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Home My WebLink About203-199MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-210 PRUDHOE BAY UN ORIN L-210 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2025 L-210 50-029-23187-00-00 203-199-0 W SPT 4492 2031990 1500 1229 1235 1228 1227 266 370 369 365 4YRTST P Bob Noble 4/23/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-210 Inspection Date: Tubing OA Packer Depth 796 2203 2159 2152IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250425150757 BBL Pumped:2 BBL Returned:1.5 Tuesday, June 10, 2025 Page 1 of 1 9 9 9 9 9 99 999 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.06.10 16:08:25 -08'00' MEMORANDUM TO: Jim Regg 2ef j �ll![ Z. ,/ P.L Supervisor (-( FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L210 PRUDHOE BAY UN ORM 4210 Src: Inspector Reviewed By: P.L Supm Z$IZ Comm Well Name PRUDHOE BAY UN ORIN L-210 API Well Number 50-029-23187-00-00 Inspector Name: Austin McLeod Permit Number: 203499-0 Inspection Date: 4/13/2021 - Insp Num: mitSAM210415164723 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-210 .Type lnj w"TVD 4492 - Tubing 954 - 965 952 - 952' PTD 2031990 - Type Test SPT Test psi 1500 IA 255 2004 _ 1954 1946 BBL Pumped: 2 BBL Returned:1.a - OA 175 376 - 364 360 - Interval 4YRTST P/F P Notes: MIT -IA Monday, April 26, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regget f DATE: Wednesday,April 26,2017 P.I.Supervisor I\ C I��l SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC. L-210 FROM: Adam Earl PRUDHOE BAY UN ORIN L-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-210 API Well Number 50-029-23187-00-00 Inspector Name: Adam Earl Permit Number: 203-199-0 Inspection Date: 4/23/2017 Insp Num: mitAGE170423133918 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-210 ' Type Inj W 'TVD 4492 Tubing 892 892 892 - 892 PTD 2031990 -IType Test SPT Test psi 1500 IA 314 1688 1662 " 1656 • BBL Pumped: 1.3 BBL Returned: 1.2 OA 145 299 - 292 - 290 Interval 4YRTST p/Fi P Notes: MIT-IA SCANNED AUG 2 3 201 Wednesday,April 26,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re J DATE: Tuesday,June 11,2013 gg `\e��C 6 it' A?' SUBJECT: Mechanical Integrity Tests P.I.Supervisor �� g Y BP EXPLORATION(ALASKA)INC L-210 FROM: Chuck Scheve PRUDHOE BAY UN ORIN L-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JE — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-210 API Well Number 50-029-23187-00-00 Inspector Name: Chuck Scheve Permit Number: 203-199-0 Inspection Date: 4/14/2013 Insp Num: mitCS130415073956 Rel Insp Num: M1TOP000004322 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-210 , Type Inj G 'TVD 4492 -I IA 538 2600 2564 2553 H 11 1 ■ T PTD 2031990 Type Test SPT Test psi' 1500 OA 1 180 •i 193 196 196 I I - Interval-14YRTST IP/F P / 1Tubing 1753 1799 1 1752 - 1751 .I L- i Notes: SCANNED FEB 2 0 2014 Tuesday,June 11,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j? �L� DATE: Wednesday,April 17,2013 P.I.Supervisor' lc'rcl. 13 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-210 FROM: Chuck Scheve PRUDHOE BAY UN ORIN L-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry,3132--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-210 API Well Number 50-029-23187-00-00 Inspector Name: Chuck Scheve Permit Number: 203-199-0 Inspection Date: 4/14/2013 Insp Num: mitCS130415073956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min L-210 n 3 2564 I 2553 1 TeD [Type J W 'TVD it 1500 � IA 538 2600 T e In 180 193 1 196 196 1 Type Test Test psi y OA us l _ 2031990 ISPT p P/F Tubing J Interval '4YRTST l -- ! P 1753 1759 1752 j Notes: FEB 2 5 alit Wednesday,April 17,2013 Page 1 of 1 Monthly Injection Report for GPB•MA, Northstar, Milne Point & Endiefor August... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Saturday, September 03, 2011 4:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for August 2011 Attachments: AOGCC Inj Report 09- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the August 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 09- 11.zip» Notes on wells: 1 Vett t 2 0 L Added to Report: None Taken off Report: 09 -36C (PTD #1951140): Reclassified as Not Operable and added to Quarterly Not Operable Report after LDL identified patch leaking. R -02 (PTD #1781000): Reclassified as Not Operable and added to Quarterly Not Operable Report after MIT -IA failed. L -119 (PTD #2020640): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. L -210 (PTD #2031990): inished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressunza i• • •. W -03 (PTD #1971390): Monitored for IA repressurization reported February, 2011. No repressurization noted. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/6/2011 Monthly Injection Report for GPB MA, Northstar, Milne Point & Endic for April 2... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIlntegrityCoordinator @bp.com] Sent: Thursday, May 19, 2011 2:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for April 2011 Attachments: AOGCC Inj Report 05- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the April 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 05- 11.zip» StANNED JUN 0 I. 2Oi Notes on wells: Added to Report: L -119: dded for being Under Evaluation for potential TxIA communication. _ 210: Added for being Under Evaluation for potential TxIA communication. 01(S —�� -217: Added for evaluation of TxIA communication diagnostics. The Well Integrity Coord ator will apply for an administrative approval pending IA repressurization. W -44: Added for being Under Evaluation for potential TxIA communication. Taken off Report: X -24A: Removed after showing no signs of IA repressurization since December, 2010. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 5/31/2011 Well L -210 Injection Plot TIO Plot Under Evaluation for IA • o Pressure vs. Rate o repressurization o o 0 0 v v Tbg IA 0 0 OA 0 0 0 0 c6 co a 0 a ° • a o AY • ° •° •• r A A. ! • • A 4111116 40 °o o e • • • 0 L ♦ Last 90 days • •Last Month r o � , , 0 0 500 1,000 1,500 2,000 2,500 3,000 3,500 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 05/01/11 1,116 877 05/01/11 1,050 360 200 04/30/11 948 874 04/30/11 1,050 360 200 04/29/11 938 865 04/29/11 1,050 360 200 04/28/11 594 918 04/28/11 1,050 360 200 04/27/11 0 1,020 04/27/11 1,050 360 200 04/26/11 0 1,017 04/26/11 1,050 360 200 04/25/11 0 997 04/25/11 1,050 360 200 04/24/11 0 990 04/24/11 1,050 1,060 200 04/23/11 0 992 04/23/11 1,050 1,060 200 04/22/11 0 1,017 04/22/11 1,050 1,060 200 04/21/11 0 1,014 04/21/11 1,050 1,060 200 04/20/11 0 996 04/20/11 1,050 980 200 04/19/11 0 975 04/19/11 1,050 980 200 04/18/11 0 969 04/18/11 980 1,000 200 04/17/11 0 969 04/17/11 1,000 1,000 200 04/16/11 0 999 04/16/11 1,000 800 400 • 04/15/11 0 1,144 04/15/11 2,100 800 400 04/14/11 0 32 04/14/11 100 460 160 04/13/11 102 922 04/13/11 1,000 1,220 200 04/12/11 1,560 985 04/12/11 1,000 1,220 200 04/11/11 1,576 990 04/11/11 1,000 1,220 200 04/10/11 1,576 997 04/10/11 1,000 1,220 200 04/09/11 1,592 996 04/09/11 1,000 1,160 200 04/08/11 1,574 981 04/08/11 1,000 1,160 200 04/07/11 1,577 980 04/07/11 1,000 1,160 200 04/06/11 1,503 961 04/06/11 1,000 1,100 200 04/05/11 173 1,253 04/05/11 1,250 950 280 04/04/11 0 832 04/04/11 1,250 950 280 04/03/11 0 2,346 04/03/11 2,800 360 160 04/02/11 0 2,602 04/02/11 2,800 360 160 04/01/11 0 2,829 04/01/11 2,800 360 160 OPERABLE: Injector L -210 (PTD #2031990) No Indication of IA Repressurization Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, May 08, 2011 9:33 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney Subject: OPERABLE: Injector L -210 (PTD #2031990) No Indication of IA Repressurization Attachments: Injector L -210 (PTD #2031990) TIO and Injection Plot.doc All, Injector L -210 (PTD #2020640) has not shown any signs of IA repressurization during the last 10 days of monitoring while on water injection. A copy of the TIO and Injection plots are included for reference. The well is reclassified as Operable. «Injector L -210 (PTD #2031990) TIO and Injection Plot.doc» Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: . 'r, Mehreen Sent: Tuesday, i d 26, 2011 12:53 PM To: 'Maunder, Thom. (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellp. • Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operation -am Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mik- Swift); Greaves, Damien C Subject: UNDER EVALUATION: Injector L -210 • #2031990) Signs of slow IA repressurization All, Injector L -210 (PTD #2031990) is exhibiting signs of slow!' . ressurization. The IA was bled from 1150 psi down to 350 psi on 4/25/2011 and has built up 60 psi during the -4onitor. The well has been reclassified as Under Evaluation. The well will remain on injection and the IA pressure wi , - monitored for the next 10 -14 days. If the well continues to exhibit IA repressurization, an AA will be submitted for - tinued injection. A T /I /O and wellbore schematic are attached for reference. Thank you, 5/31/2011 • • • Injector L -210 (PTD #2031990) TIO Plot Wet 1-210 • 4 000 1 0 00 - — U - - 1 0 0 0 • • - Tbg —A OA — 4o— 000A On 1,000 44•01111 f i 02/12/11 - 02/19/11 02/ /11 03/ /11 . 03/ 03/19/11 03/26 /11 04/02!11 04/09/1 - 04/16/1 04/23/11 04/30/11 05/07 /11 • Injector L -210 (PTD #2031990) Injection Plot Wet L -210 • 3200 3200 3,000 3.000 2,800 2,003 • • 2.600 2,600 • ''. 2,400 2.400 2.200 2,200 2.000 2000 £ -WHIP 1.800 1.800 1- 1,600 1.600 3 — MI • 1A00 - 1,400 — GI 1.200 1.200 $ — OOer 1.000 - 1,003 ■■•■■ On 800 - 800 G00 - 600 400 400 200 - 200 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 UNDER EVALUATION: Injector L -210 (PTD #2031990) Signs of slow IA repressurizat... Page 1 of 2 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, April 26, 2011 7:11 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: Injector L -210 (PTD #2031990) Signs of slow IA repressurization Attachments: L -119 TIO 4- 26- 11.doc; L -210 TIO 4- 26- 11.doc Tom, I agree with your assessment, a very definite thermal response is observed as a result of swapping these injectors to PWI from MI. L -119 was swapped to PWI on 3/21 and the IA showed an immediate increasing pressure response but then appeared to stabilize. The IA began an increasing trend again on 4/12 which could be attributed to the increase in injection rate. However, the IA also appeared to be equalizing with the tubing pressure. The IA was bled down on 4/25 to 400 psi. During the monitor period the IA pressure increased 90 psi with no correlating increase in injection pressure. L -210 was swapped to PWI on 4/3 and the thermal response on the IA was immediately evident but the IA equalized with the tubing pressure. The IA was bled down on 4/25 to 350 psi. During the monitor period an increase in IA pressure of 60 psi was seen. Given the fluid packed environment in the annuli of these injectors, it is to be expected that temperature shifts could result in substantial pressure effects. However, my concern was that after the bleeds, the lAs continued to exhibit an increasing pressure trend. Please let me know if you have further questions. Thanks, Mehreen From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, April 26, 2011 3:40 PM To: Vazir, Mehreen; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike 3 (Swift); Greaves, Damien C Subject: RE: UNDER EVALUATION: Injector L -210 (PTD #2031990) Signs of slow IA repressurization Mehreen, It is interesting that L -210 and L -119 both exhibit similar responses when it appears they are changed from MI to water. Is the initial IA pressure response to both wells attributed to the change in temperature due to the warmer water? It doesn't seem that the magnitude of the pressure changes was very great. Your comments will be appreciated. Tom Maunder, PE AOGCC From: Vazir, Mehreen [mailto:Mehreen.Vazir @bp.com] Sent: Tuesday, April 26, 2011 12:53 PM 5/31/2011 UNDER EVALUATION: Injector L -210 (PTD #2031990) Signs of slow IA repressurizat... Page 2 of 2 • • To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Greaves, Damien C Subject: UNDER EVALUATION: Injector L -210 (PTD #2031990) Signs of slow IA repressurization II I All, Injector L -210 (PTD #2031990) is exhibiting signs of slow IA repressurization. The IA was bled from 1150 psi down to 350 psi on 4/25/2011 and has built up 60 psi during the monitor. The well has been reclassified as Under Evaluation. The well will remain on injection and the IA pressure will be monitored for the next 10 -14 days. If the well continues to exhibit IA repressurization, an AA will be submitted for continued injection. A T /I /0 and wellbore schematic are attached for reference. «L- 210.pdf» «L -210 TIO 4- 26- 11.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 5/31/2011 ia2.,1.6 1 NMI 1 2 I I , 9W1 i MCFPO 1:15FR5Ji45,1Fi k , • ____ —___ .'' .' II a -----.. 1 E ; :-. . 2 ,.7 i . ...- ,- 3 :-_ 4 1 2 • i - . - 1 _ FA E E g 2 — .. ....--". , , \ 2 ; ----- E 1 § E , . d11711.,-- 04/28/11 Schlumberger ND- 5729 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shadier ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE / ci.'7 ^ i -$ i 03/14/11 1 0'7 1 17 -06 BBKA -00094 INJECTION PROFILE . is ,^ 03/10/11 1 A 1 y 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE — - ♦ 03/08/11 OZTWhtIBMUIM—_ G -23B BLP0.00079 MEM PRODUCTION PROFILE ' _A 03/09/11 0r �7 — 16 -01A BJGT- 00022 ®GL IEEMBIIIMMEM�:• —_ r BLIND-0008T 17Jaa[.I:nsaamfma :. - IKEEIMFT.L'PP'� 0�� IMMUNEEEMIMI BJGT -00023 = r1• ' 'I�t^ 111111M1110 -- 1.-- L -210 BLPO -00086 MEM INJECTION PROFILE : ojr; — 03/23/11 _ D a __ V V -105 BLPO -00091 MEM INJECTION PROFILE _ - 03/29/11 ♦.. BBSK -00065 INJECTION PROFILEWFL aF3�" Ii • • �OF:�i ? -- V III -212 BD88 -00096 ' J eN ' - OF LE r' • • 04/03/11 1 af'� y � �_ L -214A BCRJ -00073 INJECTION PROFILE ♦ i1! 03/18111 1 ♦.. BAUJ -00071 MEM INJECTION PROFILE ,•rAMRIM " ' 0N_/i0 -- BAUJ -00077 kLV,m_la._il ral_ s+i1r _� L :7 O:��b1 0�� 3- 0510 -29 BG4H -00043 �;lK ��i� -- 1.47A1M -20 BLPO -00092 MEM PRODUCTION PROFILE iY �,W.IGIIII '�■oe•WzTe111111111111111-- MINIMIEEt BBSK -00057 2011=1111/GT 3741/ •13301111PIT♦7.'.rC ~�� == 8088.00097 MEM INJECTION PROFILE jj['TiffrMMIIIIIe;MEME111111■1110FMEVANIM-- 04-11A AWJI -00134 I' 'I' "0 E 0J 0 dr °--ka 03/24/11 1 lEi 6A " =; 1 -- P2-41 BG4H -00044 PRODUCTION PROFILE - _ _ -. 03122/11 1 ..:. 14 1 -- D-26B BMSA -00009 �!;j., • 'r41111111111•0_— . r BLPO -00087 MEM PRODUCTION PROFILE ;i - 0M 0 -- Z -20 BP5G -00010 GLS fir i. –100 03/29/11 1 a Q 44 i 1 Y -29A BCUE -00122 MEM LDL i 9 (Q -- (' 03/20111 1 0C) 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechnicat Data Center LR2-1 2525 Gambell Street, Suite 400 900 E Benson Blvd Anchorage, AK 99503 -2838 - - iL,N (11 2U'�`� • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description MPJ-19A W-25A W-25A 07-26 6581-00020 AXBD-00063 AXBD-00061 BALL-00007 USIT MEM LDL MEM PROD PROFILE RST X-10 BALL-00001 PRODUCTION PROFILE X-13A BALL-00002 PRODUCTION PROFILE - GC-2E BSJN-00027 PRESSlfEMP SURVEY B-16A AZCM-00049 GLS W-25A AWYZ-00004 MEM DDL Z-16 85JN-00029 PRODUCTION PROFILE X-32 BSJN-00024 PRODUCTION PROFILE X-25 L-210 5-218 L-222 AYKP-00058 B2NJ-00043 09AKA0176 09AKA0148 PRODUCTION PROFILE MEM INJECTION PROFILE OH MWD/LWD EDR OH MWD/LWD EDIT 2-08/K-16 11'10 AZCM-00046 AP30-00066 _ RST ~ ~ RST PLEASE ACKNOWLEDGE REC FIDT Rv crc~u~~ r_ ww~n r.~~.............,.._ ___-- _ _ ___ _. _ -___.._. _......... ...... vvr. ~r~a.n ~V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. NQ. 537E Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD _ _ p~ly~R yam, ~ Ca 4 tVV{{ Icy C~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 SChl111tlb~l'~~P Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~? ~+ _ <.; , Log Description NO. 5447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 • ~G~ • ..•,~.~~~~~~~cai uata renter LR2-1 € ,~' Alaska Data & Consulting Services 900 E. Benson Blvd. ~'~ ~' '~ ~~}} ((~~+,{ .~ f3 ~ U 1 U 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 -~.1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ; ~'`', k'~~ G l~? ~ ~ .~ ~ ~~~'~ ~~'i~~~` L~iw .: ~ ~ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, OCT 0 ~ 2~09 ~tls~s~Ca ~il ~a Gas Cons. Cominis~io~ Anchora~ o`~~ 3 " ~ ~'~ ~,~-ata Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet senre as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (70-404) eaee L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Conosion inhibRor Corrosion inhibitod sealant date ft bbis ft na al L-Ot 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-t02 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012239 50029230550000 NA 2.75 NA 28.05 5/6l2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 ~-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-11S 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 102 5/6/2009 ~-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6l27f2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 STATE OF ALASKA ~~"`~ ~' ~~ L ~~9 '~/ 6 ~a ALA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATION~~~`~ Gs~ '~' '''~~• ~;ommission F, ... .,., ~. 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other CON T TO WAG Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension ~ 5/15/02009 Change Approved Program [] Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~ 203-1990 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23187-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 79.3 KB - L-210 - 8. Property Designation: 10. Field/Pool(s): ADLO-028238 - Prudhoe Bay Field/ Orion Pool 11. Present Well Condition Summary: Total Depth measured 9668 - feet Plugs (measured) None true vertical 4993.69 - feet Junk (measured) 9356 Effective Depth measured 9567 1 feet true vertical 4937.11 - feet Casing Length Size MD TVD Burst Collapse Conductor 108. 20" 215.5# A53 Surface - 108 Surface - 108 Surface 4368 9-5/8" 40# L-80 28 - 4368 28 - 2726 5750 2090 Production 9656 7" 26# L-80 26 - 9656 26 - 4987 7240 5410 ,~ ~y~, " li~~~ '~ ~~~ Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 26 - 8669 3-1/2" 9.3# L-80 8669 - 92 1 9 ~ , / Packers and SSSV (type and measured depth) 3-1l2" Baker Premier TCI I Packer 868Y` '~~ 3-1/2" Baker Premier TCI I Packer 8922 4-1/2" Baker S-3 Perm Packer 9163 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1740 949 Subsequent to operation: 2500 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 6/4/2009 Form 10-404 R ised 04/200 ~ ' ~~/ °~ '""'~ ~ ~"~ ~', ~ Submit Or' nal O y_ (~.)!r'~ ,, ' ~ ~+, ~ `,a° ill.+. ~ ~1~~ L-210 203-199 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L-210 1/15/04 PER 8,804. 8,894. 4,548.74 4,590.88 L-210 1/15/04 PER 8,959. 9,019. 4,621.74 4,650.85 L-210 1/15/04 PER 9,054. 9,084. 4,668.04 4,682.91 L-210 1/25/04 STC 8,681. 8,922. 4,492.4 4,604.08 L-210 1/25/04 STC 8,922. 9,163. 4,604.08 4,722.47 L-210 4/8/04 APF 9,279. 9,369. 4,781.65 4,828.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~, ~ • • L-210 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/24/2009 T/I/O = 500/480/240 Schmoo-b-gone.. Pumped 3bbls meth, 278bb1s SBG, 5bbls ~ ~ meth, 111 bbls 1 %KCI into injection line, down tubing. While pumping SBG, performed various step rate tests, logging pump rate, Flowmeter rate (on injection line,) and S-riser pressure. See log for data. Normal out well upon completion of test, notified Pad Op of well status. f=WHP's=600/380/220 i 4/13/2009T/I/0= 840/430/110. Temp= 102" (PWI). integral on IA. IA FL @ 210' (4 bbl). [SV= C. WV,SSV,MV= O. IA,OA= OTG. IA FL (pre AOGCC MIT-IA). No NOVP. 4/15/2009 T/I/0=850/460/170 Temp= Hot AOGCC MIT-IA PASSED to 4000 psi (MI swap) (AOGCC Witnessed by John Crisp) Pressured up IA with 6 bbls of neat meth to reach 4000 psi. MIT-IA lost 60 psi in the 1st 15 mins and 0 psi in the 2nd ~ 15 mins for a total pressre loss of 60 psi in 30 min test. Bled IA. `FWHP's=850/520/120. SV=Closed; WV, SSV, MV, IAV, OAV=Open. "**IA has an ANSI 1500 psi flange"** 4/20/2009 L-210 Shut in I/A valva P/T to 500# then pulled ANSI 3000# flange and put on a ;API 5000# flange and P/T to 5000# PASS. 5/1/2009 """Job in progress, Continue to standby for Slickline, continued on 5-2-09***, did ;not pump. ~ 5/1/20091***WELL INJECTING ON ARRIVAL"** I RIG UP SLICKLINE "*"JOB CONTINUED ON 5/2/09**" 5/2/2009 "'*Job continued from 5-1-09*** Assist Slickline with Brush and Flush, pumped 144 bbls 180'F diesel down Tbg while Slickline brushed, Slickline has control of well upon departure FWHP=1100/380/200. • __._ .__~ 5/2/2009 """JOB CONT. FROM 5/1/09**" BRUSH & FLUSH W/ 3.75" GAUGE RING & 4 1/2" BRUSH TO TOP OF XO @ 8656'SLM. BRUSH & FLUSH W/2.72" GAUGE RING & 3 1/2 BRUSH TO P15 @ 9175'SLM SET 4 1/2" MCX (SER# M-608) @ 3778'SLM "*'' TURN WELL OVER TO DSO -LEFT WELL SHUT IN, READY TO PUT ON INJ *"" FLUIDS PUMPED BBLS 144 diesel 278 SBG 111 1% KCI 14 METH 547 Total MEMORAI~IDUM To: Jim Re ~ P.I. Sup ~rvisor ~~~ ~~. ~ ~ ~ ~~ FROM: John Crisp Petroleum Inspector r~ u State of Alaska Alaska Oil and Cas Conservation Commission DATE: Monday, April 20, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-210 PRUDHOE BAY iJAl ORIN L-210 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv~ Comm Well Name• PRUDHOE BAY UN ORIN I,~210 API Well Number 50-029-23187-00-00 Inspector Name• John Crisp Insp Num: mitJCr090416080149 Permit Number: 203-199-0 Inspection Date: 4/15/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-210 Type Inj. W TVD 4492 ~ 440 4000 3940 3940 P.T. 2031990 TypeTest SPT Test psi 4000 OA 170 470 340 270 Interval OTHER Per, P Tubing 850 850 850 850 Notes• Anna Dube is WIE supervising this MIT, not Rep. on location. 6 bbl's pumped for test. ANSI 1500 flange installed on IA with potential for Crews to • Rig Up on annulus valve that would exceed the rated working pressure of ANSI 1500 flange. Subject was discussed with Anna Dube, as per WIE instructions to Hot Oil & DHD the well was left with ANSI 1500 flange on IA because it was the only flange available for installation. Test for gas injection integrity. ~t~sSei~ ~~. ISoD ~ ~e~cv~ S ~N~ l~;yt; ~ !Z?u~,~~S ~~~ c7~ ~P S cca,~M,~-r~-.~- ~v P.~«.~t.~.,ie s c.J ~' fn e - ~~~ ~ >s ~~t~~ . t Monday, Apri120, 2009 Page 1 of 1 Request: paperwork req'd for MI injection. Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 23, 2009 10:33 AM To: 'West, Taylor' Subject: RE: Request: paperwork req'd for MI injection. Taylor, I found our past email. Where WAG is approved without restrictions, as in Orion all that is needed for an operating injector is the 404 changing from WINJ to WAG with the date of first MI injection noted. So far as I am aware, the only pool "aut west" where individual well approvals are necessary to allow MI injection is Polaris. Regards, Tom Maunder, PE AOGCC From: West, Taylor [mailto:Taylor.West@bp.com] Sent: Monday, February 23, 2009 10:27 AM To: Maunder, Thomas E (DOA) Subject: Request: paperwork req'd for MI injection. Tom: ~ ~©~-t-~~C~ We are looking to put Orion wells V-216 and L-210 on MI service this year. Both are approved for WAG service in the AIO, but were permitted as WINJ. Please let me know if I need to submit any paperwork other than the 404. Thx 7tzt~lc~r ~~'est Production Engineer Orion /Polaris Heavy Oil BP Exploration (Alaska), Inc. 907.564.4647 (desk) 907.632.0111 (cell) 907.564.5016 (fax) 2/23/2009 09/29/08 ~l~s'll~~~l~pr~~pe~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh !t N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Gomm ` ~`'~" a ~~'}y 4 "~ `; ~' ~ Attn: Christine Mahnken ''''~~'~`~'" "~"~"~ ~ `fr ` ~ ` 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... new.. ..i:,... 17-12 11978484 PRODUCTION PROFILE - 09/19/08 1 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09/08/08 1 1 18-05A 11.999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT - "a 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- /(,j 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG ~ _ / Og/06/08 1 1 13-14 11978482 PROD PROFILE ~ ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE 2 _ CI'3~ 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02/08 1 1 L-216 11970842 INJECTION PROFILE - ~ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE ? 09/09/08 1 1 L-205L4 40016965 OH MWD/LWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) 1'11 LAG~G A/~V\1I~1~I1 ~ . --____-__.-.-~-.~~~~.~..~~~.... v. v.~w.~„~v. ~,~r •.r., v11,~11~M V1~~VV1-1 GMVII IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~ ~ ., I ('i Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9 03-2 8 ATTN: Beth Received by: • • +.. • °.:~.,. ii ' • ~ o3~o~izoos DO NOT PLACE .. ~:~ .. ~- '',. .~. ~„ ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\CvrPgs_Inserts~Microfilm Marker.doc RECEIVED 08/28/06 Scblulllberger SEP 1 2 2006 NO. 3947 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Oil & Gas CooS. CClTlmj~n Ar1<:i".crage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Well Job# Log Description Date BL Color CD S-03 11223120 PPROF & RST WFL 06/13/06 1 L-214 11054295 CH EDIT OF PDC FROM UBI OS/27/05 1 L-214A 11217230\ . CH EDIT OF PDC FROM USIT 03/16/06 1 L-210 10687666 CH EDIT OF PDC FROM USIT 01/14/04 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnicel Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambell 51. Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Date Delivered: Received by: SCANNED SEP 1 ~ lODG . U.T~d03-lgo¡ 1± I Lfr3S- 08/15/06 sc~...... NO. 3924 Schlumberger-DCS 2525 Gambell St, Suite 400 /Î ð Anchorage, AK 99503-2838 ()~ C7'Cf3 -fC¡, ATTN: Beth :t IL.{ öDb Company: Alaska Oil & Gas Cons Camm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Well Job# log Description Date BL Color CD Z-103 PB1 10687733 OH EDIT OF WIRELlNE LOGS 02/08105 3 1 L-21 0 40009986 OH EDIT OF MWD/LWD 01111/04 2 1 L-210 PB1 40009986 OH EDIT OF MWD/LWD 01/08/04 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Date Delivered: 11/93/tIP BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received by: . .' '. ~,~~ '1 "-'¿ ;\IJe I>..' \f..' RECEIVED AUG 2 3 2006 .AIIIka 011 & Gas Cons. eommiSSion Anchofage ScblllBberger NO. 3924 Schlumberger-DCS 2525 Gambell 51, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Camm Attn: Christine Mahnken 333 West 7th Ave, Suile 100 Anchorage, AK 99501 It (.j 06"~- U :.LC-.