Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout219-086O
LCLW
w
W
U
Z
^J
LL 01
2�
0 O
a
V r
J
Q
F—
F-
2
—
F-
2
W
Q
L
Q
0
m
U
r
z
K
Y
7
Q
a
Y
0
z
E
z
3
N
m
O
E
U
O
J
zl
E
m
N
z
0
a
c
m
c
mm
m
m
m
2
m
E❑
m
m
m
B
N
m
Z •�_
m
rn
m
rn
m
�_
m
❑
m
�
m
y
m
m
m
m
m
m
-o+ ¢
U N E O
Z
E
C
v m= Z,
O
t
O
W z
F
'n
E
❑
i
❑
E
m ¢
E
E
m
LL_
O
m
E
o a
Ud
rn
v
U
m
m
0
J
R
❑
N
EP
J W
O
J
3
❑ ~
3 m
❑
❑
C
6
❑
C
NN
❑
T
T
C
❑
❑
❑
❑
O
M
M
m
M
M
6
M
❑
❑
d
y
M
M
M
M
MM
J J
LL
LL
Z
Z
m
C
lL
C
lL
fi
U)
C
IL
C
IL
f/J
V%
'
V%
w
N
N
Y
O.
IL LL
M
th
t+�
M
M
M
M
0
0
M
l7
th
M
M
Y
M
fel
E E
i
i
f
H
c
>
j
H
UI
g❑❑
O
N
i0
i0
N
H
W
W
IL
LL
co
N
U
OI
N N
m
J
J
J
J
J
J
J
J
J
J
J
J
=
U
J
J J
U
U
rn—
rn
rn
rn
rn
rn
rn
rn
rn
rn
L)
L)
C-)
L)
0
0
0
u
6
L
C-)
6
--
05
Q
❑❑
❑
❑
❑
❑
❑
❑
❑
N
❑
❑
❑
� N
❑
O
❑
W
W
W
W
W
W
W
W
W
W_
W
W
N O
IL
lL
IL
IL
IL
lL
IL
IL
IL
IL
IL
IL
IL Is
LL 6
LL
LL ll
E o
u
v
g
o
v
v
v
u
R
v
E'c
c>
'c `�
c
c 'S<
c
'c
'c
2
c
'c
c
'c 'c
2
e
e
e
Q
Q
2
2
Q
e
e,�
e
Q
2
a
e e
U fn
U
U
U
U
U
U
V M
U M
U
U
U
O
U
U
U U
N W
d
d
d
d
d
d
0l
W
W
N
N
N
N
N
N N
W LL'
W
W
W
W
W
W
W
i
W
W
W
W
W
W W
a m
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn
rn rn
j 0
0
0
0
0
0
0
0
0
0
O
0
a
0
O
0
a 0
� N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N N
N
l\r
t`
M
M
Mn
l` M
n
r
n
n n
c
m
c
mm
m
m
m
2
m
E❑
m
m
m
B
N
m
Z •�_
m
m
m
rn
m
�_
m
❑
m
�
m
y
m
m
m
m
m
m
❑
U N E O
Z
d
C
v m= Z,
O
t
O
W z
F
'n
E
❑
i
❑
E
R
LL
O
O
LL_
O
m
E
o a
z
rn
v
U
m
m
0
J
R
N
O
J W
O
J
3
❑ ~
c
m
c
mm
m
m
m
2
m
m
m
m
m
B
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
m
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
R
A
R
—
—
m
m
m
m
m—
A
m
m
m
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
M
M
m
M
M
M
M
M
M
M
M
M
M
M
MM
M
yM
M
th
t+�
M
M
M
M
M
M
M
l7
th
M
M
M
M
fel
U
U
U
U
U
U
U
U
U
U
U
U
U
U
U
U
U
U
O
Q
❑❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
❑
O
❑
W
W
W
W
W
W
W
W
W
W_
W
W
W
W
W
W
W
N
C
E
E
0
U
E
z
O
N
N N
rn Q
L
U
0
0
L
a �
0 B
0 @
U J
`U�
`�J
Z
c
_❑
rn
0
�
IL
�
1/
@
@
rn
@
E
@
A
N
N @
rn n
� E
C
J
O
O
z
M r
v
U
O
M
z
w
o
n
n
>
m
N
U
N
ry
C
W
❑
❑
❑
❑
rn
=
o
N
z
z
z
z
n
N
O K
Hm
V
❑°
c
❑
f
G
Q O
C
F
Q
z
N
Z
U
6
z
W
W
W
W
d
Q
o
m
O
rn
rn
rn
rn
(9
0
0 m
O
a
a
ui
ui
ui
ui
ti
LL
lL
IL
IL
IL
J
c
m
E
a
mm❑ w
Q
Q
65,
v
w
v
co❑
rn W
A
°o'
S
a°i
a0i
a°i
H
W
N
W
W
Wm
N=
OQ
O
U
rn
rn
rn
rn
rn
d
a
N
N
N
N
N
W
tr
a
r
m
r
ao
r
ao
r
m
0
W
O
U
C
J
q
Z
g
J
a
m
a�
O
G O
O N
m
n
U
r
QO
F-
r_
°
C
z
=
N
C
m
J
�
m
o
Y
N
Q
@
Q
a
Y
❑
c
ID
Q
0
E
U
c
c
E
m
@
z
�
3
D
O
D
O
c
o
�
o
0
0
0
�
m
E
�
N
E
_
r
M
10
N
O
�
N
o
m
U
U
U
U
U
c
E
v
p
o
m
w
w
w
m
a
w
W
3
N
C
E
E
0
U
E
z
w
E
0
0
I
N
N N
rn Q
L
U
0
0
L
a �
0 B
0 @
U J
`U�
`�J
Z
c
_❑
rn
0
�
IL
�
1/
@
@
rn
@
E
@
A
N
N @
rn n
� E
C
J
YppN y
n °
C
U U
w
E
0
0
rn rn
N N
z
M r
w
o
>
m
0
N
C
=
o
d
n
@
O K
Hm
V
❑°
c
i
G
Q O
C
Q
O_ ❑
U
6
O
a
O
f
d
E
E
o
O
E
0 0
Z
U
0.
(9
0
0 m
w
E
0
0
M
m
c
v
L
0
O
0
O
b
A
a
M
o
Z
N
o+
0
U
7
0
N
O
V
Q
lv
L
J
v
d
c
N
�
m
d
m
Li
m
y
0
a
U
d
a
W
=_
a
W
0
U
0
♦ ♦
V
C
U
J
O
`o
Q
N
N
J
d
a
0
�
CL
0
o
ON
N
n
Uo
r
E
U
r
Q�
F
rn
2
�
0
N
O
a
Y
Q
Q
o
?
E
o
U
d
z
m
�
o
m
o
F
CO
a
rn
3
N
d
O
�
d
U
O
e
d
2
E
o
0
m
a
o
�
v
M
m
c
v
L
0
Date:
BAtUGHES August 12, 2019
BAT
GE company
Abby Bell
AOGCC
333 West 7`^ Ave, Suite 100
Anchorage, Alaska 99501
219086
31092
Letter of Transmittal
Harvey Finch
Baker Hughes, a GE Company
795 East 941^ Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
1J-IOL1PB2
IC -19L1
1R-101
RECEIVED
AUG 13 2019
aoGCC
(3) Total print
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27
)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Harvey Finch, Baker Hughes, Wellplanner
Harvey.Finch@BakerHughes.com
N
p
0)
rn o
N M
IRI
i
L
Q
i
v
Cv�(
NCL
I.L
�.
it
'—
-
Cl)
giCL
a
D
-D
o
�
as
v
O
d
d
0
`C
=
?
U
v
++
L
Q
Y
Y
N
L
a
C
N
N
UC
p
CL
CL
c
W
U
Y
Y
Lo
m
■
�«�
}\\
{§
;Z5
)\)
$!§
kGGl20
ik}(
�)t
))
k)$)
§
!!\
CL
�
!
§
k
o
K\
«64■]
:
�/
!r|!f
a
,6
,
-
,/
/
/
kk()0!
|
)!CN!
)
|
�
■
-
EL
_
E
wr
§\-77
_
=
Y���
2
{
a
!
§
[
\£
�)t§
T t0 OI O V N
2= N N N N N N N N b b 1p N tO b b b b b b tO tO 10 ID N W b 10 N N
V
m
Ih b 0
m C
NTS 101
b
P r
10
10
N N
�
E
H
O P9
Q
h YI VMI �.
pp
N
pp
N
N N
YNl N
N MNI
N
N N N_
N N
N_ N
N N N
N v01
O�
IO b
f0
f0 l0 tU b
b b
[O
�O T
10 10
tD 10
b
�O f0
1O t0
IO b
lmm0 f0 b
10 t[I
O
�IpD
pN
W
O
fp
W
P
1p
aV pN W Iy
�+PI. Iy.
m
N (V. m
b P
� OpI
p
1p0 yp pM
pN p
pC
Oi O1
TN
pI N
N
J
Y'
N
F ��„
N I
N b
N
�U
b IO
N Iti b ID
f0 LL1
lU b
b
IO
(O,. f0
IO b b
10 i0
10 b
b i0
N b
(O
N
l0, lO t0
b b b
10 IOO.
10 10
�O
W b
b IU IO
N lV
V
W
Z
m'
m_ n
n I"n ro
m in
m
ro
^. m
m m m
m_
zz
8 O� O�
z==
O�
f7 (� O O
O
O h
O f� 0O
O
O h
y O
(7
O U' �
(� U'
U' N
u zN3
b3
3
5
3
3 �S
�5 3
3
3
p p� tp
-
p
m
V
r ???
�p yI
b b
0 0 0 0
0
0 0
0 0 0
0 0
0 0
0 0
0 0
0 0
0 0 0
0 0
0 0
N
m
T 10
m
M M
1
NI
m m
gVVgmg�gpq�
�����gp
9
W
g��pgg
=
1.I
N
N IbV tNV ry
IPv N
N
(V ITV
M
M M
Irv�l
cMI t�i
In�I ln'I
fb�l 1�
Q
p��g
��pp�g�g
m��pp�gg
U
pg�
L
0
;I
1p
T
N
q
NO
pp
01 N
N
0 lV
ryry
N
��pp
CI
m
m m
�p p�
m O NP
tr1
N C'
N N
01
01
IVJ
L � N
rtS
N
OPi
N N
N
N 10
10
b 10
b IG
10
CT1
N b
10 b
b N lU
10 10
IU 10
J
T
T
p,
O
ryry
pp
O ��
N
1p
N S
tp (V
pI
N
1V
m
P OI
uu11
N
�p m
�9 N
p
N N N
lV
W
W
>
N
b
b N,
C
q O INV N
N
(O
N
b l4 m
A r
N
V
a) V
m
Or O
V O
O 0
p
I+i
p
VI
j (J
O
O
W
1� (�
WE
J O
N
m M CN, M�
pm
O
0
P 17 Cl
� OI
P
N
ONi 01
OI N
T m m
T OI
V
Y
n
r
J
0 e
CL
T
b
T
o
a
—
OV
E
O
U
m
n 0
N
rry
8
N
p
T 1Tp P
N
W M
M
N
�n
p
tO r
yy�
U) m
C N
N
N N T
M m Q
P
P C
N <_
V1 h
N
u] N 10
tPV10
b
P n
t
N
O)
i
O
6 INV
AMI
IV
P
N N N IV.
lrv'1
1'Im
< P Q
53
Y) h
���QQ
r
n
OTi
r
6
01
a
m
d
O
p
U u
1
O
Q
N� O O
ry
Op
Op N
tnl Cl
P Wp
O
b
W
IW1 N
n
0
A
"
�O1pp�
C P
y
� m
�
m
f
T
K
L
� dCW Of �
N
A N OI Q
Q
N P�
N N
OI T
P S
N O1
OI T OI
A
OI
Q
� Hd
O
Z N N
N
N N N N
N
N N
N N N
VI N
N VI
N N
N N
N N
VI N N
N N
VN ul
V
N c
ti
d
d
R
u
"C
U_
O
d
b
d
T
IIpp
O
N
NO�Q n m N
NTP
C p Np
N
0�pp �pp
INN
m fpp
p r O
��4 0
00 N
m �p
m
y O�
N N
r 4
W
.G
o
Y- m TCNI
�
pNp�I
��p o
M
Q
p
L
O
Z
19
W
W M M
M M P<
P P
<<
V P
P 4
P V
V P
V P
O
4 4
T t0 OI O V N
2= N N N N N N N N b b 1p N tO b b b b b b tO tO 10 ID N W b 10 N N
V
m
Ih b 0
m C
NTS 101
b
P r
10
10
N N
O N
H
O P9
Q
h YI VMI �.
pp
N
pp
N
N N
YNl N
N MNI
N
N N N_
N N
N_ N
N N N
N v01
O�
IO b
f0
f0 l0 tU b
b b
[O
�O T
10 10
tD 10
b
�O f0
1O t0
IO b
lmm0 f0 b
10 t[I
�IpD
pN
fp
W
P
1p
aV pN W Iy
�+PI. Iy.
m
N (V. m
b P
� OpI
p
1p0 yp pM
pN p
pC
Oi O1
TN
pI N
N
J
Y'
N
F ��„
N I
N b
N
�U
b IO
N Iti b ID
f0 LL1
lU b
b
IO
(O,. f0
IO b b
10 i0
10 b
b i0
N b
(O
N
l0, lO t0
b b b
10 IOO.
10 10
�O
W b
b IU IO
N
t0 N
V
C
W
p p� tp
p
m
V
p V�
�p yI
b b
Q ry
q p
S O Op
N N
a
'j�
N
m
T 10
m
M M
1
NI
m m
J
9
W
=
1.I
N
N IbV tNV ry
IPv N
N
(V ITV
M
M M
Irv�l
cMI t�i
In�I ln'I
fb�l 1�
Q
U
c
a
¢
Y
/�
Q
O
21p
2�p T
J
T
T
p,
O
ryry
pp
O ��
N
1p
N S
tp (V
pI
N
1V
m
P OI
uu11
N
�p m
�9 N
p
N N N
lV
10
N
V
tPV
1p
N m
OI
p
N
Mi
N
M
p
O?
j (J
^'
L
1� (�
p
P
YI N lT0 m
m OI
pm
O
N OI T
m m
T N
T OI T
ONi 01
OI N
T m m
T OI
V
Y
Y
CL
OV
n 0
0
0 N l7 N
p
O O
N
p
T 1Tp P
N
W M
N
r m 1N0
rp 1p
p
tO r
b A
NV
U) m
(�
4
NN
tPV10
V m P
VbI
P n
t
N
O)
N N N IV.
lrv'1
1'Im
< P Q
53
Y) h
r
n
OTi
6
01
a
m
d
d
6
Z j t0 N b b N m tU 0 ID �U �O t0 0 t0 1U N 10 A A^ n n n n A^^^ n n r
i
m o r
P O O V O P P Q v v v 4 4 4 v a P 4 a b
r
m
E
mm
mm Nm
m$
o m w v
m
m io
o ci
mp �mmn
0
e
yy pmp
m
mm
mNmmm
p m
mm
N
mn m
GI N N
N Cl
1n�
N
im N
qoq
N�
p
h
j
y
N
d
O
a
3
_
G
N �O
�
00
d
u
N Yl
g m
IA
3 5
5 5 5
5 0
5 0
3
3 5
3
5 5 5 0 5
3 0
5 5
5 5
0 5 3 5
5
0
3
�^ O O
O O O
O O
O O
O
O O
O
O O O
O, O
O O
O O
O O
O O O O
O
O
O
pj
ps pr
p5
p
O t�
N^
CN)
N mp
0
INO O
N
N b b N b
O
OmH
O m
N
byp m n
N
N
^
�p
td
n
i
0 m
p
m
m T N T O
p
O N.
m
o
m^
f
8i
al
i V x�
(O
m
n n
n
n
An
A
m
m N
N
J
c5
-
-
d
> N
M - -
- T
M
•-•
Cl
a7
ImV
(bV (bV lNV N
N tN`I
-N
r
�U-
a
Y2N
8
J
J
m
t
O
LL
3
F
p
N0
N OpI 1y0
V O
CJ M
N
� N
m
pp
A
Oi O� � T
0 T
Ol N
m 0
N
m 0 m
pm y
b [O
p
m 0
Z j t0 N b b N m tU 0 ID �U �O t0 0 t0 1U N 10 A A^ n n n n A^^^ n n r
i
m o r
P O O V O P P Q v v v 4 4 4 v a P 4 a b
r
mm
mm Nm
m$
o m w v
m
m io
o ci
mp �mmn
0
e
yy pmp
m
mm
mNmmm
p m
mm
N
mn m
GI N N
N Cl
1n�
N
im N
qoq
N�
p
h
j
y
N
d
O
a
3
_
G
N �O
�
00
d
u
N Yl
g m
IA
N
N N
Z j t0 N b b N m tU 0 ID �U �O t0 0 t0 1U N 10 A A^ n n n n A^^^ n n r
i
m o r
P O O V O P P Q v v v 4 4 4 v a P 4 a b
mm
mm Nm
m$
o m w v
m
m io
o ci
mp �mmn
e
yy pmp
m
mm
mNmmm
p m
mm
N
mn m
GI N N
N Cl
1n�
N
im N
qoq
N�
p
h
j
y
�[mI N N
N
N
N �O
N �O
N� N
N Yl
IA
N
N N
u
Q
D
M m
m
m N
N
N N m-
P
-
-
-
M - -
- T
M
•-•
Cl
a7
ImV
(bV (bV lNV N
N tN`I
-N
r
�U-
a
Y2N
8
J
J
m
rs
O
LL
N0
N OpI 1y0
V O
CJ M
N
� N
m
pp
A
Oi O� � T
0 T
Ol N
m 0
N
m 0 m
pm y
b [O
p
m 0
OSI
OOi O� ONi
Nd
a
OV
m
1p0
N
N P
p
CY'1
� N P
NN
1Q0 Q N tl
N
� n
�
p
YI
1[0V1 Ih
p
�O m
O
C
p�p
thtVV
pOp
Qn
N
$P
h
I
ph
p0 yNy
T
0
0 0 0$
N N
N CI 1 J m
P
10
T
i
C
O
6
O
C
Q
0 p N O p O O m � OpIp$ N fp 1p00 m p 0O 10 01 ,tea r p Vp fm0 0 0 0 m N O 0 0 N m Vm
N e n 0 N N N INN` Ino -
Z� r r n r r n r y N N 6l m m 0 m
♦ r
V 1P0 t0 � N V 1I�p pOp11 N y 1p O P pN r 1r�� 11ry� O r mmm r N mPm 1lm1pop yOy11 1M'�1�' NN 01 � 4
H' N N N h N N N �N(1 N N N m Yml N Yml 10 Ill Iml1 N
N N N . . . N N N N
— l0 N b 1U N 10 10 1U N IOO N N N N N N N N N N N N . N N 10 10 N N
d
E
m
N ry � m
g 110
m
P
N O.
r
m
01 � N
m
N
n b
0
N 01 �
P
P
d
Z
I'a
n' m' n
0
M N
Ori
m 0
N
t7
OOi
O
N
001
r
m OI
N�
� 0
10
m
P
R�
6
ui 1d 16
10
'R
�.
m m
r
r r
m of
n
3
�
� � � �
�� 3
3 3
�
d
O
C
'2
10 to
n L �
ID
N �ll N t0
10 (�
�L 10
N 10 1L
10 (O
m 00
00000
N
00000
N 10 10
0p0000
N 1D 1D
N 1U
0000300
10 10 N 10 tD
000000000
0000
a Y
y
J J
2.1
d
m
m m
N
m
O
1
V
W
N
0 M
P
tp
N 0
s
s
d
e
e m�
m
r P
N 0 OI,
mm
2 m 9
ry
m m
v m
lg 2
m
�S m
O O
O
O O
O O
O O O
O S
��
N
q
p>p>
w
n
n
�
❑ L
1
N
100
10
N 10
t0 N N
N
Imo
0
10
0
❑
O=
P P
P
J F�
Z
N
O
r
rn
m?
E Y
O m
C rtl O N
NQ
0 0
Q
�.
