Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout224-106DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
We
l
l
L
o
g
I
n
f
o
r
m
a
t
i
o
n
:
Di
g
i
t
a
l
Me
d
/
F
r
m
t
Re
c
e
i
v
e
d
St
a
r
t
S
t
o
p
OH
/
CH
Co
m
m
e
n
t
s
Lo
g
Me
d
i
a
Ru
n
No
El
e
c
t
r
Da
t
a
s
e
t
Nu
m
b
e
r
Na
m
e
In
t
e
r
v
a
l
Li
s
t
o
f
L
o
g
s
O
b
t
a
i
n
e
d
:
Tr
i
p
l
e
C
o
m
b
o
(
G
R
,
R
e
s
i
s
t
i
v
i
t
y
,
C
a
l
i
p
e
r
,
N
e
u
t
r
o
n
,
P
E
)
,
M
u
d
l
o
g
;
C
B
L
(
s
)
,
D
i
r
e
c
t
i
o
n
a
l
S
u
r
v
e
y
s
;
E
O
W
R
e
p
o
r
No
No
Ye
s
Mu
d
L
o
g
S
a
m
p
l
e
s
D
i
r
e
c
t
i
o
n
a
l
S
u
r
v
e
y
RE
Q
U
I
R
E
D
I
N
F
O
R
M
A
T
I
O
N
(f
r
o
m
M
a
s
t
e
r
W
e
l
l
D
a
t
a
/
L
o
g
s
)
DA
T
A
I
N
F
O
R
M
A
T
I
O
N
Lo
g
/
Da
t
a
Ty
p
e
Lo
g
Sc
a
l
e
DF
1/
6
/
2
0
2
5
11
4
7
4
8
8
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
C
A
S
T
-
CB
L
_
2
0
-
2
2
O
C
T
2
4
.
l
a
s
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
13
0
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
T
r
i
p
l
e
Co
m
b
o
D
e
p
t
h
D
a
t
a
.
l
a
s
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
D
E
O
W
R
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
i
n
a
l
D
e
f
i
n
i
t
i
v
e
S
u
r
v
e
y
s
(S
i
g
n
e
d
)
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
i
n
a
l
D
e
f
i
n
i
t
i
v
e
Su
r
v
e
y
s
.
x
l
s
x
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
C
A
S
T
-
C
B
L
_
2
0
-
22
O
C
T
2
4
.
d
l
i
s
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
C
A
S
T
-
C
B
L
_
2
0
-
22
O
C
T
2
4
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
E
n
d
o
f
W
e
l
l
Re
p
o
r
t
_
C
I
N
G
S
A
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
V
I
S
I
O
N
S
e
r
v
i
c
e
Me
m
o
r
y
D
r
i
l
l
i
n
g
D
a
t
a
.
d
l
i
s
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
M
D
-
5i
n
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
M
D
-
Fi
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
TV
D
-
F
i
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
L
i
t
h
o
l
o
g
y
De
s
c
r
i
p
t
i
o
n
s
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
1
o
f
9
Su
p
p
l
i
e
d
b
y
Op
Su
p
p
l
i
e
d
b
y
Op
CL
U
S
-
0
7
T
r
i
p
l
e
,
Com
b
o
D
e
p
t
h
D
a
t
a
.
l
a
s
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
L
W
D
C
o
m
b
o
L
o
g
M
D
-
Fi
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
L
W
D
C
o
m
b
o
L
o
g
T
V
D
-
Fi
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
M
u
d
L
o
g
M
D
-
F
i
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
6
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
M
u
d
L
o
g
T
V
D
-
F
i
n
a
l
.
p
d
f
39
9
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
66
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
D
e
p
t
h
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
4
6
4
5
5
5
1
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
1
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
6
1
4
5
5
6
4
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
2
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
6
4
4
5
5
6
7
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
3
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
6
7
4
5
5
7
1
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
4
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
8
7
4
5
5
8
9
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
6
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
45
5
9
0
4
5
5
9
3
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
R
u
n
0
7
Dr
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
T
i
m
e
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
13
0
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
T
r
i
p
l
e
Co
m
b
o
D
e
p
t
h
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
11
4
7
4
8
8
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
-
0
7
C
A
S
T
-
CB
L
_
2
0
-
2
2
O
C
T
2
4
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
27
9
2
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
7
-
D
r
i
l
l
i
n
g
Pa
r
a
m
e
t
e
r
s
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
27
9
2
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
S
7
-
G
a
s
Ou
t
D
a
t
a
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
G
e
o
l
o
g
W
e
l
l
s
i
t
e
A
M
R
e
p
o
r
t
f
o
r
10
-
2
5
-
2
4
v
2
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
D
r
i
l
l
i
n
g
M
e
c
h
a
n
i
c
s
De
p
t
h
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
1
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
2
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
2
o
f
9
CL
U
S
7
-
G
a
s
Out
D
a
t
a
.
l
a
s
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
3
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
4
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
6
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
R
u
n
0
7
D
r
i
l
l
i
n
g
Me
c
h
a
n
i
c
s
T
i
m
e
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
V
I
S
I
O
N
S
e
r
v
i
c
e
Me
m
o
r
y
D
r
i
l
l
i
n
g
D
a
t
a
.
d
l
i
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
2
i
n
M
D
V
I
S
I
O
N
T
r
i
p
l
e
Co
m
b
o
L
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
2
i
n
T
V
D
V
I
S
I
O
N
T
r
i
p
l
e
Co
m
b
o
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
5
i
n
M
D
V
I
S
I
O
N
T
r
i
p
l
e
Co
m
b
o
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
5
i
n
T
V
D
V
I
S
I
O
N
T
r
i
p
l
e
Co
m
b
o
L
o
g
.
P
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
M
-
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
MD
-
5
i
n
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
M
-
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
MD
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
M
-
D
e
n
s
i
t
y
-
P
o
r
o
s
i
t
y
L
o
g
TV
D
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
M
-
L
W
D
C
o
m
b
o
L
o
g
MD
2
i
n
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
M
-
L
W
D
C
o
m
b
o
L
o
g
TV
D
2
i
n
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
o
r
m
a
t
i
o
n
L
o
g
2
2
5
0
'
-
51
1
8
'
T
V
D
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
o
r
m
a
t
i
o
n
L
o
g
2
7
9
0
'
-
89
5
2
'
M
D
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
C
A
S
T
-
C
B
L
_
2
0
-
22
O
C
T
2
4
.
d
l
i
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
C
A
S
T
-
C
B
L
_
2
0
-
22
O
C
T
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
3
o
f
9
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
L
i
t
h
o
l
o
g
y
De
s
c
r
i
p
t
i
o
n
s
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
S
a
m
p
l
e
d
e
s
c
r
i
p
t
i
o
n
.
x
l
s
x
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
l
u
s
7
G
a
s
l
o
g
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
M
u
d
L
o
g
M
D
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
M
u
d
L
o
g
T
V
D
-
F
i
n
a
l
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
2
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
3
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
4
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
5
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
6
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
7
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
8
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
0
9
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
1
0
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
1
1
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
1
2
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
1
3
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
1
4
2
0
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
_
C
L
U
S
7
_
D
a
i
l
y
Mu
d
l
o
g
g
i
n
g
R
e
p
o
r
t
_
1
0
2
6
2
0
2
4
(
2
)
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
6
9
2
0
'
C
e
m
e
n
t
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
4
o
f
9
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
1
0
0
'
C
e
m
e
n
t
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
5
9
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
6
2
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
6
5
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
6
8
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
7
1
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
7
4
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
7
7
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
0
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
0
1
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
3
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
6
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
9
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
9
1
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
8
9
2
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
9
2
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
9
5
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
9
7
4
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
7
9
7
5
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
0
7
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
1
0
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
1
3
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
1
6
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
1
9
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
2
2
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
2
5
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
2
8
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
3
1
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
3
4
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
5
o
f
9
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
3
7
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
3
7
1
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
3
7
2
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
4
0
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
i
n
a
l
D
e
f
i
n
i
t
i
v
e
S
u
r
v
e
y
s
(S
i
g
n
e
d
)
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
F
i
n
a
l
D
e
f
i
n
i
t
i
v
e
Su
r
v
e
y
s
.
x
l
s
x
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
I
N
G
S
A
C
L
U
S
-
0
7
E
O
W
R
Ce
m
e
n
t
i
n
g
S
e
r
v
i
c
e
s
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
D
E
O
W
R
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
0
7
E
n
d
o
f
W
e
l
l
Re
p
o
r
t
_
C
I
N
G
S
A
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
d
a
i
l
y
d
r
i
l
l
i
n
g
s
u
m
m
a
r
y
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
G
e
o
l
o
g
W
e
l
l
s
i
t
e
A
M
R
e
p
o
r
t
f
o
r
10
-
1
3
-
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
G
e
o
l
o
g
W
e
l
l
s
i
t
e
A
M
R
e
p
o
r
t
f
o
r
10
-
1
4
-
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
G
e
o
l
o
g
W
e
l
l
s
i
t
e
A
M
R
e
p
o
r
t
f
o
r
10
-
2
4
-
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
G
e
o
l
o
g
W
e
l
l
s
i
t
e
A
M
R
e
p
o
r
t
f
o
r
10
-
2
5
-
2
4
.
p
d
f
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
4
3
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
4
6
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
4
9
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
5
2
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
5
5
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
5
8
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
6
1
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
6
4
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
6
7
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
7
0
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
6
o
f
9
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
7
3
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
7
6
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
7
9
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
8
2
0
(
1
)
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
8
2
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
8
5
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
8
8
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
8
8
1
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
9
1
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
9
4
0
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
1/
1
4
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
8
9
5
2
.
j
p
g
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
12
/
1
2
/
2
0
2
5
28
1
0
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
CI
N
G
S
A
_
C
L
U
S
7
_
D
r
i
l
l
i
n
g
D
a
t
a
_
2
8
1
0
-
8
9
5
2
f
t
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
12
/
1
2
/
2
0
2
5
28
1
0
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
CI
N
G
S
A
_
C
L
U
S
7
_
G
a
s
D
a
t
a
_
2
8
1
0
-
8
9
5
2
f
t
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
12
/
1
2
/
2
0
2
5
28
1
0
8
9
5
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
CI
N
G
S
A
_
C
L
U
S
7
_
L
i
t
h
o
D
a
t
a
_
2
8
1
0
-
8
9
5
2
f
t
.
l
a
s
39
9
5
6
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
80
4
2
6
9
7
3
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
_
S
-
7
_
2
3
-
J
a
n
-
25
_
3
0
f
p
m
U
p
P
a
s
s
.
l
a
s
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
80
8
3
6
9
7
6
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
_
S
-
0
7
_
0
1
-
Fe
b
-
2
5
_
C
o
m
p
o
s
i
t
e
M
a
i
n
U
p
P
a
s
s
.
l
a
s
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
80
5
2
6
9
7
2
E
l
e
c
t
r
o
n
i
c
D
a
t
a
S
e
t
,
F
i
l
e
n
a
m
e
:
C
L
U
_
S
-
7
_
2
4
-
J
a
n
-
25
_
C
o
m
p
o
s
i
t
e
M
a
i
n
U
p
P
a
s
s
.
l
a
s
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
S
-
7
D
a
i
l
y
C
o
m
p
l
e
t
i
o
n
R
e
p
o
r
t
Su
m
m
a
r
y
.
p
d
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
7
_
2
3
-
J
a
n
-
25
_
M
e
m
o
r
y
R
a
d
i
a
l
C
e
m
e
n
t
B
o
n
d
L
o
g
.
p
d
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
7
_
2
3
-
J
a
n
-
25
_
M
e
m
o
r
y
R
a
d
i
a
l
C
e
m
e
n
t
B
o
n
d
L
o
g
.
t
i
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
7
_
2
3
-
J
a
n
-
25
_
3
0
f
p
m
U
p
P
a
s
s
.
d
l
i
s
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
0
7
_
0
1
-
F
e
b
-
25
_
C
o
i
l
F
l
a
g
.
p
d
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
7
o
f
9
,
CIN
GS
A_
CLU
S7_
L
i
t
h
o
D
a
t
a
_
2
8
1
0
-
8
9
5
2
ft.
l
a
s
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
We
l
l
C
o
r
e
s
/
S
a
m
p
l
e
s
I
n
f
o
r
m
a
t
i
o
n
:
Re
c
e
i
v
e
d
St
a
r
t
S
t
o
p
C
o
m
m
e
n
t
s
To
t
a
l
Bo
x
e
s
Sa
m
p
l
e
Se
t
Nu
m
b
e
r
Na
m
e
In
t
e
r
v
a
l
IN
F
O
R
M
A
T
I
O
N
R
E
C
E
I
V
E
D
Co
m
p
l
e
t
i
o
n
R
e
p
o
r
t
Pr
o
d
u
c
t
i
o
n
T
e
s
t
I
n
f
o
r
m
a
t
i
o
n
Ge
o
l
o
g
i
c
M
a
r
k
e
r
s
/
T
o
p
s
Y Y
/
N
A
Y
Co
m
m
e
n
t
s
:
Mu
d
L
o
g
s
,
I
m
a
g
e
F
i
l
e
s
,
D
i
g
i
t
a
l
D
a
t
a
Co
m
p
o
s
i
t
e
L
o
g
s
,
I
m
a
g
e
,
D
a
t
a
F
i
l
e
s
Cu
t
t
i
n
g
s
S
a
m
p
l
e
s
Y
/
N
A
Y Y
/
N
A
Di
r
e
c
t
i
o
n
a
l
/
I
n
c
l
i
n
a
t
i
o
n
D
a
t
a
Me
c
h
a
n
i
c
a
l
I
n
t
e
g
r
i
t
y
T
e
s
t
I
n
f
o
r
m
a
t
i
o
n
Da
i
l
y
O
p
e
r
a
t
i
o
n
s
S
u
m
m
a
r
y
Y Y
/
N
A
Y
Co
r
e
C
h
i
p
s
Co
r
e
P
h
o
t
o
g
r
a
p
h
s
La
b
o
r
a
t
o
r
y
A
n
a
l
y
s
e
s
Y
/
N
A
Y
/
N
A
Y
/
N
A
CO
M
P
L
I
A
N
C
E
H
I
S
T
O
R
Y
Da
t
e
C
o
m
m
e
n
t
s
De
s
c
r
i
p
t
i
o
n
Co
m
p
l
e
t
i
o
n
D
a
t
e
:
2/
4
/
2
0
2
5
Re
l
e
a
s
e
D
a
t
e
:
8/
2
0
/
2
0
2
4
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
0
7
_
0
1
-
F
e
b
-
2
5
_
C
o
i
l
F
l
a
g
.
t
i
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
7
_
2
4
-
J
a
n
-
2
5
_
C
o
i
l
F
l
a
g
.
p
d
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
C
L
U
_
S
-
7
_
2
4
-
J
a
n
-
2
5
_
C
o
i
l
F
l
a
g
.
t
i
f
40
1
5
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
2
0
2
5
-
0
3
-
1
3
D
a
i
l
y
R
e
p
o
r
t
C
L
U
S
-
7.
p
d
f
40
2
3
5
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
2
0
2
5
-
0
3
-
1
4
C
L
U
S
-
7_
e
P
D
T
_
F
i
e
l
d
P
r
i
n
t
.
p
d
f
40
2
3
5
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
2
0
2
5
-
0
3
-
1
4
C
L
U
S
-
7_
e
P
D
T
_
R
e
p
o
r
t
_
R
e
v
0
.
p
d
f
40
2
3
5
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
2
5
/
2
0
2
5
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
2
0
2
5
-
0
3
-
1
4
D
a
i
l
y
R
e
p
o
r
t
C
L
U
S
-
7.
p
d
f
40
2
3
5
ED
Di
g
i
t
a
l
D
a
t
a
10
/
1
7
/
2
0
2
4
28
1
2
8
9
5
2
91
9
0
7
Cu
t
t
i
n
g
s
10
/
1
7
/
2
0
2
4
28
1
2
8
9
5
2
91
9
0
8
We
t
S
a
m
p
l
e
s
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
8
o
f
9
DA
T
A
S
U
B
M
I
T
T
A
L
C
O
M
P
L
I
A
N
C
E
R
E
P
O
R
T
AP
I
N
o
.
5
0
-
1
3
3
-
2
0
7
2
7
-
0
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
C
A
N
N
E
R
Y
L
O
O
P
U
N
I
T
S
-
7
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
GS
T
O
R
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
4
/
2
0
2
5
Pe
r
m
i
t
t
o
D
r
i
l
l
22
4
1
0
6
0
Op
e
r
a
t
o
r
C
o
o
k
I
n
l
e
t
N
a
t
u
r
a
l
G
a
s
S
t
o
r
a
g
e
A
l
a
s
k
MD
89
5
2
TV
D
51
1
8
Cu
r
r
e
n
t
S
t
a
t
u
s
GS
T
O
R
12
/
2
2
/
2
0
2
5
UI
C
No
Co
m
p
l
i
a
n
c
e
R
e
v
i
e
w
e
d
B
y
:
Da
t
e
:
Mo
n
d
a
y
,
D
e
c
e
m
b
e
r
2
2
,
2
0
2
5
AO
G
C
C
Pa
g
e
9
o
f
9
12
/
2
6
/
2
0
2
5
M.
G
u
h
l
From:Guhl, Meredith D (OGC)
To:Flora, Jake; Cerveny, Philip
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC)
Subject:RE: Digital Log Data: CINGSA CLU S-07
Date:Wednesday, December 17, 2025 9:45:00 AM
Attachments:image003.png
image004.png
Jake,
Thank you, I have added the LAS files to the dataset T39956. The litho LAS meets the requirement
for lithology percentages. Your email will serve as the transmittal.
Meredith
From: Flora, Jake <JFlora@asrcenergy.com>
Sent: Friday, December 12, 2025 8:20 AM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Cerveny, Philip <pcerveny@asrcenergy.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: RE: Digital Log Data: CINGSA CLU S-07
Hi Meredith,
Please see attached the CLUS-7 mudlog data in LAS. Would you like me to send a new data
transmittal for these also? Below is a screenshot of the transmittal from earlier this year and it
does have the mudlog included.
Thanks,
Jake
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, November 19, 2025 1:36 PM
To: Flora, Jake <JFlora@asrcenergy.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: RE: Digital Log Data: CINGSA CLU S-07
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.
⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do
not click links or open attachments unless you recognize the sender and know the content is
safe.
Hi Jake,
I’m completing the compliance review on CLU S-07 and I don’t see that a mudlog LAS file with
lithology percentages was ever submitted for this well, as requested in my email of March 12.
Please forward a mudlog LAS with lithology percentages.
Thank you,
Meredith
From: Flora, Jacob <JFlora@asrcenergy.com>
Sent: Wednesday, March 12, 2025 3:05 PM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: RE: Digital Log Data: CINGSA CLU S-07
Hi Meredith,
I have a request in with SLB on the lithology percentages. Please let us know if you find anything
else.
On the Triple combo PDF I’m seeing a decent signature that corresponds to your screenshot, see
below. Looks like your scale is 200 units and this one below is 100 units. Maybe it’s the log scale?
I do know GR is poor down here from the volcanics in the rock as well. Let me know how I can
help-
⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do
not click links or open attachments unless you recognize the sender and know the content is
safe.
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, March 12, 2025 2:42 PM
To: Flora, Jacob <JFlora@asrcenergy.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: Digital Log Data: CINGSA CLU S-07
Hi Jake,
I’ve just loaded the SLB Triple combo log data and the first 2700’ of GR data is pretty spotty:
I looked at the PDF version of the log, sometimes there is an explanation written in there as to why
the GR data is spotty, but I didn’t see one.
Can you please let us know why the data is spotty for the surface section of the well?
Also, neither mudlog LAS will load to our well display software. And the mudlog LAS file is lacking
lithology percentages. Please have SLB provide a new copy of the LAS file that includes lithology
percentages.
Please respond with requested new LAS and information by March 26, or with an ETA for when the
data will be available.
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
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 Meredith Guhl at 907-793-1235
or meredith.guhl@alaska.gov.
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, September 26, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Cook Inlet Natural Gas Storage Alaska, LLC
S-7
CANNERY LOOP UNIT S-7
Jim Regg
InspectorSrc:
S-7 G
SPT
4893
2241060 1500
1643 1645 1646 1646
67 150 104 95
Initial Test Pass
MIT-IA Int. test - on gas injection
30 MinPretestInitial15 Min
Type Test
Notes:
Interval P/F
Well Type Inj TVD
PTD Test psi
Tubing
OA
Packer Depth
190 1780 1770 1765IA
45 Min 60 Min
50-133-20727-00-00
224-106-0
Adam Earl
7/22/2025
Well Name
Permit Number:
API Well Number Inspector Name:CANNERY LOOP UNIT S-7
Inspection Date:Insp Num:
Rel Insp Num:
mitAGE250803152646
MITOP000011116
BBL Pumped:1.9 BBL Returned:1.7
Friday, September 26, 2025 Page 1 of 1
Industry Guidance Bulletin 10-02B suggests a 50 psi pressure differential between the tubing and IA but is not required; test
result accepted as PASS since the 130-ish dP was maintained throughout the 30 min test. J. Regg; 9/26/2025
Jake Flora
ASRC Consulting & Environmental Services, LLC
Petroleum Engineer
(720) 988-5375 jflora@asrcenergy.com
1
March 21, 2025
Alaska Oil and Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave, Suite 100
Anchorage, Alaska 99501
RE: DATA TRANSMITTAL 004 WELL: CINGSA CLU S-7
PTD: 224-106
API: 50-133-20727-00-00
Name Type
x >h^ͲϳĞWdĂƐŝŶŐ/ŶƐƉĞĐƚŝŽŶ>ŽŐ W&
x >h^ͲϳĞWdĂƐŝŶŐ/ŶƐƉĞĐƚŝŽŶZĞƉŽƌƚ W&
x >h^ͲϳĂŝůLJZĞƉŽƌƚƐ W&
Data Transfer Folder: CINGSA Well Logs Subfolders: 224-106 CLU Storage 7
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
224-106
T40235
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.03.25 08:00:21 -08'00'
TRUE Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _______1__________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp. 14. Permit to Drill Number / Sundry:
2/3/2025
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y-Zone- 04
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 NA (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20"136'
13-3/8" J-55 2264'
9-5/8" L-80 4954'
7" L-80 5061'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
1188 psi 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
97/64th (in)
187'
na
Oil-Bbl: Water-Bbl:
0
Water-Bbl:
PRODUCTION TEST
2/4/2025
Date of Test: Oil-Bbl:
560
2/9/2025
surface
6
Flow Tubing psi
TUBING RECORD
SIZE
14
36,000
na9,000
Flowing
Sterling C: 7680'-8044' MD, 5000'-5046' TVD (1/25/24 - 2/3/25)
0
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
2777'surface
surface
2 stage: 266 bbls, 242 bbls
68#
136'
46 bbls 14# Flexstone8-1/2"
12-1/4"40#
8160'
surface
4889'
surface 7503'
CASING WT. PER
FT.GRADE
October 26, 2024
CEMENTING RECORD
2392858.38
NA
SETTING DEPTH TVD
2394040.98
TOP HOLE SIZE AMOUNT
PULLED
278790.76
278401.69
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
NA
BOTTOM
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Triple Combo (GR, Resistivity, Caliper, Density, Neutron, PE); Mud Log; Directional Surveys; EOW Report, GR/CCL Perforating Tie-In Log(s); 9-5/8" CBL
(10/22/24); 7" CBL (1/23/25)
50-133-20727-00-00
CLU Storage 7
ADL 391627
716' FNL, 1610' FEL, Sec 9, T5N, R11W, SM, AK
426' FSL, 49' FWL, Sec 4, T5N, R11W, SM, AK
NA
September 11, 2024
8952' / 5118'
8073' / 5052'
PO Box 190989 Anchorage, AK 99519
281995.47 2392833.30
749' FNL, 457' FWL, Sec 9, T5N, R11W, SM, AK Cannery Loop / Sterling C Gas Storage GL: 33' KB: 54.4'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Cook Inlet Natural Gas Storage Alaska, LLC
WAG
Gas
224-106 / 324-656
DEPTH SET (MD)
7289' / 4889' (LTP)
PACKER SET (MD/TVD)
Conductor NA
16"
Driven
surface 243 bbls lead, 82 bbls tail surface
TOL
surface
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
26# 7289'
7302'7"
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or AbandonmentRBDMS JSB 030325
Completed
2/4/2025
JSB
GSTOR
Received 2/26/2025
G
1/26/25
DSR-4/7/25BJM 11/10/25
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
N/A N/A
Top of Productive Interval 7680' 5000'
5610' 4024'
6130' 4332'
7536' 4963'
8204' 5068'
Sterling C2 8952' 5118'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Jake Flora
Digital Signature with Date:Contact Email:jflora@asrcenergy.com
Contact Phone:720-988-5375
CINGSA Director
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange 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.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
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.
