HomeMy WebLinkAbout20081024Elam Direct.pdfBEFORE THE RECE
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IDAHO PUBLIC UTILITIES CClM~~~~~~~HW;I,í?C:l'\~,1
UTIU1It:S l,Vf!ì¡M",'..d-'¡'1
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-08-10
AUTHORITY TO INCREASE ITS RATES )
AND CHARGES FOR ELECTRIC SERVICE )
TO ELECTRIC CUSTOMERS IN THE STATE)OF IDAHO. )
)
)
)
DIRECT TESTIMONY CF MATT ELAM
IDAHO PUBLIC UTILITIES COMMISSION
OCTOBER 24, 2008
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Q.Please state your name and business address for
the record.
A.My name is Matthew Elam. My business address
is 472 West Washington Street, Boise, Idaho.
Q.By whom are you employed and in/what capacity?
A.I am employed by the Idaho Public Utilities
Commission (Commission) as a Utilities Analyst in the
Engineering Section of the Utilities Division.
Q. What is your education and experience?
A. I graduated from Boise State University earning
a Bachelor of Arts degree in Economics. Following this I
worked for Albertson's as a Business Analyst in Finance
and Corporate Planning before transitioning to Research
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16 and Market Analysis. My primary duties included
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demographic profiling, modeling, and demand forecasting
for the purposes of determining ROIC (Return on Invested
Capital). Following this I accepted a Business Analyst
position working in a similar capacity for geoVue Inc.
where I would later be promoted to a Senior Business
Analyst and Modeler.
Q.What is the purpose of your testimony?
A.Under the direction of Randy Lobb, Utilities
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 1
STAFF
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Administrator, I will discuss the Company's rate design
proposals for Schedule 7, Schedule 9, Schedule 19,
Lighting Schedules, and the Non-metered Schedule 40 and
provide my rate recommendations based on the Staff
revenue requirement recommendation for each class.
Q.Please summarize your testimony in this case.
A.I fully support the Company's rate design
proposals to (1) add a block rate on the energy charge
during the non-summer time period for Schedule 7, (2) add
time-of -use (TOU) rates to customers taking service at
the Primary and Transmission level for Schedule 9, and
(3) increase the differentials between the On-Peak, Mid-
15 Peak, and Off-Peak Energy Charges during the summer and
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16 non-summer seasons for Schedule 19 customers. With the
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exception to maintain current Schedule 7 customer
charges, I further agree with the Company's proposed rate
component differentials adjusted for the Staff proposed
revenue requirement for each class.
I also agree with the Company's proposal that
Schedule 9 not include a "phase-in" period of shadow
billing for the proposed TOU rates.
Q.What are Staff's obj ecti ves in evaluating rate
CASE NO. IPC-E-08-10
10/24/08 ELAM, M. (Di) 2
STAFF
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design?
A. Staff's objectives are that rates recover the
revenue requirement of each customer class based on the
class revenue requirement recommendations of Staff
witness Keith Hessing; send an appropriate cost based
price signal to customers encouraging the wise and
efficient use of energy; provide rate stability and avoid
unnecessary complexity.
Q. Do you have exhibits illustrating the Schedules
with your proposals?
A.Yes, they are provided as Exhibits 1-5.
SMAL GENERA SERVICE, SCHEDULE 7
Q.What rate design does the Company recommend for
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16 Schedule 7?
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A.The Company is proposing to (1) increase the
Energy Charges, (2) increase the Service Charge, (3)
increase the summer differential between the first block
and the second block, and (4) add a block rate on the
energy charge during the non-summer time period that has
a lower differential than summer.
Q.Do you agree with the Company's proposed rate
design changes?
CASE NO. IPC-E-08-1010/24/08 ELAM, M. (Di) 3
STAFF
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A.Yes, I agree with the increase in summer
differential between the first block and second block,
and to add a non-summer tiered block rate as adjusted for
Staff's class cost of service revenue requirement that
6 does not increase for Schedule 7. However, I recommend
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that the customer charge for this class remain unchanged
given the small increase in class revenue requirement
proposed by Staff. I believe tiered block rates are a
reasonable surrogate to TOU rates and send a message to
reduce demand and encourage the efficient use of energy.
