P PROD1 00:35 - 01 :35 1.00 DRILL P PROD1 01 :35 - 02:30 0.92 DRILL P PROD1 02:30 - 03:30 1.00 DRILL P PROD1 03:30 - 03:37 0.12 DRILL P PROD1 03:37 - 04:26 0.82 DRILL P PROD1 04:26 - 07:00 2.57 DRILL P PROD1 07:00 - 07:40 0.67 DRILL P PROD1 07:40 - 08:00 0.33 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:15 0.75 DRILL P PROD1 09:15 - 09:30 0.25 DRILL P PROD1 09:30 - 10:40 1.17 DRILL P PROD1 Start: Rig Release: Rig Number: Spud Date: 12/27/1981 End: 12/1/2004 12/27/2004 N1 I I RI H with BHA #9 with 1.1 deg motor and 3.0" HCC bi-center bit 1#9. OAL '" 58.98'. I Log RA tie-in, -3 ft CTD. i RIH to 10,250'. Stack wt in shales. Orient to as drilled TF and I¡Ream shales. RIH and tag bottom at 10,771'. Drilling lateral in Z2. 1.8/1.8 bpm, 3350 - 3900 psi, 90R. 81 Ideg incl, Drilled to 10,799'. [Orient TF to 30R. Drilling lateral in Z1. 1.8 /1.8 bpm, 3350 - 3900 psi, 30R. 83 I deg incl, Drilled to 10,825'. II Drilling lateral in Z1. 1.8/1.8 bpm, 3350 - 3900 psi, 76R. 83 deg incl, Drilled to 10,836'. Drilling lateral and adjust TF to drop angle 120 R, drilling at 100R lop", 1.74/1.81 bpm at Pp '" 3250 /3600 psi I Resultant hole angle needed is 89 deg IWiPer trip to WS, clean PUH, RIH TF at 115R, little motor work at 10260 ft Little motor work at 10355 ft going in the hole. I Drilling lateral at 115R to 140R drilling in sand lOp'" 1.74 /1.81 bpm at Pp '" 3250 13600 psi ROP", 140 fph Orient TF around Drilling lateral at 150R to 166R drilling in sand Trying to cut-coss sands Op", 1.74/1.81 bpm at Pp '" 3307 13500 psi ROP '" 50-140 fph Started mud swap at 23:15 hrs and 10966 ft ¡Work CT up hole with new mud going down CT Drilling lateral at 150R to 166R drilling in sand Trying to cut-coss sands Op", 1.74/1.81 bpm at Pp '" 3307 13538 psi ROP", 60-140 fph Orient TF around Orient TF Drilling TF 115R to 120R Op", 1.70/1.84 bpm Pp '" 3350 13425 psi Wiper trip to window. Clean trip Orient TF to 90R from 144R Drilling in shale TF still 135R Op", 1.70/1.84 bpm Pp '" 2975/3395 psi PUH to 10,900 ft orient TF Drilling in shale TF 56 to 140R Op = 1.70/1.84 bpm Pp = 2975/3395 psi Mud swap finished at 0500 hrs Vp '" 315 bbl Wiper trip to window. Some motor work in shales at 10,250'. Log GR tie-in at RA tag. Add 4.5 ft CTD. RIH clean to bottom. DrillingZ1/ateral, 1.7/1.7bpm, 3350-4000 psi, 100R, 91 deg incl, 100 fph, Drilled to 11,266'. Orient TF to 100L. Drilling Z1 lateral, 1.7/1.7 bpm, 3350-4000 psi, 110L, 88 deg incl, 100 fph, Drilled to 11,370'. Printed: 12/31/2004 9:22:20 AM mmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/1/2004 12/27/2004 N1 Spud Date: 12/27/1981 End: 0.67 DRILL P PROD1 Wiper trip to window. Clean hole. 0.67 DRILL P PROD1 RIH. Clean trip to bottom. 0.50 DRILL P PROD1 Drilling Z1 lateral, 1.7/1.7 bpm, 3350-4000 psi, 80L, 88 deg incl, 100 fph, Drilled to 11,428 Need to drop hole angle 12:30 - 14:05 1.58 DRILL P PROD1 Orient TF to 130L 14:05 - 14:10 0.08 DRILL P PROD1 Drill and trying to drop hole angle. TF rolling up to 87L Op = 1.75/181 bpm; Pp= 3450/3780 psi ROP in sand at 150 fph 14:10 - 14:45 0.58 DRILL P PROD1 Orient TF to drop hole angle from 90 to 88 deg 14:45 - 15:22 0.62 DRILL P PROD1 Drilling 155L1143L Op = 1.75 /181 bpm; Pp= 3350/3875 psi 15:22 - 16:30 1.13 DRILL P PROD1 Wiper Trip 16:30 - 16:40 0.17 DRILL P PROD1 Drilling Unable to get TF to 90 L Op = 1.75/181 bpm; Pp= 3350/3875 psi 16:40 - 17:25 0.75 DRILL P PROD1 Orient TF to get TF at 100L on bottom drilling 17:25 - 18:00 0.58 DRILL P PROD1 Drilling Unable to get TF to 104 L to 115 L Op = 1.70/181 bpm; Pp= 3350 / 3790 psi ROP varies 20 to 100 fph. Stacking in shales, having to work CT to get back to drilling. Try and hole 87 deg and drill up good sand. Need to be at 8,721 ft TVD at 11,600 ft MD 18:00 - 23:20 5.33 DRILL P PROD1 Drilling TF 100L to 11,647' MD. Op = 1.70/181 bpm; Pp= 3350 /3790 psi - 00:00 0.67 DRILL P PROD1 Wiper trip. 12/22/2004 00:00 - 00:45 0.75 DRILL P PROD1 Wiper trip to window. 00:45 - 01 :30 0.75 DRILL P PROD1 Orient TF to 90L. 01 :30 - 03:30 2.00 DRILL P PROD1 Drill ahead in lateral to TO at 11,715' MD. 103:30 - 05:45 - 3500 psi free spin - 1.6/1.7 bpm at 3700 psi. 2.25 DRILL P PROD1 Final wiper to window. Tie in, +6 ft correction. RBIH. Minimal motor work I stack at 10,270' Confirm TD at 11,720' MD. - Lay in 25 bbls liner pill. 05:45 - 08:10 2.42 DRILL P PROD1 POOH - Slight over pull while coming off bottom. Painted flag at 7608 ft EOP 08:10 -10:00 1.83 DRILL P PROD1 OOH, LD drilling BHA Weekly BOP function. Install SCR card, didn't work put old one back in. Need to change out motherboard on SCR 1 assigment #4 PJSM on handling Memory Res Tool PU PDS Memory Resistivity tool 10:00 - 12:00 2.00 DRILL P PROD1 RIH with M Res Tool 12:00 - 13:08 1.13 DRILL P PROD1 RIH logging at 30 fpm with Res tool Tagged at 11699 ft, wait 1 minute 13:08 - 14:20 1.20 DRILL P PROD1 PUH 9650 ft laying in liner pill and logging at 30 fpm 14:20-16:15 1.92 DRILL P PROD1 POOH 16:15 - 16:50 0.58 DRILL P PROD1 LD PDS tools Down load PDS res data Working on SCR panels 16:50 - 17:45 0.92 CASE P RUNPRD Load and pump dart to clean out CT Vol = 40 bbl 17:45 - 18:45 1.00 DRILL N DFAL PROD1 Working to retrieve Res data. Printed: 12/31/2004 9:22:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/22/2004 12/23/2004 ! 23:40 - 00:00 I I I 00:00 - 00:50 i I I 00:50 - 02:15 i 02:15-02:45 i ! 02:45 - 03:20 ! I 03:20 - 07:15 I I ! 07:15 - 07:45 ¡ 07:45 - 09:40 I I I 09:40 - 11 :00 I I ! 11 :00 - 14:45 14:45 - 15:10 15:10 - 16:18 16:18 -16:30 16:30 - 18:30 BP EXPLORATION Operations S . Y Report Start: 12/1/2004 Rig Release: 12/27/2004 Rig Number: N1 Spud Date: 12/27/1981 End: 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 m.-Toj .Ho~i Task 17:45 - 18:45 I 1.00 DRILL N 18:45-20:30 i 1.751 DRILL N I ! I I i 20:30 - 22:30 I 22:30 - 23:40 i I I I 2.00 I DRILL 1.17\ DRILL I I I 0.33i DRILL I 0.831 DRILL , 1.42 ¡ DRILL 0.50 I DRILL I 0.58 ¡ CASE 1 3.92! CASE ¡ i 0.50 I CASE 1.921 CASE i I 1.331 CASE I 3.751 CEMT I I 0.42 CEMT 1.13 CEMT 0.20 CEMT 2.00 CEMT DFAL PROD1 DFAL PROD1 N N DFAL PROD1 DFAL PROD1 I: DFAL PROD1 DFAL PROD1 N DFAL PROD1 N DFAL PROD1 P RUNPRD P RUNPRD P P RUNPRD RUNPRD P RUNPRD P RUNPRD P RUNPRD P RUNPRD P RUNPRD P RUNPRD - Confirmed data is bad due to tool failure/malfunction. - Program new logging tools. - PJSM for PU logging tools. - Bring tools to floor. PU PDS memory resistivity tools. MU injector. RIH with logging tools at 85 fpm, circulating at 0.25 bpm. Stop at 9650' MD. Log down at 30 fpm. Circ liner pill down at 0.25 bpm. Tag TD at 11,715.5' MD. Wait 1 minute. PUH to 9650' MD logging at 30 fpm, laying in liner pill at 0.25 bpm. PUH to 9650' MD logging at 30 fpm, laying in liner pill at 0.25 bpm. POOH. Lay down PDS logging tools. - Good data. PJSM for liner running. Prepare rig floor for running liner. RIH with 75 jts 2-3/8" STL liner as per tally. Drift all connect to 1.87" Fill pipe at jt 34. Crew change and PJSM on tubing handling MU injector head, Set counters 2406 ft mechanicat at 3 ft RIH with liner Wt Chect above window 10,037 ft PU = 30.5k SO = 16k Tagged at 11,650 ft, PUH and worked down to 11,720 ft