Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout223-107DA
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
.
50
-
0
2
9
-
2
2
8
2
4
-
6
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
1-
O
I
L
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
6
/
2
0
2
4
Pe
r
m
i
t
t
o
D
r
i
l
l
22
3
1
0
7
0
Op
e
r
a
t
o
r
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
MD
24
9
3
8
TV
D
78
7
5
Cu
r
r
e
n
t
S
t
a
t
u
s
1-
O
I
L
1/
1
3
/
2
0
2
6
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
:
AB
G
,
B
a
s
e
s
t
a
r
,
G
R
,
A
D
R
M
D
&
T
V
D
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
2/
1
6
/
2
0
2
4
20
0
2
5
2
4
8
8
5
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
:
M
P
U
F
-
3
4
L
1
AD
R
Q
u
a
d
r
a
n
t
s
A
l
l
C
u
r
v
e
s
.
l
a
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
18
6
9
9
2
4
9
3
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
:
M
P
U
F
-
3
4
L
1
LW
D
F
i
n
a
l
.
l
a
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
We
l
l
P
l
o
t
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
We
l
l
P
l
o
t
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
W
e
l
l
R
e
p
o
r
t
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
P
o
s
t
-
W
e
l
l
Ge
o
s
t
e
e
r
i
n
g
X
-
S
e
c
t
i
o
n
S
u
m
m
a
r
y
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
W
e
l
l
P
l
o
t
H
i
g
h
R
e
s
o
l
u
t
i
o
n
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
W
e
l
l
P
l
o
t
L
o
w
R
e
s
o
l
u
t
i
o
n
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
c
g
m
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
c
g
m
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
D
e
f
i
n
i
t
i
v
e
s
u
r
v
e
y
re
p
o
r
t
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
F
i
n
a
l
S
u
r
v
e
y
s
.
t
x
t
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
G
I
S
.
t
x
t
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
P
l
a
n
-
z
o
o
m
e
d
in
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
P
l
a
n
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
Tu
e
s
d
a
y
,
J
a
n
u
a
r
y
1
3
,
2
0
2
6
AO
G
C
C
P
a
g
e
1
o
f
4
MP
U
F
-
3
4
L
1
LW
D
F
i
n
al.
l
as
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
.
50
-
0
2
9
-
2
2
8
2
4
-
6
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
1-
O
I
L
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
6
/
2
0
2
4
Pe
r
m
i
t
t
o
D
r
i
l
l
22
3
1
0
7
0
Op
e
r
a
t
o
r
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
MD
24
9
3
8
TV
D
78
7
5
Cu
r
r
e
n
t
S
t
a
t
u
s
1-
O
I
L
1/
1
3
/
2
0
2
6
UI
C
No
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
s
u
r
v
e
y
s
.
x
l
s
x
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
V
S
e
c
-
z
o
o
m
e
d
in
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
V
S
e
c
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
_
F
-
3
4
L
1
_
A
D
R
_
I
m
a
g
e
.
d
l
i
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
_
F
-
3
4
L
1
_
A
D
R
_
I
m
a
g
e
.
v
e
r
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
2/
1
6
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
20
0
2
5
2
4
8
8
5
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
:
M
P
U
F
-
3
4
L
1
AD
R
Q
u
a
d
r
a
n
t
s
A
l
l
C
u
r
v
e
s
.
l
a
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
18
6
9
9
2
4
9
3
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
:
M
P
U
F
-
3
4
L
1
LW
D
F
i
n
a
l
.
l
a
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
We
l
l
P
l
o
t
R
E
I
S
S
U
E
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
We
l
l
P
l
o
t
R
E
I
S
S
U
E
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
C
u
s
t
o
m
e
r
Su
r
v
e
y
.
x
l
s
x
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
W
e
l
l
R
e
p
o
r
t
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
P
o
s
t
-
W
e
l
l
Ge
o
s
t
e
e
r
i
n
g
X
-
S
e
c
t
i
o
n
S
u
m
m
a
r
y
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
G
e
o
s
t
e
e
r
i
n
g
E
n
d
o
f
W
e
l
l
P
l
o
t
H
i
g
h
R
e
s
o
l
u
t
i
o
n
R
E
I
S
S
U
E
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
c
g
m
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
c
g
m
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
D
e
f
i
n
i
t
i
v
e
s
u
r
v
e
y
re
p
o
r
t
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
F
i
n
a
l
S
u
r
v
e
y
s
.
t
x
t
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
Tu
e
s
d
a
y
,
J
a
n
u
a
r
y
1
3
,
2
0
2
6
AO
G
C
C
P
a
g
e
2
o
f
4
MP
U
F
-
3
4
L
1
LW
D
F
i
n
al.
l
as
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
.
50
-
0
2
9
-
2
2
8
2
4
-
6
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
1-
O
I
L
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
6
/
2
0
2
4
Pe
r
m
i
t
t
o
D
r
i
l
l
22
3
1
0
7
0
Op
e
r
a
t
o
r
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
MD
24
9
3
8
TV
D
78
7
5
Cu
r
r
e
n
t
S
t
a
t
u
s
1-
O
I
L
1/
1
3
/
2
0
2
6
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
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
Co
m
p
l
e
t
i
o
n
D
a
t
e
:
2
/
6
/
2
0
2
4
Re
l
e
a
s
e
D
a
t
e
:
1
1
/
2
1
/
2
0
2
3
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
G
I
S
.
t
x
t
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
P
l
a
n
-
z
o
o
m
e
d
in
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
P
l
a
n
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
s
u
r
v
e
y
s
.
x
l
s
x
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
V
S
e
c
-
z
o
o
m
e
d
in
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
_
V
S
e
c
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
e
m
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
_
F
-
3
4
L
1
_
A
D
R
_
I
m
a
g
e
.
d
l
i
s
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
_
F
-
3
4
L
1
_
A
D
R
_
I
m
a
g
e
.
v
e
r
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
p
d
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
M
D
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
DF
3/
1
9
/
2
0
2
4
E
l
e
c
t
r
o
n
i
c
F
i
l
e
:
M
P
U
F
-
3
4
L
1
L
W
D
F
I
n
a
l
T
V
D
.
t
i
f
38
5
1
2
ED
Di
g
i
t
a
l
D
a
t
a
Tu
e
s
d
a
y
,
J
a
n
u
a
r
y
1
3
,
2
0
2
6
AO
G
C
C
P
a
g
e
3
o
f
4
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
.
50
-
0
2
9
-
2
2
8
2
4
-
6
0
-
0
0
We
l
l
N
a
m
e
/
N
o
.
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
Co
m
p
l
e
t
i
o
n
S
t
a
t
u
s
1-
O
I
L
Co
m
p
l
e
t
i
o
n
D
a
t
e
2/
6
/
2
0
2
4
Pe
r
m
i
t
t
o
D
r
i
l
l
22
3
1
0
7
0
Op
e
r
a
t
o
r
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
MD
24
9
3
8
TV
D
78
7
5
Cu
r
r
e
n
t
S
t
a
t
u
s
1-
O
I
L
1/
1
3
/
2
0
2
6
UI
C
No
Co
m
m
e
n
t
s
:
Co
m
p
l
i
a
n
c
e
R
e
v
i
e
w
e
d
B
y
:
Da
t
e
:
Da
t
e
C
o
m
m
e
n
t
s
De
s
c
r
i
p
t
i
o
n
Tu
e
s
d
a
y
,
J
a
n
u
a
r
y
1
3
,
2
0
2
6
AO
G
C
C
P
a
g
e
4
o
f
4
1/
1
5
/
2
0
2
6
M.
G
u
h
l
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 03/18/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL: (REISSUE)
WELL: MPU F-34L1
PTD: 223-107
API: 50-029-22824-60-00
FINAL LWD FORMATION EVALUATION + GEOSTEERING (01/15/2024 to 01/27/2024)
x iCRUISE (ABG), BASESTAR GR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders: (REISSUED PLOTS – EMF, PDF, TIFF)
Please include current contact information if different from above.
223-107
T38512
3/19/2024
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.03.19 08:19:29 -08'00'
KUPARUK RIVER OIL AND UNDEFINED OIL POOLS
By Grace Christianson at 12:04 pm, Feb 23, 2024
Completed
2/6/2024
JSB
RBDMS JSB 030624
G
DSR-3/11/24
Drilling Manager
02/22/24
Monty M
Myers
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143)
Date: 2024.02.22 11:53:45 -
09'00'
Taylor Wellman
(2143)
_____________________________________________________________________________________
Revised By: JNL 2/6/2024
SCHEMATIC
Milne Point Unit
Well: MPU F-34 / F-34L1
Last Completed: 2/3/2024
PTD: 197-197 / 223-107
OPEN HOLE / CEMENT DETAIL
30” 250 sx of Arcticset I (Approx)
12-1/4” 2,200 sx PF ‘E’, 775 sx Class ‘G’
8-1/2” 263 sx Class ‘G’
6-1/8” Uncemented Drilled Liner
JEWELRY DETAIL
No Depth Item
1 200’ GLM w/ DPSOV
2 16,696’ GLM w/ Dummy Valve
3 16,751’ XN Nipple, 2.313”
4 18,460’ Discharge Head
5 18,461’ Pump #4 – 400 Series, SF2700 1:3 AR, SHB, TS3
6 18,483’ Pump #3 – 400 Series, SF2700 1:3 AR, SHB, TS3
7 18,505’ Pump #2 – 400 Series, SF2700 1:3 AR, SHB, TS3
8 18,526’ Pump #1 – 400 Series, SF2700 1:3 AR, SHB, TS3
9 18,548’ Gas Separator / Intake: GS 400X
10 18,552’ Upper Tandem Seal: 400 Series
11 18,560’ Lower Tandem Seal: 400 Series
12 18,569’ Motor UT: 456 Series, FNS2, 180 HP / 1,570V / 80A 12RTR
13 18,589’ Motor LT: 456 Series, FNS2, 180 HP / 1,570V / 80A 12RTR
14 18,609’ Motor Gauge
15 18,612’ Centralizer: Bottom @ 18,614’
16 18,795’ SLZXP Liner Top Packer / Liner Hanger
TD =20,980’ (MD) / TD = 7,653’(TVD)
20”
ES Cement e
@ 2,067’
Orig. KB Elev.: 46.29’/ GL Elev.: 12.0’
7”
3
L1 PBTD = 24,937’ (MD) / L1 PBTD = 7,875’ (TVD)
9
2
9-5/8”
1
(2) 7” X 20’ Short
Joints from 18,758’
to 18,798’ wlm.
L1 TD =24,938’ (MD) / L1 TD =7,875’ (TVD)
PBTD =20,863’ (MD) / PBTD = 7,645’(TVD)
10&11
KUP Sands
12-14
16
4
Mid –perf=
7,616’TVD,
19,845’MD
Window:
20,016’ – 20,027’
5-8
15
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 0.3553
9-5/8" Surface 40 / L-80 / Btrc 8.835 Surface 8,680’ 0.0758
7" Production 26 / L-80 / EUE 8rd 6.276 Surface 20,948’ 0.0383
4-1/2” Liner (Drilled) 13.5 / L-80 / EUE 8rd 3.920 18,795’ 24,938’ 0.0152
TUBING DETAIL
2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 18,614’ 0.0152
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. Sands 18,970’ 19,005’ 7,560’ 7,567’ 35 2/4/1998 Open
Kup. Sands 19,018’ 19,040’ 7,569’ 7,573’ 22 2/4/1998 Open
Kup. Sands 19,385’ 19,571’ 7,611’ 7,614’ 186 2/4/1998 Open
Kup. Sands 19,676’ 19,820’ 7,615’ 7,626’ 144 2/4/1998 Open
Kup. Sands 20,050’ 20,454’ 7,649’ 7,674’ 404 2/4/1998 Open
Kup. Sands 20,599’ 20,720’ 7,677’ 7,673’ 121 2/4/1998 Open
Ref Log: LWD 12/23/1998– 4.5” Perf Guns
L1: Kup 18,947’ 24,240’ 7,557’ 7,868’ 5,293 1/30/2024 Open
WELL INCLINATION DETAIL
KOP @ 400’ / L1: 20,016’
Tangent Hole Angle= 69 to 74 Degrees f/ 3,650’ to 17,100’
Max Hole Angle = 96° / L1: 93°
Hole Angle through perfs = Horizontal
TREE & WELLHEAD
Tree Cameron 2-9/16” 5M
Wellhead
11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC tbg
hng, 3” LH acme on top and 2-7/8” EUE 8rd on
bottom, 2.5” CIW BPV profile
GENERAL WELL INFO
API: 50-029-22824-00-00 / 60-00
Drilled, Cased & Completed by Nabors 27E - 2/8/98
RWO ESP by Nabors 4ES 1/22/2010
RWO ESP by ASR#1 – 9/30/2016
RWO ESP by ASR#1 – 10/25/2020
L1 Sidetrack by Doyon 14 – 2/6/2024
NOTE
7” Emergency Slips Required
0
4
8
12
16
20 22 24 26 28 30 32 34 36
0
5
10
15
20
25
30
35
40
45
50
55
60
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
0 10203040506070
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
834
634
568
526492470449430413398384377
2720 2714 2710 2707 2706 270427042704270327032703
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
0 5 10 15 20 25 30 35
Pr
e
s
s
u
r
e
(p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
MP F-34L1
MP F-34L1
MP F-34L1
MP F-34L1
MP F-34L1
MP F-34L1
MP F-34L1
RDMO 03:00 2/6/24.
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 02/16/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL:
WELL: MPU F-34L1
PTD: 223-107
API: 50-029-22824-60-00
FINAL LWD FORMATION EVALUATION + GEOSTEERING (01/15/2024 to 01/27/2024)
x iCRUISE (ABG), BASESTAR GR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
FINAL LWD Subfolders:
FINAL Geosteering Subfolders:
Please include current contact information if different from above.
PTD: 223-107
T38512
2/16/2024Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.16
13:10:54 -09'00'
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:Alaska NS - Doyon 14 - DSMs
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Subject:2-7/8" test
Date:Sunday, February 4, 2024 11:53:14 AM
Attachments:Doyon 14 BOP_ MPU F-34L1_2-2-24.xlsx
Good afternoon,
Well- MPU F-34L1 original approved well program called for a 4-1/2” upper completion. A revision
was sent in with a request to change this to a 2-7/8” upper completion. This was approved. We then
tested rams and annular with a 2-7/8” test joint. Results are attached.
Thank you.
Mark Brouillet
Hilcorp Alaska, LLC
Doyon Rig 14
Office: 907-670-3090
Doghouse: 907-670-3092
Cell: 907-631-9850
mark.brouillet@Hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
0LOQH3RLQW8QLW)/
37'
change this to a 2-7/8” upper completion
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:14 DATE: 2/2/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #22231070 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1493
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping NA Well Sign NA Upper Kelly 0NA
Permit On Location NA Hazard Sec.NA Lower Kelly 0NA
Standing Order Posted NA Misc.NA Ball Type 0NA
Test Fluid Water Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 N/A NA Trip Tank NA NA
Annular Preventer 1 13-5/8"P Pit Level Indicators NA NA
#1 Rams 1 2-7/8" x 5"P Flow Indicator NA NA
#2 Rams 1 Blinds NA Meth Gas Detector NA NA
#3 Rams 1 2-7/8"X5"P H2S Gas Detector NA NA
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" X 5000 P Time/Pressure Test Result
HCR Valves 2 3-1/8" X 5000 NA System Pressure (psi)NA
Kill Line Valves 1 3-1/8" X 5000 P Pressure After Closure (psi)NA
Check Valve 0NA200 psi Attained (sec)NA
BOP Misc 0NAFull Pressure Attained (sec)NA
Blind Switch Covers: All stations NA
CHOKE MANIFOLD:Bottle Precharge:NA
Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA
No. Valves 14 NA ACC Misc 0NA
Manual Chokes 1NA
Hydraulic Chokes 1NA Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer NA
#1 Rams NA
Coiled Tubing Only:#2 Rams NA
Inside Reel valves 0NA #3 Rams NA
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:0 Test Time:2.5 HCR Choke NA
Repair or replacement of equipment will be made within 0 days. HCR Kill NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 1/31/24 19:31pm
Waived By
Test Start Date/Time:2/2/2024 19:30
(date) (time)Witness
Test Finish Date/Time:2/2/2024 22:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
Test with 2-7/8" test jt. Annular to 2500 psi, Upper and Lower VBR's to 3500 psi against the test plug and choke and kill line
manual valves. Test required after approved plan change on upper completion from 4-1/2" to 2-7/8"
J Hansen / N Hamilton
Hilcorp
M Brouillet / J Vanderpool
MPU F-34L1
Test Pressure (psi):
rig14@doyondrilling.com
skaNS-Doyon14-DSMs@hilcorp.c
Form 10-424 (Revised 08/2022) 2024-0202_BOP_Doyon14_rams-annular_MPU_F-34L1
+LOFRUS$ODVND//&MEU
9 9
9
9 9 9
9
9
9
9
9
9
9
9
9
9
- 5HJJ
jppp pgp
Test required after approved plan change on upper completion from 4-1/2" to 2-7/8"
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:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: 20240131 1559 APPROVAL for Completion Alteration MPU F-34L1 (PTD 223-107) Procedure Revision
Date:Thursday, February 1, 2024 8:41:50 AM
Attachments:MP F-34L1 PROPOSED Rev1 - Conventional ESP 1-24-2024.pdf
From: Rixse, Melvin G (OGC)
Sent: Wednesday, January 31, 2024 3:59 PM
To: Taylor Wellman <twellman@hilcorp.com>
Cc: aogcc.inspectors@alaska.gov
Subject: 20240131 1559 APPROVAL for Completion Alteration MPU F-34L1 (PTD 223-107) Procedure
Revision
Taylor,
Hilcorp is approved to alter the 4-1/2” completion to a 2-7/8” completion with tested 2-7/8” VBR
rams as described below.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
AOGCC is inspectors
From: Taylor Wellman <twellman@hilcorp.com>
Sent: Wednesday, January 31, 2024 3:55 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Subject: MPU F-34L1 (PTD 223-107) Procedure Revision
Mr. Rixse,
For the sidetracked well MPU F-34L1 (PTD 223-107) operations have gone fairly well and the liner
has been landed. After reviewing the well we have we would like to change the upper completion
from a 4-1/2” Conventional ESP to a 2-7/8” Conventional ESP completion. This change would
require the following changes to the approved PTD procedural steps (also see attached schematic):
14.1 Perform BOP test on components for running 2-7/8” tubing (VBR’s and Annular) to
250/3,500psi.
Last BOP test was performed on the planned smallest tubing/drill pipe size of 4” on
1/24/24.
14.2 – 14.3 ESP description to be updated to new design run on 2-7/8” tubing.
Reason/Justification: There was a large difference in predicted lateral length and net sand that
what was originally predicted. The original predictions needed a large ESP sized to move ~5,000
bfpd which required 4-1/2” tubing. After the well was TD’d and analyzed, the predicted fluid rates
are much lower and can be produced using a smaller ESP and 2-7/8” tubing. The optimized ESP size
will allow for extended run life of the pump and the smaller tubing will allow the ASR to perform
future workovers as needed.
If you see any issue with this course of action please let us know.
Thank you,
Taylor
Taylor Wellman
Hilcorp Alaska, LLC: Wells Manager – Milne Point
Office: (907) 777-8449
Cell: (907) 947-9533
Email: twellman@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________MILNE PT UNIT F-34L1
JBR 03/05/2024
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
Tested everything with 4" & 4.5" test joints. PVT and flow sensor tested good. Tested all H2S and LEL sensors/ alarms. Lower
IBOP failed, greased and functioned, failed again. Swapped it out and it passed. Very good test besides that. Nitrogen:
15@1066 psi.
Test Results
TEST DATA
Rig Rep:Oriville Williams.Operator:Hilcorp Alaska, LLC Operator Rep:I Toomey, Mark Broulet
Rig Owner/Rig No.:Doyon 14 PTD#:2231070 DATE:1/24/2024
Type Operation:DRILL Annular:
250/3500Type Test:BIWKLY
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopJDH240123183446
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 11
MASP:
1493
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 FP
Ball Type 2 P
Inside BOP 2 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 2-7/8X5"P
#2 Rams 1 Blinds P
#3 Rams 1 2-7/8X5"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 2 3-1/8" 5M P
HCR Valves 2 3-1/8" 5M P
Kill Line Valves 2 3-1/8" 5M P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1550
200 PSI Attained P46
Full Pressure Attained P215
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1970
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P15
#1 Rams P8
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
_____________________________________________________________________________________
Revised By: TTW 1/31/2024
PROPOSED Rev 1
Milne Point Unit
Well: MPU F-34 / F-34L1
Last Completed: TBD
PTD: 197-197 / TVD
JEWELRY DETAIL
No Depth Item
1 ±18,456’ Discharge Head
2 ±18,460’ Pump #1 – Summit SF2700 TS3 AR
3 ±18,482’ Pump #2 – Summit SF2700 TS3 AR
4 ±18,504’ Pump #3 – Summit SF2700 TS3 AR
5 ±18,526’ Pump #4 – Summit SF2700 TS3 AR
6 ±18,548’ Gas Separator Intake – GS H2X Tandem
7 ±18,553’ Upper Tandem Seal – 5.13 EXHL Seal
8 ±18,562’ Lower Tandem Seal – 5.13 EXHL Seal
9 ±18,571’ Motor: 456 FMS2 Tandem (360 Hp)
10 ±18,612’ Motor Gauge
11 ±18,615’ Centralizer: Bottom @ 18,615’
12 ±18,795’ SLZXP Liner Top Packer / Liner Hanger
TD =20,980’ (MD) / TD = 7,653’(TVD)
20”
ES Cementer
@ 2,067’
Orig. KB Elev.:45.7’/ GL Elev.:12.0’
7”
5
L1 PBTD = 32,559’ (MD) / L1 PBTD = 8,151’ (TVD)
9-5/8”
1
(2) 7” X 20’ Short
Joints from 18,758’
to 18,798’ wlm.
L1 TD = 32,559’ (MD) / L1 TD = 8,151’ (TVD)
PBTD =20,863’ (MD) / PBTD = 7,645’(TVD)
7&8
KUP Sands
9&10
12
Mid –perf=
7,616’TVD,
19,845’MD
Whipstock Set @
±20,016’
2-5
11
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20"Conductor 91.1 / NT80LHE / N/A N/A Surface 113'0.3553
9-5/8"Surface 40 / L-80 / Btrc 8.835 Surface 8,680’0.0758
7"Production 26 / L-80 / EUE 8rd 6.276 Surface 20,948’0.0383
4-1/2” Liner (Pre-Perf) 12.6 / L-80 / EUE 8rd 3.958 ±18,795’ ±24,239’ 0.0152
4-1/2”Liner (Solid)12.6 / L-80 / EUE 8rd 3.958 ±24,239’ ±24,938’ 0.0152
TUBING DETAIL
2-7/8”Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±18,615’ 0.0152
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. Sands 18,970’19,005’7,560’7,567’35 2/4/1998 Open
Kup. Sands 19,018’19,040’7,569’7,573’22 2/4/1998 Open
Kup. Sands 19,385’19,571’7,611’7,614’186 2/4/1998 Open
Kup. Sands 19,676’19,820’7,615’7,626’144 2/4/1998 Open
Kup. Sands 20,050’20,454’7,649’7,674’404 2/4/1998 Closed
Kup. Sands 20,599’20,720’7,677’7,673’121 2/4/1998 Closed
Ref Log:LWD 12/23/1998–4.5” Perf Guns
OPEN HOLE / CEMENT DETAIL
20"250 sx of Arcticset I (Approx) in a 30” Hole
9-5/8"2,200 sx PF ‘E’, 775 sx Class ‘G’ in a 12-1/4” Hole
7”263 sx Class ‘G’ in a 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 400’ / L1: 20,011’
Tangent Hole Angle= 69 to 74 Degrees f/ 3,650’ to 17,100’
Max Hole Angle = 96°
Hole Angle through perfs = Horizontal
TREE & WELLHEAD
Tree Cameron 2-9/16” 5M
Wellhead
11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC tbg
hng, 3” LH acme on top and 2-7/8” EUE 8rd on
bottom, 2.5” CIW BPV profile
GENERAL WELL INFO
API: 50-029-22824-00-00
Drilled, Cased & Completed by Nabors 27E - 2/8/98
RWO ESP by Nabors 5S 7/8/1998
RWO ESP by Nabors 4ES 3/12/2003
RWO ESP by Nabors 4ES 5/22/2007
RWO ESP by Nabors 4ES 1/22/2010
RWO ESP by ASR#1 – 9/30/2016
RWO ESP by ASR#1 – 10/25/2020
NOTE
7” Emergency Slips Required
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
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Milne Point, Kuparuk River Oil Pool, MPU F-34L1
Hilcorp Alaska, LLC
Permit to Drill Number: 223-107
Surface Location: 1970' FSL, 2750' FEL, Sec 06, T13N, R10E UM, AK
Bottomhole Location: 591' FNL, 2571' FEL, Sec 08, T14N, R10E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced 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.
