20040706Teinert Direct.pdf

Idaho F'ub.!lr;j Ut!!ltl,~ CO!11:,;"!ssion
OHic" ~f ,h~ ~fj(Jr0'1l1ryFiECElven
JUL - 2 2004
BEFORE THE IDAHO PUBLIC UTILITIES ~8~~ON
IDAHO POWER COMPANY.
CASE NO. IPC-E-O4-04
COMPLAINTANT .
VS.
THE CITY OF EAGLE , IDAHO.
RESPONDENT.
DIRECT TESTIMONY AND EXHIBITS OF
PIKE TEINERT
ON BEHALF OF
THE CITY OF EAGLE , IDAHO
PLEASE STATE YOUR NAME AND BUSINESS ADDRESS.
My name is Pike Teinert and my business address lS
834 Harcourt Road Boise, Idaho 83702.
WHAT IS YOUR OCCUPATION?
principal consul tant for Energy Strategies
Group LLC, a consulting firm that provides services to clients in
the utility industry.
ARE YOU SPONSORING ANY EXHIBITS WITH THIS TESTIMONY?
Yes.I am sponsoring Exhibit Nos .108 through 118.
PLEASE DESCRIBE YOUR QUALIFICATIONS TO TESTIFY AS AN
EXPERT IN THIS PROCEEDING.
am an electrical englneer and I have thirty-four
years experlence in the energy industry in positions ranging from
design engineer to Vice President. As an engineer for Texas Power
and Light Company,designed and managed the construction of
138KV and 345KV switch yards. Over 20 years of my experlence were
in customer relations positions that included responsibility for
negotiating customer service contracts including line extension
and system betterment provisions. From 1996 through January 2003
I was with the Electric Power Research Institute, EPRI' s, client
relations division and was responsible for collaborative research
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and development coordination incl uding transmission and
distribution largestR&D for several North America
utilities.My complete resume , including educational background
and employment history, is presented as Appendix
HAVE YOU PREVIOUSLY APPEARED AS AN EXPERT WITNESS
BEFORE THIS COMMISSION?
Yes. I have provided direct and rebuttal testimony in
the Idaho Public Utili ties Commission Case No.IPC-E-00-
regarding an industrial class customer and line extension policy
wi thin Schedule 19.have also provided direct and rebuttal
12 .testimony in the Idaho Public Utilities Commission Case No. IPC-
E-03-13, Idaho Power Company s most recent general rate case.
WHY ARE YOU TESTIFYING IN THIS CASE NO. IPC-E-O4-04?
have been retained by the City Eagle
witnessexpert assist the analysis Idaho Power
complaint filed in this case. The City of Eagle and Idaho Power
began discussing the City concerns about upgrading the 69KV
line 138KV between the Eagle substation and the new Star
substation in 1999.Al though the Company has proposed several
al ternati ve routes for the 138KV sub-transmission upgrade,
methods and technologies other than 138KV upgrade that can
address the City s concerns and could have been considered , were
explorednot Idaho Power and proposed the City.
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testimony will outline technology that Idaho Power could have
proposed that can offer the City an acceptable option to those
currently offered by the Company. My silence on other issues in
this case does not necessarily imply acceptance of the Company
position.
PLEASE DESCRIBE HOW YOUR TESTIMONY IS ORGANIZED.
My testimony and exhibits will address demand side
alternatives that could impact the proposed upgrade to the 69KV
line from Eagle substation to the new Star substation and also
delivery technologies that were not included as alternatives by
the Company to the City of Eagle.
YOU SAY THAT DEMAND SIDE ALTERNATIvES WERE NOT
INCLUDED IN THE COMPANY'S PLANS TO UPGRADE THE 69KV LINE FROM THE
EAGLE SUBSTATION TO THE STAR SUBSTATION. CAN YOU GIVE EXAMPLES?
Yes.Al though Idaho Power Company 2002 Integrated
Resource Plan, 2002 Demand Side Management Report, DSM 2003-2005
Business Plan and 2003 Conservation Plan , Exhibit Nos. 108, 109
110 and III respecti vely all incl ude discussions load
reduction benefi ts gained from demand side resources,the
benefi ts of these resources were not explained and identified to
the Ci ty by Idaho Power as al ternati ves that could help diminish
the rate of load growth in the Eagle and Star service areas.
Examples of programs included in these documents that could have
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been discussed to slow load growth in Eagle and Star are found on
page 18 of the Company s DSM 2003-2005 Business Plan, Exhibit No.
110. They include residential and commercial programs, important
in this case Residentialsuch as the Lighting Coupon Program,
new Construction Program , AC Direct Load Control Program and the
Residential Air Conditioning Cycling Pilot Program. Additionally,
Idaho Power 2002 Demand Side Management Report,Exhibi t No.
109 , that includes Idaho Power , September 12 , 2002 , Residential
Time-of Use Study quantifies significant load reduction potential
from AMR/TOU. When the Company was ordered by the Commission , in
its Order No.9196, in March , 2003 to submit a plan to replace
the current Idahometers withPower advanced meters,the
Company subsequently proposed its Emmett service area as an area
for AMR technology deployment.Given the substation and 69KV
constraints in Eagle and Star , the Company should have proposed
Eag Ie and Star locations initiate thatAMR would
demonstrate both the load reduction and delivery asset management
benefits of AMR/TOU in the Eagle and Star area and help resolve
the 69KV sub-transmission issues in this complaint.
Q. HAD THE COMPANY CONSIDERED DEMAND SIDE INITIATIVES AS
POSSIBLE SOLUTIONS TO ADDRESS DELIVERY CONSTRAINTS PRIOR TO THE
DEVELOPMENT OF THE DOCUMENTS YOU'VE CITED?
A. Yes. In the Company s 2002 IRP filing, the IPUC's Order
No. 28583, dated December 18, 2000, Exhibit No. 112 , page 5, the
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indicatesCompan y will Perform and present feasibili ty
study the applicationnear-term mobile generators
provide not only additional power and energy but also to provide
reinforcement to the delivery system and potentially defer
avoid capaci t upgrades deli very facilities-November 2000
(emphasis added)". It is clear that the Company is and was aware
of the potential of demand side ini tiati ves to defer or avoid
capacity upgrades to delivery facilities like the 69KV line from
the Eagle substation to the new Star substation. Yet, the Company
did not offer demand side initiatives to the City as alternatives
to upgrading the 69KV line between Eagle and Star.
Q. IF THE CITY HAD BEEN INFORMED IN 1999 OF THE POTENTIAL
TO AVOID OR DEFER THE UPGRADE OF THE 69KV EAGLE/STAR LINE USING
DEMAND SIDE COULD THE CITY AND THE COMPANY HAVEINITIATIVES
COOPERATED TO DEVELOPED AND EXECUTE THE PROGRAMS.
Yes.Clearly there was time to develop and ini tiate
demand side programs. In his testimony Idaho Power s David Sikes
Exhibit No., estimates the cost of the 69KV to 138KV upgrade to
range from $2 500,000 to $2 840 000 with no additional cost to
the City. Clearly if that level of funding had been budgeted for
demand side programs they would yield significant long-term load
reduction benefits and avoid or defer capacity upgrades to the
delivery system.Based on the Expenditure Chart of the Company
2003-2005DSM Business Plan Exhibi tPage 110,No.the
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estimated cost of the sub-transmission upgrade in this case would
exceed the total system DSM program expenditures for Idaho Power
in each year from 1999 through 2002.
Also, the general public was certainly sensitive to the
exceptionally high and volatile energy prices at that point in
the 2000-2001 energy crisis and would have been very receptive to
demand side programs that would not only have avoided or deferred
deli very upgrades but would also have helped mitigate large
future PCA increases necessitated by record high prices in the
wholesale market.
Q. WOULD DEMAND SIDE PROGRAMS HELP DIMINISH THE RATE OF
LOAD GROWTH IN EAGLE AND STAR?
Yes.The Company would have had almost four and one
half years to plan and execute DSM programs that would have
deferred or avoided the need for the Eagle to Star 69KV to 138KV
upgrade.
TEINERT HAVE YOU REVIEWED IDAHO POWER COMPANYMR.
DOCUMENTS THAT PROVIDE SUBSTATION CAPACITY AND LOADING FOR THE
EAGLE SUBSTATION?
The documentYes.identified as Exhibit No.113
provided by the Company in the IPUC Commission Case No. IPC-E-OO-
12.
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Q. BASED ON THE COMPANY'S INFORMATION PROVIDED IN EXHIBIT
NO.113 WHAT IS YOUR ASSESSMENT OF THE LOADING ON THE EAGLE
SUBSTATION?
A. As shown in Exhibit No. 113, the Eagle substation 2000
summer peak demand was 33.MW. The substation capaci ty was
MVA and therefore was loaded to about 60% of its capaci ty at a
load factor of 85%.
Q. SINCE THE EAGLE SUBSTATION WAS ONLY 60% LOADED IN THE
SUMMER OF 2000 COULD IDAHO POWER HAVE MANAGED THE GROWTH AT TH I S
SUBSTATION WITH DEMAND SIDE PROGRAMS AND DEFFERED OR AVOIDED THE
CAPACITY UPGRADE TO THE EAGLE/STAR 69KV LINE.
Yes.the 2000 the heightenedsummergl ven
awareness of the soaring price of wholesale electricity, demand
side programs would have been especially effective and would have
been huge public relations opportunity for the Company to
demonstrate its for sustainablesupport energy DSM practices
specifically in Eagle and Star and would also have been a model
for the remainder of Idaho Power s system.
SINCE THE STAR SUBSTATION WAS NOT BUILT UNTIL 2004
COULD IDAHO POWER HAVE MANAGED THE GROWTH IN STAR USING DEMAND
SIDE PROGRAMS AND DEFFERED OR AVOIDED THE CAPACITY UPGRADE TO THE
EAGLE/ STAR 69KV LINE.
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A. Yes. As I've stated previously in my testimony, in the
summer of 2000 gl ven the heightened awareness of the soarlng
price of wholesale electricity, demand side programs would have
been especially effecti ve and would have been huge public
relations opportunity for the Company to demonstrate its support
for sustainable energy practices.