Circulate and work on CTDS computer. Locate ball drop position. Drop 5/8" steel ball Lanch ball. RIH and set 10k on liner Pumped 32.6 bbl ball released from liner at 4547 psi, PU released from liner Stacked 10 down on liner Cleaning pit and Displace well with 2% KCL Qp = 1.77 /1.48 bpm, CTP = 2065 psi Lost 35 bbl while cir mud out of hole Cir and mixing 30 bbl Biozan pill PJSM on liner cement job. Mitigated all issues Batch mix 15 bbl cement and add 7 bbl of Biozan to pill pit Cement at 15.8 ppg at 15:10 hrs Pumped 3 bbl 2% KCL SD and PT to 4000 psi Pumped 10.3 bb115.9 ppg cement SD load dart, vac back lines and line up to biozan Pumped 38 bbl Bio water and LWP hit at 38.9 bbl, LWP sheared at 3700 psi Pumped 8.7 bbl ( Vol total =47.6 bbl LWP bumped. Bumped at 1000 psi over cir P Cir 8.6 bbl up annulus and at 1.00 bpm, Q ratio at 1:1 With 300 psi, unstung from deployment. Pulled up 9,271 ft replacing CT voilage At 9,271 ft, inc Qp to 3.00 bpm and displace wellbore and wash up jewerly as POOH POOH at 3.00 bpm took 60 bbl contaminated cement to cutting Printed: 12/31/2004 9:22:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: EXPLORA TI Operations Summ 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 10 of Start: 12/1/2004 Rig Release: 12/27/2004 Rig Number: N1 Spud Date: 12/27/1981 End: Hours Task Code NPT 12/23/2004 box. LD BOT CTLRT. Jet stack and surface lines/valves. Cut 100' of coil. Weld on new coil tubing connector. Pressure test CTC to 4000 psi. Pull test to 40k. PJSM. RIH with 78 jts 1" CSH, mud motor and 1.8" mill. 12/24/2004 RIH with 78 jts 1" CSH, mud motor and 1.8" mill. RIH to TD. - Cement at 1400 psi compressive strength prior to entering liner. - Pump bio pill, chase out of hole. POOH. Drop 5/8" ball and open CS to cir 1" CSH PJSM LD 78 jnts 1" CSH. POOH standing 1" CSH in derrick PJSM on handling Load source in logging tool. MU tool and BHA RIH 80 jts 1" CSH MU top MHA and stab injector RIH Logging down at 30 fpm from 9200 ft to 11684 ft PUH loging at 60 fpm and laying in 20 bbl perf pill POOH Stand back injector, LD MHA and make ready to LD 22 jts 1" CSH POOH LD 22jts 1" CSH tubing PJSM on source and tool handling LD MCNL tool and make ready to PT liner lap Pressure up annulus with MEOH to 1000 psi. Presure test liner lap to 2000 psi for 30 minutes. chart same. Took 1 bbl to pressure up 16:30 - 18:30 2.00 CEMT P RUNPRD 18:30 - 18:45 0.25 CEMT P RUNPRD 18:45 - 19:30 0.75 CEMT P RUNPRD 19:30 - 20:00 0.50 CEMT P RUNPRD 20:00 - 21:15 1.25 CEMT P RUNPRD 21:15 - 21:30 0.25 CEMT P RUNPRD 21 :30 - 00:00 2.50 EVAL P LOWER1 00:00 - 00:45 0.75 EVAL P LOWER1 00:45 - 03:30 2.75 EVAL P LOWER1 03:30 - 05:30 2.00 EVAL P LOWER1 05:30 - 06:45 1.25 EVAL P LOWER1 06:45 - 08:30 1.75 EVAL P LOWER1 08:30 - 09:00 0.50 EVAL P LOWER1 09:00 - 09:15 0.25 EVAL P LOWER1 09:15 - 10:50 1.58 EVAL P LOWER1 10:50-11:15 0.42 EVAL P LOWER1 11:15-12:25 1.17 EVAL P LOWER1 12:25 - 13:50 1.42 EVAL P LOWER1 13:50 - 14:35 0.75 EVAL P LOWER1 14:35 - 15:45 1.17 EVAL P LOWER1 15:45 - 17:30 1.75 EVAL P LOWER1 17:30 - 17:50 0.33 EVAL P LOWER1 17:50 - 18:00 0.17 EVAL P LOWER1 18:00 - 19:15 1.25 EVAL P LOWER1 19:15 - 20:45 1.50 CEMT P RUNPRD Time Pressure Delta 0 1975 5 1897 78 10 1853 44 15 1824 29 20 1802 22 25 1787 15 30 1776 11 Borderline test. Bump back up to 2000 psi to confirm holding. Time Pressure Delta 0 2000 5 1849 151 10 1805 44 15 1776 29 20 1747 29 25 1725 22 Printed: 12/31/2004 9:22:20 AM BP Operations of 12 Discussed tests with CTD drilling engineer and DS11 Pad engineer. Will fore-go liner top packer given pressure stabilizing throughout test. LOWER1 PJSM. Rig up and pick up 33 perf guns and partials. LOWER1 RIH with 29 stands of 1" CSH from derrick. LOWER1 RIH to TO, pumping 0.2 bpm, 150 psi. LOWER1 Tag at 11,690' MD. Correct to 11,685.3' PBTD from CNUGRlCCL log. - Correct -1 ft on the upstroke. - PU 29.3k; SO 16k - Pump 15 bbls perf pill. - Drop 1/2" steel ball. Chase ball at 1 bpm at 2500 psi, slow to 0.5 bpm at 1000 psi at 30 bbls away. - 214 bbls pit volume prior to firing. - Did not see ball land on seat. - Increased rate at 1/2 bpm increments. Total volume pumped: 49.2 bbls. No pressure increase. Suspect ball in check valve. LOWER1 Perforate. - Drop second 1/2' steel ball. - Pump ball down at 0.8 bpm at 1500 psi. - Ball down hole at 29.3 bbls away. - With 46 bbls away, pressure up to 4000 psi. Bleed off. - Bring rate up to 0.8 bpm, 2300 psi. Stablilized. - Pressure up to 3200 psi at 52.3 bbls away. Fired at 11,666.6' MD, l' off depth. - Lost 1 bbl when fired. POOH at 44 fpm with perf guns. - Hold 200 psi back pressure - Pumping at 0.3 bpm, 250 psi. Flow check well at TOL. - Trip sheet accurate. POOH at 100 fpm. - Fill the back side - Hold back pressure. OOH, check flow. Stand injector back. LD MHA and PJSM POOH LD 58 jts 1" CSH PJSM on handling perf guns LD perf guns, recovered 1 1/2" ball Data from MCNL MCNL TOL at 9320.5 ft MCNL PBTDllanding collar at 11685.33 ft Load out perf guns and 1" CSH Make ready to FP the well bore RI H to 2000 ft FP wellbore. POOH pumping 33 bbl MEOH POOH laying in MEOH OOH, close MV, RU to blow down CT PJSM Wind speeds inc to 20/25 mph Pump 30 water 10 bbl MEOH and blow down CT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Code NPT 12/24/2004 19:15 - 20:45 1.50 CEMT Ip RUNPRD 30 20:45 - 23:00 23:00 - 00:00 12/25/2004 00:00 - 02:10 02: 1 0 - 03:45 03:45 - 05:00 1.25 PERFO P 05:00 - 05:40 LOWER1 05:40 - 06:10 LOWER1 06:10 - 07:10 LOWER1 07:10 - 08:15 LOWER1 08:15 - 09:45 LOWER1 09:45 - 10:15 LOWER1 10:15 - 12:30 LOWER1 12:30 - 13:30 LOWER1 13:30 - 14:23 0.88 WHSUR P POST 14:23 - 14:45 0.37 WHSUR P POST 14:45 - 17:00 2.25 WHSUR P POST Start: Rig Release: Rig Number: Spud Date: 12/27/1981 End: 12/1/2004 12/27/2004 N1 1710 15 Printed: 12/31/2004 9:22:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17:00 - 21 :00 21 :00 - 00:00 12/26/2004 00:00 - 06:00 06:00 - 06:45 06:45 -11:15 11:15-18:10 118:10-19:30 19:30 - 00:00 12/27/2004 00:00 - 01:00 01 :00 - 06:00 12 of 1 2 BP EXPLORATION Summary Start: 12/1/2004 Rig Release: 12/27/2004 Rig Number: N1 NÎ'T~:~ S,nt p,,,, "on, b.ok to ya'" doe to 25130 mph w;nd 'p"d, I Recovered 2nd 1/2" ball i POST Close MV and changed to 2-3/8" rams in SOPE. i NO Hydraulic lines from HCR. I POST PJSM. Spool pipe across. Secure reel. Prep for removal. II POST Rig down goose neck. Rig down injector. Change out gripper blocks and stuffing box. I POST and weekly safety meeting I POST Working on reel shims and inspecting chains. Wind at 90 /100 mph I Phase 3 at 1115 hrs, Stopped all work details and hunker down Fuel at 2700 gals and water at 70 bbl WAIT I POST Rig on Standby during Phase 3 i WOW Phase 3 WOW Phase 2 Move snow off location Crew travel in convoy from BOC and SLB Deadhorse Complete work on injector. Stab injector into box. Place rig on normal operation charges while finishing up the RD OFF CRITICAL PATH OPERATIONS - Location management in preparation for rig move. - Loader escorting traffic off pad due to drifting/blowing snow. NO BOPE. NU and test tree cap to 4000 psi. Rig on standby due to weather at 01:00 hrs 12/27/2004 