Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout1988 Endicott Oil PoolBP EXPLORATION
February 28, 1989
C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
BP Exploration (Alaska) Inc.
900 East Benson Baulevaro
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
RE: Year-end 1988 Endicott Oil Pool - Waterflood Surveillance Report
Dear Mr. Chatterton:
Attached is the semi-annual Endicott Waterflood Surveillance Report. This
report covers the status of the Phase 1 waterflood program from the initiation
of injection in February 1988 through December 1988. In addition, field
surveillance and material balance information is provided from field start-up
in October 1987 through December 1988.
BP Exploration recommends a briefing to illustrate the present status and
future waterflood plans. Please advise a convient time for the meeting and
any other informational needs to Mr. John F. Oldenburg at 564-4757.
Sin ererrly, pp��
J. W. Buckee
Vice President,
Development Planning
JWB/RQM:
cc: Working Interest Owners
:ias:ia G'fj sc G2s Cor
Anchorage
ENDICOTT OIL POOL
WATERFLOOD SURVEILLANCE REPORT
DECEMBER 1988
MMINNISIM
This report covers the period from the start of water injection on February 29,
1988 through December 31, 1988 for the Endicott Oil Pool. During the report
period water injection occurred in four wells, three previously reported wells
and one new well. Exhibit 1 shows a map of the field with the year end wells
including the existing water and gas injectors.
Cumulative pool production since start-up is 46.2 MMB of oil, 42.5 BSCF of
gas, and 2.6 MMB of water. Cumulative water injection into the Endicott Oil
Pool from the start-up of water injection through December 1988 is 6.6
MMBW as detailed in Exhibit 2. The cumulative injected and produced
reservoir volumes since start-up for the lower 3 subzones or sands are shown
in Exhibit 3. The volumes shown in Exhibit 3 do not include production from
subzones 3B and 3C as no injection has occurred in these sands. As of
December 31, 1988, reservoir voidage had exceeded gas and water injection
by 24.5 MMB.
Injection Well Performance
Exhibit 4 provides graphs of the injection rates, injectivity index and wellhead
pressure versus time for the four active water injection wells,1-37/P-24, 5-
02/SD-10, 4-02/0-28 and 3-45/M-39. The waterflood performance overview
shows the total injection volume of 6.4 MMBW with the average rate and
injectivity through December 1988.
Well 3-45/M-39 was the fourth water injector commissioned for the Endicott
Pool. Pre -production of the well was attempted in August and September
1988 to clean the wellbore of completion debris. The productivity was too
low to achieve stable production and on October 1, 1988 3-45/M-39 was
converted to a water injector. A mud acid stimulation was performed to initiate
injection.
Rate
II
Cumulative
Well Name
MBW D
PD i
MMBW
1-37/P-24
6.0
7
1.6
3-45/M-39
6.5
4
0.6
4-02/Q-28
15.0
20
2.6
5-02/SD-10
6.3
8
1.8
Well 3-45/M-39 was the fourth water injector commissioned for the Endicott
Pool. Pre -production of the well was attempted in August and September
1988 to clean the wellbore of completion debris. The productivity was too
low to achieve stable production and on October 1, 1988 3-45/M-39 was
converted to a water injector. A mud acid stimulation was performed to initiate
injection.
To inject sufficient water volumes all wells have been operated at pressures
above fracture gradient. The wells exhibited low injection rates of 0 to 6
MBW/D at pressures below fracture gradient. Step rate tests and pressure
fall-off tests have shown fracture gradients of 0.51 to 0.54 psi/ft with short
fracture lengths of less than 60 feet. Temperature profiles show no vertical
fracture growth out of perforated intervals. Based on the above analysis it is
acceptable to inject above fracture gradient. Regular step rate test, pressure 7
fall-off test, temperature profiles and other injection well surveillances
techniques will be employed to monitor whether fracture growth continues. D
Water Injection Performance
Routine pressure surveys taken as part of the reservoir surveillance program
verify the restricted pressure communication across the mid -field fault system.
The observed pressures in the SDI region continue to be 100 to 200 psi
lower than those observed in the MPI region. The lack of pressure support
can be attributed to limited communication with the gas cap in the MPI area
and the limited SDI gas cap volume. Implementation of water injection in the
SDI area has reduced the pressure decline and has started to repressure
subzone 3A. Refer to Exhibit 5 for the summarized bottomhole pressure data
obtained since field start-up.
Radioactive Tracer Program
Radioactive elements injected into the water injectors have provided another
surveillance tool to monitor the injection fluid movement and pressure
support provided by injection wells. Three of the four active water injection
wells had tracers added in July 1988.
',-- fi,%
Well Name Tracer Element
1-37/P-24 Cobalt -60
3-45/M-39 no tracer added Ccs. 2crrs (s,.