TPI (Top of Producing Interval).
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Authorized Name and
Sterling B
Sterling C1
Formation Name at TD:
Sterling C2
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Sterling A
Authorized Title:
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
TRUE Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _______1__________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y-Zone- 04
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 NA (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20"136'
13-3/8" J-55 2264'
9-5/8" L-80 4954'
7" L-80 5061'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
1188 psi 24-Hour Rate
DEPTH SET (MD)
7289' / 4889' (LTP)
PACKER SET (MD/TVD)
Conductor NA
16"
Driven
surface 243 bbls lead, 82 bbls tail surface
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Cook Inlet Natural Gas Storage Alaska, LLC
WAG
Gas
224-106 / 324-656
50-133-20727-00-00
CLU Storage 7
ADL 391627
716' FNL, 1610' FEL, Sec 9, T5N, R11W, SM, AK
426' FSL, 49' FWL, Sec 4, T5N, R11W, SM, AK
NA
September 11, 2024
8952' / 5118'
8073' / 5052'
PO Box 190989 Anchorage, AK 99519
281995.47 2392833.30
749' FNL, 457' FWL, Sec 9, T5N, R11W, SM, AK Cannery Loop / Sterling C Gas Storage GL: 33' KB: 54.4'
CASING WT. PER
FT.GRADE
October 26, 2024
CEMENTING RECORD
2392858.38
NA
SETTING DEPTH TVD
2394040.98
TOP HOLE SIZE AMOUNT
PULLED
278790.76
278401.69
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
NA
BOTTOM
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Triple Combo (GR, Resistivity, Caliper, Density, Neutron, PE); Mud Log; CBL(s); Directional Surveys; EOW Report, GR/CCL Perforating Tie-In Log(s)
2777'surface
surface
2 stage: 266 bbls, 242 bbls
68#
136'
46 bbls 14# Flexstone8-1/2" TOL
12-1/4" surface
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
40#
8160'
surface
4889'
surface 7503'
26# 7289'
7302'7"
TUBING RECORD
SIZE
390
36,000
na141,000
Flowing
*** Please see attached schematic for perforation detail ***
0
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Sr Res EngSr Pet GeoSr Pet Eng
97/64th (in)
187'
na
Oil-Bbl: Water-Bbl:
0
Water-Bbl:
PRODUCTION TEST
2/4/2025
Date of Test: Oil-Bbl:
670
2/4/2025
surface
138
Flow Tubing psi
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:34 am, Feb 26, 2025
2/4/2025 JSB
Superseded
Superseded
1/26/25
CLUS-07 Daily Drilling Summary
8/22/24 Start Rig Up.
9/10/24 End Rig Up.
9/11/24 MU BHA – .
9/12/24 –
4 –
9/14/24 OOH.
9/15/24 –
9/16/24 Grade bit, c --55 casing
9/17/24 - . Cut
9/18/24
12.0 ppg
ppg
9/19/24
9/20/24 -5/8” NU
-
9/21/24 .
9/22/24 test.
9/24/24
9/25/24 –
9/26/24
9/27/24
9/28/24 C&C. .
9/29/24 , C&C.
10/1/24
10/2/24
10/4/24 . Rotate pipe and reciprocate
10/5/24
10/6/24 MU 9--80 VAM
, run
10/7/24 -5/8” casing.
10/8/24 -5/8” casing to .
10/9/24 RU , 5
5 14 ppg
to rig #2 pump
pressure 490 psi
10/10/24 -
MU 8- -15k.
9-5/8" 2nd stage cement is likely compromised.
OA ,
Drill out the closing plug and inner sleeve of ES cementer.
10/12/24
10/14/24 – ,
5
-
10/15/24 RU E-
10/16/24 -
, tractor to
-
10/17/24
10/18/24
backside up to 1500 psi
free
10/19/24 .
Test. RU E-
10/20/24
.
10/21/24
in returns
& RIH.
10/22/24 og OOH. MU
. ,
shoe.
10/24/24
McLeo
10/25/24
10/26/24
10/27/24
track
10/28/24
10/29/24
11/01/24
shoe,
11/02/24 MU
.
11/04/24
11/05/24 U
2200 psi to hanger, good set.
11/06/24
spacer,
11/07/24
high
11/08/24
11/09/24
-tube into tubing.
11/10/24
hrs, 11/11/24.
11/14/2024
William Isaacson
Page 1/1
Well Name: CLUS-7
Report Printed: 2/25/2025www.peloton.com
Cement
API/UWI
50-133-20727-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.45
KB-Casing Flange Distance (ft) Spud Date
9/11/2024 04:30
Rig Release Date
11/11/2024 00:00
Surface Casing Cement
Surface Casing Cement, Casing, 9/18/2024 21:00
Type
Casing
Cementing Start Date
9/18/2024
Cementing End Date
9/19/2024
Wellbore
Original Hole
String
Surface, 2,777.8ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method
Returns to Surface
Cement Evaluation Results
Comment
1, 26.0-2,790.0ftKB
Top Depth (ftKB)
26.0
Bottom Depth (ftKB)
2,790.0
Full Return?
Yes
Vol Cement Ret (bbl)
118.6
Top Plug?
Yes
Bottom Plug?
No
Initial Pump Rate (bbl/min)
5
Final Pump Rate (bbl/min)
3
Avg Pump Rate (bbl/min)
5
Final Pump Pressure (psi)
900.0
Plug Bump Pressure (psi)
1,975.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date
Lead
Fluid Type
Lead
Fluid Description
12.0 PPG
Amount (sacks)
553
Class
G
Volume Pumped (bbl)
243.5
Estimated Top (ftKB)
25.0
Estimated Bottom Depth (ftKB)
2,290.0
Percent Excess Pumped (%)
37.0
Yield (ft³/sack)
2.47
Mix H20 Ratio (gal/sack)
14.48
Free Water (%)
1.24
Density (lb/gal)
12.00
Plastic Viscosity (cP)
8.0
Thickening Time (hr)
6.65
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Chemical Extender D020 3.0
Liquid Antifoam Agent D047 0.05
Cement Dispersant D065 0.2
Chemical Extender D079 1.5
Liquid Accelerator D186 0.2
Tail
Fluid Type
Tail
Fluid Description
15.8 PPG
Amount (sacks)
381
Class
G
Volume Pumped (bbl)
65.5
Estimated Top (ftKB)
2,290.0
Estimated Bottom Depth (ftKB)
2,790.0
Percent Excess Pumped (%)
75.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.07
Free Water (%)
0.00
Density (lb/gal)
15.80
Plastic Viscosity (cP)
98.0
Thickening Time (hr)
1.50
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Liquid Antifoam Agent D047 0.02
Cement Dispersant D065 0.5
Fluid Loss Control D167 0.35
Page 1/1
Well Name: CLUS-7
Report Printed: 2/25/2025www.peloton.com
Cement
API/UWI
50-133-20727-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.45
KB-Casing Flange Distance (ft) Spud Date
9/11/2024 04:30
Rig Release Date
11/11/2024 00:00
Intermediate Casing Cement
Intermediate Casing Cement, Casing, 10/6/2024 12:30
Type
Casing
Cementing Start Date
10/6/2024
Cementing End Date
10/8/2024
Wellbore
Original Hole
String
Intermediate, 7,504.0ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method Cement Evaluation Results
Comment
1, 3,449.0-7,504.0ftKB
Top Depth (ftKB)
3,449.0
Bottom Depth (ftKB)
7,504.0
Full Return?
Yes
Vol Cement Ret (bbl)
267.0
Top Plug?
Yes
Bottom Plug?
Yes
Initial Pump Rate (bbl/min)
5
Final Pump Rate (bbl/min)
3
Avg Pump Rate (bbl/min)
7
Final Pump Pressure (psi)
315.0
Plug Bump Pressure (psi)
490.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
6,900.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB)
6,900.0
Drill Out Diameter (in)
81/2
Drill Out Date
10/14/2024
Lead
Fluid Type
Lead
Fluid Description
12.0 ppg Extended Class G
Cement
Amount (sacks)
490
Class
G
Volume Pumped (bbl)
215.0
Estimated Top (ftKB)
3,650.0
Estimated Bottom Depth (ftKB)
7,400.0
Percent Excess Pumped (%)
15.0
Yield (ft³/sack)
2.46
Mix H20 Ratio (gal/sack)
14.32
Free Water (%)
0.60
Density (lb/gal)
12.00
Plastic Viscosity (cP)
9.0
Thickening Time (hr)
9.40
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Chemical Extender D020 3.0
Liquid Antifoam Agent D047 0.05
Cement Dispersant D065 0.2
Chemical Extender D079 1.1
Low Temp Liq Retarder D110A 0.3
Tail
Fluid Type
Tail
Fluid Description
14 PPG FLEXSTONE TAIL
Amount (sacks)
220
Class
G
Volume Pumped (bbl)
55.1
Estimated Top (ftKB)
7,400.0
Estimated Bottom Depth (ftKB)
7,400.0
Percent Excess Pumped (%)
15.0
Yield (ft³/sack)
1.30
Mix H20 Ratio (gal/sack)
4.14
Free Water (%)
0.00
Density (lb/gal)
14.00
Plastic Viscosity (cP)
286.0
Thickening Time (hr)
3.70
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Liquid Antifoam Agent D047 0.1
Low Temp Liq Retarder D177 0.03
Cement Dispersant D202 0.6
GAS CONTROL AGENT D400 0.5
2, 21.3-3,449.0ftKB
Top Depth (ftKB)
21.3
Bottom Depth (ftKB)
3,449.0
Full Return?
Yes
Vol Cement Ret (bbl)Top Plug?
Yes
Bottom Plug?
No
Initial Pump Rate (bbl/min)
5
Final Pump Rate (bbl/min)
3
Avg Pump Rate (bbl/min)
7
Final Pump Pressure (psi)
190.0
Plug Bump Pressure (psi)
386.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
2,700.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB)
3,449.0
Drill Out Diameter (in)
81/2
Drill Out Date
10/11/2024
Lead
Fluid Type
Lead
Fluid Description
12.0 ppg Class G Extended
Cement
Amount (sacks)
250
Class
G
Volume Pumped (bbl)
243.0
Estimated Top (ftKB)
21.4
Estimated Bottom Depth (ftKB)
3,449.0
Percent Excess Pumped (%)
15.0
Yield (ft³/sack)
2.47
Mix H20 Ratio (gal/sack)
14.47
Free Water (%)
1.40
Density (lb/gal)
12.00
Plastic Viscosity (cP)
11.0
Thickening Time (hr)
7.85
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Chemical Extender D020 3.0
Liquid Antifoam Agent D047 0.05
Cement Dispersant D065 0.2
Chemical Extender D079 1.5
Liquid Accelerator D186 0.25
Page 1/1
Well Name: CLUS-7
Report Printed: 2/25/2025www.peloton.com
Cement
API/UWI
50-133-20727-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.45
KB-Casing Flange Distance (ft) Spud Date
9/11/2024 04:30
Rig Release Date
11/11/2024 00:00
Production Liner Cement
Production Liner Cement, Casing, 11/6/2024 02:30
Type
Casing
Cementing Start Date
11/6/2024
Cementing End Date
11/6/2024
Wellbore
Original Hole
String
Liner, 8,160.0ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method Cement Evaluation Results
Comment
1, 7,289.0-8,160.0ftKB
Top Depth (ftKB)
7,289.0
Bottom Depth (ftKB)
8,160.0
Full Return?
Yes
Vol Cement Ret (bbl)Top Plug?
Yes
Bottom Plug?
No
Initial Pump Rate (bbl/min)
4
Final Pump Rate (bbl/min)
300
Avg Pump Rate (bbl/min) Final Pump Pressure (psi)
725.0
Plug Bump Pressure (psi)
1,275.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date
Tail
Fluid Type
Tail
Fluid Description Amount (sacks)
158
Class
G
Volume Pumped (bbl)
46.0
Estimated Top (ftKB)
7,289.0
Estimated Bottom Depth (ftKB)
8,160.0
Percent Excess Pumped (%)
28.0
Yield (ft³/sack)
1.63
Mix H20 Ratio (gal/sack)
5.02
Free Water (%) Density (lb/gal)
14.00
Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi)
Cement Stage Fluid Additives
Add Type Conc
Jake Flora
ASRC Consulting & Environmental Services, LLC
Petroleum Engineer
(720) 988-5375 jflora@asrcenergy.com
1
February 25, 2025
Alaska Oil and Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave, Suite 100
Anchorage, Alaska 99501
RE: DATA TRANSMITTAL 003 WELL: CINGSA CLU S-7
PTD: 224-106
API: 50-133-20727-00-00
Name Type
x >h^ͲϳWƌŽĚƵĐƚŝŽŶ>ŝŶĞƌĞŵĞŶƚŽŶĚ>ŽŐ W&͕d/&&͕>^͕/>^
x >h^Ͳϳ'Zͬ>Žŝů&ůĂŐ;ƐͿ W&͕d/&&͕>^
x >h^ͲϳĂŝůLJŽŵƉůĞƚŝŽŶ^ƵŵŵĂƌLJ W&
Data Transfer Folder: CINGSA Well Logs Subfolders: 224-106 CLU Storage 7
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
224-106
T40152
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.02.25 14:45:16 -09'00'
224-106
T39956
Jake Flora
ASRC Consulting & Environmental Services, LLC
Petroleum Engineer
(720) 988-5375 jflora@asrcenergy.com
1
January 06, 2025
Alaska Oil and Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave, Suite 100
Anchorage, Alaska 99501
RE: DATA TRANSMITTAL - WELL: CINGSA CLU S-7
PTD: 224-106
API: 50-133-20727-00-00
Name Type
x >h^ͲϳDƵĚ>ŽŐds&ŝŶĂů W&
x >h^ͲϳDƵĚ>ŽŐD&ŝŶĂů W&
x >h^Ͳϳ>tŽŵďŽ>ŽŐdsͲ&ŝŶĂů W&
x >h^Ͳϳ>tŽŵďŽ>ŽŐDͲ&ŝŶĂů W&
x >h^Ͳϳ>ŝƚŚŽůŽŐLJĞƐĐƌŝƉƚŝŽŶƐ W&
x >h^ͲϳĞŶƐŝƚLJͲWŽƌŽƐŝƚLJ>ŽŐdsͲ&ŝŶĂů W&
x >h^ͲϳĞŶƐŝƚLJͲWŽƌŽƐŝƚLJ>ŽŐDͲ&ŝŶĂů W&
x >h^ͲϳĞŶƐŝƚLJͲWŽƌŽƐŝƚLJ>ŽŐDͲϱŝŶ W&
x >h^ͲϬϳdƌŝƉůĞŽŵďŽĞƉƚŚĂƚĂ >^
x >h^ͲϬϳs/^/KE^ĞƌǀŝĐĞDĞŵŽƌLJƌŝůůŝŶŐĂƚĂ >/^
x >h^Ͳϳ> W&͕>^͕>/^
x >h^ͲϳĞĨŝŶŝƚŝǀĞ&ŝŶĂů^ƵƌǀĞLJƐ W&͕y>^
x >h^Ͳϳ KtZĞƉŽƌƚ W&
Data Transfer Folder: CINGSA Well Logs Subfolders: 224-106 CLU Storage 7
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
224-106
T39912
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.01.06 09:58:36 -09'00'
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Initial Completion
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
Exploratory Development
3.Address:Stratigraphic Service
6.API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?SIO-9
Yes No
9. Property Designation (Lease Number): 10. Field:
Sterling C Gas Storage Pool N/A
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
8952' 5118'8073' 5052' 1744 psi None None
Casing Collapse
Structural
Conductor n/a
Surface 1950 psi
Intermediate 3090 psi
Production
Liner 5410 psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16.Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Jake Flora
Contact Email:
Contact Phone: 720-988-5375
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
12/20/2024
8160'871'
7"
5061'
7" ZXP LTP, WR-SSSV (planned)
Perforation Depth MD (ft):
26#
7482'
2756'
7503'
planned
7"
planned
Tubing Size:Perforation Depth TVD (ft):
136'
2777'
20"
13-3/8"
115'
9-5/8"
7302'
MD
5750 psi
n/a
3450 psi
136'
2264'
4954'
Length Size
Proposed Pools:
CLU Storage 7
PRESENT WELL CONDITION SUMMARY
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 391627
224-106
PO Box 190989 Anchorage, AK 99519 50-133-20727-00-00
Cook Inlet Natural Gas Storage Alaska, LLC
AOGCC USE ONLY
7240 psi
Tubing Grade: Tubing MD (ft):
JFLORA@ASRCENERGY.COM
CINGSA Director
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Cannery Loop
7289' MD/4890' TVD, 187' MD/187' TVD
m
n
P
66
t
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 10:01 am, Nov 20, 2024
Matthew
Federle
Digitally signed by Matthew
Federle
Date: 2024.11.20 07:39:20
-09'00'
324-656
X
BJM 11/26/24
CT BOP test to 3000 psi
SFD 11/20/2024
10-404
DSR-11/21/24*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.11.27 09:11:53 -09'00'11/27/24
RBDMS JSB 112924
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
November 2024
Rev. 0
November 20, 2024
Mrs. Jessie Chmielowski, Commissioner
Mr. Greg Wilson, Commissioner
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Application for Sundry Approval
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA): CLU Storage 7
PTD: 224-106
Dear Commissioners,
Cook Inlet Natural Gas Alaska, LLC (CINGSA), hereby applies for Sundry Approval to complete the CLU
Storage 7 gas storage injection well, located in Kenai, Alaska.
Please find attached for review of the Commission the 10-403 Form, Completion Procedure, Proposed Well
Schematic, BOPE Diagram, and Nitrogen Operating Procedure.
Fox Coiled Tubing will be used to complete this work, commencing approximately December 20, 2024.
If you have any questions regarding the enclosed application, please contact Jake Flora at (720) 988-5375.
Sincerely,
Mathew Federle
CINGSA Director
y
OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE
ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com
Page 1 of 3
To: Matt Federle
Director of CINGSA
From: Jake Flora / Doug Cismoski P.E.
ASRC Consulting & Environmental
Well Name:CLU Storage 7 API:50-133-20727-00-00
PTD: 224-106
Status:Drilled & cased wellbore w/ no perforations
Engineer:Jake Flora, (720) 988-5375
Well Summary:
CLU Storage 7 is the first of two new wells drilled in the fall of 2024 to provide additional deliverability from the
CINGSA gas storage facility. The wellbore has a 60 degree sail angle rising to 85 degrees through the Sterling C
Sand target interval(s) and will be perforated with coiled tubing deployed TCP.
Scope:
Use coiledtubing to clean out drilling mud from 7” liner, reverse wellbore dry with nitrogen, and perforateselected
target intervals within the Sterling C Gas Storage Pool. Following perforating the well will be flow tested. If sand
or water are suspected during the flow test, coiled tubing will return to the well to tag and evaluate for water entry.
