2015 Annual Report
1
2015
North Central Electric
Bottineau, ND
About Central Power
Wayne Martian – Manager
Jean Brandt – President
Ken Brenden
Jesse Fahnestock
Kenneth Haarsager
Ray Keplin
Ray Keplin
Lori Kittleson
David O’Connell
R. Jay Paul
Christine Peterson
Board of Directors
Vice President
Verendrye Electric
Velva, ND
Bruce Carlson – Manager
Blaine Bruner – President
Bruce Anderson
Howard Anderson
Karen Hennessy
Robert Wolf
Shawn Kaylor
Maxine Rognlien
Kenneth Schild
John Warner
Robert Wolf
Asst. Sec./Treas.
Northern Plains Electric
Carrington, ND
Bruce Garber – Manager
Tracy Boe – President
Mark Brehm
Russell Carlson
Jack Geske
McLean Electric
Garrison, ND
Martin Dahl – Manager
Alvin Myers – President
Clarence Behles
Larry Gessele
Troy Presser
Mark Brehm
Darcy Klain
Troy Presser
Thomas Sheldon
Rodney Stockdill
Curtis Hanson
Bruce Olsen
Randall Simon
David Teigen
Curtis Wiesz
President
Sec./Treas.
Capital Electric
Bismarck, ND
Central Power Electric Cooperative is a wholesale power supply and transmission
cooperative organized in 1949 to generate power for its member rural electric
distribution cooperatives.
Ordean (Lars) Nygren – Manager
Dwight Wrangham – President
Rodney Eckroth
Sheri Haugen-Hoffart
Kyle Hilken
Kyle Hilken
Director
Central Power today continues to supply the bulk power needs of its members
through a backbone system of transmission and subtransmission facilities. The six
member cooperatives that make up Central Power combine to serve over 65,281
farms, homes and businesses located in a service area of 25 counties across the central
and southeastern third of North Dakota.
Dakota Valley Electric
Milnor, ND
Bruce Garber – Manager
Richard Schlosser – President
Connie Bitz
Arden Fuher
John Hauschild
Central Power’s facilities required to serve the members include 167 delivery points,
25 wholly owned and 10 jointly owned high-voltage transmission stations, and 1,381
miles of transmission line interconnected with the Western Area Power Administration,
Basin Electric Power Cooperative, and three investor-owned utilities. In all, Central
Power has a $248.5 million investment in utility plant
2
Central Power Electric Cooperative, Inc.
Josh Kramer
David Liuska
Arlene Olson
Bill Patrie
Deon Vilhauer
Arden Fuher
2015 Annual Report
Richard Johnson
Blaine Lundgren
David Paulson
Kim Rasmussen
Matt Thompson
Director
3
Message from the President
To say that 2015
was a good year for
Central Power Electric
Cooperative would be
an understatement.
Indeed, 2015 was a very
remarkable year at your
G&T and a year filled with
significant achievements
in which we can all feel
a major sense of pride
Mark Brehm
and accomplishment.
President
This success did not
come about by happenstance and luck; rather, it was
the culmination of considerable strategic thinking,
foresight, critical decisions, and hard work. As a board,
we have a responsibility to provide the necessary policy
direction and budgetary approvals for the cooperative
and then turn our management team loose to carry out
our objectives. This is rather easy to do when you have
complete confidence in your staff and it is easy to have
this confidence when they have a record of delivering.
We have what I would consider to be one of the finest
management teams in the industry and rest assured
they have laser-like focus on delivering value to the
members. Your G&T’s Board of Directors could not be
more pleased with their dedication and motivation to
do just that.
A purported ancient Chinese curse reads “May you
live in interesting times” and clearly we are operating
in “interesting times” in the electric utility industry. It
would be fair to say the intended characterization of
“interesting times” is indeed “challenging times” and
these times demand a lot of commitment, effort, and
vision from our organizations’ leaders and employees.
I for one feel strongly we can rest assured that we have
the resources to not only respond to the challenges, but
also to be proactive in addressing them and seeking
out, creating, and capitalizing on opportunities; in a
way, “Charting a Course for a Powerful Future”!
4
What is challenging in today’s utility environment? Just
about every aspect that comes to mind; government
regulations and compliance requirements, including
environmental issues like the Clean Power Plan, Waters
of the US, the recent Federal Coal Lease Moratorium,
Regional Haze, Coal Combustion Residuals (Ash),
Cross-State Air Pollution, Endangered Species Act
and the seemingly endless march of reliability
compliance requirements under the North American
Reliability Corporation, NERC, and Midwest Reliability
Organization, MRO; permitting; right-of-way and site
acquisition; rate pressures; and Regional Transmission
Organization, RTO, integration and the Federal Energy
Regulatory Commission, FERC, approval process to
name a few.
A prime example of “Charting a Course for a Powerful
Future” would certainly include our vision turned
into action to move toward having as much of an
independent transmission system as we could plan,
design, and construct in the past ten years to address
system deficiencies, and in so doing, positioning
ourselves extremely well for the future.
Conjoined to the previous example of “Charting a
Course for a Powerful Future”, it would have been
possible for our management team to continue our
significant discussions with Otter Tail Power to extend
our Integrated Transmission Agreement, ITA, beyond
its stated termination date of December 31st, 2015 and
stay in our comfort zone with a familiar agreement that
we have operated with for 43 years. But that would
have been the easy course, which would have required
significant compromise on Central Power’s part, and one
which would not have moved us fully forward into the
RTO environment or afforded us the opportunity to take
advantage of many of the benefits associated with that
transition. So we decided, after extensive deliberation,
to join and integrate into Southwest Power Pool, SPP, as
a Transmission Owner, TO, in the Upper Missouri Zone,
UMZ, and to let the ITA expire under its own terms.
Central Power Electric Cooperative, Inc.
Last October we applied for membership in SPP with
a request for several cooperative minded governance
amendments and submitted our Annual Transmission
Revenue Requirement, ATRR. We are also in the process
of mutually cancelling most of our Basin IS Leases;
and Basin is in the process of applying for facility
credits on our behalf for our qualifying facilities in the
Midcontinent Independent System Operator, MISO, RTO
in the Otter Tail Power zone.
On December 30th, 2015, our SPP ATRR was
conditionally accepted by FERC with an effective date
of January 1, 2016. Following is the language from the
order in Docket ER16-209:
1. In this order, we accept Southwest Power Pool,
Inc.’s (SPP) proposed revisions to its Open Access
Transmission Tariff (Tariff ) to add a formula rate
template and implementation protocols to
accommodate the recovery of an annual
transmission revenue requirement for SPP
member Central Power Electric Cooperative,
Inc. (Central Power), effective January 1, 2016,
subject to refund, and establish hearing and
settlement judge procedures.
Our requested membership agreement amendments
were accepted by FERC on February 8th, with an
effective date of February 14th, as requested by SPP.
This was the most significant foundational change
Central Power has undergone since the ITA was formed
in 1972 and it is a very positive step. However, we did
not get to where we are alone. Basin Electric’s RTO team
has been an incredible resource to us and we wish to
sincerely thank them for all they have done to assist
Central Power and the other Basin members with this
entire proposition. We also recognized we would need
outside legal and engineering assistance so we engaged
the engineering firm Guernsey, Engineers, Architects,
Consultants from Oklahoma City, OK; the legal firm
of Schiff Hardin, LLP from Washington, DC, and GDS
Associates, Inc. from Marietta, GA, bringing some of the
best and brightest industry experts onboard to assist
us getting this right and this is also part of “Charting a
Course for a Powerful Future”.
Basin is taking SPP and/or MISO transmission tariff
service for service to our loads. The MISO transmission
tariff service costs to serve Central Power’s load is
substantial but under Basin’s Transmission Policy
approved by their board in July of 2014, the impact
to Central Power is substantially reduced. Under this
policy change, all but the WAPA portion of the MISO
transmission costs are borne by Basin, which leaves
us to pay an estimated $750k annually. This policy
change was the result of a very concerted effort on
Central Power’s part to bring comparability to the Basin
membership and to put Basin in a place to properly
evaluate which RTO to join, and what resources
to build and where, by having all the relevant cost
considerations as their responsibility. This was the single
biggest policy change in the history of Basin Electric
and is a shining example of what can be accomplished
by “Charting a Course for a Powerful Future!”
2015 Annual Report
5
Report from the General Manager
This policy change moved Basin to providing
comparable transmission service to all of its members
regardless of direct physical access to the Basin/WAPA
Integrated System and will save Central Power and its
members millions of dollars annually.
We were also confronted with a very serious issue
with the portion of our WAPA hydropower allocation
that is delivered to our loads in the MISO footprint.
MISO’s rules and procedures did not appropriately
recognize our monthly peak demand allocation and the
unrecognized demand would have had to be made up
by Basin at their Class A demand rate. This represented
over a million dollar a year impact to Central Power. We
worked alongside Basin and other similarly affected
Basin members to come up with a fix. Ultimately, Basin
senior staff came up with a very good compromise
solution that was palatable to WAPA and we cannot
thank Basin enough for developing this solution. The
compromise is not as good as the solution put forward
by Central of redirecting our WAPA allocation to our
deliveries in only the SPP footprint which would have
helped Central avoid the estimated $750,000 per year in
MISO transmission tariff expense.
We were pleased to be able to reciprocate some of
Basin’s assistance in these RTO matters and we like to
think we helped with some level of assistance to SPP,
Basin, and WAPA in dealing with their SPP Integration
with regards to their October 1, 2015 integration and
Otter Tail’s intervention and protest.
