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HomeMy WebLinkAbout2013 Prudhoe Oil and Put River Oil PoolsRe
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
April 2, 2014
Ms. Cathy Foerster, Chair
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: ANNUAL RESERVOIR SURVEILLANCE REPORT
WATER AND MISCIBLE GAS FLOODS
PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2013
Amended Exhibits 1-C, 1-E, 1-F
Dear Chair Foerster,
BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Unit, submits
herewith a consolidated Surveillance Report for the Prudhoe Bay Waterflood Project,
Miscible Gas Project, Gas Cap Water Injection Project, Field Gravity Drainage Area
and Put River Oil Pool in accordance with the requirements of Conservation Orders
341C (originally CO 279), 341D and 559. This report covers the time period of
January 1 through December 31, 2013.
The value for pressure in the Gravity Drainage area has been corrected in 3 exhibits,
1-C, 1-E, 1-F.
The Operators of the Prudhoe Bay Field reserve the right to amend or supplement the
content of the analyses contained in this report at any time based upon the most
recent surveillance information obtained. Any questions can be directed to the
undersigned or to Paulo Ballin at 564-4299, Paulo.Ballin@bp.com.
Sincerely,
Katrina Garner
Head of Base Management
Alaska Reservoir Development, BPXA
564-4212
Attachments: Exhibits 1 through 12
Cc: H. Jamieson, ExxonMobil Alaska, Production Inc.
K. Fishter, ExxonMobil Alaska, Production Inc.
M. Agnew, ExxonMobil Alaska, Production Inc.
E. Reinbold, CPAI
J. Schultz, CPAI
Eric Reinbold CPAI
P. Ayer, Chevron USA
D. Roby, AGGCC
K. Smith, DNR
W. Montague, BPXA
S. Digert, BPXA
J. Starck, BPXA
J. Dean, BPXA
E. Apolianto, BPXA
S. Kent, BPXA
R. Skillern, BPXA
P. Ballin, BPXA
ANNUAL RESERVOIR SURVEILLANCE
REPORT
WATER AND MISCIBLE GAS FLOODS
PRUDHOE OIL POOL
JANUARY THROUGH DECEMBER 2013
2013 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
6
4.0
PROJECT SUMMARIES
7
4.1
Flow Station Two Water / MI Flood Project
7
4.2
Eastern Peripheral Wedge Zone Water / MI Project
8
4.3
Western Peripheral Wedge Zone Water / MI Project
9
4.4
Northwest Fault Block Water / MI Project
10
4.5
Eileen West End Waterflood Project
11
4.6
Gas Cap Water Injection Project
12
4.6.1 Observation Well RST Surveys and Zonal Conformance
12
(includes previous section 4.6.2 used till 2007 report)
4.6.2 2014 Surveillance Plans ns
13
4.6.3 Plans for Change in Project Operation
13
4.7
Put River Pool
14
5.0
GAS MOVEMENT SURVEILLANCE
15
5.1
Gas Movement Summary
15
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
LIST OF EXHIBITS
1-A Prudhoe Bay Unit Field Schematic
1-B PBU Well Statistics
1-C PBU Production / Injection Statistics
1-D PBU Pressure Map
1-E Areally Weighted Average Pressure Plot
1-F Areally Weighted Pressure Data
1-G Average Monthly CGF MI Rates and Compositions
2 Fieldwide Reservoir Balance
3-A FS -2 Base Flood Map
3-B FS -2 Reservoir Balance
3-C FS -2 Areal Average Reservoir Pressure
3-D FS -2 Daily Average RMI
4-A EPWZ Base Flood Map
4-B EPWZ Reservoir Balance
4-C EPWZ Areal Average Reservoir Pressure
4-D EPWZ Daily Average RMI
5-A WPWZ Water/ MI Flood Base Map
5-B WPWZ Reservoir Balance
5-C WPWZ Areal Average Reservoir Pressure
5-D WPWZ Daily Average RMI
6-A NWFB Base Flood Map
6-B NWFB Reservoir Balance
6-C NWFB Areal Average Reservoir Pressure
6-D NWFB Daily Average RMI
7-A
EWE Base Flood Map
7-B
EWE Reservoir Balance
7-C
EWE Daily Average RMI
8 Wells Surveyed for Gas Movement
9 Pressure Surveys
10 S1 Well List
11-1 GCWI Flood Front and Well Locator Map
11-2 GCWI Water Bank Cross-section Interpretation - 2013
12 Put River Lobe Map
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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1.0 INTRODUCTION
As required by Conservation Orders 341C (Approved June 12th, 1997), 341D (Approved
November 30th, 2001) and 559 (Approved November 22, 2005) 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 plus a section for the Put River Pool. The time period covered is
January through December of 2013.
In keeping with the requirements of the Conservation Orders, 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 throughout the 2013 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), and Eileen West End (EWE) along with information on the GCWI in the
Gravity Drainage region and the Put River Pool. Water and miscible gas floods are described in
each section. A separate section has been provided with detailed information on gas -oil contact
surveillance. As agreed in 2004 with the Commission, the discussion of Gas Production
Mechanisms was not included in the report.
In response to the amendment of condition 5 of CO 547.004, an update on the Weatherford Gen -
2 meters in the Prudhoe Bay Unit will be provided in the Satellites surveillance report in
September.
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
2.0 OVERVIEW
Exhibit IA identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as
follows: FS -2, EPWZ, WPWZ, NWFB, EWE, and GD. The Waterflood Project encompasses all
five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active throughout
the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after
successfully establishing EWE injection potential. EWE information since waterflood startup in
September 2001 is 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 are included.
During the report period of January through December 2013, field production averaged 218.0
MBOD, 7144.5 MMSCFD (GOR 32,769 SCF/STB), and 849.8 MBWD (water -cut 79.6 %).
Waterflood project injection during this period averaged 1,385.4 MBWD with 134.3 MMSCFD
of miscible gas injection.
Cumulative water injection in the five major projects from waterflood startup through December
2013 was 11,925 MMSTB, while cumulative MI injection was 3,065 BCF. Cumulative
production since waterflood startup was 2,901 MMSTB oil, 12,247 BCF gas, and 8,330 MMSTB
water. As of December 31, 2013, cumulative production exceeded injection by 7,104 MMRB
compared to 6,676 MMRB at the end of 2012. Similar to last year, production and injection
values have been calculated based upon the waterflood start-up dates for the project areas rather
than for each injection pattern.
Exhibit 1-D provides analysis of pressure static, buildup, and falloff data that was collected from
2011 through 2013 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. Using the
three year rolling technique improves the statistical validity of the pressure distribution since it
roughly triples the number of data points employed versus only using the current year static
pressures.
As in the past, abnormal pressures, such as pressures taken in fault compartments and in the Sag
Formation have been removed. As shown in Exhibit IE, the historic pressure decline appears to
have stabilized due to gas -cap water injection with 62% of repeat 2013 pressure surveys found
equal to or greater than their 2011 or 2012 pressure measurements. For 2013, average pressure in
the PBMGP project areas using three years of pressure static measurements was calculated to be
3,347.6 psia by areal weighting, as compared to 3,348 in 2012 (Exhibit 1F). The GD area
pressure was stable decreasing seven psi from 3,283 psia in 2012 toW-276 in 2013. This subtle
pressure decrease is within the expected statistical variation with a different annual pressure
sampling data sets.
Confirmed MI breakthrough has occurred in 85 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
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
previous year showed MI breakthrough in 109 wells. This number is stable and inside expected
variation considering that similar MI volume was injected in the PBMGP areas between the two
years.
Exhibit 1-G shows the 2013 average monthly CGF MI rates and compositions for the field.
3.0 PRESSURE UPDATE
3.1 Pressure Monitoring
Exhibit 9 provides pressure, buildup, and falloff data collected in 2013 at a datum of 8,800 ft,
subsea used for the Full Field Dominant Zone. For this report, as 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 good communication with the rest of the reservoir, have been
excluded from Exhibit I -D. Also excluded were wells shut-in less than a week that had not
stabilized as compared to offsetting statics, as well as the pressure data acquired by SRT —
Echometer, which were used for internal technical analysis and calibration purpose only. Other
wells completed in Zone 1 and Zone 413, which are in poor communication with the rest of the
reservoir and therefore have lower pressures, were still included in the map and calculations if
their shut-in times were deemed long enough. The excluded pressure measurements are listed
separately in Exhibit 9. 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
8,800' SS.
It was agreed with the commission that the polygon pressures would be calculated differently
starting with the 2005 than it had in past reports due to the advent of pressure response to gas -
cap water injection. That methodology consisted of utilizing only the pressure gathered during
the reporting period. Starting with the 2009 report, since the field pressure has stabilized,
pressure points from a rolling three year period will be used to construct the pressure map so as
to reduce the statistical variation induced by changing year-to-year well sets. Exhibit I -D
illustrates the 2013 pressure map using 2011 through 2013 data points.
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 2014
calls for collection of 80 pressure surveys fieldwide. The number of surveys proposed is similar
to last year.
Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run
during 2013 is presented in Exhibit 9.
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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4.0 PROJECT SUMMARIES
4.1 Flow Station Two Water / MI Flood Project
The Flow Station Two area (FS -2), which comprises the eastern third of the Eastern Operating
Area, is shown in Exhibit 3-A. The locations of production and injection wells are shown with
the EOR injection patterns identified. There were 100 producing wells and 61 injection wells
that contributed to production/injection during 2013 within the FS -2 flood area.
Production/injection data was calculated with the polygon boundaries as in last year's report.
The FS -2 waterflood area oil production averaged 21.7 MBOD for 2013 compared to 27.1
MBOD in 2012. Cumulative production since waterflood start-up through the end of 2013 is
1,073 MMSTB of oil 5,473 BCF of gas, and 4,240 MMSTB of water.
Injection rates averaged 386 MBWD and 50.2 MMSCFD in 2013. Since 12/31/11, the
waterflood imbalance has increased from a cumulative under injection of 2,526 MMRB to 2,671
MMRB under injected. During the report period, production exceeded injection by 145 MMRB.
Under -injection is related to production of free gas influxing from the gravity drainage region
which should not be replaced so as to maintain a steady declining gas contact. Waterflood
strategy is to replace voidage on a zonal basis after accounting for the free gas influx.
Cumulative water and MI injection since waterflood start-up, through the end of 2013, is 6,262
MMSTB and 1,031 BCF respectively.
The flood area's GOR decreased from an average of 26,522 SCF/STB in 2012 to an average of
23,851 SCF/STB in 2013. Gas influx continues along the FS-2/GD GDWFI area, and in the high
permeability conglomerates in the Updip Victor area. Water -cut stayed the same, at 94%, from
2012 to 2013.
A breakdown of the production and injection data is provided in Exhibit 3-B for the report
period. See Exhibit 1-C for a comparison of the cumulative figures with last year's AOGCC
report.