4-02/Q-28 Carbon-14
5-02/SD-10 Tritium Acchoraoe
The tracer surveillance program consists of 13 oil producers with wellhead
water samplers. Refer to Exhibit 6 for maps of the tracer and monitoring wells.
Data evaluated by BP Exploration Warrensville's laboratory through
December 1988 show Carbon-14 has been detected in 2 wells, 3-05/0-29
and 3-23/N-32. The water breakthrough seen in the SDI 3A subzone is
consistent with reservoir simulation predictions.
The future tracer program may expand to include as many as 12 source
injectors. This would include the present 4 water injectors and could
potentially include the future 8 to 9 water injectors. The number of monitoring
wells is undecided at the present time, but would increase above the present
13 wells.
Presently there are four active water injection wells in the field injecting
nominally 40 MBW/D. The plans are to add 4 water injection wells in the
1089 and an additional 3 wells by the end of the 2089. By year end 1989
our objective is to have 11 to 12 injection wells with a capacity of 110+
MBW/D. Waterflood plans incorporated the results from reservoir simulation
that predict 110 MBW/D requirement for voidage balancing.
An SDI 3B/3C water injector is under evaluation and could be in service by
the end of the second quarter 1989. The selected well will be pre -produced
to clean up the perforations and produce downdip oil before conversion to
water injection. A pressure build up test and production logging will also be
required to aid in pressure decline and injection profile analysis.
EXHIBIT BP EXPLORATION
C< ENDICOTT OIL FIELD
�l 2 26 K$ I J-98 a3L/
j 1-1 I Gas Injectors
2-16 1 J-19 ", U,
2-34
M-16
2 44 P-14 2-14 2-4 O Oil Producers
O 5 k'
R-12 1_3g Q-16 Mtl Sid?2
P-)7 I `ry2 Water Injectors
=28 1-25 r
S 14 2-62 A%19
Q-17
P-20 / 2
S 17 68 1-41 D-10 I 3_q
1 9 0-23 �1-�29 L-28
135—
,j;5 O
2 —
\
157 1-43 4-8 3-1 i I 3-15
R 23�, P-24 K-33
P-26 P-27 _
, I 1.55 6 3- - -27 3-2L-34 3 33 � 3
3-23 K-37 39
-2 N-32 4-20 I J-39
Q-28 M-35 3-35 L-36 3-49
-26
I— — — — — — 4-6 4 — — — — J_40
Q-32 4-28
N-37
4-14 M -39I
1 I % 1 83425 41i2 1
P-38
I
EXHIBIT 2
ENDICOTT OIL POOL
SUMMARY OF PERTINENT DATA
(as of December 31, 1988)
Water Injection Start-up: February 29, 1988
Endicott Production since Field Start -Up:
Oil (MMSTB) 46.2
Gas (BCF) 42.5
Water (MMSTB) 2.6
Endicott Injection since Field Start -Up:
Gas (BCF) 33.0
Water (MMSTB) 6.6 "
Wells in Operation:
Oil Production 39
Gas Injectors 3
Water Injectors 4
Produced Water Disposal 1 "
Drilled (not in service) 5
Total 52
' Water injection volumes do not include Cretaceous injection
Cretaceous injector not shown in Exhibit 1
Produce
w
Free Gas
Water
Total
Ini teedVo�g
Gas
Water
Total
Net Vo caae Volumes
Total
PrateVole
a
Free Gas
Water
Total
Iniected Volumes
Gas
Water
Total
Net Voidaae Volumes
Total
EXHIBIT 3
ENDICOTT OIL POOL
RESERVOIR BALANCE FOR WATERFLOOD SANDS
EFFECTIVE PRODUCTION SINCE FIELD START-UP
(October 1987 to December 1988)
(Values in MMRB)
MPI
3A Sand
6.11
Region
2B Sand
10.28
0.84
0.21
lu
415
7.06
10.65
Arcs Cr ns y"T:?:
2A Sand
14.95
MPI Total
31.34
0.25
1.30
4.22
4.42
15.42
33.13
4.37
8.04
9.01
21.42
1.40
0.21
Water
094
4.37
9.59
10.84
24.80
269
1.06
4.58
8.33
3M
6.10
0.56
M
7.49
0
U
3.2
4.29
lim
6.79
0
472
7.51
0
4
0
7.51
Produced Volumes
01
FI I
3A Sand
1221
D TOTALS
213 Sand
17.07
Free Gas
1.40
0.21
Water
094
Total
14.55
18.16
Iniected Volumes
Gas
4.37
8.04
Water
2M
].M
Total
7.57
9.59
Net Voidaae Volumes
Total
6.98
8.57
Injected water volumes excludes injection into the Cretaceous reservoir
2A Sand
4.18
0
021
4.39
0
0
0
4.39
19.13
0.25
4.43
19.81
9.01
IM
10.84
8.97
II Tot
17.07
0.56
J_M
19.39
0
bu
3.2
16.19
1Q To
48.41
1.86
Z25
5252
21.42
LM
28.00
24.52
EXHIBIT 4
ENDICOTT PHASE 1 WATER INJECTION WELLS
INJECTION RATE, WELL HEAD PRESSURE AND INJECTION INDEX
VERSUS
INJECTION TIME
(START-UP THROUGH DECEMBER 31, 1988)
INJECTION RATE / WHP /
PRESS. GRAD. / INJ. INDEX
WELL 1-37
0
N
N
IL
m
.!O
x—
W
G
Z_
N
z
Z
O
m
O
H
V
CL
v
Q N
Q Q
W
IL
IL
8
0
N
/\O
U• O
_ O
H
Q.
