Hydroreview201411 Dl

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INSIDE THIS ISSUE:

16 NEW POWERHOUSE ATTRACTS FISH,INCREASES GENERATION

24 100-YEAR-OLD PLANT ATTESTSTO ENDURING NATURE OF HYDRO

36 METHOD FOR SELECTINGNEW SMALL HYDRO TECHNOLOGY

StayCurrent

Hidden TreasurePUMPED STORAGE IS POISED TO STEP INTO THE SPOTLIGHT

November 2014
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NOVEMBER 2014

www.hydroworld.com November 2014 / HYDRO REVIEW 1

Bill ChristmanChelan County

Public Utility District

Linda Church CiocciNational Hydropower Association

Douglas A. Dixon, PhDEPRI

Ginger GillinGEI Consultants Inc.

John Gulliver, PhDUniversity

of Minnesota

Jacob IrvingCanadian Hydropower

Association

Gregory D. Lewis, P.E.Duke Energy Corporation

Charles I. Lipsky, P.E.Consultant

Patrick A. MarchHydro Performance

Processes Inc.

Henry MartinezSouthern California Edison

Paul NorrisOntario Waterpower Association

Lee H. Sheldon, P.E.Hydropower Consulting

Engineer

Tom SpicherHydro Y.E.S.

Paul Willis, P.E.Consulting Engineer

ADVISORY BOARD

Peer Reviewed

DEPARTMENTS 3 | Perspectives:

The Importance ofTelling Hydros Story

4 | Hydro Currents

44 | Sticky Wickets:Modifying Operationof a Pumped-StorageProject

46 | Tech Briefs

48 | Canadian Spotlight

52 | MarineHydrokinetics

54 | R&D Forum

56 | Dam Safety& Security

60 | From the Web

64 | Index to Advertisers

Follow HydroWorld.com

on Twitter and Facebook

COVER STORY

8 |A (Potentially) Bright Future for Pumped Storage in the U.S.By Elizabeth Ingram

There is a lot of potential for pumped-storage development in the

U.S. What will it take to get construction of this valuable generating

resource moving forward again?

ARTICLES

16 |Removal by Additionon the Skokomish River

By Patrick McCartyWhen faced with the pros-

pect of improving its Cush-

man Hydroelectric Com-

plex, Tacoma Power was

able to remove fish passage barriers while adding generating capacity

with an innovative expansion project.

24 |Historic Stevens Creek FacilityAdapts to a Century of ChangeBy Ginny Jones

The 18.8-MW Stevens Creek facil-

ity has operated reliably since it was

commissioned in 1914, despite a host

of changes. This historic plant is the

newest inductee into the Hydro Hall of

Fame and stands as a testament to the

enduring nature of hydro projects.

36 |Method for Assessing andSelecting New Small Hydro Technology By Qin Fen Zhang, Patrick OConnor,

Scott DeNeale and Rocio Martinez

With sign ificant development potential available at small run-of-river sites and non-powered dams in the U.S., the authors propose

a software program to help interested parties choose the best type

of technology to install at these sites.
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Vol. 33, No. 9, November 2014

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P e r s p e c t i v e s

The Importanceof Telling Hydros Story

In October 2014, at the HydroVision Brasil event in

Sao Paulo, the International Hydropower Association

(IHA) held a hydropower briefing. IHA wanted to

hear from representatives of its Brazilian member

companies the answers to this question: What are

the most important, urgent issues youd like to see

IHA work on in the coming year?

The most important topic on the minds of the

Brazilians attending the briefing was not a technical- or

business-focused one. Instead, the issue getting the

most traction was ... communications. Specifically,

the need to tell hydros story to the media and to the

general public.

My observation of this interchange quickly took

me back to 1992. Twenty-two years ago, Hydro

Reviewmagazine organized an R&D Forum. The

idea was to bring together hydro industry leaders

from throughout North America to discuss and

debate the top needs in hydro research and develop-

ment. The top needs would then be taken to policy-

and decision-makers in North America to influence

change. In that forum, the top R&D need was

identified as ... you guessed it communications.

At that time in North America, hydros image

among the public and the press was either negative

or not even on the radar. There was even debate

about whether hydro could even be referred to as a

renewable electric power resource!

In the aftermath of that fateful forum, a number

of associations, companies and individuals made

sustained efforts over the years to remedy this image

problem. As a result, today, the image of hydropower

in North America is much better than it was 20

years ago.

According to the website of the National Hydro-

power Association (NHA), results of a recent poll

conducted by Princeton Survey Research Associ-

ates International show that Hydropower enjoys

a strongly positive reputation as an energy source.

Nearly four-in-five Americans (78%) believe

hydropower is cleaner than other current forms of

energy, and roughly the same number (77%) think of

hydropower as an environmentally-friendly resource.

Moreover, hydropower is also seen as renewable

(74%) and reliable (72%) by nearly three-quarters

of Americans.

The headlines of recent electric-power-related

articles published by the Associated Press and Wall

Street Journalare great examples of the media giving

hydropower its due:

`Hydroelectric Power Making a Comeback

as Companies Turn to Renewable Energy

Strong Currents for Hydropower

But, the work is not over, no matter these results.

Communicating hydros story to the public and to

the press must be a sustained effort and one the

industry must never take for granted ... wherever

you are in the world.

