20031015Teinert Exhibits.pdf

July, 2003
Principal
Pike Teinert
energy s tra tegies group LLC
Pike Teinert, Principal
esg
energy stra tegies group LLC
834 Harcourt Road
Boise, Idaho 83702
Work [phone]Cell [phone]Fax [phone]
Email pteinert&cableone. net
Home [phone]
PROFESSIONAL BACKGROUND
Thirty-four years of experience in the energy industry in positions
ranging from Design Engineer to Vice President provide a breath and
depth of experience uncommon in the industry.
Encompassing positions at investor
Electric Power Research Institute,
industry experience has provided a
and challenging energy industry.
An engineer by education, with several years of engineering/technical
background, positions in customer services, marketing and sales
management positions have for the last 30 plus years immersed me in theindustrys complex marketplace. At Texas Utilities Company during the
mid 1980' s head-to-head competition with gas and electric energy
companies provided the experience of successfully competing in an
industry that had been heavily regulated and noncompetitive for many
years. This unique blend of experience with some of the industry
leading companies offers an exceptional resource for industrial,institutional, commercial and mass-market clients that require
strategic energy service/solutions.
owned/public power utilities, the
EPRI, and consulting this broad
unique perspective of the changing
SUMMARY
Extensive experience in the utility industry encompassing engineering,electric service rules and regulations, consulting, sales, human
resources, field management, regional operations management, corporate
management and executive management positions provide a diverse and
solid base of experience. Significantly, this background with public
power, investor owned utilities and energy R&D, is vital experience in
understanding today ' s complex energy challenges. Frequent meetings withclient and company management and roundtable discussions with non-
management staff are important communications and discovery tools used
to develop understanding, consensus and solution driven results and
val ue .
Replacement Exhibit
Teinert, Di
As Corporate Account Executive, Regional Operations Manager and Retail
Regional Manager for EPRI, the energy industry s premier R & D
organization, an understanding of a broad range of energy industry
organizations, functions and practices have been added to my experience
base. Complex strategic sales to clients like, Southern Company, TVA,
TXU, Williams Energy, Reliant Energy, UtiliCorp and other North
American energy companies averaging $45 million per year in sales
provide insight and understanding of strategies and practices in North
America s leading energy companies.
As Vice President at the Orlando Utili ties Commission, I reorganized
the 207 employee, $10 million annual budget, Customer Service &
Conservation business unit into a customer driven, rapid response team
that reduced department expense by $1,000,000 annually and increased
Conservation program participation by 300%.
At Texas Utili ties, I analyzed, planned and negotiated contracts with
large industrial, commercial and institutional customers such as Texas
Instruments, Abbott Laboratories, Nucor Steel, Baylor University, EDS
and the Ft. Hood Military Base in Killeen, Texas. These agreements
increased their reliability, provided effective and efficient service
extensions, decreased their exposure to sabotage, improved their energy
efficiency and reduced their per unit electricity costs. At Ft. Hood, 9
distribution points of delivery were reduced to 2 transmission points
for this 62 MW client and included a facilities lease and maintenance
agreement.
As project team leader at Texas Power & Light Company, I developed
TP&L I s and subsequently Texas Utilities first interruptible rate, which
ultimately served multiple customers with over 600 MW of dispatchable,
interruptible load. This rate offered customers discounted energy costs
in return for demand interruption and also gave TP&L/TU an attractive
capacity avoidance and economic development/customer retention program
element.
In summary, this background and experience offers breath and depth that
is uncommon, unique, extremely beneficial and timely given the energy
industry I s rapidly changing and complex environment.
EXPERIENCE , EDUCATION, PROFESSIONAL
Principal - (February 2003 to Present)
esg, energy strategies group LLC, Boise, Idaho
Founded esg, energy strategies group LLC, an energy consulting firm, to
provide all markets with a strategic energy consulting practice
dedicated to energy solutions that ensure a stable and sustainable
energy future. Develops energy extension/service options that improve
service efficiency and effectiveness and provide value driven rate
options. Demand side strategies designed to develop, deploy and manage
strategic energy solutions for efficient and economic energy use. Using
industry leading technology and 30 plus years of experience, esg,
energy strategies group, LLC based in Boise, helps Idaho plan a clear
and concise energy road map for a stable and sustainable energy future.
Corporate Account Executive - (November 2001 to January 2003)
EPRI , Dallas, Texas
Managed the relationship/sales engagement with EPRI' s largest clients,
TVA, Southern Company, TXU and many other North American energy
companies. Responsibilities included initiating, developing and
maintaining account plans for each of these large and complex accounts,
including all business units. Account plans integrated the strategy,
goals and objectives of all business units with corporate
vision/mission and EPRI resources including future, current and past
products and services. Responsible and accountable for $45M in total
annual sales of EPRI resources to these key clients. Initiated and
maintained Value Analysis and Partnership Plans for each of the key
clients which demonstrated the value of EPRI resources in their
companies and provided a roadmap for continued high value benefits.
Retail Regional Manager - (January 2000 to November 2001)
EPRI , Dallas, Texas
Manage EPRI I S Retail Sector sales in South Central North America
averaging over $11 million annually, exceeding maximum sales goals.
EPRI's Retail Sector includes Industrial, Commercial and Mass markets
technologies for end use equipment efficiency, load management, market
research, power quality, customer service, transportation and
marketing/trading leading edge technologies.
Regional Operations Manager - (January 1998 to January 2000)
EPRI , Dallas, Texas
Managed EPRI Regional Operations for South Central North America, with
sales averaging $70 million annually. This new position forecasted,
contracted, monitored, expedited and reported and tracked sales for the
region. Customer contract and project status reporting was a critical
client contact function of this position that improved customersatisfaction significantly.
Retail Regional Manager - (January 1996 to January 1998)
EPRI , Dallas, Texas
A new position that managed EPRI' s Retail Sector sales in South Central
North America averaging more than $ 11 million annually. Focused
heavily on customer care for EPRI I S Retail sector, technologies which
includes Industrial, Commercial and Mass markets for end use equipment,
efficiency, load management, market research, power quality, customer
service, transportation and marketing/trading technologies.
Self Employed - (August 1994 to January 1996)Orlando, Florida
Managing family equity assets during this time increased my knowledge
of financial markets in the U. S. and abroad. Success in this endeavor
provided time to re-examine past experience and affirm career
aspirations for the future. As the energy industry continued to move
toward deregulation and a competitive future, more innovative customer
options providing value added products, services and pricing became
available to the marketplace and provided significantly greater energy
industry opportunities.
Vice President, Customer Services and Conservation - (September 1993 toSeptember 1994)
Orlando Utilities Commission , Orlando, Florida
Direct responsibility for the 207 employee Customer Service,
Operations and Conservation Divisions for this 1100 employee,
customer electric and water utility. Overall, preparing these
Field
240,000
divisions
at OUC to be successful in the competi ti ve marketplace was the primary
goal. Reducing costs; improving service through benchmarking; improving
response time; consolidating and reorganizing nonresidential customer
service functions; develop, acquire and install a new state-of-the-art
customer information system and changing the conservation function to
increase customer participation in programs were methods used to reach
Customer Service and Field Operations mission and budget goals. Staff
were reduced, customer service improved, and response time reduced and
customer participation in conservation programs more than tripled.
Overall, quarterly customer opinion surveys improved as the three
divisions in this department prepared for the competitive future.
Manager, Customer Services - (December 1992 to August 1993)
Orlando Utilities Commission, Orlando, Florida
Selected for this position in October 1992 by OUC's General Manager and
an executive peer group committee in a vigorous and detailed selection
procedure following a national search. Primary goal of the selection
procedure was to find and hire an experienced knowledgeable leader to
manage the new Customer Service department and to prepare it for the
competi ti ve marketplace.
Corporate Customer Service Consultant - (October 1991 to November 1992)
Texas Utilities Electric Company, Dallas, Texas
Customer Service, Technical and Marketing Support for 47,408 commercial
and industrial customers with an annual revenue of $333,711,000.
Competition for new customers, increasing sales to existing customers
and marketing demand side management technologies were most important
functions. Team Leader for New Rate Implementation and Distributed
Energy Interconnection Guideline committees.
Manager of Technical Services - (August 1985 to October 1991)
Texas Utilities Electric Company, Dallas, Texas
Developed customer service and marketing policies, practices and
procedures for residential, commercial and industrial customers
encompassing 1,122,000 customers and $1,956,609,000 annual revenue.
Successfully downsized this office by 18 employees during company
mergers. Chaired Edison Electric Institute s Commercial & Industrial
Applications and Cogeneration/Customer Service Committees at the
Company.
Manager of Industrial Services - (December 1980 to July 1985)
Texas Power & Light Company, Dallas, Texas
Developed policies, practices and procedures for new service,
marketing, sales strategy and tactics for 108,000 commercial and
industrial customers with annual revenue of $553,357,000. Held
positions on Edison Electric Institute and Electric Power Research
Institute Committees.
Manager, Bonham Office - (March 1979 to December 1980)
Texas Power & light Company, Bonham, Texas
Accountable for all operations, civic and community responsibilities
for Bonham and several surrounding towns for this investor owned
utility. Represented the Company before county and city officials, on
civic and community boards and was accountable for all Company
functions in the service area.
Assistant to the District Manager - (November 1977 to March 1979)
Texas Power & Light Company, Richardson, Texas
Responsible for management of all district employees in the largest
district in the Company, including approximately 80,000 customers, 100
employees in construction, engineering, accounting and customer service
functions with a construction and operating budget of $10,000,000annually.
Supervisor of Employment and Recruiting (June 1974 to November 1977)Texas Power & Light Company, Dallas, Texas
Interviewed and hired all professional personnel for the Company and
all non-exempt personnel for the corporate office. During fall and
spring recruiting seasons, supervised 5 to 10 recruiters on each trip
to 12 maj or uni versi ty campuses and filled an average of 30
engineering, accounting and sales positions each regular semester.
Power Consultant - (December 1972 to June 1974)
Texas Power & Light Company, Waco, Texas
Accountable as professional sales representative for 50 of the
Company s largest commercial and industrial customers, with annual
revenues of $35,000,000. Responsible for sales, billing concerns, new
service, service expansion/extension, rates and demand side management
programs.
Engineer (September 1968 to December 1972)
Texas Power & light Company, Dallas, Texas
Designed electrical facilities for new and existing central station
power plants in the 375 to 750 megawatt range, with project costs up to$350,000,000. Interfaced with mechanical and civil engineering design
teams to integrate electrical design with their system.