v
IL
So
3N
0
e
e
0
9
n
00
ae
me
W
f
� e
.O
00
Z
221
I
W77-7-777777777:1
We
O
a„
w
3
7
I
M
7 11;
N
e
APR
MAY
JUN JUL AUG SEP OCT NOV DEC JAN
1989
LJ M
Q
1988
ppSefl
Z
Water (blue Produced 'Nater (green \\\\\ )
Z Q
= p
� w
INJECTION RATE / WHP /
PRESS. GRAD. / INJ. INDEX
WELL 3-45
n
S
0-
(a
W
Q
0:
z
Z_
K
W
Q
3
O
vv wocrt NUVLMBER DECEMBER
1888 JANUARY
1989
Sea Water ( blue //"/ )I lProduced Water ( reen \\\\\ )
INJECTION RATE / WHP /
PRESS. GRAD. / INJ. INDEX
WELL 5-02
0
N
i1
N
a
IL
IL
m
m
,,a-
x
w
0
z
z
z
0
a
0
H
In
a
v
Q N
Q �
VI
W
Ix
a
e
0
0
n
V1 c
v4
0
a-
3
8
0
a
n
a.
a
vo
wo
c
1b
z o
to
w
LLI
Q
�
3
M
N
o
APR
MAY JUN JUL AUG SEP OCT NOV DEC JAN
Q
1988
1989
ZC)
ZQ
IS08 Water ( blue ///// )I Produced `Nater (Green \\\\\ )
� p
d' W
EXHIBIT 5
ENDICOTT PHASE 1 WATER INJECTION WELLS
BOTTOM HOLE PRESSURE REPORT
(START-UP THROUGH DECEMBER 31, 1988)
Production Database
STATIC PRESSURE REPORT
Test RR
TEST DATE Depth Temp PEAR
Well Name API Number DD-MM-YY Pt as F psia
1-011J-19 500292180100 05-JUN-88 10000 00 216 4745
28-JUN-88 10000.00 209 4709
19-NOV-88 10000.00 217 4618
1-05/0-20 500292160500 14-APR-88 10000 .00 212 4833
1-09/J-18 500292174300 01-OCT-87 10000.00 204 4890
22-MOV-87 10000.00 4813
02-FEB-88 10000.00 212 4788
10-OCT-88 10000.00 212 4628
1-27/P-20 500292169300 29-NOV-88 10000 .00 213 4669
1-29/M-25 500292166900 02-FEB-88 10000.00 216 4768
O1-APR-88 10000.00 216 4790
11-JUN-88 10000.00 220 4726
23-OCT-88 10000.00 211 4644
1-35/0-25 500292167200 21-JAN-88 10000.00 4809
25-APR-88 10000.00 209 4758
12-JUN-88 10000.00 218 4742
25-OCT-88 10000.00 209 4721
1-37/P-24 500292174800 07-JAM-88 10000.00 207 4801
1-39/P-17 500292182700 23-AUG-88 10000.00 213 4705
02-DEC-88 10000.00 215 4609
1-43/P-26 500292186400 16-DEC-88 10000.00 213 4656
1-47/Q-21 500292162500 17-DEC-87 10000.00 213 4631
1-55/R-25 $00292178800 07-MAY-88 10000.00 203 4790
O6-JUN-88 19000.00 205 4666
04-SEP-88 10000.00 4544
2-04/M-19 500292158500 28-FEB-88 10000.00 215 4769
12-JUN-88 10000.00 216 4751
2-06/J-22 500292169900 30-MAR-88 10000 .00 218 4849
2-08/K-16 500292177100 07-MAR-88 10000 .00 205 4789
20-OCT-88 10000.00 207 4531
2-14/0-16 500292163900 16-OCT-88 10000.00 214 4678
2-26/3-14 500292181500 29-JUN-88 10000 .00 204 4837
29-JUL-88 10000.00 207 3718
O8-OCT-88 10000.00 209 3320
2-28/P-19 500292184700 27-SEP-88 10000.00 209 4695
2-34/P-14 500292166200 14-APR-88 10000.00 202 4486
2-44/R-12 500292176700 27-FEB-88 10000.00 206 4802
28-MAR-88 10000.00 206 4502
11-SEP-88 10000.00 203 4482
16-OCT-88 10000.00 4783
2-52/5-14 500292175000 25-OCT-87 10000.00 202 4900
.. 27-JAN-88 10000.00 205 4784