Well Information:
Max Expected BHP 2243 psi (Based on 0.449 psi/ft gradient @ 4996’TVD)
MPSP: 1744 psi (Based on BHP minus 0.1 psi/ft gas gradient)
Total Depth: 8952’ MD / 5118’ TVD
Plug back depth: 8073’ MD / 5052’ TVD (Landing Collar)
Minimum ID 4.750” / 187’ SVLN Protection Sleeve / Tubing
MIT-Tubing 3000 psi (Passed 11/09/2024)
MIT-Annulus 1750 psi (Passed 11/09/2024)
Procedure:
1. Provide AOGCC 24hrs notice for BOP test
2. Review all approved COAs
3. MIRU 2” Coiled Tubing
4. RU BOPE, perform BOP test to 3000 psi
5. MU cleanout BHA
6. Using freshwater clean out wellbore to landing collar at 8073’
x If PBTD is found high due to cement stringers, PU motor/bit to clean out to TD
7. MU Memory CBL logging BHA
8. RIH to TD, log OOH, flag pipe above perforation interval
OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE
ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com
Page 2 of 3
9. At surface download data, send to geologist for correlation
10. MU reverse nozzle BHA
11. Conduct Nitrogen safety meeting, review CINGSA Nitrogen SOP
12. RIH, cool down nitrogen pump
13. 5’ above PBTD reverse all fluid from wellbore (~350 bbls to recover)
14. POOH trapping ~1700 psi of nitrogen pressure on wellbore
15. Above closed swab valve, fluid pack coiled tubing with methanol, bleed lubricator dry to slop tank, pop
off
16. Hold TCP perforating safety meeting
17. MU TCP BHA
x Coiled tubing connector, ball drop disco, rupture sub, XO, pressure actuated firing head, (50’) 3-
3/8” 6spf perf guns: BHA OAL = 60’
x Firing head pinned to shear at 4400 psi absolute pressure
18. RIH to flag, correlate to perf depth, using methanol pressure up coil to 2600 psi to perforate, POOH
Planned Perforations: ± 7656’ – 8073’ MD / ± 4996’ – 5062’ TVD
x Perforations will be shot bottom up
x All perforations lie in the Sterling C Gas Storage Pool
19. Shut down coil pump while POOH, bleed coil pressure to 0 psi
x Maintain and monitor open bleed from coiled tubing to slop tank
20. Bleed off lubricator, pop off to confirm guns have fired
21. Repeat steps 17-20 perforating the entire desired footage (Estimated 10 runs)
22. RDMO Coiled Tubing, move to CLUS-6
23. Vent Nitrogen from wellbore
24. Hand well to Operations to flow test through pad test separator
Contingency Coiled Tubing Steps: In the event sand is detected during the well test, or logging data is
required
1. MIRU 2” Coiled Tubing
2. RU BOPE, perform BOP test to 3000 psi
3. MU cleanout BHA
4. RIH, tag TD, evaluate wellbore for sand entry
5. Log PT survey if water is suspected
6. Perform cleanout or unload well with nitrogen if necessary
OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE
ASRC Consulting & Environmental, LLC | 3900 C Street, Suite 601, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com
Page 3 of 3
7. RDMO Coiled Tubing
Post Perforating & Flow Test:
1. MIRU Slickline, PT lubricator to 2000 psi
2. Pull protection sleeve from hydraulic landing nipple at 187’
3. Set WRSSSV, function test
4. RD Slickline, hand well to Operations
Attachments:
1. Current Wellbore Diagram
2. Proposed Wellbore Diagram
3. Coiled Tubing BOPE Diagram
4. CINGSA Nitrogen SOP
Casing Detail
Size Type Wt Grade ID Top Btm MD / TVD
20"20" Conductor - - - 0' 136' / 136'
13-3/8" Surface 68# J-55 12.415" 0' 2777' / 2264'
9-5/8" Intermediate 40# L-80 8.998" 0' 7503' / 4954'
7" Tubing 26# L-80 6.276" 0' 7302' / 4893'
7" Liner 26# L-80 6.276" 7289' 8160' / 5061'
Cement Detail
13-3/8"
9-5/8"
7"
Jewellry Detail
Item ID Depth
13-3/8"A 5.963" 187'
4.750" 187'
B NA 3449'
C 6.180" 7302'
D 6.180" 7289'
E 7" x 9-5/8" Baker HRD-E ZXP Hanger 6.170" 7310'
F RN Nipple, No Go, 13cr 5.838" 7326'
G Baker Landing Collar (LC, FC, FS; 8073' - 8160') NA 8073'
9-5/8"
7"
Last Rev: 11/15/2024
By: Jake Flora
Hydraulic Landing Nipple, Halliburton RRQ
Halliburton 7in RRQ SVLN Protection Sleeve
ES Cementer, Halliburton (9.625" Int Csg)
1st stage 216 bbls 12.0# Class G lead, 51 bbls 14# Flexstone tail, TOC @ 4312' (10-22-24 CBL)
2nd stage 242 bbls 12.0 ppg Class G, cement to surface, overdisplaced while closing stage tool
46 bbls 14# Flexstone, no losses during job, circulated cement off TOL
Description
243 bbls 12.0# Class G lead, 82 bbls 15.8# tail, cement to surface
CINGSA
CLU Storage 07
Current Schematic
Bullet Tieback Seal Assembly, 9.58'
7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP, 11' PBR
PBTD = 8073' MD / 5052' TVD
TD = 8952' MD / 5118' TVD
PTD: 224-106
API: 50-133-20727-00-00
FMC Wellhead: 13-5/8" 5k Multibowl
FMC Tree: 7" 5k complete with SSV
Ground Elevation: 33'
KB: 54.4' AMSL
Tubing Minimum ID: 5.963"
Casing Minimum ID: 5.838"
A
B
C, D, E
F
G
14.5 ppg
mud
9.2 ppg
hi-vis
mud
Casing Detail
Size Type Wt Grade ID Top Btm MD / TVD
20"20" Conductor - - - 0' 136' / 136'
13-3/8" Surface 68# J-55 12.415" 0' 2777' / 2264'
9-5/8" Intermediate 40# L-80 8.998" 0' 7503' / 4954'
7" Tubing 26# L-80 6.276" 0' 7302' / 4893'
7" Liner 26# L-80 6.276" 7289' 8160' / 5061'
Cement Detail
13-3/8"
9-5/8"
7"
Jewellry Detail
Item ID Depth, Top
13-3/8"A 5.963" 187'
3.495" 187'
B NA 3449'
C 6.180" 7302'
D 6.180" 7289'
E 7" x 9-5/8" Baker HRD-E ZXP Hanger 6.170" 7310'
F RN Nipple, No Go, 13cr 5.838" 7326'
G Baker Landing Collar (LC, FC, FS; 8073' - 8160') NA 8073'
9-5/8"
Perforation Detail (PLANNED)
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date
Sterling C ± 7656' ± 8073' ± 4996' ± 5062' ± 417' PLANNED
7"
Last Rev: 11/15/2024
By: Jake Flora
PBTD = 8073' MD / 5052' TVD
TD = 8952' MD / 5118' TVD
1st stage 216 bbls 12.0# Class G lead, 51 bbls 14# Flexstone tail, TOC @ 4312' (10-22-24 CBL)
2nd stage 242 bbls 12.0 ppg Class G, cement to surface, overdisplaced while closing stage tool
46 bbls 14# Flexstone, no losses during job, circulated cement off TOL
Description
Hydraulic Landing Nipple, Halliburton RRQ
WRSSSV, Halliburton
ES Cementer, Halliburton (9.625" Int Csg)
Bullet Tieback Seal Assembly, 9.58'
7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP, 11' PBR
243 bbls 12.0# Class G lead, 82 bbls 15.8# tail, cement to surface
CINGSA
CLU Storage 07
Proposed Schematic
PTD: 224-106
API: 50-133-20727-00-00
FMC Wellhead: 13-5/8"5k Multibowl
FMC Tree: 7" 5k complete with SSV
Ground Elevation: 33'
KB: 54.4' AMSL
Tubing Minimum ID: 5.963"
Casing Minimum ID: 5.838"
A
B
C, D, E
F
G
14.5ppg
mud
CINGSA Storage CLUS-6/7
Well Head Rig Up
1
1
1
1
Hydraulic Stripper over/under 4 1/6" 10K
4 1/16" 15K Lubricator 5X or 6X - 10 ft bowen
connectoin, 50' or 60' total as necessary for tool length
100" Gooseneck
HR680 Injector Head
4 1/16" 10K Flow Cross, 2" 1502 10k Flanged
Valves
ϰϭͬϭϲΗƚŽƉĨůĂŶŐĞ ϭϱŬďŽǁĞŶ
4 1/16" 10K Combi BOPs
Blind/Shear Ram
Pipe/Slip Ram
API Crossover flange to bowen10K to 15K
API Flange Adapter 10K to 5K for riser/wellhead
CINGSA General Safety & Well Procedure
For Nitrogen Operations
Safety/Awareness While Working With Nitrogen & Stop Work Authority
To be reviewed prior to job with all personnel on location.
x Hold Pre-job safety meetings to discuss nitrogen asphyxiation awareness and note areas in
which nitrogen could accumulate and personnel can access.
x Recognize tank location and wind direction. Be aware of weather forecast/changes in wind
direction.
x Make certain ALL work personnel are informed of Stop Work Authority.
Safety Procedure While Working With Nitrogen
1. MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport.
2. Notify Pad Operator of upcoming nitrogen operations.
3. Hold pre-job safety meeting. Review vendor standard operating procedures, safety, and
appropriate Safety Data Sheets for all materials on location.
4. Record risks and mitigations plans. Confirm flow paths and safety barriers are in place.
NITROGEN DISPLACES OXYGEN. Make sure ALL personnel on location are aware of nitrogen
asphyxiation causes and signs and identify emergency muster location.
5. Spot N2 pumping unit and transport. Record N2 volumes in transport.
6. Rig up flow lines from N2 pumping unit to the well and returns to frac tank.
7. Place signs and placards warning of high pressure and nitrogen operations on location where
nitrogen could accumulate or be released.
8. Have pressure gauges downstream of liquid and nitrogen pumps to appropriately measure
tubing and casing pressures.
9. Set pressure gauges upstream and downstream of any check valves.
10. Ensure valve positions are in correct position.
11. Confirm 4-gas detection is on location, calibrated and tested to detect H2S/CO2/LEL/O2 levels
accurately.
12. Pressure test lines upstream of well to approved Sundry pressure or Maximum Potential
Surface Pressure (MSPS) (whichever is greater). Pressure test lines downstream of well at or
greater than MSPS. Visually inspect lines for any leaks.
13. Bleed off pressure and prepare for pumping nitrogen.
14. Pump nitrogen at desired rate, monitor rate and pressure. All nitrogen returns to be routed to
frac tank.
15. Once desired nitrogen levels have been achieved, isolate well from nitrogen pump unit and
bleed down lines between well and nitrogen pump unit.
16. Confirm lines are bled down, be aware of trapped pressure, and any accumulation of nitrogen.
Once confirmed begin rigging down nitrogen pump unit.
17. Note final rates, pressures, and volumes from the job. Record remaining nitrogen in transport.
18. Demob nitrogen pumping unit and transport.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 01/28/2025
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
Tested with 4.5 and 7 inch test joints. Tested h2s and lel alarms ( calibrated 11-2-24). PVT's all tested good as well as flow
paddle to 100%. Zero issues during testing. Rig was very squared away and crew worked efficiently.
Test Results
TEST DATA
Rig Rep:Robert BorganOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:Josh Drury
Rig Owner/Rig No.:Nordic 37 PTD#:2241060 DATE:11/3/2024
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopSTS241120111542
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 3
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 4 1/2"P
#2 Rams 1 7"P
#3 Rams 1 Blinds P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 2 3 1/8"P
Kill Line Valves 1 3 1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P2975
Pressure After Closure P1725
200 PSI Attained P21
Full Pressure Attained P105
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2400
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P17
#1 Rams P5
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9
9
9999
9
9
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 12/13/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
4-1/2" & 7" joints. Outermost kill FP-grease/cycle for a pass.
Test Results
TEST DATA
Rig Rep:Kelly/BorgenOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:LeBlanc/Drury
Rig Owner/Rig No.:Nordic 37 PTD#:2241060 DATE:10/24/2024
Type Operation:DRILL Annular:
250/2500Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopSAM241027214226
Inspector Austin McLeod
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 4-1/2"P
#2 Rams 1 7"P
#3 Rams 1 Blinds P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3-1/8"P
HCR Valves 2 3-1/8"P
Kill Line Valves 2 3-1/8"FP
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1700
200 PSI Attained P23
Full Pressure Attained P121
Blind Switch Covers:PAll stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2400
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P27
#1 Rams P5
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9 9
9999
9
9
9
FP
Outermost kill FP
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 12/20/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:2
Tested BOPE with 4 1/2" and 7" test joints. H2s and LEL were calibrated on 10/11, H2S in the pits initally did not give audible,
calibrate, retest, and pass. Variable rams failed, functioned and still failed. No other variables on location. Change out uppers
and lowers to 4 1/2" and 7" solids and retest. I did not witness the testing of either of the solid body rams. Charts of passing
tests attached to report.
Test Results
TEST DATA
Rig Rep:Nate WoodsOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:Joe LeBlanc
Rig Owner/Rig No.:Nordic 37 PTD#:2241060 DATE:10/13/2024
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopSTS241029103809
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 4 1/2" x 7"FP
#2 Rams 1 7"NT
#3 Rams 1 blinds P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 1 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1750
200 PSI Attained P21
Full Pressure Attained P111
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2400
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P FPH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P26
#1 Rams P4
#2 Rams P4
#3 Rams P5
#4 Rams P0
#5 Rams P0
#6 Rams P0
HCR Choke P2
HCR Kill P2
9999
9
9
9
9
9
9
9
FP
FP
H2S in the pits initally did not give audible
Variable rams failed
Charts of passing
tests attached to report.
did not witness the testing of either of the solid body rams
BOPE; Nordic Rig 37 – Component Retests
10/13/2024
Page 1 of 2
BOPE Test Charts – Nordic 37
CLU S-7 (PTD 2241060)
AOGCC Insp # bopSTS241029103809
10/13/2024
BOPE; Nordic Rig 37 – Component Retests
10/13/2024
Page 2 of 2
1
Gluyas, Gavin R (OGC)
From:McLellan, Bryan J (OGC)
Sent:Wednesday, August 21, 2024 10:43 AM
To:Isaacson, William
Cc:Regg, James B (OGC)
Subject:RE: New Permit Number 224-106 - CINGSA CLU Storage 7
Bill,
CINGSA has approval for initial and subsequent BOP tests to 3000 psi for well CLU Storage 7.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, August 21, 2024 10:37 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: New Permit Number 224-106
Bryan,
See below drawing… the red line and dots show where the test plug seals will sit in the head prior to the
installation of the 9-5/8” casing. This allows you to test the 3000 psi flange as part of the BOP test, otherwise there
is no way to test it, other than the upcoming casing test. The blue line and dots show where they will sit after the 9-
5/8” casing and pack-oƯ assembly have been installed.
2
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Wednesday, August 21, 2024 10:26 AM
To: Isaacson, William <wisaacson@asrcenergy.com>
Subject: RE: New Permit Number 224-106
Bill,
Where do you set the BOP test plug in this diagram? Hilcorp often sets the test plug above the 3k flange in similar
situations and leaves the OA valve open during the test in case the test plug leaks.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
3
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
4
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, August 21, 2024 9:00 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: FW: New Permit Number 224-106
Morning Bryan,
On the approved Permit to Drill it has listed that the initial BOP test needs to be performed to 5000 psi. However,
as noted in the supporting paperwork with the application, the wellhead flange between the upper and lower head
that will be exposed to this test pressure is only a 3000 psi rated flange, limiting this initial test to 3000 psi. The
request is to proceed with 3000 psi tests for the well, however if a 5000 psi test is required it could be performed
on a follow-up test after the 9-5/8” casing has been installed and this 3000 psi flange is isolated.
Regards,
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>
Sent: Tuesday, August 20, 2024 3:20 PM
To: Matthew.Federle@cingsa.com; Isaacson, William <wisaacson@asrcenergy.com>
Subject: New Permit Number 224-106
Hello,
Attached is the new Permit for CLU 7.
Thank you,
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.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
5
Grace Christianson
Executive Assistant,
Alaska Oil & Gas Conservation Commission
(907) 793-1230
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 Grace Christianson at (907-793-1230) or
(grace.christianson@alaska.gov).
1
Gluyas, Gavin R (OGC)
From:McLellan, Bryan J (OGC)
Sent:Wednesday, November 6, 2024 4:20 PM
To:Isaacson, William
Subject:RE: PTD #224-106 CLU Storage 7 - 9-5/8" Casing & 7" Liner Pressure Test
Bill,
CINGSA has approval to reduce the test pressure as described in your email below.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, November 6, 2024 2:01 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: PTD #224-106 CLU Storage 7 - 9-5/8" Casing & 7" Liner Pressure Test
Bryan,
As discussed earlier today, CINGSA would like to make a change to the value of a pressure test on the ongoing
CLU Storage 7 well. Below is a cut and paste from the Approved Permit to Drill. The original plan was to test the 9-
5/8” casing and 7” liner all to 3000 psi as outlined in step #1 below. The desire is to decrease the pressure test to
2500 psi. The original 3000 psi planned was a conservatively high value to cover a potential load case during
operating the well (tubing failure at surface with maximum injection pressure), however the 2500 psi will still cover
that load case, plus an additional 10% safety factor.
The 9-5/8” casing was tested to 3000 psi prior to drilling out the shoe, however the desire is to not expose it to
higher than required pressures if not necessary.
The remaining tests on the final wellbore will still be as planned below in steps 3 and 4. Please let me know if you
have any questions. Thanks
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.
2
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
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:McLellan, Bryan J (OGC)
To:Isaacson, William
Cc:Matthew Federle; Dewhurst, Andrew D (OGC); Roby, David S (OGC)
Subject:RE: PTD #224-106 CLU Storage 7 - 7" Production Liner
Date:Monday, November 4, 2024 12:36:00 PM
Attachments:image004.png
Bill,
CINGSA has approval to make the modification to the PTD as proposed in your email below.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Saturday, November 2, 2024 12:03 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: PTD #224-106 CLU Storage 7 - 7" Production Liner
Morning Bryan,
As we discussed yesterday, we reached TD on our 8-1/2” production hole on the CLUS-7 well
within the Sterling C Sand Gas Storage Pool. We encountered good reservoir sands within the
first ~700’ MD of the near horizontal section, however over the remaining ~750’ MD of section
only mudstone, claystone and coal sections were drilled. TD was called early versus the plan
due to no quality reservoirs sands being encountered.
We made an initial attempt to run the 7” liner to TD, however encountered tight hole and pack-
off issues within the intervals below the reservoir sands. The liner was pulled successfully and
a cleanout run made to TD. On the cleanout run we encountered significant problems across
that same non-reservoir section of the last ~750’ of the hole section. These problems have led
us to develop an alternative plan for not attempting to run the liner to TD, but only install it
across the C1 portion of the Sterling C reservoir sands. The entire 8-1/2” hole section that will
be left open below the 7” liner shoe is all within the Sterling C Sand Gas Storage Pool.
The following is the plan you and I had discussed yesterday as well as a high level schematic;
1. Run in with 4-1/2” DP to TD and spot a heavy 14.3 to 14.5 ppg mud pill from TD to up
above the planned set depth for the 7” liner shoe.
2. Pull up to the planned liner set depth and circulate out the excess heavy mud pill.
3. Run the 7” liner, placing the shoe at the base of the Sterling C1 Sand.
4. Cement the 7” liner with the planned 14.0 ppg Flexstone Cement back into the 9-5/8”
casing and to the 7” liner top.
5. Run completion as per original design.
Please let me know if you have any questions. Thanks
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483One Crew, One JourneyHonoring the values of our founders as we develop the future.
Philip Cerveny
Cook Inlet Natural Gas Storage Alaska, LLC
Consultant Geoscientist
(907) 227-2563
pcerveny@asrcenergy.com
1
October 23, 2024
Alaska Oil and Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave, Suite 100
Anchorage, Alaska 99501
RE: DATA TRANSMITTAL - WELL: CLU Storage 07
API: 50-133-20727-00-00
In support of the geologic sampling data reporting requirements associated with the CLUS-07 Well,
located in the Cannery Loop Storage Unit, Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) has
collected the samples listed below and is hereby transferring these samples to AOGCC.
224-106
1907
1908
1907
Philip Cerveny
Cook Inlet Natural Gas Storage Alaska, LLC
Consultant Geoscientist
(907) 227-2563
pcerveny@asrcenergy.com
2
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
1908
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.10.30 10:45:38 -08'00'
1
Gluyas, Gavin R (OGC)
From:Isaacson, William <wisaacson@asrcenergy.com>
Sent:Wednesday, October 23, 2024 10:57 AM
To:McLellan, Bryan J (OGC)
Subject:PTD #224-106 CLU Storage 7 - Production Casing Shoe FIT Results
Attachments:RE: PTD 224-106 - CLU Storage 07 FIT at 9-5/8" Casing Shoe; CLUS 7 Intermediate
Casing 9.25 test and FIT 10.23.24.pdf
Bryan,
Enclosed is a copy of the FIT that was performed at our 9-5/8” production casing shoe. This FIT was performed
after drilling 20’ of new hole below our 12-1/4” interval TD at 7570’ MD, which is back to the original contingency
plan as outlined in the email requesting the lower FIT value and per the drawing below.
Since our discussion last Friday, we were able to recover the fish from across the 9-5/8” shoe. We then were
planning for a short 7” scab liner across the coal below the 9-5/8” shoe, however after encountering minimal eƯort
to clean-out below the 9-5/8” shoe to the 12-1/14” TD, we reverted back to the plan to drill 8-1/2” hole to TD as per
the original design. Please let me know if you have any questions. Thanks
Bill Isaacson
Drilling Engineer
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.
2
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
1
Gluyas, Gavin R (OGC)
From:McLellan, Bryan J (OGC)
Sent:Thursday, October 10, 2024 6:16 PM
To:Isaacson, William
Cc:Rixse, Melvin G (OGC)
Subject:RE: PTD 224-106 - CLU Storage 07 FIT at 9-5/8" Casing Shoe
Bill,
The plan for a LOT to 10 ppg is approved.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Thursday, October 10, 2024 12:48 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: PTD 224-106 - CLU Storage 07 FIT at 9-5/8" Casing Shoe
Thanks Bryan, and yes later today works.
The 9-5/8” casing shoe is placed at 7504’ MD / 4955’ TVD
Kick zone is assumed to be deepest point in the well at 9377’ MD / 5149’ TVD
Drilling 8-1/2” hole with 200’ of 6.75” OD BHA and 4.5” DP
Below are the pore pressure estimates.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, October 10, 2024 6:23 AM
To: Isaacson, William <wisaacson@asrcenergy.com>
Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: RE: PTD 224-106 - CLU Storage 07 FIT at 9-5/8" Casing Shoe
Bill,
Please send me the actual depths, MD/TVD of casing shoe and copy Mel. I will have time to look at this at the end
of the day today if that works.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, October 9, 2024 10:33 PM
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
3
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: PTD 224-106 - CLU Storage 07 FIT at 9-5/8" Casing Shoe
Bryan,
As you are aware, the 9-5/8” casing was set short of our planned set depth by ~55’ MD / 16’ TVD, placing it just
above the top of the Sterling C in the Sterling B5 Coal, rather than just below the top of the Sterling C. This will
result in the B5 Coal being exposed below the casing shoe after drilling out.
Based upon the above, we have concerns with taking our FIT below the 9-5/8” shoe to the original planned 13.0
ppg EMW. The concerns are around exposing the B5 Coal to the high pressures swing that will result from the 13.0
ppg EMW FIT. The high pressures could fracture the coal, pushing fluid back into the coal and possibly
destabilizing the interval.
The original plan for the 13.0 ppg EMW was based on the results achieved during the drilling of the first 5 wells on
the pad (these were below the B5 Coal), however is not required for the successful drilling operation on the CLUS
07 well. The desire is to change the FIT to a lower value of 10.0 ppg EMW to reduce the possible breakdown and
destabilization. With the casing set immediately on top of the planned drilling interval, the 10.0 ppg FIT will still
provide an infinite kick tolerance while drilling the gas storage interval with the planned MW of 9.2 to 9.3 ppg.
Please let me know if are good with this change or have any questions or need additional information in your
consideration of this request.
Regards,
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
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.
