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HomeMy WebLinkAbout199-033 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, March 15, 2016 2:40 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Sayers, Jessica; Dickerman, Eric; Pettus,Whitney; Munk, Corey; Odom, Kristine; Schultz, Kirsten L Subject: OPERABLE: Producer 12-28A (PTD#1990330) MIT-T Passed post valve changeout All, Producer 12-28A(PTD#1990330) passed a MIT-T to 2700 psi on March 12, 2016 following gas lift work. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please use caution when bringing the well online as the annuli are fluid packed. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAR 1 12016 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GI WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, June 24, 2015 2:58 PM To: AK, OPS FS1 OSM; AIZ,'OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: NOT OPERABLE: Producer 12-28A (PTD #1990330) Sustained Inner Annulus Casing Pressure above MOASP All, Producer 12-28A(PTD#1990330) was reported to have sustained inner annulus casing press�bove MOASP on 06/22/15. The pressures were reported to be inner annulus/outer annulus 2050/20. The well is shut in for planned facility maintenance. The well is reclassified as Not Operable until barriers can be restored and confirmed. 1 • . Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 26, 2015 10:53 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 12-28A (PTD #1990330) NOT Ready to Place on Production for Evaluation Attachments: Producer 12-28A (PTD #1990330) TIO Plot.docx All, Producer 12-28A (PTD#1990330) will NOT be placed on production at this time for evaluation. The well is reclassified back to NOT OPERABLE until well can be placed on production. Please call with any questions or concerns. Thank you, Kevin Parks (Artern?te Whitney y Pettv, SCANNED AUG 1 12016. BP Alaska -Well Integrity Coordinator G�/�� Global Wells Y Y Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Monday, October 26, 2015 9:36 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wal lace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Producer 12-28A (PTD #1990330) Ready to Place on Production for Evaluation All, Producer 12-28A(PTD#1990330) was reported to have sustained inner annulus casing pressure above MOASP on June 22, 2015.The well is ready to place on production for evaluation. The well is reclassified as Under Evaluation and placed on a 28 day clock. 1 • • Plan forward: 1. Operations: Place well on production 2. DHD: Perform TIFL A copy of the TIO plot is included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal W Organizationells Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, June 24, 2015 2:58 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg©alaska.gov) Subject: NOT OPERABLE: Producer 12-28A (PTD #1990330) Sustained Inner Annulus Casing Pressure above MOASP All, Producer 12-28A (PTD#1990330) was reported to have sustained inner annulus casing pressure above MOASP on 06/22/15. The pressures were reported to be inner annulus/outer annulus 2050/20. The well is shut in for planned facility maintenance. The well is reclassified as Not Operable until barriers can be restored and confirmed. The surface safety valve was closed on the well for well safe out,therefore the tubing pressures could not be obtained. Plan forward: 1. DHD: Perform TIFL after the wells are placed on production Copy of the TIO plot is included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GANGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegritVCoordinator@bp.com 2 , •� 1 Producer 12-28A(PTD#1990330)TIO Plot .ar -aro -i-M zar -•••--a aa. -4.-000. 0-YI6 tam MAN{ WV'S earl! Man MMS NOW. .. MIMS WFltS • • Feb( IZ -zeA f93 c Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 'q 7 36 ,1L Sent: Friday, July 27, 2012 1:51 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; Dos Santos, Higino W Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA during shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forward. 01 -34A • ! • !; s 12 -28A (PTD # 1990330) All the wells listed above are reclassified as Not Operable until start-up operations commence and are stable or the well passes a pressure test confirming integrity. After start-up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) SCANNED MAY 0 2 2013 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 & .. . ---. -• Email: AKDCWeIIIntegrityCoordinator (c�BP.com 1 OPERABLE: Producer 12 -28A (PTD #199033E/Tubing Integrity Confirmed Page 1 of 1 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] if it Sent: Tuesday, November 22, 2011 9:49 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS12 Operator; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike J; King, Whitney; LeBaron, Michael J; Catron, Garry R (Northern solutions) Subject: OPERABLE: Producer 12 -28A (PTD #1990330) Tubing Integrity Confirmed All, Producer 12 -28A (PTD #1990330) passed an MIT -IA to 3000 psi after dummying the gas lift valves on 11/19/2011. The passing test confirms the presence of two competent barriers in the well. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 r . Cell (907) 752 -0755 �j `; f L�� I ' i Pager (907) 659 -5100 Ext. 1154 '''- ' 3 ` From: AK, D &C Well Integrity Coordinator Sent: Monday, June 20, 2011 9:43 PM To: 'Maunder, Thomas E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS12 Operator; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan Cc: Walker, Greg (D &C); Meixueiro, Paulina Subject: NOT OPERABLE: Producer 12 -28A (PTD #1990330) Sustained Casing Pressure on IA All, Producer 12 -28A (PTD #1990330) has been found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA = SSV /2060/100 on 6/17/2011. The well is currently shut in for turnaround activity and has been reclassified as Not Operable. Once turnaround activity is complete, it will be reclassified as Under Evaluation and brought online for the following diagnostics: 1. DHD: TIFL 2. WIE: Evaluate GLV C/O A TIO Plot and wellbore schematic have been included for reference. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com 11/22/2011 NOT OPERABLE: Producer 12 -28A (oD #1990330) Sustained Casing Pressulon IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, June 20, 2011 9:43 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS12 Operator; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan Cc: Walker, Greg (D &C); Meixueiro, Paulina Subject: NOT OPERABLE: Producer 12 -28A (PTD #1990330) Sustained Casing Pressure on IA Attachments: 12- 28A.pdf; 12 -28 TIO Plot.doc All, i Producer 12 -28A (PTD #1990330) has been found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA = SSV /2060/100 on 6/17/2011. The well is currently shut in for turnaround activity and has been reclassified as Not Operable. Once turnaround activity is complete, it will be reclassified as Under Evaluation and brought online for the following diagnostics: 1. DHD: TIFL 2. WIE: Evaluate GLV C/O A TIO Plot and welibore schematic have been included for reference. «12- 28A.pdf» «12 -28 TIO Plot.doc» Thank you, Mehreen Vazir fi (Alternate: Gerald Murphy) ,�� t ►� JUN Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 6/21/2011 PBU 12 -28A PTD # 1990330 6/20/2011 TIO Pressures Plot Wa& 12 -28 4,000 • 3,000 • -U- LA VIISOSIPOIr A t IA OA 2000 - — — �_ DDA —4r— 000A On 1,000 - 1 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05 /14/11 05/21/11 05 /28/11 06/04/11 06/11/11 • 06/18/11 TREE = FMC GEN 3 • WELLHEAD = FMC 2-28 � SAFEf ES: ***CHROME TBG*** ACTUATOR = AXELSON 1 2 KB. ELEV = 69' BF. ELEV = w KOP = 2948' Max Angle = 60 @ 8360' I 2238' H5 -1/2" HES X NIP, ID = 4.562" Datum MD = 11832' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2590' 5 -1/2" TBG, 17 #, 13CR -80, . — 5774' .I-- I 5774' I--I5 - 1/2" X 4 -1/2" XO, ID = 3.958" I 0232 bpf, ID = 4.892" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3987 3854 51 LB DOME T2 16 06/09/09 ITOP OF 7" LNR H 5870' 2 7087 5849 49 KBG2LS DOME INT 16 06/09/09 3 9169 7105 47 KBG2LS DOME INT 16 06/09/09 4 9953 7601 47 KBG2LS DMY INT 0 Minimum ID = 3.813" @ 11384' 5 10609 8002 50 KBG2LS SO INT 24 07/14/10 HES X Nipple 11351' I- X 4 -1/2" BKR S -3 PKR, ID = ? I 4* Ii 11384' H4-1/2" HES X NIP, ID = 3.813" I Vj , 11384' I 4 -1/2" BRK SLIMPACK 1 SCREE N (05/25/11) . 7 ,r,I.,. 11405' I— I4 -1/2" WLEG, ID = 3.958 " I H EL TT NOT LOGGED I k I 11728' H WF ECLIPSE PKR, ID = ? ? ?? I • \ 11847' - 11917' - 1GRAVEL PACK, ID = 1.995" ��� 6670r-, I SEEWELLFILEFORSPECS 9 -5/8" CSG, 47 #, L -80, ID = 8.681" IR 11666' E — • I4 -1/2" TBG, 12.6 #, 13CR -80, .0152 bpf, ID= 3.958" I—I 11406' 11932' I BAKER 1AA CIBP SET 12/28/04 I TOP OF 4-1/2" LNR H 11405' I I 11970' H 4 -1/2" CIBPI 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I 11570' � PERFORATION SUMMARY ` REF LOG: SWS CBL ON 05/21/99 ANGLE AT TOP PERF: 40 @ 11604' Note: Refer to Production DB for historical perf data . SIZE SPF INTERVAL Opn /Sqz DATE \11 +., 2 -7/8" 6 11607 - 11634 0 10/21/08 \10P 2 -1/2" 4 11878 - 11890 0 05/12/02 3 -3/8" 12 11878 - 11890 0 12/28/04 14 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-I 12114' 2 -1/2" 4 11897 - 11917 0 05/12/02 3 -3/8" 12 11897 - 11917 0 12/28/04 3 -3/8" 4 11897 - 11930 S 05/24/99 3 -3/8" 4 11986 - 12000 C 05/24/99 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT R 1984 ORIGINAL COMPLETION 07/17/10 WEC/PJC GLV C/O (07/14/10) WELL: 12 -28A 05/17/99 SIDETRACKED "A" 12/20/10 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 1990330 12/11/99 RWO 02/09/11 MB /JMD REMVD SSSV SAFETY NOTE API No: 50- 029 - 21086 -01 06/14/09 DAV/TLH GLV CIO (06/09/09) 05/31/11 CJN/ PJC SET ROCK SCREEN (05/25/11) SEC 17, T10N, R15E, 264.95' FEL & 4768.44' FNL 02/03/10 KNC /PJC PERF DEPTH CORRECTION 04/29/10 CJN/PJC GLV C/O (04/25/10) BP Exploration (Alaska) - OPERABLE: Producer 12-28A (PTD~990330) Tubing integrity restored • Page 1 of 2 Regg, James B (DOA) _~, _.~_ _ ~____.~~.~. ~ ~_ _ __ -r_. ____..~.,_ ~._~._ ~ _~__ ~ ~~.~ From. AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~~ Sent: Wednesday, July 14, 2010 10:56 AM To: AK, D&C Well Integrity Coordinator; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS12 Operator; AK, OPS PCC EOC TL; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R Cc: King, Whitney; Meixueiro, Paulina Subject: OPERABLE: Producer 12-28A (PTD #1990330) Tubing integrity restored All, Producer 12-28A (PTD #1990330) passed an MIT-T on 07/13/10 after dummy gas lift valves were set. The passing test verifies tubing integrity has been restored. The well has been reclassified as Operable and may be placed on production a er s Ic Ine set Vs. Thank you, Toxin Roschinger (alt. 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: Friday, July 02, 2010 9:44 AM To: 'Maunder, Thomas E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)'; AK, OPS FSl OSM; AK, OPS FSl Facility OTL; AK, OPS FSl DS Ops Lead; AK, OPS FSl DS12 Operator; AK, OPS PCC EOC TL; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; Meixueiro, Paulina Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: Producer 12-28 (PTD #1990330) TxIA communication All, Producer 12-28 (PTD #1990330) has been found to have sustained casing pressure due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 194/2200/120 on 6/22/2010. A cold TIFL performed on 6/24/2010 was inconclusive and the well showed sustained pressure again on 6/30/2010. 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. Slickline: Set tubing tail plug 2. Fullbore: MIT-T to 3000 psi, CMIT TxIA to 2500 psi ~ A TIO plot and wellbore schematic have been included for reference. « File: Producer 12-28 07-02-2010 TIO Plot.doc » « File: Producer 12-28 (PTD #1990330} schematic. pdf » 7/15/2010 OPERABLE: Producer 12-28A (PTD~990330) Tubing integrity restored • Page 2 of 2 Please call if you have questions or concerns. Gerald Murphy (alt. Toxin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, June 22, 2010 6:41 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)' Cc: AK, D&C Well Integrity Coordinator Subject: Producers with sustained casing pressure on IA due to the current proration Jim/Tom/Guy, The following wells have been found to have sustained casing pressure on the IA during the current proration. The immediate action is to perform a TIFL or MIT on each of the wells when tanks are available and evaluate for IA repressurization. If any of the wells fail the TIFL or MIT, a follow up email will be sent to the AOGCC for each individual well. E-17A (PTD #2042040) F-43 (PTD #1910750) N-15 (PTD #1810790) Y-33 (PTD #1910300) 12-28A (PTD #1990330) Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 7/15/2010 PBU 12-28~ PTD #1990330 7/2/2010 TIO Pressures Plot Weil_ 12-28 /~ 4,L100 3,000 2,000 1.nni~ # Tbg -~-- IA -~ CIA CI CIA oooA On • 04,'03110 04:'10!1 0 0411 711 0 0412411 0 05101 11 0 05108.10 05115/10 05122110 05/29/10 06105.{10 06!12110 05,'7 9110 06i 20.10 TREE = FMC GEN 3 WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = 69` R BF. ELEV.- KOP = 2948' Max Angie - 60 @ 8360' Datum MD = 11832' Datum TV D = 8800' SS ~ 12-28A 13-3/8" CSG, 72#, L-80, ID = 12.347" 2590' 5-1/2" TBG, 17#, 13GR-80, .0232 bpf, ID = 4.892" 5774' TOP OF 7" LNR ~-') 5$70' Minimum ID = 3.813" @ 11384' HES X Nipple AFETY NOTES: CHROME TBG 5-112" HES X NIP, ID = 4.562" 5774' --~ 5-112" X 4-1 /2" XO, ID = 3.958" GAS LIFT MANDRELS 5T MD TV D DEV TYPE V LV LATCH PORT DATE 1 3987 3854 51 LB DOME T2 16 06!09109 2 7087 5849 49 KBG2LS DOME INT 16 06/09/09 3 9169 7105 47 KBG2LS DOME INT 16 06/09/09 4 9953 7601 47 KBG2LS DMY 1NT 0 5 10609 8002 50 KBG2LS SO INT 24 04(25/10 7" X 4-1(2" BKR S-3 PKR, ID = ? d' ~ 4-1/2" HES X N1P. ID = 3.813" 9-518" CSG, 47#, L-80, ID = 8.681" ~ 11666' 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, iD = 3.958" 11406' TOP OF 4-1/2" LNR 11405' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11570' PERFORATION SUMMARY REF LOG: SWS CBL ON 05121(99 ANGLE AT TOP PERF: 40 @ 11604' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 11607 - 11634 O 10/21/08 2-1i2" 4 11878 - 11890 O 05/12!02 3-318" 12 11878 - 11890 O 12/28/04 2-112" 4 11897 - 11917 O 05/12/02 3-3i8" 12 11897 - 11917 O 12/28/04 3-318" 4 11897 - 11930 S 05!24/99 3-318" 4 11986 - 12000 C 05/24/99 11405' I-~-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 1172$' '-~ WF ECLIPSE PKR, ID = ???? 1$47'-11917 GRAVEL PACK, ID= 1.995" 5EE WELL FILE FOR SPECS '('(932' BAKER 1AA C1BP SET 12/28/04 ~ 11970' ~ 4-1/2" CiBP 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-{ 12114' DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 05!17/99 SIDETRACKED "A" 12!11/99 RWO 06(14109 DAV/TLH GLV C/O (06!09/09) 02/03/10 KNC/PJC PERF DEPTH CORRECTION 04/29/10 CJWPJC GLV C/O (04/25110) PRUDHOE BAY UNIT WELL: 12-28A PERMIT No: 1990330 API No: 50-029-21086-01 SEC 17, T10N, R15E, 264.95' FEL & 4768.44' FNL BP Exploration (Alaska) OPERABLE: Producer 12-28A (PTD #1990330) Tubing integrity restored • Regg, James B (DOA) Page 1 of 2 From: NSU, ADW Well Integrity Engireer [NSUADWWeIIlntegrityEngineer@BP.comj ~~~~ ~~~tlc° Sent: Wednesday, April 28, 2010 1:58 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Cc: Cooper, Katrina N; Janowski, Carrie Subject: OPERABLE: Producer 12-28A (PTD #1990330) Tubing integrity restored All, Producer 12-28A (PTD #1990330) passed a TIFL on 04/27/10 after the screened orifice was changed out. The passing test verifies that tubing integrity has been restored. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, April 23, 2010 8:10 AM ,~ r. ;' ~ ~,' ~ ~ To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; 'Regg, James B (DOA)'; Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; 'Maunder, Thomas E (DOA)'; GPB, Gas Lift Engr Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Cooper, Katrina N Subject: UNDER EVALUATION: Producer 12-28A (PTD #1990330) Sustained Casing Pressure due to TxIA Comm All, Well Producer 12-28A (PTD #1990330) is an artificially lifted well and has been found to have TxIA communication allowing for sustained casing pressure on the IA. The wellhead pressure readings were tubing/IA/OA equal to 224/2220/200 on 04/20/10 when a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while further diagnostic work is completed. The plan forward includes: 1. DHD: TIFL -FAILED 2. Slickline: Change out OGLV 3. DHD Re-TIFL A TIO plot and wellbore schematic have been included as reference. « File: 12-28 TIO Plot 04-23-10.doc» « File: 12-28A.pdf» 4/29/2010 OPERABLE: Producer 12-28A (PTD #1990330) Tubing integrity restored • Page 2 of 2 Please call with any questions or concer~ Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4/29/2010 UNDER EVALUATION: Producer 12-28A (PTD #1990330) Sustained Casing Pressure due to T... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] /~`2.3~Ic ~2l c( Sent: Friday, April 23, 2010 8:10 AM To: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Gas Lift Engr Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Cooper, Katrina N Subject: UNDER EVALUATION: Producer 12-28A (PTD #1990330) Sustained Casing Pressure due to TxIA Comm Attachments: 12-28 TIO Plot 04-23-10.doc; 12-28A.pdf ,/ All, Well Producer 12-28A (PTD #1990330) is an artificially lifted well and has been found to have TxIA communication allowing for sustained casing pressure on the IA. The wellhead pressure readings were tubing/I OA equal to 224/2220/200 on 04/20/10 when a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and may remain online while further diagnostic work is completed. The plan forward includes: 1. DHD: TIFL -FAILED 2. Slickline: Change out OGLV 3. DHD Re-TIFL A TIO plot and wellbore schematic have been included as reference. «12-28 TIO Plot 04-23-10.doc» «12-28A.pdf» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ,~ 4/23/2010 PBU 12-28A PTD 1990330 4/23/2010 TIO Pressures Plot Well: 12-28 4,000 ~ 3,000 f Tbg f- IA 2.000 --a- OA OOA • OOOA Dn 1.000 L 01/30/10 02/06110 02113!10 02120110 02/27110 03106!10 03!13!10 03!20!10 03/27/10 041D3110 04110!10 04!17/10 TREE = FMC GEN 3 'WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 69' BF. ELEV = KOP = 2948` ~~Max Angle = 60 @ 8360' ', Datum MD = 11832' Datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 5-112" TBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" TOP OF 7" LNR I~ 5$70' Minimum ID = 3.813" @ 11384' HES X Nipple 12-28A SAFEI"Y NOTES: CHROME TBG 5-1 /2" HES X NIP, ID = 4.562" 5774` -~ 5-112" X 4-1/2" XO, ID = 3.958" CAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3987 3854 51 LB DOME T2 16 06/09/09 2 7087 5849 49 KBG2LS DOME INT 16 06/09/09 3 9169 7105 47 KBG2LS DOME INT 16 06/09/09 4 9953 7601 47 KBG2LS DMY INT 0 5 10609 8002 50 KBG2LS SO INT 24 06/09/09 11351" -j 7" X 4-1 /2" BKR S-3 PKR, ID = ? 