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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:NSK Wells Integrity Eng CPF2 Cc:Automation, AK Wells; Livingston, Erica J; Sullivan, Sean T (OGC) Subject:RE: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling Date:Friday, July 11, 2025 10:36:00 AM Timeframe for receiving the results of sample analyses? CPAI’s inspection frequency while we wait for the results? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com> Sent: Wednesday, July 9, 2025 10:19 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling Well Name: 2L-326 Facility: CFP2 PTD: 209-027 Well Type: Prod AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Jim, I was informed that during State Witnessed SVS testing on 2L, Sully requested information regarding gas bubbling in the cellars of 2L-326, 2L-327, and 2L-328 (PTD 209-027, 207-008, 214-189) . These wells are gas lifted production wells. CPAI conducts gas sampling of wells which experience bubbling in cellars and conductors and compares the bubbling gas samples to the lift gas samples and produced gas samples to confirm if the bubbling gases are coming from the applied lift gas in the IA, the target reservoir, or are shallow thawing hydrates on the pad. These wells have been sampled extensively in the past. The test results are attached. New samples were taken but the results will not be available for some time. All well’s bubbling gases have shallow thawing hydrate gas signatures marked by the lack of ethane and heavier gases. CPAI intends to keep these wells online. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 !"# $"! "%& !" ' ' ( ( ) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 ( )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- ( )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 ( 7&<'= 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; !"# $"! "%& !" ' ' ( ( ) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 074"'$- ,;2 45 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- >; *, * ) ,A<& ;<&@ !"# $"! "%& !" ' ' ) # $% ! * )3, &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- )6 0-49 1- -49 1- )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- ( 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 ,A<& ;<&@ !"# $"! "%& !" ' ' ) # $% ! * )3, &$'!( , .%/ %" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; *, * ) 3 , @%>: . !"# $"! "%& !" ' ' ) # $% ! * )3, &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , ( )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- ( 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 ( 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 3 , @%>: . !"# $"! "%& !" ' ' ) # $% ! * )3, &$'!( , .%/ %" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; *, * ) ( !"# $"! "%& !" ' (' ( ) # $% ! * #$+",- &$'!( 9> &B/C" ' ' ( )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- (( )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 ( 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" ' (' ( ) # $% ! * #$+",- &$'!( 9> &B/C" ' ' ( )($ #%& *+$*) # 74"'$- ,;2 45 ( 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- ( @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- (( )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 ( 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 ( 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) ( !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( &DB,> ." ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 ( )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- (( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , ( )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( &DB,> ." ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 ( 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- ( )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , ( )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 ( >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 ( 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- >; *, * ) !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' (' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 ( )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 !"# $"! "%& !" ' ' #) # $% ! * #$+",- &$'!( , .%/ %" ' (' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 ( 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) ( !"# $"! "%& !" ' ' ( #) # $% ! * #$+",- &$'!( , .%/ %" ' (' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 ( )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- (( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- ( )6 01#-14 1- 1#-14 1- ( )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" ' ' ( #) # $% ! * #$+",- &$'!( , .%/ %" ' (' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) !"# $"! "%& !" '' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 !"# $"! "%& !" '' #) # $% ! * #$+",- &$'!( , .%/ %" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 ( 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) ( !"# $"! "%& !" ' ' ) # $% ! * #$+",- &$'!( .%@/ A E" '' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- ( )6 037"4 1- 37"4 1- ( )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , ( )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- ( 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" ' ' ) # $% ! * #$+",- &$'!( .%@/ A E" '' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- ( >; *, * ) !"# $"! "%& !" ' ' ) # $% ! * #$+",- &$'!( @D/,D %@" '(' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ ( )6 0,(9- :3-$ ,(9- :3-$ ( )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 !"# $"! "%& !" ' ' ) # $% ! * #$+",- &$'!( @D/,D %@" '(' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 ( 7&<',; +131-0#$-"$- 31-#$-"$- ( @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- >; *, * ) ( !"# $"! "%& !" (' ' #) # $% ! * #$+",- &$'!( @D/,D %@" (' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 ( )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- ( )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- (( )6 037"4 1- 37"4 1- ( )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , ( )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 ( >' 0#*$ :3- #-,3;3,*$ :3- 0#*$ :$- #-,3;3,*$ :$- ( 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" (' ' #) # $% ! * #$+",- &$'!( @D/,D %@" (' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- (( @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- >; *, * ) ( !"# $"! "%& !" ' ' ( ) # $% ! * #$+",- &$'!( C BC%>@" ' ' )($ #%& *+$*) # 01 2134$+*-15 1 2134$+*-15 )6 0, $7+13+83- , $7+13+83- )6 0)-49 1- )-49 1- )6 0-49 1- -49 1- ( )6 0#$+# 1- #$+# 1- )6 037"4 1- 37"4 1- )6 017"4 1- 17"4 1- )6 03#-14 1- 3#-14 1- )6 01#-14 1- 1#-14 1- )6 04+4 , 4+4 , )6 04+4 , 4+4 , )6 0, 9- :3-$ , 9- :3-$ )6 0,(9- :3-$ ,(9- :3-$ )6 01-49- 4+;,+)7"43+1 1-49- 4+;,+)7 7&<',; 0 :-$ *-)+4 :-$ *-)+-," $4 >' 0#*$ :3- #-,3;3,*$ :3- ( 0#*$ :$- #-,3;3,*$ :$- ( 0,+)#; ,4+$ ,+)#$-37334? 074"'3- ,;2$?5 74"'3- ,;2$?5 ( 7&<',; 074"'$- ,;2$?5 74"'$- ,;2$?5 ( 7&<',; 074"'$- ,;2 45 ( !"# $"! "%& !" ' ' ( ) # $% ! * #$+",- &$'!( C BC%>@" ' ' )($ #%& *+$*) # 74"'$- ,;2 45 7&<',; 074"'3- ,;2 45 74"'3- ,;2 45 7&<',; +131-0#$-"$- 31-#$-"$- @% +131-04-)#-$ 4"$- 4-)#-$ 4"$- >; *, * ) • • • u -3/7 ('Th zeriodf30 Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, August 11, 2017 4:00 PM To: Bixby, Brian D (DOA) ! jOI�I+� Cc: Regg,James B (DOA) cj Subject: 170701 KRU 2L-Pad Deficiency Report Attachments: 2L AOGCC Deficiency Report - Completed File - 08-11-2017.pdf Brian, Please see the completed deficiency report for 2L. The paperwork, photo and lab reports have all been combined into a single file for simplicity. If you prefer separate files or need anything additional from us please let me know. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhiliaps Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 Original Message From: NSK Prod Engr Specialist Sent: Sunday,July 02, 2017 9:22 AM To: Bixby, Brian D (DOA)<brian.bixby@alaska.gov> Subject: RE: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Brian-enclosed is a signed copy of the AOGCC Deficiency Report for your records. We will follow up on this and send you documentation of the corrective actions taken when completed. Thanks, Darrell Humphrey 907-659-7535 Original Message From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent: Sunday,July 02, 2017 7:20 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Darrell, Please print this, sign it and send it back to me. Thanks, 1 • • Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. 2 • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Kg° ZL' 314 Date: ter zoi PTD: 2.1/4 -407.3 Operator: ecw joext (fi.,1144ii}S ALA‘VA- Type Inspection:¶ /s Operator Rep: ReLL tiuimilR�y Inspector& 1 11 Position:jap CtirJ ,�. -►ALIST 1 Op.Phone: q co, G59- /GSS�' Correct by(date): S per ) Xyn� . Op.Email: n f 3QeLNocoP14 . e.7 Follow Up Req`d: Detailed Description of Deficiencies Date Corrected 1 , 4 r� 14V V Z L -3)4 /‘16-64 inku..�l&LrAt.Let /ir / l ! .464v4. ALA- 6CCS 71-16g6 I S OatarC-ZUMLiPifrt up pu 66,(Ae. 11,41> Ah7--/17. AL.g. vP `r -LR' 'rHE FLuz-es O#'-k IIAJ US �„/ve.sr+(:)4TE 'To > ;; our 'Mt gAs Mb rt✓(1 6� ,Sc—.6 ,r is "i/OT" Attachments: {pr) O Ir�Sitated vLN S'/ n(2L-.3iv) LAB repos+s —gas anailpis. ‘\-) Operator Rep 7, 2. 7 Signatures: MA", (a L AOGCC Inspector *After signing,a copy of this form is to be le with the operator. Follow-up instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • KAA zL- 3,l • P7 looso Conor©Phillips Alaska AOGCC EXCEPTION REPORT Location: 2L Date: 07/01/17 AOGCC Inspector: Brian Bixby Correct by: September 1st 2017 Instructions: All exceptions listed below must be corrected by date noted on the AOGCC Deficiency Report. Documentation of the work performed is to be entered into the 'Action Taken'section below. Note - Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: 2L-314 - a well sign needs to be installed -Confirm sign is in place with a photo. 2L Wells- All wells need to be inspected for gas bubbling up through the cellars and Flutes. A gas sample is requested to determine the source. See AOGCC deficiency report. Action Taken to Correct Problem: Gas samples from the bubbling conductors/cellars as well as the IA's were taken from wells 2L-327 and 2L-326 on 7/6/17 (the OA FL's for both wells were at surface; therefore no OA gas sample could be obtained). Lab analysis of the composition of the gas samples from conductor/cellars showed they were methane and N2 primarily(as would be expected from natural ground sources with Date: 07/17/17 Initials: KAL air contamination). They did not match the annulus qases which contain significant quantities of ethane/propane/butane/pentane. On 2 separate occasions we attempted to obtain cellar/conductor samples from 2L-321 (bubbling had been observed from that well on the day of the inspector visit). However no t?ubbling was present on either day, which supports our understanding that the natural ground source gas liberation tends to be intermittent. A new sign with pertinent well information was installed on the Date: 08/11/17 Initials: MCR t/ outside of the well house. Please see attached photo. Date: Initials: Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod. Engr. Specialist: VIII • • • . n1139("?a,conocophillips.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops & DOT Pipelines Supt NSK Fieldwide Operations Supt • KUPARUK LAB ANALYTICAL REPORT oOPhilli ps 907-659-7214 n1020@cop.com Sample Number:S-170713-00229 • Sample Name: IA Casing Valve Location: Area:KUPARUK Unit:DS2L Sample Point:2L-327 (i7r Ze70060) Sampled Date: 7/6/2017 7:45:00AM Matrix Id: GAS-M1SC Reviewed By: Carville,Daniele Date:07/16/2017 Analysis Results: 1811 Parameter Result UOM D-1945*N2(NITROGEN) N2(NITROGEN) 0.361 Mole% D-1945*CARBON DIOXIDE CARBON DIOXIDE 1.190 Mole% D-1945•METHANE METHANE 81.776 Mole% D-1945*ETHANE ETHANE 8.312 Mole% D-1945*PROPANE PROPANE 4.647 Mole% D-1945*I-BUTANE I-BUTANE 0.954 Mole% D-1945*N-BUTANE N-BUTANE 2.001 Mole% D-1945*I-PENTANE I-PENTANE 0.307 Mole% D-1945*N-PENTANE N-PENTANE 0.300 Mole% D-1945*TOTAL C6S TOTAL C6S 0.098 Mole% D-1945*TOTAL C7S TOTAL C7S 0.046 Mole% D-1945*C6 HEAVIER C6 HEAVIER 0.151 Mole% D-1945*C8 HEAVIER C8 HEAVIER 0.007 Mole% D-1945*NET HEAT OF COMBUSTION NET HEAT OF COMB 1101.5 Btu/SCF D-1945*AVERAGE MOL WT AVERAGE MOLECULAR WT 20.59 g/mol D-1945*SP GRAV IDEAL SPECIFIC GRAV IDEAL 0.7108 D-1945*SP GRAV REAL SPECIFIC GRAV REAL 0.7129 D-1945*COMP FACTOR COMPRESSIBILITY 0.9967 D-1945*BTU/IDEAL CF(DRY) BTU/IDEAL CF(DRY) 1218.1 Btu/SCF D-1945*BTU/REAL CF(DRY) BTU/REAL CF(DRY) 1218.3 Btu/SCF D-1945*BTU/REAL CF(SAT) • • KUPARUK LAB ANALYTICAL REPORT y • ConocoPhillips 907-659-7214 n1020@cop.com Sample Number:S-170713-00229 Sample Name:IA Casing Valve Location: Area;KUPARUK Unit:DS2L Sample Point:2L-327 Sampled Date: 7/6/2017 7:45:00AM Matrix Id: GAS-MISC Reviewed By: Carville, Daniele Date:07/16/2017 Analysis Results: RAI Parameter Resul( UOM BTU/REAL CF(5AT) 1197.0 Btu/SCF D-1945*BTU/IDEAL CF(SAT) BTU/IDEAL CF(SAT) 1199.7 Btu/SCF Sample Notes/Comments • • KUPARUK LAB ANALYTICAL REPORT +C)1'iOCCIPhill1pS 907-659-7214 n1020@cop.com Sample Number:S-170713-00224 Sample Name:Conductor Flutes Location: Area:KUPARUK Unit:DS2L Sample Point: 2L-327 Sampled Date: 7/6/2017 9:45:00AM Matrix Id: GAS-MISC Reviewed By: Carville,Daniele Date:07/16/2017 Analysis Results: LeAt Parameter Result UOM D-1945*N2(NITROGEN) N2(NITROGEN) 49.204 Mole% D-1945*CARBON DIOXIDE CARBON DIOXIDE 0.152 Mole% D-1945*METHANE METHANE 50.590 Mole% D-1945*ETHANE ETHANE 0.007 Mole% D-1945*PROPANE PROPANE 0.001 Mole% 0-1945*I-BUTANE I-BUTANE 0.000 Mole% O-1945*N-BUTANE N-BUTANE 0.000 Mole% D-1945*1-PENTANE I-PENTANE 0.000 Mole% D-1945*N-PENTANE N-PENTANE 0.000 Mole% D-1945*TOTAL C6S TOTAL C6S 0.002 Mole% D-1945*TOTAL C75 TOTAL C7S 0.005 Mole% D-1945*C6 HEAVIER C6 HEAVIER 0.046 Mole% 0-1945*C8 HEAVIER C8 HEAVIER 0.039 Mole% D-1945*NET HEAT OF COMBUSTION NET HEAT OF COMB 460.3 Btu/SCF D-1945*AVERAGE MOL WT AVERAGE MOLECULAR WT 22.02 g/mol D-1945*SP GRAV IDEAL SPECIFIC GRAV IDEAL 0.7603 O-1945*SP GRAV REAL SPECIFIC GRAV REAL 0.7608 D-1945*COMP FACTOR COMPRESSIBILITY 0.9990 D-1945*BTU/IDEALCF(DRY) BTU/IDEAL CF(DRY) 513.9 Btu/SCF D-1945*BTU/REAL CF(DRY) BTU/REAL CF(DRY) 512.8 Btu/SCF D-1945*BTU/REAL CF(SAT) • KUPARUK LAB ANALYTICAL REPORTConoaPhillips 907-659-7214 n1020@cop,com Sample Number 5-170713-00224 Sample Name:Conductor Flutes Location: Area:KUPARUK Unit:DS2L Sample Point:2L-327 Sampled Date: 7/6/2017 9:45:00AM Matrix Id: GAS-MISC Reviewed By: Carville,Daniele Date:07/16/2017 Analysis Results: Test Parameter Result UOM BTU/REAL CF(SAT) 503.9 'Btu/SCF D-1945*BTU/IDEAL CF(SAT) BTU/IDEAL CF(SAT) 506.1 Btu/SCF Sample Notes/Comments ~ . ~~~ ~ ~~~~~~~ ~~~ ~'~~~~' ~~~~ '~~~~~~ ~ Or ar-ezon done wo-sided ~~I II'I I~ II II I II III ^ Rescarr Needed I) I II~I ~I I~ ( I III II~ 9 ~~ > ~ RESC N DIG TAL DATA OVERSIZED (Scannable) olor items: Diskettes, No. 1 ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERStZED (Nan-Scannabfe) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: Date: ~S~ ~ BY: Mar~a Project Proofing II I II'I I) II III I I'II BY: Maria Date: ~ ~S~ Scanning Preparation _~"~, x 30 =~ s +~= TOTAL PAGES !~ 3 ~/~~ ~ (Count does not include cover sheet) ~/~ ~ BY: Maria Date: ~S~ Y r~ Production Scanning Stage 1 BY: Stage 1 BY: Page Count from Scanned File: ~(Count does include co r sheet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: g p~, ~ C~ ~ ~S~ ~~ ~ ~ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s/~~ ~~.~.~.~.~~ ~~.~~ Scanning is complete at this point unless rescanning is required. P~eSCanned BY: Maria Comments about this file: Date: Quality Checked lsl II ~I II ~II II'I ~I~ 10/6/2005 Well History File Cover Page.doc ^1 ~ _ .} ~~ s ,: ~ _,,: ~~ ~ . _. ~ ~„ -, x V~+ ~ ~~ ~q "' y a '~ ~~ ~"` a: ~ =sf~b ~ ~, c ~QSy ,. MICROFILMED 6/30/201.0 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc F ~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070080 Well NamelNo. KUPARUK RIV U TARN 2L-327 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20542-00-00 MD 6568 ND 5648 Completion Date 7/19/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI~N Types Electric or Other Logs Run: Gr/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~y meairrnn rvumuc~ name ~cme ~ncwa rvo ~~R ~[op ~ ~.n R@GEIVCU ~.ornrnrnw pt 15229 Report: Final Well R Open 6/19/2007 Final Well Report, Table of Content, Equip & Crew, Well Detaiis. Geo Data, Pres/Form Data, Drilling Data, Daily Reports, w/Graphics PDF & TXT og 15229 Mud Log 2 Col 80 6568 Open 6/19/2007 MD Formation Log og 15229 Mud ~og 2 Col 80 6568 Open 6/19/2007 ND Formation Log Log 15229 Lithology 2 Col 80 6568 Open 6/19/2007 MD Lithology Log ' ~ Log 15229 Lithology 2 Col 80 6568 Open 6/19/2007 TVD Lithology Log og 15229 See Notes 2 Coi 80 6568 Open 6/19/2007 MD Gas Ratio Log Log 15229 See Notes 2 Col 80 6568 Open 6/19/2007 ND Gas Ratio Log I og 15229 See Notes 2 Col 80 6568 Open 6/19/2007 MD Drilling Dynamics Log Log 15229 See Notes 2 Col 80 6568 Open 6/19/2007 ND Drilling Dynamics Log og Temperature 5 Blu 1 50 6470 Case 7/25/2007 Temp Survey, Pres, GR, CCL 17-Ju1-2007 og Pressure 5 Blu 1 6050 6300 Case 7/30/2007 SBHPS, Temp, Pres, GR, ~ D Asc Directional Survey 0 6568 Open 8/23/2007 CCL 21-Ju1-2007 ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070080 Well Name/No. KUPARUK RIV U TARN 2L-327 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20542-00-00 MD sb6s ~w ~s compieuonuate //ly/ZUU/ GOl1lp12i10~5L8LUS l-UIL GUff@f1LJialUS l-VIL uw rv D C Lis 15408 Induction/Resistivity 445 6446 Open 9/12/2007 LIS Veri, FET, GR, ROP, NCNT, FCNT, NPHI, RHOB, w/Graphics PDF and EMF D C Lis 15409 ~Induction/Resistivity 445 6446 Open 9/12/2007 LIS Veri, FET, GR, ROP, NCNT, FCNT, NPHI, RHOB pt 15409 LIS Verification 445 6446 Open 9/12/2007 LIS Ver'r, FET, GR, ROP, NCNT, FCNT, NPHI, RHOB og `'Pressure 5 Blu 5770 6200 Open 7/10/2008 SBHPS, Pres, Temp, GR, CCL 28-Jun-2008 D C Pds 16582 ~essure 5770 6200 Open 7/10/2008 SBHPS, Pres, Temp, GR, CCL 28-Jun-2008 ED C 15229 Report: Final Well R r~(~. ~~ ~j~?, ~~j f ~~~~~,~,p ~, Open 6/19/2007 Final Well Report, Tabie of Content, Equip & Crew, Well Details. Geo Data, Pres/Form Data, Drilling Data, Daily Reports, w/Graphics PDF & TXT Well Cores/Samples Information: Name Sampie Interval Set Start Stop Sent Received Number Comments ADDITIONAI INFORMATION Weli Cored? Y~ Daily History Received? ~~ N Chips Received? Y~~ Formation Tops ~N Analysis Y /l~ Received? ~ ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 716/2009 Permit to Drill 2070080 Well Name/No. KUPARUK RIV U TARN 2L-327 Operator CONOCOPHILLIPS AL/~SKA INC API No. 50-103-20542-00-00 MD 6568 ND 5648 Completion Date 7/19/2007 Completion Status 1-OIL Current Status 1-OIL UIC N ,f . i Compliance Reviewed By: Date: ~ • ~ ~ Final LWD data for 2L-327 ConocoPhillips recently informed Sperry Drilling that all of the data distribution requirements for 2L-327 had apparently not been met. The data were originally distributed on August 31, 2007. Upon consulting our transmittal records, we were not able to ascertain whether or not all parties had received the data as specified by the ConocoPhillips Alaska Greater Kuparuk Area Data Distribution guidelines. Therefore, Sperry Drilling is re-issuing the data that should have been received in early September 2007. Please return a signed and dated copy of the transmittal to verify the data distribution requirements for this well have been met. Note that the data being re-submitted have not changed since the original distribution of August 2007. Regards, ° Bryan Burinda Principal Log Analyst Halliburton Sperry Drilling Services 6900 Arctic Blvd Anchorage AK 99518-2146 Direct: 907 273 3536 Cell: 907 748 3912 ~~~~~~~`a JUL 2 7 ~p~o ?~a'i~t~ ~il & Gas Cr,r~s. t._;~,, . ~. Anchora~e ~~ ~ ~~ ~ ~ ~ ~ ~EL,~ ~OG/~A°~A T NSI~II~1'AL Too AOGCC. Attn: Librariar- 2L-327 50-103-20542-00 LWD Final Data - 2L-327 2"/5" EWR/DGR MD 2"/5" EWR/DGR ND 2"/5" DGR/CTN/ALD MD 2"/5" DGR/CTN/ALD TVD 2"/5" DGR/BAT MD 2"/5" DGR/BAT ND Digitat Data: CD ROM disk Digital graphic logs in EMF, CGM, and PDF formats Viewers for EMF and CGM formats included. 1 Disk PLEASE ACKNOWLEDGE RECEIPT OF THESE DATA BY RETURNING A SIGNED AND DATED COPY OF THIS TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 ,; Fax: (907) 273-3536 ,~;€ y s~ Bryan~~3,~inda~l-l~al~ib_urton.com '~"~ ,> . ~ ~ ~. ;~ Date: _ - - ~ - Signed: ` Jtaly 16, 2009 AK-NIW-0004987725 1 Color Print 1 Color Print 1 Color Print 1 Color Print 1 Color Print 1 Color Print ~ - ~~~ -~~ ~ ~ ~S J~/'~ r; ~ /' i / / ; r , ,. ~~ ~ ,; f-~...__.._ . _ _ ___ ___ __.. - ~, Sct~lum~e~g~r NO. 4775 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD o~i~oios 2W-04 12061711 INJECTION PROFILE J O6/24/08 1 ~ 1 L-20A 10215099 PRODUCTION PROFILE QU '~ O6l26/08 1 1 1 G-05 12080389 LDL (p O6/27/08 1 1 3B-10 12061714 INJECTiON PROFILE °(' ~~ / - 06/27/08 1 ~ 2L-327 12061715 SBHP SURVEY `v 06/28/08 1 1 1J-1U9 12080390 SBHP SURVEY ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~'~r-- ~ 06/28/08 1 1 2X-15 12080392 SBNP SURYEY C- O6/29/08 1 1 2N-303 12061717 SBHP SURVEY O6/29/08 1 1 2L-309 12061718 SBHP SURVEY - f 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 ~ 2X-11 12080393 SBHP SURVEY ~j- s 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE ~ -- ( /(Q~j" 07/05/OS 1 1 2H-05 12080396 SBHP SURVEY ~'-.~- O6/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ O6/30/08 1 ~ 2H-11 12080394 SBHP SURVEY j 06/30/08 1 1 iD-07 12080398 SBHPSURVEY -_i 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ~ p 06/30/08 1 1 3C-15 11982441 USIT -(}(~ 1(0 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - (p ' 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE J p-6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 ~ ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ !~?~/ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska August 31, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2L-327 AK-MW-4987725 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2L-327: Digital Log Images 50-103-20542-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGI~TING AND RETURr1ING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ,~~ ~518 , ,~~~: ~~ ~ .,~ Da~~;~~,? . '.`a ^~~ ~i€ ~ ~ ;L , ; ~1 ;: s ~~a~9~^s3 ~ 4~, ,~~,~~, Signed: ab~--~b~ ~ ~ 5 ~~p ~ C~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Lo~s 2L-327 • August 31, 2007 AK-MW-4987725 1 LDWG formatted CD Rom with verification listing. API#: 50-103 -20542-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGIVING AI~TD RETLTRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ ~; ~~~ ~ ~~:~ ~ ~ ~~~~~ Date: rt~~'s~'N"~z „ ;j~~ y~s~,y. a~il3is~i I~3P(?i' .~.:;~iUi"~~~"-~ Signed: C~b~"d0~5 ~ 1 J ~l ~ ~' ~ ~. ~ . . ConocoPh~fl~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVED auG 2 s 2007 Alaska Oil & Gas Cons. Comm~ssion Anchorage f ~`O 01 ~--`~ ~ ~~ ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of . these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treahnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 12-13, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and voluxnes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ~~~ ~~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor , . ~ ~ ConocoPhillips Alaska inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Il~4n -- a/7 3/LW / Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top aff date Corrosion inhibitor Corrosion inhibitor/ sealant date 2L-305 2L-307 2L-311 2L-313 2L-315 2L-317 2L-323 2L--325 2L-327 21-329 198-240 198-256 203-155 198-219 198-218 200-210 198-251 198-209 2Q7-008 198-225 ft SF 10" 15" 15" 23" SF 9" 24" 20" 24" bbls N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A ft N/A N/A N/A N/A NIA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A al 1.7 8 9 5.9 5.9 4.2 3.4 9.3 6.8 6.8 8/13/2007 8/13/2007 8/13/2007 8/12/2007 8/12/2007 8/12/2007 ~ 8/12/2007 8/12/2007 8/12/2007 8/12/2007 . ~ ~ s a Co~-oCOP~r~ll~ps ~ Randy Thomas Kuparuk Drilling Team Leader Drilling & Welis P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~ ~' Y ~. ~ August 20, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t'' Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2L-327 AUG 2 1 ?~~17 Alaska Dil & Cas Cuns. C~tnmi~~i~~fl Anchorag~ , Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2L-327. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, _...~ ~-----~ ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~ STATE OF ALASKA ~ AUG 2 I 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ~'-~` ~~~.&~,~RCons. Commissio~ oraae 1a. Well Status: Oil ~ ~ Gas Plugged Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Weil Class: Development Q' Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., J~yf (/~~ ZesD7 or a,band.: J~, 2007 ~ 12. Permit to Drill Number: 207-008 /' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~.Z • May 30, 2007 ' 13. API Number: 50-103-20542-00 4a. Location of Well (Governmental Section): Surface: 226' FNL, 894' FEL, Sec. 22, T10N, R7E, UM ~ 7. Date TD Reached: June 11, 2007 ~ 14. Well Name and Number: 2L-327 ~ Top of Productive Horizon: 1553' FNL, 1431' FWL, Sec. 23, T10N, R7E, UM 8. KB (ft above MSL): Ground (ft MSL): 147' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 1738' FNL, 1572' FWL, Sec. 23, T10N, R7E, UM 9. Plug Back Depth (MD + ND): 6567' MD / 5647' TVD T8m Oil Pool '" 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460756 ' y- 5927621 ° Zone- 4 10. Total Depth (MD + TVD): ` 6568' MD / 5648' ND ' 16. Property Designation: ADL 380051 ' 3~'~S TPI: x- 463076 y- 5926282 Zone- 4 Total Depth: x- 463216 ~ - 5926098 ~ Zone- 4 11. SSSV Depth (MD + ND}: nipple @ 516' MD 17. Land Use Permit: g•2'f~o7 4599 18. Directional Survey: Yes ^~ No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1150' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE Wf. PER FT. GRADE TOP BOlTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 16" 62.5# H-40 28' 80' 28' 80' 24" 9 cu yds High Early 9-5/8" 40# L-80 28' 2550' 28' 2375' 12.25" 463 sx AS Lite, 262 sx DeepCRETE 7" 26# L-80 28' 5970' 28' 5114' 8.75" 235 sx LiteCRETE 4.5" 12.6# L-80 5772' 6560' 4937' 5641' 8 ~ 55 sx Class G ~~ i 23. Open to production or injection? Yes ~/ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET , 3.5" 5820' 4772' 6183'-6203' MD 5304'- 5321' ND 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6183' - 6203' MD 272980# of 16/20 carbolite 26. PRODUCTION TEST Date First Production July 31, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 8/1/2007 Hours Tested 23.5 hours Production for Test Period --> OIL-BBL 2312 GAS-MCF 420 WATER-BBL 58 CHOKE SIZE 60% GAS-OIL RATIO 627 Flow Tubing press. 1177 p Casing Pressure 2p32 Calculated 24-Hour Rate -> OIL-BBL 1878 ~ GAS-MCF 1178 WATER-BBL 59 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No / Sidewall Cores Acquired? Yes ` No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~i 4~ ~1~ ~ i._ =' ~r; ,•'', y ~4~:: ~ ~, . . NONE ~~s VE Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~J~~~7~~I"1L ~~`~ ( /-~ ~Ly~~? . a~ ~"'~Y~~ G ~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Pe~maf~ost - TOp surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1154' 1150' needed, and submit detailed test information per 20 AAC 25.071. C80 2670' 2470' C50 4274' 3738' C40 4757' 4117' C37 5075' 4366' T~ 5575 4768' T4 5862' S017' T3 6056' 5192' TZ 6238' 5352' K-3 6348' 5450' N/A ' Formation at total depth: Bermuda ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, cement detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Mike Greener @ 263-4820 Printed Name Randv Thomas Titie: Drillina Team Leader ~'~ "--.- ~ l2 c~sCO 7 ~ Signature 1 ~cv~~..L~ ~ ----- Phone ~~- ~.~~ ~~ Date INSTRUCTIONS Sharon Allsup-Dreke 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. 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: Report true vertica- thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 intervai 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConacaPhillips FtieNrk•w Web RepartJng Well Name: 2L-327 Job Type: DRILLING ORIGINAL Time Log Summary 05/29/2007 09:00 12:00 3.00 0 0 MIRlJ MOVE PSIT P Move rig off 2L-321 and over 2L-327 well. Align rig over wellbore, place containment and set down. RU diverter lines and prep rig for drilling. Loading and strapping 5" drill pipe in pipe shed. RU riser. RIG ACCEPTED THIS DATE @ 1200 hrs. Loading and stra in 5" Drill Pi e in i e shed. 12:00 17:00 5.00 0 0 MIRU DRILL RURD P Strap and tally driil pipe w/ finish NU riser on diverter. RU/ Power up EPOCH and S er Sun lo in units. 