Education, Professional, Civic
BS, Electrical Engineering - (September 1968)
Texas Tech University, Lubbock, Texas
Bachelor of Science, Electrical Engineering, 1968
Registered Professional Engineer - Texas, 1991-1998.
In Texas: Rotary International, Chamber of Commerce,Lions Club
System Forecast Requirements
RECORD OF DECISION (ROD) DOCUMENTATION SUPPORT
TITLE
BCRT BUILD NEW 69/12.5KV STATION
Function:Key Info:CUSTOMER-Orig Date:5/27/99 Sequence No: 2113
Status:COMPLETED Region:In-Service-Date:6/1/00 Rev Num:
Sponsor:DISTPLAN Area:BOISE MRDN EAGLE Proj. Lead Tim 13 Mos Rev Date 6/20/00
By:KA GEORGESON Projects:BCRT: NEW SUBSTATION Cost In K$:560 Bucket:CRITICAL
DECISION:
Build a new 69/12.5kV 20MVA station near the HP Call Center site on Franklin Rd between Maple Grove and 5
Mile Roads.
SCOPE:
Determine the best course of action to serve the customer load requests for 4MW of additional load North of the existing HP Call
center, off of Emerald Sl between Kimball and Mitchell St. by June of 2000.
DRIVING FORCES:
Feeder Loading
Right-of-way concems
Short Construction time
Continuing to serve the load growth in the area
Railroad access fees
INFORMATION:
A new distribution feeder could be built from the existing Cloverdale substation to serve this new load but this would only be a temporary
fix. CasHer this line could run about $100,000 per year In Railroad R/W fees. Within a year or so an additional feeder would also be
required to continue to serve the increasing loads in this area. This 5th feeder running east out of Cloverdale would cause a problem of
where to build the circuit. The exiting 2 lines are already contain double distribuion circuits, with a transmission line on top. The best
answer to this problem is to install additional capacity to relieve the distribution of the higher than normal load densities at the end of the
lines. This will allow the existing circuits to pick up the other existing and future loads In Cloverdale s service area.New loads:
Phase 1: 1500kVA by Oct 1 , 1999
Phase 2: 1500kVA byJan 1, 2000
Phase 3: 1oookVA by Mar 1, 2000
Phase 4: included with Phase 1 by June 1 , 2000
Phase 5: 1oookVA byJan 1, 2001
A~~ M~fnr",..",...hl" " 1t'lr",.
Do nothing
Build an additional feeder out of Cloverdale Substation
Refuse to serve this added load
Exhibit 12
Page 1 of 2
Teinert, Di
Distribution Planning, RODSFCST.mdb, Sequence Numb 2113 BCRT STN OO1.DOC Printed 0 Thursday, May 03,2001
INTERROGATORY NO.4: Please provide dates of installation, sizes,
and current loads of substations within a seven-mile radius of the Bethel Court
substation.
Response To Interrogatory No.4: The substations within a seven-mile
radius of Bethel Court substation, including sizes and peak demand, are:
C/rrtA., ~ . t--,
leq fa b; I'
-.;
2000 Summer PeakStation ~ze (fv1V A) peaILDemandJMW)
Bethel Court
Boise
Butler
Cloverdale
Eagle
Gary
Gowen
Grove
Hewlett Packard
Joplin
Locust Grove
Meridian
State
Ustick
Victory
Wye
11.4
79.
50.
42:3
33.
32.
12.
53.
13.
(under construction)
72.
36.
42.
64.
32.
55.
A map was prepared to identify and provide the location of these
substations and is attached. The installation year of each substation is being provided
under the Response to Interrogatory No.7. The load information listed is a .snapshot"
of conditions representative at that time. Detailed load information on these substations
is available for inspection and viewing by Complainants at Idaho Power offices. The
Company has agreed to have personnel available on June 14 and June 15 at the
Company s Corporate Headquarters located at 1221 West Idaho Street commencing at
IDAHO POWER COMPANY'S SUPPLEMENTAL
RESPONSE TO FIRST PRODUCTION REQUEST, Page 4
Exhibit 12
Page 2 of 2
Teinert, Di
The 1 a-Year Transmission Plans of the Treasure Valley
The 10-Year Transmission Plans of the Treasure Valley
Buildout Projection
Distribution Planning
2002-2012
EXECUTIVE SUMMARY.......... .... ...................... .................... .................. ..... 1
STU DY APPROACH ................ ..... .............................
...... .................. .......
..... 2
METHODS.............. ..................................................................... .................... 2
Land Use Studies...
.................... ....... ......... ..... ............ ..... ................. .~. ............
......... ...... 2
Model for System Adaptation ......
................ .............. .................. ............
......... ...... ....... 2
Econom ics and U ncertai nty ......
...... ................................ ................... .................... .......
- F eas i bility and Performance... ......
...... ............ .....;.......... ............ ...... ..... ........ ........... ......
DISCUSSION..... .........
....... ............................................................~.... .
......... 4
Review of the 75~Year Study and Plans........................................................................
Land Use Study Results and Load Validation ..~............................................................................. 4
The Present System......... ............. ......
....... .............. ..... """""" """" .............. '" ,~.......
............... ...... 7
138 kV Triggers ..
...... .................. .... ................. """'" """"" ......~... ................ .:... ...; """"""""""
..... 8
230 kV Triggers """"""'" ....... .............
........ ...... ..... ....... .......... ....... ...... ..... ........ ...;..........
;........ ...... 8
10- Y ear System Changes .............................................
;........................................."""'"""" ..........
East Treasure Valley.
""""""""" ..... ................ ""'" ....... ....... """"" ............. ...... ...........................
West Treasure Valley .......
:..............................................:...............;................
..................... ........ 13
The 138Kv Transmission ..............
;............
0""""""'0""""""""""""""""""""'" .......
TIMING OF THE 138 KV TRANSMISSION ................................................. 16
2003.... ........ ...... .............. ......
................. ... .............. ...................... ...... .... ..........
......... ..... 16
2004.. .... ... ......... ...
.... ........ ...... ..... .......
.......................... .......... ................. .......... ........... ... 17
2005....... .......... ....
....................... ........... ........... ...... ............ .................... ..............
0.. .......
2006.......... ...... ...
...... ....... ...... ....... ..... ....... .................. ;..... ................. ....... .......... .......... ....
2007.... ...... ..... .......... ....... .....
..... ... ..... ... ....... ......... ...... ........ ......... .......-........ ....... ....
......... ... 23
2009...... ... ...... ..........
..... .... ....... .............. ....... .... .......... ......... .... ........ ....... ... ....
............. .... 24
2010.......... .......................................... ................ ................... .........................................
2012................... .................. ........ ...........
......... ....................
................... .................. ...... 26
Beyond 201 2 ..... ....... ...............
.................................... ............................. ......................
Summaries................. .....................
"""" ...........................................
"""""""""""""""""""""'. 33
TIMING OF THE 138 KV SOURCES........................................................... 35
The 1 O-Year System .....................................................................................................
2004................................................................................................................... '-:-
...........
2005.................... ....................................................0....................................................... 36
2007............ .....
............................................ ................ .................. ................... ..............
2009.... ...... ......
................................................................................ .................. ... ...........
2012............ .................................................................................... ....
........... ... ...... ........
Exhibit 13
Pages i thru 78
Teinert, DiPage i
The 1 a-Year Transmission Plans of the Treasure Valley
MOUNTAIN HOME TRANSMISSION AREA............................................... 39
Definition of Mountain Home Transmission Area......................................................
Land' Use................ ..................... ..... ............................
.......... .................. ......
~.............. 40
Load Density & Estimation
................................................................... ................... ....
Present System........
...................... ............ ................... .......... ............... .......................
75- Year Plan...................... ................ ............
............... .......................... .......................
10- Year Plan............. ......
............ ......................
............................... ....... ....................... 43
BEYON D 10 YEARS ...................
... ......... """""""""""..............
......... ....... 45
Plans, For 2003 And Beyond ...........................................................
........
~.................... 46
Transmission .....,...........................................................................................................................
Substation............................................."""""""""""""""
"""""""""""".....................,..............
Conc,usion ................. ............
............ """'" .... ...... ............ ......... .......... ....~............ ........
Append ix A............................................................
.................................. ......................
The Loop Mode1.
,.... ................,....... ....... ..................... .... ................. .................. .......~.
.,....... ......... 47
Design Criteria and Planning .......... """"'
""'~' ......... .....~.....;..... ..... :........... ,...... ............ .....
........... 49
Contributing Authors """""""""""""""""""""
"""""""........................................,...................
Appendix B.
...... ......... ......... .... .......... ........ ......... ................. ... ......... ..... ............... ... .... ....
Summary of Base Case Loads and Changes """""""""""""""
"""""""";""""""
"""""""""'" 51
Appendix C....
.......... ""'" ......... .......................... .......................~............ ......~........ ""'" ....
Appendix D....
............. ..... ......................... ........... ........
.............. ................ ........................ 77
Base Case Descriptions and Contingency Reports .............................;......................................... 54
Mountain Home/Elmore 69 kV Study .....
;.................................,......................,......:..............
,..... 77
Canyon Creek Radial Service and Options .......................................................................;........... 77
Page Ii
The 1 a-Year Transmission Plans of the Treasure Valley
EXECUTIVE SUMMARY
With an estimated yearly growth of 40-45 MW load over then next ten years, 400 MW pr more is
expected in the Treasure Valley, serving about 320 000 people with 15 to 20 new substations and an
additional 110 miles of transmission. Presently, about 40 substations serve 280 000 customers in the
Treasure Valley and about 1600 MW of summer load.
Two main changes are incorporated in the final plans of the 10-year study. A briefassessment of the
75- Y ear study of November 2001 includes new assumptions about the rights-of-way using more
double circuits for public impact than single circuits for reliability. And, the 10-yearperformance
studies strongly support the use of three high-voltage transmission lines instead of two to meet the
reliability standards for the underlying 138 kV system.
Reliability is briefly at a minimum during the building of some projects because of constraints or
alternate system operations, and is expected to be back to nonnal or exceed normal after the
construction. Construction activities center around system upgrades, building load centers, forming
parallel lines into loops, and using existing loops to assist lines nom future loops. Most facilities are
scheduled according to growth, while some facilities are scheduled ahead of growth to avoidunacceptable system conditions.
~'"
Page 1
The 1 a-Year Transmission Plans of the Treasure Valley
STUDY APPROACH
The lO-year study ofland use, the adaptation of the loop model into system configuration, and its
perfonnance results in a plan for a looped transmission system that is flexible with the growth
economic and reliable, and usable at buildout.