- go'3 - tC¡'ì Field: Borealis Orion Well Job# Color Log Description Date BL CD Z-103 PB1 10687733 OH EDIT OF WIRELlNE LOGS 02108/05 3 1 L·210 40009986 OH EDIT OF MWD/LWD 01/11/04 2 1 L·210 PB1 40009986 OH EDIT OF MWD/LWD 01/08/04 2 1 ., PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 î 900 E Benson Blvd. t Anchorage AK 99508-4254,1i} ! I A ~ Date Delivered b _~.I ¿------- ~ ~t(Jh -·r ;'~1-":;'¡ . ~vf.."t;¡,,;' ~.i~""". 5chlumberger·DCS 2525 Gambell St. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: RECE\VED AUG 2 3 ZOû6 Alaska Oil & Gas Coos. commissicf1 Ancl1oI'a9-i'! £1 ~:~ 08/15/06 . . / Î /=e.0 DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031990 Well Name/No. PRUDHOE BAY UN ORIN L-210 MD 9668 TVD 4994 Completion Date 1/17/2004 REQUIRED INFORMATION Mud Log No -~---~_.__._-- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name t.e6' D Wrd Directional Survey Directional Survey Directional Survey Directional Survey Cement Evaluation vZt D Wrd RPS/ "" aòg --~- Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION y~ Well Cored? Chips Received? '"""Y'7l'r"- Analysis ~. Received? Operator BP EXPLORATION (ALASKA) INC Completion Status 1WINJ Current Status 1WINJ Samples No API No. 50-029-23187-00-00 ~y ~ Directional s~ZYes ~__ --~-_._--,._- (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ . Scale Media No Start Stop CH Received Comments 0 9668 1/26/2004 0 9668 1/26/2004 0 1 0040 1/26/2004 PB1 0 1 0040 1/26/2004 PB1 5 Blu 5670 9510 2/11/2005 USIT/AMS/CCUGR ---~.~- Sample Set Sent Received Number Comments Daily History Received? ~N . Formation Tops (!Y Comments: fv\ ¡ ~ So (' ""\ è vY\cl ~ l.. ~ t: 1* ß l- / ~" U'-J'ì D,')d~. ~ h~^r'\4 b\.vJ'1. Fó.!''""''''-~- (Av¡J¡/j~". hMHÝ @, hp. Cow-. ) - ~'" Compliance Reviewed By: Date: (\ì~ ~~ TO: Jim Regg P.I. Supervisor . '24ft £1 is 105' '-'~..~'" 0.. .n.la~n.a Alaska Oil and Gas Conservation commie DATE: Wednesday, June 15,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-210 PRUDHOE BAY UN ORIN L-21O J......~J..'f.'-'~~J. ........,U.1..... FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: -Jb'F- P.I. Suprv '-- . Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UN ORIN L-210 Insp Num: mitCS050612082907 ReI Insp Num: API Well Number: 50-029-23187-00-00 Permit Number: 203-199-0 Inspector Name: Chuck Scheve Inspection Date: 6/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. , , , Well i L-2IO IType Inj. I W TVD 4492 IA 600 1700 1640 1640 P.T. ! 2031990 ITypeTest i SPT Test psi 1123 OA 400 520 490 490 I I I Interval INIT AL P/F p Tubing 875 875 875 875 Notes: Wednesday, June 15,2005 Page I of I Schlumberger Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description . '7.<11- 00'5 -L-218 ¿¡I.Y.l '1 "0 V-211 /} 0'"'( - ¡"'A L-210 r:" 0';' -I ~'1 V-216 ~ ./ ï '" :;z O"t '" V 05/14104 11/19/04 01/14104 09/09/04 10687775 US IT (PDC) 10919914 USIT 10687666 US IT 10687707 USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotecfnicai Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 ¥Js Date Delivered: . NO. 3335 Company: Alaska Oil & Gas Cons Comm Atto: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Date Color CD BL Schlumberger-DCS 2525 Gambel! St. Suite 400 ~;¡~d~ ¿,{)3 -- /99' 02111105 e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 181 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2605' NSL, 3559' WEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 3734' NSL, 3300' EWL, SEC. 35, T12N, R11 E, UM Total Depth: 3569' NSL, 4018' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583354 y- 5978329 Zone- ASP4 TPI: x- 590199 y- 5979536 Zone- ASP4 Total Depth: x- 590918 y- 5979380 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT 22. One Other 5. Date Camp., Susp., or Aband. 1/17/2004 6. Date Spudded 1/1/2004 7. Date T.D. Reached 1/11/2004 8. KB Elevation (ft): 79.3' 9. Plug Back Depth (MD+ TVD) 9567 + 4937 10. Total Depth (MD+TVD) 9668 + 4994 11. Depth where SSSV set (Nipple) 3796' MD 19. Water depth, if offshore N/A MSL GRADE A53 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTIIIIGOePTHMb S¡;¡TtII1lGDEItrH TVP ~onÖM ~OUÖM Surface 108' Surface 108' 28' 4368' 28' 2726' 26' 9656' 26' 4987' 20" X 34" 9-5/8" 215.5# 40# 26# 7" 23. Perforations op'en to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Gun Diameter, 5 spf 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 8804' - 8894' 4549' - 4591' 9279' - 9369' 4782' - 4829' 8959' - 9019' 4622' - 4651' 9054' - 9084' 4668' - 4683' E )IH14 Revised: 07/01/04, Put on Inj. & Add Perf 1 b. 'Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 203-199 13. API Number 50- 029-23187-00-00 14. Well Name and Number: PBU L-210i 15. Field I Pool(s): Prudhoe Bay Field I Orion Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 48" 260 sx Arctic Set (Approx.) 12-1/4" 643 sx Arcticset Lite, 382 sx 'G' 8-3/4" 468 sx Class 'G' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BBL GAs-McF WATER-BBL SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.3#, L-80 DEPTH INTERVAL (MD) 2200' TUBING RECORD DEPTH SET (MD) 8670' 9220' PACKER SET (MD) 8681' 8922' & 9163' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 159 Bbls of Diesel 26. Date First Production: June 9, 2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". OIL-BBL None Form 10-407 Revised 12/2003 GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) CONTINUED ON REVERSE SIDE , ,". _ """.,t(. ,. .". RBÐUS~ JUt .Il 3 â GY n PIG' !\! !J. , e 28. GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Base Schrader / Top Colville 5033' 7630' 7749' 7976' 8222' 8396' 84 77' 8591' 8808' 8964' 9062' 9179' 9284' 9400' 9493' 9574' 2998' 4069' 4115' 4201' 4298' 4369' 4402' 4452' 4551' 4624' 4672' 4731' 4784' 4846' 4896' 4941' None Ugnu Ugnu MA Ugnu MB1 Ugnu MB2 Ugnu MC Schrader Bluff NA Schrader Bluff NB Schrader Bluff NC Schrader Bluff OA Schrader Bluff OBa Schrader Bluff OBb Schrader Bluff OBc Schrader Bluff OBd Schrader Bluff OBe Schrader Bluff OBf 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~ . ~ Title Technical Assistant Date 0 7.. D (..() if PBU L-21Oi 203-199 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Thomas Schaefer, 564-4685 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Well: Field: API: Permit: e . 12/31/03 01/01/04 01/17/04 Nabors 9ES 04/07/04 PULLED BALL AND ROD. PULLED RP-GLV FROM 8538' SLM. SET DGLV. MIT TUBING TO 2000 PSI. PULLED RHC PLUG BODY FROM 9172' SLM. RAN 1.5" IMPRESSION BLOCK. L-201 i Prudhoe Bay Unit 50-029-23187 -00-00 203-199 Accept: Spud: Release: POST RIG WORK 04/08/04 RUN DRIFT WILlB TO 9187'. RUN HDF FIRING HEAD TO 9187'. WAITED FOR DETONATION. RUN LIB TO VERIFY GUNS HAD DROPPED. SET BPV. LEFT WELL SI. . TREE = 4-1/16" CIW WELLHEAO = FMC ÄCTUA-TOFr;;--~·-'\jA ~~ ",~~-~ KB. ELEV = 79.3' ~_ . H~_~'~' n~_ BF. ELEV = 53.4' Rop;,·-- 200' MãX-Ängle-;·~- 6a"@ iã68~ ~...., _~.,,'_ ,"m~_."_~___',,____.~. Datum MO = 8652' nm~~ ~~~_" ",~___,~'- _m__ __ ^ Datum lVO = 4400' SS 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 4368' Minimum ID = 2.813" @ 8739'/ 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8669' PERFORA TION SUMMARY REF LOG: SWS USIT 1/14/04 ANGLE AT TOP PERF: 620 @ 8804' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 8804 -8894 0 01/15/04 4-1/2" 5 8959 - 9019 0 01/15/04 4-1/2" 5 9054 - 9084 0 01/15/04 4-1/2" 5 9279 - 9369 0 04/18/04 13-1/2" TBG, 9.2#/9.3#, L-80, .0087 bpf, ID = 2.992" H 9219' I PBTD H 9567' 17" CSG, 26#, L-80, ID = 6.276" H 9656' ~ GAS LIFT MANDRELS IST MD lVD DEVI ìYÆ VLVILATCHPORT DATE 5 8559 4443 64 KBG2 DMY BK 0 04/07/04 WA TERFLOOD MANDRELS ST MD lVD DEV ìYÆ VLV LATCH 4 8760 4476 62 MMG DMY RK 3 8883 4585 62 MMG DMY RK 2 8948 4620 61 MMG DMY RK 1 9122 4752 60 MMG DMY RK L-21 0 = =-1 I L .. I ------i I Z Z-----1 .. I --1~ I I :8: :8: ~ ---.I: ~ I , o I 'r ~ OA TE REV BY COMMENTS DA TE REV BY 01/25/04 JAF/TLH ORIGINAL COMPLETION 04/07/04 JLJ/KAK GLV C/O 05/14/03 TW/KAK DATUMMO&lVDCORRECTIONS 04/18/04 TW/KAK FIRESWS SXARGUNS COMMENTS . SAFETY NOTES: 1016' H 9-5/8" TAM PORT COLLAR I 3796' 1-1 4-1/2" HES X NIP, ID = 3.813" I PORT DATE o 01/16/04 o 01/16/04 o 01/16/04 o 01/16/04 7620' H 7" MARKER JT W/ RA TAG I 8669' H 4-1/2" HES X NIP, 10 = 3.813" I 8670' H 4-112" X 3-1/2" XO, 10 = 2,992" I 8681' H 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 8739' H 3-1/2" HES X NIP, 10 = 2.813" I 8743' H 7" MARKER JT W/ RA TAG I 8892' H 3-1/2" TBG CENTRALIZER W/ RA MARKER 8911' H 3-1/2" HES X NIP, 10 = 2.813" I 8922' H 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 9150' H 3-1/2" HES X NIP, 10 = 2.813" I 9160' H 3-1/2" X 4-1/2" XO, 10 = 2.910"1 9163' H 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I 9166' H 4-1/2" X 3-1/2" XO, 10 = 2.910" I 9189' H 3-1/2" HES X NIP, 10 = 2.813" I 9201' H 3-1/2"HESXNIP,10=2.813" 9219' H 3-1/2" WLEG, 10 = 3.00" I 9356' H FISH - SWS SXAR GUN ASSEMBLY I ORION UNIT WELL: L-210 PERMIT No: 2031990 API No: 50-029-23187-00 SEC 34, T12N, R11 E, 2605' NSL & 3559' WEL BP Exploration (Alaska) _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATI0f'J COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 1m WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2605' NSL, 3559' WEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 3734' NSL, 3300' EWL, SEC. 35, T12N, R11E, UM Total Depth: 3569' NSL, 4018' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583354 y- 5978329 Zone- ASP4 TPI: x- 590199 y- 5979536 Zone- ASP4 Total Depth: x- 590918 y- 5979380 Zone- ASP4 18. Directional Survey 1m Yes 0 No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT One Other 5. Date Camp., Susp., or Aband. 1/17/2004 6. Date Spudded 1/112004 7. Date T.D. Reached 1/11/2004 8. KB Elevation (ft): 79.3' 9. Plug Back Depth (MD+ TVD) 9567 + 4937 10. Total Depth (MD+TVD) 9668 + 4994 11. Depth where SSSV set (Nipple) 3796' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" X 34" 9-5/8" 7" WT. PER FT. 215.5# 40# 26# GRADE A53 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTINGDEPTH'MD SËTI1NG DEPTHniD HOLE Top BOTTOM Top BOTTOM SIZE Surface 108' Surface 108' 48" 28' 4368' 28' 2726' 12-1/4" 26' 9656' 26' 4987' 8-3/4" 22. 23. Perforations op'en to Production (MD + TVD of To£ and Bottom Interval, Size and Number; if none, state 'none"): 4-1/2" Gun Diameter, 5spf 4-112" Gun Diameter, 5 spf MD TVD MD TVD 8804' - 8894' 4549' - 4591' Gun Assembly 8959' - 9019' 4622' - 4651' attached to 9054' - 9084' 4668' - 4683' bottom of tubing, Not Fired Yet 9279' - 9369' 4782' - 4829' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested 1b. Well Class: o Development 0 Exploratory o Stratigraphic Test 1m Service 12. Permit to Drill Number 203-199 13. API Number 50-029-23187-00-00 14. Well Name and Number: PBU L-210i 15. Field I Pool(s): Prudhoe Bay Field I Orion Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 643 sx Arcticset Lite, 382 sx 'G' 468 sx Class 'G' AMOUNT PUllED 24. SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.3#, L-80 25. DEPTH INTERVAL (MD) 2200' DEPTH SET (MD) 8670' 9220' PACKER SET (MD) 8681' 8922' & 9163' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 159 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil-Bel GAs-McF WATER-Bel PRODUCTION FOR TEST PERIOD ... CALCULATED ...... 24-HoUR RATE""" Oil-Bel Flow Tubing Casing Pressure Press. GAs-MCF WATER-Bel CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none"~,,_._,._ None '~Gi';5, OR/BIHAr ï.;~,~ Form 10-407 Revised 12/2003 \ 'MAR 0 5 200,- () CONTINUED ON REVERSE SIDE MAR \)9 1nn4 (,ç' ØB}MS aFL 28. GEOLOGIC MARKER'- 29. eRMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu Ugnu MA Ugnu MB1 Ugnu MB2 Ugnu MC Schrader Bluff NA Base Schrader I Top Colville 5033' 7630' 7749' 7976' 8222' 8396' 8477' 8591' 8808' 8964' 9062' 9179' 9284' 9400' 9493' 9574' 2998' 4069' 4115' 4201' 4298' 4369' 4402' 4452' 4551' 4624' 4672' 4731' 4784' 4846' 4896' 4941' None Schrader Bluff NB Schrader Bluff NC Schrader Bluff OA Schrader Bluff OBa Schrader Bluff OBb Schrader Bluff OBc Schrader Bluff OBd Schrader Bluff OBe Schrader Bluff OBf 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fÔ~. ~~ Title Technical Assistant Date 03 -DS ·01..( PBU L-210i 203-199 Prepared By NamelNumber: Te"ieHubb/e, 564-4628 Well Number P Drilling Engineer: Thomas Schaefer, 564-4685 ermit NO.1 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Name: L-210 Common Name: L-210 Test Date 1/6/2004 Test Type Test Depth (TMD) " ----...- ._. - - LOT 4,368.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) AMW --.. -...".---- ---.-" .- --- . .--.....-.... ..-... .- 2,725.0 (ft) 9.30 (ppg) I Surface Pressure Leak Off Pressure (BHP) , -"--"--'''- 570 (psi) 1 ,886 (psi) Page 1 of 1 EMW 13.33 (ppg) . . Printed: 1/19/2004 9:47:27 AM . . BP EXPLORATION Operations Summary Report Page 1 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/28/2003 21 :00 - 00:00 3.00 MOB N WAIT PRE Wait on weather, Phase II unable to move rig. Standby with full crews 12/29/2003 00:00 - 00:00 24.00 MOB N WAIT PRE Phase 2 worsening to Phase 3 weather conditions by 15:00 hrs - wait on weather to move rig to L Pad. Heavy equipment escort from roads & pads to change out crews at midnight. 12/30/2003 00:00 - 09:00 9.00 MOB N WAIT PRE Continue waiting on weather, Phase 3 conditions. Winds subsided to less than 20 mph, Phase conditions reduced to Phase 1 on the Spine Rd, Phase 2 on access roads and pads 09:00 - 13:00 4.00 MOB P PRE Bridal up and prepare to lay down derrick. 13:00 - 14:00 1.00 MOB P PRE PJSM with rig personnel. Lay down derrick. 14:00 - 15:30 1.50 MOB P PRE Snow removal around pits, shop and satellite camp. 15:30 - 17:30 2.00 MOB P PRE PJSM with Security, Tool Service, Peak and Rig personnel. Move pits, shop and satellite camp to L-Pad. 17:30 - 00:00 6.50 MOB P PRE PJSM with Security, Tool Service, Peak and Rig personnel. Move sub to L-Pad 12/31/2003 00:00 - 00:30 0.50 MOB P PRE Continue moving sub onto L-Pad 00:30 - 03:00 2.50 RIGU P PRE DSM bleeding down flow lines and gas lift lines on adjacent wells. Remove snow for diverter line. 03:00 - 04:30 1.50 RIGU P PRE PJSM with rig personnel. Inspect and raise derrick. MU diverter line. 04:30 - 09:00 4.50 RIGU P PRE RU rig floor. Bridle down. RU diverter line. 09:00 - 12:00 3.00 RIGU P PRE Prepare location to spot rig. 12:00 - 14:00 2.00 RIGU P PRE Spot sub and pits over L-210i. MU all service lines RIG ACCEPTED @ 14:00 HRS 14:00 - 22:00 8.00 RIGU P PRE NU Diverter. Take on water and build spud mud. 22:00 - 00:00 2.00 RIGU P PRE PU DP from pipe shed, Mu stands and stand back in derrick. 1/1/2004 00:00 - 02:30 2.50 RIGU P PRE Continue PU DP 02:30 - 04:00 1.50 RIGU P PRE PU HWDP, jars and collars 04:00 - 05:00 1.00 RIGU P PRE Function test knife valve and diverter system. Witness of diverter test waived by Jeff Jones with AOGCC. 05:00 - 05:30 0.50 RIGU P PRE Pre-spud meeting with Anadril, Gyrodata, Sperry, MI and all rig personnel. 05:30 - 06:00 0.50 RIGU P PRE Fill hole and pressure test lines and circulating system to 3500 psi. 06:00 - 07:30 1.50 RIGU P PRE PU BHA #1, orient MWD and UBHO 07:30 - 08:00 0.50 RIGU P PRE PJSM with Sperry, GyroData and all rig personnel. RU wireline unit for gyro surveys. 08:00 - 11 :00 3.00 DRILL P SURF Drill 12-1/4" surface hole from 108' to 439'. Kick off well at 200' sliding 1 00% to build angle. WOB = 20-30klbs RPM = 50 Torque off Btm = 5.5k FtLb, Torque on Btm = 2.5k FtLb GPM = 550 @ 810 psi on Btm, 680 psi off Btm P/U 54k S/O 54k ROT 54k SPUD @ 08:00 hrs. 11:00-11:30 0.50 DRILL P SURF Ciculate the hole clean and POH 3 stands of HWDP. MU saver sub and jars. Printed: 1/19/2004 9:47:35 AM . . BP EXPLORATION Operations Summary Report Page 2 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/25/2003 Rig Release: 1/17/2004 Rig Number: Spud Date: 1/1/2004 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2004 11 :30 - 12:00 0.50 DRILL P SURF RIH and tag bottom at 439' 12:00 - 13:30 1.50 DRILL P SURF Drill 12-1/4" surface hole from 439' to 629'. Sliding 100% to build angle. WOB = 20-30klbs RPM = 80 Torque off Btm = 5.5k FtLb, Torque on Btm = 2.5k FtLb GPM = 665 @ 1888 psi on Btm, 1725 psi off Btm P/U 77k S/O 59k ROT 69k 13:30 - 14:00 0.50 DRILL P SURF CBU , 665 gpm, 845 psi 14:00 - 14:30 0.50 DRILL P SURF Run Gyro survey. RD Sperry wireline unit 14:30 - 22:30 8.00 DRILL P SURF Drill 12-1/4" surface hole from 629' to 1559'. Sliding 100%to build angle, inclination @ 1559' = 40 degrees. WOB = 25-30klbs RPM = 80 Torque off Btm = 5.5k FtLb, Torque on Btm = 2.7k FtLb GPM = 665 @ 1879 psi on Btm, 1725 psi off Btm P/U 77k S/O 59k ROT 69k P/U 82k S/O 69k No Pumps ART = 8.97 Hrs AST = 0.88 Hrs. Drilling Time last 24 Hrs= 9.85 hrs 22:30 - 23:30 1.00 DRILL P SURF Circulate weighted sweep surface to surface. 665 gpm, 1880 psi, reciprocating DP at 80 rpm. 23:30 - 00:00 0.50 DRILL P SURF Monitor well - static, blow down top drive. POH to pick up a new 12-1/4" Hughes MX-C1 bit P/U 77k S/O 59k ROT 69k P/U 82k S/O 69k No Pumps 1/2/2004 00:00 - 00:30 0.50 DRILL P SURF Continue POH to pick up new bit 00:30 - 01 :30 1.00 DRILL P SURF Stand back HWDP and Collars 01 :30 - 02:00 0.50 DRILL P SURF Clean and clear rig floor 02:00 - 02:30 0.50 DRILL P SURF Service top drive and blocks 02:30 - 03:30 1.00 DRILL P SURF Pick up new 12-1/4" Hughes MX-C1. MU BHA#2 03:30 - 04:00 0.50 DRILL P SURF RIH, work through intermittent tight spots. Break circulation, stage up pumps and wash last stand to bottom at 1559' 04:00 - 13:00 9.00 DRILL P SURF Drill 12-1/4" surface hole from 1559' to 3105'. Sliding as required to build inclination to 67 degrees. WOB = 25-30klbs RPM = 80 Torque off Btm = 3.5k FtLb, Torque on Btm = 8.1 k FtLb GPM = 688 @ 2933 psi on Btm, 3120 psi off Btm P/U 89k S/O 66k ROT 77k 13:00 - 15:00 2.00 DRILL P SURF Circulate and condition mud. Heavy clay returns had to decrease rate to keep the flow line and possum belly from packing off and to keep from running mud over the shakers 15:00 - 22:30 7.50 DRILL P SURF Drill 12-1/4" surface hole from 3105' to 4382'. Sliding 1as required to maintain inclination at 67 degrees. WOB = 25-30klbs Printed: 1/19/2004 9:47:35 AM ,.,-' - BP EXPLORATION Operations Summary Report Page 3 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/25/2003 Rig Release: 1/17/2004 Rig Number: Spud Date: 1/1/2004 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations "_"__ ·...._._._v_._. 1/2/2004 15:00 - 22:30 7.50 DRILL P SURF RPM = 80 Torque off Btm = 6.3k FtLb, Torque on Btm = 8.3k FtLb GPM = 645 @ 3120 psi on Btm, 2966 psi off Btm P/U 103k S/O 62k ROT 80k Top of the SV1 Sand is at 4167' MD ART = 6.73 Hrs AST = 4.27 Hrs. Drilling Time last 24 Hrs= 11.00 hrs 22:30 - 00:00 1.50 DRILL P SURF Circulate and condition hole. Pump sweep around at 675 gpm, 3100 psi while reciprocating DP 10' at 100 rpm 1/3/2004 00:00 - 01 :00 1.00 DRILL P SURF Continue circulating the sweep out of the hole. After the sweep was out of the hole and the returns started cleaning up started slowly backreaming out until 2.5 X BU volume had been circulated. 01 :00 - 01 :30 0.50 DRILL P SURF Attempted to POH without pumps, hole swabbing and pulling tight. 01 :30 - 05:30 4.00 DRILL P SURF MU top drive and continue backreaming out. 665 gpm @ 3100 psi and 100 rpm, P/U 95k S/O 57k ROT 70k 05:30 - 07:00 1.50 DRILL P SURF POH, pumping out at 350 gpm without rotating from base of permafrost to 1200'. 07:00 - 07:30 0.50 DRILL P SURF POH without pumps from 1200' to the top of the HWDP at 900' 07:30 - 09:30 2.00 DRILL P SURF RIH to 4270', fill DP halfway. No problems on TIH, hole looked good. 09:30 - 12:00 2.50 DRILL P SURF Stage pumps to 650 gpm @ 3410 psi. Wash last stand to bottom at 4382'. Circulate and condition hole at 100 rpm. P/U 105k S/O 64k ROT 84k 12:00 - 14:30 2.50 DRILL P SURF POH from 4382', stand back DP and HWDP. 14:30 - 16:30 2.00 DRILL P SURF Stand back jars & collars, LD BHA #2 16:30 -17:00 0.50 DRILL P SURF Clean and clear rig floor. 17:00 - 18:30 1.50 CASE P SURF MU fill-up tool. CO bails. RU 9-5/8" csg equipment. Make dummy run with hanger and landing joint. 18:30 - 19:00 0.50 CASE P SURF PJSM with Nabors Casing, MI and all rig personnel on running 9-5/8" surface csg. 19:00 - 00:00 5.00 CASE P SURF PU shoe track, fill and check floats. Run 105 joints, 4311' of 9-5/8", 40#, L-80, BTC surface casing filling each joint and circulating every 20th joint down. 1/4/2004 00:00 - 02:30 2.50 CASE P SURF Continue running 105 joints, 4311' of 9-5/8", 40#, L-80, BTC surface casing filling each joint and circulating every 20th joint down. 02:30 - 02:45 0.25 CASE P SURF MU landing joint. RD fill-up tool and csg equipment. 02:45 - 03: 15 0.50 CEMT P SURF Land csg at 4368'. RU cement head and cement lines. 03:15 - 05:00 1.75 CEMT p' SURF Break circulation and stage pumps to 420 gpm @ 600 psi. Reciprocated OK. 05:00 - 05:30 0.50 CEMT P SURF PJSM w/ all personnel. 05:30 - 06:00 0.50 CEMT P SURF Air up and prime up cemeters. Pump 5 bb110.6 ppg mud push to clear lines and pressure test cement lines to 3500 psi. Continue pumping 75 bbls 10.6 ppg mud push. 06:00 - 07:00 1.00 CEMT P SURF Drop bottom plug and pump 490 bbls (643 sxs) 10.7 ppg lead cement, followed by 79.5 bbls (382 sxs) 15.8 ppg tail cement. Printed: 1/19/2004 9:47:35 AM .., ,A BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES ; Date From - To Hours ¡ Task ¡Code NPT Phase ; ---- --. ..... ..- ...--- 1/4/2004 06:00 - 07:00 1.00 CEMT P SURF 07:00 - 08:30 1.50 CEMT P SURF 08:30 - 10:30 2.00 CEMT P SURF 10:30 - 14:30 4.00 DIVRTR P SURF 14:30 - 18:00 3.50 WHSUR P SURF 18:00 - 19:00 1.00 CASE P SURF 19:00 - 21:30 2.50 BOPSURP SURF 21 :30 - 00:00 2.50 BOPSUR P SURF 1/5/2004 00:00 - 02:00 2.00 BOPSURP SURF 02:00 - 02:30 0.50 BOPSURP SURF 02:30 - 05:30 3.00 DRILL P PROD1 05:30 - 08:30 3.00 DRILL N SFAL PROD1 08:30 - 12:00 3.50 DRILL P PROD1 12:00 - 14:30 2.50 DRILL N SFAL PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 16:30 1.50 DRILL P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 19:00 2.00 DRILL P PROD1 19:00 - 20:30 1.50 CASE P SURF 20:30 - 21 :30 1.00 DRILL P PROD1 21 :30 - 00:00 2.50 DRILL P PROD1 1/6/2004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01 :00 0.50 DRILL P PROD1 01 :00 - 01 :30 0.50 DRILL P PROD1 Page 4 of 13 Start: Rig Release: Rig Number: Spud Date: 1/1/2004 End: 1/17/2004 12/25/2003 1/17/2004 Description of Operations Spacer returns 30 bbls into the tail cement. Drop top plug and kick out with 10 bbls water to flush cement lines. Switch to rig pumps and displace with mud at 10 bpm. Bump plugs on calculated strokes. FCP = 1030 psi, pressure up to 3500 psi and hold for 10 minutes. Bleed down pressure, floats holding Full returns throughout cement job. 80 bbls clean cement returns. CIP @ 08:00 hrs. RD cement head and flush and LD landing joint. RD casing equipment and CO bails. ND diverter line, riser and Hydril. MU speed head and tbg spool, test metal to metal seal to 1000 psi. NU BOPE. Rig down casing equipment and clear from rig floor. Cut and slip 1200' of drilling line. RU test equipment and test BOPE to 4000 psi high and 250 psi low. Test annular to 3500 psi. BOP test witnessed by Lou Grimaldi with AOGCC. continue test BOPE to 4000 psi high and 250 psi low. Test annular to 3500 psi. BOP test witnessed by Lou Grimaldi with AOGCC. RD test equipment. Install wear bushing PU 3000' of DP from pipe shed. Remove upper top drive valve to be rebuilt. Continue pickup DP from Pipe shed, 4100' total. POH standing back stands Replace upper top drive valve and test to 5000 psi PJSM with Anadrill and all rig personnel on PU BHA and loading RA source. MU BHA #3. Load source and orient MWD tools. Shallow test MWD. Close rams and pressure test TAM port collar to 1000 psi. RIH, picking up 51 jts of DP from pipe shed. Continue RIH with DP from derrick to 4200'. Fill lines circulate 1 DP volume. test surface csg to 3500 psi fro 30 minutes. Bleed down pressure and blow down lines. Hold D5 Well Kill drill. Circulate through the choke, check volume to fill gas buster. Allow crew members to operate the choke while bringing pumps up to rate. RIH and tag up on cement at 4266'. Drill cement from shoe track and rat hole to 4382'. Drill 20' new hole from 4382 to 4402 Displace well to new 9.3 ppg LSND ,mud Perform LOT. EMW = 13.3 ppg Surf press = 570 psi MW = 9.3 ppg TVD = 2725' Printed: 1/19/2004 9:47:35AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . BP EXPLORATION Operations Summary Rep'ort Page 5 of 13 L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/25/2003 Rig Release: 1/17/2004 Rig Number: Spud Date: 1/1/2004 End: 1/17/2004 Date From - To i Hours Task Code NPT Phase -.------ ---..-..........---..--. -.-.---"¥"--------- 1/6/2004 01 :30 - 02:00 02:00 - 00:00 1/7/2004 00:00 - 11 :30 11 :30 - 15:00 15:00 - 18:00 18:00 - 22:00 Description of Operations 0.50 DRILL P PROD1 Establish baseline ECD's at drilling parameters. 22.00 DRILL P RPM = 80 GPM = 585 ECD = 9.9 ppg PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 4,402' to 8,128' WOB Rotating 5,000# -15,000#, WOB Sliding 5,000# To 10,000#, RPM 80 To 100, Motor RPM 286, Torque Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 570 gpm, SPP Off Bottom 3,440 psi, On Bottom 3,600 psi. String Weight Up 114,000#, String Weight Down 74,000#, String Weight Rotating 92,000# - ART = 3.04 hrs. - AST = 5.96 hrs. Slide As Required To Maintain Inclination And Azimuth Circulate Hole Clean And Pump Sweeps As Needed To Control ECD 11.50 DRILL P Back Ream Every Stand At 585 GPM And 100 RPM, Reducing Flow Rate To 450 GPM On Down Stroke PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 8,128' to 10,040' WOB Rotating 10,000# - 20,000#, WOB Sliding 10,000# To 20,000#, RPM 80 To 100, Motor RPM 294, Torque Off Bottom 7,800 ft /Ibs - On Bottom 10,200 ft /Ibs, Pump Rate 588 gpm, SPP Off Bottom 3,750 psi, On Bottom 3,910 psi. String Weight Up 155,000#, String Weight Down 89,000#, String Weight Rotating 114,000# - ART = 3.55 hrs. - AST = 2.00 hrs. Slide As Required To Maintain Inclination And Azimuth Circulate Hole Clean And Pump Sweeps As Needed To Control ECD 3.50 DRILL P Back Ream Every Stand At 588 GPM And 100 RPM, Reducing Flow Rate To 450 GPM On Down Stroke PROD1 Circulate Sweep Around At 14.0 BPM With 3,820 Psi. While Rotating And Reciprocating Drill String - RPM 110, String Weight Up 161,000#, String Weight Down 91,000#, String Weight Rotating 119,000# - With Pump Off String Weight Up 169,000#, String Weight Down 94,000# 3.00 DRILL P Final ECD At 10.61 - Calculated At 10.31 PROD1 Monitor Well Bore (Static) - POH With Directional BHA NO.3 From 10,040' To 9,793' - Tight 20K Above Normal Upward Drag - RIH Connect Top Drive And Establish Circulation Stage Pumps Up To 13.9 BPM - Back Ream Slow Monitoring ECD From 9,799' To 9,421' - Pump Hi And Low Vis Sweeps Surface To Surface While Mad Pass Logging From 9,383' To 9,291' At 300 FPH, 80 RPM, 3,570 Psi. - Continue To Back Ream From 9,291' To 9,050' Above Ghost Reamer Depth At TD PROD1 POH With Directional BHA NO.3 From 9,050' - Work Thru Intermittent Tight Spots At 7,620' And 6,347' - POH To 5,150' Tight 20K Above Normal Upward Drag - Attempt To Work Thru 4.00 DRILL P Printed: 1/19/2004 9:47:35 AM ..., . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours I Task Code NPT , ! Start: Rig Release: Rig Number: Phase PROD1 No Good PROD1 RIH To 5,225' Connect Top Drive And Establish Circulation Stage Pumps Up To 13.9 BPM With 2,275 Psi. - Back Ream Slow Monitoring ECD From 5,225' To 9 5/8" Casing Shoe At 4,368' Circulate Sweep Around At 13.9 BPM With 2,275 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore Static - Pump Dry Job - Blow Down Top Drive POH With Directional BHA NO.3 From 4,293' To 944' Handle BHA NO.3 - Stand Back HWDP, And Drilling Jars - Held PJSM For Schlumberger Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Flush Out BHA With Fresh Water - Remove Hycalog PDC Bit And Lay Down Mud Motor - Clear Rig Floor Rig Up Casing Tools And Equipment For Cement Stinger Hold Pre-Job Safety Meeting For Picking Up Cement Stinger - Down Load MWD Tools In Pipe Shed - Load Pipe Shed With 3 1/2" Tubing Make Up Mixing Sub (Plug Catcher) And Pick Up 45 Joints Of 3 1/2" NSCT 9.2 lb. Tubing Torqued To 3,000 ftllbs - Install Cross Overs Rig Down Power Tongs - Tools And Equipment RIH With 3 1/2" NSCT 9.2 lb. Tubing On 4" Drill Pipe From 1,400' To 10,000' With No Problems Pick Up Single Of 4" DP With Safety Valve, Pup Joint, And Head Pin - Install Circulating Lines - Establish Circulation With Full Returns - Wash To Bottom At 10,040' - Reciprocate And Condition Mud For Cement Job At 11.7 BPM With 2,810 Psi. - String Weight Up 140,000#, String Weight Down 81,000#- Held PJSM With All Personal Regarding Cementing Operation - Batch Mix Cement (Plug No.1) PROD1 Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 3,500 Psi. (Test Good) - Pump 5 BBLS Water, 87 BBLS (421 Sacks) 15.8 PPG Class "G" Tail Cement At 7.3 BPM, Followed With 1.5 BBLS Water- Swap Over To Rig And Displace With 82 BBLS 9.3 PPG LSND Mud To Balance Plug - Cement In Place At 13:43 Hours - Rig Down Cementing Line And Equipment Cement Plug NO.1 Spotted From 10,040' To 9,153' PROD1 POH Slow Allowing Cement To Fall From 10,040' To 9,150' At 25 FPM PROD1 Drop Wiper Plug And Circulate With 9.3 PPG LSND Mud At 9.5 BPM With 1,600 Psi. - At Bottoms Up 30 SBLS Cement To Surface - Reciprocate And Condition Mud For Second Cement Balenced Plug - String Weight Up 156,000#, String Weight Down 66,000# - Held PJSM With All Personal Regarding Cementing Operation - Batch Mix Cement (Plug No.2) PROD1 Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 3,500 Psi. (Test Good) - Pump 5 BBLS Water, 87 BBLS (421 Sacks) 15.8 PPG Class "G" Tail Cement At 7.3 BPM, Followed With 1.5 BBLS Water- Swap Over To Rig And Displace With 74 BSLS 9.3 PPG LSND 1/7/2004 18:00 - 22:00 22:00 - 00:00 4.00 DRILL P 2.00 DRILL P 1/8/2004 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 02:00 1.00 DRILL P PROD1 02:00 - 04:00 2.00 DRILL P PROD1 04:00 - 04:30 0.50 CEMT P PROD1 04:30 - 05:30 1.00 CEMT P PROD1 05:30 - 07:00 1.50 CEMT P PROD1 07:00 - 07:30 0.50 CEMT P PROD1 07:30 - 11 :00 3.50 CEMT P PROD1 11 :00 - 13:00 2.00 CEMT P PROD1 13:00 - 14:00 1.00 CEMT P 14:00 - 15:00 1.00 CEMT P 15:00 - 19:30 4.50 CEMT P 19:30 - 20:15 0.75 CEMT P Page 6 of 13 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Description of Operations _____.___ ---.-.---. ----.---- ----..-..---...---............-.... "P- ... ._"_ _.._._._ . ______ Printed: 1/19/2004 9:47:35 AM .. .. Page 7 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To L-210 L-210 DRILL +COMPLETE Start: 12/25/2003 NABORS ALASKA DRILLING I Rig Release: 1/17/2004 NABORS 9ES Rig Number: Hours I Task! Code NPT: Phase , __...._,., , ....______'.._m'..._'_.......1.. ..__ __.._m__._'_______ _ . _____ _ ...._ ___ .. ____ ______.... ___, 1/8/2004 0.75 CEMT P PROD1 Mud To Balance Plug - Cement In Place At 20:08 Hours - Rig Down Cementing Line And Equipment Cement Plug No.2 Spotted From 9,150' To 8,250' PROD1 POH Slow Allowing Cement To Fall From 9,150' To 7,900' At 20 FPM PROD1 Drop Wiper Plug And Circulate With 9.3 PPG LSND Mud At 10.0 BPM With 1,570 Psi. .. 164 BBLS Contaminated Mud Back To Surface Prior To Bottoms Up .. Reciprocate And Condition Mud - String Weight Up 137,000#, String Weight Down 67,000# Circulate Reciprocate And Condition Mud At 10.0 BPM With 1,350 Psi.String Weight Up 137,000#, String Weight Down 67,000# Monitor Well Bore (Static) - Pump Dry Job And Blow Down Top Drive POH With 3 1/2" NSCT 9.2 lb. Tubing (Cementing Stinger) On 4" Drill Pipe From 7,900' To 1,400' With No Problems Rig Up Casing Tools And Equipment For Cement Stinger Lay Down Cross Overs, 45 Joints Of 31/2" NSCT 9.2 lb. Tubing, And Mixing Sub (Plug Catcher) From 1,400' Rig Down Casing Tools And Equipment - Clear Rig Floor Slip And Cut 80 Feet Of 1 1/4" Drilling Line - Set And Function Crown Saver Service Top Drive, Traveling Blocks, And Crown Sheaves Pull Wear Bushing And Flush Stack With Ported Sub Hold Pre-Job Safety Meeting - Install Test Plug - Rig Up Testing Equipment.. Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular At 250 Psi. Low And 3,500 Psi. High, Test Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower Valves At 250 Psi. Low And 4,000 Psi. High - Perform Accumulator Test PROD1 Pull Test Plug - Install Wear Bushing And Energize LDS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor PROD1 Make Up BHA No.4 And RIH To 944' - Pick Up Schlumberger Motor, Make Up 8 3/4" Hycalog DS70 PDC Bit, Pick Up Float Sub, Stabilizer. And MWD / LWD Tools - Orient And Initialize MWD/LWD Tools - Hold PJSM And Install Nuke Sources Lower Below Rig Floor - RIH Out Of Mast With Drill Collars, Daily Drilling Jars, And 4" HWDP - Surface Test Schlumberger Equipment (Test Good) - Blow Down Top Drive RIH With Directional Drilling Assembly BHA No.4 From 944' To 4,368' Circulate Bottoms Up While Rotating And Reciprocating .. Stage Pump Rate Up To 9.5 BPM With 1,600 Psi. - String Weight Up 120,000#, String Weight Down 60,000# RIH With Directional Drilling Assembly BHA No.4 From 4,368' To 5,400' - Establish Circulation Pump 1,000 Strokes - RIH From 5,400' To 6,250' Taking Weight Attempt To Work Thru Area With No Luck - Connect Top Drive Wash And Ream At Reduced Pump And Rotary Rate From 6,250' To 6,430' - RIH 19:30 - 20:15 20:15 - 21:45 1.50 CEMT P 21 :45 - 00:00 2.25 CEMT P 1/9/2004 00:00 - 01 :30 1.50 CEMT P PROD1 01 :30.. 02:00 0.50 CEMT P PROD1 02:00 - 05:30 3.50 CEMT P PROD1 05:30 - 06:00 0.50 CEMT P PROD1 06:00 - 08:00 2.00 CEMT P PROD1 08:00 - 09:00 1.00 CEMT P PROD1 09:00 - 10:00 1.00 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30.. 11 :00 0.50 BOPSURP PROD1 11 :00 - 14:30 3.50 BOPSURP PROD1 14:30 - 15:00 0.50 BOPSUR P 15:00 - 17:30 2.50 DRILL P 17:30 .. 19:30 2.00 DRILL P PROD1 19:30 - 21:30 2.00 DRILL P PROD1 21 :30 - 00:00 2.50 DRILL P PROD1 Spud Date: 1/1/2004 End: 1/17/2004 Description of Operations .. .. ....... ..._~ .__.__"_n _. ._ _.·........_..···.w.___· Printed: 1/19/2004 9:47:35 AM ... . BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations 1/9/2004 21 :30 - 00:00 2.50 DRILL P PROD1 From 6,430' To 6,846' Taking Weight Connect Top Drive And Work Thru Area - RIH From 6,846' To 7,048' Taking Weight Connect Top Drive And Attempt To Work Thru Area With No Luck - Orient Tool Face To High Side And Attempt To Work Thru With No Luck - Final Depth Achieved At 7,054' 1/1 0/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate Bottoms Up While Rotating And Reciprocating - Stage Pump Rate Up To 11.9 BPM With 2,575 Psi. - RPM 80 To 100, Motor RPM 250, Torque Off Bottom 10,000 ft /Ibs String Weight Up 175,000#, String Weight Down 60,000#, String Weight Rotating 92,000# 'NOTE' Cement Stringers And High PH At Bottoms Up - Witnessed By AOGCC Inspector Jeff Jones - Consult With Anchorage Operations Drilling Engineer Tom Schaefer Regarding Hole Problems And Depth Reached. 01 :00 - 02:00 1.00 DRILL P PROD1 Monitor Well Static - POH From 7,054' To 6,200' 02:00 - 04:00 2.00 DRILL P PROD1 Held PJSM With Truck Drivers, Drilling Crews, And Service Personal Regarding Mud Displacement - Pumped 30 Barrel Hi-Vis Spacer Followed Up With 9.3 PPG LSND Mud At 10 BPM With 1,550 Psi. - Recorded New ECD Base Line At 10.10 PPG And Slow Pump Rates w/ New Mud System 04:00 - 04:30 0.50 STKOH P PROD1 Pick Up Directional BHA To 6,110' Orient To Low Side Of Well Bore - Time Drill And Trench Open Hole Side Track At 6,110' To 6,130' - 585 GPM With 2,400 Psi. 04:30 - 07:30 3.00 DRILL P PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 6,130' To 6,446' WOB Rotating 5,000# - 15,000#, WOB Sliding 5,000# To 15,000#, RPM 100, Motor RPM 275, Torque Off Bottom 5,000 ft /Ibs - On Bottom 6,000 ft /Ibs, Pump Rate 550 gpm, SPP Off Bottom 2,200 psi, On Bottom 2,400 psi. String Weight Up 122,000#, String Weight Down 79,000#, String Weight Rotating 94,000# - ART = .21 hrs. - AST = 1.37 hrs. Slide As Required To Maintain Inclination And Azimuth Circulate Hole Clean And Pump Sweeps As Needed To Control ECD Back Ream Every Stand At 550 GPM And 100 RPM, Reducing Flow Rate To 415 GPM On Down Stroke 07:30 - 08:30 1.00 DRILL N FLUD PROD1 Circulate At Reduced Rate While Changing Shaker Screens - 250 GPM With 600 Psi. 08:30 - 09:00 0.50 DRILL P PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 6,446' To 6,534' 09:00 - 12:00 3.00 DRILL N FLUD PROD1 Circulate At Reduced Rate While Changing Shaker Screens - Screen Blinding Due To Cement Contaimination - Condition Mud With Soda Ash At 200 GPM With 430 Psi. 12:00 - 00:00 12.00 DRILL P PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 6,534' To 8,625' WOB Rotating 5,000# - 20,000#, WOB Sliding 5,000# To 20,000#, RPM 80 To 100, Motor RPM 294, Torque Off Bottom 7,600 ft /Ibs - On Bottom 10,000 ft /Ibs, Pump Rate 588 gpm, SPP Off Bottom 3,488 psi, On Bottom 3,710 psi. String Weight Up 142,000#, String Weight Down 80,000#, String Weight Rotating 103,000# - ART = 2.9 hrs. - Printed: 1/19/2004 9:47:35 AM ..... . BP EXPLORATION :Operations Summary Report Legal Well Name: L-210 Common Well Name: L-210 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date I From - To Hours Task Code NPT I 1/10/2004 1/11/2004 Start: Rig Release: Rig Number: Phase 12:00 - 00:00 12.00 DRILL P PROD1 AST = 3.1 hrs. ---.--. -----. Page 9 of 13 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Description of Operations Slide As Required To Maintain Inclination And Azimuth Circulate Hole Clean And Pump Sweeps As Needed To Control ECD Back Ream Every Stand At 550 GPM And 100 RPM, Reducing Flow Rate To 415 GPM On Down Stroke PROD1 Drilled 8 3/4" Directional Hole By Rotating And Sliding From 8,625' To 9,668' WOB Rotating 10,000# - 20,000#, WOB Sliding 10,000# To 20,000#, RPM 100, Motor RPM 294, Torque Off Bottom 7,800 ft /Ibs - On Bottom 10,000 ft /Ibs, Pump Rate 588 gpm, SPP Off Bottom 3,800 psi, On Bottom 4,040 psi. String Weight Up 152,000#, String Weight Down 82,000#, String Weight Rotating 113,000# - ART = 3.65 hrs. - AST = 1.04 hrs. 00:00 - 08:00 8.00 DRILL P Slide As Required To Maintain Inclination And Azimuth Circulate Hole Clean And Pump Sweeps As Needed To Control ECD 08:00 - 10:30 2.50 DRILL P Back Ream Every Stand At 550 GPM And 100 RPM, Reducing Flow Rate To 415 GPM On Down Stroke PROD1 Pump Hi-Vis Sweep Around - Clean Hole 3 X Bottoms Up - Rotate And Reciprocate Drill String - 588 GPM With 3,860 Psi. At RPM 110 Calculated ECD = 10.40 - Actual ECD 10.82 PROD1 Monitor Well Bore (Static) - POH For Wiper Trip From 9,668' To 9,530' - Upward Drag Increased 25K To 30K From 9,530' To 9,400' - RIH From 9,400' To 9,668' - Back Ream At Drilling Rate From 9,668' To 8,700' POH With Out Pumping From 8,700' To 8,200' - Monitor Well Static - Pump Dry Job - Blow Down Top Drive - POH From 8,200' To 4,300' Service Top Drive, Traveling Blocks, Crown Sheaves, And Draworks RIH With Directional BHA No.4 From 4,300' To 6,050' - Connect Top Drive And Establish Circulation - Stage Up Pump Rate - Orient To Low Side - Blow Down Top Drive - RIH From 6,050' To 7,410' Taking Weight Attempt To Work Thru Area (No Good) Work Thru Area At 7,410' - Wash And Ream At Reduced Pump Rate 146 GPM And 60 RPM To 7,435' - Circulate Hole Clean While Backreaming At 560 GPM With 2,720 Psi. RIH From 7,435' To 9,575' With No Problems - As Precaution Wash Last Stand To Bottom From 9,575' To 9,668' Pump Hi-Vis Sweep Around - Clean Hole 2.5 X Bottoms Up - Rotate And Reciprocate Drill String - 560 GPM With 3,800 Psi. - RPM 100 With 8,000 ftllbs Torque - String Weight Up 152,000#, String Weight Down 82,000#, String Weight Rotating 113,000# 10:30 - 13:00 2.50 DRILL P 13:00 - 15:30 2.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 22:00 2.50 DRILL P PROD1 Printed: 1/19/2004 9:47:35 AM ... - BP EXPLORATION Operations Summary Report Page 10 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations -----------..--..------ .----....--.. .-.. -...-" -....--- -...-. - ..-- _.__...._--_....._.._._......~-_.._-~. --- 1/11/2004 19:30 - 22:00 2.50 DRILL P PROD1 Calculated ECD = 10.36 - Actual ECD 10.47 Pump "G" Seal 310 Barrels And Spot - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 22:00 - 00:00 2.00 DRILL P PROD1 POH With Directional BHA NO.4 From 9,668' To 7,126' With No Problems 1/12/2004 00:00 - 02:00 2.00 DRILL P PROD1 POH With Directional BHA No.4 From 7,126' To 944' 02:00 - 04:30 2.50 DRILL P PROD1 Handle BHA No.4 - Lay Down 1 Joint 4" HWDP, And Ghost Reamer - Stand Back (21 Joints) 4" HWDP - Lay Down Cross Over, (2 Joints) 5" HWDP, Drilling Jars, Saver Sub, And NM Drill Collar - Held PJSM For Anadrill Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Flush Out BHA With Fresh Water And Blow Down Surface Equipment - Lay Down NM Drill Collar, MWD/LWD Tools, String Stabilizer, And Float Sub - Remove Hycalog 8 3/4" DS70 PDC Bit And Lay Down Mud Motor 04:30 - 05:00 0.50 DRILL P PROD1 Clear Rig Floor Of 8 3/4' Drilling Tools And Equipment 05:00 - 06:00 1.00 BOPSURP COMP Pull Wear Bushing And Flush Stack With Ported Sub - Blow Down Top Drive - Drain BOP Stack And Install Test Plug 06:00 - 07:30 1.50 BOPSUR P COMP Change Out 31/2" By 6" Variable Pipe Rams In Top BOP Gate To 7" Casing Rams - Rig Up Testing Equipment - Test 7" Door Seals To 250 Psi. Low And 3,500 Psi. High (Good Test) - Rig Down Testing Equipment And Pull Test Plug 07:30 - 08:00 0.50 CASE P COMP Pick Up Fluted Hanger And 7" Landing Joint - Make Dummy Run - Change Out Bails To Long Set 08:00 - 09:00 1.00 CASE P COMP Rig Up Franks Fill Up Tool, Power Tongs, And Casing Equipment 09:00 - 17:30 8.50 CASE P COMP Hold Pre-Job Safety Meeting With All Personal Regarding Casing Running Operation - Pick Up And RIH With 7" Shoe Track - Baker Lock Connections To Float Collar Joint NO.3 - Verify Floats Holding - RIH With 100 Joints Of 7" BTC-M 26 lb. L-80 Casing To 4,287' At 30 Seconds Per Joint Slip To Slip - Fill Every Joint And Break Circulation Every 10 Joints - Make Up To Mark Torqued To 7,200 ftIlbs. Using Best-O-Life Thread Compound 17:30 - 18:00 0.50 CASE P COMP Circulate Bottoms Up At 4,287' - Stage Pump Rate Up To 7 BPM With 410 Psi. - String Weight Up 112,000#, String Weight Down 86,000# 18:00 - 00:00 6.00 CASE P COMP RIH With 188 Joints Of 7" BTC-M 26 lb. L-80 Casing From 4,287' To 8,022' At 60 Seconds Per Joint Slip To Slip - Fill Every Joint And Break Circulation And Circulate 10 Minutes Every 15 Joints 1/13/2004 00:00 - 03:45 3.75 CASE P COMP RIH With 227 Joints Of 7" BTC-M 26 lb. L-80 Casing From 8,022' To 9,628' At 60 Seconds Per Joint Slip To Slip - Fill Every Joint And Break Circulation And Circulate 10 Minutes Every 15 Joints - Pick Up Fluted Hanger And Landing Joint- Land 7" Casing At 9,656' 03:45 - 04:15 0.50 CASE P COMP Rig Down Franks Fill Up Tool - Make Up Cementing Head And Circulating Lines 04:15 - 07:30 3.25 CASE P COMP Reciprocate 7" Casing - Establish Circulation At 3 BPM With 441 Psi. Stage Pump Rate Up To 7 BPM With 875 Psi. With Full Returns - Reciprocate casing. Circ 3 X B/U, String Weight Up 175,000#, String Weight Down 95,000# Printed: 1/19/2004 9:47:35 AM ~ . BP EXPLORATION Operations Summary Report Page 11 of 13 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: l-210 l-210 DRill +COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: Rig Release: Rig Number: 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Date From - To ! Hours Task Code NPT Phase Description of Operations I 1/13/2004 07:30 - 10:00 2.50 CEMT P COMP Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,000 Psi. (Test Good) - Pump 20 BBLS CW 100, Followed With 35 BBLS 10.3 PPG Mud Push - Release Bottom Plug - Mix And Pump 100 BBLS (455 Sacks) 15.8 PPG Class "G" Tail Cement At 6.0 BPM - Wash Up Lines To Floor Thru Tee - Drop Top Plug And Displace With 8.6 PPG Sea Water At 7 BPM. Slow Rate To 3.0 BPM With Final Circulating Pressure At 690 Psi. - Bump Plug With A Total Of 365.8 BBLS Pumped Increase Pressure To 3,500 Psi. - Bleed Off Pressure And Check Floats (Floats Held) - Reciprocated Casing Throughout Job. Cement In Place At 09:40 Hours On 01/13/2004. Float Shoe at 9656', Float Collar at 9568' 10:00 - 11 :00 1.00 CEMT P COMP Blow Down All Lines, RID Cement Head, UD Landing Jt, RID Cement Equipment 11 :00 - 12:00 1.00 WHSUR P COMP Install 7' x 9 5/8" Pack-off, RILDS, torque to 450 ftlbs And Test to 5000 PSI For 10 Minutes, OK. 12:00 - 12:30 0.50 CASE P COMP Change Out Bail's 12:30 - 14:00 1.50 BOPSURP COMP Install Test Plug, Change Upper Rams to 31/2" x 6" VBRs, Test To 3500 PSI 14:00 - 15:00 1.00 CLEAN P COMP P/U, RIH w/ BHA - 6 1/8" Bit, FS, 7" Scraper, X-O, 4 stands Of 4" HWDP, Jars, 3 stands of 4" HWDP 15:00 - 18:00 3.00 CLEAN P COMP RIH w/4" DP to 9517', Filling Pipe Every 30 stands 18:00 - 19:00 1.00 CLEAN P COMP Wash down f/9517' to 9568' @ 3 bpm, tagged float collar, displace well to a 9.3 ppg brine at 10 bpm w/2800 psi, reciprocate drillstring 19:00 - 20:30 1.50 CLEAN P COMP Cut and slip drlg line, service TD 20:30 - 00:00 3.50 CLEAN P COMP POH, LD DP to 5500' Inject 125 bbls of 9.3 ppg mud down 7" x 9 5/8" annulus, break over at 1 bpm 650 psi, final 3 bpm 550 psi 1/14/2004 00:00 - 03:30 3.50 CLEAN P COMP POH to BHA. LD DP. 03:30 - 04:30 1.00 CLEAN P COMP POH. LD BHA. 04:30 - 05:00 0.50 CASE P COMP Cleared and clean floor 05:00 - 06:30 1.50 BOPSUR P COMP Pull wear ring, Install test plug. Changing out top rams to 7", test door seals to 3500 psi, pulled test plug, installed wear ring 06:30 - 08:30 2.00 EVAL P COMP PJSM w/ Schl. wireline service, RlU E-line, install and test lubricator to 1 000 psi 08:30 - 14:00 5.50 EVAL P COMP RIH w/ USIT Logging Tools to 9510', Log up to 5840', top of cement, POH, UD logging tools 14:00 - 15:00 1.00 CASE P COMP Test 7" casing to 4000 psi for 30 minutes 15:00 - 18:30 3.50 PERF P COMP PJSM on RlU and Perforating, MU, RIH, Perforated w/30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 9084' - 9054' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, all shots fired, no loss to well. 18:30 - 21 :30 3.00 PERF P COMP M/U Perf Run #2 - RIH, Perforated w/ 30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 9019' - 8989' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, all shots fired, no loss to well. GR tool quit working after guns fired. 21 :30 - 00:00 2.50 PERF P COMP C/O GR Tool, M/U Perf Run #3 - RIH, Perforated w/ 30' of 4.5" Printed: 1/19/2004 9:47:35 AM .... . Page 12 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-210 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I I I From - To I Hours Task I Code NPT! Phase ___~ ___.__u__ 1/14/2004 21 :30 - 00:00 2.50 PERF P COMP 1/15/2004 00:00 - 03:00 3.00 PERF P COMP 03:00 - 07:00 4.00 PERF P COMP 07:00 - 13:30 6.50 PERF N DFAL COMP 13:30 - 15:30 2.00 PERF P COMP 15:30 - 17:30 2.00 PERF P COMP 17:30 - 20:00 2.50 PERF P COMP 20:00 - 22:00 2.00 PERF P COMP 22:00 - 00:00 2.00 PERF P COMP 1/16/2004 00:00 - 01 :00 1.00 PERF P COMP 01 :00 - 02:00 1.00 BOPSURP COMP 02:00 - 02:30 0,50 RUNCOMP COMP 02:30 - 03:30 1.00 RUNCOMP COMP 03:30 - 04:00 0.50 RUNCOMP COMP 04:00 - 04:30 0.50 RUNCOMP COMP 04:30 - 06:30 2.00 RUNCOMP COMP 06:30 - 07:30 1.00 RUNCOMN SFAL COMP .... Start: Rig Release: Rig Number: Spud Date: 1/1/2004 End: 1/17/2004 12/25/2003 1/17/2004 Description of Operations perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 8989' - 8959' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, all shots fired, no loss to well. M/U Perf Run #4 - RIH, Perforated w/ 30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 8894' - 8864' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, all shots fired, Lost 7 bbls to well. M/U Perf Run #5 - RIH, Perforated w/ 30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 8864' - 8834' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, Loss rate at 2 bph. Guns fired on third attempt. Little Red Hot Oil Services RIU on 9 5/8" X 7" annulus, Tested Lines to 3000 psi. Freeze protected well with 70 bbls of 90 degree crude at 3 bpm, 800 psi. Change out firing head, M/U Perf gun Assy #6 w/ 30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 8834' - 8804' based on USIT/GR log, dated 01/14/2004. Attempt to fire guns several times, guns did not fire. POH, LD live guns and GR tool, changed out cable head M/U Perf Run #6RR - RIH, Perforated w/ 30' of 4.5" perf guns, 5 spf, 72 degree phasing, correlate and spot guns across perf interval from 8834' - 8804' based on USIT/GR log, dated 01/14/2004. Monitor well, stable, POH, Loss rate at 3 bph. Change cable head, M/U 6.05" GRlJB, RIH to 9200', POH, retrieve 1 gal of perf debris consisting of iron and spent shot RIH w/6.05" GRlJB to 9450', POH, retrieve 3/4 gal of perf debris consisting of iron and spent shot RIH w/6.05" GRlJB to 9450', POH, retrieve 2 - 16 ounce cups of perf debris consisting of iron and spent shot RIH w/6.05" GRlJB to 9450', POH, retrieve 1 - 4 ounce cup of perf debris consisting of spent shot LD GRlJB, RD E-line, clear and clean floor Pull wear ring, install test plug, c/o and test top rams to 3 1/2" x 6" VBR's, test bonnet seals to 3500 psi, pull test plug Make dummy run with tbg hgr, change over to long bails RIU tbg and perf gun handling equipment PJSM, running tbg conveyed guns on 3 1/2" X 4 1/2" completion string M/U 90' of 4.5" Power Jet Perf Gun, 5 SPF, 72 degree phasing w/ automatic release SXAR and ported sub and TCF firing head and 90' of Blank Guns spaced through out C/O handling tools, P/U, Run 3.5" 9.3 # L-80 TC-11 tbg, torque turn to 2300 ftlbs, bakerlok the lower packer assy tail pipe. Install centraliser with RA pip under the #3 GLM & secure to tubing with set screws. 3.5" elevators not biting properly on pipe. Wait on replacement set to be brought out from Deadhorse yard. Perform handrail inspection around rig while waiting - no deficiencies or unsafe Printed: 1/19/2004 9:47:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 13 of 13 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Phase I I L-21 0 L-210 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES , Date From - To ! Hours Task Code NPT 1/16/2004 06:30 - 07:30 07:30 - 08:30 08:30 - 00:00 1/17/2004 00:00 - 00:30 00:30 - 01 :00 01 :00 - 04:00 1.00 RUNCOMN 1.00 RUNCOMP SFAL COMP COMP 15.50 RUNCOMP COMP 0.50 RUNCOMP COMP 0.50 RUNCOMP 3.00 RUNCOMP COMP COMP 04:00 - 04:30 0.50 RUNCOMP COMP 04:30 - 05:30 1.00 RUNCOMP COMP 05:30 - 09:00 3.50 RUNCOMP COMP 09:00 - 12:00 12:00 - 15:30 14:30 - 18:30 18:30 - 21 :00 3.00 BOPSURP 3.50 WHSUR P COMP COMP 4.00 WHSUR P COMP 2.50 WHSUR P COMP 12/25/2003 1/17/2004 Spud Date: 1/1/2004 End: 1/17/2004 Description of Operations conditions found. Change to new elevators and continue running 3.5" tubing and jewelry. Change over to 4 1/2" tbg handling equipment, P/U RIH w/4 1/2" 12.6 L-80 TC11 tbg, MU torque 2800 ftlbs, Pipe dope was Jet Lube Seal Guard, Grant Prideco witnessed the running of the tbg. 7 joints had to be made up 2 or more times for proper M/U. Ran a total of 8 jts of 3 1/2" TC11 Tbg and 206 Jts of 4 1/2" TC11 Tbg. Hole taking 8 BPH. MU and Land Tbg Hgr. PU Tbg hgr 2' to be able to monitor and keep hole filled. When tbg hgr is landed Perf Guns are at 9279' to 9369', Bottom Packer S3 at 9162', Middle Premier Packer at 8921', Top Premier Packer at 8681', RA tag at 8891.4'. Loss at 1 bph RlU E-line, Held PJSM on Logging Operations RIH w/ GRlCCL tools, Tie-in the RA tag in 7" csg at 8738' w/ US IT Log 1/14/04, Correlate to the RA tag in the tbg string at 8889.5' + 2' (Tbg Hgr is PU 2') = 8891.5'. No space out adjustments needed. Perf Guns will be fired on Depth at 9279' to 9369'. POH, LD Logging tools, RD E-line. Stack off 2' landing tbg hgr, Run in lockdown studs on tubing spool. Rev. Circ clean corrosion inhibited 9.3 ppg brine down the annulus above the upper packer at 8681' Drop Ball w/1 1/2" Roller Rod Assy to RHC-M Plug in X Nipple at 9188', Pull Landing Jt, Pressure up down tbg to 2800 psi to set S-3 Packer at 9162', increase pressure to 4200 psi to set Premier Packers at 8921' and 8681', Hold for 30 minutes testing tbg. Bleed Pressure down to 1500 psi on tbg, pressure up on annulus to 4000 psi, Hold for 30 minutes. Bleed annulus and tbg down to 0 psi, Pressure up on annulus to 2400 psi, shearing DCK valve, Set TWC, test to 2800 psi. ND BOP stack Snake tree into cellar, thaw-out w/ steam, NU adapter flange and tree, test to 5000 psi, RU Lubricator, pull TWC PJSM, RU hot oil unit, test lines to 3500 psi, pump 159 bbls of diesel dn the annulus at 2.5 bpm, 1750 psi, U-tube to tbg, freeze protect tubing and IA to 4700' MD. Install VR plug in tubing spool outlet. Pump 20 additional bbls diesel freeze protect to OA. Install BPV, test from below to 1000 psi, RID hot oil unit, DSM, remove secondary annulus valve, Install VR Plug in other tbg spool outlet on off driller side. secured tree and cellar for rig move. Release rig at 21:00 Hrs on 01/17/2004 f/ L-210i Printed: 1/19/2004 9:47:35 AM . . L-21 0 Survey Report roer Report Date: 11·Jan·04 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 75.000" Field: Prudhoe Bay Un. . WOA Verttcal Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot L·PAD / L·210 TVD Reference Datum: KB Well: L·210 TVD Reference Elevation: 79.30 ft relative to MSL Borehole: L·210 Sea Bed I Ground level Elevation: 49.85 ft relative to MSL UWVAPI#: 500292318700 Magnetic Declination: 25.110" Survey Name I Date: L·210/ January 11, 2004 Total Field Strength: 57553.513 nT Tort / AHD / 001 / ERD ratio: 163.454" / 7711.99 ft / 6.387 / 1.544 Magnetic Dip: 80.819" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04. US Feet Declination Date: January 09, 2004 location Lat/Long: N 70 21 2.727, W 149 19 23.663 Magnetic Declination Model: BGGM 2003 Location Grid N1E YIX: N 5978328.650 ftUS, E 583354.280 ftUS North Reference: True North Grid Convergence Angle: +0.63735513" Total Carr Mag North -> True North: +25.110" Grid Scale Factor: 0.99990789 Local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical / Along Hole I NS EW I DLS I Buiki Rate l Walk Rate I Northin9 Easting Lat~ude Long~ude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/looft) (deg/looft) (deg/looft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 -79.