WOW. Phase 2, High winds. - Ready rig for derrick down - Perform PM. Heavy equipment cleaning location Have Peak warm crane Winds still at 20/30 mph Phase 1/2 Winds speed at 8 mph with gust to 15, called Peak crane Crane arrived, Held PJSM on lifts Spotting crane and open pipe shed door to extract traction motor Reel Swap 11-06 11-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 4.00 0.75 4.50 6.92 1.33 WAIT ¡POST I WAIT ¡ POST 4.50 1.00 BOPSU P 5.00 RIGD N I I I I II· POST ,POST WAIT 06:00 - 14:00 8.00 RIGD N WAIT POST 14:00 - 15:45 1.75 RIGD N WAIT ¡POST 15:45 - 16:00 0.25 RIGD P POST 16:00 - 16:30 0.50 RIGD P POST 16:30 - 18:00 1.50 RIGD P POST Spud Date: 12/27/1981 End: RIG RELEASE AT 18:00 HRS. 12/27/04 Printed: 12/31/2004 9:22:20 AM Halliburton Sperry-Sun North Slope Alaska BPXA 11-06A . Job No. AKMW3444751, Surveyed: 22 December, 2004 Survey Report 30 December, 2004 Your Ref: API 500292067401 Surface Coordinates: 5951353.08 N, 707506.70 E (70016' 13.8171" N, 148019' 17.9663" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 62.00ft above Mean Sea Level sper"r"V-sul"1 DRIL.L.ING SERViceS A Halliburton Company Survey Ref: svy4468 Halliburton Sperry-Sun Survey Report for 11-06A Your Ref: API 500292067401 Job No. AKMW3444751, Surveyed: 22 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10000.00 36.000 304.170 8389.77 8451.77 2080.99 N 3628.60 W 5953333.23 N 703822.11 E -3628.60 Tie On Point MWD Magnetic 10067.00 36.780 303.900 8443.71 8505.71 2103.23 N 3661.54 W 5953354.56 N 703788.57 E 1.188 -3661.54 Window Point 10105.43 49.830 312.220 8471.64 8533.64 2119.60 N 3682.06 W 5953370.36 N 703767.60 E 37.003 -3682.06 10128.24 51.080 316.020 8486.16 8548.16 2131.85N 3694.68 W 5953382.25 N 703754.64 E 13.965 -3694.68 . 10157.88 54.400 324.310 8504.13 8566.13 2149.95 N 3709.74 W 5953399.94 N 703739.09 E 24.906 -3709.74 10192.83 57.300 335.390 8523.78 8585.78 2174.92 N 3724.19W 5953424.50 N 703723.96 E 27.498 -3724.19 10221.89 55.900 342.940 8539.80 8601.80 2197.57 N 3732.82 W 5953446.90 N 703714.71 E 22.213 -3732.82 10253.46 55.360 352.070 8557.65 8619.65 2222.96 N 3738.45 W 5953472.13 N 703708.38 E 23.924 -3738.45 10282.92 56.780 1 .400 8574.11 8636.11 2247.32 N 3739.83 W 5953496.44 N 703706.34 E 26.705 -3739.83 10314.20 57.300 9.490 8591.15 8653.15 2273.41 N 3737.33 W 5953522.59 N 703708.11 E 21.759 -3737.33 10345.78 59.150 15.110 8607.79 8669.79 2299.62 N 3731.61 W 5953548.95 N 703713.11 E 16.221 -3731.61 10375.95 64.340 19.510 8622.07 8684.07 2324.97 N 3723.68 W 5953574.50 N 703720.33 E 21.465 -3723.68 10409.56 68.990 27.420 8635.40 8697.40 2353.23 N 3711.37 W 5953603.09 N 703731.86 E 25.649 -3711.37 10442.73 74.000 33.220 8645.93 8707.93 2380.35 N 3695.49 W 5953630.63 N 703746.99 E 22.424 -3695.49 10474.11 77.690 40.250 8653.61 8715.61 2404.70 N 3677.29 W 5953655.48 N 703764.51 E 24.697 -3677.29 10511.60 80.420 49.570 8660.75 8722.75 2430.72 N 3651.33 W 5953682.21 N 703789.74 E 25.467 -3651.33 10549.55 83.580 55.720 8666.03 8728.03 2453.51 N 3621.47 W 5953705.81 N 703818.96 E 18.077 -3621.47 10587.10 84.550 61.340 8669.92 8731.92 2472.99 N 3589.63 W 5953726.17 N 703850.25 E 15.109 -3589.63 10620.31 84.250 64.020 8673.16 8735.16 2488.16 N 3560.27 W 5953742.14 N 703879.19 E 8.082 -3560.27 10650.68 84.200 62.050 8676.22 8738.22 2501 .86 N 3533.34 W 5953756.58 N 703905.73 E 6.456 -3533.34 10681.14 83.140 65.030 8679.58 8741.58 2515.35 N 3506.24 W 5953770.81 N 703932.45 E 10.327 -3506.24 . 10718.46 81.210 72.240 8684.66 8746.66 2528.82 N 3471.83 W 5953785.22 N 703966.47 E 19.825 -3471.83 10749.33 79.540 74.350 8689.82 8751.82 2537.57 N 3442.69 W 5953794.76 N 703995.36 E 8.641 -3442.69 10781.31 80.860 79.450 8695.27 8757.27 2544.70 N 3412.00 W 5953802.74 N 704025.84 E 16.247 -3412.00 10811.33 83.370 83.640 8699.39 8761.39 2549.07 N 3382.60 W 5953807.92 N 704055.11 E 16.156 -3382.60 10844.01 90.610 86.660 8701.11 8763.11 2551.82 N 3350.11 W 5953811.57 N 704087.51 E 23.997 -3350.11 10877.45 92.720 93.340 8700.13 8762.13 2551.83 N 3316.70 W 5953812.49 N 704120.91 E 20.940 -3316.70 10914.65 91.490 99.660 8698.77 8760.77 2547.62 N 3279.78 W 5953809.30 N 704157.92 E 17.296 -3279.78 10945.69 89.910 104.940 8698.39 8760.39 2541.01 N 3249.47 W 5953803.53 N 704188.41 E 17.754 -3249.47 10976.93 88.070 108.980 8698.94 8760.94 2531.90 N 3219.60 W 5953795.25 N 704218.52 E 14.208 -3219.60 11007.99 87.360 113.020 8700.18 8762.18 2520.78 N 3190.63 W 5953784.94 N 704247.78 E 13.196 -3190.63 11049.44 84.990 120.410 8702.95 8764.95 2502.21 N 3153.72 W 5953767.39 N 704285.19 E 18.684 -3153.72 11082.07 83.670 125.680 8706.17 8768.17 2484.51 N 3126.51 W 5953750.44 N 704312.88 E 16.573 -3126.51 11116.52 88.860 130.250 8708.42 8770.42 2463.37 N 3099.43 W 5953730.06 N 704340.54 E 20.052 -3099.43 11152.95 87.890 135.870 8709.45 8771.45 2438.52 N 3072.83 W 5953705.95 N 704367.81 E 15.649 -3072.83 30 December, 2004 - 14:24 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 11-06A Your Ref: API 500292067401 Job No. AKMW3444751, Surveyed: 22 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11183.61 88.070 140.620 8710.53 8772.53 2415.67 N 3052.43 W 5953683.67 N 704388.83 E 15.494 -3052.43 11216.44 89.030 145.720 8711.36 8773.36 2389.40 N 3032.76 W 5953657.96 N 704409.21 E 15.802 -3032.76 11246.56 91.410 151.340 8711.25 8773.25 2363.73 N 3017.05 W 5953632.73 N 704425.63 E 20.262 -3017.05 11275.20 92.110 153.800 8710.37 8772.37 2338.32 N 3003.86 W 5953607.69 N 704439.51 E 8.926 -3003.86 11313.06 89.210 150.110 8709.93 8771.93 2304.92 N 2986.07 W 5953574.80 N 704458.22 E 12.395 -2986.07 . 11346.85 87.730 144.910 8710.83 8772.83 2276.44 N 2967.93 W 5953546.83 N 704477.14 E 15.995 -2967.93 11376.72 87.710 139.210 8712.02 8774.02 2252.91 N 2949.59 W 5953523.81 N 704496.12 E 19.068 -2949.59 11414.48 89.810 133.860 8712.84 8774.84 2225.52 N 2923.63 W 5953497.15 N 704522.82 E 15.217 -2923.63 11443.18 89.740 129.020 8712.95 8774.95 2206.53 N 2902.12 W 5953478.76 N 704544.85 E 16.866 -2902.12 11486.26 87.100 126.910 8714.14 8776.14 2180.04 N 2868.17 W 5953453.22 N 704579.51 E 7.844 -2868.17 11519.51 86.660 121.990 8715.95 8777. 95 2161.27 N 2840.80 W 5953435.20 N 704607.39 E 14.834 -2840.80 11552.04 86.750 114.600 8717.82 8779.82 2145.89 N 2812.23 W 5953420.62 N 704636.38 E 22.682 -2812.23 11580.38 85.430 111.090 8719.76 8781.76 2134.91 N 2786.18 W 5953410.36 N 704662.72 E 13.205 -2786.18 11616.70 89.030 108.630 8721.51 8783.51 2122.59 N 2752.07 W 5953398.99 N 704697.16 E 12.000 -2752.07 11646.68 93.340 108.800 8720.89 8782.89 2112.97 N 2723.68 W 5953390.16 N 704725.80 E 14.387 -2723.68 11680.72 91.850 103.530 8719.35 8781.35 2103.51 N 2691.03 W 5953381.60 N 704758.69 E 16.073 -2691.03 11700.11 91.410 101.250 8718.80 8780.80 2099.35 N 2672.11 W 5953377.96 N 704777.73 E 11.971 -2672.11 11720.00 91.410 101.250 8718.31 8780.31 2095.47 N 2652.60 W 5953374.62 N 704797.33 E 0.000 -2652.60 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. . The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 90.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11720.00ft., The Bottom Hole Displacement is 3380.43ft., in the Direction of 308.308° (True). 