11384' 4-112" HES X NIP, ID = 3.813" 11405' -14-112" WLEG, ID = 3.958" -1 F1MD TT NOT LOGGED 11728' -~ WF ECLIPSE PKR, ID = ???? 11847'-11917 -1~rwVEL PACK, ID= 1.995" SEE WELL FILE FOR SPECS 9-5l8" CSG, 47#, L-80, ID = 8.681" ~-L 11666' 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" (TOP OF 4-112" LNR J-~ 914! 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: SWS CBL ON 05!21!99 ANGLE AT TOP PERF: 40 @ 11604' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11607 - 11634 O 10/21108 2-1/2" 4 11878 - 11890 O 05(12102 3-3l8" 12 11878 - 11890 O 12/28/04 2-1/2" 4 11897 - 11917 O 05!12(02 3-318" 12 11897 - 11917 O 12/28/04 3-3/8" 4 11897 - 11930 S 05124/99 3-3/8" 4 11986 - 12000 C 05/24199 I 11570' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 10/19/07 DRS/ PJC GRAVEL PK DEPTH CORRECTIOI 05!17!99 SIDETRACKED "A" 11!21108 RKK/TLH PERFS (10/21!08) 12111!99 RWO 06/14/09 OAV/TLH GLV C/O {06/09!09) 02!01!05 / TLH 4ES GRAVEL PACK 02!03!10 KNC/PJC PERF DEPTH CORRECTION 02(05!05 KSB/TLH GLV C/O 03/06/05 MGS/PJC GLV C/O '' BAKER 1AA CIBP SET 12(28/04 11970' 4-v2°CIBP PRUDHOE BAY UNfT WELL: 12-28A PERMff No: 1990330 API No: 50-029-21086-01 SEC 17, T10N, R15E, 264.95' FEL & 4768.44' FNL BP Exploration (Alaska} OPERABLE': Producer 12-28A (PTD~990330) Passing TIFL verifies tuing i my Page 1 of 2 Regg, James B (DOA) _~ _ __ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ` ' l ~ ~ j~1 I l~ Sent: Thursday, March 25, 2010 2:27 PM l ~ To: N~U, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (D,OA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R ~iSteven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Erfigr; GPB, EOC Specialists; GPB, FS2 DS Operators Cc: Cooper, Katrina N; Quy, Tiffany Subject: OPERABLE: Producer 12-28A (PTD #1990330) Passing TIFL verifies tuing integrity All, '~ Producer 12-Z8A (PTD #1990330) passed a~1E~ on 03/25/10 after the well was put on production. The passing test verifies tubingj, integrity. The well has been reclassified as Operable. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 6,59-5100 Ext. 1154 . ~. From: NSU, ADW Well Integrity Engineer Sent: Monday, march 22, 2010 10:31 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr East (F51/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossbe g, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators Cc: Cooper, Katrina N; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNpER EVALUATION: Producer 12-28A (PTD #1990330) Potential Sustained Casing Pressure on IA All, Producer well',., 12-28A (PTD #1990330) has been reclassified as Under Evaluation so that is may be placed on production and evaluated for potential sustained casing pressure on the IA. The flowline inspections have been completed. The plan forward includes: 1. Operations,: POP well 2. DHD: TIFL,once well is online Please let us Iknow if there are any questions. Thank you, ', Anna ~Du6e, ~.~. (alt Toxin Roschinger) Weil Integrity Coordinator GPB Wells Group Phone: (907, 659-5102 Pager: (907y 659-5100 x1154 3/31/2010 OPERABL~: Producer 12-28A (PTD~990330) Passing TIFL verifies tuing i~rity Page 2 of 2 From: NSU, ADyV Well Integrity Engineer Sent: Sunday, I,anuary 24, 2010 11:26 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FSl DS Ops Lead; Rossb~'rg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operatorsl, Cc: Cooper, Kaltrina N; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NqT OPERABLE: 12-28A (PTD #1990330) Potential Sustained Casing Pressure on IA All, Well 12-28A (PTD# 1990330) was reported as having high IA pressure on 1/18/10 when the annulus pressures were IA/OA equal do 2300/140 psi. Over the last several days, attempts have been made to arrange for a bleed of the IA pressure to cpnfirm if there is sustained casing pressure. Due to flow line inspections that are currently in progress, there has not been!an opportunity to bleed either to the system or to a tank. The well has been reclassified as Not Operable and will be safed but with a load and kill as soon as safely possible. Once the inspections are completed in the next couple of weeks, the will will be reclassified and diagnostic work will continue. The plan fonnrard includes: 1. Fullbore: Load and kill to safe out well 2. WIC: Whey ready, reclassify as Under Evaluation to POP 3. DHD: TIFL' 4. WIE: If TIF',L fails, eval for GLV c/o A TIO plot and wellbore schematic has been included for reference. « File: 12-28A TIO Plot.doc » Please let us',know if there are any questions. Thank you, Anna ~~de, ~.~. (alt Torin Roschinger) Welllntegrit Coordinator GPB Wells ~roup Phone: {907) 659-5102 Pager: {907 659-5100 x1154 III 3/31/2010 UNDER EVALUATION: Producer 1~3A (PTD #1990330) Potential Sustain~asing Pressur... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWN/elllntegrityEngineer@BP.com] 1~G~tc ~Z ~~I v Sent: Monday, March 22, 2010 10:31 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators Cc: Cooper, Katrina N; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Producer 12-28A (PTD #1990330) Potential Sustained Casing Pressure on IA All, Producer well 12-28A (PTD #1990330) has been reclassified as Under Evaluation so that is may be placed on production and evaluated for potential sustained casing pressure on the IA. The owline inspections have been completed. The plan forward includes: Operations: POP well DHD: TIFL once well is online Please let us know if there are any questions. Thank you, Anna ~u6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: .Sunday, January 24, 2010 11:26 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSi OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators Cc: Cooper, Katrina N; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 12-28A (PTD #1990330) Potential Sustained Casing Pressure on IA All, Well 12-28A (PTD# 1990330) was reported as having high IA pressure on 1/18/10 when the annulus pressures were IA/OA equal to 2300/140 psi. Over the last several days, attempts have been made to arrange for a bleed of the IA pressure to confirm if there is sustained casing pressure. Due to flow line inspections that are currently in progress, there has not been an opportunity to bleed either to the system or to a tank. The well has been reclassified as Not Operable and will be safed out with a load and kill as soon as safely possible. Once the inspections are completed in the next couple of weeks, the well will be reclassified and diagnostic work will continue. The plan forward includes: 1. Fullbore: Load and kill to safe out well 2. WIC: When ready, reclassify as Under Evaluation to POP 3. DHD: TIFL 4. WIE: If TIFL fails, eval for GLV c/o 3/23/2010 UNDER EVALUATION: Producer 12- A (PTD #1990330) Potential Sustai~Casing Pressur... Page 2 of 2 A TIO plot and wellbore schematic has be included for reference. « File: 12-28A TIO Plot.doc » Please let us know if there are any questions. Thank you, Anna ~3ude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907) 659-5100 x1154 3/23/2010 NOT OFERABLE: 12-28A (PTI~990330) Potential Sustained Casing P~sure on IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, January 24, 2010 11:26 AM `l~~ `~Z~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; GPB, FS2 DS Operators Cc: Cooper, Katrina N; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 12-28A (PTD #1990330) Potential Sustained Casing Pressure on IA Attachments: 12-28A TIO Plot.doc; 12-28A.pdf All, Well 12-28A (PTD# 1990330) was reported as having high IA pressure on 1/18/10 when the annulus pressures were IA/OA equal to 2300/140 psi. Over the last several days, attempts have been made to arrange for a bleed of the lA pressure to confirm if there is sustained casing pressure. Due to flow line inspections that are currently in progress, there has not been an opportunity to bleed either to the system or to a tank. The well has been reclassified as Not Operable and will be safed out with a load and kill as soon as safely possible. Once the inspections are completed in the next couple of weeks, the well will be reclassified and diagnostic work will continue. The plan forward includes: 1. Fullbore: Load and kill to safe out well 2. WIC: When ready, reclassify as Under Evaluation to POP 3. DHD: TIFL 4. WIE: If TIFL fails, eval for GLV c/o A TIO plot and wellbore schematic has been included for reference. «12-28A TIO Plot.doc» «12-28A.pdf» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 a~~~~,"BBL .~~I~ ~, o ~Q ~~' 1/25/2010 PBU 12-28A PTD #1990330 1 /24/2010 TIO Pressures 2,000 1.000 ~' --f- Tbg -~ IA -~ OA OOA DDOA On 10124/09 10131!09 11/07109 11/14109 11121/09 11/28/09 12!05109 12/12/09 12119/09 12/25109 01/02110 01/03/10 01?16110 01123:'1 i_ • TREE = FMC GEN 3 .. __._ WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 69' BF. ELEV = KOP = 2948' Max Angle = 60 @ 8360' Datum MD = 11832'1 Datum TV D = 8800' SS'. ~ 12-28A SAFEf'Y NOTES: CHF2OME TBG 723$' ~-{ 5-112" HES X NIP, ID = 4.562" 13-318" CSC, 72#, L-80, ID = 12.347" 2590 5-112" TBG, 17#, 13CR-B0, .0232 bpf, ID = 4.892" 5774' LTOP OF 7" LNR ~ 5870 Minimum ID = 3.813" @ 11384' HES X Nipple 4' --) 5-1/2" X 4-112" XO, lD = 3.958" t~AS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3987 3854 51 LB DOME T2 16 06/09/09 2 7087 5849 49 KBG2LS DOME IN7 16 06/09/09 3 9169 7105 47 KBG2LS DOME INT 16 06!09/09 4 9953 7601 47 KBG2LS DMY INT 0 5 10609 8002 50 KBG2LS SO INT 24 06/09/09 7" X 4-1/2" BKR S-3 PKR, ID 1384' 4-1/2" HES X NIP, ID = 3.813" 11405" 4-1/2" WLEG, ID=3.958" ~-) ELMD TT NOT LOGGED 9-5/8" CSC, 47#, L-80, ID = 8.681" ~ 11666' \'~ 4-112" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 11406' TOP OF 4-1 /2" LNR. 11405' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11570 PERFORATION SUMMARY REF LOG: SWS CBL ON 05121!99 ANGLE AT TOP PERF: 40 @ 11604' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11604 - 11634 O 10/21/08 2-1/2" 4 11878 - 11890 O 05(12102 3-318" 12 11878 - 11890 O 12/28/04 2-112" 4 11897 - 11917 O 05/12/02 3-3/8" 12 11897 - 11917 O 12!28104 3-3/8" 4 11897 - 11930 S 05/24/99 3-3/8" 4 11986 - 12000 C 05/24/99 -1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 10!19107 DRS/ PJC GRAVEL PK DEPTH CORRECTIOI 05/17/99 SIDETRACKED"A" 11/21/08 RKK/TLH PERFS(10/21/08) 12/11199 RWO 06/14/09 DAV/TLH GLV C!O (06109/09) 02!01/05 !TLH 4ES GRAVEL PACK 02/05/05 KSB/TLH GLV GO 03!06/05 MGS/PJC GLV GO 11728 -I WF ECLIPSE PKR, ID = ???? 11847'-11917 GRAVEL PACK, ID = 1.995" SEE WELL FILE FOR SPECS 11932 BAKER 1AA CIBP SET 12/28/04 1197(}' ~ 4-1/2" CIBP PRUDHOE BAY UNIT I WELL: 12-28A PERMIT Na: 1990330 API No: 50-029-21086-01 SEC 17, T10N, R15E, 264.95' FEL & 4768.44' FNL BP Exploration (Alaska) ~~~d STATE OF ALASKA ~~` ALF~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS .~E~~ ~~/Ooh'-~~ - fi ~~G~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Q Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ ~ 'Time'Extbns+on [~ Change Approved Program ~ Operat. Shutdown Perforate Q ~ Re-enter Suspended U~Jell 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' - Exploratory '. 199-0330 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21086-01-00 7. KB Elevation (ft): 9. Well Name and Number: 69.3 KB - PBU 12-28A 8. Property Designation: 10. Field/Pool(s): ADLO-028329 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12200 - feet Plugs (measured) 11932 11970 true vertical 9174.7 ~ feet Junk (measured) None Effective Depth measured 11932 feet true vertical 8951 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Surface 2561 13-3/8"72# L-80 27 - 2588 27 - 2588 4930 2670 Production 8353 9-5/8" 47# L-80 26 - 8379 26 - 6629 6870 4760 Liner 5700 7" 29# L-80 5870 - 11570 5079 - 8662 8160 7020 Liner 709 4-1/2" 12.6# L-80 11405 - 12114 8537 - 9102 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# 13Cr80 24 - 5774 4-1/2" 12.6# 13Cr80 5774 - 11406 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 11351 WF ECLIPSE PKR 11728 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): T ~ ~ reatment descriptions including volumes used and final pressure: tiU ~ 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 144 355 828 265 Subsequent to operation: 400 2743 1542 270 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~"' Development ',' - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' ~ Gas WAG GINJ WINJ WDSPL 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/27/2008 .. ~ Form 10-404 R vised 04/2006 1 ~ ~ ~'~~.,~~ ~ _ ~ ft1' .i.~~ ~~~~ Submit Original Only ~~~ 12-28A 199-0330 PERF ATTArHIIAFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-28A 5/24/99 PER 11,897. 11,930. 8,922.02 8,949.12 12-28A _ 5/24/99 PER 11,986. 12,000. 8,995.37 9,007. 12-28A 12/13/99 BPS 11,970. 11,986. 8,982.12 8,995.37 12-28A 10/29/00 RPF 11,897. 11,910. 8,922.02 8,932.68 12-28A 10/29/00 RPF 11,910. 11,930. 8,932.68 8,949.12 12-28A 8/10/01 FIL 11,905. 11,970. 8,928.58 8,982.12 12-28A 10/15/01 FIL 11,901. 11,905. 8,925.3 8,928.58 12-28A 4/5/02 SQZ 11,861. 11,970. 8,892.6 8,982.12 12-28A __ 4/9/02 SQF 11,861. 11,970. 8,892.6 8,982.12 12-28A 5/12/02 RPF 11,878. 11,890. 8,906.48 8,916.29 12-28A 5/12/02 RPF 11,897. 11,917. 8,922.02 8,938.43 12-28A 6/5/03 FIL 11,915. 11,970. 8,936.79 8,982.12 12-28A 12/25/04 BPS 11,935. 11,986. 8,953.23 8,995.37 12-28A 12/28/04 RPF 11,878. 11,890. 8,906.48 8,916.29 12-28A 12/28/04 RPF 11,897. 11,917. 8,922.02 8,938.43 12-28A 1/20/05 SPS 11,929. 11,986. 8,948.29 8,995.37 12-28A 1/21/05 SPS 11,902. 11,929. 8,926.12 8,948.29 12-28A 10/21/08 APF 11,607. 11,634. 8,690.45 8,711.34 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ 12-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 10/21/2008:*"*WELL FLOWING ON ARRIVAL""" "^^ INITIAL PRESSURES 200/1700/650. TRIPLEX 90-521 HAS BROKEN ''!GROUND STRAP AND THROTTLE CABLE. '"PERFORATED 11607'-11634' W/ 2.88" HSD 6SPF, PJ2906 GUN. DEPTH ''CORRECTED TO SLB RST GRAVEL PACK LOG DATED 2-9-05. 'SHUT-IN WELL TO PERFORATE. ALL SHOTS FIRED, DSO NOTIFIED !WELL CAP ON AND TESTED. DSO SAID TO POP WELL, OPENED WING, ':!WELL FLOWING ON DEPARTURE, 'DSO NOTIFIED OF VALVE POSITIONS. I"`*'`JOB COMPLETE*'`'` FLUIDS PUMPED BBLS 1 diesel 1 Total 09/16/08 Schlum6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wull i..w x ~~~~~~ ~fi~ ~ 2Q~1~ a3 gR \-~~``~ N0.4881 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 14-188 11978479 MEM GRADIOMANOMETER LOG ~a.~ 08/24/08 o~ 1 a,olor cu 1 04-28 11988951 LDL (REVISED) j = 06/29/08 1 1 R-12 12066544 MEM FLUID PROPERTIES LOG ~ j(p 08/20/08 1 1 PSI-OS 12103673 MEM DENSITY LOG 08/23/08 1 1 OS-35 11962620 USIT (.. (p 08/26108 1 1 B-36 12017516 USIT ~ ` 09/03/08 1 1 V-207 12057639 USIT Q _ 08/11/08 1 1 Z-19A 40013908 OH MWD/LWD EDIT r - - ~/ 09/10/05 3 1 12-28A 11962607 RST 07/01/08 1 1 B-12A 11998993 RST [r j _ u 03/05/08 1 1 V-207 12057639 CH EDIT (USIT) 08/11/08 1 PLEASE ACKNr]WI Ft1r:F ac ecluT av mr_r u~~r_ AQIA OGTII~~O~~n n BP Exploration (Alaska) Inc. _. _._ _._ _ _ _. -~ .. • re-v.. • v. Petrotechnical Data Center LR2-1 ~ ~ ~ _ f ~~„_ d ~ ., ~ 900 E. Benson Blvd. ~ ~~-,11 " ~'~ '~ ~ ~.. Anchorage, Alaska 99508 Date Delivered: ~~ i_ ' i ; .>I_!` _s~ `< ,!(~Qi~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 38 ATTN: Beth Received by: ~...---~~ c3 '\ STATE OF ALASKA) ALAS..A OIL AND GAS CONSERVATION COMMI,-,ùION 1. Operations Abandon 0 REP2p~~~~ SU~~~~o~~L~ O~~~~ONS·:""'~~F¿~ 1 "2005 Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time ExtensionD:' Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [;?': Exploratory 199-0330 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21086-01-00 7. KB Elevation (ft): 9. Well Name and Number: 69.3 KB 8. Property Designation: ADl-028329 11. Present Well Condition Summary: Total Depth measured 12200 true vertical 9174.7 Effective Depth measured 0 true vertical 0 Casing Conductor Surface Production Liner Liner length 80 2561 8353 5700 709 Size 20" 91.5# H-40 13-3/8" 72# l-80 9-5/8" 47# l-80 7" 29# l-80 4-1/2" 12.6# l-80 Perforation depth: Measured depth: 11878 - 11890 True Vertical depth: 8906.48 - 8916.29 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11878' - 11917' Treatment descriptions including volumes used and final pressure: see attached fluid summary TIO 220/1900/200 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations 469 x 12-28A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool feet feet Plugs (measured) Junk (measured) 11932,11970 None feet feet MD 28 - 108 27 - 2588 26 - 8379 5870 - 11570 11405 - 12114 TVD 28 - 1 08 27 - 2588 26 - 6628.51 5078.62 - 8661.98 8537.09 - 9102.3 Burst 1490 4930 6870 8160 8430 11897 - 11917 ~.' "'. r-" ,\) 1. C2rìn\~ ~'./,'h·'~~"~\F~. (\ìt·P {J J" _.t...", \)í:.,ç'~li \;i ç >¡;[¡;.