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:CLUS 7 Date:10/11/2024
Csg Size/Wt/Grade:9 5/8 40# L-80 Supervisor:LeBlanc/Ackerman
Csg Setting Depth: 7504 TMD 4954 TVD
Mud Weight:9.2 ppg LOT / FIT Press = 235 psi
LOT / FIT =10.11 ppg Hole Depth = 7590 md
Fluid Pumped=0.6 Bbls Volume Back =0.6 bbls
Estimated Pump Output: Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Volume (bbls) Enter Pressure Enter Volume (bbls) Enter Pressure
Here Here Here Here
->0 0 ->0 0
->0.1 89 ->0.5 220
->0.2 130 ->1 482
->0.3 160 ->1.5 745
->0.4 190 ->2 1012
->0.5 210 ->2.5 1251
->0.6 240 ->3 1468
-> ->3.5 1726
-> ->4 1970
-> ->4.5 2220
-> ->5 2435
-> ->5.5 2690
-> ->6 2930
-> ->6.5 3160
-> ->6.75 3260
-> ->
-> ->
-> ->
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0 235 ->0 3158
->1 233 ->2 3150
->2 231 ->4 3144
->3 230 ->6 3140
->4 229 ->8 3136
->5 227 ->10 3133
->6 226 ->16 3124
->7 226 ->20 3118
->8 225 ->26 3112
->9 225 ->30 3110
->10 225 ->
-> ->
-> ->
-> ->
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
3100
3200
3300
3400
3500
0.00 1.00 2.00 3.00 4.00 5.00 6.00 7.00 8.00Pressure (psi)Volume (bblS)
LOT / FIT DATA CASING TEST DATA
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
3100
3200
3300
3400
3500
3600
3700
3800
3900
4000
0 5 10 15 20 25 30Pressure (psi)Time (Minutes)
LOT / FIT DATA CASING TEST DATA
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:McLellan, Bryan J (OGC)
To:Isaacson, William
Cc:Matthew Federle; Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Roby, David S (OGC)
Subject:RE: PTD #224-106 CLU Storage 7 - Operations Shutdown
Date:Friday, October 18, 2024 4:55:00 PM
Bill
CINGSA has approval to proceed with the operations shutdown procedure listed in your email
below. Follow up with a written sundry request for the Operations Shutdown within 3 days.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Friday, October 18, 2024 4:01 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: PTD #224-106 CLU Storage 7 - Operations Shutdown
Bryan,
As per our conversation, CINGSA is requesting a verbal approval of our plans for Operations
Shutdown on our current well CLU Storage 7. While cleaning out the 12-1/4” rathole below the
9-5/8” casing, the 8-1/2” drilling assembly packed-off and became stuck across the casing
shoe depth. We have backed-off above the BHA and are currently attempting to fish the BHA
with a fishing assembly, however progress has been minimal. We will continue with fishing
operations throughout the day, however if unable to recover the BHA we will be moving
forward with the below outline of work to prepare the well for a shutdown of operations.
CINGSA will be looking at plans to return to the well and sidetrack from the 9-5/8” casing and
resume operations to target the same bottom hole location, however the details will need to
be worked for this plan. If all equipment and materials can be obtained, the desire will be to
return to the well following drilling operations on CLU Storage 6.
Enclosed is wellbore schematic showing the current casing configuration, location of the fish
and the proposed plugging plan for the well. A variance to the requirements of 20 AAC 25.112
(b) of the regulations is being requested , to allow foregoing the placement of a cement plug
across the 9-5/8” shoe by either the displacement or down-squeeze methods. The 8-1/2” BHA
fish is stuck across the shoe eliminating the ability to spot a balanced plug. In addition,
pressures in excess of 1200 psi have been applied to the ~66’ of open hole section below the
9-5/8” shoe and there has been no injectivity possible and very little leak-off. The section of
open hole below the 9-5/8” shoe is entirely within the cap rock of the Sterling C Gas Pool and
no hydrocarbon intervals are exposed within that 66’ MD section.
Below is the proposed plan for operations shutdown and to isolate the open hole section
below the 9-5/8” shoe.
1. Run in hole with 9-5/8” bridge plug on drill pipe and set at ~7275’ MD, which is ~23’ MD
above the BHA fish. Set 15,000 lbs down weight on the plug to verify location and
integrity.
2. Pressure test the 9-5/8” casing and bridge plug to 2000 psi for 30 minutes.
3. Spot a minimum 200’ MD balanced 15.8 ppg cement plug immediately on top of the
bridge plug.
4. Pull above the plug and displace the 9-5/8” casing over to 8.9 ppg brine to surface.
5. Pull out of hole with drill pipe and freeze protect the well at 150’ MD/TVD back to
surface.
6. Land the 7” hanger in the wellhead with 1 joint of 7” hung-off below.
7. Nipple down the BOP and nipple up 7” adapter and dry hole tree.
8. Rig down and move Nordic 37 to CLU Storage 6.
Please let me know if you have any questions or require additional information. Thank you.
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483One Crew, One JourneyHonoring the values of our founders as we develop the future.
CLUStorage7
OperationsShutdownProposedCondition
20"ConductorPipe
136'MD/136'TVD
13Ͳ3/8"68#JͲ55BTC
2778'MD/2265'TVD
TailCementto~500'MDabove
Shoe&LeadCementtoSurface
9Ͳ5/8"40#LͲ80VAMTop
7504'MD/4954'TVD
Stage1:TailCementto~500'
MDaboveShoe&LeadCement
EstimatedTOCat~4000'MD
Stage2:LeadCementto
SurfacethroughESCementer,
withmudchanneltosurface
duetooverͲdisplacement.
9Ͳ5/8"ESCementerStageCollar
3450'MD/2597’TVD
12Ͳ1/4"OpenHole
7570'MD/4973’TVD
Fishat7298’to7514’MD
8Ͳ½”DrillingBHAconsistingofbit,motor,MWD,GR/RESLWD,NM
DC’sand2xHWDP
FormationTops:
SterlingB5Coal 7490’MD/4950'TVD
SterlingC7535’MD/4964’TVD
SterlingCGasStorageSands NotPenetrated
7"TubingHangerLandedinwellheadwith1jointoftubing
hungoffbelow.
9Ͳ5/8"BridgePlugsetaboveFishat~7275’MDand200'MD15.8
ppgcementplugplacedontop.
9Ͳ5/8"Casingleftwith8.9ppgbrine
and~150'MDdieselfreezeprotect
7"DryHoleTreeInstalled
10/18/2024
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 11/25/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:4
4.5" and 9 5/8" test joints used for testing. Test #1- the flange from the mudcross to the manual choke leaked. The nuts and
bolts were hand tight. Tightened bolts and retest for a pass. The gas alarms failed the audible portion of the test due to two
audible alarms for both H2S and LEL. One audible for the low and a totally different audible for the high. The audibles for the
low on both gasses were disabled and they passed the retest. There are 18 charge bottles for the accumulator system. Charge
bottle #18 had a bad bladder and was isolated and to be repaired. The other 17 bottles ranged from 975 psi to 1100 psi. 11
gallon bottles are in this system and with #18 isolated they still delivered more than required to operate the BOPs. Charge
bottle #18 failure is captured in Accumulator misc.
Test Results
TEST DATA
Rig Rep:J. Kelly/S StuckartOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:D. Ackerman/J. Drury
Rig Owner/Rig No.:Nordic 37 PTD#:2241060 DATE:9/24/2024
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopGDC240920170055
Inspector Guy Cook
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 11.5
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8" 5000 P
#1 Rams 1 4.5"x7" VBR P
#2 Rams 1 9 5/8" Solid P
#3 Rams 1 Blinds P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8" 5000 P
HCR Valves 2 3 1/8" 5000 P
Kill Line Valves 2 3 1/8" 5000 P
Check Valve 0 NA
BOP Misc 1 Mudcross fla FP
System Pressure P3000
Pressure After Closure P1700
200 PSI Attained P24
Full Pressure Attained P136
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2600
ACC Misc F1
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P FPMeth Gas Detector
P FPH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P22
#1 Rams P6
#2 Rams P5
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9999
9
9
9
9
9
9
9
mudcross to the manual choke leaked
gas alarms failed the audible portion of the test
Charge
bottle #18 had a bad bladder and was isolated and
FP
FP
FP
F
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 11/25/2024
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:6
Remarks:Function Test w 4.5 DP. All FP's were retests witnessed by myself, all failures witnessed by Guy Cook. Rig was in nice new condition. Remote
panel, gas alarms and strobes.
TEST DATA
Rig Rep:Nathan WoodsOperator:Cook Inlet Natural Gas Storage Alaska, LLC Operator Rep:Dennis Ackerman
Contractor/Rig No.:Nordic 37 PTD#:2241060 DATE:9/9/2024
Well Class:DEV Inspection No:divAGE240917104100
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
Test Time:1.5
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign FP
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:FP FP
Hydrogen Sulfide:FP FP
Gas Detectors Misc:0 NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?FP
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25 P
Hole Size:16 P
Vent Line(s) Size:16 P
Vent Line(s) Length:130 P
Closest Ignition Source:76.5 P
Outlet from Rig Substructure:115 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:NA
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:32 P
Knife Valve Open Time:10 P
Diverter Misc:0 NA
Systems Pressure:P3000
Pressure After Closure:P1800
200 psi Recharge Time:P16
Full Recharge Time:P96
Nitrogen Bottles (Number of):P4
Avg. Pressure:P2400
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
9
9 9
9
9
9
9
9
3RRUWHVWFRQVLGHULQJWKHQXPHURXVGHOD\VDQGDSUHYLRXV$2*&&
LQVSHFWLRQGD\VSULRUWRWKLVWHVW-5HJJ
FP FP
FP FP
FP FP
6
All FP's were retests witnessed by myself, all failures witnessed by Guy Cook
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-7
JBR 11/25/2024
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:9
Remarks:Access to the vent line was not properly blocked on two access points and they had no signs at these locations as well. No sign at the entrance
of the pad either. There was equipment staged in the exclusion/blast zone of the vent line that I informed them needed to be removed. The gas
alarms had several failures: They did not have different audibles for each gas although there were up to three different audibles going off each
time a detector was tested. The visual/strobes for the gas alarms were in the doghouse and not within the sight of the driller. The cellar LEL
detector needed to be calibrated to pass. The visual for methane was blue insead of red. Audibles could not be heard in the cellar and in other
locations on the rig. The remote panel at the drillers station for the accumulator did not work. After troubleshooting the system they found an
air valve closed and told me that was the issue. Before we could test for annular/knife times the electric motor for the accumulator stopped
working, so the drawdown and test times could not be done. Horrible test. They were clearly not ready. PLB – No corresponding operator
report submitted for 9/7/24; tested again on 9/9/24.
TEST DATA
Rig Rep:N. Sipes/R. BorgenOperator:Cook Inlet Natural Gas Storage Alaska, LLC Operator Rep:D. Ackerman/J. Leblanc
Contractor/Rig No.:Nordic 37 PTD#:2241060 DATE:9/7/2024
Well Class:DEV Inspection No:divGDC240903115113
Inspector Guy Cook
Inspector
Insp Source
Related Insp No:
Test Time:3
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign F
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:F FP
Hydrogen Sulfide:P F
Gas Detectors Misc:2 F
Designed to Avoid Freeze-up?P
Remote Operated Diverter?F
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25 P
Hole Size:16 P
Vent Line(s) Size:16 P
Vent Line(s) Length:133 P
Closest Ignition Source:88 P
Outlet from Rig Substructure:128 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:NA
Divert Valve(s) Full Opening:NT
Valve(s) Auto & Simultaneous:
Annular Closed Time:NT
Knife Valve Open Time:NT
Diverter Misc:2 F
Systems Pressure:NT
Pressure After Closure:NT
200 psi Recharge Time:NT
Full Recharge Time:NT
Nitrogen Bottles (Number of):NT
Avg. Pressure:NT
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
9
9
9
9
9
9
9
9
9
9
9
F
F FP
2 F
NT
NT
NT
NT
NT
NT
F
NT
NT
NT
F
Horrible test. They were clearly not ready
tested again on 9/9/24
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Mathew Federle
CINGSA Director
Cook Inlet Natural Gas Storage Alaska, LLC
PO Box 190989
Anchorage, AK, 99519
Re: Cannery Loop, Sterling C Pool, CLU Storage 7
Cook Inlet Natural Gas Storage Alaska, LLC
Permit to Drill Number: 224-106
Surface Location: 716' FNL 1610' FEL SEC 9 T5N R11W
Bottomhole Location: 730' FSL 236' FEL SEC 5 T5N R11W
DearMr. Federle:
Enclosed is the approved application for the permit to drill the above referenced well.
$OOGU\GLWFKVDPSOHVHWVVXEPLWWHGWRWKH$2*&&PXVWEHLQQRJUHDWHUWKDQIRRWVDPSOHLQWHUYDOV
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run
must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
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 AOGCCreserves 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 AOGCCspecifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC
order, or the terms and conditions of this permit may result in the revocation or suspension of the permit.
Sincerely,
Jessie /Chmielowski
Commissioner
DATED this20thday of August2024.
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2024.08.20
14:20:30 -08'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2.Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3.Address: 6.Proposed Depth: 12.Field/Pool(s):
MD:TVD:
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8.DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 15. Distance to Nearest Well Open
Surface: x- y- Zone- to Same Pool:
16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name:
Contact Email:
Contact Phone:
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Commission Use Only
See cover letter for other
requirements.
Perforation Depth MD (ft):
Authorized Title:
Authorized Signature:
Production
Liner
Intermediate
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Conductor/Structural
LengthCasing
Cement Quantity, c.f. or sacks
Cement Volume MDSize
Plugs (measured):
(including stage data)
18. Casing Program: Top - Setting Depth - BottomSpecifications
Total Depth MD (ft): Total Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Authorized Name:
ions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane,gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
See cover letter for other
requirements.
Permit Approval
Date:
API Number:to Drill
er:
Commission Use Only
Contact Name:
Contact Email:
Contact Phone:
Date:
hereby certify that the foregoing is true and the procedure approved herein will not be
ed from without prior written approval.
ized Title:
ized Signature:
ized Name:
tachments: Property Plat BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
ulic Fracture planned?Yes No
Perforation Depth TVD (ft):ation Depth MD (ft):
Liner
Production
ntermediate
Surface
ductor/Structural
TVDMDCementVolumeSizeLengthCasing
Junk (measured):Effect. Depth TVD (ft):Effect. Depth MD (ft):Plugs (measured):Total Depth TVD (ft):l Depth MD (ft):
PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)Y
(including stage data)MD TVDLength MD TVDCasing Weight Grade Couplinge
Cement Quantity, c.f. or sackssing Program:Top - Setting Depth - BottomSpecifications
viated wells:Kickoff depth:feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle:degrees Downhole:Surface:
cation of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft):15. Distance to Nearest Well Open
e: x- y-Zone-to Same Pool:GL / BF Elevation above MSL (ft):
ress:6.Proposed Depth:12.Field/Pool(s):
MD:TVD:
ocation of Well (Governmental Section):7. Property Designation:
e:
Productive Horizon:8.DNR Approval Number:13. Approximate Spud Date:
Depth:9. Acres in Property:14. Distance to Nearest Property:
rator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
pe of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp1c. Specify if well is proposed for:
Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
-XO\
Cook Inlet Natural Gas Storage Alaska, LLC
PO Box 190989, Anchorage, AK 99519
716' FNL 1610' FEL SEC 9 T5N R11W
958' FNL 487' FWL SEC 9 T5N R11W
730' FSL 236' FEL SEC 5 T5N R11W
281995.47 2392833.30 4
105639794
9351'5104'
ADL 391627
ADL 230925
1272
54.1
33.0
CLU Storage 7
Cannery Loop / Sterling C Pool
9/1/2024
1532' at TD
1277' (CLUS 1)
300
90 2223 psi 1728 psi
Driven 20" 133 X56 Welded 115' Surface Surface 136' 136' N/A
16" 13-3/8" 68 J-55 BTC 2771' Surface Surface 2792' 2251' 713 sxs lead, 378 sxs tail
12-1/4" 9-5/8" 40 L-80 VAM TOP 7441' Surface Surface 7462' 4959' 503/590sxs lead 1st/2nd, 176sxs tail
8-1/2" 7" 26 L-80 VAM TOP 2089' 7262' 4914' 9351' 5104' 228sxs tail
9-5/8" stage collar at 3500' MD
Matthew Federle
CINGSA Director
William Isaacson
wisaacson@asrcenergy.com
907-339-6455
✔
✔
✔
✔
✔✔
✔
✔
✔
✔
✔
By Grace Christianson at 12:04 pm, Jul 24, 2024
Provide 48 hrs notice for rig inspection prior to spud surface hole.
DSR-8/14/24
Variance to 25.412(b) approved to set production packer > 200' above perfs. see email attached for justification.
Submit FIT/LOT results within 48 hrs of performing test
Provide 24 hrs notice for AOGCC opportunity to witness
Annulus test to 1500 psi.
A.Dewhurst 16AUG24
Initial BOP test to 5000 psi. All annular tests to 2500 psi.
Subsequent BOP tests to 3000 psi.
BJM 8/19/24
50-133-20727-00-00224-106
*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.08.20 14:20:54 -08'00'
08/20/24
08/20/24
RBDMS JSB 082324
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
July 2024
Rev. 0
July 24, 2024
Mrs. Jessie Chmielowski, Commissioner
Mr. Greg Wilson, Commissioner
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Application for Permit to Drill
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA): CLU Storage 7
Dear Commissioners,
Cook Inlet Natural Gas Alaska, LLC (CINGSA), hereby applies for a Permit to Drill for the CLU Storage
7 gas storage injection well, located in Kenai, Alaska.
Please find attached for review of the Commission the 10-401 Form, Drilling & Completion Procedures,
Geological Information, Proposed Well Schematics, and Hazard Analysis, as required by 20 AAC 25.005.
Additional information includes MASP Calculations, Rig Layout, BOP & Choke Diagrams, as well as Mud,
Cement, and Directional Programs.
Nordic-Calista Rig 37x will be used to complete this work, commencing approximately September 1, 2024.
If you have any questions regarding the enclosed application, please contact William Isaacson at (907) 339-
6455 (office).
Sincerely,
Mathew Federle
CINGSA Director
y
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
July 2024
Rev. 0
Permit to Drill (10-401)
CLUS 7 (Cannery Loop Unit Storage 7)
Kenai, Alaska
July 2024
Prepared for
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 1 July 2024
Rev. 0
TABLE OF CONTENTS
Page
Table of Contents .......................................................................................................................................... 1
1.0CLU Storage 7 ................................................................................................................................. 3
1.1Well Summary .................................................................................................................. 3
1.2General Well Information ................................................................................................... 3
2.0Location Summary ........................................................................................................................... 3
2.1Well Trajectory & Proximity Risk ...................................................................................... 4
3.0Diverter System Information ........................................................................................................... 4
4.0Blowout Prevention Equipment Information ................................................................................... 4
5.0Drilling Hazard Analysis ................................................................................................................. 5
6.0Geologic Summary & Abnormal Pressure Formations ................................................................... 5
7.0Formation Integrity Test Procedure ................................................................................................. 6
8.0Casing & Cement Program .............................................................................................................. 7
9.0Drilling Fluid Program & Fluid System .......................................................................................... 8
10.0Evidence of Bonding........................................................................................................................ 8
11.0Proposed Drilling Program .............................................................................................................. 9
12.0Proposed Wellbore Schematic ....................................................................................................... 10
13.0Bottom Hole Assemblies & Well Trajectory ................................................................................. 11
14.0Drilling Waste Storage ................................................................................................................... 11
15.0Logging Plan .................................................................................................................................. 11
16.0Mud Logging Plan ......................................................................................................................... 12
17.0Regulatory Waivers and Special Procedures Requests .................................................................. 12
List of Tables
Table 2.0-1. Well Location Details ............................................................................................................... 3
Table 6.0-1. Geologic Formation Tops ......................................................................................................... 6
Table 9.0-1. Mud Program Detail - Surface Hole ......................................................................................... 8
Table 9.0-2. Mud Program Detail - Intermediate Hole ................................................................................. 8
Table 9.0-3. Mud Program Detail - Production Hole .................................................................................... 8
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 2 July 2024
Rev. 0
Table 9.0-4. Fluid System Equipment .......................................................................................................... 8
Table 13.0-1. BHA Program ....................................................................................................................... 11
Table 15.0-1. Logging Program – 16” Surface Hole .................................................................................. 11
Table 15.0-2. Logging Program – 12-¼” Intermediate Hole ...................................................................... 12
Table 15.0-3. Logging Program – 8-½” Production Hole ........................................................................... 12
List of Figures
Figure 12.0-1. Proposed Wellbore Schematic ............................................................................................ 10
List of Attachments
Attachment 1 – Cannery Loop Gas Storage Lease Map
Attachment 2 – As-Built Pad Design
Attachment 3 – Directional Program
Attachment 4 – Diverter Schematic
Attachment 5 – BOPE Schematic
Attachment 6 – Choke Manifold Schematic
Attachment 7 – Wellhead / Tree Schematic
Attachment 8 – Casing Design Program
Attachment 9 – Rig Equipment, Layout & Fluids System
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 3 July 2024
Rev. 0
1.0 CLU Storage 7
Requirements of 20 AAC 25.005(f)
1.1 Well Summary
Cook Inlet Natural Gas Storage Alaska LLC’s (“CINGSA”) is planning to drill two additional wells at the
underground natural gas storage facility in the City of Kenai, Alaska. The wells will be Cannery Loop Unit
Storage 6 and 7 (CLUS 6 & CLUS 7). The CLU Storage 7 well is planned as the first of the two (2) wells.
Drilling is slated to begin September 1, 2024 and the time required to drill and complete each well is
estimated at approximately 35 days (70 days total).
The overall objective of the program is to drill two (2) new gas storage wells into the Sterling C Sand Pool
in 2H of 2024. These wells will be in addition to the five (5) existing gas storage wells drilled from the pad
in 2011 – 2012 and will add to the ability of CINGSA to manage the varying gas demand in south central
Alaska. The two new wells will have a casing and completion design similar to the existing wells.
1.2 General Well Information
Reservoir Pressure / TVD: 2223 psi (7437’ MD / 4954’ TVD @ 0.449 psi/ft maximum)
MASP: 1728 psi (4954’ TVD with 0.10 psi/ft gas gradient to surface)
Wellhead Type/Pressure Rating: FMC – 3M x 5M psi - Wellhead Assembly
BOP Configuration: 13-5/8” 5M - Annular/Pipe Rams/Pipe Rams/Blind/Choke & Kill Line
Well Type: Service Well
Estimated Start Date: September 1, 2024
2.0 Location Summary
Requirements of 20 AAC 25.005(c)(2)
General Location Kenai, Alaska
Ground Elevation 33.0’ above MSL
KB Elevation 21.1’ above Ground Elevation
RKB 54.1’ above MSL
Table 2.0-1. Well Location Details
Date X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec / T / R
Surface Location 281995.470 2392833.300 716’ / 4564’ 1610’ / 3670’ Sec 9/T5N/R11W UM
Top of Production Zone 278816.690 2392648.780 958’ / 4322’ 4793’ / 487’ Sec 9/T5N/R11W UM
Bottom Hole Location 278122.910 2394349.750 4550’ / 730’ 236’ / 5044’ Sec 5/T5N/R11W UM
See Attachment 1: Cannery Loop Gas Storage Lease Map
See Attachment 2: As-Built Pad Design
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 4 July 2024
Rev. 0
2.1 Well Trajectory & Proximity Risk
Requirements of 20 AAC 25.005(c)(2) & (d)
At surface, the nearest existing wellbores to the planned CLUS 7 wellbore are the existing CINGSA wells
on the pad, with CLUS 5 being the closest at approximately 150 ft directly west. The surface hole will be
closely monitored for verticality and will kick-off at 300 ft and build to the south of CLUS 5 and all other
wells on the pad, therefore mitigating any shallow anti-collision concerns. As the CLUS 7 well profile
turns back to the north it passes either over or under the existing 5 CINGSA wells once they have all
diverged from each other and risk of intersection is minimum. The only wells which fall within 200’ of
any portion of the planned CLUS 7 wellbore are the existing CINGSA wells at surface. These wells and
all wells in the area were scanned and pass SLB major risk anti-collision rules.