17:00 1830 1.50 0 0 MIRU DRILL PULD P RU floor to handie 5" DP and BHA e ui ment. 18:30 19:00 0.50 0 0 MIRU RIGMN SVRG P Service top drive and blocks. 19:00 22:00 3.00 0 0 MIRU DRILL PULD P PJSM, PU and make up 5" DP stands. Brin s ud mud aboard ri . 22:00 23:00 1.00 0 0 MIRU DRILL PULD P Load and tally 5" HWDP in pipeshed. 23:00 00:00 1.00 0 0 MIRU DRILL PULD P Pickup, drift and make up 5" HWDP stands in derrick. 05/30/2007 00:00 01:30 1.50 0 0 MIRU DRILL PULD P Finish PU 5" HWDP in stands, rackin back in derrick. 01:30 07:30 6.00 0 0 MIRU DRILL PULD P Load pipe shed w/ 9 5/8" casing, drift, strap and tally same. Take on additional s ud mud. 07:30 08:30 1.00 0 0 MIRU WELCT BOPE P Test diverter system. All tests successful, no re-tests. Witness waived Mr. Bob Noble AOGCC 08:30 09:00 0.50 0 0 MIRU DRILL OTHR P Calibrate Epoch / MWD systems. 09:00 10:30 1.50 0 0 SURFA DRILL PULD P PJSM, PU BHA for spud. 10:30 11:00 0.50 0 0 SURFA DRILL RURD P PJSM, RU Gyro unit / sheaves. 11:00 12:00 1.00 0 63 SURFA DRYLL DDRL P Commence drill ahead 12-1/4 hole. Ice at 32 ft. Drill out space for tools. WELL 2L-327 SPUDDED AT 1100 HRS 12:00 12:30 0.50 63 63 SURFA DRILL PULD P MU UBHO and stabilizer. 12:30 18:00 5.50 63 495 SURFA DRILL DDRL P Drill ahead 12-1/4 hole dir drl f/ 63' - 495' w/ Gyro surveys @ 222', 313', 404', 495'. 18:00 19:30 1.50 495 495 SURFA DRILL TRIP P TOH to PU remaining BHA. 19:30 23:00 3.50 495 495 SURFA DRILL PULD P PJSM, PU MWD, tesUprog same. PU NM Flex DC's. • 05/30/2007 23:00 00:00 1.00 495 543 SURFA DRILL DDRL P Cont Drlg f/ 495' - 543'. 05/31/2007 00:00 09:30 9.50 543 1,194 SURFA DRILL DDRL P Drill ahead 12-1/4 hole dretnl 543 - 1194 ft. Note discrepancy MWD with G ro data. 09:30 10:00 0.50 1,194 1,194 SURFA DRILL CIRC T Troubleshoot MWD, determine toolface readin s 90 dr out. 10:00 10:30 0.50 1,194 1,194 SURFA DRILL CIRC T Circfortrip. Shakerclean, cuttings normal quantity / quality. No gain / loss. 10:30 11:00 0.50 1,194 1,194 SURFA DRILL OWFF T Flow check, well static. 11:00 11:30 0.50 1,194 1,194 SURFA DRILL TRIP T PJSM, POH 5" DP to BHA. no drag / swab / ain / loss. 11:30 14:00 2.50 1,194 1,194 SURFA DRILL PULD T Flow check, handle BHA, discover MWD scribed 90 deg out of phase rior to run in hole. 14:00 14:30 0.50 1,194 1,194 SURFA DRILL SRVY T Download MWD data. 14:30 15:30 1.00 1,194 1,194 SURFA DRILL PULD T Flow check, handle BHA, RIH same, surface test MWD. MWD operational. RIH remainder BHA. 15:30 16:30 1.00 1,194 1,194 SURFA DRILL TRIP T Flow check, RIH 5" DP. No downdrag / ain / loss. 16:30 00:00 7.50 1,194 1,797 SURFA DRILL DDRL P Drill ahead 12-1/4 hole dretnl 1194 - 1797'. Max Gas 1367 units after drilling hydrates at 1330'. PU 102 klbs, SO 95 klbs, Rot Wt 100 klbs. 06/01/2007 00:00 11:30 11.50 1,797 2,575 SURFA DRILL DDRL P Drill ahead 12-1/4 hole dretnl 1797 to TD (12-3/4 interval) 2575 ft. ART = 4.71 hrs, AST = 3.60 hrs. Up 115, Dn 100, Rot 105. TD SURFACE INTERVAL THIS DATE 1130 HRS. AT 2575 FT. 11:30 13:00 1.50 2,575 2,575 SURFA DRILL CIRC P Survey, collect data, circ well clean. Cuttings returns normal quantity / quality. Cont cire shaker clean. No ain / loss. Back round as 10 - 16. 13:00 15:00 2.00 2,575 2,575 SURFA DRILL TRIP P PJSM, POH 5" DP. No drag / swab. Correct hole fill. 15:00 16:00 1.00 2,575 2,575 SURFA DRILL PULD P Ffow check, handle BHA. 16:00 16:30 0.50 2,575 2,575 SURFA DRILL SRVY P Download MWD data. 16:30 17:30 1.00 2,575 2,575 SURFA DRILL PULD P LD remainder MWD / dretnl assy. 17:30 18:00 0.50 2,575 2,575 SURFA DRILL PULD P MU bit sub / bit / BHA, fiow check, RIH BHA. 18:00 20:00 2.00 2,575 2,575 SURFA DRILL TRIP P Flow check, follow BHA with 5" DP. RIH U 2460', wash f/ 2460' - 2575' @ 100 spm x 2& 1400 psi. Had si nificant cla on bottoms u. 20:00 22:00 2.00 2,575 2,575 SURFA DRILL CIRC P CBU, circulate and condition mud. PU 105 klbs, SO 93 kibs. Circ @ 103 s mx2&1300 si. 22:00 00:00 2.00 2,575 2,575 SURFA DRILL TRIP P POOH f/ 2575' - 30'. Hole condition qood. Stabilizer and bit balled up. ~ 06/02/2007 00:00 02:00 2.00 2,575 2,575 SURFA DRILL PULD P Finish laying out bit and motor. Clean off floor. 02:00 0530 3.50 2,575 2,575 SURFA CASIN< RURD P Rig down drilling equipment on floor. Clear and RU casing running equipment. Perform dummy run w/ casing landing jt and hanger mandrel to insure proper set, OK. LD, cont to et read for runnin cs . 05:30 14:30 9.00 2,575 2,575 SURFA CASIN( RNCS P PJSM, commence RIH 9-5/8 / L80 / BUTT & HYD csg. MU shoe track (Guide shoe, 2 jts BTC csg, float shoe), one jt BTC csg, XO jt, 35 jts Hyd 511 csg, XO jt, Tam port collar, 21 jts BTC csg, csg pup and hgr. Final depths Guide shoe 2550 ft, Float collar 2469 ft. Note: CBU at 900, 2000, 2400 ft. Heavy clays to surFace. Clean up readily. Slight attending dn drag increase at circ depths. Cont to TD, circ last jt dn, no fili, no gain / loss. Correct displacement. Ave gas 45, eakin at 550 units. 14:30 15:30 1.00 2,575 2,575 SURFA CASIN( CIRC P PJSM, MU FMC mandrel hgr, test seat in Idg ring, cont re-cip pipe. Up 147, Dn 95. 15:30 17:30 2.00 2,575 2,575 SURFA CASINC CIRC P Circulate and condition mud for cement job @ 4 bpm & 250 psi., 6 bpm & 340 psi. PU 130 Klbs, SO 110 Kibs. Full retums. 17:30 21:00 3.50 2,575 2,575 SURFA CEME~ DISP P PJSM. Begin cmtjob, pump 5 bbls CW-100, Press Test lines to 4000 psi. Pump 45 bbls CW-100 @ 5 bpm & 340 psi. Drop btm plug, pump 50 bbls 10.9 ppg mud push w/ dye marker at start 5 bpm & 350 psi. Pump 367 bbls 10.7 ppg lead cmt @ 7 bpm & 570 psi. Pump 73 bbls 12.0 ppg tail cmt @ 5 bpm & 570 psi: Drop top plug. Pump 20 bbls CW100 @ 7 bpm & 550 psi. Displace remainder w/ rig @ 4 bpm. Bump plug at calculated displacement of 167 bbls. with 1400 psi. Bleed, floats holding. Had full returns through job. Reciprocated pipe through 1/3 displacement. Had dye to surface at 57 bbls total displacement away. Cmt in place at 2100 hrs. Total estimated cmt returns to surface 80.5 bbls. 21:00 23:30 2.50 2,575 2,575 SURFA CEME~ RURD P Rig down csg running eq, cmt head, wash down diverter and flow lines, clear/clean floor for next hase. 23:30 00:00 0.50 2,575 2,575 SURFA WELCT NUND P Nipple down diverter. 06/03/2007 00:00 12:00 12.00 2,575 2,575 SURFA WELCT NUND P PJSM, ND Diverter. Install wellhead. NU BOPE. ~ ~ 06/03/2007 12:00 16:30 4.50 2,575 2,575 SURFA WELCT BOPE P PJSM, test BOPE all components 250 / 3500 psi. Test successful, no re-tests. Witness waived Mr Chuck Scheive AOGCC. 16:30 17:00 0.50 2,575 2,575 SURFA WELCT BOPE P Pull test plug, set wear ring. 17:00 21:00 4.00 2,575 2,575 SURFA DRILL PULD P PJSM, PU 5" DP, stand bk in mast for drill out. 21:00 21:30 0.50 2,575 2,575 SURFA CASIN( OTHR P Perform quick pressure test on 9 5/8" casing to 2500 psi before pick up BHA to validate no roblems. OK 21:30 00:00 2.50 2,575 2,575 SURFA DRILL PULD P PJSM, pick up/make up BHA. 06/04/2007 00:00 01:30 1.50 2,575 2,575 SURFA DRILL PULD P Finish PU BHA. 01:30 02:30 1.00 2,575 2,575 SURFA DRILL PULD P Test & Upload MWD. PJSM, Install Nuke sources in lo in toois. 02:30 03:00 0.50 2,575 2,575 SURFA DRILL PULD P RIH w/ HWDP, Change out Jars. 03:00 05:00 2.00 2,575 2,575 SURFA DRILL TRIP P TIH w/ BHA #4. Slow and rotate throu h TAM ort collar. 05:00 06:00 1.00 2,575 2,575 SURFA DRILL CIRC P Continue RIH. Tag up at 2440'. CBU, cond mud, blow down top drive and re are for casin test. 06:00 07:00 1.00 2,575 2,575 SURFA CASIN OTHR P Test 9-5/8 csg 3000 psi / 30 min. Test successful. No re-tests. 07:00 08:30 1.50 2,575 2,575 SURFA CEME~ COCF P Wash to plugs / float collar at 2469 ft. Drill float, shoe track and guide shoe at 2550 ft. Hard cmt 2540 - 2555 ft. 08:30 09:00 0.50 2,575 2,600 SURFA DRILL DDRL P Drill new formation 2575 - 2600 ft. 09:00 10:00 1.00 2,600 2,600 SURFA DRILL CIRC P Flow check, C/C fluids for FIT. No loss / ain. 10:00 12:00 2.00 2,600 2,600 SURFA DRILL FIT P PJSM, perform FIT to EMW 16 ppg. (805 psi surface press) Build to 805 psi, no leak off. Close in, monitor press. Bleeds to 750 psi. Re-test, build to 805 psi, linear increase, no leak off. Close in, monitor press. Bleeds 750 psi in 10 min, then stable. Determine FIT 15.50 EMW. Monitor press 30 min, bleed approx .5 bbl. RD test e ui . 12:00 13:00 1.00 2,600 2,600 INTRM1 DRILL TRIP T Attempt drill ahead. MWD will not function. PJSM, POH 5" DP for MWD. 13:00 14:30 1.50 2,600 2,600 INTRM1 DRILL PULD T Flow check at BHA, handle BHA. remove source, LD MWD. 14:30 16:00 1.50 2,600 2,600 INTRM1 DRILL PULD T Trouble-shoot MWD Tools. 16:00 18:30 2.50 2,600 2,600 INTRM1 DRILL PULD T MU BHA, test & upload MWD. Shallow test, OK. PJSM, instali radioactive sources. 18:30 2030 2.00 2,600 2,600 INTRM1 DRILL TRIP T Trip in hole U 2540'. Circulate and work on MWD arameters. 20:30 00:00 3.50 2,600 2,790 INTRM1 DRILL DDRL P Tag up, drill 8 3/4" hole f/ 2600' - 2790 ft. SPP 1960 psi @ 550 gpm. PU 130 klbs. SO 90 klbs. WOB 5- 10klbs. 06/05/2007 00:00 00:00 24.00 2,790 4,437 INTRMI DRILL DDRL P Drill ahead f/ 2790' - 4437 ft Determine top Campanian sands at 2746' per geo. No flow, no noticeable gas.Up Wt. 175k Dn 110k Rot 130k TQ 8400 on 7500 off. ECD Max 10.8 Min. 10.4 PP 2090 Wt on bit 10k RPM 70 Max gas 33 units. ADT 15.49 AST 4.0 Wellbore exc condition. ECDs 10.70, no drag on connections. Torque low and stable. No ain / loss. 06/06/2007 00:00 01:30 1.50 4,437 4,512 INTRM1 DRILL DDRL P Cont drill ahead 8-3/4 hole dretnl 4437 - 4512 01:30 02:00 0.50 4,512 4,512 INTRM1 DRILL CIRC P Cire sweep for wiper trip. Approx 15% increase cuttings return at shaker. Cont cire shaker clean. 02:00 03:30 1.50 4,512 4,512 INTRM1 DRILL TRIP P PJSM, POH wiper trip to 2481 ft. Wellbore exc condition. 03:30 05:30 2.00 4,512 4,512 INTRM1 DRILL TRIP P Flow check, PJSM, RIH, wash 90 ft to btm, no fill. 05:30 00:00 18.50 4,512 5,880 INTRM1 DRILL DDRL P Drill ahead 8-3/4 hole dretnl 4512 to 5880'. 5034' ND 223k up 123k dn 148k ROT PP 2430 on 2300 off WOB 10-15k RPM 100 240 SPM 587 gals. TQ 12k ECD Max 11.0# Max gas 33 units. ART 10.1 hrs. AST 3.4 hrs. 06/07l2007 00:00 02:00 2.00 5,880 5,980 INTRM1 DRILL DDRL P Drlg. 8 3/4" directionai hole from 5880 to 5980'. TVD 5124'. 02:00 03:30 1.50 5,980 5,980 INTRM1 DRILL CIRC P Pump 35 bbl. weighted hi-vis sweep & clean hole for wi er tri . 0330 04:00 0.50 5,980 5,980 INTRM1 DRILL OTHR P Break down top drive & monitor well. 04:00 05:00 1.00 5,980 4,311 INTRM1 DRILL TRIP P Wiper trip from 5980' to 4311'. Hole in good condition-20k overpull in 2 places in lower art of hole. 05:00 06:00 1.00 4,311 5,980 INTRM1 DRILL TRIP P RIH to bottom, wash 5914 - 5980, no fill. 06:00 07:30 1.50 5,980 5,980 INTRM1 DRILL CIRC P Pump sweep, circ 150 bls csg fluid. Shaker clean, no gain, no loss. Fluid caliper with sweep indicates 5% washout. 07:30 08:00 0.50 5,980 5,980 INTRM1 WELCT OWFF P Flow check, well static. 08:00 14:30 6.50 5,980 2,481 INTRM1 DRILL PULD P PJSM, POH laying dn 5" DP for 7" cs run to 2481'. 14:30 16:30 2.00 2,481 2,481 INTRM1 DRILL OTHR P Clean Floor-PJSM=Siip & cut drlg. line. 16:30 18:30 2.00 2,481 864 INTRM1 DRILL PULD P Continue laying down 5" DP to 864'. 18:30 20:00 1.50 864 120 INTRM1 DRILL PULD P Empty pipe shed-lay down 5" HWDP= ars & 3 flex collars. 20:00 22:00 2.00 120 120 INTRM1 DRILL OTHR P PJSM-Remove nukes & download S er tools. 22:00 23:30 1.50 120 0 INTRM1 DRILL PULD P Lay down sperry tools & flush out same. 23:30 00:00 0.50 0 0 ~INTRM1 DRILL OTHR P Unload toofs & clean floor. 06/08/2007 00:00 01:00 1.00 0 0 INTRM1 CASIN( NUND P PJSM-Pull wear ring. 01:00 02:00 1.00 0 0 INTRM1 CASIN( NUND P Change upper rams to 7". 02:00 02:30 0.50 0 0 INTRM1 CASIN( OTHR P Test 7" rams 250-3500 psi. 02:30 06:00 3.50 0 0 INTRM1 CASINC RURD P PJSM-Rig up to run csg. 06:00 1430 8.50 0 4,200 INTRM1 CASINC RNCS P Commence RIH 7", 26", L80, BTC csg. Thread lock guide shoe, 2 jts csg, float collar, 1 jt csg. Test floats, cont RIH. CBU at 2550, 4200 ft. Clay / wall cake returns. Circ clean all circ de ths. 14:30 16:30 2.00 4,200 5,790 INTRM1 CASINC CIRC T Tight hole at 5780 ft. RU / circ 5 BPM / 420 psi. Wash free 5780 - 5790 ft. Clay / wallcake returns. No gain / loss. 16:30 18:00 1.50 5,790 5,970 INTRMI CASINC CIRC P Wash 5790 to 5940. PU Idg jt / csg hgr, wash 5940 to btm at 5980 ft, no fill. Re-cip csg, C/C drig fluids. 5 bpm at 487 si. U 195, Dn 110. 18:00 20:00 2.00 5,970 5,970 INTRM1 CASINC CIRC P Rig down fill up tool, Rig up circ. lines. CBU @ 6 BPM 450 psi. Circ. & reci rocate 20'. 20:00 20:30 0.50 5,970 5,970 INTRM1 CEME~ RURD P Break out circ. swedge & rig up cement head & circ. lines. 20:30 21:00 0.50 5,970 5,970 INTRM1 CEME~ CIRC P Circ. & condition hole & mud @ fi bpm 500 si. 21:00 22:30 1.50 5,970 5,970 INTRM1 CEME~ DISP P Test lines to 3500 psi Pump cement ~,~s, t~c/V`~~ 'f7~~ 4.~~ ` u~ Cti'~ per program. Bump plug w! 1700# 2:30 hrs. 22:30 00:00 1.50 5,970 5,970 INTRM1 CEME~ OTHR P Check floats, flush lines & rig down cement e ui ment. 06/09/2007 00:00 01:30 1.50 0 0 INTRM1 CEME~ OTHR P PJSM-Set packoff & test same to 5000 si OK. 01:30 02:30 1.00 0 0 INTRM1 CEME~ RURD P Change bails-pick up wash tool & wash bo ,s. 02:30 05:30 3.00 0 0 INTRM1 CEME~ OTHR P Rig up & pump 93 bbls. seawater down 9 5/8" X 7" annulus-Final pressure 500 psi followed with 85 bbls. diesel freeze protect-final pressure 1000 psi.. Change pipe rams to 4" while um in on annulus. 05:30 10:30 5.00 0 0 INTRM1 WELCT BOPE P PJSM, test BOPE, all related components 250 / 3500 psi. Perform accumulator press / volume / time test. Nitrogen full. All tests successful, no re-tests. Witness waived Mr John Cris AOGCC. 10:30 11:00 0.50 0 0 INTRM1 WELCT BOPE P Pull test ptug, set wear ring. 11:00 14:30 3.50 0 0 INTRM1 RIGMN SVRG P PJSM, C/O saver sub top drv, service ri , RU floor. 14:30 20:00 5.50 0 5,308 ~INTRM1 DRILL PULD P PJSM, commence PU 4" DP to 5308'. ~ 06/09/2007 20:00 21:00 1.00 5,308 5,308 INTRM1 DRILL OTHR P Rack & tally 27 jts. 4" drill pipe & 8 'ts. 4" hwd . 21:00 22:30 1.50 5,308 0 INTRM1 DRILL TRIP P POH from 5308' to Surface. 22:30 00:00 1.50 0 0 INTRM1 DRILL PULD P Clean floor-PJSM-Making up BHA. 06/10/2007 00:00 02:00 2.00 0 100 INTRM1 DRILL PULD P Pick up & make up BHA. 02:00 03:30 1.50 100 100 INTRM1 DRILL OTHR P Upload MWD & test same. 03:30 04:00 0.50 100 100 INTRM1 DRILL OTHR P PJSM=Load nukes. 04:00 06:00 2.00 100 1,150 INTRM1 DRILL PULD P Pick up 27 singles 4" DP & 8 jts. HWDP. 06:00 07:30 1.50 1,150 5,540 INTRM1 DRILL TRIP P Running in hole w/ BHA #7. Follow BHA with 4" DP in sgls include 43 stds from mast. 07:30 08:30 1.00 5,540 5,880 INTRM1 DRILL CIRC P Wash 5540 - 5880 to tag float collar. Trace cmt to surface. 08:30 09:00 0.50 5,880 5,880 INTRM1 DRILL CIRC P Cont cire shaker clean for esg test. 09:00 11:00 2.00 5,880 5,880 INTRM1 CASINC DHEQ P P,1SM, test 7" csg to 300Q psi /30 min. Test successful, no re-tests. 11:00 14:00 3.00 5,880 5,980 INTRM1 CEME~ COCF P Drill float collar, shoe track, guide shoe, 10 ft o en hole cmt. 14:00 14:30 0.50 5,980 6,000 INTRM1 DRILL DDRL P Drill ahead 6-1/8 hole 5980 - 6000 ft for LOT 14:30 16:30 2.00 6,000 6,000 INTRM1 DRILL CIRC P Displace well to 12 ppg drlg fluids. Cont C/C fluids. 16:30 17:30 1.00 6,000 6,000 INTRM1 DRILL LOT P Perform LOT (5141 ND, 12 ppg, 970 surface press) resulting in 15.60 EMW. 17:30 21:30 4.00 6,000 6,100 PROD1 DRILL DDRL P Drill ahead 6-1/8 hole dretnl 6000 -6100'. 21:30 22:00 0.50 6,100 6,100 PROD1 DRILL CIRC P Circulate bottoms up for samples. 22:00 00:00 2.00 6,100 6,160 PROD1 DRILL DDRL P Drlg. from 6100 to 6160'. 06/11/2007 00:00 11:00 11.00 6,160 6,568 PROD1 DRILL DDRL P Drlg. 6 1/8" Directional hole from 6160' to TD at 6568 ft. TD determined on site Geo. 11:00 13:00 2.00 6,568 6,568 PROD1 DRILL CIRC P Cire sweep, calculated fluid caliper indicates 3% washout. Cont circ shaker clean. Cuttings normal quantity / ualit . No ain / loss. 13:00 13:30 0.50 6,568 6,568 PROD1 DRILL TRIP P PJSM, POH 4" DP to 7" shoe at 5970. Wellbore exc condition. Normal drag. No swab / ain / loss. Correct hole fili. 13:30 14:00 0.50 6,568 6,568 PROD1 DRILL CIRC P Pump wt pill, flow check. 14:00 16:30 2.50 6,568 6,568 PROD1 DRILL TRIP P PJSM, POH for 4-1/2 liner run to BHA 16:30 19:00 2.50 6,568 6,568 PROD1 DRILL PULD P Flow check, handle BHA, lay dn HWDP, dretnl ass , download data. 19:00 20:30 1.50 6,568 6,568 I PROD1 DRILL PULD P Lay down & clean out sperry BHA. ~ • 06/11/2007 20:30 22:00 1.50 6,568 6,568 COMPZ DRILL OTHR P Clean floor, change out handling e ui ment. 22:00 00:00 2.00 6,568 6,568 COMPZ DRILL PULD P PJSM-Topic=Running 4.5" liner on 4" d. RIH to 558' w/ 4.5" liner. 06/12/2007 00:00 01:30 1.50 6,568 6,568 COMPZ CASIN RUNL P PJSM-Topic=running 4.5" liner. Run liner from 558' to 780'. 01:30 03:00 1.50 6,568 6,568 COMPZ CASIN OTHR T While making up liner hanger assembly to SBE, gaulded threads-lay down liner hanger & dress threads-change out x-over collar on sbe-retrieve liner wiper plug from below sbe. 03:00 04:00 1.00 6,568 6,568 COMPZ CASIN OTHR P Lubricate rig-send out directional tools & cs . e ui ment. 04:00 04:30 0.50 6,568 6,568 COMPZ CASIN WOEQ T Wait on x-over collar & liner wiper plug from baker deadhorse. 04:30 05:30 1.00 6,568 6,568 COMPZ CASINC OTHR T Make up x-over & install new liner wiper plug. Make up liner hanger assembl . 05:30 06:00 0.50 6,568 6,568 COMPZ CASINC OTHR P Change out handling equipment to handle 4" d . 06:00 07:00 1.00 6,568 6,568 COMPZ CASIN( RUNL P RIH w/ liner on 4" dp to 896'. & circ. ca aci of 4.5" liner & d. 07:00 13:00 6.00 6,568 6,568 COMPZ CASIN( RUNL P RIH w/ 4.5" liner on 4" dp from 896' to 5970' 13:00 14:30 1.50 6,568 6,568 COMPZ CASINC CIRC P Circ. bottoms up @ shoe as per town en ineer. 700 si 4 b m. 14:30 15:00 0.50 6,568 6,568 COMPZ CASIN RUNL P RIH from 5970' to 6560'. 15:00 17:30 2.50 6,568 6,568 COMPZ CASIN CIRC P Make up cement head -rig up cement lines & circ. & reci rocate. 17:30 18:30 1.00 6,568 6,568 PROD1 CEME~ DISP P Pressure test lines 3500. Cement liner as per program. Saw DP wiper and liner wiper plug latch-up and plugs bump at calculated displacement, ~ v~~- ~~~~ C~ C7L~ ~ t~ C~1D~ bumped plugs to 3750 psi and set hanger. Set down and verified hanger set. Rotate setting tool free, pressure ~ up to 1000 psi and picked up to see seals clear setting sleeve, OK. Circulate 40 Bbls at 8 BPM to ciear excess cement above liner. Set down on liner top and saw pins shear setting ZXP Liner To Packer, OK. 18:30 19:30 1.00 6,568 6,568 COMPZ CEME CIRC P Circ. out cement & condition mud. 19:30 20:30 1.00 6,568 6,568 COMPZ CEME OTHR P Rig down cement equipment & blow down lines. 20:30 00:00 3.50 6,568 6,568 COMPZ CEME PULD P POH laying down 4" dp. 06/13/2007 00:00 03:00 3.00 6,568 0 COMPZ CEME PULD P POH laying down 4" XT-39 DP. 03:00 03:30 0.50 0 0 ~ COMPZ CEME~ PULD P Break & lay down liner running tool. 06l13/2007 03:30 11:00 7.50 0 0 COMPZ RPCO OTHR P Rack, drift & tally completion string 3.5" tbg. Change out handling equipment-wash inside bop,s & chan e rams to 3.5". 11:00 13:30 2.50 0 0 COMPZ RPCOti OTHR P Load completion assembty on rig floor. Test 3.5" rams 250-3500 si. 13:30 15:30 2.00 0 0 COMPZ RPCOh OTHR P Load injector control line & spooler, cannon clam s& han sheave. 15:30 17:00 1.50 0 0 COMPZ RPCOh RCST P PJSM-Topic=Running 3.5" completion. RIH to chemical in'ection mandrel. 17:00 19:30 2.50 0 0 COMPZ RPCOh OTHR T Hook up & test chemical line. Dummy valve leaking by-change dummy valve & test new one, & test line both held OK. 19:30 00:00 4.50 0 3,500 COMPZ RPCOh RCST P Running in hole w/ 3.5" completion to 3500 MD. u wt. 60k down wt. 50k. 06/14/2007 00:00 03:30 3.50 3,500 5,820 COMPZ RPCOti RCST P Continue RIH PU 3-1/2" tubing & 'ewei as er detail. 03:30 05:30 2.00 5,820 5,820 COMPZ RPCOh RCST P Rig up & circ. down to seal entry @ 5802. No go tagged @ 5822'. Up wt. 97k dn wt. 64k. 05:30 06:30 1.00 5,820 5,820 COMPZ RPCOh HOSO P Space out & make up hanger. 06:30 08:30 2.00 5,820 5,820 COMPZ RPCO CIRC P Displace well w/ seawater @ 4 bpm. 08:30 09:00 0.50 5,820 5,820 COMPZ RPCOh CIRC P Pump & spot 10 bbls. 1% CRW-132 corrosion inhibitor @ bottom of com Ition in annulus. 09:00 13:00 4.00 5,820 5,820 COMPZ RPCO DHEQ P Rig up & test tbg. 2500 psi, Hold & chart for 30 mins. OK. Test 3.5" X 7" Annulus to 2500 psi. Hold & chart for 30 mins. OK Bleed tbg. & shear dck valve . Confirmed 13:00 15:30 2.50 5,820 5,820 COMPZ RPCOh OTHR P PJSM- rig down lines-change pipe rams to 5". 15:30 18:00 2.50 5,820 5,820 COMPZ RPCO NUND P PJSM-nipple down bope. 18:00 20:30 2.50 5,820 5,820 COMPZ RPCOti NUND P Secure bope-pick diverter-pick tree-install tree ada ter-ni le u tree. 20:30 22:00 1.50 5,820 5,820 COMPZ RPCOti DHEQ P Test tree 250-5000 psi-test chemicai in~ection line & han er void OK. 22:00 23:30 1.50 5,820 5,820 COMPZ RPCOh FRZP P Pull two way check-rig up lines-freeze protect well w/ 100 bbls. diesel-& 'U' tube same. 23:30 00:00 0.50 5,820 5,820 COMPZ RPCOh OTHR P Set back pressure valve-rig down & move off well 2L-327. (Rig released from 2L-327 Cc~ 2400 hrs. 6-14-07) r • 2L-327 Well Events Summary ~ J DATE Summary 7/16/07 TAG @ 6473' RKB. DRIFT TBG TO 6275' RKB W/ 16' DMY GUN & A MAX OD OF 2.70", NO PROBLEMS. JOB COMPLETE 7/17/07 TOOK TEMPERATURE LOG FROM TD AT 6470' TO SURFACE. ALSO TOOK TEMPERATURE SURVEYS EVERY 500'. TEMPERATURE AT 6470' WAS 144 DEGF. 7/18/07 PULLED DCK-2 SHEAR VALVE @ 5572' RKB AND SET DV. MIT TBG & IA INDIVIDUALLY TO 3500 PSI, GOOD TESTS. READY FOR PERFORATING. 7/19/07 SHOT PERFORATING GUNS FROM 6183'-6203'. GUN WAS LOADED WITH 6 SPF HSD HYPERJET 2506 CHARGES. HAD 2950 PSI ON WELL WHEN WE SHOT GUNS WHICH IMMEDIATELY BLED OFF TO 1600 PSI. 7/21/07 PRESSURE AT 6193' IS 3218 PSI. PRESSURE AT 6080' IS 3143 PSI. 7/26/07 Frac T3 Zone, With a total of 272980# of 16/20 Carbolite 12 PPA on formation 3148 BBL of SW, with an average pressure of 3265 psi average rate of 20 BPM. Frac pumped to completion, ISIP= 1422 psi, 15 min pressure = 1313 psi. NO FREEZE PROTECTION. 7/27/07 POST FRAC FCO TO 6455' CTMD USING SLICKSEAWATER AND 1.5# BIO SWEEPS, MAINTAINED 1.2 - 1 RETURNS DURING CLEAN OUT. WELL FREEZE PROTECTED TO 2500', TURN OVER TO SLICK LINE FOR POST FCO D&T, (( NOTE: IA WAS ON A VAC DURING FCO )) .IN PROGRESS 7/28/07 TAGGED FRAC SAND AT 6432' RKB, EST. 229' RATHOLE. PULLED DV FROM 5572' RKB. CIRC 150 BBL DSL DOWN TBG OUT IA. SET 5/16" OV AT 5572' RKB. COMPLETE. i • Halliburton Company Survey Report ~ ~ Halliburton Company Survey Report ~~Cnmp~dp . C~nactsPi~l~~-s,~last~a.tl~1C ~~= ~ Date 7Pi 1120~ Tlme 1~€ €}8 31 ~ Pa~~ ; ~~' =~id. - ` ~rparW[c Rn€ertlisit Co-nrd~nat~i~,~~tefegeuce ~ SiU~11 ~l; ~~'~~ 7ru~ lVorth , ~ Sai+~ ~u~~{'utc~l~ P~d _ '4~ert~al('~'~S?~f~~te~reace ~1.~32~" 1~~ 7 ' ~ l~ell~ . ~L ~'~ ~+e~on ~'~~}_Rel"ere~c~ ~i811 {~;t3~#T~,f}~~pE 19~~~Azi~ ~-Wellpatti: 2L.3~T ~~€ruey Ca~I~tio n M~fh~i. . ' TUlinimum Cunr~ture ' Ixb. O~acFe ; Survey 14m Iricr : az;m T~D :.' sys Tvn Nt~ : Etw :' nmap~i 14TapE ~.. ~i~~ I , ,, ft ` _o-~~ ',deg ' ft; ft ' ' ft .. : " :'.__'. ft ,: : ',ft _::; ft,, ~~. 2505.87 37.72 126.24 2340.04 2192.94 -339.28 478.04 5927279.06 461232.66 MWD+IFR-AK-CAZ-SC 2693.63 38.08 117.42 2488.31 2341.21 -399.95 575.83 5927217.89 461330.13 MWD+IFR-AK-CAZ-SC 2789.09 37.59 113.71 2563.72 2416.62 1325.22 628.63 5927192.35 461382.79 MWD+IFR-AK-CAZ-SC 2884.42 37.49 110.47 2639.31 2492.21 -447.05 682.44 5927170.24 461436.48 MWD+IFR-AK-CAZ-SC 2978.04 37.03 111.52 2713.82 2566.72 -467.36 735.35 5927149.66 461489.28 MWD+IFR-AK-CAZ-SC i 3073.90 37.14 114.99 2790.30 2643.20 -490.18 788.44 5927126.57 461542.25 MWD+IFR-AK-CAZ-SC ; 3160.41 37.18 117.30 2859.25 2712.15 -513.20 835.34 5927103.31 461589.02 MWD+IFR-AK-CAZ-SC ~ 3249.75 37.43 118.48 2930.32 2783.22 -538.53 883.20 5927077J3 461636J4 MWD+IFR-AK-CAZ-SC I 3354.38 37.95 118.59 3013.11 2866.01 -569.09 939.39 5927046.89 461692.77 MWD+IFR-AK-CAZ-SC ~ 3450.97 37.75 117.91 3089.38 2942.28 -597.14 991.60 5927018.57 461744.83 I MWD+iFR-AK-CAZ-SC i 3539.79 37.87 117.54 3159.55 3012.45 -622.47 1039.80 5926992.99 461792.89 MWD+-FR-AK-CAZ-SC i ~ 3640.39 37.59 116.66 3239.12 3092.02 -650.51 1094.60 5926964.66 461847.54 MWD+IFR-AK-CAZ-SC ~ 3727.34 37.42 116.61 3308.10 3161.00 -674.25 1141.92 5926940.68 461894.73 MWD+IFR-AK-CAZ-SC 3823.48 37.73 116.84 3384.29 3237.19 -700.61 1194.28 5926914.05 461946.95 MWD+IFR-AK-CAZ-SC ! 3924.10 38.21 117.09 3463.62 3316.52 -728.68 1249.46 5926885.69 462001.97 MWD+IFR-AK-CAZ-SC ' 4016.94 38.27 117.24 3536.53 3389.43 -754.92 1300.59 5926859.20 462052.96 MWD+IFR-AK-CAZ-SC 4112.04 38.26 118.50 3611.20 3464.10 -782.45 1352.65 5926831.40 462104.87 MWD+IFR-AK-CAZ-SC 4208.75 38.18 118.67 3687.18 3540.08 -811.08 1405.19 5926802.50 462157.25 MWD+IFR-AK-CAZ-SC 4301.81 38.52 118.36 3760.16 3613.06 -838.64 1455.92 5926774.68 462207.84 MWD+IFR-AK-CAZ-SC 4396.32 38.07 116.05 3834.34 3687.24 -865.42 1508.00 5926747.63 462259.78 MWD+IFR-AK-CAZ-SC 4486.78 37.87 113.58 3905.66 3758.56 -888.77 1558.51 5926724.02 462310.16 MWD+IFR-AK-CAZ-SC 4585.21 38.53 113.37 3983.01 3835.91 -913.02 1614.34 5926699.48 462365.85 MWD+IFR-AK-CAZ-SC 4673.52 38.76 117.16 4051.99 3904.89 -936.55 1664.19 5926675.69 462415.58 MWD+IFR-AK-CAZ-SC 4776.18 38.75 119.01 4132.05 3984.95 -966.80 1720.88 5926645.15 462472.11 MWD+IFR-AK-CAZ-SC 4868.57 38.79 117.98 4204.09 4056.99 -994.40 1771.73 5926617.29 462522.80 MWD+IFR-AK-CAZ-SC I 4956.75 38.71 118.25 4272.86 4125.76 -1020.41 1820.41 5926591.03 462571.34 MWD+IFR-AK-CAZ-SC ~ 5055.42 38.24 118.08 4350.10 4203.00 -1049.39 1874.53 5926561.77 462625.31 MWD+IFR-AK-CAZ-SC ~ 5151.84 37.78 117.15 4426.07 4278.97 -1076.92 1927.14 5926533.98 462677.77 MWD+IFR-AK-CAZ-SC 5246.03 37.30 115.90 4500.76 4353.66 -1102.55 1978.48 5926508.08 462728.97 MWD+IFR-AK-CAZ-SC 5337.11 36.65 115.59 4573.52 4426.42 -1126.34 2027.83 5926484.03 462778.19 MWD+IFR-AK-CAZ-SC 5430.54 35.85 114.86 4648.87 4501.77 -1149.89 2077.80 5926460.23 462828.03 MWD+IFR-AK-CAZ-SC 5525.81 33.94 117.52 4727.01 4579.91 -1173.91 2126.71 5926435.96 462876.81 MWD+IFR-AK-CAZ-SC 5620.67 32.18 119.72 4806.51 4659.41 -1198.67 2172.14 5926410.96 462922.11 MWD+IFR-AK-CAZ-SC 5715.87 29.67 123.82 4888.18 4741.08 -1224.36 2213.74 5926385.06 462963.57 MWD+IFR-AK-CAZ-SC 5806.32 28.17 128.60 4967.36 4820.26 -1250.15 2249.03 5926359.09 462998.72 MWD+IFR-AK-CAZ-SC 5902.80 25.52 133.35 5053.45 4906.35 -1278.63 2281.95 5926330.44 463031.49 MWD+IFR-AK-CAZ-SC 5977.06 24.34 136.39 5120.79 4973.69 -1300.69 2304.14 5926308.27 463053.56 MWD+IFR-AK-CAZ-SC j 6073.55 28.22 141.67 5207.30 5060.20 -1333.00 2332.02 5926275.82 463081.27 MWD+IFR-AK-CAZ-SC ~ ~ 6169.80 28.52 142.06 5291.99 5144.89 -1368.98 2360.26 5926239.70 463109.32 MWD+IFR-AK-CAZ-SC ~ 6260.32 27.83 143.03 5371 J9 5224.69 -1402.90 2386.25 5926205.64 463135.14 MWD+IFR-AK-CAZ-SC ~ i 6354.59 26.59 143.23 5455.62 5308.52 -1437.38 2412.12 5926171.03 463160.82 MWD+IFR-AK-CAZ-SC ~ 6446.04 26.07 142.31 5537.58 5390.48 -1469.68 2436.66 5926138.61 463185.19 MWD+IFR-AK-CAZ-SC ; 6531.56 25.02 143.37 5614.74 5467.64 -1499.06 2458.94 5926109.11 463207.31 MWD+IFR-AK-CAZ-SC ~ . 6568.00 25.02 143.37 5647J6 ~ 5500.66 -1511.43 2468.13 5926096.70 463216.44 ~ PROJECTED to TD ~'"*.~:`~ ~ ~ ~ ~s ~ ~ ~ ~ .. , .- a ~"• ~~ " ~ .. , ; a'~ ~ ~ . ~.. ~ , ~ . ~: .:.. v~~ • _ . API I UWI Surface Legal Location Field Name BU/JV Latitude (DMS) Longitude (DMS) 5010320542 10N 7E 22 TARN PARTICIPATING AREA Alaska 70° 12' 46.39" N 150° 19' 10.517" W ~ ~ Well Type Well Configuration Type Original KB Elevation (ft) KB-Ground Distance (ft) KB-CF (ft) ConocoPhillips WI (%) j ~ Development VERTICAL ; ' . .• :~ , - - :.~ v~~(~~ ,_ - _. ~b ;,, ,,. ,... :~' :~' , . - ,~'v ~-... ~ d , . , ~ , , :•i ~E€<< _9, ' "; ~ , ..,.o ~'E,.I~t~. ;~ ~ .' " ' _ , ~ E .,. .; ... .....: ....~~..: .n,,..,:.. . ~ ~ . ........ :; 1 _. Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 6/12/2007 18:00 6/12/2007 19:00 2L-327 Comment -.. ~:~1'~1iE'[tt S`.~ p~+, .~R .r!?1::....... t .. .; ~ . -' ,..,.; ~: : ~'r... , ,,, .,r ~. ~._ ~: ~- .... : ~..~ : ::.' . ~ .<,~~..~-:~~.~.~~ .,i n&.. ~..... -~ .~~....~~E~E~. ~i r ~ ~ . .!~'..a'~y ~~~... ~~ 1i~~ Ek~I~I~:....:.. ,E:, . ' ' ~ .,, „ `.:~ s ~.~/~.•, .: ~ . .; IE ......, t.... €A ~; ..' . .. .~~. .~~~5~ ...\~\ . ..., -s f .~. . ~.. ~'~. ~ ~~. h .... ~ ~ £:- ., , , " .~....... \\_C Description Objective Top (ftK6) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? ' Btm P1ug? Production Casing Cement Liner 5,772.0 6,567.0 Yes No No ~ Cement ~ ~ ~ Q (start) (bbl%min) Q (end) (bbl/min) Q (avg) (bbllmin) P (final ) (psi) P (bump) (psi) ~Recip? Stroke (ft) , Rotated? Pipe RPM (rpm) 4 4 4 1,067.0 3,800.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) ~ Comment ~ 1~~Yy p y~ ~s 1~ ~ . .MF~~~:R7i•I4~~IUYGS . ... .... E .....~EE :E E.. .`•?E .... :..-....,.; ... . ..;~: .~~'" .e.~~ EE~~. I` 7a E . •~ l~ E', \ ~' .:;~,~~~~ `~~.'