¡w'" ".J ," ¡ 8922.02 - 8938.43 5-1/2" 17# 4-1/2" 12.6# 13DR80 13CR80 24 - 5774 5774 - 11406 4-1/2" Baker S-3 Perm Packer WF Eclipse Packer 11351 11728 RBDMS 8Fl SEP 192005 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl Casing Pressure SHUT -IN 60 1077 I 1336 400 15. Well Class after proposed work: Exploratory! Development P 16. Well Status after proposed work: Oil P' Gas r WAGr Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJ ! WINJ r Contact Sharmaine Vestal Printed Name Sharmaine Vestal ... / A Signatu~~f' ~ Form 10-404 Revised 04/2004 Collapse 470 2670 4760 7020 7500 Tubing pressure 1840 196 r WDSPL í Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr O Rp pOG '6~4f2^ L I :..., ~ , '~, \ Date 9/15/2005 Submit Original Only ') ) 12-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/7/2005 T/I/O= 2050/1000/140. Job continued on 8-8-05. Pumped 106 bbls crude down I.A. and 154 bbls diesel for (ACID STIM.) 8/8/2005 T/I/O= 2050/1000/140. Continued from 8-7-05, pumped 106 bbls crude down lA, switched to diesel 248 bbls. for (ACID STIM.) FWHP's 1900/460/120. 8/9/2005 CTU #9 w/1.75" CT. MIRU. Perform BOP test. MU/WOT/SLB Jet Blaster Nozzle, kill well, spot Lubtex Cocktail and RIH **** Continued on 8/10/05 WSR **** NOTE: Acid Tritration Data: 15.1 % HCL, Fe < 22 ppm 8/10/2005 CTU #9 w/1.75" CT. **** Continued from 8/9/05 **** RIH and Jet Blast gravel pack perfs from 11878 - 11917 with 48 bbls 15% HCL acid. As acid was jetted into perfs, whp decreased from 450 to 275. With all (48 bbls) acid out and water in perfs, whp increased to 610 and slowly decreased to 475 and held that until all overflush away. POH ****RDMO **** Job Complete **** Notify DSO well ready to POP to ASRC Seperator **** FLUIDS PUMPED BBLS 106 Crude 473 Diesel 444 Seawater 32 Lubtex Pill 48 150/0 HCL acid 101 Gallons A-261 ,A-153,A-179,W-54,W-60,F-1 03,L-58 , STATE OF ALASKA, ALASKA_)L AND GAS CONSERVATION CO.'í.t1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028329 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Gravel Pack Assy Perforation Depth MD (ft): Perforation Depth TVD (ft): IBI Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 99519-6612 69.3' 12200 9175 11932 8951 feet feet feet feet 80' 2590' 8343' 20" 13-3/8" 9-518" 5701' 806' 189' 7" 4-1/2'1 Gravel Pack Assy 118781 - 11917' (Above 8906' - 8938' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11878' - 11917' 0 Other 0 Time Extension 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 199-033 6. API Number: 50-029-21086-01-00 9. Well Name and Number: PBU 12-28A 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool FEB 2 82005 Plugs (measured) Junk (measured) 11932,11970 None Size Burst Collapse MD TVD 801 2590' 8343' 801 2590' 6610' 1490 5380 6870 470 2670 4760 5869' - 11570' 5078' - 86621 113941 - 12200' 8529' - 91751 11728' - 11917' 87851 - 8938' SCt\NNED FES R 2005 7240 8430 N/A 5410 7500 N/A 5-1/2", 17# x 4-1/2", 12.6# 7" x 4-1/2" Baker 'S-3' packer; 5-1/2" HES IX' Nipple ..- .-....~) 'Þ n 20í1¡::1 SCt~NNED f E. \J ,-, \~.- \. 13Cr80 11406' 11351' 2238' RBDMS BFl FEB2 8 2005 Treatment description including volumes used and final pressure: Gravel Pack Assembly: Placed -6,300 Ibs of 12-18 Carb-O-Lite behind Screens. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casina Pressure 927 1535 762 1033 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 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 Paul Chan, 564-5254 NIA 13. Oil-Bbl Prior to well operation: 2113 Subsequent to operation: 479 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Terrie Hubble s¡gnatur....1111ÁtQ.. ~ Form 10-404 Revised 04/2004 Tubina Pressure 1125 200 Title Technical Assistant Phone Date O~1J¡I05 Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 " ,1 \j 1........ ) ) Well: Field: API: Permit: 12-28A, Rig W orkover Prudhoe Bay Unit 50-029-21086-01-00 199-033 Accept: Spud: Release: Rig: 01/26/05 N/A 01/31/05 Nabors 4ES PRE-RIG WORK 09/22/04 DRIFTED WI 3.70 CENT & TANDEM PETRADAT GAUGES, TAG CIBP AT 11935' SLM, CORRECTED +35' TO 11970' ELM. PULL UP TO 11900' ELMD FOR 30 MIN. STOP AT 11,900'. 09/23/04 DRIFTED WI 3.75 DRIFT (15' OAL). UNABLE TO GET PAST 8316' SLM, 58 DEGREE DEVIATION & 11 DEGREE DOGLEG AT THAT DEPTH. DRIFTED WI 3.74 BARBELL SETUP (10' OAL). SO AT 11,887' SLM, 11,922' CORR MD. 12/25/04 RAN JUNK BASKET AND 3.625" GAUGE RING, TAGGED TO AT 11970 FT. SET CIBP AT 11932 FT AS PER PROGRAM, GOOD INDICATIONS OF SETTING. 12/28/04 PERFORATE INTERVAL 11897 -11917 FT AND 11878 -11890 FTWITH 3-3/8 HSD 12 SPF GUNS. TAGGED TD SLIGHTLY HIGHER THEN EXPECTED AT 11926 FT, LIKELY DUE TO SCALE FALLING AFTER SETTING CIBP. 01/07/05 PUMP BAIL OFF TOP OF CIBP AT 11,902' SLM. RECOVERED WHAT APPEARS TO BE FORMATION SAND, GUN JUNK, & CEMENT. RUNNING 3.85" GAUGE RING. 01/08/05 TAG 5 112" X 4 1/2" X-OVER W 3.85" GAUGE RING AT 5754' SLM + 20' = 5774' MD. COULD NOT WORK GAUGE RING PAST X-OVER. PUMP BAIL WI 3" BAILER, 11904' SLM, RECOVERED 2 GALLONS OF JUNK 2 ATTEMPTS WI 3" BAILER, NO RETURNS 111908' SLM + 20' = 11928' MD (METAL MARKS ON BOTTOM OF BAILER BOTH TIMES). RAN 3.807" CENT/3.5" LIB TO 1 0,623' SLM. RESULTS INCONCLUSIVE. RDMO DUE TO HIGH WINDS. 01/20/05 RAN PDS MEMORY TOOL (CCL,GAMMA RAY) TO 11,902' SLM (11,929' CaRR TO), DUMP BAILED FRAC SAND TO 11897'. 01/21/05 DRIFTED W/2.80 CENT TO 11,894' SLM (11,921' MD), LRS KILLED & FREEZE PROTECTED WELL. SET 41/2" PX PLUG (95" PRONG W/1.75" FISH NECK). LRS MIT TUBING TO 3500#, PASSED. ASSIST DSM WI BPV. ) ) BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-28A 12-28A RECOMPLETION NABORS ALASKA DRILLING I NABORS 4ES Start: 1/25/2005 Rig Release: 1/31/2005 Rig Number: Spud Date: 4/4/1999 End: Date Frorh:':To Houts Täsk Code NPT Phase P~sêriptiÒnQtoÞ.erati()n~ 1/25/2005 16:00 - 19:00 3.00 RIGD P POST RID rig. Scope down & lower derrick. 19:00 - 01 :00 6.00 MOB P PRE Move from C-20 to DS 12-28 01 :00 - 04:00 3.00 RIGU P PRE Spot sub Base, Pits, and Pipe Shed. Raise and scope Derrick. Spot Rig Camp. Accept Rig at 04:00 hrs. 04:00 - 06:00 2.00 WHSUR P RUNCMP Rig up lines to Tiger Tank. Pick-up Lubricator and pull BPV. TP = 0 psi. IA = 300 psi. OA = 50 psi. Bleed down IA to Tiger Tank. 1/26/2005 00:00 - 01 :00 1.00 MOB P PRE Move from C-20 to DS12-28 01 :00 - 04:00 3.00 RIGU P PRE Spot sub Base, Pits, and Pipe Shed. Raise and scope Derrick. Spot Rig Camp. Accept Rig at 04:00 hrs. 04:00 - 09:00 5.00 WHSUR P RUNCMP Rig up lines to Tiger Tank. Pick-up Lubricator and pull BPV. TP = 0 psi. IA = 200 psi. OA = 50 psi. Bleed down IA to Tiger Tank. Set BPV. 09:00 - 10:30 1.50 WHSUR P RUNCMP Nipple down Production Tree and Adaptor Flange. 10:30 - 12:30 2.00 BOPSUP P RUNCMP Nipple up BOPE. Rig Up Test Equipment. 12:30 - 17:00 4.50 BOPSUR P RUNCMP Test BOPE per BP/AOGCC requirements at 250/3,500 psi. State's right to witness test, waived by J. Chrisp. Valve # 13 needs rebuilding. 17:00 - 19:00 2.00 BOPSUP P RUNCMP M/U running tool & pull blanking plug. UD running tool. M/U Ibricator & pull BPV. UD plug & lubricator. 19:00 - 21 :30 2.50 BOPSUP P RUNCMP Test pipe rams & valve # 13 on choke manifold. LP 250 psi, HP 3500 psi. Blow down lines, RID test equip. 21 :30 - 00:00 2.50 RUNCOMP RUNCMP R/U handling equip to run 2 7/8" PAC pipe. P/U 2 7/8. PAC DP 1 x1 & RIH. Had 75 jts in hole. 1/27/2005 00:00 - 01 :00 1.00 RUNCOrvP RUNCMP Con't to P/U 27/8. PAC DP & RIH. Ran 117 jts to 3639'. 01 :00 - 01 :30 0.50 RUNCOIVP RUNCMP R/U to circulate down 2 7/8. DP. 01 :30 - 04:30 3.00 RUNCOMP RUNCMP Circulate out oil & diesel from well bore. Pumped 100 bbls, then SID for 30 min. Con't pumping & circulate tubing clean. Pumped 270 bbls of 150 degree fresh water. Pumped 3 BPM @ 625 psi. Blow down lines. RID circulating equip. 04:30 - 06:30 2.00 RUNCOtv1P RUNCMP POOH & stand back 2 7/8. PAC DP. 06:30 - 08:00 1.50 RUNCOrvP RUNCMP Spot slick line Unit. PJSM. Rig Up. 08:00 - 12:00 4.00 RUNCOI\IP RUNCMP Make up Tool String. RIH to 11,355' slm. Pulled Prong from PX Plug. POOH. (Took three run to get a good latch and pull Prong). 12:00 - 13:30 1.50 RUNCOrvP RUNCMP Change out Tools. RIH with a 41/2. GR. Latch PX Plug. Jar free. POOH. 13:30 - 15:30 2.00 RUNCOI\IP RUNCMP M/U retreiving tool. RIH & pull plug. POOH wi plug. 15:30 - 16:00 0.50 RUNCOtvP RUNCMP RID slick line equip. 16:00 - 17:30 1.50 RUNCOI\IP RUNCMP Load & tally 27/8. PAC DP in shed. 17:30 - 19:30 2.00 RUNCOI\IP RUNCMP P/U & M/U screen assy. RIHwl same. 19:30 - 22:00 2.50 RUNCOI\IP RUNCMP RIH wi screen assy on 39 stands of DP from derrick. 22:00 - 00:00 2.00 RUNCOI\IP RUNCMP P/U 2 7/8. PAC DP 1 x 1 & RIH. 1/28/2005 00:00 - 07:00 7.00 RUNCOI\IP RUNCMP Con't to P/U 2 7/8" DP 1x1 & RIH. Picked up 379 jts & tagged bottom at 11,917.8'. Packer at 11756'. POW = 120K, SOW = 65K. Fill DP & prep to set packer. 07:00 - 08:00 1.00 RUNCOI\IP RUNCMP Fill Drill Pipe. Make up Top Pin and TIW Valve. 08:00 - 14:00 6.00 RUNCOI\IP RUNCMP Set Packer. Fill Annulus with 45 bbls. Attempted to test Packer several times. No-Joy. Discuss plan forward with Anch Eng. 14:00 - 19:00 5.00 RUNCOtv'N DFAL RUNCMP Shear off of Packer. POOH with 2 7/8" Drill Pipe. 19:00 - 20:00 1.00 RUNCOtv'N DFAL RUNCMP UD packer running tools. Printed: 2/7/2005 9:38:32 AM ') ) Page 2 of 3 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-28A 12-28A RECOMPLETION NABORS ALASKA DRILLING I NABORS 4ES Date Fron1-"To Hours Task Code < NPT Phase 1/28/2005 1.00 RUNCOrv1\l DFAL RUNCMP 20:00 - 21 :00 1/29/2005 21 :00 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 05:30 3.00 RUNCOrv1\l 2.00 RUNCOrv1\l 1.00 RUNCOrv1\l 2.50 RUNCOrvP DFAL RUNCMP DFAL RUNCMP DFAL RUNCMP RUNCMP 05:30 - 09:30 4.00 RUNCOMP RUNCMP 09:30 - 10:30 1.00 RUNCOrvP RUNCMP 10:30 - 14:00 3.50 RUNCOMP RUNCMP 14:00 - 19:00 5.00 RUNCOrv1\l DFAL RUNCMP 19:00 - 21 :30 2.50 RUNCOrv1\l DFAL RUNCMP 21 :30 - 23:00 1.50 RUNCOrv1\l DFAL RUNCMP 23:00 - 00:00 1.00 RUNCOrv1\l DFAL RUNCMP 1/30/2005 00:00 - 04:00 4.00 RUNCOrv1\l DFAL RUNCMP 04:00 - 06:00 2.00 RUNCOrv1\l DFAL RUNCMP 06:00 - 08:00 2.00 RUNCOtvP RUNCMP 08:00 - 10:00 2.00 RUNCOtvP RUNCMP 10:00 - 14:30 4.50 RUNCOtvP RUNCMP Start: 1/25/2005 Rig Release: 1/31/2005 Rig Number: Spud Date: 4/4/1999 End: Clear & clean rig floor. P/U & M/U circulating sub & packer retreiving tool. RIH wI retreiving tool & circ sub. Con't to RIH wi retreiving tool. Space out wi DP & sting into packer. load backside. Dump 3 drums of super pickle fluid down DP. Tie onto DP & displace fluid to packer @ 1 BPM, 400 psi.. Pumped 52 bbls of displacement. Switch lines & reverse pickle fluid out. pumped 55 bbls @ 3 BPM , 400 psi. Mix and Pump down Annulus at 2 bpm/1150 psi as follows: 20 bbls Dirt Magnet solution...20 bbls 2% KCL...20 bbls Dirt Magnet solution. Displace to top of Packer at 11,756' with 75 bbls 2% KCL. Swap over and pump down Drill Pipe at 2.5 bpm/1800 psi with -145 bbls 2% KCL and bring Dirt Mangnet treatment back to surface. (Schlumberger Acid Crew arrive on location and RU). PJSM with All. Test Lines to 3,000 psi. Pump Drill Pipe pickle as follows: 500 gal/Pickle Acid and Additives at 2.2 bpm/1200 psi. Displace to end of Drill Pipe with 41 bbls 2% KCL at 2.4 bpm/1460 psi. SWS RD. Reverse circulate with Rig Pump at 2.5 bpm/1800 psi and bring Pickle treatment back to surface (neutrilize with Soda Ash solution). Continue reversing with clean 2% KCL (2% going down hole = -11 NTUs). Used 300 bbls to clean up well bore and Drill Pipe. Final NTU readings from return samples = 22, 21, 17, 14. (Resume Non-Planned Ops). Pull Packer and Gravel Pack free. POOH with 27/8" Drill Pipe and Gravel Pack Assembly. Lay down Fishing Tools. Lay down Packer and Gravel Pack Assembly. Packer Eement was intact. Inspect Screens. Clean and clean Floor. Pick-up new Packer. Pick-up Gravel Pack Assembly (Note: added 30' of Blank Pipe and 30' of Wash Pipe to GP Assy...this will raise the Packer setting depth up to the the next Liner Jt.). TIH with Gravel PAck Assembly, Packer, and 27/8" PAC Drill Pipe. Continue TIH with Gravel Pack Assembly, Packer (total OAL = 195.43'), and Drill Pipe (total Jts = 378). PUW = 106K. SOW = 70K. Tagged bottom at 11,917'. Packer depth at 11,728' (center element). Screen depth 11,917 - 1,837'. (Perfs covered by Screens 11,917' - 11,878') Fill Drill Pipe. Set Packer with center of element at 11,728'. Fill Annulus (21 bbls). Test Annulus to 500 psi with much Joy. Call out SWS Pumping Services. Blow down Lines. SWS traveling to Location. However, presently delayed due to Rig moving on Spine Road. RU SWS Pumping Services. PJSM with All. Test Lines to 4,000 psi. Good. Open Well. Pressure up to 3,500 psi down Drill Pipe to shift Tool into circulating position. Start Acid at 2.1 bpm/125 psi. Acid away with 19 bbls at 2.0 bpm/330 psi. Displace Acid to perfs with 2% KCL (no returns) at 2.0 bpm/320 psi. Pump Acid into Perfs with 150 bbls 2% KCL at 2.0 bpm/200 psi (no Printed: 2/7/2005 9:38:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 3 of 3 BP EXPLORATION Operations Summary Report 12-28A 12-28A RECOMPLETION NABORS ALASKA DRILLING I NABORS 4ES 1/30/2005 10:00 - 14:30 Frorrl;.Tó Hóurs Task Code NPT Phase 4.50 RUNCOMP RUNCMP IJate 1/31 12005 14:30 - 16:00 16:00 - 17:00 17:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:00 03:00 - 08:00 1.50 RUNCOMP 1.00 RUNCOMP 7.00 RUNCOrvP 0.50 RUNCOrvP 1.00 RUNCOMP 1.50 RUNCOMP 5.00 RUNCOrvP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 08:00 - 10:00 2.00 RUNCOrvP RUNCMP 10:00 - 14:00 4.00 RUNCOrvP RUNCMP 14:00 - 16:30 2.50 RUNCOrvP RUNCMP 16:30 - 17:00 0.50 RUNCOrvP RUNCMP 17:00 - 19:00 2.00 BOPSUP P RUNCMP 19:00 - 20:00 1.00 WHSUR P RUNCMP 20:00 - 21 :00 1.00 WHSUR P RUNCMP 21 :00 - 22:00 1.00 WHSUR P RUNCMP Start: 1/25/2005 Rig Release: 1/31/2005 Rig Number: Spud Date: 4/4/1999 End: DèsptiþtiOhof.C)þ~ri3.ti()h$ returns). Pump Sand Slurry #1 as follows: 30 bbls of HEC (50 Ibs/1000 gal) Gel with 12-18 Carbolite at 1.5 - 2.0 ppa., 5 bbls clean Gel, displace with 2% KCL. Pumped Sand behind Screens with a final of 2.7 bpm/111 0 psi (no returns). Pumped Sand Slurry #2 as follows: 51 bbls HEC (50 Ibs/1000 gal) Gel with 12-18 Carbolite at 1.5 - 2.0 ppa. 5 bbls clean Gel. Displace with 2% KCL. Sand at Screens with 2.5bpm1700 psi. Pressure gradually ramped up to 1,700 psi (no returns). Then locked up at 3,000 psi. Shut down Pump. Left - 6 bbls of Sand Slurry in Drill Pipe. Pick-up on Drill Pipe to shift Tool into reverse position. Reverse 2 Drill Pipe Volumes. Lower Drill Pipe to close Tool. Re-Stress Gravel Pack at 1.0 bpm/1 ,550 psi. Total Carbolite behind Screens -6,300 Ibs. Blow down Lines. RD SWS Pumping Services. P/U & reverse out 2 DP volumes. 3BPM @ 1500 psi. POOH & stand back 21 stands in derrick. POOH & UD 2 7/8" PAC DP. UD gravel pack tools & wash pipe. Clear & clean rig floor. R/U slickline equip. Hold PJSM & RIH set 51/2" "PX" plug in "X" nipple @ 2238'. Made 2nd run & set prong in "PX" plug. FL found @ 1500'. Fill Wellbore with 2% KCL. Test Plug at 1,000 psi. Good. Rig down S-Line Unit. TIH with -2,050' of Drill Pipe from Derrick. WO Lil' Red to be released from their present job. Rig up Lil Red. Test Line. Circulate Well with Diesel to Freeze Protect. Freeze protect well wi 50 Bbls of diesel. 2.5 BPM @ 1000 psi. POOH wi 63 jts 2 7/8" PAC DP & UD same. Set BPV & test to 1000 psi. NID BOPE N/U tree. Pull BPV. Set tree test valve. Test tree to 5000 psi, Ok. Pull tree test valve. Set BPV. Secure well. Clear & clean cellar. RELEASE RIG @ 2200 hrs. Printed: 2/7/2005 9:38:32 AM TREE = \NELLHEA:Ð = Äë-rÜÄ. TOR ~. w...." ",,''''''........ .,,, .... KB. ELEV = 'BF.äÐ/~. .. .........."" ... ...MO< ....0<,... ..... KOP = 2948' wMcïxAñgTe.~==6õ"W@836Öï .. ............. ....<0......... ...'..... . ..'m........ ... Datum MD = 11832' "'M"...'~.'.","'.''<'','-'"^''' ".",'.«.'.<WN,'''''W,'"',,,,<,,,,,,''''''.'-'.'''-''.,v.''''',..,,,'.<'.,,,,.,,,,,,....'m.Y.',"'-W...""".' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2590' ~ FMC GEN 3 FMC .. ,'. " AXELSON , ..." ,... . 69' ") ) SAFETY NOTES: CHROME TBG 12,-28A I I 2238' l-i 5-1/2" HES X NIP, ID = 4.562" I I ~ 15-1/2" TBG, 17#, 13-CR-80, .0232 bpf, ID = 4.892" l-i 5774' I \ I TOP OF 4-1/2" TBG l-i 5774' ¡------- I 5774' l-i 5-1/2" X 4-1/2" XO I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 51 LB DOME T2 49 KBG2LS SO INT 47 KBG2LS DMY INT 47 KBG2LS DMY INT 50 KBG2LS DMY INT PORT DATE 16 02/05/05 20 02/05/05 0 0 0 I TOP OF 7" LNR l-f 5870' 1 I L - ST MD ND 1 3987 3854 2 7087 5850 3 9171 7106 4 9953 7602 5 10609 8002 Minimum ID = 3.813" @ 11384' HES X Nipple 4-1/2" TBG, 12.6#, 13-CR-80, -i .0152 bpf, ID = 3.958" TOPOF 4-1/2" LNR l-i I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" l-i 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i I 11406' 1 ~ 11351'1-i 7" X 4-1/2" BAKERS-3 PKR I 11384' 1-1 4-1/2" HES X NIP, ID = 3.813" 1 1 11405' 1-1 4-1/2" WLEG 1 I l-i ELMD IT NOT LOGGED 1 11728' l-i WF ECLIPSE PKR, ID = ???? 