See Attachment 3: Directional Program
3.0 Diverter System Information
Requirements of 20 AAC 25.005 (c)(7)
The diverter system has a working pressure of 2000 psi and a 16” diverter vent line.
See Attachment 4: Diverter Schematic
4.0 Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
BOP Configuration: 13-5/8” 5M BOPE - Annular/Pipe Rams/Pipe Rams/Blind/Choke & Kill Line
The BOP system of Nordic-Calista Rig 37x is rated at 5,000 psi working pressure, however, the wellhead
rated working pressure is 3000 psi on the lower flange and 5000 psi after the intermediate casing is installed.
The calculated maximum anticipated surface pressure in this well is 1728 psi, therefore the initial and all
subsequent BOP tests will test all equipment to 3000 psi, except the annular BOP which will be tested to
50% of its rated working pressure (~2500 psi). The stack is designed to comply with requirements for an
operation of 3000 psi or less, however an additional set of pipe rams will be installed to allow the inclusion
of the required casing rams for the operation. The BOPE will be tested every 14 days per 20 ACC 25.035.
See Attachment 5: BOPE Schematic
See Attachment 6: Choke Manifold Schematic
See Attachment 7: Wellhead / Tree Schematic
wells andyp p g
all wells in the area were scanned and pass SLB major risk anti-collision rules.
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 5 July 2024
Rev. 0
5.0 Drilling Hazard Analysis
Requirements of 20 AAC 25.005(c)(4)
Maximum Down Hole Pressure: = (0.052)*(8.63)*(4954’ TVD)
= 2223 psi
Maximum Anticipated Surface Pressure: = (2223) - (0.1 psi/ft * 4954’ TVD)
MASP: = 1728 psi
Kick Tolerance: 12-¼” Hole: 268 bbls with 9.2 ppg mud, a 14.0 ppg FIT at surface shoe
8-½” Hole: Infinite with 9.2 ppg mud, and a 13.0 ppg FIT at intermediate shoe
Abnormal Pressure: Abnormally pressured hazards are not anticipated in the drilling of CLUS
6 & 7 as based upon the historical drilling of other wells in the area and on
the CINGSA pad. See Geologic Prognosis for additional information.
Potential Oil & Gas Zones: No oil sands are expected to be encountered and the first potential gas zone
is the Sterling A at 3955’ TVDss. The potential for gas continues through
the Sterling B and will be encountered in the targeted Sterling C. The
Sterling A & B have a most likely pore pressure of a fresh water gradient
and the Sterling C may be slightly sub-normal with the potential for
isolated sand packages at original normal pressure gradient. Monitoring
the well for proper hole fill and indications of swabbing will be key.
Hydrogen Sulfide: H2S containing strata are not targeted in this well.
Potential Hole Problems: Surface: Minor Gravel Sloughing, Tight hole and Stuck Pipe.
Intermediate: Lost Circulation, Differential Sticking, Tight Hole & Stuck
Pipe due to Coals, and Directional Difficulties due to soft formations.
6.0 Geologic Summary & Abnormal Pressure Formations
Requirements of 20 AAC 25.005 (c)(9) & 20 AAC 25.071
The CINGSA gas storage reservoir interval is the Cannery Loop Sterling C Gas Pool, which is vertically
defined as the formations comprising the C1 and C2 sands. The pool is bound above by the B5 coal at the
base of the Sterling B sands and below by the Upper Beluga formation. The gross reservoir thickness
averages ~200’ across the pool area, and average net sand thickness is ~95’. The interval is comprised of
fluvial channel sandstones with interbedded silty sands and shales folded in a structural 4-way dip closure
and the original gas accumulation was charged by biogenic methane. The overlying Sterling A & B sands
are transient sands never tested and may contain gas.
Oil sands have not been encountered in the area across the targeted interval and are not expected in the
drilling of CLUS 6 & 7. Additionally, no abnormal gradients are expected. The original pressures within
the interval from surface through the Sterling Sands existed at a normal gradient. The initial 5 wells all
successfully drilled the overburden at mud weights in the 9.0-9.4 ppg range, and the Sterling C Pool was
significantly depleted at that time. The Sterling C is expected to be in the ~1950 psi (7.5 ppg) range at the
time of drilling CLUS 6 & 7, with the potential for isolated sand packages at original pressure.
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 6 July 2024
Rev. 0
Table 6.0-1. Geologic Formation Tops
7.0 Formation Integrity Test Procedure
Requirements of 20 AAC 25.005 (c)(5)
Surface casing shoe will be tested to a pre-determined equivalent mud weight. Prior to drilling out of casing
strings, test BOPs to the specified pressure listed in the BOP Program section, and casing to pressure listed
in Proposed Drilling Program section. Plot test and record volume required on the drilling report.
Formation Integrity tests (FIT) are to be conducted as described below:
• Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out
• Pull drill bit into the casing shoe and close pipe ram preventer. Line up to choke manifold with a closed choke
• Begin pumping fluid down the drill string at ½ bpm while recording casing & drill pipe pressures at ½ bbl intervals
• The Drill Site Manager will keep a running plot of pressure versus volume while the test is in progress
• Plot volume and pressure until the appropriate surface pressure is achieved for the FIT at the shoe.
• Shut down at the required surface pressure. Monitor and plot pressure drop and time after shut-in for a minimum
of 10 minutes or until the shut-in pressure stabilizes
• Bleed the pressure off and record the fluid volume recovered.
The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at
least 1.0 ppg higher than the EMW’s estimated for all planned cementing operations, and to allow for an
appropriate amount of kick tolerance in case well control measures are required.
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 7 July 2024
Rev. 0
8.0 Casing & Cement Program
Requirements of 20 AAC 25.005 (c)(6)
See Attachment 8: Casing Design Program
13-3/8” Surface Casing w/ Shoe at 2792’ MD
PreFlush / Spacer: 80 bbl 10.5 ppg MudPush II
Lead Slurry: Top of slurry: Surface
Extended Class G Cement, 12.0 ppg density
75% excess in open hole + excess to surface for stab-in job
Yield: 2.41 cu ft/sk
Volume: 306 bbls (713 sx) including excess
Tail Slurry: Top of slurry: 500’ MD above shoe
Class G Cement, 15.8 ppg density
75% excess in open hole + 80’ shoe track
Yield: 1.16 cu ft/sk
Volume: 78 bbls (378 sx) including excess & Shoe track
9-5/8” Intermediate Casing – 1st Stage w/ Shoe at 7462’ MD
PreFlush / Spacer: 50 bbl 10.7 ppg MudPush II
Lead Slurry: Top of slurry: At Stage Tool at 3500’ MD
Extended Class G Cement, 12.0 ppg density
15% excess in open hole + 100’ MD above stage collar
Yield: 2.41 cu ft/sk
Volume: 216 bbls (503 sx) including excess
Tail Slurry: Top of slurry: 700’ MD above shoe
FlexStone cement, 14.0 ppg density
15% excess in open hole + shoe track
Yield: 1.63 cu ft/sk
Volume: 51 bbls (176 sx) including excess & shoe track
9-5/8” Intermediate Casing – 2nd Stage w/ Stage Collar at ~3500’ MD
PreFlush / Spacer: 45 bbl 10.5 ppg MudPush II
Lead Slurry: Top of slurry: Surface
Extended Class G Cement, 12.0 ppg density
15% excess in open hole + cased hole + 30 bbls excess to surface
Yield: 2.41 cu ft/sk
Volume: 253 bbls (590 sx) including excess
7” Production Liner w/ Shoe at 9351’ MD and Liner Top at 7262’ MD
PreFlush / Spacer: 35 bbl 11.0 ppg MudPush II
Tail Slurry: Top of slurry: At 7” Liner Top
FlexStone cement, 14.0 ppg density
10% excess in open hole + liner lap + 150’ DP x Casing annulus + shoe track
Yield: 1.63 cu ft/sk
Volume: 66 bbls (228 sx) including excess & shoe track
Verified cement calcs. -bjm
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 8 July 2024
Rev. 0
9.0 Drilling Fluid Program & Fluid System
Requirements of 20 AAC 25.005 (c)(8)
See Attachment 9: Rig Equipment, Layout & Fluids System
Table 9.0-1. Mud Program Detail - Surface Hole
Interval Mud System Mud Wt
(ppg) PV YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
16” Gel Spud Mud 8.8-9.4 15-24 >30 <18 70-150 8.0-9.0 <6
Table 9.0-2. Mud Program Detail - Intermediate Hole
Interval Mud System Mud Wt
(ppg)
PV
(cP)
YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
12-¼” KLASHIELD 9.0-9.4 10-16 12-18 5-7 30-50 9.0-9.5 <6
Table 9.0-3. Mud Program Detail - Production Hole
Interval Mud System Mud Wt
(ppg)
PV
(cP)
YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
8-½” KLASHIELD 9.0-9.4 10-16 12-18 4-6 40-50 9.0-9.5 <6
Table 9.0-4. Fluid System Equipment
Item Equipment Specification
Shakers 3 Derrick Hyperpool shakers
Centrifuge Brandt HS-1960 Fully Variable Speed (external unit)
Mud Pit Capacity 920 bbls with 830 bbls usable & 23 bbl trip tank
10.0 Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Bond Number 105639794
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 9 July 2024
Rev. 0
11.0 Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
CONDUCTOR:
1. Drive/drill 20" conductor to ~140’ below ground (or refusal if earlier). Install 20" 2000# landing ring.
2. Move in and rig up rotary drilling rig.
3. Nipple up 21-¼", 2M diverter, 16" diverter valve, and 16" diverter line.
4. Function test diverter and diverter valve. Notify regulatory agencies 24 hours prior to test.
SURFACE:
1. Directionally Drill a 16" hole to surface hole TD, as per the directional plan.
2. RIH with 13-3/8" casing. Rig up false table and RIH with inner string and sting into stab-in float collar.
3. Cement 13-3/8" casing. Un-sting and circulate drill pipe clean. POH with inner string.
4. Lift riser, install 13-3/8” slips and cut off 13-3/8" casing. ND diverter.
5. Install and test 13-3/8" slip lock connection x 13-5/8" 5M flanged multi-bowl wellhead.
6. Nipple up 13-5/8" 5M BOP'S. Test BOP's and choke manifold to 250psi low / 3000 psi high. Notify
regulatory agencies 24 hours prior to test.
7. Set wear bushing. Make up 12-¼" BHA and RIH to shoe. Pressure test 13-3/8” Casing to 2000 psi.
INTERMEDIATE:
1. Drill out float equipment and make 20' of new hole. CBU.
2. Perform Formation Integrity Test to 14.0 ppg EMW.
3. Directional drill 12-¼" hole to intermediate hole TD as per directional program. Exact depth will be
determined by Geologist, with base plan as 25’ MD below Top Sterling C1 plus rat hole.
4. At TD circulate hole clean. Make wiper trip. Circulate hole clean and POH.
5. Run and cement 9-5/8" casing in two stages. Back out landing joint and set wear bushing.
PRODUCTION:
1. Pick up 8-½" bit and directional BHA. Drill out DV and pressure test casing to 3000 psi. Continue to RIH
and drill float equipment and 20' of new formation. CBU.
2. Perform Formation Integrity Test to 13.0 ppg EMW.
3. Directionally drill 8-½" hole to production hole TD as per the directional program. Note: exact TD will be
determined in real time from the top of Sterling C2 pick, targeting a minimum of 15' vertically above the
Beluga Sand formation.
4. At TD circulate hole clean. Make wiper trip as required. Circulate well clean. POH.
5. Rig up e-line unit and Run CBL.
6. Set Test Plug and test 4-½" x 7" variable rams if not done previously with 7" pipe.
7. Pick up 7" liner assembly (~200' Liner Lap) and RIH on drillpipe. Circulate and condition hole. Cement liner
according to program. Set hanger and liner top packer. Circulate casing and drill pipe clean. POH.
COMPLETION:
1. Pick up polish mill and RIH. Test liner, liner lap, and 9-5/8" casing to 3,000 psi for 30 minutes.
2. Polish seal bore extension and displace well to completion brine. POH laying down drill pipe.
3. Pull wear bushing. Pick up 7" seal assembly and RIH on tubing. Stab into Liner hanger polished bore
receptacle. Pressure up back side to 1000 psi confirming stab in.
4. Pick up and space out. Reverse in 8.7 ppg packer fluid. Stab into polished bore receptacle. Land and test
hanger seals and Annulus to 1,500 psi. Test tubing to 3,000 psi.
5. Back out landing joint. Set BPV. ND BOPs.
6. NU adapter assembly and tree. Test to 5,000 psi.
7. Rig down and move out drilling rig.
Note: Perforating will be done post rig with coiled tubing.
Provide 24 hrs notice for AOGCC opportunity to witness
Annulus test to 1500 psi. -bjm
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 10 July 2024
Rev. 0
12.0 Proposed Wellbore Schematic
Figure 12.0-1. Proposed Wellbore Schematic
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 11 July 2024
Rev. 0
13.0 Bottom Hole Assemblies & Well Trajectory
Table 13.0-1. BHA Program
16” Surface BHA 12-¼” Drilling BHA 8-½” Drilling BHA
Mill Tooth Bit
Motor
arcVISION (GR/Res)
TeleScope (MWD)
NMDC
HWDP
Jar
HWDP
Drillpipe
PDC Bit
RSS
arcVISION (GR/Res)
TeleScope (MWD)
ADN (Den/Neu)
NMDC
HWDP
Jar
HWDP
Drillpipe
PDC Bit
RSS
arcVISION (GR/Res)
proVISION (NMR)
TeleScope (MWD)
ADN (Den/Neu)
NMDC
HWDP
Jar
HWDP
Drillpipe
14.0 Drilling Waste Storage
Requirements of 20 AAC 25.005 (c)(14)
Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and
fluids will be disposed of in either:
Hilcorp Alaska’s Kenai Grind & Inject Facility or Alaska Eco Resources Nikiski Monofill Cell Facility
Cuttings vac boxes or totes will be used to deliver cuttings and entrained fluids to the G&I or Monofill
facility, while Vac trucks will transport bulk fluids. Disposal will be per the agreement between CINGSA
and Hilcorp and/or Alaska Eco Resources. Every load will be manifested prior to leaving location in
accordance with CINGSA and receiving facility manifest requirements.
CINGSA will not request authorization under 20 AAC 25.080 for an Annular Disposal Operation.
15.0 Logging Plan
Requirements of 20 AAC 25.071 (a)
Table 15.0-1. Logging Program – 16” Surface Hole
Type BHA Details
Drilling GR/Resistivity
Open Hole None
Cased Hole None
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 12 July 2024
Rev. 0
Table 15.0-2. Logging Program – 12-¼” Intermediate Hole
Type BHA Details
Drilling GR/Resistivity/Neutron/Density
Open Hole None
Cased Hole CBL
Table 15.0-3. Logging Program – 8-½” Production Hole
Type BHA Details
Drilling GR/Resistivity/Neutron/Density/Magnetic Resonance
Open Hole None
Cased Hole None
16.0 Mud Logging Plan
A four-man mud logging crew (2 mud loggers & 2 sample catchers) will be on location, rigged up, and
logging from below the surface casing shoe through TD of the production hole section.
x Gas chromatography
x Dry cuttings samples (30’ intervals)
x Wet cuttings samples (30’ intervals)
17.0 Regulatory Waivers and Special Procedures Requests
(1) AOGCC 20 AAC 25.412 (b)… The packer must be placed within 200 feet measured depth above
the top of the perforations, unless the commission approves a different placement depth as the
commission considers appropriate given the thickness and depth of the confining zone.
CINGSA requests to increase the distance between the packer and top perforations to 400' MD for this
well. The 9-5/8” intermediate casing string will be cemented into the top of the Sterling C, however,
the expected top perforations may be 100 to 150’ MD below the 9 5/8" shoe. The exact location will
not be known until the logs are processed. The liner lap is designed to be 200' MD to provide optimal
liner lap isolation with cement. The packer is planned as a BakerHughes ZXP liner top packer.
CINGSA believes the primary isolation of injection to the reservoir is the ~500-700' of high
compressive strength premium cement used for the tail slurry of the 9 5/8" cement job. Secondary
protection is the cemented 7" liner with calculated top of cement above the liner top. Tertiary protection
is then provided by the liner top packer.
Variance request is approved. The liner top packer will be set within the confining
zone for the Sterling Gas pool (see attached email from William Isaacson dated 8/6/24.
-bjm
Please note the data submission
requirements of 20 AAC 25.071(b)(1-2).