3
ti
2 O
n S
o 0
0 0
8
0 p N O p O O m � OpIp$ N fp 1p00 m p 0O 10 01 ,tea r p Vp fm0 0 0 0 m N O 0 0 N m Vm
N e n 0 N N N INN` Ino -
Z� r r n r r n r y N N 6l m m 0 m
♦ r
V 1P0 t0 � N V 1I�p pOp11 N y 1p O P pN r 1r�� 11ry� O r mmm r N mPm 1lm1pop yOy11 1M'�1�' NN 01 � 4
H' N N N h N N N �N(1 N N N m Yml N Yml 10 Ill Iml1 N
N N N . . . N N N N
— l0 N b 1U N 10 10 1U N IOO N N N N N N N N N N N N . N N 10 10 N N
m
N ry � m
g 110
m
P
N O.
r
m
01 � N
m
N
n b
0
N 01 �
P
P
0=
0
M N
Ori
m 0
N
t7
OOi
O
N
001
r
m OI
N�
� 0
10
m
P
R�
6
ui 1d 16
10
'R
�.
m m
r
r r
m of
n
m
m g
� gi
�
d
O
C
'2
10 to
n L �
ID
N �ll N t0
10 (�
�L 10
N 10 1L
10 (O
N
10 10 Ip
N
10 10
N 10 10
10
N 1D 1D
N 1U
10 t0 i0
10 10 N 10 tD
U
a Y
y
J J
2.1
d
m
m m
N
m
O
1
V
N
0 M
P
tp
N 0
N r
N
e
e m�
m
r P
N 0 OI,
N l0
r S
O
��
O O
O
O O
O O
O O O
O S
��
N
q
p>p>
w
1
N
100
10
N 10
t0 N N
N
Imo
0
10
0
❑
O=
P P
P
J F�
Z
N
O
r
0 p N O p O O m � OpIp$ N fp 1p00 m p 0O 10 01 ,tea r p Vp fm0 0 0 0 m N O 0 0 N m Vm
N e n 0 N N N INN` Ino -
Z� r r n r r n r y N N 6l m m 0 m
♦ r
V 1P0 t0 � N V 1I�p pOp11 N y 1p O P pN r 1r�� 11ry� O r mmm r N mPm 1lm1pop yOy11 1M'�1�' NN 01 � 4
H' N N N h N N N �N(1 N N N m Yml N Yml 10 Ill Iml1 N
N N N . . . N N N N
— l0 N b 1U N 10 10 1U N IOO N N N N N N N N N N N N . N N 10 10 N N
0
m
N ry � m
g 110
`ai
$
v�
m
o Imn
mn
'r
Inn a
O1 � m
m�
n r1 e��
0=
M N
Ori
0
��pp
N
11pp
O
pp
m
0 m
N
N 0 n
r
m OI
ry
m 10
� 0
10
m
2y
n N
6
ui 1d 16
10
'R
�.
m m
r
r r
m of
n
m
m g
� gi
�
q
O
C
a em
10 to
Y' O
(O
N �ll N t0
N N
N
IO
N
N N
N
N 10 1D
10
1U 10
IO IO
N N
N
N N
10 10 N 10 tD
U
0
m
N ry � m
g 110
`ai
$
v�
m
o Imn
mn
'r
Inn a
O1 � m
m�
n r1 e��
0=
M N
Ori
0
��pp
N
11pp
O
pp
m
0 m
N
N 0 n
r
m OI
ry
m 10
� 0
0
01p
A
2y
33
a i
m
o
ID (nO
r
r r
m of
n
m
m g
� gi
�
q
O
C
T
y
m .no
f N N
N
lV
N N
N
N N N
N
N N
N N
N N
a1
13
�
t K
U
a Y
y
J J
2.1
o m
m
m m
N
m
O
1
V
m
n"
m
N ry � m
g 110
`ai
$
v�
m
o Imn
mn
'r
Inn a
O1 � m
m�
n r1 e��
ryy
yy NNy
vm1
y
co
g
10
yy
yy
33
q
O
C
T
y
f N N
N
lV
N N
N
N N N
N
N N
N N
N N
N
s
a d
2.1
� a` rn
3 3
❑"
N
1
m
n"
r
0
ut
Q
s
CL
0
V
C
V
T
O C T
a m a m m
v a` rn 3 3 ci m
c
0
c
c
Q
m
E
N
2 F = m m_ R R m m_ R R R n. m R n_ R in
o U O O O O O O O O O O O O O O O O O O O O O O O O O O O O O c9
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O 0
O O O O O O
�gg��ggggggg��gg�g�ggg����ggg�gg
.2 ry 8 8 n& a
m y— ti m m m m of m ai m m m m m m m w v: m ai of of m
> m
m 0 N r m W m M (� P tmV N OOi ^ 0 r 0 YI O Q Q p O N W m ry N
YOI O N 0 N O Oi N
J m
O
m m 0 1m S m ry v
e m ren ` m m of P m m '9m' m m m m o m m s$
N (O M N m m 10 M1 P P m N b Q VNI O N 10 m 0 m, N N P P m 0 NO (O
o1 m m ry n m" v N �+ v e e `� N f @ m o i `Irk m ry
E 0 0 0 n n m 17 P n N 0 m N. 0 0 0
q« M1 r r n 1� 1� n I� r r r r r r r r r
'2 O m Ori OI O� O� S OI OI A T Ori Ori O^i O) N W OI o T m O) o A Q P T
Z N N N N N m m u) N N N N VI N N N N N m h N N N N m N N N N N N
m N � ro 0 10 (O 0 0 O P Orl 0 m M m O N m (O O Oml (rO N OI P O m ON
m M (V lV m
.. � m 0 0 0 m m 4] Ot m (O 0 m T OI m Oi Oi m P O'
i } m
N OIp m N 0 r v01 r �m = tV N V P m fPU O n m N 0 N� N Imo � ONi O P�
N S' IV N N m vi 0 I+M u) ul N Ifn v v) v 10
� m N N N vl N N �n N ifl N N N N h N N N m N
Ve m 16 m m m m m m 16 m m m m m m m n lu � m m n m 16 to In m m m
N O m lmJ 0 1m- in n ON+'n N (h O 1� N 0 0 N N N Imo O O N
m m m 'e m
F] co Id Iti m m m m m m m Iti e m m m m m m e e ro m d Id m lu a 16 e m to
m� pryren 0 0 0 0a m�
OPi N N Oml O� OI A m m 0 0 OOI R N 0 0 W 0 0 T Oml OV I 25;51-.
A N 9
C Q m r y N m I my P h f0 0 N O r 100 m 10 � 0 IrY 100 V P S P O� 0 CJ � 10 (O
V V V V m m 2 � m
N N ry N n m m m m m n m m
F
N
n
Y
p u
O � T
O Oi O O O d J
c
b
0
E
m
E o
y U U O O O O O O O OO O O O O O O O O O O O O O O O O w
N � s sy� sp s s sp sp� s i i s s s f s
y y— m m m m m m. m m m m m of m m ai m m m m m m o b
9 N
L i n F I� (O j W 0 j pj pj pj p (p 0� 0 m W W 0 m m 0 t0 W W 0
j N b b N N N N b N N N b N N b N N N b N N N h N N h M N
T N f Oi O1 Oi YI W N OW YI W O� Q m O N N O
v v
`vi m
. .
m_ m_ a..
of. a .. of ai of m m.-
8 8 m � vr'i o mQ m n m� 8 `�i ��yi n `8 pmr `p8 rvp y' Oy1 m c 8p n n n n m
N y N N b h b N b N b N h N N VI N N b Y1 Y] N V1 N N h N YI N N
Ov b 10 �U 1D b 10 N W b b W b b 1O 10 LLl b b W (O b 10 10 10 �O b W
� �y^j tD � � IX �O b �O � �O_ •D � 0 � b � � 41 b W. b, f0 10_ �O �O 10 b Vm) ul
'J tD 10 �O �D t0 b t0 b W W b b tD b 14 <O b 10 b b (ti b 10 10 W t0 N to
eW] 10 t7 IBJ M M m Ib+l M M
S 8 R 8 n o `& r$ S N' m$ 8 p!
(p m� b Us Wmm N yry mNm tM`I N CJ {W{pp N N ,�,�jj 10 � m0m W p N N 8P O
BAKER 0 PRINT DISTRIBUTION LIST
STATUS Final Replacement: No
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. B04
PERSON ATTENTION
4
1 UP North 510pe.
EOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage. AK 99510
21 9 00 6
3 104 3
Please sign and return one copy of this transmittal form to:
ConocoPhillips Alaska, Inc.
Tom Osterkamp (WNS Petroleum Technician)
700 G Street.
Anchorage, Alaska 99510
to acknowledge receipt of this data.
LOG TYPE
GR -RES
LOG DATE June 28, 2019
TODAYS DATE July 30, 2019
Revision
Details:
Rev. Requested by: ---
FIELDI
UGHES
CD/DVD
FINAL
a GE company
PRELIM
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME
1C -19L1
REPORT
FIELD
Greater Kuparuk Area
CGM, Final Surveys)
COUNTY
North Slope Borough
# OF PRINTS
BHI DISTRICT
Alaska
# OF COPIES
AUTHORIZED BY
Patrick Rider
EMAIL Patrick.Rider�hes.com
STATUS Final Replacement: No
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. B04
PERSON ATTENTION
4
1 UP North 510pe.
EOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage. AK 99510
21 9 00 6
3 104 3
Please sign and return one copy of this transmittal form to:
ConocoPhillips Alaska, Inc.
Tom Osterkamp (WNS Petroleum Technician)
700 G Street.
Anchorage, Alaska 99510
to acknowledge receipt of this data.
LOG TYPE
GR -RES
LOG DATE June 28, 2019
TODAYS DATE July 30, 2019
Revision
Details:
Rev. Requested by: ---
FIELDI
FINAL
CD/DVD
FINAL
PRELIM
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTS
# OF COPIES
# OF COPIES
# OF COPIES
3 ExxonMobil, Alaska 0 0
Att.: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage. AK 99503
of Alaska -AOGCC
Natural Resources Technician Il
V. 7th Ave, Suite 100
orage, Alaska 99501
Division of Oil ti Gas
,: ***
c Resource Evaluation
West 71h Avenue, Suite 1100
horage, Alaska 99501
*** Stam. "ronfidential" on all material deliver to DNR
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
RECEIVE®
TOTALS FOR THIS PAGE: 0 1 2
0
L; VEx..,11
�Y-
STATE OF ALASKA
At A3KA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Ia. Well Status: Oil Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions:
lb. Well Class:
Development Q Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Aband.: 6/30/2019
14. Permit to Drill Number/ Sundry:
219-086 '
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
6123/2019
15. API Number:
50-029.23149-60-00 '
4a. Location of Well (Governmental Section):
Surface: 1615' FNL, 1360' FWL, Sec 12, T11N, R10E, UM '
Top of Productive Interval:
1056' FNL, 32' FWL, Sec 6, T11N, R11 E, UM
Total Depth: T IZ V He"
2102' FNL, 595' FWL, Sec 31, 14,2, R11 E, UM
8. Date TD Reached:
612 812 01 9
16, Well Name and Number:
KRU 1C -19L1
9. Ref Elevations: KB:87
GL: 52 . BF:
17. Field / Pool(s):
Kuparuk River Field/Kuporuk River Oil Pool '
10. Plug Back Depth MD/TVD:
N/A
18, Property Designation:
ADL 25649, ADL 28242, ADL 47449
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 562368 ' y- 5968624.5.941M 0Zone- 4
TPI: x- 566268 y- 5 Z ' "d Zone- 4
Total Depth: x- 566793 y- 5978735 Zone- 4
11. Total Depth MD/TVD:
14637/6590
19. DNR Approval Number:
ALK 467
12. SSSV Depth MD/TVD:
N/A
20. Thickness of Permafrost MD/rVD:
1856/1789
5. Directional or Inclination Survey: Yes Q (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
NIA (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
10143/6545
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
16 62.5 B 29 138 29 138 42 175sx ArcticCrete
9.625 40 L-80 28 6745 28 4474 12.25 655 bbls AS III Lite, 144 bbls
7 26 L-80 26 10429 26 6788 8.5 240sx Class G
2.375 4.6 L-80 10050 14637 6468 6590 3 Slotted Liner
24. Open to production or injection? Yes Q No ❑
If Yes, list each interval open (MD/rVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED LINER@:
10050.14637 MD and 6468-6590 TVD
COMPLETION
6ATE
- q
� (
VF EQ
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
3 112 10067 1 1003616456
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No Q
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTHINTERVAL(MD)AMOUNT AND KIND OF MATERIAL USED
27, PRODUCTION TEST
Date First Production:
71312019
Method of Operation (Flowing, gas lift, etc.):
GAS LIFT
Date of Test:
7/6/2019
Hours Tested:
18
Production for
Test Period
Oil -Bbl:
613
Gas -MCF:
1 217
Water -Bbl:
1319
Choke Size:
176
Gas -Oil Ratio:
354
Flow TubingCasing
Press. 31$
Press:
1374
Calculated
24 -Hour Rate
Oil -Bbl:
818
Gas -MCF:
Water -Bbl:
17
Oil Gravity - API (corr):
20.
Form 10-407 Revised 5/2017 (P 77 h/3// 7Af! I;ONTI10 ON PAGE 2 RBDMS�' JUL 3 t 2019 Submit OR�IGII�AL onl
28. CORE DATA Conventional Corals): Yes ❑ No Q Sidewall Cores: Yes ❑ No R]
If Yes, list formations and intervals cored (MDRVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No ❑Q
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1856
1789
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
10143
6545
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk C
Formation at total depth:
Ku aruk D Shale
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontoloaical report, productionI r 20 AAC 25,070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: James Ohlin er Contact Name: Shane Germann .SG
Authorized Title: Staff CTD En ineer Contact Email: Shane. erman(c'bco .com
Authorized Contact Phone: 263-4597
7130/
signature: Date:
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 512017 Submit ORIGINAL Only
KUP PROD WELLNAME IC -19 WELLBORE 1C-19
�(] �/'/yr_J B'� Well AHribuk Max Angle' l TD
OnO�"•t"'E�� FICItl Name WeIIWne APBVWI We(IWre aUlue ncl r) MOB. lett Blm (nN81
AIasKB. iRC. H"ARUK RIVER UNIT 500292314 9 0 0 PROD 50.1J 5,856eo 10,435.0
a51
tole.7avareta4zs AM
Last Tag
VeNctl.-altrose (evan)
Annolaxon
Depth(nKB) 1 EM Dale WeIIMre Lost Most ay
Last Tag: RIDS
10,16/0 1wevaclu 1C-19 zemhaej
........ ....... ..........wvicea;ua...-
......_.
Last Rev Reason
MnatatbnI
East.
Weaxm.
Lest Most By
7.77.-D.7-MCUNKNOWN OBSTRUCTION IN CASING WITHELINE
6/122019
1C-19
coneijw
CALIPER
Casing Strings
easing Desenp(ion 0011nl IDlml Toplecip sN Dep,b(IRE) Stl DePm La,.T.. WIILen ll__Graoe Top In
CONDUCTOR 16 15.06 29.0 1380 138.0 62.50 H-00 WELDED
Cost, OexrlpHon ODlhe IO lint Topa' Se(Dep0"Ke1 Set dpin 11V01... WIILen L.. GraEe Tap Im.
SURFACE 95]8 8.83 280 6,]44) 4,4]4.1 40.00 L-80 BTCM
Casing 0nctlplbn OD BM la (in) Top 11191SM Depm("m Set dptn (N01... W(ILe 11 Tap TnrcM
lanes
PRODUCTION 7 618 260 104297 6788.6 26.00 680 BTCM
I I
wxcucTOR: aB.a1mD
Tubing Strings
mems 0essnpiion senna ma... lD(ln) ropinKel $N Dapm lh. se[Depin (ND1r.. wgINM11 Gnae Top eonnecnoa
TUBING wO 3112 2.99 22.9 10,029.5 64505 930 L-80 EUE-bra
NIPP(E.a
Completion Details
Top (No Top incl Nommai
Top (MR) PIKE) C IRM Des Co. IO (in)
22.9 22.9 0.00 HANGER GEN IV TUBING HANGER 2.990
509.2 509.2 078 NIPPLE 2.87E DB' NIPPLE 2.875
10,016.8 6,440.1 34.68 LOCATOR BAKER LOCATOR 2.990
GAs uFT; atm.-
10,01].6 6,4408 34.67 SEAL ASSY BAKER 804OSEALASSY 2.990
Tubing Dem,lpxon 44ing mKID Se De .S6e4t8DepmTVDL_ WMGRtle p Connection
.M0
TUBING Onginal 59 10021.3 006].9 2
Completion Details
Top RWD) Top and
Nommai
Top(MB)
mKB) PI Item da
coin ID (m)
papi: e.mo
1,021.3
6,4438 34.66 PFR
BAKER 8040 PBRISBR -FUBING STRING HAS Qi OF THE 3.000
PBR'-"
10,035.9
6,455.8 3452 PACKER
BAKER SABa PERMANENT PACKERw/ MILLOUTERTENSI N 3710
ID 3.71"
10,05 .9
6,4]5.] 34.27 NIPPLE
CAM ODNIPPLEw E ""MILLED 2.800
OUTTO2.80""«"'
1006].0
6481.5 34.20 WLEG
BAKER WIRELINE ENTRY GUIDE 3.000
SVRFALE,$ps.744.7�
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (IVD Top ma
wst-FT;e,49.9
TOP nine) nite f) Dee com Ran Date
ID (in)
10,143.0 8,5447 33.07 WM1lps(ock N.S. High expansion whipstock 612112 0 7 9
10,163.5 6.561.9 3261 UNKNOWN UNKNOWN RE TRI TII.N. NOT ABLE TO DRIFT 611212019
2000
RESTRICTION PAST
GeSLIFT:a31e0
perforations Be Slots
anoe
Den
roti118)
Bim(")
lsnmsM
TOP1nKBt
sten (nKE)
mleel
(petal
LmEea znn.
d1e
1
type
com
10,1500
10,1800
6.550.6
,575.
4,1C-19
6/182003
401PERF
25"H5D,2 PP
peesLIFT: e.sa.e
HVPERJET, 4 SPF
PDWERJET
10,152.0
14,619.0
6.55.
C-0, 1C-19
L TS
Slolled completion
Frac Summary
sun Dam sentiment dsened pa) PlappnMlnpamnammust
IWM03 20,3000
LOCATORi K.oRa
stet
Si+I Datr Top DepiM1 (M(B) BM (flNB) Link W Fm. System Volclun(ba0 Vo191menii
SEALTssYi
1
10.+1200 10150.0 10,1800 crypt>, <fluiEname>
10176
sen; 1D.,)
SpndW Peoppanidspm4llb) Pvto" nFwpnomm(W)
9/1012017 200,0000 200,263.0
Se
gent dte Top Depin mKa) ebn MED LmxWHuw sYSWm vnleWn
mM omsse,i
PACKER:,B.c0.5e
1
9/102017 10,1500 10,180.0 Gelled Sall Water, HyhorG 2,]85.0
2,972.00
Mandrel Inserts
u
NIPPLE:,0.P29.9
N Top IN01 Tame IOWs Pal Sire TRO Run
Top INKe1 IB) Make MG ODIQ Sery Time Type (in) Run Date Core
.233
3,133.7 2,1027 CAM O MMG 112 GAS LIFT GLV RK 0.188 1,233.0 9/132017
2S9
wLEc'no.oa7.o
2 6,0147 4,102] ICAMCO MMG 112 GAS LIFT OV RK 0.250 00 9/13209
3 8.126.6 5,20].] CAMCO MMG 112 GAS LIFT DMY RK 0000 00 92]2013
tier U OTDeMaeck',
4 9,3190 5912.1 CAMCO MMG 112 GAS LIFT DMY RK I 0000 I 00 9272013
5 99569 6,390.9 CAMCO MMG 11/2 GAS LIFT DMY RK 00001 00 1911r2oll
10w0.,-14.070
.soon 1D leaa
Notes: General B Safety
EnddWnemmenn
uNKNO'NNFEITRIcnox;
1/1112011
NOTE'. View Schematic wl Alaska SCIemnpc 0
10,105
(PERF: 10150010.1¢10
FRAC;m Wo
XydyEFmions, 0,150.0
-_
PRODIICT,ONi Sals%4257�
SLOM, 10152.0148i
KUP PROD WELLNAME 1C-19 WELLBORE 1C -19L1
p '+i..l' WeIIA@ributt Max Angle TD
C ,"'r�� .,E Name WIIIDon, PPYUWI We11Wre5 tus MO( ACI01m (NINE)
A1a9ka.InC KUPARUK RIVER UNIT 500292314960 PROD 146450
icmi90.1/JNA19104i:31NA
Culling strings
Vsemlavwrmmlacwem
Casing DescriptionOD (m)
Liner LI CTD Sidetrack 231(6
ID(m) Top(fll(BI BN Deplb(11MB) Set Depth lIPID).
199 10,0501 14,63>.0
WULen B...Grace
4.60 L-80
TOP ThmaE
STL
..........................._.................... ......
......_..
Liner Details
HANGER:Z1.3-
minellD
TOP ImLeI I Top
MDI(Itice)
Top Incl l')
Item Des
Co.
Ito)
10,080.1
Deployment
SMony Deployment Sleeve
1.920
Sleeve
13,049.8
Deployment
S11oM Deployment Sleeve
1.920
Sleeve
13,84.7
Deployment
Slwdy Deployment Sleeve
1.920
Sleeve
Free Summary
SWI DNB
PreppantCngnW(a)Proppantlnpoovan(a)
rm
10/)2003
200,300.0
C0NDUCTOR:2E0130.0
SW# SIart ONe
Tap DCA0h(XNBI Blm(MNB) Linh to R.Id Sypem
VW Cl...(ban
Vel Sluny(bbm
1 10212003
10,1500
10,1800 <Iypt+, e0Didlame�
SYrt DateP""e".ILL
ILIN
Pmppant In Formstan(ILI
91(10201)
200,000.0
200263.0
mPRE: SD3
S1g•
StartDM
Top DegbntILID Sbn(IN(Bl Li.L.R.Wityabm
VOI CIean(-0
VOI51urry(bbl)
1
9110209
10,150.0
10,1800 Ge6ed Salt Water, Hybc,G
2,]6600
29]200
Ws utT 3.133<
GPS 111T. 6,at 17
SURFACE; M0 .]H 1�
G43 LIFT; 0.130.0
GPS LIFT: a 3190
GAS LIFT, 9 ma l
LOWTOR', IO,MflB
SEALALSY'. 1GMTS
Pap: l0.R19
PACRER', 100lA9
NIPPLGIomG9
WLEG: taws
PR0DUCTI0N:30.410a36.1�
Lm Lt CTD Seebeck,
10,0501-1a,w.
1C-19 final CTD Schematic
16" 62.50 H-40 shoe
®138'MD
958" 40# LA0 shoe
6745' MD
Caand parts
10150' - 10180' MD
7" 26# LA0 shoe
10,429' MD
upde , 7rvm198M
3-1/2" DS Nipple@ 509' MD (2.875" ID)
3-1/2" 9.3#L-80 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrel @ 3133', 6015', 8127',
9319'. & 9957' MD
Baker 31/2" PER ® 10,021' MD (3.0" ID)
Baker SAB -3 packer (1p 10,036' MD (3.710" ID)
Camra D -Nipple @ 10,060' MD (Milled to 2.80' ID)
3-12" WLEG 0 10,067' MD
1C491-1TD = 14,63T MD
TOL = 10,050' MD BOL = 14,637' MD
2-3/8' slotted liner w/ deployment sleeve
Operations Summary (with Timelog Depths)
r
113-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (W)
Phase
Op co"
Advo Cafe
Time P -T -X
Operation
(ftKB)
End Deptir(ftKB)
6/20/2019
6/20/2019
6.34
MIRU
MOVE
MOB
P
Continue RDMO from 1J-10, load out
0.0
0.0
10:00
16:20
DTH trucks, secure rig landings and
stairs, secure cellar, NES arrives on
site at 11:45am, PJSM for Rig Move,
Mobilize rig towards 1C-19,
6/20/2019
6/20/2019
5.00
MIRU
MOVE
MOB
T
Notified rig has dropped a wheel at 1 D
0.0
0.0
16:20
21:20
-pad/spine road intersection, notify
security and DTH, upon inspection
found that the driller side module tires
have moved off roadway, notify Town
Team, DTH on location, spot in
cribbing and rig mats. jack up rig place
dunnage under wheels, jack down, lay
more dunnage, hook up D8's x 2 to
rear of module, walk rig backwards
onto solid ground, Nabor's Mechanic
on location, inspect moving system,
steer module past soft spot and edge
of roadway (4hrs), continue moving
towards 1C.