~ \~ ~. ..:-... ' , ~~ C . ' ~ ...... . .:~... ~ . . . .: . ..... ~.:.: ~F ~`PE~ ~E E~,, ~~~' h.~1~; t~3 ..: .. ~'1, ~f . .: ' -2._."'.~.~. ~:.. . , .. :. -~ ~r~;,~ii ,.: ... ...~..:~'•i ~ : ~ ~ .. E g y .3~ _ .......... ...e . ~'3 '~.. '~~Za ~ .,, ~ ...\~~ ~ : . . . . . . , . '~z ~ . ..-. . ...:: Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbq Mud Push ( Yield (ft'Isack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) ~ Thickening Time (hrs) CmprStr 1(psi) ~j (.~u~,~y~~ . ~~7i.i~~~aA'a„ . .....: . .~. ~ .v..,..: .>- ~as,i'. : . . . f /„~y,F~.a~'..,`~........ . ...... ~ .. : . . =:. .. ,> ., _: . : . ,,. ~. . ...:~ , '~~ .,.,.:~ ~~ V'~f~ ..~~fE; .:~: • ......... . . . ~ . e`. ° Additive Type Concentration Conc Unit label ~t~~~ .'~ ~'~. , , .'. . ,. . ... . . .. : '. : J% ~' .~ „~~i : ., ( / 2~:. ~ ,., ,i ,,,~ ~..: , . - .... ..: ~~ ~/ ,. ' ~ , --: 4EE~~~~[E t-• ' ' ; : ....' ... ~..i:. .« . ..: :. , , .. . . "C .. I..P~.t...x. . ~ :., Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class iVolume Pumped (bbl) Production Cement 5,772.0 6,567.0 155 G ~ 30.9 ~` Yield (ft /sack) Mix H20 Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) i CmprStr 1(psi) 1.17 5.15 15.80 4.15 ,,. ..,} •~,, .r.~ ~~A.f~4i1~~~.~ , - . : , ~ ~~ ~~k \. :~.. ''. ..... .. . .. .....-.. . . ~: : .~.. `~ - '~ . , .',. . •'.., . '~. ~~.. l , . , . : . . < < `I:~ €~EE€ ~ ~E~~I .. ..~~ ....~. .YS 5 E ~. ~` . :~ v ~~ @~.•~ . . E~~ .~.. .. ~..~ ~'. . ~ . < '~ i\` ~ \ ~.: i+-*'€ . -a ., x.... . ~~. _ : Additive "- Antifoam ',Type i ( Concentretion ConcUnitlabel F: ~ __ ' Additive _ ! Type Concentration Conc Unit label Barite Additive ;Type Concentration Conc Unit label Chemical Wash ~ i ~ Additive I Type Concentration Conc Unit label ~u Gas Block ~ ~~ Additive ~ T e YP Concentration Conc Unit label Mud Spacer - Wate r Based Additive Type Concentration Conc Unit label Retarder ~: ~ ~ ~ ei ~ ~? ~_ "~~ ~ ~ s ~ ~ ... ~~ < ~~~~~ ~ ~ ~~~ ~~, ` ~ ~„ ~ ' ~ ~~e~ ,, ~ ::- ~T ~Y:F;. .k"~. 2_•.. ~~ . ~ ~ 3 C ~_ _ ~ i 31-Ju1-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-327 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 30.00' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 6,568.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ Date ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) o~c~~?- ~~~ ~ ~ "~ ~~~ ~~ ~~r~~~~~~s~~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ ~ ~, ~ ~~~ ~~..t! ~.~~.5~.~ ~ ~ ~~t17 ~~~~~ ~ii ~ ~~„~ ~>'~rr5. ~a~nrnis~ian r~n~hr~r~g~~ NO. 4343 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 07/27/07 1H-08 17850414 1NJECTION PROFI~E 07/23I07 1 2L-327 11665460 SBHP SURVEY 07121/07 1 2M-28 11850413 PRODUCTION PROFILE 07122/07 1 2M-32 17850415 GLS 07/24/07 1 2P-448A 11850403 SBHP SURVEY 07/21/07 1 1H-03 11632739 INJECTION PROFILE 07123107 1 2T-37 11632740 PRODUCTION PROFILE 07124/07 1 2H-14 11632738 PRODUCTION PROFILE 07122/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/23/07 ~ \~ ~~~~~7,~N~~~~~ U~~, ~ "~ ~. kt ~!! ~,~ ~'~rr n, NO. 4336 Schlumberger-DCS "~~°~i-- ~ ~ ~~~~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 `~~~~~+~'~ ~~l~ ~'~ {-~~~ ~~~!?~~ ~~~1r~f~~i~~it~1 ATTN: Beth ~~~~~'~~~r~`~`~ Kuparuk ~~ ~0~ -~~ Well Job # Log Description Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Color CD 2M-20 11629044 PRODUCTION PROFILE 07/11107 1 3M-20. 11665456 INJECTtON PROFILE 07113107 1 2M-27 11665457 INJECTION PROFILE 07114107 1 1 R-20 11632727 LDL 07112107 1 2M-47 11632731 INJECTION PROFILE 07114/07 1 3M-27 11632732 LDL 07115/07 1 1R-15 11632734 INJECTION PROFILE 07/17107 1 2L-327 11665460 TEMPERATURE SURVEY 07I17/07 1 2V-08A 11665459 USIT 07116l07 ~ 2Z-16 71665458 SCMT 07115/07 1 2N-343 11665463 INJECTION PROFILE 07I20107 1 1L-07 11632735 INJECTION PROFILE 07120107 1 1A-09 91632736 INJECTION PROFILE 07121107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~ ~t'~r'1~C~~11~~1 5 ~ ~ F~~,~ TRANSMITTAL / I/ CONFl~ENT/AL DATA ~~aska p~~ ~N 7 ~ ~~ FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken q~a'~Cons ~00, ConocoPhillips Alaska, Inc. AOGCC Suite 100 h~~a ~~ ss~a P.O. Box 100360 333 W. 7~' Ave., A'~ ~~ n Anchorage AK 99510-0360 Anchorage, Alaska 9950i RE: 2~-327 Permit: 205-042 DATE: 06/15/2007 Tarn Field, Kuparuk River Unit, North Slope, Rlaska 501032054200 ~D~-~~ ~~~~ Final Mudlog report with CDROM Final Well Report, Tarn 2L-327, Epoch Mud loggers, report date 6/11/2007; contents, equipment and crew, well details, geological data, pressure/formation strength; drilling data, daily reports. Formation logs(all 2"=100'); Formation log (MD}, formation log (ND); LWD lithology log (MD), LWD formation log (TVD); Gas Ratio Log (MD); Gas Ratio Log (7VD); Drilling Dynamics (MD); Drilling Dynamics (ND) CDROM: Final well report; morning reports, LAS data; DML data; remarks file Please sign, scan transmittal, save as .pdf format and e-mail to address below. Or return ta GPAI via mail. To a11 data recipients: A!l data is con~dentia! unti! State ofA/aska desiqnated AOGCC release date CC: Andy Andreou, PAI Geologist Receipt: Date: 1,~/~~D'~ ~~lJh9 . GIS-Technica/ Data Management ~ ConocoPhil/ips ~.~nchorage, A/aska ~ Ph~ 907.265.6947 Sandra.D.Lemke~Conocophillrps com Re: 2L-327 change of casing plan ~ ~ Tim and Mike, Sorry I didn't get back to you sooner. Your change of plans is appropriate given the information available. Nothing further is needed. I will put a copy of this message in the file. Tom Maunder, PE AOGCC Billingsley, Tim A wrote, On 4/12/2007 2:14 PM: Mr. Tom Maunder, After 2N-311A, we plan to move Nordic #3 out of Tarn and perform workovers in the Kuparuk field until returning to 2L pad to spud 2L-327 on approximately 5/25/07. Df 2L-327 APD (appr #207-008) was originally proposed as a 7" x 4-1/2" tapered long string. However, recent reservoir pressure information from offset injector 2L-329A indicates the reservoir pressure at 2L-327 proposed BHL could be as high as 11.8 ppg EMW (Data at the time of the permit to drill application indicated the reservoir pressure at 2L-327 would be only 10.5 ppg EMW). Therefore, if we attempted to drill all the way to TD with a 12.0+ pp mud, the ECDs of 12.7 ppg EMW would probably cause lost circulation somewhere in the long shale interval from the surface casing shoe to above the Bermuda pay interval. Therefore, CPAI proposes to top set with 7" casing just above the Bermuda pay interval and then drill out with a 6-1/8" bit and run a cemented 4-1/2" liner through the pay interval. The directional plan remains the same. «2L-327 schematic top set 4-5-07.doc» Here is the revised schematic. The cement program for the three casing strings is as follows: 9-5/8" surface casing same as on approved APD 7" intermediate string to 5964' MD, 1000' of cement above shoe with 50% excess = 80 sks or 47 bbls of 11.0 ppg Lite Crete 4-1/2" liner, 6561' TD to 5764' liner top, 130 sx or 27 bbls of Class G at 15.8 ppg. «2L-327, 70 Summary, V3 _1000'_.pdf» «2L-327, 70 CADE, V3 _100Q'_ pdf» 7" intermediate cementing summary and details «2L-327, 45 Liner Summary, V3.pdf» «2L-327, 45 Liner CADE, V3.pdf» 4-1/2' liner cement summary and details Please let me know if a revised APD is required. My last day of work will be Friday April 20, 2007 and then Mike Greener will be your contact for this well. 1 of~ ~ 4/17/2007 11:13 AM .~, ~ 2L-327 Producer Top Set Proposed Completion Schematic 3-1/2" Completian String C~ 3%" 9.2# L-80 EUE 8rd Spaceout Pups as Required 3%z' 9.2# L-80 EUE 8rd Tubing to Surface 3%' Camco 'DS mppie w/ 2.875" No-Go Profile. 3%:" x 6' L-80EC1E 8rd 30" x 16" 62.6# ! handlmg pups installed above and below, set at +/- 500' MU @ +/- 80' IvID ~ Cc~rt ~;ledcsr~, f'ci~ ~ 1~ i~cr tc? `[>S' n3~~i[:,,tt~ tn !~e ~is-iftecl #u 2.=3I". 3%a" x 1" Camco'KBMG' mandrels with dwnmy valves 3%2" x 6' Lr80 with E[JE 8rd handling pups installed above and below. GLM #1 at 2571' MD/2400' TVD Surface csg. GLM #2 at 4342' MD/3800' TVD 9-5/8" 40# L-80 BTC C"amcu Che~tc.=.1 Ij~,= ~4<a3~dre3 at i~~o;t~ ai~c>ve I;>.vest G~ ~-9 ~; +/- 2571' MD / 2,400' TVD (:I,M #3 at wo joints ~~nve sliding c~ ~~'t.;: ~~ Lowest 3%2" x I" Camco'KBMG' mandrel w! shear valve, pinned for 2000 psi shear (casing to tubing differential) two jts above sleeve. Load rest of GLMs with dwnmy valves 3%2' Baker 'CMU' siiding steeve w/ 2.813" Camco DS Q profile EUE 8rd, with 3%i' x 6' L-80 EUE 8rd handling pups installed two jts above 2.75" no-go profile 3%z" Camco'D' nipple w/ 2.75" No-Go Profile. 3%:" x 6' L-80EUE 8rd handling pups installed above and below, set at one jt above seals 7" 26# Is80 BTCM @5964' MD 3%:" Baker 80-40 GBH-22 casing seal assembly w/ 15' stroke, 3%z" x ]00' MD above top Bemuda 6' L-80 EUE 8rd crossover handling pup installed on top Baker Sea] Liner top, with ZXP packer and SBE set at +/~00' MD above 7" casing shce Future Bermuda Perforations top at 6064' MD/ 5197' TVD Praduction Liner 4%z' 12.6# Ir80 IBT Mod Baker 4%z" IBTM la~ding +/- 656]' MD / 5,64T TVD collar, float shce, float collar aisio~ ~ Preliminary Job Design Volume Calculations and Cement Svstems Volumes are based on 50% excess. Tail siurry is designed for 1000' MD above the intermediate casing shoe. Tail Slurrv Minimum thickening time: 190 min. (Pump time plus 120 min.) LiteCRETE @ 11.0 ppg - 3.30 ft3/sk 0.1503 ft3/ft x 1000' x 1.50 (50% excess) = 225.5 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 225.5 ft3 + 17.2 ft3 = 242.7 ft3 242.7 ft3/ 3.3 ft3/sk = 73.5 sks Round up to 80 sks BHST = 117`F, Estimated BHCT = 94`F. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time ~bpm~ (bbl) (min) (min) Drop Bottom Plug 10.0 10.0 MudPUSH II 5 25 5.0 15.0 Tail Slurry 6 47 7.8 22.8 Drop Top Plug 5.0 27.8 Pump Water 4 20 5.0 32.8 Switch to Rig Pum 5.0 37.8 Displacement 5 185 37.Q 74.8 Slow Rate 3 20 6.7 81.5 MUD REMOVAL Recommended Mud Properties: 10 ppg, P~ < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, P~ = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest and 2 per joint across shoe joint for proper cement placement. ~ ~ CemCAD E*well cementing recommendation for 7" Intermediate Operator : ConocoPhillips Alaska Well : 2L-327 Slant Producer Country : United States of America Field : Tarn State : Alaska Prepared for : Tim Billingsley Location Proposal N o. : V3 Service Point Date Prepared : 04-06-2007 Business Phone FAX No. Prepared by : Maureen Torrie Phone : 1-907-265-6336 E-Mail Adtlress : mtorrieQslb.com : 2L Pad : Prudhoe Bay : (907- 659-2434 : (907-659-2538 Disclaimer Notice: This information is presented in good faith, but no warranty is given 6y and Schlumberger assumes no liabiliry for advice or recommendations made wnceming results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment The results depend on input data provided by the Operamr and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlum6erger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring I well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date ot issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. ~ Freedom from infringement of patents of Schlumberger or others is not to be inferred. # Mark of Schlumberger ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 5964.Q ft BHST : 133 degF Bit Size : 8 3/4 in Previous String MD OD Weight ID ft in Ib/ft in 2571.0 9 5/8 40.0 8.835 Landing Collar MD : 5884.0 ft Casing/liner Shoe MD : 5964.0 ft ~ Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 5964.0 7 40.0 26.0 6.276 L-80 5410 7240 BTC Mean OH Diameter : 8.750 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 9.505 in Total OH Volume : 297.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 5900.0 8.750 50.0 9.505 5964.0 8.750 50.0 9.505 Page 2 2L-327 cement, V3.cfw; 04-06-2007 ; LoadCase Intermediate 1000' ; Version wcs-cem45_89 ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' Max. Deviation Angle : 38 deg Max. DLS : 3.511 deg/100ft MD ft Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 OA 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 330.0 330.0 0.6 180.0 -2.000 430.0 430.0 2.6 180.0 2.000 530.0 529.8 4.6 180.0 2.000 550.0 549.7 5.0 180.0 2.000 630.0 629.4 4.7 203.5 -2.494 730.0 729.0 5.5 230.7 2.497 800.0 798.6 6.5 244.1 2.507 830.0 828.4 5.9 237.8 -3.009 930.0 928.0 4.8 207.7 -3.000 1030.0 1027.6 5.3 173.5 2.999 1130.0 1127.0 7.2 151.5 3.002 1230.0 1225.9 9.6 139.6 2.991 1330.0 1324.1 12.3 132.6 3.006 1430.0 1421.2 15.1 128.2 2.996 1530.0 1517.1 18.0 125.1 3.002 1630.0 1611.4 20.9 122.9 3.000 1730.0 1703.8 23.8 121.2 3.000 1830.0 1794.2 26.8 119.8 3.000 1930.0 1882.3 29.7 118.7 3.005 2030.0 1967.8 32.7 117.8 2.996 2130.0 2050.5 35.7 117.0 3.004 2201.0 2107.4 37.8 116.5 3.015 2230.0 2130.3 37.8 116.5 0.000 2330.0 2209.4 37.8 116.5 0.000 2430.0 2288.4 37.8 116.5 0.000 2530.0 2367.4 37.8 116.5 0.000 2571.0 2399.8 37.8 116.5 0.000 2630.0 2446.4 37.8 116.5 0.000 2730.0 2525.5 37.8 116.5 0.000 2830.0 2604.5 37.8 116.5 0.000 2930.0 2683.5 37.8 116.5 0.000 3030.0 2762.5 37.8 116.5 0.000 3130.0 2841.6 37.8 116.5 0.000 3230.0 2920.6 37.8 116.5 0.000 3330.0 2999.6 37.8 116.5 0.000 3430.0 3078.6 37.8 116.5 0.000 3530.0 3157.7 37.8 116.5 0.000 3630.0 3236.7 37.8 116.5 0.000 3730.0 3315.7 37.8 116.5 0.000 3830.0 3394.7 37.8 116.5 0.000 3930.0 3473.8 37.8 116.5 0.000 4030.0 3552.8 37_8 116.5 0.000 4130.0 3631.8 37.8 116.5 0.000 4230.0 3710.8 37.8 116.5 0.000 4330.0 3789.9 37.8 116.5 0.000 4430.0 3868.9 37.8 116.5 0.000 4530.0 3947.9 37.8 116.5 0.000 ~ Page 3 21-32J cement, V3.cfw; 04-06-2007; LoadCase Intermediate 1000'; Version wcs-cem45_89 ~ ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Couniry : United States of America Loadcase : Intermediate 1000' MD ft Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 4630.0 4027.0 37.8 116.5 0.000 4730.0 4106.0 37.8 116.5 0.000 4830.0 4185.0 37.8 116.5 0.000 4930.0 4264.0 37.8 116.5 0.000 5030.0 4343.1 37.8 116.5 0.000 5130.0 4422.1 37.8 116.5 0.000 5230.0 4501.1 37.8 116.5 0.000 5330.0 4580.1 37.8 116.5 0.000 5430.0 4659.2 37.8 116.5 0.000 5530.0 4738.4 37.3 117.1 -0.588 5630.0 4819.3 34.6 120.9 -3.502 5730.0 4902.9 32.1 125.2 -3.483 5830.0 4988.7 29.7 130.2 -3.511 5930.0 5076.5 27.5 135.9 -3.489 5964.0 5106.7 27.5 135.9 0.000 Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1617.8 12.50 8.20 PermafroSt Sandstone 2650.0 12.50 8.20 C80 Sandstone 4230A 1220 9.00 C50 Sandstone 4730.0 1220 9.00 C40 Sandstone 5050.0 12.20 9.00 C37 Sandstone 5964.0 12.20 9.50 TD Sandstone Geothermal Temperature Profile MD ND Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1153.2 1150.0 30 0.4 2571.0 2399.8 62 1.6 5964.0 5106.7 133 2.1 Page 4 2L-327 cement, V3.ciw; 04-06-2007 ; LoadCase Intermediate 1000' ; Version wcs-cem45 89 ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' ~ Page 5 2L-3D cement, V3.cfiv; 04-06-2007 ; LoadWse Iniermediate 1000' ; Version wcs-cem45_89 ~ Client : ConocoPhillips Alaska Well : ZL-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loatlcase : Intermediate 1000' Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :5954.0 ft Casing Shoe :5964.0 ft NB of Cent. Used :79 NB of Floating Cent. :79 ~ Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2804.0 23 1/3 1121670-7-6-16 (1 /8")B 0.0 2786.0 4844.0 0 0/0 0.0 2804.0 5964.0 56 2/1 1121670-7-6-16 (1/8")B 0.0 4852.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ib 1121670-7-6-16 7 8.752 8.000 No Houma 8.500 254.03 1494.98 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 2L327cement,V3.cfvu;04-O6-2007; LoadCaselntermediate1000';Versionwcs-cem45_89 ~ Client : ConocoPhillipsAlaska Well : 2L327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' Section 3: fluid description Mud DESIGN Fluid No: 1 Rheo. Model : BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type : Fresh MUDPUSH II DESIGN Fluid No: 3 Density : 10.50 Ib/gal Rheo. Model : HERSCHEL B. k : 2.42E-1 Ibf.s^n/ft2 At temp. : 120 degF n : 0.181 Ty :1.601bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 25.0 bbl Density :10.OOIb/gal P~ : 14.000 cP Tv :22.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 205.1 bbl ~ 11 ppg LiteCRETE DESIGN Fluid No: 5 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL B. k : 7.62E-2 Ibf.s^n/ft2 At temp. : 115 degF n : 0.534 Ty :0.061bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 10.956 gal/sk Yield : 3.30 ft3/sk Porosity : 44.4 % Density :8.321b/gal Job volume : 432 bbl Quantity : 73.51 sk Solid Fraction : 55.6 % Base Fluid : 10.946 gal/sk Page 7 2L-327 cement, V3.cfw ; 04-06-2007 ; LoadCase Imermediate 1000' ; Version wcs-cem45_89 ~ ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' Section4:fluid sequence Job Objectives: Set Casing 100' above Bermuda top, isolate weaker zones from production zone (Bermuda). TOC=1000' above TD. Original fluid Mud 10.00 Ib/gal P~ : 14.000 cP Tr : 22.00 Ibf/100ft2 Displacement Volume 225.1 bbl Total Volume 293.4 bbl TOC 4964.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al MUDPUSH II 25.0 622.5 4341.5 10.50 k:2.42E-1 Ibf.s^n/ft2 n:0.181 Tv:1.60 Ibf/100ft2 11 ppg LiteCRETE 43.2 1000.0 4964.0 11.00 k:7.62E-2 Ibf.s"n/ft2 n:0.534 Tv:0.06 Ibf/100ft2 Water 20.0 5361.3 8.32 viscosity:3.000 cP Mud 205.1 0.0 10.00 P~:14.000 cP Tv:22.00 Ibf/100ft2 Static Security Checks : Frac 312 psi at 2571.0 ft Pore 188 psi at 5964.0 ft Collapse 5054 psi at 5884.0 ft Burst 7240 psi at 4341.5 ft Csg.Pump out 55 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments MUDPUSH II 5.0 25.0 5.0 25.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test, Drop Wiper Plug 11 ppg 6.0 43.2 7.2 43.2 80 LiteCRETE Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 4.0 20.0 5.0 20.0 80 Pause 0.0 0.~ 5.0 0.0 80 Switch to rig pump Mud 5.0 185.1 37.0 185.1 80 Mud 3.0 20.0 6.7 205.1 80 Total 01:20 293.4 bbl hr:mn Dynamic Security Checks : Frac 134 psi at 2571.0 ft Pore 133 psi at 5964.0 ft Collapse 5054 psi at 5884.0 ft Burst 6696 si at 0.0 ft Page 8 2L327 cement, V3.ctw; 04-0&2007 ; loadCase Intermediate 1000' ; Version wcs-cem45_89 ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of Americ~ Loadcase : Intermediate 1000' ft 8 o~ i- O O O N O O O ~ ~ ~ fh~gal 10 12 14 ' Time (min} -- -- ~- Nin. kydrostatic -__---I o ~ '~, ~ ~ . . - Max. Qynarric '~ ~ ~ ~..... Mn. D~rnarric j ', '~ «~„ Frac ' ' ~ .~.o .. ~ Pore , , , ~. ~, 'y tq ~ M/drostatic ~ ~~~ ~ ~' a =o ' , ~ ~ N , '. . ~ I I O 0 0 N O C .~ ~ 0 30 60 90 Fluid Sequence Dynamic Well Security Time (min) o _ Depth = 5964 ft p ~ .~,.,,w. Collapse ; ~~'., '~. ~~. ', ~. . '~~. O~ i.,~.... Burst i ' '.. ' ' '.. v ! ~ pgnarric ~ . ... . ... . _ .. : ~ : I : : 0 10 20 30 40 50 60 70 80 90 Time (min) M N ~ ~ N 7 ~-- y ~ ~ N a` c c Q rn 0 Page 9 2l-3D cement, 43.cfw; 04-D6-2007; LoadCase I~termediate 1000' ; Version wcs-cem45_89 10 20 30 40 50 60 70 80 90 Time (min) ~ ~ Client : ConocoPhillips Afaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate 1000' Section 6: WELLCLEAN II Simulator % % deg ~ 60 80 100 0 100 0 20 ° _ ._-- _ ~ o; ~--- Std Belw. Cent. ----- tvLd Contarrination i •~ Deviation ~ ! l ---- Cement Coverage - Uncontaninated Slurry , . ~ i , '~~ ~ '~. ~, . , . . '~~. ' '~, ' . ~ '~ I i ~ I I '~. .. '~. ~ ~', ~'~ i ' , .. '~~. '. ', ~ '. ', '~~ 0 °o ~ 0 o° c~ - Fluid Sequence Uncontaminated Slurry 40 Deviation Page 10 2L-327 cement, V3.ciw; 04-0G2007 ; LoadCase Intermediate 1000' ; Version wcs-cem45_89 Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 4/6/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@sib.com Top of Tail at ~ 5,464' MD < Liner Top at 5,764' MD Previous Csg. 7", 26.0# casing at 5,964' MD Volume Calculations and Cement Svstems Volumes are based on 50% excess. Displacement is calculated with a 4.5"- 16.6# drill string. Tail Slurrv Minimum thickening time: 160 min. (pump time plus 120 min.) GasBLOK w/ Class G+ 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + Q.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1044 ft3/ft x 300' x 1.00 (no excess) = 31.3 ft3 Liner Cap Liner Lap: 0.1044 ft3/ft x(5964' - 5764') x 1.00 (no excess) = 2~.9 ft3 Annular Vofume: 0.0942 ft3/ft x(6561' - 5964') x 1.50 (50% excess) = 84.4 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 7.7 ft3 Totals: 31.3ft3+20.9ft3+84.4ft3+7.7ft3= 144.3ft3 144.3 ft3/ 1.17 ft3/sk = 123.3 sks Round up to 130 sks BHST = 135~, Estimated BHCT = 106~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage ~bpm~ Volume ~min} Time (bbl) (min) < 4 1/2", 12.6# casing in 6 1/8" OH TD at 6,561' MD (5,647' ND) Pressure Test 10.0 - MudPUSH II 5 15 3.0 3.0 Tail Slurry 5 27 5.4 8.4 Drop Top Plug 3.0 11.4 Displacement 3 93 31.0 42.4 MUD REMOVAL Recommended Mud Properties: 12 ppg, P~ < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, P~ = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from 5764' MD to TD for proper cement placement. Mark of Schlumberger i '~ CemCADE*well cementing recommendationfor4.5" Liner Operator : ConocoPhillips Alaska Well : 2L-327 Slant Producer Country : United States of America Field : Tarn State : Alaska Prepared for : Tim Billingsley Location Proposal No. : V3 Service Point Date Preparetl : 04-06-2007 Business Phone FAX No. Prepared by : Maureen Torrie Phone : 1-907-265-6336 E-Mail Address : mtorrieQslb.com : 2L Pad : Prudhoe Bay : (907) 659-2434 : (907-659-2538 Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability tor advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the motlel, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighbming I ' well or wells might be affected by the treatment proposed herein it is the Operaror's responsibiliry ro notify the owner or owners of the well or wells accordingly. , Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of pa[ents of Schlumberger or others is not to be inferred. ~ Mark of Schlumberger . Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner Section 1: well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6561.0 ft BHST : 147 degF Bit Size : 6 1/8 in Previous String MD OD Weight ID ft in Ib/ft in 5964.0 7 26.0 6.276 ~ Drill Pipe MD OD Weight ID Grade Collapse Burst ft in Ib/ft in si si 5760.0 4 1/2 20.0 3.640 X-95 16410 15890 Liner Hanger : 5760.0 ft Landing Collar MD : 6481.0 ft Casing/liner Shoe MD : 6561.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in si si 6561.0 41/2 40.0 12.6 3.958 L-80 7500 8430 IBT Page 2 2L-327 cemenL V3.ctw; 04-06-2~01; LoadCase Liner, Version wcs-cem45_89 ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner Mean OH Diameter : 6.125 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 6.793 in Total OH Volume : 26.8 bbl (including excess) Max. Deviation Angle : 38 deg Max. DLS : 3.574 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 330.0 330.0 0.6 180.0 -2.000 430.0 430.0 2.6 180.0 2.000 530.0 529.8 4.6 180.0 2.000 550.0 549.7 5.0 180.0 2.000 630_0 629.4 4.7 203.5 -2.494 730.0 729.0 5.5 230.7 2.497 800.0 798.6 6.5 244.1 2.507 830.0 828.4 5.9 237.8 -3.009 930.0 928.0 4.8 207.7 -3.000 1030.0 1027.6 5.3 173.5 2.999 1130.0 1127.0 7.2 151.5 3.002 1230.0 1225.9 9.6 139.6 2.991 1330.0 1324.1 12.3 132.6 3.006 1430.0 1421.2 15.1 1282 2.996 1530.0 1517.1 18.0 125.1 3.002 1630.0 1611.4 20.9 122.9 3.000 1730.0 1703.8 23.8 121.2 3.000 1830.0 1794.2 26.8 119.8 3.000 1930.0 1882.3 29.7 118.7 3.005 2030.0 1967.8 32.7 117.8 2.996 2130.0 2050.5 35.7 117.0 3.004 2201.0 2107.4 37.8 116.5 3.015 2230.0 2130.3 37.8 116.5 0.000 2330.0 2209.4 37.8 116.5 0.000 2430.0 2288.4 37.8 116.5 0.000 2530.0 2367.4 37.8 116.5 0.000 2571.0 2399.8 37.8 116.5 0.000 2630.0 2446.4 37.8 116.5 0.000 2730.0 2525.5 37.8 116.5 0.000 2830.0 2604.5 37.8 116.5 0.000 2930.0 2683.5 37.8 116.5 0.000 3030.0 2762.5 37.8 116.5 0.000 3130.0 2841.6 37.8 116.5 0.000 3230.0 2920.6 37.8 116.5 0.000 3330.0 2999.6 37.8 116.5 0.000 3430.0 3078.6 37.8 116.5 0.000 3530.0 3157.7 37.8 116.5 0.000 3630.0 3236.7 37.8 116.5 0.000 3730.0 3315.7 37.8 116.5 0.000 3830.0 3394.7 37.8 116.5 0.000 3930.0 3473.8 37.8 116.5 0.000 4030.0 3552.8 37.8 116.5 0.000 \J Page 3 21327 cement, V3.cfiv; 04-0&2007 ; loadCase Liner, Version wcs-cem45_89 . Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner MD ft D'rrectional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 4130.0 3631.8 37.8 116.5 0.000 4230.0 3710.8 37.8 116.5 0.000 4330.0 3789.9 37.8 116.5 0.000 4430.0 3868.9 37.8 116.5 0.000 4530.0 3947.9 37.8 116.5 0.000 4630.0 4027.0 37.8 116.5 0.000 4730.0 4106.0 37.8 116.5 0.000 4830.0 4185.0 37.8 116.5 0.000 4930.0 4264.0 37.8 196.5 0.000 5030.0 4343.1 37.8 116.5 0.000 5130.0 4422.1 37.8 116.5 0.000 5230.0 4501.1 37.8 116.5 0.000 5330.0 4580.1 37.8 116.5 0.000 5430.0 4659.2 37.8 116.5 0.000 5530.0 4738.4 37.3 117.1 -0.588 5630.0 4819.3 34.6 120.9 -3.502 5730.0 4902.9 32.1 125.2 -3.483 5830.0 4988.7 29.7 130.2 -3.511 5930.0 5076.5 27.5 135.9 -3.489 6030.0 5166.0 25.6 142.5 -3.511 6064.0 5196.7 25.0 145.0 -3.574 6130.0 5256.5 25.0 145.0 0.000 6230.0 5347.2 25.0 145.0 0.000 6330.0 5437.8 25.0 145.0 0.000 6430.0 5528.4 25.0 145.0 0.000 6530.0 5619.1 25.0 145.0 0.000 6561.0 5647.1 25.0 145.0 0.000 ~ MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 1617.8 12.50 8.20 Permafrost Sandstone 2650.0 12.50 8.20 C80 Sandstone 4230.0 12.20 9.00 C50 Sandstone 4730.0 12.20 9.00 C40 Sandstone 5050.0 1220 9.00 C37 Sandstone 6064.0 15.00 11.70 Bermuda Top Sandstone 6250.0 15.00 11.70 Bermuda Base Sandstone 6300.0 15.00 11.70 C35 Sandstone 6561.0 15.00 11.70 TD Sandstone Geothermal Temperature Profile MD ND Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1153.2 1150.0 30 0.4 2571.0 2399.8 62 1.6 6561.0 5647.1 147 2.2 Page 4 2L327 cement, V3.ciw; 04-06-2007 ; LoadCase liner; Version wcs-cem45_89 . Client : ConocoPhillips Alaska Well : 21-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner ~ LJ Page 5 2L-321 cement, V3.cfw; 04-06-2007 ; LwdCase liner, Version wcs-cem45_89 ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Gountry : United States of America Loadcase : Liner Section 2: centralizer placement Top of centralization :5964.0 ft Bottom Cent. MD :6551.0 ft Casing Shoe :6561.0 ft NB of Cent. Used :22 NB of Floating Cent. :0 ~ Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft} 0081.0 6 2/1 P1104641-4 1/2-4-46 (3/16")B 43.6 5971.0 0401.0 8 1/1 P1104641-4 1l2-4-46 (3/16")B 67.4 6321.0 0561.0 8 2/1 P1104641-4 1/2-4-46 (3/16")B 89.6 6561.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ib P1104641-41/2-4-46 41/2 9.252 5.500 No Houma 8.500 94.42 903.73 (1) - Centralizer performance data is based on tests by WEATHERFORD as perthe current API 10D specifications Page 6 2L327 cement, V3.cfw ; 04-0E2007 ; LoadCase Liner; Version wcs-cem45_89 ~ Client : ConocoPhillips Alaska Well : 2L327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner Section 3: fluid description Fluid No: 1 Rheo. Model : BINGHAM At temp. : 80 degF MItD Mud Type : WBM Water Type : Fresh Mud DESIGN ~ Density :12.OOIb/gal P~ : 14.000 cP Ty :22.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 85.1 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 13.00 Ib/gal Rheo. Model : HERSCHEL B. k : 2.42E-1 Ibf.s^n/ft2 At temp. : 120 degF n : 0.181 Ty : 1.60 !bfl100ft2 Gel Strength : (Ibf/100ft2) Job volume : 15.0 bbl G cement DESIGN Fluid No: 7 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL B. k : 7.15E-3 Ibf.s^n/ft2 At temp. : 119 degF n : 0_707 Ty :21.181bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.155 gal/sk Job volume : 25.6 bbi Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Quantity : 123.36 sk Sack Weight : 94 Ib Porosity : 592 % Solid Fraction : 40.8 % BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Base Fluid : 2.955 gal/sk Page 7 2L3D cement, V3.cfw; 04-06-2007 ; LoadCase Liner, Version wcs-cem45_89 • Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner Section4:fluid sequence Job Objectives: Seal off liner top by bringing cement 300' above liner top. ~ Original fluid Mud 12.00 Ib/gal P~ : 14.000 cP Tr : 22.00 Ibf/100ft2 Displacement Volume 85.1 bbl Drill Pipe Volume 74.1 bbl Total Volume 125.7 bbl TOC 5460.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl} (ft) (ft) (Iblgal) MUDPUSH II 15.0 806.8 4653.2 13.00 k:2.42E-1 Ibf.s^n/ft2 n:0.181 Tv:1.60 ibf/100ft2 G cement 25.6 1101.0 5460.0 15.80 k:7.15E-3 Ibf.s^n/ft2 n:0.707 Tv:21.18 -bf/100ft2 Mud 85.1 0.0 12.00 p~:14.000 cP Tv22.00 ibf/100ft2 Static Security Checks : Frac 611 psi at 5964.0 ft Pore 216 psi at 6064.0 ft Collapse 6872 psi at 6481.0 ft Burst 8430 psi at 6481.0 ft Cs .Pum out 43 ton Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Pause 0.0 0.0 10.0 0.0 80 Pressure Test MUDPUSH II 5.0 15.0 3.0 15.0 80 G cement 5.0 25.6 5.1 25.6 80 Pause 0.0 0.0 5.0 0.0 80 Drop dart Mud 3.0 85.1 28.4 85.1 80 Total 00:51 725.7 bbl hr:mn D namic Securi Checks : Frac 127 psi at 5964.0 ft Pore 81 psi at 6064.0 ft Collapse 6872 psi at 6481.0 ft Burst 8213 si at 5760.0 ft Temperature Results BHCT 112 degF Simulated Max HCT (degF) Simulated BHCT (degF) Max HCT Depth (ft) CT at TOC de F Max HCT Time (hr:mn:sc) Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) (degF) Bottom Hole (degF) de F de F Page 8 2L-327 cement, V3.cfw ; ~4-06-2007 ; loadCase Lirier; Version wcs-cem45_89 ~ Client : ConocoPhiliips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner INc ~al ~ , 10 12 14 o - O ~ i Mn. Hydrostatic O i ~ Max. Dynarric ~ ! ----- Mn D9namic 0 0 °o ~ O O O ~ O O O O Fluid Sequence ~ Frac I.... ~"' Pore ~~ Hydrostatic ........ ~ 1 0 O y . ~' O d ~ S ~ 0 0 0 M C •~ O ~ N T U O N O ~ O C ! Q O 20 40 60 Time (min) ue ii1 = b5b"I T[ Annular Velociry ~'~; 0 20 40 60 Time (min) o, - --- p ~ i ~ Collapse ~~ ~. . . ~~ ~~ ~ FSeudo Hydrostatic - i . x I ~ D~namic . ', ~., '., . ~. ~'~. o ~ 'I ao~ '~ ~ ~ ~ ~ ~ O ° 0 5 10 15 20 25 30 35 40 45 50 55 Time (min) ~ ------ ---~th = 6561 ft - - -- - ~ i~ F~~a~ I ~ '~.. . ~. ~'~~. '~.. : ~ ~. '~, . ~ . -' . ~~i'. ~~. ~~~, , ~ C C Q O ~. . . ~. .. . .._ ~. ~ . . .. I .... ... . .. I ~.I._- r-_. -r .._..... _i ~ ~ i i 0 5 10 15 20 25 30 35 40 45 50 55 Time (min) Page 9 2L-3D cement, V3.ciw ; 04-D6-2007 ; loadCase Liner; Version wcs-cem45_89 . ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 4.5 District : Prudhoe Bay Country : United States of America Loadcase : Liner Section 6: WELLCLEAN II Simulator ft % % 60 80 100 0 100 0 °o ~ o ----- Std Betw. Cent. ---- fuLd Contartination ~ ---- Cement Coverage - Uncontarrinated Slurry i ~ ' I ~, i i ~ I ' ' ~ , i 0 0 0 ~ 0 0 0 ~ 0 °o ~- Uncontaminated Slurry ~ 1 : Deviation Page 10 2L-3D cement, V3.cfw; ~4-~6-2007; LoadCase Liner, Version wcs-cem45_89 Fluid Sequence ~ ~ " y~ ~_' ~; ~ _ `ii`, , ;_ - - ~ ~ ` ~ , -' ~ . ~. i _ , ~ , _ . _: _ , '. ry`' . _ . _ , _._ SARAH PAL/N, GOVERNOR ~aa~a~7~ ~au~ p~sai ~-.7 333 W. 7thAVENUE, SUITE 100 CONSERQA~O~T COMDIISSIO~ ANCHORAGE, AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-327 ConocoPhillips Alaska, Inc. Permit No: 207-008 Surface Location: 226' FNL, 894' FEL, SEC. 22, T10N, R7E, UM Bottomhole Location: 1743' FNL, 1574' FWL, SEC. 23, T10N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90~59-3607 (pager). K. N DATED this ~(oday of January, 2007 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com January 18, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill 2L-327 Dear Commissioners, ~~ ,~ ~ ~~~~~~~~~~~~` ~~~~~~~~~ ~A~ ~, 9 ZOQ7 ~iask~ ~~i1 ~ ~a~ ~~:n~~~ ~~~9S5i9tl ~ncha~r~~~ ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore producer well 2L- 327. The well will be drilled and completed using Nordic Rig #3. The planned spud date for 2L- 327 is March 1, 2007. . Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Tim Billingsley at 907- 265-6531. Sincerely, .~.. \ \L' t ~ ......,.. . ~V...':.~'/L' ~ ~~'°'^-~s...~....~aqR_~i~ 1 Randy Thomas Kuparuk Drilling Team Leader ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~~ V ~~ /.Y.' .~~~ ~ ~ 2~~~ ~,« ~(~ Alasle~ ~'s~ & ~a~ CQnsr Cammissi~n ~s~~t~r~a a~~ 7a. Type of Work: Drill Q' Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Q/ Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone Q - 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: 2L-327 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 6561' . ND: 5647' , 12. Field/POOI(S): Kuparuk River Field 4a. Location of Well (Governmental Section): SurFace: 226' FNL, 894' FEL, Sec. 22, T10N, R7E, UM 7. Property Designation: ADL 380051 Tarn Oil Pool Top of Productive Horizon: 1571' FNL, 1453' FWL, Sec. 23, T10N, R7E, UM 8. Land Use Permit: ALK 4599 13. Approximate Spud Date: 3/1/2007 Total Depth: 1743' FNL, 1574' FWL, Sec. 23, T10N, R7E, UM 9. Acres in Property: 2560 14. Distance to ,~3~ Nearest Property: ~.aaile ~, 4b. Location of WeH (State Base Plane Coordinates): Surface: x- 460756 ~ y- 5927621 ' Zone- 4 10. KB Elevation ~,,h ~~~ ~ ~ ~.2z (Height above GL): 3O' RKB feet 15. Distance to Nearest ~ i,~,;~ ',~w Well within Pool: 2L ~3 ~L7' @ 450' ~~ 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum HoleAngle: 38° ' deg 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.o35) Downhole: 2858 psig o Surface: 2287 psig ' 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size peC Ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 80' 30' 30' 120' 920' Driven 12.25" 9-5/8" 40# L-80 BTC Z ,.~ ' 30' .aT2400' ' 470 sx AS Lite, 170 sx DeepCRETE 8.75" 7" 26# L-80 BTCM 5881' 30' 30' 5881' 5033' 110 sx LiteCRETE 8.75" 4.5" 12.6# L-80 IBTM 680' 5881' S033' 6561' 5647' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND ConductodStructural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch ~ Drilling Program Q Time v. Depth Plot ~ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Tim Billingsley @ 265-6531 Printed Name Randy Thomas Titie Greater Kuparuk Area Drilling Team Leader Signature ~~~ ~~~--~_`y~~ ~~~ Phone Z~ S~ ~~~~~ Date ~ r( /~ db nAll u k ~ - Commission Use Only Permit to Drill Number. ~ ~~ ~~j API Number: 50- ~~3' ,Zds~2 "'~(~ Permit Approval Date: . ~~ • a ~ See cover letter for other requirements Conditions of BpprOVal : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas h rates, or gas contained in shales: Samples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [/~ Other: 3j~Q~ ~S~` ,M \~~ ~v~~ ~\~ H2S measures: Yes [~ No ire ~ al svy req'd: Yes [~ No ^ -~ Il~~ ~ O APPROVED BY THE COMMISSION DATE: f , COMMISSIONER ;~. ;~,02 Form 10-401 Revised 12/2005 ~ 4.r) ~~~~ S~bmit i~~~ ~I~j ~-~ '''~ ~ Permit It - Kuparuk Well 2L-327 Application for Permit to Drill Document t~+l~~ll~~ll M a x i m i a~ VJe~II Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25. 005 (t~ ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ........................................................ ....................... .... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 2L-327 APD Page 1 of 7 Printed: 17-Jan-07 ~ation for Permit to Drill, Well 2L-327 Saved: 17-Jan-07 ~T~~F T~ ~~ Q ~ ~ ~I NAL ~ A~ion for Permit to Drill, Well 2L-327 Saved: 17-Jan-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plan ............................................................................................................... 7 Attachment 2 Drilling Hazards Summary .............................................................................................. 7 Attachment 3 Well Schematic ............................................................................................................... 7 Attachment 4 Cement Summary ........................................................................................................... 7 Attachment 5 Diverter Placement Drawing ........................................... Error! Bookmark not defined. 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch musr similarly be identified by a unique ~ame and API number by adding a su~x to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-327. - 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identiFed in the application: (2) a plat idenCifying the property and the property's owners and showing (A)the coordinates nf the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed de~pth of the well at the top of each objective formation and at total depth; Location at Surtace 226' FNL, 894' FEL, Sec 22, T10N, R7E, UM ~ NGS Coordinates ~ RKB Elevation 147.1' AMSL --'" Northings: 5,927,620.79 Eastings: 460,756.44 ~ Pad Elevation 117.1' AMSL ~ Location at Top of Productive Interval Bermuda 1571' FNL, 1453' FWL, Sec 23, T10N, R7E, UM - NGS Coordinates Measured De th, RKB: 6064' Northings: 5,926,264.00 Eastings: 463,099.00 Total Vertical De th, RKB: 5197' Total Vertical De th SS: 5050' Location at Total De th 1743' FNL, 1574' FWL, Sec 23, T10N, R7E, UM NGS Coordinates Measured De th, RKB: 6561' Northings: 5,926,091.50 Eastings: 463,218.45 Total Vertical De th, RKB: 5647' Total Vertical De th, SS: 5500' and (D) other information required by ZO AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a we!( is to be intentiona(ly deviated, the application for a Permit to Drill (Form 10-401) must (i) indude a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within Z00 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and 2L-327 APD Page 2 of 7 Printed: 17-Jan-07 ~~~~~.~~~!~~ « . .. . „ _ , 3 _.,_ ~ ~ation for Permit to Drill, Well 2L-327 Saved: 18-Jan-07 (2) for al! wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show Yhat each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app(ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) informatron on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Offset well data (pressure fall-offs on injectors 2L-329A and 2L-305) indicates a max BHP of 2850 psi at 5197' TVD for the 2L-327 location. ~~ Equivalent Mud Weight @TD = 2g50psi =10.Sppg '~ 5197'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 2L-327 is calculated using the predicted 2850 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an Bermuda top TVD of 5197'. ~ MPSP = ~GradientMua - GradientGas ~TVD Gradient„~ud =10.5ppg x 0.052 = 0.55 fl t Gradient~as = 0.11 fZ t TVD=5197ft MPSP = 0.55 psl - 0.11 psl 5197 ft = 2287 psi ft ft (8) data on pofential gas zones; / The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strvta, lost circulation zones, and zones that have a propensity for di(ferential sticking; Please see Attachment 2- Drilling Hazards Summary 2L-327 APD Page 3 of 7 Printed: 18-Jan-07 { ~ ~ ~~~QL ~~~~ ~ A~ion for Permit to Drill, Well 2L-327 Saved: 18-Jan-07 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(~; Drill out surface casing shoe and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ide~ntrfied in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD (in) (in) t(Ib/ft) Grad Connection (ft) (ft) (ft) Cement Program e 16 24 62.5 0 Welded 80' Surf 120'/120' Driven 4 Lead: 470 sx 10.7 ppg AS Lite 9-5/8 i~4 40.0 80 BTC 2471' Surf 2471'/2400' Tail: 170 sx 12.0 ppg DeepCRETE Planned TOC=Surface 110sx11.Oppg 7 x „ 26.0 L- BTCM 5881' Surf 5881'/5033' ~LiteCrete' w/ additives. 4-1/2 8-3~4 12.6 80 IBTM 680' S881' 6561'/5647' P~anned TOC=5564 MD ' above top of (500 Bermuda 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wifh the commission and ide,ntified in the application; (7) a diagram and a!escription of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Nordic 3. 2L-327 APD Page 4 of 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ Printed: 18-Jan-07 ~ .~ , w. w , , ~ ~ L J ~ation for Permit to Drill, Well 2L-327 Saved: 17-Jan-07 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on Fle with the commission and identified in Yhe application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nordic 3 on 2L-327 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. i 4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (2571' MD/ 2400' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. ~" 5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to required pressure as per AOGCC approved permit to drill. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. RIH clean out to float collar 9. Drill out cement and 20' minimum to 50' maximum of new hole. Pertorm formation integrity test not to exceed 16.0 ppg EMW. ~ 10. Directionally drill 8-3/4" hole to 6561' MD/ 5647' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 11. Run 7" 26# L-80 BTCM x 4-1/2" 12.3# L-80 IBTM tapered casing to TD with crossover at approximately 5900' MD. Pump cement and drop wiper plug that wipes both 7" and 4-1/2". Displace with mud, land casing hanger and bump plug. (Crossover contains a 3-1/2" tbg seal bore for landing tbg string) 12. Install packoff. 13. Run 3-1/2" tubing with GLMs and chemical injection mandrel with control line attached 9for paraffin inhibition) to OD of tbg. Land 3-1/2" completion tubing string in the seal bore at the 7" x 4-1/2" crossover point and pressure test to 3000 psi. Record results. 14. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 15. Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 16. Clean location and RDMO. 17. MIRU coiled tubing. Displace mud from well with brine. 18. RU E-Line, perforate well. Flow test well. 19. RU Dowell, frac well. 20. RD Dowell, secure well, handover to production 2L-327 APD Page 6 of 7 ~ ; Printed: 17-Jan-07 ~~~`'~~~ ~~~ r~ ~ A~tion for Permit to Drill, Well 2L-327 Saved: 17-Jan-07 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a~ Permit to Drill must 6e accompanied by each of the following items, except for an item already on file with the commission and idE=ntified in the application: (8) a drifling fluid program, including a diagram and description of the dri/ling fluid system, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface Interval Production Interval Mud T e S ud Mud LSND Densi 8.5-10.2 ~ 9.5-10.7 Funnel Viscosi sec 150-Z50* 45-55 Yield Point cP 30-50 22-28 Plastic Viscosit Ib/i00 sf 20-60 14-25 10 sec. Gel Ib/100 s 10-35 5-9 API Filtrate cc NC-6 4-6 H 8.5-9.5 9-9.5 Solids % +10 < 5% ~ *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds r Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identiFed in the application: (9) for an exploratory or stratig~aphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(~; N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicatron for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the application: (10) for an exploratory or stratigraphic tesf well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (Ii) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed condition.s as required by 20 AAC 25. 061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An appfication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evrdence showing that the requirements of 20 AAC 25.025 {eonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 2L-327 APD Page 5 of 7 Printed: 17-Jan-07 ~~?~~~~~L ~ ~ation for Permit to Drill, Well 2L-327 Saved: 17-Jan-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in Yhe well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15.Attachments Attachment 1 Directional Plan Attachment 2 Dri/ling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L-327 APD Page 7 of 7 Printed: 17-Jan-07 ~~~~~NAL ~ ~ 2L-327 Drilling Hazards Summary Surface Hole Risks Event Risk Level Miti ation Strate / Contin enc Broach of conductor Low Monitor cellar & ad continuousl durin interval Gas Hydrates Moderate Minimum mud weight of 10.0 ppg. If observed - control drill, reduce pump rates, reduce drilling fluid tem eratures, addition of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole trips filling (use of trip sheets), pumping out of hole as needed Production Hole Risks Event Risk Level Miti ation Strate y/ Contin enc Insufficient or undetermined Low Importance of LOT communicated to all parties, LOT all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 MW e uivalent Swabbing Campaignian Moderate Minimum mud weight of 9.6 ppg, mandatory sands (50 ft TVD below C- flow check above sands on all trips 80 Low OH LOT /High reservoir Low Open hole LOT to be performed before drilling pressure into the Bermuda, wellbore strengthening can be performed if OH LOT is not sufficient to drill into Bermuda. 7" contingency top set available if WBS is not successful High ECD / Tight hole on Moderate Condition mud & clean hole prior to trips. trips/ Swabbing Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, ro er hole fillin use of tri sheets) Lost circulation Moderate Keep hole clean - use PWD to monitor hole cleaning. If losses occur- reduce pump rates and mud rheolo , use LCM Q!\l~~~~~ 2L-327 Slan Producer ~ ~- ` Proposed Completion Schematic ~~~~~~~~ ~~~ ~ p~ 3-1/2" Completion String 3'/2" 9.2# L-80 EUE 8rd Spaceout Pups as Required 3'/z" 9.2# L-80 EUE 8rd Tubing to Surface 3'/z" Camco'DS' nipple w/ 2.875" No-Go Profile. 3'/z" x 6' L-80 EUE 8rd 30" x 16" 62.6# crossover handling pups installed above and below, set at +/- 500' MD @+/- 80' MD Completion, from hanger to `DS' nipple, to be be drifted to 2.91 ". Surface csg. 9-5/S" 40# L-80 BTC F/- 2571' MD / 2,400' TVD 3'/z" x 1" Camco 'KBMG' mandrels with dummy valves 3'/2" x 6' L-80 with EUE 8rd crossover handling pups installed above and below. DEPTHIsI TO BE Determined Camco Chemical Inj Mandrel at depth to be determined Lowest 3'/z" x 1" Camco 'KBMG' mandrel w/ shear valve, pinned for 3000 psi shear (casing to tubing differential). Load rest of GLMs with dummy valves 3'/z" Baker'CMU' sliding sleeve w/ 2.813" Camco DS profile EUE 8rd, with 3'/z° x 6' L-80 EUE 8rd handling crossover pups installed 7" 26# L-80 BTCM X 4'/z" 12.6# L-80 IBTM .:.: ~~ 3'/z" Baker 80-40 GBH-22 casing seal assembly w/ 15' stroke, 3'/z" x 6' L-80 EUE 8rd crossover handling pup installed on top seal bore extension at +/- 5881' ~~ ~:::::: ° MD / 5034' TVD aker Seal Bore Extension, with 7 BTCM box top and 4'/z" IBTM bottom pin SBE set at +/- 200' MD above the top of the Bermuda Target nterval and just above 7" x 4-'/Z" crossover Future Bermuda Perforations top at 6064' MD/ 5197' TVD Production csg PESI 4-'/~" IBTM float shoe, 7" 26# L-80 BTCM x float collar and 7" x 4-'/z" 4'h" 12.6# L-80 IBT Mod wiper plug receiver on bottom +/- 6561' MD / 5,647' TVD 3 joints of 4-'h" IBT mod casing l/l7/07 QRlG1NAL onocoPhilli s Alaska In~ P ~ CPAI Report Company: ConocoPhillips Alaska Inc: Date: 1/4/2007 Time: 09:4Q:38 Page: ' 1 Fietd: Kuparuk River Unit Co-ordinate(NE) Reference: WeIL' Plan: 2L 327, True North -' Site: ' Kuparuk 2L Pad VerNcal (TVD) Reference: ' Plan: 2L-327 147.1 Welt; ' Plan: 2L-327 Section (VS) Reference: ' WeU (0`,OON,O.OOE,193.OOAzi) Wellpath: Plan: 2L-327wp07 (Vertical) Survey Calculation Method: Minimum Curvature - Db: Oracle Plan Section Information MD Inc( < Azim TVD +N/-S +E/-W DLS . Build Turn TFO Target ft deg deg ft ft ft ' degl100ft deg/100ft deg/100ft deg 30.00 Q.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 550.00 5.00 180.00 549.68 -10.90 0.00 2.00 2.00 0.00 180.00 800.00 6.53 244.16 798.64 -28.01 -12.80 2.50 0.61 25.66 110.00 2201.42 37.79 116.54 2107.85 -265.35 314.43 3.00 2.23 -9.11 -133.55 5513.51 37.79 116.54 4725.32 -1172.31 2129.98 0.00 0.00 0.00 0.00 6064.41 25.00 145.00 5197.10 -1344.73 2349.81 3.50 -2.32 5.17 142.42 2L-327wp03 T-3 6560.93 25.00 145.00 5647.10 -1516.62 2470.17 0.00 0.00 0.00 0.00 Plan: 2L-327wp07 Date Composed: 10/23/2006 VertlCal Version: 9 Principal: Yes Tied-to: From Well Ref. Point Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Kuparuk 2L Pad Site Position: Northing: 5927695.13 ft Latitude: 70 12 48.272 N From: Map Easting: 461077.91 ft Longitude: 150 18 50.048 W Position Uncertainty: 0.00 ft North Reference: True Ground LeveL• 0.00 ft Grid Convergence: -0.30 deg Well: Plan: 2L-327 Slot Name: Well Position: +N/-S -76.00 ft Northing: 5927620.79 ft~ Latitude: 70 12 47.525 N +E/-W -321.11 ft Easting : 460756.44 ft~ Longitude: 150 18 59.370 W Position Uncertainty: 0.00 ft Wellpath: Plan: 2L-327wp07 (Vertical) Drilled From: Well Ref. Point Vertical Tie-on Depth: 30.00 ft Current Datum: Plan: 2L-327 Height 147.10 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2006 Declination: 23.33 deg Field Strength: 57574 nT Mag Dip Angle: 80.68 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 193.00 Survey Program for Definitive R'ellpath Date: 10/23/2006 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft Q~[G~~AL ~ WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot PIan:2L327 -76.00 -321.11 5927620.79 460756.44 70°12'4Z525N 150°l8'S9370W N/A WELLPATH DETAILS Plan: 2L327wp07 (Vertica l) VertiCal Rig: Re£. Datum~. Plan~. 2L-327 147.]Oft V.Section Ori~in Origin Starting Angle +N/-S +E/-W From TVD , 193.00° 0.00 0.00 30.00 > ~ ~ ~ 1000 wonFY~K~) [soooroiv~ ~ ~ 2 >" 2 PLAN DETAILS 2L-327wp07 Vertical Version 9 10/23/2006 Start Point MD Inc Azi TVD +N/-S +E/-W 30.00 0.00 0.00 30.00 0.00 0.00 ; 5000 ~ . HALLtBtJRTG?N ~ ~ ~5, : ~.~ ~11~~ ~s ConocoPhill~p~s ' ' :. ~ 6~ ' ' , ~~, . ~ : ~~. . 2L-327w 07 07 Vertical : ~ ..........._ -_ __.... .....__. . ._...._ ....... ,_ - ___. __ ' ~~. ~. '~.. ~~~. REFERENCE RVFORMATION ,.. v ... ~ , v..... ~~~.~ ~ °~ Co-ordinate (N/E) Reference: Well Centre: Plan: 2L-327, True North ~~- Vertical ('I'VD) Refecence: Plan: 2L-327 147.10 -4000 -2000 0 2000 4000 6000 Saction(VS)Refecence~. Slot- (O.OON,O.OOfl) ven+~i saeo„ e~ t9a.oo~ ~zooom~~q Measured Depth Reference: Plan: 2L327 14Z 10 Calculation Method: Minimum Curvature ~ ~ ~ ~ ~ ~ ~ ~ ~onocoPhilli s Alaska Inc•. P ~ CPAI Report Company: ; ConoCOPhillips Alaska InCi Date: 1/4/2007 Time: 09:40:38 ' Page: ' 2' Field: ' Kuparuk River Unit Co'-ordinate(NE) Reference: ' Well: Plan: 2L-327, True North Site: ' Kuparu k 2L Pad Vertica t (TVD) Reference: ' Plan: 2L-327 147. 1 WeII: Plan~ 2 L'-327 Sec ~ion (VS) Reference: ` Well (O;OON,O.OOE,193 .OQAzi} Wellpath: Plan: 2 C-327wp07 (Verticalj Survey Calculation Method: ' M inimum CurUature I Db: Oracle .SllCVC3' MD Incl' Azim TVD Sys TVD N/S ' E!W MapN MapE DLS VS Comme t ft deg deg ft ' ft ft ft '' ft ft' deg/100ft < ft 30. 00 0 .00 0. 00 30. 00 -117. 10 0 .00 0 .00 5927620 .79 460756. 44 0.00 0 .00 100. 00 0 .00 0. 00 100. 00 -47. 10 0 .00 0 .00 5927620 .79 460756. 44 0.00 0 .00 200. 00 0 .00 0. 00 200. 00 52. 90 0 .00 0 .00 5927620 .79 460756. 44 0.00 0 .00 300. 00 0 .00 0. 00 300. 00 152. 90 0 .00 0 .00 5927620 .79 460756. 44 0.00 0 .00 KOP; 2 DLS 400. 00 2 .00 180. 00 399. 98 252. 88 -1 .75 0 .00 5927619 .05 460756. 43 2.00 1 .70 500. 00 4 .00 180. 00 499. 84 352. 74 -6 .98 0 .00 5927613 .81 460756. 40 2.00 6. 80 550. 00 5 .00 180. 00 549. 68 402. 58 -10 .90 0 .00 5927609 .89 460756. 38 2.00 10. 62 Build; 2.5 DLS 600. 00 4 .72 194. 42 599. 50 452. 40 -15 .07 -0 .51 5927605 .72 460755. 85 2.50 14. 80 700. 00 5 .12 223. 53 699. 15 552. 05 -22 .29 -4 .61 5927598 .52 460751. 71 2.50 22. 76 800. 00 6 .53 244. 16 798. 64 651. 54 -28 .01 -12 .80 5927592 .85 460743. 50 2.50 30. 17 Build; 3 DLS 900. 00 4 .96 218. 13 898. 16 751. 06 -33 .88 -20 .59 5927587 .02 460735. 68 3.00 37. 65 1000. 00 4 .96 182. 87 997. 80 850. 70 -41 .60 -23 .47 5927579 .32 460732. 75 3.00 45. 81 1100. 00 6 .52 156. 78 1097. 32 950. 22 -51 .13 -21 .45 5927569 .78 460734. 73 3.00 54. 65 1200. 00 8 .85 142. 49 1196. 42 1049. 32 -62 .45 -14 .53 5927558 .42 460741. 59 3.00 64. 12 1300. 00 11 .50 134. 40 1294. 84 1147. 74 -75 .53 -2 .72 5927545 .28 460753. 33 3.00 74. 21 1400. 00 14 .28 129. 37 1392. 32 1245. 22 -90 .33 13 .94 5927530 .40 460769. 91 3.00 84. 88 1500. 00 17 .14 125. 97 1488. 57 1341. 47 -106 .82 35 .40 5927513 .80 460791. 29 3.00 96. 11 1600. 00 20 .04 123. 53 1583. 35 1436. 25 -124 .94 61 .62 5927495 .55 460817. 40 3.00 107. 87 1700. 00 22 .96 121. 68 1676. 38 1529. 28 -144 .64 92 .50 5927475 .68 460848. 18 3.00 120. 13 1800. 00 25 .90 120. 23 1767. 42 1620. 32 -165 .89 127 .98 5927454 .26 460883. 54 3.00 132. 85 1900. 00 28 .85 119. 05 1856. 22 1709. 12 -188 .60 167 .94 5927431 .34 460923. 39 3.00 145. 99 2000. 00 31 .81 118. 08 1942. 52 1795. 42 -212 .73 212 .30 5927406 .98 460967. 61 3.00 159. 52 2100. 00 34 .78 117. 26 2026. 10 1879. 00 -238 .21 260 .91 5927381 .25 461016. 08 3.00 173. 41 2200. 00 37 .75 116. 55 2106. 72 1959. 62 -264 .96 313 .65 5927354 .23 461068. 68 3.00 187. 61 2201. 42 37 .79 116. 54 2107. 85 1960. 75 -265 .35 314 .43 5927353 .84 461069. 46 3.00 187. 82 Start Sail; 37 Inc 2300. 00 37 .79 116. 54 2185. 75 2038. 65 -292 .34 368 .47 5927326 .57 461123. 35 0.00 201. 96 2400. 00 37 .79 116. 54 2264. 78 2117. 68 -319 .73 423 .28 5927298 .90 461178. 01 0.00 216. 31 2500. 00 37 .79 116. 54 2343. 81 2196. 71 -347 .11 478 .10 5927271 .24 461232. 68 0.00 230. 66 -- 2571. 10 37 .79 116. 54 2400. 00 *~ 2252. 90 -366 .58 517 .08 5927251 .56 461271. 55 0.00 240. 87 9 5/8" 2600. 00 37 .79 116. 54 2422. 84 2275. 74 -374 .49 532 .91 5927243 .57 461287. 35 0.00 245. 01 2700. 00 37 .79 116. 54 2501. 86 2354. 76 -401 .88 587 .73 5927215 .90 461342. 02 0.00 259. 37 2800. 00 37 .79 116. 54 2580. 89 2433. 79 -429 .26 642 .55 5927188 .24 461396. 68 0.00 273. 72 2900. 00 37 .79 116. 54 2659. 92 2512. 82 -456 .64 697 .36 5927160 .57 461451. 35 0.00 288. 07 3000. 00 37 .79 116. 54 2738. 95 2591. 85 -484 .03 752 .18 5927132 .91 461506. 02 0.00 302. 42 3100. 00 37 .79 116. 54 2817. 97 2670. 87 -511 .41 806 .99 5927105 .24 461560. 68 0.00 316. 77 3200. 00 37 .79 116. 54 2897. 00 2749. 90 -538 .79 861 .81 5927077 .58 461615. 35 0.00 331. 12 3300. 00 37 .79 116. 54 2976. 03 2828. 93 -566 .18 916 .62 5927049 .91 461670. 02 0.00 345. 47 3400. 00 37 .79 116. 54 3055. 06 2907. 96 -593 .56 971 .44 5927022 .25 461724. 69 0.00 359. 82 3500. 00 37 .79 116. 54 3134. 09 2986. 99 -620 .94 1026 .26 5926994 .58 461779. 35 0.00 374. 17 3600. 00 37 .79 116. 54 3213. 11 3066. 01 -648 .33 1081 .07 5926966 .92 461834. 02 0.00 388. 52 3700. 00 37 .79 116. 54 3292. 14 3145. 04 -675 .71 1135 .89 5926939 .25 461888. 69 0.00 402. 87 3800. 00 37 .79 116. 54 3371. 17 3224. 07 -703 .09 1190 .70 5926911 .59 461943. 35 0.00 417. 22 3900. 00 37 .79 116. 54 3450. 20 3303. 10 -730 .48 1245 .52 5926883 .92 461998. 02 0.00 431 .57 4000. 00 37 .79 116. 54 3529. 22 3382. 12 -757 .86 1300 .33 5926856 .26 462052. 69 0.00 445. 93 4100. 00 37 .79 116. 54 3608. 25 3461. 15 -785 .24 1355 .15 5926828 .59 462107. 36 0.00 460. 28 4200. 00 37 .79 116. 54 3687. 28 3540. 18 -812 .63 1409 .96 5926800 .93 462162. 02 0.00 474. 63 4300. 00 37 .79 116. 54 3766. 31 3619. 21 -840 .01 1464 .78 5926773 .26 462216. 69 0.00 488. 98 4400. 00 37 .79 116. 54 3845. 34 3698. 24 -867 .39 1519 .60 5926745 .59 462271. 36 0.00 503. 33 4500. 00 37 .79 116. 54 3924. 36 3777. 26 -894 .78 1574 .41 5926717 .93 462326. 03 0.00 517. 68 4600. 00 37 .79 116. 54 4003. 39 3856. 29 -922 .16 1629 .23 5926690 .26 462380. 69 0.00 532. 03 4700. 00 37 .79 116. 54 4082. 42 3935. 32 -949 .55 1684 .04 5926662 .60 462435. 36 0.00 546. 38 4800. 00 37 .79 116. 54 4161. 45 4014. 35 -976 .93 1738 .86 5926634 .93 462490. 03 0.00 560. 73 4900. 00 37 .79 116. 54 4240. 47 4093. 37 -1004 .31 1793 .67 5926607 .27 462544. 69 0.00 575 .08 ~~ t ~~1 tl' `~ . ~ ~onocoPhilli s Alaska Inc. A ~ CPAI Report Company: ' ConoCOPhillips Alaska lnC. Date: 1/4/2007 Time: 09:40:38 ' Page: 3 Field: ' Kuparuk River Unit Co-ordinate(NE) Reference: Wellt Plan: 2L-327, True North Site: Kuparuk 2L Pad Vertical (TVD) Reference: Plan: 2L-327 14Z.1 We1L• Plan: 2L-327 Section (VS) Reference: Well (O,OON,O.OOE,193.OOAzi) Wellpath: Plan: 2L-327wp07 (Vertical) Survey Calculation Method: Minimum Curvature Db: Oracle Survey 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 ,. 5513.51 5600.00 5700.00 5800.00 5900.00 6000.00 6064.41 6100.00 6200.00 6300.00 6400.00 6500.00 .