111837'-119171- GRAVEL PACK, ID = 1.995" SEE WELL FILE FOR SÆCS 11405' ~ 11570' I 11666' ~ ~ I 11932' 1- BAKER 1AA CIBP SET 12/28/04 ÆRFORA TION SUMMARY REF LOG: SWS CBL ON OS/21/99 ANGLE AT TOP ÆRF: 35 @ 11878' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11878 - 11890 0 05/12/02 3-3/8" 12 11878 - 11890 0 12/28/04 2-1/2" 4 11897 - 11917 0 05/12/02 3-3/8" 12 11897 - 11917 0 12/28/04 3-3/8" 4 11897 - 11930 S OS/24/99 3-3/8" 4 11986 - 12000 C OS/24/99 DATE 1984 05/17/99 12/11/99 02/11/02 04/05/02 04/21/02 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACKED LAST WORKOVER RN/TP CORRECTIONS JKB/TLH CMT PLUG KSB/KK MILL CEMENT PLUG I 11970' l-i 4-1/2" CIBP 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 12114' DATE 05/12/02 12/28/04 02/01/05 02/05/05 REV BY COMMENTS CWS/KK ADÆRFS LDKlTLP CIBP, ADD ÆRFS / TLH 4ES GRAVEL PACK KSB/TLH GL V C/O PRUDHOE BAY UNIT WELL: 12-28A PERMIT No: 1990330 API No: 50-029-21086-01 SEC 17, T10N, R15E, 264.95' FEL & 4768.44' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Cement Sqz / Add-RePerf Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 69 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4067' FNL, 5165' FEL, Sec. 17, T10N, R15E, UM (asp's 697700, 5931543) 12-28A At top of productive interval 9. Permit number / approval number 4952' FNL, 478' FEL, Sec. 08, T10N, R15E, UM (asp's 702257, 5936064) 199-033 At effective depth 10. APl number 4861' FNL, 362' FEL, Sec. 08, T10N, R15E, UM (asp's 702371, 5936158) 50-029-21086-01 At total depth 11. Field / Pool 4768' FNL, 265' FEL, Sec. 08, T10N, R15E, UM (asp's 702462, 5936250) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12200 feet Plugs (measured) PBTD Tagged @ 11964' (04/25/2002) true vertical 9175 feet CIBP set @ 11970' (12/09/1999) Effective depth: measured 11964 feet Junk (measured) true vertical 8977 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 1870 sx Poleset 110' 110' Surface 2560' 13-3/8" 1700 sx PF E, 400 sx PF 2590' 2590' C Intermediate 8313' 9-5/8" 500 sx G, 300 sx PFC 8343' 6610' Liner 5700' 7" 87 sx Class 'G' 5870' - 11570' 5079' - 8662' Sidetrack Liner 795' 4-1/2" 108 sx Class 'G' 11405' - 12200' 8537' - 9175' Perforation depth: measured Open Perfs 11878' - 11890', 11897' - 11917', Sqzd Perfs 11917' - 11930' Perfs below CIBP 11986' - 12000' true vertical Open Perfs 8907' - 8916', 8922' - 8938', Sqzd Perfs 8938' - 8949' Perfs below CIBP 8929' - 8932' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13-CR-80 @ 5774' MD. 5-1/2" X 4-1/2" @ 5774'. 4-1/2" 12.6#, 13-CR-80 @ 11406'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 PKR @ 11351'. 5-1/2" HES X Nipple @ 2238' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ,. 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 05/14/2002 1734 13884 1517 493 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,,~'¢~¢~.~.~/.~'2~¢[/~..~..rt.~ Title: Technical Assistant Date May 15, 2002 DeWayne R. Schnorrk.._..- ~ Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03/26/2002 O3/27/2OO2 O3/27/2O02 03/28/2002 03/28/2002 O3/29/2OO2 O3/3O/2OO2 03/31/2OO2 04/04/2002 O4/O5/2OO2 O4/O8/2OO2 O4/O8/2OO2 O4/09/2OO2 04/19/2OO2 04/20/2002 04/21/2002 O4/25/2OO2 05/12/2OO2 03/26/02 O3/27/O2 O3/27/O2 O3/28/O2 O3/28/O2 O3/29/02 03/30/02 03/31/02 12-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT-TO DUMMY VALVES; MIT-IA CEMENT SQUEEZE: MIT-IA CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT-TO DUMMY VALVES; MIT-IA CEMENT SQUEEZE: MIT-IA CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT-TO DUMMY VALVES; MIT-IA CEMENT SQUEEZE: DRIFT/TAG; GAS LIFT-TO DUMMY VALVES; MIT-IA CEMENT SQUEEZE: MIT-IA CEMENT SQUEEZE: MIT-IA CEMENT SQUEEZE: CEMENT SQUEEZE CEMENT SQUEEZE: CEMENT SQUEEZE CEMENT SQUEEZE: MILL MISC-NRWO: DRIFT/TAG; GAS LIFT--FOR RATE CEMENT SQUEEZE: MILL CEMENT SQUEEZE: DRIFT/TAG CEMENT SQUEEZE: MILL CEMENT SQUEEZE: MILL CEMENT SQUEEZE: DRIFT/TAG CEMENT SQUEEZE: PERFORATING EVENT SUMMARY RUN EQUALIZING PRONG TO ROCK SCREEN ASSY @ 11,358' WLM. MIT IA WITH S-LINE. PULLED 4 1/2" X-LOCK & ROCK SCREEN FROM XLN @ 11358' WLM. RUN PDS MEM GR/CCL JEWELRY LOG. CORRECTED TAG: >>>11,934'<<< SET SLIP STOP CATCHER. PULLED I 1/2" LGLV FROM STA #1. HAVING DIFFICULTY PULLING 1" OGLV FROM STA #2. IN PROGRESS. MIT IA CONTINUED FROM 3-27-02 - LOAD 380 BBLS DIESEL- STANDBY FOR S- LINE TO FISH VALVE. JOB POSTPONED AT 17:00 UNTIL S-LINE CAN RETRIEVE VALVE, RDMO, ROAD TO SHOP. HAVING DIFFICULTY TRYING TO PULL 1" OGLV FROM STA #2. IN PROGRESS. PULLED STA# 2 INT-OGLV. SET STA# 2 INT-DGLV. PULLED C-SUB. RDMO LEFT WELL SHUT-IN. LOADED IA WITH 170 BBLS DIESEL (PREP FOR MITIAM PRE CEMENT SQUEEZE). MITIA PASSED TO 2500 PSI, PRE-CEMENT SQUEEZE. Page 1 04/04/02 04/05/02 O4/O8/O2 04/08/02 04/09/02 04/19/O2 O4/2O/O2 04/21/02 12-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS MIRU DS CTU #8. LOAD AND KILL WELL. TAG BTM & CORRECT TO 11934' (SL TAG 03/27/02). LIGHTEN COLUMN WITH DEAD CRUDE. MIX 84 BBLS CEMENT PUMP 80. UNABLE TO BUILD SQUEEZE PRESSURE. CONTAMINATE ACROSS PERFS AND PUMP AWAY. RELOAD CEMENT AND FLUIDS. PUMP 2ND BATCH OF CEMENT: 40 BBLS. PLACED ESTIMATED 31.5 BBLS BEHIND PIPE. FINAL SQUEEZE PRESSURE OF 2100 PSI DP AT PERFS HELD FOR 30 MINUTES. CLEANED OUT CEMENT TO >>>11,850'<<<. CHASED ALL CEMENT OOH @ 80% WITH BIOZAN AND SLICK WATER JETTING ALL JEWELRY ON REPEAT PASSES MAINTAINING 1000 PSI dP ON PERFS. FREEZE PROTECT WELL TO 2500' WITH 60/40 METHANOL. RETURNS 1:1 DURING CLEAN-OUT. TRAPPED 300 PSI ON WELL. ***NOTIFY DSO TO LEAVE WELL SI FOR UPCOMING WELL WORK*** MIRU CTU #5. ARRIVE LOCATION. WAIT ON PIS INSTALLATION (DELAYED BY SLICKLINE). TAG TOC @ 11861' CORRECTED DEPTH. SET CATCHER. SET OGLV IN ST# 2, AND LGLV IN ST# 1. PULL CATCHER. RDMO, -NOTIFY DSO OF WELL STATUS- RIG UP. DRIFT COIL W/1-1/4" BALL. M/U WEAHTERFORD 2-7/8" MHA / 2-7/8" MOTOR/3.75" CHOMPS MILL. TEST & RIH. DRY TAG TD @ 11914' CTM. SUSPECT SQZ HAS BROKE DOWN. CLOSE CHOKES & PUMP 35 BBLS @ 1.3 BPM / 700 PSI. DRY TAG @ 11915' CTM. POOH. BULLHEAD 45 BBLS 60/40 METH DOWN TBG TO FREEZE PROTECT. WHP BUILT UP TO 900 PSI @ 1.3 BPM BUT QUICKLY FELL OFF TO 0 PSI WHEN NOT PUMPING. DECISION FROM APE TO RIG DOWN & POP WELL. NOTIFIED DSO OF WELL STATUS. WSR DRIFTED TUBING WITH A 4.5" X-LINE ( 3.75" OD - SELECT POSITION ) AND LOCATED 4.5" X NIPPLE AT 11365' AMS-SLM. TAGGED PBTD AT 11880' AMS-SLM. GOT TO 11907' AMS WITH A 2.5" PUMP BAILER AND CAME BACK WITH A SAMPLE OF CEMENT. WELL POP. CTU #8, MILL CMT. RIH WITH WFD 2-7/8" MOTOR / 3.75" CHOMPS MILL. TAG BOTTOM @ 11,908' CTMD. BEGIN MILLING AHEAD. MILL HARD CEMENT FROM 11910' CTMD. MILLING HARD CEMENT. HAD SEVERAL STALLS @ 11932' CTMD. WORKED THROUGH 11,932'. SAW DRILLING BREAK AT 11934' CTMD. EASY CLEANING TO TOP OF BRIDGE PLUG @ 11,969' CTMD. PUMP BIOZAN SWEEP AND RECIPROCATE THROUGH 11,900; TO 11,969'. POOH AT 80%. FP TUBING TO 2500' WITH 60/40 METHANOL. DSO WILL HAVE FLOW LINE FREEZE PROTECTED WITH CRUDE. <<<JOB COMPLETED>>> Page 2 12-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS O4/25/O2 RAN 2.5 DUMMY GUN W/4 1/2" X~LINE ON BOTTOM W. SAMPLE BAILER, TAG XNIPPLE @ 11,362' SLM (ELMD= 11,383' FOR A CORRECTIONOF + 21') CONT' IN HOLE & SET DOWN @ 11,900' CORRECTED DEPTH (TARGET DEPTH WAS 11,969' SLM) . RAN 2.5 DUMMY & SAMPLE BAILER MINUS 4 1/2 LINE & USING PRIOR CORRECTION FACTOR (+21') SET DOWN @ 11,964' CORRECTED DEPTH. WELL TURNED OVER FOR PRODUCTION. 05/12/02 PDC GAMMA RAY ON FIRST RUN --WELL FLOWING @ 200 PSI DURING PERF OPERATIONS FINAL WELL PRESSURE 273 PSI AFTER PERF. COMPLETE ADPERF/REPERF WITH 2.5" POWERJETS @ 4 SPF-- INTERVALS ARE 11878 TO 11890 AND 11897 TO 11917. Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TEST) 5 METHANOL 292 60/40 METHANOL WATER 655 DIESEL 510 1% KCL WATER 920 1% KCL SLICK WATER 681 1% KCL EXTRA SLICK WATER 20 1.5# BIOZAN 2O 2# BIOZAN 226 BIO 197 FRESH WATER 80 15.8 PPG LARC CEMENT, FIELD LOSS 76 ML/30 MIN. FILTER CAKE 0.84". 40 15.8 PPG CEMENT 175 DC 3823 TOTAL ADD PERFS 05/12/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-1/2" PJ 4 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11878' - 11890' 11897'- 11917' Page 3 199-033-0 PRUDHOE BAY UNIT 12-28A 50- 029-21086-01 Roll #1: Start: Stop Roll #2:, ~S~rt Stop MD 12200 c'TVD 09175/Completion~a(6:--5724/99 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: T Name Interval Sent Received T/C/D c 9237f-----'-~' 1 SCHLUM PEX-AIT/BHC OH 6/11/99 6/16/99 C 9271 ~ 5-7 /-'S~QHLUM IMP-CDR OH 7/14/99 7/26/99 L BHCS "~AL 11570-12208 OH 6/11/99 6/16/99 L IBP/GR/CCL ~fl~)kL 500-8600 5/2/99 CH 5 6/9/99 6/16/99 L IMP-GR-MD ~'~.~98·360-12200 OH 7/14/99 7/26/99 L IMP~GR-TVD ~,~'~L 6618-9174 OH 7/14/99 7/26/99 L PEX-CN/GR ~ 11570-12208 OH 6/11/99 6/16/99 L PE×-CN/LDT ~-~; 11570-12208 OH 6/11/99 6/16/99 L PEX-MICRO ...,I~AL 11570-12208 OH 6/11/99 6/16/99 L PROD--13Ld~'-I-- ~.,~&L 11800-11933 ~5 ~'~0~ CH 5 4/20/00 5/12/00 L PROD-DEFT ~~' 11790-12040 11/27/99 CH 5 12/9/99 12/29/99 L SCMT FINAL C..~)10560-12075 5/22/99 CH 5 6/9/99 6/16/99 L SLIM-AIT/GR FINAD.~1570-12208 OH 6/11/99 6/16/99 L SRVY RPT ,~gLq"~LUM 0-12200. OH 5/19/99 5/21/99 Tuesday, May 01,2001 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. Ali well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 69 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4067' FNL, 5165' FEL, Sec. 17, T10N, R15E, UM (asp's 697700, 5931542,) 12-28A At top of productive interval 9. Permit number / approval number 326' FSL, 4804' FWL, Sec. 08, T1 ON, R15E, UM (asp's 702257, 5936064) 199-033 At effective depth 10. APl number 50-029-21086-01 At total depth 11. Field / Pool 4768' FNL, 265' FEL, Sec. 8, T10N, R15E, UM (asp's 702462, 5936250) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12200 feet Plugs (measured) PBTD tagged @ 11937' MD (10/29/2000) true vertical 9175 feet ClBP @ 11970' MD (set 12/09/99) Effective depth: measured 11937 feet Junk (measured) true vertical 8982 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1870 Sx Poleset 80' 80' Surface 2521' 13-3/8" 1700 Sx PF E &400 Sx PFC 2590' 2590' Production 8273' 9-5/8" 500 Sx Class G & 300 Sx PFC 8343' 6610' Liner 5700' 7" 87 Sx Class G 1 1570' 8662' Liner 709' 4-1/2" 108 Sx Class G 12200' 9175' Perforation depth: measured 11897' - 11930'; 11986' - 12000' (under ClBP) RECEIVED 9 000 true vertical 8922' - 8949'; 8929' - 8952' (under CIBP) Ataska Oil & Gas Cans. Comm~ Tubing (size, grade, and measured depth) 5-1/2"17#, 13CR80 Tbg @ 5774' MD; 4-1/2"12.6#, 13CR80 Tbg @ 11406' MD. /~C~10¢~. Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER S-3 PACKER @ 11351' MD. 5-1/2 HES X @ 2238' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1963 23222 1794 511 Subsequent to operation 1896 26026 1816 858 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~-~ . ¢~. ~:'c...,-._~-~__ Title DS 12 Surveillance Engineer Date . Andy Parker Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 12-28A - .... DESCRIPTION OF WORK coMPLETED REPERFORATING oPERATIONS 10/27/2000: Tagged PBTD @ 11938' eLM. 10/29/2000: MIRU ELU. PT equip to 3000 psi. RIH w/pedorating guns &tagged PBTD @ 11937'. Reperforated the following intervals: 11897' - 11930' MD (Zone 4) Used 2-7/8" carriers & a~l shots @ 6 SPF, 600 phasing, & random orientation. Well was shut in during perforating operations, poOH w/guns - ASF. RD ELU. Returned well to production & obtained valid we[ltest data. RECEIVED NOV 0 9 ~000 Alaska 0il & Gas Cons. Commission Schlumberger NO. 121410 4~27~00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 3-04 /~ ~ ~ INJECTION PROFILE W/PSP 000420 I 1 D.S. 12-28R PRODUCTION PROFILE W/DEFT 000423 I 1 D.S. 6-23 ..~,.~(~ I:::)"l RST 000208 I I 1 I - . ,,- r- ~ I r' !'~ s,~.~: ._ _ ' ....... o^~: MAi' 1 ?_ Alaska 0ii & (~as C;0~s. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317...*,nE yOU. ' STATE OF ALASKA . ~l ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate_ Pull tubing _ Alter casing _ Repair well _ Other_X (ClBP) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 69 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4067' FNL, 5165' FEL, Sec. 17, T1 ON, R15E, UM (asp's 697700, 5931543) 12-28A At top of productive interval 9. Permit number / approval number 326' FSL, 4804' FWL, Sec. 08, T10N, R15E, UM (asp's 702257, 5936064) 199-033 At effective depth 10. APl number 50-029-21086-01 At total depth 11. Field / Pool 4768' FNL, 265' FEL, Sec. 8, T10N, R15E, UM (asp's 702462, 5936250) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12200 feet Plugs (measured) ClBP @ 11970' MD (12/09/99) true vertical 9175 feet Effective depth: measured 1 1970 feet Junk (measured) true vertical 8982 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 1870 Sx Poleset 80' 80' Surface 2521' 13-3/8" 17oo sx PF E &4co Sx PFC 2590' 2590' Production 8273' 9-5/8" 500 Sx Class G & 300 Sx PFC 8343' 6610' Liner 5700' 7" 87 Sx C~ass G 11570' 8662' Liner 709' 4-1/2" lO8 Sx C~ass G 12200' 9175' Perforation depth: measured 11897'- 11930'; 11986'- 12000' (under CIBP)ORIGINAL true vertical 8922' - 8949'; 8929' - 8932' (under CIBP) Tubing (size, grade, and measured depth) 5-1/2"17#, 13CRSOTbg @ 5774' MD; 4-1/2"12.6#, 13CRSOTbg @ 11406' re~:. ~. ~. ~ ~ ~! Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER S-3 PACKER @ 11351' MD. ~ ..?- :~, 5-1/2 HES X @ 2238' MD. ~ :' ~'\ . 13. Stimulation or cement squeeze summary - -~, .~,~ o ~'~3~--~'~~''' Intervals treated (measured) (see attached)~-~ -M~'~'~ ~'r~ ~ Treatment description including volumes used and final pressure 14. Representative Dailv Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1191 12378 5806 - 345 Subsequent to operation 2560 21748 901 351 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '"/../-.4,~,~ ~'-'-~ ' ~"~' Title ARCO Engineering Supervisor Date /'' / '~ "~ Signed Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 12-28A DESCRIPTION OF WORK COMPLETED SET CAST IRON BRIDGE PLUG FOR WSO Date Event Summary 12/29/1999: 1 2/13/1999: Tagged PBTD @ 12060' SLM. RIH & set CIBP @ 11970' MD for water shutoff on the following perforation intervals: 11986'- 12000' MD (Zone 3) Returned well to production & obtained valid welltest data. RECEIVED 12/9/99 Schlumberger NO. 121010 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AI-rN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-33 STATIC PRESSURE SURVEY 991129 I 1 D.S. 4-47 STATIC PRESSURE SURVEY 991127 I 1 D.S. 11-22A L1 STATIC PRESSURE SURVEY 991126 I 1 !D.s. 12-28A PRODUCTION PROFILE W/DEFT 991127 I 1 D.S. 18-01A LEAK DETECTION LOG 991130 I 1 D.S. 18-03A LEAK DETECTION LOG 991204 I I ,,, D.S. 18-07 STATIC PRESSURE SURVEY 991128 I 1 ,, ~ :,:~".' Z 9 1999 DATE: /t~ll~a 011 & Gas Cons. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 7/14/99 Schlumberger NO. 12687 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CD D.S. 12-28A 99225 MWD CDR/IMPULSE:GR,ROP5,TAB (MD) 990512 I 1 D.S. 12-28A 99225 MWD CDR/IMPULSE:GR,ROP5,TAB (TVD) 990512 I 1 D.S. 12-28A 99225 MWD CDR/IMPULSE:GR,ROPS,TAB 1;::~-~'Z.~ J 990512 1 ~;;~i,;~ ii:,;:':', ..... ~, i;,:i,: i r\, .~t,,; ~.'~'~ SIGNED DATE: ' t:~as Cons. C0n'a~ia~ion Alaska Oil & "' Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well Classification of Service~l~.~'~-C0r81~.~$~ [] Oil ~ Gas ~ Suspended ~ Abandoned ~ Se~ice '"Ye - 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 99-33 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21086-01 4. Location of well at suflace ~ ~~: 9. Unit or Lease Name 1209' NSL, 113' EWL, SEC. 17, T10N, R15E, UM ~ t,,,,r, ,--~¢,,,, ~ . ~~S~ Prudhoe Bay Unit At top of productive inte~al ,~~- ~~ ~~J.~ , 10. Well Number Attotal depth ~ '~iI:!~ ~ 11. Field and Pool 509' NSL, 4996' EWL, SEC. 08, T10N, R15E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lea~'~'D'b~i~lb'6 and Serial No. Pool KBE = 69.30'~ ADL 028329 ~ 7. lotal Depth (MD+WD) 18. ~lu0 Back Depth (MD+~D)II~. Directional Su~oy 12o. ~epth whore SSSV set [21. Thickness of ~ormafrost 12200 9175 FT 12114 9102 FTI ~Yes ~NoI (Nipple) 2238' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES, GR, CCL, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASING~ LINER AND CEMENTING RECORD CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO~OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Su~ace 80' 30" 1870 sx Poleset 13-3/8" 72~ L-80 Sudace 2590' 17-1/2" 1700 sx PF 'E', 400 sx PF 'C' 9-5/8" 47~ L-80 Sudace 8343' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 7" 26~ L-80 5869' 11570' 8-1/2" 87 sx Class 'G' 4-1/2" 12.6~ L-80 11394' 12200' 6" 108 sx Class 'G' 24. Perforations open to Production (MD+~D of Top and 25. TUBING RECORD Bottom and intewal, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) 3-3/8" Gun Diameter, 4 spf 5-1/2", 17~, 13Cr80 5776' MD ~D MD ~D 4-1/2", 12.6~, 13Cr80 5776' - 11406' 11351' 11897' - 11930' 8922' - 8949' 11986' - 12000' 8996' - 9007' 26. AC~D, F~CTURE, CEMENT SQUEEZE, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST L Date First Production ~Method of Operation (Flowing, gas lift, etc.) May 24, 1999~ Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OIL ~TIO TEST PERIOD 1 Flow Tubing Casing Pressure 0ALCU~TED OIL-BBL GAS-MCF WATER-BBL O~L G~w~-API Press. 24-HouR ~TE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 11599' 8685' Shublik 11633' 8711' Sadlerochit 11729' 8786' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fore. going is true and correct to the best of my knowledge Signed ~~ ~/~)t~ t(~ TerrieHubble Title TechnicalAssistantlll Date ,..,,.,,. '",,,.. ' 12-28A 99-33 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28-' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 12 Well 12-28A Rig Page 1 Date 20 May 99 Date/Time 11 Apr 99 04:30-06:00 06:00-10:30 10:30-19:30 19:30-06:00 12 Apr 99 06:00-10:00 10:00-17:30 17:30-00:00 13 Apr 99 00:00-01:00 01:00-04:30 04:30-06:00 06:00-12:00 12:00-19:00 19:00-20:00 20:00-21:00 21:00-22:30 22:30-01:00 14 Apr 99 01:00-02:00 02:00-02:30 02:30-05:30 05:30-06:00 06:00-17:00 17:00-18:30 18:30-19:00 19:00-19:30 19:30-22:00 22:00-05:30 15 Apr 99 05:30-06:00 06:00-08:00 08:00-10:00 10:00-14:00 14:00-18:00 18:00-19:30 19:30-22:00 22:00-23:30 23:30-00:30 16 Apr 99 00:30-02:30 02:30-06:00 06:00-07:30 07:30-08:00 08:00-16:00 16:00-17:00 17:00-19:00 19:00-22:00 22:00-00:00 17 Apr 99 00:00-02:00 02:00-03:00 03:00-03:30 03:30-06:00 06:00-08:00 08:00-09:00 09:00-15:00 15:00-17:00 17:00-18:00 18:00-01:00 Duration 1-1/2 hr 4-1/2 hr 9hr 10-1/2 hr 4hr 7-1/2 hr 6-1/2 hr lhr 3-1/2 hr 1-1/2 hr 6hr 7hr lhr lhr 1-1/2 hr 2-1/2 hr lhr 1/2 hr 3hr 1/2 hr llhr 1-1/2 hr 1/2hr 1/2 hr 2-1/2 hr 7-1/2 hr 1/2 hr 2hr 2 hr 4hr 4hr 1-1/2 hr 2-1/2 hr 1-1/2 hr lhr 2hr 3-1/2 hr 1-1/2 hr 1/2 hr 8hr lhr 2hr 3hr 2 hr 2hr lhr 1/2 hr 2-1/2 hr 2hr lhr 6hr 2 hr 1 hr 7hr Activity Rig moved 15.00 % Rig moved 100.00 % (cont...) Worked on BOP - Production wing - surface tree Circulated at 10000.0 ft Bleed down well Monitor wellbore pressures Circulated at 10000.0 ft Monitor wellbore pressures Rigged down Tubing head spool Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Rigged up Bell nipple Removed Hanger plug Rigged up Tubing handling equipment Pulled Tubing on retrieval string to 40.0 ft Laid down 200.0 ft of Tubing Flow check Circulated at 9300.0 ft Laid down Tubing of 200.0 ft Laid down 7532.0 ft of Tubing (cont...) Repaired Handling equipment Serviced Top drive Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 4464.0 ft R.I.H. to 5500.0 ft R.I.H. to 7584.0 ft (cont...) Pulled out of hole to 6189.0 ft Held safety meeting Pulled out of hole to 7584.0 ft Pulled BHA Laid down 1730.0 ft of Tubing Made up BHA no. 2 Serviced Top drive Repaired Draw works R.I.H. to 5425.0 ft R.I.H. to 9285.0 ft (cont...) Fished at 9320.0 ft Pulled out of hole to 307.