Publisher and Chief Editor
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4 HYDRO REVIEW/ November 2014 www.hydroworld.com

Hydro project funding awarded to four Indian tribes

The federal Office of Indian Energy and Economic Development

awarded $1.9 million to four Indian tribes for hydroelectric projects

as part of $9.4 million to assist in developing energy and mineral

resources. The grants were awarded under the Energy and Mineral

Development Program administered by the office, which is a

division of the Office of the Assistant Secretary-Indian Affairs.

Projects funded are for renewable energy sources, including

hydropower, that are to provide clean low-cost power to tribal

members and encourage business on tribal lands.

The largest amount, $1.2 million, goes to the Confederated

Salish and Kootenai Tribes of the Flathead Reservation to help

them acquire critical expertise and infrastructure necessary to

acquire and operate the 194-MW Kerr Dam hydro project on the

Flathead River in Montana (see story at right). When the tribes

acquire the project in 2015, they will become the first tribes in the

nation to own and operate a major hydroelectric project.

The program awarded $325,000 to the Pyramid Lake Paiute

Tribe in Nevada to help assess the hydro potential of Marble Bluff

Dam and Numana Dam on the reservation. The funding also is to

help assess run-of-river applications for an irrigation system and

small hydropower on perennial streams to offset high electricity

costs for fish hatcheries.

The program awarded $189,080 to the Pueblo of Cochiti in

New Mexico to study the financial and technical feasibility of

producing hydroelectric power at Cochiti Dam on the Rio Grande

to provide income for the tribe.

And the program awarded $140,000 to the Metlakatla Indian

Community in Alaska to evaluate the feasibility of replacing three

1.2-MW turbine-generators at Metlakatla Power & Lights 3.5-MW

Purple Lake hydro project on Annete Island. The project was built

in 1956 and needs system updates.

U.S. awards fish passage construction for 810-MW

Lower Granite Dam

Garco Construction Inc. has received a $48.3 million contract

to upgrade the juvenile fish passage facility at 810-MW Lower

Granite Dam on the Snake River in Washington.

Garco, of Spokane, Wash., is to construct an upgraded fish

passage system to provide additional water through enlarged

14-inch orifices. To accommodate the added flow, the U.S. Army

Corps of Engineers said concrete mining is required to enlarge the

existing collection channel and the existing transportation channel.

A new section of transportation channel is to be mined through

the dam to exit the downstream face of the dam. Additionally,

a new transportation channel and associated systems are to be

installed from the dam to the juvenile fish facility.

Montana PSC approves PPL sale of 11 hydro plants

to NorthWestern Energy

The Montana Public Service Commission issued its formal final

order approving PPL Montanas sale of 11 hydro plants totaling

663 MW to NorthWestern Energy.

PPL Montana said the PSC action follows prior approval

by the Federal Energy Regulatory Commission of hydropower

license transfers to NorthWestern upon close of the transaction.

PPL said before the transaction can close, NorthWestern must file

with FERC and obtain approval of certain financing transactions.

PPL Montana, a subsidiary of Pennsylvania-based PPL Corp.,

announced the $900 million deal in September 2013. The seller

expects its net cash proceeds to be about $880 million. NorthWestern

Energy acquired the original hydro project owner, Montana Power,

in 2000, at which time the hydro projects were sold to PPL Corp.

Included in the sale are the Missouri-Madison project compris-

ing the 19-MW Hauser, 48-MW Holter, 21-MW Black Eagle,

60-MW Rainbow, 69-MW Cochrane, 60-MW Ryan and 48-MW

Morony plants on the Missouri River, and the 8-MW Madison

plant and the unpowered Hebgen Dam on the Madison River;

94-MW Thompson Falls on Clark Fork; 12-MW Mystic Lake on

West Rosebud Creek; and 194-MW Kerr on the Flathead River.

NorthWestern Energy has said the deal also confirms commit-

ments to proceed with the transfer of Kerr Dam to the Confeder-

ated Salish and Kootenai Tribes.

FERC relicenses one project, OKs expansions and

exemptions at others

The Federal Energy Regulatory Commission relicensed a Texas-

Louisiana hydropower project, authorized expansion of an Oregon

project and approved an Oregon conduit exemption during August.

The Energy Infrastructure Update for August 2014, compiled

by FERCs Office of Energy Projects, features relicensing of the

Toledo Bend project on the Sabine River on the Texas-Louisiana

border. The Toledo Bend relicense adds a new 1.3-MW minimum

flow unit to the project for total installed capacity of 82.3 MW.

In their relicense application, joint licensees Sabine River

Authority of Texas and the Sabine River Authority, State of Louisi-

ana, proposed to construct a 1.3-MW horizontal Francis minimum

flow turbine-generator in a second powerhouse downstream of

the Toledo Bend spillway.

FERC also issued a license amendment to Portland General

Electric allowing the utility to utilize minimum flow turbine-

generators to expand by 3.89 MW the 136.6-MW Clackamas

River project in Clackamas County, Ore.

The amendment authorizes PGE to construct: a powerhouse

at the base of Timothy Lake Dam housing two 950-kW turbines;
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6 HYDRO REVIEW/ November 2014

For the most current hydro news, log on to

a powerhouse at Crack-in-the-Ground housing a 1-MW turbine;

a powerhouse housing a 135-kW turbine utilizing return flows

from the juvenile downstream migrant collection systems and

the North Fork fishway adult fish trap; and a powerhouse and an

850-kW turbine and induction generator utilizing North Fork

fishway attraction flows.