~ 6560.93 [ncF' Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 37.79 116.54 4319.50 4172.40 -1031.70 1848.49 37.79 116.54 4398.53 4251.43 -1059.08 1903.31 37.79 116.54 4477.56 4330.46 -1086.46 1958.12 37.79 116.54 4556.58 4409.48 -1113.85 2012.94 37.79 116.54 4635.61 4488.51 -1141.23 2067.75 37.79 116.54 4714.64 4567.54 -1168.61 2122.57 37.79 116.54 4725.32 4578.22 -1172.31 2129.98 35.43 119.73 4794.75 4647.65 -1196.59 2175.46 32.82 123.89 4877.53 4730.43 -1226.09 2223.14 30.37 128.67 4962.71 4815.61 -1257.01 2265.39 28.12 134.16 5049.98 4902.88 -1289.23 2302.05 26.12 140.47 5138.99 4991.89 -1322.64 2332.98 25.00 145.00 5197.10 5050.00 -1344.73 2349.81 25.00 145.00 5229.36 5082.26 -1357.05 2358.44 25.00 145.00 5319.99 5172.89 -1391.67 2382.68 25.00 145.00 5410.62 5263.52 -1426.29 2406.92 25.00 145.00 5501.25 5354.15 -1460.91 2431.16 25.00 145.00 5591.88 5444.78 -1495.52 2455.40 25.00 145.00 5647.10 ° 5500.00 -1516.62 2470.17 MapN MapE DLS < ft ft' degH( 5926579.60 462599.36 0.00 5926551.94 462654.03 0.00 5926524.27 462708.70 0.00 5926496.61 462763.36 0.00 5926468.94 462818.03 0.00 5926441.28 462872.70 0.00 5926437.54 462880.08 0.00 5926413.03 462925.44 3.50 5926383.28 462972.96 3.50 5926352.15 463015.04 3.50 5926319.74 463051.53 3.50 5926286.17 463082.28 3.50 5926264.00 463099.00 3.50 5926251.64 463107.56 0.00 5926216.89 463131.62 0.00 5926182.15 463155.68 0.00 5926147.41 463179.74 0.00 5926112.67 463203.79 0.00 5926091.50 463218.45 0.00 589.43 603.78 618.14 632.49 646.84 661.19 663.13 676.55 694.57 715.19 738.34 763.93 781.67 2L-327wp03 T-3 791.73 820.01 848.29 876.57 904.85 922.08 4 1 /2" Targets Map Map <---- Latitude ----> <--- Longitude ---> Name' Description TVD +N/-S +E/-W Northing ' Easting Deg Min Sec Deg Min' Sec Dip. Dir. ft ft ft ft ft` 2L-327wp03 T-3 5197.10 -134473 2349.81 5926264.00 463099.00 70 12 34.296 N 150 17 51.167 W -Plan hit target Annotation ' NID ft TVD ft' 300.00 300.00 KOP; 2 DLS 550.00 549.68 Build; 2.5 DLS 800.00 798.64 Build; 3 DLS 2201.42 2107.85 Start Sail; 37 Inc for 33312' 6064.41 5197.10 T-3; at 25 Inc 6560.92 5647.09 TD Casing Points MD TVD Diameter , Hole Size Name ft ft ' ' in in 2571.10 2400.00 9.625 12.250 9 5/8" 6064.41 5197.10 7.000 8.500 7" 6560.93 5647.10 4.500 8.500 41/2" Formations ~~~~ ~~~~~ ~onocoPhilli s Alaska In~ P ~ Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1l412007 Time: 09:37:18 ' Page: ' 1 Field: ' Kuparuk River Unit Reference Site: i Kuparuk 2L Pad ' Co-ordinate(NE) Reference: Well: Plan: ~G327, True North Reference Well: t Plan: 2L-327 Vertical (TVD) Reference: Plan: 2L-327 147.1 Reference Wellpath:i Pian: 2L-327wp07 (Vertical) Db: Oracle GLOBAL SCAN APPLIED: All wellpa ths within 200'+ 100/1000 of reference Reference: Plan: 2L-327wp07 & NOT PLANNED PRO Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.00 to 6560.93 ft Scan Method: Trav Cylinder North Maximum Radius: 853.09 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter = Hole Size Name ft ft ' in in' 2571.10 2400.00 9.625 12.250 9 5/8" 6064.41 5197.10 7.000 8.500 7" 6560.93 5647.10 4.500 8.500 41/2" Plan: 2L-327wp07 Date Composed: 10/23/2006 Vertical Version: 9 Principal: Yes Tied-to: From Well Ref. Point Summary ~'- ---------------- Offset Welipath -== --------'------> ' Reference Offset < Ctr-Ctr No-Go' Allowable Site Well " Wellpath MD MD Distance Area i Deviation Warning ' "ft ' ft ft ` ft ' ft ' Kuparuk 2L Pad 2L-309 2L-309P61 V6 29778 300.00 272.18 6.08 266.10 Pass: Major Risk Kuparuk 2L Pad 2L-311 2L-311 VO 278.79 275.00 240.65 4.76 235.89 Pass: Major Risk Kuparuk 2L Pad 2L-313 2L-313 V2 399.35 400.00 210.66 6.19 204.47 Pass: Major Risk Kuparuk 2L Pad 2L-315 2L-315 V2 2834.10 2725.00 158.22 63.40 94.82 Pass: Major Risk Kuparuk 2L Pad 2L-317 2L-317 V2 269.28 275.00 150.84 4.83 146.01 Pass: Major Risk Kuparuk 2L Pad 2L-317 2L-317A V6 269.28 275.00 150.84 4.83 146.01 Pass: Major Risk Kuparuk 2L Pad 2L-321 2L-321 V2 400.28 400.00 91.82 6.16 85.65 Pass: Major Risk Kuparuk 2L Pad 2L-323 2L-323 V2 400.44 400.00 61.19 6.05 55.14 Pass: Major Risk Kuparuk 2L Pad 2L-325 2L-325 V2 450.57 450.00 26.89 6.48 20.41 Pass: Major Risk Kuparuk 2L Pad 2L-329 2L-329 V2 401.16 400.00 27.79 6.48 21.31 Pass: Major Risk Kuparuk 2L Pad 2L-329 2L-329A V2 401.16 400.00 27.79 6.48 21.31 Pass: Major Risk Kuparuk 2L Pad Plan: 2L-319 Plan: 2L-319 V1 Plan: 327.83 325.00 120.25 6.85 113.40 Pass: Major Risk Kuparuk 2L Pad Plan: 2L-319 Prelim: 2L-319ST V1 PI 327.83 325.00 120.25 6.85 113.40 Pass: Major Risk Kuparuk 2L Pad Plan: 2L-327 Plan: 2L-327wp06 (Hori 325.00 325.00 0.21 6.86 -6.65 FAIL: Major Risk Kuparuk 2L Pad Plan: 2L-330 Plan: 2L-330 V1 Plan: 331.01 325.00 45.06 6.71 38.36 Pass: Major Risk ~RAM ~ ~ ~ ~ t ~ ~ ~ i ~ .~ lt-COIlISiO\' SETIt\'<~S < <1~nnT oEiaus 'I"~ Ini~W lauon\IMad\m In~enal~. 2ai~i Day~hRanP«rum: ?(I.M To: 6~di~~? ..~~oFfiJli~vAWYcirc FM~~N ~. \~awnumitangc: e_.IH Ncfncn.c:l'lan~..l.._]x~~N~] .~I ~InFN A eou~ m ISCN'SA C ~A4Uod i Cvl~.bv'o,m vwbu F.uiM~ul-~'mi~e ~~ MeJwJ RuleOnxd I~n~m Colour 1'~~ MD ;n - ?i0 '_iU ~ iU(t 5(NI ~ 7J(I 750 ~ IOW I(K~ - 1250 i.so - i3oo isiro - nso nso - zooo 2ot~ - seso ~ x~,so - ~~oo - Nli~ ' naou iot,su io~~oo u iso 11400 25000 7lPkbidibAlO))S'I1 ~?I.-? 17~ i -U Travelling Cylinder Aamuth (TFO+pZ1) [de~] vs Centre to Centre Separation ~?~(; in~ sa ~m i~ ,u, run ~ws .~.w rn.~e rFaa vs« rsBm 1 O.W 3000 0000 OW OW 10 ~~ ~1?80 ~~IUp 30.1] ~0~85 36835 ll~ll ~I)]55 le]a? 11~231 ]I]998 66).I) AI.41 :L.t2twp0) T3 B 6n0.a3 ?Sw I~Sao SH].~0 ~1516.G_ _1IU1) O.W UW e...06 Travelling Cylinder Azimuth (iFO+AZp [deg] ~s Centre to Centre Separation [7SIL~in~ o~~~iN~~ Lf....- -L.)ZCf1Ld:51.Melor2uk ~ _ _ '~1rN.~tNie4 ~~TRi.k - _ ~ Hi~4 99S1~MalmRav4 ~I`lan I IwRUk ~l w~~l Ah ~~ GemCADE Prel~man"ar Jo~~ Qesi ~~ Schlumberger ; ~ ~ ~t~ /~~ ~ ~P ~ ~S ~`~ 9 ~/8°'. SUrf~C~~>> : ~~ ~ ~Preliminary Job Design based on limited input data. For estlmate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc Revision Date: 1/10/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 80' MD < Base of Permafrost at 1,617.8' MD (1600' ND) < Top of Tail at 1,771' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 2,571' MD (2,400' ND) ~ Mark of Schlumberger Volume Calculations and Cement Svstems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 1771' MD (800' of tail). Because of uncertainty in the permafrost depth, a permafrost depth of 1150' 7VD is used in temperature calculations, while 1600' is used in all other caiculations. Lead Slurrv Minimum pump time: 230 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.7632 ft3/ft x(80') x 1.00 (no excess) = 61.1 ft3 0.3132 ft3/ft x(1618' - 80') x 4.00 (300% excess) = 1962.8 ft3 0.3132 ft3/ft x(1771' - 1618') x 1.50 (50% excess) = 71.9 ft3 61.1 ft3 + 1962.8 ft3+ 71.9 ft3= 2059.8 ft3 2059.8 ft3/ 4.45 ft3/sk = 462.9 sks Round up to 470 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 180 min. (pump time plus 120 min.) DeepCRETE @12.0 ppg - 2.47 ft3/sk 0.3132 ft3/ft x(2571' - 1771') x 1.50 (50% excess) = 375.8 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 375.8 ft3 + 34.1 ft3 = 409.9 ft3 409.9 ft3/ 2.47 ft3/sk = 165.9 sks Round up to 170 sks BHST = 62~, Estimated BHCT = 70~. (BHST calculated using a gradient of 2.6`F/100 ft. below 1150' TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage ~bpm~ Volume ~min~ Time (bbl) (min) CW 100 5 25 5 5 Pressure Test Lines 10 15 CW 100 5 25 5 20 Drop Bottom Plug 5 25 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 366.8 52.4 85.7 Tail Slurry 7 73 10.4 96.2 Drop Top Plug 5 101.2 Water 5 20.0 4 105.2 Switch to Rig Pumps 5 110.2 Displacement 6 148.9 24.8 135 Slow Rate 3 20 6.7 141.6 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* I I, P~ = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~t~~~~~~"~~.~ ~ ~ Schiumberger CemCAD E*well cementing recommendation for 9 5-8" Surface Uperatur : ConocoPhiilips Alaska Well : 2L-327 Slant Producer Country : United States of America Field : Tarn State : Alaska Prepared for : Tim Billingsley Location : 2L Pad Proposal No. : Service Point : Prudhoe Bay Date Prepared : 01-05-2007 Business Phone :(907- 659-2434 FAX No. : (907) 659-2538 Prepared by : Maureen Torrie Phone : 1-907-265-6336 E-Mail Atltlress : mtorrieQslb.com ~isclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided 6y the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input tlata. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than a6solute values. The quality of input data, and hence results, may 6e improved through the use of certain tests antl procedures which I Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affeciing them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perfarm these services. I Freedom from infringement of patents of Schlumberger or others is not to be inferred. ~ Mark of Schlumberger C~RI~~NAL ~ ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2571.0 ft BHST : 62 degF Bit Size : 12 1/4 in Previous String MD OD Weight ID ft in Ib/ft in 80.0 16 65.0 15.250 Landing Collar MD : 2491.0 ft Casing/liner Shoe MD : 2571.0 ft S~~I~~r~~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2571.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess : 204.3 % Mean OH Equivalent Diameter: 16.352 in Total OH Volume : 647.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1617.8 12.250 300.0 17.954 2571.0 12.250 50.0 13.371 MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 1617.8 12.50 8.20 Base Permafrost Sandstone 2650.0 12.50 8.20 C80 Sandstone 4230.0 12.00 9.00 C50 Sandstone 4730.0 12.00 9.00 C40 Sandstone 5050.0 12.00 9.00 C37 Sandstone 6064.0 12.00 10.63 Bermuda Top Sandstone 6250.0 12.00 10.63 Bermuda Base Sandstone 6300.0 12.00 10.63 C35 Sandstone 6560.0 12.00 10.63 TD Sandstone 2L-327cement.cfw;01-16-2007; LoadCaseSurface;Versionwcs-cem45_89 Page 2 ~~~~~~~~~~~ ~ ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface Geothermal Temperature Profile MD TVD Temperature Gradient ft ft (degF) de F/100ft) 0.0 0.0 25 0.0 1153.2 1150.0 30 0.4 2571.0 2399.8 62 1.6 5000.0 4319.3 112 2.0 6560.0 5552.2 144 2.2 Max. Deviation Angle : 38 deg Max. DLS : 3.015 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 330.0 330.0 0.6 180.0 -2.000 430.0 430.0 2.6 180.0 2.000 530.0 529.8 4.6 180.0 2.000 550.0 549.7 5.0 180.0 2.000 630.0 629.4 4.7 203.5 -2.494 730.0 729.0 5.5 230.7 2.497 800.0 798.6 6.5 244.1 2.507 830.0 828.4 5.9 237.8 -3.009 930.0 928.0 4.8 207.7 -3.000 1030.0 1027.6 5.3 173.5 2.999 1130.0 1127.0 7.2 151.5 3.002 1230.0 1225.9 9.6 139.6 2.991 1330.0 1324.1 12.3 132.6 3.006 1430.0 1421.2 15.1 128.2 2.996 1530.0 1517.1 18.0 125.1 3.002 1630.0 1611.4 20.9 122.9 3.000 1730.0 1703.8 23.8 121.2 3.000 1830.0 1794.2 26.8 119.8 3.000 1930.0 1882.3 29.7 118.7 3.005 2030.0 1967.8 32.7 117.8 2.996 2130.0 2050.5 35.7 117.0 3.004 2201.0 2107.4 37.8 116.5 3.015 2230.0 2130.3 37.8 116.5 0.000 2330.0 2209.4 37.8 116.5 0.000 2430.0 2288.4 37.8 116.5 0.000 2530.0 2367.4 37.8 116.5 0.000 2571.0 2399.8 37.8 116.5 0.000 2L-3Dcement.cfw;01-i6-2007; LoadCaseSurface;Versionwcs-cem45_89 '~ ~'1 R, t~ ~ ~t; ~ ,~ ~ ~li - ~ ~ ~. , , `~ a._.. ~~~I~~r~~r Page 3 ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2561.0 ft Casing Shoe :2571.0 ft NB of Cent. Used :34 NB of Floating Cent. :34 ~ Schlumd~rg~r Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth ft Joint % ft 1371.0 0 0/0 0.0 1389.1 2411.0 26 1/1 541 - ANJO-9 5/8-6-36 (.171") 2.7 1391.0 2571.0 8 2/1 541 - ANJO-9 5/8-6-36 .171") 89.7 2421.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf 541 - ANJO-9 5/8-6- 9 5/8 13.252 9.846 No Houma 12.250 299.00 1733.28 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 ZL-327 cemenLCfw; 01-16-1007 ; LoadCase Surface ; Version wcs-cem45_89 QRIGII~AL ~ ~ Client : ConocoPhillipsAlaska ~~~~~~~~~~ Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.50 Ib/gal Rheo. Model : BINGHAM p~ : 20.000 cP At temp. : 80 degF Ty : 30.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume : 168.9 bbl Water Type : Fresh CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model : NEWTONIAN At temp. : 80 degF Viscosity : 5.000 cP Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 10.50 Ib/gal Rheo. Model : HERSCHEL B. k : 3.95E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.366 Ty :10.191bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl 12 ppg DeepCRETE DESIGN Fluid No: 4 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL B. k : 1.18E-2 Ibf.s^n/ft2 At temp. : 64 degF n : 0.797 Ty :15.121bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 8.149 gal/sk Yield : 2.47 ft3/sk Porosity : 44.2 % Density :8.321b/gal Job volume : 73.0 bbl Quantity : 166.12 sk Solid Fraction : 55.8 % Base Fluid : 8.149 gal/sk 2L-327cement.ciw;01-i6-2007; LoadCaseSurface;Versionwcs-cem45_89 Page 5 ~~~~~~~~~ ~ ~ Client : ConocoPhillips Alaska ~~~I~~r~~r We11 : 2L-327 Siant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface ASL lead DESIGN Fluid No: 5 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL B. k : 3.24E-2 Ibf.s^n/ft2 At temp. : 66 degF n : 0.431 Ty :18.751bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 8.149 gal/sk Yield : 4.49 ft3/sk Porosity : 62.9 % Density :8.321b/gal Job volume : 366.8 bbl Quantity : 458.43 sk Solid Fraction : 37.1 % Base Fluid : 8.149 gal/sk 2L-327cement.cfw;01-i6dOD7; LoadCaseSurface;Versionwcs-cem45_89 ~~~~~~~~~~~r Page 6 ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface Section 4: fluid sequence Original fluid Mud 9.50 Ib/gal P~ : 20.000 cP Displacement Volume 188.9 bbl Total Volume 728.7 bbl TOC 0.0 ft C~ S~f~l~a~r~~r Tr : 30.00 Ibf/100ft2 Name Volume bbl Ann. Len ft Top ft Fluid Sequence Density Ib/ al Rheology CW 100 50.0 0.0 8.33 viscosity:5.000 cP MUDPUSH II 50.0 0.0 10.50 k:3.95E-2 Ibf.s"n/ft2 n:0.366 Tv:10.19 Ibf/100ft2 ASL lead 366.8 1771.0 0.0 10.70 k:3.24E-2 Ibf.s^n/ft2 n:0.431 Tv:18.75 Ibf/100ft2 12 ppg DeepCRETE 73.0 800.0 1771.0 12.00 k:1.18E-2 Ibf.s"n/ft2 n:0.797 Tv:15.12 Ibf/100ft2 Water 20.0 2227.2 8.32 viscosity:3.000 cP Mud 168.9 0.0 9.50 P~:20.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks : Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2798 psi at 2491.0 ft Burst 5750 psi at 0.0 ft Csa.Pumo out 34 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments CW100 5.0 25.0 5.0 25.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test Lines CW100 5.0 25.0 5.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 ASL lead 7.0 366.8 52.4 366.8 80 12 ppg 7.0 73.0 10.4 73.0 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Pumps Mud 6.0 148.9 24.8 148.9 80 Mud 3.0 20.0 6.7 168.9 80 Slow to Bum Total 02:21 728.7 bbl hr:mn Dynamic Security Checks : Frac 6 psi at 80.0 ft Pore 1 psi at 80.0 ft Collapse 2798 psi at 2491.0 ft Burst 5474 psi at 0.0 ft 2L-3D cement.ciw; 01-16-2007 ; LoadCase Surface ; Version wcs-cem45_89 Page 7 ~ ~ ~ ~ ~ ~~ ~ ~ Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 9 5-8 District : Prudhoe Bay Country : United States of America Loadcase : Surface ft 8 o ~ I- 0 0 o- O LL N S ~ O i I 0 400 800 Pumped Volume (bbl) _ I.. : 0 0 0 N O O c+~ - 0 0 0 X `~ O N Q N N~ ~ ~ ~ m ~ 0 400 800 Fluid Sequence Dynamic Well Security Pumped Volume (bbl) Pumped Volume (bbl) ~ _Depth = 2571 ft ~ Frac m ~ Pore . .. ..... . ,~~. . ~ ~ I-NArostatir. W 0 100 200 300 400 500 600 700 800 Pumped Volume (bbl) 0 ~ c j', ~°o T '~.. ~~~,~,: ~O N i ',. ~ ~ C C Q 2L-321cementcfw;01-16-2007; LoadCaseSurface;Versionwcs-cem45_89 ORlGIN~L Scf~l~~b~rg~r Page 8 CernCAC~E~~ Prefirni~nary~ri.Jc~b ~~`sign ~~~I~~~~~~~~ „~d; ~~1%2" t~ 7`~ Lan strin ~~~ ~~ ~ Preliminary Job Design based on limited input data. For esfimate purposes only. Volume Caiculations and Cement Systems Volumes are based on 50% excess through the 7" casing and 22.5% through the 4 1/2 " casing. Top of cement must come 500' above the top of the Bermuda @ 6064' MD. Therefore, the top of cement must be 5564' MD. Tail Slurry Minimum thickening time: 205 min. (pump time plus 120 min.) 11.0 ppg LiteCRETE = 3.30 ft3/sk Annular Volume (7" casing): 0.1503 ft3/ft x(5881' - 5564') x 1.50 (50% excess) = 71.5 ft3 Annular Volume (4.5" casing): 0.3071 ft3/ft x(6561' - 5881') x 1.225 (22.5% excess) = 255.8 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 6.8 ft3 Totals: 71.5 ft3+ 255.8 ft3+ 6.8 ft3= 334.1 ft3 334.1 ft3/ 3.30 ft3/sk = 101.2 sks Round up to 110 sks BHST = 147~, Estimated BHCT = 102~. (BHST calculated using a gradient of 2.6`F/100 ft. below 1150' TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage ~bpm~ Volume ~m~n~ Time (bbl) (min) MudPUSH II 4 25 6.3 6.3 Pressure Test, Dro Wi er Plu 10 16.3 MudPUSH II 4 50 12.5 28.8 LiteCRETE 4 59.6 14.9 43.6 Drop Top Plug 5 48.6 Water 4 20 5 53.6 Switch to rig pump 5 58.6 Displacement 4 194.2 48.6 107.2 Slow to Bump 2.5 20 8 115.2 MUD REM4VAL Recommended Mud Properties: 10.7 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.8 ppg MudPUSH* II, P~ ~ 19-22, TY = 22-29 Centralizers: Recommend 1 centralizer per joint through 4%2" section and three centralizers per 2 joints (3/2) through the 7" section to the TOC to improve zonal isolation. ~ Mark of Schlumberger ~~~~~~~~~ i i Schlumberger Cem CAD E*well cementing recommendation for 7"- 4.5" Intermediate Operator : ConocoPhillips Alaska Well : 2L-327 Slant Producer Country : United States of America Field : Tarn State : Alaska Prepared for : Tim Billingsley Location : 2L Pad Proposal No. : Service Point : Prudhoe Bay Date Preparetl : 01-05-2007 Business Phone :(907~659-2434 FAX No. : (907) 659-2538 Prepared by : Maureen Torrie Phone : 1-907-265-6336 E-Mail Adtlress : mtorrie@slb.com Disclaimer Notice: This information is presentetl in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced 6y a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests antl procedures which Schlumbergercan assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affectetl by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringemeni of patents of Schlumberger or others is not to be inferred. ` Mark of Schlumberger ~~~~~~~~$ ~, ~'~ s ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (a- Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6561.0 ft BHST : 147 degF Bit Size : 8 3/4 in Previous String MD OD Weight ID ft in Ib/ft in 2571.0 9 5/8 40.0 8.835 Landing Collar MD : 6481.0 ft Casing/liner Shoe MD : 6561.0 ft S~~I~~rg~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 5881.0 7 40.0 26.0 6.276 L-80 5410 7240 BTC 6561.0 41/2 40.0 12.6 3.958 L-80 7500 8430 IBT Mean OH Diameter : 8.750 in Mean Annular Excess : 42.1 % Mean OH Equivalent Diameter: 9.499 in Total OH Volume : 349.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 5900.0 8.750 50.0 9.509 6561.0 8.750 22.5 9.446 2L-327 cement.cTw; 01-17-2~07; LoadCase Intermediate (a~; Version wcs-cem45_89 Page 2 ~'~°~1~°~~~ ~~ ~_ '~ ' * Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (al Max. Deviation Angle : 38 deg Max. DLS : 3.574 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 330.0 330.0 0.6 180.0 -2.000 430.0 430.0 2.6 180.0 2.000 530.0 529.8 4.6 180.0 2.000 550.0 549.7 5.0 180.0 2.000 630.0 629.4 4.7 203.5 -2.494 730.0 729.0 5.5 230.7 2.497 800.0 798.6 6.5 244.1 2.507 830.0 828.4 5.9 237.8 -3.009 930.0 928.0 4.8 207.7 -3.000 1030.0 1027.6 5.3 173.5 2.999 1130.0 1127.0 7.2 151.5 3.002 1230.0 1225.9 9.6 139.6 2.991 1330.0 1324.1 12.3 132.6 3.006 1430.0 1421.2 15.1 128.2 2.996 1530.0 1517.1 18.0 125.1 3.002 1630.0 1611.4 20.9 122.9 3.000 1730.0 1703.8 23.8 121.2 3.000 1830.0 1794.2 26.8 119.8 3.000 1930.0 1882.3 29.7 118.7 3.005 2030.0 1967.8 32.7 117.8 2.996 2130.0 2050.5 35.7 117.0 3.004 2201.0 2107.4 37.8 116.5 3.015 2230.0 2130.3 37.8 116.5 0.000 2330.0 2209.4 37.8 116.5 0.000 2430.0 2288.4 37.8 116.5 0.000 2530.0 2367.4 37.8 116.5 0.000 2571.0 2399.8 37.8 116.5 0.000 2630.0 2446.4 37.8 116.5 0.000 2730.0 2525.5 37.8 116.5 0.000 2830.0 2604.5 37.8 116.5 0.000 2930.0 2683.5 37.8 116.5 0.000 3030.0 2762.5 37.8 116.5 0.000 3130.0 2841.6 37.8 116.5 0.000 3230.0 2920.6 37.8 116.5 0.000 3330.0 2999.6 37.8 116.5 0.000 3430.0 3078.6 37.8 116.5 0.000 3530.0 3157.7 37.8 116.5 0.000 3630.0 3236.7 37.8 116.5 0.000 3730.0 3315.7 37.8 116.5 0.000 3830.0 3394.7 37.8 116.5 0.000 3930.0 3473.8 37.8 116.5 0.000 4030.0 3552.8 37.8 116.5 0.000 4130.0 3631.8 37.8 116.5 0.000 4230.0 3710.8 37.8 116.5 0.000 4330.0 3789.9 37.8 116.5 0.000 4430.0 3868.9 37.8 116.5 0.000 4530.0 3947.9 37.8 116.5 0.000 ~~~I~~rg~r 2L-3D cement.cfiv; 01-17-2~07; LoadCase Intermediate (a~; Version wcs-cem45_69 r~ u Page 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Client : ConocoPhillipsAlaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediatela) MD ft) Directional Survey Data TVD Deviation Azimuth (ft) deg) de Dogleg Sev. de /100ft 4630.0 4027.0 37.8 116.5 0.000 4730.0 4106.0 37.8 116.5 0.000 4830.0 4185.0 37.8 116.5 0.000 4930.0 4264.0 37.8 116.5 0.000 5030.0 4343.1 37.8 116.5 0.000 5130.0 4422.1 37.8 116.5 0.000 5230.0 4501.1 37.8 116.5 0.000 5330.0 4580.1 37.8 116.5 0.000 5430.0 4659.2 37.8 116.5 0.000 5530.0 4738.4 37.3 117.1 -0.588 5630.0 4819.3 34.6 120.9 -3.502 5730.0 4902.9 32.1 125.2 -3.483 5830.0 4988.7 29.7 130.2 -3.511 5930.0 5076.5 27.5 135.9 -3.489 6030.0 5166.0 25.6 142.5 -3.511 6064.0 5196.7 25.0 145.0 -3.574 6130.0 5256.5 25.0 145.0 0.000 6230.0 5347.2 25.0 145.0 0.000 6330.0 5437.8 25.0 145.0 0.000 6430.0 5528.4 25.0 145.0 0.000 6530.0 5619.1 25.0 145.0 0.000 6561.0 5647.1 25.0 145.0 0.000 MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 1617.8 12.50 8.20 Permafrost Sandstone 2650.0 12.50 8.20 C80 Sandstone 4230.0 12.20 9.00 C50 Sandstone 4730.0 12.20 9.00 C40 Sandstone 5050A 12.20 9.00 C37 Sandstone 6064.0 12.20 10.63 Bermuda Top Sandstone 6250.0 12.20 10.63 Bermuda Base Sandstone 6300.0 12.20 10.63 C35 Sandstone 6561.0 12.20 10.63 TD Sandstone Geothermal Temperature Profile MD ND Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1153.2 1150.0 30 0.4 2571.0 2399.8 62 1.6 5000.0 4319.3 112 2.0 6561.0 5647.1 147 2.2 Scl~l~~rg~r 2L-327cement.cfw;01-17-2007; LoadCaselntermediate~a~;Versionwcs-cem45_89 Page 4 ~ ~ ~ ~ ~ ~ ~ i ~~ ~ ! "S~ rs~ €~.. • • Client : ConocoPhillips Alaska Well : 2L327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (a) Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :6541.0 ft Casing Shoe :6561.0 ft NB of Cent. Used :85 NB of Floating Cent. :70 Schluma~rg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 521.0 4 1/3 1501570-7-6-POSITIVE 0.0 491.0 2481.0 49 1/1 1501570-7-6-POSITIVE 0.0 2462.8 5481.0 0 0/0 0.0 2481.0 5881.0 15 3/2 61103670-7-4-36B (1/8")B 0.0 5499.2 6561.0 17 1/1 P1104641-4 1/2-4-46 (3/16")A _ 63.9 6561.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf P1104641-41/2-4-46 B11036 150157 7 8.500 8.500 No Houma N.A. (3/16")A 70-7-4- 0-7-6- I 36B POSITI (1/8")B VE (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 5 7L~327cemznt.cfw;07-17-2007; LoatlCaselntermetliatela~;Versionwcs-cem45_89 QRIG~N~L N.A. N.A. I . ~ Client : ConocoPhillipsAlaska Well : 21-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (a) Section 3: fluid description ~c~l~~rg~r Mud DESIGN Fluid No: 1 Density : 10.70 Ib/gal Rheo. Model : BINGHAM p~ : 14.000 cP At temp. : 80 degF Ty : 22.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume : 214.2 bbl Water Type : Fresh MUDPUSH II DESIGN Fluid No: 3 Density : 10.80 Ib/gal Rheo. Model : HERSCHEL B. k : 2.42E-1 Ibf.s"n/ft2 At temp. : 120 degF n : 0.181 Ty :1.601bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 75.0 bbl 11 ppg LiteCRETE DESIGN Fluid No: 5 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL B. k : 7.62E-2 Ibf.s^n/ft2 At temp. : 115 degF n : 0.534 Ty :0.061bf/100ft2 Gel Strengt h : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 10.956 gal/sk Job volume : 59.6 bbl Dry Density : 199.77 Ib/ft3 Yield : 3.30 ft3/sk Quantity : 101.3 sk Sack Weight : 94 Ib Porosity : 44.4(%) Solid Fraction : 55.6(%) BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Base Fluid : 10.946 gal/sk Page 6 2L-3DcementcTw;01-17-2007; LoadCaselntermediatela~;Versionwcs-cem45_89 ~ ~ ~ ~ ~ ~~ 9 ~ ~ .,,. t i r Client : ConocoPhillips Alaska ~~[y~~~~~~~ Well : 2L-327 Slant Producer j] String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (a) Section 4: fluid sequence Originaf fluid Mud 10.70 Ib/gal P~ : 14.000 cP Tv : 22.00 {bf/100ft2 Displacement Volume 234.2 bbl Total Volume 368.7 bbi TOC 5564.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al MUDPUSH II 75.0 1863.7 3700.3 10.80 k:2.42E-1 Ibf.s^nlft2 n:0.181 Tv:1.60 Ibf/100ft2 11 ppg LiteCRETE 59.6 997.0 5564.0 11.00 k:7.62E-2 Ibf.s^n/ft2 n:0.534 7v:0.06 Ibf/100ft2 Water 20.0 5596.9 8.32 viscosity:3.000 cP Mud 214.2 0.0 10.70 P~:14.000 cP Tv:22.00 Ibf/100ft2 Static Security Checks : Frac 224 psi at 2571.0 ft Pore 33 psi at 6064.0 ft Collapse 5082 psi at 5881.0 ft Burst 7240 psi at 0.0 ft Csg.Pump out 57 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Yolume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments MUDPUSH II 4.0 25.0 6.3 75.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test, Drop Wiper Plug Ml1DPUSH II 4.0 50.0 12.5 75.0 80 11 ppg 4.0 59.6 14.9 59.6 SO LiteCRETE Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 4.0 20.0 5.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig pump Mud 4.0 194.2 48.6 194.2 80 Mud 2.5 20.0 8.0 214.2 80 Slow to Bump Total 01:55 368.7 bbl hr:mn Dynamic Securi Checks : Frac 11 psi at 5930.0 ft Pore 19 psi at 6130.0 ft Collapse 5064 psi at 5881.0 ft Burst 6653 si at 0.0 ft Page 7 2L327cement.cfw;07-17-2007; LoadCaselntermediatela~;Versionwcs-cem45_89 ~~?~~~~~~~~... . Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediate (a) ft 8 o ~ ,~ 0 0 ~ N 0 0 °o ~ O O O ~ f~ - Fluid Sequence I tJgal 0 o ~ ~ Collapse 0 ~ ~ Pseudo Hydrostatic ~ ~ D~nartic •N Q O N N N a ' ~ I 0 0 ~------ „~ 0 40 80 ~ c~ o~ ~ ~ ~ m N N a` ~ c Qo 0 160 200 240 Pumped Volume (bbl) • Calc. PUrrQ Ress. Calc. WHP ~ U ~ 50 100 150 Time (min) o Depth = 6561 ft ~ ~ ~ Annular Velocity . c ~ ~ ~ T .U . ..: . .. .. .. O N~ ~ ~ C '.,~~. ~~.~ II ' I I I C Q ... ~ ...._.~~.. .. O 0 50 100 150 Time (min) 0 40 80 120 160 200 240 280 320 360 400 Pumped Volume (bbl) ~~hl~~~i~rg~r Page 8 21-327 cement.cTw ; 01-17-20~7 ; LoadCase Intermediate ~a) ; Version wcs-cem45_89 0~lGINAL 14 ~ °o ~ O ,-.p ~y ~ ^. a =o ~~ ~ o 0 • Client : ConocoPhillips Alaska Well : 2L-327 Slant Producer String : 7 District : Prudhoe Bay Country : United States of America Loadcase : Intermediatelal Section 6: WELLCLEAN II Simulator ft % % 25 50 75 100 0 100 0 °o o - Std Betw. CenL - Mud Conlarrination ~ - Cement Coverage - Uncontaminated Slurry 0 0 o- ~ 0 0 0 ~- Fluid Sequence .^- 5900 s 6000 ~ 6104 O szoa Cement Coverage Fluids Concentrations ~ o ~ 5500 - 5B00 - 5700 - 5800 - 5?00 ~^ - fi4~70 r - 8100 m - O - 6200 - 6300 - 6A00 ~ ssoo 6 ~ ~ 6306 6~00 fi506 ~ Mud 0 11 ppg LiteCRETE ~ Water ~ MUDPUSH II ~ Schlumherg~r deg Uncontaminated Siurry Deviation Risk Mud on the Wall ~ o ~ 590a ~ r . . ' .. 5500 5600- ~ ~ 5800 570d- ;~ j 5T00 560d- - - 5800 ~ 5404- == ~ 5900 ~ s ~ 6D00- 8100- -, ~ 6400 r 8100 ~ 6 - O szoa- s~oo 63~0- 6300 6400- 6A00 s~oa- e5oo o O ~ p m a ~ ~ O Z (_] High 0 Low ~ PAedium ~ hJone 2L-327cement.ciw;01-17d007; LoadCaselntermediatela~;Versionwcs-cem45_89 QRIGINAL Page 9 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 - 5950000 5900000 ! 5850000 ~ ~ 400000 500000 600000 700000 800000 ~ • SHARON K. ALLSUP-DRAKE ~ ~ 71 CONOCOPHILLIPS AT01530 700 G ST. ~ ~~GGtiu~WI,ZeXJ~ ANCHORAGE AK 99504 oare _~__ 1551/441 PAY TO THE ST ~ T E OF f'~ ~lSC.rf r 1 C/~--~ C` ~ I OO. ~v ORDER OF ~.~ ~ ~ o! i~~.... ~~ ~ ~~ -.~ 8 J PMorganEhase ~ v~ia up To 5000 oouars JPMorgan Chase Bank; N.A. Columbus, OH MEMO 2 L' ~ ~~ /~~_ . C~~~'1%~ ~ ~:044~L55~L~:52874?L90792?ii'LL7L ~ ~ T'1tANSMIT'~'AL LET'TEIa C~-I~CKLIST `v~LL ~~~~~ ~,~~( z ~ - 3 Z-7 PTU# ~v`7-ao~ V Development Service Ex lorato ~ Strati ra hic ~'est - P rY g P Non-Conventional Well C'ircle Appropriate Letter / Paragraphs to be Ineluded in Transmittal Letter ~ CHECK i ADD-ONS ~ TEXT' FOR APPROVAL LETT'ER ; w'HAT (OPTIONS) ;' ' APPLIES ~ ~ ' i ; ~ , I MULTI LATERAL ~ The permit is for a new we(lbore segment of existing ; ~ ~ ~ wel( ~ i(If last two digits ,, API number in ~~ P~~it ,vo , API No. ~0- - - are , ; between 60-69) ; Production should continue to be reported as a function of the i ~ ; original API number stated above. ; ~ ~ ~ ' PILOI' HOLE ~ In accordance with 20 AAC 2~.00~(~, a!1 records, data and logs ,' i ~ acquired for the pilot hole must be clearly differentiated in both ~ i ; well name ( PH) and API number i ~(50- - -_~ from records, data and lo~s t ~ ~~ acquired for well i i SPACING The permit is approved subject to fult compliance with 20 AAC i ' EXCEPTION ~ 2~.0». Approval to perforate and produce / inject is contingent ; i I upon issuance of a conservation order approvin; a spacing ~ i' ~ exception. assumes the j i i liabi(ity of any protest to the spacing exception that may occur. ~ ; DRY D[TCH ~ ~ AII dry ditch samp(e sets submitted to the Commission must be in ; i' SA'.~IPLE I no greater than 30' samp(e intervals from below the permafrost or ; I I from where samples are first caught and 10' sample intervals ; ;' ~ through target zones. i , , ~ i Please note the following special condition of this permir: ~ ~ tion-Conventional i production or production testing of coal bed methane is not allowed j i~'z~I ~ for (name of well) until after (Com~anv lvrame) has designed and ~ ~ implemented a water well testing program to provide baseline data ~ I ; on water quality and quantity. ~Com~any Name) must contact the ; ~ Commission to obtain advance approval of such water wel( testing ! 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O w+ ~ N ~'~. ~ . ~ N I ~ N O N N ,~ ~ ~ '~ C ~ I ~ O'~ ,.-~. ~ ~ y '~ d ~ I I T ~ ~ U ~ a Q a~ a N ~ W a a w ~ ! o a0 ~ acn , ~ Well History File APPENDIX Information of detailed nature that is not C~ particula~ly geRnane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.pl~fy finding infoRnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ` # • 2L-327.tapx Sperry-Sun ~rilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 04 10:10:27 2007 Reel Header Service name .............LISTPE ~ate . ...................07/09/04 Ori in ...................STS Ree~ Ndme. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/09/04 Origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS Writing Library. Physical EOF • scientific Technical services scientific Technical services comment Record TAPE HEADER Tarn MWD/MAD LOGS # WELL NAME: 2L-327 API NUMBER: 501032054200 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry TAPE CREATION DATE: 27-AUG-07 # JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: K-Mw-4987725 K-Mw-4987725 K-MW-4987725 LOGGING ENGINEER: 0. OBI 0. OBI O. OBI OPERATOR WITNESS: D. MORRIS D. MORRIS D. MORRIS MWD RUN 4 MWD RUN 5 JOB NUMBER: K-MW-4987725 K-MW-4987725 LOGGING ENGINEER: 0. OBI A. SHANAHAN OPERATOR WITNE55: D. MORRIS D. MORRIS # SURFACE LOCATION SECTION: 22 TOWNSHIP: lON RANGE: 07E FNL: 226 FSL: FEL: 894 FWL: Page 1 aa~--~~ ~~5~~9 ~ ~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 15T STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 2~-327.tapx .00 147.10 117.