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 AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this 22 day of January 2024.
Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.01.22 12:49:00 -09'00'
REVISED
Change of Bottom Hole
Location over 500'
Drilling Manager
01/04/24
Monty M
Myers
By Grace Christianson at 12:26 pm, Jan 04, 2024
A.Dewhurst 09JAN24
* Initial BOPE pressure test to 4000 psi. Annular to 2500 psi.
* Subsequent BOPE pressure tests to 3500 psi. Annular to 2500 psi.
* Not approved for subsequent BOPE pressure test below 3500 psi.
223-107
MGR05JAN2024
50-029-22824-60-00
DSR-1/19/24*&: JLC 1/22/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.01.22 12:49:17 -09'00'01/22/24
01/22/24
Milne Point Unit
(MPU) F-34L1
Application for Permit to Drill
Version 2
January 3, 2024
Table of Contents
1.0 Well Summary ........................................................................................................................... 2
2.0 Management of Change Information ........................................................................................ 3
3.0 Tubular Program ....................................................................................................................... 4
4.0 Drill Pipe Information ............................................................................................................... 4
5.0 Internal Reporting Requirements ............................................................................................. 5
6.0 Wellbore Schematics .................................................................................................................. 6
7.0 Drilling / Completion Summary ................................................................................................ 9
8.0 Mandatory Regulatory Compliance / Notifications ................................................................ 10
9.0 R/U and Test BOPE ................................................................................................................. 12
10.0 Pull 2-7/8” Tubing, Cleanout, Test Casing .............................................................................. 14
11.0 Mill 6-1/8” Window and Kick Off ........................................................................................... 15
12.0 Drill 6-1/8” Production Hole Section ....................................................................................... 18
13.0 Run 4-1/2” Liner ...................................................................................................................... 21
14.0 Run Upper Completion............................................................................................................ 24
15.0 RDMO ...................................................................................................................................... 26
16.0 Post-Rig Work ......................................................................................................................... 27
17.0 Doyon 14 BOP Schematic ........................................................................................................ 28
18.0 Wellhead Schematic ................................................................................................................. 29
19.0 Days Vs Depth .......................................................................................................................... 31
20.0 Formation Tops & Information............................................................................................... 32
21.0 Anticipated Drilling Hazards .................................................................................................. 33
22.0 Doyon 14 Layout ...................................................................................................................... 35
23.0 FIT Procedure .......................................................................................................................... 36
24.0 Doyon 14 Choke Manifold Schematic ..................................................................................... 37
25.0 Casing Design Information ...................................................................................................... 38
26.0 6-1/8” Hole Section MASP ....................................................................................................... 39
27.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 40
28.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 41
Page 2
Milne Point Unit F-34L1
Drilling Procedure
1.0 Well Summary
Well MPU F-34L1
Pad Milne Point “F” Pad
Planned Completion Type 4-1/2” Pre-Drilled Liner
Target Reservoir(s) Kuparuk A
Planned Well TD, MD / TVD 29,921’ MD / 8,091’ TVD 32,559 MD / 8,151’ TVD
PBTD, MD / TVD 29,921’ MD / 8,091’ TVD 32,559 MD / 8,151’ TVD
Surface Location (Governmental) 1970' FSL, 2409' FWL, Sec 6, T13N, R10E, UM, AK
Surface Location (NAD 27 – Zone 4) X=541,813 Y=6,035,422
Top of Productive Horizon
(Governmental) 2162' FSL, 540' FEL, Sec 19, T14N, R10E, UM, AK
TPH Location (NAD 27) X=543,870, Y=6,051,463
BHL (Governmental)
2041' FSL, 2317' FWL, Sec 8, T14N, R10E, UM, AK
594’ FNL, 2571’ FEL, Sec 8, T14N, R10E, UM, AK
BHL (NAD 27)
X=546,627, Y=6,061,919
X = 546,993, Y = 6,064,565
AFE Drilling Days 30 Days
AFE Completion Days 5 Days
Maximum Anticipated Pressure
(Surface) 1,493 psi
Maximum Anticipated Pressure
(Downhole/Reservoir) 2,254 psi (5.7ppg EMW)
Work String 4” 14# S-135 XT-39
KB Elevation above MSL: 33.7 ft + 12.0 ft = 45.7 ft
GL Elevation above MSL: 12.0 ft
BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams
Page 3
Milne Point Unit F-34L1
Drilling Procedure
2.0 Management of Change Information
Page 4
Milne Point Unit F-34L1
Drilling Procedure
3.0 Tubular Program
Hole
Section
OD
(in)
ID (in)Drift
(in)
Conn
OD (in)
Wt
(#/ft)
Grade Conn Burst
(psi)
Collapse
(psi)
Tension
(k-lbs)
6-1/8” 4-1/2” 3.92 3.795 4.714 13.5 L-80 H625 9,020 8,540 279
Tubing 4-1/2” 3.958 3.833 5.0 12.6 L-80 JFE Bear 8,430 7,500 288
4.0 Drill Pipe Information
Hole
Section
OD
(in)
ID (in)TJ ID
(in)
TJ OD
(in)
Wt
(#/ft)
Grade Conn M/U
(Min)
M/U
(Max)
Tension**
(k-lbs)
Production 4” 3.34” 2.563”4.875”14.0 S-135 XT39 18,500 22,200* 446
**Assumes 1.0 friction factor pipe dope, use 24,420 ft-lbs for 1.1 FF dope
*Tension Rating Based on Premium Pipe
All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery).
Page 5
Milne Point Unit F-34L1
Drilling Procedure
5.0 Internal Reporting Requirements
Fill out daily drilling report and cost report on Wellez.
x Report covers operations from 6am to 6am
x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left
of the data entry area – this will not save the data entered, and will navigate to another data entry
tab.
x Ensure time entry adds up to 24 hours total.
x Try to capture any out of scope work as NPT. This helps later on when we pull end of well
reports.
x Enter the MD and TVD depths EVERY DAY whether you are making hole or not.
Afternoon Updates
x Submit a short operations update each work day to mmyers@hilcorp.com,
nathan.sperry@hilcorp.com,jengel@hilcorp.com and joseph.lastufka@hilcorp.com
Intranet Home Page Morning Update
x Submit a short operations update each morning by 7am on the company intranet homepage. On
weekend and holidays, ensure to have this update in before 5am.
EHS Incident Reporting
x Health and safety: Notify EHS field coordinator.
x Environmental: Drilling Environmental coordinator
x Notify Drlg Manager & Drlg Engineer
x Submit Hilcorp Incident report to contacts above within 24 hrs
Casing Tally
x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com
Casing and Cement report
x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com
Hilcorp Milne Point Contact List:
Title Name Work Phone Email
Drilling Manager Monty Myers 907.777.8431 mmyers@hilcorp.com
Drilling Engineer Joe Engel 907.777.8395 jengel@hilcorp.com
Drilling Engineer Nathan Sperry 907.777.8450 nathan.sperry@hilcorp.com
Operations Engineer Taylor Wellman 907.777.8449 twellman@hilcorp.com
Geologist Graham Emerson 907.564.5242 Graham.emerson@hilcorp.com
Reservoir Engineer Alan Abel 907.564.5032 Alan.abel@hilcorp.com
Safety Manager Laura Green 907.777.8314 lagreen@hilcorp.com
Drilling Tech Joe Lastufka 907.777.8400 Joseph.Lastufka@hilcorp.com
_____________________________________________________________________________________
Revised By: TDF 7/10/2023
CURRENT SCHEMATIC
Milne Point Unit
Well: MPU F-34
Last Completed: 8/15/2021
PTD: 197-197
TD =20,980’ (MD) / TD = 7,653’(TVD)
20”
ES Cementer
@ 2,067’
Orig. KB Elev.: 45’/ GL Elev.: 12’ (N27E)
DF to Tbg. Spool = 30.8’ (N 27E)
7”
2
3
9
10 & 11
9
14
12
9-5/8”
1
Min ID= 2.205”
@ 16,761’
(2) 7” X 20’ Short
Joints from 18,758’
to 18,798’ wlm.
PBTD =20,863’ (MD) / PBTD = 7,663’(TVD)
4&5
KUP Sands
6, 7 & 8
Mid –perf=
7,616’TVD,
19,845’MD
13
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 91.1 / NT80LHE / N/A N/A Surface 113' 0.3553
9-5/8" Surface 40 / L-80 / Btrc 8.835 Surface 8,680’ 0.0758
7" Production 26 / L-80 / EUE 8rd 6.276 Surface 20,948’ 0.0383
TUBING DETAIL
2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 18,844’ 0.0058
JEWELRY DETAIL
No Depth Item
1 199’ GLM STA# 2: 2-7/8” x 1” w/1” Orifice Valve
2 16,709’ GLM STA# 1: 2-7/8” x 1” KBMM w/ Dummy
3 16,761’ 2-7/8” XN-Nipple (2.205 No-go ID)
4 18,748’ Ported Pressure Sub: ADPT 400P 2-7/8”
5 18,749’ Discharge Head: DSCHG B/O PMP 400 2.88X8 EUE
6 18,749’ Pump #3: PMP 400 143 Stage SF675
7 18,770’ Pump #2: PMP 400 143 Stage SF675
8 18,793’ Pump #1: PMP 400 66 Stage SF675
9 18,803’ Gas Separator Intake
10 18,808’ Upper Tandem Seal
11 18,816’ Lower Tandem Seal
12 18,825’ Motor: MTR 456 120/1970/43
13 18,840’ Motor Gauge
14 18,841’ Centralizer: Bottom @ 18,844’
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. Sands 18,970’ 19,005’ 7,560’ 7,567’ 35 2/4/1998 Open
Kup. Sands 19,018’ 19,040’ 7,569’ 7,573’ 22 2/4/1998 Open
Kup. Sands 19,385’ 19,571’ 7,611’ 7,614’ 186 2/4/1998 Open
Kup. Sands 19,676’ 19,820’ 7,615’ 7,626’ 144 2/4/1998 Open
Kup. Sands 20,050’ 20,454’ 7,649’ 7,674’ 404 2/4/1998 Open
Kup. Sands 20,599’ 20,720’ 7,677’ 7,673’ 121 2/4/1998 Open
Ref Log: LWD 12/23/1998– 4.5” Perf Guns
OPEN HOLE / CEMENT DETAIL
20" 250 sx of Arcticset I (Approx) in a 30” Hole
9-5/8" 2,200 sx PF ‘E’, 775 sx Class ‘G’ in a 12-1/4” Hole
7” 263 sx Class ‘G’ in a 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 400’
Tangent Hole Angle= 69 to 74 Degrees f/ 3,650’ to 17,100’
Max Hole Angle = 96°
Hole Angle through perfs = Horizontal
TREE & WELLHEAD
Tree Cameron 2-9/16” 5M
Wellhead
11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC tbg
hng, 3” LH acme on top and 2-7/8” EUE 8rd on
bottom, 2.5” CIW BPV profile
GENERAL WELL INFO
API: 50-029-22824-00-00
Drilled, Cased & Completed by Nabors 27E - 2/8/98
RWO ESP by Nabors 5S 7/8/1998
RWO ESP by Nabors 4ES 3/12/2003
RWO ESP by Nabors 4ES 5/22/2007
RWO ESP by Nabors 4ES 1/22/2010
RWO ESP by ASR#1 – 9/30/2016
RWO ESP by ASR#1 – 10/25/2020
RWO ESP by ASR#1 – 8/15/2021
NOTE
7” Emergency Slips Required
_____________________________________________________________________________________
Revised By: JNL 1/2/2024
PROPOSED PRE-SIDETRACK
Milne Point Unit
Well: MPU F-34
Last Completed: 8/15/2021
PTD: 197-197
GENERAL WELL INFO
API: 50-029-22824-00-00
Drilled, Cased & Completed by Nabors 27E - 2/8/98
RWO ESP by ASR#1 – 8/15/2021TD =20,980’ (MD) / TD = 7,653’(TVD)
20”
ES Cementer
@ 2,067’
Orig. KB Elev.: 45.05’/ GL Elev.: 12.0’
DF to Tbg. Spool = 30.8’ (N 27E)
7”
9-5/8”
1
(2) 7” X 20’ Short
Joints from 18,758’
to 18,798’ wlm.
Whipstock set
@ ~20,011’
PBTD = 20,011’ (MD) / PBTD = 7,645’(TVD)
KUP Sands
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 0.3553
9-5/8" Surface 40 / L-80 / Btrc 8.835 Surface 8,680’ 0.0758
7" Production 26 / L-80 / EUE 8rd 6.276 Surface 20,948’ 0.0383
TUBING DETAIL
2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 18,844’ 0.0058
JEWELRY DETAIL
No Depth Item
1 20,011’ Whipstock
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. Sands 18,970’ 19,005’ 7,560’ 7,567’ 35 2/4/1998 Open
Kup. Sands 19,018’ 19,040’ 7,569’ 7,573’ 22 2/4/1998 Open
Kup. Sands 19,385’ 19,571’ 7,611’ 7,614’ 186 2/4/1998 Open
Kup. Sands 19,676’ 19,820’ 7,615’ 7,626’ 144 2/4/1998 Open
Kup. Sands 20,050’ 20,454’ 7,649’ 7,674’ 404 2/4/1998 Open
Kup. Sands 20,599’ 20,720’ 7,677’ 7,673’ 121 2/4/1998 Open
Ref Log: LWD 12/23/1998– 4.5” Perf Guns
OPEN HOLE / CEMENT DETAIL
24" 250 sx of Arcticset I (Approx)
12-1/4" 2,200 sx PF E, 775 sx Class G
8-1/2” 263 sx Class G, 230 sx Class G
WELL INCLINATION DETAIL
KOP @ 400’
Tangent Hole Angle= 69 to 74 Degrees f/ 3,650’ to 17,100’
Max Hole Angle = 96°
Hole Angle through perfs = Horizontal
TREE & WELLHEAD
Tree Cameron 2-9/16” 5M
Wellhead
11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC tbg
hng, 3” LH acme on top and 2-7/8” EUE 8rd on
bottom, 2.5” CIW BPV profile
NOTE
7” Emergency Slips Required
_____________________________________________________________________________________
Revised By: JNL 1/2/2024
PROPOSED
Milne Point Unit
Well: MPU F-34 / F-34L1
Last Completed: TBD
PTD: 197-197 / TVD
JEWELRY DETAIL
No Depth Item
1 ±18,663’ Discharge Head
2 ±18,664’ Pump #2
3 ±18,687’ Pump #1
4 ±18,710’ Gas Separator Intake
5 ±18,715’ Upper Tandem Seal
6 ±18,720’ Lower Tandem Seal
7 ±18,730’ Motor: MTR 562
8 ±18,748’ Motor Gauge
9 ±18,750’ Centralizer: Bottom @ 18,750’
10 ±18,810’ SLZXP Liner Top Packer / Liner Hanger
TD =20,980’ (MD) / TD = 7,653’(TVD)
20”
ES Cement e
@ 2,067’
Orig. KB Elev.:45.7’/ GL Elev.: 12.0’
7”
4
L1 PBTD = 32,559’ (MD) / L1 PBTD = 8,151’ (TVD)
9-5/8”
1
(2) 7” X 20’ Short
Joints from 18,758’
to 18,798’ wlm.
L1 TD = 32,559’(MD)/ L1 TD = 8,151’(TVD)
PBTD =20,863’ (MD) / PBTD = 7,645’(TVD)
5&6
KUP Sands
7&8
10
Mid –perf=
7,616’TVD,
19,845’MD
Whipstock Set @
±20,011’
2&3
9
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
20" Conductor 91.1 / NT80LHE / N/A N/A Surface 113' 0.3553
9-5/8" Surface 40 / L-80 / Btrc 8.835 Surface 8,680’ 0.0758
7" Production 26 / L-80 / EUE 8rd 6.276 Surface 20,948’ 0.0383
4-1/2”Liner (Pre-
Drilled)12.6 / L-80 / EUE 8rd 3.958 ±18,800’ ±32,559’ 0.0152
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / TXP-BTC 3.958 Surface ±18,800’ 0.0152
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Kup. Sands 18,970’ 19,005’ 7,560’ 7,567’ 35 2/4/1998 Open
Kup. Sands 19,018’ 19,040’ 7,569’ 7,573’ 22 2/4/1998 Open
Kup. Sands 19,385’ 19,571’ 7,611’ 7,614’ 186 2/4/1998 Open
Kup. Sands 19,676’ 19,820’ 7,615’ 7,626’ 144 2/4/1998 Open
Kup. Sands 20,050’ 20,454’ 7,649’ 7,674’ 404 2/4/1998 Closed
Kup. Sands 20,599’ 20,720’ 7,677’ 7,673’ 121 2/4/1998 Closed
Ref Log: LWD 12/23/1998–4.5” Perf Guns
OPEN HOLE / CEMENT DETAIL
20" 250 sx of Arcticset I (Approx) in a 30” Hole
9-5/8" 2,200 sx PF ‘E’, 775 sx Class ‘G’ in a 12-1/4” Hole
7” 263 sx Class ‘G’ in a 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 400’ / L1: 20,011’
Tangent Hole Angle= 69 to 74 Degrees f/ 3,650’ to 17,100’
Max Hole Angle = 96°
Hole Angle through perfs = Horizontal
TREE & WELLHEAD
Tree Cameron 2-9/16” 5M
Wellhead
11” x 7-1/16” 5M FMC Gen 5A w/ 2-7/8” FMC tbg
hng, 3” LH acme on top and 2-7/8” EUE 8rd on
bottom, 2.5” CIW BPV profile
GENERAL WELL INFO
API: 50-029-22824-00-00
Drilled, Cased & Completed by Nabors 27E - 2/8/98
RWO ESP by Nabors 5S 7/8/1998
RWO ESP by Nabors 4ES 3/12/2003
RWO ESP by Nabors 4ES 5/22/2007
RWO ESP by Nabors 4ES 1/22/2010
RWO ESP by ASR#1 – 9/30/2016
RWO ESP by ASR#1 – 10/25/2020
NOTE
7” Emergency Slips Required
Page 9
Milne Point Unit F-34L1
Drilling Procedure
7.0 Drilling / Completion Summary
MPU F-34L1 is a sidetrack production well targeting the Kuparuk River Pool, located on Milne Point ‘F-
pad’. The directional plan is a single string horizontal well with the kick off point at 20,011’ MD. Maximum
hole angle is ~91 degrees.
Drilling operations are expected to commence approximately December 10th, 2023, pending rig schedule.
Production liner will be 4-1/2” 13.5# L-80 pre-drilled liner run to 29,921’ MD / 8,091’ TVD 32,559 MD /
8,151’ TVD.
All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located
on “B” pad.
General sequence of operations:
1. MIRU Doyon 14
2. N/U 13-5/8” x 5M BOPE and test
3. Pull upper completion
4. Cleanout run
5. Run RBP to test 7” casing. Run storm packer swap tubing spool. Pull storm packer and RBP.
6. Set 7” WS and mill 6-1/8” window
7. Drill with kickoff (motor) assembly until sufficient separation achieved
8. Drill 6-1/8” hole with RSS to TD
9. Run 4-1/2” production liner
10. Run 4-1/2” production tubing
11. N/D BOP, N/U Tree, RDMO
Reservoir Evaluation Plan:
1. Production Hole: No mud logging. LWD: GR/Res
Page 10
Milne Point Unit F-34L1
Drilling Procedure
8.0 Mandatory Regulatory Compliance / Notifications
Regulatory Compliance
Ensure that all drilling and completion operations comply with all applicable AOGCC regulations.
Operations stated in this PTD application may be altered based on sound engineering judgement as
wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from
the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation,
do not hesitate to contact the Anchorage Drilling Team.
x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of
approval are captured in shift handover notes until they are executed and complied with.
x BOPs shall be tested at (1) week intervals prior to initiating window milling and (2) week intervals
during the drilling and completion of MPU F-34L1. Ensure to provide AOGCC 24 hrs notice prior
to testing BOPs.
x The initial test of BOP equipment will be to 250/4,000 psi & subsequent tests of the BOP equipment
will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial
and subsequent tests).Confirm that these test pressures match those specified on the APD.
x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the
well bore, AOGCC is to be notified and we must test all BOP components utilized for well control
prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP
test.
x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid
program and drilling fluid system”.
x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and
completion: blowout prevention equipment and diverter requirements”.
o Ensure the diverter vent line is at least 75’ away from potential ignition sources
x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test
must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a
minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test
pressure must show stabilizing pressure and may not decline more than 10 percent within 30
minutes. The results of this test and any subsequent tests of the casing must be recorded as required
by 20 AAC 25.070(1)”.
AOGCC Regulation Variance Requests:
x None
3500 psi pressure test required - mgr
Page 11
Milne Point Unit F-34L1
Drilling Procedure
Summary of BOP Equipment and Test Requirements
Hole Section Equipment Test Pressure (psi)
6-1/8”
x 13-5/8” x 5M Hydril “GK” Annular BOP
x 13-5/8” x 5M Hydril MPL Double Gate
o Blind ram in btm cavity
x Mud cross w/ 3” x 5M side outlets
x 13-5/8” x 5M Hydril MPL Single ram
x 3-1/8” x 5M Choke Line
x 3-1/8” x 5M Kill line
x 3-1/8” x 5M Choke manifold
x Standpipe, floor valves, etc
Initial Test: 250/4000
Subsequent Tests:
250/4000
Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air
pump, and emergency pressure is provided by bottled nitrogen.
The remote closing operator panels are located in the doghouse and on accumulator unit.
Required AOGCC Notifications:
x Well control event (BOPs utilized to shut in the well to control influx of formation fluids).
x 24 hours notice prior to spud.
x 24 hours notice prior to testing BOPs.
x 24 hours notice prior to casing running & cement operations.
x Any other notifications required in APD.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov
Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov
Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov
Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
3500 psi min - mgr
Page 12
Milne Point Unit F-34L1
Drilling Procedure
9.0 R/U and Test BOPE
This is an in-reservoir sidetrack. The existing perforations will not be isolated via a CIBP.
9.1 Ensure Sundry, PTD, and drilling program are posted in the rig office and on the rig floor.
9.2 Level pad and ensure enough room for layout of rig footprint and R/U.
9.3 Ensure rig mats cover entire footprint of rig.
9.4 MIRU Doyon 14. Ensure rig is centered over the wellhead to prevent any wear to BOPE or
wellhead.
x Mud loggers will not be used on F-34L1.
9.5 RU to pump down the tubing and take returns from the IA to a tank. Pump at least 1 truck of
seawater followed by at least one soap sweep surface to surface per MI.
x Estimated Kuparuk pore pressure is 5.7ppg and fracture gradient is 12.0ppg.
x The whipstock will be set at ~20,011’ MD.
x Note that it is recommended to circ another BU after pulling the hanger to the floor to clear
the annulus of any scale/debris.
x Tubing volume to the lower GLM is ~97 bbls
x IA volume to the lower GLM is ~505 bbls.
x Note: Circulation point will depend on prep work. If possible, the tubing will be
punched as close to the ESP as possible. Verify circ point with OE.
9.6 Install BPV. N/D the tree. Install test dart in the BPV.
9.7 N/U 13-5/8” x 5M BOP as follows:
x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13-
5/8” x 5M mud cross / 13-5/8” x 5M single gate
x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity,blind ram in
bottom cavity.
x Single ram can be dressed with 2-7/8” x 5” VBRs
x N/U bell nipple, install flowline.
x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to
mud cross).
x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual
valve
9.8 Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min.
x Test 2-7/8” x 5” VBR’s with 2-7/8” and 4-1/2” test joints
x Confirm test pressures with PTD
See attached emails for further discussion. -A.Dewhurst 09JAN24
Estimated Kuparuk pore pressure is 5.7ppg a
Page 13
Milne Point Unit F-34L1
Drilling Procedure
x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure
is trapped underneath test plug
x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech
9.9 R/D BOP test equipment.
9.10 Pull test dart and BPV.
9.11 Order out 8.6ppg fluid for production hole.
9.12 Ensure 5-1/2” or 5-3/4” liners in mud pumps (maximize available pump pressure).
Page 14
Milne Point Unit F-34L1
Drilling Procedure
10.0 Pull 2-7/8” Tubing, Cleanout, Test Casing
Pull tubing, cleanout, set retrievable bridge plug, test casing, set storm packer, swap tubing
spool, pull storm packer, pull RBP
10.1 PU landing joint or spear and recover the tubing hanger.
x The FMC 11” x 7-1/16” x 2-7/8” hanger was installed in 2021 by ASR.