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 6413.0 ft Serviced Block line R.I.H. to 9300.0 ft Circulated at 9300.0 ft Fished at 9341.0 ft Pulled out of hole to 5250.0 ft Pulled out of hole to 338.0 ft (cont...) Pulled BHA Laid down fish Rigged up Top ram Made up BHA no. 4 R.I.H. to 10393.0 ft Facility Date/Time 18 Apr 99 19 Apr 99 20 Apr 99 21 Apr 99 22 Apr 99 PB DS 12 Progress Report Well 12-28A Page Rig (null) Date Duration Activity 2 20 May 99 ,' ,ECEiVE 01:00-01:30 01:30-02:00 02:00-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-09:00 09:00-09:30 09:30-11:30 11:30-12:30 12:30-13:00 13:00-14:30 14:30-15:00 15:00-16:00 16:00-16:30 16:30-17:30 17:30-21:00 21:00-21:30 21:30-22:30 22:30-04:30 04:30-06:00 06:00-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-10:00 10:00-11:00 11:00-12:30 12:30-14:00 14:00-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-22:00 22:00-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-13:30 13:30-17:00 17:00-19:30 19:30-20:30 20:30-23:00 23:00-00:30 00:30-03:30 03:30-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-12:30 12:30-13:00 1/2 hr 1/2 hr 1/2hr lhr 1/2 hr lhr lhr 3 hr 1/2hr 2hr lhr 1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr lhr 3-1/2 hr 1/2 hr lhr 6hr 1-1/2 hr 18-1/2 hr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 4hr lhr 1-1/2 hr 1-1/2 hr 4hr 1/2 hr 1/2 hr lhr 2hr 4hr 3-1/2 hr 1/2 hr 1/2 hr 2hr 5hr 3-1/2 hr 2-1/2 hr lhr 2-1/2 hr 1-1/2 hr 3hr 2-1/2 hr 2hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr Functioned Cement retainer Tested Cement retainer - Via annulus Circulated at 10390.0 ft Mixed and pumped slurry - 15.000 bbl Pulled out of hole to 10164.0 ft Circulated at 10164.0 ft Pulled out of hole to 8300.0 ft Pulled out of hole to 0.0 ft (cont...) Made up BHA no. 5 R.I.H. to 2533.0 ft Rigged up Instrument lines Tested Casing R.I.H. to 4957.0 ft Tested Casing R.I.H. to 6264.0 ft Tested Casing Tested Casing Pulled out of hole to 0.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 10170.0 ft Circulated at 10170.0 ft Milled Casing at 10057.0 ft Circulated at 10057.0 ft Pulled out of hole to 9955.0 ft Circulated at 9955.0 ft Pulled out of hole to 9220.0 ft Pulled out of hole to 7494.0 ft (cont...) Circulated at 7494.0 ft Pumped out of hole to 7280.0 ft R.I.H. to 7443.0 ft Worked stuck pipe at 7443.0 ft Held safety meeting Rigged up Logging/braided cable equipment Repaired Top drive Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged down Logging/braided cable equipment (cont...) Circulated at 7114.0 ft Pulled Drillpipe in stands to 7114.0 ft Made up BHA no. 7 R.I.H. to 3400.0 ft Circulated at 3400.0 ft R.I.H. to 7107.0 ft Washed over string at 7160.0 ft Circulated at 7160.0 ft Pulled out of hole to 362.0 ft Pulled BHA Jet wellhead Retrieved Wear bushing Tested BOP stack Installed Wear bushing Progress Report Facility PB DS 12 Well 12-28A Rig (null) Page 3 Date 20 May 99 Date/Time 13:00-13:30 13:30-15:00 15:00-17:30 17:30-19:00 19:00-20:00 20:00-20:30 20:30-01:30 23 Apr 99 01:30-06:00 06:00-07:00 07:00-11:00 11:00-14:30 14:30-15:00 15:00-16:00 16:00-20:00 20:00-21:00 21:00-21:30 21:30-02:00 24 Apr 99 02:00-02:30 02:30-03:00 03:00-06:00 06:00-07:00 07:00-11:00 11:00-12:00 12:00-13:30 13:30-14:30 14:30-16:30 16:30-17:30 17:30-20:30 20:30-21:00 21:00-22:00 22:00-22:30 22:30-23:00 23:00-01:00 25 Apr 99 01:00-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-08:30 08:30-10:30 10:30-10:45 10:45-11:00 11:00-11:30 11:30-12:00 12:00-12:15 12:15-12:45 12:45-13:30 13:30-14:30 14:30-15:30 15:30-18:30 18:30-19:30 19:30-20:30 20:30-00:00 26 Apr 99 00:00-03:30 03:30-05:00 Duration 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr lhr 1/2 hr 5hr 4-1/2 hr lhr 4hr 3-1/2 hr 1/2hr lhr 4hr lhr 1/2 hr 4-1/2 hr 1/2hr 1/2 hr 3hr lhr 4 hr lhr 1-1/2 hr 1 hr 2hr lhr 3hr 1/2hr lhr 1/2 hr 1/2 hr 2hr lhr 2hr lhr lhr 2-1/2 hr 2hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 3/4 hr lhr 1 hr 3 hr lhr lhr 3-1/2 hr 3-1/2 hr 1-1/2 hr Activity Serviced Top drive Made up BHA no. 8 R.I.H. to 6823.0 ft Serviced Block line Serviced Draw works R.I.H. to 7112.0 ft Worked stuck pipe at 7082.0 ft Pulled out of hole to 0.0 ft Laid down fish Serviced Top drive Rig waited: Downhole fish Held safety meeting Made up BHA no. 9 R.I.H. to 7408.0 ft Circulated at 7408.0 ft Fished at 7439.0 ft Pulled out of hole to 305.5 ft Pulled BHA Made up BHA no. 10 R.I.H. to 7439.0 ft Fished at 7439.0 ft Pulled out of hole to 0.0 ft Serviced Drillfloor / Derrick Serviced Block line Serviced Top drive Repaired Draw works Made up BHA no. 11 R.I.H. to 7439.0 ft Fished at 7439.0 ft R.I.H. to 10053.0 ft Pulled out of hole to 9600.0 ft Circulated at 9600.0 ft Pulled out of hole to 4020.0 ft Repaired Top drive pipe handler Pulled out of hole to 305.0 ft Pulled BHA Ran Drillpipe in stands to 1860.0 ft Ran Drillpipe in stands to 10051.0 ft (cont...) Circulated at 10051.0 ft Pulled Drillpipe in stands to 9865.0 ft Ran Drillpipe in stands to 10051.0 ft Held safety meeting Batch mixed slurry - 30.000 bbl Tested High pressure lines Mixed and pumped slurry - 30.000 bbl Pulled Drillpipe in stands to 8842.0 ft Circulated at 8842.0 ft Held 500.0 psi pressure on 2.000 bbl squeezed cement Pulled Drillpipe in stands to 0.0 ft Laid out BHA from derrick Installed Wear bushing Made up BHA no. 12 R.I.H. to 9464.0 ft Washed to 9938.0 ft Facility PB DS 12 Progress Report Well 12-28A Page 4 Rig (null) Date 20 May 99 Date/Time 27 Apr 99 28 Apr 99 29 Apr 99 30 Apr 99 01 May 99 02 May 99 05:00-05:30 05:30-06:00 06:00-07:30 07:30-10:30 10:30-12:00 12:00-14:00 14:00-17:30 17:30-18:00 18:00-03:00 03:00-03:30 03:30-06:00 06:00-08:00 08:00-11:00 11:00-11:30 11:30-20:30 20:30-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-10:00 10:00-17:00 17:00-18:00 18:00-22:00 22:00-00:30 00:30-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-08:30 08:30-11:30 11:30-18:00 18:00-20:00 20:00-01:00 01:00-01:30 01:30-03:30 03:30-06:00 06:00-08:00 08:00-08:30 08:30-09:30 09:30-15:00 15:00-21:30 21:30-23:00 23:00-23:30 23:30-04:00 04:00-06:00 06:00-12:00 12:00-15:30 15:30-16:00 16:00-16:30 16:30-19:30 19:30-20:30 20:30-21:00 21:00-02:30 02:30-04:15 Duration 1/2 hr 1/2 hr 1-1/2 hr 3hr 1-1/2 hr 2hr 3-1/2 hr 1/2 hr 9hr 1/2 hr 2-1/2 hr 2hr 3 hr 1/2 hr 9hr 4-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 4 hr 7hr lhr 4hr 2-1/2 hr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 3 hr 6-1/2 hr 2hr 5 hr 1/2 hr 2hr 2-1/2 hr 2 hr 1/2 hr 1 hr 5-1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 2 hr 6 hr 3-1/2 hr 1/2 hr 1/2 hr 3 hr 1 hr 1/2 hr 5-1/2 hr 1-3/4 hr Activity Drilled cement to 9995.0 ft Circulated at 9995.0 ft Circulated at 9995.0 ft (cont...) Pulled out of hole to 586.0 ft Pulled BHA Made up BHA no. 13 R.I.H. to 9995.0 ft Drilled cement to 10008.0 ft Drilled to 10035.0 ft Repaired Testing equipment Circulated at 10007.0 ft Worked toolstring at 10035.0 ft Drilled to 10042.0 ft Serviced Mud pumps Worked toolstring at 10042.0 ft Pulled out of hole to 643.0 ft Pulled BHA Serviced Block line Made up BHA no. 14 Made up BHA no. 14 R.I.H. to 9960.0 ft Functioned downhole tools at 10025.0 ft Milled Tubing cutting tools at 9978.0 ft Worked toolstring at 9978.0 ft Circulated at 9945.0 ft Worked toolstring at 9978.0 ft Worked toolstring at 9978.0 ft Milled Tubing cutting tools at 9978.0 ft Milled Casing at 9987.0 ft Circulated at 9987.0 ft Pulled out of hole to 1000.0 ft Pulled BHA Tested All functions Serviced Top drive Made up BHA no. 15 R.I.H. to 5700.0 ft R.I.H. to 9900.0 ft Set tool face Drilled to 9997.0 ft Worked toolstring at 9958.0 ft Pulled out of hole to 0.0 ft R.I.H. to 600.0 ft Serviced Top drive R.I.H. to 9950.0 ft Milled Other sub-surface equipment at 9962.0 ft Milled Other sub-surface equipment at 9962.0 ft (cont...) Reamed to 9958.0 ft Pulled out of hole to 9028.0 ft Circulated at 9028.0 ft Pulled out of hole to 5000.0 ft Serviced Top drive Held safety meeting Serviced Block line Pulled out of hole to 617.0 ft Progress Report Facility PB DS 12 Well 12-28A Rig (null) Page 5 Date 20 May 99 Date/Time 04:15-06:00 06:00-13:30 13:30-15:30 15:30-20:30 20:30-22:00 22:00-06:00 03 May 99 06:00-08:00 08:00-09:00 09:00-14:00 14:00-15:30 15:30-17:00 17:00-19:00 19:00-19:30 19:30-20:30 20:30-06:00 04 May 99 06:00-07:30 07:30-08:30 08:30-14:00 14:00-14:30 14:30-15:30 15:30-17:30 17:30-19:00 19:00-19:30 19:30-20:30 20:30-06:00 05 May 99 06:00-04:00 06 May 99 04:00-06:00 06:00-08:00 08:00-11:00 11:00-12:45 12:45-14:00 14:00-06:00 07 May 99 06:00-20:00 20:00-22:00 22:00-22:30 22:30-01:00 08 May 99 01:00-02:00 02:00-04:30 04:30-06:00 06:00-08:30 08:30-08:45 08:45-09:00 09:00-12:30 12:30-13:30 13:30-17:00 17:00-19:30 19:30-21:30 21:30-23:30 23:30-06:00 09 May 99 06:00-11:00 11:00-11:30 11:30-13:00 13:00-15:30 15:30-17:00 Duration 1-3/4 hr 7-1/2 hr 2hr 5 hr 1-1/2 hr 8hr 2hr lhr 5hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 1 hr 9-1/2 hr 1-1/2 hr lhr 5-1/2 hr 1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 1 hr 9-1/2 hr 22 hr 2 hr 2hr 3 hr 1-3/4 hr 1-1/4 hr 16hr 14hr 2 hr 1/2 hr 2-1/2 hr lhr 2-1/2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 1/4 hr 3-1/2 hr 1 hr 3-1/2 hr 2-1/2 hr 2hr 2hr 6-1/2 hr 5hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr Activity Pulled BHA Conducted electric cable operations Made up BHA no. 17 R.I.H. to 8373.0 ft Functioned downhole tools at 8373.0 ft Milled Casing at 8379.0 ft Pulled out of hole to 5000.0 ft Serviced Top drive Pulled out of hole to 0.0 ft Serviced Bore protector Made up BHA no. 18 R.I.H. to 6000.0 ft Serviced Crown block R.I.H. to 8363.0 ft Drilled to 8456.0 ft Drilled to 8517.0 ft Circulated at 8517.0 ft Pulled out of hole to 1000.0 ft Pulled BHA Made up BHA no. 19 R.I.H. to 6500.0 ft Serviced Drillfloor / Derrick R.I.H. to 8517.0 ft Washed to 8517.0 ft Drilled to 8875.0 ft Drilled to 10173.0 ft Circulated at 10173.0 ft Pulled out of hole to 8360.0 ft Serviced Top drive Serviced Block line R.I.H. to 10173.0 ft Drilled to 11012.0 ft Drilled to 11575.0 ft Circulated at 11575.0 ft Flow check Pulled out of hole to 8300.0 ft Serviced Top drive R.I.H. to 11575.0 ft Circulated at 11575.0 ft Circulated at 11575.0 ft Dropped EMSS survey barrel Flow check Pulled out of hole to 8309.0 ft Held safety meeting Pulled out of hole to 800.0 ft Pulled BHA Installed Pipe ram Rigged up Casing handling equipment Ran Liner to 3500.0 ft (7in OD) Ran Liner to 5617.0 ft (7in OD) Installed Liner hanger Circulated at 5617.0 ft Ran Liner on landing string to 8300.0 ft Circulated at 8300.0 ft Progress Report Facility PB DS 12 Well 12-28A Rig (null) Page 6 Date 20 May 99 Date/Time 17:00-20:15 20:15-21:00 21:00-21:30 21:30-06:00 10 May 99 06:00-08:45 08:45-09:15 09:15-10:00 10:00-10:30 10:30-12:15 12:15-12:45 12:45-13:00 13:00-13:30 13:30-15:30 15:30-17:30 17:30-20:00 20:00-22:30 22:30-04:30 11 May 99 04:30-06:00 06:00-08:00 08:00-12:00 12:00-13:30 13:30-17:00 17:00-18:00 18:00-19:00 19:00-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-06:00 12 May 99 06:00-09:30 09:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-19:30 19:30-21:30 21:30-00:30 13 May 99 00:30-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-10:30 10:30-15:00 15:00-17:00 17:00-21:00 21:00-21:30 21:30-22:00 22:00-23:30 23:30-05:30 14 May 99 05:30-06:00 06:00-08:00 08:00-12:00 12:00-12:30 Duration 3-1/4 hr 3/4 hr 1/2 hr 8-1/2 hr 2-3/4 hr 1/2 hr 3/4 hr 1/2 hr 1-3/4 hr 1/2 hr 1/4 hr 1/2 hr 2hr 2hr 2-1/2 hr 2-1/2 hr 6hr 1-1/2 hr 2hr 4hr 1-1/2 hr 3-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 7hr 3-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 5 hr 2hr 3hr 4hr lhr 1/2 hr 1-1/2 hr 3hr 4-1/2 hr 2 hr 4 hr 1/2 hr 1/2 hr 1-1/2 hr 6hr 1/2 hr 2 hr 4hr 1/2 hr Activity Ran Liner on landing string to 11575.0 ct Circulated at 11575.0 ft Worked toolstring at 11575.0 Ct Circulated at 11566.0 ft Circulated at 11566.0 ft Held safety meeting Pumped Water based mud spacers - volume 20.000 bbl Mixed and pumped slurry - 18.000 bbl Displaced slurry - 268.000 bbl Functioned Liner hanger Pulled Drillpipe in stands to 5869.0 ft Circulated at 5869.0 ct Pulled Drillpipe in stands to 4500.0 ft Serviced Block line Pulled Drillpipe in stands to 0.0 ft Installed Pipe ram Tested BOP stack Made up BHA no. 20 Made up BHA no. 20 (cont...) R.I.H. to 5184.0 ct Held drill (Kick (well kill)) R.I.H. to 10972.0 ft Washed to 11478.0 ft Tested Casing - Via annulus Drilled cement to 11595.0 ct Flow check Drilled to 11605.0 ft Circulated at 11605.0 ft Drilled to 12007.0 ft Drilled to 12200.0 ft (cont...) Circulated at 12200.0 ft Took MWD survey at 12200.0 ft Pulled out of hole to 11570.0 ft R.I.H. to 12200.0 ft Circulated at 12200.0 ct Pulled out of hole to 507.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Made up BHA no. 21 R.I.H. to 900.0 ft R.I.H. to 4000.0 ft (cont...) Repaired SCR R.I.H. to 11890.0 ft Washed to 12200.0 ft Circulated at 12200.0 ft Pulled out of hole to 11556.0 Ct R.I.H. to 12200.0 ft Circulated at 12200.0 ct Pulled out of hole to 227.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Progress Report Facility PB DS 12 Well 12-28A Rig (null) Page 7 Date 20 May 99 Date/Time 15 May 99 16 May 99 17 May 99 12:30-13:00 13:00-14:00 14:00-14:30 14:30-19:30 19:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:00 11:00-12:00 12:00-13:00 13:00-14:30 14:30-15:30 15:30-02:30 02:30-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-08:00 08:00-16:00 16:00-02:30 02:30-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-10:00 10:00-12:00 12:00-17:00 17:00-18:00 18:00-19:00 19:00-20:00 20:00-20:30 20:30-21:30 Duration 1/2 hr lhr 1/2 hr 5 hr 9hr 1 hr 1/2 hr 1/2 hr 3hr lhr 1/2 hr lhr lhr 1-1/2 hr lhr llhr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 8hr 10-1/2 hr 2-1/2 hr lhr 1-1/2 hr 1 hr 1 hr 1/2 hr 2 hr 5hr lhr lhr lhr 1/2 hr 1 hr Activity Rigged down Logging/braided cable equipment Installed Tubing handling equipment Held safety meeting Ran Liner to 807.0 ft (4-1/2in OD) Ran Drillpipe in stands to 11555.0 ft Circulated at 11555.0 ft Ran Drillpipe in stands to 11700.0 ft Ran Drillpipe in stands to 12200.0 ft (cont...) Circulated at 12200.0 ft Displaced slurry - 116.000 bbl Functioned Liner hanger Circulated at 12100.0 ft Pulled Drillpipe in stands to 11270.0 ft Serviced Block line Circulated at 11270.0 ft Laid down 12100.0 ft of Drillpipe Laid down 673.0 ft of Tubing Removed Wear bushing Rigged up Top ram Tested BOP stack Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 5630.0 ft (4-1/2in OD) Ran Tubing to 11403.0 ft (5-1/2in OD) Circulated at 11395.0 ft Space out tubulars Space out tubulars Set packer at 11350.0 ft with 4000.0 psi Tested Permanent packer Installed Hanger plug Rigged down BOP stack Installed Xmas tree Installed Hanger plug Tested Xmas tree Freeze protect well - 155.000 bbl of Diesel Installed Hanger plug Reverse circulated at 0.0 ft 12-28A DESCRIPTION OF WORK COMPLETED PERFORATIONS OPERATIONS Date Event Summary 5/24/1999: MIRU E-line unit. PT'd equipment to 3000 psi. RIH w/perforating guns & shot 47' of Initial Perforations at: 11897' - 11930' (Zone 4A) 11986' - 12000' (Zone 3) POOH w/guns. ASF. RD. Used 3-3/8" carriers & shot all perfs ~ 4 SPF, underbalanced press, 60° phasing, underbalanced, & random orientation. Placed well 12-28A on initial production & obtained a valid well test. 6/11/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12640 Compan~ Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CDR D.S. 12-28A 99226 PEX/SAI'r/BHC -~C~1 990514 D.S. 12-28A 99226 SLIM AlT 990514 ] ] :D.S. 12-28A 99226 BHC 990514 , D.S, 12-28A 99226 PEX-MCFL 990514 ] D.S. 12-28A 99226 PEX-CNL 990514 1 1 D.S. 12-28A 99226 ~ 990514 1 1 -") ":'- _ '". address. Thank y~u. Please sign and re urn one copy of this transmittal lo Sherrie at the above ~ 6/9/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12637 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Sepia CDR GNI 2 ~,~I ~_~- TEMP SURVEY 990425 1 1 D.S. 3-23 PROD PROFILE W/DEFT & GHOST 990427 1 1 D.S. 3-25A PROD PROFILE W/DEFT 990426 ] ] D.S. 4-18 PROD PROFILE W/DEFT 990408 1 1 D.S. 4-32 PROD PROFILE W/DEFT 990422 ] 1 D.S. 4-48 PROD PROFILE W/DEFT 990409 1 1 D.S. 5-12A iINJECTION PROFILE 990504 1 1 D.S. 11-11 PROD PROFILE W/DEFT 990505 1 1 D.S. 12-4A !PROD PROFILE W/DEFT 990430 1 1 ,, D.S..12-12 PROD PROFILE W/DEFT & GHOST 990428 ] ] D.S. ,12-28/0( BP GR/CCL 990502 ] ] D.S..14-27 L~{ C_,~ 'INJECTION PROFILE 990405 1 ] D.S,, 17-08 ~ INJECTION PROFILE 990405 I 1 D.S. 18-24A IGR/CCL 990505 ] 1 " '" li',i /6 t999 $~GNE "'~ DATE: ~...X ~le~se sign ~nd return one copy of this tmns~i~l 1o Sherrie ~t the ~bove ~ddress or f~x lo (gO7) 5~2%521, lh~nk you, 6/9/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12637 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Print D.S. 1-26A 99238 CBL/SCMT 990403 1 D.S. 12-28A 99238 CBL W/PSP/SCMT 990522 1 P.S. 14-0SA 99238 SCMT 9e0218 I SIGNi~ "' ' DATE: . Pleas~ sign a,d return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. ~B.'