Why all of this explanation of “Charting a Course for a
Powerful Future” you may ask. Well, all of these actions
allowed us to dampen the Basin’s roughly 7.8% rate
increase for 2016 to a much more modest 2.65% from
Central to its members. That is a very big deal when
one considers that Basin represents about 81% of our
total costs (Central Power’s cost of operation is roughly
10% so it takes a lot of reduction to effect that kind
of dampening). At the end of 2015, we provided the
first ever Central Power Bill Credit from operations of
6
$1.5M in addition to passing on the roughly $305k in
Renewable Energy Credits from Basin that we budgeted
to keep in 2015 in order to provide a lower mill rate and
in addition to these bill credits, the Central Power board
passed through Basin’s $2.642M Bill Credit. All told,
Central Power bill credited the members $4.447M at the
end of 2015 which should further assist the members
mitigate the 2.65% increase - “Charting a Course for a
Powerful Future”.
Another example of “Charting a Course for a Powerful
Future!” would certainly include extending our
Wholesale Power Contract with Basin Electric from 2050
to 2075 and entering into a Scheduling Agreement
& and a Power Services Agreement. This was done
subsequent to Central Power’s members extending
their All-Requirements Wholesale Power Contracts with
Central Power until 2075 which we thank the members
for executing so quickly and without ado.
Many thanks to our engineers and craftsmen for all
the tremendous amount of design and permitting
and construction they completed in 2015. Some of
this work was on an extremely fast track and our
personnel didn’t miss a beat. Our staff is also heavily
engaged in reliability compliance with the Midwest
Reliability Organization, MRO, working hard to keep
us in compliance and avoid any potentially significant
financial penalties.
The board is certainly pleased to report that our
employees worked safely this past year in that they have
driven 7,126,897 miles without a chargeable accident
since January 24, 1996 and worked 88,568 hours
without a lost time accident since September 6, 2013.
This is a remarkable accomplishment.
Today we have many challenges but with the continued
dedicated service and efforts from our Board of
Directors, our employees, our members, and our
affiliated organizations, we will be able to continue
“Charting a Course for Powerful Future!”
Central Power Electric Cooperative, Inc.
It is my pleasure to report
on 2015’s operations at
Central Power Electric
Cooperative. While the
challenges and issues
we dealt with this past
year were numerous and
significant, I am very
pleased to report that the
state of Central Power
Electric Cooperative is
Tom Meland, P.E. strong and we continue
General Manager
to be intensely focused on
“Charting a Course for a Power Future”! What motivates
us to continue pressing for solutions to these new and
significant challenges and issues? Our strong desire
to assist our members in their efforts to provide safe,
reliable electric service at the lowest practical cost to
their member-owners.
As we close the books on 2015, it is an appropriate
time to pause, catch our breath, and reflect back on the
past year. There should be no doubt that we were fully
engaged in the second most significant transformation
Central Power has undertaken in its vibrant history.
As the President stated, the Integrated Transmission
Agreement, ITA, we shared with Otter Tail Power since
1973 reached the end of its term at year’s end. While
we have struggled at times with that relationship given
our very different business models and priorities, it did
assist us in keeping our transmission costs reasonable.
However, the future of transmission arrangements
was moving front and center with our power suppliers
concluding their analysis of Southwest Power Pool, SPP,
membership and integrating into SPP on October 1,
2015, at nearly the same time as our ITA was set to
expire. Central Power was deeply involved with Basin
and WAPA’s consideration of SPP membership and we
take great satisfaction in our belief that we were the
prime mover and most influential member at the Basin
Managers Advisory Committee and at the Basin board
level with regard to Basin passing what is the most
significant policy change in Basin Electric’s history –
its updated Transmission Service Policy.
This past year Central Power’s average member mill
rate (delivered at the substation low side) was 58.42
mills per kilowatt hour, not including the year-end bill
credits the Central Power Board of Directors approved.
The member average mill rate includes the members’
Central Power Base Rate (Blended Rate), Electric Heat
Rate, and Interruptible Rate purchases. As the President
mentioned, Central Power was facing a nearly 7.8%
effective rate increase from Basin going into 2016 and
given that Basin represents approximately 81% of our
total cost of service, this was a formidable concern.
However, Central Power was able to moderate that
increase to our members down to approximately 2.65%
by seizing opportunities afforded to us through our
support of Basin and WAPA joining SPP and through
lobbying Basin for the Transmission Service Policy
change. It is also important to remember Central
Power provided an extremely significant buffer to the
members for 2016 in the form of $4.447 million in yearend bill credits.
So how did we accomplish this dampening when our
total power costs from 2015 to 2016 are budgeted to
go from 50.25 to 53.78 mills per kilowatt-hour, or a 3.53
mill increase? Our internal cost of service, less other
revenues including Basin IS Lease Payments, is projected
to go down from 5.31 mills per kilowatt-hour to 3.96,
or a 25% reduction. The 3.96 is the lowest level it has
been in the 21 years that I have been at Central Power.
Most remarkable is the fact that while our non-power
cost of operations is projected to drop 25% on a mills
per kilowatt-hour basis, our Total Utility Plant at the end
of 2015 was up from 2014’s $226 million to nearly $250
million, or an 11% increase.
Additionally, we are working to obtain appropriate
credits for our facilities in the MISO OTP zone and
should be able to take advantage of the opportunity
to reduce our system losses, potentially saving an
estimated $2 to $3 million annually in total. These
2015 Annual Report
7
savings were not budgeted for 2016 as there was some
uncertainty associated with them. Also, we will avoid
future ITA deficiency payments of approximately $200
thousand per year.
There are some increased costs as well, primarily due to
MISO transmission service costs on power supplied by
WAPA to our load in MISO. Basin will serve as the Market
Participant to handle the transactions required to serve
our load in MISO, but they are not responsible for the
charges applicable to the portion of our power supply
that comes from WAPA. At one point, we were looking
at additional annual costs as high as $2.5 million that
would be incurred due to WAPA power delivered to
our load in MISO but it now appears that we will avoid
the bulk of this additional expense and our costs will
probably be in the $750 thousand per year range.
We did not budget the original amount of $2.5 million
for 2016 as it appeared to be a reasonable offset to
the unbudgeted positive amounts listed in the
previous paragraph.
8
Central Power has moderated relatively significant rate
increases all while making significant improvements to
our system. Most remarkably and rewarding, after quite
a few years of strategizing and negotiating and with
the crucial help of U.S. Senator Hoeven, we completed
and energized the 35 mile Bottineau – Dunning 115kV
line with the final approval and completion of the one
mile J. Clark Salyer National Wildlife Refuge Crossing
this past year. This was critical to placing this important
reliability enhancing facility into service and to have
it qualify under our SPP Annual Transmission Revenue
Requirement, ATRR, so as to achieve cost recovery for it.
substation and we expect to take delivery of this
new mobile around the time of our 2016 Annual
Meeting. More recently the Board approved writing
a specification and requesting proposals to provide a
replacement for our existing 5MVA mobile substation
with a 69x60x43.8-25x12.5kV, 10MVA unit. We expect
to present proposal information to the Board during
the first half of 2016 in order to provide the Board with
information necessary for them to determine if we should
replace our existing 1968 unit. The Board is also considering
a new storage building at our Minot yard to store the
new mobile substation as well as other equipment.
We have worked extensively this past year reinforcing
our system in the Dunning (Westhope) area as outlined
in detail in the Engineering and Operations Department
report later in this report booklet. The Dunning projects
also included an in-line 60kV power circuit breaker
which allowed us to bring these facilities on-line in a
closed loop method of operation which will improve
reliability and allow us to put these 60kV facilities into
our SPP ATRR as well.
In 2015 we recognized the need for our three breaker
115kV Towner switching station, built in the early 1960’s,
to be completely rebuilt. We looked to turn the rebuilding
and future ownership of this station over to WAPA as it
makes more sense in the RTO environment and they will
begin construction of the new station in 2017.
This past year we also completed work to operate our
newer 69kV lines between Bottineau SE and Thorne
as well as between Thorne and Rolla in a closed loop
configuration with the addition of in-line power circuit
breakers, which also improve reliability. We also made
system modifications on our Rugby area facilities that
will have the effect of moving more of our load into the
SPP Balancing Area and Energy Market.
Our engineers and craftsman made extensive
improvements in the Capital Electric area including
establishing distribution substation low-side metering
to meter Capital at the same point we meter all the
other members’ loads, rather than relying on upstream
metering and contractual loss factors as we have done
the last two years. We also initiated and completed
thorough transmission studies of the Bismarck and
Minot areas which identified several needed projects.
I would also note that we met Basin’s Load Monitoring
Incentive Credit requirements in all 12 months of 2015
and received $152 thousand in credits from them. In
fact, we have received approximately $1.3 million in
these credits dating back to 2003. Basin recognizes the
value of this information and they are increasing the
credit from 7 cents per MWh to 10 cents for 2016 so our
credits should increase. Central Power also provides
incentive credits to our members that perform this
function and has issued $2.4 million in Load Monitoring
Credits to those members since 2004.
Our staff was hard at work this past year with Midwest
Reliability Organization reliability compliance
requirements. We continue adding new facilities
and the standards are continuously updated which
creates a challenge in keeping our programs and
procedures up to date.
In closing, I would like to take this opportunity to
recognize several long serving managers for their
notable careers in light of their upcoming retirements.
