Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout185-018MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, October 14, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2U-05
KUPARUK RIV UNIT 2U-05
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/14/2024
2U-05
50-029-21281-00-00
185-018-0
W
SPT
5675
1850180 3000
2320 2320 2320 2320
440 760 780 780
REQVAR P
Sully Sullivan
8/4/2024
MITIA to MAIP per AIO 2B.084
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 2U-05
Inspection Date:
Tubing
OA
Packer Depth
360 3300 3215 3200IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240805101610
BBL Pumped:3.2 BBL Returned:2.8
Monday, October 14, 2024 Page 1 of 1
9
9
9
9
9
9 99
9
9
9
9
MITIA AIO 2B.084
James B. Regg Digitally signed by James B. Regg
Date: 2024.10.14 15:31:57 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, October 14, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2U-05
KUPARUK RIV UNIT 2U-05
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/14/2024
2U-05
50-029-21281-00-00
185-018-0
W
SPT
5675
1850180 1800
2290 2290 2300 2310
760 2020 1970 1955
REQVAR P
Sully Sullivan
8/4/2024
MIT-OA to 1800 psi per AIO 2B.084
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 2U-05
Inspection Date:
Tubing
OA
Packer Depth
380 430 430 430IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240805102053
BBL Pumped:0.5 BBL Returned:0.5
Monday, October 14, 2024 Page 1 of 1
9
9
9 9
99
9 9
999
9
9
9
MIT-OA AIO 2B.084
James B. Regg Digitally signed by James B. Regg
Date: 2024.10.14 15:34:20 -08'00'
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2U-05 (PTD #185-018) 30 day monitor period has been completed.
Date:Wednesday, March 13, 2024 9:38:22 AM
Attachments:image001.png
AnnComm Surveillance TIO for 2U-05.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Wednesday, March 13, 2024 9:12 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2U-05 (PTD #185-018) 30 day monitor period has been completed.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has completed the 30 day monitor to verify IA integrity after
a failed IA DDT during barrier testing in preparations for a Braiden head repair. During the monitor
period the well displayed no additional signs of loss of integrity. CPAI has returned the well to
“waivered” status and will continue to operate the well under AIO 2B.084. Attached is a copy of the
current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or
disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Wednesday, January 10, 2024 12:40 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: RE: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has completed the Braiden Head repair and the 10-404 has
been submitted as required. As previously reported, the well failed an IA DDT during the barrier
testing for the Braiden Head repair. The well was secured, the IA was circulated out and the well
passed a MIT-T, CMIT-TxIA, MIT-IA and IA draw down test. During the repair the well showed no
indications of the IA pressure increasing. CPAI intends to return the well to injection and monitor
the well for 30 day to verify IA integrity. Please let me know if you have any questions or disagree
with the plan. Attached is a current 90 day TIO plot and wellbore schematic.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, November 27, 2023 9:45 AM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has failed an IA draw down test during the barrier
verification prior to performing a Braiden Head repair. CPAI intends to secure the well and perform
additional diagnostics to identify the failure mechanism of the failing IA draw down test. At the
completion of the diagnostics, CPAI will submit the proper notifications for continued injection or
repair. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you
have any questions or disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM - EST 120' OF FILL 8,988.0 2U-05 3/22/2015 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled Catcher and RBP 2U-05 1/31/2024 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered well IA x OA Communication, water injection only 2/4/2014 hipshkf
NOTE: View Schematic w/ Alaska Schematic9.0 9/16/2011 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 37.0 4,078.6 2,978.0 36.00 J-55 BTC
PRODUCTION 7 6.28 37.0 9,277.3 6,086.2 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.2
Set Depth …
8,939.7
Set Depth …
5,865.4
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.2 34.2 0.11 HANGER 8.000 MCEVOY TUBING HANGER 3.500
1,919.4 1,789.8 41.62 SAFETY VLV 5.935 CAMCO TDRP-1A NON-
EQUALIZING SAFETY VALVE
2.813
2,025.1 1,866.5 45.54 GAS LIFT 5.390 CAMCO KBUG 2.920
4,143.9 3,013.3 57.35 GAS LIFT 5.390 CAMCO KBUG 2.920
5,314.9 3,659.4 53.36 GAS LIFT 5.390 CAMCO KBUG 2.920
5,883.2 3,995.8 54.07 GAS LIFT 5.390 CAMCO KBUG 2.920
6,235.0 4,202.1 53.97 GAS LIFT 5.390 CAMCO KBUG 2.920
6,743.9 4,500.2 54.47 GAS LIFT 5.390 CAMCO KBUG 2.920
7,255.4 4,800.8 53.42 GAS LIFT 5.390 CAMCO KBUG
7,768.5 5,106.0 53.04 GAS LIFT 5.390 CAMCO KBUG 2.920
8,250.3 5,409.4 49.85 GAS LIFT 5.390 CAMCO KBUG 2.920
8,605.4 5,642.0 48.16 GAS LIFT 5.750 CAMCO MMG-2 2.920
8,645.2 5,668.6 48.04 SBR 4.000 OTIS SBR 2.813
8,656.3 5,676.0 48.01 PACKER 6.156 OTIS RRH PACKER 2.970
8,693.9 5,701.2 47.89 INJECTION 5.750 CAMCO MMG-2 2.920
8,765.4 5,749.1 47.94 INJECTION 5.750 CAMCO MMG-2 2.920
8,805.3 5,775.8 47.99 BLAST RINGS 4.500 CARBIDE BLAST RINGS 2.992
8,897.3 5,837.2 48.36 INJECTION 5.750 CAMCO MMG-2 2.920
8,915.5 5,849.3 48.42 LOCATOR 4.000 OTIS STRAIGHT SLOT LOCATOR 3.000
8,916.9 5,850.2 48.43 PACKER 6.156 OTIS WD PERMANENT PACKER 4.000
8,919.9 5,852.2 48.44 SBE 4.000 OTIS SEAL BORE EXTENSION 3.000
8,931.0 5,859.6 48.47 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750
8,938.5 5,864.5 48.50 SOS 4.510 OTIS SHEAR OUT SUB 2.900
8,939.3 5,865.0 48.50 WLEG 4.510 WIRELINE RE-ENTRY GUIDE,
ELMD TTL @ 8926' ON HES IPROF
4/1/11
2.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
8,884.0 5,828.4 48.31 LEAK - GLV 3/29/95: RAN STDG. VALVE
AT 8918'RKB. ATTEMPTED
TO PRESS. TEST TBG.
WOULDN'T TEST. PULLED
DV AT 8884'RKB. (EROSION
ON BTTM. OF DV.)RAN AT
8884'. MANDREL WASHED
OUT.
3/29/1995
8,890.0 5,832.3 48.33 PATCH
PERM - UPR
22.3' HES TBG PATCH OVER
GLM #13
(Otis Merla Perm Patch)
1/19/1996 2.375
9,160.0 6,010.0 49.39 FISH 3/8" OV & RK-1 PULL TOOL
IN RATHOLE
3/6/1994 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,025.1 1,866.5 45.54 1 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
4,143.9 3,013.3 57.35 2 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,314.9 3,659.4 53.36 3 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,883.2 3,995.8 54.07 4 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,235.0 4,202.1 53.97 5 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,743.9 4,500.2 54.47 6 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,255.4 4,800.8 53.42 7 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,768.5 5,106.0 53.04 8 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
8,250.3 5,409.4 49.85 9 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
8,605.4 5,642.0 48.16 1
0
GAS LIFT DMY RK 1 1/2 0.0 12/13/2023 0.000
8,693.9 5,701.2 47.89 1
1
INJ DMY RK 1 1/2 0.0 3/23/2015 0.000
8,765.4 5,749.1 47.94 1
2
INJ DMY RK 1 1/2 0.0 9/10/2010 Close
d
0.000
2U-05, 2/1/2024 4:20:38 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FLOAT SHOE; 9,275.7-9,277.3
FLOAT COLLAR; 9,191.0-
9,192.4
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
WLEG; 8,939.3
SOS; 8,938.5
NIPPLE; 8,931.0
SBE; 8,919.9
PACKER; 8,916.9
LOCATOR; 8,915.5
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PACKER; 8,656.3
SBR; 8,645.2
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
FLOAT SHOE; 4,076.8-4,078.6
FLOAT COLLAR; 3,988.5-
3,990.2
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
HANGER; 37.0-41.2
HANGER; 34.2
KUP INJ
KB-Grd (ft)
41.60
RR Date
3/6/1985
Other Elev…
2U-05
...
TD
Act Btm (ftKB)
9,318.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128100
Wellbore Status
INJ
Max Angle & MD
Incl (°)
59.15
MD (ftKB)
3,400.00
WELLNAME WELLBORE2U-05
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: TRDP
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
8,897.3 5,837.2 48.36 1
3
INJ PATCH RK 1 1/2 0.0 1/17/1996 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
8,824.0 8,870.0 5,788.4 5,819.0 C-4, 2U-05 4/21/1985 12.0 IPERF 5" Dresser Atlas
8,970.0 9,044.0 5,885.4 5,934.2 A-4, A-3, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
9,139.0 9,145.0 5,996.3 6,000.2 A-2, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
2U-05, 2/1/2024 4:20:38 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FLOAT SHOE; 9,275.7-9,277.3
FLOAT COLLAR; 9,191.0-
9,192.4
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
WLEG; 8,939.3
SOS; 8,938.5
NIPPLE; 8,931.0
SBE; 8,919.9
PACKER; 8,916.9
LOCATOR; 8,915.5
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PACKER; 8,656.3
SBR; 8,645.2
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
FLOAT SHOE; 4,076.8-4,078.6
FLOAT COLLAR; 3,988.5-
3,990.2
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
HANGER; 37.0-41.2
HANGER; 34.2
KUP INJ 2U-05
...
WELLNAME WELLBORE2U-05
Or
i
g
i
n
a
t
e
d
:
D
e
l
i
v
e
r
e
d
t
o
:
1ͲMa
r
Ͳ24
Ha
l
l
i
b
u
r
t
o
n
A
l
a
s
k
a
O
i
l
a
n
d
G
a
s
C
o
n
s
e
r
v
a
t
i
o
n
C
o
m
m
.
Wi
r
e
l
i
n
e
&
P
e
r
f
o
r
a
t
i
n
g
At
t
n
.
:
Na
t
u
r
a
l
R
e
s
o
u
r
c
e
T
e
c
h
n
i
c
i
a
n
At
t
n
:
F
a
n
n
y
H
a
r
o
u
n
3
3
3
W
e
s
t
7
t
h
A
v
e
n
u
e
,
S
u
i
t
e
1
0
0
69
0
0
A
r
c
t
i
c
B
l
v
d
.
A
n
c
h
o
r
a
g
e
,
A
l
a
s
k
a
99
5
0
1
An
c
h
o
r
a
g
e
,
A
l
a
s
k
a
9
9
5
1
8
Of
f
i
c
e
:
9
0
7
Ͳ27
5
Ͳ26
0
5
FR
S
_
A
N
C
@
h
a
l
l
i
b
u
r
t
o
n
.
c
o
m
Th
e
t
e
c
h
n
i
c
a
l
d
a
t
a
l
i
s
t
e
d
b
e
l
o
w
i
s
b
e
i
n
g
s
u
b
m
i
t
t
e
d
h
e
r
e
w
i
t
h
.
P
l
e
a
s
e
a
d
d
r
e
s
s
a
n
y
p
r
o
b
l
e
m
s
o
r
co
n
c
e
r
n
s
t
o
t
h
e
a
t
t
e
n
t
i
o
n
o
f
t
h
e
s
e
n
d
e
r
a
b
o
v
e
WE
L
L
N
A
M
E
A
P
I
#
S
E
R
V
I
C
E
O
R
D
E
R
#
F
I
E
L
D
N
A
M
E
J
O
B
T
Y
P
E
D
A
T
A
T
Y
P
E
L
O
G
G
I
N
G
D
A
T
E
P
R
I
N
T
S
#
D
I
G
I
T
A
L
#
E
S
E
T
#
11
B
Ͳ16
A
5
0
Ͳ02
9
Ͳ22
4
5
7
Ͳ01
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
L
e
a
k
D
e
t
e
c
t
L
o
g
F
i
e
l
d
Ͳ
Fi
n
a
l
2
7
ͲDe
c
Ͳ23
0
1
21
D
Ͳ13
0
5
0
Ͳ02
9
Ͳ22
8
1
5
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
P
a
t
c
h
S
e
t
t
i
n
g
R
e
c
o
r
d
F
i
e
l
d
Ͳ
Fi
n
a
l
4
ͲDe
c
Ͳ23
0
1
31
D
Ͳ14
1
A
5
0
Ͳ02
9
Ͳ22
9
6
7
Ͳ01
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
M
u
l
t
i
F
i
n
g
e
r
C
a
l
i
p
e
r
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
2
5
ͲDe
c
Ͳ23
0
1
41
H
Ͳ10
2
5
0
Ͳ02
9
Ͳ23
5
8
0
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
M
u
l
t
i
F
i
n
g
e
r
C
a
l
i
p
e
r
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
2
4
ͲJa
n
Ͳ24
0
1
51
Y
Ͳ06
A
5
0
Ͳ02
9
Ͳ20
9
5
8
Ͳ01
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
M
u
l
t
i
F
i
n
g
e
r
C
a
l
i
p
e
r
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
2
0
ͲFe
b
Ͳ24
0
1
62
A
Ͳ10
A
5
0
Ͳ10
3
Ͳ20
0
5
6
Ͳ01
9
0
9
1
7
6
6
9
3
K
u
p
a
r
u
k
R
i
v
e
r
P
e
r
f
o
r
a
t
i
o
n
R
e
c
o
r
d
F
i
e
l
d
Ͳ
Fi
n
a
l
2
6
ͲFe
b
Ͳ24
0
1
72
C
Ͳ12
5
0
Ͳ02
9
Ͳ21
2
2
2
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
M
u
l
t
i
F
i
n
g
e
r
C
a
l
i
p
e
r
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
3
0
ͲDe
c
Ͳ23
0
1
82
F
Ͳ15
5
0
Ͳ02
9
Ͳ21
0
4
8
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
M
u
l
t
i
F
i
n
g
e
r
C
a
l
i
p
e
r
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
2
5
ͲFe
b
Ͳ24
0
1
92
U
Ͳ05
5
0
Ͳ02
9
Ͳ21
2
8
1
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
P
l
u
g
S
e
t
t
i
n
g
R
e
c
o
r
d
F
i
e
l
d
&
P
r
o
c
e
s
s
e
d
8
ͲDe
c
Ͳ23
0
1
10
2
W
Ͳ01
5
0
Ͳ02
9
Ͳ21
2
7
3
Ͳ00
n
/
a
K
u
p
a
r
u
k
R
i
v
e
r
P
a
t
c
h
S
e
t
t
i
n
g
R
e
c
o
r
d
F
i
e
l
d
Ͳ
Fi
n
a
l
6
ͲDe
c
Ͳ23
0
1
PL
E
A
S
E
A
C
K
N
O
W
L
E
D
G
E
R
E
C
E
I
P
T
B
Y
S
I
G
N
I
N
G
A
N
D
R
E
T
U
R
N
I
N
G
A
C
O
P
Y
O
F
T
H
E
T
R
A
N
S
M
I
T
T
A
L
L
E
T
T
E
R
T
O
T
H
E
A
T
T
E
N
T
I
O
N
O
F
:
Fa
n
n
y
H
a
r
o
u
n
,
H
a
l
l
i
b
u
r
t
o
n
W
i
r
e
l
i
n
e
&
P
e
r
f
o
r
a
t
i
n
g
,
6
9
0
0
A
r
c
t
i
c
B
l
v
d
.
,
A
n
c
h
o
r
a
g
e
,
A
K
9
9
5
1
8
FR
S
_
A
N
C
@
h
a
l
l
i
b
u
r
t
o
n
.
c
o
m
Da
t
e
:
Si
g
n
e
d
:
Tr
a
n
s
m
i
t
t
a
l
D
a
t
e
:
T3
8
5
7
5
T3
8
5
7
6
T3
8
5
7
7
T3
8
5
7
8
T3
8
5
7
9
T3
8
5
8
0
T3
8
5
8
1
T3
8
2
8
2
T3
8
5
8
3
T3
8
5
8
4
21
8
-
1
5
5
19
7
-
1
8
3
20
8
-
0
1
6
21
7
-
0
9
7
19
7
-
1
3
4
22
3
-
0
9
2
18
4
-
2
0
6
18
3
-
1
7
2
18
5
-
0
1
8
18
5
-
0
1
0
Me
r
e
d
i
t
h
G
u
h
l
Di
g
i
t
a
l
l
y
s
i
g
n
e
d
b
y
M
e
r
e
d
i
t
h
G
u
h
l
Da
t
e
:
2
0
2
4
.
0
3
.
0
4
1
5
:
1
9
:
5
8
-
0
9
'
0
0
'
185
-018
2U
Ͳ05
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Date:Wednesday, January 10, 2024 4:34:03 PM
Attachments:image001.png
AnnComm Surveillance TIO for 2U-05.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Wednesday, January 10, 2024 12:40 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: RE: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has completed the Braiden Head repair and the 10-404 has
been submitted as required. As previously reported, the well failed an IA DDT during the barrier
testing for the Braiden Head repair. The well was secured, the IA was circulated out and the well
passed a MIT-T, CMIT-TxIA, MIT-IA and IA draw down test. During the repair the well showed no
indications of the IA pressure increasing. CPAI intends to return the well to injection and monitor
the well for 30 day to verify IA integrity. Please let me know if you have any questions or disagree
with the plan. Attached is a current 90 day TIO plot and wellbore schematic.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, November 27, 2023 9:45 AM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has failed an IA draw down test during the barrier
verification prior to performing a Braiden Head repair. CPAI intends to secure the well and perform
additional diagnostics to identify the failure mechanism of the failing IA draw down test. At the
completion of the diagnostics, CPAI will submit the proper notifications for continued injection or
repair. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you
have any questions or disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag: SLM - EST 120' OF FILL 8,988.0 2U-05 3/22/2015 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set DMY 2U-05 12/13/2023 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered well IA x OA Communication, water injection only 2/4/2014 hipshkf
NOTE: View Schematic w/ Alaska Schematic9.0 9/16/2011 ninam
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 37.0 4,078.6 2,978.0 36.00 J-55 BTC
PRODUCTION 7 6.28 37.0 9,277.3 6,086.2 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.2
Set Depth …
8,939.7
Set Depth …
5,865.4
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.2 34.2 0.11 HANGER 8.000 MCEVOY TUBING HANGER 3.500
1,919.4 1,789.8 41.62 SAFETY VLV 5.935 CAMCO TDRP-1A NON-
EQUALIZING SAFETY VALVE
2.813
2,025.1 1,866.5 45.54 GAS LIFT 5.390 CAMCO KBUG 2.920
4,143.9 3,013.3 57.35 GAS LIFT 5.390 CAMCO KBUG 2.920
5,314.9 3,659.4 53.36 GAS LIFT 5.390 CAMCO KBUG 2.920
5,883.2 3,995.8 54.07 GAS LIFT 5.390 CAMCO KBUG 2.920
6,235.0 4,202.1 53.97 GAS LIFT 5.390 CAMCO KBUG 2.920
6,743.9 4,500.2 54.47 GAS LIFT 5.390 CAMCO KBUG 2.920
7,255.4 4,800.8 53.42 GAS LIFT 5.390 CAMCO KBUG
7,768.5 5,106.0 53.04 GAS LIFT 5.390 CAMCO KBUG 2.920
8,250.3 5,409.4 49.85 GAS LIFT 5.390 CAMCO KBUG 2.920
8,605.4 5,642.0 48.16 GAS LIFT 5.750 CAMCO MMG-2 2.920
8,645.2 5,668.6 48.04 SBR 4.000 OTIS SBR 2.813
8,656.3 5,676.0 48.01 PACKER 6.156 OTIS RRH PACKER 2.970
8,693.9 5,701.2 47.89 INJECTION 5.750 CAMCO MMG-2 2.920
8,765.4 5,749.1 47.94 INJECTION 5.750 CAMCO MMG-2 2.920
8,805.3 5,775.8 47.99 BLAST RINGS 4.500 CARBIDE BLAST RINGS 2.992
8,897.3 5,837.2 48.36 INJECTION 5.750 CAMCO MMG-2 2.920
8,915.5 5,849.3 48.42 LOCATOR 4.000 OTIS STRAIGHT SLOT LOCATOR 3.000
8,916.9 5,850.2 48.43 PACKER 6.156 OTIS WD PERMANENT PACKER 4.000
8,919.9 5,852.2 48.44 SBE 4.000 OTIS SEAL BORE EXTENSION 3.000
8,931.0 5,859.6 48.47 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750
8,938.5 5,864.5 48.50 SOS 4.510 OTIS SHEAR OUT SUB 2.900
8,939.3 5,865.0 48.50 WLEG 4.510 WIRELINE RE-ENTRY GUIDE,
ELMD TTL @ 8926' ON HES IPROF
4/1/11
2.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
8,683.0 5,693.9 47.92 CATCHER Set catcher w/ stinger (no
packing) on top of RBP (2.78"
x 63")
CPAI 12/8/2023 0.000
8,688.0 5,697.2 47.91 PLUG Set 2.725 RBP (OAL 7.2')TTS RBP CPP3
5179
12/8/2023 0.000
8,884.0 5,828.4 48.31 LEAK - GLV 3/29/95: RAN STDG. VALVE
AT 8918'RKB. ATTEMPTED
TO PRESS. TEST TBG.
WOULDN'T TEST. PULLED
DV AT 8884'RKB. (EROSION
ON BTTM. OF DV.)RAN AT
8884'. MANDREL WASHED
OUT.
3/29/1995
8,890.0 5,832.3 48.33 PATCH
PERM - UPR
22.3' HES TBG PATCH OVER
GLM #13
(Otis Merla Perm Patch)
1/19/1996 2.375
9,160.0 6,010.0 49.39 FISH 3/8" OV & RK-1 PULL TOOL
IN RATHOLE
3/6/1994 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi)Run Date Com Make Model
Port
Size (in)
2,025.1 1,866.5 45.54 1 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
4,143.9 3,013.3 57.35 2 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,314.9 3,659.4 53.36 3 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,883.2 3,995.8 54.07 4 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,235.0 4,202.1 53.97 5 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,743.9 4,500.2 54.47 6 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,255.4 4,800.8 53.42 7 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,768.5 5,106.0 53.04 8 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
8,250.3 5,409.4 49.85 9 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
2U-05, 12/14/2023 9:12:46 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
PACKER; 8,916.9
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PLUG; 8,688.0
CATCHER; 8,683.0
PACKER; 8,656.3
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
KUP INJ
KB-Grd (ft)
41.60
RR Date
3/6/1985
Other Elev…
2U-05
...
TD
Act Btm (ftKB)
9,318.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128100
Wellbore Status
INJ
Max Angle & MD
Incl (°)
59.15
MD (ftKB)
3,400.00
WELLNAME WELLBORE2U-05
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: TRDP
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi)Run Date Com Make Model
Port
Size (in)
8,605.4 5,642.0 48.16 1
0
GAS LIFT DMY RK 1 1/2 0.0 12/13/2023 0.000
8,693.9 5,701.2 47.89 1
1
INJ DMY RK 1 1/2 0.0 3/23/2015 0.000
8,765.4 5,749.1 47.94 1
2
INJ DMY RK 1 1/2 0.0 9/10/2010 Close
d
0.000
8,897.3 5,837.2 48.36 1
3
INJ PATCH RK 1 1/2 0.0 1/17/1996 0.000
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
8,824.0 8,870.0 5,788.4 5,819.0 C-4, 2U-05 4/21/1985 12.0 IPERF 5" Dresser Atlas
8,970.0 9,044.0 5,885.4 5,934.2 A-4, A-3, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
9,139.0 9,145.0 5,996.3 6,000.2 A-2, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
2U-05, 12/14/2023 9:12:46 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
PACKER; 8,916.9
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PLUG; 8,688.0
CATCHER; 8,683.0
PACKER; 8,656.3
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
KUP INJ 2U-05
...
WELLNAME WELLBORE2U-05
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Braden Head Repair
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 9,318' feet 8,688' feet
true vertical 6,111' feet 9,130' feet
Effective Depth measured feet 8,656' & 8,917 feet
true vertical feet 5,676' & 5,850' feet
Perforation depth Measured depth 8,824' - 9,145' feet
True Vertical depth 5,788' - 6,000' feet
Tubing (size, grade, measured and true vertical depth)3 1/2" J-55 8,940' MD 5,865'
Packers and SSSV (type, measured and true vertical depth)SSSV: CAMCO TDRP-1A 1,919' MD 1,790' TVD
Packer: OTIS RRH 8,656' 5,676'
Packer: 8,917' 5,850'
12. Stimulation or cement squeeze summary:N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:Contact Name:
Contact Email:
Authorized Title:Contact Phone:
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Burst Collapse
OTIS WD PERMANENT
measured
TVD
measured
true vertical
4,079'2,978'
9,277'
Plugs
Junk measured
N/A
Length
77'
4,042'
115'Conductor
Surface
16"
9 5/8"
Size
115'
7"
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025644
KUPARUK RIVER / KUPARUK RIVER OIL
ConocoPhillips Alaska, Ink.