30 December, 2004 - 14:24 Page 3 of 4 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 11-06A Your Ref: API 500292067401 Job No. AKMW3444751, Surveyed: 22 December, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10000.00 10067.00 11720.00 8451.77 8505.71 8780.31 2080.99 N 2103.23 N 2095.47 N 3628.60 W 3661.54 W 2652.60 W Tie On Point Window Point Projected Survey . Survey tool program for 11-06A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10000.00 0.00 10000.00 8451.77 11720.00 8451.77 CB-GYRO-MS (11-06) 8780.31 MWD Magnetic (11-06A) . 30 December, 2004·14:24 Page 4 of 4 Dri/lQuest 3.03.06.006 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 11-06A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,000.00' MD 10,067.00' MD 11,720.00' MD (if applicable) o 1-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date).. ì J M.--~fi~ '-- Signed '~ {JjJJ ( Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ,f). û ~l '- J---)..) · . ~1f~1fŒ (ID~ ~~~~~~ AlfASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 11-06A BP Exploration (Alaska) Inc. Permit No: 204-225 Surface Location: 370' SNL, 57' WEL, SEC. 33, T11N, RI5E, UM Bottomhole Location: 1668' NSL, 3003' WEL, SEC. 28, TIIN, RI5E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 (pager). Si BY ORDER 91 THE COMMISSION DATED this-f: day of November, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .. " i",'n, 1a. Type of work o Drill III Redrill rb. Current Well Class o Exploratory II t)evel()pme~t Oil DMultiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: IHI Blanket o Single Well 11. Well Name and Number: .' BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 11-06A ~ 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11650 TVD 874755 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028325 370' SNL, 57' WEL, SEC. 33, T11 N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1668' NSL, 3618' WEL, SEC. 28, T11N, R15E, UM December 15, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1668' NSL, 3003' WEL, SEC. 28, T11N, R15E, UM 2560 5-1/2 Miles 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 707507 y- 5951353 Zone- ASP4 (Height above GL): 62' feet 11-34 is 788' away at 10050' MD 16. Deviated Wells: Kickoff Depth: 9900 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 88 decrees Downhole: 3400 Surface: 2520../ 1!S\I..;~~lng Sþåcification$ " TI,~tting" trimi" i' Size Hole Casino Weiaht Grade CouDlina Lenath MD TVD MD TVD (includinn staae data) 3" 2-3/8" 4.7# L-80 STL 2275' 9325' 7848' 11600' 8744' 58 sx Class 'G' 19/ P~ESEI\T WELI..COI\DITION$ÜMMA~'I"'(T()~cômpl~tedfor .~$qfillAND··.Rø--entryØ~r~~¡Qij$) i"" Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 10558 8884' 10242 10242 8644 10231 ",i'i: At\nth .'·i: "Si7A i,'} i 't": Wi, ~W ~...._ 'iii"'ifiii'i'r,!!''I#i ......"..,...".... ~trllr.h I r::l I Conductor 80' 20" 250 sx PF 'C' 80' 80' Surface 2453' 13-3/8" 2300 sx Fondu, 400 sx PF 'C' 2515' 2515' i::¡tA 9787' 9-5/8" 500 sx Class 'G' 9849' 8328' Production LinAr 4574' 7" 459 sx Class 'G' 5983' - 10557' 5555' - 8883' Scab Liner 1031' 3-1/2" Approx. 106 sx Class 'G' 9340' - 10371' 7921' - 8743' Perforation Depth MD (ft): None perfOration Depth TVD (ft): None 20. Attachments IHI Filing Fee, $100 IHI BOP Sketch IHI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IHI Drilling Fluid Program 1H120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer , -Jí11fvLJ k;#n.dt!lI'LJ7/ 11/3! (yLJ-. Prepared By Name/Number: Signature Phone 564-4388 Date Terrie Hubble, 564-4628 "i i '.·..~....,i.i '" i .·:i· "",.1.2., ·.i··'.·. ..................... i··.. :i}J0jii)..;~.... .'i< Permit To Drill v API Number: Permit APpro~1 ~ See cover letter for Number: 2..0 q- .2.2-6 50- 029-20674-01-00 Date: II. ~ ¿) (/ other requirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required , o Yes ~No nU1r.le Measures )gYes [J No Directional Survey Required ~Yes DNo Other: T t' S. +- -R...o p ~ Soe j? C;[ , MDrov~Ø~~ nR I r'\t\1 ¡~ I APPROVED BY II/~ ¿If . - Î"" THE COMMISSION Date ~. ~ "', Form 1 0-401 Revised'tJG'í2004 '- ~/ "-" , ., ,Submit In Duplicate V-/4 t\- u/4·/zo04 . STATE OF ALASKA . icY ALASKA Oil AND GAS CONSERVATION COMMISSIO~ PERMIT TO DRILL V 7n04 20 MC 25 005 . . BP 1l-06A Sidetrack CTD Sidetrack Summary 1) MIRU CTD rig. 2) Mill 2.74" OD window 3) Drill 2.70" x 3" bicenter hole with MWD/RES/GR. 4) Run 2 3/8" solid liner and cement. 5) Clean out, MCNL, Perforate -600ft ,/ Mud Program: · Milling: 8}PP) seawater · Drilling: U:'Ppg used PIo Pro for drilling build, new mud as needed. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: ~-.) · 23/8" solid cemented liner. The liner cement volume is planned to b~IS of 15.8 ppg class G. .- Parent Well Casinas Hole Size Burst (psi) CollaDse (DSi\ 13 3/8" 72# L-80 5380 2670 9%" 47#, L-80 & SOO-95 6870 4760 7" 29#, L-80, BTC liner 8160 7020 3 W' 9.3# 13Cr80, ST-L 10160 10530 Sidetrack Casings 23/8" 4.7#, L-80, STL - Prod LNR 3" 11200 11780 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 11-06A will be approximately 788'md center to center away from well 11-34 at 1O,050'md · 1l-06A will be approximately 5.5miles from the unit boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray and Resistivity log will be run over all of the open hole section. · MCNL will be run cased hole. Hazards · 11-06 measured.).ppm H2S 4/03 · Max recorded H2S on DS llis 660ppm, well 11-36, 6/04. All H2S monitoring equipment will be operational. · One small fault crossing is predicted, lost circulation risk is considered "low", LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated to be 3400 psi at 8800' ss (7.4 ppg EMW). Max. surface pressure with gas (0.10 psilft) to surface is 2520 psi. / TREE - WB.LHEAD = A(5;TUATOR= KB. B.EV = BF. B.EV = KOP= Max Angle - Datum MD = DatumlVD= FMC GEN 2 cr# BAKER C 62 31 3200' 49 @ 6600' 10396' 8700' SS . 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2515' TOP OF 7" SCAB LNR 9 5/8" leak '97 Minimum ID = 2.813" @ 9360' 3-1/2" HES X NIPPLE 4-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 7" LNR-TIEBACK, 29#, L-80, .0371 bpf, ID = 6.184" 11-06 NOTES: CHROMETBG. **IAx OACOMM. PERATING PRESSURE OF THE 13-3/8" ANNULUS MUST NOT EXCEED 2000 PSI (02107/03 W AlVER)** **3-1/2" LNR & 4-112" CHROME TBG** 2082' 4-112" HES X NIP, ID = 3.813" ST MD lVD 1 3320 3315 2 5025 4841 3 6019 5564 4 6379 5808 5 9216 7825 GAS LIFT MANDRELS DEV TYPE VLV LATCH 13 MMG-M DMY RK 36 MMG-M DMY RK 46 KBG-2 DMY RK 48 KBG-2 DMY RK 40 KBG-2 DMY RK PORT DATE o 07/22/03 o 07/22/03 o 12/31/01 o 12/31/01 o 12/31/01 BAKERZXPPKR I 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 4-1/2" HES X NIPW/ RHCSLV, ID = 3.813" -13.70" DEPlOYMENT SLY, 10 - 3.0" (4" GS) 3-1/2" X N!P, !D '" 2.813" I 4-1/2" UNIQUE OVERSHOT, ID = 3.875" -17" X 4-1/2" BAKERS-3 PKR, 8/97,ID= 3.875" -14-1/2" HES X NIP, 9Cr, ID = 3.813" I 4-1/2" WLEG, ID = 3.958" B.MD TT LOGGED 07/27/03 7" BAKER LINER HANGER I 9-5/8" CSG, 47#, L-80 & SOO-95, ID = 8.681" H 9849' CALCTOC I DATE 01/30/82 08/28/97 12/31/01 10/25/01 12/08/01 02/07/03 07/22/03 ÆRFORA TION SUMMARY REF LOG: BHCS ON 01/22/82 ANGLEATTOPÆRF: 39 @ 10232' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 10232 - 10236 s 01/28/04 3-3/8" 4 10244 - 10248 s 01/28/04 ? 