Bruce Carlson, General Manager of Verendrye Electric
Cooperative, having worked there for 33 years, with 7
years at Sheyenne Valley EC in between; Lars Nygren,
General Manager of Capital Electric Cooperative,
having worked there for 32 years after his initial 8 years
at Verendrye; and Central Power’s long-time friend
and supporter Dennis Hill, Executive V.P. & GM of the
NDAREC, is retiring with 35 years at Statewide. Thank
you gentlemen for your dedicated service. Your wise
counsel will be missed.
We are pleased to see that our two member
cooperatives have selected their replacement
managers and that the new managers are experienced
individuals with whom we already have experience
and relationships. Congratulations to Paul Fitterer, new
General Manager at Capital Electric, and Randy Hauck,
new General Manager at Verendrye Electric. They will
do a great job in their new positions.
We have an extremely busy year ahead getting into full
swing with SPP operations and with completing the
project load we have lined up. With steadfast direction
and support from the Central Power Board of Directors,
input from the Managers Advisory Committee,
and outstanding employee effort, we will continue
“Charting a Course for a Powerful Future”! I also want
to thank Basin Electric and the Western Area Power
Administration for our excellent working relationship
and for their major role and significant participation
in working together “Charting a Course for a
Powerful Future”.
Some time ago the Central Power Board approved
purchasing a new 115x69-24.5x12.5kV, 20MVA mobile
Central Power Electric Cooperative, Inc.
2015 Annual Report
9
Member Load Growth
Energy
in Gigawatt
- HoursGrowth
Member
Load
Year in Review
Energy
3,000.0in Gigawatt - Hours
Member
Load Growth
3,000.0
The following report
summarizes the highlights
of Central Power’s
operations over the
past year.
from Basin’s coal-fired plants in North Dakota and
Wyoming, along with some smaller amounts of peaking
and wind power. Central Power’s WAPA/Basin resource
mix is 10/90 without the Minot Air Force Base’s WAPA
allocation and respective load.
Member Energy Purchases
Member energy purchases
of 2,418.9 GWH in 2015
demonstrated a 3.0 %
decrease from 2014.
Central Power’s peak
Mick Kossan, C.P.A.
demand for 2015 was set
Manager of Accounting
& Finance
in January at 463.7 MW.
This is the second highest
peak recorded over the past two years of having six
fully consolidated members, trailing only the 477.6 MW
realized in January of 2014. Looking ahead to 2016,
Central Power’s peak in January was 438.2 MW, well
below both 2014 & 2015.
In 2015, Central Power paid an average power supply
cost of 50.46 mills per kWh, up from 49.46 mills per kWh
in 2014, an increase of 2.0%.
Rates
In 2015, Central Power on behalf of its members spent
Western Area Power Administration
The 13 percent federal hydropower resource is secured
through a firm Contract Rate of Delivery (CROD)
contract with WAPA. The conditions from 2011 where
the main-stem reservoir system was at unprecedented
levels above the Corps of Engineers preferred storage
levels has declined in the years following, but capacity
remains close to average. Because of this, WAPA has not
made any modifications to the 2010 rate for the years
2011-2015. While the composite rate on a mills per
kWh basis remains the same for 2015 at 33.25 mills, the
$125,881,214 on wholesale power purchases. This
amounts to over 88 percent of Central Power’s annual
operating expense. Adding in Central Power’s cost of
operation, including $190,666 in wheeling payments to
Otter Tail Power for use of their transmission facilities
and accounting for system losses, Central Power’s
members paid an all-inclusive average of 57.80 mills per
kWh in 2015, up from 56.71 mills in 2014, which is an
increase of approximately 1.9%.
Power Supply
Central Power’s two power supply resources, the
Western Area Power Administration (WAPA) and Basin
Electric Power Cooperative (Basin), comprise over
88 percent of Central Power’s operating expenses.
Approximately 13 percent of Central Power’s power
supply is federal hydropower produced from the mainstem Missouri River system and marketed by WAPA.
The balance, or 87 percent, of our power is supplied
rate incorporates a 4.84 mill decrease in the drought adder,
to 11.83 mills, and an offsetting increase in the base rate The
base rate will continue to be subject to the Federal Register
process, but WAPA can recalculate the drought adder each
year as additional revenue is needed to cover additional
purchased power to meet its contracts or if above median
water conditions should occur and the adder liability goes
down. WAPA has the ability to adjust the drought adder up
or down 2 mills a year without having to facilitate the public
hearing process.
Energy
in Gigawatt - Hours
2,500.0
3,000.0
2,500.0
Member
Load Growth
Energy
2,000.0in Gigawatt - Hours
2,500.0
2,000.0
3,000.0
1,500.0
2,000.0
1,500.0
2,500.0
1,000.0
1,500.0
1,000.0
2,000.0
500.0
1,000.0
500.0
1,500.0
0.0
500.0
0.0
1,000.0
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2009
2010
2011
2012
2013
2014
2015
0.0
Member
Peak Demand
2004 2005 2006 2007 2008
Megawatts
Member
Peak Demand
Megawatts
600
Member
Peak Demand
600
Megawatts
Basin Electric Power Cooperative
The 87 percent Basin primarily coal-fired generation was
purchased at 53.31 mills per kWh, including the fixed charge,
under our Basin Supplemental All-Requirements Contract.
This is up from 52.01 mills per kWh, or 2.5%,
in 2015.
After holding the rate increase that Basin implemented in
2013, which incorporated a base demand rate of $16.74/
kW and an energy charge of 27.51 mills/kWh, through 2015,
Basin’s power rates are increasing significantly in 2016. The
base demand rate for 2016 is $18.06/kW, a 7.8% increase,
while the energy rate is 29.55 mills/kWh, a 7.4% increase.
Basin’s budgeted composite rate for 2016 to Central Power is
57.13 mills/kWh, an increase of 4.11 mills from 2015.
The IS Lease Program, whereby Basin “leases” qualifying
member-owned components of high voltage transmission
facilities, was not modified. Under this lease arrangement,
Basin has contracted rights to these facilities and they are
included in the Integrated System (IS) and are therefore
included in the tariff that is charged to all users of the Upper
Missouri Zone (UMZ) in SPP. Central Power received IS
lease payments totaling $3,292,783 in 2015. Central Power
budgeted to receive an estimated $2.27 million in IS Lease
payments in 2016.
500
600
Member
Peak Demand
500
Megawatts
400
600
500
400
300
500
400
300
200
400
300
200
100
300
200
100
0
200
100
0
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2007
2008
2009
2010
2011
2012
2013
2014
2015
100
0
0
Member
Rates
2004
2005 2006
Average
Mills/kWh
Member
Rates
Average Mills/kWh
0.6
60
Member
Rates
60
Average Mills/kWh
0.9
50
60
Member
Rates
50
1.7
Average Mills/kWh
40
60
50
40
30
50
40
30
0.8
1.31
1.13
0.8
1.31
1.13
31.7
31.57
31.7
31.57
20
40
30
20
31.7
31.57
10
30
20
10
31.7
31.57
0
20
10
0
2004
2004
2004
0.8
0.8
1.31
32.86
32.86
0.99
0.99
35.32
31.86 35.32
31.86
1.13
0.99
35.32
1.7
39.58
39.58
1.7
47.7
0.9
43.22
43.22
0.9
1.7
52.65
47.7
0.9
52.65
47.7
43.22
39.58
52.65
0.9
0.9
0.9
0.9
52.65
55.44
55.44
55.44
55.44
56.71
56.71
56.71
56.71
0.6
57.8
57.8
0.6
57.8
0.6
57.8
47.7
43.22
32.86
31.86
32.86
31.86
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2008
2009
2010
2011
2012
2013
2014
2015
1.13
1.31
0.99
39.58
35.32
10
0
Total
Utility Plant
0
$,
Millions Utility Plant
Total
2004 2005 2006 2007
$, Millions
300,000,000
Total
Utility Plant
300,000,000
$, Millions
250,000,000
Total
300,000,000Utility Plant
$,
Millions
250,000,000
300,000,000
200,000,000
250,000,000
200,000,000
250,000,000
150,000,000
200,000,000
During 2015, Central Power extended the all requirements
supplemental wholesale power contract with Basin through
the year 2075. In a corresponding move, our members
extended their all requirements contract with Central Power
150,000,000
200,000,000
100,000,000
150,000,000
100,000,000
150,000,000
50,000,000
100,000,000
50,000,000
100,000,000
0
50,000,000
0
Central Power Electric Cooperative, Inc.
2005
2004
0.0
500.0
50,000,000
0
10
2004
2015 Annual Report
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014 2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014 2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014 2015
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014 2015
0
11
for the same time period. Our long term contract helps
provide certainty at Basin which allows them to secure
reliable, affordable electric energy for the membership
for years to come.
jointly served under the ITA will now be full tariff loads
in either SPP and/or MISO. All of these issues as well as
the completion of the integration into SPP is shaping
2016 into being an unique and challenging year.
Southwest Power Pool
In October of 2015, the Central Power Board of Directors
voted to have Central Power join the Southwest Power
Pool(SPP) as a Transmission Owner. SPP is the regional
transmission organization that both WAPA and Basin
Electric had joined earlier. With this decision, Central
Power was able to submit qualifying high voltage
transmission facilities for inclusion into the tariff of the
UMZ, the new zone created in SPP for the integration
of WAPA and Basin into the RTO, and receive revenue
requirements from SPP for providing those qualifying
facilities. While the integration of Central Power into
SPP is still on-going with negotiations and hearings in
front of the Federal Energy Regulatory Commission, the
revenues anticipated to be received from becoming a
Transmission Owner in SPP are estimated to be $6.4
million. On a related note, the Integrated Transmission
Agreement (ITA) between Central Power and Ottertail
Power Company (OTP) expired on December 31, 2015.