FOCUS ING THE COMPANY'ASSERTION THAT THE STAR
SUBSTATION MUST BE BUILT BY THE SUMMER 2005 TO AVOID SERVICE
DEGRATION IN THE EAGLE STAR AREA HOW DOES IDAHO POWER'S DAVID
SIKES CHARACTERIZE THE GROWTH IN STAR?
A. Mr. Sikes in his direct testimony, page 4 beginning at
line 9, states that:
While the load growth in Star is materializing at
slightly slower rate due to the smaller size of the community and
the additional commute distances from Star to Boise and Meridian
commercial hubs, with increasing housing costs in Ada County and,
specifically Boise and Meridian,development Star
accelerating. "
DOES MR .SIKES INDICATE WHY THE COMPANY DECIDED TO
BUILD THE STAR SUBSTATION EVEN THOUGH THE GROWTH IN STAR WAS
MATERALIZING AT A SLOWER RATE THAN EXPECTED?
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A. No. Mr. Sikes simply says on page, 4 beginning at line
23 :
" In 1999 the Compan y decided theconstruct Star
substation by the summer of 2004 in order to maintain adequate
service in the area.
There is no explanation of the need to complete the Star
substation in the summer of 2004 regardless of the slower growth.
Q. DID THE COMPANY CONTINUE WITH ITS PLAN TO BUILD THE
138KV STAR SUBSTATION EVEN THOUGH THERE WERE DELAYS IN PERMITTING
THE 138KV LINE TO SERVE THE STAR SUBSTATION?
A. Yes.
Q. MR. TEINERT , WAS BUILDING THE STAR SUBSTATION IN THE
SUMMER OF 2004 PRUDENT SINCE THERE WAS NOT A 138KV SOURCE
AVAILABLE FOR THE NEW 138KV STAR SUBSTA'1'ION?
A. No. Normally, the source for a distribution substation
like the 138KV Star substation,would have confirmed 138KV
source before the decision to build the sub is finalized. In this
case the decision to build the sub and construction both took
place even though the 138KV source was not secure.Mr. Sikes
testimony clearly states the decision to build the sub was made
1999.The Company applied for CUP December 2000
upgrade the Eagle sub to Star 69KV to 138KV and in February 2001
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the Eagle Planning and Zoning Commission formally recommended
that the City Council deny the application.
Q. AFTER THE CITY P&Z COMMISSION'S DENIAL RECOMMENDATION
OF IDAHO POWER'S FIRST CUP APPLICATION , DID THE COMPANY OFFER THE
CITY ANY ALTERNATIVES OTHER THAN 138KV ALTERNATIVES?
A. No.
Q. DID THE COMPANY SUBMIT ANOTHER APPLICATION FOR A CUP TO
UPGRADE THE 69KV LINE FROM EAGLE TO STAR TO 138KV?
A. Yes.In September 2002 the Company submitted another
CUP application for a 138KV alternative route along Highway
through Eagle.September 2003,the City Eagle P&Z
Commission recommended denial of Idaho Power s second application
for a CUP to build a new 138KV line through Eagle.
AFTER THE DENIAL RECOMMENDATION OF ITS SECOND CUP
APPLIcATION , DID THE COMPANY , OFFER THE CITY ALTERNATIVES OTHER
THAN 138KV ALTERNATIVES?
A. No.
Q. GIVEN THIS HISTROY OF SLOWER LOAD GROWTH IN THE STAR
AREA AND THE P&Z' TWO DENIAL RECOMMENDATIONS , WHAT WAS DRIVING
THE COMPANY'S RUSH TO BUILD THE STAR SUBSTATION AND THE 138KV
EAGLE TO STAR UPGRADE?
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A. It is reasonable to conclude that the Company s 10 Year
Transmission Plan for the Treasure Valley, Exhibit No. 114 , page
documenting the timing of the Company 138KV Transmission
plan , rather than the load in Star , was driving force behind the
Company s push to complete the Star substation and 138KV source
from Eagle 2004.Upon completion thesummer 138KV
substation in Star,the Company asserts they would then need a
138KV source from Eagle to serve it. However , the Company offers
no data or analysis concluding that the existing 69KV feed to the
Star substation is not adequate or that it could be upgraded to
provide 69KVpermanent feed.The Company silence any
solution other than 138KV solution provides further support
that the Company 10 Year Transmission Plan rather that the
load in Star and Eagle is driving the plan and timetable for this
proj ect
Q. MOVING TO ALTERNATIVES OTHER THAN THE COMPANY'S 138KV
OPTIONS DID HAS THE COMPANY EVER OFFERED THE CITY
ALTERNATIVES OTHER THAN THE 138KV ALTERNATIVES OUTLINED IN MR.
SIKES' TESTIMONY?
A. There is no documentation in the testimony or exhibits
this that indicates the Citycase offeredwasever any
alternatives other that the 138 KV alternatives in Mr.Sikes
testimony.
Also, Mr. Said's testimony on page 2, line 21 states:
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" . . the Company has attempted identify
alternative acceptable to all interested parties
There has clearly been option other
alternatives identified Idaho Power and
repeatedly found the 138KV alternative unacceptable.
the Company has failed completely identify
alternatives for the City.
Sikes,Mr.in his testimony,states on page
that:
route and
than 13 8 KV
the City has
Therefore,
acceptable
line
Idaho power has been diligent and prudent in its effort
to site new transmission facilities.
Again , neither Mr. Said nor Mr.Sikes has identified any
alternative other than new 138kV alternatives regardless of the
City obj ection to newstrong 138KV transmission facilities.
Therefore, the diligence and prudence of the Company s search for
solution acceptable to the City is questionable and clearly
inadequate.
IS IT PRUDENT PLANNING AND DESIGN STRATEGY TO EXCLUDE
ALL ALTERNATIVES OTHER THAN 138KV ALTERENATIVES IF THE CITY IS
FIRMLY IN OPPOSITION TO THE 138KV ALTERNATIVES?
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A. No. The Company s rush to adhere to building the 138KV
Star substation and 138KV line from Eagle to the Star substation
as outlined in its 10 Year Transmission Plan is unreasonable
given the City s concerns. It is reasonable to conclude that the
Company was totally committed to its 10 Year Transmission Plan
and was did not seek alternatives other than 138KV options.
Q. MR TEINERT HAVE YOU REVIEWED THE BLACK AND VEATCH STUDY
IDENTIFIED AS EXHIBIT NO. 11s?
A. Yes.
Q . BASED ON YOUR REVIEW OF THE BLACK AND VEATCH STUDY WERE
THERE ALTERNATIVES OTHER THAT THE 138KV OVERHEAD AND UNDERGROUND
LINE ALTERNATIVES ANALYZED AND REPORTED TO THE CITY IN THE BLACK
AND VEATCH STUDY?
A. No.
Q. THEREFORE , BASED ON THE DOCUMENTATION IN THIS CASE DO
,. ,
YOU FIND THAT BOTH THE COMPANY AND BLACK AND VEATCH PRESENTED
ONLY 138KV OVERHEAD AND UNDERGROUND ALTERNATIVES?
A. Yes. The only alternatives analyzed in the B&V study
the 138 KV overhead andwere underground solutions previously
identified by Idaho Power. Certainly the City had hoped that the
B&V study would explore other reasonable alternatives to 138KV
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given the City obj ection to the height of 138KV overhead and
the expense of 138KV underground.
HASN'RECENT RESEACH AND DEVELOPMENT PROVIDED THE
ELECTRIC UTILITY INDUSTRY WITH .sEVERAL TECHNOLOGY ADVANCEMENTS
LIKE SUPERCONDUCT ING CONDUCTOR CAPABLE SIGNIFICANTLY
INCREASING THE CAPACITY OF TRANSMISSION SYSTEMS?
A. Yes. My seven years experlence at EPRI through early 2003
provided inside look several advances transmission
technology that will significantly improve the capacity of the
existing transmission grid.Transmission superconductors FACT S
Flexible Transmission Systems)and Dynamic Line Rating
technology are examples of technologies that have been developed
tested and introduced to the industry by EPRI in the last few
years.
Q. ARE THESE TECHNOLOGIES THAT IDAHO POWER SHOULD HAVE
REVIEWED AND CONSIDERED AS ALTERNATIVES TO THE 138Kv SOLUTIONS
THEY IDENTIFIED?
A. Yes. Some of them are potential solutions. However , the
latest developments in these technologies have been developed by
EPRI and its members and Idaho Power has not been a member of
EPRI since 2001 and therefore , may not be aware of them.
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Q. MOVING TO THE ISSUE OF DELIVERY SYSTEM CAPACITY AND
UPGRADES TO THE STAR SUBSTATION DOES MR .SIKES EXPLAIN WHY
SERVICE TO THE STAR SUBSTATION FROM THE CALDWELL-LANSING 69KV
LINE IS ONLY TEMPORARY?
A. Yes, Mr. Sikes explains in his direct testimony that
the 69KV line from Caldwell cannot provide ampacity and voltage
support to the Star substation beyond the load levels expected at
the Star substation in early 2005.
DOES MR .SIKES OFFER ANY SOLUTIONS FOR THE VOLTAGE
SUPPORT AND AMPACITY PROBLEM ON THE 69KV LINE SERVING THE STAR
SUBSTATION FROM CALDWELL-LANSING OTHER THAN THE 138KV EAGLE TO
STAR UPGRADE?
A. No. Mr. Sikes simply says in his testimony beginning on
page 16, line 10 that:
This line limited by both conditions and will
requlre a capacity upgrade in the future.
TECHNOLOGIESARETHERE AVAILABLE RESOLVE THE
CALDWELL-LANSING 69KV LINE VOLTAGE SUPPORT AND AMPACITY PROBLEMS
GIVEN THE CITY OF EAGLE'CONCERNS ABOUT CONSTRUCTING A 138KV
LINE THORUGH EAGLE?