4 10348 - 10368 S 06/11/88 ? 4 10366-10376 S 06/11/88 3-3/8" 1 10368 - 10378 s 01/28/04 ? 4 10384 - 10416 S 06/11/88 3-3/8" 4 10416 - 10446 S 07/05/91 3-3/8" 4 10420 - 10440 s 01/28/04 TO 10558' REV BY COMMENTS ORIGINAL COM PLETION WORKOVER41/2"L-80 DAC/KK LAST WORKOVER4 1/2" 13Cr RN/TP CORRECTIONS TMN/ll.H TUBING CUT JMP/KK WAWER SAFETY NOTE JCMlTLH GL V C/O I FISH - 2-1/2" GS LATCH FINGER 9/30/04 AND 10-1/4' FISH, 1.81 FN NEED 2.5" -I TOP OF CEMENT I -13-1/2" BAKER, ST-L. 13-CR-80 LANDING COLLAR -1 BOTTOM OF CEMENT I PRUDHOE BAY UNIT WB.L: 11-06 ÆRMIT No: "1811610 API No: 50-029-20674-00 SEC 33, T11N. R15E. 3977.22' FB. & 3381.92' FNL DA TE REV BY COMMENTS 07/27/03 KSB/KK B.MD TT LOG DEPTH 01/28/04 JAFITLP 3 1/2" Inr 02/06/04 BJMcNlK FISH 10/16/04 GRClTLH KB & BF B.EV CORRECTIONS 09/10/04 JGMlTLP CTGS TO LATCH 09/30/04 KCFITLP FISH 11/02/04 MSE ADD DRLG DETAILS BP Exploration (Alaska) TREE = FMC GEN 2 1 1 06A/ ~NOTES: CHROMETBG. **IAxOACOMM. WELLHEAD - cr.¡..¡ ACTUATOR = BAKER C - OPERATING PRESSURE OFTHE 13-3/8" ANNULUS KB. ELEV - 62 Proposed CTD Sidetrack MUST NOT EXCEED 2000 PSI (02/07/03 WAlVER)** BF. ELEV - 31 **3-1/2" LNR & 4-1/2" CHROME TBG** KOP= 3200' Max Angle = 49 @ 6600' Datum MD = 10396' I I 2082' 4-112" HES X NIP, ID = 3.813" I Datum 1VD = 8700' SS GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE ~ ~ 1 3320 3315 13 MMG-M DMY RK 0 07/22/03 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2515' 2 5025 4841 36 MMG-M DMY RK 0 07/22/03 ~ 3 6019 5564 46 KBG-2 DMY RK 0 12/31/01 4 6379 5808 48 KBG-2 DMY RK 0 12/31/01 5 9216 7825 40 KBG-2 DMY RK 0 12/31/01 5983' !xl 5983' H BAKERZXPPKR I TOP OF 7" SCAB LNR 19 5/8" leak '97 6340' ~ 9243' - 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 1 9308' - 4-1/2" HES X NIPW/ RHC SLY, ID = 3.813" 1 ITOP of Cement I 9325' 9325' -iTop of 2-3/8" Liner I 9340' 13/0" DEH()YMENT SLV ID '" '30" (4" (;3) I 9300' 3-1/7' X NiP. ID /61.) I 4-1/2" TBG, 12.6#, 13-CR. .0152 bpf, ID = 3.958" 9369' 9309' 4-UZ' UNIQUE O\!FFS.HOT. iD '" 3.875" I 9400' -i 'p X 4-112" p~ KER ~-<{ PKn if) '" '" B'n," I ;; ... .."·,,0,·,,... 0 <..'. ,'>.. ,.,. ,/, f.,<, _ 13-1/2" LNR, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" 9429' -1 ".. " 12" ['Ie- '< '~'P ID"- 3 p 1 0" I '~. 1: , .,,;) /,! i ~ - .... ,d ,) I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9441' 9441' 4·112" ,Mi FT~ in 3f)5B~~ I I TOP OF 7" LNR 9524' 9438' ELMD IT LOCCED 07/27/03 I 7" LNR-TIEBACK, 29#, L-80, .0371 bpf, ID = 6.184" 9525' t- 9524' H 7" BAKER LINER HANGER I ..--t 9700' H CALC TOe I 9-5/8" CSG, 47#, L-80 & SOO-95, 10 = 8.681" 9849' ~ ~ Il\i1echanìcal Whipstock 9900' I I 2-3/8" cmt'ed and perfed I 11600' I ÆRFORA TION SUMMARY REF LOG: BHCS ON 01/22/82 -- I PBTD H 11560' 1 ANGLE AT TOP ÆRF: 39 @ 10232' j CT fish cut and retrieved below 10200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10232 - 10236 s 01/28/04 3- 3/8" 4 10244 - 10248 s 01/28104 H 10242' FISH - 20' BHA (JARS, MOTOR, MILL) 5/8" I ? 4 10348 - 10368 S 06/11/88 STEEL DISCONNECT BALL IN CT ? 4 10366 - 10376 S 06/11/88 3-3/8" 1 10368 - 10378 s 01/28/04 ~ ? 4 10384 - 10416 S 06/11/88 ~ 3-3/8" 4 10416 - 10446 S 07/05/91 3-3/8" 4 10420 - 10440 s 01/28/04 . 17" LNR, 29#, L-80, BTC, 0.0371 bpf, ID = 6.184" I 10557' r I TD I 10558' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 01/30/82 ORIGINAL COMPLETION 07/27/03 KSB/KK ELMD TT LOG DEPTH I WELL: 11-06A 08/28/97 WORKOVER 01/28/04 JAFITLP MIN ID, DEPLOY SL V, X NIP, CMT ÆRMIT No: 12/31/01 DAC/KK LAST WORKOVER 02/06/04 BJMcNlKI< FISH API No: 50-029-20674-01 10/25/01 RN/TP CORRECTIONS 10/16/04 GRClTLH KB & BF ELEV CORRECTIONS SEC 33, T11N, R15E, 3977.22' FEL & 3381.92' FNL 12/08/01 TMN/TLH TUBING CUT 09/10/04 JGIINTLP CT GS TO LATCH 02/07/03 JMP/KK WAIVER SAFETY NOlE 09/30/04 KCFITLP FISH 07/22/03 JCIINTLH GLV C/O 11/02/04 MSE ADD DRLG DETAILS BP Exploration (Alaska) BP Amoco WELLPATH DETAILS PI..#411.oSA 500212087401 P....ntW.llp.thl 11·0. TleonMDz 1800.00 RI,_ Nordic 1 Ref. Datuml 111 08UIZ7/1..1 00100 V.s.ctlon ~~~ ~~~; ::::Ttu Angl. 90.00' 0.00 0.00 34.00 REFERENCE INFORMATION c~~rc~r ~5~ ~:~:~:g6:~ ~~:e~n~:~~ 1S~~ ~e~:J North Section (VS) Reference: Slot - 06 (O.OON,O.OOE) Measured Depth Reference: 11: 06 12/27/1981 00:00 62.00 CalculatIon Method: Minimum Curvature SECTtoN DETAILS M' ,., .. TV' ..~ '0éW OL.. TFa.." vs... T.rø.' ..00.00 3!II.00 303.87 8226.20 2018,87 -3833.05 0.00 0.00 -3533.05 "00.00 34.75 303.72 83011.24 2041.87 -3580.57 ::~~ 1=:~~ ~=~~ 8820.00 36.45 3Ø4.7. 8324.50 20511.22 -3500.19 8970.00 42.43 311.80 8383.12 207..... -3014..' 16.00 40.00 -38'4..'" H20.00'1.31 40.27 8ea1.01 2478.58 -3588.14 15.00 94.70 -35".14 1020.00 '..04 115.3' 8715.32 2174.00 ·3117.23 15.00 88.70 -3117.23 1850.00 87.81 209.8. .740.83 2838.30 -21150.48 18.00 82..5 -28øo.48 ANNOTATIONS TARGET DETAILS , MD Annot.tion ,~ NO .w. +eJ.JN Shape .20 1800.00 TIP ¡1:g¡~~~3.1 8:88 =:~~ ~m:~ ~= .24 8'00.00 KOP H~~~~ 86J~ ~~:: ~i:~ ~;: .50 8820.00 end' DLS I begin 1$ DI .12 8870.00 4 U-ooAT3.2 8747.00 2063.70-2981.1G Þoinl .0110520.00 5 .32 11020.00 1 .13 11"0.00 TD Plan: Plan #4 (11-06/Plan#411-06A) Created By: Bnj Potnis Date: 9/1/2004 Contact ¡nforrnatior:: Baker Hugh€!:':: Azimuths to True North Magnetic North: 25.26' Magnetic Field Strength: 57630n T Dip Angle: 80.87' Date: 9/1/2004 Model: bggm2004 T l 11-06(11-06) Plan#4 11-06A Plan #4 e e ....281 C ~ 2700] 0' ~261 ... +",251 - .c 1:241 o Ë:231 - I ;ë221 .. :I 021 en TT'~"rTT r: T "TYTTY""t""iT 50 -3400 -3350 -3300 -3250 -3200 -3150 -31' 00 -3050 -3000 -2950 -2900 -2850 -2800 -2150 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2 i 00 -2050 -2000 -1950 -1900 -1850 Vertical Section at 90.00' [50ft/in] 81 ë'8200 ~ 8250 o !!?83oo .c b.8350 GI Q 8400 ¡ U 8450 1: GI 8500 > GI 8550 2 to- 8600 'in "";''',..¡',¡-,..,.-, -3800 -3750 -3700 -3650 -3600 -3550-3500 . BP-GDB Baker Hughes INTEQ Planning Report . Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB OS 11 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5949527.78 ft 707585.65 ft Latitude: 70 15 Longitude: 148 19 North Reference: Grid Convergence: 55.850 N 17.134 W True 1.58 deg Well: 11-06 Slot Name: 06 11-06 Well Position: +N/-S 1827.17 ft Northing: 5951353.38 ft Latitude: 70 16 13.820 N +E/-W -28.67 ft Easting : 707506.61 ft Longitude: 148 19 17.969 W Position Uncertainty: 0.00 ft Wellpath: Plan#4 11-06A 500292067401 Current Datum: 11 : 06 12/27/1981 00:00 Magnetic Data: 9/1/2004 Field Strength: 57630 nT Vertical Section: Depth From (TVD) ft 34.