10.2 Back out lock down screws.
10.3 Pull tubing hanger with landing joint/XO to the floor.
10.4 The tubing is expected to be in good condition.
10.5 Note and record PU weight required to pull the tubing from cut.
10.6 The expected weight of the string in a vertical hole filled with seawater is 110 klbs. PU weight
will be significantly less due to the deviation. Note: Final PU weight on the original
completion was 100klbs.
10.7 Recommend that at least 1X BU is circulated after pulling the hanger to the floor. If desired,
circulate another soap sweep surface-to-surface to clean the tubing.
10.8 Pull and lay down the upper completion.
10.9 Run wear ring.
10.10 PU 4” drill pipe and RIH with cleanout assembly per Baker rep.
10.11 When on bottom circulate at max rate a minimum of 1X BU or until returns are clean. Pump
high vis sweep if necessary.
10.12 POOH with cleanout assembly.
10.13 PU retrievable bridge plug and RIH to ~18,900’ MD. Set the RBP and test the casing to 2,500
psi. Rack back 2-5 stands and PU a storm packer.
10.14 TIH and set the storm packer. Test above the storm packer to 2,500 psi for 10 mins.
10.15 ND BOPE. ND the existing 7-1/16” x 11” Gen 5a FMC tubing spool. NU the 11” x 11” Gen 5
per wellhead rep. Pressure test spool per wellhead rep. Pressure test the BOPE break to 250 psi
low / 4,000 psi high.
10.16 RIH. Engage storm packer and release. POOH and lay down the storm packer. RIH and
retrieve the RBP. CBU. Flowcheck. POOH.
30 minute pressure test. Charted and recorded. - mgr
Page 15
Milne Point Unit F-34L1
Drilling Procedure
11.0 Mill 6-1/8” Window and Kick Off
Note: All following operations will be covered under by the PTD for F-34L1
x A CBL was run on January 26, 1998. The logging company picked the top of cement at
18,040’ MD (original KB). They noted good cement from the bottom of the logged interval
(19,232’ MD original KB) to their TOC pick.
11.1 Whipstock Set Depth Information:
x Planned TOW: ~20,011’ MD
i. Collars are located at 19,957.5’, 19,997.7’, and 20,037.1’ (parent RKB reference)
x WS will be set to avoid a collar based on the F-34 7” tally (Nabors 27E RKB of 30.55’).
Note that the original paperwork reports a 30.55’ RKB from the rig floor to the base flange.
x Doyon 14’s RKB on F-34L1 is 33.7’ (RKB to base flange) plus 12.0’ ground level for
45.7’. There is a 3.15’ shift from the OKB (Nabors 27E) to the Doyon 14 RKB.
x Drilling foreman, whipstock service hand, and drilling engineer to review parent tally and
agree on the set depth.
11.2 MU 6-1/8” mill/whipstock assembly as per Baker Hughes tally
x Make up HWDP, string magnets, and float sub
x Ensure magnets are in trough, under shakers and flow area to capture metal shavings
circulated
11.3 Install MWD and orient. Rack back mill assembly.
x Ensure a dedicated MWD is available for orientation of the whipstock
11.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD
and milling rep. Document and record offset in well file.
11.5 Slowly run in the hole as per fishing Rep. Run extremely slow through the BOP & wear bushing
to prevent damaging the shear bolt.
11.6 Run in hole at 1 ½ to 2 minutes per stand, or per Fishing Rep. Ensure work string is stationary
prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening
the shear bolt and prematurely setting the anchor.
11.7 Shallow test MWD
11.8 Stop at least 30-45’ above planned set depth and obtain survey with MWD.
11.9 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string,
measure and record P/U and S/O weights. Obtain good survey to orient whipstock face.
Page 16
Milne Point Unit F-34L1
Drilling Procedure
11.10 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP
to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is
30q ROHS.
11.11 Whipstock Orientation Diagram:
Desired orientation of the whipstock face is 10R to 30R, target is 30 ROHS
Hole Angle at window interval (20,011’ MD) is ~85°, Azimuth 359°.
11.12 Once whipstock is in desired orientation, set WS per fishing rep.
11.13 Pressure up per rep to set hydraulic set whipstock, (verify highlighted values with whipstock rep)
P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by
slacking off weight on the whipstock shear bolt. (35klbs shear value, verify with whipstock rep).
11.14 P/U 5-10’ above top of whipstock.
11.15 Displace to window milling fluid. CBU and confirm 8.6 ppg MW in/out
x Ensure mud properties are sufficient for transporting metal cuttings
x Milling fluid will be 8.6 ppg solids free mud
11.16 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight
and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch
metal cuttings. Pump high visc sweeps as necessary.
11.17 If possible, install catch trays in shaker underflow chute to help catch metal cuttings.
11.18 Clean catch trays and ditch magnets frequently while milling window.
11.19 Mill window until the uppermost mill has passed across the entire tray and 20’ of new hole has
been milled. Dress and polish window as needed.
30R10R
Page 17
Milne Point Unit F-34L1
Drilling Procedure
11.20 After window is milled and before POOH, shut down pumps and work milling assembly through
window watching for drag. Dress and polish window as needed. After reaming, shut off pumps
and rotary (if hole conditions allow) and pass through window checking for drag.
11.21 Circulate bottoms up until even MW in/out and hole is clean of metal shavings.
11.22 Pull back into 7” casing and perform FIT to 11.5 ppg EMW. Chart Test.
x Note: A 9.0ppg FIT with 8.6ppg fluid density provides 125 bbl kick tolerance assuming 5.7ppg
pore pressure (swabbed kick at 8.6ppg).
11.23 POOH & LD milling BHA. Gauge mills for wear.
11.24 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris.
Page 18
Milne Point Unit F-34L1
Drilling Procedure
12.0 Drill 6-1/8” Production Hole Section
12.1 PU 6-1/8” kickoff assembly.
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing.
x Workstring will be 4” 14# S-135 XT 39
x Run x2 Solid Plunger Floats for MPD
12.2 6-1/8” hole mud program summary:
x Density:The Kuparuk reservoir pressure is expected to be 5.7ppg. 8.6ppg MW will be used.
x Solids Concentration:It is imperative that the solids concentration be kept low while drilling
the production hole section. Keep the shaker screen size optimized and fluid running to near the
end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest
screens possible.
x Inhibition:3% KCl will be used for inhibition. Watch MBT levels, dilute as necessary to
maintain. Increase KCl % as needed
x Run the centrifuge continuously while drilling the production hole, this will help with solids
removal and minimize sand content and LGS to maintain fluid properties and quality of the mud
system.
x PVT will be used throughout the drilling phase. Remote monitoring stations will be available at
the driller’s console, Co Man office, & Toolpusher office.
System Type:8.6 - 9.8ppg FlowPro SF 3% KCl Inhibited
Properties:
Section Density
Plastic
Viscosity Yield Point Total
Solids
MBT pH
6-1/8” 8.6 - 9.8 ALAP 12-20 <5%< 7 9.0 - 9.5
12.3 TIH w/ 6-1/8” directional assembly on 4” DP to above window. Shallow test MWD and LWD
on trip in.
12.4 Ensure even 8.6ppg MW in and out. Note: MPD is NOT needed for drilling with the motor
assembly.
12.5 Drill 6-1/8” hole section with kickoff assembly at least until we have confirmed we have
separation from the old wellbore. TOOH.
pg y
The Kuparuk reservoir pressure is expected to be 5.7ppg.
Page 19
Milne Point Unit F-34L1
Drilling Procedure
12.6 P/U 6-1/8” RSS Directional BHA
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing.
x Workstring will be 4” 14# S-135 XT 39
x Run x2 Solid Plunger Floats for MPD
12.7 Install MPD Element
x Ensure rig crew is familiar with MPD connection operations
12.8 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer.
x Flow Rate: 150-250 gpm (Target 200 ft/min AV)
x RPM: 120 – 180
x WOB as needed
x Target ECD and CBHP: As low as reasonably possible to minimize lost circulation
x Take MWD surveys every stand drilled.
x Kuparuk PP estimate is 5.7 ppg. Good drilling and tripping practices are vital for avoidance
of differential sticking.
x Watch for fluid losses while drilling through Kuparuk.
12.9 At TD, circulate a minimum of 2X BU
x Circulate at full drill rate (150-250 gpm) while rotating at 120 rpm’s
x We can slowly rack back a couple of stands while performing the BU circulations.
12.10 Backream to the window:
x Circulate at max rate while minimizing drilling ECD’s
x Perform CBHP connections
x Rotate at maximum rpm that can be sustained.
x Limit pulling speed to 5 – 10 min/std (slip to slip time, not including connections).
x Continue backreaming to the window and circ at least 1X BU at the window.
x Rack back DP while TOOH. Do not lay down drill pipe. This is to minimize open hole time
before liner is on bottom.
x Once inside casing, drop rabbit on remaining drillpipe on TOOH that will be used to run the
4.5” liner. Confirm diameter drift with Baker for setting liner hanger.
12.11 Circulate a minimum of 2X BU at 7” window and clean casing with high vis sweeps.
12.12 Monitor well for flow. Increase mud weight if necessary
x Wellbore breathing has been seen on past MPU Kuparuk wells. Perform extended flow checks
to determine if well is breathing, treat all flow as an influx until proven otherwise
x If necessary, increase MW at shoe for any higher than expected pressure seen
Page 20
Milne Point Unit F-34L1
Drilling Procedure
12.13 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball
drops.
Page 21
Milne Point Unit F-34L1
Drilling Procedure
13.0 Run 4-1/2” Liner
Plan to alternate 1 solid joint and 1 pre-drilled joint.
13.1 Well control preparedness: In the event of an influx of formation fluids while running the 4-
1/2” injection liner with pre-drilled liner, the following well control response procedure will be
followed:
x With a pre-drilled joint across the BOP: P/U & M/U the 4” safety joint (with 4-1/2” crossover
installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This
joint shall be fully M/U and available prior to running the first joint of 4-1/2” liner.
x With 4-1/2” solid joint across BOP: Slack off and position the 4-1/2” solid joint to MU the TIW
valve. Shut in ram or annular on 4-1/2” solid joint. Close TIW valve.
13.2 Set the test plug and flush the stack with the wash tool. Pull test plug.
13.3 Ensure rams have been tested to cover 4” and 4-1/2” test joints prior to running liner.
13.4 Ensure wear bushing is installed in wellhead.
13.5 R/U 4-1/2” casing running equipment.
x Ensure all casing has been drifted prior to running.
x Be sure to count the total # of joints before running.
x Keep hole covered while R/U casing tools.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
13.6 Run 4-1/2” liner per completion tally.
x Dope pin end only w/ paint brush.
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
4-1/2” Tenaris Hydril 625 Make-Up Torques
Casing OD Minimum Optimum Maximum
4.5”8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs
4-1/2” Tenaris Hydril 625 Operating Limit Torques
Casing OD Operating Yield
4.5”12,800 ft-lbs 15,000 ft-lbs
Page 22
Milne Point Unit F-34L1
Drilling Procedure
Page 23
Milne Point Unit F-34L1
Drilling Procedure
13.7 Ensure to run enough liner to provide for approximately 150’ overlap inside 7” casing. Ensure
hanger/pkr will not be set in a 7” connection.
13.8 Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe
deck to make sure it coincides with the pipe tally.
13.9 M/U Baker SLZXP liner top packer.
13.10 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a
clear flow path exists.
13.11 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid
surging the hole. Slow down running speed if necessary.
13.12 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe
depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the
string to bottom.
13.13 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
20, & 30 rpm.
13.14 RIH to TD. Monitor run for losses.
13.15 Follow Baker procedure to set SLZXP.
13.16 Unsting and CBU X2.
13.17 Swap well to KCl completion brine. Ensure the density matches the final mud weight used
during the liner run.
13.18 Perform flowcheck. POOH LDDP.
Page 24
Milne Point Unit F-34L1
Drilling Procedure
14.0 Run Upper Completion
14.1 M/U ESP assembly and RIH to setting depth. TIH no faster than 90 ft/min.
x Ensure wear bushing is pulled.
x Ensure 4-½” TXP- BTC x XT39 crossover is on rig floor and M/U to FOSV.
x Ensure all tubing has been drifted in the pipe shed prior to running.
x Be sure to count the total # of joints in the pipe shed before running.
x Keep hole covered while R/U casing tools.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
x Monitor displacement from wellbore while RIH.
4-1/2” TXP-BTC Make-Up Torques
Tbg OD Minimum Optimum Maximum
4.5”5,550 ft-lbs 6,170 ft-lbs 6,790 ft-lbs
4-1/2” TXP-BTC Operating Limit Torques
Tbg OD Operating
4.5”8,800 ft-lbs
Page 25
Milne Point Unit F-34L1
Drilling Procedure
Page 26
Milne Point Unit F-34L1
Drilling Procedure
4-½” Upper Completion Running Order - ESP
Conventional ESP
x Centralizer (OD = ±5.85”), Base at ±18,750’ MD
x Intake Sensor
x 500Hp 562 Motor (OD = 5.62”)
x Lower Seal Section
x Upper Seal Section
x Intake / Gas Separator
x Pump Section 1
x Pump Section 2
x Discharge Head
x Joints 4-1/2”, 12.6#, L-80, TXP-BTC tubing
x 4-½” 12.6#/ft, L-80 TXP-BTC space out pups
x 1 joint 4-½” 12.6#/ft, L-80 TXP-BTC tubing
x Tubing hanger with 4-1/2” TXP-BTC pin down
14.2 Follow all service company procedures for handling, make up and deployment of the ESP
system.
i. Typical clamping is every joint for the first 15 joints and then every other joint to surface.
Make note of clamping performed in tally.
ii. Perform electrical continuity checks every 2,000’ MD.
14.3 Land hanger. RILDs and test hanger.
14.4 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and
tree.
14.5 Pull BPV. Set TWC. Test tree to 5000 psi.
14.6 Pull TWC. Set BPV. Bullhead tubing & IA freeze protect if/as needed.
14.7 Secure the tree and cellar.
15.0 RDMO
15.1 RDMO Doyon 14.
Page 27
Milne Point Unit F-34L1
Drilling Procedure
16.0 Post-Rig Work
16.1 Pull BPV. Bullhead tubing freeze protect if/as needed.
Page 28
Milne Point Unit F-34L1
Drilling Procedure
17.0 Doyon 14 BOP Schematic
Typical Ram Configuration
Page 29
Milne Point Unit F-34L1
Drilling Procedure
18.0 Wellhead Schematic
Current Wellhead Schematic
Page 30
Milne Point Unit F-34L1
Drilling Procedure
Proposed Wellhead Schematic after Tubing Spool Swap
2-7/8”
Page 31
Milne Point Unit F-34L1
Drilling Procedure
19.0 Days Vs Depth
Page 32
Milne Point Unit F-34L1
Drilling Procedure
20.0 Formation Tops & Information
Formation TVD TVDss MD EMW (PPG)
Top C 7558.7 -7513 18,958 5.7
Top A2 7614.7 -7569 19,569 5.7
Top A1 7667.7 -7622 20,257 5.7
MPU F-Pad Data Sheet
Page 33
Milne Point Unit F-34L1
Drilling Procedure
21.0 Anticipated Drilling Hazards
Window Exit:
Tracking Casing
The KOP is cemented. The motor run will help us ensure departure from the parent bore prior to drilling
ahead with a rotary steerable system.
Production Hole Sections:
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up
with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor
ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe
rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe
moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation
after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of
200 ft/min.
Lost Circulation:
Monitor ECD’s during production section to ensure ECD’s stay below 12.0ppg (target as low as
possible). Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early
signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
The Kuparuk FG is predicted to be ~12.0ppg.
Wellbore Stability:
This is an in-zone sidetrack. Wellbore instability is viewed as a low risk. Maintain sufficient MW for
stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles.
Use MPD to offset swab effect while TOOH.
Anti-Collision:
This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic
interference while drilling ahead.
Faulting:
There are no mapped faults in the production interval.
H2S:
Treat every hole section as though it has the potential for H2S. H2S events have typically been minor
from F-pad Kuparuk wells. The vast majority of sample data is less than 10 ppm. F-69 recorded a
sample with 47 ppm. F-53 had one sample test come back with 32 ppm.
1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements
of 20 AAC 25.066.
Page 34
Milne Point Unit F-34L1
Drilling Procedure
3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Page 35
Milne Point Unit F-34L1
Drilling Procedure
22.0 Doyon 14 Layout
Page 36
Milne Point Unit F-34L1
Drilling Procedure
23.0 FIT Procedure
Formation Integrity Test (FIT) and
Leak-Off Test (LOT) Procedures
Procedure for FIT:
1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe).
2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe.
3. Close the blowout preventer (ram or annular).
4. Pump down the drill stem at 1/4 to 1/2 bpm.
5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs.
drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe.
6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes.
Record time vs. pressure in 1-minute intervals.
7. 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 estimated reservoir pressure, and allowing for an appropriate amount of kick
tolerance in case well control measures are required.
Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of
stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid;
at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure
monitored as with an FIT.
Page 37
Milne Point Unit F-34L1
Drilling Procedure
24.0 Doyon 14 Choke Manifold Schematic
Page 38
Milne Point Unit F-34L1
Drilling Procedure
25.0 Casing Design Information
Page 39
Milne Point Unit F-34L1
Drilling Procedure
26.0 6-1/8” Hole Section MASP
Need to confirm 5.7 ppge pore pressure!
Page 40
Milne Point Unit F-34L1
Drilling Procedure
27.0 Spider Plot (NAD 27) (Governmental Sections)
Page 41
Milne Point Unit F-34L1
Drilling Procedure
28.0 Surface Plat (As Built) (NAD 27)
6WDQGDUG3URSRVDO5HSRUW
'HFHPEHU
3ODQ 038)/ZS
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
3ODQ 03)
3ODQ 038)/
63
3
3
66
6
7
70
0
0
73
3
3
76
6
7
80
0
0
True Vertical Depth (500 usft/in)
16
8
0
0
1
7
7
3
3
1
8
6
6
7
1
9
6
0
0
2
0
5
3
3
2
1
4
6
7
2
2
4
0
0
2
3
3
3
3
2
4
2
6
7
2
5
2
0
0
2
6
1
3
3
2
7
0
6
7
2
8
0
0
0
2
8
9
3
3
2
9
8
6
7
Ve
r
t
i
c
a
l
S
e
c
t
i
o
n
a
t
1
4
.
7
0
°
(
1
4
0
0
u
s
f
t
/
i
n
)
MP
U
F
-
3
4
L
1
w
p
1
4
t
g
t
0
3
MP
U
F
-
3
4
L
1
w
p
1
4
t
g
t
0
4
MP
U
F
-
3
4
L
1
w
p
1
4
t
g
t
0
7
MP
U
F
-
3
4
L
1
w
p
1
3
h
e
e
l
MP
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
1
MP
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
2
MP
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
5
MP
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
6
19500
20000
20500
20 9 80
MP
F
-
3
4
7"
T
O
W
4
1
/
2
"
x
6
"
20500
21000
21500
22000
22500
23000
23500
24000
24500
25000
25500
26000
26500
27000
27500
28000
28500
29000
29500
30000
30500
31000
31500
32000
32500
32559
MP
U
F
-
3
4
L
1
w
p
1
4
K
O
P : Start Dir 12º/100' : 20010.65' M
D, 7645.81'TVD : 30° RT TF
End Dir : 20027.65' M
D, 7647.09' TVD
Start Dir 5º/100' : 20057.65' M
D, 7648.9'TVD
End Dir : 20807.29' M
D, 7706.52' TVD
Start Dir 5º/100' : 20841.13' M
D, 7709.49'TV
D
End Dir : 21324.07' M
D, 7743.87' TV
D
Start Dir 2.5º/100' : 21359.07' M
D, 7745.7'TVD
End Dir : 21538.41' M
D, 7748.08' TV
D
Start Dir 2.5º/100' : 22205.95' M
D, 7730.88'TVD
End Dir : 22516.06' M
D, 7741.69' TVD
Start Dir 2.5º/100' : 23564.77' M
D, 7806.48'TV
D
End Dir : 23837.14' M
D, 7812.56' TV
D
Start Dir 2.5º/100' : 24938.71' M
D, 7825.7'TVD
End Dir : 25129.36' M
D, 7832.54' TV
D
Start Dir 2.5º/100' : 26185.2' M
D, 7895.7'TV
D
End Dir : 26565.13' M
D, 7911.31' TVD
Start Dir 2.5º/100' : 27440.42' M
D, 7930.7'TVD
End Dir : 27621.3' M
D, 7937.07' TVD
Start Dir 2º/100' : 29872' M
D, 8045.7'TV
D
End Dir : 29977.78' M
D, 8050.31' TVD
Total Depth : 32559.45' M
D, 8150.7' TVD
KU
P
_
A
2
KU
P
_
A
1
KU
P
_
A
1
KU
P
_
A
1
KU
P
_
A
1
B
KU
P
_
A
_
B
A
S
E
KU
P
_
A
_
B
A
S
E
KU
P
_
A
1
B
KU
P
_
A
1
B
KU
P
_
A
1
B
WE
L
L
D
E
T
A
I
L
S
:
P
l
a
n
:
M
P
F
-
3
4
N
A
D
1
9
2
7
(
N
A
D
C
O
N
C
O
N
U
S
)
A
l
a
s
k
a
Z
o
n
e
0
4
Gr
o
u
n
d
L
e
v
e
l
:
12
.
0
0
+N
/
-
S
+
E
/
-
W
N
o
r
t
h
i
n
g
E
a
s
t
i
n
g
La
t
i
t
u
d
e
Lo
n
g
i
t
u
d
e
0.
0
0
0
.
0
0
60
3
5
4
2
2
.
0
9
54
1
8
1
3
.
4
8
70
°
3
0
'
2
7
.
6
8
8
8
N
1
4
9
°
3
9
'
2
8
.
4
1
7
6
W
CA
S
I
N
G
D
E
T
A
I
L
S
TV
D
TV
D
S
S
MD
S
i
z
e
Na
m
e
76
4
5
.
8
4
7
6
0
0
.
1
4
2
0
0
1
1
.
0
0
7
7
"
T
O
W
81
5
0
.
7
0
8
1
0
5
.
0
0
3
2
5
5
9
.
4
5
4-
1
/
2
4
1
/
2
"
x
6
"
Pr
o
j
e
c
t
:
M
i
l
n
e
P
o
i
n
t
Si
t
e
:
M
P
t
F
P
a
d
We
l
l
:
P
l
a
n
:
M
P
F
-
3
4
We
l
l
b
o
r
e
:
P
l
a
n
:
M
P
U
F
-
3
4
L
1
De
s
i
g
n
:
M
P
U
F
-
3
4
L
1
w
p
1
4
SE
C
T
I
O
N
D
E
T
A
I
L
S
Se
c
M
D
I
n
c
A
z
i
T
V
D
+
N
/
-
S
+
E
/
-
W
D
l
e
g
T
F
a
c
e
V
S
e
c
t
T
a
r
g
e
t
A
n
n
o
t
a
t
i
o
n
1
2
0
0
1
0
.
6
5
8
4
.
7
8
3
5
9
.
5
4
7
6
4
5
.
8
1
1
7
0
4
6
.
2
6
2
1
6
5
.
3
6
0
.
0
0
0
.
0
0
1
7
0
3
7
.
7
7
K
O
P
:
S
t
a
r
t
D
i
r
1
2
º
/
10
0
'
:
2
0
0
1
0
.
6
5
'
M
D
,
7
6
4
5
.
8
1
'
T
V
D
:
3
0
°
R
T
T
F
2
2
0
0
2
7
.
6
5
8
6
.
5
4
0
.
5
6
7
6
4
7
.
0
9
1
7
0
6
3
.
2
1
2
1
6
5
.
3
8
1
2
.
0
0
3
0
.
0
0
1
70
5
4
.
1
7
E
n
d
D
i
r
:
2
0
0
2
7
.
6
5
'
M
D
,
76
4
7
.
0
9
'
T
V
D
3
2
0
0
5
7
.
6
5
8
6
.
5
4
0
.
5
6
7
6
4
8
.
9
0
1
7
0
9
3
.
1
5
2
1
6
5
.
6
7
0
.
0
0
0
.
0
0
1
7
0
8
3
.
2
1
S
t
a
r
t
D
i
r
5
º
/
1
0
0
'
:
20
0
5
7
.
6
5
'
M
D
,
7
6
4
8
.
9
'
T
V
D
4
2
0
8
0
7
.
2
9
8
4
.
9
6
3
8
.
1
2
7
7
0
6
.
5
2
1
7
7
8
5
.
8
9
2
4
0
8
.
5
8
5
.
0
0
9
3
.
7
8
1
7
81
4
.
9
1
E
n
d
D
i
r
:
2
0
8
0
7
.
2
9
'
M
D
,
77
0
6
.