-A.Dewhurst 14AUG24
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 13 July 2024
Rev. 0
Attachment 1 – Cannery Loop Gas Storage Lease Map
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 14 July 2024
Rev. 0
Attachment 2 – As-Built Pad Design
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 15 July 2024
Rev. 0
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 16 July 2024
Rev. 0
Attachment 3 – Directional Program
CLU S-7 wp16.1 Trajectory Proposal Geodetic ReportNon-Def PlanCommentsMD(ft)Incl(°)Azim(°)TVDSS(ft)TVD(ft)VSEC(ft)NS(ft)EW(ft)GTF(°)DLS(°/100ft)Directional Difficulty IndexExclusion Zone AlertExclusion Zone Angle(°)GeoMag Th(nT)Northing(ftUS)Easting(ftUS)RTE 0.00 0.00 0.00 -54.08 0.00 0.00 0.00 0.00 HS 0.00 16.57 15,706.07 2,392,833.47 281,995.30100.00 0.00 220.00 45.92 100.00 0.00 0.00 0.00 HS 0.00 0.00 16.57 15,706.07 2,392,833.47 281,995.30200.00 0.00 220.00 145.92 200.00 0.00 0.00 0.00 HS 0.00 0.00 16.57 15,706.07 2,392,833.47 281,995.30KOP Crv 1.5/100 300.00 0.00 220.00 245.92 300.00 0.00 0.00 0.00 HS 0.00 0.00 16.57 15,706.07 2,392,833.47 281,995.30400.00 1.50 220.00 345.91 399.99 0.44 -1.00 -0.84 HS 1.50 0.29 17.93 16,954.33 2,392,832.48 281,994.44Crv 3/100 500.00 3.00 220.00 445.83 499.91 1.76 -4.01 -3.36 0.13R 1.50 1.20 19.31 18,211.30 2,392,829.52 281,991.86600.00 6.00 220.06 545.51 599.59 4.41 -10.02 -8.41 0.06R 3.00 1.90 22.11 20,731.14 2,392,823.61 281,986.71700.00 9.00 220.08 644.64 698.72 8.82 -20.00 -16.81 0.04R 3.00 2.37 24.96 23,239.54 2,392,813.78 281,978.12800.00 12.00 220.09 742.96 797.04 14.98 -33.94 -28.55 HS 3.00 2.73 27.84 25,716.36 2,392,800.06 281,966.13900.00 15.00 220.10 840.18 894.26 22.87 -51.80 -43.58 HS 3.00 3.01 30.74 28,146.33 2,392,782.49 281,950.771,000.00 18.00 220.11 936.05 990.13 32.48 -73.52 -61.88 HS 3.00 3.24 33.65 30,517.16 2,392,761.11 281,932.081,100.00 21.00 220.11 1,030.31 1,084.39 43.77 -99.05 -83.38 HS 3.00 3.44 36.58 32,818.45 2,392,735.98 281,910.121,200.00 24.00 220.11 1,122.68 1,176.76 56.72 -128.31 -108.03 HS 3.00 3.61 39.52 35,041.11 2,392,707.17 281,884.931,300.00 27.00 220.11 1,212.93 1,267.01 71.29 -161.23 -135.76 HS 3.00 3.77 42.46 37,177.03 2,392,674.77 281,856.601,400.00 30.00 220.11 1,300.80 1,354.88 87.44 -197.72 -166.50 HS 3.00 3.90 45.41 39,218.83 2,392,638.86 281,825.191,500.00 33.00 220.12 1,386.06 1,440.14 105.12 -237.67 -200.17 HS 3.00 4.03 48.37 41,159.75 2,392,599.53 281,790.801,600.00 36.00 220.12 1,468.46 1,522.54 124.29 -280.98 -236.66 HS 3.00 4.14 51.33 42,993.59 2,392,556.90 281,753.521,700.00 39.00 220.12 1,547.79 1,601.87 144.90 -327.53 -275.88 HS 3.00 4.25 54.29 44,714.61 2,392,511.09 281,713.451,800.00 42.00 220.12 1,623.82 1,677.90 166.88 -377.19 -317.72 HS 3.00 4.35 57.25 46,317.53 2,392,462.21 281,670.711,900.00 45.00 220.12 1,696.35 1,750.43 190.18 -429.82 -362.07 HS 3.00 4.44 60.22 47,797.52 2,392,410.40 281,625.402,000.00 48.00 220.12 1,765.18 1,819.26 214.74 -485.29 -408.81 HS 3.00 4.52 63.19 49,150.14 2,392,355.81 281,577.652,100.00 51.00 220.12 1,830.11 1,884.19 240.48 -543.43 -457.80 HS 3.00 4.61 66.16 50,371.41 2,392,298.58 281,527.602,200.00 54.00 220.12 1,890.98 1,945.06 267.34 -604.09 -508.92 HS 3.00 4.68 69.13 51,457.74 2,392,238.88 281,475.372,300.00 57.00 220.12 1,947.62 2,001.70 295.24 -667.10 -562.02 HS 3.00 4.76 72.11 52,405.95 2,392,176.86 281,421.12End Crv 2,392.25 59.77 220.12 1,995.97 2,050.05 321.84 -727.17 -612.64 HS 3.00 4.82 74.85 53,155.80 2,392,117.74 281,369.412,400.00 59.77 220.12 1,999.87 2,053.95 324.11 -732.29 -616.96 HS 0.00 4.83 74.85 53,155.80 2,392,112.70 281,365.002,500.00 59.77 220.12 2,050.23 2,104.31 353.36 -798.35 -672.64 HS 0.00 4.87 74.85 53,155.80 2,392,047.67 281,308.122,600.00 59.77 220.12 2,100.58 2,154.66 382.61 -864.42 -728.31 HS 0.00 4.91 74.85 53,155.80 2,391,982.64 281,251.242,700.00 59.77 220.12 2,150.93 2,205.01 411.87 -930.49 -783.99 HS 0.00 4.95 74.85 53,155.80 2,391,917.61 281,194.3613.375 in Casing 2,792.25 59.77 220.12 2,197.38 2,251.46 438.86 -991.43 -835.35 HS 0.00 4.98 74.85 53,155.80 2,391,857.62 281,141.892,800.00 59.77 220.12 2,201.28 2,255.36 441.12 -996.55 -839.67 HS 0.00 4.99 74.85 53,155.80 2,391,852.58 281,137.482,900.00 59.77 220.12 2,251.63 2,305.71 470.38 -1,062.62 -895.34 HS 0.00 5.02 74.85 53,155.80 2,391,787.55 281,080.603,000.00 59.77 220.12 2,301.98 2,356.06 499.63 -1,128.69 -951.02 HS 0.00 5.05 74.85 53,155.80 2,391,722.53 281,023.723,100.00 59.77 220.12 2,352.33 2,406.41 528.89 -1,194.76 -1,006.70 HS 0.00 5.08 74.85 53,155.80 2,391,657.50 280,966.843,200.00 59.77 220.12 2,402.68 2,456.76 558.14 -1,260.82 -1,062.37 HS 0.00 5.11 74.85 53,155.80 2,391,592.47 280,909.963,300.00 59.77 220.12 2,453.03 2,507.11 587.40 -1,326.89 -1,118.05 HS 0.00 5.14 74.85 53,155.80 2,391,527.44 280,853.08Crv 3/100 3,351.17 59.77 220.12 2,478.80 2,532.88 602.37 -1,360.69 -1,146.54 129.37R 0.00 5.15 74.85 53,155.80 2,391,494.17 280,823.973,400.00 58.84 221.45 2,503.72 2,557.80 617.04 -1,392.49 -1,173.97 128.7R 3.00 5.17 73.78 52,878.73 2,391,462.88 280,795.973,500.00 57.00 224.24 2,556.84 2,610.92 649.45 -1,454.62 -1,231.55 127.22R 3.00 5.22 71.62 52,259.34 2,391,401.83 280,737.253,600.00 55.22 227.15 2,612.61 2,666.69 684.98 -1,512.61 -1,290.93 125.59R 3.00 5.26 69.47 51,573.71 2,391,344.94 280,676.823,700.00 53.51 230.18 2,670.88 2,724.96 723.52 -1,566.29 -1,351.92 123.83R 3.00 5.30 67.36 50,826.85 2,391,292.39 280,614.853,800.00 51.88 233.35 2,731.49 2,785.57 764.97 -1,615.53 -1,414.37 121.91R 3.00 5.33 65.28 50,024.39 2,391,244.32 280,551.513,900.00 50.34 236.66 2,794.28 2,848.36 809.22 -1,660.18 -1,478.10 119.83R 3.00 5.37 63.24 49,172.61 2,391,200.85 280,486.984,000.00 48.90 240.11 2,859.07 2,913.15 856.14 -1,700.12 -1,542.93 117.59R 3.00 5.40 61.24 48,278.51 2,391,162.11 280,421.424,100.00 47.57 243.71 2,925.69 2,979.77 905.61 -1,735.25 -1,608.70 115.19R 3.00 5.43 59.30 47,349.76 2,391,128.20 280,355.024,200.00 46.35 247.47 2,993.96 3,048.04 957.49 -1,765.46 -1,675.22 112.63R 3.00 5.46 57.40 46,394.76 2,391,099.22 280,287.964,300.00 45.26 251.37 3,063.68 3,117.76 1,011.63 -1,790.68 -1,742.31 109.91R 3.00 5.49 55.57 45,422.67 2,391,075.24 280,220.424,400.00 44.31 255.41 3,134.67 3,188.75 1,067.90 -1,810.83 -1,809.78 107.04R 3.00 5.51 53.81 44,443.36 2,391,056.33 280,152.60Grid Scale Factor:Version / Patch:Well HeadLocal Coord Referenced To:14.001°Magnetic Declination:Declination Date:0.99995408(Applied)Magnetic Declination Model:60°32'39.04111"N , 151°12'39.17905"WTort / AHD / DDI / ERD Ratio:CRS Grid Convergence Angle:July 30, 2024Location Lat / Long:-1.054°N 2392833.470 ftUS , E 281995.300 ftUSLocation Grid N/E Y/X:NAD27 Alaska State Plane, Zone 04, US Feet231.613 ° / 6893.796 ft / 6.466 / 1.351Coordinate Reference System:Survey Name:CLU S-7 wp16.1 TrajectorySurvey Date:API#:CLU S-7Structure / Slot:Well:Borehole:CLU S-7Cannery Loop Unit / CLU S-7Minimum Curvature / Lubinski290.330 °(TRUE North)0.000 ft, 0.000 ftRKBSurvey / DLS Computation:TVD Reference Datum:Vertical Section Azimuth:Vertical Section Origin:Report Date:Alaska - Kenai UnitClient:CINGSAJuly 30, 2024 - 10:35 PM ( UTC 0 )54.080 ft above MSLTVD Reference Elevation:Ground Elevation:33.000 ft above MSLField:Total Gravity Field Strength:1001.1859mgn (9.80665 Based)Total Corr Mag North->True North:Gravity Model:55069.864 nTGARMTotal Magnetic Field Strength:Magnetic Dip Angle:North Reference:73.429°August 01, 2024BGGM 2024True North0°14.001°Grid Convergence Used:2024.4.0.4
CommentsMD(ft)Incl(°)Azim(°)TVDSS(ft)TVD(ft)VSEC(ft)NS(ft)EW(ft)GTF(°)DLS(°/100ft)Directional Difficulty IndexExclusion Zone AlertExclusion Zone Angle(°)GeoMag Th(nT)Northing(ftUS)Easting(ftUS)4,500.00 43.51 259.57 3,206.73 3,260.81 1,126.13 -1,825.87 -1,877.44 104.04R 3.00 5.54 52.12 43,467.44 2,391,042.55 280,084.674,600.00 42.86 263.86 3,279.67 3,333.75 1,186.16 -1,835.74 -1,945.13 100.91R 3.00 5.56 50.52 42,506.20 2,391,033.92 280,016.824,700.00 42.37 268.23 3,353.28 3,407.36 1,247.84 -1,840.42 -2,012.64 97.69R 3.00 5.59 49.02 41,571.54 2,391,030.48 279,949.244,800.00 42.06 272.67 3,427.36 3,481.44 1,310.99 -1,839.90 -2,079.79 94.4R 3.00 5.61 47.61 40,675.90 2,391,032.24 279,882.114,900.00 41.91 277.15 3,501.71 3,555.79 1,375.44 -1,834.18 -2,146.40 91.07R 3.00 5.63 46.33 39,832.02 2,391,039.18 279,815.625,000.00 41.94 281.64 3,576.12 3,630.20 1,441.01 -1,823.28 -2,212.29 87.73R 3.00 5.65 45.17 39,052.81 2,391,051.29 279,749.945,100.00 42.15 286.11 3,650.40 3,704.48 1,507.52 -1,807.23 -2,277.27 84.41R 3.00 5.68 44.14 38,350.98 2,391,068.54 279,685.275,200.00 42.53 290.53 3,724.33 3,778.41 1,574.80 -1,786.06 -2,341.17 81.14R 3.00 5.70 43.26 37,738.74 2,391,090.88 279,621.775,300.00 43.07 294.87 3,797.72 3,851.80 1,642.65 -1,759.84 -2,403.82 77.96R 3.00 5.72 42.53 37,227.36 2,391,118.24 279,559.625,400.00 43.78 299.11 3,870.37 3,924.45 1,710.89 -1,728.64 -2,465.03 74.87R 3.00 5.74 41.97 36,826.76 2,391,150.56 279,499.005,500.00 44.63 303.24 3,942.07 3,996.15 1,779.33 -1,692.55 -2,524.65 71.92R 3.00 5.76 41.58 36,545.01 2,391,187.74 279,440.065,600.00 45.64 307.23 4,012.63 4,066.71 1,847.79 -1,651.66 -2,582.50 69.1R 3.00 5.78 41.36 36,388.01 2,391,229.69 279,382.975,700.00 46.77 311.08 4,081.85 4,135.93 1,916.07 -1,606.09 -2,638.44 66.44R 3.00 5.80 41.32 36,359.08 2,391,276.28 279,327.885,800.00 48.03 314.78 4,149.55 4,203.63 1,984.00 -1,555.95 -2,692.30 63.93R 3.00 5.82 41.46 36,458.85 2,391,327.39 279,274.955,900.00 49.40 318.33 4,215.54 4,269.62 2,051.38 -1,501.40 -2,743.95 61.59R 3.00 5.83 41.77 36,685.18 2,391,382.89 279,224.326,000.00 50.88 321.73 4,279.63 4,333.71 2,118.03 -1,442.57 -2,793.23 59.41R 3.00 5.85 42.26 37,033.30 2,391,442.61 279,176.136,100.00 52.45 324.98 4,341.66 4,395.74 2,183.77 -1,379.64 -2,840.02 57.39R 3.00 5.87 42.91 37,496.08 2,391,506.39 279,130.516,200.00 54.11 328.10 4,401.46 4,455.54 2,248.41 -1,312.76 -2,884.18 55.52R 3.00 5.89 43.73 38,064.37 2,391,574.06 279,087.596,300.00 55.85 331.09 4,458.85 4,512.93 2,311.79 -1,242.13 -2,925.59 53.81R 3.00 5.91 44.69 38,727.45 2,391,645.44 279,047.496,400.00 57.65 333.96 4,513.69 4,567.77 2,373.72 -1,167.94 -2,964.15 52.24R 3.00 5.93 45.79 39,473.48 2,391,720.32 279,010.306,500.00 59.52 336.71 4,565.81 4,619.89 2,434.03 -1,090.39 -2,999.74 50.8R 3.00 5.95 47.02 40,289.92 2,391,798.51 278,976.156,600.00 61.44 339.36 4,615.09 4,669.17 2,492.57 -1,009.70 -3,032.27 49.5R 3.00 5.97 48.37 41,163.92 2,391,879.79 278,945.116,700.00 63.41 341.91 4,661.38 4,715.46 2,549.17 -926.08 -3,061.64 48.32R 3.00 5.99 49.83 42,082.63 2,391,963.93 278,917.286,800.00 65.43 344.37 4,704.55 4,758.63 2,603.67 -839.77 -3,087.79 47.25R 3.00 6.01 51.39 43,033.44 2,392,050.70 278,892.736,900.00 67.49 346.75 4,744.50 4,798.58 2,655.93 -751.00 -3,110.63 46.3R 3.00 6.03 53.04 44,004.21 2,392,139.87 278,871.537,000.00 69.57 349.07 4,781.10 4,835.18 2,705.80 -660.01 -3,130.10 45.45R 3.00 6.05 54.77 44,983.35 2,392,231.20 278,853.747,100.00 71.69 351.32 4,814.27 4,868.35 2,753.15 -567.06 -3,146.15 44.71R 3.00 6.07 56.57 45,959.95 2,392,324.43 278,839.407,200.00 73.84 353.52 4,843.90 4,897.98 2,797.84 -472.39 -3,158.74 44.06R 3.00 6.09 58.44 46,923.79 2,392,419.30 278,828.557,300.00 76.00 355.67 4,869.91 4,923.99 2,839.76 -376.28 -3,167.83 43.5R 3.00 6.11 60.36 47,865.41 2,392,515.57 278,821.23End Crv 7,386.83 77.90 357.50 4,889.52 4,943.60 2,873.82 -291.84 -3,172.87 HS 3.00 6.13 62.08 48,658.22 2,392,600.07 278,817.757,400.00 77.90 357.50 4,892.28 4,946.36 2,878.81 -278.98 -3,173.43 HS 0.00 6.13 62.08 48,658.22 2,392,612.94 278,817.43Target 7,436.83 77.90 357.50 4,900.00 4,954.08 2,892.79 -243.00 -3,175.00 HS 0.00 6.13 62.08 48,658.22 2,392,648.95 278,816.52Top Sterling C1 7,436.83 77.90 357.50 4,900.00 4,954.08 2,892.79 -243.00 -3,175.00 HS 0.00 6.13 62.08 48,658.22 2,392,648.95 278,816.529.625 in Casing 7,461.83 77.90 357.50 4,905.24 4,959.32 2,902.27 -218.58 -3,176.07 HS 0.00 6.13 62.08 48,658.22 2,392,673.38 278,815.907,500.00 77.90 357.50 4,913.24 4,967.32 2,916.75 -181.30 -3,177.69 HS 0.00 6.14 62.08 48,658.22 2,392,710.69 278,814.96Crv 3/100 7,511.83 77.90 357.50 4,915.72 4,969.80 2,921.24 -169.74 -3,178.20 16R 0.00 6.14 62.08 48,658.22 2,392,722.25 278,814.677,600.00 80.44 358.24 4,932.28 4,986.36 2,954.32 -83.21 -3,181.42 15.86R 3.00 6.16 64.55 49,724.02 2,392,808.82 278,813.04Crv 3/100 7,666.83 82.37 358.79 4,942.27 4,996.35 2,978.88 -17.15 -3,183.13 82.59L 3.00 6.17 66.42 50,472.42 2,392,874.90 278,812.557,700.00 82.50 357.80 4,946.63 5,000.71 2,991.21 15.71 -3,184.11 82.45L 3.00 6.18 66.63 50,553.62 2,392,907.77 278,812.187,800.00 82.91 354.80 4,959.34 5,013.42 3,031.60 114.68 -3,190.51 82.07L 3.00 6.20 67.32 50,810.08 2,393,006.84 278,807.597,900.00 83.33 351.81 4,971.32 5,025.40 3,076.71 213.28 -3,202.09 81.72L 3.00 6.22 68.06 51,081.60 2,393,105.62 278,797.838,000.00 83.77 348.82 4,982.56 5,036.64 3,126.41 311.21 -3,218.80 81.38L 3.00 6.24 68.86 51,365.00 2,393,203.85 278,782.928,100.00 84.23 345.84 4,993.02 5,047.10 3,180.57 408.23 -3,240.61 81.07L 3.00 6.25 69.72 51,657.01 2,393,301.24 278,762.908,200.00 84.70 342.86 5,002.66 5,056.74 3,239.04 504.07 -3,267.46 80.78L 3.00 6.27 70.63 51,954.29 2,393,397.55 278,737.838,300.00 85.19 339.89 5,011.48 5,065.56 3,301.65 598.45 -3,299.26 80.52L 3.00 6.29 71.60 52,253.55 2,393,492.50 278,707.778,400.00 85.69 336.93 5,019.43 5,073.51 3,368.25 691.13 -3,335.94 80.28L 3.00 6.31 72.61 52,551.48 2,393,585.83 278,672.808,500.00 86.20 333.96 5,026.50 5,080.58 3,438.63 781.85 -3,377.39 80.07L 3.00 6.33 73.66 52,844.89 2,393,677.29 278,633.03Top Sterling C2 8,588.30 86.66 331.35 5,032.00 5,086.08 3,503.78 860.12 -3,417.87 79.91L 3.00 6.34 74.62 53,097.69 2,393,756.29 278,594.008,600.00 86.72 331.00 5,032.68 5,086.76 3,512.62 870.35 -3,423.50 79.89L 3.00 6.35 74.75 53,130.64 2,393,766.63 278,588.568,700.00 87.25 328.05 5,037.93 5,092.01 3,590.01 956.41 -3,474.14 79.74L 3.00 6.36 75.88 53,405.77 2,393,853.60 278,539.518,800.00 87.79 325.09 5,042.25 5,096.33 3,670.58 1,039.77 -3,529.18 79.61L 3.00 6.38 77.04 53,667.44 2,393,937.96 278,486.028,900.00 88.34 322.14 5,045.63 5,099.71 3,754.12 1,120.22 -3,588.46 79.51L 3.00 6.40 78.24 53,913.01 2,394,019.48 278,428.239,000.00 88.88 319.19 5,048.06 5,102.14 3,840.39 1,197.54 -3,651.82 79.44L 3.00 6.42 79.46 54,140.01 2,394,097.94 278,366.319,100.00 89.44 316.24 5,049.53 5,103.61 3,929.17 1,271.50 -3,719.09 79.39L 3.00 6.43 80.70 54,346.20 2,394,173.13 278,300.419,200.00 89.99 313.29 5,050.03 5,104.11 4,020.20 1,341.91 -3,790.08 79.38L 3.00 6.45 81.97 54,529.59 2,394,244.83 278,230.73End Crv 9,204.36 90.01 313.16 5,050.03 5,104.11 4,024.22 1,344.90 -3,793.26 HS 3.00 6.45 82.02 54,537.04 2,394,247.87 278,227.619,300.00 90.01 313.16 5,050.01 5,104.09 4,112.36 1,410.32 -3,863.02 HS 0.00 6.46 82.02 54,537.04 2,394,314.57 278,159.07TD 9,350.70 90.01 313.16 5,050.00 5,104.08 4,159.09 1,445.00 -3,900.00 0.00 6.47 82.02 54,537.04 2,394,349.92 278,122.747 in Casing 9,350.70 90.01 313.16 5,050.00 5,104.08 4,159.09 1,445.00 -3,900.00 0.00 6.47 82.02 54,537.04 2,394,349.92 278,122.74PartMD From (ft)MD To (ft)EOU Freq (ft)Hole Size(in)Casing Diameter(in)Expected Max Inclination (deg)1 0.000 2,790.000 1/100.000 16 13.3751 2,790.000 7,460.000 1/100.000 16 – 12.25 13.375 – 9.6251 7,460.000 9,350.698 1/100.000 12.25 – 8.5 9.625 – 7EOU Geometry:7,461.83012.2509.625Intermediate9,350.6988.5007.000ProductionCLU S-7 / CLU S-7 wp16.1 Trajectory2,792.24916.00013.375SurfaceDescriptionSurvey Tool Code Vendor / ToolSurvey Error Model:ISCWSA0 3 - D 95 % Confidence 2.7955 sigmaSurvey Program:Borehole / SurveyEnd MD (ft) Hole Size (in) Casing Size (in) NameSLB_MWD+SAGCLU S-7 / CLU S-7 wp16.1 TrajectorySLB_MWD+SAGCLU S-7 / CLU S-7 wp16.1 TrajectorySLB_MWD+SAG
Borehole: Well: Field: Structure:
CLU S-7 wp16.1 CLU S-7 Alaska - Kenai Unit Cannery Loop Unit
Gravity & Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous
Model:BGGM
2024 Dip: 73.429° Date: 01-Aug-2024
MagDec:14.001° FS:
55069.864n
T Gravity FS:1001.186mgn (9.80665
Based)
Lat: N 60 32 39.04 Northing:
2392833.47ft
US Grid Conv: -1.0544°
Lon: W 151 12 39.18 Easting: 281995.3ftUS Scale Fact: 0.99995408
Slot: CLU S-7 TVD Ref: RKB (54.080 ft above MSL)
Plan: CLU S-7 wp16.1 Trajectory
-500 0 500 1000 1500 2000 2500 3000 3500 4000 4500
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
Vertical Section (ft) Azim = 290.33° Scale = 1:800.00(ft) Origin = 0N/-S, 0E/-WTVD (ft) Scale = 1:800.00(ft)CLU S-7 wp16.1 Trajectory
RTE
0 MD 0 TVD
KOP Crv 1.5/100
300 MD 300 TVD
Crv 3/100
500 MD 500 TVD
End Crv
2392 MD 2050 TVD
Crv 3/100
3351 MD 2533 TVD
End Crv
7387 MD 4944 TVD
Target
7437 MD 4954 TVD
Crv 3/100
7512 MD 4970 TVD Crv 3/100
7667 MD 4996 TVD
End Crv
9204 MD 5104 TVD TD
9351 MD 5104 TVD
13.375 in Casing
2792 MD 2251 TVD
9.625 in Casing
7462 MD 4959 TVD
7 in Casing
9351 MD 5104 TVD
Top Sterling C1 (4954 TVD)
Top Sterling C2 (5086 TVD)
Borehole: Well: Field: Structure:
CLU S-7 wp16.1 Plan: CLU S-7 Alaska - Kenai Unit Cannery Loop Unit
Gravity & Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous
Model: BGGM 2024 Dip: 73.427° Date: 30-Aug-2024
MagDec: 13.98° FS: 55065.36nT Gravity FS: 1001.319mgn (9.80665 Based)
Lat: N 60 32 39.04 Northing: 2392833.3ftUS Grid Conv: -1.0544°
Lon: W 151 12 39.18 Easting: 281995.47ftUS Scale Fact: 0.99995408
Slot: CLU S-7 TVD Ref: Rotary Table(54.08ft above MSL)
Plan: CLU S-7 wp16.1
-4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0
-2500
-2000
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
-4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0
-2500
-2000
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
EW (ft) Scale = 1:800.00(ft)NS (ft) Scale = 1:800.00(ft)CLU S-7 wp16.1
RTE
0 MD 0 TVD
KOP Crv 1.5/100
300 MD 300 TVD
Crv 3/100
500 MD 500 TVD
End Crv
2392 MD 2050 TVD
Crv 3/100
3351 MD 2533 TVD
End Crv
7387 MD 4944 TVD
Crv 3/100
7512 MD 4970 TVD
Crv 3/100
7667 MD 4996 TVD
End Crv
9204 MD 5104 TVD
TD
9351 MD 5104 TVD
13-3/8" Csg
2792 MD 2251 TVD
9-5/8" Csg
7462 MD 4959 TVD
7" Lnr
9351 MD 5104 TVD
CLU lease lines
Borehole: Well: Field: Structure:
CLU S-7 wp16.1 Plan: CLU S-7 Alaska - Kenai Unit Cannery Loop Unit
Gravity & Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone 04, US Feet Miscellaneous
Model: BGGM 2024 Dip: 73.427° Date: 30-Aug-2024
MagDec: 13.98° FS: 55065.36nT Gravity FS: 1001.319mgn (9.80665 Based)
Lat: N 60 32 39.04 Northing: 2392833.3ftUS Grid Conv: -1.0544°
Lon: W 151 12 39.18 Easting: 281995.47ftUS Scale Fact: 0.99995408
Slot: CLU S-7 TVD Ref: Rotary Table(54.08ft above MSL)
Plan: CLU S-7 wp16.1
-6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500
-3500
-3000
-2500
-2000
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
-6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500
-3500
-3000
-2500
-2000
-1500
-1000
-500
0
500
1000
1500
2000
2500
3000
EW (ft) Scale = 1:1000.00(ft)NS (ft) Scale = 1:1000.00(ft)CLU S-7 wp16.1
0
TV
D
500
TV
D
1000
TV
D
1500
T
V
D
2000
TV
D
2500
TV
D
3000TVD3405TVD3500TVD4000TVD4360 TV D4500TVD
5000 TVD5104TVD5104TVD
CLU-6
4
0
0
0
T
V
D
4
5
0
0
T
V
D5
0
0
0
T
V
D
5
2
7
8
T
V
DCLU S-5 1TVD5
0
1
T
VD1
0
0
1
T
V
D1
5
0
1
T
V
D
2
0
0
1
T
V
D2
5
0
1
T
V
D3
0
0
1
T
VD3
5
0
1
T
V
D4
0
0
1
T
V
D
4
5
0
1
T
V
DCLU-7
4012
T
V
D
45
12
T
V
D
501
2
T
V
D
5512
T
V
D
6012
T
V
D65
1
2
TVD7
0
1
2
T
V
D7512T
VD8004TVDCLU-14
4516TVD5016TVD
5 5 1 6 T V D6016TVD6516TVD7016TVD
7 5 1 6 T V D8016TVD
8 0 5 9 T V D
CLU-1RD
7
0
1
2
T
V
D
7
5
1
2
T
V
D8012TVD 8512TVD8650TVDCLU-3 19TVD519TVD1019TVD1519TVD2019TVD2519TVDCLU-15 1TVD501TVD1
0
0
1
T
V
D
1501
T
V
D
2001
T
V
D
2501
T
V
D
3001
T
V
D
3501
TVD
4001TVD
4501TVD
5001TVD5501TVD
6001TVD
6501TVD7001TVD
7501TVD7960TVD
CLU-13
7016
T
V
D
7516
T
V
D
8016TVD
8
5
1
6
T
V
D
8747
TV
D
CLU S-1
1
T
V
D
501 TVD1
0
0
1
T
V
D1501T
VD20
01TVD2
5
0
1
TVD3
0
01TVD35
01TVD4001TVD4501TVD5 0 0 1 T V D
5 1 6 5 T V D
CLU-1RDPB1
7
0
1
2
T
V
D
7
5
1
2
T
V
D
8
0
1
2
T
V
D
8
5
1
2
T
V
D
8
6
9
4
T
V
DCLU-12
-14TVD486TVD986TVD1486TVD1986TVD2486TVD2986TVD3486TVD3986TVD4486TVD4986TVD5486TVD5
9
8
6
T
VD6
4
8
6
T
V
D6986TVD
7 4 8 6 TVD7986TVD
8 0 7 0 T V D
CLU S-4 4TVD5
0
4
TVD1004
TVD1
5
0
4
T
VD2
0
0
4
TVD2
5
0
4
TVD3
0
0
4
TVD3
5
0
4
T
VD4
0
0
4
TVD45
0
4
TVD5004TVDCLU-1
8510TVD9010 TVD9510TVD10010TVD10226TVDCLU-8
4512TVD5012TVD5
5
12TVD6012
TVD6512TVD7012TVD7
5
1
2
T
V
D
7953 T
VD
CLU-4 19TVD5 1 9 T V D
1019TVD1
5
1
9
T
V
D
2
0
1
9
TV
D2519TVD3019TVD3519TVD4019TVD4519TVD5019TVD5519TVD6019TVD6519TVD7019TVD7519TVD8019TVD8519TVD9019TVD95
1
9
TVD1
0
0
1
9
T
V
D1
0
5
1
9
T
VD1
1
0
1
9
T
V
D
11
5
1
9
T
V
D
12019
T
V
D
12519
T
V
D13019 TVD13519
T
V
D
14019TVD
14519TVD
15019TVD
15519 TVD15979TVD
CLU S-6 wp08
0TVD500TVD1000TVD1500TVD2000TVD2500TVD3000TVD3500TVD4000TVD4500TVDCLU-11 -2TVD498TVD9
9
8
T
V
D
1
4
9
8
T
V
D1
9
9
8
T
V
D
2
4
9
8
T
V
D
2
9
9
8
T
V
D
3
4
9
8
T
V
D
3
9
9
8
T
V
D
4
4
9
8
T
V
D4
9
9
8
T
V
D5
4
9
8
T
V
D5
9
9
8
TVD6498TVD6998TVD
7498
T
V
D
7913TVD
CLU S-2
-1TVD499TVD
9
9
9
T
V
D1499TVD1999TVD2499TVD2999TVD3499TVD3999TVD4499TVD4999TVD5109TVDCLU S-3 1TVD5 0 1 T V D
1
0
0
1
T
V
D 1501 TVD2001TVD2
501TVD3
001 TVD3501TVD4001TVD4501TVD5001
T
V
D
5108
T
V
D
CLU lease lines
True North
Tot Corr (M->T 13.980°)
Mag Dec (13.980°)
Grid Conv (-1.054°)
Grid
True
Mag
Analysis Date-24hr Time:
Client:
Field:
Structure:
Slot:
Well:
Borehole:
Scan MD Range:
Trajectory Error Model:
Bounding box scan:
Selection filters:
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Results highlighted in red: Sep-Factor <= 1.5
Result highlighted in boxed, red and bold: all local minima indicated.