Design and operational strategies tackle the west Treasure Valley s marked dependency on Boise
Bench for power, and a growth center in the Locust-Meridian gradually shifting toward Nampa
while ensuring that the system is unaffected by the through-flows of the main transmission grid and
wide-area outages.
System improvements are designed to be independent from each other in timing, so each may be
built in stages according to growth. Major construction projects in the move to the future load
centers and loops involve system upgrading, building source stations, and fQnning parallel linesfrom the source station into loops.
Timing and economic strategies include scheduling some facilities ahead of growth to avoid
unacceptable system conditions, and using existing loops to assist lines from future loops. Several
138 kV source station sites such as the Nampa 230 kV substation, the Southeast Nampa 230 kV
substation, and the Mora 230 kV substation, were studied for their effect and timing in the needs
the Treasure Valley transmission system.
Source-side strategies assume a 250 MW of large-scale generation installed in 2006 at Gamet, and
that the capacity of the source side transmission will be increased by another 200 MW for the
expected growth in Treasure Va11eyby 2012. Various routes for the high-voltage transmission are
guessed as a necessity in simulating the power flow models without the benefit of plans of the
future high-voltage transmission. These routes may change in future studies as the high-voltageplans become more defined.
Generation strategies are beyond the scope of study and are limited to ideas for potential sites of
local large-scale generation and distributed generation, and potential transmission interconnects ofremote generation.
METHODS
Land Use Studies
Obtaining the load densities to assess needs is the first tool to shape the electrical system. Finding
the location and amount of load in land use studies in the 10-year study involved a bottom-up look
at load density while the 75-year study emphasizes a top-down look. A glimpse of the short-term
future looks into means of assessing recent growth and delVing into county and city comprehensive
plans. A glimpse of the long-tenD future, such as the 75-year plan, tends toward assessing land
potential and natural resources.
Model for System Adaptation
The second tool in planning the future electrical system is a flexible blueprint ofthe distant future
system configuration that can be adapted to the upcoming demands on the present configuration.
The loop model used in this study is one that is flexible in the physical reality, timing, economics
and reliability. A detailed discussion of the loop model and design criteria appears in Appendix A.
The logic behind the loop model for Treasure Valley is to isolate or limit the WSCC east and west
power flows in the bulk high-voltage grid to the Idaho Power 138 kV and lower transmission.
Page 2
The 1 Q-Year Transmission Plans of the Treasure Valley
Second, turn the wide-area outages we have been experiencing in our system into local outages.
Third, cope with the logistics of high- and low-growth areas, timing, and economics. Fourth; satisfy
FERC policies of regulated and deregulated transmission.
Economics and Uncertainty
A set of economic analysis instruments and models is the third essential tool. Because of time
constraints in this study, economic assessment is simplistic in the I a-year planas well as in the 75-
year plan. Revision and follow-up studies of the first five years will use more economic analysistools along with risk assessment.
Feasibility and Performance
The power-flow studies and contingency studies of the future system are fourth in the tool set They
help coagulate the plans for the future electrical system by evaluating their robustness and
con-ectness of timing with growth and economics.
Load levels instead of years were used to forge the 10-year plan because of the uncertainties in the
growth and economy. Each load levelrepresents an annual growth of 40-50 MW in the Treasure
Valley. The projected load con-elates with data from sources such as land use, city comprehensive
plans, and government publications, and as well as load forecast and company infonnation about
future subdivision growth tallies and real-time data of substations and feeders:
Starting from the present to 2012, the power flow study models each load level with its electrical
facilities, followed by a single-outage contingency study to see which facilities are at risk. The
finished configuration for the load level must meet both steady-state and single-outage reliability
criteria, and serve as a stable base for the next load level study. For unforeseen delays, the load level
is increased twice more, and a single-outage contingency study is run for each growth increase toevaluate the associated risks.
In the power flow studies and contingency studies of single-line outage, these are our considerations
for reliability and voltage for design purposes only:
During steady-state conditions, the transmission facilities must not exceed their 100%
nameplate rating, and the system voltages may neither dip below 95% nor exceed 105% ofthe nominal voltage.
During single-line outages, these facilities must not exceed their 11 0% nameplate rating,
and system voltages may neither dip below 90% nor exceed 110% of the nominal voltage.
Page 3
The 1 a-Year Transmission Plans of the Treasure Valley
DISCUSSION
Review of the 75-Year Study and Plans
Land Use Study Results and Load Validation
With a shorter time into the future, the lO-year study tends toward growth trends, delving into
county and city comprehensive plans, and other societal influences in contrast to the 75-year study
where assessment tends toward land potential and natural resources.
"';'
\t':
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,p
29'
f!;
g;:
Figure 2A. Load Densities at Buildout in the Treasure Valley
The buildout load and population values were compared to the kW usage parameter that is relatively
constant. The land-use study provided the 7200 MW by multiplying load densities by their square
miles. The population was estimated at 1.6 million people, according to the state ofldaho statistics
(using a population of about 500 000 in Ada and Canyon counties in 2002 with a 1.6to 2.0 %
growth rate for 75 years). The 4.3 kW usage per person validates the independent methods ofland
use study and growth estimation.
Page 4
The 1 Q-Year Transmission Plans of the Treasure Valley
75- Year Transmission Projection
About 100 substations in looped systems connected to a dozen or more source stations will serve
the Treasure Valley load of 7200 MW. The range ofload for substations varies between 10 and 120
, and the range of capacity of source stations varies between 400 and 900 MY A.
The loops in the projected electrical system were revised from the original 75-year study to
minimize public impact. By condensing the rights-of-way with more double circuits, some 660
, miles oflines translate into about 400 miles of double-circuit transmission. The reliability of double
circuits built with steel poles is equivalent to the reliability of single circuits using wood pole
construction.
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Page 5
The 1 a-Year Transmission Plans of the Treasure Valley
75- Year Source Stations
The 138 kV source stations are designed with three high-voltage lines for reliability of supply to the
underlying looped transmission. Three lines also may supply a combination of source stations.
Source stations in congested areas were decreased in scope to serve as a satellite source station to a
major source station. Examples are the Southeast Nampa and Nampasource stations, as well as the
North Caldwell and Caldwell source stations.
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Page 6
The 1 Q-Year Transmission Plans of the Treasure Valley
The Present System
Presently, the three major source stations that serve Treasure Valley are Boise Bench, Locust, and
Caldwell. The system in Treasure Valley is also tied to the Mountain Home area system via the
Boise Bench source station. The east and west Treasure Valley systems are studied here, while the
study of the Mountain Home area system is separate.
Separation of Tied Systems
The two shaded areas shown in Figure 3A represent how the system serves loads with different
profiles, such as the rural customers in the west and urbanized customers in the east. Natural breaks
in the Treasure Valley system occur by opening the Meridian-Nampa 69 kV line, the Bowrnont-
Mora 138 kV line, and the Boise Bench-Emmett 138 kV line. The loads can be further subdivided
into smaller loads, and source stations are added as the areas grow, following a growth shifts from
east to west by 2012.
Figure 3A. Separation of East and West Treasure Valley
The load in Treasure Valley is defined by the flow truncated at the boundaries at the Caldwell
230/138 kV transfonners the Boise Bench 230/138 kV transfonners, the DRAM230/138 kV
transfonners, the Caldwell-Panna 69 kV line, the Hidden Springs-Emmett 138 kV line, the Black
Mesa-Lower Malad 138 kV line, and the Glenn s Ferry Tap-Upper Salmon 138 kV line.
The west load is defined by the flow at the boundaries of the 230/138 kV Caldwell transfonners, the
Caldwell-Panna 69 kV line, the Bowrnont-Mora 138 kV line, the Bowrnont-Sinker 138 kV line, and
the Zilog Tap-Meridian 69 kV line. After the Gamet project, the flow at the boundaries of the
Gamet-Linden 138 kV line and the Gamet-Hill 138 kV line will also be included. The east load is
defined by the flow at the boundaries at Boise Bench 230/138 kV transfonners, the Hidden Springs-
Page 7
The 1 a-Year Transmission Plans of the Treasure Valley
Emmett 138 kV line, the Meridian-Zilog Tap 69kV line, the Mora(Kuna)-Bowmont 138 kV line
the Micron-Dram 138 kV line, and the Boise Bench-Black's Creek 69 kV line.
138 kV Triggers
The triggers for the 138 kV projects are growth-oriented. The associated projects and timing are
discussed in the Treasure Valley 10- Year Transmission document, and further infonnation is
available in the substation area studies. Summarizing the main projects:
East Treasure Valley
The Cloverdale-Bethel Court- Wye-Butler 138 kV line is triggered by the capacity of the Boise
Bench 69 kV loop, and the need for the fourth line from Boise Bench for growth and reliability.
West Treasure Valley
The Garnetarea 138 kV project is triggered by the Nampagrowth, the relief of the. Caldwell
230/138 kV transfonners, the Caldwell-Linden 138 kV, the Boise Bench 230/138 kV transfonners
and 138 kVlines.
230 kV Triggers
The triggers for the 230 kV projects are documented in the Treasure Valley 138 kV source
document. Summarizing the major points:
The capacity of four Boise Bench 230/138 kVtie transfonners must be increased when the
flow through the transfonners exceeds 700 MY A during steady-state conditions, for serving
load and for supporting configuration changes.
. A second transfonner is needed at either Locust or Cloverdale when flow through the first
230/138 kV 300 MY Atransfonner exceeds 216 MY A during steady':'state conditions. A third
transfonner is needed at either Locust or Cloverdale when the two 230/138 kV 300 MY
transfonners exceed 342 MY A.
. A flow of about240 MY A through the two Caldwell 230/138 kV 200 MY A transfonners
during steady-state conditions may trigger the Nampa 230 kV and the Nampa-Cloverdale 230
. kV, and lor the East Nampa 230 kV. After these facilities are built, and the Caldwell 230/138
kV 200 MY A transfonners exceed 240 MY A a third 230/138 kVtrarisfonner is needed at
Caldwell or in the North Caldwell area and/or the Houston area.
The Garnet 230 kV generation is triggered by the relief of the Caldwell 230/138 kV
transfonners and the Boise Bench 230/138 kV transfonners
Nanipa 230 kV substation is triggered by the growth in the Nampa area and by the relief for
the Caldwell 230/138 kV transfonners.
The relief of the Boise Bench 230/138 kV transfonners and l38 kV lines triggers the
Cloverdale230 kV substation.
The East Nampa 230 kV substation is triggered by the growth in the Chestnut-Nampa areaand the relief of the Caldwell 230/138 kV transfonners.