In addition they more accurately assign the cost
associated with providing increased supply to customers
wi th higher usage.
Q.What are your specific recommendations for
Schedule 7?
A.I am recommending that (1) the service charge
be maintained at $4.00 and the minimum service charge
stay at $2.00, (2) the energy rate for the first 300kWh
decrease by 3.44% to .067860/kWh in the summer and non-
summer, and (3) the energy rate in excess of 300kWh
increase by 2.05% to .080781/kWh in the summer and
increase by 2.052% to .071722/kWh in the non-summer.
CASE NO. IPC-E-08-1010/24/08 ELA., M. (Di) 4
STAFF
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This rate design is comparable to the Company proposal
with respect to block sizes and rate differentials.
Q.Why is Staff proposing a two block rate design
instead of a three block rate design as proposed for the
residential class?
A.The unïque characteristics of Schedule 7
customers tend to be less homogeneous when compared to
the Residential Schedules and therefore make it difficult
to define the potential third block baseline usage. In
addition, the concentration of a high percentage of
customer consumption in the first block, the Company's
proposal for a non- summer tiered rate differential of
5.69%, and the increase of 6.41% to the current summer
differential add a sufficient cost based price signal for
this class to provide incentive for customers to conserve
and use energy efficiently. My rate recommendations for
Schedule 7 are shown on Staff Exhibit No.1.
LAGE GENERA SERVICE, SCHEDULE 9
Q.What rate design does the Company recommend for
23 Schedule 9?
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A.The Company is proposing to (1) increase the
Energy Charges, (2) increase the Service Charge, (3 )
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 5
STAFF
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increase the Basic Charges, (4) increase the Demand
Charges differential between the Secondary Service summer
and non-summer second block, (5) increase the
differential between the Primary and Transmission non-
6 summer and summer Demand Charges, (6) add a summer On-
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Peak Demand Charge to Primary and Transmission Services,
and (7) add mandatory TOU rates to customers taking
Primary and Transmission Service.
Q. Do you agree with the Company's proposed rate
design changes?
A.Yes, I agree with the design component changes
recommended by the Company as adjusted for Staff's class
cost of service revenue requirement increase of 0.60%.
However, I recommend that the customer charge for the
secondary service class remain unchanged given the small
increase in class revenue requirement proposed by Staff.
My rate design proposal attempts to maintain the same
billing determinant spreads and relationships as those
proposed by the Company. I also agree with the Company's
23 TOU rate proposal as adjusted for Staff's revenue
24 requirement. As previously stated, I believe time of use
25 is the most efficient way to accurately assign the costs
CASE NO. IPC-E-08-10
10/24/08 ELA, M. (Di) 6
STAFF
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of providing services and send a cost-based price signal
to customers encouraging the wise and efficient use of
energy. My rate recommendations for Schedule 9 Primary,
Secondary and Transmission service are shown on Staff
Exhibit No.2, pages 1, 2 and 3, respectively.
Q.How did you evaluate the TOU differentials
associated with Schedule 9 and the potential impact on
load shifting?
A. i utilized the Schedule 19 historical time-of-
use data implemented in Order No. 29547 to determine how
the demand for energy shifted to different times given
the price structure movement from a traditional rate
15 design to a TOU rate design. By analyzing this load
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shifting along with the embedded differentials following
the implementation of TOU rates, I gained insight into
how sensitive customers may be to TOU rates. This
provides more insight in evaluating the potential impact
of changing TOU rate differentials.
Q.How does this provide insight into how the
23 Schedule 9 TOU rate design differentials should be
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25 A.It is reasonable to analyze the Schedule 19
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 7
STAFF
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historical data in order to evaluate how the mandatory
change from a traditional rate design to a TOU design
impacted customers' usage given the price signals
associated with the differentials. This is done by
6 evaluating how customers shifted load between Off-Peak,
7 Mid-Peak, and On-Peak. The reaction of customers, or the
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shift in usage, provides insight into how the historical
differentials may have changed usage patterns.
Once the customers' sensitivity toward these
changes has been evaluated, Staff can more accurately
determine the best structure for TOU rates.