KUPARUK RIV UNIT 2U-05
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
185-018
5002921281-0000P.O. Box 100360, Anchorage, Alaska 99510
3. Address:
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
N/A
Water-BblOil-Bbl Gas-Mcf
MD
Production 9,240'
Casing
6,086'
Sr Pet Eng:Sr Pet Geo:Sr Res Eng:
WINJ WAG
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Brennen Green & Roger Mouser
N1927@conocophillips.com
907-659-7506W.I Field Supervisor
p
k
ft
t
Fra
O
s
185
6. A
G
L
PG
,
r
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E
=n1927@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.01.02 15:09:17-09'00'
Foxit PDF Editor Version: 13.0.0
Brennen Green
By Grace Christianson at 7:57 am, Jan 04, 2024
DSR-1/26/24
RBDMS JSB 011124
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
January 2, 2024
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Please find enclosed the10-404 from ConocoPhillips Alaska, Inc. for the Braden Head repair on
well KRU 2U-05 (PTD 185-018).
If you have any questions, please feel free to contact me or my alternate, Roger Mouser, at 659-
7506
Sincerely,
Well Integrity Field Supervisor
N1927@conocophillips.com
ConocoPhillips Alaska, Inc.
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.01.02 15:08:59-09'00'
Foxit PDF Editor Version: 13.0.0
Brennen Green
Date Event Summary
Executive
Summary Repair Braden Head by seal welding leak area.
12/08/23
CLEAN DRIFT TO 8800' RMD W/ 2.72" DUMMY RBP, SET 2.72" RBP @ 8688' RKB (CE) (7.2' OAL / SN:CPP35179),
MIT TBG 2500 PSI (PASS) SET 3 1/2 CATCHER W/ STINGER @ 8688' RKB (OAL 63"), PULLED DV @ 8605' RKB.
READY FOR PUMPING
12/11/23 CIRC-OUT/ CMIT-TxIA TO 2500 PSI
12/13/23 SET 1.5'' DMY VLV W/RK LATCH IN ST #10 @ 8605' RKB. READY FOR MIT-IA & DHD.
12/17/23 MIT-IA (PASSED TO 2500 PSI) T-DDT (PASSED) IA-DDT (PASSED) OA-DDT (PASSED)
12/19/23 RIG UP OA PURGE JEWELRY (COMPLETE) PURGE OA (COMPLETE)
12/28/23 RIG UP THE INDUCTION HEATING UNIT (COMPLETE)
12/29/23 WELD THE BH (COMPLETE)
12/30/23 RIG DOWN INDUCTION HEATING UNIT (COMPLETE), MT BRADEN HEAD WELD (PASSED) GAS MIT-OA TO 1306
PSI (PASSED), MIT-OA TO 1800PSI (PASSED)
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM - EST 120' OF FILL 8,988.0 2U-05 3/22/2015 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set DMY 2U-05 12/13/2023 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered well IA x OA Communication, water injection only 2/4/2014 hipshkf
NOTE: View Schematic w/ Alaska Schematic9.0 9/16/2011 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 37.0 4,078.6 2,978.0 36.00 J-55 BTC
PRODUCTION 7 6.28 37.0 9,277.3 6,086.2 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.2
Set Depth …
8,939.7
Set Depth …
5,865.4
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.2 34.2 0.11 HANGER 8.000 MCEVOY TUBING HANGER 3.500
1,919.4 1,789.8 41.62 SAFETY VLV 5.935 CAMCO TDRP-1A NON-
EQUALIZING SAFETY VALVE
2.813
2,025.1 1,866.5 45.54 GAS LIFT 5.390 CAMCO KBUG 2.920
4,143.9 3,013.3 57.35 GAS LIFT 5.390 CAMCO KBUG 2.920
5,314.9 3,659.4 53.36 GAS LIFT 5.390 CAMCO KBUG 2.920
5,883.2 3,995.8 54.07 GAS LIFT 5.390 CAMCO KBUG 2.920
6,235.0 4,202.1 53.97 GAS LIFT 5.390 CAMCO KBUG 2.920
6,743.9 4,500.2 54.47 GAS LIFT 5.390 CAMCO KBUG 2.920
7,255.4 4,800.8 53.42 GAS LIFT 5.390 CAMCO KBUG
7,768.5 5,106.0 53.04 GAS LIFT 5.390 CAMCO KBUG 2.920
8,250.3 5,409.4 49.85 GAS LIFT 5.390 CAMCO KBUG 2.920
8,605.4 5,642.0 48.16 GAS LIFT 5.750 CAMCO MMG-2 2.920
8,645.2 5,668.6 48.04 SBR 4.000 OTIS SBR 2.813
8,656.3 5,676.0 48.01 PACKER 6.156 OTIS RRH PACKER 2.970
8,693.9 5,701.2 47.89 INJECTION 5.750 CAMCO MMG-2 2.920
8,765.4 5,749.1 47.94 INJECTION 5.750 CAMCO MMG-2 2.920
8,805.3 5,775.8 47.99 BLAST RINGS 4.500 CARBIDE BLAST RINGS 2.992
8,897.3 5,837.2 48.36 INJECTION 5.750 CAMCO MMG-2 2.920
8,915.5 5,849.3 48.42 LOCATOR 4.000 OTIS STRAIGHT SLOT LOCATOR 3.000
8,916.9 5,850.2 48.43 PACKER 6.156 OTIS WD PERMANENT PACKER 4.000
8,919.9 5,852.2 48.44 SBE 4.000 OTIS SEAL BORE EXTENSION 3.000
8,931.0 5,859.6 48.47 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750
8,938.5 5,864.5 48.50 SOS 4.510 OTIS SHEAR OUT SUB 2.900
8,939.3 5,865.0 48.50 WLEG 4.510 WIRELINE RE-ENTRY GUIDE,
ELMD TTL @ 8926' ON HES IPROF
4/1/11
2.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
8,683.0 5,693.9 47.92 CATCHER Set catcher w/ stinger (no
packing) on top of RBP (2.78"
x 63")
CPAI 12/8/2023 0.000
8,688.0 5,697.2 47.91 PLUG Set 2.725 RBP (OAL 7.2') TTS RBP CPP3
5179
12/8/2023 0.000
8,884.0 5,828.4 48.31 LEAK - GLV 3/29/95: RAN STDG. VALVE
AT 8918'RKB. ATTEMPTED
TO PRESS. TEST TBG.
WOULDN'T TEST. PULLED
DV AT 8884'RKB. (EROSION
ON BTTM. OF DV.)RAN AT
8884'. MANDREL WASHED
OUT.
3/29/1995
8,890.0 5,832.3 48.33 PATCH
PERM - UPR
22.3' HES TBG PATCH OVER
GLM #13
(Otis Merla Perm Patch)
1/19/1996 2.375
9,160.0 6,010.0 49.39 FISH 3/8" OV & RK-1 PULL TOOL
IN RATHOLE
3/6/1994 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,025.1 1,866.5 45.54 1 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
4,143.9 3,013.3 57.35 2 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,314.9 3,659.4 53.36 3 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
5,883.2 3,995.8 54.07 4 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,235.0 4,202.1 53.97 5 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
6,743.9 4,500.2 54.47 6 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,255.4 4,800.8 53.42 7 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
7,768.5 5,106.0 53.04 8 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
8,250.3 5,409.4 49.85 9 GAS LIFT DMY BK-2 1 0.0 4/24/1985 0.000
2U-05, 12/14/2023 9:12:46 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
PACKER; 8,916.9
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PLUG; 8,688.0
CATCHER; 8,683.0
PACKER; 8,656.3
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
KUP INJ
KB-Grd (ft)
41.60
RR Date
3/6/1985
Other Elev…
2U-05
...
TD
Act Btm (ftKB)
9,318.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128100
Wellbore Status
INJ
Max Angle & MD
Incl (°)
59.15
MD (ftKB)
3,400.00
WELLNAME WELLBORE2U-05
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: TRDP
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
8,605.4 5,642.0 48.16 1
0
GAS LIFT DMY RK 1 1/2 0.0 12/13/2023 0.000
8,693.9 5,701.2 47.89 1
1
INJ DMY RK 1 1/2 0.0 3/23/2015 0.000
8,765.4 5,749.1 47.94 1
2
INJ DMY RK 1 1/2 0.0 9/10/2010 Close
d
0.000
8,897.3 5,837.2 48.36 1
3
INJ PATCH RK 1 1/2 0.0 1/17/1996 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
8,824.0 8,870.0 5,788.4 5,819.0 C-4, 2U-05 4/21/1985 12.0 IPERF 5" Dresser Atlas
8,970.0 9,044.0 5,885.4 5,934.2 A-4, A-3, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
9,139.0 9,145.0 5,996.3 6,000.2 A-2, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
2U-05, 12/14/2023 9:12:46 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
PACKER; 8,916.9
INJECTION; 8,897.3
PATCH PERM - UPR; 8,890.0
LEAK - GLV; 8,884.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PLUG; 8,688.0
CATCHER; 8,683.0
PACKER; 8,656.3
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
KUP INJ 2U-05
...
WELLNAME WELLBORE2U-05
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Date:Monday, November 27, 2023 3:39:00 PM
Attachments:image001.png
AnnComm Surveillance TIO for 2U-05.pdf
From: Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent: Monday, November 27, 2023 9:45 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2
<n2549@conocophillips.com>
Subject: Kuparuk injector 2U-05 (PTD #185-018) failed IA draw down test.
Chris-
Kuparuk injector 2U-05 (PTD #185-018) has failed an IA draw down test during the barrier
verification prior to performing a Braiden Head repair. CPAI intends to secure the well and perform
additional diagnostics to identify the failure mechanism of the failing IA draw down test. At the
completion of the diagnostics, CPAI will submit the proper notifications for continued injection or
repair. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you
have any questions or disagree with the plan.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.062
Top (ftKB)
38.0
Set Depth (ftKB)
115.0
Set Depth (TVD) …
115.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.921
Top (ftKB)
37.0
Set Depth (ftKB)
4,078.6
Set Depth (TVD) …
2,978.0
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.276
Top (ftKB)
37.0
Set Depth (ftKB)
9,277.3
Set Depth (TVD) …
6,086.2
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.992
Top (ftKB)
34.2
Set Depth (ft…
8,939.7
Set Depth (TVD) (…
5,865.4
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDMOD
Completion Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
34.2 34.2 0.11 HANGER MCEVOY TUBING HANGER 3.500
1,919.4 1,789.8 41.62 SAFETY VLV CAMCO TDRP-1A NON-EQUALIZING SAFETY VALVE 2.813
8,645.2 5,668.6 48.04 SBR OTIS SBR 2.813
8,656.3 5,676.0 48.01 PACKER OTIS RRH PACKER 2.970
8,805.3 5,775.8 47.99 BLAST RINGS CARBIDE BLAST RINGS 2.992
8,915.5 5,849.3 48.42 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000
8,916.9 5,850.2 48.43 PACKER OTIS WD PERMANENT PACKER 4.000
8,919.9 5,852.2 48.44 SBE OTIS SEAL BORE EXTENSION 3.000
8,931.0 5,859.6 48.47 NIPPLE CAMCO D NIPPLE NO GO 2.750
8,938.5 5,864.5 48.50 SOS OTIS SHEAR OUT SUB 2.900
8,939.3 5,865.0 48.50 WLEG WIRELINE RE-ENTRY GUIDE, ELMD TTL @ 8926' ON
HES IPROF 4/1/11
2.900
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)
8,890.0 5,832.3 48.33 PATCH 22.3' HES TBG PATCH OVER GLM #13 1/19/1996 2.375
9,160.0 6,010.0 49.39 FISH 3/8" OV & RK-1 PULL TOOL IN RATHOLE 3/6/1994 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Zone Date
Shot
Dens
(shots/f
t)Type Com
8,824.0 8,870.0 5,788.4 5,819.0 C-4, 2U-05 4/21/1985 12.0 IPERF 5" Dresser Atlas
8,970.0 9,044.0 5,885.4 5,934.2 A-4, A-3, 2U-
05
4/21/1985 4.0 IPERF 4" Dresser Atlas
9,139.0 9,145.0 5,996.3 6,000.2 A-2, 2U-05 4/21/1985 4.0 IPERF 4" Dresser Atlas
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi)Run Date Com
1 2,025.1 1,866.5 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
2 4,143.9 3,013.3 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
3 5,314.9 3,659.4 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
4 5,883.2 3,995.8 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
5 6,235.0 4,202.1 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
6 6,743.9 4,500.2 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
7 7,255.4 4,800.8 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
8 7,768.5 5,106.0 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
9 8,250.3 5,409.4 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 4/24/1985
1
0
8,605.4 5,642.0 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/16/1985
1
1
8,693.9 5,701.2 CAMCO MMG-2 1 1/2 INJ DMY RK 0.000 0.0 3/23/2015
1
2
8,765.4 5,749.1 CAMCO MMG-2 1 1/2 INJ DMY RK 0.000 0.0 9/10/2010 Close
d
1
3
8,897.3 5,837.2 CAMCO MMG-2 1 1/2 INJ PATC
H
RK 0.000 0.0 1/17/1996
Notes: General & Safety
End Date Annotation
9/16/2011 NOTE: View Schematic w/ Alaska Schematic9.0
2/4/2014 NOTE: Waivered well IA x OA Communication, water injection only
Comment
SSSV: TRDP2U-05, 3/25/2015 11:59:30 AM
Vertical schematic (actual)
PRODUCTION; 37.0-9,277.3
FISH; 9,160.0
IPERF; 9,139.0-9,145.0
IPERF; 8,970.0-9,044.0
WLEG; 8,939.3
SOS; 8,938.5
NIPPLE; 8,931.0
SBE; 8,919.9
PACKER; 8,916.9
LOCATOR; 8,915.5
INJECTION; 8,897.3
PATCH; 8,890.0
IPERF; 8,824.0-8,870.0
INJECTION; 8,765.4
INJECTION; 8,693.9
PACKER; 8,656.3
SBR; 8,645.2
GAS LIFT; 8,605.4
GAS LIFT; 8,250.3
GAS LIFT; 7,768.5
GAS LIFT; 7,255.4
GAS LIFT; 6,743.9
GAS LIFT; 6,235.0
GAS LIFT; 5,883.2
GAS LIFT; 5,314.9
GAS LIFT; 4,143.9
SURFACE; 37.0-4,078.6
GAS LIFT; 2,025.1
SAFETY VLV; 1,919.4
CONDUCTOR; 38.0-115.0
HANGER; 34.2
Annotation
Last Tag: SLM
Depth (ftKB)
8,988.0
End Date
3/22/2015
Annotation
Rev Reason: GLV C/O, TAG
Last Mod By
lehallf
End Date
3/24/2015
KUP INJ
KB-Grd (ft)
41.60
Rig Release Date
3/6/1985
Annotation
Last WO:
End Date
2U-05
H2S (ppm) Date
...
TD
Act Btm (ftKB)
9,318.0
Well Attributes
Wellbore API/UWI
500292128100
Field Name
KUPARUK RIVER UNIT
Wellbore Status
INJ
Max Angle & MD
Incl (°)
59.15
MD (ftKB)
3,400.00
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, September 2, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Austin McLeod
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2U-05
KUPARUK RIV UNIT 2U-05
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/02/2022
2U-05
50-029-21281-00-00
185-018-0
W
SPT
5675
1850180 3000
2500 2500 2500 2500
610 900 900 900
REQVAR P
Austin McLeod
8/7/2022
Two year MITIA to MAIP. AIO 2B.084.
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 2U-05
Inspection Date:
Tubing
OA
Packer Depth
740 3350 3200 3155IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSAM220808194215
BBL Pumped:4.7 BBL Returned:4.3
Friday, September 2, 2022 Page 1 of 1
9
9
9
9
9
9
9 9
9 99
Two year MITIA to MAIP. AIO 2B.084.
James B. Regg Digitally signed by James B. Regg
Date: 2022.09.02 13:44:36 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, September 2, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Austin McLeod
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
2U-05
KUPARUK RIV UNIT 2U-05
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/02/2022
2U-05
50-029-21281-00-00
185-018-0
W
SPT
5675
1850180 1800
2525 2525 2500 2500
580 2020 1950 1925
REQVAR P
Austin McLeod
8/7/2022
Two year MITOA. AIO 2B.084.
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 2U-05
Inspection Date:
Tubing
OA
Packer Depth
755 800 790 785IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSAM220808194616
BBL Pumped:0.9 BBL Returned:0.7
Friday, September 2, 2022 Page 1 of 1
9
9
9 9
9
9
9
9
9 9 9
Two year MITOA. AIO 2B.084.
James B. Regg Digitally signed by James B. Regg
Date: 2022.09.02 13:42:37 -08'00'
MEMORANDUM
TO: Jim Regg
P.I. Supervisor ��}I
FROM: Guy Cook
Petroleum Inspector
Well Name KUPARUK RIV UNIT 2U-05
Insp Num: mitGDC200803112535
Rel Insp Num:
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Thursday, August 6, 2020
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska, Inc.
2U-05
KUPARUK RIV UNIT 2U-05
Src: Inspector
Reviewed By:
P.I. Supry��
Comm
API Well Number 50-029-21281-00-00 Inspector Name: Guy Cook
Permit Number: 185-018-0 Inspection Date: 8/1/2020
Packer
Depth
Pretest
Initial 15 Min
30 Min 45 Min 60 Min
Well 2U-OSType
jnj
W '',iTVj)
5675 Tubing
1930
1930 ' 1930
1930 '
PTD 1850180
Type TOSt
SPT
(Test psi
3000
j jA
700
-
3310 j 3180
--- -
3170
-
BBp
Returned-
4
OA
120
430 440 "
440 -
Interval REQVAR
-'IP�F
-
_P
Notes: MIT -IA -IA e�years to max anticipated injection pressure per AIO 2B.084.
Testing was completed with a Little Red Services pump truck and
calibrated gauges.
Thursday, August 6, 2020 Page I of 1
• 0
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg e 6/41 (7 DATE: Friday,April 21,2017
P.I.Supervisor SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2U-05
FROM: Lou Grimaldi KUPARUK RIV UNIT 2U-05
Petroleum Inspector
Src: Inspector
NON-CONFIDENTIAL
Well Name KUPARUK RIV UNIT 2U-05 API Well Number 50-029-21281-00-00 Inspector Name: Lou Grimaldi
Permit Number: 185-018-0 Inspection Date: 2/14/2017
Insp Num: mitLG170214101542
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2U-05 ' ',Type Inj W' TVD 5675 Tubing 2100 2125 - 2110 - 2110 -
PTD 1850180 Type Test SPT Test psi 1500 IA 790 3290 - 3170 - 3150 -
BBL Pumped: 5.2 , BBL Returned: 4.1 OA 85 3-2-5- 1 325 325
Interval Required by Variance 1P/F Pass ✓
Notes: Test required by AIO 2B.084.All required paperwork on location this morning. .,
Friday,April 21,2017 Page 1 of 1
• S
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
q 14J t 7 DATE: Friday,April 21,2017
Supervisor TO: im Rp � ( SUBJECT: Mechanical Integrity Tests
P.1.
CONOCOPHILLIPS ALASKA INC
2U-05
FROM: Lou Grimaldi KUPARUK RIV UNIT 2U-05
Petroleum Inspector
Src: Inspector
NON-CONFIDENTIAL
Well Name KUPARUK RIV UNIT 2U-05 API Well Number 50-029-21281-00-00 Inspector Name: Lou Grimaldi
Permit Number: 185-018-0 Inspection Date: 2/14/2017
Insp Num: mitLG170214103151
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2U-o5 Type Inj w`TVD 5675 - Tubing 2175 2175 - 2175 2175 -
PTD 1850180 Type Test SPT Test psi 1500 - IA 720 740 - 750 - 750
BBL Pumped:
0.9 BBL Returned: 0.8 OA 60 2015 - 1950 1915 '
Interval Required by Variance P/F Pass
Notes: Test of Outer Annulus required by AIO 2B.084.All required paperwork on location this morning. --
SCANNED
SCANNED AUG 1 5 2 017
Friday,April 21,2017 Page 1 of 1
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
To Jim Regg DATE: Monday,January 04,2016
P.I.Supervisor 1�e�( i/S�/( SUBJECT: Mechanical Integrity Tests
1 CONOCOPHILLIPS ALASKA INC
2U-05
FROM: Chuck Scheve KUPARUK RIV UNIT 2U-05
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry\,:f6 f--
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2U-05 API Well Number 50-029-21281-00-00 Inspector Name: Chuck Scheve
Permit Number: 185-018-0 Inspection Date: 12/27/2015
Insp Num: mitCS151228061926
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2U-05 Type Inj W TVD 5676 - Tubing 2175 2175 2175 - 2175
PTD 1850180 Type Test SPT Test psi, 3000 - IA 960 3300 3200 - 3190 -
Interval 1REQVAR iP/F P ✓ OA 240 480
480 480 -
Notes: MIT-IA tested per AIO 2B.084
SCANNED SEP 1 6 2016
Monday,January 04,2016 Page 1 of 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Monday,January 04,2016
Jim Regg
P.I.Supervisor f S I/tP SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2U-05
FROM: Chuck Scheve KUPARUK RIV UNIT 2U-05
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry 1 or—
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 2U-05 API Well Number 50-029-21281-00-00 Inspector Name: Chuck Scheve
Permit Number: 185-018-0 Inspection Date: 12/27/2015
Insp Num: mitCS151228062334
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2U-05 ,1Type Inj w 'ITVD 5675 Tubing 2200 2200 - 2200 - 2200 — —
;Type SPT - psi 1800... 960 1000 -
PTD 1850180 1T e a Tes Test Test IA 1000 - 1000
IntervalP/F
REQVAR P / OA 190 2010 - 1960 - 1940
Notes: MIT-OA tested per AIO 2B.084
SCANNED SEP 1 6 2016
Monday,January 04,2016 Page 1 of 1
•
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. April 12, 2011
Attn.: Christine Shartzer
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Injection Profile: 2U -05 MINED APR I 9 ZQ
Run Date: 4/1/2011
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
2U -05
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50- 029 - 21281 -00
Injection Profile Log 1 Color Log
50- 029 - 21281 -00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907 - 273 -3535
klinton.wood @halliburton.com cg o`)D6.
7'
Date: Signed:
•
MEMORANDUM
To: Jim Regg ~
P.I. Supervisor ~~~ ~~~~~
1t
FROM: Chuck Scheve
Petroleum Inspector
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, August 25, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2U-OS
KUPARUK RIV UNIT 2U-Os
Src: Inspector
NON-CONFIDENTIAL
•
Reviewed By:
P.I. Suprv
Comm
Well Name: KUPARUK RIV UNIT 2U-OS
Insp Num: mitCS100823054503
Rel Insp Num: API Well Number: s0-029-21281-00-00
Permit Number: 185-018-0 Inspector Name: Chuck Scheve
Inspection Date: 8/22/2010
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 2u-os ~ Type Inj. N " TVD s6~s Ip 96o zo2o ~ zooo zooo '
P.T.Di Issolso' TypeTest~ SPT Test psi Isoo pA o 0 0 0
Interval axRTST p/F P Tubing za6o za6o 2a6o za6o
Notes: pre-test pressures were observed for 30+ minutes and Found stable. '
' ~ ~ ~ s.,. ~, i.r~ ! j , t,
'" ...
Wednesday, August 25, 2010 Page 1 of 1
r~
WELL LOG TRANSMITTAL
To: .Alaska Oil and Gas Conservation Comm.
Attn.: Christine Mahnken
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Injection Profile: 2U-OS
Run Date: 2/9/2010
April 23, 2010
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
2U-OS
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-029-21281-00
Injection Profile Log
50-029-21281-00 .~~ ~ ~~v~ ; .~il~ ~ f ~` '~(~~~'
1 Color Log
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE. ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Rafael Barreto
Anchorages Alaska 99518 U ~ ~ t ~ `~ ~ 1 ~ "~ ~ ~ Od
Office: 907-273-3527
Fax: 907-273-3535
rafael.ba ~~
Date: '; ; ~~~ ,~ ~.!~ , _~
Signed:
~~, ~.. ~.
.. ~~:l
~~~z;~,
U
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm.