5
2
'
T
V
D
5
2
0
8
4
1
.
1
3
8
4
.
9
6
3
8
.
1
2
7
7
0
9
.
4
9
1
7
8
1
2
.
4
1
2
4
2
9
.
3
9
0
.
0
0
0
.
0
0
1
7
8
4
5
.
8
4
S
t
a
r
t
D
i
r
5
º
/
1
0
0
'
:
2
0
8
4
1
.
1
3
'
M
D
,
7
7
0
9
.
4
9
'
T
V
D
6
2
1
3
2
4
.
0
7
8
7
.
0
0
1
4
.
0
0
7
7
4
3
.
8
7
1
8
2
4
1
.
9
9
2
6
3
9
.
3
3
5
.
0
0
-
8
6
.
0
8
1
8
3
1
4
.
6
4
E
n
d
D
i
r
:
2
13
2
4
.
0
7
'
M
D
,
7
7
4
3
.
8
7
'
T
V
D
7
2
1
3
5
9
.
0
7
8
7
.
0
0
1
4
.
0
0
7
7
4
5
.
7
0
1
8
2
7
5
.
9
0
2
6
4
7
.
7
9
0
.
0
0
0
.
0
0
1
8
3
4
9
.
5
8
M
P
U
F
-
34
L
1
w
p
1
3
h
e
e
l
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
1
3
5
9
.
0
7
'
M
D
,
7
7
4
5
.
7
'
T
V
D
8
2
1
5
3
8
.
4
1
9
1
.
4
8
1
3
.
7
6
7
7
4
8
.
0
8
1
8
4
4
9
.
9
4
2
6
9
0
.
7
9
2
.
5
0
-
3
.
1
2
1
8
5
2
8
.
8
4
E
n
d
D
i
r
:
2
1
5
3
8
.
4
1
'
M
D
,
77
4
8
.
0
8
'
T
V
D
9
2
2
2
0
5
.
9
5
9
1
.
4
8
1
3
.
7
6
7
7
3
0
.
8
8
1
9
0
9
8
.
1
2
2
8
4
9
.
4
7
0
.
0
0
0
.
0
0
1
9
1
9
6
.
0
7
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
2
2
0
5
.
9
5
'
M
D
,
7
7
3
0
.
8
8
'
T
V
D
10
2
2
4
2
5
.
0
2
8
6
.
0
0
1
3
.
7
6
7
7
3
5
.
7
0
1
9
3
1
0
.
7
8
2
9
0
1
.
5
3
2
.
5
0
1
7
9
.
9
6
1
9
4
1
4
.
9
8
M
P
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
1
11
2
2
5
1
6
.
0
6
8
6
.
4
6
1
1
.
5
3
7
7
4
1
.
6
9
1
9
3
9
9
.
4
1
2
9
2
1
.
4
2
2
.
5
0
-
7
8
.
4
7
1
95
0
5
.
7
6
E
n
d
D
i
r
:
2
2
5
1
6
.
0
6
'
M
D
,
7
7
4
1
.
6
9
'
T
V
D
1
2
2
3
5
6
4
.
7
7
8
6
.
4
6
1
1
.
5
3
7
8
0
6
.
4
8
2
0
4
2
5
.
0
1
3
1
3
0
.
5
5
0
.
0
0
0
.
0
0
2
0
5
5
0
.
8
6
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
3
5
6
4
.
7
7
'
M
D
,
7
8
0
6
.
4
8
'
T
V
D
13
2
3
6
7
9
.
6
6
8
9
.
3
3
1
1
.
5
0
7
8
1
0
.
7
0
2
0
5
3
7
.
5
0
3
1
5
3
.
4
7
2
.
5
0
-
0
.
5
1
2
0
6
6
5
.
4
8
M
P
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
2
14
2
3
8
3
7
.
1
4
8
9
.
3
2
7
.
5
6
7
8
1
2
.
5
6
2
0
6
9
2
.
7
7
3
1
7
9
.
5
4
2
.
5
0
-
9
0
.
2
2
2
0
8
2
2
.
2
8
E
n
d
D
i
r
:
23
8
3
7
.
1
4
'
M
D
,
7
8
1
2
.
5
6
'
T
V
D
15
2
4
9
3
8
.
7
1
8
9
.
3
2
7
.
5
6
7
8
2
5
.
7
0
2
1
7
8
4
.
6
8
3
3
2
4
.
5
1
0
.
0
0
0
.
0
0
2
1
9
1
5
.
2
4
M
P
U
F
-
34
L
1
w
p
1
4
t
g
t
0
3
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
4
9
3
8
.
7
1
'
M
D
,
7
8
2
5
.
7
'
T
V
D
16
2
5
1
2
9
.
3
6
8
6
.
5
7
1
1
.
4
6
7
8
3
2
.
5
4
2
1
9
7
2
.
5
3
3
3
5
5
.
9
8
2
.
5
0
1
2
5
.
2
3
2
2
1
0
4
.
9
3
E
n
d
D
i
r
:
2
5
1
2
9
.
3
6
'
M
D
,
7
8
3
2
.
5
4
'
T
V
D
1
7
2
6
1
8
5
.
2
0
8
6
.
5
7
1
1
.
4
6
7
8
9
5
.
7
0
2
3
0
0
5
.
4
6
3
5
6
5
.
4
0
0
.
0
0
0
.
0
0
2
3
1
5
7
.
1
9
M
P
U
F
-
3
4
L
1
w
p
1
4
t
g
t
0
4
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
6
1
8
5
.
2
'
M
D
,
7
8
9
5
.
7
'
T
V
D
18
2
6
5
6
5
.
1
3
8
8
.
7
3
2
0
.
7
2
7
9
1
1
.
3
1
2
3
3
6
9
.
7
7
3
6
7
0
.
5
1
2
.
5
0
7
7
.
0
8
2
3
5
3
6
.
2
5
E
n
d
D
i
r
:
2
6
5
6
5
.
1
3
'
M
D
,
7
9
1
1
.
3
1
'
T
V
D
19
2
7
4
4
0
.
4
2
8
8
.
7
3
2
0
.
7
2
7
9
3
0
.
7
0
2
4
1
8
8
.
2
6
3
9
8
0
.
1
1
0
.
0
0
0
.
0
0
2
4
4
0
6
.
5
1
M
P
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
5
S
t
a
r
t
D
i
r
2
.
5
º
/
10
0
'
:
2
7
4
4
0
.
4
2
'
M
D
,
7
9
3
0
.
7
'
T
V
D
20
2
7
6
2
1
.
3
0
8
7
.
2
3
1
6
.
4
5
7
9
3
7
.
0
7
2
4
3
5
9
.
5
6
4
0
3
7
.
7
1
2
.
5
0
-
1
0
9
.
4
0
2
4
5
8
6
.
8
2
E
n
d
D
i
r
:
2
7
6
2
1
.
3
'
M
D
,
7
9
3
7
.
0
7
'
T
V
D
21
2
9
8
7
2
.
0
0
8
7
.
2
3
1
6
.
4
5
8
0
4
5
.
7
0
2
6
5
1
5
.
6
2
4
6
7
4
.
2
9
0
.
0
0
0
.
0
0
2
6
8
3
3
.
8
4
M
P
U
F
-
3
4
L
1
w
p
1
3
t
g
t
0
6
S
t
a
r
t
D
i
r
2
º
/
1
0
0
'
:
2
9
8
7
2
'
M
D
,
8
0
4
5
.
7
'
T
V
D
22
2
9
9
7
7
.
7
8
8
7
.
7
7
1
4
.
4
0
8
0
5
0
.
3
1
2
6
6
1
7
.
4
9
4
7
0
2
.
3
9
2
.
0
0
-
7
5
.
3
2
2
6
9
3
9
.
5
1
E
n
d
D
i
r
:
2
9
9
7
7
.
7
8
'
M
D
,
8
0
5
0
.
3
1
'
T
V
D
23
3
2
5
5
9
.
4
5
8
7
.
7
7
1
4
.
4
0
8
1
5
0
.
7
0
2
9
1
1
6
.
1
5
5
3
4
4
.
0
0
0
.
0
0
0
.
0
0
2
9
5
1
9
.
1
9
M
P
U
F
-
3
4
L
1
w
p
1
4
t
g
t
0
7
T
o
t
a
l
D
e
p
t
h
:
3
2
5
5
9
.
4
5
'
M
D
,
8
1
5
0
.
7
'
T
V
D
SU
R
V
E
Y
P
R
O
G
R
A
M
Da
t
e
:
2
0
2
3
-
0
7
-
0
5
T
0
0
:
0
0
:
0
0
V
a
l
i
d
a
t
e
d
:
Y
e
s
V
e
r
s
i
o
n
:
De
p
t
h
F
r
o
m
D
e
p
t
h
T
o
Su
r
v
e
y
/
P
l
a
n
T
o
o
l
10
0
.
6
5
2
1
0
0
.
6
5
C
o
p
y
o
f
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
P
B
1
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
19
9
8
_
P
i
p
e
21
5
0
.
6
5
1
0
8
0
0
.
6
5
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
19
9
8
_
P
i
p
e
10
8
5
3
.
7
5
2
0
0
1
0
.
6
5
S
u
r
v
e
y
#
2
(
M
P
F
-
3
4
)
3
_
M
W
D
20
0
1
0
.
6
5
2
0
4
1
0
.
0
0
M
P
U
F
-
3
4
L
1
w
p
1
4
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
_
I
n
t
e
r
p
A
z
i
+
S
a
g
20
4
1
0
.
0
0
3
2
5
5
9
.
4
5
M
P
U
F
-
3
4
L
1
w
p
1
4
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
+
I
F
R
2
+
M
S
+
S
a
g
16800
17500
18200
18900
19600
20300
21000
21700
22400
23100
23800
24500
25200
25900
26600
27300
28000
28700
29400
30100
So
u
t
h
(
-
)
/
N
o
r
t
h
(
+
)
(
1
4
0
0
u
s
f
t
/
i
n
)
0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400
West(-)/East(+) (1200 usft/in)
MPU F-34L1 wp13 tgt06
MPU F-34L1 wp13 tgt05
MPU F-34L1 wp13 tgt02
MPU F-34L1 wp13 tgt01
MPU F-34L1 wp13 heel
MPU F-34L1 wp14 tgt07
MPU F-34L1 wp14 tgt04
MPU F-34L1 wp14 tgt03
765 3
MPF-34
7" TOW
4 1/2" x 6"
7750
8000
8151
MPU F-34L1 wp14
KOP : Start Dir 12º/100' : 20010.65' MD, 7645.81'TVD : 30° RT TF
End Dir : 20027.65' MD, 7647.09' TVD
Start Dir 5º/100' : 20057.65' MD, 7648.9'TVD
End Dir : 20807.29' MD, 7706.52' TVD
Start Dir 5º/100' : 20841.13' MD, 7709.49'TVD
End Dir : 21324.07' MD, 7743.87' TVD
Start Dir 2.5º/100' : 21359.07' MD, 7745.7'TVD
End Dir : 21538.41' MD, 7748.08' TVD
Start Dir 2.5º/100' : 22205.95' MD, 7730.88'TVD
End Dir : 22516.06' MD, 7741.69' TVD
Start Dir 2.5º/100' : 23564.77' MD, 7806.48'TVD
End Dir : 23837.14' MD, 7812.56' TVD
Start Dir 2.5º/100' : 24938.71' MD, 7825.7'TVD
End Dir : 25129.36' MD, 7832.54' TVD
Start Dir 2.5º/100' : 26185.2' MD, 7895.7'TVD
End Dir : 26565.13' MD, 7911.31' TVD
Start Dir 2.5º/100' : 27440.42' MD, 7930.7'TVD
End Dir : 27621.3' MD, 7937.07' TVD
Start Dir 2º/100' : 29872' MD, 8045.7'TVD
End Dir : 29977.78' MD, 8050.31' TVD
Total Depth : 32559.45' MD, 8150.7' TVD
CASING DETAILS
TVD TVDSS MD Size Name
7645.84 7600.14 20011.00 7 7" TOW
8150.70 8105.00 32559.45 4-1/2 4 1/2" x 6"
Project: Milne Point
Site: M Pt F Pad
Well: Plan: MPF-34
Wellbore: Plan: MPU F-34L1
Plan: MPU F-34L1 wp14
WELL DETAILS: Plan: MPF-34
Ground Level: 12.00
+N/-S +E/-W Northing Easting Latitude
Longitude
0.00 0.00
6035422.09 541813.48 70° 30' 27.6888 N 149° 39' 28.4176 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPF-34, True North
Vertical (TVD) Reference: MPU F-34A RKB @ 45.70usft
Measured Depth Reference:MPU F-34A RKB @ 45.70usft
Calculation Method:Minimum Curvature
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0DS6\VWHP
*HR'DWXP
3URMHFW
0DS=RQH
6\VWHP'DWXP 866WDWH3ODQH ([DFWVROXWLRQ
1$' 1$'&21&2186
0LOQH3RLQW$&70,/1(32,17
$ODVND=RQH
0HDQ6HD/HYHO
8VLQJ:HOO5HIHUHQFH3RLQW
8VLQJJHRGHWLFVFDOHIDFWRU
6LWH3RVLWLRQ
)URP
6LWH
/DWLWXGH
/RQJLWXGH
3RVLWLRQ8QFHUWDLQW\
1RUWKLQJ
(DVWLQJ
*ULG&RQYHUJHQFH
03W)3DG75
XVIW
0DS XVIW
XVIW
6ORW5DGLXV
1
:
:HOO
:HOO3RVLWLRQ
/RQJLWXGH
/DWLWXGH
(DVWLQJ
1RUWKLQJ
XVIW
(:
16
3RVLWLRQ8QFHUWDLQW\
XVIW
XVIW
XVIW*URXQG/HYHO
3ODQ 03)
XVIW
XVIW
:HOOKHDG(OHYDWLRQ XVIW
1
:
:HOOERUH
'HFOLQDWLRQ
)LHOG6WUHQJWK
Q7
6DPSOH'DWH 'LS$QJOH
3ODQ 038)/
0RGHO1DPH0DJQHWLFV
,)5
3KDVH 9HUVLRQ
$XGLW1RWHV
'HVLJQ 038)/ZS
3/$1
9HUWLFDO6HFWLRQ 'HSWK)URP 79'
XVIW
16
XVIW
'LUHFWLRQ
(:
XVIW
7LH2Q'HSWK
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
7RRO)DFH
16
XVIW
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
'RJOHJ
5DWH
XVIW
%XLOG
5DWH
XVIW
7XUQ
5DWH
XVIW
3ODQ6HFWLRQV
79'
6\VWHP
XVIW
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.23 6WDUW'LU
0'
79' 577)
72:
.83B$
(QG'LU
0'
79'
6WDUW'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$
(QG'LU
0'
79'
6WDUW'LU
0'
79'
.83B$
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$%
.83B$%
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$%
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$B%$6(
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$B%$6(
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$%
.83B$%
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$%
.83B$%
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
7RWDO'HSWK
0'
79'[
7DUJHW1DPH
KLWPLVVWDUJHW
6KDSH
79'
XVIW
1RUWKLQJ
XVIW
(DVWLQJ
XVIW
16
XVIW
(:
XVIW
7DUJHWV
'LS$QJOH
'LS'LU
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSKHHO
SODQPLVVHVWDUJHWFHQWHUE\ XVIWDWXVIW0' 79'1 (
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
038)/ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
9HUWLFDO
'HSWK
XVIW
0HDVXUHG
'HSWK
XVIW
&DVLQJ
'LDPHWHU
+ROH
'LDPHWHU
1DPH
&DVLQJ3RLQWV
72:
[
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
'LS
'LUHFWLRQ
1DPH /LWKRORJ\
'LS
)RUPDWLRQV
9HUWLFDO
'HSWK66
.83B$%
.83B$
.83B$%
.83B$%
.83B$B%$6(
.83B$%
.83B$
.83B$
.83B$B%$6(
.83B$
.83B$%
.83B$%
.83B$%
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
(:
XVIW
16
XVIW
/RFDO&RRUGLQDWHV
&RPPHQW
3ODQ$QQRWDWLRQV
.23 6WDUW'LU
0'
79' 577)
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
7RWDO'HSWK
0'
79'
30 &203$66%XLOG (3DJH
&O
H
D
U
D
Q
F
H
6
X
P
P
D
U
\
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
'
H
F
H
P
E
H
U
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
0L
O
Q
H
3
R
L
Q
W
0
3
W
)
3
D
G
3O
D
Q
0
3
)
3O
D
Q
0
3
8
)
/
03
8
)
/
Z
S
5H
I
H
U
H
Q
F
H
'
H
V
L
J
Q
0
3
W
)
3
D
G
3
O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
&O
R
V
H
V
W
$
S
S
U
R
D
F
K
'
3
U
R
[
L
P
L
W
\
6
F
D
Q
R
Q
&
X
U
U
H
Q
W
6
X
U
Y
H
\
'
D
W
D
+
L
J
K
VL
G
H
5
H
I
H
U
H
Q
F
H
:H
O
O
&
R
R
U
G
L
Q
D
W
H
V
1
(
1
:
'D
W
X
P
+
H
L
J
K
W
0
3
8
)
$
5
.
%
#
X
V
I
W
6F
D
Q
5
D
Q
J
H
W
R
X
V
I
W
0
H
D
V
X
U
H
G
'
H
S
W
K
*H
R
G
H
W
L
F
6
F
D
O
H
)
D
F
W
R
U
$
S
S
O
L
H
G
9H
U
V
L
R
Q
%
X
L
O
G
(
6F
D
Q
5
D
G
L
X
V
L
V
8
Q
O
L
P
L
W
H
G
&
O
H
D
U
D
Q
F
H
)
D
F
W
R
U
F
X
W
R
I
I
L
V
8
Q
O
L
P
L
W
H
G
0
D
[
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
L
V
X
V
I
W
*/
2
%
$
/
)
,
/
7
(
5
$
3
3
/
,
(
'
$
O
O
Z
H
O
O
S
D
W
K
V
Z
L
W
K
L
Q
R
I
U
HI
H
U
H
Q
F
H
6F
D
Q
7
\
S
H
6F
D
Q
7
\
S
H
0L
O
Q
H
3
R
L
Q
W
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
I
R
U
3
O
D
Q
0
3
)
0
3
8
)
/
Z
S
&R
P
S
D
U
L
V
R
Q
:
H
O
O
1
D
P
H
:
H
O
O
E
R
U
H
1
D
P
H
'
H
V
L
J
Q
#0
H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
0L
Q
L
P
X
P
'L
V
W
D
Q
F
H
X
V
I
W
(O
O
L
S
V
H
6H
S
D
U
D
W
L
R
Q
X
V
I
W
#0
H
D
V
X
U
H
G
'H
S
W
K
XV
I
W
&O
H
D
U
D
Q
F
H
)D
F
W
R
U
6F
D
Q
5
D
G
L
X
V
L
V
8
Q
O
L
P
L
W
H
G
&
O
H
D
U
D
Q
F
H
)
D
F
W
R
U
F
X
W
R
I
I
L
V
8
Q
O
L
P
L
W
H
G
0
D
[
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
L
V
X
V
I
W
6L
W
H
1
D
P
H
6F
D
Q
5
D
Q
J
H
W
R
X
V
I
W
0
H
D
V
X
U
H
G
'
H
S
W
K
&O
R
V
H
V
W
$
S
S
U
R
D
F
K
'
3
U
R
[
L
P
L
W
\
6
F
D
Q
R
Q
&
X
U
U
H
Q
W
6
X
U
Y
H
\
'
D
W
D
+
L
J
K
VL
G
H
5
H
I
H
U
H
Q
F
H
5H
I
H
U
H
Q
F
H
'
H
V
L
J
Q
0
3
W
)
3
D
G
3
O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
0H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
6X
P
P
D
U
\
%
D
V
H
G
R
Q
0L
Q
L
P
X
P
6H
S
D
U
D
W
L
R
Q
:
D
U
Q
L
Q
J
0
3
W
)
3
D
G
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
03
)
0
3
)
0
3
)
&H
Q
W
U
H
'
L
V
W
D
Q
F
H
3
D
V
V
03
)
0
3
8
)
/
0
3
8
)
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
8
)
/
0
3
8
)
/
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
03
)
0
3
8
)
/
0
3
8
)
/
&H
Q
W
U
H
'
L
V
W
D
Q
F
H
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
8
)
/
0
3
8
)
/
Z
S
D
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
8
)
/
0
3
8
)
/
Z
S
D
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
/
0
3
)
$
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
/
0
3
)
$
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
/
0
3
)
$
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
3
%
0
3
)
$
3
%
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
'
H
F
H
P
E
H
U
&2
0
3
$
6
6
3D
J
H
R
I
0L
O
Q
H
3
R
L
Q
W
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
I
R
U
3
O
D
Q
0
3
)
0
3
8
)
/
Z
S
&R
P
S
D
U
L
V
R
Q
:
H
O
O
1
D
P
H
:
H
O
O
E
R
U
H
1
D
P
H
'
H
V
L
J
Q
#0
H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
0L
Q
L
P
X
P
'L
V
W
D
Q
F
H
X
V
I
W
(O
O
L
S
V
H
6H
S
D
U
D
W
L
R
Q
X
V
I
W
#0
H
D
V
X
U
H
G
'H
S
W
K
XV
I
W
&O
H
D
U
D
Q
F
H
)D
F
W
R
U
6F
D
Q
5
D
G
L
X
V
L
V
8
Q
O
L
P
L
W
H
G
&
O
H
D
U
D
Q
F
H
)
D
F
W
R
U
F
X
W
R
I
I
L
V
8
Q
O
L
P
L
W
H
G
0
D
[
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
L
V
X
V
I
W
6L
W
H
1
D
P
H
6F
D
Q
5
D
Q
J
H
W
R
X
V
I
W
0
H
D
V
X
U
H
G
'
H
S
W
K
&O
R
V
H
V
W
$
S
S
U
R
D
F
K
'
3
U
R
[
L
P
L
W
\
6
F
D
Q
R
Q
&
X
U
U
H
Q
W
6
X
U
Y
H
\
'
D
W
D
+
L
J
K
VL
G
H
5
H
I
H
U
H
Q
F
H
5H
I
H
U
H
Q
F
H
'
H
V
L
J
Q
0
3
W
)
3
D
G
3
O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
0H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
6X
P
P
D
U
\
%
D
V
H
G
R
Q
0L
Q
L
P
X
P
6H
S
D
U
D
W
L
R
Q
:
D
U
Q
L
Q
J
03
)
0
3
)
$
/
0
3
)
$
/
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
03
)
0
3
)
$
/
0
3
)
$
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
/
0
3
)
$
/
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
$
3
%
0
3
)
$
3
%
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
$
0
3
)
$
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
3
%
0
3
)
3
%
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
%
0
3
8
)
%
Z
S
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
&H
Q
W
U
H
'
L
V
W
D
Q
F
H
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
6X
U
Y
H
\
W
R
R
O
S
U
R
J
U
D
P
)U
R
P
X
V
I
W
7R
X
V
I
W
6X
U
Y
H
\
3
O
D
Q
6
X
U
Y
H
\
7
R
R
O
B
*
\
U
R
&
7
B
S
U
H
B
3
L
S
H
B
*
\
U
R
&
7
B
S
U
H
B
3
L
S
H
B
0
:
'
0
3
8
)
/
Z
S
B
0
:
'
B
,
Q
W
H
U
S
$
]
L
6
D
J
0
3
8
)
/
Z
S
B
0
:
'
,
)
5
0
6
6
D
J
'
H
F
H
P
E
H
U
&2
0
3
$
6
6
3D
J
H
R
I
0L
O
Q
H
3
R
L
Q
W
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
I
R
U
3
O
D
Q
0
3
)
0
3
8
)
/
Z
S
(O
O
L
S
V
H
H
U
U
R
U
W
H
U
P
V
D
U
H
F
R
U
U
H
O
D
W
H
G
D
F
U
R
V
V
V
X
U
Y
H
\
W
R
R
O
W
L
H
R
Q
S
R
LQ
W
V
6H
S
D
U
D
W
L
R
Q
L
V
W
K
H
D
F
W
X
D
O
G
L
V
W
D
Q
F
H
E
H
W
Z
H
H
Q
H
O
O
L
S
V
R
L
G
V
&D
O
F
X
O
D
W
H
G
H
O
O
L
S
V
H
V
L
Q
F
R
U
S
R
U
D
W
H
V
X
U
I
D
F
H
H
U
U
R
U
V
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
'
L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
3
U
R
I
L
O
H
V
'
L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
3
U
R
I
L
O
H
V
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
'L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
F
H
Q
W
U
H
V
L
V
W
K
H
V
W
U
D
L
J
K
W
O
L
Q
H
G
L
V
W
D
Q
F
H
E
H
W
Z
H
H
Q
ZH
O
O
E
R
U
H
F
H
Q
W
U
H
V
$O
O
V
W
D
W
L
R
Q
F
R
R
U
G
L
Q
D
W
H
V
Z
H
U
H
F
D
O
F
X
O
D
W
H
G
X
V
L
Q
J
W
K
H
0
L
Q
L
P
X
P
&
X
U
Y
D
WX
U
H
P
H
W
K
R
G
'
H
F
H
P
E
H
U
&2
0
3
$
6
6
3D
J
H
R
I
0.