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 11-06 9900.00 ft Mean Sea Level 25.26 deg 80.87 deg Direction deg 90.00 Height 62.00 ft Targets 11-06A Polygon3.1 0.00 2501.36 -3759.77 5953750.00 703679.50 70 16 38.412 N 148 21 7.457 W -Polygon 1 0.00 2501.36 -3759.77 5953750.00 703679.50 70 16 38.412 N 148 21 7.457 W -Polygon 2 0.00 1847.53 -2905.93 5953120.00 704551.00 70 1631.985 N 148 20 42.585 W -Polygon 3 0.00 2335.95 -2514.29 5953619.00 704929.00 70 16 36.790 N 148 20 31.186 W -Polygon 4 0.00 2883.54 -3361.56 5954143.00 704067.00 70 16 42.172 N 148 20 55.865 W 11-06A Fault 1 0.00 4620.46 -5181.46 5955829.00 702200.00 70 16 59.245 N 148 21 48.900 W -Polygon 1 0.00 4620.46 -5181.46 5955829.00 702200.00 70 16 59.245 N 148 21 48.900 W -Polygon 2 0.00 2962.91 -2757.12 5954239.00 704669.00 70 16 42.955 N 148 20 38.263 W 11-06AFault2 0.00 3233.78 -4235.28 5954469.00 703184.00 70 16 45.612 N 1482121.316W -Polygon 1 0.00 3233.78 -4235.28 5954469.00 703184.00 70 1645.612 N 148 21 21.316 W -Polygon 2 0.00 695.27 -3530.97 5951951.00 703958.00 70 16 20.650 N 148 21 0.769 W 11-06A Fault 3 0.00 2660.96 -3706.85 5953911.00 703728.00 70 16 39.982 N 148 21 5.918 W -Polygon 1 0.00 2660.96 -3706.85 5953911.00 703728.00 70 16 39.982 N 148 21 5.918 W -Polygon 2 0.00 1395.45 -3127.49 5952662.00 704342.00 70 16 27.538 N 148 20 49.031 W 11-06AT3.1 8663.00 2473.45 -3545.95 5953728.00 703894.00 70 16 38.138 N 148 21 1.229 W -Plan out by 20.86 at 8663.00 2488.33 -3560.57 5953742.47 703878.97 70 16 38.284 N 148 21 1.655 W 11-06A T3.2 8747.00 2063.70 -2981.10 5953334.00 704469.90 70 1634.111 N 148 20 44.776 W Annotation 9800.00 8226.20 TIP 9900.00 8308.24 KOP 9920.00 8324.50 end 9 DLS / begin 15 DLS 9970.00 8363.12 4 10520.00 8661.01 5 . BP-GDB Baker Hughes INTEQ Planning Report . Plan #4 Date Composed: 9/1/2004 Similar to Lamar's Plan #3 Version: 1 Yes Tied-to: From: Definitive Path Plan Section Information 9800.00 35.00 303.87 8226.20 2016.87 -3533.05 0.00 0.00 0.00 0.00 9900.00 34.75 303.72 8308.24 2048.67 -3580.57 0.26 -0.25 -0.15 198.87 9920.00 36.45 304.76 8324.50 2055.22 -3590.19 9.00 8.48 5.18 20.00 9970.00 42.43 311.90 8363.12 2074.98 -3614.98 15.00 11.96 14.29 40.00 10520.00 81.31 40.27 8661.01 2478.56 -3569.14 15.00 7.07 16.07 94.70 11020.00 88.04 115.39 8715.32 2574.00 -3117.23 15.00 1.35 15.02 89.70 11650.00 87.61 209.98 8746.63 2039.30 -2950.48 15.00 -0.07 15.01 92.55 Survey TIP MWD MWD MWD KOP 9920.00 36.45 304.76 8324.50 2055.22 -3590.19 5953308.73 703861.31 -3590.19 9.00 20.00 end 9 DL 9925.00 37.02 305.56 8328.51 2056.94 -3592.63 5953310.38 703858.82 -3592.63 15.00 40.00 MWD 9950.00 39.98 309.26 8348.07 2066.41 -3604.98 5953319.50 703846.21 -3604.98 15.00 39.36 MWD 9970.00 42.43 311.90 8363.12 2074.98 -3614.98 5953327.80 703835.98 -3614.98 15.00 36.46 4 9975.00 42.37 313.01 8366.81 2077 .26 -3617.47 5953330.00 703833.43 -3617.47 15.00 94.70 MWD 10000.00 42.25 318.58 8385.31 2089.31 -3629.19 5953341.73 703821.38 -3629.19 15.00 93.88 MWD 10025.00 42.40 324.14 8403.79 2102.45 -3639.69 5953354.57 703810.52 -3639.69 15.00 89.76 MWD 10050.00 42.82 329.65 8422.20 2116.62 -3648.93 5953368.48 703800.90 -3648.93 15.00 85.64 MWD 10075.00 43.50 335.04 8440.44 2131.75 -3656.85 5953383.39 703792.56 -3656.85 15.00 81.59 MWD 10100.00 44.42 340.28 8458.45 2147.80 -3663.44 5953399.25 703785.54 -3663.44 15.00 77.66 MWD 10125.00 45.57 345.33 8476.13 2164.67 -3668.65 5953415.97 703779.86 -3668.65 15.00 73.88 MWD 10150.00 46.94 350.16 8493.42 2182.31 -3672.47 5953433.50 703775.55 -3672.47 15.00 70.31 MWD 10175.00 48.50 354.77 8510.25 2200.64 -3674.89 5953451.75 703772.63 -3674.89 15.00 66.97 MWD 10200.00 50.24 359.15 8526.53 2219.58 -3675.88 5953470.65 703771.12 -3675.88 15.00 63.87 MWD 10225.00 52.13 3.31 8542.20 2239.04 -3675.45 5953490.12 703771.01 -3675.45 15.00 61.01 MWD 10250.00 54.16 7.25 8557.20 2258.95 -3673.61 5953510.08 703772.31 -3673.61 15.00 58.41 MWD 10275.00 56.31 10.99 8571.46 2279.22 -3670.34 5953530.43 703775.01 -3670.34 15.00 56.04 MWD 10300.00 58.57 14.54 8584.92 2299.77 -3665.68 5953551.09 703779.11 -3665.68 15.00 53.91 MWD 10325.00 60.93 17.92 8597.51 2320.49 -3659.64 5953571.97 703784.57 -3659.64 15.00 52.00 MWD 10350.00 63.36 21.15 8609.19 2341.32 -3652.24 5953592.99 703791.39 -3652.24 15.00 50.29 MWD 10375.00 65.86 24.24 8619.91 2362.15 -3643.53 5953614.05 703799.53 -3643.53 15.00 48.78 MWD 10400.00 68.43 27.21 8629.63 2382.89 -3633.53 5953635.07 703808.96 -3633.52 15.00 47.46 MWD 10425.00 71.04 30.07 8638.29 2403.47 -3622.28 5953655.94 703819.63 -3622.28 15.00 46.31 MWD 10450.00 73.70 32.85 8645.86 2423.79 -3609.84 5953676.59 703831.50 -3609.84 15.00 45.31 MWD 10475.00 76.39 35.55 8652.31 2443.76 -3596.27 5953696.93 703844.52 -3596.27 15.00 44.47 MWD 10500.00 79.11 38.19 8657.61 2463.29 -3581.61 5953716.86 703858.63 -3581.61 15.00 43.77 MWD 10520.00 81.31 40.27 8661.01 2478.56 -3569.14 5953732.46 703870.67 -3569.14 15.00 43.21 5 10525.00 81.31 41.03 8661.77 2482.31 -3565.92 5953736.30 703873.79 -3565.92 15.00 89.70 MWD 10550.00 81.36 44.82 8665.54 2500.40 -3549.09 5953754.85 703890.11 -3549.09 15.00 89.59 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 10575.00 81.44 48.61 8669.28 2517.34 -3531.10 5953772.28 703907.63 -3531.10 15.00 89.01 MWD 10600.00 81.56 52.40 8672.97 2533.07 -3512.03 5953788.52 703926.26 -3512.03 15.00 88.45 MWD 10625.00 81.72 56.19 8676.61 2547.50 -3491.94 5953803.50 703945.94 -3491.94 15.00 87.89 MWD 10650.00 81.91 59.98 8680.17 2560.58 -3470.94 5953817.16 703966.57 -3470.94 15.00 87.34 MWD 10675.00 82.14 63.75 8683.64 2572.25 -3449.11 5953829.42 703988.07 -3449.11 15.00 86.80 MWD 10700.00 82.40 67.53 8687.01 2582.46 -3426.55 5953840.26 704010.34 -3426.55 15.00 86.27 MWD 10725.00 82.69 71.30 8690.26 2591.18 -3403.35 5953849.61 704033.29 -3403.35 15.00 85.76 MWD 10750.00 83.01 75.07 8693.37 2598.35 -3379.61 5953857.43 704056.82 -3379.61 15.00 85.27 MWD 10775.00 83.37 78.83 8696.33 2603.96 -3355.43 5953863.70 704080.83 -3355.43 15.00 84.80 MWD 10800.00 83.75 82.58 8699.14 2607.97 -3330.92 5953868.39 704105.22 -3330.92 15.00 84.36 MWD 10825.00 84.16 86.33 8701.77 2610.37 -3306.18 5953871.47 704129.89 -3306.18 15.00 83.94 MWD 10850.00 84.59 90.07 8704.22 2611.15 -3281.32 5953872.94 704154.72 -3281.32 15.00 83.54 MWD 10875.00 85.05 93.81 8706.48 2610.31 -3256.44 5953872.78 704179.61 -3256.44 15.00 83.18 MWD 10900.00 85.53 97.54 8708.53 2607.85 -3231.65 5953871.00 704204.46 -3231.65 15.00 82.84 MWD 10925.00 86.02 101.27 8710.38 2603.77 -3207.06 5953867.61 704229.15 -3207.06 15.00 82.53 MWD 10950.00 86.54 104.99 8712.00 2598.11 -3182.77 5953862.61 704253.59 -3182.77 15.00 82.26 MWD 10975.00 87.06 108.71 8713.39 2590.87 -3158.88 5953856.04 704277.66 -3158.88 15.00 82.02 MWD 11000.00 87.61 112.42 8714.56 2582.10 -3135.50 5953847.92 704301.27 -3135.50 15.00 81.81 MWD 11020.00 88.04 115.39 8715.32 2574.00 -3117.23 5953840.33 704319.75 -3117.23 15.00 81.63 6 11025.00 88.01 116.14 8715.49 2571.83 -3112.73 5953838.28 704324.31 -3112.73 15.00 92.55 MWD 11050.00 87.85 119.89 8716.39 2560.10 -3090.68 5953827.16 704346.68 -3090.68 15.00 92.52 MWD 11075.00 87.70 123.64 8717.36 2546.95 -3069.45 5953814.60 704368.27 -3069.45 15.00 92.39 MWD 11100.00 87.56 127.39 8718.40 2532.44 -3049.12 5953800.66 704388.98 -3049.12 15.00 92.24 MWD 11125.00 87.43 131.14 8719.49 2516.63 -3029.79 5953785.39 704408.75 -3029.79 15.00 92.09 MWD 11150.00 87.31 134.90 8720.64 2499.60 -3011.53 5953768.87 704427.46 -3011.53 15.00 91.92 MWD 11175.00 87.20 138.65 8721.84 2481.41 -2994.43 5953751.16 704445.06 -2994.43 15.00 91.75 MWD 11200.00 87.10 142.40 8723.09 