~JRmm,m~[;m-~ Anadrill 12-May-1999 A summary of Anadrill's performance on DS 12-28A has been compiled. SERVICES PROVIDED: MWD D&I MWD Gamma Ray CDR APWD (PWD) CDR Gamma Ray IMPulse Gamma Ray 8360 ff to 12200 8360ff to 8517ff 8517ff to 11575 8517R to 11575 11575 ff to 12200 OPERATING STATISTICS: MWD operating time (over 200 GPM) for the well was 101.6 hours. MWD footage of 3840 ft' was accomplished in 3 MWD runs. LWD time below the rotary for this well was 140 hours. LWD pumping time was 88.7 hours. LWD footage of 3683 was accomplished in 2 runs. DIRECTIONAL ORIGINAL -, -E VED ~.Y 21 1999 g~a~.ka 0i! & Gas Cons, C0mmi~0n A total of 135 MWD surveys were used by the Directional Driller. Continuous Inclination was used on the entire well. LESSON S LEARNED: There were four non-drilling MWD runs on this well, one of these runs was also an LWD. ANADRILL appreciates the opportunity to provide ARCO Alaska / Shared Services Drilling with MWD/LWD services. Nate Rose Cell Manager 9ES Joey LeBlanc Field Service Manager, AK ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska Inc. Field .................... : Prudhoe Bay Unit Well ..................... : DS 12-28A API number ............... : 50-029-21086-01 Engineer ................. : N.Rose Rig: ..................... : Nabors 9ES , State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill floor GL above permanent ....... : 41.00 ft KB above permanent ....... : 69.30 ft DF above permanent ....... : 69.30 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ..... Latitude (+N/S-) ......... : -999.25 ft "Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 47.60 degrees [(c)1999 Anadrill IDEAL ID5 IA 12R] -- __ 12-May-99 16:28:50 Page 1 of 6 Spud date ................ : 4-26-99 Last survey date ......... : 12-May-99 Total accepted surveys...: 135 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12200.00 ft ORIGINAL Geomagnetic data - Magnetic model ........... : BGGM version 1997 Magnetic date ............ : il-Jun-1998 Magnetic field strength..: 1146.82 HCNT Magnetic dec (+E/W-) ..... : 27.83 degrees Magnetic dip ............. : 80.71 degrees MWD survey Reference Criteria Reference G .............. : 1003.00 mGal Reference H .............. : 1148.00 HCNT Reference Dip ............ : 80.71 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 27.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.83 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED ANADRILL SCHLUMBERGER Survey Report 12-May-99 23:18:38 Page 2 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 2 97.75 0.23 241.1 3 197.75 0.15 209.7 4 297.75 0.22 221.0 5 397.75 0.37 242.3 6 497.75 g.38 245.8 7 597.75 0.22 223.5 8 697.75 0.12 213.8 9 797.75 0.18 175.2 10 897.75 0.18 201.6 11 997.75 0.17 170.1 12 1097.75 0.07 188.7 13 1197.75 0.12 297.6 14 1297.75 0.12 269.1 15 1397.75 0.08 281.6 16 1497.75 0.07 265.0 17 1597.75 0.12 202.1 18 1697.75 0.08 219.9 19 1797.75 0.07 210.4 20 1897.75 0.00 210.4 21 1997.75 0.55 59.3 22 2097.75 0.60 72.1 23 2197.75 0.52 97.3 24 2297.75 0.40 107.5 25 2397.75 0.43 111.0 26 2497.75 0.55 120.5 27 2597.75 0.45 93.0 28 2697.75 0.72 70.2 29 2797.75 3.20 32.6 30 2847.75 4.77 27.9 0.00 97.70 100.10 100.00 100.00 100.00 99.90 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.10 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 50.00 TVD depth (ft) 0.00 97.70 197.80 297.80 397.80 497.79 597.69 697.69 797.69 897.69 997.69 1097.69 1197.69 1297.69 1397.69 1497.69 1597.69 1697.79 1797.79 1897.79 1997.79 2097.78 2197.78 2297.78 2397.77 2497.77 2597.77 2697.76 2797.70 2847.57 Vertical Displ Displ Total At DLS section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (deg) lOOf) 0.00 -0.19 -0.51 -0.83 -1.33 -1.96 -2.46 -2.76 -2.95 -3.19 -3.41 -3.54 -3.62 -3.74 -3.86 -3.94 -4.09 -4.25 -4.38 -4.44 -3.97 -3.02 -2.25 -1.78 -1.44 0.00 0.00 -0.09 -0.17 -0.31 -0.41 -0.56 -0.60 -0.86 -1.02 -1.15 -1.60 -1.42 -2.04 -1.65 -2.23 -1.89 -2.27 -2.19 -2.32 -2.48 -2.35 -2.69 -2.33 -2.70 -2.44 -2.66 -2.63 -2.64 -2.81 -2.64 -2.94 -2.74 -3.04 -2.89 -3.12 -2.99 -3.20 -3.05 -3.23 -2.80 -2.81 -2.40 -1.90 -2.29 -0.95 -2.46 -0.17 -2.70 0.51 -1.13 -3.07 1.28 -0.71 -3.34 2.08 0.14 -3.14 3.06 3.42 -0.58 5.16 6.72 2.43 6.88 Srvy tool type 0.00 0.00 0.00 TIP 0.20 241.10 0.24 MWD M -- 0.51 233.46 0.13 MWD M -- 0.83 226.91 0.08 MWD M -- 1.33 229.75 0.18 MWD M -- 1.97 234.46 0.02 MWD M 2.48 235.12 0.20 MWD M -- 2.77 233.54 0.10 MWD M -- 2.96 230.26 0.11 MWD M -- 3.19 226.59 0.08 MWD M -- 3.42 223.41 0.t0 3.56 220.93 0.11 3.64 222.02 0.16 3.74 224.75 0.06 3.86 226.71 0.05 MWD M -- MWD M -- MWD M -- MWD M -- MWD M -- 3.95 228.09 0.02 MWD M -- 4.09 227.96 0.11 MWD M -- 4.25 227.21 0.05 MWD M -- 4.38 226.86 0.02 MWD M -- 4.44 226.64 0.07 MWD M -- 3.97 225.12 0.55 MWD M -- 3.06 218.46 0.14 MWD M 2.48 202.61 0.26 MWD M -- 2.46 184.01 0.14 MWD M -- 2.74 169.26 0.04 MWD M -- 3.33 157.46 0.14 MWD M -- 3.93 148.06 0.26 MWD M 4.39 135.75 0.35 MWD M -- 5.19 96.42 2.67 MWD M -- 7.30 70.54 3.20 MWD M Tool qual type [(c)1999 Anadrill IDEAL ID5 iA 12RI -- -- ANADRILL SCHLUMBERGER Survey Report 12-May-99 23:18:38 Page 3 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 31 2897.75 8.47 25.2 50.00 32 2947.75 9.62 22.5 50.00 33 2997.75 11.17 20.6 50.00 34 3047.75 13.72 17.5 50.00 35 3097.75 16.95 21.7 50.00 36 3197.75 21.07 27.3 37 3297.75 23.27 31.4 38 3397.75 26.32 37.9 39 3497.75 30.40 40.5 40 3597.75 32.57 40.6 41 3697.75 35.10 41.0 42 3797.75 37.07 42.5 43 3897.75 39.27 43.1 44 3997.75 42.42 43.1 45 4097.75 45.37 42.9 46 4197.75 48.73 42.8 47 4297.75 50.63 43.1 48 4397.75 50.60 43.5 49 4497.75 51.02 43.2 50 4597.75 50.67 43.6 51 4697.75 50.85 43.8 52 4797.75 51.03 43.8 53 4897.75 50.97 43.8 54 4997.75 50.08 44.6 55 5097.75 49.93 45.2 56 5197.75 49.62 45.8 57 5297.75 49.27 45.4 58 5397.75 49.32 45.3 59 5497.75 49.18 45.6 60 5597.75 48.83 45.7 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD depth (ft) 2897.23 2946.61 2995.79 3044.61 3092.82 3187.36 3279.97 3370.75 3458.74 3544.01 3627.07 3707.88 3786.49 3862.13 3934.18 4002.31 4067.01 4130.47 4193.66 4256.80 4320.05 4383.07 4446.00 4509.57 4573.85 4638.43 4703.44 4768.66 4833.94 4899.53 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 12.09 19.28 27.37 36.82 48.51 78.50 114.33 155.17 202.15 253.98 309.26 367.85 429.43 494.62 563.72 636.65 712.64 789.71 867.00 944.34 1021.61 1099.09 1176.63 1253.68 1330.21 1406.50 1482.44 1558.19 1633.89 1709.32 7.60 9.43 12.11 51.11 7.42 MWD M 14.80 12.59 19.43 40.40 2.45 MWD M 23.19 15.90 28.11 34.43 3.17 MWD M 33.38 19.38 38.60 30.14 5.27 MWD M -- 45.81 23.86 51.65 27.51 6.83 MWD M -- 75.34 37.50 84.16 26.46 4.50 MWD M -- 108.18 56.04 121.84 27.39 2.69 MWD M -- 142.55 79.96 163.45 29.29 4.09 MWD M -- 179.30 110.03 210.37 31.54 4.26 MWD M -- 218.98 143.98 262.07 33.32 2.17 MWD M -- 261.12 180.36 317.36 34.63 2.54 MWD M -- 305.05 219.59 375.87 35.75 2.16 MWD M -- 350.38 261.58 437.26 36.74 2.23 MWD M 398.13 306.27 502.30 37.57 3.15 MWD M -- 448.84 353.54 571.35 38.23 2.95 MWD M 502.49 403.31 644.33 38.75 3.36 558.29 455.26 720.39 39.20 1.91 614.54 508.27 797.50 39.59 0.31 670.90 561.47 874.85 39.93 0.48 727.24 614.75 952.26 40.21 0.47 783.24 668.26 1029.58 40.47 0.24 839.28 722.00 1107.11 40.70 0.18 895.37 775.79 1184.71 40.91 0.06 950.71 829.61 1261.78 41.11 1.08 1004.98 883.68 1338.24 41.33 0.48 1058.49 938.14 1414.39 41.55 0.55 1111.65 992.42 1490.19 41.76 0.46 1164.93 1046.35 1565.86 41.93 0.09 1218.07 1100.34 1641.48 42.09 0.27 1270.83 1154.31 1716.82 42.25 0.36 MWD M -- MWD M -- MWD M -- MWD M -- MWD M -- MWD M MWD M -- MWD M -- MWD M MWD M -- MWD M -- MWD M -- MWD M -- MWD M -- MWD M [ (c) 1999 Anadrill IDEAL ID5 iA 12R] ANADRILL SCHLUMBERGER Survey Report 12-May-99 23:18:38 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) {deg) (ft) 61 5697.75 48.97 45.7 100.00 62 5797.75 48.75 45.9 100.00 63 5897.75 48.92 46.0 100.00 64 5997.75 48.90 46.3 100.00 65 6097.75 49.12 46.9 100.00 66 6197.75 49.67 47.0 100.00 67 6297.75 49.22 47.4 100.00 68 6397.75 50.45 48.1 100.00 69 6497.75 50.95 48.9 100.00 70 6597.75 51.57 49.5 100.00 71 6697.75 52.23 49.5 100.00 72 6797.75 52.00 49.6 100.00 73 6897.75 52.03 49.8 100.00 74 6997.75 52.07 50.5 100.00 75 7097.75 52.42 51.6 100.00 76 7197.75 52.62 51.9 100.00 77 7297.75 52.50 52.1 100.00 78 7397.75 52.30 52.0 100.00 79 7497.75 51.90 52.1 100.00 80 7597.75 51.63 52.4 100.00 81 7697.75 51.62 52.1 100.00 82 7797.75 51.28 52.4 100.00 83 7897.75 50.95 52.3 100.00 84 7997.75 51.60 52.2 100.00 85 8097.75 53.52 52.4 100.00 86 8197.75 55.35 52.3 99.90 87 8297.75 57.38 52.2 100.00 88 8343.00 58.42 52.3 45.30 89 8360.00 60.15 51.1 17.00 90 8393.96 57.75 51.6 34.00 TVD depth (ft) 4965.27 5031.06 5096.88 5162.61 5228.20 5293.29 5358.30 5422.80 5486.14 5548.72 5610.42 5671.83 5733.38 5794.87 5856.10 5916.95 5977.75 6038.76 6100.19 6162.08 6224.16 6286.48 6349.25 6411.81 6472.60 6530.70 6586.09 6610.16 6618.85 6636.38 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 1784.64 1323.46 1208.24 1859.91 1375.97 1262.23 1935.16 1428.31 1316.34 2010.50 1480.52 1370.69 2085.97 1532.39 1425.54 1792.04 42.39 0.14 1867.22 42.53 0.27 1942.38 42.66 0.19 2017.61 42.79 0.23 2092.93 42.93 0.50 2161.89 1584.21 1481.02 2168.67 43.07 2237.86 1635.83 1536.76 2244.46 43.21 2314.28 1687.21 1593.33 2320.64 43.36 2391.65 1738.49 1651.29 2397.73 43.53 2469.62 1789.45 1710.33 2475.35 43.71 2548.27 1840.56 1770.17 2553.66 43.88 2627.15 1891.76 1830.23 2632.21 44.05 2705.91 1942.74 1890.34 2710.65 44.22 2784.69 1993.27 1950.88 2789.10 44.38 2863.61 2042.97 2012.37 2867.64 44.57 2942.76 2092.10 2074.69 2946.39 44.76 3021.92 2140.98 2137.26 3025.17 44.95 3100.91 2189.70 2199.73 3103.81 45.13 3179.58 2238.23 2261.95 3182.15 45.30 3257.87 2286.32 2324.06 3260.14 45.47 3336.01 2334.31 2386.05 3338.00 45.63 3413.96 2382.19 2447.88 3415.70 45.78 3491.54 2429.74 2509.52 3493.04 45.93 3569.30 2477.50 2571.20 3570.59 46.06 3648.42 2526.05 2634.02 3649.52 46.20 3729.41 2575.69 2698.36 3730.33 46.33 3812.39 2626.66 2764.19 3813.15 46.46 3850.64 2650.16 2794.53 3851.33 46.52 3865.21 2659.21 2806.00 3865.88 46.54 3894.28 2677.41 2828.74 3894.91 46.57 0.56 0.54 1.34 0.80 0.78 0.66 0.24 0.16 0.55 0.94 0.31 0.20 0.22 0.41 0.36 0.24 0.41 0.34 0.65 1.93 1.83 2.03 2.30 11.85 7.17 MWD M -- MWD M MWD M -- MWD M -- MWD M MWD M -- MWD M -- MWD M -- MWD M -- MWD M -- MWD M MWD M MWD M -- MWD M -- MWD M -- MWD M -- MWD M -- MWD M MWD M -- MWD M MWD M -- MWD M -- MWD M -- MWD M MWD M -- MWD M -- MWD M -- MWD M -- MWD M MWD M [(c)1999 Anadrill IDEAL ID5 iA 12RI ANADRILL SCHLUMBERGER Survey Report 12-May-99 23:18:38 Page 5 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 8422.31 56.19 52.0 92 8451.79 56.32 52.4 93 8485.02 56.75 52.9 94 8516.47 57.29 54.4 95 8547.08 56.84 53.9 96 8578.84 54.62 54.4 97 8610.98 53.76 53.8 98 8704.15 50.95 45.3 99 8797.86 51.32 45.1 100 8892.17 51.52 44.3 101 8984.88 51.45 42.1 102 9076.08 51.26 45.8 103 9169.43 51.33 45.1 104 9265.31 51.30 45.4 105 9358.21 50.80 44.2 106 9452.26 50.92 48.0 107 9545.96 50.54 48.3 108 9638.90 49.96 47.7 109 9731.75 49.48 47.1 110 9825.66 50.41 48.2 111 9917.19 51.34 51.8 112 10012.80 52.78 49.6 113 10106.91 52.33 48.8 114 10199.20 51.89 48.4 115 10292.79 53.02 48.3 116 10386.51 52.67 48.0 117 10478.27 52.30 48.3 118 10570.61 52.08 47.8 119 10665.48 51.59 47.0 120 10758.75 51.32 46.7 28.30 29.50 33.20 31.50 30.60 31.70 32.20 93.20 93.70 94.30 92.70 91.20 93.30 95.90 92.90 94.10 93.70 92.90 92.80 94.00 91.50 95.60 94.10 92.30 93.60 93.70 91.80 92.30 94.90 93.30 TVD depth (ft) 6651.81 6668.19 6686.50 6703.65 6720.29 6738.13 6756.97 6813.96 6872.75 6931.56 6989.29 7046.26 7104.60 7164.54 7222.94 7282.35 7341.66 7401.07 7461.06 7521.56 7579.30 7638.09 7695.30 7751.98 7809.02 7865.61 7921.52 7978.10 8036.74 8094.88 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 3917.94 3942.39 3969.98 3996.25 4021.77 4047.79 4073.74 4147.36 4220.26 4293.88 4366.19 4437.25 4510.01 4584.80 4656.96 4729.90 4802.43 4873.86 4944.65 5016.60 5087.50 5162.77 5237.45 5310.28 5384.49 5459.17 5531.98 5604.90 5679.51 5752.47 2692.08 2847.39 2707.11 2866.77 2723.92 2888.79 2739.58 2910.07 2754.62 2930.89 2.769.96 2952.12 2785.27 2973.27 2832.99 3029.40 2884.40 3081.17 2936.80 3133.02 2989.66 3182.67 3040.93 3232.08 3092.01 3283.97 3144.71 3337.13 3195.97 3388.04 3246.56 3440.61 3294.96 3494.65 3342.75 3547.73 3390.67 3599.84 3439.13 3653.02 3484.74 3707.39 3532.49 3765.71 3581.31 3822.27 3629.48 3876.91 3678.80 3932.36 3728.62 3987.99 3777.20 4042.23 3825.95 4096.46 3876.45 4151.38 3926.36 4204.62 3918.53 46.61 5.64 3942.95 46.64 1.21 3970.49 46.68 1.80 3996.72 46.73 4.35 4022.19 46.78 2.01 MWD M MWD M -- MWD M MWD M -- MWD M -- 4048.17 46.82 7.12 MWD 4074.07 46.87 3.07 MWD 4147.66 46.92 7.82 MWD 4220.59 46.89 0.43 MWD 4294.25 46.85 0.70 MWD 4366.63 46.79 1.86 MWD 4437.75 46.75 3.18 MWD 4510.54 46.72 0.59 MWD 4585.37 46.70 0.25 MWD 4657.58 46.67 1.14 MWD 4730.54 46.66 3.13 MWD 4803.05 46.68 0.48 MWD 4874.46 46.70 0.80 MWD 4945.25 46.71 0.71 MWD 5017.19 46.73 1.33 MWD 5088.03 46.77 3.22 MWD 5163.25 46.83 2.36 MWD 5237.89 46.86 0.83 MWD 5310.70 46.89 0.59 MWD 5384.89 46.91 1.21 MWD 5459.55 46.93 0.45 MWD 5532.35 46.94 0.48 MWD 5605.26 46.96 0.49 MWD 5679.87 46.96 0.84 MWD 5752.84 46.96 0.38 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c) 1999 Anadrill IDEAL ID5 IA 12R] ANADRILL SCHLUMBERGER Survey Report 12-May-99 23:18:38 Page 6 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 10852.32 50.88 46.5 122 10944.85 50.34 45.3 123 11036.20 48.55 44.9 124 11129.99 44.80 44.3 125 11223.92 43.37 44.6 126 11316.64 42.40 46.9 127 11410.16 41.64 46.9 128 11504.90 40.63 46.8 129 11648.40 39.01 46.3 130 11742.97 36.70 47.0 131 11836.57 35.65 46.8 132 11929.65 34.65 45.8 133 12022.42 33.54 47.0 134 12115.88 32.81 45.8 135 12200.00 32.50 45.8 93.50 92.60 91.30 93.80 93.90 92.70 93.60 94.70 143.50 94.60 93.60 93.10 92.70 93.50 84.10 TVD depth 8153.60 8212.36 8271.72 8336.07 8403.52 8471.44 8540.98 8612.30 8722.51 8797.20 8872.76 8948.88 9025.64 9103.90 9174.71 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 5825.23 5896.76 5966.06 6034.19 6099.42 6162.46 6225.11 6287.40 6379.27 6437.31 6492.56 6546.14 6598.09 6649.24 6694.59 3976.35 4257.49 4026.15 4308.89 4075.11 4358.02 4123.68 4405.93 4170.32 4451.68 4214.34 4496.85 4257.15 4542.60 4299.76 4588.05 4362.95 4654.76 4402.80 4696.97 4440.55 4737.31 4477.57 4776.06 4513.41 4813.69 4548.69 4850.74 4580.33 4883.27 5825.60 46.96 0.50 MWD 5897.15 46.94 1.16 MWD 5966.48 46.92 1.99 MWD 6034.65 46.90 4.02 MWD 6099.92 46.87 1.54 MWD 6162.98 46.86 1.99 MWD 6225.64 46.86 0.81 MWD 6287.93 46.86 1.07 MWD 6379.82 46.85 1.15 MWD 6437.87 46.85 2.48 MWD 6493.12 46.85 1.13 MWD 6546.71 46.85 1.24 MWD 6598.67 46.84 1.40 MWD 6649.83 46.84 1.05 MWD 6695.20 46.83 0.37 MWD M -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- [ (c)1999 Anadrill IDEAL ID5 iA 12RI -- -- STATE OF ALASKA ALASr~' OIL AND GAS CONSERVATION C~MMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [--I Abandon [] Suspend [] Plugging I--ITime Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well []Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic I~Service 4. Location of well at surface 1209' NSL, 113' EWL, SEC. 17, T10N, R15E, UM At top of productive interval 328' NSL, 445' WEL, SEC. 08, T10N, R15E, UM At effective depth (Planned) At total depth 647' NSL, 397' WEL, SEC. 08, T10N, R15E, UM (Planned) 6. Datum Elevation (DF or KB) Plan KBE = 68.75' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-28A 9. Permit Number 99-33 10. APl Number 50- 029-21086-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12354 feet true vertical 9224 feet Effective depth: measured 12053 feet true vertical 8983 feet Casing Length Size Structural Conductor 80' Surface 2519' Intermediate Production 11595' Liner 983' Plugs (measured) Junk (measured) EZSV with cement on top at about 10193' (04/99) 8-1/2" bit and lower motor at 10042', whipstock at 9954' above junk. New EZSV set at 8373'. (04/99) Cemented MD TVD 20" 1870 sx Poleset 13-3/8" 1700 sx PF 'E', 400 sx PF 'C' 80' 80' 2590' 2590' 9-5/8" 7" 500 sx Class 'G', 300 sx PF 'C' 415 sx Class 'G' 11666' 8656' 11371'-12354' 8420'-9224' Perforation depth: measured None true vertical None ORIGINAL Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT at 10415' - 11312'; 4-1/2", 12.6#, N-80 PCT tail at 11380' Packers and SSSV (type and measured depth) Baker FHL packer at 11323' 13. Attachments [] Description summary of proposal [] Detailed operations program 14. Estimated date for commencing operation 115. Status of well classifications as: May 3, 1999 16. If proposal was verbally approved z [~ Oil [] Gas i--] Suspended Blair Wondzell .~ 5/1/99 Service Name of approver Date appr. oved Contact Engineer Name/Number: James Smith, 564-5026 B~' ~"' ~ ~ _.z. _ t_ _ ____~C~,~&l~ Prepared By Name/Number: 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~,,-- "'~, ~ Dan Stone "o*s , CEIVF Title Senior Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity__ BOP Test ~ Location clearance __ Mechanical Integrity Test Subsequent form,,r~re'~:~ 10- t0'l ORIGINAL SIGNED BY ¢,~°'~0"~.~,~e6 ,~ · . .... . ¢t_,¢~, Approved by order of the Commission Robert N. Chnstenson ~_.!.,. -_'.~ 1 /~,~Commissioner Form 10-403 Rev. 06/15/88 ...~~ I Approval N o,,~- ~0 ~;_.~'-- Submit In Triplicate ,.,hare. d r.v!ces Alaska; ri ling To: Blair Wondzell, AOGCC From: Jim Smith, SSD Date: May 3, 1999 Subject: Sundry Permit Revision, Well 12-28A Per our telephone discussion of Saturday, May 1, 1999, and your verbal approval of a revision to the kick off point on well 12-28A, please find attached a revision to the drilling permit for well 12-28A. Subsequent to the Plug and Abandon of well 12-28A sidetrack efforts were initiated as planned and approved in the existing permit from a depth of 9954'MD which is in the Seabee shales. These efforts proved very difficult and resulted in downhole mechanical problems which left considerable junk in the wellbore. Per our discussion, we have moved uphole approximately 778'TVD and 1575'MD to a new kick off point higher in the Seabee (a sandier interval). We have placed a bridge plug at 8373'MD and placed a whipstock above that point. The exit from the 9-5/8" casing was accomplished overnight Sunday, May 2 and the morning of May 3, 1999. Casing and sealing of the well will remain as planned (7" liner from 5900' to top Sag River, 4- 1/2" liner from TD to 150' inside the 7" liner shoe). Regards, Ji~Smit~ SSD DS 12-28A WELLHEAD: FMC Gert III 13 3/8", 72#/ft, MD~'~ L-80, BTC @ 2,590' 5-1/2" and 4-1/2" 13CR production tubing with 6-GLMs i  ~ Liner top at 5900'MD  above Cretaceous leak in 9-5/8" Re vised KOP at 8373'MD ' '%~~'~ Moved uphole from 9954' due to downhole mechanical problems. ~ Bridge plug at 8370'MD---------....._.