Also in Oregon, FERC issued a conduit exemption to Monroe

Hydro LLC for the 300-kW Monroe Drop project on the North

Unit Irrigation Districts main canal in Jefferson County, Ore.

Under terms of the Hydropower Regulatory Efficiency Act of 2013,

for the first time FERC was able to grant the conduit exemption

for a project located on federal lands, a Bureau of Reclamation

irrigation canal.

Corps to test 52-MW unit at Missouris Stockton Dam

The U.S. Army Corps of Engineers is preparing for testing and

operation of a new 52-MW hydropower turbine replacing the

original 45.2-MW unit at the Stockton Dam project in Missouri.

The Corps Kansas City District said work is under way to

prepare for testing and operation. It said testing, expected to begin

about Sept. 29, is to be marked by increased water releases from

Stockton into the Sac River.

Voith Hydro received a $30.8 million contract in 2010 to replace

the projects sole turbine, a Kaplan unit that was commissioned in

1973. The contract included replacing the runner, rewinding the

generator stator winding, upgrading the hydraulic governor with

a digital governor and replacing the existing excitation system

with a digital excitation system.

The original unit sustained runner blade failure in 2009, attrib-

uted to rough operation, prompting the Corps to suspect the

original unit had not been designed for that particular facility.

DOE approves transmission line to deliver

Quebec hydropower to New York

The U.S. Department of Energy issued a presidential permit

approving construction and operation of a 1,000-MW transmis-

sion line to carry Quebec hydroelectric power to customers in

New York City.

The proposed Champlain Hudson Power Express transmission

line would carry hydropower and some wind power from Canadas

Quebec Province, across the border at Champlain, N.Y., to Astoria,

Queens, New York. DOE issued a final environmental impact

statement in August, endorsing the 336-mile transmission lines

route in the U.S., while Quebec and Canadian agencies reviewed

environmental effects in that country.

A record of decision, signed Sept. 24 by Assistant DOE Secre-

tary Patricia Hoffman, granted the presidential permit necessary

for the project to proceed in the U.S. All practicable means to

avoid or minimize environmental harm from the alternative selected

have been, or will be, adopted, the order said.

The New York Public Service Commission approved the

proposal in April. Supporters say the plan will bring clean,

cheaper hydropower to the region, reducing reliance on coal and

other generating technologies, and reducing electricity prices and

greenhouse gases. Critics say importing power from Canada would

reduce local power sales and jobs in the area.

The $2 billion project owned by Champlain Hudson Power

Express Inc. and CHPA Properties Inc. involves the construction

and operation of the Champlain Hudson Power Express, which

would consist of two wires stretched mostly underwater beneath

Lake Champlain and the Hudson, Harlem and East rivers.

The EIS may be obtained at www.chpexpresseis.org/index.php.

FERC conforms its regulations to

Hydropower Regulatory Efficiency Act

The Federal Energy Regulatory Commission has amended its

regulations on preliminary permits, exemptions and conduit

projects to comply with provisions of the Hydropower Regulatory

Efficiency Act of 2013.

To reduce the regulatory burden on some hydropower develop-

ment, Congress passed HREA (H.R.267), which was signed into

law by President Obama in 2013. One finding by Congress was

that there is substantial potential for adding hydropower generation

to non-powered dams.

The HREA:

Increases the maximum small hydro licensing exemption

to 10 MW from 5 MW;

Excludes from FERC jurisdiction qualifying projects under

5 MW that are on water conduits;

Increases the maximum capacity for conduit exemptions to

40 MW regardless of whether they are owned by municipalities

(non-municipalities exemptions had been restricted to a maximum

of 15 MW) and allows them to be installed on federal lands;

Provides FERC the ability to extend preliminary permits

two years beyond their current three-year terms; and

Requires FERC to examine a two-year licensing process for

adding hydropower to non-powered dams and for closed-loop

pumped-storage projects.

Soon after passage of the act, FERC staff updated the com-

mission website to provide guidance on the new provisions and

began processing applications under the new law. However, the

latest rulemaking (RM14-22), approved Sept. 18, formalizes

compliance of the commissions regulations with the law.

In compliance with HREA, FERC has issued two-year pre-

liminary permit extensions, granted a small conduit exemption on

federal lands to the 300-kW Monroe Drop project on a Bureau of

Reclamation irrigation canal, and ruled on a number of applications

to exclude conduit projects under 5 MW from FERC jurisdiction.

It also has approved a two-year licensing pilot project for the 4.9-

MW Kentucky River Lock and Dam No. 11 project.

The new rules may be obtained at www.ferc.gov/whats-new/

comm-meet/2014/091814/H-1.pdf.
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8 HYDRO REVIEW / November 2014 www.hydroworld.com

Theres no doubt that pumped-storage hydro-

power is a valuable resource in the U.S. These

facilities are ideal to store energy from and balance

intermittent renewables, such as wind and solar,

providing stability and flexibility to the transmission

grid. In fact, in 2012, data from EPRI indicates

pumped-storage hydropower accounted for more

than 99% of bulk storage capacity worldwide, about

127,000 MW.