Exhibit 3-C presents the areal average waterflood pressure change over time. The pressure in the
FS -2 area was 3391 psia in 2013. This is an increase of 16 psi over the 2012 pressure.
Exhibit 3-D is a presentation of 2013 average returned MI (RMI) rates. Miscible gas return has
been confirmed in 21 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 4-A. In 2013, oil production averaged 17.8 MBOD, as compared to 17.1 MBOD in
2012, with an average 90% water cut and 21,067 SCF/STB Gas Oil Ratio. Injection averaged
147.9 MBWD and 34.4 MMSCFD of miscible injectant (MI).
There are a total of 71 producers and 30 injectors in the flood area that contributed to
production/injection during 2013. Of the 30 injectors, 4 injected miscible gas at some point
throughout the year, while the remaining wells injected water only.
Production and injection values have been calculated using polygon boundaries the same as last
year's report. Two waterflood start-up dates have been used, 12/30/82 for the DS 13 flood and
8/20/84 for the down -dip sections, rather than the start-up dates of each injection pattern. A
Cumulative total of 634 MMSTB of oil, 3,189 BSCF of gas, and 1,655 MMSTB of water have
been produced with 2152 MMSTB of water and 663 BSCF of miscible gas injected. Exhibit 4-B
shows the monthly injected and produced volumes on a reservoir barrel basis during 2013 and
provides cumulative volumes since injection began. During the report period, production
exceeded injection by 126 MMRB .
Exhibit 4-C shows the trend of reservoir pressure change in the EPWZ flood area with time. The
area receives pressure support from pattern injection, some aquifer influx, and GCWI. Faulting
and out of conformance injection can impair flood performance in some areas. Areas of low
pressure are being addressed by flood management strategies designed to increase voidage
replacement. The EPWZ pressure was 3335 psia in 2013. This is a decrease of 4 psi as
compared to 2012.
Exhibit 4-D shows the 2013 average of estimated RMI rates in producers, as calculated from
well tests and from numerous produced gas sample analyses. Miscible gas returns have been
confirmed in 20 wells (RMI >200 MSCFD).
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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4.3 Western Peripheral Wedge Zone Water / MI Flood Project
Exhibit 5-A is a map of the Western Peripheral Wedge Zone (WPWZ) water and miscible gas
(MI) flood areas. During the report period oil production averaged 20.6 MBOD, as compared to
20.4 MBOD in 2012, with a gas/oil ratio of 14,695 SCF/STB and a watercut of 87%. Injection
averaged 114.9 MBWD of water and 23.3 MMSCFD of miscible injectant.
For the WPWZ project, 42 injectors (1 I WAG injectors and 31 water injectors, 0 gas injectors),
and 93 producers contributed to the production and injection during 2013. 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 2013 was 1,723
MMSTB while cumulative MI injection was 605 BSCF. Cumulative production since waterflood
start-up is 523 MMSTB oil, 1,917 BSCF gas, and 1280 MMSTB water. As of December 31,
2013 cumulative production exceeded injection by 1218 MMRB. Exhibit 5-13 provides the
monthly injection and production data from 01/13 through 12/13. During the report period,
production exceeded injection by 109 MMRB. The reservoir balance in Exhibit 5-B doesn't
identify support from the aquifer, thereby understating voidage replacement nor does it capture
the production of gas -cap -gas which needs not be replaced. During 2006 a produced water tie -
line was installed connecting two GC -1 slug catchers to GC -3 produced water tanks. This
allowed up -dip Zone 4 waterflood expansion and should allow ideal voidage replacement in the
eastern half of the WPWZ area.
Exhibit 5-C shows that the pressure in the WPWZ was 3,313 psia in 2013. This is a decrease of
37 psi over the pressure reported in 2012.
Exhibit 5-D indicates wells with MI breakthrough and the 12 -month averaged returned MI rates.
Miscible gas breakthrough has been confirmed in 25 wells by gas compositional analysis.
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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4.4 Northwest Fault Block Water / MI Flood Project
Exhibit 6-A is a map of the Northwest Fault Block (NWFB) water and miscible gas (MI) flood
areas. During the report period, oil production averaged 9.6 MBOD, as compared to 10.6 MBOD
in 2012, with a gas/oil ratio of 9,212 SCF/STB and a watercut of 85%. Injection averaged 49.3
MBWD and 5.3 MMSCFD of miscible injectant.
For the NWFB project, 21 injectors (1 WAG injectors, 19 water injectors, and 1 gas injector),
and 63 producers contributed to the production and injection during 2013. The well counts
reflect the number of wells actually contributing to production/injection during the reporting
period.
Production and injection values have been calculated based upon the start-up date for the project
area, 8/13/84. Consistent with last year, production and injection data are calculated on the
single area basis. Cumulative water injection from waterflood start-up in August 1984 through
December 2013 was 1,631 MMSTB while cumulative MI injection was 676 BCF as detailed in
Exhibit 61-C. Cumulative production since waterflood start-up was 597 MMSTB oil, 1,356
BSCF gas, and 1000 MMSTB water. As of December 31, 2013 cumulative production exceeded
injection by 514 MMRB. Exhibit 6-13 provides the monthly injection and production data from
01/13 through 12/13. During the report period, production exceeded injection by 35 MMRB.
However, this does not include support obtained from aquifer influx or gas cap expansion.
The areally weighted pressure in the NWFB area was 3,329 psia in 2013. This is an increase of
27 psi over last year. The historical pressure trend can be seen in exhibit 6-C. The increase in
2004 was largely due to the fact that these polygon's boundaries were expanded to the northwest
with the presence of aquifer area affecting the overall pressure of the northwest fault block.
Exhibit 6-D indicates wells with MI breakthrough and the 12 -month average returned MI rates.
Miscible gas breakthrough has been confirmed in 18 wells by gas compositional analysis.
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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4.5 Eileen West End Waterflood Project
Exhibit 7-A is a map of the Eileen West End (EWE) waterflood area and miscible gas (MI) flood
area. During the report period, oil production averaged 16.4 MBOD, as compared to 19.5
MBOD in 2012, with a gas/oil ratio of 2,903 SCF/STB and water cut of 68%. Injection averaged
39.7 MBWD and 16.9 MMSCFD of miscible gas injectant.
For the EWE project, 17 injectors (3 WAG injector, 12 water injectors and 2 gas injectors), and
64 producers contributed to the production and injection during 2013. The well counts reflect
only the active wells for the year.
Cumulative water injection from waterflood start-up in September 2001 through December 2013
was 160 MMSTB and cumulative MI injection was 90 BCF. Cumulative production since
waterflood start-up was 74 MMSTB oil, 312 BCF gas, and 154 MMSTB water. As of December
31, 2013 cumulative production exceeded injection by 242 MMRB. Exhibit 7-B provides the
monthly injection and production data from January 1, 2013 through December 31, 2013. During
the report period, production exceeded injection by 14 MMRB.
The EWE pressure was 3,663 psia in 2013 representing an average pressure increase of 32 psi
for this area from 2012. Exhibit 7-C indicates wells with MI breakthrough and the 12 -month
average returned MI rates. Miscible gas breakthrough has been confirmed in 7 wells by gas
compositional analysis.
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
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4.6 Gas Cap Water Injection Project
Details of the volume of water injected into the Gas Cap during 2013 are shown below; units in
thousands of barrels of seawater injected per month (MBWPM):
The 2013 volume of sea water injected in the PSI wells was 159.8 million barrels. The
cumulative volume injected at the end of 2013 was 1.69 billion barrels of sea water since the
project startup in 2002.
4.6.1 Observation Well RST Surveys and Zonal Conformance
The RST (Reservoir Saturation Tool) surveys run in offset producers continue to be the primary
method of monitoring water movement from the Gas Cap Water Injection project. These wells
have been logged once or twice a year since injection began. By comparing the latest RST logs
with the baseline and previous logs, the presence of injected water can be readily observed. This
procedure has provided a very clear picture of water in the Ivishak formation and allows the
monitoring of vertical and lateral movement of the waterfront.
Exhibit I1-1 is the locator map for the GCWI area and shows the PSI injectors along with the
observation wells. The dashed purple outline shows the current interpretation of the GCWI
waterfront in map view of zone 2 water propagation. The lines inside the purple outline show
the previous extent of the waterfront in 2012, 2011, 2009, 2008, and 2005. The information
from the RST logging program was also used to develop the updated west -east and north -south
cross sections (Exhibit 11-2) showing the interpretation of the surveillance data for the current
time period.
The most recent round of RST surveillance logs included the following wells: 04-22A, 04-23A,
05-26A, 11-08, 11-31A, 15-07C, 18-13C, L213A, L2-16 and L2 -21A. As the areal and vertical
extent of the water mass becomes larger, the rate of incremental advancement both laterally and
vertically has become noticeably slower in some areas and has noticeably increased in other
areas (south and west). At this point, the changes in the waterfront have followed a relatively
predictable pattern established in recent surveillance, where a portion of incremental waterfront
changes are seen in Zone 2C, as well as advancement in lower zones, particularly to the west in
Zone 1. The 2013 logs continued this pattern, showing a continued lateral advancement of the
Page 12
PSI -01
PSI -05
PSI -06
PSI -07
PSI -08
PSI -09
PSI -10
Total
1/1/2013
2,551
2,374
2,401
2,469
2,440
2,487
2,473
17,194
2/1/2013
2,449
2,436
2,425
2,466
2,454
2,464
2,425
17,120
3/1/2013
1,841
1,827
1,373
1,734
1,681
1,463
1,386
11,303
4/11/20113.
1,823
1,662
1,647
1,740
1,667
1,061
1,700
11,299
5/11/20131
3,112
2,962
3,160
3,194
3,066
3,213 1
3,145
21,851
2,733
2,738
2,810
2,839
2,821
2,854
2,764
19,558
1,157
1,155
1,192
1,189
1,176
1,202
1,187
8,257
811
830
889
910
823
915
889
6,068
P6/1/2013
1,179
984
1,060
952
922
845
852
6,793
2,152
1,914
1,937
2,026
1,985
1,957
1,894
13,864
E1,828
1,530
1,591
1,677
1,680
1,614
1 1,624
11,545
112/11/20131
2,270
2,064
2,108
2,147
2,130
2,152
1 2,090
14,960
The 2013 volume of sea water injected in the PSI wells was 159.8 million barrels. The
cumulative volume injected at the end of 2013 was 1.69 billion barrels of sea water since the
project startup in 2002.
4.6.1 Observation Well RST Surveys and Zonal Conformance
The RST (Reservoir Saturation Tool) surveys run in offset producers continue to be the primary
method of monitoring water movement from the Gas Cap Water Injection project. These wells
have been logged once or twice a year since injection began. By comparing the latest RST logs
with the baseline and previous logs, the presence of injected water can be readily observed. This
procedure has provided a very clear picture of water in the Ivishak formation and allows the
monitoring of vertical and lateral movement of the waterfront.