A. Yes. The Caldwell 69KV line could be reconductored to
mitigate the voltage support problem.Many electric utilities
have been faced with transmission capacity problems and have
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addressed them high temperature,low sag,aluminumus lng
conductor steel supported (ACSS)cable that capable
operating at approximately twice the operating temperature of
conventional conductors. As stated in Exhibit No. 116, title
ACSS/TW conductor higheroperates temperatures,
delivers more power over existing transmission corridors
ACSS cable would reduce voltage drop and significantly
the capacity the Caldwell- Lansinglncrease 69kv line
adequately serve the Star substation.This solution would not
require the proposed upgrade of the existing 69KV line through
Eagle to a 138KV line.
IF THE ACSS 69KV ALTERNATIVE IS USED TO RESOLVE THE
VOLTAGE SUPPORT AND AMPACITY PROBLEMS ON THE CALDWELL-LANSING
LINE TO SERVE THE STAR SUBSTATION WOULD IT BE NECESSARY TO BUILD
THE 138KV LINE THROUGH EAGLE AS PROPOSED BY THE COMPANY?
No.If ACSS were used to reconductor the Caldwell-
Lansing line then the Star substation could be served from that
source instead of the Eagle source.
Q. MR TEINERT , WHAT OTHER ALTERNATIVE , NOT OFFERED BY THE
IDAHO POWER COMPANY , WOULD ELIMNATE THE NEED FOR UPGRADING THE
69KV LINE TO 138KV FROM EAGLE TO THE STAR SUBSTATION?
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A. ACSS cable could also be used to reconductor the 69KV
line from Eagle to the new Star substation. Height requirements
would not need to exceed the existing 69KV line through Eagle
especially if the Company undergrounds the distribution currently
existing on the 69KV line as they have expressed a willingness to
do.Therefore it would not be necessary to erect large steel
poles through Eagle for 138KV service to the Star substation.
Facilities in the Eagle substation to step down 138KV to 69KV
would be required.
Q. CAN EITHER OF THESE TWO SOLUTIONS BE IMPLEMENTED WITHIN
THE TIME FRAME PROPOSED FOR THIS PROJECT?
Yes.ACSS cable has been "widely available for more
than a decade " as stated in Exhibit No. 116 and is available for
purchase and installation prior Idaho Power self-imposed
deadline of May, 2005.
Q. IS ACSS TECHNOLOGY RELIABLE?
A. Yes. Examples of research,studies and case histories
as provided in Exhibit Nos. 116 and 117 that include studies by
EPRI , the Electric Power Research Institute on ACSS cable , have
verified ACSS technology as a reliable and efficient technology
that effectively manages capacity problems on existing delivery
infrastructure. As stated in Exhibit No. 116,
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ACSS cable . . has been used successfully several
utili ties lmprove flows existing t r ansmi s s i power
corridors. "
ACSS adds delivery capacity as deregulation has burdened
electric utilities transmission withsystems non-nati ve
generation from unregulated companies.
Q. IS THE COST OF ACSS CABLE MORE EXPENSIVE THAN ACSR , A
MORE FREQUENTLY USED CONDUCTOR?
Yes.ACSS normally 15%-25%costs than ACSRmore
conductor. However , as shown in figure 3 of Exhibit No. upgrading
capaci ty with ACSS can save the total cost of new structures and
reduce overall conductor cost by 20%. The increased capacity of
ACSS can eliminate the need for extensive and expensive upgrading
to higher vol tages and is a much more economical alternative
than building a new 138KV steel pole line through Eagle.
INSTALLATION OF ACSSDOESTHE REQUIRE NON - STANDARD
EQUI PMENT REQUIRE NON-STANDARD INSTALLATION TECHNIQUES
TRAINING?
A. No. As stated in Exhibit No. 116, ACSS can be installed
uslng "good stringing practices Some additional care needs to
taken theprotect soft aluminum conductor dur ing
installation such as using lined stringing blocks.
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Q. IN SUMMARY DOES YOUR TESTIMONY SUPPORT USING ACSS AT
69KV AS THE BASIS FOR SERVING THE STAR SUBSTATION FROM EITHER OR
BOTH THE CALDWELL-LANSING LINE OR THE EAGLE SOURCE?
A. Yes.
Q. DOES THIS CONCLUDE YOUR DIRECT TESTIMONY?
A. Yes.
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July, 2003
Principal,
Pike Teinert
energy s tra teqies qroup LLC
Pi ke Teinert, Principal
esg
energy strategies group LLC
834 Harcourt Road
Boise, Idaho 83702
Work [phone]Cell [phone]Fax [phone]
Email pteinert~cableone. net
Horne [phone]
PROFESSIONAL BACKGROUND
Thirty~four years of experience in the energy industry in positions
ranging from Design Engineer to Vice P~esident 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 themi~ 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 noncompeti ti ve 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/so~utions.
owned/public power utili ties, the
EPRI, and consulting this broad
unique perspective of the changing
SUMMARy
Extensi ve experience in the utility industry encompassing engineering,
electric service rules and regulations, consulting ,sales, human
resources, field management, regional operations management, cqrporate
management and executive management positions provide a diverse and
solid base of experience. Significantly, this background with publicpower, investor owned utili ties and energy R&D, is vi tal experience in
understanding today ' s complex energy challenges. Frequent meetings with
client and company management and roundtable discussions with non-
management staff are important communications and discovery tool::\ usedto develop understanding, consensus and solution driven results andvalue.
APPENDIX A
As Corporate Account Executive, Regional Operations Manager and Retail
Regional Manager for EPRI, the energy industry I 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 I s leading energy companies.
As Vice President at the Orlando Utilities Commission, I reorganized
the 207 employee, $10 million annual budget, Customer Service
Conservation business unit into a customer driven, rapid response te9m
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, 9distribution points of deli very were reduced to 2 transmission pointsfor this 62 MW client and included a facilities lease and maintenance
agreement.
As proj ect team leader at Texas Power & Light Company, I developed
TP&L I s and subsequently Texas Utili ties first interruptible rate, whichul timately 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 energyindustry 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 obj ecti ves 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' 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, withsales averaging $ 70 million annually. This new position forecasted,
contracted, monitored, expedited and reported and tracked sales for the
region. Customer contract and proj ect 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' 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 competi ti ve 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 Utili ties 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
di visions
at OUC to be successful in the competi ti ve marketplace w~s 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
di visions in this department prepared for the competi ti ve 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
competitive marketplace.
Corporate Customer Service Consultant (October 1991 to November 1992)Texas Utili ties 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.
Competi tion 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 customersencompassing 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
posi tions on Edison Electric Institute and Electric Power ResearchInsti tute Committees.
Manager, Bonham Office (March 1979 to December 198
Texas Power & light Company, Bonham, Texas
Accountable for all operations, civic and community responsibilities
for Bonham and several surrounding towns for this investor ownedutili ty. Represented the Company before county and city officials, onci vic 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, 100employees 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, newservice, service expansion/extension , rates and demand side managementprograms.
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 proj ect 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
i\~-&I:
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Case No. IPC-04-
Exhibit 108
Idaho Power Company
2002 Integrated Resource Plan
SEE CASE FILE
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ii I~.. "'
Case No. IPC- E-04-
Exhibit 109
Idaho Power Company
January 30,2003
Annual Demand Side Management Report
SEE CASE FILE
- ..
_..m___...-
--.-.-- -- _- -
Demand-Side Management
at Idaho Power Company
A Business Plan 2003 - 2005
SEE CASE FILE
Case No. IPC- E-04-
Exhibit 110
."...'..,...,:... .
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~Cl
~~,;;-~~~_
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Idaho Power Company
Conservation Plan
April 15 2003
SEE CASE FILE
Case No. IPC- E-04-
Exhibit 111
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Case No. IPC- E-04-
Exhibit 112
Idaho PUC Order No. 28583
Idaho Power 2000
Electric Integrated Resource Plan
Office of the Secretary
Service Date
December 18, 2000
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE FILING BY IDAHO
POWER COMPANY OF ITS 2000 ELECTRIC
INTEGRATED RESOURCE PLAN (IRP)
CASE NO. IPC-00-
ORDER NO. 28583
On June 29, 2000, the Idaho Power Company (Idaho Power; Company) filed its 2000
Integrated Resource Plan (IRP) with the Idaho Public Utilities Commission. The Company
filing is pursuant to a biennial requirement established in Commission Order No. 22299, Case
No. U-1500-165. The IRP describes the Company s loads and resources, provides an overview
of technically available resource options including conservation and establishes a demonstrated
need for resources in 2004.
On August 3, 2000, the Commission issued a Notice of Filing in Case
No. IPC-OO-IO. The established deadline for filing written comments was August 23 , 2000.
Timely comments were filed by the Commission Staff. Late comments were filed by the
Northwest Energy Coalition and Idaho Rivers United, and Joachin Falkenhagen, one of the
Company shareholders. On October 10th the Company filed a limited response. The
comments can be summarized as follows:
Northwest Energy Coalition and United Rivers United (collectively, the Coalition)
In filed joint comments, it is recommended that the Company commitments set forth
in an August 7 letter to Comrtlission Staff be included in the Company s IRP as an addendum.
The Coalition expresses surprise, that at a time when wholesale power prices are at an all-time
high and extremely volatile, the Company s IRP is markedly supply-side oriented (focusing on
the need for peak resources) and virtually silent on the potential for demand-side measures
including load management, conservation and energy efficiency. The Coalition recommends
that the Company look to revitalizing its conservation programs because of the cost-effective
resource they provide to the utility and the economic and environmental benefits they provide to
the customers in the Company s service territory. Targeted conservation, particularly for
commercial and industrial customers, the Coalition notes, can help reduce peak demand and
1 A copy of the August 7 letter was filed by the Company in this case on November 8, 2000. The substance of the
letter is set out in our summary of Staff Comments below.
ORDER NO. 28583
EXHIBIT 112
CASE NO. IPC-04-
should be aggressively pursued by Idaho Power. The Coalition recommends the Company
explore aggressive load management and time-of-use rates to ensure system reliability and cost
effectiveness. The Coalition supports a tariff rider approach to recovery of DSM capital costs.
The Coalition takes issue with the Company s apparent discounting of the role
distributed renewable generation technologies can play in reducing distribution and transmission
constraints as well as meeting strategic load growth demands.
The Coalition recommends that Idaho Power continue to examine the increasing
competitiveness of non-hydro renewable resources as wind projects.