Attn.: Christine Mahnken
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Injection Profile: 2U-OS
Run Date: 2/9/2010
March 12, 2010
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of
Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
2U-OS
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-029-21281-00
Injection Profile Log
50-029-21281-00 ;;~`~;; C~~~r? ~. ~} ~~~
1 Color Log
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Rafael Barreto
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
rafael.barrefo~a?hallibur~on.con l
t , ~. ~ ,'~s :~~ 0
V
~G~S~
Date: ~ Signed:
r~
L
ConocoPhillips
~~~
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
- ~~'~~,
'c
~~
March 5, 2009
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
A~' .k ~ .j4s;~
g~:
~;
gg~~ ';G
~- 04fl'dsw~<~ot8 t.~L.
~~~
1~\
~-
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant
was pumped February 21St through February 23`d , 2009. The attached spreadsheet presents the
well name, top of cement depth prior to filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions.
Sincerely,
i~ ~~~~ C
M.J. Loveland
ConocoPhillips Well Integrity Projects Supervisor
•
•
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 315/2009
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009
2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009
2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009
2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009
2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009
2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2!23/2009
2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009
2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009
2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009
2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009
2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009
2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009
2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009
2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009
2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009
2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009
2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009
2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009
2W-06 184-194 16" NA 16" NA 1.4 2/22/2009
2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009
2W-09 184-219 16" NA 16" NA 3.4 2/22/2009
2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009
2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009
2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009
2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009
2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009
2W-17 207-135 8" NA 8" NA 1.1 2/22/2009
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838 ';~; 4~~~~ ~ ~_ a '~ ~~ ~~~ `
ATTN: Beth i ~ 1,~ i
Well Job #
~~S' , 05
~J
Log Description
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
11 /25/08
2V-07 12096561 INJECTION PROFILE - ~ 10/31/08 1 1
3A-11 12100434 INJECTION PROFILE 10/31/08 1 1
iG-09 12100434 INJECTION PROFILE 3 ~ 11/01/08 1 1
2V-11 12061724 PRODUCTION PROFILE $`- ~ 11/02!08 1 1
2C-14 12096565 PRODUCTION PROFILE L/ - 11/04/08 1 1
30-01 11975792 LDL 3 11/05/08 1 1
3F-09 12100435 PRODUCTION PROFILE 11/06/08 1 1
2V-12 12096567 PRODUCTION PROFILE - (~ 11/06/08 1 1
3A-07 12096568 INJECTION PROFILE - 3 11/07/08 1 1
2A-20 12100434 INJECTION PROFILE • 11/08/08 1 1
iG-17 11975792 LDL 11/09/08 1 1
2U-04 12100434 INJECTION PROFILE ~~ 11/10!08 1 1
2U-05 12096572 INJECTION PROFILE '' ,.. ~ ^'' 11/12/08 1 1
1F-06 12100457 PRODUCTION PROFILE 11/13/08 1 1
iB-06 12080456 PRODUCTION PROFILE 11/13/08 1 1
1 B-05 12080457 INJECTION PROFILE ~(} 11/14/08 1 1
2U-10 12080459 PRODUCTION PROFILE - 11/16/08 1 1
2C-15 12100462 PRODUCTION PROFILE L 11/18/08 1 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
s
•
Sc~lIImbel'lep
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
1 R-27
31-08
2M-19
3G-26
1R-18
1Y-01
2C-08
3H-32
1Y-10
3G-08
1A·06
2N-337B
2U-08
1 G-12
2N-343
2N-327
2N-327
3K-01
2X-04
2Z-29
2X-19
1A-20
1F-13
1H-10
1Q-10
2U-05
2D-12
2H-06
11850425
11839638
11813070
11813071
11837482
11813072
11813073
11837483
11837485
11813075
11837486
11837489
11813076
11837490
11745232
11837491
11837491
11632749
11846430
11850419
11850420
11850421
11850422
11846432
11846431
11846433
11846434
11846435
AUG 2, '7 2007
Oi\ïk
cmnmiss10n 'à 1. l\)\)1
!%~ ~\)\)
f.Þ~
û,
NO. 4384
Company:
o\'ò ~
\ C6 <Çr' ~ ~/ 0 Field:
~ Date BL
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Kuparuk
Color CD
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
';J7J'
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
Log Description
FPIT ¡q / - /0;;'
LDL J"'fr{,,-rI-h\
INJECTION PROFILE I JT t"_ Ie¡ I - ~2
LDL JC;C>¡ -h";}K"
SBHP/DDL Je:, J -' ^ ts?-
INJECTION PROFILE U:r:t'~ - l'Sr3 ~ó
INJECTION PROFILE' / JTI" /1r"Z. -(·~t""'-
LDL ..:Jtf") - rt1 I
INJECTION PROFILE U~ J"lf? -as-)
PRODUCTION PROFILE' ,,,,^ - (J G:,S-
INJECTION PROFILE iY'J:'C' l"irl- / If-.
PRODUCTION PROFILE . AN~ - /{A ~
LDL W&'t ,~--,...,f:).1
PRODUCTION PROFILE 1'8'3 -I~d-
MEM INJECTION PROFILE . ()T('. Iq~ - r-A::J
SONIC SCANNER Bö-:t-oco~
SONIC SCANNER·FMI ~,..."l,...,r L:I.
PRODUCTION PROFILE . Ifffo ~ 1,.)/
INJECTION PROFILE / r'r1' I<;'~ -111<'
SBHP SURVEY /1f1r ..:..)(:)'7
SBHP SURVEY ,C; Ô - J~.<'-
SBHP SURVEY /C¡() - It_::J
SBHP SURVEY U'J:.(' J'~ -I./.In
SBHPSURVEY Jq~-~
SBHP SURVEY l'if./. - JC1"x
INJECTION PROFILE / ~ ":I:f\. ~ - rv-K
PRODUCTION PROFILE I frl../ -1"'A4
LDL I~.< -I{...&>'
08/18/07
07/28/07
07/29/07
07/30/07
07/31/07
07/31/07
08/01/07
08/01/07
08/03/07
08/04/07
08/04/07
08/06/07
08/06/07
08/07/07
08/08/07
08/08/07
08/08/07
08/12/07
08/13/07
08/13/07
08/13/07
08/14/07
08/14/07
08/14/07
08/14/07
08/15/07
08/16/07
08/17/07
08/22/07
.
.
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
Commissioner
P.I. Supervisor
FROM: Jeff Jones
Petroleum Inspector
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska Inc.
2U Pad
2U-03, 2U-04, 2U-05, 2U-16
KRU
Kuparuk River Field
NON- CONFIDENTIAL
Packer Depth Pretest Initial 15 Min. 30 Min.
WellI 2U-03 ITypelnJ. I S I T.V.D. 15643 I Tubingl ~00 I ~00 I ~00 I ~00 I','e~'l ~
P.T.D. 1850060 Type testI P Test psiI 1500 Casing 1350 2400 2360 2350 P/F I P
Notes: Test fluid 2 BBLS diesel
P.T.D. 1850070 Type testI P Test psi 1500 Casing 1150 2450 2390 2360 P/F I P
Notes: Test fluid 2 BBLS diesel
P.T.D. 1850180 Type testI P Test psi 1500 Casing 1550 3200 3050 3025 P/F _P
Notes: Test fluid 4.3 BBLS diesel
P.T.D. 1842490 I Type testI P Test psi 1500 Casing 675 3500 2000 1150 P/F F
OA 600 1860 1800 1100
Notes: Test fluid 3.1 BBLS diesel. 3 casing hanger Iockdown leaks at packing glands were repaired.
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS I NJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
May 14, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAI) water injection wells 2U-03, 2U-04, 2U-06 and 2U-
16 to witness 4 year MITs.
Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and
found to be stable and the standard annulus pressure tests were then performed with wells 2U-03, 2U-04, 2U-05 passing
their MIT's. When the inner annulus of well 2U-16 was pressured up the outer annulus pressure also rose, exhibiting
IA/OA communication and this well failed the MIT. It appears that well 2U-16 wellhead pack-offis leaking. CPAI
Problem Well Supervisor MJ Loveland indicated diagnostics and repair of this item would begin within 24 hours. Four
well house inspections were also conducted with three exceptions noted. Three casing lockdown screws were leakiag at
the packing glands on well 2U-16 and were immediately tightened, stopping the leaks.
Sulnmary: I witnessed successful MIT's on CPAI's water injection wells 2U-03, 2U-04, and 2U-05 and a failed MIT on
well 2U-16 in the Kupamk River Field. Four well house inspections conducted, three exception noted.
M.I.T.'s performed: 4 Number of Failures:
Attachments: wellbore schematics (4)
Total Time during tests: 3 hrs
cc:
MIT report form
5/12/00 L.G. 2003-0514_M IT_KRU_2U- 16_jj.xls 5/19/2003
MEMORANDUM
TO: Julie Huesser,
Commissioner
THRU:
Tom Maunder,
P. I. Supervisor
State of Alaska
Alaska Oil and Gas Conservation Commission
FROM: Chuck Scheve; SUBJECT:
Petroleum Inspector
DATE: December 2, 2000
Safety Valve Tests
Kuparuk River Unit
2U Pad
Saturday, December 2, 2000: I traveled to the Kuparuk River Field and witnessed
the semi annual safety valve system testing on 2U Pad.
As the attached AOGCC Safety Valve System Test Report indicates I witnesSed the
testing of 11 wells and 22 components with three failures observed. The Iow
pressure pilots on wells 2U,5, 2U-14 and 2U-16 tripped well below the required set
point. These three pilots were adjusted and retested at the time of this test. In
addition to the three failed pilots several other pilots tripped very near the minimum
pressure, these were reset and operated properly when retested.
The 13.6% failure rate will require a retest of this Pads Safety Valve System in 90
days rather than the nOrmal ,120 day cycle.
Earnie Barndt conducted the testing today he demonstrated good test procedure
and was a pleasure to work with
Summary: I witnessed the semi annUal SVS testing at 2U Pad in the Kuparuk
River Field.
KRU 2U Pad, 11 wells, 22 components, 3 failures 13.6% failure rate
Attachment: SVS KRU 2U Pad 12-2-00 CS
X Unclassified
Confidential (Unclassified if doc. Removed)
SVS KRU 2U Pad 12-2-00 CS.doc
AlaS'ga Oil and Gas Conservation CommisSion
Safety Valve System Test Report
Operator: Phillips
Operator Rep: Emie Barndt
AOGCC Rep: Chuck Scheve
Submitted By: Chuck Scheve Date:
Field/Unit/Pad: Kupamk / KRU / 2U Pad
Separator psi: LPS 96 HPS
12/2/00
Well Permit Separ Set L/P Test Test Test Date
Oil, WAG, GIN&
Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE
2U-01 1850040 96 70 50 P P OIL
2U-02 1850050 96 70 60 P P OIL
2U-03 1850060
2U-04 1850070
2U-05 1850180 3700 2000 500 3 P 12/2/00 WAG
2U-06 1850190 96 '70 50 P P OIL
2U-07A 1850910
2U-08 1850210 96 70 50 P P OIL
2U-09 1850380
2U-10 1850390 96 70 60 'P P ,OIL
2U-11 1850400
2U-12 1850410 96 70 55 P P OIL
2U-13 1842460 96 70 50 P P OIL
2U-14 1842470 3700 2000 0 1 .. P 12/2/00 WAG
2U-15 1842480 96 70' 60 P P · OIL
2U-16 1842490 3700 2000 100 3 P 12/2/00 ' WAG
.
Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6%[]90 oar
Remarks:
Three failed pilots repaired and retested
Pad on 90 day test cycle
12/4/00 Page 1 of 1 SVS KRU 2U Pad 12-2-00 CS.xls
ARCO Alaska, Inc,{'
Posf Office Box ,00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
Date: November 17, 1987
Transmittal # 7012
RETURN TO:
ARCO Alaska, Inc.
Attn: Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
2U-16 Kuparuk Well Pressure Report (Otis) 9-11-86
2U-5 Kuparuk Well Pressure Report (Otis) 7-15-86
3A-13 Kuparuk Well Pressure Report (Camco) 11-1-87
Static
Static
Receipt Acknowledged:
DISTRIBUTION:
D&M
SAPC
EPAE ' ' Chevron Mobil
Unocal
ARCO Alaska, Inc. is a Subsidiary o! AllanllcRIchfleldCompany
Post Offi x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
---
· .
.,,,
Mr. C. V. Chatterton
Alaska Oil and Gas Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton'
Subject- Kuparuk River Field
Water Injection Surveys
In compliance with Rule 4 Conservation Order Number 198, Kuparuk River
Field Waterflood Rules, we are hereby submitting injectivity surveys
for Kuparuk Water Injection Wells for the fourth quarter of 1986.
The data is provided in the form of spinner logs or separate zone
surveys as listed in Attachment I. The spinner logs will be sent
separately. Injection rates determined by separate zone surveys are
also listed in Attachment !.
:..?
';.;iq
·
If you have any questions concerning the information reported, please ....
contact me at (907) 263-4386.
Sinc~
~. ~. Roberts, Jr.
Operations Engineer
JWR/SPT- · pg- 0052
Attachments
,,
Alaska Oil & Gas Cons. Commission
Anch0ra~e,,.
:,
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany
ATTACHMENT 1
KUPARUK RIVER FIELD
CONSERVATION ORDER 198
RULE 4 - INJEOTIVITY PROFILES
FOURTlt QUARTER 1986 SUBMITTAL
WELL
NUMBER
APl ' DATE OF DATE OF DATA TYPE REASON FOR
NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/
.50-029 I NJ ECT I ON SURVEY SURVEY SURVEY
,20706 02/22/83 12/86 SURVEY
20731 03/01/83 12/17/86 SPINNER
20713 03/01/83 12/26/86 SPINNER
21234 11/16/85 11/22/86 SPINNER
21210 10/28/85 11/23/86 SPINNER
21307 10/28/85 11/24/86 SPINNER
20950 11/01/85 11/25/86 SPINNER
21281 11/11/86 12/86 SURVEY
21055 11/27/86 12/86 SURVEY
FOLLOWUP
FOLLOWUP
FOLLOWUP
NITIAL
NITIAL
NITIAL
NITIAL
NITIAL
NITIAL
WELL
COMPLETION
ARC SS
ARC SS
ARC SS
ARC SS
ARC SS
ARC SS
ARC SS
ARC SS
ARC SS
ZONES
TAKING
WATER
A
ARC
ARC
ARC
ARC
ARC
ARC
A
A
INJECTION
BWPD
1347
4000
974
ARCO Alaska, Inc..?
Post Office ~L i00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
December 15, 1986
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton-
Attached in duplicate is a Report of Sundry Well Operations on Kuparuk
Wel 1 ·
Well Action
2U-5 Conversion
If you have any questions, please call me at 265-6840.
Sincerely,
....... ....... " '""'""'
G. B. ~mallwood
Senior Operations Engineer
GBS:pg:O057
Attachment
cc: File KOE1.4-9
D:_C~ 181986
Alaska Oil & Gas Cons. Commission
Anchorafle
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA ~"
ALAS(' .)IL AND GAS CONSERVATION COM ,ION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing []
Alter Casing [] Other X]
2. Name of Operator
ARCO Alaska, In¢,
3. Address
P.O. Box 100360, Anchoraqe~ Alaska 99510
4. Location of well at surface
488' FSL, 703' FWL, Sec. 32, T12N, RgE, UM
At top of productive interval
1410' FSL, 3573' FEL, Sec. 6, T11N, RgE, UM
At effective depth
1244' FSL, 3783' FEL, Sec. 6, T11N, RgE, UM
At total depth
1180' FSL, 3867' FEL, Sec. 6, T11N, RgE, UM
11. Present well condition summary
Total depth: measured 9318' MD feet
true vertical 6111' MD feet
Effective depth: measured 9179' MD feet
true vertical 6021' MD feet
5. Datum elevation (DF or KB)
106
6. Unit or Property name
Kuparuk River Unit
7. Well number
2U-5
8. Approval number
86-3
9. APl ~u2r~be_r
50-- 21281
Feet
10. Pool
Kuparuk River Oil Pool
Plugs (measured) None
Junk(measured)
None
Casing Length
Structural 115 '
Conductor 4079'
Surface
X X Xl~,6~,~Ye~ i at e
Production 9265'
XXX~)~i~(XX
Perforation depth: measured
Size Cemented Measured depth True Vertical depth
16" 235 SX CS11 115' MD 115'TVD
9-5/8" 790 sx PF-E& 4079' 2978'TVD
400 SX PF-C, Top job performed 2/50 SX PF "C"
7" 400 SX Class G & 9265'MD 6078'TVD
250 SX PF-C
9139'-9145' MD, 8970'-9044' MD, 8824'-8870'MD
true vertical
5996' -6000' TVD, 5885' -5934' TVD, 5788' -5819' TVD
Tubing (size, grade and measured depth)
3½" 9.3# 8940' MD
Packers and SSSV (type and measured depth)
RRH Pkr @ 8656': WD Pkr @ 8917': TRDP-1A SSSV fa 1919'
12. Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
DEC 1 8 1986
Alaska 0il & Gas Cons. Commission
Anchora§e
13.
Prior to well operation
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl
1372 445 0
Casing Pressure
1000 psi
900 ps i
Subsequent to operation (Inj.) 0
0 3700
Tubing Pressure
165 psi
1575 psi
14. Attachments
Daily Report of Well Operations []
Copies of Logs and Surveys Run []
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed
'Form 10-4{~4 Rev. 12-~85 '
Submit in Duplicate
MEMORAi ',r UM Stat- of Alaska
----------- -bf£1-------ALASKA .. GAS CONSERVATION COMMI', il .N "
TH RU:
FROM:
C. V. Chatterton
Chairman
Lonnie C. Smith
.Commissioner
Doug Amos
Petroleum Inspector
DATE: November 20, 1986
FI LE NO.: D. ADA. 63.
TELEPHONE NO.:
SUBJECT: Mech Integrity Test
ARCO KRU 1R-9 & 2U-5
Kuparuk River Field
..
·
, .
Saturday~ November 8. 1986: After witnessing the BOP test at
ARCO's PBU L3-22 well I traveled to ARCO KRU to witness the MIT on
1R-9 & 2U-5 injection wells. Both wells were successfully tested
in accordance with AOGCC regulations 20 AAC 25.030(g), 25.412(c)
and 25.252(d), and Area Injection Order No. 2.
I filled out an AOGCC mechanical integrity test form for both
wells. These two forms are attached..
.,
In summary, I witnessed the successful mechanical integrity test at
ARCO's KRU 1R-9 & 2U-5 water injection wells.
Attachments
SCANNED DEC 1 9 2002
02-001 A(Rev 10-84)
TYPE OF
AIASKA OIL AN~ C~ C~ERVATION ~SION
MECHANICAL INTEGRITY
SIZE/WI'/~DE
TBG
CSG
PRESS
Field:
S - S.~I.T ~ 3~4J
A~ FLUID:
DIESEL
GLYCOL
AOGCC WITNESS SIGNAilmE
~ANY REP SIGNATURE
20 AAC 25.030(a)
20 AAC Z5.412(c)
20 AAC 2.5.252(d)
SCANNED -DEC ! 9 2002 ......
OIL AND GAS Ct Z/{VATION ~SSION
MECHANICAL ~TY TEST
Date: yq/oV, ~; l~7R&, Company: /~~ ~L~/~ /~Jd. Field:
,
pR~-l~-r . S~AKr 15 MIN 30' ~
*p *I TYPE OF PKR CASING TBG REQ TBG TIME ~IME TIME
W'~-L *S --- ANNULUS TVD SIZE/WT/GRADE SIZE TEST CSG TBG TBG TBG C~
*M *N FlirfD MD PRESS P~-qS CSG CSG CSG
"~ PRESS PRESS PRESS
.... ,,,-~ ~ -:g~ -- ' O I ~t 75' 1 ~';5 I,~t~,o ?,~ ~,~D _
,
!
..~ ~ i
. , ,
.
,
,
Il I I
I I
I
I I
I I
I
I I
I
I I I ! I I I I
*TUBIEE INJE~ON FLUID:
P - PRODUCE WATER INJ
S = SALT WATER INJ
M = MISCIEI~ INJECTION
..... I = INJECTINg
......
C. :.'
:: --,-,:-'.':~:
,t,: ' '~ ' ":'"' ''", '"
- · -.,,-
';"': D.EWS.06 -' '.
ANNULAR FLLUD:
DIESEL
GLYCOL
SALT WATER
DRW LING MUD
OTHER
OTHER
AOGCC WITNESS SIGNATURE
C(/MP~ REP SIGNATURE
$C~NED DEC t.. 9 2002
·
.
·
-.
20 AAC ~.030 (a)
20 AAC 25.412(c)
20 AAC 25.252(d)
STATE OF ALASKA
ALAS OIL AND GAS CONSERVATION COM,...dSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other
2. Name of Operator
ARCO Alaska, Inc
Address
PO Box 100360, Anchorage, AK 99510
Location of well at surface
488' FSL, 703' FWL, Sec.32 T12N RgE UM
At top of productive interval ' ' '
141_0' FSL, 3573' FEL, Sec. 6, T1_1N, R9E, UM
At effective depth
1_244' FSL, 3783' FEL, Sec. 6, T11N, RgE, UM
5. Datum elevation (DF or KB) ~
RKB 106' feet
6. Unit or Property name
Kuparuk River Unit
7. Well number
2U-5
8. Permit number
Permit #85-18
9. APl number
50-- fl29-21281
10. Pool
Kup~iruk River Oil Pool
11. Present well condition summary(iq
Total depth: measured .~18' MD feet
true vertical6111' MD feet
Plugs (measured~One
Effective depth: measured 9179' MD feet
true verticald021' MD feet
Junk (measureo~One
Casing
Structural
Conductor
Surface
X X X)~nXtXe rXmX ~'~iXa te
Production
xxx~_~xxxx
Perforation depth:
Length Size
115'
4079'
9265'
measured
Cemented Measured depth True Vertical depth
16" 235 SX CS11 115' MD 115' TVD
9-5/8" 790 SX PF-E 4079' MD 2978' TVD
400 SX PF-C, Top job performed w/50 SX PF "C"
7" 400 SX Class G & 9265' MD 6078' TVD
250 SX PF-C
9139'-9145' MD, 8970'-9044' MD, 8824'-8870' MD
true vertical5996,_6000' TVD 5885'-5934' TVD 5788'-58190 W~ E IV E D
' ' i'~_ ~.
Tubing (size, grade and measured depth)
3½", 9.3#, 8940' MD JULY51 1986
Packers and SSSV (type and measured depth) Alaska 0il & 6as Cons. Commission
RRH Pkr Fa R656'. Wll Pkr ¢ R~17'; T~nP-]~ ~SSV ~ ]919' ,-~
12.Attachments Description summary of proposal ~ Detailed operations program Q BOpI~N~2~~
Convert well from production service to "A" Sand only water injection service.
13. Estimated date for commencing operation
August 1, 1986
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~ ..(..-~.~¢~6¢c~¢~,~,.~,tle Sr. Operations Engineer
Commission Use Only
Conditions of approval
Approved by
Dat~Uly 28, 1986
Notify commission so representative may witness I Approval No. ,~ ,,,3
[] Plug integrity [] BOP.,Tgs~,,FI Location clearanceI
,¢,< / ~"--
' ~turn~
by order of
~, ~.~ Commissioner the commission Date
Form 10-403 Rev 12-1-85 Submit in triplicate
ARCO Alaska, Inc/'--'~-''
Post Office. .... ,00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DAT~: 10-2 2- 85
TtCANSMITTAL NO: 5410
P, ETURN TO: ARCO 'ALASKA, INC.
KUPARUK OPERATIONS ENGINEE~LING
· kECORD$ CLERK'
_ ATO-1115B
-:. :-. P.O. BOX 100360 _ .
ANCHORAGE, AK 9951U
TRANSMITTED HEPd~f4ITH AK~ T~; FOLLOWING ITE~IS. '
RECEIPT AND RETURN ON~ SIGNED COPY OF THIS TRANSMITTAL.
FINAL PRINTS/. scHL/ ONE' * OF EACH
CEMENT_ BOND LOG/ VARIABLE DENSITY
~3B-8 : 06-06-85 .RUN #1 5850-8369
42X-15 11-07-.84 RUN ~1 5900-8258
"~2X-13 -11-17-84 - RUN #1 5896-8410
~2X-12. 12-08-84 ' RUN #1 3050-7215
~2X-11- 12-08-84 - RUN #1 310U-6370
~X-10 12-21-84 - kUN ~1 3350-6973
~2X-9 12-20-84 RUN ~t 5100-8338
'~2W-6 - 11-25-85 RUN ~1 5700-7290
~' 2V-16 06-06-85 kUN ~1 4550-710~
2V-15 06-07-85- RUN #1' 4650-6428 -
~2V-13- : 06-03-85 RUN #1 6590-8553 .