Exhibit I1-1 is the locator map for the GCWI area and shows the PSI injectors along with the
observation wells. The dashed purple outline shows the current interpretation of the GCWI
waterfront in map view of zone 2 water propagation. The lines inside the purple outline show
the previous extent of the waterfront in 2012, 2011, 2009, 2008, and 2005. The information
from the RST logging program was also used to develop the updated west -east and north -south
cross sections (Exhibit 11-2) showing the interpretation of the surveillance data for the current
time period.
The most recent round of RST surveillance logs included the following wells: 04-22A, 04-23A,
05-26A, 11-08, 11-31A, 15-07C, 18-13C, L213A, L2-16 and L2 -21A. As the areal and vertical
extent of the water mass becomes larger, the rate of incremental advancement both laterally and
vertically has become noticeably slower in some areas and has noticeably increased in other
areas (south and west). At this point, the changes in the waterfront have followed a relatively
predictable pattern established in recent surveillance, where a portion of incremental waterfront
changes are seen in Zone 2C, as well as advancement in lower zones, particularly to the west in
Zone 1. The 2013 logs continued this pattern, showing a continued lateral advancement of the
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2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
water front in Zone 2C with respect to its position in 2011, and a building of water thickness in
Zone 2C and Zone 3.
There is increased lateral movement of water seen to west near the gas injectors. The RST log in
the 15-07C well, located south/southeast of the NGI gas injectors, showed water for the first
time in 2011, increased water column in 2012, and a significant advancement to the west in
2013. The east/west oriented faults may be contributing to the increased rate of movement to the
west. However, there has been no impact on the gas injection rates of the wells closest to GCWI
wells. Water continued to build to the south, as seen by observation wells 18-13C, 05-26A and
11-31A, where additional water column was logged in Zone 2C and Zone 3.
As of 2012 there have been no deviations from the past RST surveillance which has shown that
water first appears on top of a major shale then builds height with time as shown in Exhibit 11-
2. The 24N shale, which forms the base of Zone 2C, is clearly the most prominent unit
controlling the lateral progression of the flood front. However, gas cap water has been produced
from 18-15C in Zone 1 which indicates that the water is potentially transmissible through the
closest fault and draining into the west side where the 24N shale is not present. The flood front
continues to maintain a sloped aspect indicating that gravity has a strong influence on the
process
There is evidence of GCWI production in 4 DS -18 wells (18-2613-18-1813, 18-12C and 18-15C)
but the propagation of the water through the reservoir is still under evaluation. One possibility is
that the water is slumping through fault; but this has not been confirmed.
4.6.2 2014 Surveillance Plans
GCWI Injectors
Injection pressures, rates, and temperatures are recorded for each well every day. Pressure -rate
plots will be routinely monitored for changes in injectivity of the wells.
Observation Well RST's
This program will continue as it has in the past by running RST's every year with the final
timing and locations determined based on the results to date.
Gravity Survey
A gravity survey is not planned for 2014.
4.6.3 Plans for Change in Project Operation
No changes to the Gas Cap Water Injection operation are planned for 2014.
Page 13
2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
4.7 Put River Oil Pool
On November 22, 2005 the AOGCC ruled in Conservation Order 559 that the Western, Central
and Southern Lobes of hydrocarbon bearing Put River sands would be defined as the Put River
Pool and that the Northern lobe would be included in the Prudhoe Oil Pool. Exhibit 12 displays
all four lobes which are in pressure isolation from each other. Additional technical information
was previously supplied with the application which led to Conservation order 559.
2013 Production
For the year 2013, all of the production and injection in the Put River Pool occurred in the
Southern Lobe. Production from the Put River Oil Pool in 2013 averaged 1000 BOPD for the
days the reservoir was in production. The total production of the Put River Pool is coming from
the two Put River well producers, well 02-23A and 02-27A.
Injection in the Southern Lobe of the Put River averaged 3016 BWPD. Cumulative Put River
water injection was 7.51 MMBW through 2013, of which 1.1 MMBW was injected in 2013.
The 2013 cumulative production for the Put River Oil Pool was 193 MBO, 1031 MBW and 73
MMSCF gas. The full life cumulative production for the Put River Oil Pool through December
31, 2013 is 2.75 MMBO and 3.47 BSCF gas.
02-14A will be worked over in 2014 and the Put Pool will be perforated and we will have access
from that well to the Put in case 02-23 and/or 02-27 failed like last year.
2013 Pressures
Put River Pressures taken during 2013 are listed in Exhibit 9. The Southern Lobe pressure
obtained in 02-23A measured 3,811 psi at 8,100' SSTVD in September 2013 and in 02-27A
measured 3,730 psi at 8,100' SSTVD in September 2012.
2013 Surveillance Plan
Southern Lobe —Production will continue from wells 02-23A and 02-27A at around 1000 BOPD
to achieve a voidage replacement ratio of approximately 1.0. If one of these wells fails, 02-14A
Put perforations will be produced. Static pressures will be taken periodically through the year to
confirm volumetric calculations. No tracer breakthrough was observed in 2012 or 2013, but
reservoir connection is evident through pressures.
Western Lobe - No 2013 production or surveillance planned.
Central Lobe - No 2013 production or surveillance planned.
Page 14
2013 ANNUAL RESERVOIR SURVEILLANCE REPORT
PRUDHOE BAY UNIT
5.0 GAS MOVEMENT SURVEILLANCE
The report on gas movement surveillance activities and interpretations provides an overall
summary of gas influx movement and summarizes the 2009 gas -monitoring logging program.
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 (GD)
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 GD 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 GD 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 regionally continuous shales. Such lenses
have been identified from neutron logs. Many lenses continue to exhibit oil drainage over time,
while others appear isolated.
Exhibit 8 lists the open and cased -hole neutron logs, as well as RST logs, run in the Prudhoe Bay
Unit during the gas -influx reporting period from January 2013 through December 2013. A total
of 98 gas -monitoring logs were run in the PBU of which 81 were cased -hole.
Page 15
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by Exhibit 1-D
0 Greater Prudhoe Bay 2013
Reservoir Pressure Map
NWFB T Kms.
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2013 Reservior Pressure•
2011 SBHP Well Test
at 8800' SS Datum
• 2012 SBHP Well Test
3,050 - 3;150 psi
Q 2013 SBHP Well Test
3,150 - 3,225 psi
Prudhoe Bay
3,225 - 3,300 psi
Unit Boundary
3,300 - 3,420 psi
Qepletion Polygons
3,420 - 3,550 psi
3,550 - 3,680 psi
NOTE: Engineered control
3,680 - 3,790 psi
points have been added to
3,790 - 3,890 psi
the field permiter to provide
-
3,890 - 4,000 psi
a more accurate contouring.
0 5.000 10.000 :\5 X U
30.000 40,000
Fow
Gas Cap
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Exhibit 1-F
Areally Weighted Average Pressure Table
DATE
FS2
EPWZ
WPWZ
NWFB
GD
EWE
PBMGP
Dec -77
3935
4005
4016
3944
3999
3968
Jul -78
3870
3967
3978
3909
3963
3914
Dec -78
3832
3930
3944
3875
3933
3873
Jul -79
3813
3895
3911
3843
3901
3844
Dec -79
3791
3861
3879
3799
3871
3816
Jul -80
3799
3831
3848
3770
3856
3798
Dec -80
3852
3819
3822
3781
3823
3818
Jul -81
3881
3821
3799
3814
3809
3840
Dec -81
3880
3815
3799
3820
3793
3842
Jul -82
3872
3806
3800
3812
3778
3833
Dec -82
3850
3795
3797
3804
3762
3818
Jul -83
3831
3784
3792
3787
3745
3804
Jan -84
3814
3771
3783
3772
3728
3790
Jul -84
3796
3758
3777
3756
3711
3774
Jan -89
3779
3743
3771
3736
3695
3755
Jul -89
3760
3730
3763
3723
3678
3740
Jan -90
3732
3708
3731
3704
3658
3713
Jul -90
3708
3693
3716
3687
3641
3695
Jan -91
3680
3676
3694
3655
3623
3666
Jul -91
3642
3657
3673
3628
3605
3635
Jan -92
3617
3641
3652
3602
3588
3615
Jul -92
3591
3626
3632
3577
3570
3593
Jan -93
3561
3600
3619
3544
3549
3582
Jul -93
3543
3595
3598
3515
3531
3565
Jan -94
3539
3555
3578
3483
3512
3537
Jul -94
3523
3536
3555
3456
3492
3516
Jan -95
3496
3524
3555
3507
3482
3506
Jul -95
3473
3507
3536
3489
3466
3486
Jan -96
3466
3485
3497
3478
3446
3463
Jul -96
3450
3467
3472
3461
3430
3443
Jan -97
3446
3484
3460
3444
3404
3441
Jul -97
3429
3467
3438