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978328.65 583354.28 N 70 21 2.727 W 149 19 23.663 100.00 0.31 295.40 100.00 20.70 -0.21 0,27 0.12 -0.24 0.31 0.31 0.00 5978328.76 583354.03 N 7021 2.729 W 1491923.670 200.00 0.07 183.85 200.00 120.70 -0.43 0.54 0.17 -0.49 0.34 -0.24 -111.55 5978328.82 583353.79 N 7021 2.729 W 1491923.677 300.00 3.37 118.44 299.94 220.64 1.68 3.51 -1.29 2.09 3.34 3.30 -65.41 5978327.38 583356.38 N 70212.715 W 149 1923.602 400.00 5.98 112.64 399.60 320.30 7.94 11.66 -4.70 9.48 2.65 2.61 -5.80 5978324.06 583363.81 N 7021 2.681 W 149 1923.386 500.00 7.76 104.03 498.88 419.58 17.97 23.60 -8.34 20.84 2.05 1.78 -8.61 5978320.55 583375.21 N 7021 2.645 W 1491923.054 546,00 9.37 96.79 544.37 465.07 24.17 30.44 -9.53 27.57 4.21 3.50 -15.74 5978319.42 583381.95 N 70 21 2.634 W 149 1922.857 570.88 10.02 87.21 568.89 489.59 28.16 34.62 ·9.67 31.75 6.98 2.61 -38.50 5978319.34 583386.13 N 7021 2.632 W 149 1922.735 662.68 11.57 79.39 659.07 579.77 45.15 51.79 -7.58 48.77 2.32 1.69 -8.52 5978321.61 583403.13 N 70 21 2.653 W 149 1922.237 755.14 14.30 84.28 749.18 669.88 65.67 72.47 -4.74 69.25 3.18 2.95 5.29 5978324.68 583423.57 N 70 21 2.681 W 1491921.639 847.29 16.73 80.61 837.97 758.67 90.10 97.11 -1.44 93.67 2.84 2.64 -3.98 5978328.25 583447.95 N 7021 2.713 W 149 1920.925 940.15 20.21 78.99 926.03 846.73 119.41 126.52 3.81 122.61 3.79 3.75 -1.74 5978333.82 583476.83 N 7021 2.765 W 1491920.080 1034.01 22.76 80.62 1013.36 934.06 153.66 160.89 9.86 156.44 2,79 2.72 1.74 5978340.25 583510.59 N 7021 2.824 W 149 19 19.091 1126.61 26,07 81.20 1097.67 1018.37 191.73 199.16 15.90 194.23 3.58 3.57 0.63 5978346.70 583548.30 N 7021 2.884 W 149 19 17.986 1219.91 29.57 80.88 1180.17 1100.87 235.02 242.70 22.68 237.23 3.75 3.75 -0.34 5978353.97 583591.22 N 7021 2.951 W 149 19 16.730 1313.11 31.87 79.67 1260.29 1180.99 282.43 290.30 30.74 284.15 2.56 2.47 -1.30 5978362.55 583638.05 N 7021 3.030 W 149 19 15.358 1407.33 36.02 79.21 1338.44 1259.14 334.87 342.90 40.39 335.86 4.41 4.40 ·0.49 5978372.77 583689.64 N70213.125 W 149 19 13.847 1498.35 40.94 78.02 1409.67 1330.37 391.38 399.52 51.60 391.36 5.47 5.41 -1.31 5978384.60 583745.00 N 7021 3.235 W 149 1912.225 1595.60 45.84 79.48 1480,32 1401.02 458.01 466.31 64.59 456.86 5.14 5.04 1.50 5978398.31 583810.35 N 7021 3.363 W 149 1910.311 1689.14 50.20 78.14 1542.87 1463.57 527.38 535.82 78.11 525.05 4.78 4.66 -1.43 5978412.59 583878.38 N 7021 3.495 W 149 198.318 1784.93 50.20 76.20 1604.19 1524.89 600.91 609.42 94.45 596.80 1.56 0.00 -2.03 5978429.72 583949.94 N 7021 3.656 W 149 196.221 1878.39 52.56 78.27 1662.52 1583.22 673,86 682.43 110.56 668,01 3.06 2.53 2.21 5978446.62 584020.96 N 70213.815 W 149 194.140 1972.29 54.98 79.98 1718.02 1638.72 749.40 758.16 124.83 742.39 2.97 2.58 1.82 5978461 .72 584095.16 N 7021 3.955 W 149 19 1.966 2066.09 57.37 81.39 1770.23 1690.93 826.93 836.08 137.43 819.28 2.84 2.55 1.50 5978475.17 584171.90 N 7021 4.079 W 149 18 59.719 2158.90 62.63 79.93 1816.62 1737.32 906.89 916.43 150.50 898.55 5.83 5.67 -1.57 5978489.12 584251.02 N 7021 4.207 W 149 18 57.402 2252.74 63.16 80.20 1859.38 1780.08 990.09 999.96 164.91 980.83 0.62 0.56 0.29 5978504.44 584333.13 N 7021 4.349 W 149 1854.997 2347.03 64.75 79.83 1900.78 1821.48 1074.48 1084.67 179.60 1064.26 1.72 1.69 -0.39 5978520.06 584416.38 N 7021 4.493 W 1491852.559 2439.44 64.29 78,80 1940.53 1861.23 1157.66 1168.09 195.06 1146.24 1.12 -0.50 -1.11 5978536.43 584498.17 N 7021 4.645 W1491850.163 2532.96 65.34 78.43 1980.33 1901.03 1242.13 1252.72 211.77 1229,20 1.18 1.12 -0.40 5978554.06 584580.93 N 7021 4.809 W 149 1847.738 2627.17 67.87 78.44 2017.73 1938.43 1328.43 1339.18 229.10 1313.90 2.69 2.69 0.01 5978572.33 584665.43 N 7021 4.980 W 1491845.263 2719.46 67.52 77.75 2052.76 1973.46 1413.69 1424,57 246.72 1397.45 0.79 -0.38 -0.75 5978590.87 584748.77 N 70215.153 W 1491842.821 2811.94 66.61 76.86 2088.80 2009.50 1498.78 1509.73 265.43 1480.53 1.32 ·0.98 -0.96 5978610.51 584831.63 N 7021 5.336 W 1491840.392 2903.69 65.43 76.84 2126.09 2046.79 1582.58 1593,56 284.64 1562.13 1.30 -1.29 -0.24 5978630.62 584913.00 N 7021 5.525 W 1491838.007 2995.29 66.83 77.41 2163.16 2083.86 1666.28 1677.33 303.45 1643.76 1.71 1.53 0.84 5978650,33 584994.41 N 7021 5.710 W 149 1835.622 3087.98 66.70 78.34 2199,72 2120.42 1751.35 1762.50 321.34 1727.03 0.93 -0.14 1.00 5978669.15 585077.46 N 7021 5.886 W 1491833.188 3183.50 66.41 77.69 2237.73 2158.43 1838.86 1850.13 339.53 1812.75 0.69 -0.30 -0.68 5978688.29 585162.97 N 7021 6.065 W 1491830.682 3278.03 65.17 77.08 2276.49 2197.19 1925.00 1936.35 358.36 1896.88 1.44 -1.31 ·0.65 5978708.05 585246.88 N 70 21 6.250 W 1491828.223 3372.61 64.91 77.04 2316.40 2237.10 2010.69 2022.09 377.56 1980.45 0.28 -0.27 -0.04 5978728,18 585330.22 N 70 21 6.438 W 149 1825.781 3466.13 67.35 77.68 2354.25 2274.95 2096.13 2107,61 396.27 2063.89 2.68 2.61 0.68 5978747.81 585413.45 N 70 21 6.622 W 149 1823.342 3559.14 66.75 78.06 2390.51 2311.21 2181.67 2193.25 414.27 2147.63 0.75 -0.65 0.41 5978766,74 585496.97 N 70 21 6.799 W 1491820.894 3648.94 65.46 77.53 2426.89 2347.59 2263.68 2275.35 431.62 2227.88 1.53 -1.44 -0.59 5978784.99 585577.01 N 70 21 6.969 W 149 18 18.549 3741.72 65.02 77.33 2465.74 2386.44 2347,85 2359.61 449.96 2310.11 0.51 -0.47 ·0.22 5978804.23 585659.02 N 70217.149 W 1491816.145 3828.89 66.39 77.89 2501.61 2422.31 2427.21 2439.05 467.00 2387.70 1,68 1.57 0.64 5978822,14 585736.42 N 7021 7.317 W 149 18 13.877 3932.50 65.77 77.77 2543.62 2464.32 2521.81 2533.76 486.97 2480.29 0.61 -0.60 -0.12 5978843.13 585828.76 N 70 21 7.513 W 1491811.171 4026.29 65.19 78.24 2582.54 2503.24 2607.02 2619.10 504.70 2563.75 0.77 -0.62 0.50 5978861 .79 585912.02 N 70 21 7.687 W 149188.732 4118.67 65.69 79.80 2620.94 2541.64 2690.84 2703.12 520.70 2646.24 1.63 0.54 1.69 5978878.71 585994.31 N 70 21 7.844 W 149 186.321 4212.07 65.33 79.49 2659.66 2580.36 2775.55 2788.11 535.98 2729.85 0.49 -0.39 -0.33 5978894.91 586077.74 N 70 21 7.994 W 149 18 3.877 4306.17 65.21 79.75 2699.02 2619.72 2860,75 2873.58 551.38 2813.92 0.28 -0.13 0.28 5978911.24 586161.63 N 70 21 8.145 W 149181.419 4417.36 62.56 79.56 2747.96 2668.66 2960.25 2973.41 569.31 2912.13 2.39 -2.38 -0.17 5978930.26 586259.62 N 70 21 8.321 W 149 1758.549 4511.53 66.42 80,52 2788.51 2709.21 3044.89 3058.39 583.99 2995.82 4.20 4,10 1.02 5978945.87 586343.14 N 70 21 8.465 W 149 1756.103 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( do31 rt-546) L·21 01L-21 0IL·210IL-210 Generated 1/23/2004 1 :22 PM Page 1 of 2 . . I I I I I Measured Inclination I Azimuth rVD I Sub-Sea rVD I Vertical Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Lathude Longitude Depth Section Departure (ft) (deg) ( deg) (ft) (ft) (ft) (ft) (ft) (It) ( deg/100 ft ) ( deg/100 It) ( deg/100 It) (ftUS) (ftUS) 4605.12 65.43 81.23 2826.69 2747.39 3129.89 3143.83 597.55 3080.19 1,26 -1.06 0.76 5978960.36 586427,34 N 7021 8.598 W 149 17 53.637 4697.53 66.96 81.21 2863.99 2784.69 3213.93 3228.38 610.45 3163.74 1.66 1.66 -0.02 5978974.19 586510.74 N 7021 8,725 W1491751.194 4791.30 66.61 80.90 2900.95 2821.65 3299.63 3314.56 623.85 3248.87 0.48 -0.37 -0.33 5978988.54 586595.70 N 70 21 8.856 W 149 1748.706 4884.01 65.46 80.30 2938.61 2859.31 3383.94 3399.27 637.68 3332.45 1.37 -1.24 -0.65 5979003.30 586679,12 N 70 21 8.992 W 149 17 46.263 4977.70 66.93 80.38 2976.42 2897.12 3469.29 3484.99 652.07 3416.95 1.57 1.57 0.09 5979018.62 586763.44 N70219.133 W 149 1743.793 5069.03 66.87 80.06 3012.25 2932.95 3552.95 3569.00 666.34 3499.74 0.33 -0.07 -0.35 5979033.81 586846,06 N 70 21 9.273 W 1491741.373 5161.40 65.77 80.65 3049.35 2970.05 3637.17 3653.59 680.51 3583,13 1.33 -1.19 0.64 5979048.91 586929.28 N70219.412 W 149 1738.936 5253.33 66.00 80.88 3086.91 3007.61 3720.65 3737.50 693.98 3665.95 0.34 0.25 0.25 5979063.29 587011.94 N 7021 9.544 W 149 1736.515 5347.59 65.99 81.38 3125.26 3045.96 3806.27 3823.60 707.25 3751.03 0.48 -0.Q1 0.53 5979077.52 587096.86 N 7021 9.674 W 149 17 34.028 5441.57 65.58 81.72 3163.81 3084.51 3891.42 3909.31 719.85 3835.81 0.55 -0.44 0.36 5979091.05 587181.48 N 7021 9.797 W 1491731.550 5533.96 65.77 82.31 3201.86 3122.56 3974.97 3993.50 731.54 3919.18 0.62 0.21 0.64 5979103.67 587264.71 N 70 219.912 W 1491729.113 5626.81 65.23 82.42 3240.37 3161.07 4058.77 4077.99 742.77 4002.92 0.59 -0.58 0.12 5979115.83 587348.31 N 70 21 10.022 W 149 1726.665 5720.41 66.24 81.95 3278.83 3199.53 4143.43 4163.32 754.37 4087.46 1.17 1.08 -0.50 5979128.37 587432.71 N 702110.136 W 149 1724.194 5814.24 66.17 82.17 3316.69 3237.39 4228.63 4249.17 766.23 4172.49 0.23 -0.ü7 0.23 5979141.17 587517.59 N 70 21 10.252 W 149 17 21.709 5906.12 65,17. 82.57 3354.54 3275.24 4311.66 4332.89 777.35 4255.46 1.16 -1.09 0.44 5979153.21 587600.43 N 70 21 10.361 W 14917 19.283 6001.16 64.86 82.01 3394.69 3315.39 4397.10 4419.04 788.91 4340.83 0.63 -0.33 -0.59 5979165.72 587685.66 N 70 21 10.474 W 149 1716.788 6093.10 65.19 80.76 3433.51 3354.21 4479.93 4502.38 801.39 4423.23 1.28 0.36 -1.36 5979179.12 587767.91 N 70 21 10.596 W 149 17 14.379 6186.74 61.67 81.14 3475.38 3396.08 4563.21 4586.12 814.57 4505.92 3.78 -3.76 0.41 5979193.21 587850,44 N 70 21 10.725 W 1491711.962 6279.13 62.92 80.67 3518.34 3439.04 4644.58 4667.91 827.50 4586.69 1.43 1.35 -0.51 5979207.04 587931.05 N 7021 10.852 W 149 17 9.601 6372.21 62.51 80.92 3561.01 3481.71 4726.88 4750.64 840.73 4668.35 0.50 -0.44 0.27 5979221.18 588012.55 N 70 21 10.982 W 149 17 7.214 6464.22 65.48 80.17 3601.34 3522.04 4809.18 4833.32 854.32 4749.91 3.31 3.23 -0.82 5979235.67 588093.95 N702111.115 W 149 17 4.830 6558.40 66.65 80.07 3639.55 3560.25 4894.91 4919.40 869.09 4834.71 1.25 1.24 -0.11 5979251.38 588178.57 N 702111.260 W 149 17 2.351 6652.26 65.80 80.06 3677.39 3598.09 4980.47 5005.30 883.91 4919.32 0.91 -0.91 -0.Q1 5979267.14 588263.00 N 702111.405 W 1491659.878 6745.55 65.93 79.80 3715.54 3636.24 5065.29 5090.43 898.80 5003.14 0.29 0.14 -0.28 5979282.96 588346.64 N 702111.551 W 1491657.428 6838.24 66.05 79.40 3753.25 3673.95 5149.69 5175.10 914.08 5086.42 0.41 0.13 -0.43 5979299.16 588429.74 N702111.700 W 149 16 54,993 6930.92 66.00 78.90 3790.91 3711.61 5234.15 5259.79 930.02 5169.59 0.50 -0.05 -0.54 5979316.03 588512.72 N 70 21 11.857 W 149 1652.562 7023.68 65.43 77.94 3829.06 3749.76 5318.55 5344.34 946.99 5252.42 1.13 -0.61 -1.03 5979333.92 588595.35 N 70 21 12.023 W 14916 50.141 7119.23 65.23 77.68 3868.94 3789.64 5405.27 5431.17 965.33 5337.29 0.32 -0.21 -0.27 5979353.19 588680.00 N 70 21 12.203 W 149 1647.659 7212.75 66.38 76.60 3907.27 3827.97 5490.51 5516.47 984.32 5420.45 1.62 1.23 -1.15 5979373.10 588762.94 N 70 21 12.389 W 1491645.228 7306.32 66.81 77.73 3944.44 3865.14 5576.32 5602.34 1003.39 5504.18 1.20 0.46 1.21 5979393.11 588846.44 N 70 21 12.576 W 1491642.781 7400.19 67.49 77.35 3980.89 3901.59 5662.74 5688.84 1022.06 5588.64 0.81 0.72 -0.40 5979412.71 588930.68 N 7021 12.759 W1491640.312 7493.51 66.96 78.02 4017.02 3937.72 5748.69 5774.89 1040.41 5672.70 0.87 -0.57 0.72 5979431 .99 589014,53 N 7021 12.939 W 1491637.854 7586.87 67.82 78.42 4052.91 3973.61 5834.74 5861.07 1058.00 5757.07 1.00 0.92 0.43 5979450.52 589098.69 N702113.111 W 1491635.388 7680.47 67.06 78.56 4088.82 4009.52 5921.01 5947.51 1075.25 5841.77 0.82 -0.81 0.15 5979468.71 589183.18 N 7021 13.280 W 1491632,912 7774.45 67.75 79.54 4124.93 4045.63 6007.56 6034.27 1091.73 5926.96 1.21 0.73 1.ü4 5979486.13 589268.17 N 702113.441 W 149 1630.421 7867.56 67.90 79.64 4160.07 4080.77 6093.51 6120.49 1107.31 6011.76 0.19 0.16 0.11 5979502.65 589352.79 N 7021 13.594 W 1491627.942 7961.55 67.64 79.90 4195.63 4116.33 6180.21 6207.50 1122.76 6097.38 0.38 -0.28 0.28 5979519.05 589438.22 N 7021 13.745 W 1491625.439 8056.10 66.43 81.19 4232.52 4153.22 6266.86 6294.55 1137.07 6183.25 1.79 -1.28 1.36 5979534.31 589523.92 N 7021 13.885 W1491622.929 8149.17 66.67 82.48 4269.56 4190.26 6351.63 6379,94 1149.19 6267.77 1.30 0.26 1.39 5979547.38 589608.29 N 70 21 14,004 W 149 1620.458 8243.08 66.68 83.96 4306.75 4227.45 6436.98 8466,17 1159.37 6353.39 1.45 0.Q1 1.58 5979558.51 589693.79 N 7021 14.103 W 149 16 17.955 8335.18 65.93 84.81 4343.76 4264.46 6520,18 6550.50 1167.62 6437.32 1.17 -0.81 0.92 5979567.69 589777.61 N 7021 14.184 W 1491615.502 8428.46 65.60 90.42 4382.07 4302.77 6603.14 6635.55 1171.17 6522.26 5.50 -0.35 6.01 5979572.18 589862.50 N 7021 14.218 W 14916 13,019 8521.96 64.14 93.85 4421.79 4342.49 6684.02 6720.20 1168.03 6606.84 3.67 -1.56 3.67 5979569.98 589947.09 N 7021 14.186 W 14916 10.547 8613.88 63.55 97.39 4462.32 4383.02 6761.23 6802.70 1159.96 6688.93 3.52 -0.64 3,85 5979562.83 590029.26 N 7021 14.106 W 149 168.147 8708.31 63.09 100.97 4504.73 4425.43 6838.19 6887.07 1146.51 6772.21 3.42 -0.49 3.79 5979550.30 590112.68 N 7021 13.973 W 149 165.714 8801.36 62.17 102.18 4547.51 4468.21 6912.09 6969.70 1129.93 6853.16 1.52 -0.99 1.30 5979534.63 590193.80 N 7021 13.809 W 149 163.348 8895.51 62.00 102.52 4591.59 4512.29 6985.98 7052.89 1112.14 6934.43 0.37 -0.18 0.36 5979517,74 590275.25 N 7021 13.634 W 149 160.973 8988.65 60.96 102.78 4636.06 4556.76 7058.47 7134.73 1094.21 7014.28 1.14 -1.12 0.28 5979500.71 590355.29 N 7021 13.457 W 149 15 58.639 9081.73 60.20 102.71 4681.78 4602.48 7130.23 7215.81 1076.33 7093.35 0.82 -0.82 -0.08 5979483.71 590434,56 N 7021 13.280 W 1491556.329 9175.43 59.84 103.00 4728.74 4649.44 7201.92 7296.89 1058.29 7172.40 0.65 -0.60 0.31 5979466.55 590513.79 N 702113.102 W 14915 54.019 9268.96 58.99 103.12 4776.47 4697.17 7272.89 7377.32 1040.11 7250.76 0.70 -0.69 0.13 5979449.25 590592.34 N 7021 12.922 W 14915 51.729 9361.93 57.78 103.34 4825.21 4745.91 7342.65 7456.49 1022.00 7327.83 1.32 -1.30 0.24 5979431.99 590669.60 N 7021 12.743 W 1491549.477 9454.49 57.01 103.32 4875.08 4795.78 7411.28 7534.46 1004.02 7403.70 0,83 -0.83 -0.02 5979414.86 590745.66 N 7021 12.566 W 1491547.260 9548.37 56.22 103.25 4926.74 4847.44 7480.31 7612.85 986.00 7479.99 0.84 -0.84 -0.07 5979397.70 590822.14 N 70 21 12.388 W 1491545.030 9593.73 55.91 103.05 4952.06 4872.76 7513.49 7650.49 977.44 7516.64 0.78 -0.68 -0.44 5979389.55 590858.87 N 70 21 12.303 W 1491543.959 9668.00 55.91 103.05 4993.69 4914.39 7567.78 7711.99 963.55 7576.55 0.00 0.00 0.00 5979376.33 590918,94 N 70 2112.166 W 149 1542.208 LeQal DescriPtion: NorthinQ IY) [ftUS] EastinQ IXI [ftUS] Surface: 2605 FSL 3559 FEL S34 T12N R11 E UM 5978328.65 583354,28 BHL: 3565 FSL 1261 FEL S35 T12N R11 E UM 5979376.33 590918.94 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rl-546 ) L-21 0\L-210\L-21 0\L-21 0 Generated 1/23/2004 1 :22 PM Page 2 of 2 . . L-210PB1 Survey Report Schlumberger Report Date: January 19, 2004 Survey I OLS Computation Method: Minimum Curvat..e I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 75.000' Field: Prudhoe Bay Un" - WOA Vertical Section Origin: N 0.000 h, E 0.000 h Structure I Slot: L-PAD / L-210 TVD Reference Datum: Rotary Table Well: L-210 rve Reference Elevation: 79.3 h relative to MSL Borehole: L-210PBI Sea Bed I Ground level Elevation: 44.100 h relative to MSL UWVAPI#: 500292318770 Magnetic Declination: 25.110' Survey Name I Date: L·210PB11 January 9. 2004 Total Field Strength: 57553.513 nT Tort I AHO I 0011 ERO ratio: 191.791' /8056.56 h / 6.494 /1.620 Magnetic Dip: 80.819' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 09,2004 Location LatILong: N 70 21 2.727, W 149 19 23.663 Magnetic Declination Model: BGGM 2003 Location Grid NÆ YIX: N 5978328.650 hUS, E 583354.280 hUS North Reference: True North Grid Convergence Angle: +0.83735513' Tota' Carr Ma9 North -) True North: +25.110' Grid Scale Factor: 0.99990789 Local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVO I Sub-Sea TVO I Vertical I Along Hole I NS EW I OLS I Build Rate I Walk Rate I Northing Easting Latitude Long~ude Depth Section Departure (h) ( deg) ( deg) (h) (h) (h) (h) (h) (h) ( deg/loo h) ( deg/loo 11) (deg/too h) (hUS) (hUS) 0.00 0.00 0.00 0.00 -79.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978328.65 583354.28 N 70 21 2.727 W1491923.663 100.00 0.31 295.40 100.00 20.70 ·0.21 0.27 0.12 -0.24 0,31 0.31 0.00 5978328.76 583354.03 N 70 21 2.729 W 1491923.670 200.00 0.07 183.85 200.00 120.70 -0.43 0.54 0.17 -0.49 0.34 ·0.24 '111.55 5978328.82 583353.79 N 70 21 2.729 W 149 1923.677 300.00 3.37 118.44 299.94 220.64 1.68 3.51 -1.29 2.09 3.34 3.30 ·65.41 5978327.38 583356.38 N70212.715 W 149 1923.602 400.00 5.98 112.64 399.60 320.30 7.94 11.66 -4.70 9.48 2.65 2.61 -5.80 5978324.06 583363.81 N 70 21 2.681 W 149 1923.386 500.00 7.76 104.03 498.88 419.58 17.97 23.60 -8.34 20.64 2.05 1.78 -8.61 5978320.55 583375.21 N 70 21 2.645 W 149 1923.054 546.00 9.37 96.79 544.37 465.07 24.17 30.44 -9.53 27.57 4.21 3.50 -15.74 5978319.42 583381.95 N 7021 2.634 W 1491922.857 570.88 10.02 87.21 568.89 489.59 28.16 34.62 -9.67 31.75 6.98 2.61 -38,50 5978319.34 583386.13 N 70 21 2.632 W 149 1922.735 662.68 11.57 79.39 659.07 579.77 45.15 51.79 -7.58 48.77 2.32 1.69 -8.52 5978321.61 583403.13 N 70 21 2.653 W 1491922.237 755.14 14.30 84,28 749.18 669.88 65.67 72.47 -4.74 69.25 3.18 2.95 5.29 5978324.68 583423.57 N 70 21 2.681 W 1491921.639 847.29 16.73 80.61 837.97 758.67 90.10 97.11 -1.44 93.67 2.84 2.64 -3,98 5978328.25 583447.95 N 70212.713 W 1491920.925 940.15 20.21 78.99 926.03 846.73 119.41 126.52 3.81 122.61 3.79 3.75 -1.74 5978333.82 583476.83 N 7021 2.765 W 1491920.080 1034m 22.76 80.62 1013.36 934.06 153.66 160.89 9.86 156.44 2.79 2.72 1.74 5978340.25 583510.59 N 70 21 2.824 W 149 19 19.091 1126.61 26.07 81.20 1097.67 1018.37 191.73 199.16 15.90 194.23 3.58 3.57 0,63 5978346.70 583548.30 N 70 21 2.884 W 149 19 17.986 1219.91 29.57 80.88 1180.17 1100.87 235.02 242.70 22.68 237.23 3.75 3.75 -0.34 5978353.97 583591 .22 N 70 21 2.951 W 149 19 16.730 1313.11 31,87 79.67 1260.29 1180.99 282.43 290.30 30.74 284.15 2.56 2.47 -1.30 5978362.55 583638.05 N 70 21 3.030 W 149 19 15.358 1407.33 36.02 79.21 1338.44 1259.14 334.87 342.90 40.39 335.86 4.41 4.40 -0.49 5978372.77 583689.64 N70213.125 W 149 19 13.847 1498.35 40.94 78.02 1409.67 1330.37 391.38 399.52 51.60 391.36 5.47 5.41 -1.31 5978384.60 583745.00 N 70 21 3.235 W 14919 12.225 1595.60 45.84 79.48 1480.32 1401.02 458.01 466.31 64.59 456.86 5.14 5.04 1.50 5978398.31 583810.35 N 7021 3.363 W 1491910.311 1689.14 50.20 78.14 1542.87 1463.57 527.38 535.82 78.11 525.05 4.78 4.66 -1.43 5978412.59 583878.38 N 7021 3.495 W149198.318 1784.93 50.20 76.20 1604.19 1524.89 600.91 609.42 94.45 596.80 1.56 0.00 -2.03 5978429.72 583949,94 N 70 21 3.656 W149196.221 1878.39 52.56 78.27 1662.52 1583.22 673.86 682.43 110.56 668.01 3.06 2.53 2.21 5978446.62 584020.96 N 70 213.815 W149194.140 1972.29 54.98 79.98 1718.02 1638.72 749.40 758.16 124.83 742.39 2.97 2.58 1.82 597846172 584095.16 N 70 21 3.955 W 149191.966 2066.09 57.37 81.39 1770.23 1690.93 826.93 836.08 137.43 819.28 2.84 2.55 1.50 5978475.17 584171.90 N 70 21 4.079 W 1491859.719 2158.90 62.63 79.93 1816.62 1737.32 906.89 916.43 150.50 898,55 5.83 5.67 -1.57 5978489.12 584251.02 N 70 21 4.207 W 149 1857.402 2252.74 63,16 80.20 1859.38 1780.08 990.09 999.96 164.91 980.83 0.62 0.56 0.29 5978504.44 584333.13 N 70 21 4.349 W 149 1854.997 2347.03 64.75 79.83 1900,78 1821.48 1074.48 1084.67 179.60 1064.26 1.72 1.69 -0.39 5978520.06 584416.38 N 70 21 4.493 W 149 1852.559 2439.44 64.29 78.80 1940.53 1861.23 1157.66 1168.09 195.06 1146.24 1.12 -0.50 -1.11 5978536.43 584498.17 N 70 21 4.645 W 149 18 50.163 2532.96 65.34 78.43 1980.33 190103 1242.13 1252.72 211.77 1229.20 1.18 1.12 -0.40 5978554.06 584580.93 N 7021 4.809 W 149 18 47.738 2627.17 67.87 78.44 2017.73 1938.43 1328.43 1339.18 229.10 1313.90 2.69 2.69 0.01 5978572.33 584665.43 N 7021 4.980 W 149 1845.263 2719.46 67.52 77.75 2052.76 1973.46 1413.69 1424.57 246.72 1397.45 0.79 -0.38 -0.75 5978590,87 584748.77 N 70 215.153 W 149 1842.821 2811.94 66.61 76.86 2088.80 2009.50 1498.78 1509.73 265.43 1480.53 1.32 -0.98 -0.96 5978610.51 564831.63 N 70 21 5.336 W 149 18 40.392 2903.69 65.43 76.64 2126.09 2046.79 1582.58 1593,56 284.64 1562.13 1.30 -1.29 -0.24 5978630.62 564913.00 N 7021 5.525 W 1491838.007 2995.29 66.83 77.41 2163.16 2083.86 1666.28 1677.33 303.45 1643.76 1.71 1.53 0.64 5978650.33 564994.41 N 70 215.710 W 149 18 35.622 3087.98 66.70 78.34 2199.72 2120.42 1751.35 1762.50 321.34 1727.03 0.93 -0.14 1.00 5978669.15 585077.46 N 70 21 5.886 W1491833.188 3183.50 66.41 77.69 2237.73 2158.43 1838.86 1850.13 339.53 1812,75 0.69 -0.30 -0.68 5978688.29 585162.97 N 70 21 6.065 W 149 1830.682 3278.03 65.17 77.08 2276.49 2197.19 1925.00 1936.35 358.36 1896.88 1.44 -1.31 -0.65 5978708.05 585246.88 N 70 21 6.250 W 149 1828.223 3372.61 64.91 77.04 2316.40 2237.10 2010.69 2022.09 377.56 1980.45 0.28 -0.27 -0.04 5978728.18 585330.22 N 70 21 6.438 W 149 1825.781 3466.13 67.35 77.68 2354.25 2274.95 2096.13 2107.61 396.27 2063.89 2.68 2.61 0.68 5978747.81 585413.45 N 70 21 6.622 W 149 1823.342 3559.14 66.75 78.06 2390.51 2311.21 2181.67 2193.25 414.27 2147.63 0.75 -0.65 0.41 5978766.74 585496.97 N 70 21 6.799 W 149 1820.894 3648.94 65.46 77.53 2426.89 2347.59 2263.68 2275.35 431.62 2227.88 1.53 -1.44 -0.59 5978784.99 585577.01 N 70 21 6.969 W 149 18 18.549 3741.72 65.02 77.33 2465.74 2386.44 2347.85 2359.61 449.96 2310.11 0.51 -0.47 -0.22 5978804.23 585659.02 N70217.149 W 1491816.145 3828.89 66.39 77,89 2501.61 2422.31 2427.21 2439.05 467.00 2387.70 1.68 1.57 0.64 5978822.14 585736.42 N70217.317 W 149 18 13.877 3932.50 65.77 77.77 2543.62 2464.32 2521.81 2533.76 486.97 2480,29 0.61 -0.60 -0.12 5978843,13 585828.76 N70217.513 W 1491811.171 4026.29 65.19 78.24 2582.54 2503.24 2607.02 2619.10 504.70 2563,75 0.77 -0.62 0.50 5978861.79 585912.02 N 70 21 7.687 W 149 188.732 4118.67 65.69 79.80 2620,94 2541.64 2690.84 2703.12 520.70 2646.24 1.63 0.54 1.69 5978878.71 585994.31 N 7021 7.844 W 149 186.321 4212.07 65,33 79.49 2659.66 2580.36 2775.55 2788.11 535.98 2729.85 0.49 -0.39 -0.33 5978894.91 586077.74 N 7021 7.994 W 149 183.877 4306.17 65.21 79.75 2699.02 2619.72 2860.75 2873.58 551.38 2813.92 0.28 -0.13 0.28 5978911.24 586161.63 N70218.145 W 149181.419 4417.36 62.56 79.56 2747.96 2668.66 2960.25 2973.41 569.31 2912.13 2.39 -2.38 -0.17 5978930.26 586259.62 N 7021 8.321 W 149 1758.549 4511.53 66.42 80.52 2788.51 2709.21 3044.89 3058.39 583.99 2995.82 4.20 4.10 1.02 5978945.87 586343.14 N 7021 8.465 W1491756.103 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) L-21 OIL -21 OIL -21 OPB IlL -21 OPB 1 Generated 1/23/2004 1 :23 PM Page 1 of 2 . . / I I I Measuroo I Inclination I Azimuth TVD I Sub-Sea TVD I Vertical Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easling Latitude Longitude Depth Section Departure . (ft) ( deg) (deg) (It) (ft) (ft) (ft) (ft) (fl) (deg/1ooft) (deg/1ooft) (deg/100ft) (ftUS) (ftUS) 4605.12 65.43 81.23 2826.69 2747.39 3129.89 3143.83 597.55 3080.19 1.26 -1.06 076 5978960.36 586427.34 N 70 21 8.598 W 14917 53.637 4697.53 66.96 81.21 2863.99 2784.69 3213.93 3228.38 610.45 3163.74 1.66 1.66 -0.02 5978974.19 586510.74 N 70 21 8.725 W1491751.194 4791.30 66.61 80.90 2900.95 2821.65 3299.63 3314.56 623.85 3248,87 0.48 -0.37 -0.33 5978988.54 586595.70 N 70 21 8.856 W 149 1748.706 4884.01 65.46 80.30 2938.61 2859.31 3383.94 3399.27 637.68 3332.45 1.37 -1.24 -0.65 5979003.30 586679.12 N 70 21 8.992 W 149 1746.263 4977.70 66.93 80.38 2976.42 2897.12 3469,29 3484.99 652.07 3416.95 1.57 1.57 0.09 5979018.62 586763.44 N 70 219.133 W 149 1743.793 5069.03 66.87 80.06 3012.25 2932.95 3552.95 3569.00 666.34 3499.74 0.33 -0.07 -0.35 5979033.81 586846.06 N 7021 9.273 W1491741.373 5161.40 65,77 80.65 3049.35 2970.05 3637.17 3653.59 680.51 3583.13 1.33 -1.19 0.64 5979048.91 586929.28 N70219.412 W 1491738.936 5253.33 66.00 80.88 3086.91 3007.61 3720.65 3737.50 693.98 3665,95 0.34 0.25 0.25 5979063.29 587011 .94 N 70 21 9.544 W 14917 36.515 5347.59 65.99 81.38 3125.26 3045.96 3806.27 3823.60 707.25 3751.03 0.48 -0.01 0.53 5979077.52 587096.86 N 70 21 9.674 W 149 1734.028 5441.57 65.58 81.72 3163.81 3084.51 3891.42 3909.31 719.85 3835.81 0.55 -0.44 0.36 5979091,05 587181.48 N 70 21 9.797 W 1491731.550 5533.96 65.77 82.31 3201.86 3122.56 3974.97 3993.50 731.54 3919.18 0.62 0.21 0.64 5979103.67 587264.71 N 7021 9.912 W1491729.113 5626.81 65.23 82.42 3240.37 3161.07 4058.77 4077.99 742.77 4002.92 0.59 -0.58 0.12 5979115.83 587348.31 N 7021 10.022 W 149 17 26.665 5720.41 66.24 81.95 3278.83 3199.53 4143.43 4163.32 754.37 4087.46 1.17 1.08 -0.50 5979128.37 587432.71 N 7021 10.136 W 149 1724.194 5814.24 66.17 82.17 3316.69 3237.39 4228.63 