The Coalition notes that environmental considerations when selecting priority
resources in the IRP seem to be absent or minimal at best (i., brief discussion of emission cost
adder for natural gas SCCT and CCCT). No environmental assessment is made of non-fossil
fuel options or conservation and load management investments. While gas-fired combined cycle
combination turbines (CCCT) are the cleanest of the fossil fuel generating technologies, CO2
released by fossil fuel combustion, the Coalition states, is the largest single source contributing
to global warming, accounting up to one-half of the total. The Coalition recommends that the
IRP explicitly consider CO2 emissions and that the Company include in its evaluation criteria for
proposals, a power supply proposal plan for mitigating CO2 emissions. Such a mitigation plan
the Coalition contends, will have added value (economic benefits) to Idaho Power when the
Company sells surplus into the market or for off-system sales.
Idaho Power Reply
The Company s filed reply in this case addresses only the Coalition s comments.
Idaho Power stands by the commitments set forth in its August 7th letter to Staff, but contends
that it would be premature to revise its IRP to include the estimated inputs of the various
initiatives. The Company believes that its IRP process may provide additional data that would
also be of value.
Although the energy product requested in the Company s Request for Proposals
(RFP) is specifically described (250 MW of peaking capability), the Company believes that its
RFP process will assist in the evaluation of capacity and energy from smaller undertakings of the
nature usually endorsed by the Coalition. Other types of resources, such as future distributed
generation and demand-side initiatives, the Company states, could be brought on in smaller
increments to compliment the selected RFP resource addition.
ORDER NO. 28583
Commenting on its anticipated "Green" tariff filing, the Company states that it is
seeking a supply source (possibly, wind resources) that will be acceptable to the environmental
community .
Idaho Power states that it is not requiring CO2 offsets as part of its RFP evaluation.
These offsets, it states, are not a current legal requirement in Idaho. The Company considers
mandated CO offsets to be a public policy issue best addressed by the Commission in a separate
proceeding.
The Company appreciates the Coalition s comments pertaining to a tariff rider
mechanism for DSM recovery, noting that the Coalition has correctly identified a ratemaking
obstacle to utility-based DSM programs.
Joachin Falkenhagen
Mr. Falkenhagen, in comments filed with the Commission, notes his interest in wind
generation, details the comparative advantages of such a technology, and recommends that wind
power be considered as an option.
Commission Staff
Commission Staff in its comments summarizes the Company s IRP filing, notes that
it participated in the IRP development process and recommends that the Commission
acknowledge receipt of the Company s IRP filing.
Staff provided specific input regarding the Company s hydro relicensing efforts and
the potential effects of related protection, mitigation and enhancement (PM&E) measures. Staff
notes that the Company fails to assume any reduction in generation from its hydro facilities as a
consequence of relicensing.
Staff had expressed concern as to the vulnerability of Idaho Power to conditions
outside its own system, constraints that might prove critical in determining the Company
ability to import or exchange power seasonally. Examining such issue, the Company in its IRP
concludes that the most serious transition bottlenecks are within its own system, and not in
surrounding transmission sytems.
The Company in an IRP draft, Staff states, had identified purchases from the market
as a preferred strategy in meeting deficits in the near term as well as a partial response in meeting
deficits into the future. Staff expressed concern regarding the risks of relying on the market
noting the failure of the market to actually deliver power when needed. Staff believed that the
ORDER NO. 28583
Company s assumption that there would always be ample resources on the market at reasonable
prices and that they will be deliverable to Idaho needed to be better supported (e., assessment
of regional reserve margins; Company response to March 2000 NWPPC report on supply
adequacy/reliability; BPA white book analysis). The Company in its IRP does not provide the
assessment that Staff was looking for but simply points out that its preferred strategy of
acquiring new generation is an effort to decrease its reliance on market resources.
While the Company s IRP addresses electric transmission constraints, Staff notes
that it provides no information comparing the costs of building new transmission capacity to
other alternatives.
Staff expresses concern regarding potential constraints that could affect the ability of
a gas-fired generator to secure inadequate fuel supply when needed. The IRP does not address
this issue. Relevant information may be gleaned from responses to the Company s RFP.
Also of interest to the Staff, is how the Company would meet load under extremely
low water conditions and address related transmission constraints. Responding to this concern
the Company in its IRP states that it is able to reasonably plan to use short-term power purchases
to meet temporary water-related generation deficiencies on its own system because the Company
has summer-peaking requirements while other utilities in the Pacific region have winter-peaking
requirements.
Regarding demand-side management, Staff recommends that the Company explore
non-traditional" programs and measures, e.
a. Tariff provisions to allow customers to self-generate.b. Tariff provisions to encourage load shifting, such as time-of-day rates,
on-peak/off-peak rates, and market-based rates.
c. Voluntary curtailment or load reduction, prirharily by large commercial
and industrial customers. It may make more sense to offer interruptible
rates, or to compensate customers for voluntary curtailment than to
purchase power during peak-load periods. Large customers may
choose to shut down, either partially or fully, or install backup
generation.
In an August 7 letter to Staff, the Company commits to investigate a variety of demand-side
programs, I.e.
Issue an RFP by August 4 2000 seeking resource proposals for 2004.
ORDER NO. 28583
Prepare an analysis of the revenue requirement impact of the most attractive
proposal versus a regulated utility-built resource-December 2000
File an Application with the Commission for either the approval of the
contract resulting from the RFP or a Certificate of Public Convenience and
Necessity to have the utility build and ratebase the project-December
2000.
Perform and present a feasibility study on the near-term application of
mobile generators to provide not only additional power and energy but also
to provide reinforcement to the delivery system and potentially defer or
avoid capacity upgrades to delivery facilities-November 2000.
Submit time-of-use pricing proposals to better reflect costs to consumers
with the next general rate case or sooner.
Submit and discuss pro forma load management tariff/contracts that target
acquiring capacity from retail customers at a price reflective of market
conditions-November 2000.
Submit a "green" tariff filing to the Commission within the next 30 days.
Because of identified transmission constraints, Staff recommended that the Company
more fully explore distributed generation alternatives. Staff notes that the Company has
committed to perform a feasibility study investigating distributed generation options.
Staff supports the Company s proposal to issue an RFP (for 250 MW of new power
starting in 2004) and hopes that in addition to new generation, the Company will consider DSM
renewables, distributed generation, load management, and voluntary curtailment as well as other
alternatives.
coMMtsslbN FINDINGS
The Commission has reviewed the filings of record in Case No. IPC-OO-
including the Company s year 2000 Integrated Resource Plan and related comments and reply.
We find the Company s IRP contains the necessary information and is in the appropriate format
as directed by the Commission in Order Nos. 22299 and 27064.
We acknowledge the Company s power supply commitments as set forth in its
August 7 letter to Commission Staff and have every confidence that the Company will follow
through on its promises. To such end, we note the Company s green energy tariff filing in Case
No. IPC-00-18 and its recent Request for Proposals (RFP). It has been pointed out in
ORDER NO. 28583
comments however, that Idaho Power in recent years has reduced or eliminated nearly all of its
prior DSM programs. In fairness to the Company, there are other regulated electric companies in
the region that have done the same. The touted justification is that utilities must position
themselves to be competitive in a restructured electric industry. In place of company specific
programs, Idaho Power now participates in the Northwest Energy Efficiency Alliance (NEEA), a
regional approach to conservation whose goal is long term market transformation.
It is now early December 2000 and the Northwest region continues to experience
record high prices in the wholesale market. Voluntary conservation is encouraged to reduce the
extent of rate increases that will follow purchases at those high prices. For the region it is a wake
up call. Creative thinking and planning by utilities and customers may serve to reduce reliance
on market purchases to the benefit of both customers and stockholders. Idaho Power and its
customers are encouraged to take inventory and stock of available demand side management and
conservation opportunities so that rate increases can be mitigated.
Although commenting parties have requested changes, we find no reason to require
, .
formal amendment to the Company s Integrated Resource Plan. We accordingly fmd
reasonable to acknowledge and accept Idaho Power s year ~OOO IRP for filing.
CONCLUSIONS OF LAW
The Idaho Public Utilities Commission has jurisdiction over Idaho Power Company,
an electric utility company, pursuant to Title 61 of the Idaho Code and the Conilnission s Rules
: of Procedure, IDAPA 31.01.01.000 et seq.
ORDER
In consideration of the foregoing and as more particularly described above, IT IS
HEREBY DRDERED and the Idaho Public Utilities Commission does hereby acknowledge and
: accept for filing Idaho Power c;.ompany s year 2000 Integrated Resource Plan.
THIS IS A FINAL ORDER. Any person interested in this Order may petition for
reconsideration within twenty-one (21) days of the service date of this Order. Within seven (7)
days after any person has petit~on~~ for reconsideration, any other person may cross-petition for
reconsideration. See Idaho Code 9 61-626.
ORDER NO. 28583
DONE by Order of the Idaho Public Utilities Commission at Boise, Idaho this
day of December 2000.
DENNIS S. HANSEN, PRESIDENT
MARSHA H. SMITH, COMMISSIONER
PAUL KJELLANDER, COMMISSIONER
ATTEST:
Jean D. Jewell
Commission Secretary
vJdJO:IPC-OO-lO sw
ORDER NO. 28583
Case No. IPC-04-
Exhibit 113
Response to Interrogatory No.
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/rrll\, ~ '
" /,-,
Q fd I J 2000 Summer PeakStationPeak Demand MW
Bethel Court
Boise
Bular
CIoverdaIe
Eagle
Gary
Gowen
G rove
Hewlett Packard
Joplin
Locust Grove
Meridian
State
Ustick
VICtory
Wye
. ..
11.
79.
SO.
42.
33.
32.2
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 infonnation 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 '~ted at 1221 West Idaho Street commencing at
IDAHO POW ER caMP ANY'S SUPPLEMENTALO~C'n".. .,.,.,... ....."" ,...Inn.....
-- -. _. . _..