0
0
1.
0
0
2.
0
0
3.
0
0
4.
0
0
Separation Factor
20
3
5
0
2
0
9
0
0
2
1
4
5
0
2
2
0
0
0
2
2
5
5
0
2
3
1
0
0
2
3
6
5
0
2
4
2
0
0
2
4
7
5
0
2
5
3
0
0
2
5
8
5
0
2
6
4
0
0
2
6
9
5
0
2
7
5
0
0
2
8
0
5
0
2
8
6
0
0
2
9
1
5
0
2
9
7
0
0
3
0
2
5
0
Me
a
s
u
r
e
d
D
e
p
t
h
(
1
1
0
0
u
s
f
t
/
i
n
)
MP
F
-
1
7
MP
U
F
-
1
7
L
1
MP
U
F
-
9
2
A
w
p
0
1
MP
F
-
3
4
No
-
G
o
Z
o
n
e
-
S
t
o
p
D
r
i
l
l
i
n
g
Co
l
l
i
s
i
o
n
A
v
o
i
d
a
n
c
e
R
e
q
u
i
r
e
d
Co
l
l
i
s
i
o
n
R
i
s
k
P
r
o
c
e
d
u
r
e
s
R
e
q
.
WE
L
L
D
E
T
A
I
L
S
:
P
l
a
n
:
M
P
F
-
3
4
N
A
D
1
9
2
7
(
N
A
D
C
O
N
C
O
N
U
S
)
Al
a
s
k
a
Z
o
n
e
0
4
Gr
o
u
n
d
L
e
v
e
l
:
1
2
.
0
0
+N
/
-
S
+
E
/
-
W
N
o
r
t
h
i
n
g
E
a
s
t
i
n
g
La
t
i
t
u
d
e
Lo
n
g
i
t
u
d
e
0.
0
0
0.
0
0
60
3
5
4
2
2
.
0
9
54
1
8
1
3
.
4
8
70
°
3
0
'
2
7
.
6
8
8
8
N
14
9
°
3
9
'
2
8
.
4
1
7
6
W
RE
F
E
R
E
N
C
E
I
N
F
O
R
M
A
T
I
O
N
Co
-
o
r
d
i
n
a
t
e
(
N
/
E
)
R
e
f
e
r
e
n
c
e
:
We
l
l
P
l
a
n
:
M
P
F
-
3
4
,
T
r
u
e
N
o
r
t
h
Ve
r
t
i
c
a
l
(
T
V
D
)
R
e
f
e
r
e
n
c
e
:
MP
U
F
-
3
4
A
R
K
B
@
4
5
.
7
0
u
s
f
t
Me
a
s
u
r
e
d
D
e
p
t
h
R
e
f
e
r
e
n
c
e
:
MP
U
F
-
3
4
A
R
K
B
@
4
5
.
7
0
u
s
f
t
Ca
l
c
u
l
a
t
i
o
n
M
e
t
h
o
d
:
Mi
n
i
m
u
m
C
u
r
v
a
t
u
r
e
SU
R
V
E
Y
P
R
O
G
R
A
M
Da
t
e
:
2
0
2
3
-
0
7
-
0
5
T
0
0
:
0
0
:
0
0
V
a
l
i
d
a
t
e
d
:
Y
e
s
V
e
r
s
i
o
n
:
De
p
t
h
F
r
o
m
D
e
p
t
h
T
o
S
u
r
v
e
y
/
P
l
a
n
To
o
l
10
0
.
6
5
2
1
0
0
.
6
5
C
o
p
y
o
f
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
P
B
1
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
98
_
P
i
p
e
21
5
0
.
6
5
1
0
8
0
0
.
6
5
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
98
_
P
i
p
e
10
8
5
3
.
7
5
2
0
0
1
0
.
6
5
S
u
r
v
e
y
#
2
(
M
P
F
-
3
4
)
3
_
M
W
D
20
0
1
0
.
6
5
2
0
4
1
0
.
0
0
M
P
U
F
-
3
4
L
1
w
p
1
4
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
_
I
n
t
e
r
p
A
z
i
+
S
a
g
20
4
1
0
.
0
0
3
2
5
5
9
.
4
5
M
P
U
F
-
3
4
L
1
w
p
1
4
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
+
I
F
R
2
+
M
S
+
S
a
g
0.
0
0
30
.
0
0
60
.
0
0
90
.
0
0
12
0
.
0
0
15
0
.
0
0
18
0
.
0
0
Centre to Centre Separation (60.00 usft/in)
20
3
5
0
2
0
9
0
0
2
1
4
5
0
2
2
0
0
0
2
2
5
5
0
2
3
1
0
0
2
3
6
5
0
2
4
2
0
0
2
4
7
5
0
2
5
3
0
0
2
5
8
5
0
2
6
4
0
0
2
6
9
5
0
2
7
5
0
0
2
8
0
5
0
2
8
6
0
0
2
9
1
5
0
2
9
7
0
0
3
0
2
5
0
Me
a
s
u
r
e
d
D
e
p
t
h
(
1
1
0
0
u
s
f
t
/
i
n
)
GL
O
B
A
L
F
I
L
T
E
R
A
P
P
L
I
E
D
:
A
l
l
w
e
l
l
p
a
t
h
s
w
i
t
h
i
n
2
0
0
'
+
1
0
0
/
1
0
0
0
o
f
r
e
f
e
r
e
n
c
e
20
0
1
0
.
6
5
T
o
3
2
5
5
9
.
4
5
Pr
o
j
e
c
t
:
M
i
l
n
e
P
o
i
n
t
Si
t
e
:
M
P
t
F
P
a
d
We
l
l
:
P
l
a
n
:
M
P
F
-
3
4
We
l
l
b
o
r
e
:
P
l
a
n
:
M
P
U
F
-
3
4
L
1
Pl
a
n
:
M
P
U
F
-
3
4
L
1
w
p
1
4
CA
S
I
N
G
D
E
T
A
I
L
S
TV
D
T
V
D
S
S
M
D
S
i
z
e
N
a
m
e
76
4
5
.
8
4
7
6
0
0
.
1
4
2
0
0
1
1
.
0
0
7
7
"
T
O
W
81
5
0
.
7
0
8
1
0
5
.
0
0
3
2
5
5
9
.
4
5
4
-
1
/
2
4
1
/
2
"
x
6
"
1
Dewhurst, Andrew D (OGC)
From:Nathan Sperry <Nathan.Sperry@hilcorp.com>
Sent:Tuesday, January 9, 2024 13:24
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Rixse, Melvin G (OGC); Joseph Lastufka
Subject:RE: [EXTERNAL] MPU F-34L1 REVISED (PTD 223-107) - Questions
Andy,
ThePPesƟmateisbasedonagaugeintheESPuppercompleƟonandourreservoirengineers’understandingof
drainageinthearea.
AŌerreceivingyoureͲmail,Iconsultedwithourreservoirengineerandgeologistandtheyexpecttheporepressureto
rangebetween5.5ppgand6.0ppgthroughtheenƟreplannedlateral.
Re:encounteringapressureͲisolatedandundrainedaccumulaƟon…theoriginalpressureintheareawasbelievedtobe
9.5ppg–9.6ppg.
Regards,
NateSperry
DrillingEngineer
HilcorpAlaska,LLC
From:Dewhurst,AndrewD(OGC)[mailto:andrew.dewhurst@alaska.gov]
Sent:Tuesday,January9,202412:58PM
To:NathanSperry<Nathan.Sperry@hilcorp.com>
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Roby,
DavidS(OGC)<dave.roby@alaska.gov>;Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>
Subject:[EXTERNAL]MPUFͲ34L1REVISED(PTD223Ͳ107)ͲQuestions
Nathan,
WearecompleƟngthereviewfortherevisedMPUFͲ34L1PTD.
IknowIaskedaboutthelow[5.7ppgEMW]porepressurebefore.Whatisthisvaluebasedon?Doyouexpectthisfor
theenƟretyoftheproducƟonhole?WhatistherageofpressuresfornaƟvereservoir(ifyouencounteredapressureͲ
isolatedandundrainedaccumulaƟon)?
Andy
AndrewDewhurst
SeniorPetroleumGeologist
AlaskaOilandGasConservaƟonCommission
333W.7thAve,Anchorage,AK99501
andrew.dewhurst@alaska.gov
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. DO NOT open links or attachments from UNKNOWN senders.
2
Direct:(907)793Ͳ1254
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named
above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this
email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed
above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,
opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and
the recipient should carry out such virus and other checks as it considers appropriate.
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.
KUPARUK RIVER OIL POOL
MPU F-34L1
X
223-107
MILNE POINT
W
E
L
L
P
E
R
M
I
T
C
H
E
C
K
L
I
S
T
Co
m
p
a
n
y
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
We
l
l
N
a
m
e
:
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
In
i
t
i
a
l
C
l
a
s
s
/
T
y
p
e
DE
V
/
P
E
N
D
Ge
o
A
r
e
a
89
0
Un
i
t
11
3
2
8
On
/
O
f
f
S
h
o
r
e
On
Pr
o
g
r
a
m
DE
V
Fi
e
l
d
&
P
o
o
l
We
l
l
b
o
r
e
s
e
g
An
n
u
l
a
r
D
i
s
p
o
s
a
l
PT
D
#
:
22
3
1
0
7
0
MI
L
N
E
P
O
I
N
T
,
K
U
P
A
R
U
K
R
I
V
E
R
O
I
L
-
5
2
5
1
0
0
M
I
L
N
E
P
O
I
N
T
,
U
N
D
E
F
I
N
E
D
O
NA
1
P
e
r
m
i
t
f
e
e
a
t
t
a
c
h
e
d
Ye
s
AD
L
0
2
5
5
0
9
,
A
D
L
3
5
5
0
1
8
,
A
D
L
3
5
5
0
1
6
,
A
D
L
3
9
4
1
6
7
2
L
e
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
U
n
i
q
u
e
w
e
l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
S
e
e
C
o
m
m
e
n
t
s
b
e
l
o
w
.
M
I
L
N
E
P
O
I
N
T
,
K
U
P
A
R
U
K
R
I
V
E
R
O
I
L
-
5
2
5
1
0
0
-
g
o
v
e
r
n
e
d
b
y
4
3
2
E
4
W
e
l
l
l
o
c
a
t
e
d
i
n
a
d
e
f
i
n
e
d
p
o
o
l
Ye
s
T
D
e
x
t
e
n
d
s
o
u
t
s
i
d
e
o
f
M
i
l
n
e
P
o
i
n
t
U
n
i
t
b
u
t
s
t
a
y
s
w
i
t
h
i
n
5
0
0
'
o
f
H
i
l
c
o
r
p
l
e
a
s
e
b
o
u
n
d
a
r
i
e
s
5
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
S
u
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
I
f
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
O
p
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
O
p
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
P
e
n
d
i
n
g
e
x
p
a
n
s
i
o
n
o
f
K
u
p
a
r
u
k
R
i
v
e
r
O
i
l
P
o
o
l
(
C
O
-
2
3
-
0
1
4
)
.
U
n
d
e
r
s
t
a
t
e
r
u
l
e
s
f
o
r
p
o
r
t
i
o
n
o
u
t
s
i
d
e
p
o
o
l
11
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
C
a
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
NA
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
NA
15
A
l
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
16
P
r
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
18
C
o
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
19
S
u
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
20
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
21
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
Ye
s
P
a
r
e
n
t
w
e
l
l
h
a
s
a
d
e
q
u
a
t
e
c
e
m
e
n
t
a
t
s
u
r
f
a
c
e
c
a
s
i
n
g
a
n
d
c
e
m
e
n
t
t
o
p
r
o
d
u
c
t
i
o
n
z
o
n
e
.
22
C
M
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
23
C
a
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
D
o
y
o
n
1
4
h
a
s
a
d
q
u
a
t
e
t
a
n
k
a
g
e
a
n
d
g
o
o
d
t
r
u
c
k
i
n
g
s
u
p
p
o
r
t
.
24
A
d
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
T
h
i
s
w
i
l
l
b
e
a
n
a
d
d
i
t
i
o
n
a
l
l
a
t
e
r
a
l
25
I
f
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
H
a
l
l
i
b
u
r
t
o
n
c
o
l
l
s
i
o
n
s
c
a
n
i
d
e
n
t
i
f
i
e
s
n
o
c
l
o
s
e
a
p
p
r
o
a
c
h
e
s
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
N
o
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
o
n
t
h
i
s
w
e
l
l
27
I
f
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
A
l
l
f
l
u
i
d
s
w
i
l
l
b
e
o
v
e
r
b
a
l
a
n
c
e
t
o
p
o
r
e
p
r
e
s
s
u
r
e
.
28
D
r
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
1
a
n
n
u
l
a
r
,
3
r
a
m
,
1
f
l
o
w
c
r
o
s
s
s
29
B
O
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
5
0
0
0
p
s
i
s
t
a
c
k
t
e
s
t
e
d
t
o
4
0
0
0
p
s
i
i
n
t
i
a
l
t
e
s
t
30
B
O
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
C
h
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
No
M
a
x
i
m
u
m
H
2
S
r
e
a
d
i
n
g
o
n
M
P
U
F
p
a
d
i
s
4
7
p
p
m
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
T
h
i
s
w
e
l
l
i
s
a
p
r
o
d
u
c
e
r
.
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
H
2
S
m
e
a
s
u
r
e
s
r
e
q
u
i
r
e
d
.
F
-
6
9
r
e
c
o
r
d
e
d
s
a
m
p
l
e
w
i
t
h
4
7
p
p
m
.
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
E
x
p
e
c
t
e
d
p
o
r
e
p
r
e
s
s
u
r
e
i
s
5
.
7
p
p
g
E
M
W
.
T
h
o
u
g
h
n
o
t
a
n
t
i
c
i
p
a
t
e
d
,
o
r
i
g
n
a
l
p
r
e
s
s
u
r
e
w
a
s
~
9
.
5
p
p
g
.
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
1/
9
/
2
0
2
4
Ap
p
r
MG
R
Da
t
e
1/
1
1
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
1/
9
/
2
0
2
4
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
TD
e
x
t
e
n
d
s
o
u
t
s
i
d
e
o
f
M
P
U
a
n
d
K
u
p
a
r
u
k
R
i
v
e
r
O
i
l
P
o
o
l
b
o
u
n
d
a
r
i
e
s
.
H
i
l
c
o
r
p
w
i
l
l
b
e
d
r
i
l
l
i
n
g
t
h
i
s
p
o
r
t
i
o
n
o
f
t
h
e
w
e
l
l
t
o
s
t
a
t
e
r
u
l
es
.
JL
C
1
/
2
2
/
2
0
2
4
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
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK, 99503
Re: Milne Point Field, Kuparuk River Oil, MPU F-34L1
Hilcorp Alaska, LLC
Permit to Drill Number: 223-107
Surface Location: 1970' FSL, 2750' FEL, Sec 06, T13N, R10E, UM, AK
Bottomhole Location: 2041' FSL, 2317' FWL, Sec 08, T14N, R10E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced 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.
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 AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of November 2023.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.21 11:25:15
-09'00'
21
Drilling Manager
11/15/23
Monty M
Myers
By Grace Christianson at 10:22 am, Nov 16, 2023
50-029-22824-60-00223-107
* Initial BOPE pressure test to 4000 psi. Annular to 2500 psi.
* Subsequent BOPE tests to 3500 psi. Annular to 2500 psi.
*Not approved for subsequent BOPE pressure tests below 3500 psi.
DSR-11/16/23MGR17NOV2023A.Dewhurst 17NOV23
1,710' to future MPU F-17L1
JLC 11/21/2023
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.11.21 11:27:11 -09'00'
11/21/23
11/21/23
Milne Point Unit
(MPU) F-34L1
Drilling Program
Version 1
October 10, 2023
Table of Contents
1.0 Well Summary ........................................................................................................................... 2
2.0 Management of Change Information ........................................................................................ 3
3.0 Tubular Program ....................................................................................................................... 4
4.0 Drill Pipe Information ............................................................................................................... 4
5.0 Internal Reporting Requirements ............................................................................................. 5
6.0 Wellbore Schematics .................................................................................................................. 6
7.0 Drilling / Completion Summary ................................................................................................ 9
8.0 Mandatory Regulatory Compliance / Notifications ................................................................ 10
9.0 R/U and Test BOPE ................................................................................................................. 12
10.0 Pull 2-7/8” Tubing, Cleanout, Test Casing .............................................................................. 14
11.0 Mill 6-1/8” Window and Kick Off ........................................................................................... 15
12.0 Drill 6-1/8” Production Hole Section ....................................................................................... 18
13.0 Run 4-1/2” Liner ...................................................................................................................... 21
14.0 Run Upper Completion............................................................................................................ 24
15.0 RDMO ...................................................................................................................................... 26
16.0 Post-Rig Work ......................................................................................................................... 27
17.0 Doyon 14 BOP Schematic ........................................................................................................ 28
18.0 Wellhead Schematic ................................................................................................................. 29
19.0 Days Vs Depth .......................................................................................................................... 31
20.0 Formation Tops & Information............................................................................................... 32
21.0 Anticipated Drilling Hazards .................................................................................................. 33
22.0 Doyon 14 Layout ...................................................................................................................... 35
23.0 FIT Procedure .......................................................................................................................... 36
24.0 Doyon 14 Choke Manifold Schematic ..................................................................................... 37
25.0 Casing Design Information ...................................................................................................... 38
26.0 6-1/8” Hole Section MASP ....................................................................................................... 39
27.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 40
28.0 Surface Plat (As Built) (NAD 27) ............................................................................................. 41
Page 2
Milne Point Unit F-34L1
Drilling Procedure
1.0 Well Summary
Well MPU F-34L1
Pad Milne Point “F” Pad
Planned Completion Type 4-1/2” Pre-Drilled Liner
Target Reservoir(s) Kuparuk A
Planned Well TD, MD / TVD 29,921’ MD / 8,091’ TVD
PBTD, MD / TVD 29,921’ MD / 8,091’ TVD
Surface Location (Governmental) 1970' FSL, 2409' FWL, Sec 6, T13N, R10E, UM, AK
Surface Location (NAD 27 –Zone 4) X=541,813 Y=6,035,422
Top of Productive Horizon
(Governmental) 1885' FSL, 546' FEL, Sec 19, T14N, R10E, UM, AK
TPH Location (NAD 27) X=543,867, Y=6,051,187
BHL (Governmental) 2041' FSL, 2317' FWL, Sec 8, T14N, R10E, UM, AK
BHL (NAD 27) X=546,627, Y=6,061,919
AFE Drilling Days 30 Days
AFE Completion Days 5 Days
Maximum Anticipated Pressure
(Surface) 1,493 psi
Maximum Anticipated Pressure
(Downhole/Reservoir) 2,254 psi (5.7ppg EMW)
Work String 4” 14# S-135 XT-39
KB Elevation above MSL: 33.7 ft + 12.0 ft = 45.7 ft
GL Elevation above MSL: 12.0 ft
BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams
Page 3
Milne Point Unit F-34L1
Drilling Procedure
2.0 Management of Change Information
Page 4
Milne Point Unit F-34L1
Drilling Procedure
3.0 Tubular Program
Hole
Section
OD
(in)
ID (in)Drift
(in)
Conn
OD (in)
Wt
(#/ft)
Grade Conn Burst
(psi)
Collapse
(psi)
Tension
(k-lbs)
6-1/8” 4-1/2” 3.92 3.795 4.714 13.5 L-80 H625 9,020 8,540 279
Tubing 4-1/2” 3.958 3.833 5.0 12.6 L-80 JFE Bear 8,430 7,500 288
4.0 Drill Pipe Information
Hole
Section
OD
(in)
ID (in)TJ ID
(in)
TJ OD
(in)
Wt
(#/ft)
Grade Conn M/U
(Min)
M/U
(Max)
Tension**
(k-lbs)
Production 4” 3.34” 2.563”4.875”14.0 S-135 XT39 18,500 22,200* 446
**Assumes 1.0 friction factor pipe dope, use 24,420 ft-lbs for 1.1 FF dope
*Tension Rating Based on Premium Pipe
All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery).
Page 5
Milne Point Unit F-34L1
Drilling Procedure
5.0 Internal Reporting Requirements
Fill out daily drilling report and cost report on Wellez.
x Report covers operations from 6am to 6am
x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left
of the data entry area – this will not save the data entered, and will navigate to another data entry
tab.
x Ensure time entry adds up to 24 hours total.
x Try to capture any out of scope work as NPT. This helps later on when we pull end of well
reports.
x Enter the MD and TVD depths EVERY DAY whether you are making hole or not.
Afternoon Updates
x Submit a short operations update each work day to mmyers@hilcorp.com,
nathan.sperry@hilcorp.com,jengel@hilcorp.com and joseph.lastufka@hilcorp.com
Intranet Home Page Morning Update
x Submit a short operations update each morning by 7am on the company intranet homepage. On
weekend and holidays, ensure to have this update in before 5am.
EHS Incident Reporting
x Health and safety: Notify EHS field coordinator.
x Environmental: Drilling Environmental coordinator
x Notify Drlg Manager & Drlg Engineer
x Submit Hilcorp Incident report to contacts above within 24 hrs
Casing Tally
x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com
Casing and Cement report
x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com
Hilcorp Milne Point Contact List:
Title Name Work Phone Cell Phone Email
Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com
Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com
Drilling Engineer Nathan Sperry 907.777.8450 907.301.8996 nathan.sperry@hilcorp.com
Operations Engineer Taylor Wellman 907.777.8449 907.947.9533 twellman@hilcorp.com
Geologist Graham Emerson 907.564.5242 907.793.0315 Graham.emerson@hilcorp.com
Reservoir Engineer Alan Abel 907.564.5032 Alan.abel@hilcorp.com
Safety Manager Laura Green 907.777.8314 907.342.7511 lagreen@hilcorp.com
Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com
Page 6
Milne Point Unit F-34L1
Drilling Procedure
6.0 Wellbore Schematics
Page 7
Milne Point Unit F-34L1
Drilling Procedure
Page 8
Milne Point Unit F-34L1
Drilling Procedure
Page 9
Milne Point Unit F-34L1
Drilling Procedure
7.0 Drilling / Completion Summary
MPU F-34L1 is a sidetrack production well targeting the Kuparuk River Pool, located on Milne Point ‘F-
pad’. The directional plan is a single string horizontal well with the kick off point at 20,011’ MD. Maximum
hole angle is ~91 degrees.
Drilling operations are expected to commence approximately December 10th, 2023, pending rig schedule.
Production liner will be 4-1/2” 13.5# L-80 pre-drilled liner run to 29,921’ MD / 8,091’ TVD.
All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located
on “B” pad.
General sequence of operations:
1. MIRU Doyon 14
2. N/U 13-5/8” x 5M BOPE and test
3. Pull upper completion
4. Cleanout run
5. Run RBP to test 7” casing. Run storm packer swap tubing spool. Pull storm packer and RBP.
6. Set 7” WS and mill 6-1/8” window
7. Drill with kickoff (motor) assembly until sufficient separation achieved
8. Drill 6-1/8” hole with RSS to TD
9. Run 4-1/2” production liner
10. Run 4-1/2” production tubing
11. N/D BOP, N/U Tree, RDMO
Reservoir Evaluation Plan:
1. Production Hole: No mud logging. LWD: GR/Res
Page 10
Milne Point Unit F-34L1
Drilling Procedure
8.0 Mandatory Regulatory Compliance / Notifications
Regulatory Compliance
Ensure that all drilling and completion operations comply with all applicable AOGCC regulations.
Operations stated in this PTD application may be altered based on sound engineering judgement as
wellbore conditions require, but no AOGCC regulations will be varied from without prior approval from
the AOGCC. If additional clarity or guidance is required on how to comply with a specific regulation,
do not hesitate to contact the Anchorage Drilling Team.
x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of
approval are captured in shift handover notes until they are executed and complied with.
x BOPs shall be tested at (1) week intervals prior to initiating window milling and (2) week intervals
during the drilling and completion of MPU F-34L1. Ensure to provide AOGCC 24 hrs notice prior
to testing BOPs.
x The initial test of BOP equipment will be to 250/4,000 psi & subsequent tests of the BOP equipment
will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial
and subsequent tests).Confirm that these test pressures match those specified on the APD.
x If the BOP is used to shut in on the well in a well control situation or control fluid flow from the
well bore, AOGCC is to be notified and we must test all BOP components utilized for well control
prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP
test.
x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid
program and drilling fluid system”.
x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and
completion: blowout prevention equipment and diverter requirements”.
o Ensure the diverter vent line is at least 75’ away from potential ignition sources
x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
x Casing pressure test criteria in 20 AAC 25.030 (e) Casing and Cementing,“A casing pressure test
must be performed if BOPE is to be installed on a casing. The casing must be tested to hold a
minimum surface pressure equal to 50 percent of the casing internal yield pressure. The test
pressure must show stabilizing pressure and may not decline more than 10 percent within 30
minutes. The results of this test and any subsequent tests of the casing must be recorded as required
by 20 AAC 25.070(1)”.