~ Cut 50' section, lost motor at 10042 -.. Set whipstock above, lost hole to junk Tubing paded at 11222' -- Packer at 11323' ~ ~ '~ '~ 7" TOL at 11371' ~ Top of sand at 11419'~ 9 5/8", 47#/~t, ~ .......... · i'i'i:' ..... ::.:: ::.: !:!!::: ::,: ·. :.:. :. .......... ...... 7", 29#/., L-80, BTC @ 12,354' MD ~ Date Revised by Comments PRUDHOE BAY UNIT 3-4-99 JES Existing well APl NO: 50-029-21086-01 ARCO-BP SSD Anadrill Schlumberger Alaska District 3940 Arctic Blvd Anchorape AK 99503 (907) 273-1700 Fax 561-8537 DIRECTION.kL WELL PLAN for SHARED SERVICES DRILLING Well ......... : D$12-2SA (PTA) FieLd ........ : Prudhoe Bay Co~utation..: Minimum Curvature Units ........ : FEET Surface Lat..' 70.21712173 N Surface Loa9.: 148,40512878 w Lepal Description Surface ...... : 1209 FSL 5567 FEL SI7 T10N R15~ OM Tie-in survey: 3835 ESL 239~ FEL S17 B}~ .......... : 550 FSL 202 LOCATIONS - ALASKA Zone: X-Coord 697700.~1 700394.61 702290.00 709526.90 4 Y-Coord 5931543,08 5934241.30 5936065.00 5936293.17 Prepared ..... : ~2 ~ay ~999 KB elewatiou.: 68.75 Magnetic Scan: ~27,$30 Scale Factor.: 0.9999%440 Convergence..: +1_5087S953 ~TATION ~ABURED I~ENTIFICATION DEPTH ANGLE TIE-IN SURVEY 8297.75 57.38 8300.00 $7-43 TOP WHIPSTOCK 8339.00 58.33 BASE WI{ZPSTOCK S351,OO 59.78 KOP/CURVE 6/100 8368,00 59.78 CT3~V~ 6/100 8398.00 60.69 8~00.00 60.69 CURVE 6/~00 8428.00 60.71 CURVE 6/100 8458.00 60.41 ~SO0.OO 57.97 PROPOSED WELL PROFILE 6600,00 52,16 DIRECTION VErTICAL-DEPTHS SECTION AZIMUTH TVS SUB-SEA DEPART 52.~9 6586,10 6517.35 3812.46 52.20 6587.31 6518.S6 3814.35 52,32 66~8,05 6539.30 3847-28 50.65 6614.22 6545.47 38S7.54 50.65 6622.77 6554.02 357~.21 %~.$6 6637.67 6568-92 3898.24 45.73 6638.65 6569.90 3899.98 46.80 6652,3~ 6583,60 3924.40 44.76 6667,09 6598,34 3950.51 45,47 6688.6~ 6619.86 3~86.54 47,32 6745.85 6677.50 4068,46. COORDINATES-FRO94 WELL,lEAD 2626.S8 2628.0{ N 2765.59 2648.26 2654.67 2663,98 = ~-- ALASKA Zone 4 TOOL DL/ X Y FACE ! 00 ~00394.6~ 5934241.30 ?~ <TIE 700396.07 S934242.50 7R 2.32 700~21.65 5934263 ,~0 45I~ 2.32 700~29 .$4 593(270 ,02 HS 17.00 700~40.65 59~4279.69 601 0.00 2680.8[ N 9831.00 2681.96 ~ 2832.31 269~.37 N 2850.39 9716.59 N 2869.11 2742.04 ~ 2894.67 70046D.07 5935296,96 901 6,00 700461.36 593429S.15 901 6.00 700479.00 5934315.03 1001 6,00 700497.23 5934333.73 166R 6.00 700522,11 5934359,84 166R 6.00 2798,S9 N 9953,97 E 700S79.91 5934417.92 165R ~.00 Fq C~ (Aha.drill (c)99 1228AP7A 3.2C 2:29 PI4 P} ~ STATfO~ I D~NT fFfCATIO~ F~D 6/100 CURVE K10 CURVE 3/100 KISKiAKJB ?SAG 02 [,lay 1999 Page 2 PRO.r~OSED WELL PROFILE M ~D%S U'RF~ I NCLN DE PT]{ ANGLE DIRECT/OM VE~T I CAL-DEPTHS AZ ltgLtTH TVD SUB-SEA SECTION DEPART COOP,]] RtATES - FROM ALASKA Zone 4 'POOL DG/ X Y FAC~I 1 O0 8612.78 51.42 9571.76 51.42 1070~.95 51.42 11001-36 51_42 11100.00 46-46 47.58 6753.75 6685,00 4078.50 47.55 7351.75 7283.00 4828.21 47.55 8057.75 7889.00 5713.31 47.58 8243.21 8174.46 5945.$Z 47.58 8306.68 8237.93 6021,31 2805.38 N 2961.36 3311.13 }4 3514.'78 3908.22 lq 4168.15 4065.07 N 4339.78 4116.00 N 43 95.51 700587.12 5934424.90 NS 6.00 703127.07 5934944.95 ES 0.OD 701764.54 5935558.92 HS 0.00 701932.00 5935720.20 L$ 0.00 701986.37 5935772.56 L$ 3-OO 11200.00 45.46 J. 1300. O0 42.46 11382 .ll 40.00 11394,01 40.00 11601 . 57 40 . 00 47,58 8374.92 ~306-1~ 6094.39 47.56 8446.89 8378-14 6163.60 47.58 8508.63 8439.88 6217.92 47.58 85[7.75 8449.00 6225.57 47.58 8676.75 8608.00 6358-98 4165.30 N 4449.45 4212.13 N 4508.69 4248.63 N 4540.64 4253.79 N 4546.29 4343.80 N 4644.77 702039.00 5935823.26 LS 3.00 702089.00 5935872.41 L$ 3.00 702127.97 5935908.94 ]{S 3-00 702133.48 5935914.25 ES O.O0 702229.57 5936006.80 }IS 0.00 7" CASING PT 11608.10 40.00 SKUBLIK 11638.12 40.00 TARf~T 11732.11 40.00 TS/d) 11732-11 40-00 ZONE 4A 11880-93 40.00 C(~OC 11897.90 40.00 CO~C 11976.22 40.00 TZ3 12014.08 ZONE 2C 12045.41 40.00 ~C'T 12093.71 40.00 ZOnE 28 12142.01 40.00 4-1/2" L~N-R PT 12243.83 40.00 TD 12243.83 40.00 47.58 865~.75 8613-00 6363-18 47.58 8704.75 8636-00 6382~48 47.58 8776.75 8708.00 6442.89 47.58 8776.75 8708.00 6442.89 47.58 8890.75 8722.00 6535.55 4346.63 N 4647.87 E 4359.65 N 4662.12 E 4400.40 N 4706.71 E 4400.40 N 4706.71 E 4464.93 N 4777.33 E 47,58 8903.75 8835.00 65~9.46 4472.29 N 4785.38 47.58 8963.75 8~95.00 6599.80 4506.25 N 4822.54 47.58 8992.75 892~-00 6624.I4 4522~67 N 4840.51 47,58 g0E6.75 8948.00 6644-28 4536-26 N 4855.37 47.58 9053.75 8985.00 6675.32 4557.20 N 4878.29 47.58 9090.75 9022.00 6706.37 4578.14 N 4901.21 47,58 9168.75 9100.tiff 6771.82 4622-3~ N 4949-52 47.58 9168-75 9[00~00 6771.82 4622.30 N 4949.52 702232.59 S936009.71 ~S 0.00 702246.49 ~936023.09 ~S 0.00 702290,00 5936065.00 ~S O-G0 702290~00 5936065.ff0 ~S 0.00 702358.90 5936131.36 ~S 0.00 702366.75 5936138,92 ES 0.00 702403.01 5936173.85 ES 0.00 702420,54 5936190,73 HS O.O~ 702435,04 5936204.70 HS O.OO 702457.41 5936226,23 ~S O.OO 702479.77 5936247,77 702526.90 5936293,17 702526.90 5936293.17 /{8 0.00 0.00 0.00 Z ('Anadrill (c>99 1228AP7A 3.2C 2;29 ~,] P) /4,'~ .,.~. D,'--~.,. L / A~,.~ . :,~r- ,-..: ~..[_, ;- F'EAS I '.P....' PLA"". - -.:, ,~ ..,,% . .. NuT A ppr r,, , , LAN ,,+ . ............ LO uq/,u~/l~u l~'~ ~u~-~bl-~b~/ ANADRILL DEC PAGE 04 SHARED SbHVICES DRILLING DS12-28A (P7A) VERTICAL SECTION VIEW Section at; 47,60 TVD Scale.- 'l ~nch = t200 feet Bep Scale i inch i IDrawn ..... 02 Nay 1999 ! ,.~ )0-- . .... Marker Ideflt~fJcat~on MB BKB SECTN !NCLN A) TIE-IN SURVEY 8298 6586 38~2 57,38 8) TOP WHIPSTOCK 8339 6608 3847 58.33 C) BASE HHIPSTOCK 835~ 6Bt4 3B58 59.78 )0-~ D) KOP/CU~VE 6/~00 8368 6623 3872 59.78 E) CURVE 8/tO0 8398 6638 3898 60,69 F) CURVE 6/~00 8~28 6658 3B24 BO.7~ lO ....... G) CURVE 6/100 8458 6667 395t 60,4~ H) END 6/~00 CURVE 86~3 6754 4079 5~.42 ]) CURVE 3/100 t~O0~ 8243 59~6 d) END 3/~00 CURVE 11382 8509 62t8 40.00 ,O-- --- K) 7" CASING PT 1~608 8682 6363 40,00 LJ TARGET i~732 8777 5~43 ~0.00 ~) 4-~/2" LNR PT ~88aa 9icg 5772 40.00 0-- , ...... N) TO ~2~44 g16g 6772 ~0,00 0-~' ~ '' ~; ....  ~~ ~ ~, .~..~:..~ ~.--.. /..5 ~ ,.~ ;~,~..,, ~r"' ?..: ..~ [. /x.. .-~ ........ .... , ........ . ,. j .... -~ro- ~ ~ .............. , I ~ u~- 3~ -~ ............. ...... ~,~~~ ~E~ ~ - - - ~I"'"'""" -'""--- ----""" ~E~ '. ~ ~' - ~~ ..... ~- ~ -~ ~.~~.~.~ ~- ........ ~ ,.- I 1 D 600 1~00 teO0 2400 3000 3600 ,~00 ,4808 5,400 6000 6600 72_00 7800 Section Be )art:ure u~>uz/i~ i~'bU ~7-561-8537 ANADRILL DEC PAGE sCqARED SER-V'ICES DRILLING i ,, i mill I Il -- A) T~E-IN SURVEY 8298 6586 3812 57.38 VERTICAL SECTION VIEW .... i - '11 i i i i i iiiiiiiiiii O) KOP/CuRvE 6/tO0 8368 6623 38?2 ~9.78 E) CURVE 6/100 8398 6838 3898 60,69 Section at: 47,60 F) CURVE 6/100 8428 6658 3984 60.71 TVB Scale.: t inch = 5O0 feet 6) CURVE 6/tO0 8458 6667 ~95~ 60.4t Dep Sca]e,: ~ ~nch : 500 feel H) END 6/~00 OURVE 86t3 8754 4079 5t.42 BpGwn ' 02 ~8y t999 [) CURVE 3/~00 ~]00] 8243 5846 5t.42 J] END 3/~00 CURVE ]]382 8509 62J8 40,00 K) 7' CASZN6 PT ~1608 8682 8363 40.00 ..... . L] TARGET ~1732 8777 6443 40,00 AnafJ]] Sch]umberger M) 4-~/2" LNR PT ~2244 9168 6772 40.08 ..... N] TD ~2244 9~6g 6772 40,00 ........................................ ' ~ ~ ~:~ ~ t A~'5/~', '"'~" ;.: '.., l. ~ ~., ~ ~. -. J ,.~ ¢ [--~.~ )--- ~ i ~.~ · _ ~~ ~ F ",-, :~,._ '- - _ ~_ ~ ................. '%%~_ .... J ZONE 2B )gl ~T~ .... .... ..... ............ I 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 5250 6500 6750 7000 ..... Sect,.On' .~Oo,~Z~... )0 : SHARED ¢'ERVI-CES Narker Iden[ificat~On Al CURVE END 3/100'CURVE 7" CASING PT D) TARGET E) 4-~/~" LNR PT F) TD MD BKB SECTN INCLN 1100~ 8243 5946 51.42 11382 8509 62~8 40.00 11608 8688 6363 ~0,00 ~1732 8777 6443 40.00 ~2244 9169 6772 40,00 ~2244 916§ 6772 40.00 I ,I,i ,ill il DRILLING DSI2-28A (P7A) VERTICAL SECTION VlE~ Section al: 47.60 TVD SCale.' ~ inch = 200 feet: Oep Sca]e,' ~ inch = 200 feet Ora~n ' O~ Nay ~999 4nadri ]7 Sch/umber#er ............ .... 5600 5700 5800 5900 6000 6 tO0 6200 6300 6400 6500 6600 6700 6800 8900 ?000 Section r)epaPtur'e id: o~ ~U/-Obl-~b~f ANADRILL DEC PAGE 87 --SHARER SERVICES ..... DRILLING MB N/S MarKer Identification A) TIE-IN SURVEY 82§8 2627M ~ 2764 B) TOP WHIPSTOCK 8339 2648 2792 C) BASE WHIPSTOCK 835~ 2655 N 2800 B) KOP/EURV£ 6/~00 8'68 2§64 281~ F> CURVE 6/100 8428 2698 N 2850 ~) CURVE 5/tO0 8458 ~7~7 N 286g K) 7" CASIN6 PT ]]608 4347N 4648 M) 4-'/2" LNR PT '2244 46~N 4950 DSI2-28A (P7A) PLAN VIEW CLOSURE · 8772 feet at Azimuth 46.96 BEOLINATION.' +~7.830 (E) SCALE ' ~ inch = ~000 feek DRANN · 02 May ~999 Anad/"J ]] SchYu/~berge/" 500 0 500 ~000 ~500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 <- ~EST' EAST -> III ii · . SHARED - EIq-V' 'CES iii DS12-28A (P7A) PLAN VIEW CLOSURE ' 6772 feet at Azimuth 46.96 DECLINATION.' +27.830 SCALE ' ~ inch = 400 feet BRAWN ' 02 May 199§ , i , BRTLLING Marker Identification MD N/S E/W A] TIE~IN SURVEY 8298 2627 N 2764 E BI TOP WHIPSTOCK 8339 2648 N 2792 E C} BASE NHIPSIOCK 835~ 2655 N 2800 E O) KOP/CURVE 6/t00 8368 2664 N 281t E E) CURVE 6/~00 8398 268J N 283J E F) CURVE 6/lDO 8428 2698 N 2850 E G) CURVE 6/~00 8458 27~7 N 2869 E H) END 6/100 CURVE 8613 2805 N 296~ E I) CURVE 3/~00 JJOOJ 4065 N 4340 E J) END 3/100 CURVE J~382 4249 N 4§4~ E K) 7" CASZNB PT J1608 4347 N 4648 E L) TARGET ~1732 4400 N 4707 E H) 4-]/~" LNR PT ~2244 4822 N 4950 E Ni TO t2244 4622 N 4950 E ~ Tar'qet (' ]00 feet ) I i ".'. "i:': :,."."!.,LA!.'.,,':.~..:: "..',': I T' E'.,/""~,) i":'~i,.- ..... ,. . . ~,.-.,~ ',;. [~ .......... 2400 2600 2800 3000 3~00 3400 3600 3800 4000 4~00 4400 4600 4800 5000 5200 EAST -> .... i iii MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert ChristensOr~ DATE: April 13, 1999 Chairman THRU: Blair Wondzell, P. !. Supervisor FROM: Lawrence M ~e SUBJECT: Petroleum Inspector FILE NO: .aesgdmgfDOC BOP Test Nabors 9ES PBU DS 12-28A PTD 99-33 April 13,1999: I traveled to ARCO's DS 12 to witness a BOP test on Nabors 9ES. The location and rig looked clean and orderly. They are doing a workover on a well with communi_cation in the casi~ng. The testing went slow due to the fastidious of tl~e c~ew and tool~usher. It was also excaberated by having to test the BOP stack with 2 different test joints because the 2 pipe rams were different sizes. The only failure was a 3 %" floor safety valve which failed the pressure test. It was replaced with a 5" and crossover and the failed floor valve were to have a kit put in it. SUMMARY: Witnessed a BOP test on Nabors 9ES, 1 failure, and 6 hours. Attachments: aesgdmgf, xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Rig No. Operator: SSD Well Name: DS 12-28A Casing Size: 7" Set @ 12,354 Test: Initial X Weekly Other 4/13/99 DATE: 9ES PTD # 9g-33 Rig Ph.# Rep.' Joe Polya Rig Rep.: Richard Larkin Location: Sec. 17 T. 1ON R. 15E Meridian Test Pressures 350/5000 659-4144 Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: (~K (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig OK Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 1 2 Pressure P/F 350/5O0O P 350/5000 350/5000 350/5000 P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 350/35O0 P P P I 350/5000 1 350/5000 1 350/5000 P 1 350/5000 2 350/5000 2 350/5000 P 350/5000 CHOKE MANIFOLD: No. Valves 14 , No. Flanges 43 Manual Chokes 1 Hydraulic Chokes 1 ,, Test Pressure PtF 350/5000 [ P 3'5o/5ooo .P,, Functioned I ~, , Functioned P 2,900 1,800 MUD SYSTEM: Visual Alarm minutes '2~5 sec. Trip Tank X X I minutes 47 sec. Pit Level Indicators X X X Remote: X Flow Indicator X X 4 ~ 2100 Meth Gas Detector X X ~ Psig. H2S Gas Detector X X -- ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Number of Failures: 1 ,Test Time: 6.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Wdtten or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I I I REMARKS: 3 1/2" floor safety valve failed, 5" with crossover passed Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: . .. Witnessed By: Larry Wade F1-021L (Rev. 12/94) aesgdmgf, xls t TONY KNOWLE$, GOVERNOR ~ KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 5, 1999 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 12-28A BP Exploration (Alaska) Inc. Permit No: 99-33 SurLoc: 1209~NSL, II3'EWL, Sec. 17, TION. R15E. UM Btmhole Loc. 647'NSL, 397'WEL, Sec. 08, TI0N. R15E. UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill docs not exempt you from obtaining additional pcrmits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be testcd in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson? P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC2 Department of Fish & Game, Habitat Section w/o cncl. Dcpartmcnt of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA ,_.,L AND GAS CONSERVATION COk...~lSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 68.75' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028329 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1209' NSL, 113' EWL, SEC. 17, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 328' NSL, 445' WEL, SEC. 08, T10N, R15E, UM 12-28A At total depth 9. Approximate spud date Amount $200,000.00 647' NSL, 397' WEL, SEC. 08, T10N, R15E, UM 04/05/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028328, 397' MDI No Close Approach 2560 12341' MD / 9100' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11041' MD Maximum HoleAngle 43° Maximum surface 2445 psig, At total depth (TVD) 8800'/3325 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 5711' 6000' 5165' 11711' 8682' 348 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-M 780' 11560' 8565' 12341' 9168' 121 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary PBTD Tag at 12053' MD (08/94) Total depth: measured 12354 feet Plugs (measured) true vertical 9224 feet , . Effective depth: measured 12053 feet Junk (measured) true vertical 8983 feet Casing- Length Size Cemented MD TVD Struotural Conductor 80' 20" 1870 sx Poleset 80' 80' Surface 2519' 13-3/8" 1700 sx PF 'E', 400 sx PF 'C' 2590' 2590' Intermediate Production 11595' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 11666' 8656' Liner 983' 7" 415 sx Class 'G' 11371' - 12354' 8420' - 9224' Perforation depth: measured 11692'-11726', 11984'-12028' ORIGINAL true vertical 8678' - 8707', 8925' - 8964' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing i~ true and correct to the best of my knowledge Signed ~,_ ~'-"~. ~/'/ Dan Stone Title Senior Drillin9 Engineer Date Oomrnission Use Only Permit Number I APl Number ~pr.~ov~.,e~,¢ I See cover letter ~'- ,~,,~ 50-029-21086-01 for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes [~ No Hydrogen Sulfide Measures J~Yes []No Directional_Survey Required J~.Yes []No Required Working Pressure for BOPE [-I 2K; I-'] 3K; ~i~ 4K; I--I 5K; I--I 10K; [-I 15K Other: ORIGINAL SIGNED BY by order of iApproved By Robert N ¢,hd.~f~.n~r~n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IDs 12-28A I Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: Target #1 Start: Total Depth: 1209' FSL, 5167' FEL, Sec. 17, T10N, R15E X = 697700.41 Y= 5931543.08 328' FSL, 445' FEL, Sec. 08, T10N, R15E X = 702290 Y= 5936065 Z = 8708' TVDss 647' FSL, 397' FEL, Sec. 08, T10N, R15E X = 702328 Y= 5936385 Z= 9,100' TVDss I AFE Number: [4J0402 Estimated Start Date: 1 4/5/99 I Rig: I Nabors 9ES IOperating days to complete: 120 [ IuD 112341' I ITVDss: 19,100' I IKBE: 168.75' I Well Design (conventional, slim hole, Conventional Twin Sidetrack etc.): Objective: P&A original completion, sidetrack out of 9-5/8 "casing, drill to the Sag River formation, run and cement a 7" liner (TOL to cover Cretaceous leak), directionally drill 6 "hole thru (1) Z4 target, TD at 12341' MD. Log on wireline, run, cmt and test 4 1/2" solid liner, complete with 5 lA"& 4-1/2", 13CR tbg, 6 GLM' s and EOA tail assy. Perf post-rig on wireline Formation Markers Formation Tops MD TVD(ss) K10 7283' K5 7989' Whipstock KOP 11041' 8098 Top Whipstock at 11029'MD in 9-5/8" Kingak JB 11499' 8449' Sag River 11705' 8608' 7" drilling liner 11715' 8613' set 7" drlg liner 10' into Sag R. TOL to cover uphole Cretaceous leak Shublik 11741' 8636' TSAD 11834' 8708' TSAD is target TZA 11982' 8822' TZ3 12114' 8924' TZ2C 12145' 8948' Total Depth 12341' 9100' 4-1/2" liner at TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MDfrVD O.D. 8-1/2" 7" 26# L-80 BTC-M 5711' 6000'/5165' 11711'/8682' 6" 4 1/2" 12.6# L-80 IBT 780' 11560'/8565' 12341'/9168' liner Mod Tubing 5 ½" 17.0# 13CR NSCC 5500' 30'/30' 5500'/4836' 4 ½" 12.6# 13CR NSCC 6200' 5500'/4836' 11700'/8675' Logging Program: I Open Hole Logs: ]Cased Hole Logs Drilling section: MWD/GR + PWD from KOP (11041') to TD (both 8-1/2 and 6" intervals). MADD pass as per Geologist request. Open Hole: Wireline Platform Express will be run after reaching TD at 12341'. Run log back up to 10800'MD to ensure tie in. Sample catchers and rig site geologist on site before drill out of 6". will run cmt bond log and perf post rig. Mud Program: Special design considerations Drill from KOP to 8-1/2" TD with LSND, drill 6" hole with MI Flo-Pro Polymer system, the formulation of the brine phase will be 6% KCL in Flo-Pro. Interval Density LSRV PV Gels Chlorides pH (ppg) (cps) 8~1/2" 10.5 8-1/2" 10.5 6" 8.7 55 - 60,000 < 15 10 sec. >18 30,000 9.0-9.5 to to expect to to 6" 8.8 55 - 60,000 8-12 10 min. >20 30,000 9.0-9.5 Record LSRV at 1,2,3 minutes: Make certain they are elevated and flat. Plan to run 3 % Lubetex by volume. Start 6" section at 3 % Lubetex Sweeps (50 bbl min at 150,000 cp), Liner slugs and CBU w/60-80 rpm & reciprocation the full 90'. Ensure good stocks of LCM on location. Directional: KOP: 1) 11041' MD, drill out of 9-5/8" casing via whipstock window at 51 o azimuth, 43° inclination, drop and turn angle to 39° inclination, 8° azimuth, hold to 7" liner at top Sag. Drill out in 6" and hold azimuth and angle to TD at 12341' MD, 9100' TVDss'. Maximum Hole 43 °just off whipstock Angle: Surface Shut-in No wells will need to be shut-in and de-pressurized before rig move on and off of the well. Close Approach There are no close approach wells to this wellbore Well: identified by Anadrill Wp #2A. Point to point separation Cement Data: Casing/Liner Lead: Tail: Sxs/Wt~ield Comments Sxs/Wt/Yield P&A of original well 72/15.8/1.15 200' of Class "G", 200' cmt in 9-5/8" TOC @ 11041'. 