2-62/Q-17 500292164800 05-eFES-88 10000.00 204 4737
13-JUN-88 10000.00 212 4673
3-01/N-29 500292167800 10-NOV-87 10000.00 _ 217 _.4839
05-DEC-87 10000 .00 215 4696
27-MAR-88 10000.00 218 4512
11-JUN-88 10000.00 219 4497
21-JUL-88 10000.00 214 4495
22-OCT-88 10000.00 211 4524
3-05/0-29 500292162400 06-DEC-87 10000.00 213 4907
30-MAR-88 10000.00 211 4813
26-MAY-88 10000.00 215 4460
23-JUL-88 10000.00 211 4498
11-OCT-88 10000 .00 212 4590
3-09/L-28 500292178000 06-APR-88 9658.00 205 4684
3-11/M-30 500292184800 27-SEP-88 10000.00 215 4503
07-OCT-88 10000.00 214 4541
3-15/K-33 500292175100 23-DEC-87 10000.00 214 4836
13-JUN-88 10000.00 220 4558
3-21/L-34 500292171400 04-DEC-87 10000.00 212 4736
3-23/N-32 500292164500 03-DEC-87 10000.00 208 4828
02-NOV-88 10000.00 212 4138
3-27/M-33 500292158600 07-OCT-87 10000.00 213 4892
17-APR-88 10000.00 220 4404
14-JUN-88 10000.00 218 4440
24-JUL-88 10000.00 217 4444
07-OCT-88 10000.00 217 4478
3-33/K-37 500292166800 09-AUG-88 10000.00 218 4513
10-AUG-88 10000.00 218 4469
Production Database
STATIC PRESSURE REPORT
Test SR
TEST DATE Depth Tamp PBAR
Well same API Number DD -MM -YY Ft as F Asia
3-35/L-36 500292170100 11-JUL-88 10000.00 221 4438
09 -OCT -88 10000.00 216 4455
3-39/J-39 500292176400 12-JUL-88 10000.00 224 4455
3-45/M-39 500292181100 23 -AUG -88 10000.00 219 4331
3-47/Q-35 500292156900 28 -FEB -88 10000.00 216 4488
16 -OCT -88 10000.00 218 4257
20 -OCT -88 10000.00 209 4359
3-49/J-40 500292173500 12 -APR -88 10000 .00 211 3492
15-JUL-88 10000.00 218 4443
10 -AUG -88 10000.00 218 4442
4-02/Q-28 500292178900 04 -MAY -88 10000.00 205 4785
4-06/0-32 500292172300 09 -DEC -67 10000.00 216 4600
4-08/P-27 $00292169200 26 -APR -88 10000.00 211 4542
14-NOV-88 10000.00 212 4617
23-HOV-88 10000.00 216 4581
4-20/M-35 500292164001 12 -AUG -88 10000.00 213 4376
4-26/0-34 500292183500 18 -SEP -88 10000.00 213 4411
4-28/N-37 500292187000 25-ROV-88 10000.00 216 4704
4-42/P-38 500292173100 26 -JUN -88 10000.00 214 4553
5-01/SG07 500292051800 27 -MAR -88 10000.00 211 4812
EXHIBIT 6 BPEXPLORATION
K 1 1-9 30 I 29
ENDICOTT OIL FIELD
^ 2-26 1 7-18
1 1-1 I / ` Water Injectors
2-16 1 J-19
2-34 M-16
2.44 P-14 2-14 Tracer Wells
R-12 25-1
1-39 •x,'16 M 1 SD -7 2-
P-17 1 5 J- 2 /
Monitoring Wells
s2 2-62 z8 10-20 '2 ;; 3
5-14 Q-17 P-19 1-27
P-20
t`
/ 5-2
2-68 1N ;, D-10 I OL?28 i
S-17 1- q-
-----
157 it 7 1113 # $':' 3 I 3-15
R-23. P-24 3
P-26 127- 1 K-33
1 _SS J 3'-2 y' 3-2 3-33 3
L-34
3-23 K-37 39
N„3 I.20-
4-2 3-49`
Q-28 4-26 J
— — — — — — — I— — — — — 4-6 — 4 J-40
— Q-32 — -
i 37 3-
-39
N
12 71x34 3351 10
4-42
P-38