Q.How did you utilize the sensi ti vi ty analysis
from the Schedule 19 historical data to evaluate the
reasonableness of the differentials included in the
proposed Schedule 9 TOU rate design?
A.I reviewed the average differentials associated
with the Schedule 19 Primary and Transmission services
directly following December 1, 2004. The average Mid-
Peak to On-Peak differential was 10.70 percent, the
average Summer Off-Peak to Summer Mid-Peak differential
was 7.23 percent, and the average Non-Summer Off-Peak to
Non-Summer Mid-Peak was 4.77 percent. The Company is
CASE NO. IPC-E-08-10
10/24/08 ELAM, M. (Di) 8
STAFF
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currently proposing Schedule 9 introductory TOU
differentials averaging a 9.81 percent difference between
Mid-Peak and On-Peak, an average Summer Off-Peak to
Summer Mid-Peak of 6.94 percent, and an average Non-
Summer Off-Peak and Non-Summer Mid-Peak of 4.07 percent.
When these past Schedule 19 differentials are compared to
the Company's proposed Schedule 9 differentials, the
proposed Schedule 9 differentials are slightly lower.
According to my analysis, the historical price signals
indicated by the differentials yielded a very minor load
shift change following the implementation of the Schedule
19 TOU rates.
Q.What Schedule 19 historical time frame did you
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A.I analyzed hourly usage data from Schedule 19
for 12 months prior to the implementation of TOU rates
and 24 months following TOU rates as approved in Order
No. 29547.
Q.Did you analyze all the Schedule 19 customers
23 prior to December 1, 2004 and compare them to all the
24 customers following December 1, 2004?
25 A.No, i utilized a sample set of Schedule 19
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 9
STAFF
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customers by eliminating those with an incomplete range
of data. Therefore, customers shifting between Schedules
and those completely adding or dropping service
throughout the time range were removed. This effectively
6 eliminated as much noise as possible in determining the
7 usage pattern associated TOU rates.
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Q.Did the differentials associated with Schedule
19 change from additional rate cases within the 24 month
time frame following the December 1, 2004 implementation
of TOU rates?
A.Yes, the differentials did change slightly
within the 24 month time frame following the December 1,
15 2004 implementation of TOU rates. However the percentage
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difference between differential changes was very minor,
no more than a 3.15 percent difference for all non-summer
and summer Primary and Transmission Service TOU
categories.
Q.Do you feel that given your sensitivity
analysis the Company's proposed Schedule 9 differentials
are reasonable and provide customers an opportunity to
adjust to the TOU rate design?
A.Yes, the differentials proposed by the Company
CASE NO. IPC-E-08-10
10/24/08 ELA, M. (Di) 10
STAFF
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and supported by Staff for Schedule 9 are reasonable
because they are less than the Schedule 19 time-of-use
start point differentials which yielded little change in
load shifting behavior. This is not to say Schedule 9
customers will react in exactly the same way as Schedule
19 customers have, however the Company's proposal
represents a reasonable starting point for evaluating
future load shifting behavior.
Q. Do you agree wi th the Company's proposal not to
include a "phase-in" period of shadow billing for the
Company's proposed Schedule 9 TOU rates?
A.Yes , given the limited changes observed in the
sensitivity analysis to the Schedule 19 usage patterns
following implementation of TOU rates and the Company's
proposed customer education plan, I do not believe a
"phase- in" period is necessary. In response to Staff's
Production Request No. 49, the Company states, "The
addi tional administrative cost of providing shadow bills
to Schedule 9 customers for six months is estimated to be
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no automated process to provide these bills; it is a
manual process both in the metering and billing areas."
CASE NO. IPC-E-08-1010/24/08 ELAM, M. (Di) 11
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This additional cost is not necessary in this case given
that the Company is implementing a customer communication
and education plan prior to the implementation of rates.
If managed correctly and proactively this comprehensive
approach would cut costs, eliminate the confusion of
customers receiving multiple bills, and maintain
effectiveness.
LAGE POWER SERVICE, SCHEDULE 19
Q. What rate design does the Company recommend for
Schedule 19?