With no extension or carry-forward arrangement in
place, both Central Power and OTP loads that were
12
Central Power Electric Cooperative, Inc.
Report from the Treasurer
Troy Presser
Secretary/Treasurer
The year 2015
operations resulted
in a net margin of
$5,342,550. An
operating margin of
$594,200 netted with
interest income of
$13,376, Basin Electric
Cooperative’s capital
credits for $4,428,438,
other patronage
dividends for $592,288,
and $285,752 in nonoperating losses make
up this net margin.
Central Power’s member energy purchases were down
3.0% from the prior year, while demand purchases
were down 1.6%, or almost 73 MW. Only two of
Central Power’s six members realized an increase in
member loads over the previous year. Purchased
power, which accounts for 88% of total expenses,
totaled $125,881,214 million, down $1,567,169 from
2014. Central Power’s total cost of service for 2015
was $142,674,149, which was $717,303 less than
2014. Transmission operations and maintenance costs
totaled $3,708,207, which was $487,172 less than
2014, and distribution operations & maintenance costs
totaled $1,828,491, which was $392,075 less than last
year as well. Administrative and general expenses
were $1,850,941, an increase of $122,353 over 2014.
Depreciation expense in 2015 totaled $5,743,773,
an increase of $992,637, while taxes were $163,765,
or $10,676 more than 2014. Interest expense was
$3,408,482 in 2015, an increase of $603,745, and
included $379,809 in costs that were capitalized to
ongoing work orders as allowance for funds used
during construction. Other deductions were $4,343 in
2015, up $753 from 2014. Total non-power expenses
were $849,866 more than last year.
The Board of Directors continues the practice of using
a rotating Financial Review Committee each month to
review the financial expenditures of the cooperative.
This committee then reports to the full board.
The accounting system is kept in accordance with
the uniform system of accounts prescribed by RUS
and audited by a certified public accounting firm
each year. The Eide Bailly LLP staff completed a 2015
records audit recently and found those documents
accurate and in accordance with Generally Accepted
Audit Principles and in compliance with Government
Auditing Standards.
2015 Annual Report
13
Board of
Directors
Central Power
Employees
Mark Brehm, President
Ray Keplin, Vice President
Northern Plains Electric Cooperative
North Central Electric Cooperative
Carrington, ND
Bottineau, ND
Troy Presser, Secretary/
Treasurer
Robert Wolf, Asst.
Secretary/Treasurer
Mclean Electric Cooperative
Garrison , ND
Verendrye Electric Cooperative
Velva, ND
Arden Fuher, Director
Kyle Hilken, Director
Dakota Valley Electric Cooperative
Milnor, ND
Capital Electric Cooperative
Bismarck, ND
Debra Hoffarth,
Attorney
Pringle and Herigstad, PC
Mick Kossan, CPA
Tom Meland, PE
Mark Sherman, PE
13 yrs • Manager of Accounting & Finance
20 yrs • General Manager
18 yrs • Manager of Operations
and Engineering
Kandace
D’Ambrosio
Dave Klein
36 yrs • Senior
Accountant
16 yrs • Executive
Assistant / HR &
Accounting Specialist
Employee Benefits
Administrator
Marlene
Guttormson
4 yrs • Info Mgmt.
Specialist
Lindsay Lawson
Lance Haugen
Alex D’Ambrosio
1 yr • Procurement
Manager
37 yrs • Operations
Superintendent
3 yrs • Compliance
Officer
Warehouse
14
Relay &
Electronics
Crew
Transmission Line Crews
North Area
Transmission
Substation Crew
Construction
Coordinator
Todd Ahmann,
CCNA
15 yrs • Network Administrator
Ryan Callahan, PE
Eric Popinga
Dennis Olson
Geri Jacob
9 yrs • Chief Transmission
Engineer
3 yrs • Real Estate
Administrator
13 yrs • Chief Substation
Engineer
33 yrs • Administrative
Coordinator
Chris Fazardo
Rolan Bye
Randy Brunner
Wil Fogarty
Jon Oster
7 mos • Assis. Network
Administrator
5 yrs • Transmission Line
Design Engineer
10 yrs • Substation
Engineer
1 yr • Substation
Engineer
16 yrs • CAD Technician
Distribution Substation Crew
South Area
Substation Crew
Support
Personnel
Don Graf
Troy Aannerud
Rick Koenig
Brady Kjos
Matt Enget
Dylan Duflo
Sheldon Baglien
Josh Larson
Kent Vollmer
Chuck McNicholas
Leon Nieters
Cody Vrem
Rick Baukol
Budd Redding
39 yrs • Warehouseman
11 yrs • Lineman
Foreman
8 yrs • Lineman
Foreman
5 yrs • Lineman
4 yrs • Lineman
4 yrs • Lineman
25 yrs • Electrician
Foreman
9 yrs • Electrician
15 yrs • Electrician
Foreman
37 yrs • Lineman
30 yrs • Lineman
Foreman
10 yrs • Electrician
38 yrs • Electrician
Foreman
36 yrs • Equipment
Operator/Welder
Randy
Miranowski
Chad Brown
Corey Carstens
Devin Blada
Lucas Ramirez
Alex Bloms
Jeremy Fix
Tanner Kavadas
Jacob Erdmann
Jonas Sova
Ron Bartsch
Doug Ferguson
Ryan Redding
Ethan Shoberg
11 yrs • App. Asst.
Warehouseman
8 yrs App. Asst.
Warehouseman
3 yrs • Lineman
1 yr • Lineman
1 yr • App. Lineman
1 yr • App. Lineman
1 yr • App. Lineman
1 yr • App. Electrician
7 mos • App. Electrician
5 yrs • Electrician
2 mos • App. Electrician
7 yrs • Electrician
1 yr • App. Lineman
7 yrs • Electrician
Central Power Electric Cooperative, Inc.
2015 Annual Report
Randy Meyer
22 yrs • Mechanic
Equipment Operator
15
15
Year in Review – Operations and Engineering
Central Power’s Operations
& Engineering Department
completed several major
projects in 2015 and
continued designing,
improving, operating,
and maintaining our
Member Cooperative’s
$248.5M investment in
Central Power. Central
Power’s very talented and
Mark Sherman, P.E.
dedicated
employees once
Manager of Operations
& Engineering
again impressed me with
their continuing efforts to build the significant system
additions required to serve our member cooperatives.
• Distribution Substation Capacity Increases
Long Term Investments
Central Power made significant system additions and
modifications in 2015 which include:
• Bismarck Area Voltage Conversion
Projects – The Circle K and Grandview Pines
distribution substations were converted from
43.8kV to 115kV high side voltages to increase
capacity and approximately 6.5 miles of
existing transmission line was reconductored/
reconfigured as part of the overall voltage
conversion project. The Circle K and Grandview
Pines voltage conversion projects included
the installation of new control systems; 115kV
power circuit breakers; and 20 MVA, 115-12.5kV
transformers at each substation.
• Dunning 60kV Transmission Loop – The
– Capacity increases were performed at
the Antler, Blue Flint, Circle K, Forbes, and
Grandview Pines substations.
• Dunning 115-60/43.8kV Transmission
Substation – A five position 115kV ring bus,
second 115-60kV transformer, new control
building, and new control system were installed
within the existing Dunning 115kV substation.
The modifications were to make provisions for
the connection of the Bottineau SE to Dunning
115kV transmission line as well as to provide
a redundant 115-60kV transformer for Central
Power loads between the Dunning substation
and Kenmare.
following projects were completed creating
a 60kV transmission loop from the Dunning
substation:
• Dunning to Westhope 7 Mile Long, 60kV
Transmission Line Construction Project
• Westhope to Antler 14 Mile Long, 60kV
Transmission Line Construction Project
• Antler to Renville Corner 7 Mile Long,
60kV Transmission Line Construction
Project
• Renville Corner 60kV Breaker Station –
The Renville Corner 60kV breaker station
was built on the same site as the Renville
Corner distribution substation (which is
described below) to segment the Dunning
60kV transmission line loop.
• Bottineau SE to Dunning 115kV
Transmission Line Project – The final mile
of the 35 mile long Bottineau SE to Dunning
115kV transmission line over the J. Clark Salyer
National Wildlife Refuge has been completed. It
took considerable work and patience to move
through the process of permitting the overhead
crossing after initially being told that we would
only be permitted to cross the Refuge with very
expensive 115kV underground construction.
16
• Renville Corner Distribution Substation
•
– The Renville Corner 14 MVA, 60 – 13.2kV
distribution substation was constructed to
provide additional area substation capacity
in the Mohall to Westhope area.
Antler and Westhope Distribution
Substation Voltage Conversion Projects
– The Antler and Westhope distribution
Central Power Electric Cooperative, Inc.
substations were converted from 43.8kV
to 60kV high side voltages to allow them
to be connected to the new Dunning 60kV
transmission loop.
• Fessenden Distribution Substation and
43.8kV Transmission Line Project – We
completed construction of a new 12 mile long,
43.8kV transmission line that connects the new
Fessenden distribution substation to our Dome
Cathay transmission line. The new substation
contains a 7 MVA, 43.8-13.2kV transformer and
associated equipment.