6/20/2019
6/20/2019
2.50
MIRU
MOVE
MOB
P
Notify security, continue mobilizing rig
0.0
0.0
21:20
23:50
to 1C-19
6/20/2019
6/21/2019
0.16
MIRU
MOVE
MOB
P
Arrive on location, remove jeeps
0.0
0.0
23:50
00:00
6/21/2019
6/21/2019
0.75
MIRU
MOVE
MOB
P
Prep well for rigs arrival place rig mat
0.0
0.0
00:00
00:45
for stomper beam, spread out
herculite, Stage Utility module on back
side of pad
6/21/2019
6/21/2019
1.75
MIRU
MOVE
MOB
P
Spot in Drilling Sub
0.0
0.0
00:45
02:30
6/21/2019
6/21/2019
0.50
MIRU
MOVE
MOB
P
Lay mats for drilling sub and spot mats
0.0
0.0
02:30
03:00
for Ufility Sub Module
6/21/2019
6/21/2019
1.50
MIRU
MOVE
MOB
P
Move in and Spot Utility module
0.0
0.0
03:00
04:30
6/21/2019
6/21/2019
1.50
MIRU
MOVE
NUND
P
Begin work RU checklist, drop stairs,
0.0
0.0
04:30
06:00
secure landings, MU hardline to TT
6/21/2019
6/21/2019
6.00
MIRU
WHDBOP
RURD
P
Crew change, called valve crew to
0.0
0.0
06:00
12:00
service tree, MV, SSV, Swab all leak
by.
Begin NU BOP, RU MP line, continue
RU checklist. On high line at 09:00.
Take on SW at 11:30
"" Rig Accept @ 10:00 hrs
6/21/2019
6/21/2019
1.00
MIRU
WHDBOP
RURD
P
Fluid pack test pump and surface
0.0
0.0
12:00
13:00
lines. Perform shell test low 275
psi/3500 psi
6/21/2019
6/21/2019
5.00
MIRU
WHDBOP
BOPE
P
Start Initial BOPE test, 250 psi 13500
0.0
0.0
13:00
18:00
psi, 2500 psi Annular, (Witnessed by
AOGCC Inspector Brian Bixby)
6/21/2019
6/21/2019
1.00
MIRU
WHDBOP
PRTS
P
Slide cart forward, replace 7" otis o-
0.0
0.0
18:00
19:00
ring, stab INJH, fluid pack, test inner
reel valve and pac-off and chart.
6/21/2019
6/21/2019
1.40
MIRU
WHDBOP
PRTS
P
Unstab INJH, slide cart back,
0.0
0.0
19:00
20:24
PU/replace o-ring/stab DS PDL, PT
250U3,500H
6/21/2019
6/21/2019
0.30
PROD1
RPEQPT
PULD
P
PJSM, NS on location load tools into
0.0
0.0
20:24
20:42
pipe shed, install lift nubbins, place
HEW into the well, MU BHI CoilTrak
tools
•" Note: Initial Tubing Pressure 1,057
psi
6/21/2019
6/21/2019
0.90
PROD1
RPEQPT
PULD
P
PD HEW Assembly
0.0
73.5
20:42
21:36
Page 1111 Report Printed: 7116/2019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Su ni Time
End Time
Our (hr)
Phase
Op Code
Adivity Code
Time P -T -X
Operation
(OKE)
End Depth (ftKB)
6/21/2019
6/21/2019
0.20
PRODt
RPEQPT
PULD
P
Slide cart forward, install BHI float
73.5
73.5
21:36
21:48
valves into upper quick connector,
stab onto tools, perform surface test
(good), stab INJH
6/21/2019
6/21/2019
1.80
PROD!
RPEQPT
TRIP
P
Function open deployment rams, tag
73.5
9,960.0
21:48
23:36
up, reset counters, RIH, taking deisel
returns out to the Kill Tank
6/21/2019
6/21/2019
0.25
PROD?
RPEQPT
DLOG
P
Log formation for depth control (K1),
9,960.0
9,995.0
23:36
23:51
correction minus 17.5'
6/21/2019
6/22/2019
0.15
PROD1
RPEQPT
TRIP
P
Continue IH
9,995.0
10,016.0
23:51
00:00
6/22/2019
6/22/2019
0.30
PROD1
RPEQPT
TRIP
P
Conintue IH 10,150', PUW 39 k, RBIH
10,016.0
10,151.8
00:00
00:18
to 10,151.8', bring pump up to shear
2,650 psi, set down 4.3 k DHWOB,
PUW 39 k
6/22/2019
6/2212019
0.20
PRODt
RPEQPT
WPST
P
PUH, continue displacing well to
10,151.8
10,136.0
00:18
00:30
SW.59 bbl away still have gas to
surface,
6/22/2019
6/22/2019
1.80
PROD1
RPEQPT
DISP
P
Continue circulating, switch to milling
10,136.0
00:30
02:18
fluid 8.78 ppg, 154 psi WHP,
BHP=3,220 psi, trending up, still losing
50%+.Displace well to milling fliud
6/22/2019
6/22/2019
1.80
PROD1
RPEQPT
TRIP
P
POOH, pumping pipe displacment
10,136.0
73.5
02:18
04:06
with closed choke. build 50 bbl 100k
LSRV pill
6/22/2019
6/22/2019
1.00
PRODt
RPEQPT
PULD
P
At surface, tagup, spaoeout PUD
73.5
0.0
04:06
05:06
setting tools
6/22/2019
6/22/2019
1.30
PROD1
WHPST
PULD
P
PD milling assembly BHA#2
0.0
77.3
05:06
06:24
6/22/2019
6/22/2019
1.60
PROD1
WHPST
TRIP
P
Tag and resit counters, RIH, pump
77.3
9,960.0
06:24
08:00
min rate, 0.32 bpm, 1127 psi, 250 psi
WHP, bled IA from 1190 psi to 830 psi,
pump super Hi Vis pill
6/22/2019
6/22/2019
0.20
PROD1
WHPST
DLOG
P
Log formation for depth control (K1),
9,960.0
10,019.2
08:00
08:12
correction minus 17.5', correct depth
to 10001.74'
6/22/2019
6/22/2019
1.00
PROD1
WHPST
CIRC
P
Circulate 50 bbls Hi Vis pill (100K
10,019.2
10,019.2
08:12
09:12
LSRV), pump w/choke closed, initially
0 psi WH, after 50 bbls away, 1.8 bpm,
CP 3361 psi, WH 250 psi
6/22/2019
6/22/2019
2.10
PROD1
WHPST
CIRC
P
Open choke and send to TT, getting
10,019.2
10,019.2
09:12
11:18
back energized fluid, attempt to circ
BU volume, mix and pump 2nd 50 bbl
Hi Vis pill (100K LSRV) against closed
chk, pump pill away, open chk, no
change in return rate, 0.8 bpm out at
1.8 bpm. Close choke, close EDC
6/22/2019
6/22/2019
2.50
PROD1
WHPST
MILL
P
Dry tag pinch point at 10147', 17K,
10,144.0
10,149.4
11:18
13:48
1.9K WOB, PU to breakover plus 1'
per NS rep, PUW 38K ("'Call TOW at
10144'.•'). Establish rate 1.85 bpm,
3430 psi free spin, 3550 psi AP, 650
psi dP, auto drill 1/10ths
6/22/2019
6/22/2019
0.70
PRODi
WHPST
MILL
P
milling window, 12.7K, 1.85 bpm, 3915
10,149.4
10,150.2
13:48
14:30
psi, 765 psi WH, 3898 psi AP, 792 dP,
1.64K WOB
•' Note: Very High Vibrations level 5
t@ 10,149.3'& 10151'-10,154'
6/22/2019
6/22/2019
2.00
PROD1
WHPST
MILL
P
mill exits the casing at 10150.3' (+6.2'
10,150.2
10,173.0
14:30
16:30
from TOW), milling ahead, 12.5K,
3949 psi, 900 psi WH, 1.86 bpm,
closed chk,
Page 2111 Report Printed: 711612019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sten oepm
StertTime
End Time
Da (m)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(W13)
EM DePth (rd(B)
6/22/2019
6/22/2019
1.25
PROD1
WHPST
REAM
P
Back ream window to 10143', at 1
10,173.0
10,173.0
16:30
17:45
FPH, 30" left and right of HS, final
pass at 160°, seems to be dean
6/22/2019
6/22/2019
1.75
PROD1
WHPST
TRIP
P
POOH
10,173.0
73.5
17:45
19:30
6/22/2019
6/22/2019
1.00
PROD1
WHPST
PULD
P
Tag up, space out, PUD window
73.5
0.0
19:30
20:30
milling assembly
" Note: Both mills backed off 1/4"
" Note: Mills Gauged 2.79 no-go
6/22/2019
6/22/2019
1.00
PROW
DRILL
PULD
P
PU/PD build section BHA #3
0.0
72.2
20:30
21:30
6/22/2019
6/22/2019
0.20
PROD1
DRILL
PULD
P
Inspect pac-off, dig out debris,
72.2
72.2
21:30
21:42
(changeout)
6/22/2019
6/22/2019
0.15
PROD1
DRILL
PULD
P
Slide cart forward, inspect o-dng, slab
72.2
72.2
21:42
21:51
INJH, surface lest BHI CoilTrak tools
(good -test)
6/22/2019
6/22/2019
0.15
PROD1
DRILL
PULD
P
Stab INJH, function open Deployment
72.2
72.2
21:51
22:00
Rams, tag up, reset counters
6122/2019
6/22/2019
1.80
PROD1
DRILL
TRIP
P
RIH
72.2
9,965.0
22:00
23:48
6/22/2019
6/23/2019
0.20
PROD1
DRILL
DLOG
P
Log formation for depth control (Kt)
9,965.0
9,991.0
23:48
00:00
correction of -17', PUW 40 k, close
EDC
6/23/2019
6/23/2019
0.20
PROD1
DRILL
TRIP
P
Continue IH to bottom
9,991.0
10,173.0
00:00
00:12
6/23/2019
6123/2019
0.20
PROD1
DRILL
DRLG
P
Establish pump parameters, 1.9
10,173.0
10,179.0
00:12
00:24
bpm/3,727 psi/544 psi, WHP=676,
BHP=3,791, IA=348, OA=344
6/23/2019
6/23/2019
0.50
PROD1
DRILL
DRLG
P
TF against stops, PUH PUW 39 k
10,179.0
10,228.9
00:24
00:54
restart 1.9 bpm/3,976 psi/491 psi,
WHP=1,012, BHP=4,060, IA=349,
OA=345
6/23/2019
6/23/2019
0.20
PROD1
DRILL
DRLG
P
TF against slops, PUH PUW 39 k
10,228.9
10,236.0
00:54
01:06
restart 1.88 bpm/4,398 psi/561 psi,
WHP=1,309, BHP=4,276, IA=351,
OA=353
6/23/2019
6/23/2019
0.45
PRODi
DRILL
DRLG
P
1.88 bpm/4,398 psi/561 psi,
10,236.0
10,272.0
01:06
01:33
WHP=1,309, BHP=4,276, IA=351,
OA=353,
*** Note: WHP = 1,340/BHP = 4,302,
Function open Choke, WHP =
413/BHP=4,049, MM In 1.91 bpm, MM
out 1.80 bpm
6/23/2019
6/23/2019
0.75
PROD1
DRILL
DRLG
P
PUH, obtain new pump parameters,
10,272.0
10,327.0
01:33
02:18
PUW 38 k. 1.90 bpm/3,761 psi/557
psi, BHP=3,785, MM in=1.91 bpm/MM
out=1.79 bpm,
6/23/2019
6/23/2019
0.20
PROD1
DRILL
WPRT
P
PUH, to log K1 PUW 39 k
10,327.0
9,965.0
02:18
02:30
6/23/2019
6/23/2019
0.40
PRODi
DRILL
DLOG
P
Log formation for depth control (Ki)
9,965.0
10,252.0
02:30
02:54
no correction, Continue IH to log the
RA marker (PIP Tag), RIW 15 k, Log
the RA marker correction of 0.5'
6/23/2019
6/23/2019
2.30
PROD?
DRILL
TRIP
P
POOH to 10120', open EDC and
10,252.0
78.3
02:54
05:12
POOH
Page 3/11 Report Printed: 711612019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan NM
an N
Siem rime
EM Time
Dur(m)
Phase
O Code
Op
Advi COMe
H
Time P -T -X
Operation
EM Depth (IIKB)
6/23/2019
6/23/2019
1.30
PROM
DRILL
PULD
P
Tag up, space out, PUD BHA #3,
78.3
0.0
05:12
06:30
inspected PO's, pack offs were
squished, heated and halves were
fused together, picked out more of the
remnants from the previous Clean out
and install new PO's, LD build motor
and bit.
6/23/2019
6/23/2019
1.40
PROM
DRILL
PULD
P
MU BHA#4,deploy, surface test
0.0
78.3
06:30
07:54
(good), MU to injector, bump up and
reset counter.
6/23/2019
6/23/2019
1.70
PROM
DRILL
TRIP
P
RIH to 500', Gose EDC, shallow test
78.3
9,965.0
07:54
09:36
(good), 1.8 bpm/1.44 pbm, 3827 psi
CP, 770 psi, WH, 1100 psi dP. CRIH
w/ EDC closed at min rate.
6/23/2019
6/23/2019
0.30
PROM
DRILL
DLOG
P
Log formation for depth control (K1),
9,965.0
10,120.0
09:36
09:54
correct depth to 9992.2'(-9.5').
6/23/2019
6/23/2019
0.30
PROD1
DRILL
TRIP
P
RIH to WLEG, bring rale to 1.86 bpm,
10,120.0
10,326.0
09:54
10:12
jog 7" casong 2x, RIH clean thru
window, and build, 13K
6/23/2019
6/23/2019
1.00
PRODi
DRILL
DRLG
P
Establish pump parameters, 1.84
10,326.0
10,405.0
10:12
11:12
bpm, 4655 psi, 100 psi WHP, 1296 psi
dP, IA=355, OA= 350, 1.68 bpm
eturns
6/23/2019
6/23/2019
0.60
PROD1
DRILL
DRLG
P
New PowerPro going downhole, 1.85
10,405.0
10,430.0
11:12
11:48
bpm/4480 psi/181 psi WHP,
BHP=3818„ DP=1330 psi,
WOB=1.5K, ROP=75, MM out= 1.59
bpm, 0.3 bpm loss rate
6/23/2019
6/23/2019
2.90
PROD1
DRILL
DRLG
P
New mud at bit, 1 OK CW, 4520 psi,
10,430.0
10,727.0
11:48
14:42
158 psi WH, 1.85 bpm in / 1.58 bpm
out, 8.65 ppg, 3810 psi BHP, 1430 psi
dP, 1.9K WOB, 123 FPH, drilling
break, followed by motor stall at
10727', time for wiper anyway, in the
C4 now
6/23/2019
6/23/2019
0.30
PRODi
DRILL
WPRT
P
Short wiper trip, 42K PUW to 10327',
10,727.0
10,727.0
14:42
1500
RBIH clean to drill
6/23/2019
6/23/2019
4.00
PROD1
DRILL
DRLG
P
OBD, 10.5K CW, 4500 psi, 47 psi
10,727.0
11,091.0
15:00
1900
WHP, 1.89 bpm in 11.61 bpm out,
3811 BHP, 1261 V,, I WOB, 164
ROP, Loss Rate= 16 to 17 BPH, at
10819', pumped 5x5 sweep. Several
drilling breaks, followed by a motor
stall
6/23/2019
6/23/2019
0.50
PROD1
DRILL
WPRT
P
Stall, PUH, pull wiper early, PUW 45 k,
11,091.0
10,070.0
19:00
19:30
launch 5x5 sweep and chase to the
window
6/23/2019
6/23/2019
0.20
PROD1
DRILL
WPRT
P
Jog the 7" 10,070'-10,140', with 5x5
10,070.0
10,165.0
19:30
19:42
sweep, RBIH, RIW 15 k
6/23/2019
6/23/2019
0.15
PROD1
DRILL
DLOG
P
Log the RA marker correction of plus
10,165.0
10,192.0
19:42
19:51
1.5'
6/23/2019
6/23/2019
0.30
PROD1
DRILL
WPRT
P
Continue wiper back in hole, RIW 15 k
10,192.0
11,091.0
19:51
20:09
6/23/2019
6/24/2019
5.00
PROD1
DRILL
DRLG
P
BOBD, 1.86 bpm/4,461 psi/1,165 psi,
11,091.0
11,392.0
20:09
01:09
BHP=3,851, WHP=71, IA=373,
OA=371, Avg. ROP 101 fph, pumping
5x5 x 2
" Stalls 11,100', 11,159', 11,294', and
11,359'
6/24/2019
6/24/2019
1.45
PROD1
DRILL
DRLG
P
OBD, 1.89 bpm/4,858 psi/1,284 psi,
11,392.0
11,490.0
00:00
01:27
WHP=10, BHP=3,934, IA=372,
OA=370
6/24/2019
6/24/2019
0.30
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 39 k
11,490.0
10,690.0
01:27
01:45
Page 4/11 Report Printed: 711612019
. Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Tame
I End Time
Our (hr)
Phase
Op Code
Activfty Cade
Time P -T -X
Operation
Stars Depth
(rt De
End Depth (fiKa)
6/24/2019
6/24/2019
0.30
PRODII
DRILL
WPRT
P
Wiper back in hole
10,690.0
11,490.0
01:45
02:03
6/24/2019
6/24/2019
5.20
PROD1
DRILL
DRLG
P
BOBD, 1.89 bpm/4,613 psi/1,050 psi,
11,490.0
11,890.0
02:03
07:15
BHP=3,907, WHP=9, IA=372,
OA=389, pump 5x5 sweep
6/24/2019
6/24/2019
1.00
PROD1
DRILL
WPRT
P
Wiper to window, 39K PUW, chase
11,890.0
10,050.0
07:15
08:15
sweep, 2nd 5x5 sweep out at EOB,
chase to W LEG, jog 7" 2X,
6/24/2019
6/24/2019
0.25
PROD1
DRILL
DLOG
P
Log RA tag for depth control, (-t'
10,050.0
10,200.0
08:15
08:30
correction)
6/24/2019
624/2019
0.50
PROD1
DRILL
TRIP
P
RIH to drill, 12.61K RIW, bring rate up
10,200.0
11,890.0
08:30
09:00
to 1.88 bpm
6/24/2019
6242019
3.50
PROD1
DRILL
DRLG
P
OBD, 1.88 bpm/4,858 psU1,284 psi,
11,890.0
12,229.0
09:00
12:30
WHP=10, BHP=4007, IA=368,
OA=361,
6/24/2019
6/24/2019
0.40
PROD1
DRILL
WPRT
P
Wiper trip early, 43K PUW, ROP has
12,229.0
11,227.0
12:30
12:54
been zero for the last 45 min, drilling
low ROP, hard formation, Geo's
consulting if we are at the base of the
C4.
6/24/2019
6/24/2019
1.00
PROD1
DRILL
WPRT
P
RIH to drill, 12K RIW, 1.88 bpm, wait
11,227.0
12,229.0
12:54
13:54
on Geo's, change TF up and steer out
of low ROP stuff
6/24/2019
6/24/2019
1.80
PROD1
DRILL
DRLG
P
OBD, 1.88 bpm/4,930 psi/1,050 psi,
12,229.0
12,413.0
13:54
1542
WHP=10, BHP=4007
6/242019
6/24/2019
2.00
PRODi
DRILL
DRLG
P
ROP slow to near zero, 40K PUW,
12,413.0
12,413.0
15:42
17:42
pick 6X, wiper up 100', RIH,
624/2019
6/24/2019
1.30
PROD1
DRILL
DRLG
P
PU, PUW 42 k, BOBD, 1.85
12,413.0
12,610.0
17:42
19:00
bpm/5,069 psi/1,050 psi, WHP=13,
BHP=4,036, IA=366, OA=358
6/242019
6/24/2019
0.80
PROD1
DRILL
WPRT
P
Wiper to the window, PUW 42 k,
12,610.0
10,070.0
19:00
19:48
chase 5x5 sweep
6/24/2019
6124/2019
0.20
PRODi
DRILL
WPRT
P
Jog the 7inch x2
10,070.0
10,165.0
19:48
20:00
6/24/2019
6/24/2019
0.20
PROD1
DRILL
DLOG
P
Log the RA marker correction of minus
10,165.0
10,192.5
20:00
20:12
4.5'
6/24/2019
6/24/2019
1.00
PROD?