A.The Company is proposing to (1) increase the
Energy Charges, (2) increase the Service Charge, (3 )
15 increase the Basic Charges, (4) increase the differential
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between the summer and non- summer Demand Charges, and (5)
increase the differentials between the On-Peak, Mid-Peak,
and Off-Peak Energy Charges during the summer and non-
summer season.
Q.Do you agree wi th the Company proposed rate
design changes?
A.Yes, I agree with the design component
recommendations of the Company as adjusted for Staff's
class cost of service revenue requirement increase of
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 12
STAFF
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4.90%. However, I recommend that the customer charge for
the secondary service class remain unchanged given the
small increase in class. revenue requirement proposed by
Staff. Consistent with my proposal for Schedule 9, my
6 rate design proposal for Schedule 19 attempts to maintain
7 the same billing determinant spreads and relationships as
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those proposed by the Company. I also agree with the
Company's proposal to increase differentials between the
On-Peak, Mid-Peak, and Off-Peak Energy Charges during the
summer and non-summer season TOU rates. However, I also
understand that there are a range of reasonable
differentials that could be accepted by the Commission
between the On-Peak, Mid-Peak, and Off-Peak TOU rates.
Throughout my testimony I have consistently maintained
that TOU rates better align the rate with costs of
increased power supply and encourages load shifting by
providing an economic signal that energy is more costly
during the peak hours of the day and the summer season.
The customers who use the most energy during On-Peak
should be assigned higher costs than those who shift load
24 to Mid-Peak or naturally use less during On-Peak. My
25 rate recommendations for Schedule 19 Primary, Secondary
CASE NO. IPC-E-08-I010/24/08 ELA, M. (Di) 13
STAFF
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and Transmission service are shown on Staff Exhibit No.
3, pages 1, 2 and 3, respectively.
Q.Which component of the Company's Schedule 19
rate design proposal dO you plan to address with the
sensitivity analysis described previously?
A.i will address the Company proposal to increase
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8 rate differentials in the TOU rates. As described
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earlier this sensitivity analysis provides insight into
how the Schedule 19 customer's have behaved historically
given TOU rates, and whether the Company's proposed
differential request is reasonable.
Q.How can you compare the historical Schedule 19
TOU differentials to the current Schedule 19
differentials and determine whether the Company's
proposed differential increases are necessary?
A.The Schedule 19 average differentials
associated with the TOU rates 24 months following their
implementation were 8.87 percent between Mid-Peak and On-
Peak, 7.23 percent between Summer Off-Peak and Summer
Mid-Peak, and 4.74 percent between Non-Summer Off-Peak
24 and Non-Summer Mid-Peak. The average TOU differentials
25 currently approved by the Commission in rates are 8.94
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 14
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percent between Mid-Peak and On-Peak, 7.29 percent
between Summer Off-Peak and Summer Mid-Peak, and 4.79
percent between Non-Summer Off-Peak and Non-Summer Mid-
Peak. Gi ven that these differentials have changed little
since the implementation of TOU rates it is reasonable to
use them in determining how effective they have
historically been in sending a price signal and shifting
time of consumption. Once this analysis has been made it
is possible to associate the historical magnitude of the
differential with the Company's proposed price
differentials and estimate whether the differential seems
reasonable to encourage Schedule 19 customers to shift
load.
Q.Based on your sensitivity analysis, how
effective do you think the current Schedule 19
differentials have been in modifying usage?
A. When analyzing the historical effect of TOU on
Schedule 19 energy consumption during all months, summer
months, and non-summer months, I found very little load
23 shifting from On-Peak to Mid-Peak, and Mid-Peak to Off-
24 Peak.
25 Q.Based on your sensitivity analysis do you think
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 15
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the Company's proposal to increase its Schedule 19
differentials is necessary?
A.Yes, since the current differentials are nearly
identical to those implemented at the beginning of time-
of-use rates and given that the sensitivity analysis
indicates load shifting was minor, I conclude that the
differentials should be increased. However, I also
understand that there are a range of reasonable
differentials that could be accepted by the Commission
between the On-Peak, Mid-Peak, and Off-Peak TOU rates.