• Rugby Area Modifications – Central
• Horizon Distribution Substation Transformer
Power worked with the Western Area Power
Administration and Otter Tail to make
transmission system modifications in Rugby.
Central Power rebuilt and reconfigured two
miles of 115kV transmission line as well as
reconfiguring Central Power’s 115kV ring bus
within the Rugby 230kV substation.
Bay Addition – A second transformer bay was
completed within the Bismarck Horizon
distribution substation to provide needed
capacity and redundancy in northwestern
Bismarck. The new substation bay contains a
14 MVA, 43.8 – 13.2kV transformer and
associated equipment.
• Turtle Lake Distribution Substation
• Leeds to Maddock 69kV Transmission Line
Replacement Project – A new Turtle Lake
substation was built as a replacement for our
old Turtle Lake substation and it contains a
5.25 MVA, 43.8-13.2kV transformer and
associated equipment.
Rebuild – We completed a 23 mile rebuild of
Central Power’s Leeds to Maddock transmission
line which was originally built in 1950.
• Long Lake 69kV Breaker Station – The Long
Lake 69kV breaker station was built directly
adjacent to the existing Long Lake distribution
substation to segment the Bottineau SE to
Thorne 69kV transmission line.
• Underwood 230kV Substation – The
substation’s original 230kV circuit switcher
was nearing the end of its useful life and was
replaced with a new 230kV circuit breaker and
disconnect switch.
• Minot West Distribution Substation
Transformer Bay Addition – A second transformer
bay was completed within the Minot West
distribution substation to provide needed
capacity and redundancy in western Minot. The
new substation bay contains a 14 MVA, 43.8 –
13.2kV transformer and associated equipment.
• Rangeley Junction to Harvey 43.8kV
Transmission Line Rebuild – We completed
a 22 mile rebuild of Central Power’s Rangeley
Junction to Harvey transmission line which was
originally built in 1950.
• Wolf Creek 69kV Breaker Station – The Wolf
Creek 69kV breaker station was built to segment
the Thorne to Rolla 69kV transmission line.
Maintenance Summary
Central Power performed the following activities as part
of our ongoing maintenance program:
• Battery Bank Testing and Maintenance –
Battery bank testing and maintenance was
performed at Agate 115kV, Barlow 115kV,
Benno Corner, Berthold 115kV, Bismarck East,
2015 Annual Report
17
Plains, or Verendrye) and a maintenance/repair
list was created from the line patrol reports.
• Transmission Substation Maintenance –
Bismarck North, Bottineau Southeast 115kV,
Central’s headquarters, Denbigh, Douglas
Creek, Dunning 115kV, Esmond 115kV, Gackle
OCB, Haram, Harvey 230kV, Hoving 115kV,
Josephine, Ludden, Max 115kV, MinnDak,
Minot South, Minot Southwest 115kV, Neal
115kV, Penn, Pleasant Lake, ProGold, Raub,
Rolette 115kV, Roseglen, Round Lake, Rolla
115kV, Rugby 115kV, Ruthville 115kV, Thorne
115kV, Towner 115kV, Underwood 230kV, and
Wyndmere OCB.
• Protective Relay Testing – Central Power
tested the protective relays at the Agate 115kV,
Blue Flint, Denbigh, Dome Cathay, Dickey OCB,
Elliott 115kV, Hoving 115kV, Max 115kV, Penn,
Rolette 115kV, Ruthville 115kV, and Ward 230kV
substations.
• Seven Year Distribution Substation
Maintenance – Central crews performed seven
year distribution substation maintenance at
Circle K, Dome Cathay, Dome Maxbass, Drake,
Forbes, Gackle, and Grandview Pines.
• Transmission Line Patrol and Maintenance
– Line patrol was completed throughout the
entire Central Power system in 2015. Central
Power’s line crew performed line patrol
activities on all Central Power 115kV lines and
the Wilton 230kV line. All remaining Central
Power transmission lines were patrolled by the
local member distribution cooperative (Capital,
Dakota Valley, McLean, North Central, Northern
18
Central performed transmission substation
maintenance at the Agate 115kV, Barlow 115kV,
Benedict OCB, Berthold 115kV, Bismarck North,
Bottineau 115kV, Bottineau Southeast 115kV,
Dickey OCB, Douglas Creek, Dunning 115kV,
Esmond 115kV, Gackle OCB, Hankinson 230kV,
Harvey 230kV, Hoving 115kV, Mallard 115kV,
Max 115kV, Minot SW 115kV, Neal 115kV,
Rangeley OCB, Rolette 115kV, Rolla 115kV,
Rugby 115kV, Ruthville 115kV, Thorne 115kV,
Towner 115kV, Wyndmere OCB, Underwood
230kV, Wahpeton 230kV, and Ward 230kV
substations.
What’s Ahead?
Central Power will continue with another aggressive
construction schedule in 2016 which will include the
following projects:
• Barlow 115-43.8kV Substation – We plan
to replace the control system at the Barlow
transmission substation as part of a planned
equipment replacement rotation.
Lucas Ramirez was named the “Outstanding Apprentice of the Year” by NDAREC.
(Top row, on stage, left to right: Chuck McNicholas, Mark Sherman, Ron Bartsch, Rick Koenig
Bottom Row, left to right: Jake Erdmann, Doug Ferguson, Leon Nieters, Brittney Ramirez,
Lucas Ramirez, Lance Haugen, Troy Aanerud)
• Bismarck 71st Avenue Distribution
Substation – A new 22 MVA, 115-12.5kV
distribution substation is needed on the north
side of Bismarck to accommodate load growth.
This project will include the construction of a
short 115kV tap line to connect the substation
to Central Power’s existing Ward to Circle K
115kV transmission line.
• Buchanan Distribution Substation
and Transmission Line Construction –
Construction was started on the Buchanan
substation in 2015 and we plan to complete the
43.8kV – 13.2kV distribution substation in 2016.
The substation will be served by a new 3.5
mile 43.8kV transmission line from our existing
Pipestem transmission line.
Central Power Electric Cooperative, Inc.
• Cleveland to Medina 43.8kV Transmission
Line Rebuild/Reroute – We plan to rebuild/
reroute approximately 8 miles of the existing
Cleveland to Medina line. The project will
include construction to modern standards as
well as removing the line from approximately
3.5 miles of sloughs. The line was originally
built in 1962.
• Crooked Lake Distribution Substation
Rebuild – We started construction on
the new Crooked Lake substation in 2015
and plan to complete the 43.8kV – 13.2kV
distribution substation in 2016. The existing
substation was built in a low lying area and is
now experiencing access and water related
problems.
• Fredonia 43.8kV Distribution Substation
• Coal Creek 43.8kV Transmission line
Maintenance – The insulators on the 6.1 mile
long transmission line have experienced higher
than normal failure rates and are scheduled for
replacement. One mile of conductor through
an area of rough terrain with long spans will
also be replaced.
2015 Annual Report
Rebuild – The Fredonia distribution substation
was built in 1951 with a single steel structure
design and is nearing the end of its useful
life. A replacement substation is planned for
construction near the existing substation.
19
• Fullerton 69kV Distribution Substation and
69kV Breaker Station Construction – The
Fullerton distribution substation and in-line
69kV breaker station construction was started
in 2015 and we plan to complete them in 2016.
The distribution substation will include a 7
MVA, 69kV – 13.2kV transformer along with the
associated equipment. The substation will be
located directly adjacent to WAPA’s Edgeley to
Forman 69kV transmission line.
• Harvey 230-115-43.8kV Substation – The
control system and the 230kV circuit switcher
at the Harvey transmission substation have
reached the end of their useful life and will
be replaced as part of a planned equipment
replacement rotation.
• Leeds to Agate 115kV Transmission Line
Selective Rebuild – We plan to replace 31
structures on the Leeds to Agate transmission
line in order to increase the transmission line’s
capacity by increasing ground clearance at
specific locations.
• Leeds Distribution Substation Low Side
Replacement – The existing Leeds distribution
substation low side structure is very compact
and is tightly located between the Western
Area Power Administration’s (WAPA) Leeds
substation and a county road. We plan to build
a new low side structure on the opposite side
of the county road to permit safer working
clearances within the structure and fenced area.
The transformer and 12.5kV breaker to the new
low side structure will continue to be located
within WAPA’s substation.
• Mohall to Sherwood 60kV Transmission
Line Construction – A new 8 mile long
60kV transmission line is planned which will
connect Central Power’s Mohall and Sherwood
distribution substations directly to Central
Power owned transmission facilities from the
Dunning 115-60kV substation.
• Neal 115kV Transmission Substation Breaker
and Control System Replacement – Four
115kV and three 43.8kV breakers as well as
the substation control system have reached
the end of their useful life and are scheduled
for replacement.
• Towner to Gardena 115kV Transmission
Line Rebuild – The Towner to Gardena 115kV
transmission line was built in 1961 with
approximately 8 miles of the route through the
J. Clark Salyer National Wildlife Refuge, which
has limited access due to the winding nature of
the Mouse and Willow rivers. We are planning
to replace structures and hardware on the eight
miles of this line through the Refuge.
• Ward 230kV Substation – Redundant 11543.8kV Transformer Addition – We plan to
install an additional transformer within the
Ward 230kV substation to provide redundancy
as well as additional capacity.