DRILL
WPRT
P
Continue wiper back to bottom, RIW
10,192.5
12,610.0
20:12
21:12
15 k
6/24/2019
6/25/2019
2.80
PROD1
DRILL
DRLG
P
BOBD, 1.89bpm/4,660 psi/1,040 psi,
12,610.0
12,824.0
21:12
00:00
WHP=14, BHP=3,990, IA=365,
OA=358
"• Note: New mud at the bit 12,637'
6/252019
6/25/2019
2.00
PROD1
DRILL
DRLG
P
OBD, 1.88 bpm/4,779 psi/1,043 psi,
12,824.0
12,991.0
00:00
02:00
WHP=12, BHP=4,017, IA=365,
OA=358
6/25/2019
6/25/2019
0.80
PROD1
DRILL
DRLG
P
OBD, 1.88 bpm/4,779 psi/1,043 psi,
12,991.0
13,004.0
02:00
02:48
WHP=12, BHP=4,017, IA=365,
OA=358
6/252019
6/25/2019
0.40
PROM
DRILL
WPRT
P
Wiper up hole to 12,210', PUW 40 k
13,004.0
12,210.0
02:48
03:12
6/25/2019
6/25/2019
0.30
PROM
DRILL
WPRT
P
Wiper back in hole, RIW 6 k
12,210.0
13,004.0
03:12
03:30
6/252019
6/25/2019
2.50
PROD1
DRILL
DRLG
P
BOBD, 1.89 bpm/4,757 psi/1,067 psi,
13,004.0
13,147.0
03:30
06:00
WHP=13, BHP=4,068, IA=366,
OA=361
6/25/2019
625/2019
2.40
PRODt
DRILL
DRLG
P
Continue drilling, 1.89 bpm/4780
13,147.0
13,290.0
06:00
08:24
psi/1046 psi, WHP=11, BHP= 4111 psi
6/25/2019
6/25/2019
2.10
PROD1
DRILL
DRLG
P
Send 5x5 Lo/Hi, Hi Vis has increased
13,290.0
13,337.0
08:24
10:30
lubes (2% LoTq and 776, each), see
little effect on surface weights
Page 5111 Report Printed: 7116120191
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
Dur (ht)
Phase
Op Code
Acdviry Code
Time P -T -X
Operation
(f2Ka)
End Depth (RKa)
6/25/2019
6/25/2019
0.10
PROD1
DRILL
WPRT
P
PIU off bottom, PUW=48K
13,337.0
13,337.0
10:30
10:36
6/25/2019
6/25/2019
1.20
PROD1
DRILL
DRLG
P
13337', Drill, 1.89 BPM @ 4780 PSI
13,337.0
13,410.0
10:36
11:48
FS. BHP=4085
6/25/2019
6/25/2019
1.30
PROD1
DRILL
WPRT
P
13410', Wiper to window, PUW=42K
13,410.0
10,165.0
11:48
13:06
6125/2019
6/2512019
0.50
PROD1
DRILL
WPRT
P
Make three recipts in 7" casing
10,165.0
10,165.0
13:06
13:36
6/25/2019
6/2512019
0.10
PROD1
DRILL
DLOG
P
Log RA for-4.5'correction
10,165.0
10,191.4
13:36
13:42
6/25/2019
612512019
1.20
PROD1
DRILL
WPRT
P
Continue wiper trip back to bottom
10,191.4
13,410.0
1342
14:54
6/25/2019
6125/2019
3.80
PROD1
DRILL
DRLG
P
Drilling, CWT -8K, WOB variable,
13,410.0
13,524.0
14:54
18:42
struggling w/ weight transfer, annular
= 4211 psi, pump = 5204 psi
6/25/2019
6/25/2019
3.30
PROD1
DRILL
DRLG
P
Drilling, CWT= -7.5K, WOB = 0.9K,
13,524.0
13,607.0
18:42
22:00
pump beaded pill, annular =4175 psi,
pump = 5288 psi, PUW = 48K from
13,552', avg ROP = 25 fph, lower ROP
beginning at •13,600' (2-15 fph)
6/25/2019
6126/2019
2.00
PROD1
DRILL
DRLG
P
Drilling, CWT =OK, WOB =2.3K,
13,607.0
13,680.0
22:00
00:00
annular = 4244 psi, pump = 5272 psi,
continue pumping beaded pills to
maintain weight treater, PUW = 43K
from 13,680', vibrations in yellow &
red, PU to grab surveys (prior difficulty
due to vibrations)
6/26/2019
6/26/2019
2.00
PROD1
DRILL
DRLG
P
Drilling, CWT= -6K, WOB 2.2K,
13,680.0
13,705.0
00:00
02:00
annular = 4278 psi, pump = 5362 psi,
continued lower ROP w/ Siderite in
samples, vibrations to 5, reduce rate
to 1.75 bpm, vibrations drop to 4's,
avg ROP = 12.5 fph
6/26/2019
6/26/2019
1.50
PROD?
DRILL
DRLG
P
Drilling, CWT= -5.8K, WOB =2.3K,
13,705.0
13,730.0
02:00
03:30
annular = 4255 psi, pump = 5035 psi,
continued low ROP (-10 fph),
continue pumping beaded pills
6/26/2019
6/26/2019
2.50
PROD1
DRILL
DRLG
P
Drilling, CWT= -3.8K, WOB =1K,
13,730.0
13,810.0
03:30
06:00
annular = 4276 psi, pump = 5153 psi,
ROP increased at -13,724'(-50-75
fph), bring rate up to 1.9 bpm
6126/2019
6/26/2019
1.00
PROD1
DRILL
WPRT
P
Pull 1000' Wiper trip, PUW=40K.
13,810.0
13,810.0
06:00
07:00
6/26/2019
6/26/2019
2.40
PRODI
DRILL
DRLG
P
13810', Drill, 1.8 BPM @ 5184 PSI
13,810.0
13,892.0
07:00
09:24
FS, BHP=4259, RIW=-2.5K,
DHWOB=.6K, Initial ROP=65 FPH
6/26/2019
6/26/2019
0.10
PROD1
DRILL
WPRT
P
Encounter heavy vibrations @13670
13,892.0
13,892.0
09:24
09:30
4's to5'. P/U @ 13892 lower Flow rate
to 1.7
6/26/2019
6/26/2019
1.50
PROD1
DRILL
DRLG
P
13892 Drill @ 1.7 BPM @ 4943 PSI
13,892.0
13,900.0
09:30
11:00
FS. Still high vibrations. Low ROP 5
FPH
6/26/2019
6/26/2019
0.10
PROD1
DRILL
WPRT
P
Pick up off bottom with high vibration,
13,900.0
13,900.0
11:00
11:08
1
1PUW=43K,
Lower rate to 1.62 BPM
6126/2019
6/26/2019
4.50
PROD?
DRILL
DRLG
P
13900', Drill, 1.62 BPM @ 4789 PSI
13,900.0
14,016.0
11:06
15:36
FS, ROP -5 FPH, 13916 ROP up to
44 FPH
6/26/2019
6/26/2019
1.20
PROD1
DRILL
WPRT
P
14016', Pull Geo viper, PUW=42K.
14,016.0
14,016.0
15:36
16:48
Come up to 13,600'. Set down at
13,900'. Had to work through tight
area. went through @ 140R. reduce
pump rate
Page 6111 Report Printed: 7116/2019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(fiKB)
End Depth (flKa)
6/26/2019
6/26/2019
2.20
PROD1
DRILL
DRLG
P
14016', Drill 1.85 BPM @ 5225 PSI
14,016.0
14,094.0
16:48
19:00
FS, BHP=4404
6/26/2019
6/26/2019
2.70
PROD1
DRILL
DRLG
P
Drilling, CWT= -6.3K, WOB =1.5K,
14,094.0
14,138.0
19:00
21:42
annular = 4427 psi, pump = 5456 psi,
vibrations up to 5, reduce rate to 1.7
bpm, avg ROP = 16.3 fph
6/26/2019
6/27/2019
2.30
PROD1
DRILL
DRLG
P
Drilling, CWT= -3.5K, WOB =1.3K,
14,138.0
14,210.0
21:42
00:00
annular = 4379 psi, pump = 5081 psi,
pumping beaded pills to maintain
weight transfer, pump 5x5 sweeps
6/27/2019
6/27/2019
1.80
PROM
DRILL
WPRT
P
Wiper up -hole to window, PUW = 38K,
14,210.0
10,075.0
00:00
01:48
dean in OH, clean through window,
jog 7" casing, swapping to pump 2
(leaking #3 cylinder on pump 1), PUW
= 34K @ window
6/27/2019
6/27/2019
0.10
PRODi
DRILL
DLOG
P
RBIH, clean through window, log RA
10,165.0
10;195.0
01:48
01:54
tag for -5.5' correction
6/27/2019
6/27/2019
2.60
PROD?
DRILL
WPRT
P
Continue RIH, CWT falling off at
10,195.0
14,210.0
01:54
04:30
-12,645', reduce rate to 1.4 bpm,
again reduce to 1.25 bpm, pump
beaded pill, reduce run in speed,
beads begin to exit bit at 13,445',
reduce rate to 0.5 bpm & 5 fpm
working to bottom, pump additional 10
bbl beaded pill, stacking weight,
multiple PU's working to bottom
6/27/2019
6/27/2019
4.50
PRODi
DRILL
DRLG
P
Drilling, FS = 1133 psi @ 1.8 bpm,
14,210.0
14,297.0
04:30
09:00
CWT= -6.5K, annular =4466 psi,
pump = 5430 psi. Pumping beaded
sweeps as needed. Pick ups as
required
6/27/2019
6/27/2019
3.30
PRODt
DRILL
DRLG
P
Got to 6543' TVD at 85° Inc. Close to
14,297.0
14,378.0
09:00
12:18
C3 interface. Build angle up to 105°
and hold. 1.79 BPM @ 4930 PSI FS,
BHP=4398
6/27/2019
6/27/2019
0.10
PROD1
DRILL
WPRT
P
14378, BHA Wiper, PUW=39K
14,378.0
14,378.0
12:18
12:24
6/27/2019
6/27/2019
5.10
PROD1
DRILL
DRLG
P
14378, Drill, 1.79BPM @ 4930 PSI
14,378.0
14,494.0
12:24
17:30
FS, BHP=4481. Continue with beaded
pills as needed, ROP=20-30 FPH
6/27/2019
6/27/2019
2.50
PROD1
DRILL
DRLG
P
Drilling, CWT= -8K, WOB < 1K,
14,494.0
14,523.0
17:30
20:00
annular = 4222 psi, pump = 5033 psi,
pump 50 bbl beaded pill
6/27/2019
6/28/2019
4.00
PROD1
DRILL
DRLG
P
Drilling, CWT = -91K, WOB below 1 K,
14,523.0
14,587.0
20:00
00:00
annular = 4240 psi, pump = 4499 psi,
50 bbl beads hit the bit at 14,525',
continue pumping 50 bbl beaded pills,
continual PUS to stay drilling, avg
ROP = 16 fph
6/28/2019
6/28/2019
3.00
PROM
DRILL
DRLG
P
Drilling, CWT= -8K, annular =4297
14,587.0
14,630.0
00:00
0300
psi, pump 5540 psi, continual PU's &
beads to drill, avg ROP = 14 fph
6/28/2019
6/28/2019
1.50
PROD1
DRILL
DRLG
P
Drilling, annular =4267 psi, pump =
14,630.0
14,645.0
03:00
04:30
5167 psi, TD called at 14,645', allow
10x10 sweeps to exit bit
6/28/2019
6/28/2019
3.40
PRODt
DRILL
WPRT
P
Wiper to swab, PUW = 38K
14,645.0
78.0
04:30
07:54
6/28/2019
6/28/2019
1.80
PROD1
DRILL
WPRT
P
Tag up at surface, reset counters, Trip
78.0
9,960.0
07:54
09:42 1
1
1
1
1
1in
well
6/282019
6/28/2019 i
0.10
PROD1
DRILL
DLOG
P
Log K1 for -21' correction
9,960.0
10,011.2
09:42
09:48
6/28/2019
6/28/2019
0.10
PROM
DRILL
WPRT
P
Continue in well
10,011.2
10,130.0
09:48
09:54
Page 7111 Report Printed: 711812019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Sf Time
End Time
our (hr)
Phase
Op Code
Activity Corte
Time P-T-X
Operation
(VS)
End DepN (ftKa)
6/28/2019
6/28/2019
0.40
PROD1
DRILL
PRTS
P
Obtain BHP, ND @ 6406.7,
10,130.0
10,130.0
09:54
10:18
ANN=3558, EMW=10,68 PPG
6/28/2019
6/28/2019
0.10
PROD1
DRILL
WPRT
P
PUH for testing
10,130.0
10,000.0
10:18
10:24
6/28/2019
612812019
0.10
PROW
DRILL
WPRT
P
Pull 10,000 to 9800', PUW=34K,
10,000.0
9,800.0
10:24
10:30
DHWOB=-.1 K, Pumping 1/2 BPM, 50
FPM
6/28/2019
6/2812019
0.40
PROD1
DRILL
WPRT
P
9800', Trip in to 11,200
9,800.0
11,200.0
10:30
10:54
6/28/2019
6128/2019
0.10
PRODi
DRILL
WPRT
P
11,200' PUH to 11,000'. PUW=35K,
11,200.0
11,000.0
10:54
11:00
DHWOB=-.1 K, 50 FPM, .5 BPM
6/28/2019
6/28/2019
0.40
PROD1
DRILL
WPRT
P
11000', Trip in to next test interval
11,000.0
12,200.0
11:00
11:24
6/28/2019
6/28/2019
0.10
PROD1
DRILL
WPRT
P
12,200' PUH to 12,000', PUW=37.3K,
12,200.0
12,000.0
11:24
11:30
DHWOB= -.2K, 50 FPM, .5 BPM
6/28/2019
628/2019
0.40
PRODt
DRILL
WPRT
P
12000', trip in to next test interval
12,000.0
13,200.0
11:30
11:54
6/28/2019
6/28/2019
0.10
PRODt
DRILL
WPRT
P
13200', PUH to 13,000'. PUW=37K,
13,200.0
13,000.0
11:54
12:00
DHWOB= -.4K, 50 FPM, .5 BPM
6/28/2019
6/28/2019
1.80
PRODt
DRILL
WPRT
P
Continue in hole to confirm TD, Had to
13,000.0
14,637.0
12:00
13:48
work from 14,627. Call TO Q 14,637
6/282019
6/28/2019
0.60
FROM
DRILL
CIRC
P
Wait for 11.1 PPG KWF pumped 55
14,637.0
14,637.0
13:48
14:24
BBIs followed by 50 BBLs beaded
liner running pill
6/28/2019
628/2019
0.50
FROM
DRILL
TRIP
P
Start out of hole, Paint yellow flag @
14,637.0
13,000.0
14:24
14:54
13,868'. Continue out
6128/2019
6/28/2019
0.10
PROD1
DRILL
TRIP
P
13000' Trip into 13,200', RIW=13K,
13,000.0
13,200.0
14:54
15:00
DHWOB=.4K, .5 BPM, 50 FPM
6/28/2019
6/28/2019
0.40
PROD1
DRILL
TRIP
P
POOH to 12,000'
13,200.0
12,000.0
15:00
15:24
6/28/2019
6/28/2019
0.10
PROD1
DRILL
TRIP
P
12000'Trip into 12,200', RIW=14.2K,
12,000.0
12,200.0
15:24
15:30
DHWOB=.1 K, .5 BPM, 50 FPM
6/28/2019
628/2019
0.40
PROD1
DRILL
TRIP
P
POOH to 11,000'
12,200.0
11,000.0
15:30
15:54
6/28/2019
628/2019
0.10
PROD1
DRILL
TRIP
P
11000' Trip into 11,200', RIW=15.7K,
11,000.0
11,200.0
15:54
16:00
DHWOB= .1K , .5 BPM, 50 FPM
6/2812019
6/2812019
0.40
PROD1
DRILL
TRIP
P
POOH to 9800'
11,200.0
9,800.0
16:00
16:24
6/28/2019
6128/2019
0.10
PROD1
DRILL
TRIP
P
9800' Trip into 10,000', RIW=16K,
9,800.0
10,000.0
16:24
16:30
DHWOB= .1 K , .5 BPM, 100 FPM
6/28/2019
6/28/2019
2.10
PRODi
DRILL
TRIP
P
POOH to surface, flow check, PJSM
10,000.0
78.0
16:30
18:36
6/28/2019
6/28/2019
1.20
PROD?
DRILL
PULD
P
LD BHA #4, UT coil, minimum
78.0
0.0
18:36
19:48
thickness = 0.180" & caliper coil,
1.983" to 2.005" OD, min wall
thickness, bit came out a 1-3 (2
chipped reamer cutters)
6/28/2019
628/2019
0.70
FROM
CASING
BOPE
P
Function test BOP's
0.0
0.0
19:48
20:30
6/28/2019
6/28/2019
2.10
COMPZI
CASING
PUTB
P
PJSM, PU liner run #1 (NP BN, 25 jnts
0.0
778.0
20:30
22:36
slotted liner, alternating 24 i-wheels, &
shorty deployment sleeve), -4.6 bph
static losses, crew change, no issues
MU i-wheels
Note: 60K max pull on i-wheel per
impact solutions rep
6/28/2019
6/28/2019
0.70
COMPZI
CASING
RUNL
P
Begin RIH w/BHA #5
840.0
3,575.0
22:36
23:18
6/28/2019
6/29/2019
0.70
COMPZI
CASING
PULD
P
PU BHA#5 Liner Running Tools,
778.0
840.0
23:18
00:00
change out checks, MU to coil, tag up,
set counters
Page 8111
Report Printed: 7/16/2019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depen
start Time
End Time
our (hr)
Phase
Op Code
Adivity Code
Time P -T -X
Operation
(WB)
End Depth(WB)
6/29/2019
6/29/2019
1.20
COMPZI
CASING
RUNL
P
Continue RIH w/ liner, -10.5' correction
3,575.0
10,000.0
00:00
01:12
to window flag, PUW = 37K
6129/2019
6/29/2019
0.10
COMPZI
CASING
RUNL
P
10,000' PUH to 9,800', CWT= 35K,
10,000.0
9,800.0
01:12
01:18
DHWOB = -0.1 5K, 0.5 BPM, 100
FPM
6/29/2019
6/29/2019
0.30
COMPZI
CASING
RUNL
P
Continue RIH, pumps off, slow to 30
9,800.0
10,740.0
01:18
01:36
fpm through window, first 3 i -wheels
through dean, increase to 50 fpm
6/29/2019
6/29/2019
0.10
COMPZI
CASING
DLOG
P
Log Kt for 4' correction
10,740.0
10,767.0
01:36
01:42
6/29/2019
6/29/2019
0.10
COMPZI
CASING
RUNL
P
Continue RIH
10,767.0
11,200.0
01:42
01:48
6/29/2019
6/29/2019
0.10
COMPZ1
CASING
RUNL
P
PUW = 40K, 11,200' PUH to 11,000',
11,200.0
11,000.0
01:48
01:54
CWT=37KK, DHWOB = -0.6K, 0
BPM, 50 FPM
6/29/2019
6/29/2019
0.50
COMPZI
CASING
RUNL
P
Continue RIH, RIW = 13.5K
11,000.0
12,200.0
01:54
02:24
6/29/2019
6/29/2019
0.10
COMPZI
CASING
RUNL
P
PUW = 40K, 12,200' PUH to 12,000',
12,200.0
12,000.0
02:24
02:30
CWT =39K, DHWOB = -2.74K, 0
BPM, 50 FPM
6/29/2019
6/29/2019
0.40
COMPZI
CASING
RUNL
P
Continue RIH, RIW = 11K
12,000.0
13,200.0
02:30
02:54
6/29/2019
6/29/2019
0.10
COMPZI
CASING
RUNL
P
PUW = 40K, 13,200' PUH to 13,000',
13,200.0
13,000.0
02:54
03:00
CWT =38K, DHWOB = -2.4K, 0
BPM, 50 FPM
6/29/2019
6/29/2019
0.70
COMPZI
CASING
RUNL
P
Continue RIH to bottom, PUW =46K,
13,000.0
14,631.0
03:00
03:42
set down 3K WOB, bring up pumps,
reach 1000 dp, PU & release off liner,
PUW = 36K
6/29/2019
6/29/2019
1.30
COMPZI
CASING
TRIP
P
POOH, pumping down the back -side,
14,631.0
9,950.0
03:42
05:00
paint window flag at 9244.2'
6/29/2019
6/29/2019
0.10
COMPZI
CASING
DLOG
P
Log Kt for+1.5'
9,550.0
9,965.0
05:00
05:06
6/29/2019
6/29/2019
1.80
COMPZI
CASING
TRIP
P
Continue out of well. Paint 9200' EOP
9,965.0
60.0
05:06
06:54
flag
6/29/2019
6/29/2019
0.60
COMPZI
CASING
PULD
P
At surface, flow check well. Good,
60.0
0.0
06:54
07:30
PJSM lay down liner running tools
6/29/2019
6/29/2019
1.00
COMPZ1
CASING
RURD
P
Prep floor to run liner, Inspect CT min
0.0
0.0
07:30
08:30
wall thicknes .160
6/29/2019
629/2019
1.20
COMPZ1
CASING
PUTB
P
P/U Ll liner intermediate section. 25
0.0
790.8
08:30
09:42
1
As no wheels
6/29/2019
6/29/2019
0.80
COMPZI
CASING
PULD
P
M/U coiltrak to liner, Surface test tool.
790.8
835.1
09:42
10:30
Tag up and set oouners
6/29/2019
6/29/2019
1.70
COMPZI
CASING
TRIP
P
Trip in hole BHA #6
835.1
10,000.0
10:30
12:12
6/29/2019
6/29/2019
0.05
COMPZI
CASING
TRIP
P
Test pull, 10,000'to 9800' PUW=36K,
10,000.0
9,800.0
12:12
12:15
DHWOB=-.67, 100 FPM
6/29/2019
6/29/2019
0.05
COMPZI
CASING
TRIP
P
Continue in well
9,800.0
10,052.5
12:15
12:18
629/2019
6/29/2019
0.10
COMPZI
CASING
DLOG
P
Tie into flag for -17.9'
10,052.5
10,034.0
12:18
12:24
6/29/2019
6292019
0.20
COMPZI
CASING
TRIP
P
Continue in well. Clean pass through
10,034.0
10,730.0
12:24
12:36
j
window, Log K1 for -2.5'
6/29/2019
6/29/2019
0.10
COMPZI
CASING
DLOG
P
Log K1 for -2.5' Stop and make
10,730.0
10,759.0
12:36
12:42
correction
629/2019
6/29/2019
0.20
COMPZI
CASING
TRIP
P
Trip in, Set down @ 10780'. PUH then
10,759.0
11,200.0
12:42
12:54
set down again. PUW=44K,
DHWOB=5K, Coil connector@
9945', GS @ 9989. Pick up then run
through.