However, its also an undeniable fact that there

has been little new development in this field in the

U.S. in the past two decades, which seems to indicate

the atmosphere is not favorable for encouraging

construction of pumped-storage facilities. But this

may be about to change. There has been a stirring

of movement lately, primarily on the regulatory side,

with regard to pumped-storage hydro in the U.S.

This article analyzes the activity to date and

provides some insight into the (potentially) bright

future of this valuable generating resource.

Background on pumped storage

My research indicates the first use of pumped-

storage units in the U.S. was in 1930 by Connecticut

Electric and Power Co., pumping water from the

Houstatonic River. This technology actually dates

to much earlier outside the U.S., with pumped stor-

age first being installed in the 1890s in Italy and

Switzerland, according to EPRI.

The heyday of this technology in the U.S. appears

to be the 1960s and 1970s, with facilities going on

line in California, Colorado, Massachusetts, Michi-

gan, Missouri, New York, Oklahoma, Pennsylvania,

South Carolina, Tennessee and Virginia. The 3,003-

MW Bath County facility, which was completed

in 1985 in Virginia, is the largest pumped-storage

plant in terms of generating capacity in the world.

It seems that the most recently completed

pumped-storage project in the U.S. is the 40-MW

Lake Hodges plant, built by the San Diego County

Water Authority (SDCWA) at the existing Oliven-

hain Reservoir and completed in September 2012.

(For more on this project, see the sidebar on page

14.) However, before that it had been more than 15

years since such a project was completed, that one

being the 1,035-MW Rocky Mountain facility in

Georgia, owned by Oglethorpe Power Corp., which

began operating in 1995.

According to the Federal Energy Regulatory

Commission (FERC), there are a 24 operating

pumped-storage projects under its jurisdiction,

with a total installed capacity of about 16,500 MW.

Only one of these projects was authorized in the

past 30 years.

The Energy Storage Association reports that the

40 total pumped-storage facilities operating in the

U.S. provide more than 20,000 GW of capacity, or

nearly 2% of the countrys electrical supply system.

While these numbers may sound good, compare

the shares in Europe (nearly 5%) and Japan (about

10%). It is clear we have a long way to go in the U.S.

However, the number of pumped-storage projects

in the U.S. looks set to jump considerably. FERC

says there are about 50 active preliminary permits for

these projects, representing more than 37,000 MW

of capacity. And while only a third of the operating

projects under FERCs jurisdiction are located west

of the Mississippi River, more than 80% of the pre-

liminary permits are located west of the Mississippi,

where the majority of existing and proposed solar

and wind generation is located.

The majority of the recently proposed pumped-

storage projects would employ a closed-loop system,

FERC says. These projects are not continuously

connected to a naturally flowing water feature. (At

this time, only one of the constructed projects under

FERC jurisdiction is closed loop.) In addition, many

of the proposed projects would use variable-speed

pump-turbines that would allow for more flexible

operation than the current fleet.

What is behind the resurgent interest in pumped

storage in the U.S.? According to Debbie Mursch,

chair of NHAs Pumped Storage Development

Council, Policy makers are finally realizing that

we cant continue to increase the amount of inter-

mittent generation while at the same time removing

By Elizabeth Ingram

Elizabeth Ingram is

managing editor of

Hydro Review.

A (Potentially) Bright Future

for Pumped Storage in the U.S.There is a lot of potential for pumped-storage development in the U.S. What will it take to getconstruction of this valuable generating resource moving forward again?

P u m p e d S t o r a g e


11/68



12/68

Supporting innovative approaches toFERC licensing and providing consulting

engineering support to clients, coast to

coast, including Sacramento MunicipalUtility District (SMUD) and Eagle Crest

Energy Company.

Iowa Hill Pumped Storage Development Project: this400-MW pumped storage hydroelectric facility, if built,

will serve as a key energy storage facility in SMUDspower generation portfolio, operating in concert

with SMUDs other renewable generation facilities toprovide energy storage and other electric grid services.

Eagle Mountain Pumped Storage Project:will provide up to 1,300 MW of clean energy

for California during peak energy demandperiods, supporting on-demand reliable

energy delivery.FERC original license issued June 19, 2014.



baseload nuclear and coal plants and not

consider the need for grid-scale storage.

The council was established to provide a

platform for the industry to keep abreast

of the latest developments in pumped stor-

age, be it legislative, new technology, policy

or global trends. The council also aims to

educate policy-makers and the public on

the benefits of pumped storage.

Perhaps the greatest quality of pumped

storage is that it is the only commercially

proven technology available for both grid-

scale energy storage and power genera-

tion, Mursch says. Developing additional

pumped storage, particularly in areas with

recently increased wind and solar capacity,

would significantly improve grid reliability

while reducing the need for construction

of additional fossil-fueled generation. Grid-

scale storage also could reduce the amount

of new transmission required to support

many states RPS goals, Mursch says.

Utilizing pumped-storage projects also

allows utilities to follow load and respond

to rapid changes in demand for power on

the grid using a non-emitting resources, as

opposed to fossil-fuel-fired units, Mursch

says. This allows the utilities to run their

fossil units more efficiently and reduces

carbon emissions output from these plants.

New development in the offing

There has been much recent activity

through FERC with regard to proposed

new pumped-storage facilities.