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 8.750 9.675 2550.0 6.125 7.000 5968.0 CJ 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED, AND REFERENCE BIT DEPTH. 2. MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DGR, EWR-4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), BIMODAL ACOUSTIC TOOL (BAT), AND PRESSURE WHILE DRILLING (PWD). DGR AND EWR-4 TOOLS ONLY EXITED CASING TO LOG NEW HOLE BEFORE TRIPPING OUT FROM MWD RUN 3. 4. LOG CURVE DATA IS CONSIDERED PDC PER THE E-MAIL FROM DERIK KLEIBACKER OF CONOCOPHILLIPS ALASKA, INC. TO B BRYANT OF SPERRY DRILLING SERVICES, DATED 17-AUG-2006. 5. MWD RUNS 1-5 REPRESENT WELL 2L-327 WITH API #: 50-103-20542-00. THIS WELL REACHED A TOTAL DEPTH (TD) oF 6568'M~/5648'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLQW SPCG). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (55 MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED FAR NEUTRON DETECTOR'S AVERAGE COUNT RATE. CTNA = SMOOTHED NEAR NEUTRON DETECTOR'S AVERAGE COUNT RATE. SBD2 = SMOOTHED BULK DENSITY COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. DTCP = SMOOTHED COMPRESSIONAL WAVE SLOWNESS - POST WELL PROCESSED. Page 2 ~ ~ ~ 2L-327.tapx DTSP = SMOOTHED SHEAR WAVE SLOWNESS - POST WELL PROCESSED. VPVS = SMOOTHED RATIO OF SHEAR TO COMPRESSIONAL WAVE SLOWNESS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75~~ & 6.25~~ NOMINAL- ACAL/SHSI MUD WEIGHT: 9.8 - 11.3 PPG MUD FILTRATE SALINITY: 26,000 - 32,000 PPM CHLORIDES FORMATION WATER SALINITY: 15000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... .......STSLIB.001 SerViCe SUb Level~Ndme... version Number. ........1.0.0 Date of Generation.......07/09/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPx 445.5 6522.5 FET 445.5 6522.5 RPS 445.5 6522.5 RPS 445.5 6522.5 RPM 445.5 6522.5 GR 453.0 6515.5 RoP 495.5 6568.0 DTC 2478.5 6448.0 PEF 2537.0 6502.5 NCNT 2549.0 6487.0 FCNT 2549.0 6487.0 NPHI 2549.0 6487.0 RHOB 2550.0 6502.5 DRHO 2551.5 6502.5 SCRA 2560.0 6446.5 DTSH 2560.0 6446.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 445.5 1194.0 MwD 2 1145.0 2574.0 Page 3 • MWD 3 MWD 4 MWD 5 $ # REMARKS: MERGED MAIN PA55. $ 2L-327.tapx 2538.0 2600.0 2478.5 5981.0 5860.5 6568.0 # Data Format Specification Record Data Record Type... ..........0 oata specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 ~epth units. . .. .. ..... ~atum Specification Block sub-type...0 . Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-5 4 1 68 32 9 FCNT MWD CNTA 4 1 68 36 10 NCNT MWD CNTA 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 DTC MwD USPF 4 1 68 56 15 DTSH MWD USPF 4 1 68 60 16 SCRA MWD NONE 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 445.5 6568 3506.75 12246 445.5 6568 ROP Mw~ FT/H 0.69 770.71 112.314 12146 495.5 6568 GR MwD API 15.99 226.1 108.731 12126 453 6515.5 rtPx MwD OHMM 0.76 1684.38 6.39169 12043 445.5 6522.5 RPS MwD OHMM 0.78 1104.42 8.25578 12043 445.5 6522.5 RPM MWD OHMM 0.78 2000 14.011 12043 445.5 6522.5 RPD MwD OHMM 0.93 2000 22.5983 12043 445.5 6522.5 FET Mw~ HOUR 0.15 89.59 1.54673 12043 445.5 6522.5 NPHI MwD PU-5 11.04 61.02 35.0448 7713 2549 6487 FCNT Mw~ CNTA 156.5 3313.4 905.334 7713 2549 6487 NCNT MWD CNTA 15778.9 201262 126825 7713 2549 6487 RHOB Mw~ G/CM 1.843 2.708 2.32824 7765 2550 6502.5 DRHO MWD G/CM -2.07 0.315 0.0538352 7765 2551.5 6502.5 PEF MwD B/E 1.77 18.28 3.36568 7804 2537 6502.5 DTC MWD USPF 47.8067 134.276 105.675 7940 2478.5 6448 DTSH MwD USPF 105.489 383.746 219.79 7558 2560 6446.5 SCRA MWD NONE 1.4119 3.2729 2.05416 7541 2560 6446.5 First Reading For Entire File..........445.5 Page 4 • 2~-327.tapx ~ast Reading For Entire File...........6568 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........ST5LI6.002 Phy5iCd1 EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical Record..65535 File Type. ............LO P1^2vi0U5 Fi12 Ndme.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH RPM 445.5 FET 445.5 RPD 445.5 RP5 445.5 RPx 445.5 GR 453.0 ROP 495.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 1144.5 1144.5 1144.5 1144.5 1144.5 1152.0 1194.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ Page 5 ~ header data for each bit run in separate files. 1 .5000 31-MAY-07 Insite 6.x 72.13 RECORDED 1194.0 445.0 1194.0 1.4 8.5 TOOL NUMBER 63122 ewr 63122 a ~ 2~-327.tapx # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Spud MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (5): 56.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 18.0 RESISTIVITY (OHMM) AT TEMPER ATURE (DEG F) MUD AT MEASURED TEMPERATU RE (MT): 57.000 2.5 MUD AT MAX CIRCULATING TE RMPERATURE : 57.000 107.0 MUD FILTRATE AT MT: 1.950 55.0 MUD CAKE AT MT: 2.200 60.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification ttecord Data Record Type... ....... ...0 Data Specification Block Type.. ...0 Log~ing Direction .............. ...DOwn optical log depth units........ ...Feet ~ata Reference Point ........... ...undefin ed Frame Spacing....... ......... ...60 .lIN Max frames per record .......... ...undefin ed Absent value ................... ...-999.25 Depth Units. . .. .. .. ... ~atum Specification Block sub-t ype...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 FET MWDO10 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 445.5 1194 819.75 1498 445.5 1194 ROP Mw~010 FT/H 2.1 770.71 160.202 1398 495.5 1194 GR Mw~010 API 15.99 107.56 58.432 1399 453 1152 RPx MWDO10 OHMM 2.76 54.38 13.8384 1379 445.5 1144.5 RPS MwD010 OHMM 4.27 206.14 25.5792 1379 445.5 1144.5 RPM MwD010 OHMM 5.1 2000 60.1428 1379 445.5 1144.5 RPD MwD010 OHMM 5.81 2000 133.047 1379 445.5 1144.5 FET MwD010 HOUR 0.15 1.4 0.714612 1379 445.5 1144.5 Page 6 a • 2L-327.tapx First Reading For Entire File..........445.5 Last Reading For Entire File...........1194 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 1145.0 2525.0 RPM 1145.0 2525.0 RPD 1145.0 2525.0 RPx 1145.0 2525.0 FET 1145.0 2525.0 Grt 1152.5 2532.5 ROP 1194.5 2574.0 $ # LOG HEADER DATA DATE LOGGED: O1-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72..13 DATA TYPE (MEMORY OR REAL-TIME): RECORDED TD DRILLER (FT): 2574.0 TOP LOG INTERVAL (FT): 1194.0 BOTTOM LOG INTERVAL (FT): 2574.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 10.1 MAXIMUM ANGLE: 37.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 7 ~ ~ 2~-327.tapx DGR DUAL GAMMA RAY 63122 EWR4 ELECTROMAG. RESIS. 4 63122 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Spud MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (5): 193.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 5.4 RE5I57IVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 57.000 2.5 MUD AT MAX CIRCULATING TERMPERATURE: 57.000 113.0 MUD FILTRATE AT MT: 1.950 55.0 MUD CAKE AT MT: 2.200 60.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 ~epth units. . .. .. ..... Datum Specification Block sub-type...0 tvame service order units size Nsam ttep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MwD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Fi rst Name Service Unit Min Max Mean Nsam Reading DEPT FT 1145 2574 1859.5 2859 1145 RoP MwD020 FT/H 1.8 329.08 127.253 2760 1194.5 GR MWD020 API 28.04 136.32 79.4031 2761 1152.5 RPx Mw~020 OHMM 1.56 53.87 9.38858 2761 1145 RPS MwD020 OHMM 1.71 124.97 11.8808 2761 1145 Page 8 Last Reading 2574 2574 2532.5 2525 2525 . 2L-327.tapx RPM MWD020 OHMM 1.71 557.53 14.373 RPD MWD020 OHMM 1.83 1517.91 17.7676 FET MWD020 HOUR 0.24 7.82 0.948743 First Reading For Entire File ..........1145 Last Reading For Entire File. ..........2574 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical rtecord..65535 File Type ................LO Next File Name...........5T5LIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD ~ 2761 1145 2525 2761 1145 2525 2761 1145 2525 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Grt 2538.0 2562.5 RPD 2545.0 2555.0 RPx 2545.0 2555.0 RPM 2545.0 2555.0 RPS 2545.0 2555.0 FET 2545.0 2555.0 ROP 2575.5 2600.0 $ # LOG HEADER DATA DATE LOGGED: 04-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): RECORDED TD DRILLER (FT): 2600.0 TOP LOG INTERVAL (FT): 2574.0 BOTTOM LOG INTERVAL (FT): 2600.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Page 9 • # 2~-327.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ # # # # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRA7E AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... . ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 ~ TOOL NUMBER 218738 127479 8.750 2550.0 lignosulfanate 9.60 41.0 9.9 910 7.4 72.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2538 2600 2569 125 2538 2600 ROP Mw~030 FT/H 0.69 162.35 116.965 50 2575.5 2600 Page 10 • ~ 2L-327.tapx GR MwD030 ,4PZ 50.8 106.96 86.7442 50 2538 2562.5 RPx MwD030 OHMM 3.77 4.31 4.07714 21 2545 2555 rtPS MWD030 OHMM 4.27 5.09 4.66048 21 2545 2555 RPM MwD030 OHMM 4.56 5.66 5.0419 21 2545 2555 RPD MWD030 OHMM 4.22 6.19 5.38762 21 2545 2555 FET MwD030 HOUR 69.62 69.66 69.6395 21 2545 2555 First Reading For Entire File..........2538 ~ast Reading For Entire File...........2600 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version rvumber. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 ServiCe SUb Level~Ndme... Version Number. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical Record..65535 File Type. ............~o Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 2478.5 5860.0 PEF 2537.0 5898.5 NCNT 2549.0 5885.5 FCNT 2549.0 5885.5 NPHI 2550.0 5885.5 RHOB 2551.5 5898.5 DRHO 2551.5 5898.5 FET 2555.5 5936.0 RPS 2555.5 5936.0 RPD 2555.5 5936.0 RPx 2555.5 5936.0 RPM 2555.5 5936.0 SC~ 2560.0 5860.0 DTSH 2560.0 5860.0 GR 2563.0 5943.0 RoP 2600.5 5981.0 $ # LOG HEADER DATA Page 11 i DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTfOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD BAT $ 2L-327.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RE5I5. 4 COMP THERMAL NEUTRON AZIMUTHAL LITHO-DEN BIMODAL ACOUSTIC BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Ddtd Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet ~ata rteference Point ..............undefined Frame 5pacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 ~epth Units. . .. .. ..... ~atum Specification Block sub-type...0 • 07-JUN-07 Insite 72.13 RECORDED 5981.0 2600.0 5981.0 25.5 38.8 TOOL NUMBER 218738 127479 231172 224102 141117 8.750 2550.0 Fresh Wtr Gel 9.70 56.0 9.6 700 4.2 68.000 .6 68.000 126.0 1.200 68.0 .550 68.0 Name service Order Units Size Nsam Rep Code Offset Channel Page 12 ~J • 2~-327.tapx DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-5 4 1 68 32 9 FCNT MWD040 CNTA 4 1 68 36 10 NCNT MWD040 ~NTA 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 DTC MWD040 USPF 4 1 68 56 15 DTSH MWD040 USPF 4 1 68 60 16 SCRA MWD040 NONE 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2478.5 5981 4229.75 7006 2478.5 5981 ROP Mw~040 FT/H 1.07 276.82 107.187 6762 2600.5 5981 GR MWD040 API 48.34 226.1 129.323 6761 2563 5943 RPx MwD040 OHMM 0.76 56.2 3.46577 6762 2555.5 5936 RPS Mw~040 OHMM 0.78 49.08 3.49577 6762 2555.5 5936 RPM MwD040 OHMM 0.78 37.12 3.5046 6762 2555.5 5936 RPD Mw~040 OHMM 0.93 24.39 3.5628 6762 2555.5 5936 FET Mw~040 HOUR 0.32 81.88 1.28702 6762 2555.5 5936 NPHI MWD040 PU-S 11.04 61.02 35.918 6672 2550 5885.5 FCNT MWD040 CNTA 542.29 3313.4 978.175 6674 2549 5885.5 NCNT MWD040 CNTA 113571 201262 142619 6674 2549 5885.5 RHOB Mw~040 G/CM 1.925 2.708 2.30615 6695 2551.5 5898.5 DRHO MWD040 G/CM -0.059 0.315 0.0467659 6695 2551.5 5898.5 PEF MwD040 B/E 1.77 15.68 2.79569 6724 2537 5898.5 DTC Mw~040 USPF 47.8067 134.276 107.62 6764 2478.5 5860 DTSH MwD040 USPF 105.489 383.746 226.17 6591 2560 5860 SCRA MwD040 NONE 1.6047 3.2729 2.0784 6574 2560 5860 First Reading For Entire File..........2478 ~ast Reading For Entire File...........5981 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version -vumber. ........1.0.0 ~ate of Generation.......07/09/04 Maximum Physical rtecord..65535 File Type ................LO Next File Name...........5T5LIB.006 Phy51Cd1 EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/04 Page 13 ~ ~ 2~-327.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB. 005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 5860.5 6448.0 GR 5943.5 6515.5 RPD 5963.0 6522.5 RPM 5963.0 6522.5 RPS 5963.0 6522.5 FET 5963.0 6522.5 PEF 5963.0 6502.5 RPx 5963.0 6522.5 SCRA 5963.5 6446.5 DTSH 5963.5 6446.5 DRHO 5968.0 6502.5 FCNT 5968.0 6487.0 RHOB 5968.0 6502.5 NCNT 5968.0 6487.0 NPHI 5969.0 6487.0 ROP 5981.5 6568.0 $ # LOG HEADER DATA DATE LOGGED: 11-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): RECORDED TD DRILLER (FT): 6568.0 TOP LOG INTERVAL (FT): 5981.0 BOTTOM LOG INTERVAL (FT): 6568.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.0 MAXIMUM ANGLE: 28.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 218738 EWR4 ELECTROMAG. RESIS 73634 CTN COMP THERMA L NEUT 231172 ALD AZIMUTHAL L ITHO-DEN 34016 BAT BIMODAL ACO USTIC 125705 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 5968.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 12.00 MUD VISCOSITY (S): 55.0 Page 14 . • 2L-327.tapx MUD PH: 10.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 68.000 1.0 MUD AT MAX CIRCULATING TERMPERATURE: 68.000 131.0 MUD FILTRATE AT MT: .950 68.0 MUD CAKE AT MT: 1.150 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet oata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value . ....................-999.25 ~epth Units. . .. .. ..... ~atum specification Block sub-type...0 Name Service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-5 4 1 68 32 9 FCNT MWD050 CNTA 4 1 68 36 10 NCNT MWD050 CNTA 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 B/E 4 1 68 52 14 DTC MwD050 USPF 4 1 68 56 15 DTSH MWD050 USPF 4 1 68 60 16 SCRA MwD050 NONE 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5860.5 6568 6214.25 1416 5860.5 6568 ROP MwD050 FT/H 12.17 106.06 49.6515 1174 5981.5 6568 GR MwD050 aPI 71.6 184.31 120.501 1145 5943.5 6515.5 RPx Mw~050 OHMM 1.21 1684.38 7.54366 1120 5963 6522.5 RPS MwD050 OHMM 1.26 1104.42 6.79587 1120 5963 6522.5 RPM MwD050 OHMM 1.24 1960.28 19.9193 1120 5963 6522.5 RPD MWD050 OHMM 1.12 1779.98 13.7662 1120 5963 6522.5 FET MwD050 HOUR 0.71 89.59 4.33667 1120 5963 6522.5 Page 15 L. • ~ 2~-32 7.tapx NPHI MwD050 Pu-5 13.23 41.28 29.3938 1037 5969 6487 FCNT MWD050 CNTA 156.5 998.9 437.441 1039 5968 6487 NCNT Mw~050 CNTA 15778.9 35439.9 25376.4 1039 5968 6487 RHOB MwD050 G/CM 0.554 2.643 2.46496 1070 5968 6502.5 DRHO MWD050 G/CM -2.07 0.198 0.0980673 1070 5968 6502.5 PEF MwD050 B/E 3.75 18.28 6.91438 1080 5963 6502.5 DTC Mw~050 USPF 66.9557 112.543 94.4859 1176 5860.5 6448 DTSH Mw~050 USPF 120.211 214.383 176.309 967 5963.5 6446.5 SC~ MwD050 NONE 1.4119 2.2343 1.88934 967 5963.5 6446.5 First Reading For Entire File..........5860.5 ~ast Reading For Entire File...........6568 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.007 Physical EOF Tape Trailer Service name .............LISTPE ~ate . ...................07/09/04 origin ...................sTs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/09/04 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File writing ~ibrary Page 16 Scientific Technical Services scientific Technical services ~ ~ • • Cono P ~ ~ co ps Alaska, Inc. ~0~-a~~f ~~sa~ FINAL WELL REPORT ~ ConocoPhillips Alaska, Inc. TARN 2L-327 226' FNL, 894' FEL Sec 22 - T10N - R7E, UM North Siope, Alaska Compiled by: Lees F. Browne, Jr. Mark Bietting June 11, 2007 r~ ~J E~ EPOCH Conoco~Phillips Tarn 2L 327 • ~ 1 MUDLOGGING EQUIPMENT & CREW ................................................................... 3 1.1 Equipment Summary ........................................................................................... 3 1.2 Crew ...................................................................................................................... 4 Z. GENERAL WELL DETAILS ...................................................................................... 5 2.1 Objectives ............................................................................................................. 5 2.2 Well Summary ...................................................................................................... 6 3. GEOLOGICAL DATA ................................................................................................ 8 3.1 Lithostratigraphy ..................................................................................................8 3.2 Mudlog Summary ................................................................................................. 9 3.3 Sampling Program / Sample Dispatch ............................................................. 23 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory ....................................... 24 4. PRESSURE / FORMATION STRENGTH DATA .................................................... 25 TABLE OF CONTENTS 4.1 Formation Integrity/Leak Off Tests .................................................................. 25 4.2 Pore Pressure Evaluation Introduction ........................................................... 25 4.3 Pore Pressure Summary ................................................................................... 26 5. DRILLING DATA ..................................................................................................... 27 5.1 Daily Activity Summary ..................................................................................... 27 5.2 Bit Record ........................................................................................................... 29 5.3 Survey Record .................................................................................................... 30 5.4 Mud Record ........................................................................................................ 33 Enclosures 2"=100' Scale 2"=100' Scale 2"=100' Scale 2"=100' Scale Mudlog LWD Combo Log Gas Ratio Log Drilling Dynamics Log E~ EPOCH 2 ConOCO~PhillipS Tarn 2L 327 MUDLOGGING EQUIPMENT & GREW 1.1 Equipment Summary Parameter Equipment Type i Positian Total Downtime Comments ditch gas QGM electric gas trap Flame ionization total & chromato raph detector 1 hour Replace agitatar biades in top hole ravel; ~ent to Totco via WITS H2S Deteator (H2S) Variable resistivity cell. Sample line, drill floor, mud pits & shakers - No Epoch H2S detectar installed Rate of penetration (ROP) BEI Encoder- Primary draw warks block position indicator - Replaced Encoder at Intermediate casin oint Pum stroke counter SPM) RIGWATCH Turck Ma netic roximit sensor - Hoak Load HLKD / Wei ht on bit WOB) RIGWATCH Ametek H draulic ressure cell - Tor ue RTOQ Tap Drive Feed - Not receivin Tor ue si nat from Totco Top drive rota RPM To Drive Feed - Totco Wits feed Standpi e 8~ casin ressure SPP/CSIP Totco H draulic ressure cell - Mud flow out (FLOW) Totca Flow Paddle - Totco Wits Feed Pit levels x 6 Ball Float sensars in all its & tri tank - Totco Wits Feed Mud lo in unit cam uter s stem Cam ac Pentium 111 - Geolo ist's workstation Com ac Pentium III Totco Warkstation Compan Man's workstation Com ac Pentium 111 - Totco Warkstation Tool usher's workstation Com ac Pentium III - Totca Workstation DriUer's workstation E och Azonix Touch Screen Class I Div II - Totco Workstation ~ ~ ~H ~3 ConocoPhilhp5 Tarn 2L 327 1.2 Crew Unit Type : Arctic Unit Number : ML012 Mudtoggers Years "~ ~Ys On Pad Geotechnicians Years Days On ~ad Technician 7rainees Lees F. Browne Jr. 26 20 Dan K. Hillegeist 1 20 Mark BiBtting 1 20 Mainuddin Chowdhury ~ 20 R' Years experience as Mudlogger Additianal Comments Two spare poly-flow gas lines were run through a heated umbiiical to insure non freezing for the gas lines and rig air lines to the unit. The QGM gas trap was routinely cleaned of drilling mud and the gas lines blown back with rig air during connections and bit trips. Pump Pressure was calibratsd retative to Totco. 81ock height was recalibrated to ensure accuracy after every cut and slip, and after casing runs. Calibration of Gas Detection and Chromatograph was checked and recalibrations pertormed if necessary ta confirm accuracy. Calibrations on all equipment held extremely well #hroughout the well. • ~ E~H .4 ~ C~onocc~Philiips Tam 2L 327 2. GENERAL WELL DETAILS 2.1 Objectives 2L-327 is a planned producer in the Bermuda interval of the Tarr~ field. This is a ciose offset weil to the pilot hoie (2L-309} drilled in ear~y 2008. The well design consists of a 9 5J8fl surface casing, 7~ intermediate casing top set above #he Bermuda pay interval and a 4'h" cemented production liner. Po#ential risks are reservoir quality and thickness, lateral continui#y and pressure support from offset injectors (which should be shut-in prior to spud of the well and remain shut-in until after the Bermuda interval is cased off}. Additionally, close monitoring must be main#ained on the degree of circulation in the show zone, as the pilot well had issues with washing out. • ~ ~ ~~u ~ ~~~~~q~ 7arn ZL 32? 2.2 Well Summarv Well Weli name A~E Classi~cation Exploration Block N/A Rig Name 1 Plordic Qrilling! Land Surface 226' FNL, 894' FEL, KB Eievatian 14T AMSL KB Elevatian 30' Type Nordic #3 Ca-Ordinates S 22, T10N, R7E, UM Primary 7arget Bermuda T-3 Primary Target 6,056' MD/ Secondary ICEBERG Secondary 5,862' Depth 5,191' TVD Target ~-_q, Target Depth MD/ 5,017' ND Spud Date 5/30107 TD Depth 6568' MD/ TD Farmation C-35 (K-3) TD Date 6/11/07 -6421 SS ND Compistion N/A Suspension N~A Days Drilling 13 Days Testing N/A Status Date Hole Maximum Depth TD Formatian Mud Weight Deviation Coring Gasing Shoe Depth FI7 Section MDRT (~) NDSS (ft) (ppg) f°inc~ / Liner MDRT l~l TVDSS (ft) (ppgl 12.25" 2075' -1928' C-85 1 Q.1-10.2 37.72 NONE 9 5/8" 2550' -2403 15.5 8.5° 5980' -5833' T-4 9.7 25.52 NONE 7" 5970' -5823 15.6 7" 6568' -5501' C-35 12.0 25.02 NONE 4,5" 6560' -5493' - ~ ~ ~CH ~6 ~ CortoCO~P'hillips Tarn 2L 327 Additianai Comments: Epoch commenced logging the 2L-327 on 5/30107 at 80' driiling ou# of 16° conductor pipe, tagging ice at 32'. Samp(es were caught at 50' intervafs to 6030' (100'above the Bermuda formation}. Gas bags were callected at 500' interv~ts and at gas kicks to a depth of 59Q4'. Sample catchers were used throughout the we8. Isotubes were collected in 30' in#ervals s#arting firom 100' above the Bermuda Formation {6050'} and a 10' sampling program was started with ditch cuttings. Drilling commenced at 0.19° drifling with a mud motor. The inciination was brought down to 37.72° by 2575' (surface casing). T~e inclinatio~ was held to 524fi', in which angle vvas dropped to 25.52° at 5902'. The inclination was increased to 28° at 6073' and slowty dropped to 25° at total depth. No hole problems were encountered drilling the surface hoie. Permafrost gravel caused minor probiems with the gas trap, with gravei being caught in the agitator spindles and breaking off one of the three spindle prongs (440' to 600'}. The spindte was repiaced and driiling commenced under the Permafrost and again gas trap problems occurred wi#h massive thick clays plugging off the gas trap and overloading the possum belly {800-200p'}. Rig crew hands were consistently washing down the shale shakers to enhance sample recovery and keep from losing drilling mud fluids off the shale shakers. Running sands and ~ gravel were limited in scope with maintained mud parameters. Sample Catchers checked and cleared #he gas #rap of clay accumulation at ~ach sample interva(, and whenever a change in gas or Irtho(ogy was noted. Gas hydrates tiows were limited to a maximum recording of 243 units with mud weights between 10,1 and 14.2 The mud system was swapped from Spud mud to LSND at 2575'. No hole problems wrere encountered while driliing from 2575' to the top of the Bermuda (Intermediate Hvle Sec#ion}. Good hole cleaning techniques were used driiiing #he deviated hoEe with high viscosity sweeps and good flow rates. Each c~nnection allowed c'rrculating time to clean the hole of cuttings above the BHA. All hole tr~ps showed no drag or sticking. Slower #rip and connection speeds prevented swab/surge damage #a #he hole. Good maximum ROP effective rates were ob#ained to clean #he angled hole with assistance of using torque and drag trends, ECD and shale shakers produetivity to establish a clean hole baseEine. The production ho{e section drilled with no hole or driiting problems. Na lost cireulating or hole sticking was encountered. The drill string was kept moving whenever {~ssble to avoid sticking. The ROP was controlled to 50 fflhr to record good ditch cuttings thraughout the produetion zone. Additionally, care and attention was taken to avoid over washing. u r~ ~nnr,u 7 Conoc~hillips Tarn 2L 327 3. GEOLQGICAL DATA 3.1 Lithostratiqraphv Drilling picks & actual wireline taps refer to provisionaf picks provided by the wellsite Geologist. FORMATION PROGNOSED DRILLING PICK ACTUAL WIRELlNE PICK HIGH/LOW MDRT (ftI TVDlTVDSS t~} MDRT (~) 7VD/SS1VD (~) MDRT f~) TVDSS (ft) ~~~ Permafrost 1154' 1150'/-1003' 9 5/8" Casin Sho~ 2571' 2400'/-1253' 2571' 2392'/-2245' -g` C80 K9 0 2643' 2457'/-2310' 2670' 2469'l-2322' +12' Camp Sand NA NA 2740' 2524'/-237T NA C50 4238' 3717'1-3570' 4274' 3738'/-3591' +21' C40 4731' 4107'/-3960' 475?' 4117'/-3970' +10' C37 5054' 4362'/-4215' 5075' 4365'I-4218' +3' T7 5565' 476T/-4620' S575' Q76T/-4620' 0' T4 5970' 5112'I-4965' S862' 5017'/-487Q' -95' 7" Casin Shoe 5964' S080'/-4933' S970' 5114'/-~967' +34' T3 7op Reservoir 6064' S197'l-5050' 6056' S191/-5044' -6' T2 Base Reservoir 6241' S357'/-5210' 6238' S357'I-5210' 0' C35 (K-3) NA NA 6348' 5448'/-5301' NA TD 6561' S647'/-55p0' 6568' S648'/-5501' 1' ~ ~ ~~H s8 ~ COnOCOPhillips Tam 2L 327 3.2 Mudioa Summary The following text provides a brief summary of the defining lithological and driliing characteristics for that part of the well, over which dril! cuttings were coilected. Surface to Surface Casing Point 80' ta 2575' MDRT ( 67' to -2428' TVDSS) The 21.