Page 9/11 ReportPrinted: 7/1612019
Operations Summary (with Timelog Depths)
1c-19
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
I
Steri Time
End Time
our inn
Phase
Op Code
Acdi fty Code
Time P -T -X
Operation
(MB)
End Depth (ftM)
6/29/2019
6/29/2019
0.10
COMPZI
CASING
TRIP
P
11,200. PUH to 11,000'@ 50 FPM,
11,200.0
11,000.0
12:54
13:00
PUW=38.5K. DHWOB=-1.25K,
RIW=15K
6/29/2019
6/29/2019
0.40
COMPZ11
CASING
TRIP
P
Continue in hole,
11,000.0
12,200.0
13:00
13:24
6/29/2019
6/29/2019
0.10
COMPZ1
CASING
TRIP
P
12,200', PUH to 12,000'. PUW=40K,
12,200.0
12,000.0
13:24
13:30
DHWOB= -.SK, 50 FPM, RIW=14.5K
6/29/2019
6/29/2019
0.30
COMPZ1
CASING
TRIP
P
Continue in hole
12,000.0
13,200.0
13:30
13:48
6/29/2019
6/2912019
0.10
COMPZ1
CASING
TRIP
P
13,200', PUH to 13,000'. PUW=40K,
13,200.0
13,000.0
13:48
13:54
DHWOB= -.31K, 50 FPM, RIW=14K
6/29/2019
6/2912019
0.30
COMPZ1
CASING
TRIP
P
13000', Continue in hole, Clean trip to
13,000.0
13,840.0
13:54
14:12
tag up @ 13,840', RIW=13.8K
6/29/2019
1612912019
0.20
COMPZ1
CASING
TRIP
P
13,840', PUH to 13361 for agitator
13,840.0
13,361.0
14:12
14:24
lest, PUW=35K
6/29/2019
6/29/2019
0.20
COMPZ1
CASING
TRIP
P
RIH, RIW=13.6K, Pumping 1 BPM @
13,361.0
13,840.0
14:24
14:36
1717 PSI FS, BHP= 4051 PSI. Slick
trip to tag up @ 13840'
6/29/2019
6/29/2019
0.20
COMPZ1
CASING
TRIP
P
Pump off liner, PUW=33K, Remove
13,840.0
13,029.7
14:36
14:48
liner length left in hole from counters
791.43'
6129/2019
6/29/2019
1.20
COMPZ1
CASING
CIRC
P
Line up and pump 50 BBL beaded
13,029.7
13,000.0
14:48
16:00
liner running pill
6/29/2019
6/29/2019
2.70
COMPZ1
CASING
TRIP
P
Trip out, flow check, PJSM
13,000.0
70.0
16:00
18:42
6/29/2019
6129/2019
0.80
COMPZ1
CASING
PULD
P
LD BHA #6
70.0
0.0
18:42
19:30
6/29/2019
6/30/2019
4.50
COMPZ1
CASING
PUTS
P
PU Liner Run #3 (1.25" ported BN,
0.0
2,990.0
19:30
00:00
pup, 97 jnts slotted, & shorty
deployment sleeve)
6/30/2019
6/30/2019
0.80
COMPZi
CASING
PULD
P
PU BHA#7 liner running tools
2,990.0
3,043.0
00:00
00:48
(including NOV agitator), pack -offs
good, change out checks, MU to coil,
tag up, set counters
6/30/2019
6/3012019
2.50
COMPZI
CASING
RUNL
P
RIH w/ Liner Run #3, BHA#7, -13.5'
3,043.0
13,050.0
00:48
03:18
correction to window flag, PUW = 38K,
arrive at set depth, PUW = 46K, RBIH,
set down 3.6K wOB, bring up pumps,
PU & release off liner, PUw = 34K,
TOL -10,050'
6/30/2019
6/30/2019
0.30
DEMOB
WELLPR
DLOG
P
Adjust depth for liner release.
13,050.0
10,035.0
03:18
03:36
Obtain SBHP per procedure: MD =
10035.84', TVD sensor = 6440.92,
annular = 3733 psi, EMW = 11.16 ppg
6/30/2019
6/30/2019
1.00
DEMOB
WELLPR
DISP
P
Displace well to seawater, PUW = 34K
10,035.0
2,500.0
03:36
04:36
6/30/2019
6/30/2019
1.10
DEMOB
WELLPR
TRIP
P
Trip out of well. PUW=32K
10,035.0
2,500.0
04:36
05:42
6/30/2019
6/30/2019
0.70
DEMOB
WELLPR
FRZP
P
RU LRS, PT to 4500 psi, freeze
2,500.0
44.0
05:42
06:24
protect from 2500' to surface
6/30/2019
6/30/2019
1.60
DEMOB
WELLPR
PULD
P
Tag up, PJSM, PUD BHA V. Liner
44.0
0.0
06:24
08:00
running tools, Lay down tools
6/30/2019
6/3012019
1.00
DEMOB
WELLPR
CIRC
P
M/U nozzle, Stab back on. Jet stack.
0.0
0.0
08:00
09:00
Pump 30 BBL corrosion inhibitor pill.
Flush rig and stack
6/30/2019
6/30/2019
1.50
DEMOB
WELLPR
CTOP
P
PJSM w/ HES N2 pumper. Perform N2
0.0
0.0
09:00
10:30
reel blow down. Bleed off N2 m CT
6/30/2019
6/30/2019
0.50
DEMOB
WELLPR
CTOP
P
Unstab injector, Break on LOC; & CTC
0.0
0.0
10:30
11:00
Page 10111 Report Printed: 7/16/2019
Operations Summary (with Timelog Depths)
%0
1 C-19
Rig:
NABORS CDR3-AC
Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
I End Time
our (hr)
Phase
Op Code
Activity Cade
Time P -T -X
Operation
(flKB)
End Depth (flKB)
6/30/2019
6/30/2019
3.50
DEMOB
WELLPR
CTOP
P
Install stabbing grapple in CT PJSM
0.0
0.0
11:00
14.30
unstab coil. pull back to storage reel
and secure. Roll spool into position
and install lifting shackles on reel
6/30/2019
6/30/2019
4.50
DEMOB
WHDBOP
NUND
P
PJSM, Nipple down BOPE - pour
0.0
0.0
14:30
19.00
methonal in tree, completeRD
checklist break -down tiger tank line,
pull mats, secure stairs & landings.
" Rig released 6/30/19 @ 19:00 hrs
Page 11/11
Report Printed: 7/16/2019
ConocoPhillips
ConocoPhillips Alaska Inc_Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
1C-191-1
50-029-23149-60
Baker Hughes INTEQ
Definitive Survey Report
25 July, 2019
BA ER
P UGHES
a GE<ompeny
Conmollhillips
u�cN6s
COIIOCOPIIlllps
Definitive Survey Report
Co.,., ConeaPhinips Alaska Inc-Kuparuk
L9al Coerdlnaa Rehrtnse: Well 1C-19
Project: Kupamk River Unit
TVD Rsftmna: 1C-19:®8).00usn(1 C-19)
Slla: Kupamk 1C Pad
MD RelamrNe: 1CAN: ® 87.00usn (1 C-19)
Well: 1C-19
North Rep..: True
We0bom 1C-1911
Survey Calculation Method: Minimum Curvature
1pt 10-19L1
Dalabase: OAKEDMP1
Projaat Kupamk River Unit, North Slope Alaska, United Slates
Map Sysmm: US 51d* Plane 1927 (Exact solution)
System Datum: Mean Sea Level
Gee Datum: NAD 1927(NAOCON CONUS)
Using Well References Point
area Zone: Alaska Zone 04
Using geodetic scale (aper
—�
Well lC-19
Well Position .W4 000 use
Northing: 5968,624.28usit
Latitude:
70.19'29.287N
. -W 000 usg
Easting: 562,368.18usH
Longitude:
149.29'39382W
Position Uncertainly 000 us0
Wellhead Elevation: Usti
Ground Level:
0.00 unit
Wellbore 1C-19L1
Magnetics Model Name Sample Data
Decgnsllon Dip Angle
Field Strength
(I
rl
Inn
MGM2018 8)112019
16.53
80.87
57,411
Design 1C-1911
Audit Notes:
Version: 1.0 Phass: ACTUAL
Tie On Depth: 10,115.74
Vertical Section: Depth From(M)
.NW .0m
Direction
IeMg
(Ilan) lusnl
(1)
07.00
099 ang
MID
survey Program _Date
_
From To
Survey
Survey
(esR) (Ush) Survey MV Mon)
Tool Nemo Description
SMn Daft
End Dab
138.00 10,115.74 10.19 Baker (1 C-19)
MWID OMG 0WGG MWD- Standard
512]2003
10,143.00 10,171.05 1C-1911 MWTI-INC (1C-19L1)
MW0.1NC_ONLV MW0.1NC ONLY_FILLER
6222019
6212019
10,201.01 14,604.41 /(-191.1 MWO(tO19L1)
MWD OWSG CMG MWD-Standard
6282019
612012019
72Y1019 390.'06pM
Pepe 2
COMPASS 500014 Bu8de5D
,
ConocoPhiilips
% 6
Conoct4itinlips
Definitive Survey Report
Compary.
ConawPollips
Alaska
Inc_ Kupamk
Local Co<rainah Reprence:
Wall 1719
Project:
Kupamk River
Unit
TVD Reference:
1C-19:®81.0usB(1C-19.)
Site:
Kupamk lC Pad
MD Reference:
1C-19:® 87.DDu4n(1O19:)
Well,
1019
None Reference'.
Tme
Wellbore:
171911
Survey Calculation
Method:
Minimum
Curvature
Deagn
1(>1911
Database:
DAKEDMPI
6urv.Y
Map
Map
Vesical
MD
lu
m
m
mm
aW4
awm
NO
Ea(itinp
DLS
Section Survey Tool Name
Annotation
I -R)
(1
11)
(14-26)
(haft)
(-am
(U(111
(el
(it)
(•1100')
lnl
10,115.74
33.69
31.76
8,521.93
6434.93
5,0'%1.90
3,924.18
5,9]4.491.9
SE6,2i9.40
I67
5,827.90 MWUINC ONLY (2)
TIP
15,14300
33.07
31.2
6544.69
6,457,69
504065
3,948.06
5,9744%76
566,26!19
220
S.B40.65 M INC ONLY(2)
KOP
10,1]195
40.22
27.40
6,56].63
6,4&183
5,05563
3.95651
5974,512.M
56695.51
23.40
5.855 M
63 WUINC ONLY(2)
IniePolated knonuth
10, 201 U1
WOR
2TQ
6588,37
6,501.37
5,87396
366,2
5,9]4,53].43
560,284.85
33.85
5,073.96 NAME) OWSG(3)
10231,28
5&24
26.09
6,605.01
6,518.81
5,89602
3977.11
5,974,55259
566,295]8
3t09
5,096.02 MrW OWSG(3)
1026137
6913
2553
6,618.85
6.53195
Sa.4o
3,998.90
5,974,57.06
SW,30736
3225
5,926,40 "JVD OWSG(3)
10,2913]
]0.]6
2556
6627.11
6,540.11
5,94628
4.001.28
5.974,60305
566,319.52
R21
5.946.29 MJJD OW6G(3)
10,32404
09.51,
24.14
663.44
6,543.44
5,97&83
4,014.95
5.064,06210
566,33295
33.27
5,975.83 MJN OWSG(3)
10,354.03
9224
25.19
6.6ffi96
6.542.98
860300
4.02UB
5,974,66916
56,345.23
9,57
6,003.08 Mt DOWSG(3)
10,30359
846
2831
6628.14
6,W.14
8,02964
406.27
59]086,]1
56,35782
9.61
6.029.64 MbD OWSG(3)
10,413.85
9559
2]52
8.825.30
6,538.30
6,05653
4'm.92
5,974,71371
506,3]124
487
6,058.53 aMD CMG (3)
10443.6
856
2&52
6622.46
6535.46
6,00273
4.06].0]
5,9]4.]40,02
56.384.97
335
6,62.73 MMD OWSG(a)
10,4]6A2
9504
29.6
6619.41
6,532.41
6,111,22
4.63.70
5,974,76,W
56,46.5
3]9
6.111,22 MhD OWSG(3)
10,503]6
95.26
30.6
6616,95
6,58.95
6,130.84
4,067.25
5,974]623]
56,413.91
192
6,134.64 MVND OWSG(3)
1053393
9082
31,14
6,614.30
6,57.30
8,1670
4,112.55
5,974,018.36
5648,00
379
6,160]0 MIND OWSG(3)
1.64,70
90.52
31,41
6611.79
6,524.79
610690
418.51
5974.844,7
56,424.74
131
6,16.98 Miff) OWSG(3)
10580.31
9399
3254
6609.60
658.60
6211.96
4,1".11
5974,869.06
56,406,12
0.22
6.211,96 MMDOWSG(3)
10,8425
938
3297
6607,8
dM72
6,237,09
4,16.27
5,974,8%.14
56.4]8.00
294
6.237.09 MJN OWSG(3)
10,65471
92.06
3306
8,60617
6519.17
6,26249
4.1]].01
59]4,926.6]
5649260
344
6.%249 MrYD OWSG(3)
1068387
92.43
35.84
6,60490
6.517.90
6.28149
4193,70
5,974940.01
56,599.09
690
6,26.49 MIAD OWSG(3)
10]10.65
9187
366
660372
6,516]2
6311,22
4211,83
5,9]4.96.6
SW 527,01
303
6,311.8 MMD OWSG(3)
10740.7
92.24
7.6
680261
6.51561
6,33620
4,230.01
5,974,993.01
56,5".99
347
6,335.20 MMD OW5G(3)
10,73.W
91.35
3Z6
6.601.71
651471
6,366
4,4].64
5,975,01681
56,56243
3 S
6,356.05 MJN OWSG(3)
10.64.6
90.81
3&45
5601.11
6,514.11
8,38247
4,266]5
5,975,54138
56,501.33
302
6383.47 MiMD OWSG(3)
10834.7
90%
3&8
6666.63
6,513.63
64600
4.265.43
5,975,6.14
56,599.82
.7
6,406.08 MJUD OWSG(3)
10,60.61
015
3804
0.599.90
6,512.98
642954
4.W186
5,9]5,081.]6
56,618.04
190
6,429.54 ~OWSG(3)
10,090.]3
91.5]
3]06
8,599,9
6.512.1]
5,4641
4,321]1
5.975.112"
506,636.20
3.16
6,453.41 MMD OWSG (3)
10.923.8
92.27
3606
65968
6,5tt8
6,4]633
4,339.8
5,9]5,1%.83
5665.02
4.30
647633 MhD OW6G(3)
10,95395
9227
3561
6597.01
6,510.01
64501,08
4,35].11
5,9]5,106]3
5667069
1.54
650108 MJUD CMG (31
to,904.1
9273
34.52
6595.65
6.56.65
6.52640
437488
59]&16,19
56,688.25
392
6,526.40 MM)OWSG(3)
]1252019 3.90:06PM
Pepe 3
Co81PA55 5000.14 Budd BSD
ConocoPhillips , 4
ConocoPhillips Definitive Surrey Report
Company.
C.m..PhINps Alaska lnc_Kupamk
LOW C Glnah ReN1e11ce:
5081110-19
PrOi
Kupamk River Unit
TVD Rafarince:
1C-19:@ 9.Musn(70-19:)
SM:
Kupamk 1C Pad
MD Roporaii
1C-19:@ 87.Nusrt (1019:)
Wall
1C-19
Ninth Rafnami
hue
WellEom:
1C-1gL1
Survey Cticulatian Mimi
Minimum Curvatme
Design:
1C -19L1
CalaEaie:
OAKEDMPI
74iWX)19 8'00:06PM Page 4 COMPASS 5000.149uiIE 850
Map
Map
'Ant1dal
MO
Inc
M
TVD
Noss
ANIS
+&-W
Within,
Sun,
OLS
$MAIn.1
survey Tool Nano: Annolalwn
IuMtl
Iry
hl
IaaM
laanl
laanl
19an)
Irtl
(ft)
1°nggl
Irl 1
71014.75
9295
34.72
6,59417
6507.17
6551.01
439187
5,975210.93
5.705.03
099
6,551.01 MND MSG (S) '
II.M4.13
93.29
.47
6,59257
6,550.5]
6.575.30
440B.31
5,975,23536
566.721.27
4.40
695.30 MND MSG (3)
11.50369
93.
31.19
6,59083
6,503.03
6,60012
4.424.64
5,975,26032
566,737.39
1.07
660012 MWDOWSGI3) '
11.104.63
91.96
31.5
6.589.36
6,502.38
6.,1
44,4101
5,95806.42
561
7.91
6,626,10 MWDOWSG(3)
11133.5
9209
31,27
6.58&37
8,501.37
6,650.55
4455.86
5.975,311.00
5W 7W 19
046
6,650.55 MWD MSG (3)
11.16427
91.97
30.34
6.5927
6,550.9
6,6719
4471.73
5.975,337.75
5.711.83
302
6,677.17 MND MSG (3)
11.194.47
9270
2946
658604
645004
6,703.33
4.413677
5.95,384.03
San 791
378
6.703.33 MND MSG (S)
11.224.$
90.09
5.9
6,5055
6,490.30
6)5.98
4,50068
5,95,39079
566.81234
1529
6,89.98 MND MSG (3)
11254.39
90.12
26.9
65855
649,125
6.756.81
4.51374
5,975.41713
565826.18
188
6755.81 MWD MSG (3)
H,204.63
9034
5.96
6,58513
6,498.13
6703.85
452720
5,95.444.9
565.835.49
252
6.763.65 MWD OWSG(3)
11314.59
9030
5.45
8.50495
8,497.85
0,91062
4540.74
5.95,471.75
swesl.3
1.70
6,01062 MWD MSG (3)
H,N4.W
91.53
25.75
6,584.47
649747
6,83707
4553]0
5,95AMM
55090U7
4fi9
6,837.07 MWD MSG 3l
11.374.45
8273
269
6,503X
6496.34
6,864.33
4,587,09
5,976,550
506,97.63
470
6,854.33 MD MSG (3)
RM4.W
9344
26.05
6501.8
6,41"M
6.891.23
4,580.83
5,975,55268
5968WN
254
6,891.23 MWD MSG 13)
11,433.05
93.16
24.0
6,58003
649303
6,917.62
4,683.35
5,975,57917
566903.44
755
6,91762 MWD MSG (3)
ll.4W.n
92.06
MEG
6.51
6,49163
6,94565
4,60596
5,975.6930
566,81582
4.44
6.945.65 MWD MSG (3)
11.40.15
89.5
SW
6,57031
6491.31
6,971.96
4,616.71
5,95933,10
50955
15.00
6,91.0 MWD 05064(3)
11,506.85
W.15
1622
657048
6,49140
7,001.67
4.677.17
5,975fi6349
566936.56
0.10
7.031.9 MWD GWSG (3)
11,55321
88.59
1490
657679
6491.79
7,02904
4.05,31
595fi9092
566,94447
1284
7,029.04 MND 05054(3)
11$84.19
90.15
1452
6,579.13
649213
7,05600
4.643.10
597572095
56695205
5.16
7,059,00 MWD MSG (3)
11,614.11
91.05
13.37
6,57056
649166
7,98603
4.650.39
5,95.75004
56691
6.34
7,08.0 MWD MSG (3)
11,64311
91.35
1213
6,57100
6490.0
7,116.88
4.658.92
5,975.770.95
5669655
4.32
7,11869 MWD MSG (3)
"ni
9224
1315
6578.85
6,489.0
7.14697
4,..V
5,975.811.00
566.91
4.11
7.149.9 MWD MSG (3)
li,fi4S5
88.59
11.01
6,576.65
6,409.65
7.9625
4.90.15
595,83641
566.9760
13.91
7,96.5 MWD MSG (3)
11,73402
NM
13.16
6570.02
6,491.02
7.205.77
4,M69
5,9758998
5669. .37
901
7,5517 1M/D MSG (3)
11,764.55
04.93
1271
6,SM31
6,493.31
7,234.0
4,W.32
6,95.895.92
556.95071
158
7,2%.68 MWD M30 (3)
11,794.54
..W
1226
6503.03
6,496.0
7,53.02
4,809.78
5975926.13
556,95090
1.71
7,53.82 MWD MSG (3)
119249
0419
11.37
6,585.95
6,498.95
7.293.17
4.655.92
5,95.955.53
WOMB
3.30
7,5317 MWD 45084(3)
11853.31
65.57
9.48
6.588.51
6,501.51
7.32123
4,701W
5,959039
5570900
615
73215 MWD 05064(3)
11,040
04.06
3.90
8,59125
6,5.5
7,3925
4704]4
5,96014.9
56701121
17M
7,%25 MWD MSG (3)
l 1191186
82.09
1.42
6594]0
650710
7.301.90
4768.15
5 O044.41
07312.36
11.46
7.391.98 MWD MSG (3)
74iWX)19 8'00:06PM Page 4 COMPASS 5000.149uiIE 850
ConocoPhillips BA;3.
COf1000PlllllF15 Definitive Survey Report
Company:
Con.Phiilipa Aleska Inc_Kupamk
Protech
Kupamk River UPS
Site:
Kupamk 1C Pad
Well:
lC-19
Worth..:
1C-1911
Design:
1C-191.1
survey
Local Co-0Idiwh RaNraltce:
Well 1C-19
WD Reference:
IC -19: @ 07.00uah (1C-19:)
MD Reference
IC -19:@ 07.0uah(1119:)
North ReMrence:
Tore
Survey Calculation Method
Minimum Curvature
Delineate:
OAKEDMPI
7252019 3:OOVIIPM Pope 5 COMPASS 5000.14 RUBE 850
Map
Map
Vertical 1
MD
1.
AS
71`0
WDSS
•N15
♦HiV
Northing
Eastin9
DLS
Section Survey Tai Ni Annotation
' IusM
PI
19
left)
lusrtl
1.11)
(ush)
IRI
Ihl
1°1100.1
IRI
11,944.79
Si
1.39
6559.76
6.51164
2411.30
4]06.88
5,9]6.0]431
567,01235
6.14
7411.86 MWG OWSG(3)
11,974,50
9413
0.51
6.60164
6,52964
7.41.50
4.707,37
5,9]6.103.94
567013.09
3.02
],44150 MND OWSG(3)
17.4,32
84.62
35961
fiei
6,517.65
],4]108
4.]0].40
59]613351
56701200
4.25
],4]100 MMDMTGS)
12,034.81
06.01
35960
6607.15
6,54.15
];501.4]
470721
5.976.16389
56]91244
456
7,0147 MW1DCWSGM)
1266439
85,91
30.97
8.09.23
6522.23
].5309]
9,705.&5
6.976.19133
567,011.85
242
7,530.97 W)OAtteGM)
12,094.0
8645
30.81
6,611'.
6,524.46
7,561
4]0639
5,81
567391194
t64
7 N MMDOWSGM)
12.12462
Btu
359.14
6,613.74
6.526]4
7,58102
4,70575
597615362
561
2.21
7,591.02 MWD MSG (3)
12,154.83
8534
368,26
6,616.03
6.529.03
7,621.13
47D5.
5,976283.52
567.[0939
3.93
7,621.13 MWD MSG (3)
12,184.53
85.08
360.05
6,61B.s4
6,531.54
],60.]1
47".11
5,978,313.09
567.08.10
am
],650.]1 MWD MSG (3)
12.2145t
05.30
357.94
6621.05
fi534.05
7,80.0
4,703ID
5,9]&3428]
56].0[5.81
0.33
7,680.0 MWD MSG (3)
12,244.40
8200
357.48
6fi23."
6536."
7,710.37
470180
S,B163R]3
0].005.3]
6116
],]1037 MWD MSG (3)
12.27464
0&02
357,39
6.624.07
6537,07
],]40.0
4700.53
5906,402.90
020037]
6.Q
7,740.66 MWD MSG (3)
12,30400
Bi
354.73
6.62498
6537.98
7,770.63
4,690.47
5,076.3295
567.00146
9.99
7,770.63 MWD MSG (3)
'24334.03
San
353.53
6,62599
&53098
7,799.89
4,595.49
5,976,461.50
586,998.24
552
7,799.69 MWD MSG (S) �
12.35463
80.65
348.Bs
602&74
6539.74
7,829.91
4603.8'
6976,4 1.