3427
3387
3421
Jan -98
3452
3417
3417
3421
3379
3430
Jul -98
3435
3409
3394
3402
3363
3415
Jan -99
3445
3391
3382
3343
3339
3443
Jul -99
3429
3378
3360
3317
3323
3426
Jan -00
3406
3361
3372
3268
3294
3418
Jul -00
3390
3351
3353
3240
3273
3395
Jan -01
3366
3325
3325
3225
3274
3358
Jul -01
3360
3310
3309
3205
3257
3347
Jan -02
3325
3334
3289
3163
3270
3358
Jul -02
3312
3324
3273
3144
3245
3347
Jan -03
3299
3316
3262
3121
3236
3696
3297
Jul -03
3285
3306
3245
3118
3223
3659
3283
Jan -04
3271
3296
3228
3116
3211
3645
3272
Jul -04
3277
3324
3281
3296
3239
3614
3290
Jul -05
3338
3344
3282
3289
3250
3542
3314
Jul -06
3304
3296
3276
3296
3233
3536
3293
Jul -07
3357
3339
3275
3248
3243
3618
3310
Jul -08
3317
3299
3298
3269
3244
3626
3299
Jul -09
3348
3310
3308
3271
3248
3663
3315
Jul -10
3367
3329
3317
3329
3259
3666
3339
Jul -11
3368
3345
3308
3322
3265
3640
3338
Jul -12
3375
3338
3350
3302
3283
3632
3348
Jul -13
3391
3335
3313
3329
3276
3663
3348
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Exhibit 8
2013 Wells Surveyed for Gas Movement
OH - Open Hole Log
CH - Cased Hole Log
2013 Drilling
p
Well
Log Date
OR / CH
GOC (MD)
GOC (7VDss)
1
01-04B
24 -Oct -13
OH
9,440
8,963
2
01-04B
24 -Oct -13
OH
9,440
8,963
3
01-17C
17 -Jan -13
CH
9,670
8,953
4
02-06C
7 -May -13
CH
11,542
8,968
5
02-12D
2 -Feb -13
OH
not present over
logged interval
6
02-13C
6 -May -13
OH
10,475
8,926
7
02-15B
23 -Mar -13
OH
9,659.00
8,881
8
02-38A
4 -Sep -13
CH
9,908
8,731
9
05-16C
26 -Sep -13
CH
11,545
8,718
10
05-35B
11 -Jan -13
CH
10,549
8,842
11
06-02B
24 -Mar -13
CH
10,544
8,916.5
12
06-08B
20 -Mar -13
CH
11,401 &12,349.5
8,916
13
06-22B
9 -Feb -13
CH
10,495.5
8,949.5
14
06-24B
6 -Mar -13
CH
10,056
8,925
15
11-28B
16 -Aug -13
CH
12,243
8,685
16
18-02C
23 -Sep -13
OH
10,910
8,575
17
18-21B
16 -Jul -13
OH
12,040
8,692
18
A -24A
24 -Nov -13
CH
12,750
8,940
19
B -05D
20 -Jun -13
CH
11,130
8,948.5
20
C -32D
1 -Nov -13
CH
10,360
8,940
21
C -41B
1 -Sep -13
CH
11,270
8,889
22
D -16B
16 -Nov -13
CH
11,390
8,912
23
D -31B
5 -Jun -13
CH
9,551
8,918
24
E -16A
22 -Jun -13
CH
9,063
8,972
25
E -25A
8 -Apr -13
CH
9,882
8,864
26
F -01B
2 -Jul -13
CH
9,074.5
8,921
27
F -09C
12 -Oct -13
CH
11,183
8,945
28
F -10C
4 -Aug -13
CH
9,926
8,922.5
29
F -13B
31 -May -13
CH
9,424
8,944
30
F -26C
30 -May -13
CH
10,496
8,956
31
F -26C
18 -Oct -13
CH
10,496
8,956
32
G -12C
18 -May -13
CH
10,394
8,939
33
G -14C
5 -May -13
CH
9,742
8,942
34
J -09B
15 -Apr -13
CH
9,968
8,918
35
J -17D
21 -Mar -13
CH
11,231
8,940
36
J-29
8 -Aug -13
OH
10,627
8,803
37
K -06C
10 -Mar -13
CH
11,297
8,915
38
P -16A
7 -Jul -13
OH
not present over logged interval
39
P-171-1
2 -Jan -13
CH
not present over logged interval
40
P-29
29 -Nov -13
OH
not present over logged interval
41
U-16
1 -Jun -13
OH
not present over logged interval
42
W-51
30 -Jun -13
OH
9,726
8,821
43
W-59
8 -Nov -13
OH
12,315
8,752
44
Z-05
2 -May -13
CH
10,037
8,883
45
Z -05A
21 -Sep -13
CH
11,170
8,850
46
Z -08A
4 -May -13
CH
11,384
8,814
47
Z -17A
31 -Oct -13
CH
13,250
8,811
48
Z-61
15 -Feb -13
OH
not present over logged interval
49
Z-66
22 -Mar -13
OH
10,250
8,780
SO
Z-68
10 -Aug -13
OH
9,896
8,803
51
Z-71
17 -Apr -13
OH
11,121
8,868
OH - Open Hole Log
CH - Cased Hole Log
2023 Surveillance
R
well
Lag Data
OH/CH
GOC (MD)
GOC (TVDss)
1
01-34A
25 -Oct -13
CH
9,128.4
8,822.9
2
04-22A
27 -Sep -13
CH
Not present over logged interval
3
04-23A
18 -Oct -13
CH
9,440.8
8,503.5
4
05-26A
5 -Nov -13
CH
11,000
8,744
5
05-31B
4 -Feb -13
CH
9,195
8,787.1
6
07-02B
5 -Sep -13
CH
11,243.1
8,967.5
7
07-36
26 -Jul -13
CH
10,695
8,898.6
8
09-04A
4 -Nov -13
CH
9,544
8,621.2
9
09-30
28 -Sep -13
CH
11,837
8,554.4
10
09-34A
5 -Nov -13
CH
Not present over logged interval
11
09-45
26 -Jan -13
CH
Not present over logged interval
12
11-08
26 -Dec -13
CH
Not present over logged interval
13
11-18
9 -Nov -13
CH
9,193.5
8,630.8
14
11-31A
2 -Nov -13
CH
Not present over logged interval
15
13-98
19 -Oct -13
CH
Not present over logged interval
16
15-14A
26 -Nov -13
CH
10,574.2
8,830.1
17
15-16B
21 -Oct -13
CH
13,341
8,618.1
18
15-29B
14 -Jun -13
CH
12,477
8,691
19
15-32B
8 -Apr -13
CH
8,950.1
8,780
20
15-34A
6 -Jun -13
CH
11,132
8,725
21
15-39A
17 -Nov -13
CH
9,150.3
8,787.6
22
15-48C
15 -May -13
CH
Not present over logged interval
23
18-01A
21 -Jul -13
CH
10,836
8,716
24
B-07
16 -Aug -13
CH
11,622
8,829.6
25
C -01B
15 -May -13
CH
Not present over logged interval
26
C -07A
28 -Dec -13
CH
12,295
8,942
27
C -39A
11 -Oct -13
CH
10,296.5
8,931
28
D -03A
23 -Oct -13
CH
10,651.5
8,921.5
29
D -19C
27 -May -13
CH
9,290
8,924
30
E -24B
5 -Oct -13
CH
10,695.5
8,843
31
E -35B
25 -Oct -13
CH
11,000
8,993
32
G -02B
5 -Jul -13
CH
10,216
8,874
33
G -02B
9 -Sep -13
CH
10,212
8,872.5
34
G -06A
6 -Sep -13
CH
9,518
8,885
35
G -15B
27 -Jan -13
CH
10,070
8,873
36 j
H -05B
j 8 -May -13
CH
11,349
8,954
37
H -22A
13 -Jun -13
CH
9,618
8,724
38
J -08A
8 -Sep -13
CH
12,017
8,922
39
N -01A
2 -Mar -13
CH
9,290.5
8,723.5
40
N -14B
18 -May -13
CH
9,644
8,777.5
41
Q -04B
11 -Mar -13
CH
9,388.5
8,951.5
42
Q -05B
1 -May -13
CH
10,103.5
8,916.5
43
Q -07B
13 -Feb -13
CH
11,615.5
8,936.5
44
W-30
11 -Dec -13
CH
9,677
8,802
45
W -32A
10 -Oct -13
CH
9,823
8,807
46
X -16A
20 -Jul -13
CH
10,508
8,739.6
47
Z-67
18 -Apr -13
I CH
9,790
8,620
OH - Open Hole Log
CH - Cased Hole Log
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Exhibit 10
9A V% ICA Chut In Well RennrF
sw name
Field
API. Number
W Date
Reason for Well
Shut-in'
Future Utility Plans &
Posslbilitiesa Current Mechanical Condition / Additional Comments
C -23D
PRUDHOE
500292077504
8/26/2013
1
3 CST 1212013. Waitim to PQP.
15-45C
PRUDHOE
500292267103
911212012
1
5 Sept -12 Z113 10' Add erfs failed. High GOR.
71-32C
PRUDHOE
500292192403
111/2010,
2
3 High WC_ LookLna at ST o lions. current) ST (20141.
01-02
PRUDHOE
500292005300
12!2012011
6
6 IBP Stuck. Looking at WW to remove. 85% donw with RWO
01-09A
PRUDHOE
500292016401
3/19/2007
7'
SI due to prod casing leak, & flow line repairs needed. Not economic to repair flowline
7 at this stage. Also needs RWO, Flowline
D1-11
PRUDHOE
500292[]26800
4/2712012
7
7 Flowline raptured.
01-15A
PRUDHOE
500292028701
9/22/Z011
31
3 well had low Pt and was a sand producer. Well is now in NWD hands
01-16
PRUDHOE
500292028800
11/11/2011
EI
Well needs RWO to restore integrity. —5 bpm leak at the K -Anchor and a high
probability of pin-hole leaks from numerous joint in well. Also appears to be corrosion /
erosion damage at either end of the existing patch. Got a waiver from the state to BOL
6 to
01-23
PRUDHOE
500292085400
2/2/2012
5
SI due to possible solid production. Doing FCO/PPROF/ASRC welltest. Going to try a
5 sand shut off,
01-31
PRUDHOE
500292162600
12/24/2011
Requires DH Screen. Pre work for sand consolidation is done, just waitng for wells
5 group and sand mane ement team to pump.
02-05A
PRUDHOE
500292008101
1/1/2009,
6
6 Well released to NWD for RWO/CTD- In plan for beginning of 2014.
02-176
PRUDHOE
500292045302
8/30/2011
7'
Flowline VSM Issues plus high GOR well. Need to talk to ops about POPing before
7 deridin if we should release to NWD.
02-20
PRUDHOE
500292072100
612212011
6
MAA. Under WIE evaluation.
0224A
PRUDHOE
500292074401
WM201 11
EI
6Tx16L Patch set in 9113 but failed MIT- LDL proararn in proaress.
02-26C
PRUDHOE
500292077403
417120071
6
6• RWO package on schedule
02-30B
PRUDHOE
500292220202
9/1/2008
6
6.Well $ ended.
02-31A
PRUDHOE
500292722701
7121/2012
1
1 Hi h GOR, Want to cycle but have to wait until 02-01 drilling complete
02-39A
PRUDHOE
500292272101
1011912007'
1
Can't pull LTP. D&T fish and welltest to evaluate healing after being SI for 3 year. Need
5. to SI 02-40 to POP this well. Sidetrack candidate.
D3 -15A
PRUDHOE
500292041401 _
8/2012011
6
Has IAxOA unmanageable by bleeds while using AL. Unstable producer because of lov
5• rate.
03-26
PRUDHOE
500292102700
719120091
3
SI for high watercut and low oil rate_ Evaulating GL optimization. Well has a lot ofjunk
3• which prevents water shut off.
03-29
PRUDHOE
500292111800
3/5/2006
6
Wellhead weld was done in Sep12 and No surface -breaking defects were found and
the well passed the Dye Penetrant test "PT" on 25Sep12. Well passed the pack -off seal
6 assembly test wellhead casing valves but after setting d Iv's in all the stations we we
03-34B
PRUDHOE
50Q2.92113202
411012010
6
Well was repaired with RWO EOS 2010 but furmanite wrap began leaking shortly after
POP. Re -wrapped with Furmanie but it leaked again. When flowing after last wrap the
6 poor. Not pursuing another repair -
04 -04A
PRUDHOE
500292009601
111!1995
6
61 CTD BHAstuck in a window and no flowline. Well classified as suspended.
04-05A
PRUDHOE
6002920107(11
1110/2010
6
B IAx0A and h h GOR. WC working on POP UNDER EVAL for W noslics.
04-07
PRUDHOE
600292018900
11111997
7
Originally SI for high WC; well slot/piping in manifold has been removed so unable to
7' pursue wellwork options. Well does not justify surface repair.