-~2U-81~:.:ii~-/! 04-02-85 ~ 'RUN;#i~_ 4970-6938' ; . ' "
~',2U-7:~:~i~i:i.''. U4-01-~5 ': KUN ~1- : 0070-~122 i-'."- .'
2U-6 i~::~.ii' 03-31-85 '-: RUN'~I ' ~: 5600-8107- :'. :
~2U-4:~:~?¥03-02-851~::-~'' i<UN #1 ~:~ 6284-7850 '
2D-16 : 12-19-84:- kUN ~1 ' 52UU-74~9 '
%V2D-15":-ili:. 12-18-84 RUN ~1'- 3285-6454 - '
~2D-1 ' ' 11-03-84 RUN #1 5693-6652
'~lR-8 ":~06-17-85 ~UN ~1- 5987-~324
'~/1R-7' 06-08-~5 - RUN #1 4302-7028
:'~JIR- 5. 06-08-85 RUN ~1 6950-8628
~lL-15 - :11-05-84 RUN #1 4883-6600 -
'~.1Q-'15 :' 05-27-85 RUN ~i 6490-7566
'~J'iQ-3 :: 04-17-85 ~ RUN. ~1 897~-10744-
'~CPF-1A-. 12-21-84 ~UN #1 2200-3856
CEMENT EVALUATION TOOL LUGS/. Ck24ENT ~vALuATIUN LOGS
'~lF-'16 . 03-12-85 "RUN #1: 8269-8712
%~i~<-5 ' 06-26-85 'RUN: #1 6974-' 8~44
.
vlR-5-1?:-i:~-i' 06-27-85 --~'. . RUN _#2 ": 8254-8532
~2U-2~::i!? 03-25-85 kUN ~1 5790-9450' -'
-~'2U-151'-i~i:_'103-07-85 . t~UN #1 . 6400-7002
'~V3B-9 ..... :::-'-:' 06-30-85. -RUN #1 - 6000-8246
.
'~3C-1~- .":: 06-29-.85 '.. RUN #1 6500-8726 '
~3C~12::
.:- 06-29-85-_' RUN ~1 . 5400-7457
B. CURRIER '- L. JOHNSTON_ EXXON
CH~..VRON - - ,4OBIT. ?I-ITL:hIPS OTL
D & M. '" "NS~ CLEICK*=L ' J,
-.
_
. .
_
: .
:
ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfielclCompany
PLEAS~ ACKNOWLEDGE
UNION
VAULT/ANo,FiL~
I~LETURN TO:
ARCO Alaska, Inc,.~.
Post Offic/ ; 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 08-16-85
TRANSMITTAL NO: 5254
ARCO ALASKA, INC.
KUPARUK OPERAS'IONS ENGINEERING
RECORDS CLERK "
ATO-1115B
P.O. BOX 1U0360
ANCHORAGE, AK 99510
TRANSMITTED hEREWITH ARE THE FOLLOWING IT[2dS.
RECEIPT AND RETURN ONE SIGNED COPY OF THIS
PRESSURE FINALS
CAMCO
lB-3
1D-8
1E-5
1H-6
1L-2
1L-5
lQ-6
lQ-9
2A-5
2A-5
2C-4
2F-7
2F-8
2F-9
2G-1
2G-1
2U-5
2U-6
2U-7
2U-8
2X-'l 0
OTIS
·
2A-2
2U-14
2V-2
2V-5
2V-13
2V- 14
zw-7
3B-3
3B-8
PBU 04-21/22-85
STATIC 04-29-85
PBU 04-26-28-85
STATIC 04-29-85
PBU 04-24/25-85
PBU 04-28/29/85
PRESSURE
FALL OFF 05-07-85
PBU 05-12/13-85
PRESSURE
FALL OFF 04-21/22-85 .'
STATIC 05-05-85
PBU 04-24/25-85
PBU 04-14-85
PBU 04-19/20-85
PBU 04-13/14-85
STATIC 04-17-85
PBU 04-29-85
STATIC 05-02-85
STATIC 'O5-03-85
STATIC 05-04-85
STATIC 05-04-85
PBU 04-25/26-85
-S TAT IC 07- 04- 85
'PBU 06-30-85
PBU 07-27-85
PBU 06-25-85
STATIC 06-22-85
STATIC 06-22-85
PBU 07-26-85
STATIC. 06-28-85
STATIC 06- 28- 85
RECEIPT ACKNOWLEDGED:
CURRIER
CtiEVRON*
M*
DISTRIBUTION:
DRILLING W. PASHER
L. JOHNSTON EXXON
'MOBIL* PHILLIPS OIL*
NSK CLERK J. RATHMELL*
PLEASE ACKNOWLEDGE
TRANSMITTAL.
kJFA,TE :... ~ ~
~,-'"'-,".t~.,.'fr. °Jl~ ," ~'.: .......... ' ......
Anchorag~
STATE OF ~ASKA*
SOHIO*
UNION*
K. TULIN/VAULT
ARCO Alaska, Inc.
Post Office BOx 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 11, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501.
SUBJECT' 2U-5
Dear Mr. Chatterton'
Enclosed is the Well Completion Report for 2U-5.
questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU10/L68
Enclosure
If you have any
RECEIVED
.' .. ~,~
,JUt_ I':~ ~'~-
..Alaska Oil & Gas Cons. Cornrn. ission
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
---. STATE OF ALASKA
ALASKA [o .,_ AND GAS GO~SERVATIO~ GG. MISSION
1. Status of Well Classification of Service Well
OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-18
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21281
4. Location of well at surface 9. Unit or Lease Name
488' FSL, 703' FWL, Sec.32, T12N, R9E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1410' FSL, 3573' FEL, Sec.6, TllN, RgE, UM 2U-5
At Total Depth 11. Field and Pool
1180' FSL, 3867' FEL, Sec.6, TllN, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
106' RKBI ADL 25644 ALK 2575
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions
02/26/85 03/04/85 03/06/85*J N/A feet MS LJ 1
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
9318'MD,6111 'TVD 9179'MD,6021 'TVD YES [~X NO []I 1919 feet MD 1500' (Approx)
22. Type Electric or Other Logs Run
D IL/SFL/SP/GR/Cal/FDC/CNL, Gyro (GCT), CBL/VDL/GR/CCL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 235 sx CS II
9-5/8" 36.0# J-55 Surf 4079' 12-1/4" 790 sx PF "E" & 940 sx [~F "C"
Top ~iob performed w/50 .x PF "C"
7" 26.0# J-55 Surf 9265' 8-1/2" 400 sx Class "G" & 250 ,~.x PF "C"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
9139' - 9145' w/4 spf, 120° phasing 3-1/2" 8940' 8917' & 8656'
8970' - 9044'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
8824' - 8870' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
See Well History icompletion details) for frac info.
r'
27. N/A PRODUCTION TEST
Date First Production ! Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED.a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE
(JO,
Form 10407 * NOTE: Tubing was run and the well perforated 4/25/85. GRU10/WC12 Submit induplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 8822f 5785f N/A
Base Upper Sand 8872~ 5819~
Top Lower Sand 89~,8~ 5869~
Base Lower Sand 9148~ 6000~
. .
31. LIST OF ATTACHMENTS
Add~.nd~m
·
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed /~~ ~ Title Ass°ciate Engi neet Date
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands, and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27: 'Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none"~
·
Form 10-407
ADDENDUM
WELL:
3/~5/85
4/01/85
4/02/85
2U-5
Arctic Pak w/250 sx PF "C", followed by 7.7 ppg Arctic
Pak.
RU & rn GCT f/9073'-surf. RIH w/CBL/VDL/GR/CCL & 6.125"
gage ring. Tag btm. Back lashed spool. Fsh ti. Wait
on new WL unit.
Rn CBL/VDL/CCL/GR f/9169'-5994'.
Dril~endent
Date
I~ET URN TO:
ARC(" ' ;a, Inc.
~_, Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215 PAGE
ARCO ALASKA, INC.
KUPARUK OPERATIONS ENGINEERING
RECORDS CLERK
ATO-1115B
P.O. BOX 100360
'ANCHORAGE, AK 99510
~,:~ z'E: 06-19 -8 5
TRANSMITTAL NO: 5230
2 OF 2
~2RANSHITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
~q. ECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL.
***CONTINUED. FROM PREVIOUS PAGE***
2D-5 FLOWING BHP ETC 05-06-85 CAMCO
2D-3 ACID JOB PREP 05-07-85 BAKER
2D-3 ACIDIZE 'C'SD 05-11-85 DOWELL
~_,~ - 9 G.R. SBHP 06-11-85 OTIS
2E-13 SBHP 06-10-85 OTIS
2E-14 SBHP 06-10-85 OTIS
2E-15 SBHP 06-09-85 OTIS
2G-1 FLOWING BHP 04-2 9-85 ' CAMCO
2H-1 BHP&TCL 05-27-85 OTIS
2H-15 SBHP & ETC. 04-29'85 OTIS
2H-1 BHP & ETC. 05-23-85 CAMCO
22q-3 BHP & ETC. 05-23-85 OTIS
2H-4 COMP BHP 05-23-85 OTIS
2.q-14 INT. SBHP&ETC 04-28-85 OTIS
2U-5 SBHP 05 -02-85 CAMCO
2U-6 SBHP & TCL 05-0 3-85 CAMCO
2U-7 SBHP PRE PROD 05-04-85 CAMCO
2U-8 SBHP & ETC. 05-04-85 BAKER/C~MCO
2U-~9 PRESSURE TEST 05-27-85 OTIS
2U-10 BHP SAMPLE 06-05-85 OTIS
2U-16 'A'SD FLUID ID 06-09-85 OTIS
2U-16 PBU 06-07-85 OTIS
2V-10 BHP & ETC. 05-17-85 OTIS
2V-11 ' STATIC 05-12-85 OTIS
2V-11 STATIC 05-23-85 OTIS
2W-13 'C'SD ACID STIM 05-20-85 DOWELL
2X-12 'C'SD ACID JOB 05-12-85 DOWELL
2Z-2 E/LINE FLUID ID 05-03-85 OTIS/CAMCO
RECEIPT ACKNOWLEDGED:
B PAE *
B. CURRIER
C HE VRON *
D & M
DRILLING
L. JOHNSTON
MOBIL*
NSK CLERK
DISTRIBUTION:
W. PASHER
EXXON
PHILLIPS OIL*
J. RATHMELL
STATE OF ALASKA
SOHIO*
UNION*
K.TULIN/VAULT
· .
ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldCompan¥
ARCO Alaska, Inc.
Post Office Bo,, 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 18, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 2U-5
Dear Mr. Chatterton'
Enclosed are copies of the 2U-5 Well History and Addendum to
include with the Well Completion Report, dated 4/4/85.
If you have any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Engineer
JG/tw
GRU9/L80
Enclosures
RECEIVED
J U N 2 z~ 1985
Alaska 0il & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Alaska, Inc,
Post Oflice L~ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 05-29-$ 5
TRANSMITTAL NO: 5199
RETURN TO:
T ]~\NSMITTED
RECEIPT AND
ARCO ALASKA, INC.
KUPARUK OPERATIONS ENCINEERING
RECORDS CLERK,
ATO-!ll5B
P.O. BOX 100360
AI'~HORAGE, AK 99510
IIER-----E%,~ITI] ARE Tile FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
RETURN ONE SIGNED CO['Y OF THIS TRANSMITTAL.
KUPARUK ~$ELL PRESSURE REPORT ENVELOPE DATA:
(ONE COPY OF EACH)
2A-4 04-22-85
2A-7 04-23-85
2F-6 03-21-85
2G-$ 03-21-85
2G-12 03-23-85
2I!-13 04-26-85
2i~-14 04-28-85
2H-15 04-29-85
2U-1 04-11-85
2U-2 04-11-85
2U-3 04-11-85
2U-4 04-11-85
2U-5 05-02-85
2U-6 05-03-85
2U-7 05-04-85
2U-8 05-04-85
2U-13 03-09-85
2U-14 03-21-85
2U-!5 03-20-85
2U-!6 03-15-85
2V-2 03-23-85
2V-SA 03-17-85
2V-UA 01-24-85
2W-4 04-13-85
2X-! 04-14-85
2X-3 04-13-85
2X-13 03-30-85
?,ECEIPT ACKNOWLEDGED:
;PAR*
CURRIER*
M*
STATIC-'C' SAND
STATIC-'A' & 'C' SAND
STATIC-PBU-'A' SAND
PBU-'A' SAND
STATIC-PBU-'A' SAND
STATIC-'A' SAND
STATIC-'A' SAND
~£A~.IC- A SAND
PBU-'A' SAND
PBU-'A' SAND
STATIC-'A' SAND
STATIC-'A' SAND
STATIC-'A' SAND
STATIC-'A' SAND
ST%~/C-'A' SAND
STATIC-'A' SAND
S TAT iC
STATIC-'A'&'C' SAND
STATIC-'A ' &'C ' SAND
STATIC-'A' &'C' SAND
STATiC-'C' SAND
STATIC-'C' SAND
STATIC-'A' &'C ' SAND
STATIC-'A' &'C ' SAND
STATIC-'A'&'C' SAND
P]3U-'A' SAND
DISTRIBUTION:
W. ~AS:I.".R
EXXON
PUiLL!PS OIL*
J. RATHMELL*
ARCO Alaska, Inc. .~''
Post Office E~,.~ 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 30, 1985
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 2U-5
Dear Mr. Chattertoh-
Enclosed is the Well Completion Report for 2U-5.
questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU9/L17
Enclosure
If you have any
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
RECEIVED
J U N 0 z~ 1985
AJaska 0il & Gas Cons. Commission
Anchorage
.... . ' .-~ STATE OF ALASKA '
ALASKA L AND GAS CONSERVATION CC..~MISSION
W,=LL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-18
3. Address 8. APl Number
P, 0. Box 100360, Anchorage, AK 99510 50- 029-21281
4. Location of well at surface 9. Unit or Lease Name
488' FSL, 703' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1410' FSL, 3573' FEL, Sec.6, TllN, RgE, UM 2U-5
At Total Depth 11. Field and Pool
1180' FSL, 3867' FEL,.Sec.6, TllN, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
106' RKB ADL 25644 ALK 2575
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
02/26/85 03/04/85 03/06/85* N/A feet MS L 1
17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
9318'MD,6111 'TVD 9179'MD,6021 'TVD YES [~X NO [] 1919 feet MDI 1500, (Approx)
22. Type Electric or Other Logs Run
D IL/$FL/SP/GR/Cal/FDC/CNL, Gyro (GCT)
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 235 sx CS II
9-5/8" 36.0# J-55 Surf 4079' 12-1/4" 7~)0 ~x PF "E" & 940 sx F'F "C"
TOD iob performed w/SO ,,.x PF "C"
· -
7" 26.0# J-55 Surf 9265' 8-1/2" 400 sx Class "G" ~ 250 ,,.x PF "C"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
9139' - 9145' w/4 spf, 120° phasing 3-1/2" 8940' R917'
8970' - 9044'
26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
8824' - 8870' w/12 spf, 120° phasing DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED
See Well History eomoletion de~.mil.~l for fran infn.
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO
'TEST PERIOD ]~
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
gECEIvE3
'qlaska 0il
&~Gas Coos
~nchorage' Oornrnission
Form 10-407 * NOTE: Tubing was run and the wellperforated 4/25/85. GRUg/Wc20
Rev. 7-1-80 CONTINUED ONREVERSE SIDE
Submit in duplicate
29. 30.
"GEOLoGIc'MARKERs ' ':" '."' :'-' ": ';' ' "FoF~M,~TI'0NTESTS ' '
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH . GOR, and time of each phase.
Top Upper Sand 8822' 5785' N/A
Base Upper Sand 8872' 5819'
Top Lower Sand 8948' 5869'
Base Lower Sand 9148' 6000'
· ',
·
.
31. LIST OF ATTACHMENTS
.
· ~.
............ J · ..... r .............. ·
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~ ~~.J~ Title Associate Engineer Date
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
al! types of lands and leases in Alaska. - .
Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals.for only the interval reported
in item 27. Submit a separate form for each additional interval tb be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27' 'Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none",
Form 10-407
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the entire
operation if space is available.
J Accounting
District County or Parish I State
I
Alaska North Slope Borough
Field Lease or Unit
Kuparuk River ADL 25644
Auth. or W.O. no. ~ T t e
AFE 603627 I ComPlete
WWS #1 API 50-029-21281
Operator [ A.R.Co. W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begun ~Date
Complete I 4/23/85
4/24/85
4/25/85
4/26/85
5/20/85
Date and depth
as of 8:00 a.m.
Old TD
0930 hrs.
Released rig
Classifications (oil, gas, etc.)
0il
.
Producing method
Potential test data
Flowing
Complete record for each day reported
cost center code
Alaska
lWell no.
2U-5
I otal number of wells (active or inactive) on this
DSt center prior to plugging and ~
bandonment of this well
our I Prior status if a W.O.
I
0600 hrs.
7" @ 9265'
~,~179' PBTD, RIH w/pkr on WL 10.9+ ppg NaCl/NaBr
Accept rig @ 0600 hrs, 4/23/85. NU & tst BOPE. RU DA, RIH
w/4" csg gun, 4 SPF, 120° phasing, perf f/9145'-9139',
9044'-8970'. RIH w/5" csg gun, 12 SPF, 120° phasing. Perf
f/8870'-8824'. PU WL pkr & tail pipe assy, RIH.
7" @ 9265'
9179' PBTD, Displ well w/crude & diesel
Crude/Diesel_
RIH w/pkr & tailpipe assy, set @ 8904'. RIH w/274 its, 3½",
9.3#, J-55 EUE 8RD IPC tbg. Set pkr, shear SBR, lnd tbg.
BPV.' ND BOPE, NU & tst tree. Displ well to crude.
Set
7" @ 9265'
9179' PBTD, RR
Crude/Diesel .~
Displ well to crude. Tst SSSV. Set BP.V'~ Ri{ @ 0930 hfs,
4/25/85. I~ ~WcH"~' ....
S-~-~ '19~',Top Pkr @ 8656',Btm Pkr @ 8904',"D" Nipple@ 8931'
Tailpipe @ 8939'.
Frac well in-7 stages w/total of 348 bbls gelled diesel, 700#
100 mesh & 15,100# of 20/40 mesh.
PB Depth
4/25/85 Kndofrig
IType complelion (single, dual, etc.)
- -Single
Official-rese~oir name(s)
Kuparuk Sands
9179' PBTD
Rotary
ED
JNew TD
Date
Well no. Date R .... oir i Producing Interval O,, or gas Test time Production
Oil on test G J-- i V
Pump size, SPM X length Choke size T.P. C.P. Water % GOF:I Gravity Allowable ,,, Effective date ' "°~ 85
corrected alaska Iii & Gao ,.,.
-v ,,uns. 'Jommission
Anchorage
The above is correct
Signature J Date {Title
For form preparation ar~ distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drillin~ Superintendent
ARCO Alaska, Inc.
Post Office Bo,, 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 23, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT- 2U-5
Dear Mr. Chatterton-
Enclosed is the Well Completion Report for 2U-5. I have not yet
received a copy of the well history, but when I do, I will
forward a copy to you. Also, tubing details will be submitted
when the well is completed. If you have any questions, please
call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU6/L117
Enclosure
RECEIVED
MAY 2 8 1985
Alaska Oil & Gas Cons. Commission
Anchorag~
ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA ~
ALASKA ._ AND GAS CONSERVATION CC VIISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-18
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21281
4. Location of well at surface I~-[; ~!.'. '¥."%i'~'~'~' 9. Unit or Lease Name
488' FSL, 703' FWL, Sec.32, T12N, RgE, UN ~ i Kuparuk River Unit
At Top Producing Interval I ! 10~ Well Number
1410' FSL, 3573' FEL, Sec.6, TllN, RgE, UM iSurf. .z/ 2U-5
At Total Depth lB. H.._~../~_~_ 11 Field and Pool
1180' FSL, 3867' FEL, Sec.6, TllN, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool
106' RKB) ADL 25644 ALK 2575
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
02/26/85 03/04/85 03/06/85 N/A feet MS L N/A
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD)19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost
9318'MD,6111 'TVD 9179'MD,6021 'TVD YES D[X NO [] N/A feet MD 1500' (Approx)
22. Type Electric or Other Logs Run
D IL/SFL/SP/GR/Cal/FDC/CNL, Gyro (GCT)
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 235 ~x C$ II
9-5/8" 36.0# J-55 Surf 4079' 12-1/4" 790 sx PF "E" & 940 ~X 'F "(?'
Top job performed w/50 ;x PF "C"
7" 26.0# J-55 Surf 9265' 8-1/2" 400 sx Class "G" & 250 x PF "C"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
None N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
,.,
27. N/A PRODUCTION TEST
Date First Production [ Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCr WATER-BBL CHOKE SIZE IGAS-OILR/~TIO
:TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATEDi~. OIL-BBL GAS-MCr WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE
,
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE -
RECEIVED
MAY 2 1985
Alaska 0ii & Gas Cons. Commission
Form 10-407 TEMP/WC10 Anchorage Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. ; 301
GEoLoGiC MARKERs ": -.'. i: ' '.. ' FORMATION TESTS
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 8822' 5785' N/A
Base Upper Sand 8872' 5819'
Top Lower Sand 89~8~ 5869' · ·
Base Lower Sand 91~+8' 6000'
i- .
.: ,
:
,
·
.
·
. .
31. LIST OF ATTACHMENTS
:
-,~ ..... r ...... ,~ -- - r ' - - ·
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
·
:
,,,
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none"..
Form 10-4.07
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
April 10, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2U-5
Dear Mr. Chatterton:
Enclosed is the Well Completion Report for 2U-5. I have not yet
received a copy of the Well History, but when I do, I will
forward a copy to you. Also, the bottomhole location, geologic
markers, TVDs, and tubing details will be submitted when the
gyroscopic survey is run and the well completed.
If you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRU5/L99
Enclosure
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
. ,~--... STATE OF ALASKA
ALASKA ~_.~- AND GAS CONSERVATION CQ..,MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-18
3'. Address 8. APl Number
P. 0. Box 100B60, Anchorage, AK 99510 50- 029-21281
4. Location of well at surface 9. Unit or Lease Name
488' FSL, 70B' FWL, Sec.~2, T12N, RgE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
To be submitted when gyro is run. 2U-5
At Total Depth 11. Field and Pool
To be submitted when gyro is run. Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
106' RKB ADL 25644 ALK 2575
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
02/26/85 0B/04/85 0B/06/85I N/A feet MS LI N/A
17. Total Depth (MD+TVD)gB18,MD 18. Plug Back Depth (MD+TVD) 9179'MD YES'9' Directional Survey[] NO [~X I20' Depth where SsSV setN/A feet MD I21' Thickness °f Permafr°st1500, (Approx)
"~2. Type Electric or Other Logs Run
D I L/SFL/SP/GR/Cal/FDC/CNL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECQRD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 255 sx CS II
9~5/8" 36.0# J-55 Surf 4079' 12-1/4" 790 sx PF "E" & 940 sx 'F "C"
Top job performed w/50 sx PF "(;"
7" 26.0# J-55 Surf 9265' 8-1/2" 400 sx Class "G" & 250 ~x PF "C"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD)
None N/A
26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OI[-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAs-oILRATIO
TEST PERIOD
Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE
RECEIV .D
APR 1 g 19B5
Alaska 0ii & Gas (,u~s. Commission
Form 10-407 TEMP/WC03 Submit in duplicate
Rev. 7-1o80 CONTINUED ON REVERSE SIDE
29. 30.
·
·
GEOLOGIC MARKERS- " " FORMATION TE~;'i'S
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
N/A N/A
.,
·
. .
.
..
31. LIST OF ATTACHMENTS
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Associate Engineer
INSTRUCTIONS
General: This form is designed for submitting a'complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none"..
Form 10-407
Oil and Gas Company
Well History- Initial Report- Daily
~ Instruotione: Prepare and submit the "Initial Repori" on the first Wednesday after a well is spudded or workover operations are starled.
Daily work prior to spudding should be summarized on the form giving inclusive dates only.
District
Alaska
Field
Kuparuk River
Auth. or W.O. no.
AYE 603627
Doyon 9
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun IDate
Spudded
Date and depth
as of 8:00 a.m.
2/27/85
2/28/85
ICounty, parish or borough
North Slope Borough
Lease ADL 25644
or
Unit
ITitlo Drill
IState
API 50-029-21281
3/01/85
3/02/85
thru
3/04/85
Complete record for each day reported
J Hour
2/26/85 2100 hrs
Alaska
IWell no.
2U-5
JARCO W.I. ·
56 24%
IPrior status if a W.O.