566.993.31
15.30
7,829.91 MND MSG (3)
1239i
917,1
348.75
6.6576
6,53976
7.65..35
4,684.0
5.976,5210
5090].23
0.50
7,859.0 VNO OWSG(3)
12424.0
90.0
348.17
ttmm
6,539.23
7,60073
4,678.90
5,976,50 .8]
509099
241
Tel MND OWSG(3)
1245,tV
89.06
347.87
6,65.10
6,539.10
7,918,11
46h.75
5,976,50].5
Galt /51
303
7,B10.11 MNDOWSG(3)
12 484.71
8929
34793
6.65.37
0,639.3]
],94]68
4,656.45
5,976.60 1
666,967,9]
1.35
784748 MNDOW5G(3)
12,514.57
88.0
347,91
6,65.93
6539.93
7,976.68
466020
5.975630.65
5669616.9
2,45
7,97668 MWD Mai (3)
12.61
90 t2
347,62
662].2]
657637
0.005.34
4135388
5,976,667.75
50.954.92
5.32
BOOS" MND MSG (3)
12676.19
91.66
347.10
56573
6,539.70
0,03604
4,848,93
Said 698.69
Set 947
5.11
8.036.84 MrYD MSG (3)
12,0313
9301
347.ot
6.61
6,536.49
606107
4,64680
5,9]6724.8]
566.94147
7.0
S..'07 MWC MSG (3)
12,046]
9273
343.0666M.69
6.50.69
8,063.01
063410
,9]0 .55
5]&
5,I)MAI
%
4]5
Si MND MSG (3)
12,04.82
9347
348.34
&02.0
6153506
8,123.5
461
5,970,781
50.928.01
2.64
8,123.5 MWD MSG (3)
12.61
9310
348.06
(6535
663335
6,152.48
462164
59]6614.11
5%.92167
155
0,152.48 MWD MSG (3)
f 12)94.]2
9113
348.63
6610.24
653224
..tet%
4615.76
6,9]604343
50,915.36
683
8.18166 MWD MSG (3)
'275432
9021
346.79
661&90
6531.90
3,210.80
4.603.99
5,976.87241
50.909.33
3.15
6.21080 MWD MSG (3)
12784.62
90.69
343.5]
6.610.82
6,531ffi
8,240.59
4,6"."
5,976,902.05
56590313
0.83
3.240.59 MWD OWSG(3)
'ZO13.10
910
346.62
6,61&40
653160
6,58.40
4,07,92
5066,929.
5060.79
666
658.40 MUSE) 00666 (3)
12."4.0
Sam
346.77
6617.18
6530.18
6.299.12
4590.0
5976.906.47
565,889,27
300
0.299,12 MND MSG (3)
7252019 3:OOVIIPM Pope 5 COMPASS 5000.14 RUBE 850
ConoeoPhillips B
Conoco PIIIIIIpS Definitive Survey Report
Compar,
GonoC PhBeps Alaska lM Kupamk
Pmq.t:
Kuporuk RNel Unit
See:
Kupamk lC Pad
Well:
1C-19
Well4ore:
IC -19L1
Design:
iC-19Lt
Local Co-ortiinals 0.eferenw:
WO Refewnee:
MO ReftRew:
North Ref arenw:
Survey Calculation MMeod
Daaex:
Pooh 16-19
1C-19'. ®87.0usg (1C-19 )
1U 9: ® 0].00usf1(I 01 li
Time
Minimum Curvature
OAKEDMPI
Ann0talbn
7/152019 3:00:06626 Pupa 6 COMPASS 500014 &ad 650
Map
Map
Vertical
MD
Inc
Pan
WD
WDSS
+NI -S
+7.y4
No
Eastin9
DLS
Section Tool Name
(usry)
11
P)
(u -ft)
(uSR)
(9afll
(all
(•110w)
survey
(ft)
nl
fll
12,8)449
9451
34559
6,81627
652827
8,32199
459356
5,976,969.28
a
56698193
691
8,32799 MWD OWSG (3)
12,906.69
94.
.5.
6,61302
6528.02
8,355.38
4.5]6.22
5,91
556.674.E
000
0,355.38 MWD MSG (3)
12,934.73
9396
346.38
6.61079
6,523.79
8,381
4,568,73
5.877.04].3]
festal
323
8,38S.22 MWD MSG (3)
12,984.53
95.81
34].2]
6.06&M
6521.26
6.415.15
4,562.09
6,91
566.859]4
7.75
8,415.15 AND O MSG (3)
12,564.33
9424
350.03
6,60685
8,51865
8.444.20
4,55638
5,971,156.33
566853.79
921
&444.28 MWD MSG (3)
13024E
91
352.11
6.60373
651673
8,473.88
4,551.73
5,971,134.89
5(6.848.89
7.93
8.473.80 MND MSG (3)
13,063,41
9170
35328
6.60250
6,516.50
8,502.67
4.548,04
5,977,163.64
556.044.95
599
0.502.67 MMD MSG (3)
13,01 1
9123
35,.13
6,601.71
6,514.71
&532.64
4.54471
6,91
566.04139
339
8,535.04 pmv MsG(3)
13,113.67
9106
354.45
660.92
8.513.92
8,562.58
4,541.74
5,91223,49
Gia'si6
2.39
8,562.58 M0D MSG (3)
13,14356
ST,15
352.56
6.601.11
6,514.11
6.592..
4.53641
5,971,253.47
566.634.59
15.42
kesi MWD MSG (a)
13,179.53
80.03
354.16
6.60226
6,51536
0,6280
4534.39
5,971,288.84
565.830.27
S.M
0..600 isi MSG (3)
13,204.07
900
35458
6.60251
6,515.51
8.652.42
453202
5,9]],31334
568.827]1
550
6.652.42 MWD MSG (3)
13.23375
pi
354.26
6,60244
6,515.44
8,88197
4,529.19
5.91342.M
5..824.
180
s(Si8] MMD MSG (3)
13,206..
9048
353.80
6,6024
6,51534
8,71165
4,52608
597L3n,41
556.ai
1.74
8,711.65 M0D MSG (3)
13.293.94
89.17
353.25
6.60233
6,515.33
6541.80
4.52266
5877402.53
566,817,60
4.71
8J410 Mind) MSG (3)
13,323.87
8906
35"02
6.264
6,515.54
13.7713U
4,51837
5,977432.04
566,814.06
3.02
8,6134 MMD MSG (3)
13,35367
6671
354.65
6.603.00
6516.00
8,06119
4,51641
5,91
566.010.88
3.77
680119 MMDGWSG(3)
13,384.63
to a
all
6,60314
6,516.74
8,132.0
4.513.72
59n49267
565.80791
210
8,MOS MMDOWSG(3)
13,413.27
80.90
351
6.604.29
6.517.29
8,860.57
4.51139
5.96,52119
5.,.535
0.55
8,880.57 M0e) 00656(3)
13444.0
90.08
356.7
&604.55
6.517.55
588102
4509.14
5,9]755241
50,802.83
4.70
0,891.82 MMD MSG (a)
13,47345
93.38
367.42
6603.69
651659
8,9i
4,50].5]
57258119
546,80103
127
0,92061 MWD MSG (3)
13.50.99
94.56
356.96
6.601.51
6,51461
8.954.04
4505.93
5,97].614.60
5%593.11
245
685404 M0D MSG (3)
13,53400
8397
359.17
6,599.62
6,512.62
6,956.95
4,50679
59]]64106
SWN775
448
8,900.95 MWD MSG (3)
1356046
9190
358.75
6,598.27
6.51127
9,0737
4,504.08
5.977,66791
5.,]86.82
8.12
907.37 MWD MSG (3)
13,594.7
90.28
357.78
6,597.63
6.510.63
9,040.86
403.
5,77,70140
566,795.51
565
9.04098 MWD MSG (3)
13624.10
810
356.12
8,598.1]
6.511P
90ID.93
4501.45
5.97].]3144
566/9366
1029
9,07093 Mand) MSG (3)
1365960
0981
35034
6596.92
651192
9,10646
4,499.85
5.977,756.06
Ni n
970
9,10646 MWD MSG (3)
13.668,32
0960
3SSS1
6,599.06
6,512.04
9,13500
4, 11M.7
577.79566
551
786
913508 MWD MSG (3)
1311413
88.46
355.14
6,593.48
6,51240
9.160.61
4,49659
5,77,0210
561.26
690
9,160.81 MWD MSG (3)
13.74463
89.14
355.27
66012
6.51312
9,19120
4494.24
5977.85106
See 785.45
227
9,19120 MWDMSG (3)
13]]40n
85 10
35321
8Sides
651305
8,221.21
449122
5,977.861.61
566.702.18
765
9,22121 MWOMSG (3)
Ann0talbn
7/152019 3:00:06626 Pupa 6 COMPASS 500014 &ad 650
Survey
ConocoPhiliips
COnocoPhilllpS
Definitive Survey Report
company: Conoco Phillips Alaska Inc Kuparuk
Local Conld irs to Reference.
W 11 IC -19
Protect: Kuparuk River Unit
TVD Reference:
1619:@ 87.09usk(1C-19'.I
Skis: Kuparuk 1C Pae
MD Reference:
lC-19:? 07.00usn(1P19:I
Well: 10.19
North Reference:
True
W.Ili 1C -19L1
Survey Calculation Method:
Minimum Curv9Wfe
Deni 1C 1911
Database:
OAKEDMPI
Survey
Annotation
�1 !'G"�g
0
7!!52019 3:0:O6PM Pep 7 COMPASS 500014 Sudol 850
Map
Map
Vertical
MD
IM
AM
TVD
TVDSS
aryls
�VAe
Northing
E aetin8
DLS
Section Survey Tool Nam
rys1T1
1°I
1°I
loan)
lusnl
luznl
(uart)
IRI
Irtl
1°n9rc1
Inl
13,803.68
07.30
35240
6602.00
651500
9,249a2
446161
59]/,91019
566.]]833
394
9249.82 MWD OW6G(3)
13,8335
69.97
35211
Grail
6,51595
9,27852
441GS7
59]1.93965
566.]]/04
591
9,27952 MW➢9W6G(3)
135323
son
35197
8,602.97
6,515.97
9,30865
4,4]8]4
5,977,999.15
RR 76998
7.06
9,30805 Mr4D 69756 (3)
13.89371
9000
35241
6,602]2
6.515]2
9.339.00
44755
5.9]].993.34
568,]558]
386
9.33900 MWT3DAYS. (3)
13,9338
90]]
351.45
6.602.52
6,515.52
9,31
4.471.67
5,978.029.02
597,]81.41
410
9.358.79 MWD CW6G(3)
13,111
91.41
352M
6.80106
8.5155
9,390.02
4457.65
5,978050.21
5.75715
4.98
9,39802 MJUD 69766 (3)
13,90583
9046
353618
6,601."
6,59784
9.43040
4403.05
5,8]0.090.55
SWRG.07
293
9,430.40 MOVE) CMG (3)
14,013.55
Ni
355.26
860135
0514.35
8,457.99
4461.17
5.970,118.11
566]50.17
5.81
9.457.99 MOVED GWSG(3)
14,042]4
87.60
Mai
6,601]6
6,514.Ri
9.407.13
4,459.69
5,970147 .23
5040.45
15.59
8,467.13 MND OWSG(3)
14,073.19
84.40
358.59
6,60.3.89
6,516.09
9,517.49
4.459.03
5.978 1T`59
5561]47.54
10%
9.517.49 MWD 0W6G(3)
14,10539
83b3
1.33
6.601
8,520.55
9.552.40
4,459.41
5,970,21249
555,]4].22
807
9,552.4➢ MWD MSG (3)
1414323
83.11
383
6,61L56
6,524.58
9,50]05
446057
5,9]824]17
566.748.50
7.26
9.597.06 MWD 09766(3)
14,173.21
02.70
5'.
6.615.29
052826
9,616 ]t
4,46304
5,978276.83
W,7W.72
835
9,81871 MND Gori (3)
14,198.25
8329
35
6,618.30
6,531.30
9,641.48
4455.05
5,978.301.62
581
0.30
9.64'.48 MWD Mi (3)
14.233.33
84.71
6.71
8,621.]8
65M.78
9.674.24
440004
5,978.314.40
R6,755.24
10.12
9,674.24 MWD MSG (3)
14,263.04
03.97
7.28
6.824.66
8537.98
9.706.35
4471.98
5,978,356.54
56,758.91
287
9,797.33 MWD MSG (3)
14.29223
0498
]]4
6.82770
8,540]0
9;1437
44]56]
5,9]839456
SWj62J]
391
9,734.37 MWD MSG (3)
14.33135
Book
719
6,Cd0.W
6,54306
9,772.90
4,48073
5,978,433.23
5E6.m 11
8.69
9.M.90 MWD MSG (3)
14,30375
91.32
8.12
6.63022
6,543.22
9,05.19
4,485.05
5.978,465.47
505,7417
1034
9605.19 MVW 0W8G(3)
14.38888
92.40
6.42
6629.41
6,542.41
982990
4488.21
5,978.490.20
556,77412
0.00
9029.90 MWD 0WBG(3)
1941315
9335
6.29
6620.19
6,54'.19
9,854.19
4490.92
5,978.51451
55.77862
382
9,85419 MCN OW6G (3)
14A385
9477
801
66-26.36
6,539.37
9,67971
4,493.67
5,970,54005
55,77916
562
9,8]9]1 MiVD001i
14.471.85
9062
582
662309
6,536.09
9,91234
4.497.05
5,978.52.70
56,70227
564
9,91234 MWD 69766(3)
14.04.0
Was
4.20
6618.79
6.531.79
9,944.35
4,499.6
5,978604.73
56.784.01
].96
9.944.35 MrW GWSG(3)
14.539.50
101.19
4.11
6.612]2
6,525]2
9,978.96
4,597.37
5,970.833.36
Met 787,03
7,24
9,9785 MND Devil (3)
14571,29
104.11
3T1
6.605.76
6,516.76
10,009.91
4,`.44.35
5,978WDM
55,7676
958
10,90891 MND 69766 (3)
14,97441
1035
433
8597.73
6.51073
10.041.97
4506.47
6,97e,702.39
55,790.61
328
10,041,97 MVVD 69736 (3)
1457.00
10196
433
6,56987
6.50207
10,073.51
4508.5
5,978.733.95
Me 70073
000
10,073.51 PROJECTED IO TO
Annotation
�1 !'G"�g
0
7!!52019 3:0:O6PM Pep 7 COMPASS 500014 Sudol 850
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C -19L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-086
Surface Location: 1615' FNL, 1360' FWL, Sec. 12, TI IN, RIOE, UM
Bottomhole Location: 2260' FNL, 690' FWL, Sec. 31, T12N, RI IE, UM
Dear Mr. Ohlinger:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.alasko.gov
Enclosed is the approved application for the permit to drill the above referenced development well.
The permit is fora new wellbore segment of existing well Permit No. 203-054, API No. 50-029-23149-
00-00. Production should continue to be reported as a function of the original API number stated
above.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required by
law from other governmental agencies and does not authorize conducting drilling operations until all
other required permits and approvals have been issued. In addition, the 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,
J ssiLr e�mielowski
Commissioner
DATED this ]�_ day of June, 2019.
STATE OF ALASKA
AL .A OIL AND GAS CONSERVATION COMMI JN
PERMIT TO DRILL
2n AAC 25.005
it a Fi _1s :..'
JUN 0 5 2019
Ia. Type of Work:
Drill ❑ Lateral ❑'
Reddll ❑ Reentry ❑
1b. Proposed Well Class: Exploratory - Gas ❑ Service- WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development - Oil ❑� Service - Winj ❑ Single Zone ❑� '
I Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1 c. Speci f e p d for:
Coalbed Gas Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket Q . Single Well ❑
Bond No. 5952180 •
11. Well Name and Number:
KRU 1 C -19L1
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth: 1V j &57
MD: 14503' • TVDSS 6458'
12. Field/Pool(s):
Kuparuk River Pool /
`!g Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
Surface: 1615' FNL, 1360' FWL, Sec. 12, T11 N, R10E, UM
Top of Productive Horizon:
1048' FNL, 36' FAIL, Sec. 06, T11 N, R11 E, UM
Total Depth:
2260' FNL, 690' FWL, Sec. 31, T12N, R1 1E, UM
7. Property Designation 4 {q APL, y,
ADL 25649, A ADL 28242
8. DNR Approval Number:
LONS 79-016
13. Approximate Spud Date:
6/19/2019 '
9. Acres in Property:
2560
14. Distance to Nearest Property:
2400' .
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 562368 y- 5968624 • Zone- 4
10. KB Elevation above MSL (it): 87'
GL / BF Elevation above MSL (ft): 52'
15. Distance to Nearest Well Open
to Same Pool: 971 (1C -O6)
16. Deviated wells: Kickoff depth: 10160 feet
Maximum Hole Angle: 100 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 3888 . Surface: 3232
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 4453'
10,050' 6468' 14,503' 6545' Slotted
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (N): Effect. Depth TVD (ft): Junk (measured):
10,435' 6794' N/A 10,429' 6717' N/A
Casing Length Size Cement Volume MD TVD
Conductor/Structural 109' 16" 175 Sx ArcticCrete 138' 138'
Surface 6745' 9-5/8" 655 bbl As III Lite, 144 bbl LiteCrete 6745' 4474'
Production 10,403' 7" 240 Sx Class G 10,429' 6789'
Perforation Depth MD (ft): 10,150'-10,180' Perforation Depth TVD (ft): 6550'-6576'
Hydraulic Fracture planned? Yes[] No ❑� '
20. Attachments: Property Plat ❑ DiveOot
er Sketch
Drilling
Report
B Drilling Fluid Program
Shallow Hazard Analysis
e 20 AAC 25.050 requi ementsB
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval. Contact Name: Shane Germann
Authorized Name: James Ohlinger Contact Email: Shane. erman0 CO .COM
Authorized Title: Staff CTD Engineer / G Contact Phone: 907-263-4597
Authorized Signature: C Date:
Commission Use Only
Permit to Drill
Number: �vG ��
API Number:
0 7
/�-J�7% ��
50- " tcp.i�
Patermit Approval
De:
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: J/
Other: pap trS 35eo 266.4 q Samples req'd: Yes ❑ Nov Mud log req'd: Yes El p10 LvJ
f,�✓LY{ U /A r /p rl ✓eve r r,i f to Z 15 4vri" asures: Yes No[] Directional svy req'd: Yes [�}/No❑
Spacing exception req'd: Yes ❑ Nor Inclination -only svy mq'd: Yes[] Norvf/
Post initial injection MIT eq'd: Yes F1 Noa'
APPROVED BY I//
Approved by: COMMISSIONER THE COMMISSION Date: ( (/-f r`
V V/L 4-PI?1/91 Submit Form and
Form 10401 Revised 5/2017 This permit is valid foy24 Wpn{jlsjCorp the dat¢.oLapproval per 20 AAC 25.005�Afiaptimentsin Duplicate� /�
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 3, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permits to drill one lateral out of the KRU
IC -19 (PTD# 203-054) using the coiled tubing drilling rig, Nabors CDR3-AC. .
CTD operations are scheduled to begin in June 2019. The objective will be to drill one lateral KRU 1 C-191-1
targeting the Kuparuk C -sand interval.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 —
AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of
being limited to 500' from the original point. nodes d
Attached to the permit to drill application are the following documents:
- Permit to Drill Application Form (10-401) for 1C-191-1
- Detailed Summary of Operations
- Directional Plan for 1C-191-1
- Current wellbore schematic
- Proposed CTD schematic
Attached to the sundry application are the following documents:
- Sundry Application Form (10-403) for 1C-19
- Summary of Operations
- Current wellbore schematic
- Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-263-4597.
Sincerely,
54
1
Vr�( , Sz� ^�
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Lateral
1C -19L1
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................
2
(Requirements of 20AAC 25.005([) and 20AAC 25.005(6)) .............. ............ .11.1...1...
.........11....1.............1.. ..............2
2.
Location Summary..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2)).. ....................... 11...1...1 ... .............. ..--...........
........ ......... 1111............. .........._1.1-2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20AAC 25.005 (c)(3)). .....11..1...1 ..................... ...................... ..._..._....
....--- ... . ...........................2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20AAC 25.005 (c)(4)).. ...................... ............ ............ ..................
...1.1.11........... .I.. I..... ................2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20AAC 25.005(c)(5)).. 1111........... 111.1...................................
..... ..... .... 2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6)) .. .............. ................. ............ .....1111....
........... ..11 1 ..1....... ...............3
7.
Diverter System Information ..........................................................................................................3
....__. ... .1111 ............. ........_..._.....
(Requirements of 20 AAC 25.005(c)(7)).. ........ .............. ..
.. ............. ...........3
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(8)) .......... .................... ..1........1 ................. ............. ..
............. ..1..1..1......1 ......._..._....3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9)) .. .................. .........._.._.. 11.1.1.......... ...1.. ..... .....
........................... .....__.................4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20AAC 25.005(c)(10)). . ....._.... ............. ........................ 1.1..1.........1. ............._
............................ .._. _...4
11.
Seabed Condition Analysis............................................................................................................
4
(Requirements of 20 AAC 25,005(c)(11))-- ....... .... ........._........... ........... ...1...11.1.
............. .... ...... ........... ........... 4
12.
Evidence of Bonding......................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(12))............. ..... .............................. ...... .. ................... ..............
111.1 ................ .. _... ..... ..4
13. Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13)) ............. ....1..1..... .. ................ ....--- ......................
_................. ._...............4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................5
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5
(Requirements of 20 AAC 25.005(c)(14)) ..... ............. .. ........ ...................... ............5
15. Directional Plans for Intentionally Deviated Wells....................................................................... 6
(Requirements of 20 AA C 25.050(6)) ......... ... ............... .......... ............. .1...111,..................... ........ ......... .................. . ................6
16. Attachments....................................................................................................................................6
Attachment 1: Directional Plans for 1C-191-1 ..................................................................................................................6
Attachment 2: Current Well Schematic for 1C-1911 ........................................................................................................6
Attachment 3: Proposed Well Schematic forl C-1911 lateral...........................................................................................6
Page 1 of 6 May 13, 2019
PTD Application: 1C-191-1
1. Well Name and Classification
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))
The proposed lateral described in this document is 1C-191-1. The lateral will be classified as "Development -Oil'
well.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
The lateral will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and
subsurface coordinates of the 1C-191-1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
- Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3 500 nsi. Using the f
maximum formation pressure in the area of 3888 psi at the datum in 1C-11 (i.e. 11.9 ppg EMW), the
maximum potential surface pressure in 1C-19, assuming a gas gradient of 0.1 psi/ft, would be 3232
psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details.