EXHIBIT 113
CASE NO. IPC-O4-
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Case No. IPC-04-
Exhibit 114
The 10- Year Transmission Plans
of the Treasure Valley, Buildout Projection
Distribution Planning 2002 - 2012
SEE CASE FILE
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Case No. IPC- E-04-
Exhibit 115
City of Eagle, Idaho, Underground Sub-Transmission Line
Alternative Assessment for the Proposed
Eagle-Star 138kV Sub-Transmission Line
prepared by Black Veatch Corporation
July 8, 2003
SEE CASE FILE
Case No. IPC-04-
Exhibit 116
Electric Transmission Week
April 7, 2003
ACSS/TW Conductor Operates at Higher Temperatures,
Delivers More Power Over Existing Transmission Corridors.
E L I C from the publisher of POWeR CaIL!:::ITl=laNSMISSICN
ACSS/TW conductor operates at higher temperatures,delivers more power over existing transmission corridors
f anything is certain in today the new construction involved in this cause it has very little strength, so
rapidly changing electric power approach is likely raise permitting is- it puts all the mechanical load on the
industry, it's. that increasing de- sues in many jurisdictions. steel. And now as you change the
mand for power and opposition to Another option that could provide temperature, you re really changing
the construction of new high-volt- some relief is using techniques such as the temperature of steel. The coef-
age transmission lines are forcing dynamic line rating (ETW, 12/23/2002). ficient of expansion of steel is very
utilities to find new ways to push Utilities are also increasingly look- slight - about half of what aluminum
more and more power through ing at new types of conductors to is - so the sag increases a whole
existing lines " EPRISolutions has replace the industry standard alumi- lot slower than it would if the alumi-stated. num conductor steel reinforced (ACSR) num were carrying a whole lot of
Utilities facing this situation cable. Several conductors, such as the mechanical load (as it does in the
have several options. For ex- 3M aluminum conductor composite re- ACSR conductor).
ample, they could install either inforced (ACCRi ETW 8/26/2002) and As a result, ACSS cable can op-
more conductors or larger conduc- conductors with advanced glass fiber erate at much higher temperaturetors on new structures. composite cores (ETW, 11/11/2002), than ACSR and therefore carry more
Besides being ex- are in relatively early stages of devel- current before it reaches its sag con-
pensive, opment or commercialization. tingency. Transmission operators
The aluminum conductor steel sup- generally limit ACSR to 100oC;
ported (ACSS) cable, on the other hand Southwire states that its ACSS can
has been widely available for more than be operated safely up to 250oC. The
a decade and has been used success- company further claims that the
fully by several utilities to improve maximum operating temperature of
power flows in existing transmission ACSS is limited only by the tempera-corridors. ture at which damage will occur to
Heat is the prime enemy of conduc- the coating of the steel core.
tors. The more power that is pushed Southwire says it uses a mischmetal
through them, the more they heat and coated core which has been tested
sag, and it is sag and clearance that up to 343OC.
ultimately determine maximum conduc- "Now take this a step furthertor loading. Ware continued. In the last eight
ACSS has slightly more conductiv- years or so companies such as
ity than ACSR, but the main advantage Southwire have begun to shape the
of ACSS is that its sag does not in- aluminum conductor wires into a
crease as much as ACSR does as trapezoidal shape. The conductor
temperature increases. Nick Ware takes on a more compact profile,
technical director for the energy divi- which helps with wind and ice load-
sion at Southwire, one of the major ings, Ware said. "Or, for a given
manufacturers of ACSS conductor, ex- diameter, I can get more metal in
plained the design features of ACSS that package - more conductor, car-
that allow it to operate at higher tem- rying more current on that right ofperatures: way," he added.
We have manufactured the cable Southwire states that an ACSS
with totally annealed aluminum wires; conductor of a given diameter us-
these aluminum wires are 'dead soft.ing trapezoidal wire (ACSS/TW) has
What that means to the mechanical 200/0 more conductor area
operation of the cable is when you try than an ACSR conductor
to put tensile stress on the cable, the of the same diameter. The
aluminum elongates very readily be- increase in conductor area
www.powerdaily.com
3 ATC continues fight for
Arrowhead-Weston line
8 4 JEA offiCial teils Senate SMD
could hamper SeTrans effort
85 Reliant, Tenaskaobjed to
Progress ' Energy transmission
tariff changes
8 6 ACS:,fTWconductordeliversmore power over existing
transmission corridors
Transmission rate incentives
sh6uld focus on outcomes, not
favorlargeinvestrTIE!nts
, "
DOEtelisFERC
9 Virginia defehdsRTO law;
more parties enter dispute
8 10 NY..ISO questions cost
Cilliocation of Cross Sound
reassignment plan
8 11 Hydro-Quebec wants New
England to resolve inter-
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,.
ellerg~r6'ublication
Monday April 2003
----
Copyright 2003 - /0 Energy LLCEXHIBIT 116
CASE NO. IPC-O4-
(f)
Monday April 2003
TRaNSMISSION
- --
ACSS offers higher temp rating
...
from p.
combined with the ability to operate need to replace or modify existing
at a higher temperature means that transmission structures, so with a
an ACSS/TW conductor provides relatively small investment, "it's not
double the ampacity of an ACSR con- uncommon to be able to double the
ductor of the same diameter with capacity of a right of way by putting
both operating at their maximum (ACSS/TW) in," Ware said.temperature. Or, he continued, "If you need
These characteristics make to replace the structures anyway,
ACSS/TW an attractive option for with only a little more investment you
reconductoring, Southwire believes. can double or triple the capacity of
With ACSS/TW there is generally no the corridor" with ACSS/TW.
Use of ACSSrrw provides CenterPoint
with increased ampacity and major savings
ouston utility CenterPoint En- structures. "Right off the bat
ergy (formerly Reliant Energy saw a $26 million saving on the first
and before that Houston Light and project," Bennett remarked.
Power) is a satisfied Southwire Since that first project, Center-
ACSS/TW customer. At the end of the Point has upgraded over 1,200 miles
1990s, the utility was faced with the of circuits. "Bottom line is, we
need to make major improvements saved over $100 million," Bennett
to its transmission system to relieve said. "ve upgraded one-third of
transmission constraints identified our system and there are no con-by ERCOT. straints identified on our system
The upgrades, mainly to accom- now.
modate merchant power plants CenterPoint was the first utility
involved about a third of the utility'to use Southwire s ACSS/TW at 345
500 miles of 69 kV, 138 kV and 345 kv. The company wasn t sure about
kV lines. "We were faced with about the electrical characteristics of the
$500 million worth of upgrade cable at the higher voltage , so it had
projects in the next three to five it tested at the EPRISolutions test
years," CenterPoint Manager of facilities at Lenox, Mass., and
Transmission Engineering Chuck Haslet, Texas.
Bennett said, based on the need to This testing satisfied concerns
replace structures and put up new over the cable, but raised the issuewire. that cable fittings currently are not
However, CenterPoint decided certified to operate at ACSS/TW'
to tackle the first project using 250oC maximum temperature. Con-
ACSS/TW wire. The company re- sequently, CenterPoint has rated
placed a 2-conductor ACSR with a its ACSS/TW lines at 180oC.
3-circuit ACSS/TW. Not only did the Bennett also said that Center-
use of ACSS/TW dramatically lower Point is working with ANSI
the cost of the project - $8 million develop new standards for high-
instead of the estimated $33 million temperature fittings and with Oak
cost of replacing all the structures Ridge National Laboratory to test fit-
and stringing new ACSR - but the tings to 250oC. In addition, the
capacity on the line was tripled company has agreed to submit itsBennett said. ACSS/TW cables to extensive field
The reconductoring required testing as part of EPRI's High Tem-
only minor modifications on the tow- perature Low Sag conductor
ers and beefing-up some dead end initiative (ETW, 11/11/2002).
Copyright 2003 10 Energy LLC
Ware said that ACSS/TW con-
ductor can be installed using
standard cable accessories and
standard "good stringing practices.
Some additional care needs to be
taken to protect the soft aluminum
wires during installation such as us-
ing a lined stringing block. Longer
dead ends and splices are also used
in light of the high temperature op-
eration.
ACSS/TW is a more expensive
product than ACSR; Ware said it has
a price premium of 150/0-25%. Given
its performance advantages, espe-
cially in the reconductoring arena,
many utilities are likely to find
ACSS/TW an eco-
nomic choice.
Case No. IPC- E-04-
Exhibit 117
Innovations with EPRI Technology
June 2001
Use of ACSS Cable and Hardware
znnovatorsE P R
.....
e t= 121
..
~SOLUTIONS
Creative Testing at EPRlsolutions Lenox Test Center Verifies
a Novel Use of ACSS Cable and Hardware-Saves Reliant
Energy $25 million in Construction Costs
EPRIsolutions
Stringing Suwannee ACSSfTW cable at the EPRlsolutions test facility in Lenox, MA.
Benefits
. Reliant Energy s decision to use
ACSS/TW cable to more than
double the capacity of two
345 kV transmission lines will
save the utility at least $25 mil-
lion in construction costs.
. Reliant Energy plans to upgrade
more than a third of its trans-
mission system, replacing a large
percentage of its old Drake con-
ductor with new ACSS conductor.
The company anticipates this will
result in an additional $80 million
in savings in construction costs.
. EPRIsolutions innovative
approach to cable testing not
only confirmed that Reliant
assumptions were correct but also
that the testing could be done
quickly and at a reasonable cost.
JUNE 2001
Problem
When Reliant Energy needed to double
the capacity of tWO 345 kV transmission
lines, it had two choices. The conventional,
but very costly, approach was to rebuild
the lines with new structUres and replace
the existing ACSR conductors (aluminum
conductor steel reinforced) with larger
diameter conductors of the same type. An
alternative, and far more economical, solu-
tion involved an unusual choice of conduc-
tor, the Suwannee ACSS/TW (aluminum
conductor steel supponedJrrapezoidal wire).
Constructed of pre-annealed, trapezoidal
aluminum strands loosely laid over a steel
core, this cable would be installed in three-
conductor bundles and operated at a much
higher temperatUre than the existing ACSR
conductors. Most importantly, Reliant
would be able to more than double the
capacity of each circuit with only limited
modifications to its structures.
We needed to know
whether our choice of the
Suwannee conductor was
the right one. . . and
EPRlsolutions proved that
was, both quickly and at a
reasonable cost."