AOGCC Regulation Variance Requests:
x None
3500 psi minimum. - mgr
Page 11
Milne Point Unit F-34L1
Drilling Procedure
Summary of BOP Equipment and Test Requirements
Hole Section Equipment Test Pressure (psi)
6-1/8”
x 13-5/8” x 5M Hydril “GK” Annular BOP
x 13-5/8” x 5M Hydril MPL Double Gate
o Blind ram in btm cavity
x Mud cross w/ 3” x 5M side outlets
x 13-5/8” x 5M Hydril MPL Single ram
x 3-1/8” x 5M Choke Line
x 3-1/8” x 5M Kill line
x 3-1/8” x 5M Choke manifold
x Standpipe, floor valves, etc
Initial Test: 250/4000
Subsequent Tests:
250/4000
Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air
pump, and emergency pressure is provided by bottled nitrogen.
The remote closing operator panels are located in the doghouse and on accumulator unit.
Required AOGCC Notifications:
x Well control event (BOPs utilized to shut in the well to control influx of formation fluids).
x 24 hours notice prior to spud.
x 24 hours notice prior to testing BOPs.
x 24 hours notice prior to casing running & cement operations.
x Any other notifications required in APD.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email:jim.regg@alaska.gov
Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email:Victoria.loepp@alaska.gov
Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email:melvin.rixse@alaska.gov
Primary Contact for Opportunity to witness:AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
3500 psi minimum
Page 12
Milne Point Unit F-34L1
Drilling Procedure
9.0 R/U and Test BOPE
This is an in-reservoir sidetrack. The existing perforations will not be isolated via a CIBP.
9.1 Ensure Sundry, PTD, and drilling program are posted in the rig office and on the rig floor.
9.2 Level pad and ensure enough room for layout of rig footprint and R/U.
9.3 Ensure rig mats cover entire footprint of rig.
9.4 MIRU Doyon 14. Ensure rig is centered over the wellhead to prevent any wear to BOPE or
wellhead.
x Mud loggers will not be used on F-34L1.
9.5 RU to pump down the tubing and take returns from the IA to a tank. Pump at least 1 truck of
seawater followed by at least one soap sweep surface to surface per MI.
x Estimated Kuparuk pore pressure is 5.7ppg and fracture gradient is 12.0ppg.
x The whipstock will be set at ~20,011’ MD.
x Note that it is recommended to circ another BU after pulling the hanger to the floor to clear
the annulus of any scale/debris.
x Tubing volume to the lower GLM is ~97 bbls
x IA volume to the lower GLM is ~505 bbls.
x Note: Circulation point will depend on prep work. If possible, the tubing will be
punched as close to the ESP as possible. Verify circ point with OE.
9.6 Install BPV. N/D the tree. Install test dart in the BPV.
9.7 N/U 13-5/8” x 5M BOP as follows:
x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13-
5/8” x 5M mud cross / 13-5/8” x 5M single gate
x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity,blind ram in
bottom cavity.
x Single ram can be dressed with 2-7/8” x 5” VBRs
x N/U bell nipple, install flowline.
x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to
mud cross).
x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual
valve
9.8 Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min.
x Test 2-7/8” x 5” VBR’s with 2-7/8” and 4-1/2” test joints
x Confirm test pressures with PTD
Page 13
Milne Point Unit F-34L1
Drilling Procedure
x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure
is trapped underneath test plug
x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech
9.9 R/D BOP test equipment.
9.10 Pull test dart and BPV.
9.11 Order out 8.6ppg fluid for production hole.
9.12 Ensure 5-1/2” or 5-3/4” liners in mud pumps (maximize available pump pressure).
Page 14
Milne Point Unit F-34L1
Drilling Procedure
10.0 Pull 2-7/8” Tubing, Cleanout, Test Casing
Pull tubing, cleanout, set retrievable bridge plug, test casing, set storm packer, swap tubing
spool, pull storm packer, pull RBP
10.1 PU landing joint or spear and recover the tubing hanger.
x The FMC 11” x 7-1/16” x 2-7/8” hanger was installed in 2021 by ASR.
10.2 Back out lock down screws.
10.3 Pull tubing hanger with landing joint/XO to the floor.
10.4 The tubing is expected to be in good condition.
10.5 Note and record PU weight required to pull the tubing from cut.
10.6 The expected weight of the string in a vertical hole filled with seawater is 110 klbs. PU weight
will be significantly less due to the deviation. Note: Final PU weight on the original
completion was 100klbs.
10.7 Recommend that at least 1X BU is circulated after pulling the hanger to the floor. If desired,
circulate another soap sweep surface-to-surface to clean the tubing.
10.8 Pull and lay down the upper completion.
10.9 Run wear ring.
10.10 PU 4” drill pipe and RIH with cleanout assembly per Baker rep.
10.11 When on bottom circulate at max rate a minimum of 1X BU or until returns are clean. Pump
high vis sweep if necessary.
10.12 POOH with cleanout assembly.
10.13 PU retrievable bridge plug and RIH to ~18,900’ MD. Set the RBP and test the casing to 2,500
psi. Rack back 2-5 stands and PU a storm packer.
10.14 TIH and set the storm packer. Test above the storm packer to 2,500 psi for 10 mins.
10.15 ND BOPE. ND the existing 7-1/16” x 11” Gen 5a FMC tubing spool. NU the 11” x 11” Gen 5
per wellhead rep. Pressure test spool per wellhead rep. Pressure test the BOPE break to 250 psi
low / 4,000 psi high.
10.16 RIH. Engage storm packer and release. POOH and lay down the storm packer. RIH and
retrieve the RBP. CBU. Flowcheck. POOH.
Page 15
Milne Point Unit F-34L1
Drilling Procedure
11.0 Mill 6-1/8” Window and Kick Off
Note: All following operations will be covered under by the PTD for F-34L1
x A CBL was run on January 26, 1998. The logging company picked the top of cement at
18,040’ MD (original KB). They noted good cement from the bottom of the logged interval
(19,232’ MD original KB) to their TOC pick.
11.1 Whipstock Set Depth Information:
x Planned TOW: ~20,011’ MD
i. Collars are located at 19,957.5’, 19,997.7’, and 20,037.1’ (parent RKB reference)
x WS will be set to avoid a collar based on the F-34 7” tally (Nabors 27E RKB of 30.55’).
Note that the original paperwork reports a 30.55’ RKB from the rig floor to the base flange.
x Doyon 14’s RKB on F-34L1 is 33.7’ (RKB to base flange) plus 12.0’ ground level for
45.7’. There is a 3.15’ shift from the OKB (Nabors 27E) to the Doyon 14 RKB.
x Drilling foreman, whipstock service hand, and drilling engineer to review parent tally and
agree on the set depth.
11.2 MU 6-1/8” mill/whipstock assembly as per Baker Hughes tally
x Make up HWDP, string magnets, and float sub
x Ensure magnets are in trough, under shakers and flow area to capture metal shavings
circulated
11.3 Install MWD and orient. Rack back mill assembly.
x Ensure a dedicated MWD is available for orientation of the whipstock
11.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD
and milling rep. Document and record offset in well file.
11.5 Slowly run in the hole as per fishing Rep. Run extremely slow through the BOP & wear bushing
to prevent damaging the shear bolt.
11.6 Run in hole at 1 ½ to 2 minutes per stand, or per Fishing Rep. Ensure work string is stationary
prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening
the shear bolt and prematurely setting the anchor.
11.7 Shallow test MWD
11.8 Stop at least 30-45’ above planned set depth and obtain survey with MWD.
Page 16
Milne Point Unit F-34L1
Drilling Procedure
11.9 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string,
measure and record P/U and S/O weights. Obtain good survey to orient whipstock face.
11.10 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP
to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is
30q ROHS.
11.11 Whipstock Orientation Diagram:
Desired orientation of the whipstock face is 10R to 30R, target is 30 ROHS
Hole Angle at window interval (20,011’ MD) is ~85°, Azimuth 359°.
11.12 Once whipstock is in desired orientation, set WS per fishing rep.
11.13 Pressure up per rep to set hydraulic set whipstock, (verify highlighted values with Baker rep) P/U
5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by
slacking off weight on the whipstock shear bolt. (35klbs shear value, verify with Baker rep).
11.14 P/U 5-10’ above top of whipstock.
11.15 Displace to window milling fluid. CBU and confirm 8.6 ppg MW in/out
x Ensure mud properties are sufficient for transporting metal cuttings
x Milling fluid will be 8.6 ppg solids free mud
11.16 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight
and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch
metal cuttings. Pump high visc sweeps as necessary.
11.17 If possible, install catch trays in shaker underflow chute to help catch metal cuttings.
11.18 Clean catch trays and ditch magnets frequently while milling window.
11.19 Mill window until the uppermost mill has passed across the entire tray and 20’ of new hole has
been milled. Dress and polish window as needed.
30R10R
Page 17
Milne Point Unit F-34L1
Drilling Procedure
11.20 After window is milled and before POOH, shut down pumps and work milling assembly through
window watching for drag. Dress and polish window as needed. After reaming, shut off pumps
and rotary (if hole conditions allow) and pass through window checking for drag.
11.21 Circulate bottoms up until even MW in/out and hole is clean of metal shavings.
11.22 Pull back into 7” casing and perform FIT to 11.5 ppg EMW. Chart Test.
x Note: A 9.0ppg FIT with 8.6ppg fluid density provides 125 bbl kick tolerance assuming 5.7ppg
pore pressure (swabbed kick at 8.6ppg).
11.23 POOH & LD milling BHA. Gauge mills for wear.
11.24 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris.
Page 18
Milne Point Unit F-34L1
Drilling Procedure
12.0 Drill 6-1/8” Production Hole Section
12.1 PU 6-1/8” kickoff assembly.
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing.
x Workstring will be 4” 14# S-135 XT 39
x Run x2 Solid Plunger Floats for MPD
12.2 6-1/8” hole mud program summary:
x Density:The Kuparuk reservoir pressure is expected to be 5.7ppg. 8.6ppg MW will be used.
x Solids Concentration:It is imperative that the solids concentration be kept low while drilling
the production hole section. Keep the shaker screen size optimized and fluid running to near the
end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest
screens possible.
x Inhibition:3% KCl will be used for inhibition. Watch MBT levels, dilute as necessary to
maintain. Increase KCl % as needed
x Run the centrifuge continuously while drilling the production hole, this will help with solids
removal and minimize sand content and LGS to maintain fluid properties and quality of the mud
system.
x PVT will be used throughout the drilling phase. Remote monitoring stations will be available at
the driller’s console, Co Man office, & Toolpusher office.
System Type:8.6 - 9.8ppg FlowPro SF 3% KCl Inhibited
Properties:
Section Density
Plastic
Viscosity Yield Point Total
Solids
MBT pH
6-1/8” 8.6 - 9.8 ALAP 12-20 <5%< 7 9.0 - 9.5
12.3 TIH w/ 6-1/8” directional assembly on 4” DP to above window. Shallow test MWD and LWD
on trip in.
12.4 Ensure even 8.6ppg MW in and out. Note: MPD is NOT needed for drilling with the motor
assembly.
12.5 Drill 6-1/8” hole section with kickoff assembly at least until we have confirmed we have
separation from the old wellbore. TOOH.
y
k reservoir pressure is expected to be 5.7ppg. 8.6ppg MW will be used.
Page 19
Milne Point Unit F-34L1
Drilling Procedure
12.6 P/U 6-1/8” RSS Directional BHA
x Ensure BHA components have been inspected previously.
x Drift and caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
x Ensure TF offset is measured accurately and entered correctly into the MWD software.
x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing.
x Workstring will be 4” 14# S-135 XT 39
x Run x2 Solid Plunger Floats for MPD
12.7 Install MPD Element
x Ensure rig crew is familiar with MPD connection operations
12.8 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer.
x Flow Rate: 150-250 gpm (Target 200 ft/min AV)
x RPM: 120 – 180
x WOB as needed
x Target ECD and CBHP: As low as reasonably possible to minimize lost circulation
x Take MWD surveys every stand drilled.
x Kuparuk PP estimate is 5.7 ppg. Good drilling and tripping practices are vital for avoidance
of differential sticking.
x Watch for fluid losses while drilling through Kuparuk.
12.9 At TD, circulate a minimum of 2X BU
x Circulate at full drill rate (150-250 gpm) while rotating at 120 rpm’s
x We can slowly rack back a couple of stands while performing the BU circulations.
12.10 Backream to the window:
x Circulate at max rate while minimizing drilling ECD’s
x Perform CBHP connections
x Rotate at maximum rpm that can be sustained.
x Limit pulling speed to 5 – 10 min/std (slip to slip time, not including connections).
x Continue backreaming to the window and circ at least 1X BU at the window.
x Rack back DP while TOOH. Do not lay down drill pipe. This is to minimize open hole time
before liner is on bottom.
x Once inside casing, drop rabbit on remaining drillpipe on TOOH that will be used to run the
4.5” liner. Confirm diameter drift with Baker for setting liner hanger.
12.11 Circulate a minimum of 2X BU at 7” window and clean casing with high vis sweeps.
12.12 Monitor well for flow. Increase mud weight if necessary
x Wellbore breathing has been seen on past MPU Kuparuk wells. Perform extended flow checks
to determine if well is breathing, treat all flow as an influx until proven otherwise
x If necessary, increase MW at shoe for any higher than expected pressure seen
Page 20
Milne Point Unit F-34L1
Drilling Procedure
12.13 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball
drops.
Page 21
Milne Point Unit F-34L1
Drilling Procedure
13.0 Run 4-1/2” Liner
Plan to alternate 1 solid joint and 1 pre-drilled joint.
13.1 Well control preparedness: In the event of an influx of formation fluids while running the 4-
1/2” injection liner with pre-drilled liner, the following well control response procedure will be
followed:
x With a pre-drilled joint across the BOP: P/U & M/U the 4” safety joint (with 4-1/2” crossover
installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This
joint shall be fully M/U and available prior to running the first joint of 4-1/2” liner.
x With 4-1/2” solid joint across BOP: Slack off and position the 4-1/2” solid joint to MU the TIW
valve. Shut in ram or annular on 4-1/2” solid joint. Close TIW valve.
13.2 Set the test plug and flush the stack with the wash tool. Pull test plug.
13.3 Ensure rams have been tested to cover 4” and 4-1/2” test joints prior to running liner.
13.4 Ensure wear bushing is installed in wellhead.
13.5 R/U 4-1/2” casing running equipment.
x Ensure all casing has been drifted prior to running.
x Be sure to count the total # of joints before running.
x Keep hole covered while R/U casing tools.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
13.6 Run 4-1/2” liner per completion tally.
x Dope pin end only w/ paint brush.
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
4-1/2” Tenaris Hydril 625 Make-Up Torques
Casing OD Minimum Optimum Maximum
4.5”8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs
4-1/2” Tenaris Hydril 625 Operating Limit Torques
Casing OD Operating Yield
4.5”12,800 ft-lbs 15,000 ft-lbs
Page 22
Milne Point Unit F-34L1
Drilling Procedure
Page 23
Milne Point Unit F-34L1
Drilling Procedure
13.7 Ensure to run enough liner to provide for approximately 150’ overlap inside 7” casing. Ensure
hanger/pkr will not be set in a 7” connection.
13.8 Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe
deck to make sure it coincides with the pipe tally.
13.9 M/U Baker SLZXP liner top packer.
13.10 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a
clear flow path exists.
13.11 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid
surging the hole. Slow down running speed if necessary.
13.12 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe
depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the
string to bottom.
13.13 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
20, & 30 rpm.
13.14 RIH to TD. Monitor run for losses.
13.15 Follow Baker procedure to set SLZXP.
13.16 Unsting and CBU X2.
13.17 Swap well to KCl completion brine. Ensure the density matches the final mud weight used
during the liner run.
13.18 Perform flowcheck. POOH LDDP.
Page 24
Milne Point Unit F-34L1
Drilling Procedure
14.0 Run Upper Completion
14.1 M/U ESP assembly and RIH to setting depth. TIH no faster than 90 ft/min.
x Ensure wear bushing is pulled.
x Ensure 4-½” TXP- BTC x XT39 crossover is on rig floor and M/U to FOSV.
x Ensure all tubing has been drifted in the pipe shed prior to running.
x Be sure to count the total # of joints in the pipe shed before running.
x Keep hole covered while R/U casing tools.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
x Monitor displacement from wellbore while RIH.
4-1/2” TXP-BTC Make-Up Torques
Tbg OD Minimum Optimum Maximum
4.5”5,550 ft-lbs 6,170 ft-lbs 6,790 ft-lbs
4-1/2” TXP-BTC Operating Limit Torques
Tbg OD Operating
4.5”8,800 ft-lbs
Page 25
Milne Point Unit F-34L1
Drilling Procedure
Page 26
Milne Point Unit F-34L1
Drilling Procedure
4-½” Upper Completion Running Order - ESP
Conventional ESP
x Centralizer (OD = ±5.85”), Base at ±18,750’ MD
x Intake Sensor
x 500Hp 562 Motor (OD = 5.62”)
x Lower Seal Section
x Upper Seal Section
x Intake / Gas Separator
x Pump Section 1
x Pump Section 2
x Discharge Head
x Joints 4-1/2”, 12.6#, L-80, TXP-BTC tubing
x 4-½” 12.6#/ft, L-80 TXP-BTC space out pups
x 1 joint 4-½” 12.6#/ft, L-80 TXP-BTC tubing
x Tubing hanger with 4-1/2” TXP-BTC pin down
14.2 Follow all service company procedures for handling, make up and deployment of the ESP
system.
i. Typical clamping is every joint for the first 15 joints and then every other joint to surface.
Make note of clamping performed in tally.
ii. Perform electrical continuity checks every 2,000’ MD.
14.3 Land hanger. RILDs and test hanger.
14.4 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and
tree.
14.5 Pull BPV. Set TWC. Test tree to 5000 psi.
14.6 Pull TWC. Set BPV. Bullhead tubing & IA freeze protect if/as needed.
14.7 Secure the tree and cellar.
15.0 RDMO
15.1 RDMO Doyon 14.
Page 27
Milne Point Unit F-34L1
Drilling Procedure
16.0 Post-Rig Work
16.1 Pull BPV. Bullhead tubing freeze protect if/as needed.
Page 28
Milne Point Unit F-34L1
Drilling Procedure
17.0 Doyon 14 BOP Schematic
Typical Ram Configuration
Page 29
Milne Point Unit F-34L1
Drilling Procedure
18.0 Wellhead Schematic
Current Wellhead Schematic
Page 30
Milne Point Unit F-34L1
Drilling Procedure
Proposed Wellhead Schematic after Tubing Spool Swap
2-7/8”
Page 31
Milne Point Unit F-34L1
Drilling Procedure
19.0 Days Vs Depth
Page 32
Milne Point Unit F-34L1
Drilling Procedure
20.0 Formation Tops & Information
Formation TVD TVDss MD EMW (PPG)
Top C 7558.7 -7513 18,958 5.7
Top A2 7614.7 -7569 19,569 5.7
Top A1 7667.7 -7622 20,257 5.7
MPU F-Pad Data Sheet
Page 33
Milne Point Unit F-34L1
Drilling Procedure
21.0 Anticipated Drilling Hazards
Window Exit:
Tracking Casing
The KOP is cemented. The motor run will help us ensure departure from the parent bore prior to drilling
ahead with a rotary steerable system.
Production Hole Sections:
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up
with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor
ECD’s to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe
rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe
moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation
after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of
200 ft/min.
Lost Circulation:
Monitor ECD’s during production section to ensure ECD’s stay below 12.0ppg (target as low as
possible). Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early
signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
The Kuparuk FG is predicted to be ~12.0ppg.
Wellbore Stability:
This is an in-zone sidetrack. Wellbore instability is viewed as a low risk. Maintain sufficient MW for
stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles.
Use MPD to offset swab effect while TOOH.
Anti-Collision:
This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic
interference while drilling ahead.
Faulting:
There are no mapped faults in the production interval.
H2S:
Treat every hole section as though it has the potential for H2S. H2S events have typically been minor
from F-pad Kuparuk wells. The vast majority of sample data is less than 10 ppm. F-69 recorded a
sample with 47 ppm. F-53 had one sample test come back with 32 ppm.
1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements
of 20 AAC 25.066.
Page 34
Milne Point Unit F-34L1
Drilling Procedure
3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Page 35
Milne Point Unit F-34L1
Drilling Procedure
22.0 Doyon 14 Layout
Page 36
Milne Point Unit F-34L1
Drilling Procedure
23.0 FIT Procedure
Formation Integrity Test (FIT) and
Leak-Off Test (LOT) Procedures
Procedure for FIT:
1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe).
2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe.
3. Close the blowout preventer (ram or annular).
4. Pump down the drill stem at 1/4 to 1/2 bpm.
5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs.
drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe.
6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes.
Record time vs. pressure in 1-minute intervals.
7. 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 estimated reservoir pressure, and allowing for an appropriate amount of kick
tolerance in case well control measures are required.
Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of
stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid;
at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure
monitored as with an FIT.
Page 37
Milne Point Unit F-34L1
Drilling Procedure
24.0 Doyon 14 Choke Manifold Schematic
Page 38
Milne Point Unit F-34L1
Drilling Procedure
25.0 Casing Design Information
Page 39
Milne Point Unit F-34L1
Drilling Procedure
26.0 6-1/8” Hole Section MASP
Page 40
Milne Point Unit F-34L1
Drilling Procedure
27.0 Spider Plot (NAD 27) (Governmental Sections)
Page 41
Milne Point Unit F-34L1
Drilling Procedure
28.0 Surface Plat (As Built) (NAD 27)
6WDQGDUG3URSRVDO5HSRUW
2FWREHU
3ODQ 038)/ZS
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
3ODQ 03)
3ODQ 038)/
48
0
0
56
0
0
64
0
0
72
0
0
80
0
0
88
0
0
True Vertical Depth (1200 usft/in)
16
8
0
0
17
6
0
0
1
8
4
0
0
1
9
2
0
0
2
0
0
0
0
2
0
8
0
0
2
1
6
0
0
2
2
4
0
0
2
3
2
0
0
2
4
0
0
0
2
4
8
0
0
25
6
0
0
26
4
0
0
2
7
2
0
0
2
8
0
0
0
Ve
r
t
i
c
a
l
S
e
c
t
i
o
n
a
t
1
4
.
