Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2000 Endicott Oil PoolSE
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
March 30, 2001
Ms. Julie Heusser, Mr. Dan Seamount, Ms. Camille Oechsli Taylor
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave #100
Anchorage, AK 99501-3539
RE: Year End 2000 Endicott Oil Pool - Reservoir Surveillance Report
Dear Commissioners:
Attached is the 2000 annual Endicott Reservoir Surveillance Report. This report
is a compilation of three reports tracking the Key Well Pressure Program, Key
Well Gas -Oil contact Monitoring Program, and the Waterflood Surveillance
Program.
As in the past, BP Exploration extends an offer to brief the AOGCC regarding the
reservoir depletion status and future plans for the pool. Please advise Jim
Ambrose at 564-4375 concerning a convenient time for a meeting or if there are
any other questions.
Sincerely, ( 1
-101
Mark Weggeland
Endicott Development Team Leader
cc: Ambrose, Jim
Kleppin, Daryl
Millholland, Madelyn
Robertson, Daniel
Sauve, Mark/ Spearman, Jim
Weiss, Troy
Working Interest Owners
RECEIVED
MAR 2 9 2001
Alaska Oil & Gas Cons. Commission
Anchorage
2000 Reservoir Surveillance Report
Endicott Oil Pool
March 31, 2001
Waterflood Surveillance Program
Key Well Pressure Monitoring Program
GOC Monitoring Program
END shut-in wells 99
ENDICOTT/SAG DELTA NORTH Shut -In Wells
Date Reason Well Shut-
Well Name Shut -In In
Tubing
Pres. (psi)
IA Pres. (psi)
OA Pres. Current Mechanical
(psi) Condition of the Well
Future Utility
Plans & Possibilities
Comments
1-17/1-17 13 -May -99 High TGOR
2300
2300
400 Mechanical condition satisfactory.
1. sidetrack candidate
low productivity, high we.
1-37/P-24 16 -Jul -98 D. -- Tubing Leak
2000
2300
0 Wireline plugs in tubing
1. rig workover or sidetrack
studying field injection requirements
2-42/P-13 27 -Jul -97 B. -- High TGLR
2400
2100
200 Mechanical condition satisfactory.
1. sidetrack candidate
high water -cut & low PI
2-68/S-17 11 -Jan -97 B. — High TGLR
1000
900
100 Mechanical condition satisfactory.
8. resume production
future EOR producer
3-17d/M-31 02 -Mar -99 B. -- High TGOR
1000
1200
0 Mechanical condition satisfactory.
1. sidetrack candidate
Low pressure zone
3-21/L-34 11 -Jan -98 B. •- High TGLR
800
1200
0 Suspended with cement plug
3. sidetrack candidate
future TTRD sidetrack to K-35 EHL
3-33/K-37 07 -Jul -971B. — High TGLR
2000
200
0 Mechanical condition satisfactory.
1. sidetrack candidate
using as 2B pressure monitor
3-35/L-36 02 -Mar -9718. — High TGLR
1450
15001
0 Mechanical condition satisfactory.
1. sidetrack candidate
using as 3A pressure monitor
3-43/P-36 20 -Jun -99 C. -- Low PI/high we
1250
2200
0 Mechanical condition satisfactory.
8. resume production
Hydrate plug cleaned out.
4-14/R-34 12 -Jan -99 C. -- Low II
1550
350
0 9-5/8' Casing leak
1. sidetrack candidate
EOR MI injector.
4-20/M-35 19 -Oct -99 B. -- High TGOR
1800
500
0 Mechanical condition satisfactory.
8. resume production
Waiting on WAG
4-26/0-34 21 -Jun -99 18. -- High TGOR
1200
2000
80 Mechanical condition satisfactory.
B. resume production
Waiting on WAG
4-40/P-43 08 -Nov -97 C. --Low If
1750
200
0 Mechanical condition satisfactory.
1. sidetrack candidate
Possible MI Injector
4-42/P-38 08 -Nov -97 B. — High TGLR
1000
2300
0 Mechanical condition satisfactory.
8. resume production
future EOR producer
4-44/M-44 15 -Jan -93 C. -- Poor Injectivity
3000
2550
100 380' coiled tubing fish in hole
1. sidetrack candidate
needs rig to fish coil first
4-48/K-43 03 -Apr -97 G. -- WF Management
350
350
0 Mechanical condition satisfactory.
1. sidetrack candidate
not providing useful WF support
4-50/K-41 20 -May -98 B. -- High TGLR
2001
350
35019 5/8"pack-off needs sealing
8. resume production
has potential as future EOR producer
Reasons for Well Shut -In
A. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems
B. High water, currently uneconomic to produce, no known mechanical problems
C. Low production or injection rate, no known mechanical problems
D. Mechanical Problem: Tubing or Casing Leak
E. Mechanical Problem: Artificial Lift
F. Mechanical Problem: Other (Specify under comments)
F. Awaiting installation of facilities
G. Other (Specify under comments)
Future Utility
1. Evaluating remedial, sidetrack and/or redrill opportunities
2. Remedial well work planned
3. Sidetrack planned
4. Suspended well
5. P&A planned
6. Well has been returned to production or injection
7. Waiting for gas sales
8. Other (Specify under comments)
Page 1
2000 Endicott Reservoir Surveillance Report
Table of Contents
Page 1
Waterflood Surveillance Program:
Introduction
Page 2
Project Status Summary
Page 2
Injection Well Performance
Page 3
Waterflood Tracer
Page 4
Future Waterflood/EOR Plans
Page 4
Endicott Field Well Plat (highlighting injectors)
Figure 1
Summary Of Pertinent Data
Table 1
Reservoir Balance For Waterflood Sands
Table 2
Injection Well Data
Table 3
Waterflood Tracer Plat
Figure 2
Pressure Monitoring Program:
Introduction
Page 5
2000 Pressure Monitoring Program
Page 5
2001 Pressure Monitoring Program
Page 6
Endicott Field Well Plat (highlighting Key Wells)
Figure 3
2000 Key Well Pressure Monitoring Program
Table 4
2000 Key Well Pressure Data
Table 5
2001 Key Well Pressure Monitoring Program
Table 6
GOC Monitoring Program:
Introduction
Page 7
2000 Gas -Oil Contact Monitoring Program
Page 8
2001 GOC Monitoring Program
Page 8
Endicott Field Well Plat (highlighting Key Wells)
Figure 4
Gas -Oil Contact Monitoring Program
Table 7
Appendices:
1. Production Rate vs Time Plots
2. Cumulative Crude Production & Percent Recovered vs Time Plots
3. Cumulative Voidage & Reservoir Pressure vs Time Plots
4. Injection Well Rate & Pressure vs Time Plots
5. Endicott Oil Field Historical Key Well Pressure Data
6. Pressure vs Time Endicott Field
Endicott Oil Field
2000 Waterflood Surveillance Program
Introduction
Conservation Order 202 Rule 12 approved a field wide waterflood project for the Endicott
reservoir. The waterflood was to be implemented within two years of regular production
and a waterflood plan submitted three months before actual water injection began. By
letter, dated June 15, 1988, the plan to implement the field wide waterflood was approved
and semi-annual pressure maintenance project reports stipulated. The Endicott
Waterflood development was recognized as complete and fully operational by letter, dated
January 11, 1991, and annual waterflood surveillance reporting was approved. This
document constitutes the report for 2000.
Project Status Summary
Endicott Field production began in October 1987. From field start-up, produced gas has
been reinjected back into the existing gas cap to provide pressure support. Water injection
was initiated in February 1988, and a tertiary recovery process was initiated this past year
with the installation of a miscible injection compressor and commencement of miscible
injection in March 1999. This report summarizes the cumulative effects of pressure
maintenance since field start-up and details activities in 2000.
The Endicott Field is generally described as having three areas. The three areas are fault
blocks that are identified as the MPI (Main Production Island area), the SDI (Satellite
Drilling Island area), and the NFB (Niakuk Fault Block). Vertically there are six subzones
(3C, 3B, 3A, 2B, 2A, 1) that are the general geological subdivisions within the Kekiktuk
formation.
Initially produced gas was reinjected into the gas cap in the updip portion of MPI subzones
2A and 2B. Gas injection was extended into the MPI subzone 3A gas cap in May 1988,
and into the subzone 3C gas cap in both the MPI and the SDI areas in 1993. Reservoir
studies subsequently identified the SDI 3C area as a primary EOR target and supported
the decision to halt immiscible gas injection in that subzone. As a result, SDI 3C gas
injector 1-15/P-25 was shut-in July 1998. In October 2000 well 1-15/P-25 was placed back
on production when gas injector 2-06/J-22 was shut in with annular communication. Well
1-15/P-25 will be shut in once a workover to return 2-06/J-22 to gas injection is completed.
2
Water injection is occurring in peripherally placed injectors in all subzones in all areas of
the field with the exception of Zone 1, which is on primary depletion.
Endicott's EOR project began in March of 1999. The original EOR Phase I implementation
plan consisted of 8 water -alternating -gas (WAG) injection wells, with two wells being on MI
at any given time. This plan was based on an MI compressor design rate of 45 mmscfpd.
In reality, the maximum sustainable MI rate achieved by the compressor has been closer to
20 mmscfpd, which can be handled by one well at a time. As a result, miscible gas
injection has primarily been alternated between NFB 3A injector 2-22/L-14 and SDI 3C
injector 4-04/T-26. Produced gas samples have been collected in all of the producers
offset from these injection wells to provide a baseline for use in MI breakthrough
monitoring.
Figure 1 shows a map of the field with current well statuses including the existing water
injectors, gas injectors and oil producers. No well service additions or changes have
occurred since the last report date.
Table 1 summarizes total production, injection, and well count data for the entire pool
through December 2000. Table 2 details the reservoir balances by area and subzone
through December 2000. The NFB is included in with the MPI on Table 2 for simplicity.
Appendix 1 provides graphs of Production and Gas/Oil Ratio versus Time by area and
subzone.
Appendix 2 provides graphs of Cumulative Crude Production and Percent Original Oil in
Place (OOIP) Recovered versus Time by area and subzone.
Appendix 3 provides graphs of Cumulative Voidage and Reservoir Pressure versus Time
by area and subzone.
Infection Well Performance
Table 3 provides an overview of the performance of each of the pressure maintenance
injectors. Included in this exhibit are the start-up dates, cumulative injection volumes, and
current target injection rates.
Appendix 4 provides graphs of the injection rates, injectivity index, and wellhead pressure
versus time for each of the active injectors.
3
Waterflood Tracer
The waterflood tracer program was started in 1988. A total of 19 water injectors have been
traced: 3 in 1988, 8 in 1989, 6 in 1991, and 3 in 1996 (well 2-44/R-12 was traced with two
different tracers). The program has been very successful in identifying the progress of the
waterflood as depletion matures. Numerous interventions have been implemented on
producers and injectors to improve ultimate recovery.
Figure 2 is an Endicott well plat showing the dates and types of tracers injected and the
producing locations where the tracer has appeared.
Future Waterflood/EOR Plans
In 2001 there are no plans to trace additional water injectors. Twelve wells will be
monitored for tracer, and fifteen wells will be monitored for seawater breakthrough. The
number of wells in the 2001 tracer program is reduced from prior years as the
concentration of many of the tracers is currently below the detectable level. Samples of
produced gas will continue to be obtained in the production wells that offset the EOR
injection wells to monitor MI movement. The Endicott owners made significant preogress
in 2000 working with Nuovo Pignone, the company that designed the miscible gas
compressor, to bring its performance closer to design standards.
Reservoir pressure and gas and water movement will continue to be closely monitored
through logging, mechanical isolations, and well testing. Changing pressure maintenance
needs will continue to be met through new well drilling, converting producers to injectors,
profile modification of existing injectors, and target injection rate control. Offtake will
continue to be optimized through new well drilling, remedial work on existing producers,
and production rate control.
4
BP EXPLORATION (ALASKA) INC.
2000
WELL STATUS
ENDICOTT FIELD
FIGURE 1 SCALE: DATE:
1V= 4000 2/1/2001
Annm,...a .41,
7
«r
DUCK
1As
«r
a
..'CDTTHED
Y0191
2223
0....v.
1 ISLAND
O
I '
^ 1
.gym w.nu
SUSEONE 23
177
SN -01
«AF
O
O
ON
O
ISLAND
BLAND
O
nao
27
26
30
FS —
Nu
X
BP EXPLORATION (ALASKA) INC.
2000
WELL STATUS
ENDICOTT FIELD
FIGURE 1 SCALE: DATE:
1V= 4000 2/1/2001
Annm,...a .41,
7
«r
DUCK
1As
«r
a
3 2
I i
Q DUCK \
70 � 11
�W
..'CDTTHED
SUROMu
•
0....v.
SUB30NE3B
O
SUiONEM
^ 1
.gym w.nu
SUSEONE 23
O
SU BSONE 0
Q
O
SUMONE1
O
um —coua
TOP SAOLEIIOONR
O
FAULTS
FS —
3 2
I i
Q DUCK \
70 � 11
�W
TABLE 1
ENDICOTT OIL POOL
SUMMARY OF PERTINENT DATA
(as of December 31, 2000)
Water Injection Start-up: February 29, 1988
Miscible Gas Injection Start-up: March 24, 1999
Endicott Production since Field Start -Up:
Black Oil and Condensate (MMSTB) 392.6
NGL's (MMSTB) 15.7
Gas (BSCF) 1,283.7
Water (MMB) 442.2
Endicott Injection since Field Start -Up:
Gas (BSCF) 1,120.3
Miscible Injectant (BSCF) 4.6
Water (MMB) 788.4*
Wells in Operation:
Oil Producers 47
Gas Injectors 4
Water Injectors 19
Water -Alternating -Gas Injectors 2
Waste Water Disposal 1 ••
Total 73
Water injection volumes do not include Cretaceous injection
Cretaceous injector not shown in Exhibit 1
00 AOGCC Table 2
TABLE 2
ENDICOTT OIL POOL
RESERVOIR BALANCE FOR WATERFLOOD SANDS
Throughl2/31/2000
(Values in MMRB)
r
MPI REGION by SUBZONE
Produced Volume
3C
3B
3A 2B
2A
1
Oil
23.64
8.77
58.60 72.57
140.43
3.27
MPI TOTAL
307.28
Free Gas
36.75
9.29
101.76 133.54
217.17
3.54
502.04
Water
12_14
3.00
65_40 60_96
83_44
0.90
226.74
Total
72.5321.95
225.76 267.07
441.04
7.71
1,036.06
Injected Volumes
Gas
79.28
0.04
186.85 169.78
276.56
0.00
712.50
MI
0.00
0.04
1.87 0.00
0.00
0.00
1,91
Water
23_10
8.02
104.94 99_88
128.93
0.00
364.87
Total
102.37
8.10
293.66 269.66
405.49
0.00
1,079.29
Net Voidaae Volumes
Total
-29.84
13.85
-67.90 -2.60
35.55
7.71
-43,22
SDI REGION by SUBZONE
Produced Volume
3C
3B
3A 2B
2A
Oil
1
SDI TOTAL
50.58
14.70
31.87 84.58
41.26
0.04
223.04
Free Gas
69.95
14.30
7.43 31.03
47.34
0.09
170.14
Water
44_57
17_30
28.82 99_76
38_19
0.02
228.66
Total
165.11
46.30
68.13 215.38
126.78
0.15
621.84
Injected Volumes
Gas
61.08
0.51
0.00 0.00
0.00
0.00
61.59
MI
1.18
0.03
0.00 0.00
0.00
0.00
1.21
Water
83_61
40_22
53_14 197.43
72_54
0_00
446.95
Total
145.87
40.75
53.14 197.43
72.54
0.00
509.75
Net Voidaae Volumes
Total
19.23
5.55
14.98 17.94
54.24
0.15
112.09
FIELD TOTALS by SUBZONE
3C
3B
3A 28
2A
1
FIELD TOTAL
Produced Volume
Oil
74.23
23.47
90.48 157.15
181.69
3.31
530.32
Free Gas
106.70
23.58
109.19 164.57
264.51
3.62
672.18
Water
56_71
21_20
94_22 160.72
121.63
0.92
455.40
Total
237.6468.25
293.89 482.45
567.82
7.85
1,657.90
Iniected Volumes
Gas
140.36
0.54
186.85 169.78
276.56
0.00
774.09
MI
1.18
0.07
1.87 0.00
0.00
0.00
3.12
Water
106.71
48_24
158.08 297.32
201.47
0.00
811.82
Total
248.2548.85
346.80 467.10
478.03
0.00
1,589.03
Net Voidaae Volumes
Total
-10.61
19.39
-52.91 15.35
89.79
7.85
68.87
NOTE: Water injection volumes do not include Cretaceous
injection
00 AOGCC Table 2
Table 3
Endicott Oil Pool
Injection Well Data
Through 12/31/2000
MPI Reservoir Area
1-43/P-26
1-51/V-20
1-671T-20
1-69N-19
"3-07/N'-28
3-37/L-35
3-41/K-39
3-45/M-39
3-47/Q-35
3-49A/M-40
+ 4-02/Q-28
4-04/T-26
4-08/P-27
4-14/R-34
4-40/P-43
++ 4-48/K-43
Total
23.00
3.00
5.00
2.00
0.00
11.00
17.00
10.00
4.00
3.00
0.00
6.00
12.00
0.00
0.00
0.00
210.00
20.00 (MI)
360.00
92.08
7.54
5.42
13.31
47.61
10.50
86.24
36.00
11.45
1.88
8.48
26.50
29.89
38.10
7.09
11.85
788.17
Cumulative
Gas
BSCFG
270.71
358.61
116.02
294.61
88.37
Cumulative
Gas
BSCFG
88.37
1216.67
Note: Water injection volumes do not include Cretaceous injection.
Sidetracked in 9/97
Converted to production in 8/98
+ Converted to production in 4/96
++ SI since 4/97
Cumulative
Water
Gas
Cumulative
BSCFG
Target
Target
Water
Well Name
MBWPD
MMSCFGPD
MMBW
1-05/0-20
Dec -95
100.00
Oct -87
1-23/0-15
18.00
36.99
1-37/P-24
0.00
23.11
1-41/0-23
12.00
25.79
2-06/J-22
Jan -92
0.00
Dec -90
2-12/0-16
Jul -89
80.00
Oct -87
2-16/M-16
16.00
49.50
2-221-14
17.00
20.00 (MI)
35.26
2-24/M-12
4.00
3.49
2-34/P-14
16.00
45.40
`2-44/R-12
0.00
20.78
2-54/0-12
14.00
48.91
2-64/U-10
2.00
2.46
2-70/1-1-15
5.00
16.36
5-01/SD-07
110.00
5-02/SD-10
10.00
46.18
SDI Reservoir Area
Water
Gas
Cumulative
Target
Target
Water
Well Name
MBWPD
MMSCFGPD
MMBW
1-15/P-25
70.00
1-43/P-26
1-51/V-20
1-671T-20
1-69N-19
"3-07/N'-28
3-37/L-35
3-41/K-39
3-45/M-39
3-47/Q-35
3-49A/M-40
+ 4-02/Q-28
4-04/T-26
4-08/P-27
4-14/R-34
4-40/P-43
++ 4-48/K-43
Total
23.00
3.00
5.00
2.00
0.00
11.00
17.00
10.00
4.00
3.00
0.00
6.00
12.00
0.00
0.00
0.00
210.00
20.00 (MI)
360.00
92.08
7.54
5.42
13.31
47.61
10.50
86.24
36.00
11.45
1.88
8.48
26.50
29.89
38.10
7.09
11.85
788.17
Cumulative
Gas
BSCFG
270.71
358.61
116.02
294.61
88.37
Cumulative
Gas
BSCFG
88.37
1216.67
Note: Water injection volumes do not include Cretaceous injection.
Sidetracked in 9/97
Converted to production in 8/98
+ Converted to production in 4/96
++ SI since 4/97
Cumulative
MI
Start -Up
BSCFG
Date
May -88
Mar -95
Dec -87
Dec -95
Oct -87
Apr -93
Mar -89
2.80
May -89
Mar -95
0.08
Nov -89
Mar -89
Jan -92
1.69
Dec -90
Jul -89
Oct -87
Jan -88
Cumulative
MI
Start -Up
BSCFG
Date
Jun -93
Apr -89
Apr -93
May -99
Dec -90
Apr -89
Aug -98
Apr -89
Sep -88
0.08
Mar -95
Apr -99
May -88
1.69
Mar -90
May -93
Oct -89
Oct -92
Dec -90
4.57
00 AOGCC Table 3
ENDICOTT FIELD
UJGa C G3G� o0 oOD T pAt PQ pv(UO PAA
NIAKUK�FAULLT
/ v LEL
11.0
*s
MIDFIELD FAULT
or ry
OPROD WELL
LO INJ/PREVIOUS PROD
INJ WELL
P&A WELL
�-_� ]A J30
22
�Y+ 2-a6 � -
IL`�tY
3-19 e�L9
FI -28
r.
- SDI *D,-0,,
_ ar %33
4-34
(1-06
, 4.42
P36
TYPES
OTritium
1988 Program
® Ammonium
0
Colbalt-57
Thiocynanate (SCN)
•
Mg & SO4
• Sodium Benzoate (P-14)
OSodium
22
• Potassium Hexacyanocobaltate
OCarbon-14/SCN
Tmcer
O Carbon-14APA
OColbalt
60
CobaN60
A,
s
W
Y,c
M.Mlllholland 2129/00
FIGURE 2
1988 Program
Well
Tracer
1-37/P-24
Colbalt-60
4-02/Q-28
Carbon-14/SCN
5-02/SD-10
TriNum
1989 Program
Well
Tmcer
2-18/1-16
Carbon-iMSCN
2-22A-14
CobaN60
2-44/R-12
Tritium
2-70/U-15
QDlbaft60
3-07/N-28
Colbett-57
341/K39
TriNUm
3-45/M39
Colbaft-60
4-14/R34
Carbon-14/SCN
1991 Program
Well
Tracer
169At-19
Carbon-14/SCN
4-04/r-26
Tritium
4484(43
Carbon 14/SCN
143P-26
Ammonium Thiocyanate
234/P-14
Ammonium Thiocyanate
244/R-12
Sodium Benzoate
s
W
Y,c
M.Mlllholland 2129/00
FIGURE 2
1996 Program
Well
Tracer
1-23/0-15
Sodium 22
4-0a/P-27
Carbon-14APA
440/P-43
Potassium Hexacyanacebalte
s
W
Y,c
M.Mlllholland 2129/00
FIGURE 2
Endicott Oil Field
2000 Pressure Monitoring Key Well Program
Introduction
A pressure monitoring key well program was submitted to and approved by the AOGCC in
Administrative Approval No. 202.5. This program supersedes the requirements of
Conservation Order 202, Rule 6(c), and complies with Conservation Order 202, Rule 6(d).
The pressure monitoring program key wells were chosen to provide a real coverage of
reservoir pressure in each of the major subzones in the two production areas of the
reservoir. Historically, the Key Well Program has included at least two points of pressure
measurement for each of the producing subzones, one from each MPI and SDI area, to
ensure that a valid picture of reservoir pressure behavior can be drawn.
Seventeen wells were identified as key wells to track pressure variation within the five
major subzones in each of the two main producing areas of the reservoir. Changes have
been made through time as reservoir and well characteristics changed in order to provide
representative data. Much more reservoir pressure data, other than the key well data, is
gathered to address specific well and reservoir surveillance needs.
Figure 3 is an Endicott well plot showing the location of the seventeen 2000 Key Well
reservoir pressures.
2000 Pressure Monitoring Program
Table 4 summarizes the wells included in the Proposed 2000 Key Well Program. The
2000 program consisted of seventeen key wells. Table 5 summarizes the key well
pressure data gathered in 2000. The zone 1 pressure was observed in Well 1-09A/L-21
rather than the proposed well 1-25/K-22 due to operational concerns.
Appendix 5 lists, by subzone, all current and former key wells with the reservoir pressures
obtained since field start-up. These pressures are adjusted to a datum depth of 10,000
feet TVDSS, as is customary in our state pressure reporting.
Appendix 6 plots, by subzone and area, key well reservoir pressures along with all other
reservoir pressure surveys. Generally speaking there is good agreement between the key
5
well reservoir pressures and other pressure gathered around the field. There are a few
exceptions where wells are in small pressure isolated regions.
2001 Pressure Monitoring Program
The Endicott Key Well Pressure Monitoring Program has been successful in establishing
and monitoring pressure trends within each of the major subzones. Although changes in
well service and configuration occasionally necessitate changes to the pressure monitoring
program in order to obtain representative data, BPX recommends no changes in the 2001
program.
Table 6 summarizes the 2001 Endicott key well pressure monitoring program proposal.
As in past years, the amount of static pressure data obtained annually will likely exceed the
seventeen wells included in the proposed 2001 Key Well Pressure Monitoring Program. At
the operators discretion, representative reservoir pressures gathered in other wells during
2001 might be substituted for the proposed key wells to minimize production impacts or for
operational necessity. As the field matures, we will be increasingly challenged with
managing this need for additional pressure data while minimizing the cost and associated
production impacts.
n.
27
29 0
V0191
r ISLAND
•
SA TA 310
x \
L t4 � � r
x\
BP EXPLORATION (ALASKA) INC.
2000 KEY WELL
RESERVOIR PRESSURE DATA
ENDICOTT FIELD
FIGURE 3 SCALE: DATE:
1 — 4000' 2/29/00
lnnnhnrri Ginn
x
30
7
0
T'
32 33
3 2
sP
x
x
x ,
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1s2
1999 KEY WELL PRESSURE MONITORING PROGRAM PROPOSAL
ENDICOTT FIELD
TABLE 4
Well Area Subzone(s) Comments
1-25A/K-22 MPI Z1
1-01/J-19
Niakuk
2A
2-18/L-16
Niakuk
3A
2-26/N-14
Niakuk
313/3C Commingled pressure
1-33B/L-24
MPI
2A
1-61/Q-20
MPI
26
Single zone high angle well
1-39/P-17
MPI
3A
Lower 3A monitor point
2-42/P-13
MPI
3B
Lower 3A monitor point
2-52/S-14
MPI
3B/3C
Commingled pressure
2-58/S-09
MPI
3C
Eastern area
3-39A/1-37
SDI
2A
3-33/K-37
SDI
2B
3-35/L-36
SDI
3A
Upper 3A monitor point
4-32/K-38
SDI
3A
Lower 3A monitor point
3-23/N-32
SDI
3B
4-18/S-30
SDI
3C
Eastern area
1-57/R-23
SDI
3C
Western area
Notes on changes between the 1999 and 2000 proposed programs:
00 AOGCC Table 4
2000 KEY WELL PRESSURE MONITORING PROGRAM DATA
ENDICOTT OIL FIELD
TABLE 5
Well Area Subzone(s) Pressures
1-09A/L-21 MPI Zi 2508 psia
1-01/J-19
Niakuk
2A
4308 psia
2-18/L-16
Niakuk
3A
4156 psia
2-26/N-14
Niakuk
313/3C
5896 psia
1-33B/L-24
MPI
2A
4317 psia
1-61/Q-20
MPI
26
4548 psia
1-39/P-17
MPI
3A
4724 psia
2-42/P-13
MPI
313
5156 psia
2-52/S-14
MPI
313/3C
5179 psia
2-58/S-09
MPI
3C
2685 psia
3-39A/1-37
SDI
2A
4319 psia
3-33/K-37
SDI
213
4699 psia
3-35/L-36
SDI
3A (Upper)
5178 psia
4-32/K-38
SDI
3A (Lower)
4666 psia
3-23/N-32
SDI
313
4940 psia
4-18/S-30
SDI
3C
4375 psia
1-57/R-23
SDI
3C
4270 psia
DATUM: 10000' TVDss
Note: Well 1-09A/L-21 was substituted for 1-25/K-22 in original
program due to operational difficulties
00 AOGCC Table 5
2001 KEY WELL PRESSURE MONITORING PROGRAM PROPOSAL
ENDICOTT FIELD
TABLE 6
Well Area Subzone(s) Comments
11 1-25A/K-22 MPI Z1 11
1-01/J-19
Niakuk
2A
2-18/L-16
Niakuk
3A
2-26/N-14
Niakuk
313/3C Commingled pressure
1-33B/L-24
MPI
2A
1-61/Q-20
MPI
2B
Single zone high angle well
1-39/P-17
MPI
3A
Lower 3A monitor point
2-42/P-13
MPI
313
Lower 3A monitor point
2-52/S-14
MPI
313/3C
Commingled pressure
2-58/S-09
MPI
3C
Eastern area
3-39A/1-37
SDI
2A
3-33/K-37
SDI
2B
3-351-36
SDI
3A
Upper 3A monitor point
4-32/K-38
SDI
3A
Lower 3A monitor point
3-23/N-32
SDI
313
4-18/S-30
SDI
3C
Eastern area
1-57/R-23
SDI
3C
Western area
No change from the 2000 proposed program.
00 AOGCC Table 6
Endicott Oil Field
2000 GOC Monitoring Key Well Program
Introduction
A GOC (Gas - Oil Contact) Monitoring Key Well Program was submitted for the Endicott
Field in October 1988, one year after field start-up in accordance with AOGCC
Conservation Order 202, 9(c). At that time, BP Exploration sought, and received a waiver
(Administrative Approval Order 202.5) from the State of Alaska, to initiate the key well
program for Endicott on a subzone basis for each of the three distinct reservoir
development areas of the field. Administrative Order No. 232.1 provided an exemption for
key well GOC monitoring in Sections 1, 3, 7, 9, 10, and 35 of the field as being outside a
real gas cap limits of the reservoir.
The key well program for Endicott is based on the understanding of a limited ability to
monitor fieldwide gas cap movement. A scarcity of wells and limited lateral offset from gas
severely restricts the use of time lapse cased -hole logging as a viable toot to predict gas
movements at Endicott. It is recognized that narrow hydrocarbon corridors caused by a
relatively steep 6 degree structural dip combined with sands separated by thick laterally
continuous shales promotes under -running as a common gas movement mechanism. In
addition to the continuous shales that separate the reservoir into six vertically isolated
subzones, major east -west trending fault offsets provide either lateral hydraulic isolation or
partial pressure communication between the three main Endicott development areas.
Key wells were designed to focus on the 3A and 2B subzones, the more massive high
quality sands where more regional GOC effects could be noted. Key wells to monitor gas
movement in the 2A (MPI), 3B, and 3C are not practical due to the close proximity to gas
and complex stratigraphy (shaliness), respectively. In these cases, it is highly doubtful time
lapse logging would provide meaningful data with respect to regional GOC movements.
Six key wells were originally proposed and approved for GOC monitoring: 1-01/J-19,
1-09/J-18, 1-27/P-20, 1-29/M-25, 2-04/M-19, 3-01/N-29. Waivers from continued GOC
monitoring have been received for three of the key wells due to gas influx from maturing
reservoir depletion. Following are the wells no longer monitored:
• 1-09/J-19 : 3A gas under -run.
• 2-04/M-19 : 2B gas under -run.
• 3-01/N-29 : Completed as 3A & 2B producer after waterflood response.
7
Figure 4 is an Endicott well plot showing the six GOC Monitoring Program wells.
2000 GOC Monitoring Program
During 2000, a total of 18 cased - hole pulsed and compensated neutron logs (PNL / CNL)
were acquired, including the three key well surveys. These logs are routinely used for
reservoir surveillance and diagnosing well problems in order to develop reservoir
management plans and remedial interventions. Following is a list of the wells from which
neutron logs were acquired during 2000:
Well
Location
Well
Location
1-01/J-19
2-14/0-16
1-27/P-20
2-36/0-14
1-29/M-25
2-44A/Q-11
1-31/M-21
3-01/N-29
1-39/P-17
3-27/M-33
1-47A/M-20
3-31/K-32
1-61/Q-20
3-41/K-39
1-65/N-25
4-10/M-28
2-06/J-22
I
4-32/K-38
18 Wells Total
Key Wells
Table 7 details the history of pulsed neutron log observations in the six GOC key wells,
including the 2000 observations. Three of the six original key wells continue to provide
useful gas -oil contact movement information, as gathered through time lapsed cased hole
neutron logging. Note the use of the CNL is precluded in all wells except 1-27/P-20 due to
size restrictions of down -hole completion equipment employed at Endicott. The table also
identifies GOC movement and gas influx by under -running major shales within Subzones
3A and 2B.
2001 GOC Monitoring Program
The Endicott GOC Monitoring Key Well Program has been successful in establishing
baseline and repeat PNL / CNL surveys to monitor and document rates of gas cap
movement and gas under -runs in the six key wells. It appears that the gas cap itself has
not moved significantly since about 1995 in Subzone 2B & 3A in the MPI. In the Niakuk
H
Fault Block in well 1-01/J-19, Subzone 2B has been re -saturated with oil and has remained
so since 1996. This target was perforated in 2000 after obtaining permission from the
AOGCC.
BPX recommends that the 2001 GOC Key Well Program continue with the three remaining
key wells: 1-01/J-19, 1-27/P-20, 1-29/M-25. As in past years the number of GOC
monitoring logs taken at Endicott exceeds the number in the GOC Key Well Program. Due
to mature reservoir depletion BPX proposes, in lieu of a Key Well Program, the option of
continuing the GOC monitoring program with a specified number of GOC monitoring logs to
be taken in wells at operator discretion to address localized gas management issues.
Production logging and down -hole mechanical isolation of gas prone intervals has also
provided a means to monitor gas influx. Together, these tools constitute an effective
means to monitor gas movement at Endicott.
9
'(0191
LAN
22 ISLAND
O 1988-00 GOC KEY WELLS
23 4 '
1988-94 GOC KEY WELLS
NMI ,
o " ,,, ((( • 1988-91 GOC KEY WELLS
SOLUTION eN-01
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BP EXPLORATION (ALASKA) INC.
r e / X '
2000 ENDICOTT " ��_ o DUCK 11 •"
GOC MONITORING PROGRAM t0
4
ENDICOTT FIELD
o /
SCALE: DATE: DUCK 18.
FIGURE 4 „ _ 162
1 — 4000' 2/1/01 DUCK
4000bord.dgn
WELL
GOC SUBZONE
DATE OF BASELINE
MONITOR SURVEYS
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
1-01/J-19 1-091J-18
2B 3A
2 -Jan -90
14 -Jan -88
NM, GUS (2A)
NM
13 -Feb -91
1 -Feb -89
NM, GUS (2A)
GCX (4'),GUR(2B5)
31 -Jan -91
14 -Feb -90
NM, GUS (2A)
GCX (10'), GUR(2B5)
29 -Mar -93
24 -Feb -91
NM, GUS (2A)
GCX (7'), OUR (285)
28 -Jul -94
16 -Mar -92
NM, GUS (2A)
GCX (5'), OUR (2B5)
24 -jun -95
22 -Aug -93
NM, GUS (2A)
GCX(2'), GUR(2B5)
18 -Jul -96
313 -Jul -94
GCX (-30' in 213), GUR (ZA)
NM, GUS (265)
10 -Aug -97
Waiver -No Monitor Logs
GCX (-30' in 213), GUR (2A)
Well sidetracked to new location
27 -Sep -98
GCX (-30' in 213), GUR (2A)
13 -Mar -99
GCX (-30' in 2B), GUR (2A)
16 -Aug -00
GCX (-30' in 20), GUR (2A)
NM = NO GAS CAP MOVEMENT
GUS =GAS UNDERRUN (STRAT. SEC.)
GCX = GAS CAP EXPANSION (FEET TVD)
ENDICOTT OIL POOL
GAS OIL CONTACT MONITORING PROGRAM
STATUS REPORT- 12/3112000
1-27/P-20
3A
21 -Feb -87
NM (OHCNL)
9 -May -88
NM
4 -Aug -88
NM, GUS (2B3)
12 -Apr -89
NM,GUR (283)
17 -Jun -90
GCX(9'), GUS (2B3)
4Jul-91
GCX (14'), GUS (283 / 3A2)
13 -Jun -92
GCX (23'), GUR (2133r02)
26 -Jun -93
GCX(28'), GUR(3A2)
31 -Jul -94
GCX (30'), GUR (263)
27 -Mar -95
GCX (30'), GUR (263)
19 -Jul -96
GCX (31'), GUR (283)
13 -Jul -97
GCX (31'), GUR (2123)
25 -Sep -98
GCX (30'), GUR (263)
12 -Mar -99
GCX (30'), GUS (2B3)
10 -Jur oo
Note: obtained neutron log for reservoir survellaince for Infill drilling program
1-29/M-25
28
3 -Feb -88
GCX (I T)
8 -Aug -88
GCX (33')
S -Aug -89
GCX (43')
5 -Sep -90
GCX (48')
25 -Mar -91
GCX (53')
17 -Mar -92
GCX (72')
24 -May -93
GCX(92'), GUR(2A3)
29 -Jul -94
GCX (97'), GUR (2A3)
26 -Jun -95
GCX (97'), GUR (2A3)
18Jul-96
GCX (97'), GUS (2A3)
1-Au9-97
GCX (95?), OUR (2A3)
25 -Sep -98
GCX (94'), GUS (2A3)
12 -Mar -99
GCX (94'), GUR (2A3)
14 -Aug -00
GCX (901, GUR (2A3)
2-04/M-19
26
1 -Mar -88
GCX (25')
20 -Mar -89
GCX(35'), OUR (2B2)
16 -Jun -90
GCX(4'), GUS (2A3)
29Jun-91
GCX (NM), GUS (2A3)
14 -Jun -92
GCX (2'), OUR (2A3)
25 -Jun -93
NM, GUS (2A3)
9 -Jul -94
NM, GUR (2A3)
'11 -Aug -97
GCX (18' in 2B), GUS (2A3)
Waiver -No Mm or Lags
3-01/N-29
3A/2B
19 -Feb -89
NM
12 -Feb -90
NM
28 -Feb -91
NM
Waiver -No Monitor Logs
00 AOGCC Table 7
I,
1
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1987 8 89 90 91 92 93 94
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5000
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BP EXPLORATION, ENDICOTT FIELD
1 r5
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10000
m
1000
10`
101
100 m
L
BP EXPLORATION, ENDICOTT FIELD
1C
10
10
ZONE:K2A
PRODUCTION - Niakuk Region
Black Oil Rate (CD) ( bbl/d
Gas/ Oil Ratio( cf/bbI
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BP EXPLORATION, ENDICOTT FIELD
150
1200(
KI
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3000
MPI Region ZONE: K3C
CUMULATIVE PRODUCTION & %OOIP
50
40
U
a
30p
O
U
20
/0,0
10
0
1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
400(
3000
2000
1000
MPI Region
ZONE: K3B
CUMULATIVE PRODUCTION & %OOIP
5(
4C
30
20
10
0
1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
50
4000C
30000
20000
10000
0
MPI Region ZONE: K3A
CUMULATIVE PRODUCTION & %OOIP
1987 88 89
90
91
92
93
94
95
96
97
98 99 2000
BP EXPLORATION, ENDICOTT FIELD
MPI Region ZONE: K2B
CUMULATIVE PRODUCTION & %OOIP
50000
sc
40000
40
9 30000
�
30
O
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U
m
E
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20
10000
ID Ar
10
0
n
ludl au 89 9u 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
10000(
8000(
6000(
40000
990
MPI Region ZONE: K2A
CUMULATIVE PRODUCTION & %OOIP
50
40
30
20
Orr
10
n
1567 00 69 9u 91 92 93 94 95 96
a
a
0
O
U
97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
L=L
1500
1000
500
0
1967
MPI Region ZONE: ICI
CUMULATIVE PRODUCTION & %OOIP
88 89 90 91 92 93 94 95 96 97 98 99 2000 V
BP EXPLORATION, ENDICOTT FIELD
50C
4000(
3000C
NMI]
10000
SDI Region ZONE: K3C
CUMULATIVE PRODUCTION & %OOIP
i
5(
4C
09 30
20
10
n
aoi oo as 9u 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
20
16000
Z 12000
O
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U
N
m
E
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8000
4000
0
SDI Region ZONE: K3B
CUMULATIVE PRODUCTION & %OOIP
C0
1111011111m
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roi 00 as 9V 97 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
SDI Region
ZONE:K3A
CUMULATIVE PRODUCTION & %OOIP
25000
50
20000
40
15000
30
10000----
5000--
0
0000 50000
0
1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
100c
8000(
6000(
40000
20000
SDI Region ZONE: K2B
CUMULATIVE PRODUCTION & %OOIP
50
40
U
Q
30 'p
O
U
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20 I
10
0
1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
SDI Region ZONE: K2A
CUMULATIVE PRODUCTION & %OOIP
50000 —
40000
30000
20000
10000
0
.3o=
40
U
a
30 O
O
U
!0
iaat as a9 9u 91 92
93
94
95
96
97
98 99 2000
BP EXPLORATION, ENDICOTT FIELD
5u
40
nel
20
10
0
1987 88
SDI Region ZONE: Kl
CUMULATIVE PRODUCTION & %OOIP
89 90 91 92 93 94 95 96
5.0
4.0
U
CL
a
3.0 0
O
U
gut
J.0
97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
Niakuk Region ZONE: K3C
CUMULATIVE PRODUCTION & %OOIP
5000
4000
3000
.a
O
Y
U
lC
m
E
U
2000
/100
1000
0
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40
0
Vol as a9 9u 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
5001
400(
300(
2000
1000
Niakuk Region ZONE: K3B
CUMULATIVE PRODUCTION & %OOIP
5(
I
4C
30
20
10
1987 88 69 90 91 92 93 94 95 96 97 98 99 2000 0
U
Q
n
0
O
U
BP EXPLORATION, ENDICOTT FIELD
20001
16001
1200(
4000
Niakuk Region ZONE: K3A
CUMULATIVE PRODUCTION & %OOIP
50
1
40
I
30
20
10
0
1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
Niakuk Region ZONE: K2R
CUMULATIVE PRODUCTION & %OOIP
7500
6000
a 4500
U
Y
U
_N
m
E
:3
U 3000
1500
0
.3i�
40
MIIIIIIIIIIII
0
BP EXPLORATION, ENDICOTT FIELD
Niakuk Region ZONE: K2A
CUMULATIVE PRODUCTION & %OOIP
30000
25000
20000
O 15000
Y
U
N
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E
7
U
10000
5000
1
0
f
50
LS
.0
0
94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
BP EXPLORATION, ENDICOTT FIELD
REGION: MPI ZONE: K3C(17)
CUMULATIVE-VOIDAGE (injection -production)
35
---------------------------------
---r 6000
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2500
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1987 88 89 90 91 92 93 94 95 96 97
98 99
1500
2000
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0
m
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C 2
70
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I I I I I
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1987 88 89 90 91 92 93
5500
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7
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L
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94 95 96 97 98 99 2000 3750
111.1 BP EXPLORATION, ENDICOTT FIELD
K3A(14)
120
110
-----� - ;-
------
73
100
--------'*
mI
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90
--------`-------- '-------------------
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4900
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60
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50
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------
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5000
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4900
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`' -----'--------;-4800
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4100 NL Ir
---------IL 4000
-------- 3900
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95 96 97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
WE
REGION: MPI ZONE: K2A(21)
25� CUMULATIVE VOIDAGE (injection -production)
------;---------------------------------------------------------------
20
15
10
1�
------- ------------------------------ --------- --------
------ - 5500 'CU
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1987 86 89 90 91 92 93 94 95
----'--------;-4000
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96 97 98 99 ' 2000
2500
2000
BP EXPLORATION, ENDICOTT FIELD
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15
r r _ ------ ---------------- -----------
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10
2500
1987 88 89 90 91 92 93 94 95 96 97 98
99 2000
BP EXPLORATION, ENDICOTT FIELD
REGION: SDI ZONE: K3C(26)
5 CUMULATIVE VOIDAGE (injection -production)
•u ; ♦ ; •♦ ,
0
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1987 88 89 90
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91 92
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91 92
93
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2000
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94 95 96 97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
_8
----i'-'------ ------ I ------------------ ---i'--------------------------------- 3000
-12
1987 88 89
♦
-- - - - -- I------- i------- F - --
90 91 92 93 94 95 96 97 1 98
--------- 2500
jr 2000
99 2000
BP EXPLORATION, ENDICOTT FIELD
REGION: SDI ZONE: K3B(29)
CUMULATIVE VOIDAGE (injection -production)
2
I I I I I 1--------- --------- --------------i ------------
r------------------- 5500
L
0
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1987 88 89
♦
-- - - - -- I------- i------- F - --
90 91 92 93 94 95 96 97 1 98
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jr 2000
99 2000
BP EXPLORATION, ENDICOTT FIELD
R
REGION: SDI ZONE: K3A(23)
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(injection -production)
I
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I
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5500
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1987 88 89 90 91
92 93 94 95 96 97 98
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99 ' 2000
4000
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Ai
I
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I
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1987 88 89 90 91
92 93 94 95 96 97 98
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4000
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BP EXPLORATION, ENDICOTT FIELD,
0
►R
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-30
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CUMULATIVE VOIDAGE (injection-produi
1987 ' 88 89 90 91 92
93
94
95 96
•
-------------------------------------- 5000
00
Q
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F-
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4
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L
W
L
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•:
d
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4000
97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
--------------------------
•i
1987 ' 88 89 90 91 92
93
94
95 96
•
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00
Q
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F-
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4
co
L
W
L
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4000
97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
REGION: SDI ZONE: K2A(16)
----CUMULATIVE VOIDAGE (injection -production)
0 ----------- ----------------- 5000
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-------- ----- -r -------' -------- ------ ----
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100
1987
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88 89 90 91
3000
92 93 94 95 96 97 98 99 ' 2000
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BP EXPLORATION, ENDICOTT FIELD
m
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0
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99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
REGION: NIAK ZONE: K3B(4)
CUMULATIVE VOIDAGE_(injection-production)
4.0
3.0 -------- ;--------- `--------- --------- '--------- 1 --------------- ----- 00
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1987 88 89
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94 95 96 97 98 99 2000 2000
BP EXPLORATION, ENDICOTT FIELD
-35
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1987 88
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89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
10
5
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1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
REGION: NIAK ZONE: K2B(6)
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1987 88 89 90 91 92 93 94 95 96 97 98 99 2000
BP EXPLORATION, ENDICOTT FIELD
ml
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1987 88 89
90 91 92
93 94 95 96
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97 98 99 2000
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W
0
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------------------------
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r
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L
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94 95 96 97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
{i
------
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101987 88 89 90
Fy ______ _________i__ ______-I______
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4000
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94 95 96 97 98 99 ' 2000
BP EXPLORATION, ENDICOTT FIELD
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ML
I I I I I I I
I I I I I I SIM
I I 1 1
Ts
I I I I E
I I I I I
I I I I 1 1
I I I I I
I I I I I
I I I 1
I I I I I I I
I I
I I r I I
I I I I
I I I
1 1 I 1 I I
I I I I I
1 1 1 1
I I
I I I I
I I I I I
I I 1
I I I
I I I i I
I I I I I
CIN
I I I I prp
1 I I I I I
I I 1 I I I
I I y I I
I I I I I I
PTA
I I I I I I
INJ INDEX
Water Injection Volume (bbl)
OO O O O
O O O O O O O
N
V
O
m
�o
0
N
w
A
N
W
(O
V
m
0
0
O O O O p O
O O O O O
Wellhead Pressure (psia)
D
G G
M D
= m
M
M 70
a z
o M
m m
M
� O
CO z
C G
17 p
M r
^ C
w M
v
1
V
1
1
1
t
O O O O p O
O O O O O
Wellhead Pressure (psia)
D
L
i
O
W
X a
O
D
O
z
M
c
O C
O
A
T
Fn
r
v
INJ INDEX
N W A
O O O O O
Water Injection Volume (bbl)
0 0 o a o 0
o O O O O O
O O O O O O O
m
m
0
N
W
N
m
V
m
N
O
O O O O O O O
O O O O O
Wellhead Pressure (psia)
Elm=
r.
M
-M
IM"
CO
z
METERM
IME
MENNEN
O O O O O O O
O O O O O
Wellhead Pressure (psia)
]NJ INDEX
Water Injection Volume (bbl)
N W A n m
O O O O O O O
O t]1 N N W
O O O o o O
Wellhead Pressure (psia)
G <
m D
= m
m �
D z
o
m m
O
<n z
C c
M O
M r
^ c
a �
�• m
v
Cr
t--5
-
O t]1 N N W
O O O o o O
Wellhead Pressure (psia)
[NJ INDEX
Water Injection Volume (bbl)
0 0 0
0 0
0 0 0 0 0 0 0
a
N
W
A
rn
V
m
0
0
Wellhead Pressure (psia)
INJ INDEX
Water Injection Volume (bbl)
0
0 0 0 0 0 0
T
M - - N N W
O O O O O O
Wellhead Pressure (psia)
INJ INDEX
Water Injection Volume (bbl)
0
o a o o a o
o a o 0 0 0 0
V
m
m
0
2
Wellhead Pressure (psia)
D 0
G <
m a
r �
= m
m 70
a z
o
� m
CO O
(Y) z
c <
O
M r
^ c
N M
m
v
I
1
Wellhead Pressure (psia)
D 0
I
INJ INDEX
Water Injection Volume (bbl)
0 0 0 0 0
0
0 00 0 0 0
C O O O O O O
V
CJ
m
(O
O
m
N
w
A
N
O1
V
m
V7
O
O
Wellhead Pressure (psia)
■■■■I
T
■■■■I
•
CO
z
•
!I
y
�t
Wellhead Pressure (psia)
i
i
4
Y
C
W tl
M
x a
r
O
1
O
z
M
v �
0
A
n
Fn
r
v
INJ INDEX
Water Injection Volume (bbl)
N W ? (T W
O O O O O O
O O O O O o O
V
CJ
O
N
w
A
m
V
ip
8
0
Wellhead Pressure (psia)
7
V
■■■■I
�
■I
CO
z
0
..
lllll�
Wellhead Pressure (psia)
7
V
E
W
0
M
% 4
0 C
r
O
D
� u
O
Z
M
Z C
C
C)
0
1
n
M
r
INJ INDEX
0 0 0 0 0
O
q
w
9
N
O
J
N
C;
O
C
Water Injection Volume (bbl)
Wellhead Pressure (psia)
]NJ INDEX
Water Injection Volume (bbl)
N W A tP W
O O O O O O
O O O O O O O
O
OD
V
N
m
0
M
O O O O O
Wellhead Pressure (psia)
G
G
m
D
=
m
m
�
a
z
v
�
n
CO
o
(1)
z
C:
70
M
O
r-
-
c
a
`�•
m
�
m
Cr
i
I
O O O O O
Wellhead Pressure (psia)
C
W 4
x
0
0
Z
Z c
g €
0
1
n
Fn
r
v
INJ INDEX
a o 0 0 0
Water Injection Volume (bbl)
0 0 0 0 0
0 0 0 0 o S
0 0 o S a o 0
J
m
O
Wellhead Pressure (psia)
MAIN
Wellhead Pressure (psia)
i
c
W
M
X 4
0 C
r
O
D
� u
O
Z
Z "c
v
0
1
n
Fn
r
v
INJ INDEX
G
Water Injection Volume (bbl)
0 0 0 0 0 0
0 0 0 0 0 0
o 0 0 0 0
Wellhead Pressure (psia)
CO
O
J
Z
N
w
::
O
INJ INDEX
Water Injection Volume (bbl)
0 0 0 0 0 0
O o 0 0 0 0 0
V
m
a
0
T
Wellhead Pressure (psia)
m D
r �
= m
m �
D Z
O �-
.9 m
O
cn z
c <
O
m r
^ c
a �
'm M
6
I
I
I
Wellhead Pressure (psia)
INJ INDEX
O
Water Injection Volume (bbl)
N W A
O O O 00 O
M
Wellhead Pressure (psia)
w
A
INJ INDEX
_ Water Injection Volume (bbl)
O O O O N O
O O
O O O O p O
13
Wellhead Pressure (psia)
INJ INDEX
0 0 0 0 0
MI Injection Volume (mscf)
Water Injection Volume (bbl)
O O O O CO
O O O O O
Wellhead Pressure (psia)
I
m .D
cim
v0-
--I?
Z
cn 00
c C<
M m0
^c
w M
Q
R
M1
N
Z
3
N
n
_N
O O O O CO
O O O O O
Wellhead Pressure (psia)
INJ INDEX
O O O O O
Water Injection Volume (bbl)
0 0 0 0 0 0
0 0 o S o 0
0 0 0 0 0 0 0
V
m
0
N
w
A
N
W
f0
J
m
N
O
Wellhead Pressure (psia)
A
A a
M
M 7D
o C-
M
M
M o
cn z
C
3 o
M
^ c
o g
SD m
SD
v
C7
i
I
1
O N
O
N
O o O
N W
O o
Wellhead Pressure (psia)
INJ INDEX
0 0 0CO 0 0
Water Injection Volume (bbl)
N w a cn m
0 0 0 0 0 0
0 0 0 0 0 0 0
m
m
V
m
m
m
m
m
0
m
N
w
A
N
m
m
co
V
m
m
N
O
O
•+ � o O O
Wellhead Pressure (psia)
<
G
m
m
D
O
�
�
Z
�
m
CO
N
C
m
O
Z
O
r
^
C
m
m
6
a
i
I
1
1
I
•+ � o O O
Wellhead Pressure (psia)
I
INJ INDEX
MI Injection Volume (mscf)
Water Injection Volume (bbl)
0 0 0
O p O
0 0 0 0 0 0 0
0
N
W
N
W
V
m
0
0
O O O O O O
O O O p p
Wellhead Pressure (psia)
■■■■
■■■■M
,
0-
05
M KO
GL M
O O O O O O
O O O p p
Wellhead Pressure (psia)
i
i
C
V
x
0
0
z
M 2
v
0
0
A
n
Fn
r
v
INJ INDEX
Water Injection Volume (bbl)
iv w A cn m
0 0 0 0 0 0
0 0 0 0 0 0
W
0
N
w
A
N
m
V
m
0
O P N N w
01 M
O O O O O O
Wellhead Pressure (psia)
u6
MEN
E*�i
EM
CnOWNER
�lr
O P N N w
01 M
O O O O O O
Wellhead Pressure (psia)
u6
INJ INDEX
O
Water Injection Volume (bbl)
O O O 00 O
I
Wellhead Pressure (psia)
INJ INDEX
Water Injection Volume (bbl)
N W A Ui O1
O O 00 O O O O
Wellhead Pressure (psia)
G <
m a
r �
= m
M
D Z
O M
� m
M
� O
(n z
C <
X O
M r
^ c
a �
w M
Q
i
I
i
Wellhead Pressure (psia)
I
i
i
4
C
U
C
U
M
x
m a
r
O
D
O
Z
M
v
65
O
n
Fn
r
v
INJ INDEX
Water Injection Volume (bbl)
0 0 0 0 0 0
V
m
m
m
0
N
N
w
A
N
U)
m
U)
V
m
m
0
S
Wellhead Pressure (psia)
m
=
D
m
m
D
O
�
70
Z
�
m
cmn
fn
c
m
^
y
w
O
Z
c
O
r
c
m
Cr
v
1
i
I
Wellhead Pressure (psia)
INJ INDEX
O O O O O
O
Water Injection Volume (bbl)
O O p A (T
O
O O O O Q O
O O C
Wellhead Pressure (psia)
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE WELL
11987
9/5/1987 1-47/01-21
9/5/1987 1-47/0-21
10/1/1987 1-09/J-18
10/1/1987 1-09/J-18
11/10/1987 3-01/N-29
11/22/1987 1-09/J-18
12/5/1987 3-01/N-29
12/12/1987 1-47/01-21
12/12/1987 1-47/0-21
1988
1/19/1988 1-35/0-25
1/27/1988 2-52/S-14
1/27/1988 2-52/S-14
1/28/1988 1-29/M-25
2/2/1988 1-09/J-18
2/3/1988 2-62/Q-17
2/15/1988 2-08/K-16
2/15/1988 2-08/K-16
2/15/1988 2-08/K-16
2/28/1988 3-47/Q-35
3/1/1988 3-33/K-37
3/1/1988 3-33/K-37
3/27/1988 3-01/N-29
3/30/1988 3-35/L-36
4/22/1988 1-35/0-25
5/25/1988 3-05/0-29
6/5/1988 1-55/R-25
6/5/1988 1-55/R-25
6/9/1988 1-29/M-25
6/10/1988 1-35/0-25
6/11/1988 3-01/N-29
6/11/1988 2-62/Q-17
6/16/1988 2-26/N-14
6/16/1988 2-26/N-14
6/21/1988 3-01/N-29
6/29/1988 2-26/N-14
6/29/1988 2-26/N-14
7/23/1988 3-05/0-29
7/27/1988 2-26/N-14
7/27/1988 2-26/N-14
7/30/1988 4-26/0-34
7/30/1988 4-26/0-34
7/30/1988 4-26/0-34
7/30/1988 4-26/0-34
7/30/1988 4-26/0-34
9/4/1988 3-11/M-30
3C 3B
4897
4897
4631
4631
4784
4784
2B I 2A Z1 1111 3C
NO
4809
4767
4788
4736
4800
4750
4789
4758
4726
4742
4671,
4600
2B I 2A I Zi
4839
4696
44661
4569
4514
4551
4460
4800
4800
4600
4497
4590
4528
4850
4400
4497
4494
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE WELL
9/4/1988 3-11/M-30
9/4/1988 3-11/M-30
9/4/1988 3-11/M-30
9/4/1988 3-11/M-30
9/18/1988 4-26/0-34
10/7/1988 3-11/M-30
10/8/1988 2-26/N-14
10/8/1988 2-26/N-14
10/10/1988 1-09/J-18
10/11/1988 3-05/0-29
10/13/1988 2-14/0-16
10/20/1988 2-08/K-16
10/20/1988 3-47/Q-35
10/21/1988 1-29/M-25
10/22/1988 1-35/0-25
10/23/1988 3-01/14-29
11/17/1988 1-35/0-25
11/25/1988 1-09/J-18
11/25/1988 1-09/J-18
12/4/1988 3-11/M-30
12/13/1988 1-49/P-21
12/13/1988 2-08/K-16
1989
1/5/1989 2-26/N-14
1/5/1989 2-26/N-14
1/15/1989 3-35/L-36
2/2/1989 2-26/N-14
2/2/1989 2-26/N-14
2/21/1989 4-26/0-34
3/19/1989 1-29/M-25
3/20/1989 2-46/0-15
3/20/1989 2-46/Q-15
3/20/1989 2-46/Q-15
3/20/1989 2-46/Q-15
3/25/1989 1-35/0-25
3/29/1989 3-47/Q-35
4/3/1989 3-33/K-37
4/18/1989 4-26/0-34
4/27/1989 2-26/N-14
4/27/1989 2-26/N-14
5/7/1989 1-49/P-21
5/11/1989 2-14/0-16
5/11/1989 2-14/0-16
6/6/1989 1-09/J-18
6/6/1989 1-09/J-18
6/21/1989 2-08/K-16
6/21/1989 2-08/K-16
3B I 3A 1 28 1 2A
INN, 101,
4678
3287
3287
4440
4614
4634
4600
C[ W
3C I 3B 3A 2B 2A Z1
4576
4525
4563
4436
4411
4504
4590
4359
4644
4524
4B22
4490
46351
4623
4664
2
4278
i
4993
09
4019
4405
4532
4721
4700
4615
4563
4491
2800
2800
MA
2894
4450
4732
4509
4731
4631
3287
3287
4440
4614
4634
4600
C[ W
3C I 3B 3A 2B 2A Z1
4576
4525
4563
4436
4411
4504
4590
4359
4644
4524
4B22
4490
46351
4623
4664
2
4278
i
4993
09
4019
4405
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE WELL
6/21/1989 2-46/Q-15
6/21/1989 2-46/0-15
8/3/1989 2-52/S-14
8/3/1989 1-47/Q-21
8/3/1989 2-52/5-14
8/3/1989 1-47/0-21
8/4/1989 2-46/0-15
8/4/1989 2-46/Q-15
8/15/1989 3-47/Q-35
8/19/1989 3-05/0-29
8/21/1989 3-01/N-29
9/12/1989 4-50/K-41
9/12/1989 4-50/K-41
9/23/1989 4-26/0-34
9/23/1989 4-26/0-34
9/24/1989 1-35/0-25
9/25/1989 2-62/Q-17
10/29/1989 3-11/M-30
11/25/1989 2-52/S-14
11/25/1989 2-52/S-14
11/27/1989 3-05/0-29
12/22/1989 2-46/Q-15
12/22/1989 2-46/0-15
12/30/1989 3-33/K-37
12/30/1989 3-33/K-37
1990
1/3/1990 1-45/Q-26
2/7/1990 2-26/N-14
2/7/1990 2-26/N-14
2/25/1990 3-05/0-29
2/26/1990 2-62/Q-17
2/26/1990 1-47/Q-21
2/26/1990 1-47/Q-21
2/28/1990 1-35/0-25
3/1/1990 1-49/P-21
3/17/1990 2-14/0-16
3/17/1990 2-14/0-16
3/19/1990 1-09/J-18
3/19/1990 1-09/J-18
3/22/1990 1-55/R-25
3/22/1990 1-55/13-25
4/5/1990 1-55/11-25
4/5/1990 1-55/R-25
4/9/1990 4-26/0-34
4/9/1990 4-26/0-34
4/29/1990 4-50/K-41
4/29/1990 4-50/K-41
3C 3B 3A 2B 2A Z1
4420
4420
4456
4410
4456
4410
14427
4427
4570
4600
4505
4505
4456
4456
4006
4006
4642
4453
4453
4611
4557
4606
4628
4667
4639
3
SDI
3C
3B
3A
2B
2A
Z1
4317
4332
4421
4780
4280
4000
4143
4440
_4417
4437
4432
4411
4506
4322
4322
4369
4369
4147
4029
4976
IL
4426
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
MPI/N FB SDI
DATE WELL 3C 3B 3A 2B 2A Z1 3C 3B 3A 28
5/1/1990 1-45/Q-264370
5/1/1990 1-45/Q-26 4400
5/2/1990
2-181-16
5/2/1990
2-18/L-16
5/2/1990
2-181-16
5/24/1990
2-08/K-16
5/24/1990
2-08/K-16
8/11/1990
4-26/0-34
8/12/1990
1-35/0-25
8/12/1990
1-29/M-25
8/12/1990
2-26/N-14
8/12/1990
2-26/N-14
8/13/1990
2-52/S-14
8/13/1990
2-52/S-14
8/13/1990
2-46/Q-15
8/13/1990
2-46/Q-15
8/13/1990
1-49/P-21
8/14/1990
4-26/0-34
10/10/1990
3-33/K-37
10/10/1990
3-33/K-37
10/20/1990
3-01/N-29
10/28/1990
3-11/M-30
1991
4/22/1991
1-49/P-21
4/30/1991
2-46/Q-15
4/30/1991
2-46/Q-15
5/12/1991
1-47/Q-21
5/12/1991
1-47/Q-21
5/15/1991
2-26/N-14
5/15/1991
2-26/N-14
5/18/1991
1-09/J-18
5/18/1991
1-09/J-18
5/23/1991
2-08/K-16
5/23/1991
2-18/L-16
5/28/1991
3-11/M-30
6/1/1991
1-45/0-26
6/l/1991
1-45/Q-26
6/4/1991
3-47/Q-35
6/4/1991
2-62/0-17
6/7/1991
1-55/13-25
6/7/1991
1-55/R-25
6/17/1991
3-33/K-37
6/17/1991
3-33/K-37
6/26/1991
4-08/P-27
7/15/1991
3-25/M-27
7/24/1991
3-25/M-27
9/14/1991
2-14/0-16
4617
4660
4725
4660
4684
4714
3486
3486
4500
4500
4465
4465
47081
4761
4339
4339
4227
4227
1823
1823
4922
4961
4903
4783
4707
4813
4894
4900
4
3971
3838
4108
4108
4157
4140
4140
4815
4414
4357
4427
4376
4704
4724'
4750
ENDICOTT
DATE WELL
9/14/1991
2-14/0-16
10/6/1991
2-62/Q-17
10/7/1991
1-49/P-21
10/12/1991
4-08/P-27
10/19/1991
3-33/K-37
10/19/1991
3-33/K-37
11/12/1991
1-47/Q-21
11/12/1991
1-47/0-21
11/18/1991
2-08/K-16
11/18/1991
2-08/K-16
11/20/1991
2-18/L-16
1992
1/22/1992
2-46/Q-15
1/22/1992
2-46/Q-15
1/29/1992
1-09/J-18
1/29/1992
1-09/J-18
3/27/1992
1-49/P-21
3/31/1992
2-62/0-17
4/3/1992
4-08/P-27
4/6/1992
1-45/Q-26
4/6/1992
1-45/0-26
4/10/1992
3-47/0-35
4/10/1992
3-47/0-35
4/10/1992
3-47/Q-35
4/10/1992
3-47/Q-35
4/19/1992
2-26/N-14
4/19/1992
2-26/N-14
5/9/1992
3-11/M-30
5/15/1992
3-25/M-27
5/15/1992
3-25/M-27
5/18/1992
3-33/K-37
5/18/1992
3-33/K-37
6/2/1992
4-50/K-41
6/15/1992
2-52/S-14
6/15/1992
2-52/S-14
7/23/1992
2-14/0-16
7/23/1992
2-14/0-16
7/26/1992
1-29/M-25
7/26/1992
2-18/L-16
7/27/1992
1-47/Q-21
7/31/1992
4-26/0-34
11/17/1992
2-14/0-16
11/18/1992
2-62/0-17
11/23/1992
1-45/Q-26
11/23/1992
1-45/Q-26
11/24/1992
4-08/P-27
11/26/1992
1-49/P-21
OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
MPI/NfUSDI
3C 3B I 3A 2B 2A Z1 13B 3A 2B 2A
4803
4872
4898
4771
4562
4473
4180
4180
4657
4725
4657
4245
4245
4824
4796
4869
4890
4657
3919
3919
4608
4608
4608
4608
1482
1482
4739
4874
4779
4751
4726
3966
3952139521
14846
4693
4087
4879
48521
4841
4767
3033
4470
3762
4393
Z1
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
11 MPI/NFB SDI
DATE WELL X 3B 3A 2B 2A Z1 X 3B 3A 2B 2A Z1
11/28/19921 2-26/N-14 1229
11/28/1992 2-26/N-14 1229
11/30/1992! 3-47/0-35 4399'
12/4/1992 3-33/K-37 4542
12/4/1992 3-33/K-37 4639
12/5/1992 3-25/M-27 4776
12/5/1992 3-25/M-27 48961
12/5/1992 2-52/S-14 4572
12/5/1992 2-52/S-14 4572
12/19/1992 3-11/M-30 4671
12/30/1992 4-26/0-342484
1993
1/7/1993 4-50/K-41 ! 3700
1/7/1993 4-50/K-41 5172' 1
5/3/1993 1-47/0-21 4065
5/3/1993 1-47/Q-21 4065',
5/18/1993 2-62/0-17 4862
5/20/1993 2-26/N-14 1513
5/20/1993 2-26/N-14 1513
5/21/1993 1-49/P-21 4919
5/23/1993 3-47/Q-35 49041
7/16/1993 3-25/M-27 4713
7/16/1993 3-25/M-27 47801
7/21/1993 2-18/L-16 4390
7/24/1993 4-26/0-34 12279
7/24/1993 4-26/0-34 j 12811 !
8/25/1993 ! 1-09/J-18 4691
8/25/1993 1-09/J-18 46381
9/19/1993 3-25/M-27 4621
9/24/1993 1-35/0-25 4643
11/1/1993 4-50/K-41 114575
11/1/1993 4-50/K-41 3359.
11/7/1993 3-11/M-30 43351
11/7/1993 3-11 /M-30 4316
11/9/1993 2-46/Q-15 4549
11/10/1993' 1-45/Q-26 4435 4211
11/24/1993 2-50/U-08 3801
1994
3/17/1994 1-47/Q-21 4628
3/19/1994 1-35/0-25 4555
3/22/1994 3-03/J-33 3905
3/24/1994 3-47/0-35 4283
4/17/1994 2-58/S-09 2497
4/18/1994 2-62/0-17 4773
4/20/1994 2-18/L-16 4309
4/25/1994 2-52/S-14 4449 4736 4608
5/16/1994 1-45/0-26 1
0
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE WELL
6/7/1994 2-26/N-14
1/7/1995 1-49/P-21
1/l/1995 1-09/J-18
7/14/1994 4-38/K-34
11/20/1994 3-11/M-30
11/30/1994 4-26/0-34
1/6/1995 2-14/0-16
12/23/1994 3-25/M-27
12/9/1994 4-50/K-41
1995
1/7/1995 1-49/P-21
1/14/1995 1-45/Q-26
1/17/1995 1-61/0-20
1/20/1995 3-15/K-33
4/4/1995 2-46/Q-15
4/24/1995 4-18/S-30
5/2/1995 3-05/0-29
5/3/1995 2-52/S-14
5/8/1995 2-58/S-09
7/3/1995 1-09/J-18
10/19/1995 1-19/1-18
10/20/1995 1-33/M-23
12/8/1995 2-18/L-16
12/16/1995 2-26/N-14
12/28/1995 4-50/K-41
1996
1/4/1996 3-43/P-36
1/13/1996 1-01/J-19
1/23/1996 2-18/L-16
1/26/1996 3-11/M-30
1/27/1996 1-31/M-21
1/28/1996 2-52/S-14
1/30/1996 4-18/S-30
2/17/1996 2-42/P-13
2/28/1996 1-09/J-18
3/3/1996 1-65/N-25
3/7/1996 1-57/R-23
3/10/1996 1-35/0-25
3/28/1996 2-64/U-10
4/1/1996 3-21/L-34
4/2/1996 3-39/J-39
4/6/1996 1-39/P-17
4/6/1996 2-26/N-14
4/14/1996 2-58/S-09
4/15/1996 1-67/T-20
4/19/1996 3-23/N-32
MPI/NFB
3C 3B 3A
2B
2A
Z1
1370
I 2A Z1
I
3829
4704
2817
4367
4277
5194
5194
4303
4301
4232,
4704
4745
4603
4930
4930
4713
4713
4985
2223
5097
4657
4498
4788
4260
4348
2428
4380
4040
1590
1590
4243
4184
4366
5019
5001
4542
4564
4604
5055
i
4656
1934
2215
7
SDI
3C
3B
3A 26
I 2A Z1
I
3829
4452
2817
4277
5194
5194
4301
4924
4745
4916
3658
4566
4985
5097
4657
4788
4260
2428
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE
WELL
3C
4/21/1996
3 -09/L -28A
4/21/1996
3-15/K-33
5/9/1996
2-50/U-08
3456
7/20/1996
3-37/L-35
7/20/1996
4-10/M-28
8/10/1996
4-26/0-34
8/16/1996
3-47/Q-35
9/2/1996
3-35/L-35
9/19/1996
3-33/K-37
10/16/1996
4-06/Q-32
11/11/1996
4-32/K-38
11/25/1996
4-38/K-34
11/16/1996
1-21/K-25
12/12/1996
1-63/T-22
12/16/1996
2-16/M-16
1997
1/14/1997
4-34/0-38
2/4/1997
1-09/J-19
2/22/1997
4-50/K-41
3/29/1997
1-17A/1-17
3/31/1997
2-58/S-09
2483
4/1/1997
2-52/S-14
5305
4/2/1997
4-18/S-30
4/5/1997
1-09A/L-21
4/5/1997
2-60/U-13
4709
4/14/1997
2-26/N-14
2391
4/15/1997
1-25/N-22
4/16/1997
1-17A/1-17
4/16/1997
1-57/R-23
4/24/1997
3-49A/M-40
5/4/1997
2-50/U-08
3622
5/4/1997
4-06A/Q-30
5/9/1997
2-42/P-13
5/13/1997
3-39/J-39
6/6/1997
1-03/P-16
6/19/1997
1-25A/K-22
6/28/1997
3-39A/1-37
7/1/1997
2-201-15
1431
7/1/1997
2-24/M-12
7/5/1997
1-21/K-25
7/9/1997
1-61/Q-20
7/16/1997
3-351-36
7/26/1997
3-17B/M-31
7/26/1997
3-49A/M-40
7/30/1997
2-14/0-16
8/5/1997
1-01/J-19
3B 1 3A 1 IN 2B I 2A Zi I 13C
4791
4382
4372
4810
4548
3A 2B 2A Z1
4382
4154
4514
3156
5654
4374
4550
51791
4524
4983
4652
3649
5203
3911
4335
3817
4990
3996
4659
4848
4537'
3937
4596
2287
4567
L3595
4428
4378
8
4964
4526
4971
4202
3883
BL[Y7
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
6
3186
3C 3B I 3A 12B I 2A I Z1
5143
4466
4414
4380
5494
4723
4980
3665
4281
4617
4229
2797
5166
4798
4437
4856
5375
4180
5225
4088
4583
4470
DATE
WELL
13C
3B
3A
2B
2A
8/5/1997
1-31/M-21
438E
8/7/1997
1-39/P-17
4650
8/7/1997
3-23/N-32
8/23/1997
3-15/K-33
8/28/1997
4-32/K-38
9/24/1997
1-09A/L-21
9/30/1997
2-44/R-12
5314
10/3/1997
4-50/K-41
10/13/1997
2-18/L-16
4381
10/29/1997
3-17B/M-31
11/14/1997
4-48/K-43
11/15/1997
2-46B/S-13
4801
12/13/1997
3-03/J-33
12/21/1997
3-27/M-33
1998
1/6/1998
1-17A/1-17
3410
2/12/1998
1-25A/K-22
2/13/1998
3-29/J-32
2/20/1998
3-39A/1-37
2/20/1998
4-34/0-38
2/22/1998
3-31/K-32
3/3/1998
1-33/M-23
4324
3/19/1998
1-61/Q-20
4577
3/19/1998
2-08/K-16
4240
4190
3/20/1998
2-18/L-16
3/21/1998
1-03/P-16
4556
3/22/1998
1-09A/L-21
3/22/1998
2-26/N-14
2739
3/31/1998
1-39/P-17
4661
3/31/1998
1-57/R-23
4/3/1998
3-33/K-37
4/8/1998
3-05/0-29
4/8/1998
4-20/M-35
4/13/1998
4-18/S-30
6/10/1998
2-52/S-14
5387
6/15/1998
3-37/L-35
6/22/1998
2-58/S-09
3209
7/15/1998
1-33/M-23
4294
7/20/1998
1-31 /M-21
4288
8/15/1998
4-02/Q-28
8/21/1998
2-60/U-13
5118
8/31/1998
4-38/K-34
9/26/1998
1-01/J-19
4313
4266
9/26/1998
1-47A/M-20
9/26/1998
2-44A/Q-11
4573
9/27/1998
2-20/L-15
1447
9/27/1998
4-32/K-38
6
3186
3C 3B I 3A 12B I 2A I Z1
5143
4466
4414
4380
5494
4723
4980
3665
4281
4617
4229
2797
5166
4798
4437
4856
5375
4180
5225
4088
4583
4470
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
MPI/NEB SDI
DATE WELL 3C 3B 3A I 2B 2A Z1 3C 3B 3A I 2B 2A
10/15/1998 2-30/0-094175
10/15/1998 3-07A/L-29 4290
10/20/1998 3-17D/M-31 4910
12/23/1998 1-25A/K-22 2962
1999
2/2/1999 2-22/L-14 4193
2/20/1999 1-33B/L-24 4306
2/22/1999 3-33/K-37 4641
2/23/1999 1-57/R-23 4931
2/23/1999 3-35/L-36 5250
2/28/1999 2-08/K-16 4173
2/28/1999 2-26/N-14 2828 2$2.8
3/1/1999 2-42/P-13 5340
3/2/1999 2-52/S-14 5263 5263
3/3/1999 4-02/Q-28 4966
3/12/1999 1-39/P-17 4639
3/12/1999 1-61/Q-20 4530
3/13/1999 2-58/S-09 3055
3/13/1999 2-18/L-16 4115
3/13/1999 1-01/J-19 4299
6/20/1999 4-32/K-38 4692
6/20/1999 3-39A/1-37 4456
7/30/1999 1-25A/K-22 3301
9/11/1999 4-34/0-38 5776.
9/11/1999 1-35/0-25 4643
9/12/1999 3-11/M-30 4587
9/13/1999 1-17A/1-17 4060
9/13/1999 , 3-01 /N-29 5043
9/14/1999 1-19/1-18 4254
9/17/1999 2-44A/Q-11 4632 4632
9/17/1999 1-09A/L-21 2679
10/12/1999 1-67/T-20 4474
10/24/1999 3-49A/M-40 4491
11/4/1999 3-03/J-33 3473
11/4/1999 2-18/L-16 4242
1/15/1999 4-18/S-30 4332
2000
1/6/2000 3-15/K-33 4550
1/9/2000 3-23/N-32 4901
2/13/2000 3-25/M-27 4352
3/20/2000 3-33/K-37 4699
3/22/2000 3-35/L-36 5178
5/3/2000 2-62/Q-17 5157 5157
5/5/2000 2-52/S-14 5159 5159
5/6/2000 2-42/P-13 5156
5/6/2000 1-57/R-23 4270'
5/7/2000 2-26/N-14 5898 5898
10
ENDICOTT OIL FIELD HISTORICAL KEY WELL PRESSURE DATA
DATE WELL
5/8/2000 1
1-39/P-17
5/8/2000
3-23/N-32
5/13/2000
3-03/J-33
6/9/2000
2-58/S-09
6/13/2000
3-37/L-35
7/5/2000
3-01 /N-29
7/11/2000
3-39A/1-37
9/17/2000
1-01 /J-20
9/17/2000
1-33B/L-24
9/17/2000 11
1-61 /Q-20
9/18/2000
1-09A/L-21
9/19/2000
4-32/K-38
11/23/2000'
3-15/K-33
11/24/2000 i
1-47A/M-20
12/7/2000
2-18/L-16
12/15/2000
4-18/S-30
12/26/2000
2-28/ P-19
3C 3B 3A 2B 2A Z1
L 4940'
3844
4625
4812
4319
4666,
4443
I � I
4376
■
m
D_
m
41
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If.
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6
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m
7
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7
6
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L
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co
0
co
L
V
L
m
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7
co
m
0
0
L
d
Q
N
O
O
O
Pressure at 10,000 ft TVD ss Datum
(.n O cn O Ln O cn O
O O O O O O O O
I I 1 I
1 I I I
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