Page 8
The 1 a-Year Transmission Plans of the Treasure Valley
10-Year System Changes
The discussion for the east and west Treasure Valley systems for the next ten years is based findings
in the power flow and the contingency studies. The results are summarized in the Appendix. Also
available in a separate publication are the base case single line diagrams for the load level
configuration and the two load growth cases, and each of their contingency reports.
The resulting system configuration for the next ten years includes finished loops such as the Boise
Bench No.1 loop, Cloverdale No.1 and 2 loops, and Locust No.1 and 2 loops. Since a majority of
the loop transmission is already constructed, the 10-year focus is on building the source stations andformation of loops.
Figure 4A. Present System With Partial Loops Figure 4B. Present Source Stations and Grid
Figure 4c. 10- Year System and Loops Figure 4D. lO.;Year Source Stations and Grid
Page 9
The 1 a-Year Transmission Plans of the Treasure Valley
East Treasure Valley
Boise Bench and Cloverdale
Boise Bench No.1 loop and CloverdaleNo.1Ioop. The critical loads in the east Treasure Valley
are centered on the Boise, Grove, Butler, Bethel Court, Wye, and Ustick substations. One 138 kV
line from Locust and three 138 kV lines from Boise Bench serve the critical loads, and as they
continue to grow, so increase the risks of cascading wide-area outages caused by an outage of any
one Boise Bench line.
The, 138 kV line from Locust is the Locust-Locust tap 138 kV with a 203 MY A line rating. The
three 138 kV lines from Boise Bench are Boise Bench-Grove 138 kV with a 277 MY A line rating,
Boise Bench-Emmett 138 kV with a 129 MY A line rating, and the Boise Bench-Mora 138 kV with
a 203 MYA line rating. A fifth 138 kV line from Boise Bench to Cloverdale with a 277 MY A line
rating is planned.
As soon as the Cloverdale source station and the Boise Bench-Cloverdale 138 kV line are built
loops can be formed from the two parallel Boise Bench to Cloverdale lines to miIiimize the risk to
the critica110ad. The lines are the Boise Bench-Grove-Boise.,.Ustick-Cloverdale 138 kV line and the
Boise Bench-Butler-Wye-Bethel Court-Cloverdale 138 kV line. The loops formed are the Boise
Bench No.1 loop and the Cloverdale No.1 loop. The Boise.BenchNo. 1 loop serves the Boise
Grove, Boise, and Butler substations. The Cloverdale No. 1 loop serves the Bethel Court, Wye,and
Ustick substations.
The construction proJects for Boise Bench No.1 loop and Clov~dale No.1 loop include:
138 kV Conversions ofWye, Bethel Court and Meridian substations
. New Cloverdale-Bethel Court 138 kV, rated at 277 MY A
. New Cloverdale-Wye 138 kV, rated at 277 MY A
. New Wye-Butler 138 kV, rated at 203 MY A
. New Boise-Butler 138 kV, rated at 203 MY A
. New section in Wye-Ustick 138 kV, rated at 203 MY A
The Locust-Locust Tap Upgrade and split Project:
Upgrade to 277 MY A, sections in the: Locust-Locust tap-Cloverdale 138 kV for the
Locust-Meridian 138 kV
~ New Cloverdale-Meridian 138 kV tie at 277 MY A, a tie to the Locust-Meridian 138 kV.
~ New Cloverdale-Locust tap section at 277 MVA, part of the Cloverdale-Ustick 138 kV
Upgrade sections of the Cloverdale-Ustick 138 kV to 277 MY A
Eckert 138 kVsubstation radial from Boise Bench
The study uncovered a supply shortage to the Cloverdale source station that causes the power to
flow from Boise Bench instead of Gamet. Possible explanations for this phenomenon are that the
Boise Bench supply is greater than Gamet's , or the large critical loads are acting as giant sink.
However, as the parallel system is changed into loops, the supply problem is more evident during
some outages when the power flows to Cloverdale on the weaker rated Boise Bench-Mora 138 kV
line and the Boise Bench-Dry Creek 138 kV line.
Page 10
The 1 Q-Year Transmission Plans of the Treasure Valley
To assist these lines, a tie is closed between the Boise Bench No. 1 loop and the Cloverdale No. I
loop, causing power to be rerouted from weaker Boise Bench via these higher-rated lines. The tie
closed is the Boise-Ustick 138 kV tie. This situation is seen in the years before the Stat~ 138 kV
conversion after which the tie is re-opened. It may be remedied earlier by a supply closer to
Cloverdale.
By using a high-voltage tie between the Locust and Cloverdale source, we follow the source station
model for reliability since these source stations serve large critical business and residential loads.
The Locust-Cloverdale 230 kV serves as the third line and a strategic tie between the two sources
even though the electrical characteristics and the economic costs of the Locust-Cloverdale 230 kV
line and the alternative Locust-Cloverdale 230 kV tap are similar. This tie can be abandoned when
the Locust-Dry Creek line is built and the bay can be used for this purpose. Until then, the three-line
criteria for reliability still holds.
Cloverdale No.2. The new Cloverdale-Victory 138 kV line will complete the Cloverdale No. 2 loop
(Cloverda1e-Victory-Hillsdale-Stoddard).The Mora-Victory 138 kV line serves as a tie to the Mora
area.
Locust
Meridian and Nampa 69 kV System
The reliability of the Nampa-Caldwell69 kV line, and the capacity of the Nampa 138/69 kV
transformer will improve when Meridian-Cloverdale 69 line is removed and the Zilogload is radial
from Nampa. The 138/69 kV transformers from Cloverdale will be installed in Caldwell and
Bowmont.
Locust Loop No.1. The Locust-Meridian 138 kV line is built after the upgrade of the Locust-
Locust tap upgrade, and after the new Cloverdale-Meridian 138 kV line, and the new Cloverdale
230kV substation are built. The Locust-Meridian 138 kV line will use a new section to connect to
the upper part of the Cloverdale-Meridian line, bypassing the Cloverdale substation. The lower part
of the Cloverdale-Meridian 138 kV will serve as a tie. The Locust No. 1 loop will serve Meridian
Black Cat, and Ten Mile.
Locust Loop No.2. The Locust-Eagle 138 will be built when the reliability of service is at risk or
when the Gary tap is opened because of the State 138 kV conversion. The Star tap is a tap in the
Locust-Eagleline for temporary service to Star. The Locus No.2 is completed with the Locust-
Eagle 138 kV construction and will serve H., Joplin, Eagle loads and loads north of the Beacon
Light area. The Eagle-Ustick 138 kV line serves as a tie to the Cloverdale source. A source in the
north Star area will serve the Star substation.
Dry Creek
Timing of the State 138 kV Conversion. Because there is a lack of capacity to serve State on the
Boise Bench-Mora and the Boise Bench-Dry Creek 138 kV lines, the State 138 kV load will be
served from the Boise Bench No. 1 loop via a new Boise-State 138 kV line. The Boise Bench No.
loop is not formed until after the Cloverdale 230 kV substation is in service. Until then, State load
must be contained to 65 MW or less because ofthe capacity of the Boise Bench-State 69 kV lines or
the new Dry Creek 230 kV substation will have to be built to serve the State 138 kV load.
The new double circuit of Gary-State 138 kV line will be part of the Dry Creek No. 1 loop. The
alternative to the Gary-State 138 kV line is the State-Dry Creek 138 kV line. The Dry Creek No.1
loop will serve State, Gary, and the northeast loads of the Treasure Valley.
Page 11
The 10-Year Transmission Plans of the Treasure Valley
Mora
Mora 138 kV Measures
The Boise Bench-Mora 138kV line with a 203 MY A line rating is at risk during contingencies. The
following processes can be used to reduce the overloads.
Support from Boise Bench is briefly available, but sporadic after the Cloverdale 230 kV
construction, but before the State 138 kV conversion. Closing the Boise-Ustick tie line between
the Boise Bench Loop No.1 and the Cloverdale Loop No.1 is effective during some but not allcontingencies.
Open the Mora-Victory after the Cloverdale 230 kV construction to prevent overloads on the
Boise Bench-Mora 138 kV line, which will serve the Mora and Gowen load radially.
Remove Boise Bench support for Meridian by converting Meridian to 138 kV and moving
about 45 MW ofload from Boise Bench to Locust with the Locust-Meridian. 138 kV. This step
isalso beneficial for the Nampa-Caldwell 69 kV system.
Openthe Mora-Bowmont 138 kV line when the Boise Bench-Mora line hasno capacity and is
unable to support the Bowmont area load during contingencies or growth in the Mora area. This
stage will require a 138 kV source in the east Nampa-Bowmont-area.
The Mora 230 kV conversion.
Page 12
The 1 Q-Year Transmission Plans of the Treasure Valley
West Treasure VaHey
Nampa and Caldwell
The Nampa 230 kV source station provides relief for the Caldwell 230/138 200 MV A kV
transfonners and theCaldwell-Nampa 138 kV transmission system, and serves the growing load of
the Nampa and Caldwell areas. Studies indicate that one Caldwell 230/138 kV transformer is at risk
until approximately 2003 during steady-state conditions, as well as the Caldwell-Linden 138 kV
line and Lowell-Chestnut 138 kV line during contingencies.
The new Southeast Nampa 230 kV substation serves the loads in the Nampa-Bowmont area after
the Mora-Bowmont 138 kV line is opened for growth in the Mora area. The Southeast Nampa 230
kV substation is also an alternative to the Gamet project and provides for the relief for the Caldwell
230/138 kV transformers.
Impact of Garnet
The Gamet project provides 250 MW of generation and relieves the Caldwell 230/138 kV
transfonners, the Boise Bench 230/138 kV transformers, and the Boise Bench 138 kV lines. Not
building would accelerate the Cloverdale 230 kV substation , the Nampa 230 kV substation, and theEast Nampa 230 kV substation.
The Locust soUrce station does not supply enough power to the heavy load area between Boise
Bench and Locust, causing a stressing power flow from Boise Bench through the Boise Bench
230/138 kV transformers and its 138 kVlines. A generated power supply west of Locust such as
Gamet would supply enough power to relief the Boise Bench transmission system. Without the .
Gamet project, the Cloverdale 230 kV substation would be accelerated to bring power closer to the
heavy load area to relief the Boise Bench.
The installation of250 MW of generation between Caldwell and Locust 230 kV substations
generates more power flow to the already-stressed Caldwell 230/138 kV transfonners, the
Caldwell-Nampa 138 kV, and the Caldwell-Bowmont 138 kV lines.