04-09
PRUDHOE
500292020700
1011712012
6
2 NntO erahla_
04-14
PRUDHOE
600292031000
12/20/20111
7
7 Flowline needs to be repaired. Package Approved
04-17
PRUDHOE-
600292153200
8/9/2012
7
7 Flowline/Surface
04-26
PRUDHOE
500292152000
5/31/2011
3
3 IJiqh WC. low oiI110R. No current plans. Well is now P&A -ed
04-28
PRUDHOE
600292148800
7/29/2010
B
TxlA. Tubing patch failed; considered pkr squeeze, however some uncertainty given FL
Is slated for SI Dec 2012 due to wall loss and FL replacement will likely not compete for
1 expense dollars. Pkr ueana econ payout is 1 years, but would only have 18 mont
04-30
PRUDHOE
500292134500
4125/20111
3•
3 Oil Wumn disappeared; FC01adperf program on W81, -
04-32A
PRUDHOE
500292132601
4111/20111
2
Currently SI for high WC. Split in S -Riser. Operations repaired S -riser 517/11 and now
2 waltina ons ace at FS2 to return well to service.
04-34A
PRUDHOE.
500292216001
11/19/1997
22
WC, low IOIZ Flowline not fit for service.
04-35A
PRUDHOE
500292214701
1/8/2011
2'
High WC, low IOR. Wellbore previously planned to be used for Beach Boys target (WID
2 signed 2/3/11. Higher risk ad erfs tables because flowline not fit for service -
04 -36
PRUDHOE
500292216200
11/14/2001
2
2 Fit h WC, low IOR.
04-40
PRUDHOE
500292222400
5/23/2010
7'
SI for velocity excursion. Total gas rate needs to be below 6 MMCFD in LP/19 MMCFD
7 In HP. Evaluating WSO options.
04-42
PRUDHOE
500292222900
8/18/2012
6
SC Leak. ResMan to determine if we can justify a fix for this well. Major contibutor to
8 excess water at FS2
04-43
PRUDHOE
500292244300
1 122OL20111
7'
7 FL repair package submitted
04-46
PRUDHOE
500292243400
2f13120111
2 Hiab WC. Evaluating wellwork options -
tions.SC
04-48
PRUDHOE
500292249800
8115120101
EI
SC leak & TxIA. Secure program on WBL. RWO pkg internally approved on 2/7/11.
WIO's will not sign off. 04-48 is on SC Excavation repair backlog. Leaving as RWO
6 candidate pending kick-off of excavation work
05-03C
PRUDHOE
500292014703
1/11/2012
7
7 Flowline corrosion.
05-06A
PRUDHOE
500292017301
10/15/2010
6
6 Released to NWD
05-126
JPRUDHOE
500292024402
1119/2005
6
Originall SI for High GOR. Now Mechanical. Evaluating the reserves to opt for
6 wellwork/RWO or sidetrack
05-13B
PRUDHOE.
500292025002
3/1/2010
6
6RWO cu letecL waituia for 23/8"coil tubin to pullstuck plug
05-17B
PRUDHOE
500292027102
11/112002
6
B Low existing value - collapsed tb
05-18A
PRUDHOE
500292196001
2/3/2003
1.
1 Casing Leak. Slimhole. RST package in Hopper though High cost wel.
05-21A
PRUDHOE
500292196901
1018/2011
1
1 High GOR
05-25C
PRUDHOE
500292198803
911SQ0121
1
1 Hi h GOR.
05-34A
PRUDHOE
500292221701
2/10/2012;
ti
1 High GOR
05-39
PRUDHOE
500292271500
7/3120101
7
7 RWO SOR submitted 20 2013.
0540
PRUDHOE
500292270700
11/1/2002'
6
6 Failed RWO - stuck CT durina cleanout
06-03A
PRUDHOE
500292018601
9/28/2012
7
DS6 CL velocity reduced. Economic because should cycle on with higher IOR, and
7' maybe do future ad erf.
D6-15
PRUDHOE
1500292045900
7/15/2006
6
Surface casing leak, Integrity team suggests P&A. Released to NWD for excavation
61 repair + sidetrack but not sure if theX have a tar et identified -
06 -17
PRUDHOE
500292076000
511120041
6
6 Well is abandoned.
07-07B
PRUDHOE
500292090101
3/1/2010
6
EI TxIA. Rig ST candidate. 2 DWP Patches over collar leaks, 11 DGLVs, high GOR.
07-16A
PRUDHOE
50(1292085601
911120111
6
6 RWO on schedule for May, 2013. SI for SC leak & IAxOA comm. LP access only.
07-18
PRUDHOE
500292087900
1/11/2011
6
6 Surface Casing leak. Not Operable. Need Rig ST,
07-21
PRUDHOE
500292090700
1/i 0120101
6
6 RWO schedule
07-34A
PRUDHOE
5nm421a12n1
d/RI90pF'
6
RW0 failure Feb, 2013. Rig Sidetrack candidate. IAxOA; Stuck IBP fish in tubing. Rig
6 ST candidate. but LP access only.
Exhibit 10
9mn IPA 4hnt J. Wau Ronnrt
Reason roe Wall
Future Utility Plans &
sw name
Field
API Number
SI Data
Shut-inA
Possibilitiess Currant Mechanical Condition / Additional Comments
07-35A
PRUDHOE
500292281101
1/13/2013;
7
7 Shut-in for 7C115C commanline velocity. Water cut is too high and affects velocity limit.
SI for high WC and H2S. Reservoir needs time to recover from over -injection. Injection
rates reduced in Spring 2011 but this area of DS09 has been dump flooded for years.
09-05A
PRUDHOE
500292021501
11/24/2009
2
1 There may not be a lot left for this well. On WBL for WSO. HEX Plug failed. Need
SI for high WC and 1-12S. Reservoir needs time to recover from over -injection, Injection/
rates reduced in Spring 2011 but this area of DS09 has been dump flooded for years.
09-09
PRUDHOE
500292023200
1/812011
2
1 There may not be a lot left for this well. On WBL for WSO. HEX Plug failed. Need
SI for Organoseal Job to squeeze off zone 3. Cement squeeze with Fiber was partially
09-18
PRUDHOE
500292025900
6/14/2012!
5
5- successful. New Job submitted in JMS
IAxOA after RWO cemented OA to surface, high OAP due to external gas, working on
solutions. Well Integrity is POPing these wells one by one. Still hoping to get well
09-23A
PRUDHOE
500292106601
7/16/2008
6•
fit POPed under eval.
09-24
PRUDHOE
500292142800
5/15/2012
2
2 High Water cut. WID•ed for Coll ST ELVEDERE
Shut in for high WC, Needs Zone 4 squeeze of 2009 adperfs. Was on hold due to
LoSal pilot but actions can be progressed now. Would need flowline sleeves to com
09-28A
PRUDHOE
500292129201
8/23/2009
2!
2! back online- PMPs have WO submitted.
09-34A
PRUDHOE
SW292132901
5110/Z012
31
31 Low Pl High GOR, Ftl WC. RPM and AdPod on WK
Attempted packer squeeze summer 2010- Pressure tests failed. Needs evaluation on
other wellwork fixes. If no wellwork fix there is no utilization. In dual injector pattern
09-37
PRUDHOE
500292245100
717=09
a
6 with 09-17.
Infector injects out of zone for pattern conformance. In dual injector Pattern vdth 49.161
which injects into Z4. No plans to restore injetion due to over injection in this area of
09-38
PRUDHOE
500292191900
4/10/20111
El
EI DS09.Candldatefor Z4 MIST trials
09-42A
1PRUDHOE
500292205901
12112/2002
EI
6 2006 RWO falled- Now s161a SC look. No rill fix for this well -
09 -44A
PRUDHOE
500292208701
10/3/2008
6
5 ST In 2010 failed. Wolfing on revised target. well plan & risk assessment.
High WC, low PI. WID'd for Coil ST (5 -spot Reconfiguration). Sidetrack delayed for
09-47
PRUDHOE
500292209800
9/21/2011
2!
2 excavation work. Excavation current/ on-going
IAxOA to gas- not manageable by bleeds. Economics don't justify RWO unless Res
09-48
PRUDHOE
500292212800
11/30/2004
Et
6 Man uses as sidetrack candidate or adds lateral. RWO package in motion
09-49
PRUDHOE
500292231700
9/21/2011
2
2 H h WC. WID-ed For Sidetrack SANTANAfROOTS
SI for high WC. Could rotary drill good DS09 targel'Yes" from here. 2014 Rig Stdelra
09-50
PRUDHOE
500292232500
2/1412010,
2
2 (5 -spot Reran} uraaon
09-51
PRUDHOE
500292232000
11128 012
7'
7 Supposed to o on PWI but Frank on PWI line.
11-12
PRUDHOE
500292121200
12/7/20101
1
1 come back but the well is blinded and since FS2 is water limited, ops not willing to
11-17A
PRUDHOE
500292159801
5117/2012
3
3 Low Pt. RPM on WBLpossible add perf.WeltIscurrent l blinded.
11-25A
PRUDHOE
500292048802
21`1112002
6
6 PC Leak and IAxOA Communication, No current ans.
11-29
PRUDHOE
500292246600
21112006•
6
7 TAA that acts like a one-way leak.
SI for velocity excursion. And F rank on S riser, Well is twinned with a more competitive
wall and both cannot flow into the twinned line at current gas rates. Have S -riser
11-34
PRUDHOE
500292251600
3/1/2011
7
7 package Nowl by Trina iNWrmg on FS2 NdIRY FS+ r and CIPS lineline teem to Cres
Water injection line inoperable, waiting on repair- Slight TxIA comm, hot MIT -IA to
confirm integrity post-flowline repair planned. We have SealTite job on WBL to fix well,
11-35
PRUDHOE
600292247600
5/12/2008
6
1 estimated to happen 1Q13. Flowline is fixed Flowline
11-36
PRUDHOE
500292247700
8f31f20T0
6
6• SC leak; Brinker treatment failed. Well does not justify RWO. On excavation list.
High OA pressure post RWO that cemented OA, Seal -Tice tried twice but failed.
12-03
PRUDHOE
500292037700
1/29/2009!
6.
6 WajUna to be handled as a biguer project.
High OA pressure post RWO that cemented OA. Waiting to be handled as a bigger
1207A
PRUDHOE.
500292040901
5/29/20091
6.
6 protect
12-30
PRUDHOE
600292189100
1111312013
7
7 Choke started leakinQ from the stem pecking. wadifing on peftL
TxIAxOA; produces rocks, sand screen installed, swiss cheese tubing. Pians to further
diagnose. Well to be Non -rig Reservoir Abandoned. Dec 2012: Decided to proceed with/
13-04
PRUDHOE
500292032600
10/3/2002[
6;1
EI RWO. not to be abandoned! Working on the RWO packaQe
TxIAxOA; replaced by 13-06Ai MI injector. FL decommissioned 8/09. No plans at this
13-05
PRUDHOE
500292062600
11/1/1997
6,
6 time. P&A with Cement PLua in 2004. Well was reservoir abandoned in 2012-
13-10
PRUDHOE
500292067800
6/1/19941
61
El IAxOA on GL: uneconomic RWO hi h WCJ_ No plans at this time. Released.