4249.17 766.23 4172.49 0.23 -0.07 0.23 5979141.17 587517.59 N 7021 10.252 W 1491721.709 5906.12 65.17 82.57 3354.54 3275.24 4311.66 4332.89 777.35 4255.46 1.16 -1.09 0.44 5979153.21 587600.43 N 7021 10.361 W 149 17 19.283 6001.16 64.86 82.01 3394.69 3315.39 4397.10 4419.04 788.91 4340.83 0.63 -0.33 -0.59 5979165.72 587685.66 N 70 21 10.474 W 149 17 16.788 6095.07 65.46 80.82 3434.14 3354.84 4481.79 4504.26 801.63 4425.09 1.32 0,64 -1.27 5979179.37 587769.77 N 7021 10.599 W 149 1714.325 6187.35 67,73 77.39 3470.80 3391.50 4566.24 4588.94 817.65 4508.23 4.21 2.46 -3,72 5979196.32 587852.71 N 70 21 10.756 W 149 17 11.895 6279.26 71.21 74.90 3503.03 3423.73 4652.27 4675.00 838.28 4591.77 4.56 3.79 -2.71 5979217.87 587936.01 N 70 21 10.958 W 149 179.452 6372.70 72.98 71.30 3531.77 3452.47 4741.12 4763.90 864.14 4676.82 4.13 1.89 -3.85 5979244.67 588020.76 N702111.212 W 149 176.966 6465.19 74,51 66.90 3557.67 3478.37 4829.41 4852.69 895.81 4759.74 4.86 1.65 -4.76 5979277.27 588103.32 N 702111.523 W 149 17 4.542 6558.06 74,80 63.10 3582.25 3502.95 4917.59 4942.25 933.66 4840.89 3.96 0.31 -4.09 5979316.01 588184.03 N 70 21 11.894 W149172.169 6651,14 75.83 59.96 3605.85 3526.55 5005.14 5032.28 976.58 4920.03 3.45 1.11 -3.37 5979359.80 588262.68 N 7021 12.316 W 149 1659.855 6744.29 75.24 59.92 3629.12 3549.82 5092.24 5122.48 1021.76 4998.09 0.63 -0.63 -0.04 5979405.84 588340.23 N 7021 12.760 W 14916 57.573 6837.15 74.38 60.23 3653.45 3574.15 5178.83 5212.10 1 066.46 5075.76 0.98 -0.93 0.33 5979451 .40 588417.39 N702113.199 W 149 1655.302 6930.01 74.65 58.65 3678.25 3598.95 5265.04 5301.58 1111.96 5152.82 1,67 0.29 -1.70 5979497.75 588493.92 N 7021 13.646 W 149 1653.048 7023.18 76.51 57.15 3701 .45 3622.15 5351.27 5391 .82 1159.91 5229.25 2.53 2.00 -1.61 5979546.55 588569.81 N702114.117 W 149 1650.813 7117.Q4 79.31 56.45 3721.11 3641.81 5438.45 5483.58 1210.17 5306.03 3.07 2.98 -0.75 5979597.64 588646.03 N 7021 14.611 W 1491648.568 7211.21 77.94 57,10 3739.68 3660.38 5526.14 5575.90 1260.75 5383.26 1.60 -1.45 0.69 5979649.08 588722.68 N 7021 15.108 W 1491646.310 7305.15 76.54 56.20 3760.43 3681.13 5613.09 5667.52 1311.11 5459.79 1.76 -1.49 -0,96 5979700.29 588798.64 N 70 21 15.603 W 1491644.072 7398.81 75.77 56.97 3782.84 3703.54 5699.38 5758.46 1361.19 5535.70 1.15 -0.82 0.82 5979751.20 588873.97 N 70 21 16.094 W 1491641.852 7492.18 78.56 57.46 3803.58 3724.28 578605 5849.49 1410.48 5612.23 3.03 2.99 0.52 5979801.34 588949.94 N 702116.579 W 149 1639.614 7585.79 77.74 56.74 3822.80 3743.50 5873.23 5941.10 1460.24 5689.15 1.15 -0.88 -0.77 5979851.95 589026.30 N 70 21 17.068 W 149 1637.364 7679.16 76.37 56.33 3843.72 3764.42 5959.54 6032.10 1510.42 5765.06 1.53 -1.47 -0.44 5979902.96 589101.64 N 70 21 17.560 W 149 1635.144 7773.13 76.45 57.31 3865.80 3786.50 6046.32 6123.43 1560.41 5841.50 1.02 0.09 1.04 5979953.79 589177.52 N 7021 18.051 W 149 1632.908 7866.13 77.09 58.70 3887.08 3807.78 6132.90 6213.96 1608.37 5918.28 1.61 0.69 1.49 5980002.60 589253.75 N 7021 18.523 W 149 1630.663 7960.25 77.10 5908 3908.10 3828.80 6221.04 6305.71 1655.77 5996.83 0.39 0.01 0.40 5980050.87 589331 .76 N 7021 18.988 W 149 1628.366 8055.20 75.95 59.39 3930.23 3850.93 6309.90 6398.04 1703.01 6076.17 1.25 -1.21 0.33 5980098.97 589410.56 N 70 21 19.452 W 1491626.045 8148.27 75.20 60.23 3953.41 3874.11 6396.88 6488.18 1748.33 6154.08 1.19 -0.81 0.90 5980145.16 589487.95 N 70 21 19.897 W 1491623.767 8241.63 73.25 61.88 3978.79 3899.49 6484.07 6578.02 1791.82 6232.69 2.69 -2.09 1.77 5980189.51 589566.07 N 70 21 20.324 W 1491621.468 8334.51 71.72 63.61 4006.75 3927.45 6570.62 6666.59 1832.38 6311.42 2.42 -1.65 1.86 5980230.94 589644.33 N 70 21 20.722 W 1491619.165 8428.43 69.58 63.56 4037.87 3958.57 6657.47 6755.20 1871.80 6390.78 2.28 -2.28 -0.05 5980271.24 589723.24 N 702121.110 W 149 1616.845 8521 03 66.67 65.04 4072.37 3993.07 6741.90 6841.12 1909.07 6468.19 3.47 -3.14 1.60 5980309.37 589800.23 N 70 21 21.475 W 149 16 14.581 8613.69 63.59 65.47 4111.33 4032.03 6824.74 6925.18 1944.26 6544.53 3.35 -3.32 0.46 5980345.40 589876.16 N 70 21 21.821 W 149 16 12.348 8708.40 59.82 67.87 4156.22 4076.92 6907.23 7008.55 1977.30 6621.07 4,56 -3.98 2.53 5980379.29 589952.33 N 70 21 22.145 W 1491610.110 8802.35 58.47 68.62 4204.40 4125.10 6987.32 7089.20 2007.20 6695.98 1.59 -1.44 0.80 5980410.01 590026.89 N 7021 22.439 W 149 167.919 8895.43 56.32 68.81 4254.56 4175.26 7065.25 7167.61 2035.66 6769.03 2.32 -2.31 0.20 5980439.28 590099.62 N 70 21 22.718 W 149 165.783 8988.83 54.32 69.13 4307.70 4228.40 7141.63 7244.41 2063.23 6840.72 2.16 -214 0.34 5980467.64 590170.98 N 70 21 22.988 W 149163.687 9083.14 52,79 68.68 4363.72 4284.42 7217.06 7320.28 2090.53 6911.50 1.67 -1.62 -0.48 5980495.73 590241 .45 N 70 21 23.256 W 149161.617 9176,62 52.00 69.24 4420.76 4341 .46 7290.71 7394.33 2117.12 6980.62 0.97 -0.85 0.60 5980523.08 59031 0.26 N702123.517 W 1491559.595 9269.37 51.41 69.91 4478.24 4398.94 7363.18 7467.13 2142,52 7048.83 0.85 -0.64 0.72 5980549.24 590378.18 N 70 21 23.766 W 149 1557.601 9362.54 51.37 69.99 4536.38 4457.08 7435.70 7539.93 2167.48 7117.23 0.08 -0.04 0.09 5980574.96 590446.29 N 70 21 24.011 W 149 1555.600 9454.59 51.34 70.04 4593.87 4514.57 7507.32 7611.82 2192.05 7184.79 0.05 -0.03 0.05 5980600.28 590513.57 N 70 21 24.252 W 149 1553.625 9548.47 50.43 69.92 4653.09 4573.79 7579.88 7684.66 2216.99 7253.23 0,97 -0.97 -0.13 5980625.97 590581 .72 N 7021 24.497 W 1491551.623 9642.10 50.42 70.39 4712.74 4633.44 7651.79 7756.83 2241.49 7321.11 0.39 -0.01 0.50 5980651,22 590649.32 N 70 21 24.737 W 1491549.638 9735.33 49.78 71.16 4772,55 4693.25 7723.12 7828.35 2265.04 7388.64 0.93 -0.69 0.83 5980675.52 590716.58 N 70 21 24.968 W 1491547.663 9828.86 48.70 70.96 4833.61 4754.31 7793.79 7899.20 2288.03 7455.65 1.17 -1.15 -0.21 5980699.25 590783.32 N 702125.193 W 149 1545.704 9922.76 48,15 71.43 4895.92 4816.62 7863.88 7969.44 2310.68 7522.15 0.70 -0.59 0.50 5980722.63 590849.55 N 70 2125.415 W 149 1543.759 9967.18 47.96 71.11 4925.61 4846.31 7896.85 8002.48 2321.29 7553.44 0.69 -0.43 -0.72 5980733.59 590880.72 N 70 21 25.520 W 149 1542.844 1004000 47.96 71.11 4974.38 4895.08 7950.81 8056.56 2338.80 7604.60 0.00 0.00 0.00 5980751.67 590931.69 N 70 2125.691 W 149 1541.348 LeQal DeseriDtion: NorthinQ (y) rftUSl EastinQ (X) rftUS] Surface: 2605 FSL 3559 FEL S34 T12N R11 E UM 5978328.65 583354.28 BHL: 4940 FSL 1230 FEL S35 T12N R11 E UM 5980751.67 590931.69 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546) L -21 0\L-21 OIL-21 OPB1\L-21 OPB 1 Generated 1/23/2004 1 :23 PM Page 2 of 2 TREE = WELLHEAD = ~.~ <,~_,__.._m" ACTUATOR = ~_.- > ._..~ -~~,,-~,~~ KB. ELEV = ~~,~. ""~,~,-,,~~~,,-~ . BF. ELEV = KOP;' .. Max Angle = .... .M.._.~<,~m.",.'..', Datum MD = Datum ND = /' . . 4-1/16" CIW FMC NA 79.3' 53.4' 200' 68 @f,á68' xxxx' xxxx'SS 9-5/8" CSG, 40#, L-80, ID = 8.835" H 4368' Minimum ID = 2.813" @ 8739'1 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8669' PERFORA TION SUMMARY REF LOG: SWS USIT 1/14/04 ANGLEATTOPÆRF: 62° @ 8804' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 8804 -8894 Open 01115/04 4-112" 5 8959 - 9019 Open 01/15/04 4-1/2" 5 9054 - 9084 Open 01/15/04 4-1/2" 5 9279 - 9369 Not Fired 13-1/2" TBG, 9.2#/9.3#, L-80, .0087 bpf, ID = 2.992" H I PBTD H 9567' IT· CSG, 26#, L-80, ID = 6.276" H 9656' DA TE REV BY COMMENTS 01/25/04 JAFITLH ORIGINAL COMPLETION 9219' DA TE REV BY ~ GAS LIFT MANDRELS IST MD IND I DEV TYÆ VLVLATCH PORT DATE 5 8559 4443 64 KBG2 DCK BEK 0 01/16/04 WATERFLOOD MANDRELS ST MD ND DEV TYÆ VLV LATCH 4 8760 4476 62 MMG-W DMY RK 3 8883 4585 62 MMG-W DMY RK 2 8948 4620 61 MMG-W DMY RK 1 9122 4752 60 MMG-W DMY RK L-210 = =----1 I L r I --j I Z :8:--1 . j ~~ . I :8: :8: ---t ~ , , I, I I II ~ COMMENTS ~ ¡;A' dY NOTES: 1016' H 9-5/8" TAM PORT COLLAR 1 3796' H 4-112" HES X NIP, ID = 3.813" I PORT DATE 01/16/04 01/16/04 01/16/04 01116/04 7620' 1--1 7" MARKER JT W/ RA TAG I 8669' H 4-1/2" HES X NIP, ID = 3.813" 1 8670' H 4-1/2" X 3-1/2" XO, ID = 2.992" I 8681' H 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 8739' 1--1 3-1/2" HES X NIP, ID = 2.813" 1 8743' 1-1 7" MARKER JT W/ RA TAG I 8892' H 3-1/2" TBG CENTRALIZER W/ RA MARKER 8911' H 3-1/2" HES X NIP, ID = 2.813" I 8922' H 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 9150' 9160' 9163' 9166' 9189' 9201' 9219' 9219' H 3-1/2" HES X NIP, ID = 2.813" 1 H 3-1/2"X4-1/2"XO,ID=2.910"1 H 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 H 4-1/2" X 3-1/2" XO, ID = 2.910" I H 3-1/2" HES X NIP, ID = 2.813" 1 H 3-1/2" HES X NIP, ID = 2.813" I H 3-1/2" WLEG, ID= 3.00" I H SWS SXAR GUN ASSEMBLY I ORION UNIT WELL: L-210 ÆRMIT No: 2031990 API No: 50-029-23187-00 SEC 34, T12N, R11 E, 2605' NSL & 3559' WEL BP Exploration (Alaska) SCRLUMBERGER Survey report Client.......... .........: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: L-210i PB1 API number..... ..........: 50-029-23187-70 Engineer...... .......,...: St. Amour 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.. ........: Driller's Pipe Tally GL above permanent..... ..: 49.85 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 79.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).... .....: 0.00 ft Departure (+E/W-)... .....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-). ........: N 70.35075763 Departure (+E/W-)........: W 149.32323966 Azimuth from rotary table to target: 75.00 degrees ~~~fv\~~ 7-Jan-2004 18:24:45 Spud date.......... ......: Last survey date.... .....: Total accepted surveys...: MD of first survey... ....: MD of last survey.... ....: (3)03- \ 9°, Page 1 of 5 01-Jan-04 07-Jan-04 110 0.00 ft 10040.00 ft . ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2003 Magnetic date... .........: 01-Jan-2004 Magnetic field strength..: 1151.08 RCNT Magnetic dec (+E/W-). ....: 25.12 degrees Magnetic dip....... ......: 80.82 degrees ----- MWD survey Reference Reference G.... ...... ....: Reference R.... ..........: Reference Dip... ....... ..: Tolerance of G.. .........: Tolerance of R.... ... ....: Tolerance of Dip... ......: Criteria --------- 1002.68 mGal 1150.48 RCNT 80.79 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ~~~~~t~~r~:~t~~~~W=~~~~~~~------;;~;~-~~~~~~~ 4IIÞ Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.31 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction RECEIVED .IN'! 2 62Q04 ÞJlBkaOiJ & Gas Cœs,Commilion j}¡¡~ SCHLUMBERGER Survey Report 7-Jan-2004 18:24:45 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tie-in Point 2 100.00 0.31 295.40 100.00 100.00 -0.21 0.12 -0.24 0.27 295.40 0.31 GYRO 3 200.00 0.07 183.85 100.00 200.00 -0.43 0.17 -0.49 0.52 289.15 0.34 GYRO 4 300.00 3.37 118.44 100.00 299.94 1. 68 -1. 29 2.09 2.45 121. 71 3.34 GYRO 5 400.00 5.98 112 .64 100.00 399.60 7.94 -4.70 9.48 10.58 116.35 2.65 GYRO 6 500.00 7.76 104.03 100.00 498.88 17.97 -8.34 20.84 22.45 111. 81 2.05 GYRO . 7 546.00 9.37 96.79 46.00 544.37 24.17 -9.53 27.57 29.17 109.07 4.21 GYRO 8 570.88 10.02 87.21 24.88 568.89 28.16 -9.67 31.75 33.19 106.94 6.98 MWD IFR MSA 9 662.68 11. 57 79.39 91. 80 659.07 45.15 -7.58 48.77 49.36 98.84 2.32 MWD IFR MSA 10 755.14 14.30 84.28 92.46 749.18 65.67 -4.74 69.25 69.41 93.91 3.18 MWD IFR MSA 11 847.29 16.73 80.61 92.15 837.97 90.10 -1. 44 93.67 93.68 90.88 2.84 MWD IFR MSA - 12 940.15 20.21 78.99 92.86 926.03 119.41 3.81 122.61 122.67 88.22 3.79 MWD IFR MSA - 13 1034.01 22.76 80.62 93.86 1013.36 153.66 9.86 156.44 156.75 86.39 2.79 MWD IFR MSA - 14 1126.61 26.07 81. 20 92.60 1097.67 191.73 15.90 194.23 194.88 85.32 3.58 MWD IFR MSA - 15 1219.91 29.57 80.88 93.30 1180.17 235.02 22.68 237.23 238.32 84.54 3.75 MWD IFR MSA 16 1313 .11 31.87 79.67 93.20 1260.29 282.43 30.74 284.15 285.81 83.83 2.56 MWD IFR MSA - 17 1407.33 36.02 79.21 94.22 1338.44 334.87 40.39 335.86 338.28 83.14 4.41 MWD IFR MSA - 18 1498.35 40.94 78.02 91.02 1409.67 391. 38 51. 60 391. 36 394.74 82.49 5.47 MWD IFR MSA - 19 1595.60 45.84 79.48 97.25 1480.32 458.01 64.59 456.86 461.41 81. 95 5.14 MWD IFR MSA - 20 1689.14 50.20 78.14 93.54 1542.87 527.38 78.11 525.05 530.83 81.54 4.78 MWD IFR MSA 21 1784.93 50.20 76.20 95.79 1604.19 600.91 94.45 596.80 604.23 81.01 1.56 MWD IFR MSA . - 22 1878.39 52.56 78.27 93.46 1662.52 673.86 110.56 668.01 677.10 80.60 3.06 MWD IFR MSA - 23 1972.29 54.98 79.98 93.90 1718.02 749.40 124.83 742.39 752.81 80.46 2.97 MWD IFR MSA - 24 2066.09 57.37 81.39 93.80 1770.23 826.93 137.43 819.28 830.72 80.48 2.84 MWD IFR MSA - 25 2158.90 62.63 79.93 92.81 1816.62 906.89 150.50 898.55 911. 07 80.49 5.83 MWD IFR MSA 26 2252.74 63.16 80.20 93.84 1859.38 990.09 164.91 980.83 994.60 80.46 0.62 MWD IFR MSA - 27 2347.03 64.75 79.83 94.29 1900.78 1074.48 179.60 1064.26 1079.31 80.42 1. 72 MWD IFR MSA - 28 2439.44 64.29 78.80 92.41 1940.53 1157.66 195.06 1146.24 1162.72 80.34 1.12 MWD IFR MSA - 29 2532.96 65.34 78.43 93.52 1980.33 1242.13 211.77 1229.20 1247.31 80.22 1.18 MWD IFR MSA - 30 2627.17 67.87 78.44 94.21 2017.73 1328.43 229.10 1313.90 1333.73 80.11 2.69 MWD IFR MSA SCHLUMBERGER Survey Report 7-Jan-2004 18:24:45 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2719.46 67.52 77.75 92.29 2052.76 1413.69 246.72 1397.45 1419.06 79.99 0.79 MWD IFR MSA - 32 2811.94 66.61 76.86 92.48 2088.80 1498.79 265.43 1480.53 1504.14 79.84 1.32 MWD IFR MSA - 33 2903.69 65.43 76.64 91.75 2126.09 1582.58 284.64 1562.13 1587.85 79.67 1.30 MWD IFR MSA - 34 2995.29 66.83 77.41 91.60 2163.16 1666.28 303.45 1643.76 1671.53 79.54 1. 71 MWD IFR MSA - 35 3087.98 66.70 78.34 92.69 2199.72 1751. 35 321.34 1727.03 1756.67 79.46 0.93 MWD IFR MSA 36 3183.50 66.41 77.69 95.52 2237.73 1838.86 339.53 1812.75 1844.27 79.39 0.69 MWD IFR MSA . 37 3278.03 65.17 77.08 94.53 2276.49 1925.00 358.36 1896.88 1930.44 79.30 1.44 MWD IFR MSA 38 3372.61 64.91 77.04 94.58 2316.40 2010.69 377.56 1980.45 2016.12 79.21 0.28 MWD IFR MSA - 39 3466.13 67.35 77.68 93.52 2354.24 2096.13 396.27 2063.90 2101.59 79.13 2.68 MWD IFR MSA - 40 3559.14 66.75 78.06 93.01 2390.51 2181.67 414.27 2147.63 2187.22 79.08 0.75 MWD IFR MSA 41 3648.94 65.46 77.53 89.80 2426.89 2263.68 431. 62 2227.88 2269.30 79.04 1.53 MWD IFR MSA - 42 3741. 72 65.02 77.33 92.78 2465.74 2347.85 449.96 2310.11 2353.52 78.98 0.51 MWD IFR MSA - 43 3828.89 66.39 77.89 87.17 2501.61 2427.22 467.00 2387.70 2432.95 78.93 1.68 MWD IFR MSA - 44 3932.50 65.77 77.77 103.61 2543.62 2521.81 486.97 2480.29 2527.64 78.89 0.61 MWD IFR MSA 45 4026.29 65.19 78.24 93.79 2582.54 2607.02 504.70 2563.75 2612.96 78.86 0.77 MWD IFR MSA 46 4118.67 65.69 79.80 92.38 2620.94 2690.84 520.70 2646.24 2696.98 78.87 1. 63 MWD IFR MSA - 47 4212.07 65.33 79.49 93.40 2659.66 2775.55 535.98 2729.85 2781.97 78.89 0.49 MWD IFR MSA - 48 4306.17 65.21 79.75 94.10 2699.02 2860.75 551. 38 2813.92 2867.43 78.91 0.28 MWD IFR MSA 49 4417.36 62.56 79.56 111.19 2747.96 2960.25 569.31 2912.13 2967.25 78.94 2.39 MWD IFR MSA 50 4511.53 66.42 80.52 94.17 2788.51 3044.89 583.99 2995.82 3052.21 78.97 4.20 MWD IFR MSA 51 4605.12 65.43 81. 23 93.59 2826.69 3129.89 597.55 3080.19 3137.61 79.02 1.26 MWD IFR MSA . 52 4697.53 66.96 81. 21 92.41 2863.99 3213.93 610.45 3163.74 3222.10 79.08 1. 66 MWD IFR MSA - 53 4791.30 66.61 80.90 93.77 2900.95 3299.63 623.85 3248.87 3308.22 79.13 0.48 MWD IFR MSA 54 4884.01 65.46 80.30 92.71 2938.61 3383.94 637.68 3332.45 3392.91 79.17 1. 37 MWD IFR MSA - 55 4977.70 66.93 80.38 93.69 2976.42 3469.29 652.07 3416.95 3478.61 79.20 1. 57 MWD IFR MSA 56 5069.03 66.87 80.06 91. 33 3012.25 3552.95 666.34 3499.74 3562.61 79.22 0.33 MWD IFR MSA - 57 5161.40 65.77 80.65 92.37 3049.35 3637.17 680.51 3583.13 3647.18 79.25 1. 33 MWD IFR MSA 58 5253.33 66.00 80.88 91.93 3086.91 3720.65 693.98 3665.95 3731.06 79.28 0.34 MWD IFR MSA - 59 5347.59 65.99 81.38 94.26 3125.26 3806.27 707.25 3751.03 3817.12 79.32 0.48 MWD IFR MSA - 60 5441. 57 65.58 81.72 93.98 3163.81 3891.42 719.85 3835.81 3902.77 79.37 0.55 MWD IFR MSA SCHLUMBERGER Survey Report 7-Jan-2004 18:24:45 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5533.96 65.77 82.31 92.39 3201.86 3974.97 731. 54 3919.18 3986.87 79.43 0.62 MWD IFR MSA - 62 5626.81 65.23 82.42 92.85 3240.37 4058.77 742.77 4002.92 4071.25 79.49 0.59 MWD IFR MSA - 63 5720.41 66.24 81.95 93.60 3278.83 4143.43 754.37 4087.46 4156.49 79.54 1.17 MWD IFR MSA - 64 5814.24 66.17 82.17 93.83 3316.69 4228.63 766.23 4172.49 4242.26 79.59 0.23 MWD IFR MSA - 65 5906.12 65.17 82.57 91.88 3354.54 4311.66 777.35 4255.46 4325.88 79.65 1.16 MWD IFR MSA 66 6001.16 64.86 82.01 95.04 3394.69 4397.10 788.91 4340.83 4411.94 79.70 0.63 MWD IFR MSA . - 67 6095.07 65.46 80.82 93.91 3434.14 4481.79 801. 63 4425.10 4497.12 79.73 1.32 MWD IFR MSA - 68 6187.35 67.73 77.39 92.28 3470.80 4566.24 817.65 4508.23 4581.78 79.72 4.21 MWD IFR MSA - 69 6279.26 71.21 74.90 91.91 3503.03 4652.27 838.28 4591. 77 4667.66 79.65 4.56 MWD IFR MSA - 70 6372.70 72.98 71. 30 93.44 3531. 77 4741.12 864.14 4676.82 4755.99 79.53 4.13 MWD IFR MSA 71 6465.19 74.51 66.90 92.49 3557.67 4829.41 895.81 4759.74 4843.31 79.34 4.86 MWD IFR MSA 72 6558.06 74.80 63.10 92.87 3582.25 4917.59 933.66 4840.89 4930.11 79.08 3.96 MWD IFR MSA - 73 6651.14 75.83 59.96 93.08 3605.85 5005.14 976.58 4920.03 5016.01 78.77 3.45 MWD IFR MSA - 74 6744.29 75.24 59.92 93.15 3629.12 5092.24 1021.76 4998.09 5101.46 78.45 0.63 MWD IFR MSA 75 6837.15 74.38 60.23 92.86 3653.45 5178.83 1066.46 5075.76 5186.59 78.13 0.98 MWD IFR MSA 76 6930.01 74.65 58.65 92.86 3678.25 5265.04 1111.96 5152.82 5271. 43 77.82 1.67 MWD IFR MSA - 77 7023.18 76.51 57.15 93.17 3701.45 5351.27 1159.91 5229.25 5356.35 77.49 2.53 MWD IFR MSA - 78 7117.04 79.31 56.45 93.86 3721.10 5438.45 1210.17 5306.04 5442.29 77.15 3.07 MWD IFR MSA - 79 7211.21 77.94 57.10 94.17 3739.68 5526.14 1260.75 5383.26 5528.92 76.82 1.60 MWD IFR MSA - 80 7305.15 76.54 56.20 93.94 3760.43 5613 .10 1311.11 5459.79 5615.01 76.50 1. 76 MWD IFR MSA 81 7398.81 75.77 56.97 93.66 3782.84 5699.38 1361.19 5535.70 5700.60 76.19 1.15 MWD IFR MSA . - 82 7492.18 78.56 57.46 93.37 3803.58 5786.05 1410.48 5612.23 5786.76 75.89 3.03 MWD IFR MSA - 83 7585.79 77.74 56.74 93.61 3822.80 5873.23 1460.24 5689.15 5873.56 75.60 1.15 MWD IFR MSA - 84 7679.16 76.37 56.33 93.37 3843.72 5959.54 1510.42 5765.06 5959.64 75.32 1. 53 MWD IFR MSA - 85 7773.13 76.45 57.31 93.97 3865.80 6046.32 1560.41 5841.50 6046.32 75.04 1. 02 MWD IFR MSA 86 7866.13 77.09 58.70 93.00 3887.08 6132.90 1608.37 5918.28 6132.94 74.80 1. 61 MWD IFR MSA - 87 7960.25 77.10 59.08 94.12 3908.10 6221.04 1655.77 5996.83 6221. 22 74.56 0.39 MWD IFR MSA - 88 8055.20 75.95 59.39 94.95 3930.23 6309.90 1703.01 6076.17 6310.31 74.34 1.25 MWD IFR MSA 89 8148.27 75.20 60.23 93.07 3953.41 6396.88 1748.33 6154.08 6397.60 74.14 1.19 MWD IFR MSA 90 8241.63 73.25 61.88 93.36 3978.79 6484.07 1791. 82 6232.69 6485.14 73.96 2.69 MWD IFR MSA .. SCHLUMBERGER Survey Report 7-Jan-2004 18:24:45 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8334.51 71.72 63.61 92.88 4006.75 6570.62 1832.38 6311. 42 6572.03 73.81 2.42 MWD IFR MSA - 92 8428.43 69.58 63.56 93.92 4037.87 6657.47 1871.80 6390.78 6659.25 73.68 2.28 MWD IFR MSA - 93 8521.03 66.67 65.04 92.60 4072.36 6741.90 1909.07 6468.19 6744.04 73.56 3.47 MWD IFR MSA - 94 8613.69 63.59 65.47 92.66 4111.33 6824.74 1944.26 6544.53 6827.23 73.45 3.35 MWD IFR MSA - 95 8708.40 59.82 67.87 94.71 4156.22 6907.23 1977.30 6621.07 6910.02 73.37 4.56 MWD IFR MSA 96 8802.35 58.47 68.62 93.95 4204.40 6987.32 2007.20 6695.98 6990.35 73.31 1.59 MWD IFR MSA . 97 8895.43 56.32 68.81 93.08 4254.56 7065.25 2035.66 6769.03 7068.50 73.26 2.32 MWD IFR MSA - 98 8988.83 54.32 69.13 93.40 4307.70 7141.63 2063.23 6840.72 7145.09 73.22 2.16 MWD IFR MSA - 99 9083.14 52.79 68.68 94.31 4363.72 7217.07 2090.53 6911. 50 7220.74 73.17 1. 67 MWD IFR MSA - 100 9176.62 52.00 69.24 93.48 4420.76 7290.71 2117.12 6980.62 7294.60 73.13 0.97 MWD IFR MSA 101 9269.37 51. 41 69.91 92.75 4478.24 7363.18 2142.52 7048.83 7367.26 73.09 0.85 MWD IFR MSA - 102 9362.54 51.37 69.99 93.17 4536.38 7435.70 2167.48 7117.23 7439.95 73.06 0.08 MWD IFR MSA 103 9454.59 51. 34 70.04 92.05 4593.87 7507.32 2192.05 7184.79 7511.75 73.03 0.05 MWD IFR MSA - 104 9548.47 50.43 69.92 93.88 4653.09 7579.88 2216.99 7253.23 7584.48 73.00 0.97 MWD IFR MSA - 105 9642.10 50.42 70.39 93.63 4712.74 7651.79 2241.49 7321.11 7656.56 72.98 0.39 MWD IFR MSA 106 9735.33 49.78 71.16 93.23 4772.55 7723.12 2265.04 7388.64 7728.03 72.96 0.93 MWD IFR MSA - 107 9828.86 48.70 70.96 93.53 4833.61 7793.79 2288.03 7455.65 7798.84 72.94 1.17 MWD IFR MSA 108 9922.76 48.15 71. 43 93.90 4895.92 7863.88 2310.68 7522.15 7869.05 72.92 0.70 MWD IFR MSA - 109 9967.18 47.96 71.11 44.42 4925.61 7896.85 2321. 29 7553.44 7902.07 72.92 0.69 MWD IFR MSA 110 10040.00 47.96 71.11 72.82 4974.38 7950.81 2338.80 7604.61 7956.13 72.90 0.00 Projected to TD . [ (c) 2004 IDEAL ID8 1C_UPGRADE] SCHLUMBERGER Survey report Client........... ........: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: ORION Well. . . . . . . . . . . . . . . . . . . . .: L-210i API number.......... .....: 50-029-23187-00 Engineer. . . . . . . . . . . . . . . . .: E. Roux 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..........: Driller's Pipe Tally GL above permanent.......: 49.85 ft KB above permanent... ....: NjA - Top Drive DF above permanent.. .....: 79.30 ft ----- Vertical section origin---------------- Latitude (+NjS-).. .......: 0.00 ft Departure (+EjW-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+NjS-) .........: N 70.35075763 Departure (+EjW-) ........: W 149.32323966 Azimuth from rotary table to target: 75.00 degrees '~~'D\1\ ~ 11-Jan-2004 09:24:27 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: c9C)3-,CtC( Page 1 of 5 01-Jan-04 11-Jan-04 106 0.00 ft 9668.00 ft . ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2003 Magnetic date... .........: 01-Jan-2004 Magnetic field strength..: 1151.08 HCNT Magnetic dec (+EjW-).....: 25.12 degrees Magnetic dip.... .........: 80.82 degrees ----- MWD survey Reference Reference G... ......... ..: Reference H... ...........: Reference Dip. ........ ...: Tolerance of G.. .........: Tolerance of H.. .........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.48 HCNT 80.79 degrees (+j-) 2.50 mGal (+j-) 6.00 HCNT (+j-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+EjW-).....: 25.31 degrees Grid convergence (+EjW-).: 0.00 degrees Total az corr (+EjW-)....: 25.31 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=SchlumbergerMagnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction RECEIVED R=Magnetic Resonance Tool Correction " . ' . ' D=Dmag Magnetic Correction .... ~ 0.0'"\ ~ í , ,\, . J , ."\ v·· (.~ ,-'/\;'; L. 0 I..' ... AÏa~eOiI& Gas Cons,Comm_ ¡lll~ SCHLUMBERGER Survey Report 11-Jan-2004 09:24:27 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tie-in Point 2 100.00 0.31 295.40 100.00 100.00 -0.21 0.12 -0.24 0.27 295.40 0.31 GYRO 3 200.00 0.07 183.85 100.00 200.00 -0.43 0.17 -0.49 0.52 289.15 0.34 GYRO 4 300.00 3.37 118.44 100.00 299.94 1. 68 -1.29 2.09 2.45 121.71 3.34 GYRO 5 400.00 5.98 112.64 100.00 399.60 7.94 -4.70 9.48 10.58 116.35 2.65 GYRO 6 500.00 7.76 104.03 100.00 498.88 17.97 -8.34 20.84 22.45 111.81 2.05 GYRO . 7 546.00 9.37 96.79 46.00 544.37 24.17 -9.53 27.57 29.17 109.07 4.21 GYRO 8 570.88 10.02 87.21 24.88 568.89 28.16 -9.67 31.75 33.19 106.94 6.98 MWD IFR MSA - 9 662.68 11. 57 79.39 91. 80 659.07 45.15 -7.58 48.77 49.36 98.84 2.32 MWD IFR MSA - 10 755.14 14.30 84.28 92 .46 749.18 65.67 -4.74 69.25 69.41 93.91 3.18 MWD IFR MSA 11 847.29 16.73 80.61 92.15 837.97 90.10 -1.44 93.67 93.68 90.88 2.84 MWD IFR MSA 12 940.15 20.21 78.99 92.86 926.03 119.41 3.81 122.61 122.67 88.22 3.79 MWD IFR MSA - 13 1034.01 22.76 80.62 93.86 1013.36 153.66 9.86 156.44 156.75 86.39 2.79 MWD IFR MSA - 14 1126.61 26.07 81. 20 92.60 1097.67 191.73 15.90 194.23 194.88 85.32 3.58 MWD IFR MSA - 15 1219.91 29.57 80.88 93.30 1180.17 235.02 22.68 237.23 238.32 84.54 3.75 MWD IFR MSA 16 1313 .11 31.87 79.67 93.20 1260.29 282.43 30.74 284.15 285.81 83.83 2.56 MWD IFR MSA - 17 1407.33 36.02 79.21 94.22 1338.44 334.87 40.39 335.86 338.28 83.14 4.41 MWD IFR MSA - 18 1498.35 40.94 78.02 91.02 1409.67 391. 38 51. 60 391. 36 394.74 82.49 5.47 MWD IFR MSA - 19 1595.60 45.84 79.48 97.25 1480.32 458.01 64.59 456.86 461.41 81.95 5.14 MWD IFR MSA - 20 1689.14 50.20 78.14 93.54 1542.87 527.38 78.11 525.05 530.83 81.54 4.78 MWD IFR MSA 21 1784.93 50.20 76.20 95.79 1604.19 600.91 94.45 596.80 604.23 81.01 1. 56 MWD IFR MSA . - 22 1878.39 52.56 78 .27 93.46 1662.52 673.86 110.56 668.01 677.10 80.60 3.06 MWD IFR MSA - 23 1972.29 54.98 79.98 93.90 1718.02 749.40 124.83 742.39 752.81 80.46 2.97 MWD IFR MSA - 24 2066.09 57.37 81. 39 93.80 1770.23 826.93 137.43 819.28 830.72 80.48 2.84 MWD IFR MSA - 25 2158.90 62.63 79.93 92.81 1816.62 906.89 150.50 898.55 911.07 80.49 5.83 MWD IFR MSA 26 2252.74 63.16 80.20 93.84 1859.38 990.09 164.91 980.83 994.60 80.46 0.62 MWD IFR MSA 27 2347.03 64.75 79.83 94.29 1900.78 1074.48 179.60 1064.26 1079.31 80.42 1. 72 MWD IFR MSA - 28 2439.44 64.29 78.80 92.41 1940.53 1157.66 195.06 1146.24 1162.72 80.34 1.12 MWD IFR MSA - 29 2532.96 65.34 78.43 93.52 1980.33 1242.13 211.77 1229.20 1247.31 80.22 1.18 MWD IFR MSA - 30 2627.17 67.87 78.44 94.21 2017.73 1328.43 229.10 1313.90 1333.73 80.11 2.69 MWD IFR MSA SCHLUMBERGER Survey Report 11-Jan-2004 09:24:27 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2719.46 67.52 77.75 92.29 2052.76 1413.69 246.72 1397.45 1419.06 79.99 0.79 MWD IFR MSA 32 2811. 94 66.61 76.86 92 .48 2088.80 1498.79 265.43 1480.53 1504.14 79.84 1.32 MWD IFR MSA - 33 2903.69 65.43 76.64 91.75 2126.09 1582.58 284.64 1562.13 1587.85 79.67 1. 30 MWD IFR MSA 34 2995.29 66.83 77.41 91.60 2163.16 1666.28 303.45 1643.76 1671 . 53 79.54 1. 71 MWD IFR MSA - 35 3087.98 66.70 78.34 92.69 2199.72 1751. 35 321. 34 1727.03 1756.67 79.46 0.93 MWD IFR MSA 36 3183.50 66.41 77.69 95.52 2237.73 1838.86 339.53 1812.75 1844.27 79.39 0.69 MWD IFR MSA . - 37 3278.03 65.17 77.08 94.53 2276.49 1925.00 358.36 1896.88 1930.44 79.30 1.44 MWD IFR MSA - 38 3372.61 64.91 77.04 94.58 2316.40 2010.69 377.56 1980.45 2016.12 79.21 0.28 MWD IFR MSA - 39 3466.13 67.35 77.68 93.52 2354.24 2096.13 396.27 2063.90 2101.59 79.13 2.68 MWD IFR MSA - 40 3559.14 66.75 78.06 93.01 2390.51 2181.67 414.27 2147.63 2187.22 79.08 0.75 MWD IFR MSA 41 3648.94 65.46 77.53 89.80 2426.89 2263.68 431. 