Additionally, in response to Staff's Production Request
No. 50, the Company provides an "On-Peak/Off-Peak TOU
Energy Charge Rate Differentials" summary that outlines
what other utilities in the nation are currently using
for Large Commercial and Industrial differentials
(attached as Staff Exhibit NO.4). This further
emphasizes the Company's request is within reason.
LIGHTING AN NON-METERED SCHEDULES
Q.What change in revenue requirement do you
23 recommend for the Lighting and Non-Metered Schedules?
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A.I recommend an overall increase of 4.90% to the
Traffic Control Lighting Schedule 42. All the remaining
CASE NO. IPC-E-08-1010/24/08 ELA, M. (Di) 16
STAFF
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Lighting and Non-Metered Schedules have no increase in
revenue based on Staff's recommended revenue requirement.
Q.Are you proposing any rate design changes to
the Company's proposed Lighting and Non-Metered
Schedules?
A.No, I am not proposing any changes to the rate
structure. My rate recommendations for Lighting and non-
metered schedules are shown on Staff Exhibit No.5, pages
1 through 8.
Q. Does this conclude your direct testimony in
this proceeding?
A.Yes, it does.
CASE NO. IPC-E-08-10
10/24/08
ELA, M. (Di) 17
STAFF
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1
On-PeaklOff-Peak TOU Energ Charge Rate Diferenti
Large Commercil & Industral Customer Tari
Utah & Idaho
RM Sch.8
RMSch.9
Arna
SRPSchE-32
APS Ext Large TOU
Tucson Electric 85A
Montaa
MDURate31
Oregon
PGESch.87
Calornia
PGEE-19
SMU GS- TOUI
GS-TOU2
CS-TOU3
SDG&EALTOU
LAWPA-3
LADWPA-2
New Mexico
.PNM3B
PNM4B
Kentucky
Duke Energ, Rate.DT
Wisconsin
Wisconsin Elecric CPl
Florida
FP&L GSLDT-1
GSLDT-2
GSLDT-3
Connecticut
. Connecticut L&P 55
. On-PeakOff-Peak Ratio
48.3%
59.3%
143.9%
33.0%
12.7%
57.2%
20.0iyo.
88.3%
41.4%
89.0%
83.9%
46.1%
76.7%
.77.8%
196.0%
74.0%
23.6%
42~7% 12.5kV-138kV
45.3% GT 138kV
229.0%
269.7%
24.8%
27.2%
Exhibit No. 141
Case No. IPC-E-08-10
M. Elam, Staff
10/24/08
Id
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CERTIFICATE OF SERVICE
I HEREBY CERTIFY THAT I HAVE THIS 24TH DAY OF OCTOBER 2008,
SERVED THE FOREGOING DIRECT TESTIMONY OF MATT ELAM, IN CASE
NO. IPC-E-08-10, BY MAILING A COPY THEREOF, POSTAGE PREPAID, TO THE
FOLLOWING:
BARTON L KLINE
LISA D NORDSTROM
DONOV AN E WALKER
IDAHO POWER COMPANY
PO BOX 70
BOISE ID 83707-0070
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POCATELLO ID 83204-1391
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ATTORNEY AT LAW
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E-MAIL: bmpurdy(ihotmail.com
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VP-REGULATORY AFFAIRS
IDAHO POWER COMPANY
PO BOX 70
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E-MAIL: rgale(ßidahopower.com
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6070 HILL ROAD
BOISE ID 83703
E-MAIL: dreading(imindspring.com
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E-MAIL: yankel(ßattbi.com
KEVIN HIGGINS
ENERGY STRATEGIES LLC
PARKSIDE TOWERS
215 S STATE ST STE 200
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E-MAIL: khiggins(ßenergystrat.com
LOTH COOKE
ARTHUR PERRY BRUDER
UNITED STATE DEPT OF ENERGY
1000 INDEPENDENCE AVE SW
WASHINGTON DC 20585
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arhur. bruder(ßhq.doe.gov
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DWIGHT ETHERIDGE
EXETER ASSOCIATES INC
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UTILITY RESOURCES INC
1500 LIBERTY STREET SE, SUITE 250
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PO BOX 1731
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