Channeling the generated power flow away from Caldwell is accomplished with the Gamet 138 kV
transmission carrying the power to heavy loads in the Caldwell and the Nampa areas. The Gamet-
Hill and the Gamet-Linden lines force more power to Nampa, and additional capacity must be
added to handle thenew flow by reconductoring the Hill-Karcher-Nampa 138kV line.
Regardless of the Gamet project, the Nampa area needs a source station, and two lines or the
upgrade of existing lines, or both, to cope with the growth. The Gamet 230/138 kV transfonner and
the 138 kV transmission from Gamet to Hill and Linden constitute a very good alternative to
Nampa s growth. .
The Gamet 250 MW generation supply installed in 2006 will be exhausted the growth by 2010 and
an additional 200-MW of generation needed that could be located in Gamet, Southeast Nampa,
Bowmont, and Mora. Remote large-scale generation is an alternative and power from remote sites
can flow to the Treasure Valley via new high-voltage transmission. Di stributed generation of 50-
100 MW units may also be installed on the lines or sites that have available margin, or Ilnes that are
upgradeable or are scheduled. for upgrades.
Page 13
The 1 Q-Year Transmission Plans or the Treasure Valley
Synopsis of the Garnet Generation Project and Treasure Valley
The Gamet 250 MW generation:
The relief of the Boise Bench 230/138 kV transfonners
The relief ofthe Boise Bench 138 kV lines
. The west Treasure Valley needs are met threefold by the Gamet 138 kV transmission:
The Gamet 230/138 kV transfonner relieves the Caldwell 230/138 kV transfonners.
Building the Garnet-Hill and the Garnet-Linden prevents overloads on the Caldwell-Nampa
138 kV transmission.
. Building the Garnet-Hill and the Gamet-Linden deliver power directly to Nampa area.
Alternatives to the Garnet Project for the Treasure Valley:
Cloverdale 230 kV substation with the Locust-Cloverdale 230 line
. Nampa 230 kV substation into the Boise Bench-Caldwell 230 kV line and the Nampa-
Cloverdale 230 kV line
Southeast Nampa 230 kV substation into the Boise Bench-Caldwell 230 kV lirie.
Third 230/138 kV transfonner in Caldwell, upgrade Caldwell-Linden, and. Lowell-Chestnut
lines, add third Caldwe11138 kV line '
. Additional generation in units of50-100 MW in the Nampa-Bowmontarea and other
strategic sites
. .. '
Add another 230 kV or higher transmission line .ttom Brownlee or other strategic sites
Page 14
The 10-Year Transmission Plans of the Treasure Valley
The 138 Kv Transmission
From 2003 to 2012, a total of84.5 miles of new 138 kV transmission lines, to as many as 13 new
substations, could be built throughout the Treasure Valley. Two of these new substatioI;1s and three
existing station are scheduled as 230/138 kV (or equivalent) tie bank sources (Gamet, EastNampa,
Nampa, Cloverdale, and Mora). These source stations require an additional 28 miles of230 kV or
higher transmission. A Ten-year Transmission Line Work Summary table summarizes allthe
projects by year.
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Figure S. 10- Year Transmission Plans
Page 15
The 1 a-Year Transmission Plans of the Treasure Valley
TIMING of the 138 KV TRANSMISSION
2003
New 138 kV line tap to Kuna substation from the MORA to BOMT 138 kV line.
....-......--...-'--
Figure 6. Kuna Station Transmission Plan 2003
Wye and Bethel Court Conversion to 138 kV by adding a new 138 kV transmission line from
Cloverdale Substation to Wye.
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Figure 7: Cloverdale to Bethel Court to Wye Conversion to 138kV-2003 andButler to Wye 138 kV Line in 2004
Page 16
The 1 a-Year Transmission Plans of the Treasure Valley
2004
Wye to Butler 138 kV line to complete loop ITom Boise Bench to Butler to Wye.
(See figure #7)
Line tap to Star off the Eagle 138 kV line at Edgewood and State Street.
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Figure 8. Star Transmission Plan 2004
Line tap to new Mid-Rose station along Roosevelt for lniile. 'Taps the BOMT to Nampa 138kV
line.
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Figure 9: Mid-Rose Transmission Plan-2004
Page 17
The 1 Q-Year Transmission Plans of the Treasure Valley
New Eckert Station tap offthe BOBN to BTLR 138 kV line, running along the 230 kV corridor for
3 miles.
Figure 10. Eckert Transmission Plan-2004
Gamet 230 kV line from Caldwell (5 miles) and the Gamet to Locust 230 kV line (14 miles).
Gamet will be a 230/138 kV tie-bank source station with one 300 MY A 230/138 kV
transfonner installed initially. .
Gamet to Hill 138 kV line (5 miles).
Figure 11. Garnet and Hill Transmission Plan-2004
Page 18
The 1 a-Year Transmission Plans of the Treasure Valley
2005
Hillsdale (Eagle & Amity Rd) 138 kV I-mile tap off the Mora to Cloverdale 138 kV line. Stoddard
Hillsdale, and Victory will be part of a future 138 kV loop after a 300MV A 230/138 kV tie bank is
installed at Cloverdale (2009).
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Figure 12. Hillsdale T-:ansmission ~lan-2005
Mountain Cove (Boise Reserve) station tap off the BOBN to DYCK 138kV line. The Cartwright
station (Figure #35) is an alternative to Mountain Cove, depending on the cost to install distribution
facilities at Mountain Cove to relieve State and Grove feeders in the foothills.
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Figure 13. Mountain Cove Transmission Plan-200S
Page 19
The 1 a-Year Transmission Plans of the Treasure Valley
North Caldwell (purple Sage and Fannway Road) new 4-mile 138 kV line trom Caldwell on the
existing Caldwell to Ontario 230 structures.
caldwelitoOntario230 kV LOlO
: ".;..
Figure 14. Farmway & Purple Sage Rd Transmission Plan-2005 .
Southeast Nampa new station site (Happy Valley and Locust) 4 mile 138 kV extension from
Chestnut.
. .
Figure 15. SE Nampa Station Transmission Plan-2005
Page 20
The 10- Year Transmission Plans of the Treasure Valley
Linden 138 kV line from Garnet.
Figure 16. Linden to Garnet Transmission Plan-2005
Meridian conversion to 138 kV by converting the Cloverdale to Nampa 69 kV line to 138 kVfrom
Black Cat to Meridian. Build a new Ten Mile station at Ten Mile and Ustick Roads. Complete 11. 138
kV loop by ,adding a Meridian to Cloverdale 138 kV line in 2006. This line will connect to a bus
section in Cloverdale substation vacated by the 138/69 kV tie banks.
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Figure 17. Black Cat to Meridian 138 kV Line and Ten Mile in 2005 and
Meridian to Cloverdale 138 kV Line in 2006
Page 21
The 1 Q-Year Transmission Plans of the Treasure Valley
Tap the Caldwell to Lowell Junction 138 kV line for the Valley View Substation
Figure 18: ValleyYiew 138"kV Tap to New Station-2005
13S' kV line extension from Gamet to a new station at Star and Ustick Roads (9 miles)
Figure 19. Star and Us tick Road Transmission Plan-2005
Page 22
The 1 a-Year Transmission Plans of the Treasure Valley
2006
Meridian to Cloverdale 138 kV line to complete loop from Locust, to Ten Mile, to Black Cat, to
Meridian, and then to Cloverdale. (See figure # 17.
2007
Double-circuit the Cloverdale to Ustick Tap 138 kV line to provide a Cloverdale to Locust and a
Cloverdale to Ustick 138 kV line. (Conductor size upgraded to 1272.
, -,------_~___
kO~- T
. ,.::
. i ---
" ~~;!'!
stODDARD
Figure 20. Cloverdale to Ustick Tap Double Circuit -2007
Add 230/138 kV tie bank at Nampa Substation and tap ofBOBN-CDWL 230 kV line.
UsbckR,j
...-
ll-
:--
: i
i!!
-'-.--
lot.
""." --"',.
Figure 21. Nampa 230 kV Tie Bank and Transmission Line-2007
Page 23
The 1 Q-Year Transmission Plans of the Treasure Valley
2009
Cloverdale 230/138 kV tie banks added to Cloverdale Substation
Victory to Cloverdale completion of 138 kV loop.
--- - ---~- __
b9~_JsT
_--_::'
STODD~RD
Y",,"yRd
~..,, ', '
Figure 22. CDAL to LCST 230 kV Line-2009 and VTRY to CDAL 138 kV Line-2009
Butler to Boise 138 kV line (tap of the Butler to Wye 138 kV line installed in 2004).
Figure 23. Butler to Boise 138 kV line - 2009 (tap ofBTLR-WYEE 138 kV~installed in 2004)
Page 24
The 10-Year Transmission Plans of the Treasure Valley
2010
State Conversion to 138 kV from Gary and conversion of State to Boise 69 kV line to 138kV. (Dry
Creek to Gary to State requires help from the BOBN to GRVE to BOIS 138 kV line until a future
Dry Creek 230 kV station is added).
Figure 24. State conversion to 138 kV, Gary to State and State to Boise 138 kV Lines-2010
Huston conversion to 138 kV by tapping the Caldwell to Lowell Junction 138 kV line.
-""-----, ~~ ,, ' " ;~;--"
t-"'-f-;----"
i ,f~Wi
i:E
.._--
t"--,, ,
1)25-
rI""
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:..-..
:II
....."" ".."."",..,.."" ,
. b2S 6
.."
c..- ..
".,,_..
Figure 25. Huston Conversion to 138 kV - 2010
Paae 25
The 10-Year Transmission Plans of the Treasure Valley
2012
East Nampa 230 kV station and a 230 kV tap from BOBN to CDWL 230 kV line (4-5 miles west of
line on Amity Road)
..";;;. -- -- ', -'- "" '.,..--;--~----. "
"':_n
~____
_'_n
"--"'
7--
~"'... -..,
, E Power Ln -;1)1:'"16
... '-"-----------
"'------.,nm_
,- iii------;::1I;:
, ,
Figure 26. E N ampa 230 kV Station and Transmission Line - 2012
Boise Bench to Boise 138 kV line (along the Boise Bench to Boise 69 kV-line #23 I-line route).
Figure 27. Boise Bench to Boise 138 kV Line - 2012
Page 26
The 1 Q-Year Transmission Plans of the Treasure Valley
Mora 230 kV Tie Banks and connection to BOBN to CDWL 230 kV line.
! -,.,-:;___, -
Figure 28. Mora 230 kV Tie Bank - 2012
Zilog conversion to 138 kV by converting the Nampa to Zilog 69 kV line to 138 kV.