- The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 1 C-19 was 3,123 psi at the datum (9.6 ppg EMW) on 9/8/2017. The maxim_ um
downhole pressure in the 1C-19 vicinity is 1C-11 at 3888 psi at the datum (11.9 ppg EMW) measured on
5/1/2019. ->
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) j
The offset injection wells to 1C-19 have injected gas, so there is a possibility of encountering free gas while
drilling the 1C-19 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage -
tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) -
The major expected risk of hole problems in the 1C-19 lateral will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1C-19 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 May 30, 2019
PTD Application: 1C-191_1
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm
MD
MD
MD
TVDSS
TVDSS
Conductor
16"
62.5
H-40
Welded
Surface
2-3/8", 4.7#, L-80, ST -L slotted liner;
1C-191_7
10,050'
14,503'
6381'
6458'
with deployment sleeve on to
Existing Casing/Liner Information
Category
OD
Weight
f
Grade
Connection
Top MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
62.5
H-40
Welded
Surface
138'
Surface
138'
1640
670
Surface
9-5/8"
40.0
L-80
BTC
Surface
6745'
Surface
4474'
5750
3090
Production
7"
26.0
L-80
BTC
Surface
10,429'
Surface
6789'
7240
5410
Tubing
3-1/2"
9.3
L-80
EUE 8rd
Surface
10,030'
Surface
6451'
10,160
10,540
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based PowerVis mud (8.6 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 11.0 ppg NaCl / NaBr completion fluid in order to
provide formation over -balance and shale stability while running completions.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases,
the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke.
BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment
Information".
In the 1C-19 lateral we will target a constant BHP of at least 11.0 ppg EMW at the window. The constant BHP
target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions
if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates
or change in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 May 30, 2019
PTD Application: 1C -19L1
Pressure at the 1C -19W ndow10,160' MD, 6559' TVD Using MPD
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AA 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AA 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AA 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AA 25.005(c)(13))
Summary of Operations
Background
KRU well 1C-19 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize one lateral to target the C -sands to the north of 1C-19. The lateral will target
reservoir to the north that has been sheltered due to a large sealing fault
CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned
kick off point of 10,160' MD, The 1C -19L1 lateral will exit through the 7" casing at 10,160' MD and TD
at 14,503' MD, targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up
into the 3-1/2" tubing at 10,050' MD with a deployment sleeve.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered.
4. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 May 30, 2019
Pumps On 1.8 bpm)
Pumps Off
C -sand Formation Pressure 9.6
3274 psi
3274 psi
Mud Hydrostatic 8.6
2933 psi
2933 psi
Annular friction i.e. ECD, 0.08psi/ft)
813 psi
0 psi
Mud + ECD Combined
no chokepressure)
3746 psi
Overbalanced -472psi)
2933 psi
Underbalanced -341psi)
Target BHP at Window 11.0
3752 psi
3752 psi
Choke Pressure Required to Maintain
Target BHP
6 psi
819 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AA 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AA 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AA 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AA 25.005(c)(13))
Summary of Operations
Background
KRU well 1C-19 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize one lateral to target the C -sands to the north of 1C-19. The lateral will target
reservoir to the north that has been sheltered due to a large sealing fault
CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned
kick off point of 10,160' MD, The 1C -19L1 lateral will exit through the 7" casing at 10,160' MD and TD
at 14,503' MD, targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up
into the 3-1/2" tubing at 10,050' MD with a deployment sleeve.
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered.
4. Prep site for Nabors CDR3-AC rig.
Page 4 of 6 May 30, 2019
PTD Application: 1C -19L1
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 1C -19L I Lateral (C sand - North)
a. Set top of high expansion wedge at 10,160' MD.
b. Mill 2.80" window at 10,160' MD.
c. Drill 3" bi-center lateral to TD of 14,503' MD.
d. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,050' MD.
3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Return well to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the
Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the
Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator.
This pressure control equipment listed ensures reservoir pressure is contained during the deployment process.
During BHA deployment, the following steps are observed.
— Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the
BOP riser with the BHA inside the lubricator.
— Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the
BHA is lowered in place via slick -line.
— When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir
pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the
BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied.
The lubricator is removed once pressure is bled off above the deployment ram.
— The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to
the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is
made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and
coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
— The 1C-19 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
— While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
Page 5 of 6 May 30, 2019
PTD Application: 1C-191-1
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name Distance
IC -19L1 2400'
- Distance to Nearest Well within Pool
Lateral Name Distance Well
1C -19L1 971' 1C-06
16. Attachments
Attachment 1: Directional Plan for 1C -19L1 lateral
Attachment 2: Current Well Schematic for 1C-19
Attachment 3: Proposed Well Schematic for 1C -19L1 lateral
Page 6 of 6 May 30, 2019
Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2,, Date April 24, 2019
Coiled Tubing and 2-3/8" BHA
Quick Test Sub to Ot
Top of 7" Otis
Distances from top o
Excluding quick -test
Top of Annular
CL Annular
Bottom Annular Flan,
CL Blind/Shears
CL 2" Combi's
CL 2-318" Combi's
CL 2" Combi's
CL of Top S
Top of Swa
CL Swab 1
Flow Tee
CL SSV
CL Master
LDS
Ground
Tree Size
ne
ConocoPhillips
ConocoPhillips Alaska Inc—Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
1C-19
IC -191-1
Plan: 1C-19L1_wp03
Standard Planning Report
22 May, 2019
BA UGHES
a GE company
ConocoPhillips
Kuparuk River Unit, North Slope Alaska, United States
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Weil:
1C-19
Wellbore:
1C-19LI
Design:
1C-19L7_wp03
ConocoPhillips
Kuparuk River Unit, North Slope Alaska, United States
Planning Report
Map System:
Local Co-ordinate Reference:
Well 1C-19
TVD Reference:
Mean Sea Level
MD Reference:
1C-19: @ 87.00usft (1C-19:)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
R' UGHES
a GEompany
Project
Kuparuk River Unit, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution) - System Datum:
Mean Sea Level
Geo Datum:
NAD 1927 (NADCON CONUS)
Using Well Reference Point
Map Zone:
Alaska Zone 04
Using geodetic scale factor
Site Kuparuk 1C Pad
Site Position:
Northing:
5,968,522.46usft
Latitude: 70° 19'28.285 N
From: Map
Easting:
562,372.05usft
Longitude: 149° 29'3S.293 W
Position Uncertainty: 0.00 usft
Slot Radius:
0.000m
Grid Convergence: 0.48 °
Well 1C-19
Magnetics
Well Position +N/ -S
0.00 usft
Northing:
5,968,624.28 usft
Latitude:
70" 19'29+287 N
+E/ -W
0.00 usft
Easting:
562,368.18usft -
Longitude:
149° 29'39.382 W
Position Uncertainty
0.00 usft
Wellhead Elevation:
Usti
Ground Level:
0.00 usft
Wellbore 1C-1911
Magnetics
Model Name
Sample Date
Declination
Dip Angle
Field Strength
(1)
0
(nn
BGGM2018
8/1/2019
16.53
80.87 57,411
Design
1C-1911_wp03
Audit Notes:
Version:
Phase:
PLAN
Tie On Depth:
10,115.74
Vertical Section:
Depth From (TVD)
+N/ -S
+El -W
Direction
(usft)
(usft)
(usft)
(I
0.00
0.00
0.00
0.00
522/2019 9:07.16AM
Page 2
COMPASS 5000.14 Build 85D
✓
ConocoPhillips
BAER
ConocoPhillips
Planning Report
Build
F�IGHES
Depth
Inclination
Azimuth
aGEmmpany
Database: EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1C-19
Rate
Company: ConocoPhillips Alaska Inc_Kuparuk
TVD Reference:
Mean Sea Level
(°)
Project: Kuparuk River Unit
MD Reference:
10-19: @ 87.00usft (1C-19:)
(usft)
Site: Kuparuk I Pad
North Reference:
True
(°) Target
Well: 1IC-19
Survey Calculation Method:
Minimum Curvature
6,43493
Wellbore: iC-191-1
3,940.16
0.00
0.00
Design: 1C-19L1_Wp03
0.00
10,160.00
32.69
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
-NIS
+El -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°/100usft)
(°1100usft)
(°1100usft)
(°) Target
10,115.74
33.69
31.76
6,43493
5827.90
3,940.16
0.00
0.00
0.00
0.00
10,160.00
32.69
31.85
6,471.97
5,848.49
3,952.93
2.26
-2.26
0.20
177.22
10,189.00
37.91
31.85
6,495.63
5,862.72
3,961.77
18.00
18.00
0.00
0.00
10,320.17
93.00
31.85
6,548.04
5,960.21
4,022.34
42.00
42.00
0.00
0.00
10,420.17
99.89
33.08
6,536.82
6,044.00
4,075.64
7.00
6.89
1.23
10.00
10,650.17
90.48
46.21
6,515.96
6,219.66
4,221.45
7.00
4.09
5.71
125.00
10,760.17
89.54
53.85
6,515.94
6,290.26
4,305.69
7.00
-0.85
6.95
97.00
11,510.17
94.48
1.54
6,487.69
6,930.61
4,642.41
7.00
0.66
-6.98
276.00
11,635.16
85.75
0.84
6,487.44
7,055.46
4,645.01
7.00
-6.98
-0.55
-175.46
12,314.55
85.75
0.84
6,537.75
7,732.91
4,654.98
0.00
0.00
0.00
0.00
12,375.22
90.00
0.84
6,540.00
7,793.51
4,655.87
7.00
7.00
-0.01
-0.05
12,432.00
93.94
1.37
6,538.05
7,850.24
4,656.97
7.00
6.94
0.93
7.61
12,953.88
93.94
1.37
6,502.19
8,370.74
4,669.39
0.00
0.00
0.00
0.00
13,046.77
90.00
356.19
6,498.99
8,463.50
4,667.41
7.00
-4.24
-5.57
-127.17
13,058.71
89.18
356.04
6,499.08
8,475.41
4,666.60
7.00
-6.89
-1.23
-169.87
13,668.34
89.18
356.04
6,507.83
9,083.53
4,624.53
0.00
0.00
0.00
0.00
13,742.91
93.65
358.74
6,505.98
9,157.97
4,621.14
7.00
6.00
3.61
31.02
14,502.99
93.65
358.74
6,457.59
9,916.32
4,604.40
0.00
0.00
0.00
0.00
572212019 9:07: 16AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips BAKER
ConocoPhillips Planning Report HUGHES
aGEcompany
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 10-19
Company:
ConocoPhillips Alaska Inc-Kuparuk
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1C-19: @ 87.00usft (1C-19:)
Site:
Kuparuk 1C Pad
North Reference:
True
Well:
1C-19
Survey Calculation Method:
Minimum Curvature
Wellbore:
1C -19L1
Inclination
Azimuth
Design:
1C-19L1wp03
+E/ -W
Section
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+NIS
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(1
(1)
(usft)
(usft)
(usft)
(usft)
('1100usft)
(°)
lusft)
(usft)
10,115.74
33.69
3176
6,434.93
5,827.90
3,940.16
5,827.90
000
0.00
5,974,484.17
566,259.40
TIP
10,160.00 .
32.69
31.85
6,471.97
5,848.49
3,952.93
5,848.49
2.26
177.22
5,974,504.86
566,271.99
KOP
10,189.00
37.91
31.85
6,495.63
5,862.72
3,961.77
5,862.72
18.00
0.00
5,974,519.16
566,280.71
Start
Build 42.00
10,200.00
42.53
31.85
6,504.02
5,868.75
3,965.52
5,868.75
42.00
0.00
5,974,525.22
566,284.41
10,300.00
84.53
31.85
6,547.60
5,943.10
4,011.71
5,943.10
42.00
0.00
5,974,599.94
566,329.97
10,320.17
93.00
31.85
6,548.04
5,960.21
4,022.34
5,960.21
42.00
0.00
5,974,617.14
566,340.46
Start
DLS 7.00 TFO
10.00
10,400.00
98.50
32.83
6,540.04
6,027.29
4,064.81
6,027.29
7.00
10.00
5,974,684.57
566,382.37
10,420.17
99.89
33.08
6,536.82
6,044.00
4,075.64
6,044.00
7.00
10.10
5,974,701.36
566,393.06
Start
DLS 7.00 TFO
126.00
10,500.00
96.66
37.69
6,525.32
6,108.37
4,121.37
6,108.37
7.00
125.00
5,974,766.11
566,438.25
10,600.00
92.55
43.38
6,517.29
6,184.08
4,186.12
6,184.08
7.00
125.66
5,974,842.34
566,502.36
10,650.17
90.48
46.21
6,515.96
6,219.66
4,221.45
6,219.66
7.00
126.12
5,974,878.21
566,537.39
Start
DLS 7.00 TFO
97.00
10,700.00
90.05
49.67
6,515.73
6,253.03
4,258.44
6,253.03
7.00
97.00
5,974,911.89
566,574.10
10,760.17
89.54
53.85
6,515.94
6,290.26
4,305.69
6,290.26
7.00
97.02
5,974,949.51
566,621.03
Start
DLS 7.00 TFO
276.00
10,800.00
89.83
51.08
6,516.16
6,314.53
4,337.27
6,314.53
7.00
-84.00
5,974,974.03
566,652.41
10,900.00
90.56
44.12
6,515.82
6,381.92
4,411.07
6,381.92
7.00
-83.98
5,975,042.02
566,725.64
11,000.00
91.29
37.16
6,514.20
6,457.74
4,476.15
6,457.74
7.00
-84.01
5,975,118.38
566,790.08
11,100.00
91.99
30.19
6,511.33
6,540.88
4,531.54
6,540.88
7.00
-84.12
5,975,201.97
566,844.77
11,200.00
92.67
23.22
6,507.25
6,630.08
4,576.41
6,630.08
7.00
-84.32
5,975,291.53
566,888.90
11,300.00
93.31
16.24
6,502.03
6,724.03
4,610.10
6,724.03
7.00
-84.61
5,975,385.75
566,921.80
11,400.00
93.90
9.25
6,495.74
6,821.31
4,632.10
6,821.31
7.00
-84.97
5,975,483.20
566,942.98
11,500.00
94.43
2.25
6,488.48
6,920.48
4,642.08
6,920.48
7.00
-85.41
5,975,582.44
566,952.14
11,510.17
94.48
1.54
6,487.69
6,930.61
4,642.41
6,930.61
7.00
-85.92
5,975,592.57
566,952.39
Start
DLS 7.00 TFO
-176.46
11,600.00
88.21
1.04
6,485.59
7,020.35
4,644.43
7,020.35
7.00
-175.46
5,975,682.32
566,953.66
11,635.16
85.75
0.84
6,487.44
7,055.46
4,645.01
7,055.46
7.00
-175.47
5,975,717.42
566,953.95
Start
679.39 hold at
11636.16 MD
11,700.00
85.75
0.84
6,492.24
7,120.11
4,645.96
7,120.11
0.00
0.00
5,975,782.08
566,954.36
11,800.00
85.75
0.84
6,499.65
7,219.83
4,647.43
7,219.83
0.00
0.00
5,975,881.79
566,955.00
11,900.00
85.75
0.84
6,507.05
7,319.54
4,648.90
7,319.54
0.00
0.00
5,975,981.51
566,955.64
12,000.00
85.75
0.84
6,514.46
7,419.26
4,650.36
7,419.26
0.00
0.00
5,976,081.22
566,956.28
12,100.00
85.75
0.84
6,521.86
7,518.97
4,651.83
7,518.97
0.00
0.00
5,976,180.93
566,956.92
12,200.00
85.75
0.84
6,529.27
7,618.69
4,653.30
7,618.69
0.00
0.00
5,976,280.65
566,957.56
12,300.00
85.75
0.84
6,536.67
7,718.40
4,654.77
7,718.40
0.00
0.00
5,976,380.36
566,958.20
12,314.55
85.75
0.84
6,537.75
7,732.91
4,654.98
7,732.91
0.00
0.00
5,976,394.87
566,958.29
12,314.55
85.75
0.84
6,537.75
7,732.91
4,654.98
7,732.91
0.00
0.00
5,976,394.87
566,958.29
Start
DLS 7,00 TFO
-0.06
12,375.22
90.00
0.84
6,540.00
7,793.52
4,655.87
7,793.52
7.00
-0.05
5,976,455.48
566,958.68
Start
DLS 7.00 TFO
7.61
12,400.00
91.72
1.07
6,539.63
7,818.29
4,656.29
7,818.29
7.00
7.61
5,976,480.25
566,958.89
12,432.00
93.94
1.37
6,538.05
7,850.24
4,656.97
7,850.24
7.00
7.61
5,976,512.20
566,959.30
Start
521.86 hold at
12432.00 MD
12,500.00
93.94
1.37
6,533.37
7,918.06
4,658.58
7,918.06
0.00
0.00
5,976,580.03
566,960.35
12,600.00
93.94
1.37
6,526.50
8,017.80
4,660.97
8,017.80
0.00
0.00
5,976,679.77
566,961.91
12,700.00
93.94
1.37
6,519.63
8,117.53
4,663.35
8,117.53
0.00
0.00
5,976,779.51
566,963.46
12,800.00
93.94
1.37
6,512.76
8,217.27
4,665.73
8,217.27
0.00
0.00
5,976,879.25
566,965.01
522/2019 9:07:16AM
Page 4
COMPASS 5000.14 Budd 85D
ConocoPhillips BAER
ConocoPhillips Planning Report UGI�ES
a GE company
Database:
Company:
Project:
Site:
Well:
Wellbore:
Design:
EDT 14 Alaska Production
ConocoPhillips Alaska Inc-Kuparuk
Kuparuk River Unit
Kuparuk 1C Pad
lC-19
1C-1911
1C-19L1wp03
Target Name
Local Coordinate Reference: Well 1C-19
TVD Reference: Mean Sea Level
MD Reference: 1C-19: @ 87.O0usft (IC -19:)
North Reference: True
Survey Calculation Method: Minimum Curvature
Planned Survey
Easting
-Shape (") (') (usft) (usft) (usft) (usft)
(usft)
Latitude Longitude
1C-19L1_T04 (copy) (W 0.00 0.00 6,499.00 8,462.98 4,667.78 5,977,124.95
566,965.02
70° 20'52.505 N 149° 27'22.983 W
- plan misses target center by 0.34usft at 13046.23usft MD (6498.99 TVD, 8462.97 N. 4667.44 E)
Measured
TVD
Below
1C-1917_705 (copy) (co 0.00 0.00 6,506.00 9,157.44 4,621.56 5,977,818.94
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(1)
(°)
(usft)
(usft)
(usft)
(usft)
('1100usft)
(°)
(usft)
(usft)
12,900.00
93.94
1.37
6,505.89
8,317.00
4,668.11
8,317.00
0.00
0.00
5,976,979.00
566,966.56
12,953.88
93.94
1.37
6,502.19
8,370.74
4,669.39
8,370.74
0.00
0.00
5,977,032.74
566,967.40
Start
DLS 7.00 TFO
-127.17
13,000.00
91.99
358.79
6,499.80
8,416.79
4,669.45
8,416.79
7.00
-127.17
5,977,078.78
566,967.08
13,046.77
90.00
356.19
6,498.99
8,463.50
4,667.41
8,463.50
7.00
-127.30
5,977,125.47
566,964.64
13,046.77
90.00
356.19
6,498.99
8,463.51
4,667.41
8,463.51
0.01
0.00
5,977,125.48
566,964.64
Start
OLS 7.00 TFO
.169.87
13,058.71
89.18
356.04
6,499.08
8,475.41
4,666.60
8,475.41
7.00
-169.87
5,977,137.37
566,963.73
13,058.71
89.18
356.04
6,499.08
8,475.42
4,666.60
8,475.42
0.01
0.00
5,977,137.38
566,963.73
Start
609.63 hold at
13056.71 MD
13,100.00
89.18
356.04
6,499.67
8,516.60
4,663.75
8,516.60
0.00
0.00
5,977,178.53
566,960.54
13,200.00
89.18
356.04
6,501.10
8,616.36
4,656.85
8,616.36
0.00
0.00
5,977,278.22
566,952.81
13,300.00
89.18
356.04
6,502.54
8,716.11
4,649.95
8,716.11
0.00
0.00
5,977,377.90
566,945.09
13,400.00
89.18
356.04
6,503.97
8,815.86
4,643.05
8,815.86
0.00
0.00
5,977,477.58
566,937.36
13,500.00
89.18
356.04
6,505.41
8,915.61
4,636.15
8,915.61
0.00
0.00
5,977,577.26
566,929.63
13,600.00
89.18
356.04
6,506.84
9,015.36
4,629.25
9,015.36
0.00
0.00
5,977,676.94
566,921.90
13,668.34
89.18
356.04
6,507.83
9,083.53
4,624.53
9,083.53
0.00
0.00
5,977,745.06
566,916.62
13,668.35
89.18
356.04
6,507.83
9,083.54
4,624.53
9,083.54
0.01
0.00
5,977,745.07
566,916.62
Start
DLS 7.00 TFO
31.02
13,700.00
91.08
357.19
6,507.75
9,115.13
4,622.66
9,115.13
7.00
31.02
5,977,776.64
566,914.49
13,742.91
93.65
358.74
6,505.98
9,157.97
4,621.14
9,157.97
7.00
31.02
5,977,819.46
566,912.61
13,742.92
93.65
358.74
6,505.98
9,157.98
4,621.14
9,157.98
0.00
0.00
5,977,819.47
566,912.61
Start
760.08 hold at
13742.92 MD
13,800.00
93.65
358.74
6,502.35
9,214.94
4,619.88
9,214.94
0.00
0.00
5,977,876.41
566,910.88
13,900.00
93.65
358.74
6,495.98
9,314.71
4,617.68
9,314.71
0.00
0.00
5,977,976.15
566,907.85
14,000.00
93.65
358.74
6,489.62
9,414.48
4,615.47
9,414.48
0.00
0.00
5,978,075.89
566,904.81
14,100.00
93.65
358.74
6,483.25
9,514.25
4,613.27
9,514.25
0.00
0.00
5,978,175.64
566,901.78
14,200.00
93.65
358.74
6,476.88
9,614.03
4,611.07
9,614.03
0.00
0.00
5,978,275.38
566,898.75
14,300.00
93.65
358.74
6,470.51
9,713.80
4,608.87
9,713.80
0.00
0.00
5,978,375.12
566,895.72
14,400.00
93.65
358.74
6,464.15
9,813.57
4,606.67
9,813.57
0.00
0.00
5,978,474.86
566,892.69
14,500.00
93.65
358.74
6,457.78
9,913.35
4,604.47
9,913.35
0.00
0.00
5,978,574.60
566,889.66
14,502.99
93.65
358.74
6,457.59.