8476.24 55.35 8439.00 8420.89 234.01 OSF1.50 295.48 295.48 MinPts
8476.24 55.35 8439.00 8420.89 234.01 OSF1.50 304.81 304.81 MinPt-SF
5284.66 1425.92 4333.03 3858.74 5.57 OSF1.50 6547.43 4643.63 MinPt-CtCt
5313.24 1596.90 4247.66 3716.34 5.00 OSF1.50 6632.84 4684.70 OSF<=5.00 Enter Alert
5351.91 1681.03 4230.30 3670.89 4.78 OSF1.50 6675.12 4704.23 OSF>5.00 Exit Alert
6013.85 1573.74 4964.19 4440.12 5.74 OSF1.50 9199.70 5104.11 MinPt-CtCt
6013.84 1573.77 4964.16 4440.07 5.74 OSF1.50 9214.13 5104.11 MinPt-CtCt
7877.84 111.23 7803.37 7766.62 107.18 OSF1.50 9215.20 5104.11 TD
49.83 32.81 48.50 17.02 N/A MAS = 10.00 (m) 0.00 0.00 Surface
49.83 32.81 47.00 17.02 32.24 MAS = 10.00 (m) 300.00 300.00 MinPts
49.87 32.81 46.97 17.06 30.86 MAS = 10.00 (m) 330.26 330.26 MinPt-EOU
50.28 32.81 47.21 17.47 28.25 MAS = 10.00 (m) 400.86 400.84 MinPt-SF
81.44 32.81 75.71 48.63 18.24 MAS = 10.00 (m) 940.62 933.39 MinPt-SF
1061.10 65.85 1016.81 995.25 24.58 OSF1.50 2431.16 2069.64 MinPt-SF
1951.53 120.11 1871.12 1831.42 24.57 OSF1.50 5095.43 3701.09 MinPt-SF
1087.27 85.55 1029.90 1001.71 19.27 OSF1.50 7675.86 4997.54 MinPt-CtCt
1087.62 86.57 1029.57 1001.04 19.04 OSF1.50 7681.54 4998.29 MinPt-EOU
1087.92 86.91 1029.65 1001.01 18.97 OSF1.50 7683.48 4998.55 MinPt-ADP
1143.14 96.14 1078.72 1047.00 18.00 OSF1.50 7762.11 5008.69 MinPt-SF
1980.14 222.23 1831.66 1757.91 13.42 OSF1.50 9206.14 5104.11 MinPts
3666.18 230.95 3511.88 3435.22 23.91 OSF1.50 9349.14 5104.08 MinPts
2420.68 230.49 2266.70 2190.20 15.81 OSF1.50 9350.70 5104.08 TD
148.28 32.81 146.04 115.47 145.65 MAS = 10.00 (m) 268.49 268.49 MinPts
148.32 32.81 146.00 115.51 133.70 MAS = 10.00 (m) 290.52 290.52 MinPt-EOU
148.37 32.81 146.01 115.56 129.60 MAS = 10.00 (m) 300.54 300.54 MinPt-SF
150.23 32.81 147.86 117.42 130.49 MAS = 10.00 (m) 403.16 403.14 MinPt-SF
400.26 70.41 352.97 329.85 8.64 OSF1.50 2672.50 2191.16 MinPt-SF
607.27 93.22 544.80 514.05 9.86 OSF1.50 4183.39 3036.60 MinPt-SF
4700.03 81.65 4645.27 4618.38 87.38 OSF1.50 6067.27 4375.68 MinPts
158.25 32.81 157.03 125.44 N/A MAS = 10.00 (m) 3.58 3.58 MinPts
158.59 32.81 156.90 125.78 343.10 MAS = 10.00 (m) 143.58 143.58 MinPt-EOU
466.46 65.51 422.43 400.95 10.83 OSF1.50 2470.38 2089.39 MinPt-SF
754.69 87.28 696.18 667.42 13.10 OSF1.50 3403.57 2559.66 MinPt-SF
778.32 106.76 706.82 671.56 11.02 OSF1.50 4803.46 3484.00 MinPt-SF
770.78 104.04 701.09 666.74 11.20 OSF1.50 4960.86 3601.08 MinPt-ADP
770.38 103.57 701.01 666.81 11.25 OSF1.50 4979.39 3614.87 MinPt-EOU
769.96 102.26 701.46 667.70 11.39 OSF1.50 5024.62 3648.51 MinPt-CtCt
5329.77 87.65 5271.01 5242.12 92.23 OSF1.50 6368.16 4550.59 MinPt-SF
178.63 32.81 176.27 145.82 156.21 MAS = 10.00 (m) 300.57 300.57 MinPt-SF
178.12 32.81 175.77 145.32 156.73 MAS = 10.00 (m) 398.17 398.16 MinPt-SF
176.41 32.81 173.65 143.61 114.03 MAS = 10.00 (m) 664.35 663.46 MinPts
176.48 32.81 173.57 143.67 103.90 MAS = 10.00 (m) 691.72 690.54 MinPt-EOU
541.61 57.22 503.11 484.39 14.44 OSF1.50 2311.77 2008.08 MinPt-SF
736.15 73.68 686.68 662.48 15.19 OSF1.50 2783.79 2247.20 MinPt-SF
807.67 111.65 732.90 696.01 10.93 OSF1.50 5447.94 3958.96 MinPt-SF
783.50 104.84 713.28 678.66 11.30 OSF1.50 5633.96 4090.37 MinPt-ADP
782.89 104.09 713.17 678.80 11.38 OSF1.50 5648.34 4100.35 MinPt-EOU
782.51 102.93 713.56 679.58 11.50 OSF1.50 5669.44 4114.93 MinPt-CtCt
2515.51 79.14 2462.43 2436.38 48.26 OSF1.50 6407.43 4571.73 MinPts
211.54 32.81 210.32 178.73 3315679.11 MAS = 10.00 (m) 0.00 0.00 MinPts
211.95 32.81 209.96 179.14 277.98 MAS = 10.00 (m) 204.53 204.53 MinPt-EOU
212.25 32.81 209.89 179.44 186.40 MAS = 10.00 (m) 298.53 298.53 MinPt-EOU
212.47 32.81 210.06 179.66 177.10 MAS = 10.00 (m) 398.09 398.08 MinPt-SF
797.34 55.06 760.28 742.28 22.12 OSF1.50 2450.92 2079.59 MinPt-SF
949.87 66.54 905.15 883.33 21.74 OSF1.50 2788.33 2249.48 MinPt-SF
1178.31 77.83 1126.10 1100.48 22.98 OSF1.50 3318.35 2516.35 MinPt-SF
688.15 99.41 621.54 588.73 10.47 OSF1.50 6283.69 4503.74 MinPt-SF
674.50 95.87 610.26 578.63 10.65 OSF1.50 6341.15 4535.82 MinPt-ADP
674.30 95.59 610.25 578.72 10.68 OSF1.50 6345.20 4538.04 MinPt-EOU
CLU S-2 (DefinitiveSurvey) - Pass
13-08 (NonDefinitiveSurvey) - Warning Alert
CLU S-6 wp08 Trajectory (DefinitivePlan) - Pass
CLU S-5 (DefinitiveSurvey) - Pass
CLU S-4 (DefinitiveSurvey) - Pass
CLU S-3 (DefinitiveSurvey) - Pass
CLU S-7 wp16.1 Trajectory Anti-Collision Summary Report
Engine Version:
CLU S-7
CLU S-7
Min Pts:
Rule Set:
Reference Trajectory:
Normal Plane
CLU S-7 wp16.1 Trajectory (Non-Def Plan)CINGSA
July 31, 2024 - 12:25 AM ( UTC 0 )Analysis Method:
Every 10.00 Measured Depth (ft)Alaska - Kenai Unit Depth Interval:
2024.4.0.4
D&M AntiCollision Standard S002 v5.1/5.2
Absolute minima indicated.
Cannery Loop Unit
Separation
CLU S-7
Offset Trajectories Summary
Offset Selection Criteria
Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans
CLU S-7–CINGSA
Risk Level
0.00ft ~ 9350.70ft
- All Non-Def Surveys when no Def-Survey is set in a borehole - All Non-Def Plans when no Def-Plan is set in a borehole
Database \ Project:
ISCWSA0 3 - D 95 % Confidence 2.7955 sigma
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Separation Risk Level
674.23 95.30 610.37 578.93 10.71 OSF1.50 6349.20 4540.24 MinPt-CtCt
2924.47 84.26 2867.97 2840.21 52.66 OSF1.50 6830.13 4771.02 MinPt-SF
248.60 32.81 245.81 215.79 157.29 MAS = 10.00 (m) 399.24 399.23 MinPts
248.60 32.81 245.81 215.79 158.70 MAS = 10.00 (m) 409.11 409.10 MinPts
910.92 58.24 871.76 852.68 23.84 OSF1.50 2803.18 2256.96 MinPt-SF
376.08 100.98 308.43 275.10 5.63 OSF1.50 6008.79 4339.25 MinPt-SF
366.54 96.62 301.80 269.92 5.73 OSF1.50 6042.49 4360.33 MinPt-ADP
366.02 95.90 301.76 270.12 5.77 OSF1.50 6047.10 4363.20 MinPt-EOU
365.64 94.40 302.38 271.24 5.86 OSF1.50 6056.21 4368.84 MinPt-CtCt
1389.21 94.59 1325.82 1294.62 22.25 OSF1.50 7462.32 4959.42 MinPt-SF
1403.82 95.60 1339.76 1308.22 22.24 OSF1.50 7499.25 4967.16 MinPt-SF
1425.52 195.29 1295.00 1230.23 11.00 OSF1.50 9350.70 5104.08 MinPts
3495.92 32.81 3494.00 3463.11 ######### MAS = 10.00 (m) 8.08 8.08 MinPts
3496.03 32.81 3492.80 3463.22 2660.22 MAS = 10.00 (m) 298.08 298.08 MinPts
3496.05 32.81 3492.74 3463.24 2494.47 MAS = 10.00 (m) 319.93 319.93 MinPt-EOU
3500.18 32.81 3495.75 3467.37 1393.64 MAS = 10.00 (m) 585.91 585.57 MinPt-EOU
3492.41 32.81 3478.95 3459.60 302.39 MAS = 10.00 (m) 990.83 981.40 MinPts
3492.42 32.81 3478.06 3459.61 280.34 MAS = 10.00 (m) 1017.86 1007.09 MinPts
3492.69 32.81 3477.84 3459.88 269.86 MAS = 10.00 (m) 1039.50 1027.57 MinPt-EOU
3981.52 107.10 3909.53 3874.42 56.67 OSF1.50 3354.38 2534.50 MinPt-SF
3925.77 103.24 3856.36 3822.53 58.00 OSF1.50 3791.00 2780.02 MinPt-ADP
3925.65 103.10 3856.33 3822.55 58.08 OSF1.50 3801.51 2786.50 MinPt-EOU
3925.58 102.83 3856.44 3822.74 58.23 OSF1.50 3822.54 2799.54 MinPt-CtCt
538.94 150.42 438.13 388.52 5.42 OSF1.50 9297.13 5104.09 MinPt-CtCt
539.77 152.56 437.53 387.21 5.35 OSF1.50 9299.67 5104.09 MinPt-EOU
540.32 153.18 437.66 387.14 5.33 OSF1.50 9300.51 5104.09 MinPt-ADP
545.21 155.62 440.92 389.58 5.29 OSF1.50 9304.66 5104.09 MinPt-SF
1006.49 114.71 929.48 891.77 13.33 OSF1.50 9350.70 5104.08 TD
3483.42 32.81 3482.30 3450.61 781670.81 MAS = 10.00 (m) 21.08 21.08 WRP
3482.62 32.81 3480.41 3449.81 3163.91 MAS = 10.00 (m) 307.63 307.63 MinPts
3482.64 32.81 3480.39 3449.83 3082.58 MAS = 10.00 (m) 320.74 320.74 MinPt-EOU
3181.10 67.21 3135.96 3113.88 72.02 OSF1.50 2258.17 1978.53 MinPt-CtCt
3181.77 68.94 3135.48 3112.83 70.21 OSF1.50 2297.18 2000.16 MinPt-EOU
3182.67 70.01 3135.67 3112.66 69.14 OSF1.50 2320.64 2012.84 MinPt-ADP
3196.51 81.25 3142.01 3115.25 59.72 OSF1.50 2580.50 2144.84 MinPt-ADP
3220.37 98.84 3154.14 3121.52 49.35 OSF1.50 3119.81 2416.39 MinPt-ADP
3230.36 105.57 3159.65 3124.78 46.32 OSF1.50 3354.67 2534.64 MinPt-SF
3228.96 105.04 3158.60 3123.91 46.53 OSF1.50 3441.20 2579.36 MinPts
3228.86 104.87 3158.62 3123.99 46.61 OSF1.50 3462.83 2590.86 MinPt-CtCt
1151.87 125.17 1067.99 1026.71 13.93 OSF1.50 7309.70 4926.32 MinPt-ADP
1151.82 125.12 1067.98 1026.71 13.94 OSF1.50 7309.74 4926.33 MinPts
2785.95 66.82 2741.08 2719.14 63.46 OSF1.50 7315.99 4927.81 End Depth
3404.07 67.02 3359.06 3337.05 77.30 OSF1.50 8839.66 5097.79 MinPt-SF
5182.96 83.26 5127.13 5099.71 94.48 OSF1.50 8955.45 5101.18 TD
10405.42 32.81 10402.38 10372.62 9218.42 MAS = 10.00 (m) 292.06 292.06 MinPts
10405.43 32.81 10402.35 10372.62 8936.46 MAS = 10.00 (m) 305.38 305.38 MinPt-EOU
10406.85 32.81 10403.76 10374.04 8858.67 MAS = 10.00 (m) 363.03 363.02 MinPt-SF
7947.40 131.51 7859.19 7815.89 91.75 OSF1.50 9204.81 5104.11 MinPts
9251.66 128.66 9165.35 9123.00 109.20 OSF1.50 9347.99 5104.08 MinPts
10131.72 32.81 10129.80 10098.91 N/A MAS = 10.00 (m) 12.08 12.08 MinPts
10131.85 32.81 10129.73 10099.05 49175.43 MAS = 10.00 (m) 92.08 92.08 MinPt-EOU
10132.02 32.81 10129.72 10099.21 26159.46 MAS = 10.00 (m) 132.08 132.08 MinPt-EOU
10132.88 32.81 10129.85 10100.07 9102.00 MAS = 10.00 (m) 305.60 305.60 MinPt-EOU
10133.22 32.81 10130.13 10100.41 8624.76 MAS = 10.00 (m) 364.25 364.25 MinPt-SF
2144.23 169.08 2029.35 1975.16 19.72 OSF1.50 7613.38 4988.54 MinPt-CtCt
2144.25 169.13 2029.33 1975.11 19.72 OSF1.50 7615.81 4988.93 MinPts
2146.77 169.47 2031.65 1977.30 19.69 OSF1.50 7634.03 4991.73 MinPt-SF
2162.73 167.41 2049.13 1995.32 20.04 OSF1.50 9107.45 5103.68 MinPt-CtCt
2162.81 167.67 2049.04 1995.14 20.01 OSF1.50 9120.37 5103.79 MinPt-EOU
2162.97 167.85 2049.07 1995.12 19.99 OSF1.50 9130.16 5103.86 MinPt-ADP
2163.78 168.10 2049.72 1995.69 19.97 OSF1.50 9149.03 5103.97 MinPt-SF
5727.63 129.99 5640.27 5597.63 67.13 OSF1.50 9204.36 5104.11 MinPts
5877.20 129.77 5790.03 5747.43 68.96 OSF1.50 9204.38 5104.11 MinPts
3762.71 134.86 3671.57 3627.85 42.99 OSF1.50 9204.54 5104.11 MinPts
2162.69 170.17 2047.30 1992.52 19.69 OSF1.50 9205.82 5104.11 MinPts
2165.92 170.65 2050.24 1995.26 19.65 OSF1.50 9205.82 5104.11 MinPt-SF
2173.29 168.44 2059.00 2004.86 20.01 OSF1.50 9206.12 5104.11 End Depth
4045.78 133.71 3955.51 3912.07 46.53 OSF1.50 9212.13 5104.11 TD
3440.42 32.81 3438.51 3407.62 N/A MAS = 10.00 (m) 18.78 18.78 MinPts
3441.04 32.81 3436.92 3408.23 1558.45 MAS = 10.00 (m) 326.96 326.96 MinPt-EOU
3456.47 32.81 3449.50 3423.66 684.40 MAS = 10.00 (m) 622.20 621.65 MinPt-SF
5484.90 197.82 5352.41 5287.09 41.97 OSF1.50 3551.52 2639.33 MinPt-SF
4855.15 130.88 4767.30 4724.26 56.38 OSF1.50 4523.51 3277.89 MinPt-ADP
4852.48 127.73 4766.74 4724.75 57.76 OSF1.50 4558.65 3303.49 MinPt-EOU
4850.41 121.77 4768.64 4728.64 60.60 OSF1.50 4628.99 3355.03 MinPt-CtCt
5522.32 80.65 5468.02 5441.67 104.76 OSF1.50 8933.46 5100.63 MinPts
2154.02 171.31 2039.22 1982.71 19.04 OSF1.50 9163.63 5104.04 MinPt-CtCt
2154.04 171.35 2039.20 1982.69 19.04 OSF1.50 9164.23 5104.04 MinPts
2154.41 171.45 2039.49 1982.95 19.04 OSF1.50 9166.03 5104.05 MinPt-SF
2886.60 143.96 2789.34 2742.64 30.87 OSF1.50 9350.70 5104.08 TD
10382.50 32.81 10379.29 10349.69 8040.32 MAS = 10.00 (m) 292.03 292.03 MinPts
10382.50 32.81 10379.26 10349.69 7846.21 MAS = 10.00 (m) 305.47 305.47 MinPts
CLU-7 (DefinitiveSurvey) - Pass
CLU-4 (DefinitiveSurvey) - Pass
CLU-8 (DefinitiveSurvey) - Pass
CLU S-1 (DefinitiveSurvey) - Pass
CLU-11 (DefinitiveSurvey) - Pass
CLU-15 (DefinitiveSurvey) - Pass
CLU-6 (DefinitiveSurvey) - Pass
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Separation Risk Level
2914.10 111.85 2837.34 2802.26 41.43 OSF1.50 6650.31 4692.84 MinPt-CtCt
2914.18 112.17 2837.21 2802.01 41.30 OSF1.50 6654.28 4694.67 MinPt-EOU
2914.30 112.33 2837.23 2801.97 41.24 OSF1.50 6656.27 4695.59 MinPt-ADP
2978.91 118.58 2897.88 2860.33 39.59 OSF1.50 6743.04 4734.43 MinPt-SF
8138.79 130.47 8051.28 8008.32 94.72 OSF1.50 9205.49 5104.11 MinPts
8697.49 132.00 8608.96 8565.49 100.03 OSF1.50 9350.70 5104.08 TD
3473.39 32.81 3472.16 3440.58 ######### MAS = 10.00 (m) 0.00 0.00 MinPts
3473.64 32.81 3471.50 3440.84 3784.98 MAS = 10.00 (m) 238.07 238.07 MinPt-EOU
3474.32 32.81 3471.83 3441.51 2741.52 MAS = 10.00 (m) 321.14 321.14 MinPt-SF
3475.88 32.81 3473.32 3443.07 2602.90 MAS = 10.00 (m) 404.07 404.05 MinPt-SF
4655.38 128.62 4569.31 4526.76 54.70 OSF1.50 3351.21 2532.90 MinPt-SF
4458.35 112.88 4382.77 4345.47 59.75 OSF1.50 4146.22 3011.14 MinPt-ADP
4457.90 112.35 4382.68 4345.55 60.03 OSF1.50 4170.96 3028.06 MinPt-EOU
4457.60 111.44 4382.97 4346.15 60.52 OSF1.50 4210.26 3055.13 MinPt-CtCt
3233.05 79.65 3179.62 3153.40 61.63 OSF1.50 9350.70 5104.08 MinPts
10294.16 32.81 10288.09 10261.35 2482.26 MAS = 10.00 (m) 292.08 292.08 MinPts
10294.16 32.81 10288.09 10261.35 2476.42 MAS = 10.00 (m) 305.48 305.48 MinPts
3542.03 280.37 3352.95 3261.67 19.37 OSF1.50 7255.74 4912.93 MinPt-SF
3460.69 267.07 3280.72 3193.62 19.83 OSF1.50 7366.89 4939.34 MinPt-ADP
3459.92 266.13 3280.60 3193.80 19.90 OSF1.50 7372.94 4940.65 MinPt-EOU
3459.32 264.15 3281.35 3195.17 20.04 OSF1.50 7384.91 4943.19 MinPt-CtCt
3856.63 164.90 3744.72 3691.73 36.33 OSF1.50 9205.13 5104.11 MinPts
9115.46 128.83 9029.04 8986.63 107.45 OSF1.50 9330.63 5104.08 MinPts
8852.93 132.96 8763.75 8719.97 101.08 OSF1.50 9350.70 5104.08 MinPts
10294.16 32.81 10288.09 10261.35 2482.26 MAS = 10.00 (m) 292.08 292.08 MinPts
10294.16 32.81 10288.09 10261.35 2476.42 MAS = 10.00 (m) 305.48 305.48 MinPts
3542.03 280.37 3352.95 3261.67 19.37 OSF1.50 7255.74 4912.93 MinPt-SF
3460.69 267.07 3280.72 3193.62 19.83 OSF1.50 7366.89 4939.34 MinPt-ADP
3459.92 266.13 3280.60 3193.80 19.90 OSF1.50 7372.94 4940.65 MinPt-EOU
3459.32 264.15 3281.35 3195.17 20.04 OSF1.50 7384.91 4943.19 MinPt-CtCt
3856.63 164.90 3744.72 3691.73 36.33 OSF1.50 9205.13 5104.11 MinPts
9115.46 128.83 9029.04 8986.63 107.45 OSF1.50 9330.63 5104.08 MinPts
8852.93 132.96 8763.75 8719.97 101.08 OSF1.50 9350.70 5104.08 MinPts
10210.16 32.81 10208.94 10177.35 ######### MAS = 10.00 (m) 0.00 0.00 Surface
10207.42 32.81 10204.91 10174.61 7915.58 MAS = 10.00 (m) 298.96 298.96 MinPts
10207.42 32.81 10204.90 10174.61 7889.80 MAS = 10.00 (m) 300.73 300.73 MinPts
3878.74 90.38 3816.75 3788.36 68.21 OSF1.50 6706.24 4718.24 MinPt-CtCt
3878.75 90.46 3816.71 3788.29 68.15 OSF1.50 6708.02 4719.03 MinPt-EOU
3878.81 90.54 3816.71 3788.26 68.08 OSF1.50 6709.79 4719.82 MinPt-ADP
3944.49 93.79 3880.38 3850.70 66.36 OSF1.50 6795.63 4756.82 MinPt-SF
4929.51 89.67 4869.41 4839.85 83.36 OSF1.50 7031.73 4846.08 MinPt-SF
8515.33 128.62 8429.25 8386.71 100.06 OSF1.50 9204.39 5104.11 MinPts
9263.44 123.07 9181.06 9140.37 113.80 OSF1.50 9246.85 5104.10 MinPts
10294.16 32.81 10288.13 10261.35 2504.49 MAS = 10.00 (m) 290.08 290.08 MinPts
10294.16 32.81 10288.13 10261.36 2497.02 MAS = 10.00 (m) 306.87 306.87 MinPts
4240.81 399.47 3972.86 3841.34 16.10 OSF1.50 7122.57 4875.34 MinPt-CtCt
4241.75 402.53 3971.75 3839.22 15.98 OSF1.50 7138.21 4880.09 MinPt-EOU
4242.52 403.44 3971.91 3839.08 15.95 OSF1.50 7143.39 4881.64 MinPt-ADP
4269.07 411.77 3992.86 3857.30 15.73 OSF1.50 7203.37 4898.91 MinPt-SF
4351.56 438.11 4057.70 3913.44 15.06 OSF1.50 7359.16 4937.66 MinPt-SF
4477.00 179.05 4356.24 4297.95 38.36 OSF1.50 8990.83 5101.96 MinPts
4476.99 179.05 4356.24 4297.95 38.36 OSF1.50 8991.16 5101.96 MinPt-EOU
4476.99 179.03 4356.25 4297.96 38.37 OSF1.50 8991.57 5101.97 MinPt-CtCt
4514.33 174.16 4397.00 4340.17 39.69 OSF1.50 9036.36 5102.78 MinPt-SF
4472.48 178.16 4352.40 4294.32 38.47 OSF1.50 9325.19 5104.09 MinPt-SF
4472.42 178.13 4352.37 4294.29 38.47 OSF1.50 9326.81 5104.08 MinPts
4472.42 178.12 4352.37 4294.30 38.47 OSF1.50 9327.25 5104.08 MinPt-CtCt
4507.59 176.71 4388.62 4330.88 39.01 OSF1.50 9350.22 5104.08 End Depth
8852.93 132.96 8763.75 8719.97 101.08 OSF1.50 9350.70 5104.08 TD
10121.52 32.81 10120.34 10088.71 N/A MAS = 10.00 (m) 0.00 0.00 Surface
10121.52 32.81 10118.88 10088.71 6949.65 MAS = 10.00 (m) 294.08 294.08 MinPts
10121.52 32.81 10118.87 10088.71 6851.63 MAS = 10.00 (m) 304.22 304.22 MinPts
5723.66 91.43 5661.50 5632.23 97.70 OSF1.50 6857.45 4781.98 MinPt-CtCt
5723.70 91.56 5661.46 5632.14 97.53 OSF1.50 6860.50 4783.19 MinPt-EOU
5723.81 91.70 5661.48 5632.11 97.37 OSF1.50 6863.55 4784.40 MinPt-ADP
5901.99 98.17 5835.93 5803.83 91.90 OSF1.50 7071.93 4859.39 MinPt-SF
6186.56 139.56 6092.67 6047.00 67.71 OSF1.50 9070.95 5103.28 MinPt-CtCt
6186.61 139.70 6092.62 6046.91 67.65 OSF1.50 9072.14 5103.29 MinPts
6223.44 142.10 6127.73 6081.34 67.04 OSF1.50 9095.37 5103.56 MinPt-SF
9313.45 121.64 9232.03 9191.82 115.77 OSF1.50 9270.95 5104.10 End Depth
6739.71 148.64 6639.78 6591.07 69.15 OSF1.50 9350.70 5104.08 TD
CLU-1RD (DefinitiveSurvey) - Pass
CLU-5 (DefinitiveSurvey) - Pass
CLU-1 (DefinitiveSurvey) - Pass
CLU-13 (P2) (DefinitivePlan) - Pass