. Douglas Harms
Project Manager
Reliant Energy
With the potential for saving more than
$25 million, Reliant Energy decided to
take the alternative approach, but the
utility needed to consider a number of
issues, including whether the radio noise
(RN) and audible noise (AN) of the
ACSS/TW cable would be acceptable.
Reliant turned to EPRIsolutions for the
necessary testing and provided the benefits
listed in this document.
Innovations
EPRIsolutions' Centers and Reliant Energy
tested a novel use of ACSS cable and
hardware at high temperatUre and proved
that it can substantially increase line capac-
ity while keeping corona-generated radio
noise and audible noise within acceptable
limits.
Reliant s decision to upgrade its 345 kV
lines with Suwannee ACSS/TW cable was
a key innovation; EPRIsolutions' approach
to testing that cable was another.
1006134
EXHIBIT 117
CASE NO. IPC-O4-
First, because the upgraded lines would
generally operate at 180oC, and occasionally
at 200oC, Reliant requested that
EPRIsolutions make corona-generated radio
and audible noise measurements at similar
temperatUres. But EPRIsolutions Project
Manager George Gela determined that to
perform the tests at full current (2,000 A)
and full line voltage on a three-conductor
bundle, EPRIsolutions would need to sup-
ply 1254 MW of active power, enough to
supply a small town. To determine conduc-
tor perfOrmance in a more cost-effective
way, EPRIsolutions separated the phenom-
ena that would likely result from high
temperature operation and considered them
individually.
EPRIsolutions sent the Suwannee con-
ductor to its Haslet, TX. Test Center for
preconditioning. There, the conductor was
stressed up to 18,000 lbs. at a temperatUre
of 250oC and subjected to rain to simulate
operating conditions. This enabled
EPRIsolutions to: (1) determine the rates at
which the conductor expands when heated
and cools when wet, (2) measure AN pro-
duced by rain falling on the hot conductor,
(3) analyze the tendency of the conductor
to bird-cage, and (4) determine the conduc-
tors breaking strength.
Conductor bird-caging. which can result
from high-temperatUre operation, is one of
the phenomena that Reliant wanted to test.
It occurs when a conductors temperatUre is
elevated and the aluminum strands expand
more than the steel strands at its core. On
ACSR conductors the aluminum strands
pop," or protrude, beyond the normal
profile of the conductor, simulating a bird
cage (top photo), which potentially
increases the intensity of corona activities.
The preconditioning tests on ACSS/TW
conductor in Haslet produced minor con-
ductor bird-caging near the compression
end fittings (bottom photo), which pre-
vented the pre-annealed aluminum strands
from moving. Elsewhere along the conduc-
tor no bird-caging was evident.
EPRIsolutions' analysis noted that
because bird-caging is a function of temper-
atUre and is not related to the operating
voltage or the number of conductors in a
bundle, the source of conductor heating is
not important. Based on this, the Lenox
Test Center was able to test for corona
effects by heating the conductor for an
hour with a current of 900 - 1400 A, then
rapidly cutting off the current and applying
the operating voltage of 345 kV, and then
measuring AN and RN produced by
corona. The preconditioning tests in Haslet,
TX., determined the time available for
measuring AN and RI after the current was
discontinued.
Significant bird-caging of Drake conductor (top). Bird-caging of ACSS/TW conductor (bottom)
near an end fitting after testing at the EPRlsoludons Test Center in Haslet, TX.
EPRlsolutlons 8 3412 Hlllview Avenue. Palo Alto. California 94304
O. Box 10414. Palo Alto. California 94303 USA
800.313.3774 8 650.855.2121 8 askeprl~eprl.com . www.epri.com
Using this input, EPRIsolutions measured
AN and RI values for the Suwannee con-
ductor and found them well within the
applicable limits.
Industry Impact
If anything is certain in today s rapidly
changing electric power industry, it s that
increasing demand for power and opposition
to the construction of new high-voltage
transmission lines are forcing utilities to find
ways to push. more and more power through
existing lines. A5 such, the innovations by
Reliant and EPRIsolutions are being dis-
cussed widely throughoUt the industry. In
fact, several utilities may soon take advan-
tage of the benefits identified in these tests
and install ACSS type cable to increase
power flows over their transmission corri-
dors.
For further information, contact:
EPRIsolutions
O. Box 10414
Palo Alto, CA 94303
[phone]
[phone] (International)
George Gela
EPRIsolutions Engineering and Test Center
Lenox, Massachusetts
[phone]
Email: geogela~eprisolutions.com
Mark Ostendorp
EPRisolutions Engineering and Test Center
Haslet, Texas
[phone]
Email: mostendo~eprisolUtions.com
Products are available from EPRI Customer
Service at 1-800-313-3774 (press 2).
Interest Categories
. Overhead Transmission
. Distribution Systems
About EPRlsolutions
EPRlsolutions. a wholly-owned subsidiary of EPR~ pro-
vides R&D. technology applications services. consulting
services. field test evaluations. and privately-sponsored Ini-
tiatives to the power Industry. Its areas of focus Include
power generation. transmission and distribution. end use
technologies. market assessment and communications.
facility maintenance programs. operator training. and
online monitoring systems. EPRlsolutions offers a wide
range of technical support to expand and enhance EPRI'
overall science and technology program.
~ 200 I EPRlsolutlons. Inc. All rights reserved. EPRI and
EPRlsolutlons are registered service marks of the Electric
Power Research Institute, Ine.
Printed on recycled poper in the United States of America
Case No. IPC-04-
Exhibit 118
ACSS/TW - An Improved Conductor for
Upgrading Existing Lines or New Construction
by F.R. Thrash, Jr.
ACSSITW - An Improved Conductor for
Upgrading Existing Lines or New Construction
F. R. Thrash, Jr., Member, IEEE
Southwire Company
eurollton, GA 30119
Abstract: This paper describes the properties and performance
characteristics of an improved overhead conductor ACSsrrw.
ACSSfrW is constructed of fully annealed alwninum wires fonnedinto a trapezoidal shape. The aluminum wires are stranded around a
steel core of seven or more wires' as described in ASTM 8-857. The
improved conductor can operate continuously at temperatures up to
2S0o without loss of strength; its sag is less thap that of
conventional composite conductors; final sags are not affected by
creep; it has excellent self.wunping characteristics. ACSsrrw canbe designed with both equal area or equal diameter, compared to
conventional round stranded conductors. to optimize line design
options.
Keywords: Overhead Conductors, Sag, Reconductoring, Uprating,
Upgrading, Transmission Lines, Distribution Lines, SSAC, ACSS
I. INTRODUcnON
The electric utility industry is undergoing a changing
competitive environment These changes are affecting how
electricity is generated, transmitted and sold throughout the
US. and North America. Deregulation of the electric power
industry mCAn~more than just new business models and
acronyms. Utilities face an abundance of technical hurdles to
maintain a competitive and reliable power systenL Not theleast of thC$e is the transmiqion and distribution
infrastructure. Most agree that the nation s transmission
capacity has reached or is nearing the critical limit. Theadditional power transactions that deregulation will bring
may be more than the existing system can reliably handle.
Because of the increased uncertainty in future electrica1loads
. a competitive deregulated environment, utilities are less
willing to make large investments. Increasing competition is
requiring them to squeeze as much capacity as possible from
the existing lines. As these lines become overloaded the
thermal limit of the conductor is exceeded causing loss of
strength in the conductor and sags exceeding predicted limits.
Reviewing the needs of the utility industry, it becameapparent that the existing conductor designs had definite
limitations. A review of the design elements of existing
conductors provides options for the development of an
improved conductor design.
Annea1ed Aluminum Strand:
One design option originated with a conductor developed in
the early 1970's, fonnally known as SSAC, using fully
annealed aluminum wires (1). This conductor is presently
referred to as ACSS (5). The steel core provided the entire
support for the conductor. The abnnin'Im wires contribute
virtually no mechanical strength to the conductor. Operating
temperature is limited not by the aluminum but by the
galvanized coating on the steel COlc.
Galfan!!! Coated Steel Core
new coating for steel was developed as a suitable
replacement for galvanized coatings on steel core wire in the
late 1980's. The coating, identified as a zinc-S% aluminum-
mischmetal alloy, provides increased corrosion resistance and
improved thermal stability. ASTM standards B-802 and B-
803 were developed in 1989 defuring the requirements of
core wire using the new coating.
Trapezoidal Shaped Aluminum Wires:
In the early to mid 1980's a conductor construction was
introduced replacing the round wires in conventional
stranded conductors with trapezoidal shaped wires. Replacing
the round wires with wires of a trapezoidal shape created amore compact conductor of equal metal area having a smaller
overall diameter and less void space at the strand interstices.
The smaller conductor diameter reduced ice and windloading on the conductor. The shaped wire conductor has a
lower drag coefficient, increased resistance to vibration and
EXHIBIT 118
CASE NO. IPC-O4-
... ......-......-........""""-............-....-.....-.......--....
improved fatigue resistance. A second construction was
introduced with equal diameters to that of conventional
stranded conductors. The equal diameter design provides a
conductor with all the advantages of the equal area design,
but with increased aluminum area. With only a modest
increase in weight, the cable exhibits reduced resistance
increased current carrying capacity, and increased strength.
A shaped wire compact concentric-lay-stranded aluminum
conductor, steel supported, ACSSrrw, was developed. This
conductor combines the concept of fully annealed aluminum
wires, in a trapezoidal shape, concentric-lay-stranded around
a Galfan coated steel core. The conductor is available in
conductor constructions of both equal area and equal
diameter designs. Some of the performance advantages
e~oited by this new conductor construction:
ACSsrrw can operate continuously at temperatures
up to 2500 without any detriment to mechanical
properties.
ACSsrrw will sag significantly less at high
temperatures than other conductors when the installed
tensions under ice and wind loading are approximately
the same.
The final sag of ACSsrrw is not affected by long term
creep in the aluminum.
ACSsrrw has improved self damping characteristics
and exluoits a high degree of resistance to vibration
fatigue.
The aluminum wires of the ACSsrrw conductor have
an increased conductivity of 63% lACS.