7
0
°
(
1
2
0
0
u
s
f
t
/
i
n
)
MP
U
F
-
3
4
A
w
p
0
6
t
g
t
1
1
MP
F
-
3
4
A
w
p
0
5
T
g
t
1
MP
F
-
3
4
A
w
p
0
5
T
g
t
2
MP
F
-
3
4
A
w
p
0
5
T
g
t
3
MP
F
-
3
4
A
w
p
0
5
T
g
t
4
MP
F
-
3
4
A
w
p
0
5
T
g
t
5
MP
F
-
3
4
A
w
p
0
5
T
g
t
6
MP
F
-
3
4
A
w
p
0
5
T
g
t
7
MP
F
-
3
4
A
w
p
0
5
T
g
t
8
MP
F
-
3
4
A
w
p
0
5
T
g
t
9
MP
F
-
3
4
A
w
p
0
5
T
g
t
1
0
MP
F
-
3
4
A
w
p
0
5
T
o
e
19500
20000
20500
2 0 9 8 0 MP
F
-
3
4
7"
T
O
W
4
1
/
2
"
x
6
"
20500
21000
21500
22000
22500
23000
23500
24000
24500
25000
25500
26000
26500
27000
27500
28000
28500
29000
29500
29922
MP
U
F
-
3
4
L
1
w
p
1
2
K
O
P : Start Dir 12º/100' : 20010.65' M
D, 7645.81'TVD : 30° RT TF
End Dir : 20027.65' M
D, 7647.09' TVD
Start Dir 5º/100' : 20057.65' M
D, 7648.9'TV
D
End Dir : 20885.62' M
D, 7701.57' TV
D
Start Dir 5º/100' : 20916.45' M
D, 7701.68'TVD
End Dir : 21476.1' M
D, 7717.16' TVD
Start Dir 2.5º/100' : 21540.1' M
D, 7720.4'TV
D
End Dir : 21621.9' M
D, 7723.08' TVD
Start Dir 2.5º/100' : 21914.36' M
D, 7727.45'TV
D
End Dir : 22006.13' M
D, 7730.53' TVD
Start Dir 2.5º/100' : 22206.13' M
D, 7741'TVD
End Dir : 22339.6' M
D, 7751.84' TV
D
Start Dir 2.5º/100' : 22589.34' M
D, 7779.31'TVD
End Dir : 22726.79' M
D, 7790.35' TV
D
Start Dir 2.5º/100' : 22976.79' M
D, 7803'TVD
End Dir : 23139.5' M
D, 7805.47' TVD
Start Dir 2.5º/100' : 23477.86' M
D, 7798.6'TVD
End Dir : 23616.59' M
D, 7799.97' TV
D
Start Dir 2.5º/100' : 23816.59' M
D, 7808'TVD
End Dir : 23954.07' M
D, 7817.62' TVD
Start Dir 2.5º/100' : 24266.64' M
D, 7848.82'TVD
End Dir : 24412.16' M
D, 7858.76' TVD
Start Dir 2.5º/100' : 24637.16' M
D, 7867'TVD
End Dir : 24778.37' M
D, 7868.32' TVD
Start Dir 2.5º/100' : 25265.74' M
D, 7859.61'TVD
End Dir : 25426.74' M
D, 7862.38' TV
D
Start Dir 2.5º/100' : 25776.74' M
D, 7880.7'TV
D
End Dir : 26343.02' M
D, 7926.22' TV
D
Start Dir 2.5º/100' : 26393.89' M
D, 7931.7'TV
D
End Dir : 26545.84' M
D, 7943.59' TV
D
Start Dir 2.5º/100' : 27495.84' M
D, 7990'TVD
End Dir : 27619.94' M
D, 7995.8' TVD
Start Dir 2.5º/100' : 28520.12' M
D, 8036'TVD
End Dir : 28532.09' M
D, 8036.5' TVD
Total Depth : 29921.62' M
D, 8091.3' TV
D
KU
P
_
A
2
KU
P
_
A
1
KU
P
_
A
1
KU
P
_
A
1
KU
P
_
A
1
B
KU
P
_
A
1
B
KU
P
_
A
_
B
A
S
E
KU
P
_
A
_
B
A
S
E
KU
P
_
A
1
B
KU
P
_
A
1
B
KU
P
_
A
1
B
KU
P
_
A
1
B
WE
L
L
D
E
T
A
I
L
S
:
P
l
a
n
:
M
P
F
-
3
4
N
A
D
1
9
2
7
(
N
A
D
C
O
N
C
O
N
U
S
)
A
l
a
s
k
a
Z
o
n
e
0
4
Gr
o
u
n
d
L
e
v
e
l
:
12
.
0
0
+N
/
-
S
+
E
/
-
W
N
o
r
t
h
i
n
g
E
a
s
t
i
n
g
La
t
i
t
u
d
e
Lo
n
g
i
t
u
d
e
0.
0
0
0
.
0
0
60
3
5
4
2
2
.
0
9
54
1
8
1
3
.
4
8
70
°
3
0
'
2
7
.
6
8
8
8
N
1
4
9
°
3
9
'
2
8
.
4
1
7
6
W
CA
S
I
N
G
D
E
T
A
I
L
S
TV
D
TV
D
S
S
MD
S
i
z
e
Na
m
e
76
4
5
.
8
4
7
6
0
0
.
1
4
2
0
0
1
1
.
0
0
7
7
"
T
O
W
80
9
1
.
3
0
8
0
4
5
.
6
0
2
9
9
2
1
.
6
2
4-
1
/
2
4
1
/
2
"
x
6
"
Pr
o
j
e
c
t
:
M
i
l
n
e
P
o
i
n
t
Si
t
e
:
M
P
t
F
P
a
d
We
l
l
:
P
l
a
n
:
M
P
F
-
3
4
We
l
l
b
o
r
e
:
P
l
a
n
:
M
P
U
F
-
3
4
L
1
De
s
i
g
n
:
M
P
U
F
-
3
4
L
1
w
p
1
2
SE
C
T
I
O
N
D
E
T
A
I
L
S
Se
c
M
D
I
n
c
A
z
i
T
V
D
+
N
/
-
S
+
E
/
-
W
D
l
e
g
T
F
a
c
e
V
S
e
c
t
T
a
r
g
e
t
A
n
n
o
t
a
t
i
o
n
1
2
0
0
1
0
.
6
5
8
4
.
7
8
3
5
9
.
5
4
7
6
4
5
.
8
1
1
7
0
4
6
.
2
6
2
1
6
5
.
3
6
0
.
0
0
0
.
0
0
1
7
0
3
7
.
7
7
K
O
P
:
S
t
a
r
t
D
i
r
1
2
º
/
1
0
0
'
:
2
0
0
1
0
.
6
5
'
M
D
,
7
64
5
.
8
1
'
T
V
D
:
3
0
°
R
T
T
F
2
2
0
0
2
7
.
6
5
8
6
.
5
4
0
.
5
6
7
6
4
7
.
0
9
1
7
0
6
3
.
2
1
2
1
6
5
.
3
8
1
2
.
0
0
3
0
.
0
0
1
70
5
4
.
1
7
E
n
d
D
i
r
:
2
0
02
7
.
6
5
'
M
D
,
7
6
4
7
.
0
9
'
T
V
D
3
2
0
0
5
7
.
6
5
8
6
.
5
4
0
.
5
6
7
6
4
8
.
9
0
1
7
0
9
3
.
1
5
2
1
6
5
.
6
7
0
.
0
0
0
.
0
0
1
7
0
8
3
.
2
1
S
t
a
r
t
D
i
r
5
º
/
1
0
0
'
:
2
0
0
5
7
.
6
5
'
M
D
,
76
4
8
.
9
'
T
V
D
4
2
0
1
7
7
.
6
5
8
3
.
5
6
5
.
7
9
7
6
5
9
.
2
5
1
7
2
1
2
.
4
7
2
1
7
2
.
2
9
5
.
0
0
1
2
0
.
0
0
1
7
2
0
0
.
3
0
5
2
0
8
8
5
.
6
2
8
9
.
7
9
4
0
.
7
2
7
7
0
1
.
5
7
1
7
8
5
1
.
1
7
2
4
4
7
.
5
0
5
.
0
0
8
1
.
2
3
1
7
8
8
7
.
9
4
E
n
d
D
i
r
:
2
0
8
8
5
.
6
2
'
M
D
,
7
7
0
1
.
5
7
'
T
V
D
6
2
0
9
1
6
.
4
5
8
9
.
7
9
4
0
.
7
2
7
7
0
1
.
6
8
1
7
8
7
4
.
5
5
2
4
6
7
.
6
1
0
.
0
0
0
.
0
0
1
7
9
1
5
.
6
5
S
t
a
r
t
D
i
r
5
º
/
1
0
0
'
:
2
0
9
1
6
.
4
5
'
M
D
,
7
7
0
1
.
6
8
'
T
V
D
7
2
1
4
7
6
.
1
0
8
7
.
1
0
1
2
.
8
5
7
7
1
7
.
1
6
1
8
3
6
8
.
9
7
2
7
1
7
.
2
7
5
.
0
0
-
9
5
.
8
0
1
8
4
5
7
.
2
5
E
n
d
D
i
r
:
2
1
47
6
.
1
'
M
D
,
7
7
1
7
.
1
6
'
T
V
D
8
2
1
5
4
0
.
1
0
8
7
.
1
0
1
2
.
8
5
7
7
2
0
.
4
0
1
8
4
3
1
.
2
9
2
7
3
1
.
4
9
0
.
0
0
0
.
0
0
1
8
5
2
1
.
1
3
M
P
F
-
3
4
A
w
p
0
5
T
g
t
2
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
21
5
4
0
.
1
'
M
D
,
7
7
2
0
.
4
'
T
V
D
9
2
1
6
2
1
.
9
0
8
9
.
1
4
1
2
.
8
2
7
7
2
3
.
0
8
1
8
5
1
1
.
0
0
2
7
4
9
.
6
5
2
.
5
0
-
0
.
9
7
1
8
6
0
2
.
8
4
E
n
d
D
i
r
:
2
1
6
2
1
.
9
'
M
D
,
77
2
3
.
0
8
'
T
V
D
10
2
1
9
1
4
.
3
6
8
9
.
1
4
1
2
.
8
2
7
7
2
7
.
4
5
1
8
7
9
6
.
1
4
2
8
1
4
.
5
1
0
.
0
0
0
.
0
0
1
8
8
9
5
.
1
1
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
1
9
1
4
.
3
6
'
M
D
,
7
7
2
7
.
4
5
'
T
V
D
11
2
2
0
0
6
.
1
3
8
7
.
0
0
1
2
.
0
0
7
7
3
0
.
5
3
1
8
8
8
5
.
7
1
2
8
3
4
.
2
2
2
.
5
0
-
1
5
9
.
2
1
18
9
8
6
.
7
4
E
n
d
D
i
r
:
2
2
0
0
6
.
1
3
'
M
D
,
7
7
3
0
.
5
3
'
T
V
D
12
2
2
2
0
6
.
1
3
8
7
.
0
0
1
2
.
0
0
7
7
4
1
.
0
0
1
9
0
8
1
.
0
7
2
8
7
5
.
7
4
0
.
0
0
0
.
0
0
1
9
1
8
6
.
2
5
M
P
F
-
3
4
A
w
p
0
5
T
g
t
3
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
22
0
6
.
1
3
'
M
D
,
7
7
4
1
'
T
V
D
13
2
2
3
3
9
.
6
0
8
3
.
6
8
1
2
.
3
8
7
7
5
1
.
8
4
1
9
2
1
1
.
0
9
2
9
0
3
.
8
2
2
.
5
0
1
7
3
.
5
8
1
9
3
1
9
.
1
3
E
n
d
D
i
r
:
2
2
3
3
9
.
6
'
M
D
,
7
75
1
.
8
4
'
T
V
D
14
2
2
5
8
9
.
3
4
8
3
.
6
8
1
2
.
3
8
7
7
7
9
.
3
1
1
9
4
5
3
.
5
4
2
9
5
7
.
0
2
0
.
0
0
0
.
0
0
1
9
5
6
7
.
1
5
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
2
5
8
9
.
3
4
'
M
D
,
77
7
9
.
3
1
'
T
V
D
15
2
2
7
2
6
.
7
9
8
7
.
1
0
1
2
.
0
0
7
7
9
0
.
3
5
1
9
5
8
7
.
4
4
2
9
8
5
.
9
4
2
.
5
0
-
6
.
2
7
1
9
7
0
4
.
0
1
E
n
d
D
i
r
:
2
2
72
6
.
7
9
'
M
D
,
7
7
9
0
.
3
5
'
T
V
D
16
2
2
9
7
6
.
7
9
8
7
.
1
0
1
2
.
0
0
7
8
0
3
.
0
0
1
9
8
3
1
.
6
7
3
0
3
7
.
8
5
0
.
0
0
0
.
0
0
1
9
9
5
3
.
4
1
M
P
F
-
3
4
A
w
p0
5
T
g
t
4
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
2
9
7
6
.
7
9
'
M
D
,
7
8
0
3
'
T
V
D
17
2
3
1
3
9
.
5
0
9
1
.
1
6
1
2
.
1
9
7
8
0
5
.
4
7
1
9
9
9
0
.
7
1
3
0
7
1
.
9
3
2
.
5
0
2
.
7
0
2
0
1
1
5
.
8
9
E
n
d
D
i
r
:
2
3
13
9
.
5
'
M
D
,
7
8
0
5
.
4
7
'
T
V
D
18
2
3
4
7
7
.
8
6
9
1
.
1
6
1
2
.
1
9
7
7
9
8
.
6
0
2
0
3
2
1
.
3
7
3
1
4
3
.
3
7
0
.
0
0
0
.
0
0
2
0
4
5
3
.
8
6
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
3
4
7
7
.
8
6
'
M
D
,
7
7
9
8
.
6
'
T
V
D
19
2
3
6
1
6
.
5
9
8
7
.
7
0
1
2
.
0
0
7
7
9
9
.
9
7
2
0
4
5
7
.
0
0
3
1
7
2
.
4
4
2
.
5
0
-
1
7
6
.
8
3
2
0
5
9
2
.
4
2
E
n
d
D
i
r
:
2
3
6
1
6
.
5
9
'
M
D
,
7
7
9
9
.
9
7
'
T
V
D
20
2
3
8
1
6
.
5
9
8
7
.
7
0
1
2
.
0
0
7
8
0
8
.
0
0
2
0
6
5
2
.
4
7
3
2
1
3
.
9
9
0
.
0
0
0
.
0
0
2
0
7
9
2
.
0
4
M
P
F
-
3
4
A
w
p
0
5
T
g
t
5
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
3
8
1
6
.
5
9
'
M
D
,
7
8
0
8
'
T
V
D
2
1
2
3
9
5
4
.
0
7
8
4
.
2
7
1
1
.
7
6
7
8
1
7
.
6
2
2
0
7
8
6
.
6
5
3
2
4
2
.
2
2
2
.
5
0
-
1
7
6
.
0
2
2
0
9
2
9
.
0
0
E
n
d
D
i
r
:
2
3
9
5
4
.
0
7
'
M
D
,
7
8
1
7
.
6
2
'
T
V
D
22
2
4
2
6
6
.
6
4
8
4
.
2
7
1
1
.
7
6
7
8
4
8
.
8
2
2
1
0
9
1
.
1
3
3
3
0
5
.
6
1
0
.
0
0
0
.
0
0
2
1
2
3
9
.
6
0
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
4
2
6
6
.
6
4
'
M
D
,
7
8
4
8
.
8
2
'
T
V
D
23
2
4
4
1
2
.
1
6
8
7
.
9
0
1
1
.
5
0
7
8
5
8
.
7
6
2
1
2
3
3
.
3
1
3
3
3
4
.
8
7
2
.
5
0
-
4
.
1
1
2
1
3
8
4
.
5
4
E
n
d
D
i
r
:
2
4
4
1
2
.
1
6
'
M
D
,
7
8
5
8
.
7
6
'
T
V
D
24
2
4
6
3
7
.
1
6
8
7
.
9
0
1
1
.
5
0
7
8
6
7
.
0
0
2
1
4
5
3
.
6
4
3
3
7
9
.
7
0
0
.
0
0
0
.
0
0
2
1
6
0
9
.
0
4
M
P
F
-
3
4
A
w
p
0
5
T
g
t
6
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
4
6
3
7
.
1
6
'
M
D
,
7
8
6
7
'
T
V
D
25
2
4
7
7
8
.
3
7
9
1
.
0
2
9
.
8
6
7
8
6
8
.
3
2
2
1
5
9
2
.
3
8
3
4
0
5
.
8
6
2
.
5
0
-
2
7
.
7
4
2
1
7
4
9
.
8
7
E
n
d
D
i
r
:
2
4
7
7
8
.
3
7
'
M
D
,
7
8
6
8
.
3
2
'
T
V
D
26
2
5
2
6
5
.
7
4
9
1
.
0
2
9
.
8
6
7
8
5
9
.
6
1
2
2
0
7
2
.
4
7
3
4
8
9
.
2
8
0
.
0
0
0
.
0
0
2
2
2
3
5
.
4
2
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
5
2
6
5
.
7
4
'
M
D
,
7
8
5
9
.
6
1
'
T
V
D
27
2
5
4
2
6
.
7
4
8
7
.
0
0
9
.
9
0
7
8
6
2
.
3
8
2
2
2
3
1
.
0
3
3
5
1
6
.
8
9
2
.
5
0
1
7
9
.
3
9
2
2
3
9
5
.
8
0
E
n
d
D
i
r
:
2
5
4
2
6
.
7
4
'
M
D
,
7
8
6
2
.
3
8
'
T
V
D
28
2
5
7
7
6
.
7
4
8
7
.
0
0
9
.
9
0
7
8
8
0
.
7
0
2
2
5
7
5
.
3
5
3
5
7
6
.
9
8
0
.
0
0
0
.
0
0
2
2
7
4
4
.
0
9
M
P
U
F
-
3
4
A
w
p
0
6
t
g
t
1
1
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
5
7
7
6
.
7
4
'
M
D
,
7
8
8
0
.
7
'
T
V
D
29
2
6
3
4
3
.
0
2
8
3
.
8
2
2
3
.
7
4
7
9
2
6
.
2
2
2
3
1
1
4
.
3
0
3
7
3
9
.
7
6
2
.
5
0
1
0
3
.
4
7
2
3
3
0
6
.
7
2
E
n
d
D
i
r
:
2
6
3
4
3
.
0
2
'
M
D
,
7
9
2
6
.
2
2
'
T
V
D
30
2
6
3
9
3
.
8
9
8
3
.
8
2
2
3
.
7
4
7
9
3
1
.
7
0
2
3
1
6
0
.
6
0
3
7
6
0
.
1
2
0
.
0
0
0
.
0
0
2
3
3
5
6
.
6
6
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
6
3
9
3
.
8
9
'
M
D
,
7
9
3
1
.
7
'
T
V
D
3
1
2
6
5
4
5
.
8
4
8
7
.
2
0
2
2
.
0
0
7
9
4
3
.
5
9
2
3
3
0
0
.
1
5
3
8
1
8
.
9
8
2
.
5
0
-
2
7
.
2
7
2
3
5
0
6
.
5
8
E
n
d
D
i
r
:
2
6
5
4
5
.
8
4
'
M
D
,
7
9
4
3
.
5
9
'
T
V
D
32
2
7
4
9
5
.
8
4
8
7
.
2
0
2
2
.
0
0
7
9
9
0
.
0
0
2
4
1
7
9
.
9
2
4
1
7
4
.
4
3
0
.
0
0
0
.
0
0
2
4
4
4
7
.
7
6
M
P
F
-
3
4
A
w
p
0
5
T
g
t
9
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
7
4
9
5
.
8
4
'
M
D
,
7
9
9
0
'
T
V
D
33
2
7
6
1
9
.
9
4
8
7
.
4
4
1
8
.
9
0
7
9
9
5
.
8
0
2
4
2
9
6
.
0
6
4
2
1
7
.
7
5
2
.
5
0
-
8
5
.
6
2
2
4
5
7
1
.
0
9
E
n
d
D
i
r
:
2
7
6
1
9
.
9
4
'
M
D
,
7
9
9
5
.
8
'
T
V
D
34
2
8
5
2
0
.
1
2
8
7
.
4
4
1
8
.
9
0
8
0
3
6
.
0
0
2
5
1
4
6
.
8
4
4
5
0
9
.
0
9
0
.
0
0
0
.
0
0
2
5
4
6
7
.
9
5
M
P
F
-
3
4
A
w
p
0
5
T
g
t
1
0
S
t
a
r
t
D
i
r
2
.
5
º
/
1
0
0
'
:
2
8
5
2
0
.
1
2
'
M
D
,
8
0
3
6
'
T
V
D
35
2
8
5
3
2
.
0
9
8
7
.
7
4
1
8
.
9
1
8
0
3
6
.
5
0
2
5
1
5
8
.
1
6
4
5
1
2
.
9
6
2
.
5
0
0
.
4
3
2
5
4
7
9
.
8
7
E
n
d
D
i
r
:
2
8
5
3
2
.
0
9
'
M
D
,
8
0
3
6
.
5
'
T
V
D
36
2
9
9
2
1
.
6
2
8
7
.
7
4
1
8
.
9
1
8
0
9
1
.
3
0
2
6
4
7
1
.
7
0
4
9
6
2
.
8
3
0
.
0
0
0
.
0
0
2
6
8
6
4
.
5
8
M
P
F
-
3
4
A
w
p
0
5
T
o
e
T
o
t
a
l
D
e
p
t
h
:
2
9
9
2
1
.
6
2
'
M
D
,
8
0
9
1
.
3
'
T
V
D
SU
R
V
E
Y
P
R
O
G
R
A
M
Da
t
e
:
2
0
2
3
-
0
7
-
0
5
T
0
0
:
0
0
:
0
0
V
a
l
i
d
a
t
e
d
:
Y
e
s
V
e
r
s
i
o
n
:
De
p
t
h
F
r
o
m
D
e
p
t
h
T
o
Su
r
v
e
y
/
P
l
a
n
T
o
o
l
10
0
.
6
5
2
1
0
0
.
6
5
C
o
p
y
o
f
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
P
B
1
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
9
8
_
P
i
p
e
21
5
0
.
6
5
1
0
8
0
0
.
6
5
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
9
8
_
P
i
p
e
10
8
5
3
.
7
5
2
0
0
1
0
.
6
5
S
u
r
v
e
y
#
2
(
M
P
F
-
3
4
)
3
_
M
W
D
20
0
1
0
.
6
5
2
0
4
0
0
.
0
0
M
P
U
F
-
3
4
L
1
w
p
1
2
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
_
I
n
t
e
r
p
A
z
i
+
S
a
g
20
4
0
0
.
0
0
2
9
9
2
1
.