~stick Rd
...~ ....~--~--
- ;r"
,-,,_---- ,
i ~
9.-
Mid-Rose---00-
Figure 29. Zilog Conversion to 138 kV - 2012
P::!np. ?7
The 1 a-Year Transmission Plans of the Treasure Valley
Beyond 2012
Amity and Ten Mile station 138 kV line extension from the SE Nampa 230 kV Station
installed in 2012 (Figure #26).
',"
+bl
..-
. T
_--___
, 230kV.LinoTap. clonow230Slalion r--'
, - , !
Figure 30. New Ten Mile & Amity Transmission Plan
McDennott and Chinden station anda tap of the Garnet to Star & Ustick Road station 138 kV line
..,.. ---- .,
I ~
. ,
:I:
ST~R
, :
i--.J.. :
l~..
, "
Figure 31. McDermott and ChiDden Transmission Plan
Page 28
The 1 a-Year Transmission Plans of the Treasure Valley
Beacon Light and Linder Road station and a 138 kV line from Locust station.
D2N-
-"'-'~ ..
Beac.qnl.ig!l!.._....._...,,-,,_.
" 0
, -0
"'-. '
0:,"
---
CD'
Float~g Fe~ther ~.
~ ... '
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-0,
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r~'
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LOCiJS-T I
~,,~-=-.-~--_._-.-------_.,-----
TMIL , 'n
c__~t!~
. ,
Figure 32. Beacon Light and Linder Road Transmission Plan
Yz-:mile 138 kV line tap, to a neW Wagner and Linden station, of the CDWL to BOMT 138kV line. .
2 %-mile tap, of the Caldwell to the Purple Sage and Labor Camp station 138 kV line, to the
Willis and Emmett Road station.
-:... -
inn,,
: -
1)1,1
"00
__'
Figure 33. Willis and Emmett Road and Wagner & Linden Transmission Plan
Pace 29
The 1 Q-Year Transmission Plans of the Treasure Valley
Victory and Robinson station and a I-mile tap of the CHUT to Amity and Ten Mile 138 kV line.
5-mile 138 kV tap to the new North Side and Linden station, from the Star and Ustick Road
station.
-.-.-j-----
Figure 34. N. Side and Linden and Victory & Robinson Transmission Plan
Tap of the BOBN to DYCK 138 kV line to new Cartwright station (approximately .25 miles).
:r ,---
Figure 35. Cartwright Road Station Transmission Plan
Page 30
The 10-Year Transmission Plans of the Treasure Valley
138 kV 5-mile tap ofthe 138 kV line to Star for the new New Hope and Can Ada station betweenLansing and Star.
- b2N:9' .i \
i .
liSlickRd
Figure 36. New Hope and Can-Ada Transmission Plan
mile tap of the CDAL to MORA 1~8 kV line for the new Columbia and Meridian Road
station.
S'(i.obb~Ab
-'om
1~~;ltc
~---
~~:=_o
, -"""".j!, --..:
'Hillcdalc '
~ ""'H""~l1J'l2S-1!I~ '
Figure 37. Columbia and Meridian Road Transmission Plan
Page 31
The 10-Year Transmission Plans of the Treasure Valley
One~mile tap of the BOMT to Caldwell 138 kV line for the Orchard and Lake station southeast of
Valley View.
'" L--~!L
;---
Figure 38. Orchard and Lake Transmission Plan
Paae 32
10 Y
Summaries
ear ransmlsslon ummary
Year Station 138 kV 230 kV Location Figure(miles)(miles)
2003 Kuna Shortline & Swan Falls Rd
Wyee & Bethel Court Conversion to 138 from Cloverdale
2004 Star State St & Hwy 16
Mid-Rose Middleton & Roosevelt
Valley View Harris Ranch
Gamet-Hill.Garnetto Hill 138 kVUne
Gamet-Caldwell Garnet to Caldwell 230 kV Une
Gamet-Locust Gamet to Locust 230 kVLine
Wyee-Butler . Butler to Wyee 138 line
2005 Hillsdale 1 .Amity & Eagle Rd
Mountain Cove Boise Reserve
Farmway N Caldwell-Farmway & Purple Sage
SE Nampa SE Nampa~Happy Valley & Locust
Black Cat-Meridian Black Cat to Meridian conversion to 138
Ten Mile 025 Ten Mile, North of Ustick
Eckert . Homedale and 10th Ave.
Star and Ustick New Star & Ustick Road Substation
Nampa 230 230/138 Tie banks at Nampa
2006 Meridian-Cloverdale Meridian to Cloverdale conversion to 138
2007 Cloverdale-Ustick Tap Double Circuit toUstick Tap
2008 Gamet-Linden Gamet to Linden
2009 Victory-Cloverdale Victory toCloverdale tie line
Cloverdale 230 Cloverdale 230/136 tie banks
Butler to Boise Butler to Boisa 138 line
2010 State-Boise State to Boise 138 tie line
State State conversion to 138 from Gary
Huston to 138 Huston conversion to 138
2012 E Nampa 230 S Side 8. Amity
Boise Bench-Boise Boise Bench to Boise 138
Mora 230 Mora 230/138 kVTie Bank
Zilog to 138 kV Zilog conversion to 138 from Nampa
TOTALS===::-
The 10- Year Transmission Plans of the Treasure Valley
84.475
Page 33
The 1 a-Year Transmission Plans of the Treasure Valley
Tab) 2 Future taboRS eyon
. Station 138 kV Location Figure(miles)
01-New Amity & Ten Mile Station
02N-New Chinden & McDermott Station
02N-. New Beacon Light & Linder Station
01-New Simplot Area-Wagner & Linden Stn
02N-New Willis & Emmett Station
01-New Victory & Robinson Station
N Nampa New N Side & Linden Station
01-New Cartwright Rd Station
02N-Future New Hope & Can-Ada Station
02S-New Columbia & Meridian Station
028-9 New Orchard & Lake Station
d 2012
Page 34
The 1 a-Year Transmission Plans of the Treasure Valley
TIMING OF THE 138 KV SOURCES
The 1 0- Year Syste"
The 138 kV system in the year 2012 willneed five more sources than exist in 2002. These sources
will need to be in the following areas: east of Caldwell, at the Nampa substation, southeast of
Nampa, at the Cloverdale substation and at the Mora substation. The estimated year, load level, and
trigger when each ofthese stations is required to be placed in service is discussed below.
Figure 39. 138 kV sources and theoretical 230 kV lines in 2012
P~me ~5
The 1 a-Year Transmission Plans of the Treasure Valley
2004
East of Caldwell area 230 kV. Trigger:
Caldwell tie banks at 220 MV A with Treasure Valley load of 1354MW. East ofCa,ldwell
shown as the Gamet site but could be placed at any site within several miles along the Locust!
Caldwell 230 line. The trigger has been met, as Caldwell tie banks are over 220 MY A.
2005
Boise Bench 230 kV Capacity.
Trigger: Boise Bench tie banks at 600 MV A with Treasure Valley load of 1411 MW~ mcrease
the size of BOBN T - 231 to 224 MY A. The trigger has been met, as Boise Bench tie banks are over
600 MY A.
2007Nampa 230 kV.
Trigger: Boise Bench tie banks at 700 MV A and Caldwell tie banks at 220 MV A with
Treasure Valley load of 1532 MW. Expand the Nampa substation for a230 kV station. Subject to
confinnation, the site at Nampa substation has space to contain the 138 kV source.
2009
Cloverdale 230 kV.
Trigger: Boise Bench tie banks at 700 MV A with Treasure Valley load of 1665 MW. When the
Cloverdalesubstation is constructed, a 230 kV line is required betweenCloverdale and Locust, and
Cloverdale and Nampa. The Cloverdale-Locust 230 line pole plant exists already and needs to be
strung with conductor. The Cloverdale-Nampa is a new construction that could be designed to go
directly into Nampa or a site called Southeast Nampa, or could tap into the existing Boise Bench-
Caldwell 230 line near either of these sites. These two 230 lines to Cloverdale will be built at the
time of converting the Cloverdale station. The Clovetdale source would need three 230 kV
connections in the future-Locust, Nampa, and Mora.
2012
Southeast of Nampa 230 kV.
Trigger: Caldwell tie banks at 220 MV A with Treasure Valley load of 1874 MW, open
the Bowmont-Mora 138 kV line. A 138 kV source near Southeast ofNampa, shown as
south side but could be placed at a site within several miles on Amity road.
Dry Creek 230 kV.
Trigger: 330 MV A at Cloverdale or Locust with Treasure Valley load of 1874 MW.
Detennine if Dry Creek, Mora, or more capacity at Cloverdale or Locust is the best course
for relieving the overloaded station.
Page 36
The 1 a-Year Transmission Plans of the Treasure Valley
Figure 40. 230kV System with the Addition of Garnet 230/138 kV Station
, '
Figure 41. 230kV System with the Addition of Nampa 230/138 kV Station
Page 37
The 10- Year Transmission Plans of the Treasure Valley
Mi.r~"
:::
~ 00 ..,
Figure 42. 230kV System with the Addition of Cloverdale 230/138 kV Station
Figure 43. 230kV System with the Addition of Southeast Nampa and Mora 230/138 kV Station
Page 38
The 1 Q-Year Transmission Plans of the Treasure Valley
Mountain Home Transmission Area
Definition of Mountain Home Transmission Area
The Mountain Home transmission service area includes all of southern Elmore County. It also
includes the Bruneau Bridge station in Owyhee County and the Blacks Creek station in Ada
County. The cU1'rent system interconnects to the Boise Bench with a 69 Kv and a 138 kV line
Bowmont with a 138 kV line, and the Lower Malad and Upper Salmon power plants with 138 kV
lines. The Strike Dam is on the Snake River southwest of Mountain Home and provides generation
into' the system.
The service area presently has 171 MWs ofload on 14 stations. Ultimate build out is 277 MWs on
14 stations.
Figure 44: Overview of the Mountain Home Transmission service area in 2003
Page 39
The 1 a-Year Transmission Plans of the Treasure Valley
Land Use
The land use in the Mountain Home Transmission service area varies from the city of Mouritain
Home to small towns to irrigated agricultural land. Mountain Home includes some industrial
commercial, and residential. The service area includes the towns of Glenns Ferry, Hammett, King
Hill, Bruneau, and Grand View. These towns are small fanning communities with very little
industrial load. One exception is GlennsFerry, which does have the Magic West cogeneration
facility; this facility normally generates 10 MW s into the system. Mountain Home Air Force Base
(MHAFB), is also in the service area and has a range of industrial, commercial, and residential load.