62 2227.88 2269.30 79.04 1. 53 MWD IFR MSA - 42 3741.72 65.02 77.33 92.78 2465.74 2347.85 449.96 2310.11 2353.52 78.98 0.51 MWD IFR MSA 43 3828.89 66.39 77.89 87.17 2501.61 2427.22 467.00 2387.70 2432.95 78.93 1. 68 MWD IFR MSA - 44 3932.50 65.77 77.77 103.61 2543.62 2521.81 486.97 2480.29 2527.64 78.89 0.61 MWD IFR MSA - 45 4026.29 65.19 78.24 93.79 2582.54 2607.02 504.70 2563.75 2612.96 78.86 0.77 MWD IFR MSA 46 4118.67 65.69 79.80 92.38 2620.94 2690.84 520.70 2646.24 2696.98 78.87 1. 63 MWD IFR MSA - 47 4212.07 65.33 79.49 93.40 2659.66 2775.55 535.98 2729.85 2781.97 78.89 0.49 MWD IFR MSA - 48 4306.17 65.21 79.75 94.10 2699.02 2860.75 551. 38 2813.92 2867.43 78.91 0.28 MWD IFR MSA - 49 4417.36 62.56 79.56 111.19 2747.96 2960.25 569.31 2912.13 2967.25 78.94 2.39 MWD IFR MSA - 50 4511.53 66.42 80.52 94.17 2788.51 3044.89 583.99 2995.82 3052.21 78.97 4.20 MWD IFR MSA 51 4605.12 65.43 81. 23 93.59 2826.69 3129.89 597.55 3080.19 3137.61 79.02 1.26 MWD IFR MSA . 52 4697.53 66.96 81. 21 92.41 2863.99 3213.93 610.45 3163.74 3222.10 79.08 1. 66 MWD IFR MSA - 53 4791.30 66.61 80.90 93.77 2900.95 3299.63 623.85 3248.87 3308.22 79.13 0.48 MWD IFR MSA - 54 4884.01 65.46 80.30 92.71 2938.61 3383.94 637.68 3332.45 3392.91 79.17 1. 37 MWD IFR MSA - 55 4977.70 66.93 80.38 93.69 2976.42 3469.29 652.07 3416.95 3478.61 79.20 1. 57 MWD IFR MSA 56 5069.03 66.87 80.06 91.33 3012.25 3552.95 666.34 3499.74 3562.61 79.22 0.33 MWD IFR MSA - 57 5161.40 65.77 80.65 92.37 3049.35 3637.17 680.51 3583.13 3647.18 79.25 1. 33 MWD IFR MSA - 58 5253.33 66.00 80.88 91.93 3086.91 3720.65 693.98 3665.95 3731.06 79.28 0.34 MWD IFR MSA - 59 5347.59 65.99 81. 38 94.26 3125.26 3806.27 707.25 3751.03 3817.12 79.32 0.48 MWD IFR MSA - 60 5441. 57 65.58 81.72 93.98 3163.81 3891.42 719.85 3835.81 3902.77 79.37 0.55 MWD IFR MSA SCHLUMBERGER Survey Report 11-Jan-2004 09:24:27 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5533.96 65.77 82.31 92.39 3201. 86 3974.97 731.54 3919.18 3986.87 79.43 0.62 MWD IFR MSA 62 5626.81 65.23 82.42 92.85 3240.37 4058.77 742.77 4002.92 4071.25 79.49 0.59 MWD IFR MSA 63 5720.41 66.24 81. 95 93.60 3278.83 4143.43 754.37 4087.46 4156.49 79.54 1.17 MWD IFR MSA 64 5814.24 66.17 82.17 93.83 3316.69 4228.63 766.23 4172.49 4242.26 79.59 0.23 MWD IFR MSA 65 5906.12 65.17 82.57 91.88 3354.54 4311.66 777.35 4255.46 4325.88 79.65 1.16 MWD IFR MSA 66 6001.16 64.86 82.01 95.04 3394.69 4397.10 788.91 4340.83 4411. 94 79.70 0.63 MWD IFR MSA . 67 6093.10 65.19 80.76 91.94 3433.51 4479.93 801.39 4423.23 4495.24 79.73 1. 28 MWD IFR MSA 68 6186.74 61. 67 81.14 93.64 3475.38 4563.22 814.57 4505.93 4578.96 79.75 3.78 MWD IFR MSA 69 6279.13 62.92 80.67 92.39 3518.34 4644.58 827.50 4586.69 4660.74 79.77 1.43 MWD IFR MSA - 70 6372.21 62.51 80.92 93.08 3561.01 4726.88 840.73 4668.35 4743.45 79.79 0.50 MWD IFR MSA 71 6464.22 65.48 80.17 92.01 3601.34 4809.18 854.32 4749.91 4826.13 79.80 3.31 MWD IFR MSA - 72 6558.40 66.65 80.07 94.18 3639.55 4894.91 869.09 4834.71 4912.21 79.81 1. 25 MWD IFR MSA - 73 6652.26 65.80 80.06 93.86 3677.39 4980.47 883.91 4919.32 4998.10 79.81 0.91 MWD IFR MSA - 74 6745.55 65.93 79.80 93.29 3715.54 5065.29 898.80 5003.14 5083.23 79.82 0.29 MWD IFR MSA - 75 6838.24 66.05 79.40 92.69 3753.25 5149.69 914.08 5086.42 5167.90 79.81 0.41 MWD IFR MSA 76 6930.92 66.00 78.90 92.68 3790.91 5234.15 930.02 5169.59 5252.58 79.80 0.50 MWD IFR MSA - 77 7023.68 65.43 77.94 92.76 3829.06 5318.55 946.99 5252.42 5337.11 79.78 1.13 MWD IFR MSA - 78 7119.23 65.23 77.68 95.55 3868.94 5405.27 965.33 5337.29 5423.88 79.75 0.32 MWD IFR MSA - 79 7212.75 66.38 76.60 93.52 3907.27 5490.51 984.32 5420.45 5509.10 79.71 1.62 MWD IFR MSA - 80 7306.32 66.81 77.73 93.57 3944.44 5576.32 1003.39 5504.18 5594.89 79.67 1.20 MWD IFR MSA 81 7400.19 67.49 77.35 93.87 3980.89 5662.74 1022.06 5588.64 5681.33 79.64 0.81 MWD IFR MSA . 82 7493.51 66.96 78.02 93.32 4017.02 5748.69 1040.41 5672.70 5767.32 79.61 0.87 MWD IFR MSA 83 7586.87 67.82 78.42 93.36 4052.91 5834.74 1058.00 5757.07 5853.48 79.59 1. 00 MWD IFR MSA 84 7680.47 67.06 78.56 93.60 4088.82 5921.01 1075.25 5841.77 5939.90 79.57 0.82 MWD IFR MSA - 85 7774.45 67.75 79.54 93.98 4124.93 6007.56 1091.73 5926.96 6026.66 79.56 1.21 MWD IFR MSA 86 7867.56 67.90 79.64 93.11 4160.07 6093.51 1107.31 6011.76 6112.89 79.56 0.19 MWD IFR MSA - 87 7961.55 67.64 79.90 93.99 4195.63 6180.21 1122.76 6097.38 6199.89 79.57 0.38 MWD IFR MSA 88 8056.10 66.43 81.19 94.55 4232.52 6266.85 1137.07 6183.25 6286.93 79.58 1. 79 MWD IFR MSA - 89 8149.17 66.67 82.48 93.07 4269.56 6351.63 1149.19 6267.77 6372.25 79.61 1. 30 MWD IFR MSA - 90 8243.08 66.68 83.96 93.91 4306.75 6436.97 1159.37 6353.39 6458.31 79.66 1.45 MWD IFR MSA SCHLUMBERGER Survey Report 11-Jan-2004 09:24:27 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8335.18 65.93 84.81 92.10 4343.76 6520.18 1167.62 6437.32 6542.36 79.72 1.17 MWD IFR MSA - 92 8428.46 65.60 90.42 93.28 4382.07 6603.14 1171.17 6522.26 6626.58 79.82 5.50 MWD IFR MSA - 93 8521.96 64.14 93.85 93.50 4421. 79 6684.02 1168.03 6606.83 6709.29 79.97 3.67 MWD IFR MSA - 94 8613.88 63.55 97 .39 91.92 4462.32 6761.23 1159.96 6688.93 6788.76 80.16 3.52 MWD IFR MSA - 95 8708.31 63.09 100.97 94.43 4504.73 6838.18 1146.51 6772.20 6868.57 80.39 3.42 MWD IFR MSA 96 8801.36 62.17 102.18 93.05 4547.51 6912.09 1129.93 6853.16 6945.68 80.64 1. 52 MWD IFR MSA . 97 8895.51 62.00 102.52 94.15 4591.58 6985.98 1112.14 6934.43 7023.04 80.89 0.37 MWD IFR MSA 98 8988.65 60.96 102.78 93.14 4636.06 7058.47 1094.21 7014.28 7099.11 81.13 1.14 MWD IFR MSA - 99 9081.73 60.20 102.71 93.08 4681.78 7130.23 1076.33 7093.35 7174.55 81.37 0.82 MWD IFR MSA 100 9175.43 59.64 103.00 93.70 4728.74 7201.91 1058.29 7172.40 7250.06 81. 61 0.65 MWD IFR MSA 101 9268.96 58.99 103.12 93.53 4776.47 7272.89 1040.11 7250.76 7324.98 81.84 0.70 MWD IFR MSA - 102 9361.93 57.78 103.34 92.97 4825.20 7342.65 1022.00 7327.83 7398.75 82.06 1.32 MWD IFR MSA - 103 9454.49 57.01 103.32 92.56 4875.08 7411.28 1004.02 7403.70 7471.47 82.28 0.83 MWD IFR MSA 104 9548.37 56.22 103.25 93.88 4926.74 7480.31 986.00 7479.99 7544.70 82.49 0.84 MWD IFR MSA 105 9593.73 55.91 103.05 45.36 4952.06 7513.49 977.44 7516.64 7579.92 82.59 0.78 MWD IFR MSA 106 9668.00 55.91 103.05 74.27 4993.69 7567.78 963.55 7576.55 7637.58 82.75 0.00 Projected to TD [(c)2004 IDEAL ID8_1C_UPGRADE] . . ~Q3--/9( . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L -21 Oi PB 1 Date Dispatched: 23-Jan-04 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECEIV:D IN'! 2620)4 Alaska ( il & Gas Cons. C..1mrnis11on ÞJl~ Received By: ~«'.. ~, ~\\ ~ )">(, Ù,~t'::-/v", Please sign and return to: Drilling & Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose l@slb.com Fax: 907-561-8417 LWD Log Delivery V 1.1 , 10-02-03 "~~~\~~ Schlumberger Private . . d03'- \9'l Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-210i Date Dispatched: 23-Jan-04 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 F~ECE'V:D ,.., 6 '1'1o{'\' !AI! ( t:.W4 ~. \; I: ...... Received By: ~~(.:\~ /y~ ~ <:.J ~~ §'/"\,~ Ala~a')ii& Gas Coos,COmmÏliOn A!i~agi; Please sign and return to: Drilling & Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907-561-8417 LWD Log Delivery Vl.l, 10-02-03 Schlumberger Private ~':t~~ N"- ~ . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: TO: Jim Regg \<; I I A '\ //101" I ~ 0., P.I. Supervisor ý[[¡ Jeff Jones Petroleum Inspector Section: 34 Lease No.: 028238 Operator Rep.: Daryl Green Township: 12N Drilling Rig: Nabors 9ES CasinqlTubinq Data: Conductor: 20" O.D. Shoe@ 110' MD Surface: 9 5/8" O.D. Shoe@ 4368' MD Intermediate: O.D. Shoe@ Production: O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ Type Pluq (bottom up) Open Hole Open Hole Type Pluq Open Hole Perforation Annulus Casing Stub Surface DATE: January 9,2004 SUBJECT: Plug & Abandonement L-21 0 BPXA I L Pad Prudhoe Bay Field PBU ';."" NON- CONFIDENTIAL Range: 11 E Rig Elevation: 25.88 Meridian: UM Total Depth: 10040 Casinq Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Founded on Bottom of Cement 10040' MD 9150' MD Pluqqinq Data: Top of Cement Depth Verified? 9150' MD No 8250' MD No Pressure Test Applied ~ Mud Weight above plug 9.3 ppg 9.3 ppg January 9, 2004: I traveled to Nabors rig 9ES to witness the tag of a cement abandonment plug in BPXA's Prudhoe Bay Field well L-210. Rev.:5/28/00 by L.R.G. Bottom Balanced Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No Nabors personnel were RIH to tag the abandonment plug on my arrival. Top of cement was estimated to be at 8250' MD +1-. The rig was unable to penetrate a tight spot encountered at 7056' MD. Numerous attempts were made to ream through the tight spot with no success. BPXA representative Daryl Green believed that due to the high angle and formation characteristics of this hole section that they were beginning to sidetrack the hole and aborted the attempt to tag the cement plug. Bottoms up were circulated at this point and I checked the samples and noted a PH rise to 11.5 and viscosity of 75, consistent with cement contaminated mud. Summary: I witnessed an unsuccessful attempt to tag the top of a cement abandonment plug in BPXA's Prudhoe Bay Field well L-210. Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Attachments: none bJ -Aß(;cC beCcL~ pG~' cM= ,~c)'~ CeNIC/d- l/~\ pk¡«~ f-¿'II~ ell--C~,-,Iiw~ ./ \ S<.t~ ý?ð V0d ~ OJ It' .Ái~J G0tt I veJ· .x-:-/ (J l'~ t f('5'(C4 1/15/2004 T<'j reß(,{,( reJ el.J¡Ç~Cê ü ~ k:>o-I4vJv!S L1¡f0 ~v\S P&A PBU L-210 1-9-04 JJ.xls · AI1ASIiA. OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519-6612 - FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Re: Prudhoe Bay Unit L-210L Pennit No: 203-199 Surface Location: 2605' NSL, 3559' WEL, Sec. 34, T12N, RIlE, UM Bottomhole Location: 3528' NSL, 4012' EWL, Sec. 35, TI2N, RIlE, UM Dear Mr.Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pa er). Sincerely, ~ Sarah Palin Chair BY ORDER OF THE COMMISSION /1/> DATED this~ day of December, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. f.uGI\- 1l.-I'I2.00-S II Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2605' NSL, 3559'WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 3743' NSL, 3217' EWL, SEC. 35, T12N, R11E, UM Total Depth: 3528' NSL, 4012' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-583354 y-5978328 Zone-ASP4 16. Deviated Wells: Kickoff Depth 1$;··. Casing Progr~m Size Casing 20" x 34" 9-5/8" .. STATE OF ALASKA _ ALASKA OI~D GAS CONSERVATION COMI\.IIaION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test II Service 5. Bond: aD Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 9750 TVD 4899 7. Property Designation: ADL 028238 o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU L-210i 12. Field I Pool(s): Prudhoe Bay Field I Orion 8. Land Use Permit: 13. Approximate Spud Date: December 15,2003 ~ 14. Distance to Nearest Property: 4,473' 9. Acres in Property: 2560 Hole 48" 12-1/4" 8-3/4" Weight 215.5# 40# 26# Grade A53 L-80 L-80 Coupling Weld BTC BTC-M Length 80' 4210' 9721' 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 72.6 feet L-102 is 2420' away at 6775' MD 17. Anticipated pressure (see 20 MC 25.035) / Max. Downhole Pressure: 2220 psig. Max. Surface Pressure: 1730 psig S~tting.peptþ· '....'. Quantity of Cement Töp , ' " "Bottom (c.f. or sacks) MD TVD MD TVD (including stage data) 29' 29' 109' 109' 260 sx Arctic Set (Approx.) 29' 29' 4239' 2698' 628 sx Arcticset Lite, 387 sx 'G' ./ 29' 29' 9750' 4961' 454 sx Class 'G' ./ 300 ft Maximum Hole Angle 77° 7" 19. PRESeNT WELLCONDIJIONSUMMARY (Tobecornpletedfor RedriUAND Re-entry QpEJrations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Depth TVD (ft): Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments aD Filing Fee 0 BOP Sketch aD Property Plat 0 Diverter Sketch IperfOration Depth TVD (ft): aD Drilling Program 0 Time vs Depth Plot o Seabed Report aD Drilling Fluid Program o Shallow Hazard Analysis aD ,20 MC 25.050 Requirements Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Namefwell Crane Title Senior Drilling Engineer Signatu~,~~-1 ;l~~ Phone 564-4089 Date /1-.2j--e:..) L/ Commission Use Only Permit To Drill , I API Number: ." I Permit APprral, }'¿ I See cover letter for Number:..2 (). ?- / '7'y 50- C);L ~~ - 2. 3 / 8' 7 Date: It 21 ~J17 other requirements Conditions of Approval: Samples Required 0 Yes ø No Mud Log Re uire 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes l5?J No qirectional Survey Required ß Yes 0 No Other:Teç,.+ tboPE fo t...céi'O pç ,', HlIT) ttVl'l-l,"~.:f- õt(,¡;'Il;~ ¿'ð~ re'Û~ ~J . ¡ f Date: Contact Thomas Schaefer, 564-4685 Prepared By Name/Number: Terrie Hubble, 564-4628 Approved By: Form 10-401 Revised 3/2003 Original Signed By Sè«ah rolin COMMISSIONER BY ORDER OF THE COMMISSION Date /1Il2)0'7 S~~it In Duplicate ~~l .,rc" 1):;' 'r)h~, UL¡ ~;.., fu'1I!.~ " Greater .~udhoe Bay Orion L-210i Permit Well Plan SUmmary I Well Name: I L-21 Oi I Type of Well (producer or injector): I USH Injector Surface Location: 2,604' FSL, 3,559' FEL, Sec. 34, T12N, R11 E ./ X = 583,354 Y = 5,978,328 4,757' FSL, 3,320' FWL, Sec. 35, T12N, R11 E X = 590,205 Y = 5,980,560 Z = 4265' TVDss 5,040' FSL, 3,902' FWL, Sec. 35, T12N, R11 E X = 590,783 Y = 5,980,850 Z = 4900' TVDss 3,743' FSL, 3,217' FWL, Sec. 35, T12N, R11 E / X = 590,115 Y = 5,979,545 Z = 4,445' TVDss 3,528' FSL, 4,012' FWL, Sec. 35, T12N, R11E /' X = 590,913 Y = 5,979,340 Z = 4,889' TVDss L-210i Polygon 1A Target (Pilot Hole) Start: L-210i Polygon 1A Target (Pilot Hole) End: L-210i Polygon 2A Target Start: L-210i Polygon 2A Target End: I AFE Number: 15M3541 I Rig: 1 Nabors 9ES /' I Estimated Start Date: 1 Dec 15m 2003 / Operating days to complete: 119.22 1AMD 10,053' (Pilot) TVDrkb: TD 4,900' Max Inc. 77° KBE 72.60' 2A KOP 6,000' TVDrkb: TD 3,386' Inc. 6]0 KBE 72.60' 2AMD 9,750' TVDrkb: TD 4,899' Max Inc. 67° KBE 72.60' Well Design: USH Grassroots Schrader Injector. "r 4-W' X 3-%" TCII Completion. Current Well Information General L-210i PB1: Distance to Nearest Property: Distance to Nearest Well in Pool: -4,473' at TD to the nearest PBU property line 3,260' from PB1 top of OA at 9,396' MD to L-102 top OA at 6,775' MD Nc /Wi I,.I.J-!fl<. L-210i Mainbore: Distance to Nearest Property: Distance to Nearest Well in Pool: -5,530' at TD to the nearest PBU property line 2,420' from L-210i top of OA at 8,816' MD to L-102 top OA at 6,775' MD 50-029- ????? /' Development - Orion Schrader Injector New well, 20" X 34" insulated conductor 2,220 psi @ 4,900' TVDss (8.7 ppg EMW). Normal pressure ./ 2,195 psi @ 4,870' TVDss (8.7 ppg EMW). Normal pressure API Number: Well Type: Current Status: BHP (1A): gradient. BHP (2A): gradient. BHT: 100°F @ 4,888' TVDss Estimated (from L-pad Temp Log) Final Mechanical Condition L-210i: Nabors 9ES: Conductor: " Greater Prudhoe Bay Orion L-210i Permit Cellar Box above MSL = 44.1 ' KB I MSL = 28.5' 20" X 34", 215.5 Ibltt, A53 ERW set at 109' RKB % Mile Wellbore Near Wellbore Mechanical Integrity Summary: There are no other wells within )4 mile of this injector at it's penetration at the Top OA structure. No /~ Wellbore Near Wellbore integrity issues. Target Estimates Estimated Reserves: Materials Needed Surface Casing: Intermediate Casing: L-80 Completion: 1,950 mstb 4,231' 1 each 1 each 25 each 1 assembly 1 lot 9-%",40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 W' Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10', 20'. 9,750' 1 each 75 each 2 lots 2 each 2 each 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8)4" Rigid Straight Blade Centralizers 7" casing pups 5', 10',20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 8,900' 800' 2 each 1 each 2 each 4 each 1 each 1 each 1 each 4 each 1 each 1 each 4 112" 12.60 Ibltt, L-80, TCII tubing 3112" 9.30 I bItt , L-80, TCII tubing Baker PRM Production Packer 7" X 3-W' Baker S-3 Production Packer 7" X 3-%" Halliburton 4-112" X-Nipple (3.813" ID) Halliburton 3-W' X-Nipple (2.813" ID) 11" X 4-112" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 3-%" x 1-%" MMG GLM 3 W' RA Tag 3-%" WLEG 2 " Surface and Anti-Collision Issues Surface Shut-in Wells: Nearby Wells Distance to Target Well Rig N9ES Wellhead Separation L-119i 14.82 -15.18 L-120 15.34 -14.66 Greater Prudhoe Bay Orion L-210i Permit þ;- L103 59.91 34.91 Separation of the target wellhead from nearest well is 14.82 feet. Surface close approach limit for Nabors 9ES is 60 feet separation from rig structure to wellhead. Maximum rig width from centerline is 30'. Smallest rig to wellhead separation is therefore -15.18'. L -119 & L-120 will therefore require surface shut-in and wellhouse removal in order to move over well. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. c~~~~;Cø~~~rL~~ta~e L-119 13.77-ft L-120 16.75-ft L-103 59.64-ft Refere(fe .. 393.41-ft 243.49-ft 393.41-ft Survey and Logging Program , Allowable Deviation 7.46-ft 12.72-ft 53.34-ft Pr~_onary Comment Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) 12-1,4" Hole Section: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) Open Hole: MWD I GR Cased hole: None 8-3,4" Hole Section: MWD I GR I Res 1 Den 1 Neu I PWD (Den Neu recorded only) Cased Hole: USIT Bond Log Mud Program 121,4" Surface Hole Mud Properties: Interval Density (ppg) 8.6 - 8.6 - 9.2 9.0 - 9.5 9.5 Funnel vis 250-300 200-300 150-300 Initial Base Perm Interval TD 83,4" Intermediate Hole Mud Properties: Interval Pilot Hole 1 0,053 MD Mainbore 9,750' MD Density (ppg) 9.3 9.3 VP 25-30 22-28 3 I Spud - Freshwater Mud VP PH FL 45-70 9.0-9.5 NC 35-45 9.0-9.5 <8 25-35 9.0-9.5 <8 Freshwater Mud (LSND) PH: 9.0-9.5 <600 Chlorides PV API Filtrate MBT 12-20 6-8 < 20 12-20 4-5.5 < 20 e Greater Prudhoe Bay Orion L-210i Permit e Formation Markers (Based on Schlumberger WP6) L-210i Uphole Section (Above kick off point) Fault 1 -900 980 973 SV5 -1480 1639 1553 675 8.8 No Base Permafrost -1680 1929 1753 770 8.8 No Poss. Gas SV4 -1610 1820 1683 740 8.8 Hydrates Poss. Gas SV3 -1985 2601 2058 910 8.8 Hydrates Poss. Gas SV2 -2150 3024 2223 990 8.9 Hydrates SVl -2525 3983 2598 1160 8.8 Poss. Free Gas UG4 -2885 4905 2958 1300 8.7 No Heavy Oil betw 2915 and 3000' UG4A -2915 2988 4981 1310 8.6 SS Fault 2 -2965 5109 3038 9,~ UG3 -3140 5557 3212 1420 8.7 Maybe - Heavy Oil L-210ipbwp03 - Plugback hole section Heavy Oil betw 3700 and 3915' UGl -3620 7166 3693 1690 9.0 SS Heavy Oil betw Top Schrader BIuff/Ma 3915 and 3990' Sand -3980 8558 4053 1820 8.8 SS Mbl -4035 8689 4107 1825 8.7 No Fault 3 -4085 8798 4158 Mb2 - F/O 1850 No Mc -41 60 8950 4233 1895 8.8 No Na -4230 9081 4303 1925 8.8 No Nb -4265 9143 4338 1935 8.7 No Nc -4315 9228 4388 1950 8.7 Yes OA -4420 9396 4493 1995 8.7 Yes OBa -4495 9510 4568 2035 8.7 Yes OBb -4545 9582 4618 2070 8.8 Yes OBc -461 0 9674 4683 2095 8.7 Yes OBd -4665 9749 4738 2120 8.7 Yes OBe - Base injection interval -4735 4808 9843 2150 8.7 Yes OBf -4785 9908 4858 2175 8.7 Yes OBCBase -4830 9965 4903 2195 8.7 no PB Hole TD -4900 10052 4973 2220 8.7 no L-210iwp09 Injection Hole Section Kickoff Point - 6000' MD -3313 6000 3386 1510 8.8 Heavy Oil betw 3780 and 3915' UGl -3610 6760 3683 1625 8.7 SS Heavy Oil betw Top Schrader BIuff/Ma 3990 and 4030' Sand -3915 7541 3988 1820 8.9 SS / 4 It Greater Prudhoe Bay Orion L-21Oi Permit e Mbl -4030 7834 4102 1825 8.7 No Mb2 -4100 8014 4173 1850 8.7 No Me -4175 8205 4248 1895 8.7 No Na -4250 8388 4323 1925 8.7 No Nb -4280 8457 4353 1935 8.7 No Ne -4330 8569 4403 1950 8.7 Yes OA -4445 8815 4518 1995 8.6 Yes OBa -4520 8973 4593 2035 8.7 Yes OBb -4575 9089 4648 2070 8.7 Yes OBe -4640 9266 4713 2095 8.7 Yes OBd -4695 9342 4768 2120 8.7 Yes OBe - Base injection interval -4770 9500 4842 2150 8.7 Yes OBf -4825 9616 4898 2175 8.7 Yes OBCBase -4870 9710 4943 2195 8.7 no L-210iwp09 TD -4900 9750 4961 / / CasingfTubing Program Hole Csgl WtlFt Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. / /' (psi) (psi) MD I TVDrkb MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' / 29' 109' / 109' 12-1,4" 9-%" 40# L-80 BTC 5,750 3,090 4,210' 29' / 29' 4,239' / 2,698' 8-%" 7" 26# L-80 BTC-M 7,240 5,410 9,721' 29' / 29' 9,750' / 4,961' Tubing 4 Y2" 12.60# L-80 TCII 8,430 7,500 8,671' 29' / 29' 8,700' / 4,463' Tubing 3 Y2" 9.30# L-80 TCII 10,160 10,530 800' 8,700' / 4,463 9,500' / 4,843' Cement Calculations Casing Size 19-%-in 40-lb/ft L-80 BTC - Single Stage Basis I 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' (us as contingency only if losses while drilling) Spacer 80 bbls of Vi§!"""""""""""""""""""",i",f""",i""e""""",d"""""""""S"""""""p""""",a""""",c""""",e"""""",r"" weighted to 1 0.60 ~Ud Push) Lead 478 bbls s) 10.7Ib/gal ASL (G + adds) - ufVsk Tail 79 bbl sks) 15.8 Ib/gal Class G + adds - <f.1 ufVsk ":::i:,:::,::::::::~m"""ø'Æ'''fo~y''',',~,:,':::':::::::::::::::::::::::::~:::,'~.:::::::::::,:::::::,,',',',',',:::::::::::::::,-,-,-.______"'_____",,:::::::::::::::::::::::::::::::,:,:::::,:,',',',',',',',',',',',',',',',':':',',',',',',',',',':'::::::::::::::::::-"'-- ;:'8 Temp BHST:::: 71° F from Temp Log, BHCT 80° F estimated by Schlumberger In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Open Hole Abandonment Plug I 8 %" hole - Single Stage Basis 130% excess - TOC: 100' above Ma sanc!§, (planned Top Ma: 855.ß:-~m) Total Cement Volume: Tail 1154 bbls~~$ks) 15.8 Ib/gal G -é)ß-6ufVsk Temp I BHST :::: tUo° F from SOR, BHCT 80° F estimated by Schlumberger 5 e Greater Prudhoe Bay Orion L-210i Permit e Casin~ Size 17" 26 Ib/ft L-80 BTC-M - Single Stage Basis I 30% excess - TOC: 600' MD above the Ma sands (planned Top Ma: 7,540' MD) => 6,940' MD Total Cement Volume: Wash 20 bbls CW100 Spacer 35 bbls of Spacer (Mudpush II to 10.3 ppg Tail 97.4 bbls 15.8 G + Gasblok Temp BHST '" 100° F from SOR, BHCT 80° F estimated by Schlumberger 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,239' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 6,940' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations BHA Number Surface Surface Interm. Hole Size and Section 12-1A" 12- W' 8-3,4 Depths (MD) Bit Type Nozzles K-Revs Hours Hughes MXC-1 Hughes MXC-1 Hycalog DS70NPV 0' - 1,929' 1,929' - 4,239' 4,162' - 10,053'/9,750' 2x20 1x14 1x12 2x20 1x14 1x12 6x14 Motors and Required Doglegs BHA No. 1 & 2 3&4 Motor Size 8rtdMotor Required.- 9-%" Anadrill A962M3445 Mud Motor, 1.5° ABH with 12-W' string stabilizer (gyro to base of Perm) 6-%" Anadrill A675M4570XP Mud motor, with 1.15° ABH with 7.0" string stabilizer 'R.s 60-80 Required Doglegs'- 1.5°/100' initial build 4°/100' final build 7ye Max in 1A Target 67° Tangent in 2A Target jFlowlRate 400 - 700 gpm 500 - 600 gpm 60-120 6 e Greater Prudhoe Bay Orion L-210i Permit e Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. ,/ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,220 psi @ 4,900' TVDss - Schrader · Maximum surface pressure: 1,730 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) / Estimated 9.3 ppg Brine / 6.8 ppg Diesel 4,000/250 psi Rams & Valves 3,500/250 psi Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. " Greater Prudhoe Bay Orion L-210i Permit Drillina Hazards and Continaencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 1 A and Polygon 2a fault blocks are both expected to be normal pressured at 8.7 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at L-pad and have been encountered in wells as close as L-117 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole, however recommended practices and precautions for drilling hydrates should be followed in the surface hole. III. Lost Circulation/Breathing A. Lost circulation is unlikely. However massive losses were encountered in L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. Again in L-119 losses prevented circulation and continuous returns while cementing the 7". B. We do not expect breathing on this well. IV. Kick Tolerance/lntegrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 600' MD above the Ma sand -6,940' MD. C. The Kick Tolerance for the surface casing is 68.7 bbls with 9.3 ppg mud, 11.5 ppg LOT, and an 8.9 ppg pore pressure. If the LOT is 11.1 ppg or less EMW, then the kick tolerance will be < /' 50 bbls. D. Integrity Testing 9-%-in shoe 20-ft minimum from 9-%--in shoe LOT 11.5 minimum Stuck Pipe A. We do not expect stuck pipe. L-119 did however stick pipe while reaming tight hole at 2,687 TVD in the intermediate section due to hole not being adequately clean. The pipe was backed off and recovered. VI. Hydrogen Sulfide V. / L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm has been measured as recently as January 2003 at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: a. Adjacent producers at Surface: L-120 10 ppm L-119 10 ppm b. Adjacent producers at TD: L-120 10 ppm L-102 10 ppm 8 - Greater Prudhoe Bay Orion L-210i Permit e VII. Faults A. The 'L-Pad Fault' has been intersected in the surface hole by most wells drilled from L Pad to date. Fault #2 is a large throw fault that separates Orion Polygon 5 from Polygon 2A. It has been previously penetrated by numerous wells in the Ugnu and Schrader. Fault #3 separates Polygon 1A from 2A. This fault has been penetrated in the Colville and OBd. Both faults will be penetrated in the L-210i at high and angle, passing through the fault and damage zone quickly. They will only be penetrated in the Pilot hole section of the well. No drilling problems are expected from these faults. The fault details are listed below for reference: 'L-Pad Fault': 980' MD 974' TVD 900' TVDss Throw: 70' West Fault #2: 5,110' MD 3,039' TVD 2,965' TVDss Throw: 145' West Fault #3: 8,800' MD 4,159' TVD 4,085' TVDss Throw: 70' South CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 9 " Greater Prudhoe Bay Orion L-210i Permit Drill and Complete Procedure Summary Pre-Rig Work: 1. Set conductor for L-21 Oi. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in L-120 and L-119. ***AII pre-rig work should be charged off against the predrill AFE # ORD5M3541*** Rig Operations: 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-1,4" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4,240' __ MD. The actual surface hole TO will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar or stage tool .