6
2
M
P
U
F
-
3
4
L
1
w
p
1
2
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
+
I
F
R
2
+
M
S
+
S
a
g
16800
17400
18000
18600
19200
19800
20400
21000
21600
22200
22800
23400
24000
24600
25200
25800
26400
27000
27600
28200
So
u
t
h
(
-
)
/
N
o
r
t
h
(
+
)
(
1
2
0
0
u
s
f
t
/
i
n
)
0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400
West(-)/East(+) (1200 usft/in)
MPF-34A wp05 Toe
MPF-34A wp05 Tgt10
MPF-34A wp05 Tgt9
MPF-34A wp05 Tgt8
MPF-34A wp05 Tgt7
MPF-34A wp05 Tgt6
MPF-34A wp05 Tgt5
MPF-34A wp05 Tgt4
MPF-34A wp05 Tgt3
MPF-34A wp05 Tgt2
MPF-34A wp05 Tgt1
MPU F-34A wp06 tgt11
765 3
MPF-34
7" TOW
4 1/2" x 6"
7750
8000
MPU F-34L1 wp12
KOP : Start Dir 12º/100' : 20010.65' MD, 7645.81'TVD : 30° RT TF
End Dir : 20027.65' MD, 7647.09' TVD
Start Dir 5º/100' : 20057.65' MD, 7648.9'TVD
End Dir : 20885.62' MD, 7701.57' TVD
Start Dir 5º/100' : 20916.45' MD, 7701.68'TVD
End Dir : 21476.1' MD, 7717.16' TVD
Start Dir 2.5º/100' : 21540.1' MD, 7720.4'TVD
End Dir : 21621.9' MD, 7723.08' TVD
Start Dir 2.5º/100' : 21914.36' MD, 7727.45'TVD
Start Dir 2.5º/100' : 22206.13' MD, 7741'TVD
End Dir : 22339.6' MD, 7751.84' TVD
Start Dir 2.5º/100' : 22589.34' MD, 7779.31'TVD
End Dir : 22726.79' MD, 7790.35' TVD
Start Dir 2.5º/100' : 22976.79' MD, 7803'TVD
End Dir : 23139.5' MD, 7805.47' TVD
Start Dir 2.5º/100' : 23477.86' MD, 7798.6'TVD
End Dir : 23616.59' MD, 7799.97' TVD
Start Dir 2.5º/100' : 23816.59' MD, 7808'TVD
End Dir : 23954.07' MD, 7817.62' TVD
Start Dir 2.5º/100' : 24266.64' MD, 7848.82'TVD
End Dir : 24412.16' MD, 7858.76' TVD
Start Dir 2.5º/100' : 24637.16' MD, 7867'TVD
End Dir : 24778.37' MD, 7868.32' TVD
Start Dir 2.5º/100' : 25265.74' MD, 7859.61'TVD
End Dir : 25426.74' MD, 7862.38' TVD
Start Dir 2.5º/100' : 25776.74' MD, 7880.7'TVD
End Dir : 26343.02' MD, 7926.22' TVD
Start Dir 2.5º/100' : 26393.89' MD, 7931.7'TVD
End Dir : 26545.84' MD, 7943.59' TVD
Start Dir 2.5º/100' : 27495.84' MD, 7990'TVD
End Dir : 27619.94' MD, 7995.8' TVD
Start Dir 2.5º/100' : 28520.12' MD, 8036'TVD
End Dir : 28532.09' MD, 8036.5' TVD
Total Depth : 29921.62' MD, 8091.3' TVD
CASING DETAILS
TVD TVDSS MD Size Name
7645.84 7600.14 20011.00 7 7" TOW
8091.30 8045.60 29921.62 4-1/2 4 1/2" x 6"
Project: Milne Point
Site: M Pt F Pad
Well: Plan: MPF-34
Wellbore: Plan: MPU F-34L1
Plan: MPU F-34L1 wp12
WELL DETAILS: Plan: MPF-34
Ground Level: 12.00
+N/-S +E/-W Northing Easting Latitude
Longitude
0.00 0.00
6035422.09 541813.48 70° 30' 27.6888 N 149° 39' 28.4176 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPF-34, True North
Vertical (TVD) Reference:MPU F-34A RKB @ 45.70usft
Measured Depth Reference:MPU F-34A RKB @ 45.70usft
Calculation Method:Minimum Curvature
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0DS6\VWHP
*HR'DWXP
3URMHFW
0DS=RQH
6\VWHP'DWXP 866WDWH3ODQH ([DFWVROXWLRQ
1$' 1$'&21&2186
0LOQH3RLQW$&70,/1(32,17
$ODVND=RQH
0HDQ6HD/HYHO
8VLQJ:HOO5HIHUHQFH3RLQW
8VLQJJHRGHWLFVFDOHIDFWRU
6LWH3RVLWLRQ
)URP
6LWH
/DWLWXGH
/RQJLWXGH
3RVLWLRQ8QFHUWDLQW\
1RUWKLQJ
(DVWLQJ
*ULG&RQYHUJHQFH
03W)3DG75
XVIW
0DS XVIW
XVIW
6ORW5DGLXV
1
:
:HOO
:HOO3RVLWLRQ
/RQJLWXGH
/DWLWXGH
(DVWLQJ
1RUWKLQJ
XVIW
(:
16
3RVLWLRQ8QFHUWDLQW\
XVIW
XVIW
XVIW*URXQG/HYHO
3ODQ 03)
XVIW
XVIW
:HOOKHDG(OHYDWLRQ XVIW
1
:
:HOOERUH
'HFOLQDWLRQ
)LHOG6WUHQJWK
Q7
6DPSOH'DWH 'LS$QJOH
3ODQ 038)/
0RGHO1DPH0DJQHWLFV
%**0
3KDVH 9HUVLRQ
$XGLW1RWHV
'HVLJQ 038)/ZS
3/$1
9HUWLFDO6HFWLRQ 'HSWK)URP 79'
XVIW
16
XVIW
'LUHFWLRQ
(:
XVIW
7LH2Q'HSWK
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
7RRO)DFH
16
XVIW
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
'RJOHJ
5DWH
XVIW
%XLOG
5DWH
XVIW
7XUQ
5DWH
XVIW
3ODQ6HFWLRQV
79'
6\VWHP
XVIW
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.23 6WDUW'LU
0'
79' 577)
72:
.83B$
(QG'LU
0'
79'
6WDUW'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
.83B$%
.83B$%
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
.83B$%
.83B$B%$6(
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$B%$6(
6WDUW'LU
0'
79'
.83B$%
(QG'LU
0'
79'
.83B$%
6WDUW'LU
0'
79'
(QG'LU
0'
79'
.83B$%
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.83B$%
7RWDO'HSWK
0'
79'
7DUJHW1DPH
KLWPLVVWDUJHW
6KDSH
79'
XVIW
1RUWKLQJ
XVIW
(DVWLQJ
XVIW
16
XVIW
(:
XVIW
7DUJHWV
'LS$QJOH
'LS'LU
038)$ZSWJW
SODQKLWVWDUJHWFHQWHU
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\ XVIWDWXVIW0' 79' 1 (
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\ XVIWDWXVIW0' 79' 1(
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDW XVIW0' 79' 1(
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDWXVIW0' 79'1 (
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDWXVIW0' 79' 1(
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDWXVIW0' 79'1 (
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDWXVIW0' 79' 1(
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\ XVIWDWXVIW0' 79'1 (
3RLQW
03)$ZS7RH
SODQKLWVWDUJHWFHQWHU
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDW XVIW0' 79'1 (
3RLQW
03)$ZS7JW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDWXVIW0' 79' 1(
3RLQW
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
0LOQH3RLQW
03W)3DG
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 03)
3ODQ 038)/
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
038)$5.%#XVIW
'HVLJQ 038)/ZS
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH 038)$5.%#XVIW
1RUWK5HIHUHQFH
:HOO3ODQ 03)
7UXH
9HUWLFDO
'HSWK
XVIW
0HDVXUHG
'HSWK
XVIW
&DVLQJ
'LDPHWHU
+ROH
'LDPHWHU
1DPH
&DVLQJ3RLQWV
[
72:
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
(:
XVIW
16
XVIW
/RFDO&RRUGLQDWHV
&RPPHQW
3ODQ$QQRWDWLRQV
.23 6WDUW'LU
0'
79' 577)
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
6WDUW'LU
0'
79'
(QG'LU
0'
79'
7RWDO'HSWK
0'
79'
30 &203$66%XLOG (3DJH
&O
H
D
U
D
Q
F
H
6
X
P
P
D
U
\
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
2
F
W
R
E
H
U
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
0L
O
Q
H
3
R
L
Q
W
0
3
W
)
3
D
G
3O
D
Q
0
3
)
3O
D
Q
0
3
8
)
/
03
8
)
/
Z
S
5H
I
H
U
H
Q
F
H
'
H
V
L
J
Q
0
3
W
)
3
D
G
3
O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
&O
R
V
H
V
W
$
S
S
U
R
D
F
K
'
3
U
R
[
L
P
L
W
\
6
F
D
Q
R
Q
&
X
U
U
H
Q
W
6
X
U
Y
H
\
'
D
W
D
+
L
J
K
VL
G
H
5
H
I
H
U
H
Q
F
H
:H
O
O
&
R
R
U
G
L
Q
D
W
H
V
1
(
1
:
'D
W
X
P
+
H
L
J
K
W
0
3
8
)
$
5
.
%
#
X
V
I
W
6F
D
Q
5
D
Q
J
H
W
R
X
V
I
W
0
H
D
V
X
U
H
G
'
H
S
W
K
*H
R
G
H
W
L
F
6
F
D
O
H
)
D
F
W
R
U
$
S
S
O
L
H
G
9H
U
V
L
R
Q
%
X
L
O
G
(
6F
D
Q
5
D
G
L
X
V
L
V
8
Q
O
L
P
L
W
H
G
&
O
H
D
U
D
Q
F
H
)
D
F
W
R
U
F
X
W
R
I
I
L
V
8
Q
O
L
P
L
W
H
G
0
D
[
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
L
V
X
V
I
W
*/
2
%
$
/
)
,
/
7
(
5
$
3
3
/
,
(
'
$
O
O
Z
H
O
O
S
D
W
K
V
Z
L
W
K
L
Q
R
I
U
HI
H
U
H
Q
F
H
6F
D
Q
7
\
S
H
6F
D
Q
7
\
S
H
0L
O
Q
H
3
R
L
Q
W
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
I
R
U
3
O
D
Q
0
3
)
0
3
8
)
/
Z
S
&R
P
S
D
U
L
V
R
Q
:
H
O
O
1
D
P
H
:
H
O
O
E
R
U
H
1
D
P
H
'
H
V
L
J
Q
#0
H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
0L
Q
L
P
X
P
'L
V
W
D
Q
F
H
X
V
I
W
(O
O
L
S
V
H
6H
S
D
U
D
W
L
R
Q
X
V
I
W
#0
H
D
V
X
U
H
G
'H
S
W
K
XV
I
W
&O
H
D
U
D
Q
F
H
)D
F
W
R
U
6F
D
Q
5
D
G
L
X
V
L
V
8
Q
O
L
P
L
W
H
G
&
O
H
D
U
D
Q
F
H
)
D
F
W
R
U
F
X
W
R
I
I
L
V
8
Q
O
L
P
L
W
H
G
0
D
[
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
L
V
X
V
I
W
6L
W
H
1
D
P
H
6F
D
Q
5
D
Q
J
H
W
R
X
V
I
W
0
H
D
V
X
U
H
G
'
H
S
W
K
&O
R
V
H
V
W
$
S
S
U
R
D
F
K
'
3
U
R
[
L
P
L
W
\
6
F
D
Q
R
Q
&
X
U
U
H
Q
W
6
X
U
Y
H
\
'
D
W
D
+
L
J
K
VL
G
H
5
H
I
H
U
H
Q
F
H
5H
I
H
U
H
Q
F
H
'
H
V
L
J
Q
0
3
W
)
3
D
G
3
O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
0H
D
V
X
U
H
G
'H
S
W
K
X
V
I
W
6X
P
P
D
U
\
%
D
V
H
G
R
Q
0L
Q
L
P
X
P
6H
S
D
U
D
W
L
R
Q
:
D
U
Q
L
Q
J
0
3
W
)
3
D
G
03
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&H
Q
W
U
H
'
L
V
W
D
Q
F
H
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
/
0
3
8
)
/
Z
S
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
&H
Q
W
U
H
'
L
V
W
D
Q
F
H
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
(O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
3
D
V
V
3O
D
Q
0
3
)
3
O
D
Q
0
3
8
)
$
0
3
8
)
$
Z
S
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
3O
D
Q
0
3
)
0
3
)
0
3
)
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
3
D
V
V
6X
U
Y
H
\
W
R
R
O
S
U
R
J
U
D
P
)U
R
P
X
V
I
W
7R
X
V
I
W
6X
U
Y
H
\
3
O
D
Q
6
X
U
Y
H
\
7
R
R
O
B
*
\
U
R
&
7
B
S
U
H
B
3
L
S
H
B
*
\
U
R
&
7
B
S
U
H
B
3
L
S
H
B
0
:
'
0
3
8
)
/
Z
S
B
0
:
'
B
,
Q
W
H
U
S
$
]
L
6
D
J
0
3
8
)
/
Z
S
B
0
:
'
,
)
5
0
6
6
D
J
2
F
W
R
E
H
U
&2
0
3
$
6
6
3D
J
H
R
I
0L
O
Q
H
3
R
L
Q
W
+L
O
F
R
U
S
$
O
D
V
N
D
/
/
&
$Q
W
L
F
R
O
O
L
V
L
R
Q
5
H
S
R
U
W
I
R
U
3
O
D
Q
0
3
)
0
3
8
)
/
Z
S
(O
O
L
S
V
H
H
U
U
R
U
W
H
U
P
V
D
U
H
F
R
U
U
H
O
D
W
H
G
D
F
U
R
V
V
V
X
U
Y
H
\
W
R
R
O
W
L
H
R
Q
S
R
LQ
W
V
6H
S
D
U
D
W
L
R
Q
L
V
W
K
H
D
F
W
X
D
O
G
L
V
W
D
Q
F
H
E
H
W
Z
H
H
Q
H
O
O
L
S
V
R
L
G
V
&D
O
F
X
O
D
W
H
G
H
O
O
L
S
V
H
V
L
Q
F
R
U
S
R
U
D
W
H
V
X
U
I
D
F
H
H
U
U
R
U
V
&O
H
D
U
D
Q
F
H
)
D
F
W
R
U
'
L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
3
U
R
I
L
O
H
V
'
L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
3
U
R
I
L
O
H
V
(
O
O
L
S
V
H
6
H
S
D
U
D
W
L
R
Q
'L
V
W
D
Q
F
H
%
H
W
Z
H
H
Q
F
H
Q
W
U
H
V
L
V
W
K
H
V
W
U
D
L
J
K
W
O
L
Q
H
G
L
V
W
D
Q
F
H
E
H
W
Z
H
H
Q
ZH
O
O
E
R
U
H
F
H
Q
W
U
H
V
$O
O
V
W
D
W
L
R
Q
F
R
R
U
G
L
Q
D
W
H
V
Z
H
U
H
F
D
O
F
X
O
D
W
H
G
X
V
L
Q
J
W
K
H
0
L
Q
L
P
X
P
&
X
U
Y
D
WX
U
H
P
H
W
K
R
G
2
F
W
R
E
H
U
&2
0
3
$
6
6
3D
J
H
R
I
0.
0
0
1.
0
0
2.
0
0
3.
0
0
4.
0
0
Separation Factor
20
4
7
5
2
1
0
0
0
2
1
5
2
5
2
2
0
5
0
2
2
5
7
5
2
3
1
0
0
2
3
6
2
5
2
4
1
5
0
2
4
6
7
5
2
5
2
0
0
2
5
7
2
5
2
6
2
5
0
2
6
7
7
5
2
7
3
0
0
2
7
8
2
5
2
8
3
5
0
2
8
8
7
5
2
9
4
0
0
2
9
9
2
5
Me
a
s
u
r
e
d
D
e
p
t
h
(
1
0
5
0
u
s
f
t
/
i
n
)
MP
F
-
1
7
MP
U
F
-
1
7
L
1
w
p
1
2
MP
U
F
-
9
2
A
w
p
0
1
MP
F
-
3
4
No
-
G
o
Z
o
n
e
-
S
t
o
p
D
r
i
l
l
i
n
g
Co
l
l
i
s
i
o
n
A
v
o
i
d
a
n
c
e
R
e
q
u
i
r
e
d
Co
l
l
i
s
i
o
n
R
i
s
k
P
r
o
c
e
d
u
r
e
s
R
e
q
.
WE
L
L
D
E
T
A
I
L
S
:
P
l
a
n
:
M
P
F
-
3
4
N
A
D
1
9
2
7
(
N
A
D
C
O
N
C
O
N
U
S
)
Al
a
s
k
a
Z
o
n
e
0
4
Gr
o
u
n
d
L
e
v
e
l
:
1
2
.
0
0
+N
/
-
S
+
E
/
-
W
N
o
r
t
h
i
n
g
E
a
s
t
i
n
g
La
t
i
t
u
d
e
Lo
n
g
i
t
u
d
e
0.
0
0
0.
0
0
60
3
5
4
2
2
.
0
9
54
1
8
1
3
.
4
8
70
°
3
0
'
2
7
.
6
8
8
8
N
14
9
°
3
9
'
2
8
.
4
1
7
6
W
RE
F
E
R
E
N
C
E
I
N
F
O
R
M
A
T
I
O
N
Co
-
o
r
d
i
n
a
t
e
(
N
/
E
)
R
e
f
e
r
e
n
c
e
:
We
l
l
P
l
a
n
:
M
P
F
-
3
4
,
T
r
u
e
N
o
r
t
h
Ve
r
t
i
c
a
l
(
T
V
D
)
R
e
f
e
r
e
n
c
e
:
MP
U
F
-
3
4
A
R
K
B
@
4
5
.
7
0
u
s
f
t
Me
a
s
u
r
e
d
D
e
p
t
h
R
e
f
e
r
e
n
c
e
:
MP
U
F
-
3
4
A
R
K
B
@
4
5
.
7
0
u
s
f
t
Ca
l
c
u
l
a
t
i
o
n
M
e
t
h
o
d
:
Mi
n
i
m
u
m
C
u
r
v
a
t
u
r
e
SU
R
V
E
Y
P
R
O
G
R
A
M
Da
t
e
:
2
0
2
3
-
0
7
-
0
5
T
0
0
:
0
0
:
0
0
V
a
l
i
d
a
t
e
d
:
Y
e
s
V
e
r
s
i
o
n
:
De
p
t
h
F
r
o
m
D
e
p
t
h
T
o
S
u
r
v
e
y
/
P
l
a
n
To
o
l
10
0
.
6
5
2
1
0
0
.
6
5
C
o
p
y
o
f
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
P
B
1
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
98
_
P
i
p
e
21
5
0
.
6
5
1
0
8
0
0
.
6
5
S
u
r
v
e
y
#
1
(
M
P
F
-
3
4
)
3
_
G
y
r
o
-
C
T
_
p
r
e
-
1
9
98
_
P
i
p
e
10
8
5
3
.
7
5
2
0
0
1
0
.
6
5
S
u
r
v
e
y
#
2
(
M
P
F
-
3
4
)
3
_
M
W
D
20
0
1
0
.
6
5
2
0
4
0
0
.
0
0
M
P
U
F
-
3
4
L
1
w
p
1
2
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
_
I
n
t
e
r
p
A
z
i
+
S
a
g
20
4
0
0
.
0
0
2
9
9
2
1
.
6
2
M
P
U
F
-
3
4
L
1
w
p
1
2
(
P
l
a
n
:
M
P
U
F
-
3
4
L
1
)
3
_
M
W
D
+
I
F
R
2
+
M
S
+
S
a
g
0.
0
0
30
.
0
0
60
.
0
0
90
.
0
0
12
0
.
0
0
15
0
.
0
0
18
0
.
0
0
Centre to Centre Separation (60.00 usft/in)
20
4
7
5
2
1
0
0
0
2
1
5
2
5
2
2
0
5
0
2
2
5
7
5
2
3
1
0
0
2
3
6
2
5
2
4
1
5
0
2
4
6
7
5
2
5
2
0
0
2
5
7
2
5
2
6
2
5
0
2
6
7
7
5
2
7
3
0
0
2
7
8
2
5
2
8
3
5
0
2
8
8
7
5
2
9
4
0
0
2
9
9
2
5
Me
a
s
u
r
e
d
D
e
p
t
h
(
1
0
5
0
u
s
f
t
/
i
n
)
GL
O
B
A
L
F
I
L
T
E
R
A
P
P
L
I
E
D
:
A
l
l
w
e
l
l
p
a
t
h
s
w
i
t
h
i
n
2
0
0
'
+
1
0
0
/
1
0
0
0
o
f
r
e
f
e
r
e
n
c
e
20
0
1
0
.
6
5
T
o
2
9
9
2
1
.
6
2
Pr
o
j
e
c
t
:
M
i
l
n
e
P
o
i
n
t
Si
t
e
:
M
P
t
F
P
a
d
We
l
l
:
P
l
a
n
:
M
P
F
-
3
4
We
l
l
b
o
r
e
:
P
l
a
n
:
M
P
U
F
-
3
4
L
1
Pl
a
n
:
M
P
U
F
-
3
4
L
1
w
p
1
2
CA
S
I
N
G
D
E
T
A
I
L
S
TV
D
T
V
D
S
S
M
D
S
i
z
e
N
a
m
e
76
4
5
.
8
4
7
6
0
0
.
1
4
2
0
0
1
1
.
0
0
7
7
"
T
O
W
80
9
1
.
3
0
8
0
4
5
.
6
0
2
9
9
2
1
.
6
2
4
-
1
/
2
4
1
/
2
"
x
6
"
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.
KUPARUK RIVER OIL POOL
MILNE POINT, UNDEFINED OIL POOL
223-107
MPU F-34L1
X
MILNE POINT
W
E
L
L
P
E
R
M
I
T
C
H
E
C
K
L
I
S
T
Co
m
p
a
n
y
Hi
l
c
o
r
p
A
l
a
s
k
a
,
L
L
C
We
l
l
N
a
m
e
:
MI
L
N
E
P
T
U
N
I
T
F
-
3
4
L
1
In
i
t
i
a
l
C
l
a
s
s
/
T
y
p
e
DE
V
/
P
E
N
D
Ge
o
A
r
e
a
89
0
Un
i
t
11
3
2
8
On
/
O
f
f
S
h
o
r
e
On
Pr
o
g
r
a
m
DE
V
Fi
e
l
d
&
P
o
o
l
We
l
l
b
o
r
e
s
e
g
An
n
u
l
a
r
D
i
s
p
o
s
a
l
PT
D
#
:
22
3
1
0
7
0
MI
L
N
E
P
O
I
N
T
,
K
U
P
A
R
U
K
R
I
V
E
R
O
I
L
-
5
2
5
1
0
0
M
I
L
N
E
P
O
I
N
T
,
U
N
D
E
F
I
N
E
D
O
NA
1
P
e
r
m
i
t
f
e
e
a
t
t
a
c
h
e
d
Ye
s
AD
L
0
2
5
5
0
9
,
A
D
L
3
5
5
0
1
8
,
A
D
L
3
5
5
0
1
6
,
A
D
L
3
9
4
1
6
7
2
L
e
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
U
n
i
q
u
e
w
e
l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
S
e
e
C
o
m
m
e
n
t
s
b
e
l
o
w
.
M
I
L
N
E
P
O
I
N
T
,
K
U
P
A
R
U
K
R
I
V
E
R
O
I
L
-
5
2
5
1
0
0
-
g
o
v
e
r
n
e
d
b
y
4
3
2
E
4
W
e
l
l
l
o
c
a
t
e
d
i
n
a
d
e
f
i
n
e
d
p
o
o
l
Ye
s
T
D
e
x
t
e
n
d
s
o
u
t
s
i
d
e
o
f
M
i
l
n
e
P
o
i
n
t
U
n
i
t
b
u
t
s
t
a
y
s
w
i
t
h
i
n
5
0
0
'
o
f
H
i
l
c
o
r
p
l
e
a
s
e
b
o
u
n
d
a
r
i
e
s
5
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
S
u
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
I
f
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
O
p
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
O
p
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
P
e
n
d
i
n
g
e
x
p
a
n
s
i
o
n
o
f
K
u
p
a
r
u
k
R
i
v
e
r
O
i
l
P
o
o
l
(
C
O
-
2
3
-
0
1
4
)
.
U
n
d
e
r
s
t
a
t
e
r
u
l
e
s
f
o
r
p
o
r
t
i
o
n
o
u
t
s
i
d
e
p
o
o
l
11
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
C
a
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
NA
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
NA
15
A
l
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
16
P
r
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
18
C
o
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
19
S
u
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
20
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
21
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
Ye
s
P
a
r
e
n
t
w
e
l
l
h
a
s
a
d
e
q
u
a
t
e
c
e
m
e
n
t
a
t
s
u
r
f
a
c
e
c
a
s
i
n
g
a
n
d
c
e
m
e
n
t
t
o
p
r
o
d
u
c
t
i
o
n
z
o
n
e
.
22
C
M
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
T
h
i
s
w
e
l
l
i
s
a
n
i
n
z
o
n
e
r
o
t
a
r
y
s
i
d
e
t
r
a
c
k
f
r
o
m
a
n
e
x
i
s
t
i
n
g
w
e
l
l
b
o
r
e
w
i
t
h
p
r
s
s
u
r
e
i
n
t
e
g
r
i
t
y
23
C
a
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
D
o
y
o
n
1
4
h
a
s
a
d
q
u
a
t
e
t
a
n
k
a
g
e
a
n
d
g
o
o
d
t
r
u
c
k
i
n
g
s
u
p
p
o
r
t
.
24
A
d
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
T
h
i
s
w
i
l
l
b
e
a
n
a
d
d
i
t
i
o
n
a
l
l
a
t
e
r
a
l
25
I
f
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
H
a
l
l
i
b
u
r
t
o
n
c
o
l
l
s
i
o
n
s
c
a
n
i
d
e
n
t
i
f
i
e
s
n
o
c
l
o
s
e
a
p
p
r
o
a
c
h
e
s
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
N
o
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
o
n
t
h
i
s
w
e
l
l
27
I
f
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
A
l
l
f
l
u
i
d
s
w
i
l
l
b
e
o
v
e
r
b
a
l
a
n
c
e
t
o
p
o
r
e
p
r
e
s
s
u
r
e
.
28
D
r
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
1
a
n
n
u
l
a
r
,
3
r
a
m
,
1
f
l
o
w
c
r
o
s
s
s
29
B
O
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
5
0
0
0
p
s
i
s
t
a
c
k
t
e
s
t
e
d
t
o
4
0
0
0
p
s
i
i
n
t
i
a
l
t
e
s
t
30
B
O
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
C
h
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
No
M
a
x
i
m
u
m
H
2
S
r
e
a
d
i
n
g
o
n
M
P
U
F
p
a
d
i
s
4
7
p
p
m
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
T
h
i
s
w
e
l
l
i
s
a
p
r
o
d
u
c
e
r
.
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
H
2
S
m
e
a
s
u
r
e
s
r
e
q
u
i
r
e
d
.
F
-
6
9
r
e
c
o
r
d
e
d
s
a
m
p
l
e
w
i
t
h
4
7
p
p
m
.
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
E
x
p
e
c
t
e
d
p
o
r
e
p
r
e
s
s
u
r
e
o
f
K
u
p
a
r
u
k
A
r
e
s
e
r
v
o
i
r
i
s
5
.
7
p
p
g
E
M
W
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
11
/
1
6
/
2
0
2
3
Ap
p
r
MG
R
Da
t
e
11
/
1
7
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
11
/
1
6
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
TD
e
x
t
e
n
d
s
o
u
t
s
i
d
e
o
f
M
P
U
a
n
d
K
u
p
a
r
u
k
R
i
v
e
r
O
i
l
P
o
o
l
b
o
u
n
d
a
r
i
e
s
.
H
i
l
c
o
r
p
w
i
l
l
b
e
d
r
i
l
l
i
n
g
t
h
i
s
p
o
r
t
i
o
n
o
f
t
h
e
w
e
l
l
t
o
s
t
a
t
e
r
u
l
es
.
JL
C
1
1
/
2
1
/
2
0
2
3