• Ward Distribution Substation to Horizon
• New Mobile Substation – Central Power has
recently taken possession of our new
20 MVA, 115kV x 69kV – 25kV x 12.5kV
mobile substation.
• Additional New Mobile Substation –
Central Power has been working through the
specification and proposal process toward
the possible acquisition of an additional new
mobile substation to replace our existing
1968 mobile. This proposed mobile would
be smaller than our new mobile and would
generally be used with lower primary voltages.
The new mobile substation will be specified
as a 10 MVA unit capable of being connected
to 69kV or 60kV or 43.8kV source transmission
lines and to supply power into 12.5kV or 25kV
distribution systems. We anticipate completing
the proposal evaluation process in the first half
of 2016, at which time the Central Power Board
will determine whether to move forward with
the project.
Distribution Substation 43.8kV Transmission
Line Construction – A new 6 mile long 43.8kV
transmission line will be built to provide system
redundancy in northwest Bismarck.
• Wolford Distribution Substation and
69kV Transmission Line Construction –
Construction started on the Wolford 7 MVA,
69kV – 13.2kV distribution substation in 2015
and the substation project will be completed
along with a 9 mile transmission line from the
new substation to Western’s Leeds to Agate
transmission line in 2016.
• Planning For Future Improvement
Projects – Our staff will continue planning
and coordinating for our very significant
2016 system improvement projects and will
expend significant effort to plan for our 2017
construction schedule.
20
Central Power Electric Cooperative, Inc.
2015 Annual Report
21
Statistics
Finance & Accounting Report
Balance Sheet
ASSETS AND OTHER DEBITS
UTILITY PLANT AT ORIGINAL COST
Utility plant in service
Construction work in progress
Accumulated provision for depreciation
Net Utility Plant
INVESTMENTS IN ASSOCIATED ORGANIZATIONS
OTHER ASSETS
Cash and temporary investments
Accounts receivable
Notes receivable
Material & supplies
Prepaid expenses
Other deferred debits
Total assets and other debits
LIABILITIES AND OTHER CREDITS
MEMBER EQUITY
Member patronage equity
Current year margins
Net member equity
LONG-TERM DEBT
CURRENT AND ACCRUED LIABILITIES
Notes payable
Accounts payable
Accrued taxes and liabilities
Total liabilities and other credits
Member Power Cost Statistics
2015
2014
Difference
$239,113,012
9,428,384
(63,477,796)
$185,063,601
$53,197,851
$209,914,218
15,754,641
(59,073,610)
$166,595,248
$49,178,908
$29,198,794
(6,326,257)
(4,404,186)
$18,468,352
$4,018,943
$165,108
13,586,391
573,000
14,156,643
520,816
2,859,707
$270,123,118
$164,423
14,568,771
573,000
13,142,804
516,824
2,950,439
$247,690,417
$685
(982,380)
0
1,013,839
3,993
(90,732)
$22,432,700
COST OF ELECTRIC SERVICE
PURCHASED POWER
Central Power’s WAPA purchases
Central Power’s Basin purchases
Total purchased power
TRANSMISSION & DISTRIBUTION SYSTEM EXPENSE
Wheeling (net)
Operations
Maintenance
General plant maintenance
Consumer billing expense
Administrative and general
Depreciation
Taxes
Interest
Contributions and other deductions
Total transmission & distribution system expense
Total cost of service
Operating margin (loss)
Interest Income
Loss on retirement of plant
G&T and other capital credits
Net patronage capital and margins
2014
Capital Electric Cooperative
344.0
339.7
89.6
81.1
79.2
77.2
73.9
Dakota Valley Electric Cooperative
631.8
624.0
615.8
569.7
558.3
518.5
474.0
McLean Electric Cooperative
132.9
142.5
133.4
117.6
111.1
107.8
105.7
North Central Electric Cooperative
261.5
288.2
274.3
254.2
245.0
239.6
235.3
Northern Plains Electric Cooperative
459.9
482.6
446.5
435.2
421.7
417.5
394.9
Verendrye Electric Cooperative
518.0
543.0
499.1
459.4
430.9
399.1
381.0
70.8
72.5
72.7
71.9
73.8
72.3
71.5
TOTAL PURCHASES (GWH)
2,418.9
2,492.5
2,131.5
1,989.1
1,920.0
1,832.0
1,736.2
TOTAL REVENUE FROM MEMBERS
$139.8
$141.3
$118.2
$104.7
$91.6
$79.1
$68.7
COST TO MEMBERS (Avg Mills/kWh)
57.8
56.7
55.4
52.6
47.7
43.2
39.6
(Average Mills Before Power Bill Credits)
58.4
56.7
55.4
52.6
48.6
44.1
41.3
$57.7
VEC - Minot Air Force Base
$63,808,782
5,342,551
69,151,333
150,909,244
$57,316,408
6,492,374
63,808,782
123,183,604
$6,492,374
(1,149,823)
5,342,551
27,725,640
37,073,000
12,079,895
909,646
$270,123,118
47,173,000
12,645,905
879,127
$247,690,417
(10,100,000)
(566,010)
30,519
$22,432,700
2014
Change
$139,809,855
$3,292,783
$165,712
$143,268,350
$141,348,386
$3,404,736
$164,701
$144,917,824
($1,538,532)
(111,953)
$1,011
($1,649,474)
$10,521,077
115,360,137
$125,881,214
$10,535,654
116,912,729
$127,448,384
($14,577)
(1,552,592)
($1,567,169)
$190,666
3,262,362
2,083,669
84,934
59,904
1,791,038
5,743,774
163,765
3,408,481
4,343
$16,792,936
$190,666
4,191,172
2,034,105
85,985
65,377
1,663,210
4,751,135
153,089
2,804,738
3,590
$15,943,068
$0
(928,810)
49,564
(1,051)
(5,473)
127,827
992,637
10,676
603,745
753
$849,866
$142,674,150
$594,200
13,376
(285,752)
5,020,726
$5,342,550
$143,391,452
$1,526,371
11,337
(371,340)
5,326,006
$6,492,374
($717,303)
($932,171)
2,039
85,588
(305,280)
($1,149,823)
2012
2011
2010
2009
$125.9
$127.4
$106.2
$94.3
$81.2
$68.9
Average mills/kWh total cost
50.5
49.5
48.3
45.9
41.0
36.7
32.4
WAPA - Cost (mills/kWh)
31.8
32.0
31.9
31.9
31.9
31.8
27.5@
Basin - Cost (mills/kWh)
Percentage power cost of member revenue
53.3
52.0
51.1
48.5#
42.7#
37.7#
33.4#
90.0%
90.2%
89.9%
90.0%
88.6%
87.1%
84.0%
$150.9
$123.2
$98.9
$63.8
$47.8
$34.6
$31.1
$3.4
$2.8
$2.1
$1.8
$2.0
$2.1
$1.9
$5,342,551
$6,492,374
$5,173,320
$4,121,451
$2,830,077
$2,486,078
$6,466,643
25.6%
25.8%
27.7%
32.0%
34.9%
35.6%
36.8%
DEBT
Long-term debt
Interest expense
TOTAL MARGINS
MEMBER EQUITY
2015
2013
Central Power Statistics
PURCHASED POWER COSTS
Statement of Revenue and Expenses
OPERATING REVENUES
Sales of Electricity
Basin IS Lease Revenues
Other Electric Revenues
Total operating revenues
2015
ENERGY PURCHASES (GWH)
@
WAPA's OTP wheeling credit was changed from a purchased power credit to a transmission operation credit: Yr 2009 - $218,234
#
Basin IS lease payments were reclassified from a purchased power credit to "Other Electric Revenues": Yr 2012 - $510,888; Yr 2011 - $553,462; Yrs 2010-2009 - $654,241
2015 Total Cost of Service
Capital Credit Retirements
YearsAmount
1958-1994$3,956,164
1995-19970
1998800,000
1999460,000
2000321,000
2002981,066
2003976,446
20041,046,885
20051,300,103
20061,330,330
20071,365,562
20081,086,708
2009114,355
Basin......................... 80.86%
WAPA........................ 7.37%
Operations &
Maintenance.............. 3.75%
Depreciation &
Amortization.............. 4.03%
Interest...................... 2.39%
Administrative &
General...................... 1.36%
Wheeling................... 0.13%
Taxes & Other............ 0.11%
2010-20130
201434,101
20150
Refunds to Date:$13,772,721
22
Central Power Electric Cooperative, Inc.