- should be on location. If losses are encountered while drilling surface the port collar/stage tool will be run in the casing string to allow secondary cementing, (in the event cement is not circulated to surface during primary cementing operations). 5. NO diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. ,r" 6. MU 8-3,4" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.3 ppg mud -- 8. Drill new formation to 20' below 9-%" shoe and perform LOT (minimum 11.5 ppg EMW)./' 9. Drill ahead to Polygon 1 A Pilot Hole TO at 10,053' MD, the base of Schrader formation. 10. Condition the hole for P&A plug. POOH to LD BHA standing back the 4" DP. 11. RIH w/ 4" DP to TO, spot balanced 15.8 ppg Class G cement abandonment plug from TO to 100' ,.....- above Schrader Ma sand. 12. POOH to 3 stands above plug, circulate out drill pipe and contaminated mud, POOH. 13. MU 8-3,4" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to top of cement / plug. Place "sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place" (AOCGG). 14. POOH to 6,000' MD and lowside existing wellbore to continue with drilling the Polygon 2A Schrader injection mainbore. Drill ahead to 9750' MD (base of OBd target plus 250'). 15. Circulate and condition hole, make a short trip, TOOH to run casing. .../" 16. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with 9.3 ppg mud or seawater during cementing operations and freeze protect the 7" x 9-%" annulus. 17. PU used bit and scraper and RIH with 4" DP while waiting on cement to PBTD ±9,670' MD. Displace out the mud / seawater with 9.3 ppg brine. POOH and LD BHA. 18. RU Schlumberger E-line and run a USIT/GR log. / 19. RU Schlumberger and perforate OA, OBa, and OBb w/ 180' of 4.5" Power Jet Guns set at 5 spf in 6 runs. Depths based on USIT/GR logging run. 20. RIH w/ gage ring and junk basket to recover any perf debris. Repeat until clean. 21. M/U Schlumberger SXAR Gun Drop assembly consisting of 90' of 4-1/2" PowerJet Guns at 5 spf. 22. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-W straddle packer assembly and GLM's for injection (torque turn connections). 23. Make e-line correlation run, correct gun setting depth and tubing hanger spaceout. / /. 10 - Greater Prudhoe Bay Orion L-210i Permit e 24. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. /' 25. Install FMC TWCV. Nipple down the BOPE. Nipple up, and test the tree to 5,000 psi. I 26. Freeze protect the well to -2,200' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-%" annulus valve and secure the well. / 27. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GLV. 3. Install firing head on SXAR system and fire guns. 4. Pull dummy valves in injection mandrels and replace with injection valves. 11 e Greater Prudhoe Bay Orion L-210i Permit e --",,,~-·-'«·,\',,)I Job 1: MIRU Hazards and Contingencies: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ L-119 and L-120 will have to be shut in and require wellhouse removal for drilling and completion operations. Job 2: Drill 12W' Surface Hole Hazards and Contingencies: ~ At L-Pad, no significant surface hole drilling problems have been identified. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In only one case has an obstruction caused the well to be sidetracked. Lost circulation has not been a problem on L-pad. Some minor tight hole has also been encountered below the Permafrost. Hydrates are present at L-pad from the base of the Permafrost all the way through the SV-1 sand and should be treated with conventional practices: pretreating mud, cooling mud, increasing weight, etc. ~ Close Approach: The L-120 and L-119 are required to be shut in and have their well houses removed due to surface location proximity to the L-210i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run through the Permafrost. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Objective is to keep DLS $;10 over planned. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.50 motor bend. Vary flow rates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. ~ Drill Pipe specs: from Premium classification, not New. 5",19.5#,4-112" IF, 'G' ID Collapse 100% 4.276 8,765 psi 80% 3.250(tool joint) 7,012 psi ***Max Recommended MU Torque: 26,800 ft-Ibs ***Min Recommended MU Torque: 25,900 ft-Ibs ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. Burst 12,526 psi 10,021 psi Torsional 45,200 Ibs 36,2001bs Tensile 436,100 Ibs 348,880lbs 12 e Greater Prudhoe Bay Orion L-210i Permit e ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Job3: Install Surface CasinQ Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TO at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate 10 for the 8-3,4" bit, Le. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar can be placed at 1,OOO-ft MO if losses are encountered while drilling. (Port Collar is not expected to be run.) ~ Losses during cement job: At L-Pad lost circulation has not been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. þ> LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.9 ppg and a 9.3 ppg mud, an 11.5 ppg leak-off will provide over 60 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off-set drilling data on L- Pad, a minimum leak-off of 12.7 ppg is expected at the 9-%" shoe. ~ Pilot Hole TD - The TD for the 8 3,4" pilot hole will be will be determined by depth based on changes in GR/Res curves associated with the base OBf sand. After seeing the base OBf, TD will be called at the point in time that the onsite geologist feels that the zone has been fully penetrated and logged. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the base OBd sand. After seeing the base OBd, TD will be picked based on drilling 250' MD past this base. This footage is critical for future wellwork. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that high torque values, as high as 12,000 ft-Ibs can be expected by section TD. Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 13 e Greater Prudhoe Bay Orion L-210i Permit . bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. þ> Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the intermediate hole sections. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. þ> Faults: Three faults will be crossed in the L-210i with one in the UG4A and one in the Ugnu Mb2 after the surface casing shoe. The Pilot hole will be the only hole section to cross #2 and #3 faults. The faults have been crossed on numerous wells and are not expected to cause any drilling problems. The fault details are listed below for reference: Fault #2: Fault #3: 5,110'MD 8,800' MD 3,039' TVD 4,159' TVD 2,965' TVDss 4,085' TVDss Throw: 145' West Throw: 70' South þ> Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements. It is critical to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept ~1 0 over planned. Job 6: Install 7" Production CasinQ Hazards and Contingencies: þ> Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. þ> Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. þ> RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand þ> Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. þ> Mud Requirements: Thin the mud as per MI's Mud Program before cementing. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. þ> Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. þ> 7" Casing Specifications: 7", 26#, L-80 BTC 100% 80% ID 6.276 6.151 (drift) Collapse 5,410psi 4,328psi Burst 7,240psi 5,792psi Tensile 667,OOOlbs 533,6001bs 14 " Greater p'rudhoe Bay Orion L-210i Permit ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor for casing running. ":"'.="...........~¥."'~'}""'C'" Job 10: Perforate Well (DPC/SXAR) Hazards and Contingencies ~ The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating guns, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Schlumberger hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 180' of 4-1/2" Power Jet guns at 5 spf to be run on wire, and 90' of 4 112" Power Jet guns at 5 spf to be run with the completion using the SXAR gun drop system. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Follow the LCM decision tree for "After Perforating". Position guns by E-line measurement from USIT run for e-line perforating and by utilizing the Schlumberger GR tool in the string and RA tags for SXAR perforating. Reference RP: .:. 'Schlumberger E-line and SXAR Procedures' Job 12: Run Comø/etion Hazards and Contingencies: ' ~ Dirty Hole: It is critical to have a clean hole to run this completion due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. ~ Torque turn TCII completion connections to help assure that it doesn't leak when put on MI. Reference RP: .:. 'Completion Design and Running' RP ."",.'«.'"W.~--".-' Job 13: ND/NU/Release RiCl Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. 15 bp o I RTE KOP Bid 1.5/100 Bid 2.51100 Crv 2.5/100 Fauilt Crossing Crv 4/100 SV5 SV4 Base Perm Report OIIe: Client: Field: Structure I Slot: Well: Borehole: UWUAPlt: Survey Name I Dale: Tort I AHD I 0011 ERD ratio: Grid CoordInate System: locIIIon utIlong: location Grid N/E YIX: Grid Convergence Angle: Grid Sc:eIe Factor: Schlumberuer L-210PB1 (P3) Proposal ~ Survey/DLSCompuIItionMelhod: Vertical SectIon AzImuth: V8ftlça Sec:lion OrIgin: TVD Reference Datum: st dY TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Decllnllllon: ToIII Freid StIength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: ToIII Corr Mag North -> True North: Local CoordInates Referenced To: November 10,2003 BP Exploration Alaska Prudhoe Bay Unit - WOA L-PAD I L-21 0 Plan L-210 (N-W) Plan L-210PB1 50029 L-21OPB1 (P3) I December 20, 2003 129.463° /7939,09ft/6.318 I 1.597 NAD27 Alaska State Planes, Zone 04, US Fee1 N 70.35075586, W 149.32324200 N 5978328.000 ftUS, E 583354.000 ftUS ..0.63735293° 0.99990789 Fe.slblllty I ~ Ilnclinllllon I AzImuth I (It I (dig I (dig I 0.00 0.00 120.00 300.00 0.00 120.00 400.00 1.50 120.00 500.00 4.00 120.00 600.00 5.94 101.32 Comments 700.00 800.00 900.00 979.66 1000.00 1024.49 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1638.71 1700.00 1800.00 1820.13 1900.00 1929.03 8.19 10.55 12.96 14.90 15.40 16.00 19.02 23.02 27.01 31.01 35.01 39.01 40.56 43.01 47.01 47.81 51.01 52.17 92.29 87.20 83.98 82.15 81.75 81.31 80.89 80.50 80.22 80.01 79.84 79.71 79.66 79.59 79.49 79.47 79.40 79.38 TVD I Sub-SelTVD I VlltiCII I (It I (It I ~ 0.00 -72.60 0.00 300.00 227.40 0.00 399.99 327.39 0.93 499.87 427.27 4.32 599.49 526.89 11.42 698.73 797.39 895.29 972.60 992.24 1015.81 1087.81 1181.14 1271.74 1359.18 1443.02 1522.85 1552.60 1598.30 1668.98 1682.60 1734.56 1752.60 WellDesign Ver 3.1RT-SP3.03-HF1.2 Bld( d031rt-546) 626.13 724.79 822.69 900.00 919.64 943.21 1015.21 1108.54 1199.14 1286.58 1370.42 1450.25 1480.00 1525.70 1596.38 1610.00 1661.96 1680.00 22.86 38.60 58.62 77.61 82.89 89.47 112.06 147.74 189.83 238.13 292.40 352.38 377.06 417.77 488.25 503.02 563.49 586.17 NS (It I 0.00 0.00 -0.65 -3.05 -5.81 -7.11 -6.95 -5.33 -2.99 -2.25 -1.27 2.25 8.06 15.14 23.47 33.00 43.69 48.12 55.48 68.31 71.02 82.14 86.32 Minimum Curvature I Lubinski 75.000° N 0.000 ft, E 0.000 ft Rotary Table 72.611 relative to MSL 44.100 11 relative to MSL 25.133° 57551.909 nT 80.819° December 20, 2003 BGGM 2003 True NoM +25.133° WellHead :: L;:1t1::IL:1:J 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.13 1.50 1.50 0.00 5.29 2.50 2.50 0.00 13.38 2.50 1.94 -18.68 25.57 41.82 62.12 81.15 86.41 92.97 115.41 150.79 192.47 240.24 293.87 353.10 377.47 417.64 487.17 501.74 561.36 583.72 2.50 2.50 2.50 2.50 2.50 2.25 2.36 2.41 2.44 2.45 2.50 4.00 4.00 4.00 4·00 / 4.00 4.00 4.00 4.00 4.00 2.45 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 L-210\Plan L-210 (N-W)\Plan L-210PB1\L-210PB1 (P3) -9.03 -5.09 -3.23 -2.30 -1.94 -1.81 -0.55 -0.39 -0.28 -0.21 -0.17 -0.14 -0.12 -0.11 -0.10 -0.09 -0.09 -0.08 Tool F_I (dig I 120.ooM 120.ooM 120.00M 101.32M -30.81G -21.85G -16.83G -13.67G -11.89G -11.51G -2.58G -2.18G -1.82G -1.57G -1.38G -1.24G -1.13G -1.09G -1.04G -0.97G -O.96G -O.92G -0.90G Northing (flUS I 5978328.00 5978328.00 5978327.36 5978325.01 5978322.34 5978321.17 5978321.51 5978323.36 5978325.91 5978326.71 5978327.76 5978331.53 5978337.73 5978345.28 5978354.14 5978364.26 5978375.61 5978380.31 5978388.11 5978401.72 5978404.59 5978416.37 5978420.80 e EIsIIng (flUS I 583354.00 583354.00 583355.14 583359.32 583367.44 I.ItItude Longitude N 70.35075586 W 149.32324200 N 70.35075586 W 149.32324200 N 70.35075407 W 149.32323279 N 70.35074752 W 149.32319906 N 70.35073998 W 149.32313336 583379.64 N 70.35073643 W 149.32303443 583395.89 N 70.35073687 W 149.32290246 583416.17 N 70.35074130 W 149.32273771 583435.17 N 70.35074768 W 149.32258321 583440.43 N 70.35074972 W 149.32254048 583446.97 N 70.35075239 W 149.32248727 583469.37 N 70.35076200 W 149.32230509 583504.68 N 70.35077787 W 149.3~1784 583546.27 N 70.35079722 W 149. 9 583593.94 N 70.35081996 W 149.3 68 583647.46 N 70.35084600 W 149.32085630 583706.56 N 70.35087518 W 149.32037547 583730.88 N 70.35088730 W 149.32017762 583770.96 N 70.35090739 W 149.31985154 583840.34 N 70.35094245 W 149.31928705 583854.87 N 70.35094983 W 149.31916878 583914.36 N 70.35098019 W 149.31868476 583936.67 N 70.35099163 W 149.31850322 Generated 11/101200312:02 PM Page 1 of3 Comments End Crv SV3 SV2 SV1 9-518" Csg Pt UG4 UG4A Fault Crossing UG3 Crv4/1oo End Crv UG1 Drp 2/100 Ma Mb1 Fault Crossing Me Na L-210PB1 Tgt Nb Ne I M~red I Inclination I (It) (deg) 2000.00 55.01 2100.00 59.01 2200.00 2299.79 2601.31 3023.58 3983.27 4239.19 4904.57 4981.35 5109.31 5557.16 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6504.95 7166.02 8035.52 8100.00 8200.00 8300.00 8400.00 8500.00 8557.63 8600.00 8689.12 8700.00 8798.83 8800.00 8900.00 8950.22 9000.00 9080.56 9100.00 9142.54 9142.55 9200.00 9227.83 63.01 67.00 67.00 67.00 67.00 67.00 67.00 67.00 67.00 67.00 67.00 68.81 70.71 72.69 74.72 76.82 76.92 76.92 76.92 75.65 73.66 71.68 69.70 67.72 66.58 65.74 63.97 63.76 61.80 61.78 59.80 58.80 57.82 56.22 55.84 55.00 55.00 53.80 53.22 AzImuth I (deg) 79.33 79.26 79.19 79.13 79.13 79.13 79.13 79.13 79.13 79.13 79.13 79.13 79.13 75.28 71.53 67.87 64.28 60.76 60.59 60.59 60.59 60.76 61.03 61.31 61.59 61.88 62.05 62.18 62.46 62.49 62.80 62.81 63.14 63.31 63.48 63.77 63.84 64.00 64.00 64.00 64.00 : ISu~~TVDI 1794.72 1722.12 1849.16 1776.56 1897.62 1939.78 2057.60 2222.60 2597.60 2697.60 2957.60 2987.60 3037.60 3212.60 3385.64 3423.26 3457.86 3489.27 3517.34 3541.92 3543.05 3692.60 3889.31 3904.60 3931.06 3960.84 3993.91 4030.22 4052.60 4069.73 4107.60 4112.39 4157.60 4158.15 4206.96 4232.60 4258.75 4302.60 4313.46 4337.60 4337.61 4371.05 4387.60 WellDesign Ver 3.1RT-SP3.03-HF1.2 Bld( d031rt-546) 1825.02 1867.18 1985.00 2150.00 2525.00 2625.00 2885.00 2915.00 2965.00 3140.00 3313.04 3350.66 3385.26 3416.67 3444.74 3469.32 3470.45 3620.00 3816.71 3832.00 3858.46 3888.24 3921.31 3957.62 3980.00 3997.13 4035.00 4039.79 4085.00 4085.55 4134.36 4160.00 4186.15 4230.00 4240.86 4265.00 4265.01 4298.45 4315.00 Vertical I Section (It) 643.12 726.74 813.95 904.14 1180.97 1568.65 2449.75 2684.71 3295.60 3366.09 3483.57 3894.75 4301.32 4393.89 4487.65 4582.16 4676.95 4771.57 4776.25 5399.92 6220.24 6280.93 6374.46 6467.14 6558.89 6649.57 6701.31 6739.09 6817.79 6827.32 6913.17 6914.17 6999.53 7041.81 7083.30 7149.55 7165.36 7199.73 7199.75 7245.60 7267.56 NS (It) 96.88 112.46 128.81 145.82 198.16 271.46 438.04 482.47 597.97 611.29 633.50 711.24 788.11 808.64 835.45 868.40 907.34 952.06 954.43 1270.61 1686.50 1717.17 1764.07 1810.10 1855.20 1899.32 1924.27 1942.40 1979.88 1984.39 2024.77 2025.24 2064.90 2084.36 2103.32 2133.35 2140.46 2155.86 2155.86 2176.34 2186.15 EW I DLS I Build Rate I Walk Rate I ( It ) ( deg/100 It ) ( deg/100 It ) ( deg/100 It ) 639.84 4.00 4.00 -0.08 722.24 4.00 4.00 -0.07 808.15 896.96 1169.53 1551.25 2418.80 2650.14 3251.64 3321.04 3436.71 3841.57 4241.88 4332.21 4422.10 4511.11 4598.82 4684.79 4689.00 5249.95 5987.77 6042.38 6126.64 6210.27 6293.16 6375.22 6422.10 6456.35 6527.79 6536.45 8614.50 6615.42 6693.16 6731.72 6769.59 6830.13 6844.60 6876.05 6876.06 6918.05 6938.16 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.09 2.09 2.09 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.81 1.90 1.97 2.04 2.09 2.12 0.00 0.00 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -1.98 -2.09 -2.09 -2.09 L-210\Plan L-210 (N-W)\Plan L-21 OPB1\L-21 OPB1 (P3) TooIF_1 (deg) -O.87G -0.83G -0.06 -0.06 0.00 0.00 0.00 -0.80G O.ooG O.DOG 0.000 O.DOG 0.00 0.00 0.00 0.00 0.00 O.DOG O.DOG O.OOG O.OOG O.DOG 0.00 -3.85 -3.75 -3.66 -3.59 -63.77G -62.32G -61.02G -59.87G -S8.86G -3.52 -3.48 0.00 0.00 0.27 -58.ooG O.ooG O.DOG 172.58G 172.53G 0.27 0.28 0.28 0.29 0.30 172.46G 172.38G 172.29G 172.18G 172.12G 0.30 0.31 0.31 0.32 0.32 172.06G 171.95G 171.93G 171.79G 171.79G 0.33 0.34 0.35 0.36 0.37 171.63G 171.54G 171.45G 171.29G 171.25G 0.37 0.00 0.00 0.00 180.00G 180.00G 180.00G 180.00G Northing (flUS) 5978431.98 5978448.47 5978465.78 5978483.77 5978539.13 5978616.67 5978792.88 5978839.87 5978962.04 5978976.14 5978999.63 5979081.86 5979163.17 5979184.70 5979212.51 5979246.44 5979286.34 5979332.02 5979334.43 5979656.81 5980080.83 5980112.11 5980159.94 5980206.89 5980252.91 5980297.93 5980323.40 5980341.91 5980380.17 5980384.78 5980426.02 5980426.51 5980467.02 5980486.91 5980506.29 5980536.98 5980544.26 5980560.00 5980560.01 5980580.95 5980590.98 Easting LatiIude longitude (flUS) 583992.67 N 70.35102044 W 149.31804760 584074.88 N 70.35106299 W 149.31737867 N 70.35110764 W 149.31668123 N 70.35115407 W 149.31596020 N 70.35129696 W 149.31374735 N 70.35149701 W 149.31064831 N 70.35195148 W 149.30360481 N 70.35207263 W 149.30172649 N 70.35238752 W 149.29684276 N 70.35242384 W 149.29627924 N 70.35248438 W 149.29534004 N 70.35269622 W 149.29205280 N 70.35290563 W 149.2.....3 N 70.35296158 W 149.2Z~ N 70.35303467 W 149.28733894 N 70.35312454 W 149.28661606 N 70.35323076 W 149.28590377 N 70.35335280 W 149.28520554 N 70.35335925 W 149.28517138 N 70.35422203 W 149.28061514 N 70.35535667 W 149.27462173 N 70.35544036 W 149.27417807 N 70.35556829 W 149.27349360 N 70.35569385 W 149.27281424 N 70.35581687 W 149.27214083 N 70.35593720 W 149.27147417 N 70.35600527 W 149.27109338 N 70.35605470 W 149.27081508 N 70.35615692 W 149.27023472 N 70.35616923 W 149.27016437 N 70.35627936 W 149.26.29 N 70.35628064 W 149.2 84 N 70.35638880 W 149.26889125 N 70.35644186 W 149.26857804 N 70.35649358 W 149.26827038 N 70.35657545 W 149.26777850 N 70.35659485 W 149.26766100 590205.00 N 70.35663683 W 149.26740545 590205.01 N 70.35663685 W 149.26740535 590246.76 N 70.35669268 W 149.26706428 590266.76 N 70.35671942 W 149.26690091 Generated 11/10/2003 12:02 PM Page 2 of 3 584160.59 584249.20 584521.15 584901.99 585767.55 585998.36 566598.48 586667.72 586783.13 587187.06 587586.45 587676.54 587766.12 587854.75 587942.01 588027.47 588031.65 588589.00 589322.08 589376.34 589460.06 589543.16 589625.54 589707.10 589753.69 589787.74 589858.75 589867.36 589944.95 589945.86 590023.15 590061.48 590099.14 590159.34 590173.72 Comments M;red Ilncllnalion I AzImuth I TVD I ~Sea TVD I Vertical I NS EW I DLS I BuDd Rate I Walk Rate I Tool Face I Northing EastIng Latitude Longitude Section (It I (dea) (dea) (It I (It) (It I (It) (It) ( deg/100 It ) ( deg/100 It ) ( degl100 It ) (dea) (ftUS) (ftUS) 9300.00 51.71 64.00 4431.57 4358.97 7323.74 2211.23 6989.59 2.09 -2.09 0.00 180.00G 5980616.63 590317.91 N 70.35678783 W 149.26648303 OA 9396.38 49.70 64.00 4492.60 4420.00 7396.95 2243.93 7056.63 2.09 -2.09 0.00 180.ooG 5980650.07 590384.57 N 70.35687698 W 149.26593841 9400.00 49.63 64.00 4494.94 4422.34 7399.66 2245.14 7059.11 2.09 -2.09 0.00 180.00G 5980651.31 590387.04 N 70.35688028 W 149.26591825 9500.00 47.54 64.00 4561.10 4488.50 7473.27 2278.01 7126.51 2.09 -2.09 0.00 180.0OG 5980684.92 590454.06 N 70.35696991 W 149.26537070 OBa 9509.62 47.34 64.00 4567.60 4495.00 7480.22 2281.12 7132.87 2.09 -2.09 0.00 180.ooG 5980688.10 590460.39 N 70.35697837 W 149.26531899 OBb 9582.36 45.82 64.00 4617.60 4545.00 7532.08 2304.28 7180.36 2.09 -2.09 0.00 180.ooG 5980711.78 590507.61 N 70.35704152 W 149.26493320 9600.00 45.45 64.00 4629.94 4557.34 7544.46 2309.80 7191.69 2.09 -2.09 0.00 180.00G 5980717.44 590518.88 N 70.35705659 W 149.26484111 OBc 9674.06 43.90 64.00 4682.60 4610.00 7595.58 2332.63 7238.50 2.09 -2.09 0.00 180.ooG 5980740.78 590565.42 N 70.35711883 W 149.26446086 9700.00 43.36 64.00 4701.37 4628.77 7613.15 2340.48 7254.58 2.09 -2.09 0.00 180.00G 5980748.80 590581.42 N 70.35714022 W 149.26433018 OBd 9749.41 42.33 64.00 4737.60 4665.00 7646.13 2355.21 7284.78 2.09 -2.09 0.00 1OO.ooG 5980763.87 590611.45 N 70.35718038 W 149.26408480 9800.00 41.27 64.00 4775.31 4702.71 7679.23 2369.99 7315.09 2.09 -2.09 0.00 180.00G 5980778.98 590641.59 N 70.35722068 W 149.26383858 OBe 9842.68 40.38 64.00 4807.60 4735.00 7706.62 2382.22 7340.17 2.09 -2.09 0.00 180.ooG 5980791.49 590666.53 N 70.35725403 W 149.2.3 9900.00 39.19 64.00 4851.65 4779.05 7742.63 2398.30 7373.14 2.09 -2.09 0.00 180.00G 5980807.94 590699.31 N 70.35729787 W 149.26336697 OBf 9907.67 39.03 64.00 4857.60 4785.00 7747.38 2400.42 7377.48 2.09 -2.09 0.00 180.ooG 5980810.10 590703.63 N 70.35730365 W 149.26333165 OBf Base 9965.11 37.83 64.00 4902.60 4830.00 7782.42 2416.07 7409.57 2.09 -2.09 0.00 180.00G 5980826.11 590735.54 N 70.35734632 W 149.26307094 10000.00 37.10 64.00 4930.29 4857.69 7803.25 2425.37 7428.65 2.09 -2.09 0.00 180.00G 5980835.62 590754.51 N 70.35737168 W 149.26291598 TO 10052.67 36.00 64.00 4972.60 4900.00 7834.04 2439.12 7456.83 2.09 -2.09 0.00 O.OOG 5980849.68 590782.54 N 70.35740917 W 149.26268695 Leaal Description: Northina (Y) rftUSl Eaetina ex) rftUSl Surface: 2604 FSL 3560 FEL S34 T12N R 11 E UM 5978328.00 583354.00 Crv 4/100: 3391 FSL 4596 FEL S35 T12N R 11 E UM 5979163.17 587586.45 L-210PB1 Tgt: 4757 FSL 1960 FEL S35 T12N R11E UM 5980560.00 590205.00 BHL: 5040 FSL 1378 FEL S35 T12N R11 E UM 5980849.68 590782.54 e WellDesign Ver 3.1 RT -SP3.03-HF1.2 Bld( d031rt-546 ) L-210\Plan L-21 0 (N-W)\Plan L-210PB1\L-210PB1 (P3) Generated 11/101200312:02 PM Page 3 of 3 1000 lwat I FJElD Prudhoe Bay Unit - WOA I smUOTURE L-PAD L-210PB1 (P3) 1--- Model: BGGM 2003 Pate· Deœmbøf2(!,2003 ·1 ~l~212,721 FS; 57551,QnT .... .·lon; W1491923Jm 1_ l21. NADl7A1astœ:"Stat&Pmnes, Zone-Q4, us Fwt 591S32BßO .ftUS 563$4.00ftUS TVDRef: Oìp 6'0.819' Mag Oøc: +25J33' o 1000 2000 3000 5000 4000 6000 7000 8000 o o _KOP Bid 1.51100 -Bid 2.51100 - Cry 2.51100 1000 g 2000 2000 8 .... ~ .... II G> ~ (/) 3000 3000 0 ¡::: 4000 5000 5000 Vv. 4000 TD o 1000 2000 3000 4000 5000 6000 Vertical Section (ft) Azim = 75", Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-W 7000 8000 I WELL L-210PB1 (P3) I FIELD Prudhoe Bay Unit.. WOA 'TRUCruRE L-PAD [-""~- Model; BGGM 2003 Dip 60.819" Mag O$c; +2~U33' ~w ::::,2020001 rrL~¿:~:.;:~" WArm AJaskaStmuPlaoes,ZOM04, us fefli Grid COt\V; +0.63735200' Sca!l1l-fsct Q,9WQ078926 o 1000 2000 3000 4000 5000 6000 7000 8000 3000 3000 2000 2000 ^ ^ L-21 0 Ftl2 ^ Z - e- O 8 1000 1000 ... C ¡.SIS" CO] ......... ... tI .!II ~ -q (/) (/) V 0 0 V V -1000 -1000 o 1000 2000 3000 4000 5000 «< W Scale = 1(in):1000(ft) E >>> 6000 7000 8000 Company: Field: Refereaee Site: Reference Well: Reference WeUpath: BP Amoco Prudhoe Bay PB L Pad Plan L-210 (N-W) Plan L-21OPB1 e BPX AK Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 10052.67 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 11/612003 Validated: No Planned From To Survey ft ft 28.50 10052.67 Planned: Plan #3 V2 Casing Points MD ft 4239.19 10052.67 TVD ft 2697.60 4972.60 Diameter in 9.625 8.750 Summary < Site Offset Wellpath Well PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad L-01 L-01 L-02 L-02 L-102 L-102 L-102 L-103 L-104 L-105 L-106 L-107 L-108 L-109 L-110 L-111 L-112 L-114 L-115 L-116 L-117 L-118 L-119 L-120 L-121 L-121 L-122 Plan L-113 (N-B) Plan L-123 (N-R) Plan L-124 (N-C) Plan L-124 (N-C) Plan L-200 (N-M) Plan L-2oo (N-M) Plan L-2oo (N-M) Plan L-201 (N-U) Hole Size in Name 12.250 8.750 9 5/8" 8-3/4" open hole ~ WeUpath L-01 V14 L-01L 1 V2 Plan: Plan # L-02 V1 L-02PB1 V21 L-102 V2 L-102PB1 V10 L-102PB2 V2 L-103 V23 L-104 V7 L-105 V4 L-106 V14 L-107 V14 L-108 V18 L-109 V12 L-110V11 L-111 V24 L-112 V8 L-114 V14 L-115 V7 L-116 V10 L-117V11 L-118 V9 L-119V9 L-120 V8 L-121 V14 L-121A V1 L-122 V5 Plan L-113 V5 Plan: PI Plan L-123 V1 Plan: PI Plan L-124 PB1 V1 Plan Plan L-124 V1 Plan: PI Plan L-200 OBd V1 Plan Plan L-2ooL 1 OBa V1 PI Plan L-2ooL2 OA V1 Pia Plan L-201 V1 Plan: PI Da.e: 11/1012003 e Time: 12:45:27 Co-erdlnate(NE) 1Wen8ee: Vertical (TVD) RefereDce: Version: 6 Toolcode MWD+IFR+MS ReIereøce MD ft 497.14 497.14 385.38 385.38 950.65 854.38 854.38 393.18 550.47 692.45 831.18 592.20 734.14 345.81 295.49 246.39 338.20 488.23 438.01 538.54 343.57 485.12 393.41 243.49 246.17 246.17 343.32 346.88 398.57 393.96 393.96 397.22 397.22 397.22 349.71 Offset MD ft 500.00 500.00 400.00 400.00 950.00 850.00 850.00 400.00 550.00 700.00 850.00 600.00 750.00 350.00 300.00 250.00 350.00 500.00 450.00 550.00 350.00 500.00 400.00 250.00 250.00 250.00 350.00 350.00 400.00 400.00 400.00 400.00 400.00 400.00 350.00 P1age: 1 Well: Plan L-210 (N-W), True North L-210 Plan 72.6 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name MWD + IFR + Multi Station Ctr..(;tr No-Go Distance Area ft ft 236.12 7.99 236.12 7.99 308.82 6.68 308.82 6.79 166.60 13.94 171.17 13.60 171.17 13.60 59.64 6.30 178.60 8.11 186.08 11.93 149.91 13.29 220.41 10.77 178.75 12.50 283.68 6.90 320.56 5.23 412.16 4.26 326.98 6.89 384.32 7.40 248.61 7.11 295.88 7.90 235.07 5.26 215.08 8.72 13.77 6.31 16.75 4.03 346.94 4.32 346.94 4.32 280.69 5.46 355.17 7.48 75.66 6.87 340.70 6.91 340.70 6.91 150.47 7.02 150.47 6.90 150.47 6.90 29.89 6.21 AUowable DevIation ft 228.13 228.13 302.14 302.03 152.66 157.56 157.56 53.34 170.49 174.15 136.62 209.65 166.25 276.78 315.33 407.90 320.08 376.92 241.50 287.99 229.81 206.36 7.46 12.72 342.62 342.62 275.24 347.69 68.79 333.79 333.79 143.46 143.57 143.57 23.68 Wamin~ Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk -147 "--100 ~--50 Plan L-123 (N-R) (Plan L-123) ~O L-I03 (L-ION . ·-50 - 100 -147 Field: Site: Well: Wellpath: Prudhoe Bay PB L Pad Plan L-210 (N-W) Plan L-210PBl o 117 180 14/ Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre tn Centre Separatinn [50ftlin] e :JO e Site: PB L Pad a Drilling Target Conf.: 95% ., Description: Map Northing: 5980560.00 ft Map Easting: 590205.00 ft Latitude: 70°21 '23.893N Shape: Circle Target: L-21OPBI Tgt a: Plan L-21O (N-W) _d on: Planned Program Vertical Depth: 4265.00 ft below Mean Sea Level Local +N/-S: 2155.85 ft Local +E/-W: 6876.04 ft Longitude: 149°16'02.660W Radius: 200 ft ---- 2500 24-00 2300 ~ I 2200 -t- 2100 2000 1900 1800 0 CJ CJ CJ CJ CJ CJ CJ CJ o ~ CJ CJ CJ CJ CJ CJ CJ CJ LD I CD a- CJ N (I) ~ o j LD LD LD LD I I I I ~ J j ~ bp 0 L-210 (P9) Proposal Schlumberger Report Date: November 10, 2003 ~ .....,...