TxIA & possible packer or PC leak.NWD screening for ST. Idea to run LDL to evaluate
13-11
PRUDHOE
500292060400
12/5/2005
EI
EI If patch is an o
Waiting on MI Supply flowline repair to DS 13/14. MI line repaired to DS, well can't be
on water due to broken PWI line. Changed SI opportunity due to flow line package
13-17
PRUDHOE
500292071800
5/9/20111
'51
5 beina issued.
13-25
PRUDHOE
500292076100
1012112007
6
6 TxIA
Jax P2 sidelrack into SAG. Not purumd any further at Ihls stage, but CST could be an
13-26
PRUDHOE
500292074600
10/1112011
6
EI o Win
13-28
PRUDHOE
500292094200
511(1994
6
Et PC leak & bubbles in the cellar. Replaced by 13-13A.
13-30C
PRUDHOE
500292076803
10/29/2011
3
3 Low Pl. No Res. Pressure. Needs in
13-33
PRUDHOE
500292077300
12(111994
6
6 TxlAxOk.Well to be Non-riQ Reservoir Abandoned in 2012 or early 2013).
13-36
PRUDHOE
500292261300
9/23/2010
6
6 TXIA and possible IAxOA
TxIA and leaky 9-5/8" scab. Present to WIC to POP well under evaluation to see if it's a
competitive well and look at options for fixing the well (Non -rig vs. RWO). Wells group
14-03A
PRUDHOE.
500292031901
8/5/2009
E!
6 wants to abandon well.
Ran LDL in September'12, found leak, need to evaluate patch options- RWO signed in
14-09B
PRUDHOE
500292053402
9/5/2012
6
7 June 2013 and is scheduled for April 2014.
IAxOA and flowline; uneconomic RWO. Flowline replacement not planned due to lack o
14-14
PRUDHOE
500292062500
8/10/2006
7
7 reserves to justify entire project. Flowline
14-24
PRUGHOE
500292097000
12/62012
4
4 Sand back over Ivishak Sag frac is scheduled for Q1 2014.
Well failed MIT -IA Nov'12 and LDL found 5leaks. Already has patch, needs a RWO.
Quick Connect Liner Latch can be installed with slickline, but production needs to be
14-26
PRUDHOE
500292063200
9/12/2012
6
6.1 modelled through QCLL.
Reserves ranked high. FL repair complete 3Q11, POI waiting on IWL completion.
1217/11: Needs a new choke (not ordered @ time of FL replacement); 1Q12
replacement anticipated (3 month lead time on parts). Flowline replaced, but well
14-27
PRUDHOE
1500292104600
11/17/20041
6,
fit developed downhole rob
SAG well, drilled across fault, poor cement job, water comes up from Ivishak. Don't see
la_28A
PRUDHOE
600292070801
1 12/31/2012
2'
2 any way to isolate water from fault.
Exhibit 10
I. W.11 M.-4
sw name
Field
API Number
SI Date
Reason for Well
Shut -In"
Future Utility Plans &
Possibilitiesa Currunl Mechanical Condition / Additional Comments
14-31
PRUDHOE
500292098900
7/26/2007
6
TxIA poor tubing, low rate for the last 6 months of life. Previously considered for UZT,
but project on hold due to FS3 projected water limitations. RWO package has been
6 issued. On rig schedule for May 2014.
14-37
PRUDROE
500292181000
8f3W2005
6
6 Tx1Ax0A' RWO package issued and approved. Schadutad for May 2014.
14-39
PRUDHOE
500292188800
6/1/1994
EI
IAxOAxForm. Leak @ 81'. Flowline is corroded and not fit for service. Fullbore partial
6 P&A completed in 11/10 with 5000' of cement in IA & TBG.
15-12B
PRUDHOE
500292A66502
7/10/20101
1
Choke removed 8/1/10 (erosion). High GOR. Jul -10 Plug/perftested all gas. Sidetrack
1 candidate.
15-15C
PRUDHOE
500282069103
9M/20091
1
1 Well has PC leak. Alm Ugh GOR. POP to got tales for RWO SIM
15-19A
PRUDHOE
500292182901
7/9/200911
Pulled leaking patch over parted tubing @ - 3000' MD & Liner Top Packer, calipered
liner, logged SCMT, set WRP then performed passing CMITxIA to 2500 psi before
securing. Re -set the LTP in 9108 and well tested all gas. LTP pulled & re -set with CTU
6 in Jul
15-25B
PRUDHOE
500292184202
711212012
6
6. 17 tubing leaks and PC leak. RWO SOS is being worked.
15-28A
PRUDHOE
500292224701
3/1/2004
61
6, MITOA Falls, has cretaceous leak. Twinned wilh 15.22.
15-30B
PRUDHOE
500292228202
9/12/2012
1
1 Reset liner top packeronWBL.
15-338
PRUDHOE
500292244802
6/11/2011
1
1 End -of -life add erfs failed. Sidetrack planning delayed due to maEIjinal tubin 10/26/11
15-35
PRUDHOE
500292248800
9!3/2003
6
61 Cret kak, dumpflooded Ivishak,TXIA and PC leak
15-40A
PRUDHOE
500292251101
9/10/201 Et
1
1 High GOR. PWgfpmf failed In Set -11 0. E -line RSTAaddperf program being worked.
15-41B
PRUDHOE
500292249202
2/5/2007
7
Put/lvishak comingling issue & already swept Ivishak zone makes welfwork unattractive
5 No sidetrack tar et.
15-42B
PRUDHOE
500292262402
311120101
1
1 High GOR. Sidetrack candidate.
15-43
PRUDHOE
500292267600
12/8/2009
6.
6 Well developed Sr_ leak at The wellhead on Dec 24. 2008, Sealille failed Sept -1 0.
15-46
PRUDHOE
500292266500
9129120111
6
MIT -OA Passed to 1000 psi w/diesel; MIT -OA Failed to N2 w/ increase in N2, CO2,
and LEL's confirming SC leak, Set TTP @ 10,130 for secure. DHD set to establish /
2 locate SC leak depth. Possible Brinker candidate.
15-47
PRUDHOE
500292261700
101112002.
6
Reservoir P&A'd In 2011. Thg very rolten, ]A cemenled. Well secured w/ sand plug
EI chunks of N fal[ng down on plug. BH Incatlon Minced by 15.14A in 2005.
16-05A
PRUDHOE
500292057401
12/5/20111
6
PC leak at 6130' MD. Will pad heal In movable oil Z4 t0 check injectivity. If good, will
7 work over. If not good will give to reservoir management for sidalrack.
16-06B
PRUDHOE
500292058402
9/3120111
7
7 VSMIFlowline.Coniad Storman Norman for mgnsw. Faclilty Contralned
16-09A
PRUDHOE
500292055801
10/15/2007
6
Wells group has pushed toolstring down hole. Going to wait till it gets closer to time for
VSM to be repaired then do last welfwork package (SL punch holes). Facility
6 Constrained
16-24
PRUDHOE
500292153600
7/612006
E1
El TAA commuoicalionand tow productivity-
roductivit -SI
16-28
PRUDHOE
500292227600
1015/2005
6
SIfor high WC, SC leak. Will be non -dg reservoir abandoned. Wells group is also
6 working on possible surface casina repair to reinstate intearity to this well.
16-29A
PRUDHOE
500292227201
1116/2006
31
On Wells to be POP'd. Has a tow WOR and we need wells with low WOR since we are
3 awater conslrainsd facAil .
16-31
PRUDHOE
500292228000
4/111995
3
SI for low Pl. TxIA to gas only- needs GL to produce. In pattern with injector which
3• injects out of zone.
17-04B
PRUDHOE
500292049802
!1!213!2012
Z
2• HIGH WATER CUT
17-20
PRUDHOE
500292230000
802012
2
2' High WC
18-04C
PRUDHOE
500292087503
1/1/2007
1
3, RST 1Q 2014
18-11A
PRUDHOE
500292118101
7/10/2010
6
6. PC leak. High risk WO.NFU
18-13C
PRUDHOE
500292175603
411312012
11
1 Wekwark on. WBL
18-14C
PRUDHOE
500292161403
10/10/2012.
V
1 Fishing proposal wailing on Well Group input
18-19
PRUDHOE
500292159600
9/11200111
6
6 AnnComm, RWO on schedule
18-20
PRUDHOE
500292189000
6(7/2009
6
6 PC leak 7900' & 6100' md. High risk WO
18-23A
PRUDHOE
500292189801
7/112010
1
1 Well with slotted liner. No possibilities for GSO
18-25A
PRUDHOE
500292194801
572/2003
6
6 Cretaceous leak. No future utility. FL was donaied to well 18-15.
18-28
PRUDHOE
500292256400
1/112001
6
5 Hote in N andcasing. CTU Iish In well. Reserves too small for RWO
18-33A
PRUDHOE
500292259801
12/1/2005
6
6 TxfAxOA, Also hos Marti head leak. Low Reserves
18-34
PRUDHOE
500292261100
10/1/2000
6,
Hole in tbg and casing. Cement in lbg and IA Multiple plugs in tbg. No way to recover
El this well. Remaining value very low anyway.
A-06
PRUDHOE
500292011800
8124/2012
7'
7' Operable. SI for velocity. 2013 Caliper found holes in tb .
A -18A
PRUDHOE
500292063001
&1342003
6
6 Low TOR, SC leak Q 5'. Possible Welding candidate
A-26
PRUDHOE
600292079400
7/3/20111
3
3 Operable. Low Pl. Needs sand consolidation treatment
A-33
PRUDHOE
500292141000
ZQ54010
2!
2 Operable. SI for high WC
A 34A
PRUDHOE.
500292133901
12/25/200EI
6
Anneomm - HOAP external gas. Well is on the list to POP UE and monitor for
repressurization, but need new well's group breaking containment SOP first. Wailing on
2:1 wells aroup
A-40
PRUDHOE
500292233700
915/2009
EI
EI SC teak and fall) MIT- LO, leak dialect on WBL.
A-41
PRUDHOE
500292253000
1171/2000
211
3 Suspended- Reservoir Abandoned.
A -42A
PRUDHOE
500292254201
91912011
3
3 Removed from 1PG. Possible.cornversuln or sWelrack.
B -19A
PRUDHOE
500292070301
10/19/2009,
6
Txl com, Taw 10R. LDIL Found leak will be selling a patch to restore integrity on WBL.
Well has been selected by Sag NWD team for use as donor well for Sag Kona target.