The Galfan coated core provides improved corrosion
resistance and thermal stability.
lli. DISCUSSION OF CONDUCTOR PROPERTIES
ASTM Standard B-857 "Shaped Wire Compact Concentric-
Lay-Stranded Aluminum Conductors, Coated-Steel
Supported (ACSSllW)" defmcs the basic conductor
properties and construction requirements for ACSsrrw. A
more in depth discussion of these properties is presented
here.
j Annealed Aluminum Strand:
ACSsrrw, develops most of it's performance advantages
from the fact that the aluminum wires are fully annealed
during the manufacturing process and have very low yield
strength (1). Because of the low yield strength, rapid
permanent or inelastic elongation occurs in the aluminum
when tension is applied to the composite conductor
transferring the load to the steel core. The trapezoidal shape
has no effect on the ductility of the aluminum in the fully
annealed, "0" temper. Typical properties of the shaped
ACSS aluminum as compared to conventional hard drawn,
1350 aluminum, are listed in TABLE
TABLE
Typical Properties of
Annealed ACSS Aluminum Wires VS. HD Aluminum Wires
Property ACSS Hard Draw'
Aluminum Aluminum
T~nsile Str., Mill, Avg., ksi 5 . 11.0.23.5 - 29.
( MPa)($9 - 76)(160.0 - 200.
Elongation in 10 in., Min.
, %
20 - 30 2 to 2.
Conductivity, Min., % lACS 63 **61.2
'" 8.5 - 14 ksi (59 - 76 MPa) required by ASTM.
"'* 61.8% lACS minimum conductivity required by ASTM.
QEJfan!!! Coated Steel Core Wire
The maximum operating temperature of ACSSffW
conductor is limited only by the temperature at which
damage will occur to the coating on the steel core.
Conventional galvanized coatings deteriorate rapidly at
temperatures above 24SoC. Galfan coated steel core exh1oits
improved thermal stability and corrosion resistance over
galvanized core wire. Samples of the class "An Galfan coated
core were exposed to temperatures up to 343OC (6500P) for
32 hours without physical damage to the coating. Samples of
the core wire, aged for 32 hours, were also subjected to a Salt
Spray Corrosion test performed in accordance with ASTM B-
117. Results indicate that after aging for 32 hours at 343O
(6500P), the time to formation of red rust was in excess of
three times (3x) that required for standard class "Au zinc
galvanized core wire. Results of the corrosion test are
indicated in. TABLE 2 below.
Rated Strength
The rated strength of ACSSrrw is calculated using the
aggregate tensile strengths of the aluminum and steel
components (5). The strength is based on 96% of the
aggregate strengths of the equivalent round aluminum wires
at a minimum average tensile strength of 8.5 ksi (59 MPa)
and the m;n;mum average tensile strength for the core wire
as specified by ASTM. Because the elongation of the fully
annealed alUminum wires is several times that of the steel
core wire, the full rated strength of the steel may be utilized.
The rated strength of ACSSffW is primarily dependent upon
the grade and content of steel core wire and may be less than
conventional ACSR of the same area and/or diameter.
TABLE 3 gives a comparison for a series orarea and/or
$a1t S
Sample
1019
.285 .
, ,
s:t
' ;
.)94
. ~,
TABLE
Strength Comparison
ACSR v!;. ACSS/TW Constructions
AC'SR ACSR ACSSrrW ACSSrrW
Construction Strength Eq. Area Eq. Dia.
Ibs. (kg)Ibs. (kg)IDs. (kg)
477 kcrnil 500 15,600 18,400
26n SIr.(8,845)(7,076)(8.346)
795 kcrnil 31,500 25,900 30.700
26/7 Sir.(14.288)(11:7'18)(13,925)
""'."
500054 kcmil 25.900 16.700
45/7 SIr.(i 1.748)575)(9.299)
954 kcmi I 33,800 26,000 100
54/7 sir.( 15.33 I )(11,793)(14 LO7)
1272 kcrni!600 100 4 I ,2.00
54/1 t) Sir.(19 777)(15,468)(l8 688)
1590 kemit 200 27.900 300
45/7 Str,(19.142)(IUj)5)(1 5,558)
diameter equivalent ACSsrrw constructions as compared to
standard 795 kenail ( 402.
~)
ACSR constructions.
The strandings of ACSStrW are defined in terms of Type
numbers like ACSRIrW. The Type number indicates the
steel to aluminum area ratio in percent, i.e., a Type 16
indicates 16% steel area ratio, the same steel area ratio
contained in a 26n stranding for conventional ACSR. A
listing of Type vs. stranding is given in TABLE 4 below.
High temperature Capabaity~
The maximum continuous operating temperature for
ACSSITW conductors is 250oC. Because the alwninum wiresare fully annealed. the conductor can operate at this
temperature continuously with no loss of strength. The
Galfan coating on the steel core wire experiences no adverse
effects until exposed to temperatures well above the
suggested maximum operating temperature of 250o
Current Carrying Capacity
The maximum continuous operating temperature normally
observed for conventional conductors is 75a with a
maximum emergency overload temperature of lOOo
Typically when lines arc designed the conductor size is
determined, not only for the daily load to be transmitted, but
. '
TABLE 4
CoqI8riIon or ACSSITW Type Numbcn with
uivalont SlrIndin or ACSR.
ACSSITW Type ConventionalNumber ACSR Slnndifl.&
, "
3 t
, .
4211
(.. '
1111T ; 4SI7
a,. 84119
10' . 221113
:"
13 54/19, U 241716 . 1.617
. .. '
also to allow increased emergency loads for a contingency
ratings. With ACSSITW more emphasis can be placed on
present and projected growth loads rather than emergency
contingency loads. Also, when reconductoring a line, the
increased current carrying capacity combined with reduced
sag at higher operating temperatures can increase the tine
overload current capacity by up to 50%, without reducing
required clearances.
As seen in TABLE 5 below, the current carrying capacity of
SuwanneelACSSITW, the diameter equivalent of 795 kcmil
(402.9 DUI12) - 26/7 ACSR "Drake", is 2000 amps at 2S0oC.
This is double the current carrying capacity of standard 795
kcmil (402.9 maa2) - 26/7 ACSR at IOOo
Self-Damping C1uuacterlstic:
Conventional types of conductors inherently have some
degree of capability for damping aeolian vibration (1). The
degree of resistance to aeolian vibration is dependent upon
many factors, including metal temper. strand configuration,
conductor construction, internal friction, etc. Lower radial
compressive forces between conductor strand layers leads to
increased strand movement and higher self damping
capability. ACSsrrw exhibits lower compressive forces
between the aluminum strand layers and the steel core than
conventional ACSR because of the increased ductility of the
aluminum in the fully annealed state. When stressed, the
aluminum elongates and transfers all the tensile load to the
steel COte. This increases the self-dampini capability of the
ACSsrrw conductor construction well beyond that of
conventional conductors.
To verify that ACSSITW exhibited improved self-damping
properties, a series of self damping tests were performed. The
test consisted of four constructions of 795 (402.
kcmil-2617 ACSR equivalent conductors. The four
conductors, each having Galfan steel core, were
conventional ACS~ ACSRITW. ACSS and ACSSITW.
The conductOr wu tested at 151" 20~ and 30~ of its Rated
Tensile Strength (RTS). Upon completion of die 30~ level,
the conductor was loaded to SO ~ RTS and held for one hour.
The conductors were tested again at fina1 stress levels of 30 ~ .
TABLES
Cum:nt Canying Capacity8
795 kcmil (402.9ft1mI). 2617 ACSR '"Drake"
VI.
ACSSlTW ConductOl'l or Equal Area A DiameterConductor Standard ACSSITW ACSSITW
Temp. II(; 795 ACSR Equal Area Equal OD75 730 720 820100 990 980 I 110150 1320 1490200 1560 1770250 1740 2000
.Ampacities calculated lSSuminl an ambient temperature or 4Qo
61 mfsee wind, sua, .S coemc:icnt or emissivity and absomlivitv
The conductors were tested using the "Inverse Standing Wave 3 SO
Ratio" (lSWR) test method. The antinode displacement I 5 300 .
(double) amplitudes seIecred for !be test were 33/f (100"'/..).
! ~ ",. .
67ff (2(XJM'f.J. and WOlf (300""/.J. These values :
~ ~
200
correspond to 0.5, 1.0, and 1.5 times the fatigue limits for i i5 ISO .
a1umiDum, respectively. I ~ w
~ ./.
A minimwn of five different modes (loop lengths) per tension
c..
0 !._qq
..--.._
level were tested for each conductor. Modes 4. 8. 12. 16. and 10 I
Freq ~nC;(Hz) 30 3S
20 were chosen since they were within the ranges of the
frequencies and wind speeds classified as causing aeolian
!q..
vibrations on overhead conductors.
20~. and 15~ RTS.
Comparison of the data indicate that the ACSS and ACSSnw
constructions have a higher degree of self-damping capabilities
compared to the ACSR and ACSR.ITW constructions. With
respect to the conductors in their initial states, all four
constructions possess relatively similar dampingcharacteristi~ below 20 Hertz. The power dissipated by each
conductor is generally very low-often less than SOmW. The
power dissipation typically increases by as much as two to
four times on average at 20 Hertz and higher for the ACSS
and ACSSrrw constructions compared to the ACSR and
ACSRffW constructions.
-----~"
400 .
67 If ~ 20% RTS - Initial
-15
! -,-ACSSITW ---+-ACSS -.-ACSRTW ~ACSR 1...
__.--..-...--------------....-...-...-.-............ .q _... .q-----_.......q......_.:=-.......
~iJ---"-----
_._- ------_..---_.,... ,
IO!)OO ,
s::: 1000 i::I IU
"- ! .~ ~
100 l.. is E.
0..
. -.. q"q._...... q.' .._._....
10 15 20 25 30 .15 40 45 !
Frequency (Hz)
~~~~rfW~A
~~~~~,,:~~'~--
~~CS
(1)')'
--"" ..- ",....-.-,,-"- ,,-" -----.-.......;
The damping performance of the four constmctions varied
considerably after stretching the conductors to their final
states. The power dissipated by the ACSS and ACSSrrw
constructions compared to the ACSR and ACSRITW
constructions increases by as much as 5-20 times throughoutthe entire frequency spectrum. 8.Sag- Tension PerformtlllCe
Fig. 1 shows the power dissipation characteristic for all four
conductor constructions at a tension of 20% Rated Breaking
Strength (RBS) and an antinode displacement of 67ff
(200""/.). Fig. l(a) shows the power dissipation without
prestressing (initial) and Fig. l(b) after prestressing to 5()o~
RBS (fmal).