-327 was commenced on 5J30/07 from surface. Ice was tagged at 32' and formation was encountered at 84' as drilfing progressed under surface conductor pipe. Mud weight was 9.6 ppg at surFace with an increase #010.1 by 1900'. Surface casing was run to 2550'. FiT was run with an EMW of 15.5 ppg. Trip gas of 18 units was recc~rded after the Leak Off Test. Samples collected from surface to the top of the permafrost were predominantly coarse grain sands {canglomerate} with heavy thick clays. The clays composed of clay and claystone being light gray to medium gray and very soft. The overal! consistency and tenacity was malleable to sectile when cohesive, lumpy to clotted to gelatinous to slimy overalL Clays exhibited moderate to good cohesion wi#h very ~ good adhesion. There were no visible structures with a rare si{ty te~ciure. Sofubility was fair to moderate with moderate expansion and easily hydrated. Abundant pebble conglomerate was collected from roughly 400' to 800'. Lithologic color was very light gray to tight gray and seattered Gght green to dark brown and various hues o# aIL Glast size ranged from pebble (possible cobble} to very coarse with scattered medium to lower coarse grain as matrix sands. Cuttings where abundantly angular with bit impaction, with sub round to sub angular matrix sands dissemina#ed throughout. Most sands displayed low to moderate developed sphericity with very poor sorting and a general polished texture with pitting to impacted textures in matrix sands. No visible cement was noted and samples appeared to be of sub rnature nature. Ma#rix materia! wras very slight to non existent. Cuttings contained greater than 50°l0 lithics with fair ta good estimated porosity and permeability and no show Qf oil. Conglomerate sands graded finer downward to a coarse grained sand towards the base of the conglomerate zone (550' to 750'j. Sands were yellowish gray to light gray becoming greenish gray at fi80', Clast size ranged from coarse lower to medium lower and be'rng sub angular to sub rounded. Sphericity was low to mc~derate with rare discoidal artd triaxial grains at 630'. Sorting was modera#e with impacted and pitted textures as common. Sands were of mature nature and having a non #o very weak silic cement. No visible matrix material was noted with daminant grain suppoct. Samptes appeared arenaeeous and camposed of 9Q°to quartz, 10% chert, greenstone, igneous, metamorphic and various lithic fragments. Sample contained 30°lo greenstone at 680'. Porosity and permeability was good ~ wi#h no oil indicators. Samples below the permafrost tap of 1154' were predominantly clay and claystone. Cuttings became very thick and clumpy plugging the passum belly and gas trap with thick, r~ ~nnru 9 ~ ~~~~~~ Tam 2L 327 extremely cahes~ve and adhes~ve cfay-rfch sed~ment. Samp{es were very homogeneous showing a iight gray to very light gray eolor and being very soft to soft. Cu#tings displayed various consistency and tenacity throughout the lower zone being: malieable to sectiie, mushy to pasty, tacky ta siimy with slight to moderate cohesiveness and moderate adhesiveness. The clay fracture was amarphous with a massive habit and a moderate earthy luster. Texture was dominantly clayey with massive homogeneous clay composed of greater #han 94°lo clay with minor silt, very fine grain sand, pyroclastic relic shards and variaus de#ritaf materials. Overatl a clean c{ay. Dril1 Rate ftlhr} Tatai Gas (°~) Maximum Minimum Avera e Maximum Minimum Avera e 700 11 142 243 0 8 Surface Casing to C-80 2571' to 2670' MDRT ( 2245' to -2322' NDSS~, Samples consisted of 90% to 100% light gray clay and claystone being very soft to soft. Consistency and tenacity were variable: malleable to sectile {becoming flexible in parts), mushy to pasty with some clustered to clotted, tacky ta slimy. Cahesiveness was slight and adhesiveness was moderate. Overall, clays exhibited an amorphous fracture ar-d massive habit with a brigh# earthy to velvet lus#er and clayey #e~cture. Overall a massive homogeneous clay bed composed o# greater than 90°lo clay with minor detritaf ma#erial (silts, carbon specs and relic shards). Overali a ciean clay. Drili Rate (ftlhrj Total Gas (°~} Maximum Minimum Avera e Maximum Minirrtum Avera e 487 28 9~ 49 8 34 c-so to c-sa 2670' to 4274' MDRT (-2322' to -3591' NDSS) The C-80 succession is generally a claystone with secondary minor silts. The claystone is yelfowish gray to becoming light gray and variaus l~ues of both. Overail soft to very soft w+th various consistency and tenacity: malleable to sectile (same flexible in parts}, mushy to pasty, some clustered to clotted, tacky to slimy with a slight cohesiveness and a moderate adhesiveness. The #racture was amorphous with a massive habi# with moderate earthy #o velvet luster and clayey texture. Overall a massive homageneous cfay bed with minor silts and composed of greater than 90°lo clay and minor detrital material. Towards the base of the C-80, siits#ones are roughly 3Q°lo o# the samples and are pale yellowish brown and some light gray and variaus hues of both. The s`rlts display very poor ~ induration with some becoming crumbty in micra cutt~ngs with an overali mushy to pasty consistency and grading to claystone. Most cuttings display an amorphous fracture and a massive to sligh#ly sub nodular habit. The luster is dull earthy with silty to clayey to ashy r-~ ~nnr~u ~ c~ ~ ConoCOPhillips Tam 2L 327 textures. Overalt a massive gradationa{ silt and clay sequence composed of 70°lo sitt and 30°!o clay and various minor detrital materiai Drili Rate (ft/hr) Tatai Gas (% M~imum Minimum Avera e Maximum Minimum Avera e 224 26 105 122 1 33 C-50 to G-40 4274' ta 4757' MDRT (-3591' to -3970' NDSS~ The C-50 is composed of an upper c{aystone and a lower siltstane which is a gradation sequenee with common interbedding. The upper clays are ye!lowish gray to very light gray being very soft with various consistency and tenacity: malleable to slightly sectile, clustered to clatted and mushy to pasty. Fractures are noted as amorphaus with no distinct fractures and ccmtain a massive habit with an moderate earthy #o velvet luster and a clayey to ashy texture. Qverall massive homogeneous clay with in#erbedded silt composed of 80°lo clay, 20% sil# and various detrita! materials with a general cleanness. The lower silts are Iight gray to medium tight gray with brown to yellaw browr~ hues. Cuttings are moderately indurated with blocky to irregular habits with rare sub tabular cutt'rngs in ~ parts. ~uster's are dul! and earthy to sub vitreous. Samples display predominantly equig~anular quartz with acicular melanocratic micas and rare carbonaceous material. Silts grade into very fine grained sandstone to caarse sized silt with a sub sucrvsic to gritty texture that is weakly abrasive. Fractures are irregular to hackly. When grading into clay the matrix displays low expa~sively with moderate to low solubiliiy wi#h no visible cement fraction. Predominantfy silts with very poorly differentiated sandy siltstone interbeds. Drill Rate {ftlhr Total Gas {°~~ Maximum Minimum Avera e Maximum 1Vfinimum Avera e 181 15 104 513 9 32 C-40 t0 C-37 4757' to 5075' MDRT t-3910' to -4218' NDSS) The C-40 interval is represented by sequences of silts#ones and claystanes with thin bedded sands. The siltstones are composed of light gray to medium light gray colors with browrn to yellow brown hues that are moderately indurated with blocky to irregular habit with rare sub tabular cuttings. ~uster varies from dull earthy to sub vitreous wi#h predominantly equigranular quartz with acicular melanocratic micas ~nd rare carbonaceous rrtateriat. The sitfis grade into a fower fine grained sand to coarse silt giving a sub sucrosic ta gritty texture and ~ weakly abrasive. Fractures are irregular to slightly hackly with no visible cement and poorly differentiated sandy siitstone interbeds. The gradational clays are light gray to medium fight gray with pale brownish hues being soft to very soft and various consistency and tenacity: lumpy to clumpy some tacky and sticky, a ~nnru ~ ~ COnOCO~Phillips Tam 2L 327 ~ clustered to clatted, some gelatinous, mushy to more commanfy pasty. 4verall, mafleable to ~arely se~tile with increasing eohesion writh moderate #a goad adhesian. Fractures are amorphous and commonly gritty from suspended disaggregated sil#stone and very fine grain sand. Luster varies from duii and earthy to rare sub vitreous ~long fresh fracture surfaces. Sampfes display moderate to weak solubility with low expansivity and are m~lerately easily hydrated. Driil Rate ftlhr} Tata! Gas °~6 I~taximum Minimum Auera e Maximum Minimum Avera e 3$5 57 116 67 10 24 C-37 toT-7 5075' to 5575' MDRT ~-4218' to -4620' TVDSSI The C-37 sequence disp[ayed gra~ational siftstones and clay. The sittstones are very light gray, brittle, very poor to poor induration, crumbly, lumpy to clumpp, clustered to clotted with some being mushy to pasty. Fractures are amorphous v~rith a massive habit with ea~thy lusters. Textures are silty to ashy wi#h massive grada#ional silts and c1ay. The claystones are very light gray and very soft to soft, malleable and sectile to some being ~ flexible. Overall mushy to pasty clays, #acky to slimy with sligh# cohesiveness #o moderate to very adhesive with amorphous fracture and massive habit with a moderate ear#hy to velve# luster with a clayey to ashy texture. Qverall massive homageneous clay composed of 8Q°fo c{ay, 20°lo silt and various detrita{ materials. A thin 10' sand bed is noted at 5338' to 5348' in which 261 units of gas was recorded over a background of 15 units. The sand was light gray to medium light gray with cEast size ranging from very fine grains to very coarse silt. Sphericity is good to very good with sub rounded to rounded grains with no visible cement or ma#rix. Mostly disaggregated and moderateiy to very well sorted. No visible fluorescence or oil cut. Drill Rate (ft/hr} Tatal Gas (°,G Maximum Minimum Avera e Maximum Minimurr3 Avera e 192 20 120 261 6 2'! T-7 to T-4 {Iceberg) 5575` to 5862' MDRT (-4620' ta -4870' TVDSSI The T-7 interval dispiayed c#aystone and sil#stone Sayers ail very gradational and becoming interbedded. The siltstones are light gray to medium light gray with a trace of yellowish gray and are all ~ very poorly to moderateiy ir~durated. Cuttings are brittle to stiff with increasing s#iffness with depth. Varying consistency and #enacity throughout the silts: lumpy to clumpy to stiff, amorphous fracture to sub planar along stiff silt pianes, massive to increasing sub platy habits with earthy lusters. Textures are silty to ashy in gradational beds of stiff siltstone and ~ ~~nr,u ~ ~ ~ ~~~~~~ Tarn 2L 327 silty clays with a trace of m~crolam~nae of carbonaceous clay. The clays are very iight gray and very soft displaying varying eonsistency and tenacity: lumpy to clumpy, clustered to clotted, mushy to pasty and being slightly cohesive to moderate adhesive with an amorphous fracture and massive habit. Lusters are earthy to velvet with silty to c4ayey textures in gradational beds of silt and ciay. Drii! Rate {ftthr~ Totai Gas °~ Maxirrtum Minimum Average Maximum Minimum Avera e 269 25 '! 15 34 8 17 T-4 to T-3 (Top of Production) 5862` to 6Q56' MDRT (-4870' fo -5Q44' TVDSS) Intermedia#e 7" casing was run to 5980'. l.eak OfiF Test was ~ 5.6 ppg. Ten fioot sampies caught from 6060'. From under casing cement, samples were mushy clay and sand as per sha!lower sections. The sands were very light gray with a clast size ranging from fine iower #o very fine lower and a few scattered coarse lower grains ali being sub round to sub angular with moderate develaped sphericity and slightly bimoda{ with very fine grains and loose rare coarse. ~ Sorting is moderate with impacted very f ne grains #o sub round coarse grains. Sands grade #ram sub mature to ma#ure nature with non #o very weak siiic cement, Sands display both grain and clay matrix support with poor to some fair visible porosity and permeability. A trace weak sample fluorescence is noted but no oil cuts at fi040'. Drili Rate (ft/hr) Total Gas (%} Maximum Minimum Avera s Maximum Minimum Avera e 17Q 11 86 74 9 29 T-3 {Bermuda} to T2 (Base Reservoir) 6056' to 6238' MDRT ~,5Q44' to -52'!Q' NQSS~ The Bermuda reservoir was topped at 6056' with the rate o# penetra#ion cantrolled at 50 ft/hr to achieve maximum return on ten foot samples. Samples were eirculated out at 6060- 6074', 6086'-6100' and 6112'-6120' in which a gas kick was noted at 98 units over a background of 35 uni#s. Samples comprised of sandstone and secondary sands with minor clay and ash. Drilling progressed through the pay zone with 12.0 ppg mud. Numerous gas spikes were recorded throughout the pay zone with an average background of over 804 units with a maximum of 1615 units. Sample comprised of sandstone and sand: very fight gray with clast size ranging from very fine upper #o very fine 4ower and mostly sub rou~d with maderate developed spher~city and fair sorting. Textures were p+tted and sub mature in nature with nan to weak silic cement with scattered loose sands from weak consolidated sandstones. Ma#rix materia! of clay and ash was sligh# to moderate in parts displaying s#ratified sands#one layers as evicient by the r~ ~nnru ~ ~ ~ COnOto/Pf~tii~lips Tam 2L 327 sp~kes in th~ gas. Sands were predom~nantly gra~n supported with secondary matnx ~n locaf beds. Sands were argiiiaceous overali wi#h some avergrowths. Porosity was fiair and poor permeability was noted in par#s due to overgrowth te~ctures. Most sands displayed 80°lo to 100% bright yellowJwhite even to patchy sampie fluorescence with pin point oil noted in tt~e drilling mud and samples with a faint light brown oii stain. Degassing from clayey sandstones was noted in the majority of samp{es. A moderate petroleum door was noted in the shaker room, the cuttings bucket, and in the logging uni# as the samples were dried. Also noted were ~floater" sands covered in oil in the sample trays. Sands#ones were cut and displayed an instant cloudy moderate blue/white fluorescent cut with a slow increase ta a milky moderate blue/white fluorescence. A faint strawr visible residue stain was no#ed. Good sample fluorescence was noted in the samples fram 613Q' to 6230' in which the fluorescence drapped to 30% by 6245' and progressivefy decreased with con#inued drilling. C-1 through C-~ were detected throughout the pay zone. Digital pho#ographs were taken of representative lithologies far 10' sample intervais between 6920' and 6230'. Samples before and after this range consisted predominantly of claystone with rare siltstone and sand obscured by the thick, adhesive clays. Qrit! Rate (ffJhr) Total Gas °k} Maximum Minimum Avera e Maximum Minimum Avera e 81 3Q 56 1615 13 473 ~~ ~\ U Fl ~1~(1(~'T~ 1 4 . ~~~~~~PS Tam 2L 327 , ConceoPhillips '~1- ',I~ ~ Tarn 2L-327 t ~ ' _; ~ ' ~~ ~ ~ Nortfi Slope Borough, AK + r• API# 50.103-20542-00 `~~ ~. . ~ ` , . ~~ ~ .~ , ~ ,~` ~ =~ ~ - _~ N . » -- , +~ . ,'~ ~ '. ° , . . _ , . r' " ` . ~ ~ ~ ~M ~ ~ .. ~ -~ ' y ~ . ~ ~'~ i .~ ~ ' ` ' '~ + ~ ~~~ . y ~ ~' ' . ~ ~i~± *.~• ~~~ ,~ ~ • •, v . ~~ ~ I a• • }~ .. . r •~ ;~ ' ,` • ~i.*+ . ' b ' ~ i '` ' :~.~ ~ i. 4 ` ~'~~' y' `` , ~ ~ ~ ~ ~ ~ ' ~ ~~ • ' ~~~ ~~ • f ~ w ' , ~~ ~ *S ~r . ..r~ .~ ~' ~ ,~ .. ...ff. „~ ~ ~~ ~ ~ ~ a ~ ~ ` yr • n , r'=i y ° • E~ EPOCH ~~ 30+ ~ +~ ~ ~ ~~~~ : ,: j ConocuPhillips ~ A ;,~ - , `', '' Tarn 2L-32T ,~. s'` "~ ~~ ~ North Slope Borough, AK • ~ ~ ,k . API# 50-103-20542-00 + ' ~ 1- ? ~ ~" ' , . ~ . . ~s r, s; ~ ~* • " , : N ,s ~ R 's, a - ~ . 1 ~ ~e . ~. ~ ~ . . ~ ~ ~. ~" l ~ - _ ' rt 4 t . ~-. ~ . ~ , : -~G: ~ ° ~~ . ~ ~ ~- ~ :. ~' : • ~- ~~ ~ ~ ~ t ~ `~ `~. . " ~ f ~ ' ~ "' ~ 'j1 . . ~ ~~y ~S ~~ ~ ~ _ ~ ~,. .~ ~ ~ t r ' . . ` ~ ~ C}'• ~ Y ~ a ` ~~ ~ ' ~ o R„~.~~ ~"` ". `~' ~ . . ~ + , . *'~~ . . ~ - . ~ ~ ~. 7wm ~ ., . +~`r~ ~~, . . an o~ e.n ~ + ~ " ; ~' ~ ~ ~,_ . ~~ EPOCH ~ r~ Fnnru 1 5 ~ ~~~~~P' Tam 2L 327 ~ ~ >;~ i~~ ~:~' ~C; +~: ~ ~ ~~ conocoPnillips ~~ ~~ ~; '~'' ' . ~,- ~' Tarn 2L-327 t ~ ~ ~~ ~, ; w ~ ~'~` ~ North S{ope Borough, AK ~ ~ ~ " ~,~ ~ ' API# 50-103-20542-00 .~;~'D~' ~ . ~. ~,~ ' ~'` ~~' ~ . ~. , ~ ,, ~ '~` ~ ~=" . , ~, , ~ ~ ~~: . ~ ~ ~ ~~ ~ ~ a~« . -, . ""~ ~ ~, ~ .•~ ~r: ~~ . ' ~_ ~ ~-. ,, ~~ f ., - p ,Y~ ~ ~`• ~ .~~. r ,~ ~ ~ +~'^. c~I ~ ~' " ~; ~' "~" ' , ~Is '~! , .~' k ~, ~ ~ii ~ ~ ~ , ~ ~' ~ -~ ~,.~ _ _ , ~r . ~, ~ ~. ~ "~~ .~~~ ~a d ~. ~ ~ ` ~ _ ~ ,:~ ~ `,• `~ ~'~ ~ ~ ~-~~ ~~-~ ~-~~ ~~~i4 c :' n~ °~.~r ' ~'. ~ - ,y~ ~~i,. ~{ _aJ ~ ~'~J i+~. . ~ `~ ~ ~. ~ ~ ~ +~+, f. ~ ~ ~Y w,~ ~~ ~ ~.. ~rt,•~ , ...~ ~ +~:''"x +~ ' , ~ i ,. - ~:~.. ~~ -~ ~- ` ~ .~: ~ ~• ~p ° :.~ ~, ,.a` ~ . , ~,~ . . ,~ sa sy e.r~ l ~~ ~ ` . `, , _ , ~,'° ,~ r,,,, ,rx . .~~ , ~~ ~P~CH .-~ W~ ~ ~ • ~ ~ ~ ~. - ~j' ~~` ~. - ~:~ ~~ ~: ~ > ~~ ~ ~ ~ .'~'< f ,~"`~ ~r ., ~ f"~ : l~`y~~ ` + i ~~' ~ ~ y 3 .~ ~} ~ ~~ ~ _ ~ ~ : ~ ~ ~ y , • ` ~:.t~- ~~ •.~ •~j ~ ~ .~ ~ ~ . r- ; ,~,~,f . ~ , ~" , ` `~. ''- *~i, Fj ~ .~ , !- . '' r`' ~~, ~~'''~ F~`~' ~ ` k~4~~~ `~ ~ .; ,~,. ~ ~ ~ ~ ~ ~ ~ _~ ~ ~ . ~~ ..;-~;~ ~ ,~` r '~ ~ ~. ~` . ~;+ , ~-_ ~~ : '~ ~ . , + ~ ., +„~ w .~,,~,~ ~ ! ~ S ~ ;~' .,~ y~ 4'~'~` ~" ..1~'~', ~ ;~ ~ ~ ~ x ~ . . ~ ~~ 2 • ~ ~ . e' ~+ t • ~ ti j , ~ `,, , ':~. ` ~`~ ~ ,~~~ ~. ''~..'~'"`.~~ 1 mm ~y. , . ~ . ~, ~~ - . ~ uss esu a~s . " - ' * . . ~ ~ ~ - - ~ a . . -~ ~ . . L•'r' ,~r ~ ConocoPhillips ,~~ • ; - ~, ~ `'~.` Tarn 2L-327 ~ North Slope Bo~ough, AK ~Y~ ~. API# 50-103-28542-00 '~, ~` ~, ! `~ ~. - ~ ~` q ~' '~ '~'~ ~' ~` ~ ~ ~ , '~ ~ ~ ~~ z~ ~ ~ ~ : ~ ~' ~ a„ . ~ : • , ~N~~ ~~ ~ ~Y ~ A Fnn~u ~ h • • ~ ~~~~~PS Tam 2L 327 ~~~:;~ , ~ ~, ~ ConocoPhillips ! , : ; ,r ~ Tam 2L~327 ;/~• ~° ~• ~. North Slope Borough, AK ~ . , r ~ ~ ; u ~ . , , ~, ¢ '. API# 50-103-20542-00 ~ ~ ~ `°4 ~ '~ , :, 'n'~=` + ; ~,; A ~ eY ~+ ~ •.e~ r . ~ ~' , .,~[ _ Y"Y ~-. ~ ~ ,# ? ~~ ~ . ,- ty ~`y. ~ A' r J, ' +, ~~ . y ~ ~ ' ~ ~~ ~~'~ " ~ ~ . f ~ ~ ~f ~ . . ~ . .~ ~• ~~~ ~ ^ 4 ~~~ ~~~~ r~. F ~,- -"~ , ~ I ~~'~ .a ` , ~-~~, ~~ ~ . '~.;- •~.!' , ~'`~ ~'j '~ ~ , ~ ., $- ,. ~: r- • ~° • ' ~ '# ~ ~ . ,~ ~;r„''~=~ ~~ :a "~~ ~. ~~ ~~ ~ ~ ~ ~~ • ~ ~ ' ,~ , : ~,,~" ~w „. ' `'~ ~ ~~. : "- `°. i ~. . ` ~ ` ~ ~ ~ >. ~- . . ~- t~ ,~ ~„f~ .~ ~' ~ss ..s~ .n . ~ ~~ ~~'.~ ~" t E~ I;1'OCH ~.~ ~ -~,, » ~ ' ; ~' ~ y ' ~ ~` ConocoPhillips '' ~ ~ ~ Tarn 2L-327 .~ '~: " ~~ ~~ `~` ~`~ r •~ ~,North Slope Borough, AK ` ~ ~ -~,~ :~~~ , ~f 'API# 50-103-20542-00 - '+~ ~~; - . ~ . ,.~ - ~~: , t, '~ ~` , ;~ , ~ ,~- #~~ ,+a,.~ ~ '~ . ~°~"' ' ~ y ~ '~~.. ~~,~ _' ~ . ~ ~ "~j~y ~, ~ _ . s 'i ~ ~„f w r ~ ' ° '~' ~ , ~" ,~` ~ ~,. f . ~ . ~,,.~,,a ,. ~... , . M i ~ ~ ~ r~ +! ~ . a'E ~ a ' / •.-~+t~~ ~ ~ ~~' ~~~ .. .... `~~ ~~~t. , +'~ RT ~ # !, i ~ ~ ' ~~ ~ ~ I~ "~,~ :..~` ~„'~`~ ~ ..~r j ~ ~ '~' + .- ~ ~' , .`r~ w ;. ,~ ~ f ~.° ~ ~ y ~ R~~ • ~~ ~. + .~~~ !,. ~ y ~+` K r~~~ ` ~ • r ~ ~1'~~ ~ _ t J " '~`~' ~ '~'~ + "!~„~ ~ ~}~ t ~ G~ '~,.~". __ ; ~ * • ' ~ ~* a Y ~'~ ~ ~s '~ ~ , . ~t ' "J~`r .'E , ,~ t , ~ ~ ` ~,i ~- ~ ` +1 ~ } ~ ~. ~ ~ ~~ , ~e~ '~- _ ,•' ~ ~ . ~~' _~ y-~ ~ ' ~ ~_ ~, ~ F ` r t mm ~ ~ ~ ~ ! ~ ~~ ~:' ~, ; - ,j . ' .• ~ ~ on o3o an 4 ~-.,~ ~° ~, '°~ . i„ ~~..~; ',~' ~ ~,d~. Q~+ ;E~ EPOCH~I ~ c-~ ~nn~u i~ • U • ~~~~~~PS Tam 2L 327 ~ ~8,~ , ` ' ~ ~'~ `~~. +4 , y ` ConocoPhillips , ~' ~ ~ Tarn ZL-327 - ~~` North Slope Borough, AK ~ ~ ~'~ . ~ ~ "~ . .~.'' ~ ! API# 50-1 U3-20542-QO ~-~~~ ~~ ..~~i'' ~ ~ _. . ~ ' - {~ ~ ~•. ~ ~ ~ ~~~ ~ - • ~`.~..'- ~ ,~~,'. ' ~ ~ ~ ~,. , ~.' f ~ , ~ ~~ • j~ M . ,Ili ~!~'~ +~ ~ . +! r: ^ sIP. . „ ~ ~=.. ~ ~ /M~ • f ~ ' ' .. • ~4!f r~ . : +~ ~' ~ t.~'~ ~ '~~ - ~P~~. _ ~ . ~ ry~ r ,~ . , ~ ~. ~ - . ~``,~ ~ ~ _~. `.~ ~ - t . ~ ~ ~ . . `' . ,~ ~, . _ > `~ + .":~` ~ ~_ '~ ~• ~,~b~_ r . .'~ ~ l ~ • b 'Y ~~'` ' '~ ' ~ ` , ~ ` ~ 'y~„` ~ , ~~' ~„ - s ~. • +4~~ ''~~' ~'~ ~ . A - ~j, ~_ y If~ T!6 , ~/~ ~ - ~ .. ~~' ~ ~ .~,,~ -~ , ,* ,~ ~ ~~ d ' _ ~`~ ~"'~-.~ ~ ~ ' ..~1~ ~ .~ .s ..~ ~-~ ,~; .~ ~ ~ ~++ E~ EPOCH ~,62~~~ + ~~~ ~"' ~ ~''~ "~- ~ . ~ ConocoPhillips . ~ ~ * ~} '~ ~ Y Tarn 2L~27 ~- ~ ~ ,~ ~ North Slope 8orough, AK ~' , IAPI# 50-103-20542-00 ~, . . ~ ~ ~,. ~~ -~ ~ - ~ ~'~ ~ • ~ • ~ ..~~ p s~~ ~ ~ ~~ ~ ~ ~ -`~ , ~ ~ ~ ~ ~, . ~,.'~, ~ ~~ ~ ' ~ t ~. . ~ y ~ L ~ ~~ 1~m 0.25 03e 0.T5 s 4 ~ ~ ~ F ~ ~* ~ a ~i. ~ . ~vy, . ~ ~. _ , ~i ~ .~ f ~ s ,'~ ~ ~ ~ ~ d ~ '~, ' .~`. - , . j ~~~~ ~ ~ w ~ ~~~ ~ ~ ~'' t ~ ~ .,,•' ~" ~ +~'A . , ~ ~ . ~.# '~>] ' _- Y~.. ^~~ ~ ~i~ ~•. ~.~~~~~+ . w~ fi ~nnru i~ • ~~~~~~PS Tam 2L 327 1~~~ ~ ~', ~ ,~ ~ ~ ConocoPhiliips ~~~~ ; f ;+~..~,~ ~;, ~ y Tarn 2L,327 ~•~ ik , ~, -• Nortfi Slope Borough, AK ~-"~ ,~ ~'~ API# 50-103-20542-00 .w +'• ` ~ + ~ ~+6 "' ~ ~ t ~, , ~ ~~ ~4 ~~ i l ' r, , - ~ ~,~- . ~ . .,~.~ .,, , , r' ~ ` ~ ~'aI s ~' f~ ~;~~ ~~ '~'~~ ~~~: - .:~ ,.~ ~,.~ ~,~y ra~ ' ~ ~ ~' , Y'~` } • ~ ~~' .~;~ :~ r'~ , i ~~ ~:. ~ ~~ ..~ # ~ ~ `~: ~..: ~~~: -: { ,~ ` ~` ~„ ~ ~ ~~ ~ ~ ~ ~~ ~ ~~~ ~ ~~ ~ . .~~ . ~ }L~~ ~ ~:- f 'g'~~ ~~ ~ '~ . ~' ~ ~ ~~ ""* " ~. k~ °~~ Y ~ , ~ ~, ~, - ;.'~ie ,N: _ • ~ ~r ~ > . °~ ~ ~ ~~ ~r~~ ,. . ,~";'~ ~r • ~ • ~ f~ ~i'. R • ~~ ~ . ~ - ~n o.w e.r3 1-,....'' ~' l'~ * ti. l~R.~` ~~' 1 ~'E~ EPOCH~ ~ ~. ,r: ~ ~'j~3tj' ~i'~. Y ~~l' ~ ~~~ ~ ConocoPhiilips ` Tarn 2L-327 4 ~ ~ °'~ ~ !North Slope Borough, AK 't ~ , { , :~ API# 50-103-20542-00 ~ s -f ~ ~ . a~ • ;~ , ~ ,. _ ~ ~~`'+~ ~~ ,~ w ~~ ~ ~ ~ _. r ~ *~, ~ . ~ ~ ~v ., ~c ~- ~.~.~ ~ ' ~ ~~ ~ ~ ~ so ~ _ ~ _ ~ r ,. ~~ . `.i t' ~. .~ j, . ,~ r b, t ~ r~ -~ ~ „~~ '~ • ~ ~: , ~ ,,~ . ~ h ~.'4 . :' ~'. H ' ' ~ ,. , ~-. '~r ~"` ~ ~ ,`~r" . ~` ~~ . ~ ~~ ~ ~.~t ~` ..~, . ~ .~~~ ,~~ ., ~ e ~ - r ! ~ ' r ~ ~ • ~ + . ,q. ~ ' /S ~ -• y '~ . j •1mm f~' ~~~ ~y~~ ~. i , ,% . ~ ~ o.~ a~ ~~ ~ ~ ' { . E~ ~ ~~. ~~' .,~ ~' ~.- , *~~ ,.{i' ~ Fi Fl~(1(-'T-~ 1 9 ~ C~oco~PhiUips Tarn 2L 327 T-2 (Base of Reservoic} to C35 {K-3} 6238' to fi348' MDRT ~,5210' #o -53Q1' NDSS} The T-2 is a sequence of gradational ciays, sil#s and diminishing sandstones. Background gases siowty decreased throughout the zone with the T-3 producing same gas and recycled background gas adding to the driliing background. The increase in depth brought about slow decreases in the background gases from 395 units to184 units over roughly 100'. A silty claystone dominated the sampfes. Very gradational with clays being yeilovvish gray at 6240' and becoming light gray at 6310'. All cfays and silts are soft and mushy to pasty, tacky to slimy with slight cohesion and moderate adhesion. Fractures wrere amorphous with a massive habit with moderate earthy lusters. The te~ctures were clayey to sandy with massive clays with interbedded very fine grained sands with no shaw o# fluorescence or oil cuts. Drill Rate (ftlhr) Total Gas (°~6} Maximum Minimum Avera e Maximum (Ul+nimum Avera e 79 30 61 395 184 282 C-35 {K-3) to TD 6348' to 6568' MDRT (-5301' to -5501' NDSS~ ~ The C-35 formation is gradational with clay, silt and very f ne grain sand and some interbedded sandstone. The silts and sands are very light gray to medium gray and moderatety indurated becoming brittle to stiff in parts {rare friable}. Some are mushy to rare pasty with a high degree of hydration in clayey sections (poorly soluble). Overafi showing a moderate cohesion with an earthy and hackiy #o sub planar #racture to poorly developed bedding planes along stiff silt sectians. Textures were silty ta some granular with du1! earthy to sub vitreous lusters. No associated oil indicators. Scattered to common modera#e orange pink #o very pale orange to pale yellowish catcareous ash/tuff, which are very friable, crumbly and poorly consolidated. Drill Rate (ftlhr Total Gas (°~6 Ma~cimum Minimum Avera e Maximum Minimum Avera e 303 14 79 222 23 128 ~ ~ Fl F1X1f`T~ ~ ~ ~/~~~~~PS Tam 2L 327 EPCa~ I-~ sxow ~POR~ r~o . 1 COMPANX ConacoPhillips WELL# Tarn 2N-327 LOCATION Narth Slope Borough, AK DEPTH INTERVA~: 6118' TO 5225' (MD) TOTA~ FTG: 10T 5246' TO 5340' {TVU} BIT tNFORMATtQN: BIT TYPE: HC PDC BIT HOURS: 12.5 (totaq AVERAGES: BEFORE~ ~ DUWNG AFTER MAXIMUM ROP (fphj 50 (caretral drili) 50 (controi dr'rllj 50 5B WOB 10 14 15 19 RPM (with mud motor) MUD WT OUT 12.0 '12.0 12.4 12.0 CHLORIDES 800 800 800 800 TOTAL GAS 35 950 240 1615 ~1(ppm) 5509 32580 18969 39031 2{ppm) 361 15089 2806 19276 C3(ppm) 209 12722 2830 18673 C4(ppm) 34 6877 22Q3 12402 C5(ppm) 26 2516 4133 5131 Light yellowish CUTTFNGS FLUORESCENCE°!o: 90-100% COLOR: white Instani cloudy moderate blue- white wl slow incr INTENSITY: Bright even to pafchy CUT: to milicy white MUD PLUORESCENCE: Du11 green: possibie from mud chemicals (under UV light FORMATIpN DESCRIPTION: Sandstone 7Q% Sand 20% Clay + Ash 10°l0 ~ Sandstone/sand = very light gray; elast size ranged fram very fine upper to very fine lower becoming slightly fine fawer towarcls the base; sub round ta sub angular, moderate develaped sphericity; fair sorting; pitted #o impacted textures; sub mature #o mature nature; non to weak silic cement (loosely consolidated); slight ta madera#e claylash matrix in parts; predaminantty grain support with secondary loca! matrix support; fair visibfe porosity and permeability {poor in focal beds}; >90°1o bright yellowish white even to patchY sampfe fluorescence; pin point oil in mud and sampfes; faint ttght brown visible oit stain; visible degassiRg breaking out in sands wi#h matrix material; maderate "sweet" petroleum odar from shaker room, dri(fing mud and sample cuttings; instant cloudy moderate blue white fluarescent oif cut with a stow development to r~ Fnnru ~ ~ ~ ~/~~I~PS Tam 2L 327 milky moderate blue white fluorescence, faint s#raw residue stain; some °ffoater" cuttings; Moderatsly argillaceous and scattered overgrowrths. LOGGING GEOLOGIST{S): Lees F. Browne Jr. ~ ~ r-~ Fnn~u ~ ~ ~10COPhiII1pS Tarn 2L 327 3.3 Samplin_g Proqram / Sampie Dispatch Set Type ! Purpose Interval Frequency Dispatched ta 1 Unwashed SWET~ gQ~ _~0~~~ 50' Bayview Lab 6050' -- B330' 10' ConocoPhiltips Alaska, Inc. Sox #1 {80' - 4230'} 6~~a~ _ 6~~~~ 50' 619 Ship Creek Ave., 5te. 100 Anchorage, AK 99501 Bax #2 (4230' - 6568') Attn: D. Przywojski (907)-263-4859 Bayview Lab ~ Washed screened & dried 80' - 6Q5Q' SQ' ConocoPhillips Alaska, Inc. Dry Sam~les 6050' - 633Q' 10' 699 Ship Creek Ave., S#e. 100 6330' - 6568' S0' Ancharage, AK 99501 4 Baxes Set A Attn: D. Przywojski (90?)-263-4859 ~ Washed screened & dried 80' - 6050' S0' Bayview Lab Ory Samples 6050' - 6330' 1 Q' CanocoPhillips Alaska, Inc. 633q' - 6568' 50' 619 Ship Creek Ave., Ste. 100 4 Boxes Set B Anchorage, AK 99501 Attn: D. Przywojski (907)-263-4859 1 Gas Bags ~4~ _~ggp~ 50Q' ar gas ISOTECH LABORATORIES Bax "A" $0' - 5980' kicks 13p8 Parkland Court Champaign, IL. 61821 1 IsaTubes 6050' - 6561' 30' or gas kicks 217-398-3490/FAX 217-398-3493 One box of ~5 mail@isotechlabs.com Sample frequency was locally altered according to drill rate constraints. ~ ~ ~CH ~3 i ~ ~ U ~~~~~~~PS Tam 2L 327 3.4 Cali Bond Gas Baq Sample and IsoTube Inventory Gas Bag # De th Gas Units IsoTube # Depth Gas Units 1 680' 1 1 6050' 30 2 1180' 1 2 6080' 21 3 1314' 't 5d 3 611 Q' 40 4 1361' Ba Failure 4 6119' 89 5 1621' S6 5 6124' 215 6 2055' 12 6 6133' 80E} 7 2516' 17 7 6146' 15Q0 8 3000' 64 8 6'i 70' 453 9 3500' 42 9 6198' 867 10 4000' 28 10 6230' S75 11 4500' '100 11 6260' 302 12 5004' 15 12 6290' 239 13 534d' 2b0 9 3 6320' 2'{ 1 14 5502' 19 14 6350' 184 15 5901' 16 15 638Q' 119 16 6414' 13'! 17 6440' 151 18 6470' 176 19 6500' 121 20 6531' '{ 02 21 6561' 103 r~ ~nnru ~4 ~ ConocoPl'tiilips Tam 2L 327 4. PRESSURE J F4RMATI4P1 STRENGTH DATA 4.1 Formation IntearitvlLeak Off Tests Equivalent mud weight {EMW) is calculated from ratary table (RT). MDRT (ft NQSS {ft) LOTI FIT ( pg EMW) FORAI[ATION 2600' -2453' 15.5 CS~ SH~E + 25' 6000' -5853' ~5.6 CSG SHQE + 30' LOT {Leak Off Test} in boid italics. 4.2 Pore Pressure Evaluation Introduction Trend Indica#ors The foliowing pore pressure parameters are considered to provide reliable indicators for pore pressure #rends during the drilling of this well; ~ Background Gas (BG) Connection Gas {CG} Trip Gas (TG~ Corrected D exponent {DXC) 1 Mud Weight (MV11~ Hole Conditions {NC) Wireline Densi#y {WDEN) Resistivity (RES} Sonic {SOId) Pressure Tests (RFT} ~~ ~ ~nnru ~ 5 ~~~~~~~ Tam 2L 327 4.3 Pore Pressure Summarv Equivalent mud weight (EMW) is calculated from rotary table (RT). Farmation Primary interval Taps Pare Pressure (EMW) Trend Indicators Saurce of Quantitative Intenral Lithology MDRT t~l TNDSS ~~1 Min l p9) Max (pR ? Trend Estimate C80 CLST 2fi70' -2322' 9.5 9.6 EVEN BG g~ C~p CLST/SLTS7 4274' -3591' 9.6 9.7 SL INCR WG/MW wG C40 SLTST/CLAY 475T -3970' 9.6 9.7 ~VEN BG/CG/MW CG C37 SLTST/CLAY 5075' -4218' g.6 9.7 EVEN CG/BG gG T7 SLTST/CLAY 5575' -4620' 9.7 g.7 EVEN BG gG T4 (ICEBERG) S~TS~/UCLAY/ 5862' -4870' 12.0 12.2 INCR MWICG/BG MW T3 OR RESEVOIR) ~S 6056' -5044' 12.0 12.0 INCR MW IBG BG T2 (BABE) SS/SL7ST/ CLAYISH 6238' -5210' 12.0 12.0 DECR gG gG C35 SLTST/CLAY/ SS 6348' -5301' 12.0 12.0 ~ECR BG BG TOTAL DEPTH SLTST 6568' -5501' 12.0 12.0 EVEN BG BG ~ Refer to Section 4.3 for expianation of abbreviations used. • ~ ~CH ~6 • ~~~~~~PS Tam 2L 327 5. DRILLING QATA 5.1 Daily Activi#y Summarv 5J30107 Rig up and spud the well at 11:OQ AIUI on 5/34/Q7. Dril! and run gyro surveys to 495' and pull out of the hole and pick up directiona{ tools. Run in the hole and driN ahead. Trip gas = 0. 5/31107 Drili and survey the hole to 120Q' and pul! out of the hale to adjust the directional tool. Run in the hole and continue to drill and slide. Trip Gas = 0. 6J1 /O7 Drill and slide formation to 2575' MD12395' ND (Casing Depth} and eirculate the hole three times bottoms up and pumped a hi-visc pill around wi#h nut plug marlcer #4 ob#ain strokes for bottoms up. Pu11 out of #he hoie to surface and rig up to run 9 5/8n casing. 612107 Finish pulling out of the hole and rig up to run 9 518fl casing. Run casing to ~550' and rig up ~ cement head and circulate and condition the mud for cement job. Cement 9 5/8" casing and beg"rn working to nipple up the BQPE. 6/3107 Complete BOPE nipple up and take down the diverter and weil head and rripple up the BOPE. Test the BOPE and set the wear ring. Check #he casing tv 2500 ps~ and hold a pre job safety meeting and begin to make up the BHA. 614J07 Run in the hale with the BHA and dri11 pipe and test #he casing. Drill out cement and 25' of new hole ta 2fi00' and F.I.T. to 15.5 EMW. Gommence drilting writh MWD faiiure after a few feet. Pull out of the hole with 5" drill pipe and make up a new BHA and run to bottflm and drili formation to 279Q'. 6/5107 Continue to drill to 4512' ~ 6/6/47 Monitor the wel! static and begin a wiper trip to 2575'. Service the top drive at the shoe and run in the hole and continue drilling to 5880'. ~ Fnnru ~ ~ ~ C~noc Ph111ips Tam 2L 327 6/7107 Drill to intermediate TD reached at 5980'. Short trip the hale and circulate and pull out of the hole for 7" casing run. Remove nuke sources and download MWD and lay down BHA and unfoad tools. siaia7 Rig up casing crew to run ~" casing. Run 7n casing to 5980' and condition mud for pumping cement. Pump cement to the hole and check floa#s. Rig down cement equipmen# and cfean the rig floar. fi/9I07 Test BG1P equipment and set the wear ring. Service the top drive and single in the hole 4" drill pipe and taNy. Pull drill pipe ou# of the hole and rack back. Make up new BHA. 6/10/07 Trip to bottom and drill out cement, shoe and new fiorma#ion to 640Q', #hen displace the we!! from 9.6 mud to 92.0 mud. Run a LOT to 15.6 EMW and dri11 formation. 