6 ST will be drilled in 2013.
8-26B
PRUDHOE
500292097602
11/28/20091
EI
Well selected as donor well for Sag Longboard target. ST will be drilled late 2013/early
3 2014,
8-28
PRUDHOE
500292151000
9/21/20091
6
CMI -TAA failed_ Injector used for GD MI pilot. Tested with ASR( in 20W for producer
conversion - well was HGOR. Well is available for ST to another location. Injection
5, Fadllies.are intact.
C -19B
PRUDHOE
500292073502
21221201.1
6
Suspected packer leak. Further diagrwslies in WSL (Pull LTTP, set TTP. MIT -T & MIT -
2IA)
C -22A
PRUDHOE
500292075a01
17i7Q012
3
3, Well Struggled to Raw after GSO, add Ws In JMS 11113 wall! to PoP
-12
PRUDHOE
500292044300
4=2012
6
TxIA (LDL unable to establish leak), IAxOA manageable by bleeds, tbg in poor
6, condition, RWO Pkg signed
D-18.4
PRUDHOE
500292069401
11/6/2012
6
6 LDL confirmed tbQ leak. Working on patch & squeeze procedure as per 2/13
D-24
PRUDHOE
500292150600
7/1312012
6
6FailedMIT-T. RWO +CST plans for 2014
D -27A
PRUDHOE
600292154301
4120120101
6
Pkr and PC leak Q 4950'. Candidate for squeeze but low IOR, no chance of executing
6 Ihls job,
E -14A
PRUDHOE
600292078401
9/5/2007
6
6 TxIA Comm & surface csq leak
E-186
PRUDHOE
500292065402
11/6120041
6•
6 Suspended 2008. Sidetrack 2W attempt failed. Need Rotary Rig far sidetrack.
E -31A
PRUDHOE
500292241101
11123!7011
6.
6 Tx1A. need to look at setting another patch(already one in wellbore
E -39A
PRUDHOE
500292258701
9!412005
6,
6 IBP fish stuck in hole.
71.1A
PPt inHnE
500292009501
7/7/20111
6
Wells has annular communication MIT -T & CMIT-TxIA failed. Need to run a LDL to
7 identify the source of the leak. LLR is 0.67 2m,
Exhibit 10
71ii7 IRA qh..t In 1Mfalr Rnnn It
sw name
Field
API Numher
Sl Date
Reason for Well
Shut -In"
Future Utility Plans &
Possibilitiese Current Mechanical Condition I Additional Comments
F -11B
PRUDHOE
500292042402
1112212009
6
Suspended. Reservoir P&A 2012, Non Operable, TAA communication - collapsed
6 tubing at 8180'
F -16A
PRUDHOE
500292066101
1/29/2007
6
6. No forward plans for this well.
F -19A
PRUDHOE
500292062901
11/1012010
1
1 Sea well w/Slotted liner - no means to SO uniform ass entry
F-22
PRUDHOE
600292195100
41W21508
6
6• RWO Planned
F -23A
PRUDHOE
600292165801
7/8/2006
61
6 RWO Planned
F -28B
PRUDHOE
600292164902
4/30/2012
1
5 HIGH GOR
F-36
PRUDHOE
500292263100
11/9/2012:
6
6 SC Leak. Seal -Tice program in the works.
F-37
PRUDHOE
500292197400
61220008
1
1 Considering for Sidetrack.
G -03A
PRUDHOE
500292022101
12/3/2004
6
6 Notes indicate BHL re laced with G -31B,
G-07
PRUDHOE
500292035900
10113(2011
6
6 Currently diagnosing downhole problem
G -09B
PRUDHOE
500292059202
7020T2.
1
1 Trying Organosealtofix,
G416
PRUDHOE
500292058302
1411/2011
6
6 Currently diagnosing downhole problem
G -13A
PRUDHOE
500292060001
5/7/2007
3
31 Suspended. Collapsed tubing? Ria ST - partner re acted
GC -2A
PRUQHOE
500292016700
9/1/19954
6.
LTSI Cretaceous Disposal Well, No Flowline, Repeated attempts to cleanout fialed, CT
5, fish sin hole, no in'ectivit
GC -2C
PRUDHOE
500292177400
9/17/2007'
6•
2' Mortobore completion. OA valve 0i shows IAP MITIA passed to 1700psi on 2/6/09
GC -3D
PRUDHOE
500292030900
5/1/20021
4
5 LTSI Cretaceous Disposal Well - requires CT FCO
H -04B
PRUDHOE
500292010402
1/112
6.
0 TxIA & SC Leak- Released for ST -
H -10A
PRUDHOE
500292048701
11/24/1997'
fit
SUSPENDED - lost drill pipe and neutron source when drilling sidetrack. (Can we
EI Sidetrack and convert to injector?
H-11
PRUDHOE
500292048500
21912012
6
$C Leak - working on plan to weld in 2015. Need to write input sheet for it to move to a,
Ei 1,
H -16B
PRUDHOE
500292059202
9/2712011
6
NOT OPERABLE.Tubing collasped at 2011'. Well was being flowed back after frac job.
7 Camera confirms casing/tubiri collapse. No flowline,
H -17A
PRUDHOE
500292086201
511572012.
7'
7' Halt done aGSO. Executing wellwork.
H-34
PRUDHOE
500292280300
11/4/20044
61
NOT OPERABLE TxIA, PC leak. Repair with RWO and get Z4B well back with acid job
EI or possible RWO and Sag ST.
J-01 B
PRUDHOE
500292002002
61812008
0
6 The wall tial no OorMine which Ts estimated 10 0061 S2 mPliton,
4-03
PRUDHOE
500292002500
11/3/20041
EI
Wellhead leak, tree growing. The wellhead leak is not economical to fix. This well's
surface kit (flowline, etc,) is planned to be used for a grassrools well, J-30 in summer of
6 2014 -
J -05C
PRUDHOE
500292012003
9/13/20111
Q
Multiple Furmanite clamps have failed. Wells group is planning to weld it winter of 2013.
0 1/6/14 wells aroup is waiting on EWI documentation for welding procedures -
J -11A
PRUDHOE
500292046201
5/16/20111
1
1/6/14, in process of writing a cement squeeze to shutofff Z4 production and to return
1 to Z2 production to make the well economical again.
J -15B
PRUDHOE
500292096102
5/15/2006
E1
TxIA communicalion.1/6/14, RWO package to replace the 4.5" tubing is in process of
6 pain cam le[ed td et on the schedule for summer of 2014.
K -09C
PRUDHOE
500292173603
2/142009
6
6 Seallile failed. Looking at cementsqueeze or thermaset, then Or anoSeal.
K-13
PRUDHOE
500292175700
10/41997
6
Suspended 2010. Secured well with 500' of cement above production packer and TT
6 plug.
K -19A
PRUDHOE
500292253101
4/9/2009
F
5 Has a PC leak w/ a LLR of 3 bpm. Currently there are no future plans for this well.
L-01
PRUDHOE
500292301100
1011512011
3
5 Low PI, Welt reiess0d 0 Nii for possible ST.
L -02A
I PRUDHOE
500292304801
5/7/2007
3
5 High TGOR, low productivity. Released to NWD for possible ST.
L-03
PRUDHOE
500292326900
111110120091
7
High TGOR, previously unsupported. Plan to static and POP- when U -pad jumper
6 opens and well is more com etalive.
1_2-08A
PRUDHOE
500292176101
7/11199911
6
Evaluating RWO feasibility & possible non -rig fix . Can't flow to LPC due to gas
6limitations.
L2-11
PRUDHOE
500292288500
11/1/2008
Ei
6• RWO pkg is prepared but Partners won't sign due to poor economics.
L9 -1a -A.
PRUDHOE
500292176601
9/1/2001
6
Tbg and casing damaged. Evaluating repair options and TT CTD options. Plans to
&P&A
L-50
PRUDHOE
500292327700
5/7/2007
11
1 No flowline
M -05A
PRUDHOE
600292019401
12111/2004
6
6 RWO SOR finished likely capital RWO. Reviewing SAG target with team Jan 2014.
M -13A
PRUDHOE
600292052201
9/15/2007
6
2: Twin w/ M-14. Flowlina repaked butwell has IA x OA communication
M-16
PRUDHOE
600292061300
7/1312012:1
6
Not Operable. SC Leak. Evaluate possible Seallite candidate. Also being evaluated fol
6, SC pressure waiver.
14.186
PRUDHOE
500292085502
12/20/2011
7
6 Shut-in for flowline replacement. FL Replacement due early 0ec.2012
M -20A
PRUDHOE
500292091201
12/4/2011
7
6Shut-in for flowline replacement. FL Replacement due early Dec.2012
M -27A
PRUDHOE
500292199201
7124/1997'
6
6; Being screened for ST- The fish and fill in the well may make ST and kickoff difficult -
M -30
PRUDHOE
500292225500
12/31/2011
7
7' Shut-in for flowline replacement. FL Replacement in 21 licei .
N -11C
PRUDHOE
500292137502
10/2012000
6
NOT OPERABLE: SH leak. POP'd and got a few well tests for evaluation, Wells
6 Group evaluating for weld repair. On WBL for LDL to determine source of TxIA leak.
QWDW-SW
PRUDHOE
500292181700
211/2018
7
5 DiaposiaJ Well Not Operable
P-15
PRUDHOE
500292212000
2/4/20051
6.
SC leak. Available to Res Man for Sidetrack options, RWO option to be explored
{sidetrack location ID'd, timing for WID?? Will use either P-15 or P-18. Well is secured
with a plug and is on Risk Management list as Non Rig Reservoir Abandonment with
2, BM
P-18
PRUDHOE
500292209700
71112007
6
6C leak. Available to Res Man for Sidetrack options. RWO option to be explored
(sidetrack location ID'd, timing for WID?? Will use either P-15 or P-18. Well is secured
2 with a plug
P -23
PRUDHOE
504292239304
6/24/2002
6
Injection lines given to P-26, looking to reposition (and RWO to repair integrity) for
support of possible sidetrack of P -05A near toe of P-26 (4/15/11 update) or RWO if Y -
5 25A bettomhole localion is replaced
PWDW1-1
PRUDHOE
500292022600
7/6/2001'
6
S SI due to poor injectivitV resulting from a SSSV fish down -hole.
PWDW2-1
PRUDHOE
500292022700
2/1/2009
EI
5 LTSI Cretaceous Dis osal Well, PC Leak at 2992', would require redrill
Q -06A
PRUDHOE
500292034601
5/11/20111
EI
NOT OPERABLE: SI for SC leak. Have repaired IA x OA leak. Just wailing for patch in
1 tubing & then should be Operable. Should be complete in early November
R-02
PRUDHOE
500292035400
611 V201 111
6
6 Job in WBL to pull and redress isolation sleeve to restore integrity.
R -06A
PRUDHOE
500292038801
6/6/2006
6
6 RWO package sent 512413. TxIA, colla sed ! .
R-08
PRUDHOE
500292054800
8/13/2012
6
6 Multiple IbQ leaks. Possible SAG / Ivish tae is in area -
R -10
PRUDHOE
500292061800
311/20011
3
3 Well is meas for ST. Mulls le holes In MI.
R -17A
PRUDNOE
500292067701
2/2811005
6
6Skieimck candidale for Sag or ivlshak.