For example, FERC authorized

construction of the 400-MW Iowa Hill

pumped-storage development as part of

its August relicensing of the 637.3-MW

Upper American River project in Califor-

nia. Iowa Hill is to be an off-stream plant

that pumps water from the existing Slab

Creek Reservoir into the new Iowa Hill

Reservoir. The powerhouse will contain

three 133-MW pump-turbine units.

Many companies are involved in

development of this project, including

AF-Consult of Switzerland; AMEC in

London; Ascent Environmental in Sac-

ramento, Calif.; Carlton Engineering

in Folsom, Calif.; Crux Subsurface in

Henderson, Nev.; Foxfire Constructors

in San Clemente, Calif.; GEI Consultants

in Woburn, Mass.; HDR Engineering in

Omaha, IEC Corporation in Sacramento;

Jacobs Associates in San Francisco, Calif.;

Northwest Hydraulic Consultants in Van-

couver, British Columbia, Canada, and

The two pump-turbines in the powerhouse of the40-MW Lake Hodges pumped-storage project be-gan operating in 2012. (Courtesy San Diego CountyWater Authority)
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Stillwater Sciences in Berkeley, Calif.

In addition, FERC issued a license to

the 1,300-MW Eagle Mountain pumped-

storage project in June, authorizing Eagle

Crest Energy to build the project at the site

of an inactive iron mine in Riverside County,

Calif. There will be a head of 1,400 feet

between the reservoirs, created by adding

saddle dams and liners to two abandoned

mining pits. GEI Consultants, a developing

partner in the project, says Eagle Mountain

will be an integral component of Califor-

nias renewable energy policies and its goals

for reduction of greenhouse gas emissions.

The primary environmental issues

associated with the project are effects of

its construction and operation on ground-

water, water quality and terrestrial species

(including several sensitive bat species, the

desert bighorn sheep and threatened desert

tortoise). Groundwater will be pumped

from a series of proposed wells in the

Chuckwalla Basin to fill the reservoirs and

replace water lost to evaporation.

With California seemingly at the epicen-

ter of the interest in pumped-storage devel-

opment, its not surprising I am reporting

on interest in developing a third project in

the state. SDCWA is looking into adding

a 500-MW pumped-storage plant near its

San Vicente Dam following the closure of

the 2,200-MW San Onofre nuclear power

plant. SDCWA recently raised the dam,

adding 152,000 acre-feet of water storage

capacity to the reservoir.

Another state where were seeing interest

in pumped storage is Hawaii. In August,

Paniolo Power Co. LLC announced it

planned to issue a request for qualifications

seeking an engineering-procurement-con-

struction contractor to develop a pumped-

storage project on Parker Ranch. Capacity

of this project could range from 10 MW to

as much as 200 MW. The energy developer

said pumped storage would allow wind and

solar energy that otherwise would be cur-

tailed to be used to pump water that would

then be released in the evening to meet peak

loads being served by expensive oil-fired

generation.

Also in Hawaii, the Kauai Island Utility

Cooperative is pursuing a pumped-storage

project to be located on state land on

Kauais west site. The co-op has obtained

access to two potential sites that will allow

it to conduct technical studies.

Moving this development forward

FERC says good siting and consultation,

as well as filing of a complete application

that addresses stakeholder concerns, are key

to expediting the licensing process. On its

website, the commission has state-specific

lists of potential stakeholders to consult as

a starting point. Developers should also

consult with other site-specific interested

entities, FERC says. Early consultation with

key stakeholders on potential environmental

impacts and other concerns, in addition

to technical site evaluation, will facilitate

optimal site selection. Continued consulta-

tion on study needs and conduct of needed

studies is essential, FERC adds. Should
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16/68


a developer not agree on a study after

earnest negotiations with stakeholders, the

pre-filing dispute resolution process should

be used, rather than taking the chance on

an inadequate application, which can delay

the post-filing application process.

FERC also encourages developers to

contact commission staff before filing a

notice of intent to file an application and

a preliminary application document to dis-

cuss process selection and FERC resources

that may be helpful to them.

The Pumped Storage Development

Council issued a whitepaper on Challenges

and Opportunities for New Pumped Storage

Development. This whitepaper cites the need

for grid reliability in the U.S., provided by

reliable, affordable and grid-scale energy

storage: hydropower pumped storage. With

the tremendous growth of wind and solar

generation in the past decade, the grid is

affected by the variability of this supply.

The whitepaper also says that current

market structures and regulatory frame-

works do not present an effective means

of achieving this goal. NHAs key policy

recommendations are:

Create market products that allow

flexible resources to provide services that

help meet electric grid requirements,

including fast-responding systems that

provide critical capacity during key energy

need periods;

Level the policy playing field for

pumped storage hydropower with other

storage technologies to encourage the

development and deployment of all energy

storage technologies;

Recognize the regional differences

within the U.S. generation portfolio and the

unique roles energy storage technologies

play in different regions;

Recognize the energy security role

pumped storage hydropower plays in the

domestic electric grid;

Establish an alternative, streamlined

licensing process for low-impact pumped

storage hydropower, such as off-channel

or closed-loop projects;

Improve integration of federal and

state agencies into the early stage licensing

processes for pumped storage hydro; and

Facilitate an energy market structure

where transmission providers benefit from

long-term agreements with energy storage

facility developers.

NHA says the barriers that prevent new

pumped storage from being developed are

slowly being recognized and reduced and/or

removed. For example, Mursch says, there

is a lack of markets to fairly compensate

pumped storage for the many electrical

benefits it brings to the grid. The U.S.

Department of Energy recently provided

funding to Argonne National Laboratory

to model/quantify these benefits. Argonne

is leading a team that is seeking to provide

a comprehensive study of the technical and

market operations, economics and value of

conventional hydro and pumped-storage

plants for power system operation, includ-

ing their role in accommodating a larger

share of variable renewable energy sources.

Another example is the time it takes to

get a project licensed as compared with

other technologies. NHA says gas plants

can be licensed in fewer than two years,

while pumped storage may take five to six

years. Many developers today are consider-

ing closed-loop systems because they are

more environmentally benign and FERC

is looking to reduce licensing time for these

facilities to two years, as mandated in the

Hydropower Regulatory Efficiency Act of 2013.

Conclusion

I believe the time is now or never that

new pumped-storage plants will be built,

Mursch says. With the need for grid-scale

storage being greater than ever and barri-

ers to development slowly being removed,

pumped storages time has finally come in

the U.S., she says.

Even the U.S. Department of Energy is

getting in on the act with its Hydropower

Vision plan. As part of this plan, DOE will

issue a report that seeks to answer a number

of questions regarding the current state and

future of hydroelectric power in the U.S.,

among these how pumped-storage projects

factor into Americas energy mix.

A story of modern-day development

Development of the 40-MW Lake

Hodges pumped-storage project was

accomplished at a time when new projects

of this type simply were not being brought

on line in the U.S. So development of

this facility was both a challenge and an

achievement for the San Diego County

Water Authority in California, says Frank

Belock, deputy general manager.

Olivenhain Reservoir was impounded

in 2003 as part of SDCWAs Emergency

Storage Project to protect the region from

severe water supply shortages. Lake

Hodges sits 770 feet lower in elevation,

leading SDCWA to decide in 2002 to

add generating capability to the pumping

station that was already being designed.

From the time the pumped-storage

component was included in the scope

of work until the generating station was

completed, 10 years elapsed, Belock says.

The bottom line benefit in adding

this pumped-storage component was

estimated to be $2 million to $3 million

in annual revenue from power generation

that could be used to offset the cost of

water supply and delivery. Belock says

the $70 million pumped-storage plant

was cash financed.

Thanks to the success of this project,

SDCWA announced in July 2013 that it

was preparing to assess the potential to

develop a larger pumped-storage facil-

ity (up to 500 MW) at its San Vicente

Reservoir. Construction of this facility

is anticipated to take at least five years.

Pumped storage in Canada

The landscape for pumped-storage

development in Canada is different

from that in the U.S. because Canada

still has significant untapped potential

for conventional hydro development.

But, there has been some recent

interest in bringing pumped storage

to Canada. For example, Northland

Power, based in Toronto, proposes a

$700 million project, called Marmora,

that would use an abandoned open-

pit mine to provide a capacity of 400

MW. The company would build a new

upper reservoir for this facility, and the

powerhouse would be equipped with

Francis pump-turbine units.


17/68

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18/68


Tacoma Powers 134.6-MW Cushman Hydro-

electric Complex, located on the North Fork

of the Skokomish River in Washington, consists of

two dams, three powerhouses, two reservoirs and

26 miles of transmission lines.

The Cushman Dam No. 1 and Cushman Dam

No. 2 powerhouses produce enough clean, renewable

power each year to serve 27,000 Northwest homes.

The project supplies 11% of Tacoma Powers electri-

cal generation and has the ability to run primarily

at peak generation times.

After a federal relicensing process that took more

than three decades to complete, Tacoma Power was

faced with improving fish passage conditions at

the Cushman Hydroelectric Complex as part of

an expansion. The solution chosen consists of an

innovative approach that combines the added power

generation with a new fish collection system.

Controversial beginnings

The North Fork of the Skokomish River has long

been a place of importance for the Skokomish Indian

Tribe, who are known as People of the River, as its

water provides many uses including hydropower.

Tacoma Power constructed the Cushman project

in 1929 to meet the growing needs of the city of

Tacoma. The project was controversial from the

beginning because it diverted the water from the

North Fork of the Skokomish River into Hood Canal,

bypassing 17 miles of r iver. Later, as Tacoma Power

sought a new Federal Energy Regulatory Commis-

sion license for the project, fish habitat restoration

became a central issue as fish are an important

component in the life of the Skokomish Tribe.

The ensuing dispute would last 32 years, making

it one of the longest FERC relicensing processes

in history.

Coming to common terms

Tacoma Power, the Skokomish Indian Tribe, and state

and federal agencies including the Washington

State Department of Fish and Wildlife, Washington

Department of Ecology, National Marine Fisher-

ies Service, U.S. Fish and Wildlife Service, Forest

Service and Bureau of Indian Affairs signed a

settlement agreement in 2009 that resolved a $5.8

billion damages claim filed by the Skokomish Tribe

during the relicensing battle.

The bulk of the damages claim was centered on

the fishery. Since Tacoma Power had blocked the

North Fork of the Skokomish River with a pair of

dams and significantly reduced the flows into the

river, it impacted the natural fishery.