9,916.32
4,604.40
9,916.32
0.00
0.00
5,978,577.58
566,889.57
Planned TD at 14503.00
Targets
Target Name
-hit/miss target Dip Angle Dip Mr. TVD +N/ -S +E/ -W Northing
Easting
-Shape (") (') (usft) (usft) (usft) (usft)
(usft)
Latitude Longitude
1C-19L1_T04 (copy) (W 0.00 0.00 6,499.00 8,462.98 4,667.78 5,977,124.95
566,965.02
70° 20'52.505 N 149° 27'22.983 W
- plan misses target center by 0.34usft at 13046.23usft MD (6498.99 TVD, 8462.97 N. 4667.44 E)
- Point
1C-1917_705 (copy) (co 0.00 0.00 6,506.00 9,157.44 4,621.56 5,977,818.94
566,913.03
70° 20'59.336 N 149° 27'24.322 W
- plan misses target center by 0.41 usft at 13742.36usft MD (6506.02 TVD, 9157.43 N, 4621.15 E)
- Point
1C-191-1_703 (copy) (co 0.00 0.00 6,540.00 7,793.01 4,656.21 5,976,454.97
566,959.02
70° 20'45.916 N 149° 27'23.334 W
- plan misses target center by 0.34usft at 12374.71 usft MD (6540.00 TVD, 7793.01 N, 4655.87 E)
- Point
5222019 9:07.16AM Page 5
COMPASS 5000.14 Build 85D
�, ConocoPhillips BA ER
ConocoPhillips Planning Report FUGHES
a GE.rn, y
Database:
EDT 14 Alaska Production
Company:
ConocoPhillips Alaska lnc_Kuparuk
Project:
Kupawk River Unit
Site:
Kupamk 1C Pad
Well:
1C-19
Wellbore:
1C-19Ll
Design:
1C-19L1_wp03
Casing Points
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
well 1C-19
Mean Sea Level
1C-19: @ 87.00usft (1C-19:)
True
Minimum Curvature
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
10,115.74
L-80
7.000
8.250
14,503.00
23/8"
2.375
3.000
Plan Annotations
7,055.46
4,645.01
7,732.91
Measured
Depth
(usft)
10,115.74
10,160.00
10,189.00
10,320.17
10,420.17
10,650.17
10,760.17
11,510.17
11,635.16
12,314.55
12,375.22
12,432.00
12,953.88
13,046.77
13,058.71
13,668.35
13,742.92
14,502.99
Vertical
Depth
(usft)
6,434.93
6,471.97
6,495.63
6,548.04
6,536.82
6,515.96
6,515.94
6,487.69
6,487.44
6,537.75
6,540.00
6,538.05
6,502.19
6,498.99
6,499.08
6,507.83
6,505.98
6,457.59
Local Coordinates
-NIS
+E/ -W
(usft)
(usft)
5,827.90
3,940.16
5,848.49
3,952.93
5,862.72
3,961.77
5,960.21
4,022.34
6,044.00
4,075.64
6,219.66
4,221.45
6,290.26
4,305.69
6,930.61
4,642.41
7,055.46
4,645.01
7,732.91
4,654.98
7,793.52
4,655.87
7,850.24
4,656.97
8,370.74
4,669.39
8,463.51
4,667.41
8,475.42
4,666.60
9,083.54
4,624.53
9,157.98
4,621.14
9,916.32
4,604.40
Comment
TIP
KOP
Start Build 42.00
Start DLS 7.00 TFO 10.00
Start DLS 7.00 TFO 125.00
Start DLS 7.00 TFO 97.00
Start DLS 7.00 TFO 276.00
Start DLS 7.00 TFO -175.46
Start 679.39 hold at 11635.16 MD
Start DLS 7.00 TFO -0.05
Start DLS 7.00 TFO 7.61
Start 521.88 hold at 12432.00 MD
Start DLS 7.00 TFO -127.17
Start DLS 7.00 TFO -169.87
Start 609.63 hold at 13058.71 MD
Start DLS 7.00 TFO 31.02
Start 760.08 hold at 13742.92 MD
Planned TD at 14503.00
5222019 9:07:16AM Page 6 COMPASS 5000.14 Build 85D
ConocoPhillips B ER
ConocoPhillips Anticollision Report IUGHES
a GEcompury
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit_1
Reference Site:
Kuparuk I Pad
Site Error:
0.00 usft
Reference Well:
1C-19
Well Error:
0.00 usft
Reference Wellbore
1C-191-1
Reference Design:
1C-19L1_wp03
Reference 1C-191-1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Fiber type:
NO GLOBAL FILTER: Using user defined selection 8 filtering criteria
Interpolation Method:
MD Interval 25.00usft
Error Model:
Depth Range:
10,115.74 to 14,503.00usft
Scan Method:
Results Limited by:
Maximum center -center distance of 1,641.60 usft
Error Surface:
Warning Levels Evaluated at: 2.79 Sigma
Casing Method:
Survey Tool Program Date 5/21/2019
From To
(usft) (usft) Survey (Wellbore)
Tool Name
138.00 10,115.74 1C-19 Baker(1C-19) MWD
10,115.74 14,502.92 1C-19L1_wp03(1C-191-1) MWD
Well IC -19
Mean Sea Level
1C-19: @ 87.00usft (1C-19)
True
Minimum Curvature
2.00 sigma
EDT 14 Alaska Production
Offset Datum
ISCWSA
Tray. Cylinder North
Combined Pedal Curve
Added to Error Values
Description
MWD - Standard
MWD - Standard
Summary
Reference
Offset
Distance
Measured
Measured
Between Between
Separation Warning
Site Name
Depth
Depth
Centres Ellipses
Factor
Offset Well - Wellbore - Design
(usftl
(usftl
(usft) (usft)
Kuparuk IC Pad
1C -06-1C-06-10-06
10,215.74
10,225.00
974.03 761.28
4.578 SF
1C -06 -1C -06-1C-06
10,215.74
10,243.00
971.37 759.29
4.580 CC, ES
1C-14 - 1C -14A - IC -14A
Out of range
1 C-14 - 1 C-1 4A - 1 C -14A
Out of range
1 C-150 - 1 C-150 - 1 C-150
Out of range
1 C-150 - 1 C-150 - 1 C-150
Out of range
I C-153 - 1 C-153 - 1 C-153
Out of range
1 C-153 - 1 C-153 - 1 C-153
Out of range
1 C-154 - 1 C-154 - 1 C-154
Out of range
1 C-154 - 1 C-154 - 1 C-154
Out of range
I C-155 -1 C-155 - 1 C-155
Out of range
1 C-16 - 1 C-16 - 1 C-16
Out of range
1 C-16 - 1 C-16 - 1 C-16
Out of range
1 C-16 -1 C-16 -1C-16
Out of range
1 C-1 9 - 1 C-19 - ICA 9
10,125.00
10,125.00
0.00 -3.44
0.000 STOP Drilling, CC, ES, SF
1 C-22 - 1 C-22 - 1C-22
Out of range
1 C-22 - 1 C-22 - 1C-22
Out of range
1 C-23 - 1 C-23 - 1 C-23
Out of range
1 C-23 - i C-23 - 1 C-23
Out of range
1 C-23 - 1 G -23A- 1 C -23A
Out of range
1 C-23 - 1 C -23A- 1 C -23A
Out of range
I C-23 - 1 C-23ALl - 1 C-23ALl
Out of range
1 C-23 - 1 C-23ALl - 1 C-23ALl
Out of range
1 C-23 - i C-23AL2 -1 C-23AL2
Out of range
1 C-23 -1 C-23AL2 -1 C-23AL2
Out of range
1 C-23 - 1 C-23AL2-01 -1 C-23AL2-01
Out of range
I C-23 - 1 C-23AL2-01 -1 C-23AL2-01
Out of range
I C-23 - 1 C-23AL2-02 - i C-23AL2-02
Out of range
1C-23- 1C-23AL2-02 - 1C-23AL2-02
Out of range
1 C-23 - 1 C-23AL3 - i C-23AL3_wp00
Out of range
1 C-23 -1 C-23AL3 - i C-23AL3_wp00
Out of range
1 C-23 - 1 C-23AL3-01 -1 C-23AL3-01_wp00
Out of range
1C-23 - 1C-23AL3-01 - 1C-23AL3-01_wp00
Out of range
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
5212019 2:36:05PM Page 2 COMPASS 5000.14 Build 85D
O#P) 1+1WIuNAg4Wp
�-)—O000 -,goo zoo zo -Mj,-
...........
Z
-2
oo q=Rq-RoR.IR
.............
Iq
..eemmNO
.........
L" W m41 c� -0: rS-tr C� Le� CN r� LA� -4: C� cq
cl� IR ID .0 �q r�OOm� c� -0 R
oirbrT
.d m 6 ad .6
...y ...
..........
0 . . .
m,6 cV 'i
;zwoo V �2
Zow
I
11550
11400
11250
11100
10950
a
0
8000
7600
MOO
n jj
10350
6900
10200
rn
6000
10050
swc
900
52N
9750
90
1 U7
0
4800
9
9
WO
440L
0.
40,c
�150
z
360C
9m
3200
7
8850
28M
2400
8550
8400
no
9
2000
1600
t250
1200
8100
O#P) 1+1WIuNAg4Wp
�-)—O000 -,goo zoo zo -Mj,-
...........
Z
-2
oo q=Rq-RoR.IR
.............
Iq
..eemmNO
.........
L" W m41 c� -0: rS-tr C� Le� CN r� LA� -4: C� cq
cl� IR ID .0 �q r�OOm� c� -0 R
oirbrT
.d m 6 ad .6
...y ...
..........
0 . . .
m,6 cV 'i
;zwoo V �2
Zow
I
11550
(ui snOgj)tpdacjjewalaAanjL
11400
11250
11100
10950
(ui snOgj)tpdacjjewalaAanjL
10650
MOO
10350
10200
10050
900
9750
90
9
9
WO
300
�150
9m
8850
8550
8400
no
9
t250
8100
7950
78W
7650
75M
y
]350
72W
7056
6900
6750
660
6450
630
6150
6000
0
y
5850
(ui snOgj)tpdacjjewalaAanjL
I
a
ti
AN KUP PROD 1C-19
(:0n000A'tljjipS
Well Attributes Max Angle & MD JTD
Field Name Wellbore APIIWr1 WNIMeSlzws Incl fl M.MK., oor (flNB)
AIe.Bka, k1D.
KUPAPUK RIVER UNIT 500292314900 PR00 60.17 5,856.23 10.4350
GOonMnl ITS(pp.) Bare A`, icon Entl Oale KSGrd TV Rg Release Dale
SSSV: NIPPLE 40 914pa 17 LaSIWO. 912]12013 3470 5113/2003
1 G19. ]I3]IA191238:W PM
Last Tag
VeMcal scFemalk Get'.')
pent lMoo Ry
Antonlian End Oale ael
LAST Tag'. RKB 9/1214017 10.187.0 PPiovep
Last Rev Reason
Aennee., End Bete LasrMm Ry
Rev R...OD: H2S 7/3012018 pprOven
Casing Strings
caaln9 Description
ODtB (in) Tup(nlcej set llrRR1 sal Dawn lTVBj... WNLen a... Graae TopiMeatl
CONDUCTOR
16 15.06 29.0 138.0 1380 62.50 H-40 WELDED
Laslrp Deserlptlon
GDllnl IB(in) Tep(nKBj Sn BepIF IflKe1 Set BepIM1 ITVBI W14en 11... Gntle Top Tnreaa
SURFACE
85M 8.83 280 6744] 4,4]41 4000 L80 BTCM
Cesln80esca1lan
0811.1 IB(In) 1.1 nin.1 Sel Deprn IX KB) opt, SP,n I - -Len (I Grade Top TM1nad
PRODUCTION
7 6.28 26.0 10,428.7 6,788.6 26.00 1.80 BTCM
1
Tubing Strings
iubinp Besalplbn 91rIn9 Ma... ID 1117/ Tap IXKBI sal DeplF lk.. Sat Oepl h Noe) I... w(.1 Gnai Tap B.-fion
corvoucioa,no139D
TUBINGWO 3112 2.99 22.9 10.029.5 6.450.5 9.30 L-80 EUE-bre
Completion Details
ro A(rvD) IDp Iva Nominal
NIPPLE;5033
Top XKB (M1KR) fl Ile. 0- Coin In (In).
22.9 0.00 HANGER GEN IV TUJIING HANGER 2.990
509.2 509.2 078 NIPPLE 2.75°"DUNPPLE 2.875
10.0169 6.4401 3d68 LOCATOR BAKER L AT 2990
10,017.6 6.408 M67 SEALASSY 4 ASSY 2990
Tubing GescnpI., 91rIn9 Ma... 10 917) Top(flKB) Sd BevIn 0X11 sa oapm Irv.) I... wt pnm) Graae Tap LanecNon
TUBING Original 5.9 3.00 10,021.) 10,067.9 fi,I82.2
Completion Details
GAS UFT: al.A
ro.11B) Topma Nomiw
Top lnKel (nxal I°) Ihm Bea no. G
10,024.3 fi443.8 34.66 PER BAKER 81 PRRISBR "TUBINGST9INGHA50 R OFTHE 3.000
PSR•"'
10,635.9 6455.8 34.2 PACKER BAK A -3P RMANENT PACKEP ed MILLOUT EXTENSION 3.710
ID 3.71'
w6uFr; 6.01V
10,059.9 6,4757 34.27 NIPPLE NIPPLE WINO 0275"PROFILE 2750
10. 7. 6.481.5 . 0 WILED 1 L N GUIDE 3.000
Perforations & Slots
sed
Den:
Tcp NVX)
arra (rvD
IYnohm
iap(nKBj
BM (nKB)
(hNB
(IIKR
Linked Zane
Bah
I
Type
Com
10,1500
10,180.0
fi,5506
6. 75.8
N182003
4.0
(PERF
,5°HS0,2S f
ties, :3a0c.>aa.>-
NYPERJET, 4 SPE
POVYERJET
Frac Summary
GPS IIFi: 8,13&6
BbX Date Pm,,I DYlgned (ib) Proppanlln Formalbn 9b)
101712003 200,300.0
Sigp Shrl Ooh Tep Dewn WBJ mm (KKR) -, Vdekaneldj Vd SWrryINAI
1 10(//2003 1 p,150.0 10.1811.0
Start DW PwFpnl MlgnM Qb) Pmppanl In Formation
91702017 200,0110.0 200.2630
GV411FT', 9.919.0
SpY Slarl Oete T�U-M mKB) Rim (M1KR) - VN Ckan (bd) Vd Slurry ryNl
1 91102017 10,150.0 10,180.0 2766.00 2,97200
Mandrel Inserts
s
m
TopITVBI -Ah PMSke TRX Run
G44 XFT; 9.9X9
N TopXKB) IXKR) Make M-. 0D(in) 9ery TYPa (1170 (psll Run DNe Com
1 3,133.4 2,595) CAMCO MM' -:. 112 GAB LIFTRK 0.188 1,233.0 91 131201]
2 a014] 4,102) CAMCO M G 112 GAS LIFTRK 0250 0.0 911L201J3
tG
8,12fifi 5,2W.] AM O MMG 1 ill GASLIFTRK 0.0000.0 927/20134
9,3190 5.912.1 CAMCO MMG 1 V2 GASUFTRK 0.000 Be 92]2013
5 9,95fi.9 6.390.9 CAMCO MMG 1112 GAS LIFTRK 0.000 0.0 902017
Notes: General & Safety
Ene Bam
Annclargn
9EPLM9va0.olLs
PeR: ID.WL3
11110/11
NOTE. View Sohemanc w) Alaska olremalic9.
PACKQI; 10089
NIPME;10o599
tN EG;108]0
FRAC; 101500
/PERF: f0,1E04101..
NmmWK Frac We: 10.1500
.DUCTpN:3&X10piB.]-
§
cn
�
......
&
�
0
IT
)
��
§$
\\
-\
-
42
ƒ
�\
Cl
-
7
\
§
/:
Q
}
�
-
m!
!
m
�
12
\k
(
(�
!
/
!:
w
:
a&
o
;
�
......
&
�
0
IT
)
��
§$
\\
TRANSMITTAL LETTER CHECKLIST
WELL NAME:
PTD:
Development _Service Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: t cc �' / V�.� POOL: l�G(Q4Lr1C C i/ ll� 1� CJi I
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
LATERAL
The permit is fora jaew wellbore segment of existing_well Permit
No. API No. 50,02-V- Z-'! -60 -00
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
-� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
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
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100
Well Name: KUPARUK RIV UNIT 1C_1611 Program DEV Well bore seg ❑
PTD#: 2190860 Company CONOCOPHILLIFI ASKA INC. Initial Class/Type
�Ey_/ PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached.. .. _ .....
NA
2
Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
_ Surface location in ADL0025649; top prod int in ADL 0028242; TO in ADL0047449
3
Unique well name and numbe(. _ _ _ _ _ _
Yes
4
Well located in a. defined pool . . . . . ........ . . . .
Yes
Kuparuk River Oil Pool, governed by Conservation Order No. 432D
5
Well located proper distance from drilling unit. boundary_ _ _ _ ___ _ _ _ _ _ _ _
Yes
Conservation Order No. 432D has no interwell_spacing restrictions, Wellbore will be more than 50V
6
Well located proper distance from other wells .. _ ....... _
Yes
from an external property line_ where. ownership or landownership. changes. As proposed, well will
7
Sufficient acreage available in drilling unit _ _ _ _ .. _ .
Yes
conform to. spacing. requirements.
8
If deviated, is wellbore plat. included _ .... _ _
Yes
_
9
Operator only affected party _ _ _ _ _ _ _ _ _ .. _ _
YES
10
Operator has appropriate bond in force _ _ _ _ _ _ _ _ _
Yes
11
Permit can be issued without conservation order _ _ _ _ _ _ ...... _ _ _ _ _ _
Yes
Appr Date
12
Permit Can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ ..
Yes
SFD 6/6/2019
13
Can permit be approved before 15 -day wait_ _ _ _ _ _
Yes
14
Well located within area and strata authorized by. Injection Order # (put lO# in.comments)(For
NA
15
All wells within 1/4. mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _
NA.
16
Pre -produced injector: duration of pre -production less than 3 months _(For service well only)
NA....
17
18
Nonconven. gas conforms to AS31,05.030(61.A),(j,2.A-D) . . ........ . . . . . .......
Conductor string_ provided _ _ _ _ _ _ _ _ _ _ _ ___________ _ _ _ _ _ _ ___ _ _ _ _
NA
NA
... Conductor set for KRU 1C-19
Engineering
19
Surface casing protects all known USQWs ....
NA
Surface casing setin KRU 1C-19
20
CMT_vol adequate to circulate on conductor & surfcsg .. _ _ _ _ ... _ _ _
NA
_ Surface casing set and fully cemented
21
CMT vol adequate. to tie-in long string to surf csg.. _ _ _ _ ...... _ _ _ _ _
NA
22
CMT will Coverall known productive horizons.... _ _ _ _ _ _ _ _ ... _
No
_ _ _ Productive_ interval will be completed with uncemented slotted liner
23
Casing designs adequate for C. T. B & permafrost
Yes
24
Adequate tankage or reserve pit _ _ _ _ _ _ _ _
Yes
Rig has steel tanks; all waste to approved disposal wells
25
If a. re -drill, has_a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed _ _ _ _ _ _ ________ _ _ _ _ _
Yes
. _ _ _ _ Anti -collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations. _ _ _ _ _ . . ... . . . . . . ....
NA
Appr Date
28
DfiUing fluidprogram schematic.& equip list adequate. _ _ ........
Yes
_ . _ Max formation pressure is 3888 psig(11.9 ppg EMW); will drill w/ 8,6. ppg EMW and maintain overbal w/ MPD
VTL 6/14/2019
29
BOPEs, do they meet regulation _ _ _ _ _ _ ....
Yes
_ _____
30
BOPE press rating appropriate: test to -(put psig in comments) ............. . . .. . . .
Yes
.... MPSP is 3232 psig; will test BQPs. to 3500 psig
31
Choke manifold complies w/API_ RP -53 (May 84). _ _ _ _ _ _ _
Yes
.
32
Work will occur without operation shutdown_ ... _ _ _ _ _ .... _
Yes
33
Is presence.of H2S gas probable. _
Yes
_ _ _ _ _ H2S measures required.
34
Mechanical.conditton of wells within AOR verified (For service well only) .... _NA
35
Permit can be issued w/o. hydrogen. sulfide measures . . . . ...... . . . . ...
No_
_ _ _ _ _ Wells on_IC-Pad are H2S-bearing, H2S measures required.........
Geology
36
Data presented on potential overpressure zones ... . _
Yes
....... Max. potential rest. pressure is 11.9 ppg EMW; expected res. pressure is 9.f) ppg EMW. Well will be
Appr Date
37
Seismic analysis of shallow gas -zones _ _ _ _ _ _ ...... _ _
NA
.. _ _ _ drilled using 8,6.ppg mud, a coiled. -tubing. rig, and. managed pressure drilling technique to control _
SFD 6/6/2019
38
Seabed condition survey.(if off -shore) . . . . . . . . ........ . . . ... . . ..
NA_
....... formation pressures and stabilize skate sections with. constant BHP of. about 11.0 ppg EMW.
39
Contact name/ hone for weekl _ _ ......
_ p weekly reports [exploratory only] _ ... _ _ _ _ .
NA..
. NOTE: Chance of encountering free gas while drilling due to gasinjection performed in.this area...
Geologic Engineering Date Public Date Horizontal well branch targeting untapped Kup C reserves. SFD
Date:
Commissioner: Commissioner: Commissioner
pYS 0 (T/)? 6/1 y I °t