16" @ 115'
652', (547'), POH
Wt. 9.2, PV 16, YP 18, PH 9.0, WL 19.2
Accept rig @ 1600 hrs, 2/26/85. NU diverter sys. Spud well
@ 2100 hfs, 2/26/85. Drl, DD & surv 12¼" hole to 652'.
8W
30W
65W
l15W
16" @ 115'
2839', (2187'), Drlg Ahead @ 2839'
Wt. 9.6+, PV 16, YP 22, PH 9.0, WL 16.0, Sol 9
Drlg & surv 12-1/4" hole f/652'-2839'.
540'MD 0° 540'TVD
747'MD 6.7° S43.4W 747'TVD 12'VS S9
928'MD 13.3° S42.4W 925'TVD 44'VS S32
llll'MD 19.2° S43.8W ll01'TVD 95'VS S69
1322'MD 25.2° S34.6W 1296'TVD 174'VS S131
9-5/8" @ 4079'
4097', (1258'), Cmt'g
Wt. 9.7, PV 18, YP 24, PH 9.0, WL 12.8, Sol 10
Drl & surv 12¼' hole to 4097', circ hi-vis sweep, short trip,
POH. RU & rn 94 jts, 9-5/8", 36#, J-55 w/FS @ 4079'. Cmt @
report time.
2810', 58.3°, S41.6W, 2321 TVD, 1216 VS, 931S, 788W
3333', 58.8°, S40.6W, 2594 TVD, 1661VS, 1267S, 1081W
3648', 58.8°, S41.6W, 2754 TVD, 1930 VS, 1470S, 1258W
4067', 57.2°, S39.7W, 2979 TVD, 2285 VS, 1739S, 1490W
9-5/8" @ 4079'
9277', (5180'), Circ'g
Wt. 10.3+, PV 17, YP 14, PH 9.5, WL 4.8, Sol 14
M&P 790 sx PF "E" @ 12.3 ppg, followed by 940 sx PF "C" @ 15.6
ppg. Bump plugs. Had full rtns thruout job. No cmt rtns to
surf. ND diverter. Perform 50 sx top job w/PF "C" @ 15.6 ppg.
NU BOPE & tst same. Tst csg. DO cmt & flt equip + 10' new
formation. Conduct formation tst to 13.4 ppg EMW. Drl & surv
8½" hole to 9277'. Took 14 bbl g~in. SI; no press. Circ; no
gain while circ'g. I~~~0.4.
4681', 58.0°, S40.9W, 3308 TVD, 2802 VS, 2135S, 1825W
5021', 53.3°, S46.9W, 3500 TVD, 3083 VS, 2337S, 2020W
5687', 53.9°, S47.5W, 3895 TVD, 3618 VS, 2701S, 2413W
6321', 53.7°, S46.5W, 4270 TVD, 4129 VS, 3050S, 2787W
6955', 54.3°, S46.5W, 4642 TVD, 4641VS, 3403S, 3159W
7583', 53.6°, S47.3W, 5012 TVD, 5149 VS, 3750S, 3530W
8050', 50.9°, S49.8W, 5298 TVD, 5517 VS, 3995S, 3807W
8649', 48.0°, S49.5W, 5688 TVD, 5971VS, 4289S, 4154W
The above is correct
Signature
For form preparation arid dist-ri~i~tion,-
see Procedures Manual, Sectiorf'10,
Drilling, Pages 86 and 87.
JDate 4/16/85 [Title
Drilling Superintendent
ARCO Oil and Gas Company
Daily Well History-Final Report
~..struclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representalive test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
District ICounty or Parish
Alaska
Field ~hease or Unit
Kuparuk River I ADL 25644
Auth. or W.O. no. ]Title
AFE 603627 I Drill
Doyon 9 AP1 50-029-21281
Operator A.R.Co. W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begun Date
Spudded 2 / 26/85
3/05/85
3/06/85
Date and depth
as of 8:00 a.m.
3/07/85
Complete record for each day reported
Accounting cost center code
State
North Slope Borough Alaska
I otal number of wells (active or inactive) on this
DSt center prior to plugging and I
bandonment of this well
our I Prior stalus if a W.O.
2100 hrs
9-5/8" @ 4079'
9318', (41'), Logging
Wt. 11, PV 18, YP 20, PH --, WL 4.4, Sol Jl~
C&C to 10.4 ppg. Drl f/9277'-9318', C&C mud to 10.6 ppg, make
20 std short trip. C&C mud to 10.8 ppg, 10 std short trip.
C&C mud to 11.0 ppg, POH. RU & rn DIL/SFL/SP/GR/CAL/FDC/CNL
f/9310'-4079'.
9318', 48°, S49.5W, 6135 TVD, 6467 VS, 4613S, 4533W
9-5/8" @ 4079'
9318', (0'), Rn'g 7"
Wt. 11.1, PV 24, YP 17, PH 9.5, WL 4.6, Sol 16
Log DIL/SFL/SP/GR/CAL/FDC/CNL f/9310'-4079', RD Schl.
9114'-9318', CBU, POH, LD DP. Chg rams to 7" & tst.
begin rn'g 7" csg.
RIH, rm
RU &
Well no.
2U-5
7" @ 9265'
9179' PBTD, RR
11.0 ppg brine
Rn 220 jts + 2 40' mkr jts, 7", 26#, J-55 BTC csg w/FS @ 9265',
FC @ 9179' (top). Cmt w/400 sx C1 "G w/l% CFR-2, 5% KCl & .3%
Halad-24 @ 15.8 ppg. Displ w/brine, bump plug. CIP @ 1400
hrs, 3/6/85. Lnd 7". ND BOPE, NU & tst tree to 3000 psi; OK.
RR @ 2015 hrs, 3/6/85.
Old TD
Released rig
New TD
Date
2015 hrs.
Classifications (oil, gas, etc.)
Oil
Producing method
Flowing
Potential test data
3/6/85
PB Depth
Kind of rig
9179' PBTD
Rotary
Type completion (single, dual, etc.)
Single
Official reservoir name(s)
Kuparuk Sands
RFCF_!VED
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
Oil on test C~Ufr~ 4
Alaska Oi & Gas Crfn~ r
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effe~_.~ate
corrected
~mmissi0n
The above is correct
Si g n at u re ~jCl~Jj~ L~~i~· IDate 4/16/85
For form preparak~n al?d distri~Jt~n~
see Procedures anua, Section 1 ,
Drilling, Pages 86 and 87.
Drilling Superintendent
ADDENDUM
WELL:
3/~5/85
2U-5
Arctic Pak w/250 sx PF "C", followed by 7.7 ppg Arctic
Pak.
Drilli~SuP~-int endent
$ UB-$ URFA CE
DIRECTIONAL
SURVEY
['~ UIDANCE
['~ONTINUOUS
[-~ OOL
Company
ATLANTIC RICHFIELD COM~.ANY
Well Name
Field/Location
2U-5 (488' FSL~ 703' FWL, S32, T12N, R9E, __UM)
KUPARUK. NORTH SLOPE. ALASKA
Job Reference No.
70340
Lo~{3ed By:
LESNIE
RECEIVED
MAY 2
Alaska Oil & Gas Cons, C~;missiori
Ap~chorage
Date
08-MAY- 1985
Computed By:
CODNEY
ARCO ALASKA, INC,
2U-5
KUPARUK
~ETHODS OF COMPUTA?ION
TOOb LOC~'tTON: TANGENTIAL- averaqed dev~,ation ano azimuth
TNTERPO.b~TTON~ LINEAR
VERWlCAL SECTTON: HOt{lZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 44 DEG ~ MTN W~]~'l~'
ARC[') /%hASKA, TNC,
211,'5
KUPARtIK
NnRTH SLOPE,ALASKA
CO~PUTATZnN DAT~J 4-~AY-85
KELGY BUSHI~gG ~bEVATIUN: 106.00
INTERPOLATED VALUES FnR EVEN 100 FEET BF MEASURED DEPTH
TRUE SUB-SEA COURSF
4EAS[IRED VFRTICA[, VERTTCAL DEVIATION AZI~UTH
DEPTH DEPTH DEPTH DEG NIN D~G MTN
0 0 N 0 0 E
-6,00 0 lq $ 30 lB ~
94. O0 0 14 S 49 47 F
194.00 0 25 S 18 57 ~
293,99 0 25 $ 40 0 E
393,09 0 34 S 33 59 E
493,07 2 1 S b t W
593,75 4 50 S 28 37 W
693,12 8 ~. S 36 3P, W
791,57 1! 58 S .]9 14 W
0,00 -106.00
VERTICAL hOGLEG RE'CTANGULA[~ COUPDTNATES HORIZ, DEPARTURE
SECTION SEVERITY NORTlt/SOUTH EA~T/WEST DIST. AZZN~ITH
FEET DEG/1 00 FEET FEWT FEET DE~
0.00
100,00
~00.00
300,00
400,00
500,00
600,00
700.00
800,00
900,00
0.00 o,on O,00 N 0.U0
0.02 0,q0 0,22 S 0,20
O.ll 0.25 0,66 S 0.52
0,35 0,24 1,16 $ 0,69
0,53 0,21 1.81 S 1.08
0,62 0,44 2.,47 S 1,63
1,56 ~,05 4,15 $ 2,01
7,56 1,85 10,1! S 0,50
18,]7 3 20 19,34 S 6 52
3:4 2.90 s 17:3o
100 O0
2OO 00
3OO 00
309 99
499 90
509 97
699.75
799,1~
807,57
lO00.00 904,71 R8R,71 15 20
1100,00 1090,33 084.33 18 47
1~00,O0 11~4.00 1078,00 ~1 44
1300.00 1276 07 1170,07 ~4 2.]
1400,~0 1366 13 1~60,1.3 ~7 6
500 O0 1453 86 1347,86 ~0 14
~600 O0 1538 33 143~,]3 34 34
1700 O0 1618 60 I~1~,60 ]7 35
1800 00 1697 73 1591.73 38 9
1900 O0 1774 93 1668,93 40 55
2
000 O0 1848 50 174~.50 44 33
S 39 20 W 59,28 ~,37
S 39 4~ W 88,40 4,05
S 37 26 W 123,19 2,44
$ 33 2 W 1.61,69 3,0~
S 32 57 W 204,1,7 3,23
~ 35 37 W ~51,37 3,85
$ ]9 29 W 304,47 ~%,84
S 39 52 W 363 89 1,23
S ]9 3~ W 424:~2 1,97
$ 39 44. W 488'13 3.25
$ 39 55 W 555 60
$ 40 14 w 628:02
S 40 26 W 704,84
S 40 36 W 785,51
S 41 1 W 869 ~6
51 24 S 32,43 W 60,64 $ 39 19 ~
73 75 S 5{,O6 W 89.10 ~ 34 ,41 ,~
101 04 S 72,93 W 124 61. 5 35 49 W
132 83 S 95,50 W 163:59 G 35 42 W
169 50 S 118,79 W 206'98 5 35 1 w
209 08 $ 145.84 W 254 92 $ 34 53 W
251 39 S 178 54 W 308:34 8 35 22 W
296,98 S 2!6,99 w 367,77 8 36 8 ~
344,14 S 255,85 W 4~8,83 $ 36 37 ,
303,07 S 296,39 W 492,29 S 37 1 ~
4 16
3 57
3 59
3 b7
0 84
445 07 $ 339 73 w 559,91 S 37 21 w
500 61. S 3~b 53 W 632,47 8 37 40 W
559 32 S 436 38 W 709,42 S 37 57 ,~
620 77 S 488 94. W 790,20 S 38 13 W
684 33 S 54,3 74 W 874,05 $ 38 28 W
958,bO
2500 O0 ~ 4
oo
2700,00 2254
2800.00 2307
2900,00 2360
3000.00 2413,
3100.00 2466
320000 ~519
3300~00 2570
3~00,00 ~621
3500,00 2673
3600,00 ~724
3700,00 2776
3800,00 2828
3900,00 2881
37 2041,37 57 50
76 2094,76 57 38
1~ 2148.1.2 57 55
O0 2~01.00 58 2
05 2254,05 57 5R
21 2307,21 57 46
50 2360 50 57 58
O0 2413~00 58 48
48 2464.48 59 4
76 2~15.76 59 0
11 2567 11 59 4
67 2618:67 58 5~
53 2670,53 58 35
85 2727,85 58 19
57 2775,57 57 58
S 41 19 W 953
S 41 39 W 1038
S 41 51, W 1122
S 42 6 W 1207
S 41 52 W 1292
76
19
68
48
16
41 49 W 13'76,77
42 4 W 1461.31
41 59 W 1546,34
al 59 W 1631,99
42 21 W 1717.78
42 18 W 1803 53
4,2 13 W 1889~14
42 11 W 1974i58
42 9 W 2059 73
42 11 W 2144,64
0 lq
0 42
0 45
0 48
0 21
0 21
0 47
1 O1
0 43
0 24
0 39
0 20
0 41
0 25
0 52
747
811
874
937
1000
99 S 599 51 W S 3Lq 42 ~
35 S 655 50 W 1043,06 $ 38 5b t
44 S ';1.1 84 W ~127,54 6 39 ~
48 S 8?5 37 W 1297, 8 3g 31 W
1063 6~ $ 881 83 W 1381 63 $ 39 39 W
1176
1189
1253
1,,31'1
1380
1443
1,507
1570
1.633
53 S 938
73 S 995
52 S 1.052
50 S 1,1
93 S 1225
25 S 1~8~
43 $ ~340
40 S 1~97
41 W 1466
43 w 1 551
71 W 1636
40 W 1722
21 W 1808
82 W 1894
27 W 1979
46 w ~064
52 W 2149
19 6 30 4'1 ~v
23 $ 39 55 W
92 5 40 I ~
71 fi 40 7 ~
$ 40 14 w
09 $ 40 19 w
54 $ 40 2~ ~
72 $ 40 ~U ~
06 5 40 32 W
ARCO AbASKA, TNC,
2~I-5
K!IPARUK
NDR?H St, OPg,A[,ASKA
CDMPUTATInN DATE~ 4-MAY-85
DATE OF $0RVE~: 31-MAR-85
KELLY RUSHING FhEVATION: lfib,O0 FT
INTERPOLATED VAI,UE$ FOR EVEN 1.00 FEET OF MEASUREO DEPTH
T~UE SU~-SEA COU.SF
~EASURED VERTICAL VERTTCAb DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DFG MIN
VERTICAL DOGLEG RFCTANGUhAR COtiROINA'rF$ HORIZ, DEPAR'I'IJKF.
SECTION SEVERITY NORTH/SOOTH gAS'F/WEST DIST,
FEET DEG/IO0 FEE~ FE~'I' FEET DE~
4000 00 ~9~4,79 282~.79 57 47
4100:00 29~8.48 2~89.48 57 17
4200 O0 ]042.40 2936,40 57 26
4300~00 3096.16 2990,16 57 29
4400 00 ~149.7~ 304~,78 57 4~
4500'~0 ~203 02 3097,02 57 58
4600'00 32K5 87 3149,87 58 ~
4700:00 3308 83 3?02,83 57 5~
4800.00 3362 1~ 3956,12 57 48
4900,00 34,5 60 3309.60 57 22
5000,00 3470,32 3354,32 55 25
5100,00 ~5~9,46 342~.46 53 9
5200.00 ~5~9.44 3483,44 53 10
5~00,00 3649.27 354~,27 K3 20
5400,00 ;708.87 3602,87 53 31
5500,00 3768.'18 366~,18 53 3]
5600..00 3827.58 3721,58 53 40
5700 00 ]886,67 3780.67 53 49
580,0:00 3945,~ ~39.60 53 55
5900,00 4004, 89~,38 54 6
6000 O0 4062.94 3956.94 54 g
6100 O0 4121.51 401~.51 54 7
6200 O0 4180.22 407 : 22 54 1
6~00 O0 4239'02 4133 02 53 53
6400 O0 4297.9~ 4,91.92 53 5~
6500 O0 435~.59 4~50 59 54
~0n.o0 44,4,99 430Bi99 54
0~,00 4473.2~ 4~67 23 54 25
6800-00 4531 3~ 4425,~2 54
6900.00 4589:36 448].36 54 35
7000,00 4647 54 4541.54 53 59
7100,00 4706 84 4600.84 53 3~
7200,00 4766 37 4660,37 53 26
7300.00 4825 91 4719 91 53 25
7400 O0 4885 38 4779:~8 53 ]3
7500'00 4944 7] 4838:73 53 40
7600'00 5003 94 4~97 94 53 36
7700,00 5063 35 4~57 ~5 53 24
7800.00 51~3,3~ 5017:~2 52 52
7900,00 5185,07 5079.07 50 5~
S 42 4 W 2229.73
S 41 5& w 231],52
S ~1 42 W 2397,64
S 41 26 w 2481.85
S 41 37 w 2566.15
S 4~ 32 w 2650.69
$ 41 30 w 2735.48
S 41 23 w 2820,18
$ 41 3] W 2904.68
S 44 48 W 2989,'1
S a7 4 W 307~,77
S 49 0 W 3153.20
S 48 53 W 3232,97
$ 48 46 W 3312 86
S 48 ]~ W 3~92:O5
S 48 31 W 3473,96
S 48 28 W ]553 51
$ 48 22 W 3633~99
S 48 16 W 3714,60
$ 48 12 W 3795,32
S d8 0 W 3876 22
S 47 54 W 3957 13
S 47 5] W 4037 93
S 47 50 W 4118 67.
$ 47 51W 4,99 33
S 47 36 W 4280.18
S 47 12 W 4361.,~5
$ 47 16 W 444~o45
S 47 1] W 4523 75
S 47 1W 4605:09
$ 46 57 W 4686.35
$ a6 57 W 4766,79
$ 47 4 W 4847,06
$ 46 56 W 4927,33
$ 4b 51 W 5007,64
S 4~ 51W 50~8,O6
S 46 37 W 5168,58
$ 46 25 w 5248'07
S 46 20 W 5328'~5
$ 47 41 W 5407,5!
0.32
0,49
0,48
0,06
0,35
0,15
0.20
0.50
3.63
5 2~
0,lO
0,28
0,32
0.34
0,33
0 20
OilO
0 26
,26
(J,05
0 4O
0 24
0 4O
0 3~
0 34
0:17
0,39
0 96
0 64
0 21,
0 06
0 12
0 ]0
0,36
0.97
0,93
1696.18 S 1454,32 W
1758.84 S 1510,81 W 2318
,821,58 S 1566,9q w 2402
~884,70 S 16~2,90 W 24~7
~947.90 S ~678,85 W ~571
2011 20 S 1735,06 W 2655
2074 76 $ 1791,33 W 2741
~138 34 S 1~47,48 W 78~5
220'1 79 S ~9~3,46 W ~9~0
~263,8, S 1960,8~ W 2994
2234 29 6 40 3o ~
64 S 40 39 ~
8] S 40 42 w
15 $ 40 43 w
55 $ 40 4.5 ~
19 S ~0 4'1 ~',
08 5 40 48.,
89 S 40 ,49t
51 S 4o 5u ~
93 S 40 5~ w
23~1 87 S ~021 09 w 3078,29 6 41 2
2]75 36 S ~081141W 3158.26 6 41 13
2427 93 S 7141 73 W 3237,57 S 41 74
2480 54 $ 9202 0~ W 33~7,03 6 41 35
~533 70 $ ~2~2 35 W 33q6,74 S 41'45
~587 OJ. S 2322 68 W 3476 70 $ 41 55
2640 34 $ 23~2 92 W 3556 54 S 42 3
2693 86 S 2443 28 W ~636 8~ $ 42 12
2747,58 S 2503 62 W 3'117 17 $ 42 20
2801,47 S 2563 95 W 3797 54 8 42 27
~855 58 S 2024,32 W 3878
2909 89 $ ~08~,49 W 3959
2964
3072
3126
3181
3237
3 7
17 S 2744,54 W 4039
35 5 2804,60 W 4120
46 S 2864.62 W 4200
9' S ~9~4,56 W 428~
87 $ 29~.4,~0. W 4362
14 S 30~3,9~ W 4443
36 $ ~103,
76 $ 316],
3403 23 S 3222 S8 w 4687,10 $ 43 25 w
3458 22 $ 3281 70 w 4767 48 S 43 29 w
3512 99 S 3340 48 w ~847 67 S 4] 33 ~
3567 76 S ~399 27 w 4927 87 S 93 30 ~
3622 67 S 3457 98 w 5008 13 6 43 40 w
367'I 72 S 3516 70 W 5088 50 $ 43 43 !~
3732 95 $ 3575:39 W 5168 97 S 43 45 ,~
3788 20 $ ]533.76 W 5249 ,~2 S 43 48 ~
3843 55 S 3591,64 W 5329 26 5 43 50 ~
3897,16 S 3749,17 W 5407 79 $ 43 53 %m~
ARCD ALASKA, YNC.
20'5
NORTH SI,OPE,ALASKA
CDMPUTATIOh DATE:, 4-.~ AY- ~ 5
P~ 3
DATg'OF SURV~Y~ 31-~AR-85
KELLY ~UgH]NG ELEVATION: lOb,O0 FT
ENGINEER: LESNIE
INTERPOLATED VAT,LIES FOR EVEN 100 FEET OF MEASURED DEPTtt
TRUE SUM-SEA COUP8E
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG M~N DEG MTN
VERTTCAL, DOC, bEG RECTANGULA~ COORDINATE8 HOHIZ, DEPARTURE
SECTION SEV£RI~Y NORT~i/SOUTh EAST/WEST DIS'f, AZI~,~I'rH
FEET DEG/IO0 FEET FE~T FEET DEG ~IN
BO00.O0 ~248.06 514~.06 51 13
8100.00 5311.31 5205,31 50 17
8PO0 O0 5375.4] 5~60,43 49 57
8300'00 5439,94 5~,94 ~ ~
8400'00 5504,66 53 ,66
8500'00 5570.35 541~.35 i~ ~
8600'00 56~6,73 5~ ,73 ,
8700:00 5703,75 5597,75 47 5~
8800 00 5770.70 5664'70 47 58
8900:00 58~7,40 $73~:40 48 22
9000 O0 5903,67 5797,67 48 4~
9100:00 .~969,17 58b~,~7 49 ~4
99~00.00 6034,15 592,i15 49 30
00,00 6099,00 599] 09 49 30
9310.00 6110,78 6004 78 49 30
S 48 45 W 5485.02
S 49 35 w 556~.20
$ 49 24 W 5638.64
S 49 ~ W 5714,78
S 48 4g W 5790,78
S 48 20 W 5865,96
S 48 l~ W 5940.58
S 48 ~ W 0014,66
S 49 49 W 6088.73
S 51 1~ W 616~,79
S 51 48 w 6237,10
S 52 21 W b31~,03
$ 52 32 W 6387,28
S 52 3~ w 646?,57
S 52 3~ W. 6476,12
1,27
0.63
0'76
0,37
0,57
O. 6q
1 97
0:57
0,85
1,20
§:oo
00
0,00
3949,00 S 3807 O0 W 5485,24
3909,53 S 3865:70 w 5562,37 $ 44
4049,]4 S 39~4,09 W 56]8 76
4099 16 S ]9~2,01 W 5714 85
4149:24 S 4039,50 w 5700 83
4199'02 S 40gL,tO W 5865 99
4248,74 S ~151,98 w 5940 60
42q8,34 $ a207,1g W 60~4 66
4347,36 S 4263,00 W 6088,7]
4394,51 S 4320,67 W 6162,79
4441,08 S 4379 3~ W 6237
44R7 64 S 443~:~5 w 63~2 07
453.3,90 S 44°9,15 W 6387 38
4580,15 S 4559,51 W 6462 73
4588,47 S 4570,38 W 6476 30
ARCO AbASKA,
2U-5
KHPRRUK
CDNPUTA~ION DATE: 4-~AY-85
PAGE
S 39 29 W
S 39 55 w 555.60
$ 41 49 W 1176,77
S 42 4 W 2229.23
S 47 4 W 3o79,77
S 48 0 w 3876.22
$ 46 57 W 4686,35
$ 48 45 w 5485.02
S 51 48 W 6237,10
9318,O0 6110.78 b004,78 49 30 S 52 32 W 6476,12
0,O0 0,00 -106.00 0 0
ln00.O0 994,7] 888.71 15 20
2000 O0 1848.50 1742,50 44 33
3000:00 241.3 21 2307,21 57 46
4000.00 2934 79 2R28.79 57 47
5000.00 3470 32 3~64,~2 55 25
6000.00 4062 94 3q56,94 54 a
7000.00 4647 54 454~,54 53 59
8000 ~0 5248 06 5142.06 51 11
9000:00 5903 67 5797,67 48 42
INTFRPDI. ATED VALUES FOR EVEN 100O FEET Dy MEASURED DED'I'
ENGTNE:~.:R: ~ESNIF
TRUE SUR-SEA COURSE
qEASURED VERTICAl. VERTIC&L DEVIATION AZIMUTH
DEPTH D~PTH DEPTH DEG Nih DEG MIN
VERTICAL DUC, bEG RECTANGULAR COORDINATES HORIZ. DEPARTS]RE
5ECTIDN SEVERITY NORTH/SOUTH ~.AST/WES'I' DiS't. AZI~fH
FFET DEG/~O0 FE~T FEFT FEET DEC ~I~,~
3,37
4,~6
0,
0,3~
0,26
0,00 N
51,24 S
445,07 S 339 73 W 559
1063,62 S B81183 W 1381
~696 18 g ~45413~ W 923~
23~1 87 S ~021 0O W 3078
~855 58 $ ~6~4,32 W 3878
3403 23 S 32~2,88 W 4687
3949 O0 S 3~07,00 W 5485
4441 OB S 4'379,3~ W 6237
0 O0 E 0,00 N 0 U E
32143 W 60 64 $ 32 19 ~
91 $ 37 21 ~
63 $ 3g 39 ~
29 6 4o 3o w
29 S 41 2 ,~
32 $ 42 3~~
10 $ 43 2
24 ~ 43 57 ~
12 ~ 44 35 ~
U,UO 45~8,47 S 4570,38 W 6476,30 6 44 53 ~
DATE OF SURVEY: 31-MAR-85
KEI, LY BUSHYN~ ELEVATION: 106,o0 F'I'
ARCO AL, ASKA,
2U-5
KUPARUK
NORTH SLOPE,AI',ASKA
CDMPUTATION I)A'i'E: 4-NAY-85
PAGE 5
ENGTNF~R: LESNIE
INTERPOLATED VALUF$ FOR EVE~ 100 FEET OF SUB-SEA OEDTN
TRUF SUB-SEA CDURSF
~EASURRD VERTICAl, VE~TTCAb DEVYATION AZIMUTH
DEPTH DEPTH ~EPTH DEG
o,on -106,00
6,00 -100,o0
0 0 N 0 0 ~
0 3 ~' 16 51 ~
0,00 0 20 $ 27 41 ~
tO0.O0 0 1~ $ 45 5R F
200,00 0 25 $ ?0 50 F
~00,00 0 25 S 40 54 F
400,00 0 36 ~ 32 20 E
500.00 2 15 S 8 47 W
600.00 4 58 $ 29 1 W
700,00 8 15 S ]6 53 W
VERTTCAL DUGhFG RFCTANGUL~R COO~DTNA'£ES HORfZ, DE. PARTI!I~F
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZTNUT~
FEET DEC/lOO FEET FEET FEET DEG
0.00
6.00
106.00
206.00
]06,00
406.01
506.01
606.0]
706 ~8
806~94
0.00 0.00 0,00 N 0.00
0,00 0,03 0,00
0.03 0,34 0,25 S 0.21
0.11 0.34 0,68 S 0,54 F 0.87
0.]6 0 25 1,21 S 0.71
0.54 0~23 1,8{ S 1,11
0.63 0,58 2,5~ S 1,66
1,75 4,23 4 39 S 1,97 ~ ~ 81 S 24. 1.