R -20A
PRUDHOE
1500292064101
1 616/2006
6
6 Surface Casing Leaks, On RST IW.
Exhibit 10
7n 17 IQe IQ 0In Wnll V.-+
Reaa0n far Wall
Future Volily Plana &
sw name
Field
API Number
SI Data
Shut -In^
Possibilltlese Current Mechanical Condition / Additional Comments
LDL finished. Coil ST screening started, Passes MIT to water, getting a waiver to use
well in meantime. Can run liner above packer and cement to window to address MI tbg
JR -22
PRUDHOE
500292100500
1012212012
6;
61 leak in future ST.
OAcemented to surface. Builds up too fest to manage w blead;iL On Jose' list, possible
R-24
PRUDHOE
500292123200
101212AQ9
6
6 seablte,
8-04
PRUDHOE
500292095900
121212D11
6
6TxiAand flowflnere needed.
9-07A
PRUDHOE
500292082901
2/20/2012
6
6 SH Leak. Waiting on wells group to progress SH weld.
S-09
PRUDHOE
500292077100
10111/20121
5
5 Well injecting into faulted area that prevents it from communicating w/ any producers -
S -13
PRUDHOE
500292081000
3/1/2001 I
a
El Available for high KO sidetrack. Reservoir Abandmonent program being worked.
B-15
PRUDHOE
5002$2111300
9f1 0120101
6
6 SC leak. RWO might be an option once S-16 and S -32A are back online.
S-16
PRUDHOE
500292112300
814120041
6
6 SC leak and IAxOA. RWO SOR approved by partners.
SI Bradenhead leak, tbg in poor candiljorr, Wine needs to be replaced. Available to
5-23
PRUDHOE
500292208800
1211412QD3
Ei
Ell ResMan.
5-30
PRUDHOE
500292205100
812012003
6
61 TxIA_ Released for ST,
S-34
PRUDHOE
500292230500
7/12/2010
6
8 Not operable. IAxOA comm.
S -40A
PRUDHOE.
500292249401
812af2006
6
6 SC Leak, Fuel ST Salamalnf.
S-42
PRUDHOE
500292266200
11112/2012
2
2 Planning a WSO
Well is SI for high WC/water handling. Fish in well prevent downhole diagnostfcs.
5-44
PRUDHOE
500292273500
4/20/2012
2
2 Release for ST.
T-01
PRUDHOE
500292124100
7/1/19991
£l
8 LTSI Injector, not an effective injector, main line to pad corroded/too expensive to repair
T-07
PRUDHOE
500292073300
7/l/199911
£I
8 LTSI Injector, not an effective injector, main line to pad corroded/too expensive to re air
Hole in tubing and PC leak; Flowlines in good shape. Well available to Res Man (may
U -02A
Prudhoe
500292117001
12/2/2014.
6
5 be used for U/W Pad bounds well); Well is not secured.
U-07
Prudhoe
500292112700
4112120141
3
4 Well shut in for low oil rate well is operable -
erable.High
High walercut, flowlines given to U -15A. Well available to Rea Man or Sag Team for
U -08A
Prudhoe
500292113601
1/212014
2
5 sidetrack. Well is not secured.
Operable. Low oil rate. Ruck producer wl. fill- Released to NWD for ST oval. Wall is
U-13
PRUDHOE
500292035500
7/112006
7
7 not secured. Removed from IPC 10110113 - Unecorm mlc
No oil, no flowline, well suspected of hole collapse. Wellbore is available to Res
U -15B
Prudhoe
600292256502
71612014,
31
51 Man/Saa Team for sidetrack. Well is not secured.
V-01
PRUDHOE
500292321000
11!1112012
7
7 High TGOR. Not com etative in the EWE LDF.
SI due to scaling. Completed acid work to remedy scaling and well came back online a
99% WC. Planning water shut-ff investigation and GOC pick for Gas cap surveillance -
VV -06A
PRUDHOE
500292182201
10/12/2012
2
2 Wellwork not on WBL yet.
W -09A
PRUDHOE
500292194701
81412004
B
5 No access to liner to due clarnaged liner top. never parlorsted. Wet when drilled.
-originally SI for High WC. Comptelad Add Perls in December 2013. Now waiting for
space in EWE LDF to POP. When removed. Change SI reason & Opportunity back to
-12A
PRUDHOE
600292202301
4/6/201' 21
2'
7' 2 & 1 to reflaol o - inal SI reason.
W-18
PRUDHOE
500292188000
1211512012
6
7 Well has Iwo lubirkp leaks. RWO cam Eels. Sidetrack complete.
Well loaded up. Needs welwork- hydrlaed offend now Non-aperabie. When U -pad
W -25A
PRUDHOE
600292187401
1212GL2012
3.
2 u aro thaw well and 6ace online UE.
X-01
PRUDHOE
50Q292039000
3/18/20111
6
El Sl for sustained pressure in OA. Candidate for WI waiver.
X -03A
PRUDHOE
500292040501
8/26/20111
6
7 RWO completed in Dec. 2013. Waiting on finalpost-RWO steps.
X-04
PRUDHOE
500292041200
1ZTRIZD04
EI
El Sidetrack in n.'
X -14A
PRUDHOE
500292047401
12/3/2012
J
5 Removed from IPC. Low Pl. RelBasi3d to NWD.
X-18
PRUAHQE
5Q02W206750Q
41712011
6
6 Identified IAxOA in wellhead. Possible downhole TxIA.
SC leak. Low IOR- Can't justify RWO. Eval RST. POP'd and tested 1/2009. Still
X-34
PRUDHOE
5002W2241700
12131/2008
El
El unwMptitive.
TxIAxOA GL. Future offtake Y-03Ai,Diagnostic confirm comm is not lhru theWH. Rapid
OA repressurization- Plan is to ST away from a fault, wellbore available to Res
Man/Sag Team for Sidetrack. Well is secured with a WRP - Simple secure on Risk
Y -02A
PRUDHOE
500292039501
10[5(20Q5
6
EI management I
Y -03A
PRUDHOE
500292041101
7/1/2012
7
7 Sl and needs Wine repaired. This will not happen until 2014. able.
Y-106
PRUDHOE
9OQ292058702
8/17/2012
5
3 Proof of Concept well with no operable producers in area. Leave SI until Sidetracked.
TxIAxOA. FTS. Poor ting condition. Wellbore available to Res Man/Sag Team for
sidetrack (ST to east toward Y-34 candidate). Well is secured with sand over
Y-12
PRUDHOE
1500292051700
5/1/1999
El
6 perforations.
Well currently listed as not operable - TXIA. Side-track completed 11113. Not lied in yet.
Y -1 3A
PRUDHOE
500292063401
12/17/2006;
6
3 Wei Una on re -frac and after -10 is ST
High WC - low oil rate. PE notes indicate there is an obstruction in liner so cannot get
into liner for WSO. Wellbore is available to Res Man/Sag Team for sidetrack, possibly
Y -15A
PRUDHOE
500292094001
9/21/201al
2
2 to be used as SaQ Proof of Concept Well. Well has not been secured. Failed M
SC Leak; SI wet since the beginning. Plan to plugback to Y -17A per s for Y -03i offtake.
Wellbore is available to Res Man/Sag Team for Sidetrack. Originally SI for high WC but
Y-178
PRUDHOE
500292092002
61111affl
6
6 now has SC leak - well is secured with PX plug.
Low rate high WC well. Up"Itife Well and It available to Res MordSag team for
Y-28
PRUDHOE
600292216900
611/2010
2
21 sidetrack. Not secured
This area is swept. Mechanically operable well. Wellbore is available for Res Man/Sag1
Y-30
PRUDHOE
600292213500
11121200E
2
2! Team for Sidetrack. Not secured
SI for high WC. No obvious ST targets. Mechanically operable well, Wellbore is
Y-31
PRUDHOE
500292216100
12/4121107
2
"e' available for Res Man/Sa2 Team for Sidetrack, Not secured
81 for high WC. Mechanically Operable Well. No obvious ST targets and is available t
Y -34A
PRUDHOE
500292217801
12/4/2007
2
2 Res Man/Saa Team for sidetracks. Not secured.
Suspended Well- Coil cemented in hole. RST/Conversion candidate as part of Y-241
Pal reallignment. Removed from IPC - subsurface abandoned. Wellbore is available to
Y -37A
PRUDHOE
500292240301
4/22/2002
61
6 Res Man/Sao Team for sidetrack.
T%IA, OAxCond. Collapsed tbg; Wellbore is available to Res Man/Sag Teaml for
Y-38
PRUDHOE
500292255300
12113LM02
6
El Sidetrack. Removed from IPC - Uneconomic.
Z -01B
PRUDHOE
5DD292163002
2/9/2011
3
Ef Low P! LTSI well. No cuhgM Ullllutfan within Bess.
Z -08A
PRUDHOE
500292178701
711012010
2
5 ST failed, loot wlndaw mUna BRAdowrlhale
Low PI, Velcoity Constraints. Planned conversion to injection as twin wlh Z -67 1n
7-QQA
PRUDHOE
500292196701
8/12/2011
3
3 summer 2013, WTI work beginning now.
Not operable. TxIA. Well marginally compelalive at best due to high GOR. Planned
Z-15
PRUDHOE
500292184900
1 112117120101
Ei
6 wellwork for GOC survellance and possible patch based on partial on-time,
Exhibit 10
2AIA IPA Shur In Wall Rannrt
Reason for Well
Future UtlIIty Pians &
SW name
Fiald
API Mumhar
SI nafP
Shut-InA
Pgeeihilifi—B
Cnn-ant Marhaniral Cn_ �lifinn I Aridifinnal r—ants
OA repressurization due to shallow gas, poor cement, waiting on decision on annular
Z -19A
PRUDHOE
500292225101
7/15/2008
6
2
vents stem
SI based on gas lift usage per oil rate. Not competative for gas lift even if U -pad jumper
opened. Then would de -pressure GL system too much. No viable WSO here, possible
Z -22B
PRUDHOE
500292203702
12!7/2012
3
5
to o este via um 7 Otherwise, no utilization.
High TGOR. Was competative prior to EWE LDP velocity reduction. Scaled off, needs
Z -2&A
JPRUDROE.
15CIM2194501
9/2212012
7-1
2
acid work to POP- Acidize, POP when U- ad jumper apan
VSM's falling into the pits. Work is scheduled for 2012- waiting on confirmation on this;
17-31
1PRUDHDE
Vertical support members falling over, causing line to sag; until VSM is fixed - put well
500292167100
11/26/2011
-1
f
on iniectiore lookino to fix all VSMs
GCWI 2013 Water Movement Surveillance M
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Exhibit 12
Put River Sandstone Distribution
�5 PUT RIVER 55
Cl=10
ti
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