2462.14 -2978.56 5953732.33 704461.45 -2978.56 15.00 91.57 MWD 11225.00 87.02 146.16 8724.37 2441.87 -2963.99 5953712.48 704476.58 -2963.99 15.00 91.38 MWD 11250.00 86.94 149.91 8725.69 2420.69 -2950.77 5953691.67 704490.37 -2950.77 15.00 91.19 MWD 11275.00 86.89 153.67 8727.03 2398.70 -2938.97 5953670.01 704502.77 -2938.97 15.00 90.99 MWD 11300.00 86.84 157.42 8728.40 2375.98 -2928.64 5953647.59 704513.73 -2928.64 15.00 90.79 MWD 11325.00 86.81 161.18 8729.79 2352.64 -2919.82 5953624.50 704523.19 -2919.82 15.00 90.59 MWD 11350.00 86.79 164.93 8731.18 2328.76 -2912.54 5953600.84 704531.12 -2912.54 15.00 90.38 MWD 11375.00 86.79 168.69 8732.58 2304.46 -2906.85 5953576.71 704537.48 -2906.85 15.00 90.17 MWD 11400.00 86.80 172 .44 8733.98 2279.85 -2902.76 5953552.21 704542.25 -2902.76 15.00 89.96 MWD 11425.00 86.82 176.20 8735.37 2255.01 -2900.29 5953527.45 704545.40 -2900.29 15.00 89.75 MWD 11450.00 86.86 179.96 8736.75 2230.07 -2899.45 5953502.54 704546.92 -2899.45 15.00 89.54 MWD 11475.00 86.91 183.71 8738.11 2205.12 -2900.25 5953477.59 704546.81 -2900.25 15.00 89.33 MWD 11500.00 86.97 187.47 8739.45 2180.28 -2902.68 5953452.69 704545.07 -2902.68 15.00 89.13 MWD 11525.00 87.05 191.22 8740.75 2155.65 -2906.73 5953427.96 704541.70 -2906.73 15.00 88.93 MWD 11550.00 87.14 194.97 8742.02 2131.34 -2912.39 5953403.50 704536.71 -2912.39 15.00 88.73 MWD 11575.00 87.24 198.73 8743.25 2107.44 -2919.63 5953379.42 704530.14 -2919.63 15.00 88.54 MWD 11600.00 87.35 202.48 8744.43 2084.07 -2928.41 5953355.81 704522.00 -2928.41 15.00 88.36 MWD 11625.00 87.48 206.23 /8745.56 2061.32 -2938.71 5953332.79 704512.34 -2938.71 15.00 88.18 MWD 11650.00 87.61 209.98 8746.63 2039.30 -2950.48 5953310.45 704501.18 -2950.48 15.00 88.01 TO Nordic 1 slim hole All Measurements are from top of Riser 11/2/2004 :I.... Q) en .- cr:: bttm of bag BAG 7 1/16" 5000psi top of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ....................·····7 1/16" 5000psi middle of flow cross Mud Cross Mud Cross 71/16" 5000psi middle of blind/shears .......................... middle of pipe/slips TOTs ....................·····7 1/16" 5000psi · e r . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ßú /1- ò ~ 1'; PTD# ;;Loz¡ - :2-,2-t; - X Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new well bore segment of existing wen . Permit No, API No. . Production. sbould continue to be reponed as a function 'of tbe original API number. stated above. .' HOLE ]n accordance witb 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). PD...OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE .' Tbe permit is approved subject ·to fun . complhmce witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing f:xception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:xception tbat JDay occur. All dry ditcb sample sets subJDitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample h:ite:r:vals through target zones. .' Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: UNITJ1-06A Program DEV Well bore seg 0 PLORATION (ALASKA) INC Initial ClasslType _DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 0 iiii Administration p_ermit fee attache_d_ _ - - - - - - - - - - - Yes_ _ - - - - - 2 Leas_enumberappropriate_ _ - - - - - - - - - - - - - - - - - _ _ _ _ _ Y_es - - - - - - - - - 3 _Un [qUe welln_am_e_and Ol!mber _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _Y_es__ - ~ - - - - - - - - - - - 4 WeJUocat~d [na d_efined .pool Y~s - - - - - 5 Well located p(Oper .distanœ from driJling unit bound.ary. . . . . _ . .Y.es.. - - - - - 6 Welllocat~d pLoper .distance. from otbe.r welJs - - - - - - . . .Y_es - - - - - - 7 .S.ufficient.acreage.aYail<:lble in.drilliog l!njt. . _ . . . . _ ... _. Yes__ - - - - 8 If.d.eviated, js weJlbore plç¡tincJuded _ . . . . - - - - - .... _ Y.es - - - - 9 .Qperator only affected party. - - - -- - - - - .... Y~s _. 10 .Operator has. appropriate. bond inJorce. . . . . . . . . . . . _ _ _ _ _ _ _ _ _. _ _ _ _ Yes_. - - - - - - - - - - - -- 11 permit ~n be iSSl!ed without conservation order _ . . - - - - Y_es. . - - -- Appr Date 12 P~rmit cao Þe iSSl!ed wjthout admioistratÍlle.apPLoval . _ _ ... _ _... Yes. . RPC 11/3/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocated withio area and. strata authorized by_lnjectioo Order # (put 10# incomments)_ (For _NA 15 AJI weUs_wit]1tn Jl4. míte.area.of reyiew id~ot[fied (For servj~.we!l onlYL . _ . . . . _ _ _ . . _ .NA. . - - - - - - - - - - - -- 16 Pre-produ_ced injector; dur<:ltio.n_of pre-productioo less than 3 months (FocseMce well onJy) _NA 17 ACMP F:inding .of Con.ststency has been issued for_ this project . NA _. - - - - ~ Engineering 18 C.onductor string provided - - - - - - - NA - - - - 19 S_urfa~.casingprotects all_known USQWs _ . . . _ _ . NA _ 20 _CMT v.ot adequate. to circ_ulate.o_n_cond.uçtOL 8. SUJf.C$g . NA. . 21 _CMT vol adeQuate_ to tie-tnlQng _string to.s~JI:f C!>g. . _ . NA_. . 22 CMT wiIJ coyecaJI koownproductiye hori;zons. _ . . Yes - - - - - 23 .C.asiog desigos adequate for C,T, B_& permafrost Yes_ _ - - - - -- 24 Adequ_ate.tankç¡ge.or re_seI'Ye pit _ . . _ _ . . Y_es. CTDU._ . 25 JtaJe-_drilL has_a_ 10A03 for <:Ibandonme.nt be~o approved _ . . _Yes _ . * 26 Adequate.wellbore separatjo.n.proposed. _ _ . _ . . _ . . _ _ _ . _ . _ . . .Y~s. . - - - - - - - - - - - -- 27 Jtdiv~rter Jeq.uired. does iLmeet regulatioos_ _ . NA __ Sidetrack. _ _ . Appr Date 28 _DJilIiog fJuidprograll) schematic & eq.uipJistadequate_ - - - - - Yes_ . Max MW.8~6 ppg, . . e WGA 11/4/2004 29 .B.GP_Es, do .they meet regulatioo . _Y.es. - - - - - 30 _B.QPEpress ra_tiog appropriate; test to (puJ psig í.n.commeots) Yes_ . Test to 350Q psi. _MSF> 2520 psi._ _ 31 ChOke manifold cOll)plies w/APl RF>-53 (May 84)_ . .Y~s. . - - - - - 32 .work will occ.ur withoutoperation_shutdown. - - - - - - Yes_ . - - - - 33 Is preseoce of H2S gas_ probable _ - - - - - Yes. 660ppmon pad. 34 .Mecha_n[calcoodJUoo of wells withill AOR verified (FPL service w~1J ollly) _NA Geology 35 P_erll)it cal1 Þe issued w/o hydrogen sulfide meas.ures _ _ _ _ No 36 .D_ata_pJeseoted on pote_ntial ove_rpressurezOlles. . - - - - - NA Appr Date 37 _Seismic_anç¡lysJs_ of shallow gas_z_ooes _ . . . . _ . . _NA 38 _S~Ç\bedcol'!ditio(l survey (if off-shore) . - - - - -- - - - - NA. 39 . Contact namelp]1oneJorwe~lsly progress reports [exploratory_onIYl NA - Geologic Date: Engineering Date Commissioner Commissioner Ô/J 414- . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this C<3tegory of information. . . J. Cl,/-ll..'- Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 06 10:29:07 2005 ) ~l2 Reel Header Service name.. ......... ..LISTPE Date.................... .05/07/06 Origin. . . . . . . . . . . . . . . . . . . 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.................... .05/07/06 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 Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 11- 06A 500292067401 BP Exploration (Alaska) Inc. Sperry Drilling Services 06-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003444751 S. LATZ R. WHITLOW / MWD RUN 5 MW0003444751 S. LATZ R. WHITLOW / MWD RUN 7 MW0003444751 S. LATZ R. WHITLOW / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW0003444751 S. LATZ R. WHITLOW / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 11N 15E 370 57 62.00 27.