-..... Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 75.000° Field: Prudhoe Bay Unit - WOA dy Vertical Section OrIgin: N 0.000 II, E 0.000 II Structure I Slot: L-PAD / L-21 0 Feasibility st TVD Reference Datum: KB Well: Plan L-210 (N-W) TVD Reference Elevation: 72.611 relative to MSL Borehole: Plan L-210 Sea Bed I Ground Level Elevation: 44.100 II relative to MSL UWUAPl#: 50029 Magnetic Dec:llnalion: 25.133° Survey Name I Date: L-210 (P9) / December 20,2003 Total Field Strength: 57551.909 nT TOft I AHD I DOl J ERD ratio: 92.130°/7717.2111/6.145/1.555 Magnetic Dip: 80.819° Grid Coordlllllte System: NAD27 Alaska Slale Planes, Zone 04, US Feet DeclInation Date: December 20, 2003 Location LatlLong: N 70.35075586, W 149.32324200 Magnetic DeclInation Model: BGGM 2003 e Location GrId HIE YfX: N 5978328.000 IIUS, E 583354.000 IIUS North Reference: True North Grid Convergence Angle: ~.63735293° Total CorrMag North·> True North: +25.133° Grid Scale Factor: 0.99990789 Local Coordinllles Referenced To: Well Head Comments I~I IncIlnetlon I AzImuth I TVD I ~TVDI Vertical I NS EW I DLS I BuHdRú I W~Rú I Tool F_I Northing Ellling Latitude Longitude SectIon (deg) (deg) (It) (It) (It) (It) ( deg/100 It ) ( deg/100 It ) ( deg/100 It ) (deg) (ftUS) (ftUS) RTE 0.00 0.00 120.00 0.00 -72.60 0.00 0.00 0.00 0.00 0.00 0.00 120.00M 5978328.00 583354.00 N 70.35075586 W 149.32324200 KOP Bid 1.5/100 300.00 0.00 120.00 300.00 227.40 0.00 0.00 0.00 0.00 0.00 0.00 120.ooM 5978328.00 583354.00 N 70.35075586 W 149.32324200 Bid 2.5/100 400.00 1.50 120.00 399.99 327.39 0.93 -0.65 1.13 1.50 1.50 0.00 120.00M 5978327.36 583355.14 N 70.35075407 W 149.32323279 Crv 2.5/100 500.00 4.00 120.00 499.87 427.27 4.32 -3.05 5.29 2.50 2.50 0.00 82.15M 5978325.01 583359.32 N 70.35074752 W 149.32319906 Fauilt Crossing 979.66 14.90 82.15 972.60 900.00 77.61 -2.99 81.15 2.50 2.27 -7.89 -11.800 5978325.91 583435.17 N 70.35074768 W 149.32258321 Crv 4/100 1024.49 16.00 81.31 1015.81 943.21 89.47 -1.27 92.97 2.50 2.45 -1.87 -2.58G 5978327.76 583446.97 N 70.35075239 W 149.32248727 SV5 1638.71 40.56 79.66 1552.60 1480.00 377.06 48.12 377.47 4.00 4.00 -0.27 -1.09G 5978380.31 583730.88 N 70.35088730 W 149.32017762 SV4 1820.13 47.81 79.47 1682.60 1610.00 503.02 71.02 501.74 4.00 4.00 -0.10 -0.96G 5978404.59 583854.87 N 70.35094983 W 149.31916879 Base Perm 1929.03 52.17 79.38 1752.60 1680.00 586.17 86.32 583.72 4.00 4.00 -0.08 -O.90G 5978420.80 583936.67 N 70.35099163 W 149.31850322 End Crv 2299.79 67.00 79.13 1939.78 1867.18 904.14 145.82 896.96 4.00 4.00 -0.07 O.OOG 5978483.77 584249.20 N 70.35115407 W 149.31596020 SV3 2601.31 67.00 79.13 2057.60 1985.00 1180.97 198.16 1169.53 0.00 0.00 0.00 O.OOG 5978539.13 584521.15 N 70.35129696 W 149.31374735 SV2 3023.58 67.00 79.13 2222.60 2150.00 1568.65 271.46 1551.25 0.00 0.00 0.00 O.OOG 5978616.67 584901.99 N 70.35149701 W 149.3.1 SV1 3983.27 67.00 79.13 2597.60 2525.00 2449.75 438.04 2418.80 0.00 0.00 0.00 O.ooG 5978792.88 585767.55 N 70.35195148 W 149.3 1 9-5/8" Csg Pt 4239.19 67.00 79.13 2697.60 2625.00 2684.71 482.46 2650.14 0.00 0.00 0.00 O.OOG 5978839.87 585998.36 N 70.35207263 W 149.30 9 UG4 4904.57 67.00 79.13 2957.60 2885.00 3295.60 597.97 3251.64 0.00 0.00 0.00 O.OOG 5978962.04 586598.48 N 70.35238752 W 149.29684276 UG4A 4981.35 67.00 79.13 2987.60 2915.00 3366.09 611.29 3321.04 0.00 0.00 0.00 O.OOG 5978976.14 586667.72 N 70.35242384 W 149.29627924 Fault Crossing 5109.31 67.00 79.13 3037.60 2965.00 3483.57 633.50 3436.71 0.00 0.00 0.00 O.OOG 5978999.63 586783.13 N 70.35248438 W 149.29534004 UG3 5557.16 67.00 79.13 3212.60 3140.00 3894.75 711.24 3841.57 0.00 0.00 0.00 O.OOG 5979081.86 587187.06 N 70.35269622 W 149.29205280 KOP Drill Ahead 6000.00 67.00 79.13 3385.64 3313.04 4301.32 788.11 4241.88 0.00 0.00 0.00 O.OOG 5979163.17 587586.45 N 70.35290563 W 149.28880233 6010.45 67.00 79.13 3389.72 3317.12 4310.92 789.93 4251.33 0.00 0.00 0.00 O.OOG 5979165.09 587595.88 N 70.35291057 W 149.28872560 UG1 6759.98 67.00 79.13 3682.60 3610.00 4999.06 920.03 4928.89 0.00 0.00 0.00 O.OOG 5979302.71 588271.89 N 70.35326487 W 149.28322386 Ma 7540.53 67.00 79.13 3987.60 3915.00 5715.69 1055.53 5634.49 0.00 0.00 0.00 O.OOG 5979446.03 588975.87 N 70.35363367 W 149.27749416 Mb1 7834.84 67.00 79.13 4102.60 4030.00 5985.90 1106.61 5900.54 0.00 0.00 0.00 O.OOG 5979500.07 589241.31 N 70.35377267 W 149.27533373 Well Design Ver 3.1 RT -SP3.03-HF 1.2 Bld( d031 rt-546 ) L-210\Pian L-210 (N-W)\Plan L-210\L-210 (P9) Generated 11/10/200312:54 PM Page 1012 Comments I M=~ I Inclination I Azimuth I TVD I Su~a TVD I Vertical I NS EW I DLS I BuHd Rate I Walk Rate I Tool Face I Northing EastIng Latitude Longitude SectIon (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) ( deg/100 ft) ( deg/100 ft) ( deg/100 ft) (deg) (flUS) (flUS) Mb2 8013.98 67.00 79.13 4172.60 4100.00 6150.37 1137.71 6062.48 0.00 0.00 0.00 O.OOG 5979532.96 589402.88 N 70.35385727 W 149.27401868 Crv 4/100 8183.85 67.00 79.13 4238.98 4166.38 6306.33 1167.20 6216.04 0.00 0.00 0.00 108.36G 5979564.15 589556.09 N 70.35393748 W 149.27277170 8200.00 66.80 79.80 4245.31 4172.71 6321.14 1169.91 6230.65 4.00 -1.25 4.13 108.10G 5979567.03 589570.66 N 70.35394487 W 149.27265307 Mc 8205.79 66.72 80.04 4247.60 4175.00 6326.44 1170.84 6235.89 4.00 -1.24 4.14 108.01G 5979568.02 589575.89 N 70.35394740 W 149.27261051 8300.00 65.61 83.97 4285.68 4213.08 6411.95 1182.84 6321.20 4.00 -1.18 4.18 106.42G 5979580.96 589661.06 N 70.35397998 W 149.27191776 Na 8387.79 64.66 87.70 4322.60 4250.00 6490.16 1188.63 6400.62 4.00 -1.08 4.25 104.85G 5979587.64 589740.40 N 70.35399562 W 149.27127288 8400.00 64.54 88.22 4327.84 4255.24 6500.91 1189.02 6411.64 4.00 -1.02 4.28 104.62G 5979588.15 589751.42 N 70.35399666 W 149.27118336 Nb 8457.01 63.98 90.68 4352.60 4280.00 6550.64 1189.52 6462.99 4.00 .{J.97 4.31 103.56G 5979589.22 589802.75 N 70.35399790 W 149.27076645 8500.00 63.59 92.54 4371.59 4298.99 6587.60 1188.44 6501.54 4.00 -0.91 4.34 102.73G 5979588.56 589841.31 N 70.35399485 W 149.27045346 Nc 8569.01 63.02 95.57 4402.60 4330.00 6645.87 1184.08 6563.03 4.00 .{J.84 4.38 101.38G 5979584.89 589902.84 N 70.35398280 W 149.26995421 8600.00 62.78 96.93 4416.72 4344.12 6671.57 1181.08 6590.45 4.00 -0.77 4.41 100.75G 5979582.20 589930.29 N 70.35397453 W 149.26973161 8700.00 62.10 101.38 4463.00 4390.40 6752.44 1166.99 6677.94 4.00 -0.68 4.45 98.69G 5979569.08 590017.92 N 70.35393582 W 149.2_33 End Crv I Tgt OA 8783.97 61.65 105.15 4502.60 4430.00 6817.65 1150.00 6750.00 4.00 -0.54 4.49 O.ooG 5979552.90 590090.16 N 70.35388925 W 149.26843637 OA 8815.55 61.65 105.15 4517.60 4445.00 6841.68 1142.74 6776.83 0.00 0.00 0.00 O.OOG 5979545.93 590117.06 N 70.35386933 W 149.26821860 OBa 8973.47 61.65 105.15 4592.60 4520.00 6961.85 1106.41 6910.97 0.00 0.00 0.00 O.DOG 5979511.10 590251.59 N 70.35376975 W 149.26712974 OBb 9089.28 61.65 105.15 4647.60 4575.00 7049.97 1079.77 7009.34 0.00 0.00 0.00 O.DOG 5979485.56 590350.24 N 70.35369672 W 149.26633125 OBc 9226.14 61.65 105.15 4712.60 4640.00 7154.11 1048.28 7125.60 0.00 0.00 0.00 O.OOG 5979455.37 590466.83 N 70.35361041 W 149.26538759 OBd 9341.95 61.65 105.15 4767.60 4695.00 7242.24 1021.64 7223.97 0.00 0.00 0.00 O.OOG 5979429.83 590565.48 N 70.35353737 W 149.26458911 Tgt OBd 9499.87 61.65 105.15 4842.60 4770.00 7362.40 985.31 7358.11 0.00 0.00 0.00 O.OOG 5979395.00 590700.00 N 70.35343777 W 149.26350029 OBe 9499.89 61.65 105.15 4842.61 4770.01 7362.42 985.31 7358.12 0.00 0.00 0.00 O.OOG 5979395.00 590700.02 N 70.35343775 W 149.26350015 OBf 9615.68 61.65 105.15 4897.60 4825.00 7450.53 958.67 7456.48 0.00 0.00 0.00 O.OOG 5979369.46 590798.65 N 70.35336472 W 149.26270183 OBf Base 9710.43 61.65 105.15 4942.60 4870.00 7522.63 936.87 7536.96 0.00 0.00 0.00 O.OOG 5979348.56 590879.36 N 70.35330495 W 149.26204855 TO /7" Csg 9749.87 / 61.65 105.15 4961.33 4888.73 7552.64 927.80 7570.46 0.00 0.00 0.00 O.ooG 5979339.86 590912.96 N 70.35328007 W 149.26177661 Leaal Deseriøtion: Northina (Y) rftUS1 Eastina 00 rftUS1 Surface: 2604 F5L 3560 FEL S34 T12N R11E UM 5978328.00 583354.00 Tgt OA: 3751 FSL 2088 FEL 535 T12N R11 E UM 5979552.90 590090.16 Tgt OBd: 3586 F5L 1480 FEL 535 T12N R11E UM 5979395.00 590700.00 BHL: 3528 FSL 1268 FEL S35 T12N R11E UM 5979339.86 590912.96 e WeUDesign Ver 3.1RT-SP3.03-HF1.2 Bld( d031rt-546) L-2101Plan L-210 (N-W)IPlan L-210IL-210 (P9) Generated 11/1012003 12:54 PM Page 2 of 2 WEll L-210 (P9) FIELD Prudhoe Bay Unit· WOA STRUCTURE L-PAD ~gwat!cParam&laffi MoOO1: BGGM2Oû3 Dip 00.819' MagDec: +25.13:)' I Sutfsoolocatioo ~~:=::T20,?JJ03 .. ~:: :~~:';:'~11 NAQ27AIaska stale. f'IaMs, Zooo04, US Fool Northfig: 591832ltoo ftus: Grid Cony: +Oß37352.93' fasting: 583354.(WftU$ SœIeFacI; (t9990018926 ...""- ffiot: t-210 PI1;In: t,210(P9) TVORof: 4000 4500 5000 5500 6000 6500 7000 7500 8000 L-~10PB1 (P3) 3500 3500 g 0 ~ 4000 4000 g ..... II .!1 ,~ f/) £:) ~ 4500 4500 5000 5000 4000 4500 5000 5500 6000 6500 7000 Vertical Section (ft) Azirn '" 75°, Scale'" 1(in):500(ft) Origin'" 0 N/-S, 0 E/-W 7500 8000 WELL L·21 0 (P9) FIELD PrudhoeBêlY Unit· WOA S'fRUGTURE l..PAD MagooticParamatars Mede!: BGGM 2003 Djp: 80.819'" Mag Dm:: +~.133' ~:' ::::,20200,1 ~""t~~1'~;;~71 NAD27 AJooImStatø Planes, Zone04, us feet Northing: S9'r8326.00ftUS GridCorw: +Q·.e313~· Eîil!iÍk¡g: ~B3354~OO:f\!)S ~F<tCt:OJW9Q01-81)26. """''''''''''' S1o!.' L.21Q p¡m; L~2JJ){P9) TVORef: (ß{72ßOftaÞowMSl) $1W_;·~2I),~ 4000 4500 5000 5500 6000 6500 7000 7500 8000 2000 2000 ^ ^ ^ Z g <::) <::) '!1 ;§: 1500 1500 ...- II (!) ~ (/) V V V 1000 1000 2500 2500 L-210PB1 500 500 4000 4500 5000 5500 6000 6500 «< W Scale" 1(in):500(ft) E »> 7000 7500 8000 i Company: Field: Referenee Site: Referenee WeD: Referenee Wellpath: BP Amoco Prudhoe Bay PB l Pad Plan L-21 0 (N-W) Plan l-210 e BPX AK Anticollision Report NO GLOBAL SCAN: Using user defined selection & sean criteria Interpoiation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 9749.87 ft Maximum Radins: 10000.00 ft Survey Program for Definitive Wellpath Date: 11/10/2003 VaUdated: No Planned From To Survey ft ft 28.50 6000.00 Planned: Plan #3 V2 (1) 6000.00 9749.87 Planned: Plan #9 V2 Casing Points MD ft 4239.19 9749.87 TVD ft 2697.60 4961.33 Diameter in 9.625 7.000 Summary < Site Offset Wellpath Well PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad L-01 L-01 L-02 L-02 L-102 L-102 L-102 L-103 L-104 L-105 L-106 L-107 L-108 L-109 L-110 L-111 L-112 L-114 L-115 L-116 L-117 L-118 L-119 L-120 L-121 L-121 L-122 Plan L-113 (N-B) Plan L-123 (N-R) Plan L-124 (N-C) Plan L-124 (N-C) Plan L-200 (N-M) Plan L-200 (N-M) Plan L-200 (N-M) Plan L-201 (N-U) Hole Size in 12.250 8.750 Name 9 518" 7" =- Wellpath L-01 V14 L-01L 1 V2 Plan: Plan # L-02 V1 L-02PB1 V21 L-102 V2 L-102PB1 V10 L-102PB2 V2 L-103 V23 L-104 V7 L-105 V4 L-106 V14 L-107 V14 L-108 V18 L-109 V12 L-110V11 L-111 V24 L-112 V8 L-114 V14 L-115V7 L-116 V10 L-117V11 L-118 V9 L-119V9 L-120 V8 L-121 V14 L-121A V1 L-122 V5 Plan L-113 V5 Plan: PI Plan L-123 V1 Plan: PI Plan L-124 PB1 V1 Plan Plan L-124 V1 Plan: PI Plan L-2oo OBd V1 Plan Plan L-2ooL 1 OBa V1 PI Plan L-2ooL2 OA V1 Pia Plan L-201 V1 Plan: PI Date: 11/10/2003 e Time: 13:16:27 Page: 1 CcMmIû1ate(NE) Refereaee: Vertical (TVD) Refereøee: Well: Plan L-210 (N-W), True North l-210 Plan 72.6 Version: 2 Tooleode MWD+IFR+MS MWD+IFR+MS Reference MD ft 497.14 497.14 385.38 385.38 950.65 854.38 854.38 393.18 550.47 692.45 831.18 592.20 734.14 345.81 295.49 246.39 338.20 488.23 438.01 538.54 343.57 485.12 393.41 243.49 246.17 246.17 343.32 346.88 398.57 393.96 393.96 397.22 397.22 397.22 8391.51 Offset MD ft 500.00 500.00 400.00 400.00 950.00 850.00 850.00 400.00 550.00 700.00 850.00 600.00 750.00 350.00 300.00 250.00 350.00 500.00 450.00 550.00 350.00 500.00 400.00 250.00 250.00 250.00 350.00 350.00 400.00 400.00 400.00 400.00 400.00 400.00 10250.00 Referenee: Error Model: Sean Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name MWD + IFR + Multi Station MWD + IFR + Multi Station Ctr-Ctr No-Go Dlslanee Area ft ft 236.12 7.99 236.12 7.99 308.82 6.68 308.82 6.79 166.60 13.94 171.17 13.60 171.17 13.60 59.64 6.30 178.60 8.11 186.08 11.93 149.91 13.29 220.41 10.77 178.75 12.50 283.68 6.90 320.56 5.23 412.16 4.26 326.98 6.89 384.32 7.40 248.61 7.11 295.88 7.90 235.07 5.26 215.08 8.72 13.77 6.31 16.75 4.03 346.94 4.32 346.94 4.32 280.69 5.46 355.17 7.48 75.66 6.87 340.70 6.91 340.70 6.91 150.47 7.02 150.47 6.90 150.47 6.90 164.01 218.43 AHowable Deviation ft 228.13 228.13 302.14 302.03 152.66 157.56 157.56 53.34 170.49 174.15 136.62 209.65 166.25 276.78 315.33 407.90 320.08 376.92 241.50 287.99 229.81 206.36 7.46 12.72 342.62 342.62 275.24 347.69 68.79 333.79 333.79 143.46 143.57 143.57 -54.42 Wa~g Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk FAIL: Major Risk Site: PB L Pad A Drilling Target Conf.: 95%- Description: Top OA Map Northing: 5979552.90 ft Map Basting: 590090.16 ft Latitude: 70021'14.oo1N Shape: Circle Target: L-210 OA Tgt A: Plan L-21O (N-W) ~ on: Planned Program Vertical Depth: 4430.00 ft below Mean Sea Level Local +N/-S: 1150.00 ft Local +E/-W: 6749.99 ft Longitude: 149°16'06.371W Radius: 200 ft _.._--_._-~"- 1500 1500 14-00 1300 ~ I 1200 + 1100 1000 900 800 0 CJ CJ CJ CJ CJ CJ CJ CJ Q ~ CJ CJ CJ CJ CJ CJ CJ CJ Ln LD I m 0- CJ N ~ ~ J LD LD LD LD LD I I I ~ j } 1 Site: PB L Pad e Drilling Target Conf.: 95% Description: Base OBd Map Northing: 5979395.00 ft Map Easting : 590700.00 ft Latitude: 70021'12.376N Shape: Circle Target: L-210 OBd Tgt ~) :~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ CJ CJ (I) I CJ CJ -+ I A: Plan L-21O (N-W) ~ on: Planned Program Vertical Depth: 4770.00 ft below Mean Sea Level Local +N/-S: 985.31 ft Local +E/-W: 7358.09 ft Longitude: 149° I 5'48.60 I W Radius: 100 ft CJ CJ Ln I CJ CJ LO I 1300 1200 1100 1000 900 800 a l e TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head w/?" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" xA-1/2" tubing hanger 11" X 4-1/16" Adaptor Flange " L-210i PB 1 Pilot Hole Proposed P&A / Cellar Elevation = 52.3' Nabors 9ES RKB = 80.8' 20" X 34" 215.5 Iblft, A53 ERW Insulated 1 114' MDI 9-5/8", 40 lIft, L-80, BTC 14,231' MD I / 6,000' MD 8 3/4", Lowside KOP (Injector Mainbore) 8,458' MD Top of Cement Abandonment Plug 8,558' MD Top Schrader Ma Sand _._ I 9,965' MD Base OBf Sand I 10,053' MD 83/4", TD (PB1 Pilot Hole) Date 11/07/03 Rev By TomS Comments Pilot Hole Proposed Abandonment GP~l,1 ---1JJ,,- ç1~ ,-' - '.. '··.'7 ~ ;cø/ t~ ,l"~/ /'" llji/I';. ~./.,J ",~~t'1 j' WELL: L-210i API NO: 1 #Ift, TREE: FMC 5M & packott .4 Ii. 20" X 1 bore. TVD I 2,Jts. 4 1/2" I .. 4-1/2", 12.6 Drift 110 : 3-112",9.3Iblft, L-80, TCII Drift 110: 2.867"12.992" with bore. Packer 3" MD I MD I -/IIIII~ I PLANT hs'oo'oO' GRID " L -PAD e . N-L (NWE-1) L-111i. · N-A (NWE-2) i L-113 L-114. L-124 L-SD · L-112i · L -02 L-121 · iL-122 L-110 · L - 211 i L-SI · L-115i L-116 . · L-117 L-109 . · L-118 II L-SL · L-01 · L -200 + L-107 . ~ L-108i. :1 L -123 t L-105i. L-103i L-106 . L-201 t L-104 . L-119i s-w · L - 21 Oi L-102. I~ L-120 VICINITY MAP N.T.S. LEGEND + AS-STAKED CONDUCTOR . EXISTING CONDUCTOR NOTES 1. DATE OF SURVEY:NOVEMBER 19, 21-22, 2001. 2. REFERENCE FIELD BOOK: Wo03-14 PAGES 01-13. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTlON. 5. BASIS OF ELEVATION IS L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. 1Xsj¡,~~~ ~:ç:>,~sxx:I Jiiir"",,"" "", .( /- ."",. .J LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS L-123 y= 5,978,309.07 N= 10,000.00 70'21'02.543" 70.3507064' 498' 2,586' FSL x= 583,281.76 E= 5,295.00 -149'19'25.789" -149.3238303' . 3,632' FEL y= 5,978,240.49 N= 10,000.00 70'21'01.896" 70.3505267' 48.0' 2,521' FSL L-124 x= 583,025.81 E= 5,030.00 -149'19'33.291" -149.3259142' 3,889' FEL y= 5,978,289.66 N= 10,000.00 70'21'02.360" 70.3506556' 49.1' 2,568' FSL L-200 x= 583,209.32 E= 5,220.00 -149'19'27.912" -149.3244200' 3,704' FEL y= 5,978,320.72 N= 10,000.00 70'21'02.653" 70.3507369' 49.8' 2,597' FSL L-201 x= 583,325.22 E= 5,340.00 -149'19'24.515" -149.3234764' 3,588' FEL y= 5,978,328.48 N= 10,000.00 70'21'02.726" 70.3507572' 50.4' 2,605' FSL L-21Oi X= 583,354.20 E= 5,370.00 -149'19'23.665" -149.3232403' 3,559' FEL y= 5,978,259.90 N= 10,000.00 70'21'02.079" 70.3505775' 48.1' 2,539' FSL L-211i X= 583,098.25 E= 5,105.00 -149'19'31.168" -149.3253244' 3,816' FEL o 11/23/03 ISSUED FOR INFORMA1l0N NO. DA1E REV1S1ON ~œOb' DRAWN: ObP JACOBS CHECKED: AWSON DATE: 11/23/03 DRAWING: GPB WOA L -P AD SHEET: FRB03 WOL 02-00 ¡ ffi~~[[](l;o JOB NO: SCALE: AS-STAKED CONDUCTORS ENGI~[[RS ANO LAND SURYF:YORS 1 OF 1 JJ RFA IID1WEST f1REWEEO LAN£ 1'= 130· WELLS L-123, 124, 200, 201 210i & 211i BY CHK AN~ORAGE, ALASKA 99503 Permission to Drill L-21 Oi . . Subject: Permission to Drill L-2] Oi From: "Schaefer, Thomas J (CONTRACT PROFESSIONALS)" <schatj (iJ2 B P .com> Date: MOil, 22 Dee 2003 14:39:48 -0900 To: bob _ crandall@admin.state.ak.us CC: "Schmohr, Donll R" <SchmohDR@BP.eom> Bob, It is our intent to begin drilling operations on the L-210i in the Orion Development on approximately Friday December 26, 2003. We anticipate that it will take 19.22 days to drill the well and should take another two weeks to prepare the well for injection. That being said it would not be possible to inject until the beginning of February, 2004. Therefore it is with this letter that we ask for permission to drill and complete the L-210i. We will then wait to put the well on injection until the Area Injection and Conservation Order for the Orion Development has been approved. Please let me know what arrangements or further actions we need to take to facilitate this process and procure the drill and complete permit. Regards, Thomas Schaefer Alaska Drilling & Wells 907 564-4685 Office 907 564-4040 Fax 907 748-2883 Cell 1 of 1 12/22/20032:53 PM p055166 . . I DATE I I CHECK NO. 10/6/2003 055166 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 10/6/2003 INV# PR100103F PERMIT TO DRILL =EE Á-" ')...\0 HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .. BP EXPLORAT10N, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX NATIONAL CITY BANK Ashland, Ohio PAY: VENDOR DISCOUNT 56-389 412 NET No. P 055166 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$100.00*******1 NOT:3~~:~r~;~~~~~::~~;~.~~·:·~:::~·~~:·~~~·~:;!:}~::~i . _. l"',þI;~:~............~......._.........! :i"'(*~~~~~~~J¿i:;i~ TO THE ORDER OF: 1110 5 5 L b ¡; III I: 0... . 2 0 ~ 8 g 5 I: O. 2 ? 8 g ¡; liD · e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/] 0102 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing ,exception that may occur. AlJ dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool PRUDHOE SAY, ORION UNDEF OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L-210i Program SER Well bore seg D PTD#: 2031990 Company BP EXPLORATION (ALASKA) INC Initial ClasslType SER 11WINJ GeoArea Unit On/Off Shore On Annular Disposal D Administration 1 P~rmitfee attache-<:!, _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ ,_ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ , _ , 2 _Leas~,numberapprQpriate_, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ Y~s , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ , ,_ ,_ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ , 3 _U_nlque weltn_a(11~_a[1d o~mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WE~JIJQcat~d in_adefine-<:!PPQI. , , , _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ Xes _ The Gonsef'\{atiQn Order_a_nd AIQ forthe OriQn_deY.Area are intlJe. finatsta-ges Q(draJting._ _ _ _ _ _ _ _ _ _ , 5 WellJQcat~d proper _dista[1ce from driJling unitb9undary _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ This well.maybe apprQv_ed nQW as thes_e_ord,erswill be io place,befoJe. the welt can Þe drjlled and_beCQmes, 6 We.ll JQcat~d pr,oper _distance from QtlJer wells, _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ , _ , _ _ _ _ Xes _ _ _ _ _ OP,erational _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ 7 _S_ufficientj;lcrea9-e_aYailable in,dJilJiog ~njt , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , _ , _ _ _ Xes _ _ _ _ , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ , 8 Jtd~viated, js_ weJlbQre plç¡tincJuded , _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , , _ _ Yßs _ , _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _, ,_ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ _, ,_ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ 9 _Operator only affected party, _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ , _ _ Yßs _ _ _ _ , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ 10 _Operator bas_apprppriate_bond inJQrce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Pßrmit can be iss~ep wjtlJout consef'\{aJion Qrder _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ , , _ _ _ _ Yßs , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ , _ _ , _ _ _ _ _ _ _ , , _ _ _ _ _ Appr Date 12 Pßrmitca[1 Þe iss~ed wjtlJQut ad_mioistratilleapprpvaJ _ _ _ _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 12/19/2003 13 Can permit be approved before 15-day wait Yes 14 WelIJQC<lt~d within area al1d strç¡ta authorized byJnjectipo Ord_er # (putlO# in_cpm(11,ents) (FQr_ Xes _ _ _ _ _ _ se_e,aþQve _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJI wells_within Jl4J'uile_are.a_of review jdßotified (Fpr servjCßJl\lelJ onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre.-produj;ed injectQr; -<:!l,IratiQnof pre-pro_dI,lGtipoIßss than 3 montlJs_ (FQr_seryice well QnJy) _ _ _NA _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ , 17 ACMP,F:indjngof CQn_sistency_h_as beenissued3prJbis proiect _ _ _ _ _ _ _ , _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 18 _C9ndu_ctor st(ing_pJQvided _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , ,Yßs _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _, _ _ _ _ _ _ _ _ , 19 _S_urfaCß,casingpJQtects alLknown USDWs _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ Yßs _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , , 20 _CMTvoladequateJo circ_utate_oncond_uctor_& sU,rfcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs _ _ _ , _ _ _ Ade~l,Iate excess, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ , , 21 _CMT v,ot adequateJQ tie-inJQng ,string to_surf ~g_ , , _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ , _ _No_ , , _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ , _ 22 _CMTwill cover_aJl koownpro_ductive bQri~ons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , 23 Casing de_signs ad_ec¡uaJe fpr CoT, B,&permafrpst _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ 24 ,Adequate tankage_oJ re_serve pit _ _ _ _ _ _ , _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ Y~s , _ _ _ _ _ _ f\lab9rs9,ES, _ _ _ _ , , _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , , _ , , _ _ _ _ _ _ _ _ _ _ ,,_ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ 25 JtaJe-prilL basa 10A03 fOJ abandonment been apPJoved _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ , f\lew well, _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , 26 _Adequate well bore_ sepç¡ratio_n_proposep _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jfdjvecter Jeq,uired, dQes jt meet reguJa,tions_ _ _ _ , , , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , Appr Date 28DJiUing flujd_program schemç¡tic_&. equip Jistadequate , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y,es _ , , Mç¡x MW9,5- ppg,_ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ ,_ ,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , WGA 12/19/2003 29 ,BOPEs, do _they meet reguJation _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ , , _ _ _ Xes _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ , 30 BOPE_pre.ss raJiog appropriate; Jest to,(put psig in_comments) , _ _ _ _ _ _ _ _ _ , _ Xes _ _ _ , _ Test tp AOQO_ psi.MSF' 17_30 psi. _ _ _ _ _ _ _ _ _ , , _ , _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ , _ , 31Choke_manjfQld cQmpJies_ w/APt RF'-53 (May 64).. , _ _ _ _ Y~L _ _ _ _ _ _ , _ _ _ _ _ ,_ _ _ _ .. _ _ _ 32 WQrk will PÇCur withoutoperç¡tjonsb~tdown_ _ , _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ , _ _ _ Y~s _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _ _ _ 33 Js presençe, Qf H2S gas_ prob,aþle _ _ _ _ _ _ , _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ ,,_ _ _ _ _ _ _ , , , _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ " ,_ _ _ _ _ _ _, ,_ _ _ _ _ _ 34 MeclJa_nicç¡Lcpod,itio[1pfwe.lIswithinAOB,yerified(Fors_erviceweIJQnJy)_ _ _ _, _ _ _ _ _ _ _ _ _ Yßs _ _ _ _ _ _f\lowellsjn_AQR._ _ _ _ _ _ _ _" _ _ _ _ _ _ _ _ _ _" _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, _ _ _ _ _ _ _ _, e e Appr RPC 35 36 Date 37 12/19/2003 38 39 Permit c_an Þe issued wfo_ hYdrogen, s,ulfide meaS~res _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _Yßs _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _D_ata_PJesented on pote_ntial pverpres_sl,lre _zones, _ _ _ , , _ _ _ _ _ _ _ _ , , _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _SeLsmic_anç¡lysjs_ Qf slJaJIQW gas_zpoes, ,_ _ _ _ _ _ , _ , _ _ _ _ _ _ _ _ _ _ _ , _ , _ _ NA _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ , _ _S~ç¡bedcondjtipo S~f'\{ey ,(if off-shPre) _ _ _ , _ _ _ _ _ _ _ _ _ _ , _ _ _ , _, ,_ _ _ _ NA _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ CQnta_ct nam_elphoneJQr_weelsly prpgressreports [expIQrç¡tpry _onlYl ' _ , , _NA , _ _ _ _ _ _ _, ,_ _ _ _ _ _ _ _ _ , _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ Geology pTS Date: \ 2./<.. cj.3 Engineering Commissioner: Date ~ Public Commissioner I ~V~ Geologic Commissioner: