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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2003 Prudhoe Oil Pool
ANNUAL RESERVOIR SURVEILLANCE
REPORT
WATER AND MISCIBLE GAS FLOODS
PRUDHOE OIL POOL
JANUARY THROUGH DECEMBER 2003
2003 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
CONTENTS
SECTION PAGE
1.0 INTRODUCTION 4
2.0 OVERVIEW 5
3.0 PRESSURE UPDATE 6
3.1 Pressure Monitoring 6
3.2 Pressure Plan 7
4.0 PROJECT SUMMARIES 8
4.1 Flow Station two Water / MI Flood Project 8
4.2 Eastern Peripheral Wedge Zone Water / MI Project 9
4.3 Western Peripheral Wedge Zone Water / MI Project 10
4.4 Northwest Fault Block Water / MI Project 11
4.5 Eileen West End Waterflood Project 11
4.6 Gas Cap Water Injection Project 12
5.0 GAS MOVEMENT SURVEILLANCE 14
5.1 Gas Movement Summary 14
5.2 GOR Mechanisms 15
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LIST OF EXHIBITS
1-A Prudhoe Bay Unit Field Schematic
1-B PBU Well Statics
1-C PBU Production / Injection Statistics
1-D PBU Pressure Map
1-E Areally Weighted Average Pressure Plots
1-F Areally Weighted Pressure Pressure Data
1-G Average Monthly CGF MI Rates and Compositions
2-A FS-2 Base Flood Map
2-B FS-2 Reservoir Balance
2-C FS-2 Areal Average Reservoir Pressure
2-D FS-2 Daily Average RMI
3-A EPWZ Base Flood Map
3-B EPWZ Reservoir Balance
3-C EPWZ Areal Average Reservoir Pressure
3-D EPWZ Daily Average RMI
4-A WPWZ Water / MI Flood Base Map
4-B WPWZ Reservoir Balance
4-C WPWZ Areal Average Reservoir Pressure
4-D WPWZ Daily Average RMI
5-A NWFB Base Flood Map
5-B NWFB Reservoir Balance
5-C NWFB Areal Average Reservoir Pressure
5-D NWFB Daily Average RMI
6-A EWE Base Flood Map
6-B EWE Reservoir Balance
6-C EWE Daily Average RMI
7-A Wells Surveyed for Gas Movement
7-B Gas Production Mechanisms
8 Pressure Surveys
9 SI Well List
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1.0 INTRODUCTION
As required by Conservation Order 341C (Approved June 12th, 1997) and 341 D (Approved
November 30th, 2001) this report provides a consolidated waterflood and gas oil contact report
summary of the surveillance activities for the Waterflood Project, Miscible Gas and Gas Cap
injection projects, and the Gravity Drainage Area within the Prudhoe Oil Pool. The time period
covered is January through December 2003.
In keeping with the requirements of the Conservation Order the report format provides
information for each of the five major flood projects and the gravity drainage project in the field,
where applicable, as follows:
• Analysis of reservoir pressure surveys and trends
• Progress of the enhanced recovery projects, including the gas cap water injection project
• Voidage balance by month of produced and injected fluids
• Data on Minimum Miscibility Pressure (MMP) of injected miscible gas
• Summary of Returned Miscible Injectant (RMI) volumes
• Results of gas movement and gas-oil contact surveillance efforts.
• Results of pressure monitoring efforts
• Table of wells shut-in during 2003 calendar year
Separate sections are provided for the five major flood areas: Flow Station 2 (FS-2), Eastern
Peripheral Wedge Zone (EPWZ), Western Peripheral Wedge Zone (WPWZ), North West Fault
Block (NWFB), Eileen West End (EWE). Information on the Gravity Drainage region is
included also. Water and miscible gas floods are described in each section. Also, a separate
section has been provided with detailed information on gas-oil contact surveillance.
The wells in each polygon were reviewed during the preparation of this report. The polygons for
approximately 30 wells were updated with the most current, and accurate data. This report
includes the current polygon definitions for each well in the field.
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2.0 OVERVIEW
Exhibit 1A identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as
follows: FS-2, EPWZ, WPWZ, NWFB, EWE, WOA GD and EOA GD. The Waterflood Project
encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently
active in only portions of the waterflood areas. The Eileen West End waterflood pilot concluded
in March 1999, after successfully establishing EWE injection potential. Waterflood startup
began in September 2001, EWE information has been included in this report.
Exhibits 1-B and 1-C provide well, production, and injection statistics for the major project areas
included in this report. As in last years’ report, wells do not share project boundaries, but belong
to a single project area. The well counts therefore reflect the total number of wells actually
contributing to production and injection. Similar to last year, only wells that actually produced or
injected during the year were included.
During the report period of January through December 2003, field production averaged 387
MBOD, 7,775 MMSCFD (GOR 20,080 SCF/STB), and 1,105 MBWD (water-cut 74%).
Waterflood project injection during this period averaged 990 MBWD with 298 MMSCFD of
miscible gas injection.
Cumulative water injection in the five major projects from waterflood startup through December
2003 was 8,696 MMSTB, while cumulative MI injection was 2,658 BCF. Cumulative
production since waterflood startup was 2,533 MMSTB oil, 7,039 BCF gas, and 5,382 MMSTB
water. As of December 31, 2003, cumulative production exceeded injection by 3,028 MMRB
compared to 2,722 MMRB at the end of 2002. Similar to last year, production and injection
values have been calculated based upon the waterflood start-up dates for the project areas rather
than of each injection pattern.
Exhibit 1-C provides analysis of pressure static, buildup, and falloff data extrapolated to July 1,
2003 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. As in the past, abnormal
pressures, such as pressures taken in fault compartments and in the Sag Formation have been
removed. The project areas’ pressures are continuing to decline. As of 7/1/03, average pressure
in the PBU reservoir was 3,233 psia by areal weighting. Based on known pressure decline
between January and July 2003, a 24 psia/yr decline rate has been calculated compared to 42
psia/year in 2002. In general, pressure decline in the waterflood areas parallels the Gravity
Drainage Area.
Confirmed MI breakthrough has occurred in 193 wells during the reporting period. RMI
production is an indicator of EOR pattern performance and the presence of RMI is determined by
gas sample analyses that show a separator gas composition richer in intermediate range
hydrocarbon components. MI breakthrough in a well is considered to have occurred when the
average RMI rate over the number of producing days in a well exceeds 200 mcf/d. The previous
year showed MI breakthrough in 214 wells. The decrease in returned MI can be attributed to the
fact that MI is currently being injected into fewer wells, at higher rates.
Exhibit 1-G shows the 2003 average monthly CGF MI rates and compositions for the field.
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3.0 PRESSURE UPDATE
3.1 Pressure Monitoring
Exhibit 1C – 1F provide analysis of pressure static, buildup, and falloff data extrapolated to July
1, 2003 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. For this report and in
the past, pressures taken in fault compartments, the Sag River Formation, and in Zone 1 of the
G-Pad LPA (Low Pressure Area), which don’t appear to be in communication with the rest of the
reservoir, have been excluded. Although Zone 1 and Zone 4B are in poor communication with
the rest of the reservoir and therefore have low pressures, these pressures are included in the map
and calculations.
Unless otherwise noted, all pressure calculations are areally weighted, bound by the main field
original 50' LOC contour, and are referenced to a pressure datum of 8800' SS.
3.1.1 Northwest Fault Block (3118 psia)
Average pressure decline for this area was 6 psi/yr, based on pressures at the start of the report
period, and mid year 2003. The pressure decline rate has essentially flattened.
3.1.2 Western Peripheral Wedge Zone (3245 psia)
Average pressure decline for this area was 34 psi/yr, based on pressures at the start of the report
period, and mid year 2003.
3.1.3 Eastern Peripheral Wedge Zone (3306 psia)
Average pressure decline for this area was 20 psi/yr, based on pressures at the start of the report
period, and mid year 2003. This is the second consecutive year of lower pressure decline rate
which is largely due to producer to injector conversions and remedial work on broken injectors
to limit out of zone injection.
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3.1.4 Flow Station Two (3285 psia)
Average pressure decline for this area was 28 psi/yr, based on pressures at the start of the report
period, and mid year 2003. The pressure decline rate is the same as last year.
3.1.5 Gravity Drainage (3221 psia)
Average pressure decline for the Gravity Drainage area is 24 psi/yr, based on pressures at the
start of the report period, and mid year 2003. For most of the EOA GD area, pressure is
supported by the gas injection in the gas cap.
3.1.6 Eileen West End (3645 psia)
Average pressure decline for this area was 14 psi/yr, based on pressures at the start of the report
period, and mid year 2003.
3.2 Pressure Plan
Per C. O. 341C, Rule 6b, a pressure plan containing the number of proposed surveys for the next
calendar year is required to be filed with this report.
Prudhoe Bay reservoir depletion strategies are defined, and the goal of the pressure program is to
optimize areal coverage and provide sufficient data for well safety. The proposed plan for 2004
calls for collection of 90 pressure surveys fieldwide. The number of surveys proposed is lower
than last year, but provides adequate areal coverage due to the targeting of areas of high interest
such as NWFB and EWE.
Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run
during 2003 is presented in Exhibit 8.
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4.0 PROJECT SUMMARIES
4.1 Flow Station Two Water / MI Flood Project
The Flow Station Two area, which comprises the eastern third of the Eastern Operating Area, is
shown in Exhibit 2-A. The locations of production and injection wells are shown with the EOR
injection patterns identified. There were 121 producing wells and 70 injection wells that
contributed to production/injection during 2003 within the FS-2 flood area. Production/injection
data was calculated with the polygon boundaries consistent with last year’s report.
The FS-2 waterflood area oil production averaged 42 MBOD for 2003 compared to 45 MBOD in
2002. Cumulative production since waterflood start-up through the end of 2003 is 959 MMSTB
of oil, 3,147 BCF of gas, and 2,719 MMSTB of water.
Waterflood injection rates averaged 634 MBWD and 114 MMSCFD in 2003. Since 12/31/02,
the waterflood balance has increased from a cumulative under injection of 919 MMRB to 1023
MMRB under injected. During the report period, production exceeded injection by 104.5
MMRB. Under-injection results from the inability of tighter intervals to compete for injection
(i.e. Romeo/Victor). Waterflood strategy is to replace voidage on a zonal basis while limiting
injection rates in wells with multiple zones to avoid over injection in primary waterflood zones.
Because the reservoir balance (Exhibit 2-B) doesn't identify support from the gas-cap or aquifer,
voidage replacement is understated. Cumulative water injection since waterflood start-up
through the end of 2003 is 4476 MMSTB. (Production and injection values have been calculated
based upon the start-up date for the project area, 6/14/84, rather than of each injection pattern
and using the new polygon boundary.)
The flood area's GOR increased from an average of 11,578 SCF/STB in 2002 to 12,555
SCF/STB in 2003. Gas influx continues upstructure across Drill Sites 4, 9, and 11. Gas
breakthrough continues to be present wherever gas is underrunning shales in all of the Upper
Romeo and Tango. Increases in RMI also contribute to the increased GOR. Water-cuts remained
steady at 92% in 2003.
A breakdown of the production and injection data is provided in Exhibit 2-B for the report
period. See Exhibit 1-C for a comparison of the cumulative figures with last year’s AOGCC
report.
Exhibit 2-C presents the areal average waterflood pressure decline over time.
Exhibit 2-D is a presentation of 2003 average returned MI (RMI) rates. Miscible gas
breakthrough has been confirmed in 50 wells by gas compositional analysis (RMI>200
MSCFD).
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4.2 Eastern Peripheral Wedge Zone Water / MI Flood Project
The Eastern Peripheral Wedge Zone (EPWZ) water and miscible gas (MI) flood area is shown in
Exhibit 3-A. In 2003, oil production averaged 19.4 MBOD with an average 89% water cut and
12,373 SCF/STB Gas Oil Ratio. Injection averaged 155.2 MBWD and 62.2 MMSCFD of
miscible injectant (MI).
There are a total of 61 producers and 37 injectors in the flood area that contributed to
production/injection during 2003. Of the 37 injectors, 12 alternately injected miscible gas and
water (WAG injectors); the remaining wells injected water only.
Production and injection values have been calculated using same polygon boundary as last year’s
report. Two waterflood start-up dates have been used, 12/30/82 for the DS13 flood and 8/20/84
for the down-dip sections, rather than the start-up dates of each injection pattern. A total of 562
MMSTB of oil, 1,755 BSCF of gas, and 1,082 MMSTB of water have been produced with 1,560
MMSTB of water and 568 BSCF of miscible gas injected. Exhibit 3-B shows the monthly
injected and produced volumes on a reservoir barrel basis during 2003 and provides cumulative
volumes since injection began. During the report period, production exceeded injection by 71
MMRB. Total voidage replacement is understated because the reservoir balance analysis does
not reflect support from the gas cap or aquifer.
Exhibit 3-C shows the trend of reservoir pressure decline in the EPWZ flood area with time. The
area receives pressure support from water/WAG injection. Faulting and out of zone injection
influences the pressure in some areas. Additionally, areas of low pressure are being addressed
by selected conversions of producers to injectors.
As cumulative MI gas injection increases, rising gas saturations in the reservoir results in higher
amounts of Returned MI (RMI) produced in the wells. Exhibit 3-D shows the 2003 average of
estimated RMI rates in producers, as calculated from well tests and from numerous produced gas
sample analyses. Miscible gas breakthrough has been confirmed in 34 wells (RMI <200
MSCFD).
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4.3 Western Peripheral Wedge Zone Water / MI Flood Project
Exhibit 4-A is a map of the WPWZ water and miscible gas flood areas. During the report period
oil production averaged 23.6 MBOD at a gas/oil ratio of 5,905 SCF/STB and a watercut of 89%.
Injection averaged 93.3 MBWD of water and 58.0 MMSCFD of miscible injectant.
For the WPWZ project, 47 injectors (13 WAG injectors and 34 water injectors), and 104
producers contributed to the production and injection during 2003. The well counts reflect only
the active wells for the year.
The waterflood startup date for the WPWZ project area was September 1985, corresponding to
the start of injection in the Main Pattern Area (MPA). The production and injection data for the
project reflect this startup date. Consistent with last year, production and injection data are
calculated on the single area basis.
Cumulative water injection from waterflood start-up through December 2003 was 1,296
MMSTB while cumulative MI injection was 499 BSCF. Cumulative production since waterflood
start-up is 443 MMSTB oil, 1040 BSCF gas, and 808 MMSTB water. As of December 31, 2003
cumulative production exceeded injection by 417 MMRB. Exhibit 4-B provides the monthly
injection and production data from 01/03 through 12/03. During the report period, production
exceeded injection by 54 MMRB. During 2001, WPWZ injection targets were modified to take
into account aquifer influx occurring along the GDWFI boundary, and superpattern management
of the WPWZ waterflood to stabilize the GOC. The reservoir balance in Exhibit 4-B doesn’t
identify support from the aquifer, thereby understating voidage replacement.
The areally weighted average pressure as of July 1, 2003 was 3245 psia. This represents an
average decline rate of 34 psi/yr, based on pressures at the start of the report period, and mid
year 2003. Exhibit 4-C depicts the reservoir pressure history for the WPWZ area.
Exhibit 4-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates.
Miscible gas breakthrough has been confirmed in 53 wells by gas compositional analysis.
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4.4 Northwest Fault Block Water / MI Flood Project
Exhibit 5-A is a map of the NWFB water and miscible gas flood areas. During the report period,
oil production averaged 22.4 MBOD at a gas/oil ratio of 6,133 SCF/STB and a watercut of 82%.
Injection averaged 98.3 MBWD and 41.7 MMSCFD of miscible injectant.
For the NWFB project, 36 injectors (12 WAG injectors and 24 water injectors), and 87 producers
contributed to the production and injection during 2003. The well counts reflect the number of
wells actually contributing to production/injection
Production and injection values have been calculated based upon the start-up date for the project
area, 8/13/84, rather than of each injection pattern and using last year’s polygon boundary.
Cumulative water injection from waterflood start-up in August 1984 through December 2003
was 1,352 MMSTB while cumulative MI injection was 620 BCF as detailed in Exhibit 5-B.
Cumulative production since waterflood start-up was 553 MMSTB oil, 1015 BSCF gas, and 748
MMSTB water. As of December 31, 2003 cumulative production exceeded injection by 246
MMRB. Exhibit 5-B provides the monthly injection and production data from 01/03 through
12/03. During the report period, production exceeded injection by 45 MMRB.
The areally weighted average pressure as of July 1, 2003 was 3,118 psia. Average pressure
decline for this area was 6 psi/yr, based on pressures at the start of the report period, and mid
year 2003.
Exhibit 5-D indicates wells with MI breakthrough and the 12-month average returned MI rates.
Miscible gas breakthrough has been confirmed in 51 wells by gas compositional analysis.
4.5 Eileen West End Waterflood Project
Exhibit 6-A is a map of the EWE waterflood area. During the report period, oil production
averaged 19.4 MBOD at a gas/oil ratio of 4,178 SCF/STB and water cut of 66%. Injection
averaged 9.0 MBWD and 21.8 MMSCFD of gas.
For the EWE project, 9 injectors (3 WAG injector, 6 water injectors,), and 67 producers
contributed to the production and injection during 2003. The well counts reflect only the active
wells for the year.
Cumulative water injection from waterflood start-up in September 2001 through December 2003
was 12 MMSTB. Cumulative production since waterflood start-up was 15 MMSTB oil, 82 BCF
gas, and 25 MMSTB water. As of December 31, 2003 cumulative production exceeded injection
by 94 MMRB. Exhibit 5-B provides the monthly injection and production data from 1/03
through 12/03. During the report period, production exceeded injection by 37.6 MMRB.
The areally weighted average pressure as of July 1, 2003 was 3,645 psia. Average pressure
decline for this area was 14 psi/yr, based on pressures at the start of the report period, and mid
year 2003.
Exhibit 6-D indicates wells with MI breakthrough and the 12-month average returned MI rates.
Miscible gas breakthrough has been confirmed in 5 wells by gas compositional analysis.
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4.6 Gas Cap Water Injection Project
Details of the Volume of Water Injected during 2003 are detailed below; units in thousands of
barrels of seawater injected per month (MBWM):
Month PSI-01 PSI-06 PSI-08 PSI-09 PSI-10 Total
Jan 2,163 2,055 2,532 3,003 2,639 12,392
Feb 0 993 1,548 1,447 1,292 5,280
Mar 2,748 2,681 2,704 2,594 2,699 13,426
Apr 2,966 2,882 2,857 3,060 3,069 14,834
May 2,910 2,729 2,568 2,773 2,872 13,852
Jun 2,053 1,863 2,327 2,082 1,791 10,115
Jul 2,735 2,602 1,426 592 2,760 10,114
Aug 0 72 92 143 180 487
Sep 0 0 791 518 860 2,169
Oct 3 759 2,356 2,354 2,486 7,959
Nov 813 2,703 2,558 2,860 2,195 11,128
Dec 3,142 3,276 3,279 1,015 3,257 13,970
Total 19,533 22,615 25,038 22,441 26,100 115,727
Temperature warmback surveys were run in PSI-01, PSI-06, PSI-08, PSI-09, and PSI-10 during
May and June 2003. All five warmback surveys showed injection was contained within the
Ivishak formation as planned. In addition to these warmback surveys, an injection profile was
run in PSI-08. It showed 90% of injection entering Zone 2C/3 with the remainder entering
Zones 2A and 2B.
A pressure fall off test was attempted in PSI-08 in August 2003. Unfortunately the downhole
shut-in tool failed to close and little useful data was obtained due to a falling water column. The
reservoir pressure was 3279 psi.
Two new injectors, PSI-05 and PSI-07, were drilled from the East Dock pad in September and
October 2003. Both of these wells were drilled between the existing five PSI injectors.
Temperature surveys were made to provide a baseline for future warmback surveys. RST’s were
run in both wells in October 2003 to evaluate water fill up in the area. Each well showed water
in lower Zone 1, Zone 2, and Zone 3. RST’s were repeated in late December 2003 and showed
water continued to fill each zone.
RST’s were run over the Ivishak formation in six offset Lisburne producers and compared to
baseline RST’s run during 2002. The six wells were L2-32, L3-02, L3-05, L5-05, L5-09, and
L5-15. L2-32 showed approximately 12’ of water in Zone 2A and 10’ in Zone 2B. L3-05
showed approximately 12’ in Zn 2C. None of the remaining 4 Lisburne RST’s showed any
water.
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The second baseline surface gravity survey for the GCWI project was completed in March 2003
using absolute gravity meters. The 4D surface gravity survey will be used to monitor the
reservoir density changes within the gas cap as injection water replaces gas. The baseline survey
consists of approximately 270 gravity stations and was compared to 2002 baseline survey. This
survey also included about 40 stations that had been previously surveyed in 1994, 1997, 2000,
2001. These stations repeated within approximately 10-15 microGals (accounting for elevation
changes and including both gravity and elevation errors).
Geodetic control was obtained by high-accuracy GPS survey tied to the NGS CORS network.
The primary reference network consists of four stations: PBOC, DSL1, EDOC and PUO1. The
coordinates are in the International Terrestrial Reference system (ITRF). Orthometric heights
(or MSL height) were computed using the Geoid99 model in Alaska. All the GPS and gravity
survey data was sent to Matt Rader of the State of Alaska Department of Natural Resources on
November 17, 2003.
Additional conformance logs will be run in each PSI injector during 2004. Repeat RST’s will be
made as necessary in the offset Lisburne wells. A gravity survey is not planned for 2004.
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5.0 GAS MOVEMENT SURVEILLANCE
The report on gas movement surveillance activities and interpretations is broken into two major
sections. The first section provides a summary of gas influx movement and the second section
summarizes gas movement mechanisms.
5.1 Gas Movement Summary
Fieldwide GOC surveillance continues with collection of open-hole and cased-hole logs and
monitoring of well performance. In order to monitor gas movement in the reservoir, GOC
estimates are made across the field and are based upon the ongoing monitoring program and
historical well performance. The central portion of the field, the gravity drainage area (GDA)
exhibits in some areas almost total influx of the LOC (Light Oil Column). Gas influx is
essentially absent in the southern peripheral regions as a result of water and WAG injection in
the waterflood areas. .
It has become difficult in most parts of the field to define a single current GOC as the surface is
commonly broken into a series of oil lenses and gas underruns beneath the shales. The reservoir
is better characterized by a description of remaining oil targets. The targets within the GDA
occur within three general regions; the basal Romeo (Zones 1 & 2A) sands, the inter-underrun
sands, and oil lenses within the expanded GOC.
Production from the Romeo (Zones 1 & 2A) sands has historically been low compared to the
more prolific upper zones. This interval has a lower net to gross, lower permeability and more
limited sand connectivity than the rest of the reservoir. These factors impede gas expansion into
the Romeo. Underruns beneath shales within the Romeo sands are likely to be local.
The inter-underrun sands occur throughout the GDA and are characterized by one or more
underruns or solution gas pockets segmenting the remaining oil pad. Gas underruns are
observed beneath the top of the Sadlerochit reservoir, under Zone 4 shales, and the most regional
persistent underruns have developed under the mappable floodplain shales of Tango or Zone 2B.
Oil within the expanded GOC occurs in lenses above regional shales. Such lenses have been
identified from neutron logs. These lenses occur on Zulu (Zone 4B) shales, and above Tango
(Zone 2B) shales. Many lenses continue to exhibit oil drainage over time.
Exhibit 7-A lists the open and cased-hole neutron logs, as wells as RST logs, run in the Prudhoe
Bay Unit during the gas-influx reporting period from January 2003 through December 2003. A
total of 111 gas-monitoring logs, all cased-hole logs were run in the PBU.
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Page 15
5.2 GOR Mechanisms
Exhibit 7-B lists the primary gas production mechanism for active producing. Mechanisms are
divided initially by GOR production, (L) low GOR (< 2050 scf/stb) and high GOR (> 2050
scf/stb) production. The high GOR wells are further subdivided by mechanism; (G) high GOR
production directly from the expanded gas cap (i.e. coning), (U) high GOR production from
underruns and/or solution gas pockets, (O) high GOR production due to cement channeling, high
GOR production due to commingled Sag River production, or high GOR production from
returned MI production. A more detailed discussion of each GOR mechanism is provided
below:
Low GOR
Low GOR (< 2050 scf/stb) production is primarily limited to recently drilled development wells,
peripheral wells, and from waterflood project wells.
Expanded GOC
High GOR production directly from the expanded GOC occurs in numerous wells in the PBU.
As cumulative liquid voidage increases, gas influx occurs both vertically and areally. The
vertical and areal (within hydraulic layer) expansion of the original GOC gives rise to the
expanded GOC gas production mechanism.
Gas Underruns
Gas underrunning and free solution gas production contribute to high GOR production in many
PBU wells. Both underrunning and solution gas production are facilitated by continuous and
semi-continuous shale intervals. In underrunning, gas tongues connect to the expanded GOC.
Underrunning occurs upstructure in the lower formations of the reservoir and down-structure in
the upper formations.
Other
Channeling of gas via cement channels contributes high GOR and occurs in isolated cases
throughout the field. Remedial squeeze programs and sidetracking / re-drilling of compromised
wellbores has reduced the significance of this mechanism. High GOR also occurs due to
commingled production with the Sag River Formation.
Miscible gas production contributes to high GORs, but not appreciably to the movement of free
gas within the reservoir. This occurs in the gravity drainage waterflood interaction (GDWFI)
and waterflood areas and is associated with the WAG injectors.
Exhibit 1-A Prudhoe Bay Unit Field SchematicExhibit 1-APrudhoeBay Unit Field Schematic
Exhibit 1-B2003 PBU Well StatisticsWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2002 AOGCC ReportProducers106846411681558Injectors69548935554 -WAG2621225162 -Water Only43336683918 -Gas00000342003Producers104876712161589Injectors47369703751 -WAG1312111122 -Water Only34246582517 -Gas0021032Production Well Status in 2003 -Newly Drilled000000 -Sidetracked or Redrilled1121246Gas Injection Well Status in 2003 -Newly Drilled000000 -Sidetracked or Redrilled000000WAG Injection Well Status in 2003 -Newly Drilled000000 -Sidetracked or Redrilled0000111Water Injection Well Status in 2003 -Newly Drilled000000 -Sidetracked or Redrilled010102NOTES:(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year.(2) Project boundaries were simplified in 1998. Wells no longer share project boundaries, but belong to a single project area. (3) EOA GD and WOA GD have been combined.
Exhibit 1-C2003 PBU Production/Injection StatisticsWaterflood TotalWPWZNWFBFS-2EPWZEWECumulative Production from WF Start-Up through 12/31/03Oil (MMSTB)443553959562152533Gas (BCF)1040101531471755827039Water (MMSTB)80874827191082255382Cumulative Injection from WF Start-Up through 12/31/03Water (MMSTB)1296135244761560128696MI (BCF)499620799*56882658Cumulative Balance from WF Start-Up through 12/31/02Cum Production (MMRB)19971889575431016512806Cum Injection (MMRB)16341690482619249.610084Over/Under (MMRB)-363-199-919-1177-55.4-2722Cumulative Balance from WF Start-Up through 12/31/03Cum Production (MMRB)210019816117324611113555Cum Injection (MMRB)16831735509419981710527Over/Under (MMRB)-417-246-1023-1248-94-3028MI Breakthrough in Producing Wells> 200 mcfd535150345193AVERAGE RATE DATA 2003ProductionOil (MBD)23.622.442.219.419.4127.0Gas (MMSCFD)154.9151.9562.6255.795.41220.4Water (MBD)132.7101.8513.7164.237.4949.9InjectionWater (MBD)93.398.3634.0155.29.0989.7Gas (MMSCFD)58.041.7113.862.221.8297.5AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEFIELDWIDEBeginning of report period 1/033232326131213299331636523244Mid report period, 7/033219324531003285330636453230Pressure Decline (psi/6 month period)1316211410714Estimated Annual Decline (psi/yr)26324228201428*An error was found in the 2002 report, causing the cumulative FS-2 MI injection to be lower in 2003 than reported in 2002.Waterflood Project Area
Exhibit 1-D2003 PBU Pressure Map
Exhibit 1-EAreally Weighted Average Pressure PlotsEOA PRESSURE TRENDS (areally wtd avgs)3000310032003300340035003600370038003900Dec-82Dec-83Dec-84Dec-85Dec-86Jan-88Dec-88Dec-89Jan-91Jan-92Dec-92Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Jan-04Jan-05Jan-06PSIAFS2EPWZEOAGDWOA PRESSURE TRENDS (areally wtd avgs)3000310032003300340035003600370038003900Dec-82Dec-83Dec-84Dec-85Dec-86Jan-88Dec-88Dec-89Jan-91Jan-92Dec-92Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Jan-04Jan-05Jan-06PSIANWFBWPWZWOAGDAREAL AVG. P in the PBMGP(FS 2,EPWZ,WPWZ,NWFB) 3000310032003300340035003600370038003900Dec-82Dec-83Dec-84Dec-85Dec-86Jan-88Dec-88Dec-89Jan-91Jan-92Dec-92Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Jan-04Jan-05Jan-06PSIA
Exhibit 1-FAreally Weighted Average Pressure TableDATEFS2EPWZEOAGDWPWZNWFBWOAGDPBMGPDec-773935400540214016394439773968Jul-783870396739873978390939393914Dec-783832393039573944387539083873Jul-793813389539243911384338773844Dec-793791386138913879379938503816Jul-803799383138913848377038213798Dec-803852381938453822378138003818Jul-813881382138333799381437843840Dec-813880381538183799382037683842Jul-823872380638033800381237533833Dec-823850379537853797380437393818Jul-833831378437683792378737223804Jan-843814377137513783377237043790Jul-843796375837353777375636863774Jan-893779374337193771373636703755Jul-893760373037033763372336533740Jan-903732370836853731370436313713Jul-903708369336683716368736133695Jan-913680367636503694365535953666Jul-913642365736333673362835763635Jan-923617364136173652360235583615Jul-923591362636003632357735403593Jan-933561360035763619354435223582Jul-933543359535603598351535023565Jan-943539355535423578348334823537Jul-943523353635273555345634573516Jan-953496352435173555350734473506Jul-953473350735033536348934283486Jan-963466348534853497347834073463Jul-963450346734703472346133903443Jan-973446348434353460344433733441Jul-973429346734163438342733573421Jan-983452341734133417342133443430Jul-983435340933973394340233283415Jan-993445339133763382334333023443Jul-993429337833613360331732853426Jan-003406336133563372326832313418Jul-003390335133423353324032033395Jan-013366332533233325322532243358Jul-013360331033093309320532053347Jan-023325333432963289316332453358Jul-023312332432793273314432113347Jan-033299331632763262312131953297Jul-033285330632623245311831843283Jan-043271329632483228311631733272
Exhibit 1-G2003 Average Monthly CGF MI Rates and CompositionsEOAMI Rate*MMPMWAverage Monthly Mole%MCFDPSIMol WtCO2C1C2C3IC4NC4C5+01/03211,4633,23832.1719.93%33.79%19.72%24.22%1.38%0.93%0.03%02/03211,3023,20732.2819.97%33.52%19.67%24.26%1.47%1.10%0.01%03/03213,8663,21632.2820.08%33.60%19.59%24.06%1.51%1.15%0.01%04/03218,4633,23532.2019.99%33.85%19.51%24.15%1.45%1.02%0.03%05/03187,5643,28332.1020.34%34.00%19.65%23.77%1.29%0.92%0.03%06/03162,4303,23232.1419.51%34.46%19.09%24.07%1.59%1.26%0.03%07/03109,7453,27531.7017.94%36.24%18.35%24.97%1.04%1.43%0.03%08/03157,8543,23832.1319.70%34.16%19.33%24.36%1.03%1.39%0.03%09/03122,7783,18432.5521.24%31.81%20.43%24.68%0.74%1.06%0.04%10/03157,3533,27832.2921.07%33.55%19.69%23.00%1.26%1.41%0.03%11/03172,4563,26832.1820.56%33.56%19.75%24.13%0.78%1.18%0.05%12/03189,4343,29732.1821.13%33.20%20.34%23.43%0.74%1.15%0.02%Average176,0163,24532.1920.16%33.77%19.62%24.06%1.22%1.15%0.03%WOAMI Rate*MMPMWAverage Monthly Mole%MCFDPSIMol WtCO2C1C2C3IC4NC4C5+01/03187,8583,24132.1519.95%33.68%20.02%24.01%1.39%0.94%0.02%02/03199,1163,49831.0818.27%38.32%18.28%22.89%1.35%0.88%0.01%03/03179,1553,04532.7519.61%32.04%19.89%25.28%1.79%1.38%0.01%04/03142,7923,17032.4020.29%32.31%20.39%25.27%1.05%0.68%0.01%05/03115,1343,35331.7719.52%35.75%19.02%22.97%1.48%1.25%0.01%06/03111,5173,06632.6019.17%32.86%19.28%25.56%1.60%1.54%0.00%07/0374,1913,09432.2417.99%33.94%18.85%26.92%1.39%0.92%0.00%08/03103,1023,16432.0818.15%34.77%18.71%25.72%1.52%1.12%0.02%09/03134,5953,21032.1019.10%34.26%19.35%24.89%1.40%0.98%0.03%10/03183,9463,16832.4420.47%32.11%20.42%25.40%0.96%0.61%0.03%11/03149,0133,21232.1719.48%34.00%19.47%24.50%1.42%1.09%0.03%12/03163,4523,18232.2519.59%33.21%19.92%25.32%1.21%0.72%0.03%Average144,9993,21032.1519.40%33.95%19.53%24.75%1.37%0.99%0.02%* MMP data from 1986 Zick Correlation
Exhibit 2-AFS-2 Base Flood Area Map01-01A01-01B01-05PB101-0601-06A01-0801-0901-09A03-0103-0203-0303-0403-0503-0603-0703-0803-0903-1003-1103-1203-1303-1403-15A03-1603-16A03-1703-1803-18A03-1903-2003-20A03-2103-2303-2503-25A03-2603-2703-2803-2903-3003-3103-3203-32A03-3303-33A03-3403-34A03-34B03-3503-3604-0104-0204-02A04-0304-0404-04A04-0504-05A04-0604-0704-07PB104-0804-0904-1004-1104-11A04-1204-1304-1404-14PB104-1504-1604-16A04-1704-1904-19A04-2004-22A04-2304-23A04-2404-2504-2604-2704-2804-2904-29A04-29AL104-3004-30PB104-3104-3204-32A04-3304-3404-34A04-3504-3604-3704-3804-3904-4004-4104-41A04-41APB104-41APB204-4204-4304-4404-4504-4604-4704-4804-490429AL1PB105-02A05-05A05-32A09-0109-0209-0309-0409-04A09-0509-05A09-0609-0709-07A09-0809-0909-1009-1109-1209-1309-1409-1509-1609-1709-1809-1909-2009-2109-2209-2309-23A09-23APB109-23APB209-2409-2509-2609-2709-2809-28A09-2909-3009-30PB109-3109-31A09-31B09-31C09-3209-3309-3409-34A09-34APB109-3509-35A09-3609-36A09-36BL09-36C09-3709-3809-3909-4009-4109-4209-42A09-42APB109-4309-4409-4509-4609-4709-4809-4909-5009-5111-0111-01A11-0211-04A11-0711-07PB111-0811-1011-1111-1211-1311-13A11-1611-16PB111-1711-17A11-1811-24A11-2611-2911-3111-31A11-3211-3311-3511-3611-3712-0612-3216-0116-0216-0316-0416-04A16-0516-05A16-0616-06A16-0716-0816-08A16-0916-09A16-1016-10A16-1116-1216-12A16-1316-1416-14A16-1516-1616-1716-1816-1916-2016-2116-2216-2316-23A16-23APB116-2416-2516-2616-26A16-26APB116-26APB216-2716-27A16-27APB116-2816-2916-29A16-3016-3117-0117-01A17-03A17-03APB117-0417-04A17-04AL117-04APB117-0517-0617-0717-07A17-0817-0917-1017-10A17-1117-1317-1417-1517-15A17-15APB117-1617-1917-2017-2117-22GNI-01GNI-02GNI-03LAKEST-01PINGUT-1XXPWDW2-1SD311016SD311116
Exhibit 2-BFS-2 Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2002JanuaryFebruaryMarchAprilMayJuneOil1,238.71.8261.6911.8721.8281.3531.732Free Gas1,888.414.46014.49916.41015.65411.65313.909Water2,617.417.59115.98316.88716.27012.44216.554TOTAL5,744.633.87832.17435.16833.75225.44832.195Injected Fluids(MMRB)Water4,320.821.51119.21820.19419.07217.09920.818Gas504.83.0502.5732.1591.8862.3181.867TOTAL4,825.624.56121.79222.35320.95819.41722.685Net Injection Volumes = Injection - Production (MMRB)TOTAL-918.9-9.3-10.4-12.8-12.8-6.0-9.5Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2003Oil1.7321.6791.5871.5431.6351.6321,258.9Free Gas13.90913.23311.02211.0359.48113.1952,046.8Water16.55416.99015.98915.64416.53216.5982,811.5TOTAL32.19531.90228.59728.22227.64831.4266,117.2Injected Fluids(MMRB)Water21.30419.63121.03021.54720.02619.2024,561.5Gas1.4602.4801.6852.2762.7042.997532.3TOTAL22.76422.11122.71623.82322.73022.2005,093.8Net Injection Volumes = Injection - Production (MMRB)TOTAL-9.4-9.8-5.9-4.4-4.9-9.2-1,023.4
3000310032003300340035003600370038003900Jan-87Sep-89Jun-92Mar-95Dec-97Sep-00Jun-03Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 2-CFS-2 ArealAverage Reservoir Pressure
Exhibit 2-DFS-2 Average Daily RMI01-01A01-01B01-05PB101-0601-06A01-0801-0901-09A03-0103-0203-0303-0403-0503-0603-0703-0803-0903-1003-1103-1203-1303-1403-15A03-1603-16A03-1703-1803-18A03-1903-2003-20A03-2103-2303-2503-25A03-2603-2703-2803-2903-3003-3103-3203-32A03-3303-33A03-3403-34A03-34B03-3503-3604-0104-0204-02A04-0304-0404-04A04-0504-05A04-0604-0704-07PB104-0804-0904-1004-1104-11A04-1204-1304-1404-14PB104-1504-1604-16A04-1704-1904-19A04-2004-22A04-2304-23A04-2404-2504-2604-2704-2804-2904-29A04-29AL104-3004-30PB104-3104-3204-32A04-3304-3404-34A04-3504-3604-3704-3804-3904-4004-4104-41A04-41APB104-41APB204-4204-4304-4404-4504-4604-4704-4804-490429AL1PB105-02A05-05A05-32A09-0109-0209-0309-0409-04A09-0509-05A09-0609-0709-07A09-0809-0909-1009-1109-1209-1309-1409-1509-1609-1709-1809-1909-2009-2109-2209-2309-23A09-23APB109-23APB209-2409-2509-2609-2709-2809-28A09-2909-3009-30PB109-3109-31A09-31B09-31C09-3209-3309-3409-34A09-34APB109-3509-35A09-3609-36A09-36BL09-36C09-3709-3809-3909-4009-4109-4209-42A09-42APB109-4309-4409-4509-4609-4709-4809-4909-5009-5111-0111-01A11-0211-04A11-0711-07PB111-0811-1011-1111-1211-1311-13A11-1611-16PB111-1711-17A11-1811-24A11-2611-2911-3111-31A11-3211-3311-3511-3611-3712-0612-3216-0116-0216-0316-0416-04A16-0516-05A16-0616-06A16-0716-0816-08A16-0916-09A16-1016-10A16-1116-1216-12A16-1316-1416-14A16-1516-1616-1716-1816-1916-2016-2116-2216-2316-23A16-23APB116-2416-2516-2616-26A16-26APB116-26APB216-2716-27A16-27APB116-2816-2916-29A16-3016-3117-0117-01A17-03A17-03APB117-0417-04A17-04AL117-04APB117-0517-0617-0717-07A17-0817-0917-1017-10A17-1117-1317-1417-1517-15A17-15APB117-1617-1917-2017-2117-22GNI-01GNI-02GNI-03LAKEST-01PINGUT-1XXPWDW2-1SD311016SD311116
Exhibit 3-AEPWZ Base Flood Area Map01-0701-07A01-07APB101-1001-1301-1803-1503-15AL103-24A06-0406-04A06-0606-06A06-0906-1006-10A06-1106-1206-12A06-1306-1406-14A06-1712-0112-0212-0312-0412-04A12-0512-06A12-0712-07A12-0812-08A12-08B12-08C12-0912-1012-10A12-1112-1212-1312-13A12-13BPB112-13BPB212-1412-14A12-14AL112-14AL1PB112-14PB112-1512-1612-16A12-1712-1812-1912-2012-2112-2212-2312-2512-2612-2712-27A12-3012-3112-3312-3412-3512-35PB112-3613-0113-0213-02A13-02B13-02BL113-02BPB113-02BPB213-02BPB313-0313-0413-0513-0613-06A13-06APB113-0713-0813-08A13-08APB213-0913-1013-1113-1213-1313-13A13-1413-1513-1613-1713-1813-1913-2013-2113-2213-2313-23A13-2413-2513-2613-2713-27A13-2813-2913-29L113-3013-30A13-3113-3213-32A13-3313-3413-3513-3613-9814-0514-0714-0814-08A14-08AL114-08APB114-08APB214-0914-09A14-09ARD14-09B14-1014-1114-1214-1314-1414-16APB114-1714-17A14-1814-18A14-18APB114-18APB214-18APB314-18APB414-1914-2114-2214-22A14-2514-2614-2714-2814-2914-3014-3614-3714-3814-3914-4014-40A14-44A14-44APB117-0217-0317-1217-19ADEADH31-25OWDW-NEOWDW-SEPR131014PR141014PR171015PR181015PR191015PR201015XXPR231014XXPR241014X-15
Exhibit 3-BEPWZ Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2002JanuaryFebruaryMarchAprilMayJuneOil729.90.8290.7500.7670.6980.7000.866Free Gas1,127.66.9936.3756.8915.7294.8115.941Water1,244.15.8534.8174.9854.8425.2255.324 TOTAL3,101.613.67611.94212.64411.26910.73612.131Injected Fluids(MMRB)Water1,563.25.2124.5845.2704.8205.0465.461Gas361.11.2951.3192.2262.4681.5391.365TOTAL1,924.46.5075.9037.4967.2886.5856.827Net Injection Volumes = Injection - Production (MMRB)TOTAL-1,177.2-7.2-6.0-5.1-4.0-4.2-5.3Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2003Oil0.8660.7230.8110.7770.8360.737739.3Free Gas4.9946.1546.2975.5086.2926.7871,200.4Water4.5825.3055.2085.3275.3355.5251,306.4TOTAL10.44212.18212.31711.61212.46313.0493,246.1Injected Fluids(MMRB)Water5.8425.1144.3244.1504.3234.7531,622.1Gas0.7960.7620.7840.9580.7230.893376.3TOTAL6.6385.8765.1085.1075.0465.6461,998.4Net Injection Volumes = Injection - Production (MMRB)TOTAL-3.8-6.3-7.2-6.5-7.4-7.4-1247.7
3000310032003300340035003600370038003900Jan-87Sep-89Jun-92Mar-95Dec-97Sep-00Jun-03Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 3-CEPWZ ArealAverage Reservoir Pressure
01-0701-07A01-07APB101-1001-1301-1803-1503-15AL103-24A06-0406-04A06-0606-06A06-0906-1006-10A06-1106-1206-12A06-1306-1406-14A06-1707-01A12-0112-0212-0312-0412-04A12-0512-06A12-0712-07A12-0812-08A12-08B12-08C12-0912-1012-10A12-1112-1212-1312-13A12-13BPB112-13BPB212-1412-14A12-14AL112-14AL1PB112-14PB112-1512-1612-16A12-1712-1812-1912-2012-2112-2212-2312-2512-2612-2712-27A12-3012-3112-3312-3412-3512-35PB112-3613-0113-0213-02A13-02B13-02BL113-02BPB113-02BPB213-02BPB313-0313-0413-0513-0613-06A13-06APB113-0713-0813-08A13-08APB213-0913-1013-1113-1213-1313-13A13-1413-1513-1613-1713-1813-1913-2013-2113-2213-2313-23A13-2413-2513-2613-2713-27A13-2813-2913-29L113-3013-30A13-3113-3213-32A13-3313-3413-3513-3613-9814-0514-0714-0814-08A14-08AL114-08APB114-08APB214-0914-09A14-09ARD14-09B14-1014-1114-1214-1314-1414-16APB114-1714-17A14-1814-18A14-18APB114-18APB214-18APB314-1914-2114-2214-22A14-2514-2614-2714-2814-2914-3014-3614-3714-3814-3914-4014-40A14-44A14-44APB117-0217-0317-1217-19ADEADH31-25OWDW-NEOWDW-NWOWDW-SEOWDW-SWPR131014PR141014PR171015PR181015PR191015PR201015XXPR231014XXPR241014X-15Exhibit 3-D2003 EPWZ Average Daily RMI
Exhibit 4-AWPWZ Base Flood Area Map14-0614-4414-44PB1A-01A-01AA-02A-03A-05A-08A-09A-09AA-10A-11A-12A-14A-15A-16A-16AA-17A-18A-18AA-19A-20A-21A-22A-23A-26A-26L1A-26L1PB1A-27A-27AA-30A-30L1A-31A-31AA-32A-32AA-33A-34A-34AA-35A-37A-38A-38L1A-38L1PB1A-39A-40A-41A-42A-42PB1A-42PB2A-43B-01B-09B-11B-11AXXB-12B-12AB-13B-13AB-13APB1B-21B-24B-25B-31B-32B-32AB-33B-33AGETTY-01H-01H-01AH-01APB1H-02H-02AH-02APB1H-03H-06H-09H-10H-10AH-10APB1H-12H-21H-22H-22AH-31H-32H-33H-34H-37H-37AH-37APB1H-37L1H-37L1PB1H-37PB1HURLST-01K241112K301113M-17AMP22311113MP32301113MP43311113N-03N-10P-01P-02P-02AP-02APB1P-03P-03AP-03APB1P-03APB2P-04P-04L1P-05P-05AP-05PB1P-06P-06AP-07P-07AP-08P-08AP-08APB1P-09P-10P-11P-12P-12AP-12APB1P-12APB2P-12BP-13P-14P-15P-15L1P-16P-17P-18P-18L1P-19P-20P-20AP-20APB1P-20BP-21P-21AP-21BP-22P-23P-24P-24PB1P-25P-25L1P-26PLAGHM-01PR331113PRST01U-01U-02U-02AU-02APB1U-03U-04U-04AU-05U-06U-06AU-07U-08U-08AU-09U-09AU-10U-11U-11AU-11BU-12U-13U-14U-15U-15AU-15APB1U-15APB2U-15BU-15BPB1X-01X-04X-05X-06X-07X-08X-08AX-09X-09AX-09BX-10X-11X-11AX-12X-13X-13AX-14X-14AX-15AX-18X-19X-19AX-19BX-19BL1X-19BPB1X-20X-20PB1X-21X-21AX-21APB1X-22X-22AX-22PB1X-23X-24X-24AX-25X-26X-28X-29X-30X-30PB1X-31X-31L1X-32X-33X-33PB1X-34X-35X-35L1X-36Y-02AY-02APB1Y-03Y-04Y-05Y-05AY-06Y-07Y-08Y-08AY-09Y-09AY-09APB1Y-10Y-11Y-11AY-11BY-12Y-13Y-14Y-14AY-14BY-15AY-16Y-17Y-17AY-17BY-18Y-19Y-20Y-20AY-21Y-21AY-22Y-23Y-23AY-23APB1Y-23APB2Y-23BY-24Y-25Y-26Y-26AY-27Y-28Y-29Y-29AY-30Y-30L1Y-31Y-32Y-32L1Y-33Y-34Y-34AY-35Y-35AY-37Y-37AY-37APB1Y-38
Exhibit 4-BWPWZ Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2002JanuaryFebruaryMarchAprilMayJuneOil578.21.0861.0371.1290.9870.9430.641Free Gas628.15.4244.2374.5733.6563.2732.321Water790.35.0064.2744.4305.0903.9852.814TOTAL1,996.711.5169.54710.1339.7338.2015.776Injected Fluids(MMRB)Water1,312.63.3662.9113.0042.5942.7101.861Gas321.11.8651.5731.3410.9781.0490.796TOTAL1,633.75.2304.4844.3453.5723.7592.656Net Injection Volumes = Injection - Production (MMRB)TOTAL-363.0-6.3-5.1-5.8-6.2-4.4-3.1Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2003Oil0.6411.0120.9080.8680.8980.860589.2Free Gas3.6703.7593.1722.4552.7832.891670.3Water4.2784.0143.8414.0324.1674.425840.7TOTAL8.5908.7857.9207.3567.8478.1752,100.2Injected Fluids(MMRB)Water2.7862.8902.6783.5353.1303.9431,348.0Gas0.6760.7971.1451.8760.7901.202335.2TOTAL3.4623.6873.8235.4113.9205.1451,683.2Net Injection Volumes = Injection - Production (MMRB)TOTAL-5.1-5.1-4.1-1.9-3.9-3.0-417.1
3000310032003300340035003600370038003900Jan-87Sep-89Jun-92Mar-95Dec-97Sep-00Jun-03Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 4-CWPWZ ArealAverage Reservoir Pressure
14-0614-4414-44PB1A-01A-01AA-02A-03A-05A-08A-09A-09AA-10A-11A-12A-14A-15A-16A-16AA-17A-18A-18AA-19A-20A-21A-22A-23A-26A-26L1A-26L1PB1A-27A-27AA-30A-30L1A-31A-31AA-32A-32AA-33A-34A-34AA-35A-37A-38A-38L1A-38L1PB1A-39A-40A-41A-42A-42PB1A-43B-01B-09B-11B-11AXXB-12B-12AB-13B-13AB-13APB1B-21B-24B-25B-31B-32B-32AB-33B-33AGETTY-01H-01H-01AH-01APB1H-02H-02AH-02APB1H-03H-06H-09H-10H-10AH-10APB1H-12H-21H-22H-22AH-31H-32H-33H-34H-37H-37AH-37APB1H-37L1PB1H-37PB1HURLST-01K241112K301113M-17AMP22311113MP32301113MP43311113N-03N-10P-01P-02P-02AP-02APB1P-03P-03AP-03APB1P-03APB2P-04P-04L1P-05P-05AP-05PB1P-06P-06AP-07P-07AP-08P-08AP-08APB1P-09P-10P-11P-12P-12AP-12APB1P-12APB2P-12BP-13P-14P-15P-15L1P-16P-17P-18P-18L1P-19P-20P-20AP-20APB1P-20BP-21P-21AP-21BP-22P-23P-24P-24PB1P-25P-25L1P-26PLAGHM-01PR331113PRST01U-01U-02U-02AU-02APB1U-03U-04U-04AU-05U-06U-06AU-07U-08U-08AU-09U-09AU-10U-11U-11AU-11BU-12U-13U-14U-15U-15AU-15APB1U-15APB2U-15BU-15BPB1X-01X-04X-05X-06X-07X-08X-08AX-09X-09AX-09BX-10X-11X-11AX-12X-13X-13AX-14X-14AX-15AX-18X-19X-19AX-19BX-19BL1X-19BPB1X-20X-20PB1X-21X-21AX-21APB1X-22X-22AX-22PB1X-23X-24X-24AX-25X-26X-28X-29X-30X-30PB1X-31X-31L1X-32X-33X-33PB1X-34X-34PB1X-35X-35L1X-36Y-02AY-02APB1Y-03Y-04Y-05Y-05AY-06Y-07Y-08Y-08AY-09Y-09AY-09APB1Y-10Y-11Y-11AY-11BY-11BPB1Y-12Y-13Y-14Y-14AY-14BY-15AY-16Y-17Y-17AY-17BY-18Y-19Y-20Y-20AY-21Y-21AY-22Y-23Y-23AY-23APB1Y-23APB2Y-23BY-24Y-25Y-26Y-26AY-27Y-28Y-29Y-29AY-30Y-30L1Y-31Y-32Y-32L1Y-33Y-34Y-34AY-35Y-35AY-37Y-37AY-37APB1Y-38Exhibit 4-DWPWZ Average Daily RMI
Exhibit 5-ANWFB Base Flood Area MapF-18F-19F-24F-33F-34AF-36F-39F-42F-43F-43L1F-48KUPRST-01M-01M-02M-02PB1M-03M-03AM-03APB1M-04M-05M-05AM-05APB1M-05APB2M-06M-06AM-07M-08M-09M-09AM-09BM-10M-11M-12M-12AM-13M-13AM-14M-15M-16M-17M-18M-18AM-18BM-19M-19AM-20M-20AM-20APB1M-21M-21AM-22M-23M-24M-24AM-25M-26M-26AM-27M-27AM-28M-29M-29AM-30M-31M-32M-33M-34M-38M-38AM-38APB1N-04N-05N-08N-08AN-11N-13N-15N-18N-23N-23AN-25N-26NKUPSTPR331213R-01R-02R-03R-03AR-05R-05AR-06R-06AR-07R-07AR-08R-09R-09AR-10R-11R-11AR-14R-14AR-15R-15AR-16R-17R-17AR-18R-18AR-18BR-19R-19AR-20R-20AR-21R-22R-23R-23AR-24R-25R-25AR-26R-26AR-28R-29R-29AR-30R-31R-31AR-32R-32AR-32APB1R-34R-35R-36R-39R-39AR-40R-40PB1S-01S-01AS-01BS-02S-02AS-02APB1S-03S-04S-05S-05AS-05APB1S-06S-07S-07AS-08S-08AS-08BS-09S-10S-10AS-10APB1S-11S-11AS-11BS-12S-12AS-13S-14S-15S-16S-17S-17AS-17AL1S-17APB1S-17BS-17CS-17CPB1S-17CPB2S-18S-18AS-19S-20S-20AS-21S-22S-22AS-22BS-23S-24S-24AS-24BS-25S-25AS-25APB1S-26S-27S-27AS-27BS-28S-28AS-28BS-28BPB1S-29S-29AS-29AL1S-30S-31S-31AS-32S-33S-34S-35S-36S-37S-38S-40S-40AS-41S-41L1S-41PB1S-42S-42PB1S-43S-43L1S-44S-44L1S-44L1PB1T-01T-06XXT-07TW-C
Exhibit 5-BNWFB Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2002JanuaryFebruaryMarchAprilMayJuneOil682.40.9510.8600.9920.9730.8160.854Free Gas513.73.9813.8164.3703.5973.0803.095Water692.83.0462.9003.4152.7442.4482.941TOTAL1,888.97.9787.5758.7777.3146.3446.889Injected Fluids(MMRB)Water1,310.51.6471.8912.5652.1542.0152.484Gas376.71.4361.4111.3561.1240.3350.641TOTAL1,687.23.0833.3013.9213.2792.3503.125Net Injection Volumes = Injection - Production (MMRB)TOTAL-201.7-4.9-4.3-4.9-4.0-4.0-3.8Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2003Oil0.8540.9900.9390.8670.7520.757693.0Free Gas3.4623.7873.6852.8063.3173.850556.6Water3.5263.4683.6093.2323.3733.958731.5TOTAL7.8428.2458.2336.9067.4428.5641,981.0Injected Fluids(MMRB)Water4.0953.9763.8833.5214.4524.6441,345.9Gas0.2080.2040.1280.4371.1521.879387.0TOTAL4.3024.1814.0113.9585.6046.5221,734.8Net Injection Volumes = Injection - Production (MMRB)TOTAL-3.5-4.1-4.2-2.9-1.8-2.0-246.2
3000310032003300340035003600370038003900Jan-87Sep-89Jun-92Mar-95Dec-97Sep-00Jun-03Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 5-CNWFB ArealAverage Reservoir Pressure
Exhibit 5-D2003 NWFB Average Daily RMIF-18F-19F-24F-33F-34AF-36F-39F-42F-43F-43L1F-48KUPRST-01M-01M-02M-02PB1M-03M-03AM-03APB1M-04M-05M-05AM-05APB1M-05APB2M-06M-06AM-07M-08M-09M-09AM-09BM-10M-11M-12M-12AM-13M-13AM-14M-15M-16M-17M-18M-18AM-18BM-19M-19AM-20M-20AM-20APB1M-21M-21AM-22M-23M-24M-24AM-25M-26M-26AM-27M-27AM-28M-29M-29AM-30M-31M-32M-33M-34M-38M-38AM-38APB1N-04N-05N-08N-08AN-11N-13N-15N-18N-23N-23AN-25N-26NKUPSTPR331213R-01R-02R-03R-03AR-05R-05AR-06R-06AR-07R-07AR-08R-09R-09AR-10R-11R-11AR-14R-14AR-15R-15AR-16R-17R-17AR-18R-18AR-18BR-19R-19AR-20R-20AR-21R-22R-23R-23AR-24R-25R-25AR-26R-26AR-28R-29R-29AR-30R-31R-31AR-32R-32AR-32APB1R-34R-35R-36R-39R-39AR-40R-40PB1S-01S-01AS-01BS-02S-02AS-02APB1S-03S-04S-05S-05AS-05APB1S-06S-07S-07AS-08S-08AS-08BS-09S-10S-10AS-10APB1S-11S-11AS-11BS-12S-12AS-13S-14S-15S-16S-17S-17AS-17AL1S-17APB1S-17BS-17CS-17CPB1S-17CPB2S-18S-18AS-19S-20S-20AS-21S-22S-22AS-22BS-23S-24S-24AS-24BS-25S-25AS-25APB1S-26S-27S-27AS-27BS-28S-28AS-28BS-28BPB1S-29S-29AS-29AL1S-30S-31S-31AS-32S-33S-34S-35S-36S-37S-38S-40S-40AS-41S-41L1S-41PB1S-42S-42PB1S-43S-43L1S-44S-44L1S-44L1PB1T-01T-06XXT-07TW-C
Exhibit 6-AEWE Base Flood Area Map33-29ECHEV181112HIGHLANDSTK071112K071112RK091112K221112K331112KUPST-01L-01L-02MP00031012MP00151112MP11331112NWE1-01NWEILEEN-1NWEILEEN-2P-09L1SEEILEEN-1SEEILEEN-2V-03W-01W-01AW-01APB1W-02W-02AW-03W-03AW-04W-05W-06W-06AW-07W-08W-08AW-09W-10W-10AW-11W-12W-12AW-15W-15AW-15PB1W-15PB2W-16W-16AW-16APB1W-17W-18W-19W-19AW-19AL1W-19AL1PB1W-19AL1PB2W-20W-21W-21AW-22W-23W-23AW-24W-25W-26W-26AW-27W-29W-30W-31W-32W-32AW-34W-34AW-34APB1W-35W-36W-37W-37AW-38W-38AW-39W-40W-42W-44WENOMW01WENOMW01AWETWWKUPST-01Z-01Z-02Z-02AZ-03Z-04Z-05Z-06Z-07Z-07AZ-08Z-08AZ-09Z-10Z-11Z-12Z-13Z-14Z-14AZ-15Z-16Z-17Z-18Z-19Z-20Z-21Z-21AZ-22Z-22AZ-22BZ-23Z-23AZ-24Z-25Z-26Z-27Z-28Z-29Z-29AXXZ-30Z-30AZ-31Z-32Z-32AZ-32BZ-32BL1Z-32BPB1Z-32BPB2Z-33Z-33AZ-35Z-35PB1Z-38Z-38PB1Z-39
Exhibit 6-BEWE Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2002JanuaryFebruaryMarchAprilMayJuneOil11.30.8750.7820.9800.7890.7740.715Free Gas39.51.8591.8302.3171.8581.7441.602Water14.20.6500.7841.1291.1301.1851.152TOTAL65.03.3843.3954.4273.7763.7023.469Injected Fluids(MMRB)Water8.80.9660.7620.1850.0700.0660.189Gas0.00.2850.1800.2500.2500.3920.423TOTAL8.81.2520.9420.4350.3190.4580.613Net Injection Volumes = Injection - Production (MMRB)TOTAL-56.1-2.1-2.5-4.0-3.5-3.2-2.9Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2003Oil0.7150.7890.8300.6780.6910.75120.6Free Gas1.8241.8701.8751.4282.0622.19362.0Water1.3361.2291.3201.3681.6091.31728.4TOTAL3.8743.8884.0263.4744.3624.261111.0Injected Fluids(MMRB)Water0.1950.1400.1080.3750.2580.08412.2Gas0.2740.4320.5780.9450.9570.0755.0TOTAL0.4690.5720.6861.3201.2150.15917.3Net Injection Volumes = Injection - Production (MMRB)TOTAL-3.4-3.3-3.3-2.2-3.1-4.1-93.7
33-29ECHEV181112HIGHLANDSTK071112K071112RK091112K221112K331112KUPST-01L-01L-02MP00031012MP00151112MP11331112NWE1-01NWEILEEN-1NWEILEEN-2P-09L1SEEILEEN-1SEEILEEN-2V-03W-01W-01AW-01APB1W-02W-02AW-03W-03AW-04W-05W-06W-06AW-07W-08W-08AW-09W-10W-10AW-11W-12W-12AW-15W-15AW-15PB1W-15PB2W-16W-16AW-16APB1W-17W-18W-19W-19AW-19AL1W-19AL1PB1W-19AL1PB2W-20W-21W-21AW-22W-23W-23AW-24W-25W-26W-26AW-27W-29W-30W-31W-32W-32AW-34W-34AW-34APB1W-35W-36W-37W-37AW-38W-38AW-39W-40W-42W-44WENOMW01WENOMW01AWETWWKUPST-01Z-01Z-02Z-02AZ-03Z-04Z-05Z-06Z-07Z-07AZ-08Z-08AZ-09Z-10Z-11Z-12Z-13Z-14Z-14AZ-15Z-16Z-17Z-18Z-19Z-20Z-21Z-21AZ-22Z-22AZ-22BZ-23Z-23AZ-24Z-25Z-26Z-27Z-28Z-29Z-29AXXZ-30Z-30AZ-31Z-32Z-32AZ-32BZ-32BL1Z-32BPB1Z-32BPB2Z-33Z-33AZ-35Z-35PB1Z-38Z-38PB1Z-39Exhibit 6-C2003 EWE Average Daily RMI
Exhibit 7-A2003 Wells Surveyed for Gas MovementWellLog DateOH / CHWellLog DateOH / CHWellLog DateOH / CH01-24A10/9/2003CHD-18A6/19/2003CHPSI-0710/27/2003CH01-2910/2/2003CHD-22A5/22/2003CHPSI-0712/26/2003CH01-32A2/1/2003CHD-22B5/22/2003CHPWDW2-12/28/2003CH01-32A2/2/2003CHD-30A5/19/2003CHQ-05A8/11/2003CH01-334/15/2003CHD-30A5/20/2003CHQ-05A10/26/2003CH02-04A12/8/2003CHE-01A4/12/2003CHQ-05A10/27/2003CH02-05A6/2/2003CHE-02A3/15/2003CHX-161/16/2003CH02-08B5/30/2003CHE-04A9/15/2003CHZ-0511/28/2003CH02-08B5/31/2003CHE-05A9/16/2003CHZ-399/22/2003CH02-147/17/2003CHE-08A12/31/2003CH05-02A6/10/2003CHE-14A9/12/2003CH05-06A1/23/2003CHE-19A12/21/2003CH05-0812/27/2003CHE-3612/25/2003CH05-0812/31/2003CHF-021/3/2003CH05-16B6/15/2003CHF-04A3/2/2003CH05-16B6/16/2003CHF-06A10/11/2003CH06-04A5/7/2003CHF-11A9/9/2003CH06-14A5/13/2003CHF-11A9/10/2003CH06-2011/30/2003CHF-13A9/8/2003CH07-04A9/19/2003CHF-151/8/2003CH07-13B1/15/2003CHF-16A5/8/2003CH07-29B2/13/2003OHF-23A9/6/2003CH07-29B2/15/2003CHF-23A9/7/2003CH09-321/13/2003CHF-279/13/2003CH09-35A1/8/2003CHF-441/21/2003CH09-4110/12/2003CHF-45A5/3/2003CH11-366/4/2003CHG-03A6/4/2003CH14-17A1/19/2003OHG-12B9/28/2003CH15-08B7/14/2003CHG-15A7/11/2003CH15-08C7/14/2003CHG-161/30/2003CH15-15B1/27/2003CHG-26A1/17/2003CH15-20B10/11/2003CHH-17A8/11/2003CH15-20B10/12/2003CHH-19B9/27/2003CH15-21A5/15/2003CHH-19B9/28/2003CH15-28A8/26/2003CHH-211/30/2003CH15-28A11/21/2003CHH-269/17/2003CH15-28A11/22/2003CHH-269/18/2003CH15-48A2/17/2003OHH-27A5/9/2003CH15-48A2/19/2003CHH-27A9/30/2003CH18-06A10/30/2003CHH-359/29/2003CH18-15B11/22/2003CHK-04B10/30/2003CH18-15B11/23/2003CHK-07C9/16/2003CHA-066/27/2003CHK-20B12/7/2003CHA-239/7/2003CHK-20B12/8/2003CHC-04A6/26/2003CHN-20A1/11/2003CHC-164/30/2003CHN-21A9/9/2003CHC-27B12/8/2003CHOWDW-NW3/29/2003CHC-32B2/2/2003CHOWDW-SE3/31/2003CHC-32B2/2/2003OHOWDW-SW3/30/2003CHD-06A7/30/2003CHPSI-0510/25/2003CHD-13A6/23/2003CHPSI-0512/20/2003CHOH - Open Hole LogCH - Cased Hole Log
Exhibit 7-BGas Production MechanismsWellGas Mech CodeWellGas Mech CodeWellGas Mech Code01-02G02-16AU04-01G01-03AG02-17AU04-02AG01-04AG02-18AG04-03G01-06AU02-19U04-05AU01-07AG,O02-20G,U04-16AU01-10G02-21AG,U04-18G01-12AG02-22AG,U04-21G01-13G02-23AG04-22AU01-14G02-24G04-23AL01-15AG02-25U04-24U01-16G,U02-26BU04-26G01-18G02-27AU04-29AL1G01-19AG02-28U04-31U01-20G02-29AG04-32AG01-21U02-30BU04-33U01-22AG,U02-31AG04-34AU01-23G02-32BU04-35G01-24AG02-33AG04-37U01-25G02-34AU04-38G01-26AG02-35AU04-41AU01-28G,O02-36U04-47G01-29G,U02-37G05-01CG01-30G02-38L1U05-02AG,U01-31G02-39L1U05-03CG01-32AO03-01G05-04AU01-33G03-02L05-05BO01-34O03-03G05-06AU02-01BG03-08L05-07G02-02AG03-09U05-08G02-03BU03-14G05-09AG02-04AU03-15AL1O05-10BG02-05U03-20AO05-11AG02-05AG03-21L05-12BG02-06AU03-22U05-13AG02-07AU03-23G,U05-14AG02-08BU03-24AG05-15BG02-09BU03-25AO05-16BG02-10BU03-26G05-17BG02-11AU03-27G05-18AO02-12AU03-29U,G05-19G02-13BG03-30L05-20AG02-14U03-31U05-21AU02-14AG03-34BO05-22AG02-15AG03-35G05-23AGL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech Code05-24G07-08AU09-27O05-25BG07-09U09-28AL05-26AG07-10AU09-29G05-27AU07-11AU09-30L05-28AG07-12U09-31CU05-30G07-13BU09-32U05-31AU07-14AU09-33U05-32AG07-14BU09-34AO05-33AG07-15AU09-35AU05-34G07-16AU09-41L05-36G07-17U09-43O05-38G07-18U09-44O05-39G07-19AU09-45O05-40U07-20AU09-46L05-41G07-21U09-47O06-01G07-22U09-48U06-02O07-23AU09-49U06-03AG07-24U09-50L06-04AG07-25U09-51O06-05G07-26U11-01AL06-07G07-28AL1U11-03AO06-08AG07-29BU11-04AU06-09G07-29CU11-05AU06-10AU07-30U11-06U06-11G07-30AU11-11L06-12AG07-32AU11-13AG06-13G07-33BU11-16G06-14AG07-34AU11-17AU06-15G,O07-35U11-22AL1U06-16G07-36U11-23AL06-17G07-37U11-24AU06-18G,U09-01O11-27U06-19G,O09-02G11-28AU06-20G09-04AU11-30U06-21AG09-05AG,U11-31AG06-22AG09-06L11-32L06-23AG09-07AO11-33L06-24AG09-09O11-34U07-01AU09-11O11-36G07-02AU09-13O11-37U07-03AU09-21O12-01U07-04AU09-23AL12-03O07-05U09-24O12-04AO07-07AU09-26O12-06ALL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech Code12-07AO14-24G15-30AG12-08CU14-26O15-31AG12-09O14-28O15-32AG12-10AO14-29G15-33AG12-12O14-30G15-33BG12-13BO14-31U15-34AG12-14AL1U14-32G,U15-35O12-15O14-33G15-36AG12-16AO14-34G15-38G12-17L14-37O15-38AG12-18O14-40AL15-41BU12-22L14-41G15-42AG12-26G14-43G15-43G12-28AG14-44AL15-44G12-29G15-01AU15-45AG12-32G15-02AU15-46U12-34O15-04U15-47U12-35O15-05AU15-48AG12-36O15-07BG15-49AG13-01O15-07CG16-04AL13-02BL1O15-08BU16-06AO13-03O15-08CG16-07O13-04O15-09AG16-08AL13-08AO15-12AG16-09AO13-11O15-13AG16-12AL13-12O15-14G16-13O13-13AO15-15AG16-15L13-14O15-15BG16-17O13-29L1L15-16AG16-18O13-30AO15-17G16-19O13-34L15-18U16-21O14-02BG15-19AO16-22L14-03AG15-20AG16-23AO14-04AG15-20BG16-25O14-05AG15-21AG16-26AL14-07G15-22G16-27AL14-08AL1G15-23G16-28L14-09BL15-23AG16-29AL14-10O15-25AG16-30O14-12G15-26AG17-01AL14-16AG15-27G17-02O14-19G15-28G17-03AL14-22AO15-28AG17-04AL1O14-23G15-29AG17-05OL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech Code17-09OA-07GB-26BG17-11LA-09AGB-27AU,G17-12OA-10GB-33AG17-14OA-12OB-35G17-16OA-13GB-36U17-19AOA-14OC-01AG17-20OA-15OC-02G17-21LA-18AOC-03AG17-22LA-19OC-04AG18-02AGA-20LC-05AU18-03BGA-22LC-06AG18-04BOA-23GC-07AG18-05AGA-24GC-08AG18-06AGA-26LC-09AG18-07AGA-26L1OC-10G18-08AGA-28GC-11AG18-09BGA-29GC-12AG18-10BGA-30OC-13AG18-11DPNGA-32AOC-15G18-12AGA-33OC-16AG18-13AGA-34ALC-17AG18-14AGA-37LC-18AG18-15BGA-38L1LC-19BG18-16BGA-39OC-20BG18-17GA-40LC-21G18-18BGA-42LC-22G18-19GA-43GC-23BU18-20GB-01GC-26AG18-21AGB-02AGC-27AG18-22AGB-03BGC-27BG18-23AGB-04U,GC-28AG18-24AL2GB-05BU, GC-29AO18-25AGB-06U,GC-30U18-26AGB-07U,GC-31AG18-27CGB-08UC-31BG18-29BGB-10UC-32BG18-30GB-12AGC-33AG18-31GB-14GC-34U18-32AGB-16U,GC-35AO18-33GB-18U,GC-36AGA-01AOB-19AU,GC-37AUA-02GB-21GC-39UA-04GB-23AUC-41GA-06GB-25GC-42GL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech CodeD-01AUE-17GF-28UD-03AUE-18AGF-29GD-04AUE-19AGF-30GD-05UE-21AGF-31GD-06AUE-23BGF-32OD-07AUE-24BGF-35GD-08AGE-25GF-36O,GD-09AUE-26AOF-37GD-10GE-27AGF-39O,GD-11AGE-28AGF-40UD-12GE-29UF-41GD-13AUE-31AGF-42GD-15AGE-32AGF-43GD-16UE-33GF-43L1O,GD-17BGE-34OF-44GD-18AUE-35AGF-45UD-19BUE-36GF-45AUD-21UE-37GF-46GD-22BUE-38OF-47AUD-23AGE-39GF-48OD-24GF-01UG-01AUD-25AUF-02GG-02AUD-26AUF-03AGG-03AUD-27UF-04AGG-04AUD-28AL1GF-05GG-05UD-29UF-06AUG-07UD-30AGF-08AGG-08UD-31AGF-09AGG-10BUD-33UF-10BUG-12BUE-01GF-11AUG-13AUE-01AGF-12GG-14AUE-02AGF-13AUG-15AUE-03AGF-14OG-16UE-04AGF-15GG-17UE-05AGF-15AUG-18AUE-06AGF-16AUG-19AUE-07AGF-17AGG-21UE-08AGF-21GG-23AUE-09BGF-22GG-24UE-10AGF-23AUG-25AUE-12GF-24UG-26AUE-14AGF-26AUG-27UE-15BUF-26BOG-29AUE-16OF-27UG-30AUL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech CodeG-31AUJ-15BGM-09BLG-32AUJ-16AGM-10OH-02AUJ-17BGM-11OH-04GJ-18GM-12AGH-06UJ-19GM-15OH-07AGJ-20BGM-16LH-08GJ-21GM-17ALH-11UJ-22AGM-19AOH-13GJ-23GM-21ALH-14AGJ-24AGM-22OH-15GJ-25GM-23OH-16BGJ-26GM-24AOH-17AGJ-27AGM-25LH-18GJ-28GM-26ALH-19BGJX-02AGM-31OH-20GK-01GM-32LH-21GK-02CGM-33OH-22AUK-03AGM-34OH-23AGK-04AON-04AGH-24UK-04BGN-06LH-25GK-05BON-09GH-26GK-06AGN-10ALH-27GK-07CGN-11BOH-27AGK-08GN-12GH-29AGK-08AGN-13UH-30GK-09BGN-15GH-32UK-10BON-16GH-33GK-11GN-17GH-34UK-12AGN-18UH-35GK-14ON-19GH-36AGK-16AL2GN-20AGH-37AOK-19AGN-21AGJ-01BGK-20BGN-22AGJ-02AGL-01LN-24GJ-03GL-02LN-25UJ-05BGL2-03AGN-26OJ-06GL2-07GP-01LJ-08GL2-11GP-04L1OJ-09AGL2-13AGP-05ALJ-10AGM-04OP-06AOJ-11AGM-05ALP-07ALJ-12GM-06ALP-08ALJ-13GM-07OP-09L1LJ-14AGM-08OP-11OL - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrunO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeWellGas Mech CodeWellGas Mech CodeP-12BOS-17CLW-22LP-15L1LS-18ALW-23ALP-16LS-19OW-25UP-17LS-21OW-26AUP-18L1LS-23LW-27UP-19OS-26OW-29UP-20BLS-27BLW-30UP-21BLS-28BLW-31GP-25L1LS-30OW-32ALP-26OS-32OW-34GQ-01AUS-33LW-34AUQ-03AUS-35LW-36GQ-06AGS-36LW-37AGQ-07BUS-37OW-38ALR-04GS-38LW-39GR-08LS-40AOX-01OR-09AOS-41OX-02GR-10LS-41L1LX-03AGR-12GS-42OX-04GR-14AOS-43LX-05GR-16LS-43L1LX-07LR-17ALU-09AOX-08LR-18BOU-11BOX-08ALR-19ALU-13LX-09BLR-21OU-14LX-10OR-23ALU-15BOX-12OR-24OV-03LX-13ALR-26AOW-01UX-14AOR-27GW-01ALX-15ALR-28OW-02ALX-16GR-29AOW-04UX-17GR-30OW-05UX-18OR-31AOW-06AGX-19BLR-35OW-08ALX-21AOR-39ALW-09UX-22AOR-40LW-10AUX-25LS-01BOW-12ALX-27GS-02ALW-15ALX-30LS-03OW-16LX-31L1LS-05AOW-16ALX-32LS-07ALW-18LX-34LS-08BOW-19ALX-35L1LS-12AOW-20UY-01BOS-16OW-21ALY-02ALO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)L - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrun
Exhibit 7-BGas Production Mechanisms (Continued)WellGas Mech CodeY-04LY-09ALY-13OY-14BOY-15AOY-16LY-19OY-20ALY-23AOY-25LY-26AOY-28OY-29AL,OY-30L1OY-32L1OY-33OY-35ALY-36LZ-01GZ-03LZ-05GZ-06GZ-08ALZ-10LZ-11GZ-13LZ-15GZ-16LZ-17LZ-18LZ-21ALZ-22BLZ-23ALZ-24GZ-25UZ-26GZ-27GZ-29UZ-32BGZ-32BL1UZ-39LZ-16GZ-17UZ-18GO - Gas entering perfs from another mechanism (cement channel Sag River commingling, faults, etc.)L - Gor below 3050 scf/stbG - Gas entering perfs from GOC or aboveU - Gas entering perfs from an underrun
Exhibit 82003 Pressure SurveysWell NameAPI NumberTest DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumCommentsS-155002921113002/13/20031,0868,8003,336T/I/O = 50/200/0. Tbg FL @ 1086', FP w/2000' of 60/40 MeOH15-02A5002920697012/16/200310,7533,236.208,8003,236.10Grad = 0.221 psi/ftL-025002923048002/16/200310,1564,001.408,8004,001.40M-19A5002920897012/16/20039,9533,173.208,8003,203.70Grad = 0.153 psi/ft14-40A5002921875012/27/20039,5613,157.208,8003,328.60Grad = 0.430 psi/ftV-035002923124003/3/20039,9843,136.408,8003,136.40Well Unstable: rising at rate of 12.5 psi/hr @ 9984' MDS-265002922047003/8/20038,9733,229.808,8003,261.70Grad = 0.320 psi/ft06-23A5002920808013/16/20039,4393,264.508,8003,265Grad = 0.088 psi/ftD-04A5002920056013/18/200310,4143,221.108,8003,221.10Grad = 0.0797 psi/ftD-055002920058003/18/200310,3553,216.908,8003,216.86Grad = 0.080 psi/ft14-03A5002920319014/7/200311,0823,224.408,8003,224.50Grad = 0.441 psi/ftF-47A5002922232014/9/20039,3213,153.608,8003,153.60Well Unstable -> pressure rising at rate of 1.4 psi/hr at 9321' MD (8700' SSTVD). Deviation from SI time of 9 hrs production on 4/6 - 4/7/03.06-14A5002920458014/24/20039,7633,294.108,8003,289.70Well Unstable -> pressure rising at rate of 3.3 psi/hr at 9763' MD = 8803' SSTVD; Grad = 0.371 psi/ftE-13A5002920783014/24/200311,1203,1818,8003,181W-015002921866004/27/200312,2503,413.808,8003,413.40Grad = 0.414 psi/ft15-285002922247005/27/200310,8253,300.508,8003,369Grad = 0.348 psi/ft; Datum Pressure From PE Christopher JenkinsG-215002922604005/27/20039,9743,152.208,8003,152S-045002920959005/28/200334508,8004,037SITP = 1500 psig, FL @ 3450'S-065002920839005/28/200328008,8003,992SITP = 1200 psig, FL @ 2800'S-095002920771005/28/200332008,8003,735SITP = 1100 psig, FL @ 3200'S-11B5002920728025/28/200330508,8003,794SITP = 1100 psig, FL @ 3050'S-145002920804005/28/200331608,8003,548SITP = 960 psig, FL @ 3160'S-20A5002921637015/28/200334808,8003,625SITP = 1100 psig, FL @ 3480'S-22B5002922119025/28/200339508,8003,541SITP = 1200 psig, FL @ 3950'S-24A5002922044015/28/200326608,8004,247SITP = 1400 psig, FL @ 2660'S-345002922305005/28/200340008,8003,262SITP = 1020 psig, FL @ 4000'E-19A5002920571015/29/200311,5803,217.708,8003,248.10Grad = 0.306 psi/ftW-165002922045005/29/200310,9462,185.108,8002,192Grad = 0.336 psi/ft01-345002921609006/5/20039,1723,263.308,8003,257Grad = 0.424 psi/ft; exceptions to SI time: Flowed 11.5 hrs on 5/3, 9.6 hrs on 5/7-8, 6.5 hrs on 5/10F-26A5002921987016/6/200310,2543,169.808,8003,170Well Stable, Grad = 0.316 psi/ftA-105002920568006/14/20039,8253,269.508,8003,282.90Grad = 0.414 psi/ftS-445002922735006/16/20039,5173,325.308,8003,363.30Grad = 0.342 psi/ft14-40A5002921875016/19/20039,7453,248.408,8003,356.90Grad = .365 psi/ftC-04A5002920125016/26/200310,3253,226.608,8003,226.50Grad = 0.326 psi/ftJX-02A5002921455016/28/20039,6733,110.308,8003,110.90Wellbore gradient=0.412Z-165002922245006/28/200311,2693,293.408,8003,293.80Wellbore gradient=0.426; well still building at 3 psi/hrL-015002923011007/4/20039,1903,8118,8003,811.30Grad = 0.329 psi/ft
Exhibit 82003 Pressure Surveys (continued)Well NameAPI NumberTest DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumComments01-255002920874007/5/20039,9003,260.108,8003,260.10Grad = 0.358 psi/ft06-135002920457007/8/20039,4513,282.308,8003,286.40Grad = 0.401 psi/ft13-155002920831007/8/200310,2593,511.608,8003,511.70Grad = 0.440 psi/ft15-07C5002921166037/15/200312,0893,711.308,8003,797.20Grad = 0.430 psi/ftN-11B5002921375017/16/200310,1013,129.108,8003,144.50Grad = 0.077 psi/ftK-015002920998007/17/200310,981.503,043.308,8003,324.80Grad = 0.44 psi/ft11-065002920674007/21/200310,4023,305.508,8003,347.50Grad = 0.44 psi/ftZ-155002921849007/26/200311,4993,549.608,8003,552.30Grad = 0.398 psi/ftZ-355002922884007/28/200310,340.403,519.108,8003,903.20Grad = 0.44 psi/ft; Only able to make one stop due to high tag.A-235002920716008/5/200311,3883,256.108,8003,256.10Grad = 0.235 psi/ftK-015002920998008/12/200310,7882,953.708,8003,291.40Grad = 0.422 psi/ftH-16B5002920592028/14/20039,9343,094.808,8003,136.90Grad = 0.423 psi/ftR-305002922279008/17/200311,2423,156.408,8003,198.10Grad = 0.416 psi/ftF-305002921982008/19/200311,9622,690.908,8002,724.20Grad = 0.333 psi/ftK-085002921408008/19/200310,5693,280.108,8003,280.20Grad = 0.397 psi/ftR-09A5002920609018/21/20039,1323,140.808,8003,184.20Grad = 0.435 psi/ft05-02A5002920144018/22/20039,8583,235.108,8003,267.60Grad = 0.326 psi/ftQ-05A5002920344018/27/20039,9453,152.608,8003,137.93wellbore grad=0.323R-135002920929008/27/20039,7463,1638,8003,162.89Wellbore Grad: 0.42407-255002920938009/2/20039,4623,235.808,8003,235.82wellbore grad=0.07615-31A5002922285019/3/20039,2303,252.708,8003,288.43Grad=0.09 psi/ft18-27C5002922321039/3/20039,6503,246.108,8003,338.92Grad=0.31 psi/ft17-19A5002922297019/6/200310,1503,370.808,8003,331.24wellbore grad=0.415C-415002922385009/6/200310,8373,234.808,8003,234.71wellbore grad=0.336G-245002921671009/7/200310,1053,085.508,8003,085.54wellbore grad=0.124Z-125002921977009/7/200311,2363,687.508,8003,645.51Wellbore Grad 0.41218-21A5002921944019/9/200310,0703,2448,8003,294.53wellbore grad=0.101B-03B5002920306019/10/20039,6243,227.108,8003,227.11Grad=0.087 psi/ftB-165002920365009/10/200310,0713,251.208,8003,248.36Grad= -8.88 psi/ftG-19A5002921599019/11/200311,2503,337.408,8003,337.36Grad=0.130 psi/ftK-20B5002922555029/12/20039,6013,234.508,8003,301.36Grad = 0.222 psi/ftE-21A5002920577019/16/200310,5283,041.408,8003,041.41Grad= 0.299 psi/ftK-07C5002921045039/16/20039,6373,299.508,8003,308.29Grad=0.088 psi/ftK-03A5002921011019/20/20039,2793,310.308,8003,337.60Grad=0.09 PSI/FT18-25A5002921948019/21/20039,7933,163.408,8003,447.14Grad=0.406 psi/ft18-315002922579009/21/20039,2973,297.308,8003,356.80Grad=0.30 PSI/FT18-335002922598009/21/200311,4253,285.608,8003,372.94Grad=0.29 PSI/FTF-3350029226400010/5/200312,6132,5548,8002,554.08Grad=0.33 psi/ftS-40A50029224940110/5/20039,9373,206.908,8003,249.55Grad=0.33 psi/ftGNI-0250029228510010/8/20037,3403,1638,8004,203.18Grad=0.44 psi/ft
Exhibit 82003 Pressure Surveys (continued)Well NameAPI NumberTest DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumCommentsJ-14A50029209550110/20/200310,3183,1218,8003,121GRAD=0.437 PSI/FTF-0550029200950010/24/200311,1703,2128,8003,211.90GRAD=0.17 PSI/FT18-29B50029223160210/25/20039,4243,2628,8003,325.67GRAD=0.32 PSI/FTA-1750029205200010/25/200310,0293,3238,8003,323.07GRAD=0.41 PSI/FTJ-2350029217120010/28/20039,5273,1648,8003,164GRAD=0.08 PSI/FT15-01A50029206960110/31/20039,4703,2278,8003,227GRAD=0.398 PSI/FTN-1850029209060011/3/20039,7083,0178,8003,103.17GRAD=0.43 PSI/FTR-19A50029206370111/3/200313,3161,8838,8001,882.90GRAD=0.06 PSI/FT16-08A50029205490111/7/20039,3073,2028,8003,203.43GRAD=0.416 PSI/FT16-1750029214410011/8/20039,9893,258.808,8003,274.52GRAD=0.157 PSI/FT16-2250029220400011/8/200313,8003,254.708,8003,254.65GRAD=0.377 PSI/FT16-2550029222700011/8/20039,1383,336.508,8003,336.36GRAD=0.428 PSI/FTM-24A50029209390111/9/20039,1332,9608,8003,045.04GRAD=0.427 PSI/FTM-2550029215700011/10/200311,0203,181.108,8003,181GRAD=0.41 PSI/FTS-08B50029207780211/10/20039,1292,833.908,8002,877.80GRAD=0.44 PSI/FTK-09B50029217360211/11/20039,8683,2978,8003,297GRAD=0.08 PSI/FTS-43L150029227546011/11/20039,7603,0268,8003,026.02GRAD=0.07 PSI/FTJ-2550029217410011/12/20039,1023,1658,8003,165GRAD=0.07 PSI/FT17-15A50029222920111/15/20031,1758,8003,392FL @ 1175'B-13A50029203410111/20/200310,7003,319.508,8003,319.57Grad=0.435 psi/ftY-2550029218830011/21/200311,0013,3128,8003,312.05GRAD=0.411 PSI/FTB-3550029224060011/24/20039,2013,254.308,8003,256.54GRAD=0.154 PSI/FT04-3050029213450011/27/20039,9533,2808,8003,343Grad=0.318 psi/ft03-16A50029204150112/15/200312,1413,6128,8003,664.31Grad = 0.521 psi/ft03-18A50029204210112/16/20038,8003,219Per PE Brian Carlson09-1550029202560012/26/20039,7553,3408,8003,340grad=0.447psi/ftJ-22A50029216980112/26/200310,0973,1568,8003,156grad=0.329 psi/ft
Exhibit 92003 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments101-01BMar-9965CT cemented high in production tbg in 1993201-04ASep-0267Collapsed Tubing301-05May-9865Ann Comm: RWO uneconomic.401-17AJun-0035Low rate, high GOR, thin LOC in area501-19AOct-0173New ST produces gunk, waiting on SL to evaluate601-25Aug-0264Conversion to PWI701-30Apr-9765Cretaceous leak, thin LOC802-06AOct-0263Ann Comm waiver granted, unable to POP, sidetrack planned902-36May-0265Holes in tubing. Requires 6500' patch or RWO. No economic options.1003-05Mar-9165Temp P&A, BHL replaced1103-19Jul-0225High WC, no side track options.1203-28May-0235TxIAxOA, low PI.1303-32ANov-0122IAxOA on AL; not a good WSO candidate1404-04AJan-9565CTD BHA stuck in a window, junked1504-07Jan-9725Will bring BOL with UDVW project. Don't know test data.1604-12Jun-9465Geophones cemented in hole1704-34AMar-9425High WC. No Identified utility.1804-36Nov-0125High WC. No Identified utility.1904-39Apr-9825High WC. No Identified utility.2004-40Aug-0161Tbg leak, eval options.2104-46Nov-0125High WC. No Identified utility.2204-48Sep-02252305-11AMay-0132Holes in tubing and leak in wellhead. 2405-15BJun-0262Cretaceous leak. 1st patch failed. Will evaluate ST options in 20042505-17BNov-0265Collapsed Tubing. Low existing value.2605-19Dec-0267Holes in tubing. Low existing value. 2705-20AJun-0265Parted tubing. Low existing value.2805-35Feb-9662Need to remove blind to POP, which requires DS shutdown.2905-40Nov-0262Holes in tubing. Will evaluate ST options in 2004.3006-06AAug-9665CT fish in hole3106-09Jan-0263Rapid TxIA, ST planned.3206-12AFeb-0223Low Rate, possible CTD ST canidate.3306-14ASep-0222Watered out.3406-16Jun-0162T x IA x OA communication3506-20Mar-0261Waivered, waiting on GLV's.3606-21ADec-0162T x IA communication* NOTE-Wells shut in for all of 2003.
Exhibit 92003 Shut In Wells (continued)#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments3707-06AMay-0063Multiple tubing leaks, CTD ST approved.3807-27Aug-9065Coil in hole.3909-03May-0125IAxOA small. Requested to BOL for waiver eval.4009-36CDec-0132Low GFR.4109-42ADec-0265Cretaceous leak. No ST target. 4211-09AAug-0065LTSI; TxIA, obstruction4311-12Jan-9465Severe mech integrity. No current utility.4411-15Jan-9065Plugged and abandoned.4511-18Nov-0267Holes in tubing. No current plan for development.4611-23AFeb-9822High WC (twinned & can't compete w/ HP well. Uneconomic to de-twin. Potentially and UDVW injection conversion4711-25AMay-0267Holes in tubing. Need RWO.4811-27Sep-0241Scab liner currently being set.4911-38AJan-0172Tubing leaks. Uneconomic RWO. Evaluating conversion to produced water injector.5012-05Feb-0065Ann Comm: RWO Required.5112-11Feb-0015High TGOR.5212-12Sep-0162Tbg patch needs to be replaced.5312-32Sep-0267RWO package completed.5413-05Nov-9715LTSI. Next to MI injector5513-07Jun-9135Low rate, high TGOR (SI 10/90)5613-10Jun-9425Ann Comm: uneconomic RWO5713-26Feb-9725Ann Comm: Uneconomic RWO5813-27AAug-0262Ann Comm: Evaluate patch.5913-28May-9425Low oil, High TGOR.6013-33Dec-9415Low oil, High TGOR.6114-02BApr-0012Waiting for response to planned PWI conversion nearby.6214-06Dec-0263TxIA, FTS. Sidetrack on rig backlog.6314-11Aug-9862Eval for Rig ST.6414-15Sep-0167TxIA. Evaluating running two patches.6514-18AMay-0033Eval for ST.6614-20Feb-0067TxIA. Hole 5588. RWO for SWIPE (likely post '03)6714-38Nov-9432Low Qo, High TGOR (SI 11/94) TxIA and low PI. Eval ST6814-39Jun-9465IAxOAxForm. Leak @ 81'. No flowline.6915-03Jun-9465Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well.7015-06AJan-0261Multiple patches planned; waiting on results from 15-27 patches.7115-10AJan-9165Major leaks and a channel; no surface facilities; bottom hole location developed by 15-49* NOTE - Wells shut in for all of 2003.
Exhibit 92003 Shut In Wells (continued)#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments7215-11AOct-0263Tubing shot; look at RST or coil plus.7315-22Dec-0267Tubing shot; looking at RWO vs. RST7415-24Mar-9565Collapsed tubing, cret leak.7515-37AJan-0233Patch set - gas spike failed; will RST 1Q 2004.7615-39May-9862Extended patch with cement packer.7715-40AOct-0241RWO completed 1Q 2004, waiting on CT for milling prior to POP.7815-42ADec-0263Tubing shot; look at RST or CST w/inner string7915-47Oct-0265Tbg very rotten, IA cemented. Well secured w/ sand plug--chunks of tbg falling down on plug.8016-20Dec-0267 TxIA comm, RWO on backlog for EOS 20048116-24Aug-9625Was MIST injector; now SI for Res Management8216-31Apr-9535Was possible MIST candidate but tbg leaks on gas8317-07Oct-0262Sidetracked. POP in next couple of weeks.8417-13Jun-0132RST, but uneconomic.8518-01ADec-9967Multiple holes in tubing. RWO canidate.8618-12ADec-9913Evaluating ST.8718-14ADec-9913Rig ST planned for Feb '04.8818-15BAug-9967PC leak suspected. Evaluate RWO.8918-22AAug-0235No current plan.9018-28BNov-0065Holes in tubing and casing. Unable to recover plugs in well. Low remaining value.9118-34Oct-006592A-25ANov-9775LTSI - no tubing in well93A-41Sep-0067LTSI - cretaceous leak. Sidetrack w/ RWO.94B-11Jan-9135surface facilites given to B-3595B-15Nov-9967RWO/Conv planned96B-16Nov-0215Not healing anymore - needs sidetracked97B-20Aug-0262waiting on flow waiver to re-eval IOR to see if can justify long patch98B-22AAug-9924Conversion potential99B-24Jan-9365Aban in early 90's100B-29AOct-0115Gas production from liner lap. Needs more IOR for GSO.101B-30ANov-0262TxIA comm, FTS well -secured --> see planned action on AnnComm102C-05AFeb-0231Cannot get well to flow. Add perfs did not work, may plan gas spike103C-14May-9115SI fo high GOR, facilities taken.104C-24May-0162Holes in tubing. 2004 RWO planned.105C-25ASep-0263RWO/Coil Sidetrack Package out Dec 03.106C-38Nov-9765Cretaceous leak, flowline taken, eval ST.107D-14ASep-0261Working on new Patch. First Patch failed and new leak found.* NOTE - Wells shut in for all of 2003.
Exhibit 92003 Shut In Wells (continued)#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments108D-20Nov-0262Hope to patch. Running D&D tool to confirm patchability109E-11ASep-0063Collapsed tubing.110E-13AJul-0176Twinned well, problems with twin.111E-20Apr-0162TxIA comm, evaluating options.112F-07Jul-9165FL gone, no tbg.113F-18Sep-9965FL Gone114F-19Aug-9665FL Gone115F-34AOct-0262Holes in tubing. Awating seismic survey to evaluate ST vs. RWO options.116F-38Jan-0262Holes in tubing. Under evaluation for RWO.117G-06Jan-0262Failed production packer.118G-09AOct-0261Patch is being evaluated, IOR is low.119G-11AJun-0261TxIA leak was patched but patch leaked. Preparing to re-run patch.120G-31ADec-0261Planning to patch leaking Kinley buttons121H-01AJun-9967Slickline work on WOBL to investigate non-rig options.122H-05Dec-0162May revisit cleanout pending anncomm investigation.123H-10AOct-9765Lost source in hole - Plugged124H-12May-9165Csg collaspe appx 2000 ft125H-14ANov-0243Re-visit after N-25 package.126H-15Jul-0267RWO scheduled May 04..127H-28Apr-0162ST target available, but probably cheaper from Q-pad.128J-04May-9665129J-06Jun-9665Mature GDWFI, watered out, has 7" tubing w/ POGLM holes130J-07AJun-0067Collapsed tubing. RWO on books131K-10AJul-0122Wellbore placed to high in structure. Very low value.132K-13Oct-9767Safed out with TTPlug. Small leak produces oil to cellar.133L2-08AAug-9935No current plans for this wellbore.134L2-18AJul-0162Tbg and casing damaged. CTST planned but put on hold due to mechanical issues.135M-27AJul-9735Low rate. 136N-01Oct-0263Sidetrack package out to partners.137N-02Jul-8865Surface equipment removed.138N-03Jan-9665Wtr in cellar and high Wtr Cut139N-05Aug-8465Ann Comm, surface equipment removed.140N-07Sep-0263Sidetrack package Exxon approved.141N-14AOct-0267RWO to follow N-21a.142Q-02AMay-0231GDWFI well will not flow post SI - run POGLMs procedure submitted.143Q-04AMay-0162Holes in tubing. Under eval for CTD ST & inner string* NOTE - Wells shut in for all of 2003.
Exhibit 92003 Shut In Wells (continued)#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments144Q-05ANov-0261Rotten tubing. Long patch procedure on WBL.145R-01Nov-9365Ann Comm. No flowline or wellhouse. Replaced by R-39146R-09AJun-0267Waiting on RWO147R-10Mar-0135LTSI, low rate (also has Ann Comm issues)148R-13Aug-9915LTSI, high GOR (also has Ann Comm issues)149R-14ANov-0261New well waiting Ann Comm fix150S-10ANov-9125Never completed, No tbg. Eval ST151S-13Mar-0127SI for high WC, has failed pkr, ST candidate152S-27AApr-9632Low PI, Needs OA sqz. Low prior. Orig logs? LTSI153S-29AOct-0267evaluating RWO/conv to inj154U-01Feb-9225Plugged and abandoned.155U-02ADec-0262Hole in tubing and PC leak156U-06AFeb-0035Watered out. Failed TIT for sidetrack.157U-07Aug-9325LTSI. No flowline, poten ST?158U-08AJan-0225High watercut, flowlines given to U-15A.159U-12Jan-9975P&A'd. Tbg corrosion. Lost well during sidetrack160W-07Oct-0165bad tbg.=no patch. Not enough reserves for RWO161W-17Feb-9962IAxOAxTbg lk. Maybe future ST162WB-05Aug-0254W/O inj support163Y-08ASep-9332No Facilities - Eval ST164Y-12May-9962TxIAxOA comm FTS well - secured165Y-17BJun-0222Gel squeeze of fault or water source for GC2 injection.166Y-21ADec-0261Waiver in process.167Y-22AJan-9025Re-drilled as Y-25168Y-31Oct-9332Low GFR. Evaluating sidetrack.169Y-34AMay-9932Low GFR. Sidetrack candidate.170Y-37AApr-0265Coil cemented in hole. Sidetrack candidate.171Y-38Dec-0132Low GFR and collapsed tbg. Sidetrack candidate.172Z-04Oct-9875no surface facilites + bad tbging173Z-07AOct-9875no surface facilites 174Z-12Oct-9825watered out. Channel to aquifer175Z-19Jul-9665Tubing integrity, no flowline. Testing quality?176Z-20Feb-9815High GOR, 100' from injector177Z-30Oct-0263ST planned. Collapsed tbg. Needs RWO/ST178Z-35Apr-0135Low PI, completion problems also, poor rock Q179Z-37Jan-9935Never produced?180Z-38Dec-0141rock producer. Needs liner patch.* NOTE - Wells shut in for all of 2003.
Exhibit 92003 Shut In Wells (continued)A. Reasons for Well Shut-In1. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems2. High water, currently uneconomic to produce, no known mechanical problems3. Low production rate, no known mechanical problems4. Wellwork5. Reservoir Management6. Mechanical Problem7. Other (Specify under comments)B. Future Utility1. Wellwork Planned2. Under Evaluation3. Sidetrack Planned4. Reservoir Management5. No Current Utilization6. Surface Facilities7. RWO Candidate