8,08 1,92 10~58 S 0,'16 W 10~60
lu,]2 ~,68 20.12' $ ?,09
106 O0
206 O0
306 O0
406 O0
5O6 O0
606 O0
7O6 O0
8O6 O0
906 O0
~1 ]O06
60 1106
73 1206
97 1306
07 1406
14 1506
O6 1606
57 1706
55 1806
R 39 15 W 37,55
S 39 25 W 62 37
$ 39 28 W 93:86
S 36 39 W 132,00
32 1~ W 175,21
34 14. W ~24,81
S 38 15 W 283,01
$ 40 3 W 354,16
S 39 3] W 431.38
S 39 47 W 515,62
q08 63
1011
1116
1223
1332
1445
1561
16804
1~1
1941
800,00 12 15
O0 900,00 15 4t
O0 lO00'O0 J9 25
O0 1100,00 22 16
O0 1200,00 ~5 18
O0 1300 O0 28 30
O0 1400~00 32 55
O0 1~00 O0 37 3~
,ooioo
O0 O0 42 10
2241 67 2006,00 ]go ,00 53 4~
2422 24 2106.00 0o,00 57 45
2609 77 2206 oo 210o,00 57 3~
2798 12 2306 O0 2200,00 58 2
2986 .47 2406 oo 2300,00 57 46
3174 ~1 2506 oo 2400,00 58 32
3369 23 2606,00 2500 oo 59 lo
3563,85 2706,00 2600~00 58 56
3756.40 2806,00 2700'00 58 26
~ 2800!00 57 50
2900 00 57 20
30 3106 O0 3000 nO 57 31
63 3206 OO 3100,00 57 59
68
3306 O0 3200,00 57 52
18 3406 On 3300.00 57 29
85 3506 O0 3400,00 53 23
64 3606,00 3500,00 53 13
17 3706,00 3600,00 53 31
62 3806,00 3700,00 53 34
394~.93 2906
413 41 3006
4318
45O5
4694
4882
506O
5227
5395
5563
S 40 12 W 615,55
S 40 31 W 738,05
S 41 O W 888,02
$ 41 41 W 1046,43
$ 42 6 W 1205 88
S 41 47 W 1365~33
S 42 1 W 1524.91
S ~2 18 W 1691,37
$ 42 14 W 1858,21,
S 42 8 W 2022,63
4'2 ~ W 2183 50
41 59 W 2340:76
41 27 W 2497~27
41 32 W 2655,46
41 23 W 2815.68
44 4 W 2974,11
48 45 W 3121,96
48 53 W 3~55,03
a8 39 W .~]89.07
48 28 W 3524,30
3 30
3~43
3,67
2,'71
2,93
3,3~
4,47
~ 53
2:16
3,b{
4 41 S 18,54 w 39,09 $ 2~ 19 ~
, 3:63 S 34 40 w 63 '12 6 32 40 w
77,98 S 54 56 W 95 17 $ 34 58 ~
108 12 S 78 29 W 133 49 5 35 54 ~
I44 48 S 102 9~ W 177 40 6 35 97 ~
1~7 O0 S 130 49 W 227 98 S 34 53 w
234 64 S 164 96 W 286 83 S 35 b W
209 48 $ 2]0,6? W 358~0~ 6 36 2 W
349.22 S 260,05 W 435,41 S 36 40 w
414,26 S 314,04 W 5~9,84 5 37 9 ~
3 77
3 45
O 67
0 ]7
0 49
0,11
1,29
0,36
0,20
0,24
491 06 $ 378,45 W 619 97 S 37 37 ~
584 63 S 458.00 W '142 67 S 38 4 ~
698
81.7
936
1055
],2
1471
1542
50 $ 55u 09 w 802
51 S 660 98 w 1051
33 S 767 56 w 1.210
09 S 874 20 W 1370
78 S 991 07 W 1529
57 S 1092 59 w 1696
O1 S 1205 02 W 1863
90 S 1315 55 W 2027
S 38 31. w
30 $ 38 57 ~
73 S 3q 20 ~
19 $ 39 38 ~
79 $ 3q 53
s 40 5 (
15 S 40 17 ~
61 S 40 ~7 ~
0 3o
0 39
0 26
0 3O
0 24
4 55
1 56
0 2!
0 32
0 23
1662 2t $ ]423,63 w 2188 54 5 40 34 ~
1779 14 S 1529,0~ W 2345 90 5 40 40 W
1.633,1~ W 2502 58 40 44
!896
20]4
2134
2253
2354
2442
2531
2620
27 S $ ~
77 S 1738,22 W ~660 96 5 40 4'1 w
96 S 1844,50 W 2821 38 S 40 49 w
17 S 1950,23 W 2979 96 6 40 52 W
80 S ~057,75 W 3127 21 $ 4J 8 m
48 S 2158,40 W 3259 51 6 41 98 W
1.3 S ~259,43 W 3392 88 S 4! 45 ~
93 $ 2360,99 W 3527,54 S 42 0 W
ARCO AbASKA, ~NC,
KUPARUK
NORTH SLOPE,ABASKA
COMPUTATION DATR: 4-MAY-85
PAGE
~ATE OF SURVEY{
KELLY BUSHING EbEV~TION:
iNTERPOLATED VALUFS f'OR EVEN {00 FEET OF SUB-SEA D£PTN
4EA$1,1RED VERTICAL VERT?CAL OEVIATION AZIMUTH SECTION SEVM~ITY N~RTH/S~UTH EAST/WEST DIST, AZIN~'£M
DEPTH DEPTH DEPTH DEG MIN
513~ 77 3906,00 3800.00 53 5~
590~76 4006.00 3000,00 54 6
6073 53 4106 O0 4000,00 54 8
6243 O0 4206 00 4100.00 54 0
6413 75 4306 0o 4200,00 54 0
6584 58 4406 00 4300,00 54 19
6?56 38 4506 O0 4400,00 54 20
6928 77 4606 O0 450o,00 54 34
7098 58 4706 00 4600,00 53 32
7266 59 4806 00 4700,00 53 27
7434 71 4906 O0 4800.00 53 35
7603
777~
7q33
8091
8247
8402
8553
870]
8852
47 5006
~1 5106
06 5206
71 5306
45 54O6
07 5506
80 5606
36 5706
?9 5806
00 4900,00 53 36
On 5000,00 5~
00 5100,00 50 40
00 5200.00 50 19
00 5100,00 ¢9 50
00 5400,00 49 23
00 5500,00 48 23
00 5600,00 47 53
O0 5700.00 48 10
9003,53 5900,00 5R00,00 48 44
9156,65 6006,00 5900,00 49 30
9310'63 6106,00 6000,00 49 30
9318,00 6110,78 6004,70 49 30
DEG MTN FEET
S 48 20 W J660.~9
S 48 12 W 3797,55
$ 47 54 W 3935,71
S 47 56 W 4073.40
S 47 49 W ,t?lO 43
S 47 15 W 434~:73
S 47 16 W
S 47 0 W 462~.54
S 4b 57 W 4765.65
S 46 59 W 4900,52
$ 4b 49 W 5035,54
$ 46 36 W 5171.37
$ 46 17 W 5305.97
S 47 54 W ~43].06
S 49 35 W 5555.85
S 49 17 W 5674,79
S 48 49 W 5792.35
s w 5 o6
S 48 4 W b017:1.4
S 50 50 W 6127.7~
S 51 49 W 6~3g.73
$ 52 32 W 6354.65
S 52 3~ W 6470.58
S 52 32 W 6476,12
DEGtlO0
0,2o 2711
o 26 2802
0:07 2805
o,oo 7987
0,25 3079
0.35 3173
0,23 3268
0,4? 3363
0 64 3457
0~30 3549
0,15
1,04
0,83
0 2O
0.36
0,73
1,07
0 65
0,00
0,00
0,00
FEET FEET DEG
44 S 7463.05 W 3663.13 S 42 15
96 $ 25&5,b? W 3799,87
51 $ 266~,56 W 3937,67
98 $ ~770.91 W 4075.04
93 S 2872,86 W 42~1 80
36 S 2975.10 W 4349 88
24 S ]077,b3 w 4489 24 S 43
76 S 3180,56 W 4629 35 S 43 2
45 S 32~0,86 W 4766 .{4
44 $ 3379.57 W 4901 0~
3641 77 S
3734~86 S
3827 65 S
39]4
]995
4072
4150
42~b
4300
4372
3478 35 W 5036,0! S 43 41, ~
3577:41. W 5171,76 $ 43 4~ ,
3675,03 W 5300,29 S ~3 50 ~
37 S 3768.12 W 5433,]2 S 43 54 ~
41 S 3860.84 W 5556.03 S 44 1 ~
97 S 3951,6} W 5674.8g 5 44 ~ ~
27 S 4040.68 W 5792,40 S 44 14 ~:
70 S 4196,24 W 5906.20 S 44 19 ~
0i S 4209,04 W 6017~t5 $ 44 ~3 ~
38 S 4203,25 W 6127,;8 5 4'4 28 ~
,
4442 72 S 4381 40 W 6239,/5 S 44 ]u W
4513:85 S 44.72:98 W 6354,72 6 44 4:4 a
4585,07 S 4565,93 W 6470,'75 S 44 52 ~
4508.47 S 4570,~8 W 6476,$0 S 44 53 ~
ENGINEEr: bESSIE
106,00 FT
ARCO AbASKA, INC,
KUPARUK
NORTH ~LOPE,AI,ASKA
MARKER
TOP UPPER SAND
BASE UPPER RAND
TOP LOWER SAND
BASE LOWED SAND
TD
COMPUTATION DATE;
PAGE 7
DAT~ OF SURVEY~ 31-MAi{-B5
INTERPOLATED VALUES F~R CHOSEN HORIZONS
MEASURED DEPTH
REt, OW KB
SURFACE] LOCATION
A'.~
ORTGI~I: 488' FSL,703'
TVD ~ECTANGULAR COO ~,.~'~A'I'ES
F~O~ K~ SUM-SgA NORTH/SOIITH EAST/W~'f
BB22.0n
8872.00
R948,0o
9148,00
9179,0n
931B,00
5785.43 5679,43 4]b7,~ S 4275.52
5R19.79 5712,79 4381,]9 S 4304,]9
5~69.2,{ ~76'3,24 4416 95
6000,38 5894,38 4509:85
~020,51 5914,5{ 4524,19 S 4486 47
6110.78 6004,78 4589,47
ARCF~ AbASKA~ TNt.
KUPARUK
NOR?H ,SLOPE~ALASKA
MARKER
Trip UPPER 5AND
TD
COMPUTATION DATE:
~822,00
8872,00
8948,00
9148,00
9179,00
9318,00
4-~AY-8b
PaG~ 8
DATE .OF SURVEY: 31-MA~-~5
KELLY BUSHING ELEVATILJN:
106,00 F~J'
ENGTNE£R: L, ESNIE
(1HTGTN= 488'
TVD
SUPFA
FSL,70]'
~ECTANGI.I
NOR'~H/S
5785.43 5679 43
5~8.79 5712~79
5869.~4 576],24
6000.t8 5894,~R
6020.51 591.4,51
6110.78 6004,78
4t57,8
4381,3
4416,q
4509,~
4524,1
4588,4
4 $ 4275,52
9 S 4~04.]9
5 S 434R.73
5 S 4467,75
9 S 4486,47
7 $ 4570,3~
FINAL WELL LOCATION AT TD=
TRU~ StJR-SE~
MEASURED VERTICAL VERTICAL
DEPTH DEPTH DEPTH
q318"00 6110,7B 6004,7~
HORTZONTAL DEPSRT[JRE
DISTA{tCE AZIMUTH
FEET DKG ~TN
6476.]0 $ 44 53 W
SCHLUMBEROER
O I RECT I ONAL SURVEY
COMPANY
ARCO ALASKA !NC
WELL
2U-S
FIELO
KUPARUK
COUNTRY
USA
RUN
DATE LOOOEO
REFERENCE
FS1A.
~ELL NAME: 2U-5
SURFACE LOCATION:
NOR?H 2000 REF FSIR.
' ~' FSL, 703' FWL, S32, T12N, R9 UM
~-~ HORIZONTAL PROJECTION
$C;~LE = 1/1000 IN/FT
1ooo
-1000
-2000
-4000
-SO00
-6000
WEST
-GO00 -SO00 -4000 -9000 -2000 - 1000 0 1000
2000
EAST
4
44,
NAME: 2U-5
iFACE LOCATION:
' FSL, 703' F~YL, S32, T12N, R9i.__~JM
VERTICAL PROJECTION
-4000 -~000 0 0 g000 4000 6000 B000 10000
"'!"?-r,..'-~--r'?T':' ..... ,.""!-?"~ -T'?'T'~. .... ~'"~".'~T-~-'?'F~'T" '~'"T-E i-r'Y'~'T ......
"'FT"T T" "'FT%T- -FT'"F'~ 'TTTT' N"'fa'd~TTT'~ .... FTT'NTFFF-~TTTi-TTTT'"'TT'T'%' ~'-T'-~'T'i'~'-i'-~'t-t"r' "'?t4"'t'" ?'t-t"?-
'-~+'-f" '~H+-~. ~-~-' ,~+'+'~ .... ~--~--~-~-~'~--'-~'-~--~'~-~-~--~--~--~-+-~-~-~-'~-~' ~ ~ ~-'-~'~--t'-~-'~-.~-L~4--~...~...
._~..,..~ ...... ~ ...... ~ ......... ~ ......... T..,.~ ............. ~~:~ .... ~ .......... ~, .......... ~.~_~_~ ....... ~ ......... ~ .......... ~l .........
"f~+ "'T'"J~"J .... HH'- -~f'- 'HH-:-~ ~ ~:: [-~+~k-H-~-'~H+ ;:: ;: ] "++H- ++H- ~H~k-~'++'+'~
T~% ::Fi:F,, :[~T. '.7:~-%:,,,, ..-7:~u,:,, B~.:: ~+-~a~..: ...... ~i ¢~P H-F~'TTiT, ..... '-FF ¢~: $i~~ P~¢~*--'"-~-~~++-.~"-"~'
'-'f-i---h'l-..-i---i---r.-j ...... l'--h-H.-- .-H..-r--i ...... bi---b'b-.-i-~--b-t ....... t--~-i---r-?,~?'-4-ff'--t-'t-i--*--f-i--~' -HH.-.b'H--HHH 4--bb-b-++44--
...~.., ....... , ..... ,..., ....... n_, ............. ~ ................................... %., ............ ~ ...... ,.., ............... I~~..~-~-, ........ ~,--~ ........ ,-~.-.~ ........... ~-~ ....
-..L.!;;4..-i.-L.i-4.4---L;-.14-'..4-4--Li- :~'~ :'~'~t~' ~ i ! i i-~[t~G-' t-~----H--H---;~-~+---~---b-b]--'H-bf-
· -t'tT'~ ..... f"i-' i-'i ....... f--!-'T"i-'T"?'"f'% '-t-r4---i-t-h-~'ff ..... Hff-i--T+-i~---i-'tq-'i---fft-~ff-tff'-iff---~t-H~'ff~'--i---?-t-t-t~-t-i-~
....... ~ 'i'"i'i ..... t"'Ft?" ~"tff?-' "'t'-t"t'-t' 'Ft'ff'?"i ..... t"t"h'h~'"t"t?'h' '"t??~l"'t-t?-'h-i-!'"~"?ff~'"',-~?'tt'"~'h?ff~'""?'~t'!"t"t'"ht'
-'r',-T"~'-'"'~'"~"'r"~ .... ?"Fr'F ~"~'T'~ ...... ~n~nFFF;"r~ "TT'??-~"T'F~ ..... FFT'TT~-FFF-rr'F~TF~TN'Tr~'-""~'F~-
~-..i.--i--.1---,.-F--~-.~-.H----H.i...H+.-,--~ -%-~...~ ...... ~--'~-"H-H-H+--H'~-'-H-. '--H'F'H~t--~-F~-i- '-+"~--F~-H'~-F'~-+'" -~'+"~-~' -H"+-i ..... ~"'~"H'~-~
--H~.H~-Hk.b+-.i.--H.-.i-..i.-.?. ~..HH ...... H--.H.+-~-b.H.-~-..bbHH-.i---HH--- .-~--+-FHi.-+H.-++~H--+~.-~H~+-.-b++-i.-~
...FH..~.fH...H...H...~..~..t...~...H...t.::f..H...H+i.+~....H...H1.H..i...H...H~-i...?H...H.....H..i...H+FFh-H+~rt+.H..~
4-H..t.hi...i...i4...14--~...-i.4...' i..bi4-..4...i44...~..Li..!~-~4-4--bi .i-4..i..i..?...i4..bl.--i4..i-..i ...... !~4--i .44.~-'.~...~Lbi-.~.~b
: : : : [ ] : ' ' : : : ' : : ; : ~ ~ ~ i i i i : ....... ! ' : ' ' : ; : ,~ : : i q 2::2 l: : ' ; I :2: :- : ; : ;
...?.~..!-,! .... ??...~..., ..... ¢1.,,~...~ .... ?.~...~ ...... ~..?... :. -.: ...... ~...:...:...: ..... :..., ..... .- . ." ' ,-: .... ~'~' :-y-; ~-~- r --?'-~-~ 7 i-~ ~- 7 ~ "?'-~'f--~"~":'-'?--
.. ]...,.. ~...& - ...}...~. ~....; ..... ;..,~..4.-.~.... ~...}...i--&.......i-..4...i..--I..~...{--.~-.,~--~ - -&.-{-.-~---~-.~-[. ........ ;---~ ..... ~.-~-..&-~.-.t-.-(~ .~.--].-~.-~ ...& -~.-.&.-~..-i.--~.-&.-}...~ ..... ~.- ~..4--~--.]~.]-..&..~---.g ....... ~...~._~..~...H.z..&.. ~ .~ ....
...f_.?lt ..?.~...f.l.j..l~.l.?.l...t...?.i...?.. lll~l'lTl l[~lJ~ ....... ~..lt.~--lt 'l--l'l'?'t'''~'l~ ...... ~l lJ ~lJJ~ll IT--[ lljl lJ t- I~ lll~J' il I [~'' ~I[I~ II I~ [ JllJ~ll'~J Jl ~Jl[~[ li [[~lJl?~'J~--~J- ~l~l[' ~[Jl~lt Il [ ' I{ ~-- ~ -- i~ I11 J 'I ~ IIi ~ l--~ [~ ~ --l~ ' [ [[ [ ! J [ l~ i...~...I.I.~..I?i...T ....
· .+..~-'.?~.-.H~,"~"'i '~ ..... h' i '-;--+ '~ -'-~---H'*'-'+'--~--.H~-..F--H-~..+--?H-H- k---?.~--H-H-H-F--H-H-H.I--~-H+-+.H.~--~.%+- .--;--+--H-~-i-~-~--~-~ ...... ~-~-- F--~--T---~+-H-H-I-H+-.+--H-1.-+--H-H~ ....
..-f..i.?i...i..-H--.t.'~ ..... f..?..i.--~-..f-.f..f-.f--~---fff--f.-t--!-i-+.H---H-H'--f.T--f-H-+%-i-hffl~H-'-ff-~--t--H--i--~-H---~-t~ "-H'-?f-~-~'-'H?~"-hff~i'-'H--ff-~-
'T'Y~"T"I'T'Y]"~ ....... T'T"y~ ....... T'T"~'"~ ..... ~]"~O~D~'-~'"~'"~'- "T'TT'FTTTTT" "T'FT'T" -TTTTTTTT-~ ..... YY'~'T'r'T'?T'~ ...... TTTTYYYTT' 'TTT'~ ....
...~...:...~....~...i...:...~..¥..~ ...... ~..~.4...~ ....... H..-b.t---~..-~.-.t..+--~.-.[---t--t-.+--t~-'-++-~-.t.-[.-~-~--++----t.--~--++-t--t~+-+-++-H--~-~-+-~-.-t-+--~ ....... +-+-++-b~-.+-+-+-, ,.+++,+.1---:.-+-+-.~ ....
-..b-b-b-b-].-.bb¥-~ ....... H..-H-..~.--H-4.--~ ...... ¥+.-H..-?-b-b¥.+- -+--H--H--4-~.-.~-~---H--H-+-H---H~-~-.~--+-+--¥+.~--b¥-~ ....... H~+-+4-.-H.--¥-b-~-+-+-+--H.4-4--+-.~ ....
~ ] ~ : i : = : : · : : : : : : : ; : : : : I : : : : : : : - ~ ; : : ~ : : : : , : : : ~ : : : : : : ; :
,,.~.~,.,~.,?. I ,,~l,.~,.,~,,,~,,,l..,t 1,, ?.,~,,.~.., [,,l~,.,~,..~,,.~...~ .i~. ~ ill ~l. ~. ~ [_ ~ .ll~ ~ .i~. Ii ~" ~ ~ ~ ~ .~ ~ ?i~i--~. f .~i~--l~l~ll[ i--?--~l~l ~ l'l: [ i~[- ~lll~l. ] ~ ~il ~. ~ [~ li~ Ill ~ ll [ll~'l' ~i l~lll~li~ ' [ I ~ ' ' [ ~lll : 'll~ ..... ~'''~''?'':''l]'''~'''?--~ll--~ l~
L L,L3 ....... L4,4-,L.-.~.-L.~- ~ ...... i.,i 4 ~ ..... L,L4 ,L.:.-L.L4 L- ...L4. 2-~- ...$ ~ 4-~. $ L ~-4-4 ~.4-4---~.-. ~-L.~4...L ¥4-,.b~ ..... b-~ 4---HH~--H¥.