7" drlg liner, shoe at 260/11.0/3.31 88/15.8/1.14 lead to liner top, 11711 ', TOL at 6000' (30% excess) (500' fill) 500' G around shoe 4 V2", 12.6#, L-80 liner 121/15.7/1.17 Class "G", 40% excess Shoe at 12341' MD OH + 200' above liner Liner top@ 11560'MD top w/DP in hole Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter and BOPE system schematics on file with AOGCC. Bottom hole pressure is 3,325 psi at 8,800' TVDss (estimated) Maximum shut-in casing pressure is 2,445 psi (assumes 0.1 psi/ft gas gradient to surface). NO ANNULAR INJECTION IN THIS WELL. DS 12-28A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Name Contacts Office Home Pager Jim Smith Drilling Eng. 564 5026 345 8660 275-4015 Tony Bunch Drilling Supt. 564 5219 348 6683 275-3703 Toby Archuleta Geol/Geophy. 265 6389 345 3908 Andy Parker Pad Engr. 265 1614 248 8862 275 1793 Lowell Crane Asset Drilling Eng. 564 4089 868 7711 275 8644 Jeff Spencer Reservoir 265 6813 345 9710 Drilling Discussion Well Obiective The primary reason that this twin sidetrack is needed is due to mechanical failure of the 5-1/2" production tubing (badly corroded and parted) and leaking 9-5/8" protective casing expected to be near 6500'. Nabors 9ES will move to 12-28A on/about April 5, 1999 after completing the DS 12-26RWO.The drilling objective of 12-28A is to pull the existing 5 1/2" tubing, set a bridge plug as deep as possible, place P&A cement above the bridge plug, mill out of 9-5/8" from a whipstock on the P&A cement, drill 8-1/2" hole to the top of Sag River, run a 7" drilling liner which will be brought high enough to cover the leaking 9-5/8" casing, drill 6" hole to a location approximately 300' from the existing completion of 12-28, run and cement a 4-1/2" L- 80 production liner, run a new 5-1/2" and 4-1/2" 13CR completion. The objective of the pre-rig work is to ascertain the condition of the 5 ¥~" tubing presently in the hole; cut tubing near 11222' (if it is not fully parted); test the 9 5/8" casing and tubing hanger pack offs. Pre-Rig Operations: 1. RIH with GR/JB on wireline to as deep as possible. Make a 5-1/2" tubing cut as deep as possible (understand that the tubing may be parted at 11,222') but not below the production packer at 11,323'. If there is confirmation of tubing part at 11,222' a tubing cut will not be necessary. 2. Circulate well to seawater through the cut or part. Freeze protect to _+ 2,200' MD. 3. Pressure test the 9 5/8" packoff and tubing hanger packoff to 5,000 psi.. Carefully cycle Lock Down Screws. 4. Freeze protect the well to 2000'MD. 5. Set a BPV in preparation of the rig sidetrack. Post rig cement bond log and perforations on wireline DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is no well that will need to be shut-in during the rig move on and off of the well. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move per ASH procedures. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Anadrill directional well plan Wp #2A due to close approach requirements. PORE PRESSURE: The pore pressure in the 8-1/2" interval is estimated to be 9.7 ppg, the interval will be drilled with 10.5 ppg mud from KOP to TD in Sag River to combat Kingak shale difficulty. It is expected that the reservoir pressure (Sag River on Down) is near 7.3 ppg, 8.6 - 8.7 ppg mud will be used drilling the Sag River, Shublik and Sadlerochit formations and will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS The Kingak shale will be exposed in the 8-1/2" intermediate hole interval, historical practice to avoid Kingak problems has been to keep hole angle less than 45° (12-28A is 39°) and to maintain the mud weight at or above 10.5 ppg, (the 12-28A will be drilled with 10.5 ppg). In addition, PWD data will be collected real time and the "Kingak shale drilling practices" will be employed. There is risk of lost returns in the Sag River at TD of the 8-1/2" hole interval, this risk is driven by exposure of the highly permeable zones within the Sag River. No faults are prognosed in either the 8-1/2" or 6" hole intervals. It is recommended to stock LCM materials on location in preparation for the unexpected. No major hole problems are expected since the directional program is relatively simple and the target is drilled at relatively low angle. H_H_a_S: DS 12 is not an H2S Pad There are reported incidents of H2S at similar pads which involved circulation of annular fluids from the wellbore. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; H2S monitors with both audible and visual alarms; Access to 5-minute emergency escape air packs; Personal H2S monitors; Functional wind indicator; Posted evacuation routes (minimum of two); Muster points in designated safe areas;H__2S; -- Functional communications between rig camp and rig floor. Casing Shoe Kick Tolerance The smallest kick tolerance for the 9 5/8" casing at the whipstock exit point (1104 I'MD/8166'TVD)is calculated as 25.4 bbl of influx assuming a swabbed gas influx at the Sag River formation along the planned directional path with reservoir pressure at 10.2 ppg and a minimum FIT at the whipstock of 11.5 ppg.. The smallest kick tolerance for the 6" hole interval is infinite, based on 8.7 ppg MW (TSAG 11711'MD & 8,682' TVDss, 9.5 ppg reservoir pore pressure), and min. frac at shoe of 11.5 ppg. o - .................... ~o nr ~ArL,UHA't'IU~ ~001 Rig Sidetrack Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate well clean. g. Pull the existing 5 1/2' tubing completion. Tubing cut at +_11,222' MD. 3. Replace the leaking 9 5/8" packoff if necessary. 4. RIH with GR/JB to 11,222', set a bridge plug at 11,222' on DP, sting out and spot 200' of 15.8 ppg cement above the bridge plug for P&A. Reverse off the top of cement at 11,040'MD (DP measurement). 5. RIH with R'iFS to locate expected Cretaceous leak, test 9-5/8" to 3000 psi above leak point. 6. RIH with GR/JB to locate TOC. 7. Set 9-5/8"whipstock on cement top and mill window with milling fluid. Displace to 10.5 ppg LSND mud for drilling Kingak after window is cut. 8. Drill 8-1/2" hote along directional plan to 10'MD into top of Sag River ( top Sag River at approx. 11,705' MD). 9. Run and cement a 7" drilling liner to TD and set TOL 150' above Cretaceous leak. 10. PU 6" directional BHA and RIH to drill out float equipment, drill shoe plus 20' new hole. 11. Displace to Quickdriln. Kick-off and directionally drill the 6" hole to 12,341' TD. 12. Run Platform express wireline log suite at TD. 13. Run and cement 4 Y2", L-80 solid production liner. ;14. Run 5 ~" and 4-1/2", 13 Cr tubing completion. 15. ND BOPE, NU and test tree. RDMO. Post rig cement bond log and perforations on wireline Sidetracking this well should take 20 days Prepared by: Jim Smith, ODE Post. it.~ brand fax transmittal memo Anadrill Schlumberger Alaska District 3 940 Arctic Blvd A~chorage, AK 99503 (907} 273-1700 Fax $61-8537 0IRECTIONAL WELL ~LAN for S~LEED SERVICES Well ......... : DSl2-~SA (P2A) Field ........ : ~rudhoe Bay Com~utation..: Minimum Curvature U~its ........ : FEET 8~rface Lat..: 70.21712173 N Surface Lo~9.: 14~.40512898 W LOCAT2ONS - AiASI~A Zone: 4 Legal Description' X-Coord Y-Coord Surface ...... : 120~ FSL 5167 FEL $t7 T1O~ RL~E L~4 ~9770~.41 593154~.0~ T/e-in suz~ey: 5~3 FSL 643 FEL S~ T10~ RI~ ~ 702105,99 593~585.73 Ta~eL ....... ; 328 FSL ~45 FEL $O~ TiON R15E ~ 702290.00 5936065.~0 B~ .......... : 647 ESL ~97 F~ SOS TI~N R~SB ~ 702328.95 5936385.00 .. . ! ! !..-I/¥ PLAN NOT A??ftO\/ED FOR .... CUTtON PtAN ~re~ar~d ..... ~ 15 Feb 1999 ~er~ sect az.: 22.51 KB elevation.: 66,75 it Magnetic Dcln: +27.822 (E} ~cale Factor.: 0,99994448 Convergence.,: ~.S0078953 STATION IOSNTIFICATION IN 8URn/EM COORDINATE$-FROR ALASKA Zone A WELLKBAD X Y FACE 3926.09 ~ 4510.20 8 702105,99 5935565.73 266R 3926.97 ~ 4511.41 g 702109.18 S935586,65 ~65R 1.01 3935,31 N ~526.94 ~ ?02122.40 $955598,39 451 ~.~1 11041.00 &2,86 ~l.gO 8166.40 8097.65 $378.10 1106~.00 42.86 51.80 8178,86 $I1~,11 $388.]8 L]100,O0 41.77 47.74 8209,92 8141,17 54L3.30 11200.0Q 39.~ 37.45 8285.72 8216.~7 §~74.43 11300.00 38.$0 26,50 ~36F.20 8294.&5 S536.60 39&3.17 N 4533.35 E 702128,69 5935603.%2 HS 17.00 3950,32 ~ 4542.~4 ~ ?02137.58 5936610.80 ~31 0,00 3968.67 N 4564.02 g ?02158.68 5935629.60 ~IOL 7.00 4016.~4 N ~608.19 g ~02201.6~ 5935678.61 1021 7.00 4069.95 N ~641,6T g 702233.6~ S935732.90 941 7.00 11400.00 $8.86 15,32 8441,19 8372.44 5595,15 4128.33 N 4663.96 ~ ~02254,40 5936791.91 85~ 7.00 Ill (Anadrill (c) 99 1228A~2A 3,2C 1C':04 .aM P) ~O IDBNTIF£CATZ~N D~?TH ANGG~ ~ND 7/100 CH~ / 11462.$9 39.43 SI{TJBLIK L[~40.95 39.43 TARGET ZONE 4 11834.16 TSAD 11834.~6 39.43 ZONE 4A 11981,76 39.43 (X]OC 11998.6~ 39.4~ ZONE 2C 12144.90 39.%3 HOT 12182.80 39.4~ ZOI~ 2~ ~22~0.71 39.43 4-1/2" LN~ PT 12341.69 29.43 TI) L234L.69 39,43 PROPOSED WELL PROFILE DIRECTION VERTZCAL-DEExrHS AZIMUT~ T1;D StT~-$EA 8.44 8~89.76 S4I~.~i 8,44 85~.7~ 8449.00 8,44 86~6.75 8608.00 8,44 8681.~S 8613.00 8.44 870i.9~ 8636.00 SSCTrO~ DEPART 5637,93 5660.26 $$09.~3 8.4& -8776.75 6708,00 5866.87 ~.~% 8776.75 8708.00 5866.87 8.44 8890.75 8822.00 59~?,8L 8.44 8903,75 BB3S.00 5968.18 8.44 8963.75 8895.00 6016.Q~ 8.44 8992.75 ~924,00 6039.I8 8.~4 9016.75 6948.00 6058,32 8.44 9053.75 8985.00 6087.84 8,44 9090,76 9022.00 6117,36 8,44 9168.?S 9100.00~ 6179.58 8.t4 9L68.75 glo0.o0 &l?g.58 Feb 1999 Page 2 <:X)ORDINAT8$-FROM 4166.9i N ~672.08 4189.72 N 4675,45 4319.06 N 4694.65 4323.L3 N 45~5,25 4341.$4 N 4698.03 A[~ASF. A go~e ¢ TOO~ D~/ X Y FACE 100 702264.28 5935853.58 HS 0.00 702250.07 5935983.38 HS 0.00 ?0228D.57 593598~,46 ~ 0.00 ?02282.$5 5936006,23 ~400.40 B 4706.72 B 702290,O1 5936065.00 ES 0.00 4400.&0 ~ 4706.72 E 702290.01 5936065.0Q ES 0.O0 ~493.14 ~ 4720.48 g 70230L.33 9936258,07 ES 0.0O 4803.72 N 4722,05 E 702302.63 59361~8.68 HS 0,O0 4552,53 N 4729.29 8 ?02308.59 59362~?.66 t'lS 0.00 4576.12 N 4732.79 g ?02313,47 5936241.33 ES 0.00 4555.64 N &735-69 ~ ?023L3.85 5936260.92 H~ 0.00 4625.74 M 47¢a,15 ~ ?023L7.53 5936292.13 }IS 0.00 4695.84 N 4~4¢.62 S q0232L.22 593632~.33 ~ 0,00 4719,29 ~ 4754.03 B ~02318,95 5936385.00 0.00 47L9.29 N ~T$4.0~ E 702328,95 5936389.00 0.00 Z> Z Z> 'U IT! (Anmdrill (c}~9 1228AP2A 3,2C L0:04 AM P) ~3 0~/15/1999 10:43 907-561-8537 ANADRILL DEO PAGE 04 '- SHARED SERVICES D IELIN .... · , Il. I ill I IIll _ [ [ . I Il '-~ X ..... i Ubi~-~'UA ~A~ ,_._~?~.~ , ........... VERTICAL SECTION VIEW ,, % ~ Section at: 22.5t TVD Scale' ! inch = 150 f~et , '~ , ,, Oep Scale - I inch : ]50 feet E:~ Dnawn · ~5 Feb 1999 AnadrJ ]] Schlumberger ........ , 8) TOP WHIPSTOOK ~t029 8J57 ', --' O) K~/CURVE 7/100 11058 8179 5388 42.86 E) E~ 7/JO0 CURVE ~1463 8490 5538 39.~3  F) 7' CASING PT Ji71J 8582 579J 39.43 ; G) TARGET ZONE 4 1 ' i ' ' H) 4~1/~" LNR PT 12348 9169 6t80 39.43 I) ID J2342 9169 ~80 39.43 ~'1 ~ ........................... " ~-- .... ,, , '~' ~-~- . ~ ~ ~. , / . ~ , ~ . · ~.,. .: . : ' ~. . ./ .. ~ ';., . .., . , 'JC) .... "'" ...... ',' '":::-, i;',""..'-: ~/'~ ....... ' , -,: , .,.. ~- · . i / I 5400 5~75 B350 5425 5500 5575 5650 5725 ~800 5875 5950 Sect ~on ,~eparture ...... ....... , .... i ,. 0e/1S/1999 i0-43 907-5G1-8§37 ANADRILL DEC PAGE 06 ii '~ ,. i i . .... ii DS12-28A(P2A) PLAN VIEW -- ii i ._ CLOSURE ' 6699 feet at Azimuth 4§.2! DECLINATION,' +27.822 SCALE ' ~ inch = 150 feet DRAWN ' 2§ Feb 1999 SHARED 'SERVICE "DRILLING ' · i ._ ~na#r i l ], ,, Sc,h ],, uf~benger.. i . ii ii Marker Identification MO N/S A) TIE-IN SURVEY '10998 3926 N 45~0 E B) TOP WHIPSTOCK ~1029 3938 N 4527 E D) KOP/CURVE 7/t00 ~]058 3950 N 4542 E E) END 7/~00 CURVE 11463 4~§7 N 4672 E F) 7' CASING PT ~tT~J 4323 N 4695 E G] TARGET ZONE 4 H) 4-1/2" LNR PT I234~ 4719 N 4754 E I) TO 12342 47~g N 4754 E ii 417§ ~250 432§ 4400 4475 4550 4625 4700 4775 4850 4925 5000 5075 EAST ->  ill i . i i.,. i . . i i iii ii (~ad~i)) ic)~ L~A~.~ t0:t3 A~ Pi DS 12-28 WELLHEAD: FMC Gen III 13 3/8", 72#/ft, MD~ L-80, BTC @ 2,590' , , ~ ~ Badly co~oded 5-1/2" tubing ¢ ~ ~ Tubing paded at 11222' Packer at11323' ~~ - -- 7" TOL at 11371' ~ ............. ~ ....... d Top of sand at 11419' 9 5/8", 47~/ff, ............. :. ....................... .......... 7", 29~/ff, L-80, BTC ~ 12,354' MD ~ Date Revised by Comments PRUDHOE BAY UNIT 3-4-99 JES Existing well APl NO: 50-029-21086 ARCO-BP SSD DS 12-28A ,O/~O/)03ET3 WELLHEAD: FMC Gen III 13 3/8", 72#/ft, MD__j. L-80, BTC @ 2,590' i '7 lubin~ padod at ~ ~ 2~' Packor at ~ ~ 323' 7' lOk at ~ ~ 37~' ~ Top of sand at 11419' ~ } ~,~[~ m~ ~ ~" 9 5/8", 47~/ff, ~ ~ ~ H ~ ? ~ )1 ~ ~ ~ ~ ~ 7", ~/~ ~ L-80, BTC ~ 12,3~' MD ~ ~ ~ Date ReUsed by Comments PRUDHOE BAY UNIT ~-99 JES Existing well ~/ ~/0~~' ~ ~t~ APl NO: 5~29-21086~1 ARCO-BP SSD ALASKA OIL AND GAS CONSERVATION COMMISSION APPLIC ..... 'ION FOR SUNDRYAPPROV/ 1. Type of Request: [] ~ndon [] Suspend [] Plugging [] Time Extension [] Perforate Casing [] Repair Well [] Pull Tubing [] Vadance [] Other ; Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator , ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, 4. Location of well at surface 1209' NSL, 113' EWL, SEC. 17, T1 At top of productive interval 123' NSL, 243' WEL, SEC. 08, T10N, At effective depth At total depth 272' NSL, 28' EWL, SEC. 09, T10N, R15E, UM 99519-6612 R15E, UM ~,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12354 feet 9224 feet 12053 feet Junk 8983 feet 5. Type of well: ~ Development i---J Exploratory F-] Stratigraphic !--I Service 6. Datum Elevation (DF or KB) 71' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-28 9. Permit Number 84-31 10. APl Number 50-029-21086 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool PBTD Tag at 12053' MD (08/94) ured) Length Size MD '~ ,':!~ ~/-D Structural Conductor 80' 20" 1870 sx Surface 2519' 13-3/8" 1700 sx Intermediate Production 11595' 9-5/8" 500 sx Class Liner 983' 7" 415 sx Class 80' 80' sx PF'C' 2590' 2590' t00 sx PF'C' 11666' 8656' 11371'-12354' 8420'-9224' Perforation depth' measured 11692' - 11726', 11984' - 12028' true vertical 8678' - 8707', 8925' - 8964' Tubing (size, grade, and measured depth) 5-1/2", 17#, U-80 PCT at 11312'; 4-1/2~12.6#, N-80 PCT tail at 11380' . Packers and SSSV (type and measured depth) Baker FHL packer at 11323'; 5-1/2" C~,mco Bal-O SSSV at 2238' 13. Attachments i~ Description summary of proposal I--~ Detailed operations program F--I BOP sketch 14. Estimated date for commencing operation April 5, 1999 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: James Smith, 564-5026 I15. Status of well classifications [~ Oil F--] Gas [-1Sus Service Prepared By Name/Numb Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--------------~---- -z'~, ~ Dan Stone Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE I CHECK NO. / H 150241 VENDOR ALASKAST ! 4 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0325c~9 CKO325c~gD 100o O0 100. O0 HANDLINO INST' S/H TERRI HUBBLE X4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~l[e]lf-'lll ] 1 OO. O0 1 OO. OO :~::::, ,:BP EXPLORATION (ALASKA);?JNC!.. ,:: i ::: ,:f~; i'P. 0,.:.']~0~>:196612 i!ii.!:' '::!;::i?:;~!: :,?!!: i:i ':~: ~ ' : :'!' ~F~L[ATE,~'~::':',??::' ,' :~ '.' "::'::::' *,:,:~' ~E~vELAND, ~10 ..'., ,;',: :':' ~ :: '~,::::.: ',., ,, ,:,:: ~.: :'::: ': .::. '~:~: 412 PAY :T° The Order · 'ALASKA STATE::.LD~PT OF REVENUE ., 3001 :'i:, PORCUPINE? DR : · .. . . ANCHORAGE AK 99501-3120 i." NoT::V~LID AFTER 120 DAYS .: : . ';;...: .... ·~%..,?.,:,'. , · : ,~,,) '"-~,.:,, ~5.~ ll, l, 50~t,~,,. ':Ot,~.20~aqS': 008ht, WELL PERMIT CHECKLIST COMPANY ~,,?,_.~-~ WELL NAME,,~_~ /~--T.2~.~ PROGRAM: exp __ dev ~ redrll ~ serv wellbore sag __ann. disposal para req __ FIELD & POOL ~ ~'~/.5'~ INIT CLASS /-.f-~_...~ ,/--c3 ~ y GEOL AREA . ' ~5"'.~'C) UNIT# /~'~ ~ ON/OFF SHORE ADMINISTRATION ENGINEERING AP~ DATE. 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N Y N 14. Conductor string provided ................... /"'Y~ 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... % N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to ~ {50 r~ psig. _~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... N N GEOLOGY ARPR DATE ANNULAR DISPOSAL APPR DATE 29. 30. 31. 32. 33. 34. 35. With proper cementing rec?.p~~, this plan (A) will contain waste intuitable receiving~.ne; ....... Y N (B) will not contamipafe freshwater; or c,~e drilling waste... Y N to surface; (C) will not im~ir mechanical int~ity of the well used for disposal; Y N (D) will not d~~ucij~ormation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Y.y~ N ..~1 Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. //Y N ,,~,.,~/~ Seabed condition survey (if off-shore) ............ r'/ly]y/on Y N Contact name/phone for weekly progress reports [explorato Y N GEOLOGY: ENGINEERING~:' UIC/_.Ap..~ C_O__M_M.!.~ SJ.O_.N: -' - JDH -- RNC~ co Comments/Instructions: c:\msoffice\wordian\diana\checklist