The agreement prompted FERC to issue an

amended version of the license previously issued

in 1998. The original license, which carried a 40-year

term, was replaced with one issued in July 2010 that

carries a 50-year term, effective from July 1, 1998.

The license was signed by the utility, tribe, and state

and federal agencies after two years of mediation

and negotiation.

The agreement also called for the provision of

upstream and downstream fish passage, construction

of two hatcheries, and wildlife mitigation and recre-

ation improvements. Tacoma Power was required to

release water into the North Fork of the Skokom-

ish River from the base of Cushman Dam No. 2

throughout the year, with flows varying between

Patrick McCarty

Pat McCarty, P.E., is

generation manager

for Tacoma Power.

Removal By Addition

on the Skokomish RiverWhen faced with the prospect of improving its Cushman Hydroelectric Complex, TacomaPower was able to remove fish passage barriers while adding generating capacity with aninnovative expansion project.

N e w D e v e l o p m e n t

The fish collection pool is visible in its lowered position, ad-jacent to the completed new powerhouse and original valvehouse at Cushman No. 2.


19/68

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100 to 300 cubic feet per second to mimic

historic seasonal river flow.

Overcoming four

challenges at once

The Skokomish Indian Tribe and natural

resource agencies requested that an adult

fish collection system be located at the base

of Cushman Dam No. 2 to give migrating

fish the maximum migration experience

and spawning area.

Meanwhile, Tacoma Power wished to

recover the energy from water released

flowing into the North Fork of the Skokom-

ish River at the base of the dam. The option

to construct the North Fork Powerhouse

was included in the settlement agreement

and amended license, though the final

decision to proceed did not happen until

after Tacoma Power received a $4.7 million

American Recovery and Reinvestment Act

award from the U.S. Department of Energy.

The two goals gave the utility four chal-

lenges as it designed and built the new

powerhouse and fish facility:

1) Using water discharged from the new

turbine units to drive adult fish collection

2) Designing a method to move fish to the

top or bottom of the dam

3) Constructing the powerhouse without

dewatering the construction area

4) Maximizing available space at the bot-

tom and top of the dam given restraints

that required judicious use of every

square foot

The $28 million project was supported

by DOEs grant, with the remainder pri-

marily financed with Clean Renewable

Energy Bonds.

Solutions and innovations

The fish collection facility was intended

to serve two primary purposes: the first

being to trap and haul migrating adult fish

upstream so they can spawn in the upper

basin; and second, to provide a method and

location to put smolts that are migrating

out from the Upper North Fork and Lake

Cushman into the Lower North Fork so

they can continue their migration to the sea.

The company wanted to design a fish

collection system that used water discharged

from the turbine units draft tubes to attract

migrating adult fish and lead them into a

fish collection pool for holding. However,

turbine suppliers consulted by the company

were initially reluctant to discharge draft

tubes under the fish collection pool because

the concept had never been tested before.

The design was so sensitive that a 1:5 scale

physical model was built in a Northwest

Hydraulic Consultants laboratory and

used to validate the arrangement. The final

design protects the Andritz-manufactured

turbines from the hydraulic resonance that

may be created by the pool.

To move adult fish to the top of the dam

and juvenile fish to the bottom, Tacoma

Powers engineers designed a tram system

to move a transport hopper from the fish

collection pool to a point on the side of

the dam where a jib crane could reach the

hopper. The crane moves the hopper to a
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fish handling facility and can safely deliver

fish either direction.

Dewatering the construction area at

the base of the dam was nearly impos-

sible because of 60 feet of rubble in the

riverbed. Tacoma Power came up with a

plan to build a sediment control dam with

bags of spawning gravel and pump turbid

water to a sediment pond. This allowed

excavation to be performed in the water.

The 1-cubic-yard bags of spawning gravel

were added to the river after construction

was complete and enhance the spawning

habitat as it moves downstream.

The fish collection facility was built by

a joint venture of Tri-State Construction,

Inc. and Harbor Pacific Contractors, Inc.,

above the water on a platform and lowered

into place immediately adjacent to the

new powerhouse when complete. Draft

tubes for each of the two turbines were

lowered into the water, connected to the

powerhouse and encased in concrete.

The construction site itself also pre-

sented many challenges and limiting fea-

tures. Space constraints included fitting

the powerhouse and adult fish collector

between the existing valve house and a

canyon wall. Every part of the powerhouse

design was laid out with only inches of

room to spare.

At the top of the dam, there is limited

space between the reservoir and steep hill-

side. Tacoma Power designed a deck over

the water to create an area for fish sorting

and handling. The design includes an upper

and lower deck supported by the dam, a

retaining wall and a supporting column in

the reservoir. The fish crane foundation is

notched into the side of the dam.

Adult fish are separated, counted and

marked in a new fish handling area at the

top of the dam before being transported in

tanks by truck to locations upstream of the

Cushman dams or to one of two hatcheries

planned for completion in 2015.

The control system integrates control

of the turbines, generators, river outlet

valve and fish facility into one automated

operating system. Under normal automatic

conditions, there is only one required opera-

tor input: plant flow setpoint. This feature

sets the control system apart from other

generator plant control systems. The sys-

tem was designed by Tacoma Power with

components from Allen-Bradley.