'"7" F'~ "r"T" ~'"7 ....... ~ '" ...... 7 ..... 7'"t '"? '~ ........ ~ .... T"7"Y'?", "'~'"Y'F'? .....~ ~Y'~"T"~-~'"?'":"'Y':" '"~'- ~-~ "%': "'~-7"T"~'''~ "V-T'? 7'"i'"7" 7"-?R~ .......[ tT'"?"'d-~-F'~" P'T"~'"F'y'y y'~'-'T"?-?" y
· .;...~-.~-+..?..~..H.f..i.. ~.q.-.-H.H-~ ...... ~.. ;.-~..--~ ...... ?~-..* ....... ~...?~.-H-~ ...... ~..H.i..-H-(-.~-H-H-~ ..... ?H-i-..H.~-.-%.H.~-H.~--H-H-~...~---,--~ .-~ ...... ~ ..... H'%'?'T-.-~..-?---H ~ ..... ~'-T'?"? "+
PROJECTION ON VERTICRL PLRNE 224. - 44, SCALEO IN VERTICAL OEP?HS HORIZ SCRLE = 1/2000 IN/FT
Suggested form to be inserted in each "Active" well folder to check
for timely compliance with our regulations.
OPERATOR, WELL 4~AME' ANIf NUMBER
Reports and Materials to be received by: ~7~ --~/~~~
Date
Required Date Receiv'ed Remarks
Completion,. Report .
Well History ~
~ud ~o~ ~ _ p~, ........ ~.~.~ ~/~.
Core ChSps
Core Description
Inclination Survey .. ~--,,
Directional Surv~...,.,. ~- ,
. ~ .......
~. .... .'
Production. hTest Reports
.... .., .... ~ ..... ~ :-- ..
~... .~'
Digitized., ,Data
ARCO Alaska, Inc.
Post Office B~.....e'd360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
April 12, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: State Reports
Dear Mr. Chatterton:
Enclosed are the March monthly reports for the following wells:
1Q-3 2u-6 3B-13 17-11
1Q-4 2U-7 3B-14 L1-9
1Q-5 2U-8 3B-15 L2-28
2C-9 2V-9 3-16(W/0) L2-30
2U-5 2W-4 9-27
If you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRU5/LI06
Enclosures
RECEIVED
APR.l 6 1 tl5
Alaska Oil & Gas Cons. Commlsslort
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA ,..~,_ AND GAS CONSERVATION cO~:MISSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS
· Drilling well I~ X Workover operation []
2. Name of operator 7. Permit No.
ARCO Alaska, Inc. 85-18
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21281
4. Location of Well
at surface
488' FSL, 703' FWL, Sec.32, T12N, R9E, UM
5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo.
106' RKB ADL 25644 ALK 2575
9. Unit or Lease Name
Kuparuk River Unit
10. Well No.
2U-5
11. Field and Pool
Kuparuk River Field
Kuparuk River 0il Pool
For the Month of. Na rch ,19 85
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spudded well ~ 2100 hfs, 02/26/85. Drld 12-1/4" to 4097'. Ran, cmtd & tstd 9-5/8" csg.
Drld 8-1/2" hole to 9318'TD as of 03/04/85. Ran OH logs. Ran, cmtd, & tstd 7" csg.
PBTD = 9179'. Displ to brine. Secure well & RR @ 2015 hrs, 03/06/85.
13. Casing or liner ru.n and quantities of cement, results of pressure tests
16" 62 5#/fl, H-40, weld conductor set ~ 115' Crotd w/235 sx CZ II
, · · ·
9-5/8", 36.0#/fl, J-55, BTC csg w/FS @ 4079'. Cmtd w/790 sx PF "E" & 940 sx PF "C" & 50
sx PF "C" top job.
7", 26.0#, J-55, BTC csg w/FS ~ 9265'. Cmtd w/400 sx Class "G" cmt.
14. Coring resume and brief description
NONE
15. Logs run and depth where run
DIL/SFL/SP/GR/Cal/FDC/CNL f/9310'
- 4079'.
RECEIVED
6. DST data, perforating data, shows of H2S, miscellaneous data
NONE
Alaska Oil & Gas Cons. Comm/sslor~
Anchorage
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
NOTE--Repor~'~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed.
Form 10-404 J MM/MR71 Submit in duplicate
ARCO Alaskal Inc.
·
Post Office b... ~60
J'/~ '~(""'~ Anchorage, Alaska 99510 Telephone 907 277 5637
"
RE'I"UI::b~i F~RC(] "AI A,~I<~..,', 'fi-,~r~
A T T N · R E C ~:{ ~) 5' C I... E R !(~
ATO..-tt~.~E, .
. AHCHOF~Ai;E, Al': ?75i
T"f' E.[) IIE R E !~ ]: TI"I ¢, R F 'i" H F' F:' n l !... 0 AND F;I~:TUI:~N ONE ~']:6HF:P COPY
F: t:]: r: E: ]' r"'f' ,:i r, I'.'. ~' ["~' ,, E:))'C Ii;: l) · ' I;' ~-.-; 'f' K:
g I .~;' 'f' F:: ;1: i.; t.I 'l'/1: ()i'l ·
' ' - ' :
[, ,..ir... ):Il:;' :1:1...I... :I: i-4(; i,,i.. F:'t::~,?HI~i:R (.-~T~?f'l!!: OF-'
.T.!: ... L':UI':;I';: :1: EI';'I ....... I01 Ii ,~,'?TI.'.)N , I;:'.XX('Jhl -'-,'.;'0I-i :i: (')
I::] ~ r:',/r, I:) H i"l rj I", ]: I.. F:' H ]' !... I... :[ j:' ~
I1... ¥ /~'~ . . . ·
,.,.. E) .l: I.. !.Ji',f ]: C.
T) & H i"~~';~x CI._'EF:.:I,: ' ..J." r;:,'",TI!HliTI...I... I./,, 'i'LJL.:[[,.,-v~.~tJE-r
· ' i~. i',, ' ' "' i /''' · ~'" ·
ARCO Alaska. Inc. iq ~ ,qub.ldlaf¥ ol AIl~nllcRichllelclC,nmp~ny
.%.
M EMORArvOUM Stat ' of Alaska
ALASKA OIL AI~D GAS CONSERVATION COt,~MISSION
TO:
THRU:
FROM'
C. V. ¢~aB~rton
Chairm~ /
Lonnie C Smith
Commi s s i on e?¢_--[./~
Doug Amos-__.::.;
Petroleum Inspector
DATE: March 12, 1985
FILE NO: D.ADA. 8
TELEPHONE NO:
SUBJECT: Witness the BOPE Test
at ARCO's Kup. 2U-5,
Sec. 6, T!iM,R9E,Ui~'~,
Permit No. 85-18 on
Doyon Rig No. 9.
Thursday, February 28., 1985.. After witnessing the meter proving at
the COT Unit, I traveled to Doyon Rig #9 to standby for the BOP
test there.
Fri_da3, March 1, 1985: The BOPE test commenced at 2:15 pm and was
Concluded' at"3 '15 pm. There were no failures and I filled out an
AOGCC BOPE inspection report which is attached.
In summary, i witnessed the successful BOP test at ARCO Kup. 2U-5
well.
Attachment
02-O01AfRev. 10/79)
O&G #4
...-4/80
STATE OF ALASKA
ALASKA OIL & GAS CONSERVATION COMMISSION
B .0. P. E. Inspection Repor~c
?nspector ~P~'~ ~~.~.
Operator . /~/~, ~_3
Well
. ·
Drilling Contractor .~
Date ~///~
Representative ~.' '/~. ~'~r~; ~/
Permit # _ ~ -/~.
~ ~gCasing Set @ 407~ ft.
Rig #- ~. Representativm' ~, ~J/~/g~-~
Location, General ~'-
Well Sign 0/<
General Housekeeping . ~,
Reserve pit ~
Rig ~
BOPE Stack
Annular Preventer
Pipe Rams
Blind Rams
Choke Line Valves~~
H.C.R. Valve
Kill Line Valves~0
Check Valve
Test Pressure
~/~ ..
/z
..
/!
ACCUMULATOR SYSTEM
Full Charge Pressure _~,,_f~X2 psig
Pressure After Closure ~ 0~) psig
200 psig Above Precharge Attained: min~ sec.
Full Charge Pressure Attained: ~ min/~ sec.
N2 ~,, ~Z~Oi ~O) ~-~,/ ~ ~Opsig .~
Controls: Master ~/~
Remote Z2~ Blinds swi. tch cover ~
Kelly and Floor Safety Valves
Upper Kelly .// Test Pressure
Lower Kelly~/ ! Test Pressure
Ball Type ~ Test Pressure ~
Inside BOP / ~f' Test Pressure //
·
Choke Manifold / ~'Test Pressure '/
No. Valves /~ .
No..flanges ,~,~
Adjustable Chokes -'/
Hydrauically opekated choke_ /
,, ./ hrs. 0~;
days and
Test Results: FailUres ./~g)A~ Test Time.~
Repair or Replacement of failed equipment to be made within
Inspector/Commission office notified.
Remarks:
Distribution
orig. - AO&GCC'
cc - Operator
cc - Supervisor
Inspector
February 19, !985
Mr. J. B. Kewin
Area Drilling Engineer
ARCO Alaska, !nc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Re:
Kuparuk River Unit 2U-5
ARCO Alaska, Inc.
Permit Mo. 85-18
Sur. Loc. 488'FSL, 703'~, Sec. 32, TI2N, R9E,
Btmhole Loc. ]094'FSL, 1022'FI~, Sec. 6, TIlN, R9E,
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
If coring i.s conducted, a brief description of each core and a
one cubic inch size chip from each foot of recovered core is
required. Samples of drill cuttings and a mud log are not
required. A continuous directional survey is required as per
20 AAC 25.050(b)(5). If available, a tape containing the
digitized log information shall be s~bmitted on all logs for
copying except experimental logs, velocity surveys and dipmeter
surveys.
Many rivers in Alaska and their drainage systems have been
classified as important for the spawning or migration of
anadromous fish. Operations in these areas are subject to
AS 16.05.870 and the regulations promulgated thereunder (Title 5,
Alaska Administrative Code). Prior to commencing operations you
may be contacted by the Habitat Coordinator's Office, Department
of Fish and Game.
Pollution of any waters of the State is prohibited by AS 46,
Chapter 3, Article 7 and the regulations promulgated thereunder
(Title 18, Alaska Administrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
commencing operations you may be contacted by a representative of
the Department of Environmental Conservation.
Mr. Jeffrey B. K~n
Kuparuk River Unit 2U-5
-2-
February 19, 1985
To aid us in scheduling f~eld.~ work, please noti~v~__j this office 24
hours prior to commencing installation of the blowout prevention
equipment so that a representative of the Con~nission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. Where a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the~ conductor pipe.
In the event of suspension or abandonment, please give this
office adequate advance notification so that we may have a
witness present.
Vero~trul y
"//?/ ~, ,
C. V. Chatterton
Chairman of
Alaska Oil and Gas Conservation Commission
BY ORDER OF THE CO~ISSION
be
Enclosure
CC-:
Department of Fish & Game, Habitat Section w/o enc!.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
ARCO Alaska, Inc.
Post Office B~...~00360
Anchorage, Alaska 99510
Telephone 907 276 1215
January 31, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Kuparuk 2U-5
Dear Mr. Chatterton:
Enclosed are:
We estimate spudding this well on March 4, 1985.
questions, please call me at 263-4970.
/~erely,
JBK/HRE/tw
PD/L28
Attachments
An application for Permit to Drjll Kuparuk 2U-5, along with
a $100 application fee
Diagrams showing the proposed horizontal and vertical
projections of the wellbore
A proximity plat
A diagram and description of the surface hole diverter
system
A diagram and description of the BOP equipment
If you have any
RECEIVED
E 0 5 1985
gu ~ 'Gas 0or~s. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA'~=~L AND GAS CONSERVATION C(:>.~;MISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work.
DRILL [~X
REDRILL []
DEEPEN []
lb. Type of well
EXPLORATORY []
DEVELOPMENT OIL [](X
DEVELOPMENT GAS []
SERVICE [] STR~IGRAPHIC
SINGLE ZONE []
/
MULTIPLE ZONE ~[X
2. Nam'e of operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100:360, Anchorage, Alaska 99510
4. Location of well at surface
488' FSL, 703' FWL, Sec.32, T12N, PgE, UN
At top of proposed producing interval
1/429' FSL, 1350' FWL, Sec. 6, T11N, PgE, UH
At total depth i~ /¥1~'~ -~;~/J~i~,
1094' FSL, 1022' F/EL, Eec. 6, T11N, R9E, UN
5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no.
RKB 106', PAD 69' I ADL 256/4/4 ALK 2575
Federal Insurance Company
12. Bond information (see 20 AAC 25.025)
Type Statewide Surety and/or number #8088-26-27
9. Unit or lease name
Kuparuk River Unit
10. Well number
2U-5
11. Field and pool
Kuparuk River Field
Kuparuk River 0il Pool
Amount $500,000
13. Distance and direction from nearest town 14. Distance to nearest property or lease line /15. Distance to nearest drilling or completed
30 mi. NW of Deadhorse miles /488' @ surface feet ~U-/4 Well :360' ~ surface feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease /18. Approximate spud date
9355' HD, 6117' TVD fec. t 2560 ] 03/0/4/85
19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2663 psig@ 80°F Surface
KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 5/40l(see2OAAC25.035 (c) (2) 3075 psig@ 6002 ft. TD (TVD)
21
Proposed Casing, Liner and Cementing Program
SIZE
Hole Casing
24" 16"
[ 12-1/4" 9-5/8"
8-1/2" 7"
SE I [ING DEPTH
Length MD
80' 35' I 35'
I
3894' 35' 35'
I
TOP TVD
9321 '
I
34' I
I 34'
MD BOTTOM TVD
115' 115'
3929' 1~_2~86'_
I
9355' I 6117'
I
I
QUANTITY OF CEMENT
(include stage data)
± 200 cf Poleset
790 sx Permafrost "E"
940 sx Permafrost "C"
260 sx Class G neat
Weight
62.5#
36.0#
26. O#
22. Describe proposed program:
CASING AND LINER
Grade Coupling
H-40 I Wel ~
I
J-55 I BTC
HF-ERW
J-55 / BTC
I
HF-ERW
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9355'MD (6117'TVD).
A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The
9-5/8" casing will be set through the West Sak Sands at approximately 3929'MD (2986'TVD). A 13-5/8", 5000 psi,
RSRRA BOPE stack will be installed on the 9-5/~._'3--sur~ace pipe. It will be tested upon installation and weekly
thereafter. Test pressure will be 3000 psig{(3OOO~p~i for annular). Expected maximum surface pressure is 2663
psi. Pressure calculations are based on lates~reservoir pressure. Surface pressure is calculated with an
unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well
will be completed, using the workover rig, with 2-7/8", 6.5#, J-55, EUE 8rd tbg. Non-freezing fluids will be
left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the
Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet)
23. I hereby certify that the foregoing is true and correct to the best of my knowledge
SIGNED / /./__.~y//s~.Z~.,~ TITLE Area D ril]ing Engineer
The space
CONDITIONS OF APPROVAL
Samples required
I-lYES ~NO
Permit number
'
Form 10-401 (HRE) PD/PD'2'8
Mud log required
i-lYES [~.EJ O
Approval date
02/19/85
---/ /--i
Directional Survey required I APl number
I~,Y_ES ~NO I 50-- O ~ ~ ~
SEE COVER LETTER FOR OTHER REQUIREMENTS
,C~]MMISSIONER DATE February 19, 1985
by order of the Commission
Submit in triplicate
PERMIT TO DRILL
2U-5
installed and tested upon completion of the job. 2U-5 will be the ninth well drille~_Qn the pad. It is ±360'
away from 2U-4 at surface. There are no other close wellbores anywhere downhole. Top of cement for the
production string will be placed at 7700'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve
pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a
non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off
location, the well will be fracture stimulated.
' t .......... ~ ' - ' : ;
: <UPIM U~-~---FI~,D,~'--~H- ~0~-, ~ ALASKA
' k~~~~~~ '
1
.... loon =T :~ eUZL~ ~3 ~ I J
_
: ...... 7'~-~ ': .... [ ....
_ ~ .... :~ . TOP ~GNU ~JNDS -TVD-l~826
~ .......... : ............ ,, ~ s~" s.~ ~~.~
...................... ~i ~--~: X~-~"X~-~ ~:[- ..... : ..... ~ ........
.......
~ ~ , ~ ,.~
, . ~ ,
............., ~
.0
. . I
Hr iz
· ~
ON:T AL F
f
~1.~; 11 IH-
-
_ ~oo~.! r~:~t :?~:
SO00 '
S-~
62;
1
I
I
l
Iooo: p
t
Alaska 0~I S Gas Cons, _Anchors9e
i.
2.
3.
4.
e
Surface Oiverter System
~.6" - 2000 psi Tankco sta~ing head.
.
Tankco quick connect assy.
16" x 20" 2000 psi double studded adapter.
20" 2000 psi drilling, spool w/10" side
outl ets.
10" ball valves, hydraulically actuated,
w/10" lines to res.role pit., Valves to open
automat'ically upon closure of annular
preventer. · ~"
20" 2000 psi annular'preventer. /,
20" bell nipple.
·
h
.
Maintenance & Operation
Upon initial installation close annular
preventer and verify that .ball valves have
opened properly. ~
Close annular preventer and blow air
through diverter lines 'every 12 hours.
Clos~ annular preventer in the event-that
gas or fluid .flow to surface is detected.
If necessary, manually override and close
ball valve to upwind diverter line. Do not
shut in well under any circumstances.
16" Conductor
RECEIVED
Alaska O~i & Gas
,,o,,~. Commission
Ap, chorage
2
>
r LB 0 5 ,~9~5
Alaska Oil & Gas Cons, Commission
Anchora~oe
ARCO Alaska, Inc.
Post Office B'"0"'~ 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
January 25, 1985
Mrs. Elaine Johnson
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: Conductor As-Built Location Plats - 2U Pad
Wells 1-8, 9-16
Dear Elaine'
Enclosed is an as-built location plat for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRU3/L77
Enclosure
If
ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany
WELL 1 Y = 5,975,841.16 LAT. 70°20'42.7599''
X = 509,642.25 LONG. 149°55'18.2508''
PAD ~-2EV. 68.4 ' O.G. ELEV. 64.Z
FSL ~75 FWL 1,096
WELL 2 y = 5,975,782.54 LAT. 70°20'42.1835''
I X = 509,627.77 LONG. 149°55'18.6762''
PAD ELEV. 68.4 O.G. ELEV. 64.1
FSL 517 FWL 1,081
i WELL 3 y = 5,975,724.43 LAT. 70o20'41.6122''
X = 509,613.34 LONG. 149°55' 19.0999"
PAD ELEV. 68.3 O.G. ELEV. 64.0
I ESL 458 FWL 1,066
i WELL ~ Y = 5,975,666.21 LAT. 70°20'41.0397''
X = 509,599.09 LONG. 149o55' 19. 5187"
PAD ELEV. 68.4 O.G. ELEV. 63.9
FSL 400 FWL 1,052
WELL 5 Y = 5,975,753.43 LAT. 70°20' '41.902"
X = 509,249.86 LONG. 149°55' 29. 720"
PAD ELEV. 68.6 O.G. ELEV. 64.4
FSL 488 FWL 703
· I '~ WELL 6 Y = 5,975,811.41 LAT. 70°20' 42.472"
X = 509,264. 30 LONG. 149°55' 29.296"
· ~ PAD ELEV. 68.6 O.G. ELEV. 64.4
FSL 546 FWL 718
WELL 7 Y = 5,975,869.59 LAT. 70°20' 43..044"
X = 509,'278.75 LON'G. l~+9°55' 28 $71"
PAD ELEV. 68.6 O.G. ELEV. 64.3
ESL 604 FWL 73'2
WELL 8 Y = 5,975,927.80 LAT. 70°20' 43.616"
X = 509,293.26 LONG. !~+~°55' 2b.445
PAD ELEV. 68.5 O.G. ELEV. 64.2
51 52 FSL 662 FWL 747
~ 5
LOCATED IN PROTRACTED SECTION 32 ~,,,C,,~r....
TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. ~.749th~
· ~ .'C&%_ LS- 650zl-, _.---~'
NOTE: BASIS OF BEARING IS PAD PILING CONTROL ",~"'~'~".. ,-~,,,
· _ '... .~ .'~'~ .~._: -, ,_ .~ i~-~-..
BASIS OF ELEVATION IS 2U-5 AND 2U-4 PER ~._ ,,,~ua,, ,.....~-
LHD 8~ ASSOCIATES. "' : ' .... ~ ...... -.
I HEREBY CERTIFY 'THAT:'I AM PROPERLY REGISTERED AND
'~_ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF
UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS
a ARE CORRECT AS OF '-':~-'~'~--'-
( ARCO Alaska, Inc.
~1. ~!~ K uporuk Project North S!ope Drill
iil~,.~ DRILL SITE 2U
CONDUCTOR AS- BU I LT
~ LOCATIONS
~llSl& Dote: dan. ,8, ,985 Scale- AS SHOWN
----
sc LE: Mil Drown By' HZ Owg. No. NSK9.05.?_21d
CHECK LIST FOR NEW WELL PERMITS
Company
Lease & Well No.
ITEM APPROVE DATE
(1) Fee
(2) Loc
thru 8)
(3) Admin ~ ~ ~- -~'--F)'---- 9.
~9 thru 12) 10.
(10 and 12)' 12.
(4) C as~
'(13 thru
OPE ' z
(22 thru" 26)
13.
14.
15.
16.
17.
18.
19,
20.
21.
1. Is the permit fee attached .........................................
2. Is well to be located in a defined pool ............................
3. Is well located proper distance from property line ....... ' ..
4. Is well located proper distance from other wells ........
.
5. Is sufficient undedicated acreage available in this pool
6. Is well to be deviated and is wellbore plat included .....
7. Is operator the only affected party .....................
8. Can permit be approved before ten-day wait ..............
22.
23.
24.
25.
26.
27.
YES NO
Does operator have a bond in force '.. ..........
Is a conservation order needed ......................................
Is administrative approval needed ............................... ....
Is the lease number appropriate .....................................
Is conductor string provided ........................................ ~//
·
Is enough cement used to circulate on conductor and surface ......... ~//
Will cement tie in surface and intermediate or production strings ...
Will cement cover all known productive horizons .....................
Will surface casing protect fresh water zones .......................
Will all casing give adequate safety in. collapse, tension and burst..
Is this.well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
REMARKS
Is a diverter system required .............................. ~_
Are necessary diagrams of diverter an~ ~0~ equipment'attlc~'....
DOes BOPE have sufficient Pressure rating - Test t° 3t ~ psig //~//.
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
Is the presence of H2S gas probable .................................
Additional requirements .............................................
Additional Remarks:
o
~z
~o
· Geology:~ngineering:
WVA ~ JKT ~ HJH~
rev: 10/29/8~
6.CKLT
POOL
INITIAL
CLASS STATUS
o o.[ [
AREA ' //~"o SHORE
Well Histo.ry File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special 'effort has been made to chronologically
organize this category of information.
LIS ~ ~PE
LVP OiO.HOZ VERIFICATION LISTING PA~E i
~ REEL HEADER ~'X
SERVICE NAME :~DIT
2ATE :55/0]/i8
ORIGIN :
REEL NAME :
CONTIN~ATI]N # :01
PREVIOUS REEc
COMMENTS :LISR~RY TAPE
· ~ TAPE HEADER
SERVICE NAME :EDIT
DATE :55/03/18
ORIGIN :0000
'TAPE NAME :0166
CONTIN~ATI3N ~ :Ol
PREVIOUS
COMMENTS :'LIBRARY TAPE
~* FILE HEADE.R
FILE NAME ,:EDIT .001
SERVICE NAME
VERSION m
0 A'T E :
MAXIMU~ LENGTH : 102¢
FI cE TYPE
PREV,IO~S FIL~. :
INFORMATION RECORDS
MNEM CONTENTS
CN : ARCO ALA S'K,~
WN : ZU -5
FN : KUPARU~
RANG: gE
TOWN:
,SECT: 32
COUN: N-SLOPE
STAT: ALASKA
CTR'Y: US~
MNEM CDN~ENTS
PRES: ~E
~F~ COMMENTS
UNIT 'TYPE CATE S,IZ E
--,.,,,, --,..,.. ,,,.J,,,,..,, -- ~ ~------
000 000 016
OOO 000 .00,~ 06.5
OOO 000 008 055
OO:O 000 00£
OOO 000 O0'~ 065
000 000 OOZ 065
000 OOO O1Z 0'~5
DO0 000 006 065
00'0 00'0 003 :0'65
dNi'T TY P,E CAT E SI,Z~ CODE
000 BO0 00!
LVP OIOoHOZ VERiEiCATION LISTING PAJE £
SCHLUMBERGER
ALASKA DIVISION C2MPUTING C2NTE2
COMPANY =ARCD ALASKA INC
WELL = 2U-5
FIE:LO = KUPAR~K
COUNTY = N.SLOPE
STATE : ALASK
SECTION = 32
TOWNSHIP = liN
RANGE : gE
TAPE DENSITY = BOO 8PI
JO~ ~ 70,166
BASE LOG: ,OIL , RUN ,m I
DATE LOGGED 5 MAR ~5
BOTTOM LOG INT,ERVAL = 9302 .FT.