Long Term Creep
Conventional conductors experience permanent elongation,
long term creept due to the high tensile stresses in the
aluminum strands. Creep is not a factor in ACSsrrw
conductors. In service, all stress in the aluminum is rapidly
transferred to the steel core under operating conditions.
Therefore, creep of the aluminum does not affect the final
sags of ACSsrrw conductors. The long term creep rate of
steel is very small and can be neglected for the normal
allowable operating stresses.
Fig. 1 Power Dissipation Characteristic
Sag and tension for ACSsrrw can be generated using the
stress-strain characteristics for standard ACSS conductors
with a stranding equivalent to the Type classification for the
ACSsrrw conductors.
When tension is applied to the ACSsrrw conductor
permanent elongation of the aluminum wires occurs rapidly.
A1J the aluminum stretch~ the tensile load is transferred to
the steel. Once stressed in service or prestressed at time of
installation, the sag of the conductor is only dependent upon
the changing length of the steel with temperature. The
coefficient of thermal expansion for steel is 11.5 x 10" ?C.This is approximately half that of conventional ACSR
conductors. Therefore, the sag of ACSsrrw conductors is
much less than that of ACSR. TABLE 6 shows a comparison
in sags of 795 (402.9 mm:t) kcmil 26fl ACSR "Drake" and
equivalent diameter 565.kcmil (286.5 mm ) Type-
Suwannccl ACSS/TW" when installed to the same final sags
at 15OC (600F).
TABLE 6
Designing with lower Thermal Elongation of ACSS/TW
Conductor Drake SlI\V3nnee Ampacily
Temp. o ACSR ACSSrrW
Sag- ft Sag - fI
3 \.0 3\.0 On..
100 37.35.990/1110
150
---..
37.1490
Final sags based 1000 foot (305 meter) span.
Ampacitics based on 4O.C ambient. .61 mIw; wind. sun.
IV. LINE UPORAOE EXAMPLE
ACSsrrw conductors provide the transmission engineer with
more design options than any other conductor. One example
of reconductoring using ACSsrrw conductors is presented
below.
Example:
The line to be upgraded is a 138 kV transmission line
installed on light duty wood pole H-frame construction. No
cross-braces between poles or knee braces for cross-armswere installed. The wood pole structures are in good
condition although the line bas been in service between 30
and 40 years. The line was constructed with 477 kcmil (241.
mm2
) -
26n ACSR "Hawk" at a maximum NBSC heavy
loaded tension of7350 lb. (3334 kg). The average mIing spanwas 600 feet At the maximum conductor temperature of
lOoo the sag is 15.feet (4.85 meters). Rated current
carrying capacity of the conductor is 710 amps at the l00o
thermallUnit
Requirement:
Increase thermal capacity by at least 30%, without exceeding
the maximum sag clearance of 15.feet (4.85 meters).Upgrade must be completed with absolute minimum capitalinvestment
Considerations
Two alternatives are considered for the upgrade. One isconventional 795 kcmil (402.9 mm2
) -
26n Drake" ACSRconductor, with a current carrying capacity of 990 at l00oA second alternative is a 565.3 kcmil (286.5 man2) Type-
CalumetlACSS/rW", diameter equivalent to the existing
477 kcmil (241.7 mm2) ACSR. The CalumetlACSSIIW has a
current carrying capacity of 790 amps at l00oC and 1160 at
175OC. TABLE 7 shows a comparison of the conductors.
Option J
If conventional 795 kcmil (402.mm2
)-
26fT ~rake" ACSRis used for the reconductoring, the maximum conductor
tension under loaded conditions must be increased to 11,050
lb. (5012 kg) to maintain the maximum sag of 15.3 it. (4.
meters). Therefore, the maximum tension on the angle and
dead-end structures will increase by approximately 50%. The
suspension structure and foundation transverse loads will
increase by approximately 30%. This increase in tension will
require the strain structures to be replaced or reinforced with
cross bracing for the H-frame structures and knee bracing for
the cross arms. Most suspension structures will also need to
be reinforced or replaced The current carrying capacity of
the Drake ACSR is 990 amps at 100GC, a 39% increase.
Option
lfthe 565.3 kcmil (286.5 mm2) Type-16 CaiumetlACSSIfW
conductor is selected, it can be installed at the same ice and
wind loaded tension as the original Hawk conductor. It canalso be installed to the same sag as the Hawk ACSR but the
15.3 feet (4.85 meters) of sag now OCCUR at a conductor
temperature of 180oC. No' reinforcement is required for the
strain or suspension structures. The ampacity of the
CalumetlACSsrrw at 180o is 1200 amps. This is an
iricrease of 10% in current carrying capacity. More than two
(2) times the initial upgrade requirement for current increase
has been achieved with no structure modifications and no
increase in sag.
A comparison of the current carrying capacity versus the
temperature and sag for the conductors considered is shown
in Fig. 2. The shaded bars represent the current carryingcapacity of the conductors at the reference temperatures and
the lines indicate the comparative conductor sag ' VI.
temperature.
""11(1
11':90
J)Olli,
gIMO:
D;on:.
;,c..~rt
11MI'
. D
=== ==
.81, oI'dte 795 kcmil (401.9 mrna). 26/7 ACSR "0IU0" is buod on. 50% IIIcn8ioa Ih8D - 477 kc:mil (241.7 mm') - 26/7 ACSR "Hawk"
Flg.1 Ampacity and Sag Ys. Temperature
. :,,",,.,,' "
" fl.;,"'3 A ..; :
'" '
r'=~'"
:' ",' ,
Ltn..t;Jpgrad~An~t~::;:"="'='~~ '
. "
j AmpaGity"vs~,C:onductQf;&ltfuctur&;eos:t
40:
1$p:'
00:
! &I *:sm~cr , 'f
llt%COOO(J)J i
%AMP'$"
();"
~1!J!i!a~ :iJ~
, """'.:.".~- ~... ...."...._..~.~,..._." ,...."" ,
ow. ..",..
..' .." ".
Fig. 3 Line Upgrade Analysis
Using 795 kcmil (402.9 mm ) ACSR "Drake" as the
benchmark for conductor cost and referencing the original
471'kcmil "Hawk.. ACSR as the benchmark for line upgrade.the comparative cost are summarized in Fig.
Reconductoring with 565.3 kcmil (286.D11If) Type 6
Suwanne~ ACSSffW'\ saved the total cost of structure
modifications. reduced conductor cost by 20% and increased
the contingency current carrying capacity by 7OG".
V. CONCLUSIONS
ACSsrrw is a new conductor which provides increased
design options to an engineer when upgrading existing lines
or designing new lines. Some of the options are:
ACSsrrw can operate continuously at temperatures
up to 250o without any detriment to mechanical
properties.
ACSsrrw will sag significantly less at high
temperatures than other conductors when the installed
tensions under ice and wind loading are approximately
the same.
The fmal sag of ACSsrrw is not affected by long tern
creep in the aluminum.
ACSsrrw has improved self damping characteristics
and exhibits a high degree of resistance to vibration
fatigue.
The aluminum wires of the ACSSrrw conductor have
an increased conductivity of 63% IACS.
The Galfan coated core provides improved corrosion
resistance and thermal stability.
ACSsrrw is available in conductor constructions of
both equal area and equal diameter to optimize line
design options.
VI. ACKNOWLEDGEMENTS
The author greatly acknowledges the help and support of
colleagues in Wire Cable Technology and the Cofer
Technology Center for their help in writing this paper.
VB. RBFBRBNCES
it H. W. Adams. "Steel Supported Aluminum Conductor (SSAC)"'r
Overbead Tl'lnlmission Lines . IEEE Transaction on Power
Apparatus and Systeml, vol. PAS~3, No.5, SeptJOct1974. pp.1700-
1705.
H. w. Adams. and J.N. Ware, "Steel ,..pportcd Aluminum
Conductor'", White Paper, Reynolds Metal Co.
.J;)~William B. Zollars, "Aluminum Conductor Elevated Temperature
Considerations" ALCOA Conductor Products Company, white paper.
4..)W. B. lollars. "New Trapezoidal Wire Designs for New Consb'Uction
and Reconductoring . ALCOA Conductor Products Company white
paper, Presented at Pacific Coast Electrical Association Engineering
and Operatina Conference, M8~h 19-20, 1985, Los Angeles, CA
1997 ASTM Annual Book of Standards, vol. 02.03, ASTM 8-8S7Standard Specification for Shaped Wire Compact Concentric~Lay-Stranded Aluminum Conductors, Coated-Steel Supported(ACSSITW)"
R. Thrash, G. Hudson. D. Cooper. O. Sanders, "Overhead Conductor
Manual", Southwire Company, 1994
vm. BIOGRAPHY
Frank R. Thrash, Jr. (M'70) received his
BEE degree in electrical engineering from
Auburn University, AL. He is Chief
Engineer for overhead conductors in
Southwire Company s Wire and Cable
Technology Group. A 29-year veteran of
the wire and cable industry, his experience
is focuscd in the areas of product design.
application, and installation for both
insulated and bare electrical conductors.
Presently, he functions as a Staff Specialist
for overhead conductors and provides input
and guidance for Soulhwire s new product development, customer technical
support, and technical support for both the domestic and international sales
group. He has been instrumental in openina the Asian Market to
Southwire s products. He is co-author of the South wire Overhend Conductor
Mnnual, and author of several papers on overhead conductor design and
application.
Mr. Thrash is . member of the IEEE Power Engineering Society, Canadian
Electrical Association (CEA). the International Electrotechnical Commission
(IEC), the International Conference on Large Electric High-Tension System
(ClORE). He is chairman of t.he Electrical Technical Committee of the
Aluminum Association and is . former first vice president of the Extruded
Dielectric Power Cable Section of the Insulated Cable EnSinccrs Association
(ICEA).