2015 Annual Report
23
Central Power 2015 Delivery Point Data
Substation
KVA
Capacity
KWH
Purchased
Annual
Maximum
Demand
Annual
Load
Factor
Cogswell
3,500
7,632,000
2,481
35.1
Benedict
3,500
7,466,252
1,800
47.3
Dickey
7,000
6,408,000
2,032
36.0
Blue Flint
14,000
42,354,273
6,003
80.5
Dome Lisbon
4,200
8,277,600
1,844
51.2
Butte (OTP Balfour)
142,347
33
48.8
Dwight
7,000
13,323,600
4,230
36.0
Coal Creek
4,200
8,059,967
1,380
66.7
Edgeley
7,000
18,241,562
4,821
43.2
Coleharbor
2,800
6,779,815
1,668
46.4
Ellendale
3,500
12,524,400
3,127
45.7
Crooked Lake
1,680
5,536,800
1,619
39.0
Forbes
3,500
3,119,400
862
41.3
Douglas Creek
14,000
8,854,225
3,048
33.2
Forman
2,800
6,369,337
1,673
43.5
Garrison
7,000
12,639,600
3,377
42.7
Fredonia
2,800
5,040,000
1,373
41.9
Lewis & Clark 12.5
5,250
7,185,600
1,630
50.3
Gackle
3,500
6,424,200
1,641
44.7
Mercer
2,800
3,438,404
1,072
36.6
Geneseo
3,500
9,190,800
2,759
38.0
Raub
14,000
11,797,082
2,564
52.5
Substation
KVA
Capacity
KWH
Annual
Purchased Maximum
Demand
Annual
Load
Factor
McLEAN AREA
DAKOTA VALLEY AREA
7,000
10,332,000
2,516
46.9
Roseglen
14,000
12,309,939
2,812
50.0
14,000
70,316,618
9,439
85.0
Turtle Lake
3,500
3,779,298
1,686
25.6
1,000
2,590,200
632
46.8
Washburn
2,100
2,577,884
918
32.1
450
174,028
25
79.8
Hankinson
Hankinson Ethanol
Jud
Kulm
7,000
7,265,978
2,054
40.4
NORTHERN PLAINS AREA
Ludden
28,000
79,659,444
15,204
59.8
Amoco
2,100
878,615
721
13.9
Millarton
7,000
13,039,200
3,164
47.0
Balta
3,500
6,648,373
2,033
37.3
Milnor
7,000
11,515,200
2,639
49.8
Barlow Buffalo 12.5
750
603,522
249
27.7
Milnor, North
5,250
10,605,600
2,729
44.4
Belcourt
14,000
27,468,000
7,772
40.3
LaMoure
MinnDak #1-North Bay
22,400
49,041,781
4,690
119.4
Bisbee
5,000
7,910,258
2,420
37.3
MinnDak #2-South Bay
22,400
53,641,401
11,131
55.0
Bowdon
5,250
10,694,400
3,138
38.9
4,200
9,408,240
2,681
40.1
Mooreton
4,200
6,312,000
1,912
37.7
Brantford
Oakes North
7,000
5,316,599
2,063
29.4
Cando - Center Bay
7,000
11,777,565
3,324
40.5
11,200
11,805,802
3,845
35.1
Cando - South Bay
7,000
13,040,822
3,634
41.0
7,000
14,569,200
2,817
59.0
Cando Industrial - N. Bay
7,000
12,297,968
3,882
36.2
294,480
540
6.2
Carrington 12.5
14,000
19,958,880
4,878
46.7
Carrington Industrial
Oakes 24.9, West
Omega
Pomona, FPLE
Pro Gold #1 - West
69,400
387,774
1,674
2.6
Pro Gold #2 - East
69,400
166,756,140
21,276
89.5
Tyler
3,500
9,424,800
2,039
52.8
Wyndmere, North
2,800
5,385,600
1,459
42.1
Wyndmere, South
3,500
6,823,800
1,931
40.3
14,000
44,272,800
6,192
81.6
Churches Ferry
7,000
4,706,467
1,731
31.0
Dome Cathay
4,200
5,431,200
1,704
36.4
Dome Orrin
4,200
6,727,872
1,759
43.7
Esmond
4,200
3,788,986
1,476
29.3
Fessenden
7,000
1,739,878
1326.6
44.8
Fort Totten
5,250
8,246,916
2,124
44.3
4,200
8,063,082
2,674
34.4
Antler
14,000
18,468,215
3,661
57.6
Glenfield
Jamestown
14,000
31,730,458
6,919
52.4
Barton
2,500
4,433,608
1,420
35.7
Josephine
10,500
17,371,200
4,430
44.8
Bottineau SE
14,000
16,369,215
4,877
38.3
Kensal
2,800
9,214,591
2,448
43.0
Dome Maxbass
4,200
7,912,800
1,855
48.7
Lallie
7,000
5,263,068
1,684
35.7
Dunseith
7,000
15,364,987
4,351
40.3
Leeds 12.5
5,250
11,225,443
3,857
33.2
Haram
14,000
8,584,503
1,647
59.5
Maddock
14,000
10,809,619
5,623
21.9
Kelvin
7,000
9,475,200
2,763
42.8
Medina
1,680
5,738,780
1,348
48.6
Kramer
3,000
9,873,000
2,714
41.5
New Rockford
5,250
11,213,580
3,068
41.7
Lansford
5,250
18,357,600
3,194
65.6
Penn
7,000
18,394,507
2,737
76.7
Long Lake
14,000
7,709,023
2,409
36.5
Pingree
Metigoshe
14,000
15,969,600
5,450
33.4
Pipestem
Mohall
7,000
11,523,600
3,506
37.5
Newburg
5,250
17,217,930
3,499
56.2
Renville Corner
14,000
290,708
1,131
Rolette
2,000
7,437,600
2,090
Sherwood
7,000
13,969,192
2,996
53.2
Round Lake
Souris
7,000
15,047,011
4,280
40.1
Rugby
Turtle Mountain
8,400
22,820,437
6,538
39.8
Tuttle
Westhope
7,000
10,374,000
2,138
55.4
Wolford (OTP/CPEC Knox)
Wiley
7,000
17,287,200
3,418
57.7
Woodworth
Willow City
2,800
5,622,554
1,792
35.8
Wolf Creek
14,000
22,317,628
6,214
41.0
NORTH CENTRAL AREA
24
Substation
3,500
8,963,082
2,366
43.2
14,000
20,141,117
5,465
42.1
Pleasant Lake
7,000
22,417,060
3,461
73.9
Robinson
3,500
6,480,000
2,248
32.9
34.6
Rock Lake
3,180
4,423,446
1,172
43.1
40.6
Rolla
5,250
9,525,600
2,659
40.9
10,500
17,035,200
4,296
45.3
3,500
10,332,952
3,079
38.3
1,500
2,572,800
1,537
19.1
750
1,299,197
429
34.6
7,000
9,477,130
4,255
25.4
Central Power Electric Cooperative, Inc.
KVA
Capacity
KWH
Purchased
Annual
Maximum
Demand
Annual
Load
Factor
14,000
16,800
14,000
3,500
14,000
14,000
7,000
1,680
5,250
4,200
5,250
3,000
7,000
2,800
2,800
14,000
14,000
14,000
14,000
14,000
14,000
14,000
14,000
14,000
14,000
14000
14,000
30,686,400
20,030,039
36,410,400
12,034,800
11,751,307
8,833,568
19,244,792
4,225,200
5,714,400
12,964,702
13,975,200
5,661,000
14,313,764
5,426,294
5,517,000
12,686,903
33,019,200
27,957,600
28,815,618
9,626,396
44,352,000
36,043,200
34,603,813
12,133,751
20,489,170
6,047,294
38,477,337
507,384
12,121,200
64,887
7,516,800
8,611,471
17,960,400
10,729,800
10,245,600
9,172,800
6,307
5,695
5,731
2,435
3,244
3,507
2,835
1,075
1,468
3,391
2,429
1,696
3,996
1,688
1,804
3,548
7,754
6,142
7,581
2,472
9,202
8,741
8,222
3,508
7,114
3,422
6,607
805
2,695
79
2,155
2,513
4,813
2,966
3,187
2,338
55.5
40.1
72.5
56.4
41.4
28.8
77.5
44.9
44.4
43.6
65.7
38.1
40.9
36.7
34.9
40.8
48.6
52.0
43.4
44.5
55.0
47.1
48.0
39.5
32.9
20.2
66.5
7.2
51.4
9.4
39.8
39.1
42.6
41.3
36.7
44.8
52,217,271
11,600
51.4
1,799,994
543
37.8
VERENDRYE AREA
Air Base North
Air Base South - North Bay
Air Base South - South Bay
Bergen
Berthold - South Bay
Berthold - North Bay
Denbigh
Des Lacs
Drake
Foxholm
Glenburn
Granville
Harvey
Lincoln Valley
Lonetree
Minot, NDSU
Minot, East - North Bay
Minot, East - South Bay
Minot, North - South Bay
Minot, North - North Bay
Minot, South - North Bay
Minot, South - South Bay
Minot, Southeast -North Bay
Minot, Southeast -South Bay
Minot, West - South Bay
Minot, West - North Bay
Neal 12.5
Prairie Winds ND 1
Radar
Radar Wind Turbine
Rangely
Ryder
Surrey
Towner
Velva
Voltaire
3,500
8,120
5,250
3,500
7,000
3,500
4,200
10,500
CAPITAL
Apple Creek
Baldwin
Bismarck East
Bismarck North
Christiana
Circle K
Erickson
Goodrich
Gransview Pines
Horizon
Horizon II
Lincoln
McClusky
Menoken
Moffit
Riverview
South Central Grain
South Washington
Sterling
Ward
Wing
14,000
2,800
37,300
20,000
1,680
20,000
1,680
1,000
20,000
14,000
14,000
14,000
1,000
5,000
1,500
5,250
1,000
8,400
450
14,000
2,500
Bismarck 115kv
Bismarck, East
Bismarck, NW
Bismarck 12.5
Bismarck North
Ward
Ecklund, FPLE
Wilton Wind II
Baldwin Wind
Polarware/(OTP McClusky)
25,000
25,000
10,000
22,400
50,000
1,945,419
536
41.4
Service Area Transmission
Substations
Substation
Agate
Barlow
Bottineau, OTP
Bottineau, Southeast
Carrington, WAPA
Devils Lake, OTP
Devils Lake, WAPA
Dunning
Dunning
Dunning
Edgeley, WAPA
Edgeley, WAPA
Ellendale, MDU