TOP LOG INTERVAL = ,~0'79 FT.
CASING-LOGGER = '~,m 5215 IN,. @ ~.079
~IT SIZE : 8.500 ,IN.
TYPE H~L2 ~LUI2 = m2IGHTED/SOLT[~X DISPERS~ED
LVP OlO.H02 VERIF~CATi3N LISTING PA~E 3
2ENSITY
VISCOSITY
PH
FLdlO LOSS
RM 2 MEASo TEMP.
RMF ~ MEAS. TEMP.
RME ~ MEASo TEMP.
RM ~ ~HT
LOP: T ~ALSTEAO
: !I.00
= 46.00
= 9.00
= ~. 40
= 0.236 @ 75 F
= O. 157 @ 75 F
= 0.215 & 75 F
: 0.131 @ !GO F
~* GATA FORMAT
ENTRY ~LOC~S
TYPE SiZE REPR COO,~ ENTRY
4 1 6~ 1
8 4 73 60
9 ~ 6~ .lin
16 1 65 1
0 1 65 O,
DATUM SP,iECIFICATION 5L2CKS
MNEM SERV,ISE SERVICE UNIT API ~PI API ~PI FILE SIZE SPL REPR
tD ORDER ~ LOG TYPE CLASS
DEPT FT O0 000 O0
SFLU 2Ic ~HMN O0 2ZO
ILD DIL DHMM O0 120 46
ILM DIL OH~M OD 120
SP OIL MV O0 OlO Ol
GR OIL GAPI O0 3~0
G'R FDN GAPI O0 310 O1
CALI FDN IN O0 ZSO O1
RHO8 FD'N G/C3 O0 350
ORHO EON G/C3 O0 3~6
NRAT FDN O0 4ZO O1
RNRA FDN O0 DOD O0
NPMI FDN PU O0 ~90 O0
NCNL FDN CPS OD ~30 31
FCNL FON CPS O0 330 30
C,~,DE (OCTAL)
1 58 00000000000000
i 6~ OOOO0000000000
i 68 OOOOO000000000
1 68 O000000OO00000
1 68 O00000000000.OO
1 68 0000000000,000'0
1 68 OOO00OOOOOOOO0
1 58 00000000000000
1 68 00000000000000
1 ~8 O0000000000O,O~
1 68 .O000000000,O00'O
I 6~ ,O00000000,O00O~,
1 ~8 000000000000'00
I 68 0000000000000~
1 68 0000000000000'0
SP
RHOB
NPHI
OEPT
RHOB
,NPHI
OEPT
SP
RHOB
NPHI
OEPT
SP
RHOB
NPHI
OEPT
SP
RHOB
NPHi
OEPT
SP
RHOB
N.PHI
OEPT
SP
NPHi
SP
RHDB
NPHI
OEPT
SP
RHOB
N,PH I
DEPT
SP
RHOB
NPHI
9327.5000 SFLU
-32.7383 GR
-1.5259 DRHC
2.73%~ N£NL
9500.0000 SFLU
-31.d20t GR
-1.5259 DRHO
£.73%¢ NCNL
9ZOO,DO00 SFLU
-ZS.~?O1 GR
2,3752 ORMO
47.1680 NCNL
9100.0000 SFLU
-35. !1,33 GR
Z. 3792. 2RHO
33.3008 NCNL
9000.0000 SFLU
-50.8633 ER
2.2151 ORHO
~900.0000 SF~U
-22.9951 GR
2.~2'99 DRHO
31.6895 NCNL
8800,0000 SFLU
-~,~.9883 GR
2-3215 ORHO
49,.,013~ NCNL
8?00.0000 SFLU
-40,.$633 GR
2.3909 ORMG
5,1.9531 NCNL
B$O0.O000 SFLU
-4Z.61,3i3 GR
2.3284 ORHD
8500,,.0000 SFL.U
-35,.8633 GR
-999.2500 ORMO
-999, Z500 NCNL
8-6.00.0000 SFLU
-23o6201 G.R
-999,2500 gRflO
'-99~..2500 NCNL
2,~£21 iLD
93t9.0000 JR
-Z.9861 NRAT
32767.0000 FCNL
2.3733 ILD
9319.0000 GR
-2.9B$1 NRAT
32767.0000 FCNL
Z.7288 ILO
99.21~B
0.0503 NR~T
1650.5875 FCNL
7.0671 ILO
84.$523 &R
0.01~6 NRAT
2305.5000 FCNL
22,~580 ILO
4,5.7305 GR
0.02~4 NR~T
2693.,500'0 FC~L
5.3132
82.2773
0.0566 NRAT
236'9.5000 F£~L
Z.~5'73 ILD
118,90t3 ~R
0.130~ NRAT
1755.6875 FCN.L
1.'785~ IL, t}
11',3.96~8
0,. 04~8 NRAT
1656.687:5 FCNL
3.1838 ILO
11~.7,14.8 GR
· -0.0010 NRAT
1357.68'75 FCNL
3.63'70 I,LD
185.1875 GR
-999.2500 NR$T
-999.2500 FCN'L
3.0'0 ~,2 it g
173.8125 GR
-999.2500 NRAT
-999.2500 FCNL
Z1..5986
931~.0000
0.9139
32767.0000
2.3957
9319.0000
0.9189
32767.0000
2.6038
99-21~8
3.7170
~10.5406
8~.6523
t.9592
'741.3125
Z3.'T851
2.7639
82.27?3
2.8538
73,2.3125
2. :1,331
i18.9025
3... 318,$
· 3 it8.390 6
2.?092
113.9645
3.9788
357..3906
3.0,217
118.7148
,3.~70~
464.3906
,3. ,3811
185'1875
-999. Z 5 00
-ggg' Z500
2.5002
173.8125
-99'9.2500
ILM
CAci
RNRA
CALl
RNRA
ILM
CALI
RNRA
ILM
RNRA
ILM
CALl
RNR A
.ILM
CALI
RNRA
ILM
CALl
RNRA
I~LM
CALf
RNRA
ILM
CALI
RNRA
ILM
CALI
RNRA
CALl
RNRA
£,7356
8.~OZO
1.OOO1
2.~3~8
8.1348
1.0001
9.5801
4.gi,54
6.3~71
Lq. 93 t6
3. 107'7
29.~268
3.113 5
5.3992
9.3615
3. 234,6
2.Z3Z?
9.3457
2,. 828z~
3223
5,,3,3 5
3.1584
~.0007
3.4045
I0'9254
-999. 2500
Z.o096
-999.2500
CVP OlO.HOZ VERiFICATI2N LiS'TiNG PA&E
OEPT
SP
RHOB
NPHI
DE PT
SP
RH3B
NPHI
0 EPT
SP
RHOB
NPHI
DE PT
SP
RHDB
NPHi
gEPT
SP
NP HI
DEPT
SP
RHgB
NPHI
OEPT
SP
NPHI
OEPT
SP
RHOB
NPHI
DEPT
SP
NPHI
DEPT
SP
RHDB
NP HI
DEPT
SP
RHOB
8300.0000 SFLU
-60.2695 GR
-999. Z500 NCNL
8ZO0. O000 SFLU
-16-2~51 GR
-999.Z500 DR~O
-999.2500 NCNL
8100.0000 SFLU
-~2.3633 GR
-999.2520 DRHD
-99'9.2500 NCNL
8000.0000 SFLU
-5Z..6883 GR
-.999. 2500 gR~O
-999.2500 NCNL
7900.0000 SFLU
-41.,$133 GR
-999.250,0 DRHO
-'999. 2500 NCNC
-3Z.o%8~3 GR
-999.Z500 DR~D
-999.Z500 N.CNL
7700,0000 SFLU
-3'9.6133 GR
-999.1500 ORHO
-999.2500 NCNL
7500.0-000 SFLU
-50,.. 363,3
-)99.ZSDO
-999.2500 NCNL
7500.0000 S,FLU
'-50.7383 GR
-999.2500 gR~O
-~'99.25.00 NCN,L
7BDO. O000 SFLU
-43.238,3 GR
-999.,Z500 ~RHO
-'~99,.Z500 NCN,L
7300.0000 SFcU
-52.98~3 GR
-999.2500 ORHO
3.7151 IL 0
117.¢6,8 SR
-999,2500 NR,~T
-999.2500 FCNL
5.00~6 IL2
11~.%023 GR
-g99.ZSDO NRAT
-999.2500 FCML
5.1179
103.5273 !JR
-~99.2500 :iR~T
-999.2500 FCNL
5.5125 ILg
99.9648 SR
-999.2500 NR&T
-999.2500 ~CNL
3.;9182 ,ILO
9,3.9023 GR
-99~.2500 NR~T
-999.2500 FCNL
,Z. 7815 IL O
135.3125 GR
-999.2500 NR~T
-999.Z500 FCNL
~.05.15 ILg
I09.96~8 GR
,-999.250.0 NRAT
-999.2500 FC~'L
,4.541.4 ILD
118,.4375 GR
-999.2500 NR&T
-999.Z500 FCNL
~.~695 iL3
11Z · 5898 ~R
-999.2500 NRAT
-999.2500 FCNL
3.0354
99.~3'98 ~R
-999. Z500 NRAT
-'999..Z500 FC~L
.(+. ,~812 IL;
123. 3398 G,R
9'99,.2.500 NRAT
3.7717
11'7.~6~B
-999.2500
-999.2500
~.75~6
I14.~025
-999.2500
-999.2500
5. Z351
103.5273
-999.2500
-999.2500
5.5375
99.9648
-999.2500
-~99.2500
93.9023
-999. Z$00
-99'9.2500
2.. 7229
135.3115
-999. 2500
-999.2500
3 .- 59'99
-999.Z500
-999. ZSO,O
-999. ZSO0
4.6960
-99'9.1500
-999'250'0
-999' 2'500
-999.Z500
-999. 2500
3.~358
-999.2500
-999.Z500
-999.2500
-999.2500
-999.2500
ELM
CALI
RNRA
iLM
CALi
RNRA
ILM
CALl
RNRA
ILM
CALl
RNRA
I:LM
CALl
RNRA
.ILM
CALl
RNRA
iL M
CALl
RNRA
ILM
CA~I
RNRA
iLM
CALI
RN RA
I,L M
CALl
RNRA
,IL M
CAL.i
R,N RA
3.838I
10.~1~0
-999.2500
5.05!5
20.9082
-999.Z500
5.3289
9.5879
-999.Z5~0
5.51,~0
10.22~5
-99'9.2500
4.3289
10.9004
9.94'73
-999.2500
3.6663
-999. 2500
-999 o 2,'50 0
,-999.Z500
-999.25~'0
-99'9.25'00
-999.2500
3.~I43
-999.2500
-999'250.0
,~ 52. O-.t
-999. :Z 5 O-O
-':~ 99.25 O 0
LVP 012oH02 VERIFiCATI2N LISTING PAtE 6
NPHI
DEPT
SP
RHDB
NFHI
DEPT
SP
RHOB
NPHI
gEPT
RHDB
NPHI
2~PT
SP
RHOB
NPHI
DEPT
5P
RHOB
NPHI
DEPT
SP
RHQB
NPHI
DEPT
SP
RHOB
NPHi
DEPT
SP
RH08
NPHI
O.EPT
SP
RHOB
NPHI
OEPT
SP
NPHI
OEPT
S~P
-999.2,500 NCNL
7ZO0.O000 SFCU
-58.1~5 .$R
-999.2500 DRHD
-39:9.2500 'NCNL
7100.0000 SFLU
-59.~133 GR
-399°2500 ORHO
-999.2500 NCNL
7000.0000 SFLU
-50.1383 GR
-999.15'00 ORHO
'-999..2500 NCNL
6900.0000 SFLU
-71.09'77 GR
-399.2500 DRHO
-999.2500 NCNL
6800.0000 SFLU
-59,.14~5 GR
-999.2500 NCNL
6700.0000 SFLb
-55..6133 GR
-999.2500 ORHO
-999..~500 NCNL
650~.D000 SFLU
-57.6133 ~R
'-999.~500 ~RH.O
-999oZ$00 NCNL
6500.00D0~ S.FLU
-~8.~883 ~R
· -999.250,0 ORHO
-999.2500 NCNL
6BO0oO000 SFLU
-48.3633 GR
-999.21500 ORHC
-999o2~00 NCN,L
6300.0000 SFLU
-43.7383 GR
-~99.,Z500 D.RHO
,-999'~500 NCNL
· 6200.0000 SFLU
-~'7..2,383 GR
-999.2500 FCNL
~o3562
125.7773 &R
-999.2500 NR&T
-999o25D0 FCNL
~.1609
159.5625
-999.1500 NR~T
-999.2500 FCNL
i.~219
I13.?1~ SR
-999.2500 NRAT
-999.2500 FCNL
~.7078 ILD
131,..~375 3R
-999.2500 NRAT
-999.2500 FC'NL
~2.1331 IL'D
llZ. 9648 GR
-~99o2500 NRAT
-999.2500 FCNL
2.1311 .ZLg
107.'T1~8 GR
-999.1500 NRAT
-999.2500 FCNL
5.'77~2 ILD
I61.6875 GR
-999.2500 NR~T
-999.2500 FCNL
,~. O 0 ~6 I L g
83.96,~8 GR
-999.2500 ~RA'T
-999.2500 FCNL
3.0725
116.21,~8 GR
-999.2500 NRAT
-999.2500 FCW,L
3.1331 iL'D
132.5625 GR
-999.25-00 NRaT
-999o~500 FCNL
Z,.7952 ILO
100..Z1~8 GR
-999.2500
5.1~53
-999.2500
-999.2500
3.8577
-999.2500
-'999.Z500
-999.2500
' 1.987~
-999.2500
-'999.Z~00
-99'9,.2~00
-:999.Z500
-999,.Z500
2.3303
-999.1500
-999.2.500
-999.150.0
-999.2500
5,o36%0
-999.25,00
'-999,.Z5:~0
-99'9.2500
-999.2500
,-999,.Z500
3.28,74
-999.2590
'-999,.Z500
-999,.Z500
3,o2991
-999-25:00
-99'9.250:0
3.0706
-999.1500
ILM
CALI
RNRA
CALl
RNRA
ILM
CALl
RNRA
CALl
RNRA
ILM
CALl
RNRA
ILM
CALI
RNRA
ILM
CALl
RNRA
CALi
RNRA
ILM
CALl
RNRA
iLM
CALI
RNRA
ILM
CA~
-999.£500
-999.2500
-999. 2500
3.. 79 79
-999. 2500
-'999.2500
~. 7273
-999. Z5
-999. ZSO0
I. :37.52
-999.25 00
-999.Z500
-999.2.500
--'999.2.500
-.999.. 2500,
-999. i5'00
-g 99 . Z 500
--999.. 250 0
-993 .... ZSO0
'-999.Z500
-999-1500
'-999.2500
3..07~5
-999.2500
LVP 010.HOZ VERIFICATION CISTING PA6f 7
NPHI
DEPT
SP
NP,~I
DEPT
SP
RHOB
NPHI
@EPT
SP
RHOB
NPHI
DEPT
SP
RHOB
NPHI
DEPT
SP
RHOB
NPHI
DEPT
SP
RHDB
NPHI
DEPT
SP
RH06
NPHI
DE'PT
SP
RHDB
NPHI
OEPT
SP
RH06
NPHI
DEPT
SP
RHD8
NPHI
D .~ P 'T
- 99 9.
2500 ORHO
ZSOO NCNL
6100.0000 SFLU
-53.4BB3 GR
· -999.2500 DRHG
-999.2500 NCNL
6000.0000 SFLU
-50.3633 GR
-999.2500 ORMO
-999..Z500 NCNL
5900.0000 SFLU
-5Z. 5133 GR
-999.2500 DRHO
-999.2500 NC'NL
5~00.0000 SFLU
-5i.5133 ~R
-999..2500 ORHO
-99'9.2500 NCNL
5ZO0,.O000 SFLU
-55.1133 SR
-999.25,00 DRHO
-999.,Z500 NCNL
5500. 000'0 SFLU
-61. 7383 GR
-999.2500 ORHO
-999.Z500 NCNL
5500.0000 S.FLU
- 6,1*'r~ 633 GR
-999.1500 DRHG
-999.2500 NCNL
5~00.000,0 SFLU
-63.7383 GR
-999.2500 O'RHO
,-999,.Z$00 NCNL
5 "300 . 0000 S F L,U
-59.73~3 GR
-999.2300 DRMC,
-"999. 2500 NCNL
5200.0000 SFLU
-66,.0977 GR
-999.250,0 DRHO
,-99 9,. ZSO0 NCNL
5100.0000 SFLU
-99'9. 2500 ,~RAT
-999.2500 FC4L
2.~319 iL2
91.9023 SR
-999.2500 NRAT
-999.2500 FCNL
3.119~
t06.7148
-999.2500 NRAT
-999.2500 FCNL
2.~163 ILO
100,5513 5R
-999. Z500 NRAT
-999.2500 FC~L
2.8401 iLO
94.5898
-999.2500 NR~T
-999.25D0 FCNL
2.6506 ILO
9B.2148 GR
-999.2500 NRAT
- g 99.250'0 F C N L
2.5901 I'LO
108.5898 ~R
-999.2,500 NRAT
-999.250'0 FCN£
3.078.4
9 .£. 2773 ,~ R
-999.2500 NRAT
- 999.. 2500 FCNL
2.8440 iLD
99.5173 GR
-99'9.250:0 NRA'T
-'999.,2~00 FCNL
2o ~5,.18 iL2
98.6513 GR
-999.2500 NR.AT
'-999.2500 F.CNL
3.0,881 iLO
99,5523 ~R
-999. ,250'0 NRAT
'-99~.Z500 FCNL
3,.418Z ILD
-999.25'00
2.79~2
-999.2500
-999.2500
-999.2500
3.5178
-999.2500
-999.2500
-999.2500
2.7463
-999.2500
-999. Z500
3.0256
-999.Z$00
-99'9. 2500
-999.Z500
3.01~9
-999.Z500
-99'9. Z500
-999.2500
2.9104
-999.2500
-999.Z500
-999.Z500
.-999.2500
-9'99. Z500
-999.2500
3.2346
-999,oZ$00
-999.2500
-99'9.Z~00
3.2 1'70
-999,.2500
- 999. lSO0
-999. Z 5 O 0
3'3733
-999,2500
-999,2500
,-999,.Z500
3.7,209
RNRA
ILM
C.ALI
RNRA
ILM
'CALl
RNRA
,ILM
CALl
RNRA
ILM
CALl
RNRA
,ILM
CALl
RNRA
i:LM
CALI
RNRA
CALl
RNRA
I'LM
CALl
RN, RA
'CALl
RNRA
I,LM
CALl
RNRA
i .L M
-999.2500
2.?092
-999.2500
-999.Z500
3.~670
-99'9.2500
-999.2500
-999.2500
3.0276
-999.2500
-999.2500
2o9i80
-999.Z500
-9'99.Z500
1.8616
-999.Z500
-999.Z50'0
3.1975
-999'.Z50'0
-99'9.,Z,$00
3.1555
'-99~.Z50,0
-9'99-2500
3.17,02
-999.2500
-999.2500
.3.289'3
-99').Z500
-999
LV? 012oH02 VERI~tCATIDN kZSTZNG ?A~E 6
SP
Rh36
NPHI
OEPT
SP
RHDB
NPHI
DEPT
SP
RHGB
NPHI
DE PT
SP
RHOB
NPHI
DF. PT
SP
RH26
N P HI.
OEPT
S~P
NPHI
DEPT
SP
NiPHI
0 E P T
SP
R H 0 B
NP HI
DEPT
SP
N P H I
DEPT
SP
RHO'B
NPMI
DEPT
'SP
N,PHi
-73.2227 .6R
999.2500 ORHO
399.2500 NCNL
5000.0000 SFLU
-73.7227 GR
-999.2500 9RHO
-999.2500 NCNL
4~00.0000 SFLU
-69.2227 ~R
-999.,2500 ORHO
-999.2500 NCNL
4800.0000 SFLU
-73. 2227 ,'3R
-999.2500 DRHO
-999. 2500 NCNL
~700.0000 SFLU
-72.5977 GR
-99'9.2500 ORHO
-~99.,2500 NCNL
4500.0000 SFt. U -71.3~77
-999.2500 ,'2RHO
- '999.2500 N C N.L
4500.0000 SFLU
-7,3.5977 GR
'-~99.2500 DRHO
-999.2500 NCNL
4~00.0000 SFLU
-70.7227 GR
-999.2500 OReO
-999. Z500 NC.NL
4300.0000 SFLU
-71.59'77 G.R
-999.2500 ORHO
-999.2500 NCNL
4200.0000 SFLU
-72.5977 GR
-999,.,2500 DRH'O
-999o!500 NCNL
4100.0000 SFLU
-68.34'77 GR
-999.2500 D,RHG
-999' 2500 NCNL
88.0898 3R
-999.2500 NR~T
-~99.2500 FCNL
3.8225 ILO
98.7148 GR
-999.2500 NRAT
-999.2500 FCNL
97.2773 ~R
-999. 2500 NRAT
-999.2500 FC~L
3.5667 ILO
105. 6523 SR
-I)99.2500 NR~T
-999.2500 FCNL
.3.2678 iLO
10,3.6523 ~R
-~99.2500 ,NR~T
-999.2500 FC~L
3.8186
73.9.023
-999.2500 NR.~T
-999.2500 MCNL
3.72,29 ILO
86.5273 ~R
-999.2500 NRAT
-999.2500 FCNL
~.000?
92.5898
-999.2500 NRAT
-999.2500 FCNL
3..,6319
99. 5273
-999.2.500 NRAT
· -999.,25 O0 FCNL
~-5062 ILO
84. ~66~8 SR
-399.2500 NR~T
-999.2500 FCNL
~.0398 ILO
80.1523 GR
-999.2500 NR~T
-999.2500 FCNL
--999.2500
-999.£500
-~99.2500
-999.2500
-999.2500
-999.2500
-999.2500
-~99.2500
-999.25O0
-999.2500
3. 550.b
-999.. 2500
- 9 '~ 9.250 :O
-999* 2500
~.3'91,6
-999..2500
-999.Z500
-999.2500
-999 .... 2500
-999.2500
-999.2500
-999.2500
-'99'9.2500
-999.2500
~.1609
-999.2500
-99'9.2,500
--999.2500
5.3757
-9'99.2500
-999.2500
-,999.2500
5.055¢
-'999.2.500
-999.2.500
-999.2.500
CALI
RNRA
iLM
CALI
RNRA
ILM
CAci
RNRA
ILM
CALI
RNRA
'.IL M
.CALi
RNRA
ILM
CAc,I
RNRA
tLM
CAL.i
RNRA
.ILM
C,A~. I
RNRA
ILM
C A L I
RNRA
ILM
R:NR A
IL M
· CALi
RNRA
-999. 2500
-999.2500
-999.2.500
-999.2500
,~.. 39.53
-999.~500
-999.2500
-999.2500
-999.2500
3.$~91
-999.25'00
-999.25'00
-999..2500
-999.Z50'0
-999.1500
--999.25~0
~.3562
-999.2500
-999.1500
-999.2500
-99,9.2500
-999.2500
-999. 250'0
-999.2590
-999.,Z500
LVP O!O.MOZ VERIFICATION LISTING PASE '~
2EPT
SP
RMOB
NPMI
4065.gOgO SFLU
-132..3125 ,$R
-999° ZSO0 DRHO
-999.2500 NCNL
2000.58?5 iL~
55.6055 -~R
-99'9.2500 NRAT
~* FIL5 TRAILER ~-*
FILE NAME :EDIT .00i
SERVICE NAME :
VERSION ,~ :
DATE :
MAXIMUM LENGTH : .102~
FIUE TYPE :
NEXT FILE NAME :
** TAPE TRAILER
SERVICE NAME
DATE :B5/0~/18
ORIGIN :~ODO
TAPE NAME :01~5
CONTiN~ATiON ~
NEXT TAP~ NAME
COMM~ENTS :L,I,~.RARY TAPE
· * REEL TRAILER *~
SERVICE NAME :EDIT
DATE :55/03/:i8
UR,IGIN :
RE~L NAM~ :'.142~63
CONTINUA'TISN #
NEXT REEL NAME :
CDMM~NTS :LI,~RAR~ TAPE
15o611~ ILM
-999.2500 CALI
-999.2500 RNRA
£000.5875
-99'~.Z500