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS . . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.000 3.500 10067.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK POSITIONED IN THE 11-06 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 10067'MD/8444'TVDSS. 4. MWD RUNS 4,5,7,8 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY(PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUNS 1-3,6 MADE NO PROGRESS DUE TO EQUIPMENT FAILURES. UPHOLE TIE-IN DATA WERE MEREGED WITH RUN 4 MWD DATA. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D.SCHNORR, GEOQUEST(BP), DATED 6/30/05. 6. MWD RUNS 4,5,7,8 REPRESENT WELL 11-06A WITH API#: 50-029-20674-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11720'MD/8718'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name.... .........STSLIB.OOl Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation.. .....05/07/06 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 9852.0 10074.5 STOP DEPTH 11696.0 11719.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD BIT RUN NO MERGE TOP 4 9852.0 MERGE BASE 10088.0 . MWD MWD MWD $ 5 7 8 10088.0 10500.5 10774.0 10500.5 10774.0 11719.5 . # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction......... ..... ...Down Optical log depth units........ ...Feet Data Reference Point....... ... ....Undefined Frame Spacing.................. ...60 .1IN Max frames per record...... ..... ..Undefined Absent value............. ...... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD MWD Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9852 11719.5 10785.8 3736 9852 11719.5 ROP MWD FT/H 0.34 692.3 94.9114 3291 10074.5 11719.5 GR MWD API 18.38 835.78 52.6966 3380 9852 11696 First Reading For Entire File...... ....9852 Last Reading For Entire File........ ...11719.5 File Trailer Service name... ......... .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..05/07/06 Maximum Physical Record..65535 File Type............... .LO 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..... ..05/07/06 Maximum Physicål Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 2 header data for each bit run in separate files. 4 .5000 . FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 9852.0 10074.5 STOP DEPTH 10064.0 10088.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units........ ...Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record. ... .........Undefined Absent value................... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 . 16-DEC-04 Insite Memory 10088.0 10074.0 10088.0 .0 .0 TOOL NUMBER TLG005 2.800 10067.0 Biozan 8.50 60.0 .0 13000 .0 .000 .000 .000 .000 .0 141.0 .0 .0 Name Service Order DEPT ROP MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . GR MWD040 API 4 1 68 8 3 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9852 10088 9970 473 9852 10088 ROP MWD040 FT/H 0.34 59.11 8.88607 28 10074.5 10088 GR MWD040 API 27.6 347.58 66.5239 116 9852 10064 First Reading For Entire File...... ....9852 Last Reading For Entire File.......... .10088 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .05/07/06 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name. ......... ...STSLIB.003 Service Sub Level Name... Version Number. .... ..... .1.0.0 Date of Generation.... ...05/07/06 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 5 .5000 START DEPTH 10064.5 10088.5 STOP DEPTH 10476.0 10500.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-DEC-04 Insite Memory 10500.0 10088.0 10500.0 36.8 77.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray TOOL NUMBER TLG005 . $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing... ................. .60 .1IN Max frames per record............ .Undefined Absent value........ ............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 3.000 10067.0 Flo Pro 8.70 65.0 9.0 18000 5.0 .000 .000 .000 .000 .0 137.5 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10064.5 10500.5 10282.5 873 10064.5 10500.5 ROP MWD050 FT/H 1. 28 154.4 78.9819 825 10088.5 10500.5 GR MWD050 API 18.38 835.78 50.4539 824 10064.5 10476 First Reading For Entire File..... .... .10064.5 Last Reading For Entire File..... ..... .10500.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/06 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...... .05/07/06 Maximum Physical Record. .65535 File Type.. ........ ..... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 . header data for each bit run in separate files. 7 .5000 START DEPTH 10476.5 10501. 0 STOP DEPTH 10748.5 10774.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20-DEC-04 Insite Memory 10772.0 10500.0 10772.0 79.5 84.6 TOOL NUMBER TLG005 3.000 10067.0 Flo Pro 8.70 65.0 9.0 18000 7.2 .000 .000 .000 .000 .0 146.0 .0 .0 . VENDOR TOOL CODE GR ROP $ START DEPTH 10749.0 10774.5 STOP DEPTH 11696.0 11719.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ...... ......0 Data Specification Block Type.....O Logging Direction......... ...... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing......... ............60 .1IN Max frames per record........... ..Undefined Absent value....... .............. .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD080 GR MWD080 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API . 22-DEC-04 Insite Memory 11720.0 10772 .0 11720.0 80.9 93.3 TOOL NUMBER TLG005 3.000 10067.0 Flo Pro 8.70 65.0 9.0 23000 5.8 .000 .000 .000 .000 .0 154.3 .0 .0 Offset o 4 8 Channel 1 2 3 . . # 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 .1IN Max frames per record...... .......Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD070 MWD070 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10476.5 10774 10625.3 596 10476.5 10774 ROP MWD070 FT/H 1. 88 153.52 96.0223 547 10501 10774 GR MWD070 API 19.83 94.47 33.2268 545 10476.5 10748.5 First Reading For Entire File......... .10476.5 Last Reading For Entire File.......... .10774 File Trailer Service name. .......... ..STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/07/06 Maximum Physical Record. .65535 File Type................ LO 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...... .05/07/06 Maximum Physical Record..65535 File Type.... ........ ....LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 5 header data for each bit run in separate files. 8 .5000 . . Name DEPT ROP GR Service Unit FT MWD080 FT/H MWD080 API Min 10749 0.74 23.28 Max 11719.5 692.3 183.79 Mean 11234.3 102.813 58.4249 Nsam 1942 1891 1895 First Reading 10749 10774.5 10749 Last Reading 11719.5 11719.5 11696 First Reading For,Entire File......... .10749 Last Reading For Entire File.......... .11719.5 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number. .... .01 Next Tape Name... ....... . UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ...... .... .... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments..... ...... ..... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File