Ellendale, MDU
Elliott
Esmond
Forman, OTP
Forman, WAPA
Forman, WAPA
Hankinson, OTP #1
Hankinson, OTP #2
Harvey
Hoving
Jamestown, OTP
Jamestown, WAPA
Jamestown, WAPA
Kenmare, MDU
Leeds, WAPA
Logan, BEPC
Mallard, Xcel
Max
Neal
Oakes, OTP
Rolette
Rolla
Rolla
Rugby
Rugby, WAPA
Rugby, East OTP
Ruthville
SW Minot
Thorne
Underwood
Wahpeton, OTP
Washburn, WAPA
Wishek, MDU
Wishek, MDU
Ward Transmission
Ward Transmission
Transformer Owner
CPEC
CPEC
CPEC
CPEC
CPEC
OTP
WAPA
CPEC
CPEC
CPEC
WAPA
WAPA
MDU
MDU
CPEC
CPEC
OTP
WAPA
WAPA
CPEC
CPEC
CPEC
CPEC
OTP
WAPA
WAPA
MDU
WAPA
BEPC
CPEC
CPEC
CPEC
OTP
CPEC
CPEC
CPEC
CPEC
WAPA
OTP
CPEC
CPEC
CPEC
CPEC
CPEC
WAPA
MDU
MDU
CPEC
CPEC
KV Total KVA Capacity
115/69
46,700
115/41.6
46,700
(2) 115/41.6
42,400
115/69
56,000
115/41.6
46,700
115/41.6
56,900
115/41.6
20,000
115/41.6
46,700
115/60
74,667
115/60
30,000
115/69
20,000
115/41.6
15,000
230/115
112,000
115/41.6
46,700
115/41.6
28,000
115/69
25,000
230/115/41.6
140,000
115/69
30,000
69/41.6
12,500
230/41.6
56,000
230/41.6
41,600
230/115/41.6
140,000
115/41.6
28,000
(2) 345/115/41.6
224,000
(2) 230/115
400,000
(2) 115/41.6
29,400
115/57
30,000
115/69
40,000
230/115
200,000
(2) 115/41.6
93,400
115/41.6
46,700
115/41.6
46,700
230/41.6
33,600
115/69/41.6
56,000
69/41.6
7,000
115/69
70,000
115/41.6
46,700
115/41.6
20,000
230/115
125,000
115/41.6
56,000
115/41.6
93,000
115/69
70,000
230/41.6
44,800
(2) 230/115/41.6
280,000
230/41.6
41,667
230/115
112,000
115/41.6
30,000
230/115
125,000
115/41.6
50,000
Service Area Circuit
Breaker Stations
Substation
46,894,495
92,846,109
852,242
540
3,033,809
143,514,996
318,288
250,704
265,080
13,241
21,648
24,216
9,024
24.7
43.8
Benedict
Dickey
Carrington, OTP
Gackle
Rangely
Jamestown NW, OTP
Sykeston, OTP
Towner
Washburn, OTP
Wyndmere
11,637
37,476
480
468
581
26
3.0
43.7
7.6
6.1
5.2
5.8
CPEC Circuit Breakers in FOREIGN STATIONS
Rugby, East OTP
Edgeley, WAPA
Leeds, WAPA
Rugby, WAPA
101 SCADA OPERATED LINE SWITCHES
Transmission Substations Capacity
Trans sub capacity - CPEC owned (for Form 12)
2015 Annual Report
KV
CIRCUIT BREAKERS
41.6
69
41.6
41.6
41.6
41.6
41.6
115
41.6
41.6
1
1
3
1
1
1
1
3
3
2
115
115
115
115
3
1
1
1
3,532,534
1,763,767
25
Member Financial & Statistical Report
Power Suppliers
Capital
Dakota Valley
McLean
North Central
Northern Plains
Verendrye
Total or Average
$30,876,953
26,873,406
3,951,747
$30,825,153
51,800
1,367,040
$1,418,840
$46,301,693
40,700,624
4,271,342
$44,971,966
1,329,727
1,765,486
$3,095,213
$12,713,512
10,385,270
1,660,520
$12,045,790
667,722
443,023
$1,110,745
$22,675,310
18,660,393
3,576,425
$22,236,818
438,492
825,359
$1,263,851
$37,734,175
30,690,200
6,048,525
$36,738,725
995,450
1,456,940
$2,452,390
$47,640,762
41,723,311
5,247,435
$46,970,746
670,016
2,369,218
$3,039,234
$197,942,405
169,033,204
24,755,994
$193,789,198
4,153,207
8,227,066
$12,380,273
$96,307,726
33,347,330
$91,321,031
29,330,879
$34,268,674
8,634,969
$77,744,713
28,471,608
$122,614,137
49,601,057
$106,214,198
29,262,628
$528,470,479
178,648,471
Deferred Debits
$62,960,396
14,593,117
6,837,710
1,192,026
$61,990,152
31,664,360
12,818,601
1,347,274
$25,633,705
5,335,134
2,478,413
509,706
$49,273,105
13,322,875
5,218,929
769,406
$73,013,080
26,073,298
8,114,432
1,638,511
$76,951,570
24,665,074
10,338,697
2,295,466
$349,822,008
115,653,858
45,806,782
7,752,389
Total Assets
$85,583,249
$107,820,387
$33,956,958
$68,584,315
$108,839,321
$114,250,807
$519,035,037
$42,635,054
34,269,152
5,348,114
3,330,929
$42,359,718
52,230,942
8,206,033
5,023,694
$10,705,330
19,517,393
2,894,253
839,982
$21,659,903
33,520,554
11,538,599
1,865,259
$34,626,340
61,431,675
7,252,296
5,529,010
$35,672,637
62,487,033
9,984,810
6,106,327
$187,658,982
263,456,749
45,224,105
22,695,201
$85,583,249
$107,820,387
$33,956,958
$68,584,315
$108,839,321
$114,250,807
$519,035,037
17,381
1,781
45
19,207
5,836
598
74
6,508
3,493
400
36
3,929
6,143
1,668
32
7,843
10,172
1,359
22
11,553
14,244
1,948
49
16,241
57,269
7,754
258
65,281
207,934,111
126,330,954
1,178,414
335,443,479
128,488,776
491,594,640
800,892
620,884,308
50,773,960
68,633,258
6,179,748
125,586,966
139,293,070
111,171,205
4,189,956
254,654,231
223,004,655
212,337,926
8,090,918
443,433,499
216,257,385
264,303,119
88,143,189
568,703,693
965,751,957
1,274,371,102
108,583,117
2,348,706,176
$19,600,251
11,366,379
$13,315,186
32,776,966
$6,117,945
5,854,339
$10,493,727
10,998,603
$19,291,225
17,572,090
$20,964,928
22,110,483
$89,783,262
100,678,860
118,143
$31,084,773
95,360
$46,187,512
663,523
$12,635,807
392,919
$21,885,249
567,745
$37,431,060
4,435,807
$47,511,218
6,273,497
$196,735,619
Affiliated Organizations
Statement of Operations
Operating Revenue
Operating Expenses
Depreciation, Taxes, Interest & Other
Total Cost of Electric Service
Operating Margins
Non - Operating Margins
Total margins
Balance Sheet (Assets)
Utility Plant
Reserve for Depreciation
Net Utility Plant
Other Property and Investments
Current and Accrued Assets
Liabilities
Margins and Equities
Long - Term Debt
Current and Accrued Liabilities
Deferred Credits (operating reserves)
Total Liabilities
Other Statistics
Average number served:
All Residential (Any Irrigation)
All Commercial
All Other (For Resale)
Total
Central Power Members
kWh Sales
All Residential (Any Irrigation)
All Commercial
All Other (For Resale)
Total
Revenues
All Residential (Any Irrigation)
All Commercial
All Other (For Resale)
Total
Other Statistics
2,656
7.23
82.7/August
4,715
1.38
98.8/February
1,779
2.21
24.9/January
3,274
2.40
59.1/January
6,786
1.70
92.5/January
4,595
3.53
118.1/January
0
1,381
23,805
2.74
463.7/January
$0.093
17,465
$1,618
$11,857
$0.074
95,403
$7,097
$9,796
$0.101
31,964
$3,216
$7,104
$0.086
32,469
$2,790
$6,684
$0.084
38,383
$3,240
$5,516
$0.084
35,017
$2,925
$10,340
$0.084
35,978
$3,014
$8,264
Miles of Transmission Line
Central’s Transmission Line
Miles of Distribution Line
Consumers Served per Distribution Mile
Peak MW & month purchased from Central
Power
Revenue per kWh Sold
kWH Sold per Consumer
Annual Revenue per Consumer
Annual Revenue per Distribution Line Mile
26
Central Power Electric Cooperative, Inc.
2015 Annual Report
27
Our Mission
Central Power Electric Cooperative, Inc. exists to assist its member systems to become
the electric suppliers of choice. To accomplish our mission, we will:
• Serve as a leading and unifying force among our membership
• Provide a reliable, economical and efficient electric supply
• Perform those functions that can most efficiently be provided as a united effort
In accomplishing its mission, Central Power will adhere to the ideals of consumer
ownership and cooperative principles, where the member-consumer is placed first in
determining policies, procedures and practices.
Central Power Electric Cooperative, Inc
525 20th Avenue Southwest • Minot, ND 58701
Phone (701) 852-4407
28
Central Power Electric Cooperative, Inc.