E+
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Figure 45: Population Centers
PaQe 40
The 1 Q-Year Transmission Plans of the Treasure Valley
The table below shows the acres of agricultural land in the two counties covered by the system. Ada
County is not included since Blacks Creek has no irrigation loads. The flood and irrigated acres are
not known for the counties. It is estimated in the table below that these counties follow the state
average of2/3 pressurized and 1/3 flood irrigated.
Area Total Acres Irrigated Acres.Flood Acres Pressurized Acres
Elmore 126 529 153 30,390 60,762
Owyhee 621 82,485 549 54,935
Load Density & Estimation
The load density in the Mountain Home Transmission service area is low due to much of the area
being unpopulated. The load is concentrated in the Mountain Home andMHAFB areas and along
the Snake River~ The following table shows the existing loads on the stations in the study area and
the stations ultimate buildout. The Ultimate buildout of the stations comes from each individual
station area study. These are based on growth in the towns and cities for areas that includethese and
the conversion of the flood irrig~ted land shown in the table above to pressurized irrigation. There
could be an increase in the total acreage irrigated due to the savings of water in switching from
flood to pressurize. There is approximately a 40% water savings. However in some areas, such as
Mountain Home, fanners are not allowed to increase their acreage ~ven if they go to pressurized
irrigation. The change in irrigation practices is also pushed by yields and crop prices.
Station Present load(MW) 10 Year Load (MW)75 Year Load (MW)
Bennett
Blacks Creek 0;2
Black Mesa
Bruneau Bridge
Canyon Creek
Clampit
Elmore
Flying H
Glenns Ferry
Glenns Ferry Pipeline
Mountain Home
Mountain Home AFB
Orchard
Sailor Creek
Page 41
The 1 a-Year Transmission Plans of the Treasure Valley
Present System
The 69 kV system is the weak point in the Mountain Home transmission system. At present there
are two sources to the 69 kV system south of Elmore Substation, Elmore Substation, and Canyon
Creek Substation. There are presently 30 MWs of load in this part of the system. MHAFB has a
69 kV line to the substation but it is used as an installed spare and has no load. The Elmore
Substation has a capacity of 45 MWs on two transformers, a 20 and a 25 MY A. The Canyon Creek
Substation has the capacity of 10 MW s on one transformer. A loss of the line to Mountain Home
from Elmore will overload the Canyon Creek transformer.
The 138 kV system in the Mountain Home transmission area has no weak points.
75-Year Plan
The 75 year plan for the Mountain Home transmission area will include one 230/138 kV tie bank
station and two 138 kV loops. The 230/138 kV tie bank station should be placed in the vicinity of
the present Mountain Home Junction station. This site offers access to the current .138 kV lines as
well as close proximity to the Boise Bench/Midpoint 230 kYlines.
The 138 kV loops will be oriented as shown below. The east loop will have a total of77.5 MWs on
the five stations at build out. The stations are Bennett, Glenns Feny Pipeline, Sailor Creek, and
Glenns Feny. Bennett and Sailor Creek have mainly irrigation loads. The loop will use the existing
parallel lines that runfrom Mountain Home Junction to the Lower Malad and Upper Salmon power
plants. This loop can be constructed by placing a tie between the two 138 kV lines at Black Mesa.
The 138 kV lines presently have a minimum capacity of 87.2 MY A. Thus, no changes in the presentlines are required.
The south loop will have a total of 117 MWs on five stations at build out. Mountain Home, Elmore
Clampit, Flying H, and Bruneau Bridge. Clampit and Flying H are irrigation stations. Bruneau
Bridge has mainly irrigation loads. Canyon Creek is on the Bowmont/Strike Dam 138 kV line and is
not in the south loop. The 138 kV line that presently creates part ofthis south loop has a capacity of
141 MY A. This loop also has the embedded generation of Strike Dam.
The south loop will need several lines constructed to complete. MHAFB will need a double circuit
. of the present tap. There will need to be a line constructed from Bruneau Bridge to the Clampit tap,
then north to Mountain Home. At Mountain Home, the line could follow the present 69 kVline
north to Elmore and double circuit back to the 230 kV station or it could follow the 69 kV line route
east and then proceed north to the south leg of the east loop and double circuit back to the 230 kV
station.
The Orchard and Blacks Creek stations would be placed on the Boise Bench/Mountain Home
Junction line. These stations, as well as Bennett and Glenns Ferry Pipeline, could have 138 kV lines
run to the present stations or the stations moved to the present 138 kV lines depending on the
economics of each option.
Page 42
The 1 a-Year Transmission Plans of the Treasure Valley
Present Stations
75 yr Stations
Mountain Home 230 kV
Figure 46: 75 Year 138 kV Loops
10-Year Plan
The138 kV system in the Mountain Home transmission area has no weak points with expected
growth in the ten-year time trame. In the future, there may be a need for additional base load
generation in the 138 kV system or the addition of a 230/138 kV source.
To provide for added capacity on a line outage, a second transfonner could be placed at Canyon
Creek. This would not provide sufficient capacity for the existing load. The line between CACK
and the Clampit Tap has a capacity of 32 MW s. If 32 MW s of capacity were placed at CACK, the
losses in the rACK/Clampitt Tap line would be approximately 3.5 MWs. At 30 MWs, the present
load, the losses are just over 3 MWs. Thus, this would not provide capacity for the existing load and
would require load shedding. To provide for the present load, the CACK/ClampitTap line would
have to be rebuilt with larger capacity line. To rebuild the line from CACK to the Clampitt Tap
would be approximately 5.5 million dollars.
An alternative to placing a second transfonner at Canyon Creek is to move the 138/69 kV tie banks
to Bruneau Bridge substation. This would require the building of a line trom the Bruneau Bridge
substation to the present Canyon Creek/Clampit tap 69 kV line. This line would be built on the
69 kV line that was converted to feeder use after Bruneau Bridge was converted to 138 kV
operation. This would reduce the line miles to this point from the tie banks from 14.4 miles to 3.
miles. This line would be built to 138 kV specifications for future use in the 138 kV loop. There
Page 43
The 1 a-Year Transmission Plans of the Treasure Valley
would still need to be 4.3 miles rebuilt from this point to the Clampit tap to remove the 32 MV
capacity conductor. From the Clampit tap to the Mountain Home station and on to Elmore, the wire
is a minimum of 43 MW capacity. Assuming that tnmsfonner capacity can be obtained, no further
upgrades would be needed to the 69 kV system until it is desired to convert the system to 138 kV
operation. The driving factor for this conversion would be to remove the Bruneau Bridge from
being radial on the 138 Kv system or 69 kV equipment becoming obsolete.
EhnBJ Bi dJe
aTfJ
Ry;rgH
Figure 47: 69 kV line from Bruneau Bridge to Clampit Tap
A second alternative is to construct a line from the ElmorelMountain Home AFB 69 kV line to the
Mountain Home/Clampit Tap line. This would provide a second path of supply to the 69 kV system
in the case of a loss of the ElmorelMountain Home line. This line could take the route of the present
tie between the Elmore/Mountain Home AFB and the Elmore/Mountain Home lines and then
simply double circuit the Elmore/MountainHome line past the substation and tie into the Mountain
Home/Clampit Tap line. This could be placed on steel poles to increase reliability. By increasing the
size of the transfonner at CACK to a 20 MV A, the construction of this line could be completed with
the MNHM/ELMR line de-energized. The 20 MV A also allows CACK to support the entire load at
Clampit and Flying H upon a loss of the MNHM/Clampitt Tap line.
Page 44
The 1 a-Year Transmission Plans of the Treasure Valley
Figure 48: PossibJe 69 kV tie li~es
A study was completed on the 69kV system with the a4dition of the CACK 20 MYA transfonner
and the tie line between the MHAFB line and the Clampit Tap line. This is included as Appendix D.
This study was -conducted with load up to the transfonner rating at MHAFB arid build out load,
MNHM. The load at MHAFB would be an abnonnal condition caused by maintenance being
conducted on the 138 kV transfonner at MHAFB. This study shows that the system can supply the
entire load in the area including MHAFB at peak load. With a single-line or equipment outage the
capacity for the MHAFB load is reduced but the system can support all other load on the 69 kV. system.
The study in Appendix D also explores the benefits of adding an additional! 0 MY A transfonner at
CACK. This additional transfonner has limited benefits as CACK will not support the system at
peak load with a loss of the ELMR/MNHM lines and the 20 MY A transfonner can support the
entire system during non-irrigation conditions.
BEYOND 10 YEARS
The loading on the 69 kV system will not be a cause of upgrading the 69 kV system to 138 kV
operation. The buildout load on the 69 kV system is 49.7 kW without MHAFB. By upgrading the
transfonners at Elmore to 42 MV A', the system can support this load on single contingency
outages. A study of the system with the 42 MV As at Elmore was conducted in Appendix D. The 42
MV A transfonners at the Boise Bench should be available before they are required to be placed at
Elmore. Other forces such as changes in the 138 kV system may push the upgrading ofthe 69 kV
system.
Page 45
The 1 a-Year Transmission Plans of the Treasure Valley
Plans For 2003 And Beyond
Transmission
2004
Future
Future
Build double circuit 69 kV line from MHAFB line to Mountain Home station
Build 138 kV line from Bruneau Bridge to 230/138 kV station via MountainHome
Build tie between Black Mesa and Mountain Home Junction! Upper Salmon
138 kV line.
Substation
2003.
Future
Future
Future
Install 20 MY A 138/69 kV transfonner at Canyon Creek Substation.
Install 30 MY A or greater 138/69 kV transfonners at Elmore Substation
Build 230/138 kV tie bank station at Mountain Home Junction.
Convert stations as required to convert system to 138 kV operation from
69 k V operation.
Conclusion
The study helped determine what changes for the electrical system in Treasure Valley are needed to
meet the load demand in forecasted in 2012. The resulting plans are based on growth, economics
feasibility, and reasonable perfonnance.
Page 46
The 10-Year Transmission Plans of the Treasure Valley
Appendix A
The Loop Model
The loop model of the electrical system was first identified and used in the 75-year study in 2000.
Theloop model is build around a source of230 kV or higher voltage from which 138 kV loops
originate to serve severall2.5 or 34.5 kV substations. The components ofthe loop model are the
source station or load center and its high-voltage grid, the substation and its loops, the distribution
and its coverage.
Source
~3'=~
- -
' Pfi--~
'L_
:~
;. i-
. ,.~ ~-~ _. .; ,
Figure 49a. ASource Model with Two Sources and High-Voltage Transmission
The source in the loop model is a high-voltage to 138 kV transfonnation station that receives power
from a power supply, or on-site generation, and may be linked with substation and distribution
facilities. The source must satisfy the reliability requirements for serving the 138 kV system such as
adequate power supply and reliable transmission. Reliability for single-outage conditions requires
that a source has one line and one transfonner as redundant facilities. A source serving 600 MW has
three high-voltage 430 MW lines and three 300 MY A transfonners.