CLU-12 (DefinitiveSurvey) - Pass
CLU-1RDPB1 (DefinitiveSurvey) - Pass
0 10
20
30
40
50
60
70
80
90
100
110
120
130
140
150
160
170180190
200
210
220
230
240
250
260
270
280
290
300
310
320
330
340
350
20
40
60
80
100
120
140
2040608010012014020406080100120140CLU S-5131221301
CLU S-6 wp08
5 015 0250350451552
6 53
753
842
940
1 0 3 6
1 1 2 9
TRAVELING CYLINDER PLOT
Client ASRC
Field Alaska - Kenai Unit
Structure Cannery Loop Unit
Well Plan: CLU S-7
Borehole CLU S-7
Date 22-Jul-2024
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
Anti-Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2
Well Ticks Type: MD on CLU S-7 wp16.1
Calculation Method: Normal Plane
Ring Interval 20.00 ft
Azimuth Interval: 10.00 deg
Start Depth: 0.00 ft
End Depth: 9350.70 ft
Offset Well Count: 27
TRACT E
KN 2005-122
CITY OF KENAI
TRACT F1
KN 2014-20
STATE OF ALASKA BRIDGE
ACCESS
ROAD
S4 S3
S9 S10
SECTION 4 T5N R11W
SECTION 9 T5N R11W
SECTION 9 T5N R11WSECTION 10 T5N R11WSECTION LINE
NOT TO SCALE
B
E
A
V
E
R
L
O
O
P
R
O
A
D
CLU S-1
CLU S-2
CLU S-3
CLU S-4
CLU S-5
SECTION CORNER
NAD83
N:2393280.90'
E:1423637.27'
NAD27
N:2393518.79'
E:283617.10'
CINGSA
DRILL PAD
CLU S-6 CLU S-7 SECTION LINENOT TO SCALEREVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
-
7/3/2024
BGB
1"=150'
243002
24-04
1 2
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
717'
FNL
1660'
FEL
1610'
FEL
716'
FNL
REVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
-
7/3/2024
BGB
N/A
243002
24-04
2 2
CONTROL NOTE
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
1) BASIS OF HORIZONTAL CONTROL; NAD83 US SURVEY FEET POSITION (EPOCH 2010) IS AN OPUS
SOLUTION FROM NGS STATIONS AC23 SOLDOTNA__AK2007 CORS ARP, AC47 SLOPEMTN__AK2007 CORS
ARP & DRIFTRIVERAK2006 CORS ARP for ADOT&PF BM 601
THE ALASKA STATE PLANE NAD83 ZONE 4 COORDINATES ARE:
N: 2393464.701
E: 1422055.725
LAT: 60°32'45.5509"N
LONG: -151°12'46.71771"W
2)BASIS OF VERTICAL CONTROL IS ADOT&PF BM 601 LOCATED AT BRIDE ACCESS RD. & BEAVER LOOP
RD INTERSECTION PER AKSAS PROJECT NO. 58703.
ELEV: 42.20' (NORTH AMERICAN VERTICAL DATUM OF 1988 (GEOID12A)
3)DATUM TRANSFORMATIONS FROM NAD83 TO NAD27 WERE DONE USING CORPSCON SOFTWARE
VERSION 6.0.1.
4)SURVEY PERFORMED BY MCLANE CONSULTING INC. ON JULY 3, 2024.
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 17 July 2024
Rev. 0
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 18 July 2024
Rev. 0
Attachment 4 – Diverter Schematic
NordicCalistaRig37x
MWD/MudLog
(24'x9')Centrifuge(20'x12')~60'
MudProductStorageorRigOffices
MudLab
(12'x6')
NewlyLaid
GravelExpansion
16"DiverterLine
Approximate
EndofDiverter
900'toRoad BridgeAccess
Road
BoatLaunchRoad
CINGSA
WellPad
NordicCalistaRig37xDiverterDirection
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 19 July 2024
Rev. 0
Attachment 5 – BOPE Schematic
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 20 July 2024
Rev. 0
Attachment 6 – Choke Manifold Schematic
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 21 July 2024
Rev. 0
Attachment 7 – Wellhead / Tree Schematic
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 22 July 2024
Rev. 0
Attachment 8 – Casing Design Program
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 23 July 2024
Rev. 0
Attachment 9 – Rig Equipment, Layout & Fluids System
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 24 July 2024
Rev. 0
Cook Inlet Natural Gas Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 25 July 2024
Rev. 0
1
McLellan, Bryan J (OGC)
From:Isaacson, William <wisaacson@asrcenergy.com>
Sent:Monday, August 5, 2024 2:27 PM
To:McLellan, Bryan J (OGC)
Subject:RE: CINGSA wells
Hey Brian,
A well passes the SLB version of “Major Risk” if it has a Separation Factor (OSF) of greater than 1.5. Therefore all
oƯset wells for CLUS 7 pass “Major Risk”, which is a similar conservative calculation that BP has for “Major Risk”
wells. As part of SLB’s policy, they also added the OSF <=5.0 Ʋag to give the directional driller an added or early
warning indicator that a well is entering or exists within a distance that it needs to be “watched” a little more
closely than those with OSF greater than 5.0.
I hope this is clear, but let me know if you need further information. Thanks
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, August 5, 2024 12:16 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Subject: RE: CINGSA wells
Bill,
Please explain the close approach alert for well 13-08 on the anti-collision scan. What is the alert for and are any
mitigating measures needed?
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
2
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Thursday, August 1, 2024 4:33 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: CINGSA wells
This may be a better overall package than what was sent with the PTD.
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, August 1, 2024 1:22 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Subject: RE: CINGSA wells
Bill,
Could you send the CLUS7 anti-collision scan? I’ll attach it to the PTD.
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
3
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Thursday, August 1, 2024 12:57 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: CINGSA wells
Hey Bryan,
I’ve just submitted CLUS 7. The second well is CLUS 6 and will be submitted tomorrow or early next week. It is the
one with the spacing exception request, so held oƯ on submitting until that was all in and on its way. Thanks for
checking
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, August 1, 2024 12:52 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Subject: CINGSA wells
Bill,
I’m only seeing one CINGSA PTD so far. Did you say that you submitted the second one? Just making sure we
didn’t misplace it.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
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.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
1
McLellan, Bryan J (OGC)
From:Isaacson, William <wisaacson@asrcenergy.com>
Sent:Tuesday, August 6, 2024 5:39 PM
To:McLellan, Bryan J (OGC)
Subject:RE: CLU Storage 7 additional questions
Attachments:Nordic 37x - CINGSA CLUS7 Diverter Orientation.pdf
Bryan,
Please see my responses below in blue. Please let me know if you need additional information. Thanks
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, August 1, 2024 2:28 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Subject: CLU Storage 7 additional questions
Bill
1. What is the size of the DP and approximate BHA dimension you plan to use when drilling this well (for kick
tolerance calcs)? 4-1/2” DP and the BHA is 145’ of 8.25” in the 12.250” hole and 175’ of 6.75” in the 8.5”
hole.
2. Please send the surface location diagram that shows the rig and diverter layout relative to nearby features
like buildings and roads. Please see enclosed showing close-up orientation on the pad and zoomed out
version showing roads, etc.
3. What is the maximum planned injection surface pressure for the well once it is put into service? 2180 psi…
this is the maximum allowable operating pressure of the surface piping.
4. To support the waiver request, what is the anticipated lithology between top planned perf and liner top
packer? The top perforation is anticipated to be in the Ʊrst quality sand of the Sterling C1, which is
expected to be in a range of 70 to 110’ TVD below the planned liner top packer set depth. The Ʊrst 30’ to 60’
TVD of lithology above the top perforation is all within the Sterling C1 and consists of interbedded layers of
coals, shale, tuƯaceous siltstones / claystones and poor quality sands. The prominent Sterling B5 coal sits
immediately on top of the Sterling C1 and is ~10’ TVD. The Ʊnal 30 to 40’ TVD above the Sterling B5 Coal,
and up to the liner top packer set depth, is a fairly consistent sandy siltstone / claystone with varying levels
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.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
2
of tuƯaceous content (very low porosity sandy mudstone). This interval is fairly consistent for over 400’
TVD above the Sterling B5 Coal. Will the liner top packer be placed in a conƱning zone? The 400’ TVD
interval above the B5 Coal, and described above, is believed to be part of the conƱning zone for the Sterling
C Gas Pool and the liner top packer will be set within this interval. This is the same design/placement as
used successfully on the existing 5 CINGSA wells.
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Friday, 16 August, 2024 08:39
To:Isaacson, William
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); McLellan, Bryan
J (OGC); Matthew Federle
Subject:RE: CLU S-7 PTD (224-106): Question
Bill,
Thank you. This perfectly addresses my quesƟon.
I read that you are planning to collect a mudlog for this well. As a note, AOGCC will not require a mudlog at S-7, but will
require a set of samples if you do collect it.
Thanks,
Andy
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Thursday, 15 August, 2024 15:48
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby,
David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Matthew Federle
<Matthew.Federle@enstarnaturalgas.com>
Subject: RE: CLU S-7 PTD (224-106): Question
Andrew,
Thanks for the discussion today and clarity on the additional supporting details you were looking for with your
request. Below are the details on both wells, reviewing the mechanical condition of the well bore and the
associated cement isolation across the Sterling C Storage Pool interval. Please review and let me know if
additional information is required. Thanks
CLU 11
If you refer to schemaƟc below, the Sterling C pool is below the set depth of the 9-5/8” casing shoe and is isolated
behind the 3-1/2” producƟon casing with cement. The cement behind the 3-1/2” was logged and the log shows good
cement above and below the Sterling C storage sand. The bond log also shows good cement between the Sterling C and
Upper Beluga sands. Further conĮrmaƟon of this integrity is the UB1 perf test in 2021, which saw no Ňow or pressure
(see aƩached 10-403 and follow-up 10-404).
Key Depths:
TOC behind 3-½” 4400’ MD (06/08/2006 CBL)
9-5/8” Shoe 5595’ MD
Sterling C 6281’ – 6537’ MD
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.
2
CLU-11 3-1/2” CBL (6-08-2006)
3
CLU 15
4
If you refer to the schemaƟc below, the 7-5/8” casing is set at a depth of 7790’ MD, which is below the Sterling C
pool. The Sterling C is isolated behind the 7-5/8” intermediate casing with logged cement above and below the storage
sand (see below CBL), with the top of cement extending well above the Sterling C pool. AddiƟonally, the cement behind
the 4-½” liner extends across the Beluga interval into the 7-5/8” casing, with a logged TOC at 6904’ MD.
Key Depths:
TOC behind 7-5/8” 3675’ MD (4/15/2020 CBL)
TOC behind 4-½” 6904’ MD
Sterling C 7410’ – 7641’ MD
7-5/8” Shoe 7790’ MD
CLU 15 WBD
5
6
CLU-15 7-5/8” CBL (4-15-2020)
7
8
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, August 14, 2024 4:41 PM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby,
David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Matthew.Federle
<Matthew.Federle@enstarnaturalgas.com>
Subject: RE: CLU S-7 PTD (224-106): Question
Andrew,
Yes, this is correct, the ADL 391627 lease has the extent shown in the dashed line of Attachment 1 of the
Application for Permit to Drill.
As far as your second question, the two wells that will be within ¼ mile of the proposed CLU S-7 well are CLU-11
and CLU-15. As you may be aware CINGSA is required to submit the enclosed annual report which includes a
review of the 14 third-party wells which penetrate the Sterling C storage formation. A conclusion in the report is
that “there is no evidence of any gas leakage from the Sterling C Gas Storage Pool at the time” the report was
prepared (May 2024).
The review looks at both historical production data from the wells as well as annulus pressure monitoring. Only 5
of the 14 wells noted above remain in production and well CLU-15 is one of them (CLU-11 is shut-in). The
conclusion from the review of production history of all 5 wells (including CLU-15) is that “there is no evidence
which suggest production from any of these wells is being inƲuenced by CINGSA’s gas storage operations”.
In regards to annulus pressure monitoring of all 14 third-party wells, the review concluded that “all the current
annulus and tubing pressure readings on the Hilcorp wells are low (below 200 psi) and do not track the CINGSA
well tubing pressure trends”. The Annulus Pressure trend on the CLU-11 well is included as Figure 23, which
shows a steady value of <100 psi since the CINGSA start-up. The outer 7-5/8” x 10-3/4” annulus of CLU 15 shows
a steady 0 psi since it was drilled in 2020 (Figure 27), however the inner annulus shows a trend that has increased
and tracks tubing pressure. Below is a snip-it of a section of the report which discusses CLU 15, and the opinion
that the pressure on the inner annulus appears to be communication between the tubing and inner annulus.
Please have a review and let me know if this answers your questions. Thanks
9
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, August 14, 2024 3:01 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby,
David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: CLU S-7 PTD (224-106): Question
Bill,
Upon further review, it looks like the ADL 391627 lease as described below has the extent shown in the dashed line of
AƩachment 1. Would you please conĮrm? If so, please ignore my previous request.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
10
I had one other quesƟon: it appears that the proposed CLU S-7 well may pass within a quarter mile of at least 2 Hilcorp
CLU wells. Would you please provide a report on the mechanical condi Ɵon of each well that has penetrated the storage
zone within a one-quarter mile radius of the S-7 well?
Thanks,
Andy
From: Dewhurst, Andrew D (OGC)
Sent: Wednesday, 14 August, 2024 13:26
To: wisaacson@asrcenergy.com
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby,
David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: CLU S-7 PTD (224-106): Question
Bill,
I am compleƟng my review of the CLU Storage 7 well and have a ques Ɵon about the subsurface acreage.
I’m trying to understand the extent of the subsurface lease. According to Alaska Mapper the ADL 391627 lease is limited
to the area under the river as shown below:
11
I also noƟced in AƩachment 1 (Lease Map) a much larger area shown as a dashed line labeled ADL 391627 Gas Storage
Lease. That looks very similar in extent to the ParƟcipaƟng Area. Would you conĮrm what the dashed outline in
AƩachment 1 represents?
The proposed well path is either parƟally outside of, or just on the edge of the ADL 391627 extent show in the
screenshot above. Are there any other leases (or private fee lands) that CLU S-7 will enter? Would you be able to provide
a Įgure showing the proposed well path against boundaries where ownership changes (so as to conĮrm no spacing
excepƟon is required)?
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: __________________________ POOL: ____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
CLU S-7
KENAI C.L.U.STERLING C GAS STORAGE
224-106
-A.Dewhurst 14AUG24
WELL PERMIT CHECKLISTCompanyCook Inlet Natural Gas Storage Alaska, LLCWell Name:CANNERY LOOP UNIT S-7Initial Class/TypeSER / PENDGeoArea820Unit10320On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2241060KENAI C.L.U., STERL C GAS STOR - 449800NA1 Permit fee attachedYes ADL391627 and separate Natural Gas Storage Lease C-0616692 Lease number appropriateYes3 Unique well name and numberYes KENAI C.L.U., STERL C GAS STOR - 449800 - governed by CO 9A4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes Storage Injection Order 9A.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYes15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 1728 psi, BOP rated to 5000 psi (BOP test to 3000 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableYes See attached emails. Not included in PTD submission34 Mechanical condition of wells within AOR verified (For service well only)Yes Measures not required. Nearby wells did not encounter H2S.35 Permit can be issued w/o hydrogen sulfide measuresYes No overpressure zones. Target reservoir anticipated to be at 7.7 ppg EMW.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate8/15/2024ApprBJMDate8/19/2024ApprADDDate8/13/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/20/2024