61111Q7 Dri11 #ormaiion through pay zone to TD at 6568', maintaining a controlled drilling rate of 50'!hr until ~ 6304'. Pump a high viscosity sweep and circula#e bottoms up three times. Pult ~ out of the hofe and lay down the HWDP and drill collars. Unload the nuke sources and downioad the MWD. Glean the rig fiioor and prepare to run in the hole w"rth 4.5" liner. 6112J07 Wait on cross over and make up liner hanging while changing out floor equipment. Run in the ho{e wi#h 4.5" {iner to 896' and circulate out 17 uni#s of gas. Run in the hole to 5570' and make up cement head. Run in the hole to 6564' and circulate and condition mud. Trip gas is 123 units at 12.0 mud weight. fi/13/47 Make up liner hanger and change out floor equipment and start to run in the hole with 4.5» finer. Run in the hole to 896' and circulate out 17 uni#s of gas. Rur~ in the hole to 5970' and make up cement head. Run in the ho~e to 8560' ar~d circulate out 923 units of trip gas. Cement the liner and rig down cement equipment and blow down fines. Start to pull aut of the hoie and iay down 4.5~ driil pipe. ~ r~ ~nn~u ~ ~ CnrloCa`~Phillips Tarn 2L 327 5.2 Bit Record Bit / Run Make Type dets / Size Depth In (ftl Total Footage Bit Hrs Av. ROP (ff/hr) WOB (klbs) RPM pP Cps~~ Wear BHA . .. ,.... . .... .- ~ c.~~ nv-..c 1 HTC MXL-1 3X15, 1X13 80' 2495' 20.78' 142 18 26 w/ slides 1525 N/A #1 8.5" MULE 2 HTC HCM546Z 6X13 2575' 3405' 33.43 108 14 56 w! slides 2554 1-2-CT-S-X-I-ER-TD #2 6,125" HC?LE 3 HC PDC 5X11 5980' 5$8' 12.5 66 35 65 2351 1-2-CT-5-X-1-ER-TD #3 ~ F~~ 29 ~ ~ • ~~~~~;PS Tarn 2L 327 5.3 Survev Record Measured De th Inclination Azimuth TVD Caordinates Dog Leg Feet Degrees Degrees Depth N/ S E/ W Degrees/ 100 ft 81 0.19 51.94 $1.00 0.08N 0.11 E 023 169.00 0.23 15.96 169.00 0.34N 0.27E 0.15 258.Q0 0.36 4.76 258.00 0.79N 0.34E 0.16 345.00 Q.64 99.73 345.00 0.98N 0.84E b.87 437.00 0.81 137.69 436~99 0.42N 1.79E 0.54 536.00 1.44 154.27 535.97 1.22S 2.80E 0.71 623.00 1.46 147.19 622.94 3.14S 3.87E 0.21 720.00 1.84 152.62 719.90 5.56S 5.26E 0.42 816.00 Z.64 211.0~ 815.84 8.82S 4.83E 2.39 93$.36 6.15 ~ 246.84 937.84 13.82S 2.65W 3.51 1 Q30.10 7.38 219.34 1028.96 20.31 S 10.91 W 3.73 1122.91 8.4$ 190.17 1120.92 31.66S 15.90W 4.44 1159.93 9.38 181.21 1157.49 37.37S 16.44W 4.47 1219.53 10.10 166.66 1216.24 47.315 15.34W 4.29 1289.02 10.94 157.33 1284.57 59.32S 11.39W 2.73 1315.71 11,21 152.44 1310.76 63.96S 9, 21 W 3.66 1408.52 14.36 142.22 1401.2? 81.06S 2.01 E 4.17 1503.22 17.38 136.87 1492.36 100.675 1$.88E 3.54 1599.93 20.46 133.04 1583.88 122.755 41.12E 3.43 1691.21 23.74 126.84 1668.41 144.675 67.49E 4.40 1783.23 26.95 121.30 1751.57 166,625 100.15E 4.33 1879.19 30.61 19 2. 03 1$35.71 187.095 141.41 E ~ 6.01 ~ 1966.78 33.63 105.66 1909.90 202.01 S 185.46E 5.18 2068.52 37.00 1 Q9.64 1992.92 219.91 S 241.44E 4.01 2164.52 36.84 111.98 2069.67 240.40S 295.34E 1.47 2255.90 37.76 114.46 2142.37 262.245 346.22E 1.93 2351.07 37.71 118.53 2217.64 288.21 S 398.32E 2.62 ~ EPOCH ~ ~ 30 ~ CAr1oCOPhillips 7arn 2L 327 Measured Depth Inciination Azimuth TVC~ Coordinates Dog Leg Feet Degrees Degrees Depth N/ S E 1 W Degrees/ 100 ft 2446.13 37.81 123.73 2292.82 318.285 448.1 'I E 3.35 2505.87 37.72 126.24 2340.04 339.255 478.08E 2.58 2693.63 38.08 117.42 2488.31 399.925 575.87E 2.89 27$9.09 37.59 113.71 2563.71 425.19S 628.67E 2.44 2884.42 37.49 110.47 2639.31 447.025 682.48E 2.Q7 2978.04 37.03 111.52 2713.82 467.335 735.39E d.84 3073.9Q 37.14 ~ 114.99 2790.30 490.155 788,48E 2.19 3160.41 37.18 117.3t} 2859.25 513.175 835.38E 1.61 3249.75 37.43 118.48 2930,32 538.5QS 883.24E q.85 3354.3$ 37.95 118.59 3013.11 569.065 939.43E 0.50 3450.97 37.75 117.91 3089,38 597.11S 991.64E 0.48 3539.79 37.$7 117.54 3159.55 622.445 1039.84E 0.29 3640.39 37.59 116.66 3239.12 650.485 1094.64E 0.60 3727.34 37.42 116.61 3308.10 674.225 1141.96E 0.20 3823.48 37,73 116.84 3384.29 70Q.58S 1194.32E 0.35 3924.10 3821 117.09 3463.62 728.655 1249.50E 0.50 4016.94 38.27 117.24 3536.53 754.895 13Q0.62E 0.12 4112.04 38.26 118.50 3611.20 ?82.42S 1352.69E 0.82 4208.75 38.18 118.67 3687.18 811.05S 1405.23E 0.14 4301.81 38.52 118.36 3760.16 838.61 S 1455.96E 0.42 4396.32 38.07 116.05 3834.34 $65.395 15Q8.04E 1.59 4486.78 37.87 113.58 3905.66 $88.755 155$.55E 1.69 4585.21 38.53 113.37 3983.01 912.995 1614.38E 0.68 4673.52 38.76 117.16 4051.99 936.525 1664.23E 2.69 4776.18 37.72 119.01 4132.63 966.485 1720.29E 1.51 4$68.57 38.79 117.98 4205.18 993.71 S 1770.57E 1.35 495fiJ5 38.71 118.25 4273.95 1019.725 1819.25E 0.21 5055.42 38,24 118.08 4351.19 1 t748.705 1873.37E 0.49 5151.84 37.78 117.15 4427.16 1076.225 1925.98E 0.76 5246.03 37.31 115.90 4501.84 1101.86S 1977.33E 0.95 5337.11 36.65 115.59 4574.60 1125,655 2026.68E 0.75 5430.54 35.85 114.86 4649.95 1149.20S 2076.65E 0.97 ~ ~acH ~ ~ 31 ~ Corwco'~PhNlips ~arn 2~ 3zy Measured Depth Inclination Azimuth TVD Coordinates Coordinates Feet Degrees Degrees Depth N t S E/ W DegreesJ 100 ft 5525.81 33.94 117.52 4728.Q8 1173.22S 2125.56E 2.56 5620.67 32.18 119.72 4807.59 1197.98S 2170.99E 2.25 5715.87 29.67 123.82 48$9.26 1223.675 2212.59E 3.44 5806.32 28.18 128.60 4968.44 1249.46S 2247.89E 3.04 5902.$0 25.52 133.35 5054.52 1277.95S 2280.81E 3,54 5977.06 24.34 136.39 5120.79 1300.67S 2304.18E 2.35 6~73.55 ~~28.22 141.6? 5207.30 1332.97S 2332.06E 4.69 6169.$0 28.52 142.Q6 5291.99 136$.955 2360.30E Q.37 6260.32 27.83 148.03 5371.78 1402.$7S 2386.29E 0.91 6354.59 26.59 143.23 5455.62 1437.36S 2412.16E 1.32 6446.04 26.07 142.31 5537.58 1469.65S 2436.69E 0.72 6531.56 25.02 143.37 5614,74 149S.04S 2458.97E 1.34 *Projection to total depth. E~ EPOCH ~ ~ 32 ~ COt'10CO~P'I'IiU1p5 Tam 2L 327 5.4 Mud Recard Contractor: M-I Drilling Fluids Mud Type: SEAWATER to 3,169' Mud 7ype : LSND to 8,747' Date Dep#h MW Vis PV YP Geis API FL Solids Oi1/Water Sand PH CI Ca 5/30/Q7 495 9.6 220 20 58 55/58/68 18 7 /93 0.5 9.3 100Q 240 5/31 /07 1855 10.1 193 30 35 24/55/60 5.4 8 /92 1 9.3 600 80 6/1/07 2575 10.2 154 26 46 26/55/57 5.5 9 /91 1 9.0 600 120 6/2l07 2575 10.1 54 20 15 6/40/52 6 9 /91 0.5 8.5 650 80 6/3/07 2575 9.5 41 11 6 4/13/32 7.4 5 /95 0.25 8.5 800 80 6/4/07 2756 9.6 60 18 22 11/29/41 5 6.5 TR/94 0.25 9.9 910 80 6l51Q7 4359 9.7 56 15 27 14/18/29 4.6 6 TRI94 0.15 9.9 750 80 6/6/07 5786 9.7 52 13 25 11i15/22 4.8 8 TR/92 0.15 9.$ 730 $q 6/7/07 5980 9.7 52 15 29 13/18/24 4.1 8 TR/92 TR 9.6 700 80 6/8/0? 5980 9.6 48 10 i S 7/8/11 4 8 ~ /92 TR 10.2 7Q0 80 6/9/07 59$0 12.0 43 11 15 5/11/21 3.7 9 TR/91 TR 9.1 650 80 6/1q/07 6130 12.0 55 19 33 12/20/25 3.$ 16 TR/84 TR 10.0 80d 80 6/11/07 6568 12.0 53 18 23 7/11/16 3.4 15.5 TR/85 TR 9.8 750 80 6/12/07 6568 12.0 57 18 22 7/11/16 3.4 15.5 TR/85 TR 10.0 750 80 ~ EPOCH 3 ~ ~ ~ ~ ~ ~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~;~ 2L-327 REPORT FOR MORRISNAAGEN DATE Jun 01, 2007 DEPTH 1783.00000 PRESENT OPERATION DRILL~NG TIME 00:00:12 YESTERDAY 530.00000 24 HOUR FOOTAGE 1253' CASING INFORMATION 16" @ 80' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" MXL1 5121423 3X15, 1X13 80' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 700.3 @ 731.00000 12.2 @ 1706.00000 155.6 79.54395 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 39 @ 916.00000 1 @ 1477.00000 16.3 24.17583 KLBS ROTARY RPM 68 @ 1367.00000 SLIDE @ 1293.00000 12.1 SLIDE RPM PUMP PRESSURE 2120 @ 943.00000 817 @ 620.00000 1590.5 1598.46851 PSI DRILLING MUD REPORT DEPTH 1855' MW 10.1 VIS 193 PV 30 YP 35 FL 5.4 Gels 24/55/60 CL- 600 FC 2/ SOL 8 SD 1 OIL 0 MBL 28 pH 9.3 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 243 @ 1365.00000 0@ 572.00000 6.3 TRIP GAS 0@ 1194' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 21743 @ 1365.00000 28 @ 572.00000 799.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1783.00000 0@ 1783.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 1783.00000 0@ 1783.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 1783.00000 0@ 1783.00000 0.0 CURRENT BACKGROUND/AVG 16 PENTANE (G5) 0 @ 1783.00000 0@ 1783.00000 OA HYDROCARBON SHOWS STANDARD HYDRATE GAS INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION 1300 TO 1380 CLAY MAX 243 STANDARD GAS ITYDRATES LITHOLOGY CLAY, SAND TRACE SILTS PRESENT LITHOLOGY 100°/a CLAY SINCE 1400' DAILY ACTIVITY DRILL AND SLIDE TO 494', PULL OUT OF THE HOLE TO CHANGE OUT THE BHA, TRIP GAS = 0, DRILL AND SLIDE TO 1194' PULL OUT OF THE HOLE TO WORK ON M WD/GYRO TOOLS TG = 0 DRILL AND , SUMMARY SLIDE AHEAD TO REPORT TIME. , , EPOCH PERSONNEL ON BOARD 4 DAILY COST $3635 REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CONO... 6/ 1 /2007 • C ~ . Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSiTE REPORT ~~ E~~~~ 2L-327 REPORT FOR MORRIS, VAAGEN DATE Jun 02, 2007 DEPTH 2575.00000 PRESENT OPERATION PREP TO RUN 9 5/8" CSG TIME 11:47:26 YESTERDAY 1784.00000 24 HOUR FOOTAGE 791 CASING INFORMATION 16" @ 80' DEPTN INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2575~ 2394.72' 2505.87' 37.72 126.24 2340.04' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HTC MXL1 5121423 3X15, 1X13 80' 2575' 2495' 20J8 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 214.4 @ 2059.00000 10.8 @ 2324.00000 114.1 66.27100 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 76 @ 2266.00000 8 @ 2025.00000 25.6 27.66800 KLBS ROTARY RPM 73 @ 2477.00000 0 @ SLIDE 39.4 71.00000 RPM PUMP PRESSURE 2850 @ 2554.00000 1076 @ 1945.00000 1788.7 2694.36000 PSI DRiLLING MUD REPORT DEPTH 2575' (n/a) MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 2191.00000 1@ 1968.00000 14.0 TRIP GAS 140 @ 2575' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 9053 @ 2191.00000 213 @ 2484.00000 2486.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 26 @ 2191.00000 0@ 2569.00000 3.5 AVG 0 PROPANE (C-3) 0 @ 2575.00000 0@ 2575.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2575.00000 0@ 2575.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (G5) 0 @ 2575.00000 0@ 2575.00000 OA HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SILTSTONE, SAND PRESENT LITHOLOGY 2575' = 70% CLAY, 20% SILT, 10% SAND DAILY DRILL AND SLIDE FORMATION TO 2575', CIRCUTATE BOTTOMS UP AND PULL OUT OF THE HOLE TO 173', ACTIVITY DOWNLOAD MWD AND LAY DOWN MWD TOOLS, MAKE UP BHA AND RUN IN THE HOLE TO 2460', WASH SUMMARY TO BOTTOM (2575'), TRIP GAS = 140 UNITS, CIRCULATE HOLE CLEAN AND PULL OUT OF THE HOLE TO 31' EPOCH PERSONNEL ON BOARD 4 DAILY COST $3625 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20 Settings\RigUser~lVly%20Documents\My%20 Wells\CONO... 6/2/2007 ~ \ J . Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~~~,~ 2L-327 REPORT FOR MORRISNAAGEN DATE Jun 03, 2007 DEPTH 2575.00000 PRESEN7 OPERATION NIPPLE DOWN/UP BOP's TIME MIDNIGHT YESTERDAY 2575.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 2575' DEPTH INCLINATION AZIMUTH VERTICA~ DEPTH SURVEY DATA 2575' 2394.72' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PUL~ED 1 12.25" HTC MXL1 5121423 3X15, 1X13 80' 2575' 2495' 20.78 0/0-0-I TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH N/A SWAPPING MUD MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 788 @ 2575' CUTTING GAS @ @ WIPER GAS 479 @ 2575' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(G5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO FORMATION DRILLED PRESENT LITHOLOGY DAILY PREP AND RIG UP TO RUN 9 5/8" CASING, RUN CASING TO BOTTOM CIRCULATING AT STAGING DEPTHS, ACTIVITY WIOTH CASING ON BOTTOM CIRCULATE MUD, TRIP GAS = 788 UNITS, CONTINUE TO CIRCULATE THE SUMMARY CASING ON BOTTOM, PUMP CEMENT TO THE CASING, MAX GAS PUMPING CEMENT WAS 479 UNITS, RIG DOWN CEMENTERS AND BEGIN TO RIG DOWN DIVERTER. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3625 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20 S ettings~RigUser\My%20Documents~lVly%20 Wells\CONO... 6/3/2007 ~ ~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~,~ 2L-327 REPORT FOR MORRISNAAGE N DATE Jun 04, 2007 DEPTH 2575.00000 PRESENT OPERATION MAKE UP BHA TO DRILL TIME MIDNIGHT YESTERDAY 2575.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 2550' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2575' 2394.72 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HTC HCM506Z 7114473 6X13 2575' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2575' MW 9.5 VIS 41 PV 11 YP 6 FL 7.4 Gels 4/13/32 CL- 800 FC 2/ SOL 5 SD 0.25 OIL 0 MBL - pH 8.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE(G2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(G5) @ @ HYDROCARBON SHOWS HOLE CEMENTED OFF INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CEMENT PRESENT LITHOLOGY CEMENT DAILY ACTIVITY FINISH NIPPLE DOWN DIVERTER, NIPPLE DOWN WELL HEAD, NIPPLE UP BOP, SET WEAR RING, SUMMARY CHECK CASING TO 2500 PSI, MAKE UP BHA @ 130' EPOCH PERSONNEL ON BOARD 4 DAILY COST $3625 REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 6/4/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~,~~+~~ 2L-327 REPORT FOR MORRIS/VAAGEN DATE Jun 05, 2007 DEPTH 2766.00000 PRESENT OPERATION DRILLING TIME 00:00:23 YESTERDAY 2575.00000 24 HOUR FOOTAGE 191' CASING INFORMATION 9.625" @ 2550' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2693.63' 38.08 117.42 2488.31' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HTC HCM506Z 7114473 6X13 2575' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 486.7 @ 2576.00000 25.9 @ 2749.00000 91.3 98.40367 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 33 @ 2592.00000 0 @ SLIDE 16.3 13.43102 KLBS ROTARY RPM 71 @ 2575.00000 1 @ SLIDE 12.0 49.00000 RPM PUMP PRESSURE 5240 @ 2619.00000 2694 @ 2575.00000 4562.2 4570.71240 PSI DRILLING MUD REPORT DEPTH 2756' MW 9.6 VIS 60 PV 18 YP 22 FL 5 Gels 11/29/41 CL- 910 FC 1/ SOL 6.5 SD 0.25 OIL TR MBL 18 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 122 @ 2697.00000 8 @ 2604.00000 36.0 TRIP GAS 18 @ 2575' CUTTWG GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 23979 @ 2697.00000 1729 @ 2604.00000 7024.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 104 @ 2697.00000 1 @ 2602.00000 28.3 AVG 0 PROPANE (C-3) 8 @ 2739.00000 0 @ 2725.00000 0.9 CURRENT 0 BUTANE (C-4) 0 @ 2766.00000 0 @ 2766.00000 0.0 CUR RENT BACKGROUND/AVG 49 PENTANE (C-5) 0 @ 2766.00000 0 @ 2766.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE PRESENT LITHOLOGY 100% CLAYSTONE DAILY ACTIVITY TRIP IN THE HOLE AND DRILL OUT CEMENT AND 25' OF NEW HOLE TO 2600', F.I.T. TO 15.5 EMW, MUD SUMMARY MOTOR FAILURE, MONITOR THE WELL AND PULL OUT OF THE HOLE WITH 5" DRILL PIPE, MAKE UP BHA AND RUN IN THE HOLE AND TAG BOTTOM AT 2600' TRIP GAS 18 UNITS, DRILL AND SLIDE AHEAD. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3625 REPORT BY LEES F. BROWNE JR. ~ file://C : \Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CONO... 6/5/2007 ~ i Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~,~~~,~ 2L-327 REPORT FOR MORRISNAAGEN DATE Jun 06, 2007 DEPTH 4398.00000 PRESENT OP ERATION WIPER TRIP TIME 00:00:09 YESTERDAY 2766.00000 24 HOUR FOOTAGE 1632' CASING INFORMATION 9.625" @ 2550' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4468' 3890.98 (PROJ) 3924.10 38.21 117.09 3463.62' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HTC HCM506Z 7114473 6X13 2575' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 223.8 @ 3534.00000 14.6 @ 4290.00000 104.7 109.74940 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 40 @ 3536.00000 0 @ SLIDE 15.7 6.71551 KLBS ROTARY RPM 72 @ 3721.00000 1 @ SLIDE 48.4 71.00000 RPM PUMP PRESSURE 4654 @ 2818.00000 1430 @ 3258.00000 2717.0 2854.33398 PSI DRILLING MUD REPORT DEPTH 4359' MW 9.7 VIS 56 PV 15 YP 27 FL 4.6 Gels 14/18/29 CL- 750 FC 2/ SOL 6 SD 0.15 OIL tr MBL 14 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 87 @ 2878.00000 1@ 3891.00000 31.3 TRIP GAS CUTTING GAS 0 @ 4398.00000 0@ 4398.00000 0.0 WfPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 17126 @ 2878.00000 315 @ 3130.00000 6112.3 CONNECTIO N GAS HIGH 20 @ 4368' ETHANE (G2) 147 @ 2878.00000 1@ 3891.00000 51.9 AVG 5 PROPANE (C-3) 15 @ 4334.00000 0@ 4080.00000 3.6 CURRENT 4 BUTANE (C-4) 0 @ 4398.00000 0@ 4398.00000 0.0 CURRENT BACKGROUND/AVG 0 WIPER TRIP PENTANE (C-5) 0 @ 4398.00000 0@ 4398.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SILTSTONE PRESENT LITHOLOGY 4468' = 80% CLAY, 20% SIIT DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. file: //C :~D ocuments%20and%20 S ettings\RigUser\My%20Do cuments~lVly%20 Wells\CONO... 6/6/2007 ~ C~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~~;~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 07, 2007 DEPTH 5856.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 4398.00000 24 HOUR FOOTAGE 1458' CASING INFORMATION 9.625" @ 2550' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5806.32' 28.18 128.60 4968.44' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 2 8.75" HTC HCM506Z 7114473 6X13 2575' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 384.9 @ 4844.00000 20.3 @ 5220.00000 115.2 87.49119 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 45 @ 5132.00000 1 @ SLIDE 11.2 10.26900 KLBS ROTARY RPM 109 @ 5834.00000 1 @ SLIDE 69.9 77.00000 RPM PUMP PRESSURE 3517 @ 5619.00000 1137 @ 5231.00000 2177.9 2148.94800 PSI DRILLING MUD REPORT DEPTH 5786' MW 9.7 VIS 52 PV 13 YP 25 FL 4.8 Gels 11/15/22 CL- 730 FC 2/ SOL 8 SD 0.15 OIL TR MBL 21.25 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 513 @ 4493.00000 6@ 5524.00000 24.6 TRIP GAS CUTTING GAS @ @ WIPER GAS 513 @ 4513' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 83852 @ 4493.00000 988 @ 5524.00000 4299.4 CONNECTION GAS HIGH 22 ETHANE (C-2) 2276 @ 5342.00000 33 @ 4448.00000 169.4 AVG 3 PROPANE (C-3) 1045 @ 5342.00000 4@ 4455.00000 67.3 CURRENT 0 BUTANE (C-4) 476 @ 5342.00000 0@ 4702.00000 27.6 CURRENT BACKGROUND/AVG 16 PENTANE (C-5) 55 @ 5343.00000 0@ 5241.00000 0.5 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE AND CLAYSTONE PRESENT LITHOLOGY SILTSTONE, CLAYSTONE DAILY ACTIVITY DRILL TO 4513', PULL A WIPER TRIP TO THE SHOE (2575') TRIP BACK TO BOTTOM, WIPER GAS = 513 SUMMARY UNITS @ 900 STROKES (BOTTOMS UP 3260 STROKES), DRILL AND SLIDE AHEAD EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. \_ J file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CONO... 6/7/2007 Daily Report ~ ~ Page 1 of 2 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~,~~~,+~ 2L-327 REPORT FOR MORRISIHEIM DA7E Jun 08, 2007 DEPTH 5980.00000 PRESENT OPERATION UNLOAD MWD TOOLS TIME MIDNIGHT YESTERDAY 5856.00000 24 HOUR FOOTAGE 124' CASING INFORMATION 9.625" @ 2550' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5980 5124 (PROJ.) BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S!N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HTC HCM506Z 7114473 6X13 2575' 5980' 3405 33.43 1/2-X-S TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 169.5 @ 5895.00000 24.5 @ 5880.00000 101.4 54.69878 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 25 @ 5886.00000 6 @ 5958.00000 14.4 18.16900 KLBS ROTARY RPM 89 @ 5944.00000 61 @ 5863.00000 51.8 85.00000 RPM PUMP PRESSURE 2148 @ 5856.00000 1434 @ 5979.00000 1816.0 1613.37800 PSI DRILLING MUD REPORT DEPTH 5980' MW 9.7 VIS 52 PV 15 YP 29 FL 4.1 Gels 13/18/24 CL- 700 FC 2/2 SOL 8 SD TR OIL TR MBL 26.25 pH 9.6 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 42 @ 5924.00000 9@ 5878.00000 21.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 141 @ 5980' CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 6705 @ 5924.00000 760 @ 5958.00000 3213.7 CONNECTION GAS HIGH 15 @ 5877' ETHANE (C-2) 590 @ 5924.00000 65 @ 5958.00000 267.5 AVG 4 PROPANE (C-3) 331 @ 5979.00000 34 @ 5958.00000 140.7 CURRENT 2 BUTANE (C-4) 180 @ 5941.00000 17 @ 5958.00000 71.5 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 59 @ 5979.00000 0@ 5945.00000 9.0 HYDROCARBON SLIGHT OIL SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5908' TO 5935' 60% SILTSTONE, 30°/a BEFORE 15 MAX 30% SS VLTGY, VFGR, GRAIN SUP, 20°/a BRI SANDSTONE, 10% CLAYSTONE 42 AFTER 20 YELLO PATCHT SMPL FLOR, POOR SLO WEAK CUTS LITHOLOGY SIL7STONE, SANDSTONE, CLAYSTONE PRESENT LITHOLOGY 5980' = 50% SILTSTONE, 30% CLAYSTONE, 20% SANDSTONE DAILY ACTIVITY DRILL TO 5980' CIRCULATE HOLE CLEAN, SHORT TRIP TO 4320', TRIP TO BOTTOM, CIRCULATE OUT 141 SUMMARY UNITS OF WIPER GAS, PULL OUT OF THE HOLE, REMOVE NUKE SOURCES, DOWNLOAD MWD, LAY DOWN BHA AND UNLOAD TOOLS. ~ EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 6/8/2007 ~ ~ ~ Daily Report Page 2 of 2 file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 6/8/2007 ~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~~~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 09, 2007 DEPTH 5980.00000 PRESENT OPERATION RIG DOWN CEMENT EQUIPMENT TIME MIDNIGHT YESTERDAY 5980.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 5980Y5123' TVD DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5980~ 5124' (PROJ) BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5980' MW 9.6 VIS 48 PV 10 YP 18 FL 4 Gels 7/8/11 CL- 700 FC 2/2 SOL 8 SD TR OIL 0 MBL 25 pH 10.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 65 @ 5980 TG @ TRIP GAS 65 @ 5980' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CO NNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (G5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT RIG UP CASING TOOLS AND RUN 7" CASING TO BOTTOM (5980'), CIRCULATE AND CONDITION DRILLING DAILY ACTIVITY MUD (TRIP GAS 65 UNITS), PUMP CEMENT TO CASING, MAX GAS PUMPING CEMENT WAS 45 UNITS, SUMMARY CHECK FLOATS, RIG DOWN CEMENTING EQUIPMENT. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. ~ file://C:~Documents%20and%20Settings\RigUser\My%20Documents~Ivly%20Wells\CONO... 6/9/2007 ~ Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~~~,~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 10, 2007 DEPTH 5980.00000 PRESENT OPERATION M/U BHA TIME 02:08:22 YESTERDAY 5980.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 5970' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5980' 5124' (PROJ) BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125" HC PDC 7004309 5X11 5980' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5980' MW 12.0 VIS 43 PV 11 YP 15 FL 3.7 Gels 5/11/21 CL- 650 FC 1/1 SOL 9 SD TR OIL TR MBL 18.75 pH 9.1 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE(G2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(G5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY ACTIVITY TEST BOPE, RIG DOWN TESTING EQUIPMENT, CHANGE OUT SAVOR SUB, RIG UP SPfNNERS AND SUMMARY TONGS, SERV ICE TOP DRIVE, SINGLE IN THE HOLE 4" DRILL PIPE AND TALLY, PULL OUT OF THE HOLE FROM 5308', MAKE UP NEW BHA TO DRILL EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. ~ file://C:~Documents%20and%20 Settings\RigUser\My%ZODocuments\My%20 Wells\CON... 6/10/2007 Daily Report ~ Page 1 of 2 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~~;~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 11, 2007 DEPTH 6142.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 5980.00000 24 HOUR FOOTAGE 162' CASING INFORMATION 7" @ 5970' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6142' 5267' 6073 28.22 141.67 5207.30 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125" HC PDC 7004309 5X11 5980 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 123.6 @ 6024.00000 11.4 @ 5981.00000 57.5 51.85228 FT/HR SURFACETORQUE @ @ AMPS WEIGHT ON BIT 89 @ 6026.00000 7 @ SLIDE 41.4 14.16483 KLBS ROTARY RPM 85 @ 5980.00000 2 @ SLIDE 52.5 64.00000 RPM PUMP PRESSURE 2650 @ 6105.00000 985 @ 5992.00000 2123.8 2377.34204 PSI DRILLING MUD REPORT DEPTH 6130' MW 12.0 VIS 55 PV 19 YP 33 FL 3.8 Gels 12/20/25 CL- 800 FC 1/1 SOL 16 SD TR OIL TR MBL 16.25 pH 10.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1457 @ 6141.00000 13 @ 6062.00000 119.4 TRIP GAS 190 @ 5980' CUTTING GAS 0 @ 6142.00000 0 @ 6142.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 45816 @ 6141.00000 1922 @ 6070.00000 8780.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 22003 @ 6141.00000 135 @ 6104.00000 1702.6 AVG 0 PROPANE (C-3) 19841 @ 6141.00000 72 @ 6104.00000 1330.4 CURRENT 0 BUTANE (C-4) 10962 @ 6141.00000 32 @ 6104.00000 714.2 CURRENT BACKGROUND/AVG 290 PENTANE (C-5) 4098 @ 6141.00000 1 @ 6059.00000 251.2 HYDROCARBON GOOD OIL AND GAS SHOWS THROUGH BERMUDA SAND/SANDSTONES SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION START 6120' AND SANDSTONE AND BEFORE 35 90% BRI LT YELLO EVEN TO PATCHT SMPL FLOR, MOD PETRO CONTINUED SAND DURING 1560 ODR, PIN PT OIL IN SMPL, V LT BRN Oll. STN, INST HZY TO CLDY SLO CUTS, SLO DEVEL TO MILKY FNT STRAW RESD STN LITHOLOGY SAND, SANDSTONE, SILT, CLAY PRESENT LITHOLOGY 6140' = SAND, SANDSTONE W/ MINOR CLAY AND ASH DAILY ACTIVITY TRIP TO BOTTOM AND DRILL OUT CEMENT AND SHOE, TRIP GAS 190 UNITS, DISPLACE WELL TO SUMMARY 12.0 PPG MW, RUN LOT @ 15.6 PPG, DRILL AHEAD ~ EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. file://C:~Documents%20and%20Settings\RigUser~lVly%20Documents\My%20Wells\CON... 6/ 11/2007 C~ Daily Report Page 2 of 2 file://C:\Documents%20and%20Settings\RigUser\My%20Documents~Nly%20Wells\CON... 6/ 11/2007 Daily Report ~ Page 1 of 2 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~'~~~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 12, 2007 DEPTH 6568.00000 PRESENT OPERATION PREP TO RIH W/ LINER TIME MIDNIGHT YESTERDAY 6142.00000 24 HOUR FOOTAGE 426' CASING INFORMATION 7" @ 5970' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6567' 5646.45' 6531.56' 25.02 143.37 5614.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125" HC PDC 7004309 5X11 5980' 6568' S88' 12.5 1/2-X-S TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 303.4 @ 6391.00000 13.6 @ 6369.00000 69.2 98.56700 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 60 @ 6538.00000 10 @ 6204.00000 31.9 50.38500 KLBS ROTARY RPM 82 @ 6445.00000 62 @ 6298.00000 69.9 79.00000 RPM PUMP PRESSURE 2842 @ 6555.00000 1801 @ 6172.00000 2442.7 2842.13200 PSI DRILLING MUD REPORT DEPTH 6568' MW 12.0 VIS 53 PV 18 YP 23 FL 3.4 Gels 7/11/16 CL- 750 FC 1/1 SOL 15.5 SD TR OIL TR MBL 20 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1615 @ 6215.00000 23 @ 6567.00000 299A TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 49756 @ 6207.00000 3163 @ 6567.00000 17757.7 CONNECTION GAS HIGH 0 ETHANE (G2) 22867 @ 6143.00000 182 @ 6567.00000 3629.1 AVG 0 PROPANE (C-3) 22168 @ 6145.00000 143 @ 6567.00000 3413.7 CURRENT 0 BUTANE (C-4) 12722 @ 6145.00000 98 @ 6567.00000 2325.8 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 5131 @ 6215.00000 75 @ 6567.00000 1097.1 HYDROCARBON T-3 OIL AND GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6118' TO 6238' SANDSTONE AND BEFORE 35 MAX GOOD OIL SHOWS THROUGHOUT ZONE 90-100°/a BRI SAND 1615 AFTER 225 YELLOISH WHT FLR, MODERATE BLUWHT OIL CUTS LITHOLOGY SANDSTONE, SAND, SILTSTONE, CLAY PRESENT LITHOLOGY 6568' = 20% SAND, 40% SILT, 20% CLAY, 20% CALC TUFF ASH DAILY ACTIVITY DRILL FORMATION TO 6568', PUMP A HI-VIS SWEEP AND CIRCULATE THE HOLE THREE TIMES AND PULL SUMMARY OUT OF HOLE TO THE SHOE (MONITOR - OK) PULL OUT AND LAY DOWN HWDP + DC, UNLOAD NUKES, DOWNLOAD MWD, CLEAN FLOOR AND PREP TO RUN 4.5" LINER. ~ EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My°/o20Documents\My%20 Wells\CON. , . 6/ 12/2007 ~ \__~ Daily Report Page 2 of 2 file://C:~Documents%20and%20Settings\RigUser~lVly%20Documents~lVly%20Wells\CON... 6/ 12/2007 ~ • Daily Report Page 1 of 1 CONOCOPHILLIPS TAaN DAILY WELLSITE REPORT ~ ~,~'{~~~ 2L-327 REPORT FOR MORRIS/HEIM DATE Jun 13, 2007 DEPTH 6568.00000 PRESENT OPERATION POOH L/D DP TIME MIDNIGHT YESTERDAY 6568.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 4.5" @ 6560' DEPTH INCLINATION AZIMUTN VERTICAL DEPTH SURVEY DATA 6568' 5646.45' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6568' MW 12.0 VIS 57 PV 18 YP 22 FL 3.4 Gels 7/11/16 CL- 750 FC 1/1 SOL 15.5 SD TR OIL TR MBL 22.5 pH 10.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 @ TD @ TRIP GAS 123 @ 6568' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE(G2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (G5) @ @ HYDROCARBON SHOWS fNTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT UTHOLOGY CEMENT DAILY MAKE UP LINER HANGER, CHANGE OUT FLOOR EQUIPMENT, RUN IN THE HOLE WITH 4.5" LINER TO 896' ACTIVITY CIRCULATE OUT 17 UNITS OF GAS, RUN IN THE HOLE TO 5970' MAKE UP CEMENT HEAD, RUN IN THE SUMMARY HOLE TO 6560' CI RCULATE OUT 123 UNITS OF TRIP GAS, CEMENT LINER, RIG DOWN CEMENT EQUIPMENT AND BLOW DOWN LINES, START TO PULL OUT OF THE HOLE AND LAY DOWN DRILL PIPE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3485 REPORT BY LEES F. BROWNE JR. • file://C:\Documents%20and%20S ettings\RigUser\My%20Documents\My%20Wells\CON... 6/ 13/2007