Looped Transmission
TEN MILE
BLACKCAT
Figure 49b. A Loop Model with Two Sources and 138 kV Transmission Loops
Page 47
The 1 a-Year Transmission Plans of the Treasure Valley
A typical sub-transmission 138 kV loop originates from the source station and serves 270 MW or
less of substation load. The loop s reliability is designed for single-outage contingency, and the first
line sections from the source to the first substations are rated as getaways. If one of the first line
sections is opened, the other 277 MV A 1272 MCM ACSR conductor can radially serve the full loop
load from the source. The sections following the first line sections are usually rated at 208 MY
and built with 720 MCM ACSR conductors.
The substation transfonns 138 kV voltage to the 12.5 or 34.5 kV distribution, and an average
substation serves 80 MW load with eight 10 MW feeders, rated at 12.5 MY A each, in an 8-square-
mile area with load density of 10-12 MW per square mile. The improved radial service of the
substation in a loop satisfies its reliability requirement for single outage conditions. There is no
reliability for the transfonners as far as an on-site back up; only mobile back-up. The 80 MW
substations have two 40 or higher MY A transfonners, while some substations serving 120 MW of
sUITounding load have three transfonners.
Distribution
:;~~
co,
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i-~------
+---
Figure 49c. A Model of the Layout of the Distribution System
Associated with the average substation, the eight feeders, each serving I-square mile area,. are
arranged for reliability in serving the load to the north, south, east, and west Two transformers send
a feeder each via the four directions, so that each feeder serves a segment ofload that is bordered by
feeders from the other transfonner. In this alternating pattern, if one transfonner should fail to serve
its four load segments, the other transfQnner can pick up some of the load bordering its feeders
using the available margin of 25 MW per feeder.
For reliability, three high-voltage transmission lines are sufficient for atypical 600 MY A source
station while two high-voltage transmission lines suffice for a 300 MY A source station. However
with this model, an optimum layout for a source station may consist of facilities for four high-
voltage transmission lines, two 138 kV loops or four parallel 138 kV lines, and eight distribution
lines. The comer location allows an easy and economical getaway of transmission along the north-
south and east-west transportation grid. Two circuits may exist in each direction on opposite sides
of the road with proper rights-of way, each having a different structural design for carrying various
high voltage and 138 kV transmission overhead and the feeder lines. A circuit with one 138 kV
lines may have wood poles while a circuit with two 138 kV of higher voltage lines has steel poles
for reliability and/or strength. In the future, underground facilities may be considered to reduce the
clutter of the overhead electrical system.
Page 48
The 10-Year Transmission Plans of the Treasure Valley
Design Criteria and Planning
Design criteria are based on the model of the system that merges with the realities of a society.
Once the load, and location of the loads has been identified, design criteria are part of the second
tool set and important in the physical layout of the future electrical system. These may include
differences for 10-year and 75-year layouts; The design criteria for each component of the loop
model must be considered in tenus of geographic attributes and load density, as well as strategy,
economics, politics, land use, and societal impact. From the big picture to a microscopic view, thesecriteria continue to evolve and grow.
Land Use Criteria
When selecting a site for the source station or substation, the following are considerations:
Build substation sites away from politically or ecologically sensitive prope~ies.
Use sites near gas lines and railroads for generation sites.
Preserve present rights-of-way and substation sites
Build substations on comers of roads.
Stay on major roads for corridors.
Source Stations Criteria
~ A typical source stations is rated at 600'MVA, has three 300 MY A transfofI1?ers; and
serves 600 MW of substation and source station load.
~ A minimum of three high-voltage transmission lines minimum; a maximum of fourhigh-voltage lines.
~ Two loops of sub~transmission and/or radial lines.
Loops Criteria
One loop serves about 270 or less MW of substation load.
The first line sections from the soUrce are rated at 277 MY A, others are 203 MY A.
Loops with one or more critical substation must have tie lines for back up to adjacent
loops.
Whenever possible, provide tie line between adjacent loops of different sources.
Critical Loads Criteria
When serving areas that have critical loads such as sensitive or high-density loads, the following
reliability considerations must be addressed.
Page 49
The 10-Year Transmission Plans of the Treasure Valley
Loops with one or more critical substations must have tie lines for backup to adjacent
loops.
Critical substations must be on different 138 kV loops.
Major critical substations such as Locust and Cloverdale must on different sources.
Substations Criteria.
When designing the voltage class and capacity of a substation in an area, the following are
considerations.
~ High-density areas above 12 MW per square mile, serve about 120 MW of 12.5 kV load.
Stations of 40 MW or less supplement the load demand.
Residential areas with 10-12 MW per square mile, serve about 80 MWof.12.5 kV load.
Rural areas with 3-8 MW per square mile, serve about 80-40 MW of 12.5 kV load.
~ Low-density areas with less than 3 MW per square mile, serve 40 MWor less of 12.5 kV
or 35 kV load.
Mountain Home Area
The Mountain Home area load will be addressed in a separate study. The load is defined by the flow
at the boundaries of Lucky Peak-Dram 138 kV line, the Black's Creek-Boise Bench 69kV line, the
Swan Tap-Bowmont 138 kV line, the Black Mesa-Lower Malad 138 kV line, and the Glenn s Ferry
Tap-Lower Salmon 138 kV line.
Contributing AuthorsKeith Georgeson 2034 BOC Planning Engineer
Hilly Penton 2451 CHQ-Planning Engineer
Jeff Nofsinger 2147 BOC Planning Engineer
Amy Janibagian 2983 CHQ-Technical Writer
Finish date: January 2003. Publish date: May 2003
Page 50
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The 10- Year Transmission Plans of the Treasure Valley
Appendix D
Mountain Home/Elmore 69 kV Study
10-YearJ Area Capacity of 58 J Contingency 38
What is the system capacity during steady state and contingency conditions? What is the impact of 13 MW
MH AFB load on the 69 kV system?
Improved System
Adding the second Elmore-Mountain Home 69 kV line brings inreal and reactive capacity into the 69 kV
system, resulting in 2.8% increase in voltage. And with the 20 MY A Canyon Creek tie bank, and loads
compensated to unity power factor to maximize tie bank capacity, the system capacity is 58.3 MW, limited by
the 20 MY A tie bank at Elmore. The loads include 13.O+j4.5 atMHAFB, mature iITigationof 14.4+jO MW
and 30.9 MW+jO at Mountain Home. The limiting factor to the 60 MW is an Elmore 20 MY A tie bank. The
loading on the Boise Bench-Elmore 69 kV line is about 11.5 MW in caseHS2005~CD1'VTM-MNHM69.
The worst contingency is an outage of one Elmore tie bank that results in overloading the second Elmore tie
banks, and reduces the system capacity to 38 MY
During anoutage of the Canyon Creek tie bank, the maximum tadialload served &om the Elmore tie banks
and Boise Bench is about 44.3 MW, comprising of32.8 MW +jO, and a MH AFB load ofl1.5MW +j4.
Service to MH AFB is limited by area load. See Table 1.
Canyon Creek Radial Service and Options
A double contingency of the Elmore-Mountain Home 69 k V Illes results in radial service fh~m Canyon Creek.
The Canyon Creek 138/69 kV 20 MYA tie bank can serve about 18.4 MW of radial load with unity power
factor. Line losses are about 2 MW. Reactive losses through theCacktie bank are about 1.8 MY AR at
full load. Service to MH AFB is limited by area load.
Adding the 10 MY A tie bank to Canyon Creek, improved the radial service by 2.5 MW With loads
compensated with unity power factor, the maximum radial capacity from Canyon Creek is 20.9 MW
limited by soft voltage in the Glenns Ferry/Bennnett area.
Adding a 4.8 MV AR capacitor bank to the 10 MY A and 20 MY A tie banks at Canyon Creek improves the
radial service by 8.5MW. The maximum radial load from Canyon Creek is 26.4 MW, limited by the 10
MY A tie bank. See Table 1.
Table 1: Results orBS 2005-CDTVTM-MNM69 case
Conditions Cack tie bank Reactive Max MW Load Limitations
At Unity PF
Steady state 20 MV A 58.Elmore Mtn Home lines
Elmore 25 tie 20 MVA Elmore 20 MVA
Cack 20 tie 20 MVA 44.Elmore 20 MVA
Cack Radial 20 MVA Cack 20 MVA
Cack Radial , 10 MVA 20.Low Voltage at GFPUBNET
Cack Radial , 10 MVA 8 MVAR 26.Cack 10 MVA
M__- ~~
The 10- Year Transmission Plans of the Treasure Valley
Future, Area Capacity of 93 Mw, Contingency 60
How much is the system capacity now? What is the impact of the removal ofthe Boise Bench20MV A?
Improved System
Replace the two Elmore tie banks with 42 MY A units from Boise Bench, and leave the 20 MY A at Boise
Bench 69 kV. The Mountain Home 69kV system is fed by the two 42 MY A Elmore tie banks, the 20 MY A
at Boise Bench and 20 MY A at Canyon Creek. The system capacity is 93.0 MW limited by the line rating of
the Elmore-Mountain Home 69 kV #1 and #2 lines, each rated at 42.6 MY A, as in case HS201 O':'CDTVTM-
MNHM69.
The worst contingency is an outage of one Elmore tie bank that results in overloading the Canyon Creek
Boise Bench and Elmore tie banks, and reduces the system capacity to 68 MW.
The removal ofthe Boise Bench 20MV A from the Mountain Home 69 kV system has .no effect on the
capacity of the future Mountain Home 69 kV system during steady state conditions, but dUring contingency
condition, the system capacity is reduced to 55 MW.
Table 2. Results orBS 2010-CDTVTM-MNM69 case
Conditions Cack tie bank Elmore1&2 Max MW Load Limitations
tie banks At Unity PF
with Boise Bench
20 tie
Steady state 20 MVA 42 MVA Elmore MtJ1 Home lines
Elmore 42 tie 20 MVA 42,42 MVA Elmore 42 MVA
Cack 20 tie 20 MVA 42 MVA Elmore 42 MVA
wlo Boise Bench
20 tie
Steady state 20 MVA 42 MVA Elmore 42 MVA
Elmore 42 tie 20 MVA 42 MVA Elmore 42 MVA
Cack 20 tie 20 MVA 42 MVA Elmore 42 MVA
Paae 78