This map displays the infrastructure associated with Tacoma Powers Cushman Hydroelectric Complex.
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Results

The new North Fork Skokomish Power-

house and Fish Facility provides clean,

renewable energy for 1,700 homes and

upstream and downstream fish passage

for coho, spring chinook, steelhead and

sockeye salmon. The facilities provide for

the needs of Tacoma Power ratepayers and

the economic and environmental interests

of the Skokomish Tribe Indian and natural

resource agencies.

The new powerhouse provides an

additional 3.6 MW of hydropower gener-

ated by two Francis-style turbines, while

the fish collection and transportation facil-

ity reopens a stretch of the North Fork

Skokomish to endangered salmon and

steelhead populations for the first time in

more than 90 years.

This win-win scenario is a fortunate

outcome of what was a long and conten-

tious relationship between Tacoma Power,

the Skokomish Tribal Nation and natural

resource agencies. The completion of the

hydroelectric facility is a sign that stake-

holders in the Cushman Hydroelectric

Project have strengthened their relation-

ship and are working together to enhance

the watershed.

The project was recognized by the

National Hydropower Association with

an Outstanding Stewards of Americas

Waters Award, which are given annually

to organizations that demonstrate excel-

lence in the development and operation

of hydropower.

The Cushman plants new fish collection facility, before being lowered into the waters downstream from theNo. 2 dam.
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participate in the celebration of the power

that will be realized to the progress and

prosperity of Augusta.

This project was completed within two

years, with a workforce of more than 800.

Boarding houses, a butcher shop, bake

shop, refrigerating/ice facility and commis-

sary all were built on the original work site.

Because great care was taken to safeguard

the health of workers in the camp, filtered

water and sewerage systems were provided,

along with a fully equipped hospital with

a resident physician.

And when the dam and hydro project

was completed, local newspapers hailed it

as the most advanced engineering feat of

its kind in the Southeast.

Stevens Creek first produced power on

Feb. 16, 1914. It initially contained five

2.36-MW units. Three additional units were

added by 1926 to meet customer demand.

Its generating capacity today is 18.8 MW

and it is operated by South Carolina Elec-

tric & Gas Company.The three-level powerhouse for the Stevens Creek project originally contained eight water wheels but wasoversized to allow for future expansions.
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Joe McGill, supervisor of the facility,

is amazed by how quickly and how well

the facility was built. Its remarkable to

consider that they built this place in about

two years. They only had steam power.

Looking at the wooden forms they built

for the concrete, they must have done

them mostly by hand, and they just had

ways of building things that we dont have

anymore, McGill says. Im amazed at

how accurate they were in terms of size

and placement of all these large parts that

come together so well.

All the major mechanical components of

the original five units (including the genera-

tors), the dam and the powerhouse that

are in operation today date to the original

construction of the plant.

Stevens Creek Dam has a 2,000-foot-

wide spillway. At one end of the spillway

is a lock, 90 feet wide and 165 feet long,

which was used until the 1950s to allow

passage of barges and boats. The three-level

powerhouse has a concrete substructure,

or foundation, containing the plants eight

water wheels.

Each wheel is connected to a gen-

erator mounted on the floor of the steel-

framed, brick-covered superstructure. The

mechanical power produced by the water

wheels turns the generators to produce

electricity. The powerhouse measures

roughly 328 feet long, 52 feet wide, and 57

feet high; the foundation is larger than the

structure, to house two additional future

turbines (no plans are currently in place to

add these two units). A set of transformers

steps up the low voltage produced by the

generators to a higher voltage suitable for

long-distance transmission.

Stevens Creek Dam impounds one

of six reservoirs on the mainstem of the

Savannah River. Three U.S. Army Corps

of Engineers dams are located upstream

of Stevens Creek: Hartwell, Richard B.

Russell and J. Strom Thurmond. J. Strom

Thurmond is the closest dam upstream of

Stevens Creek, about 13 miles to the north.

Downstream of Stevens Creek are the

Augusta Canal Diversion Dam (about 1

mile downstream) and the New Savan-

nah Bluff Lock and Dam downstream

of Augusta.

Although constructed solely to generate

electricity, Stevens Creek now functions

as a re-regulating plant to mitigate the

downstream effects of the wide-ranging

discharges from J. Strom Thurmond Dam

and its 381-MW powerhouse. Normal daily

fluctuations in the water level of Stevens

Creek Reservoir are 3 to 5 feet. As part of its

role to control the effects of J. Strom Thur-

mond Dam, Stevens Creek can still produce

hydroelectricity. The Stevens Creek facility,

as completed in 1925 with the addition of

three more turbine-generator units, con-

tinues to provide a yearly average of 94

GWh of electricity.

Our Stevens Creek Hydro plant and

the staff have been an integral part of

SCE&Gs generation portfolio for 100

years, providing non-emitting generation

in the North Augusta region, said Jim
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Landreth, vice president of fossil hydro

operations with SCE&G. This plant has

a long history as a key driver to enhanc-

ing the local area infrastructure to attract

industry and providing for vital community

health and social enrichment.

A rich history

In 1995, the Federal Energy Regulatory

Commission (FERC) issued a new license

to SCE&G for continued operation of the

Stevens Creek Hydroelectric Project. As

part of the relicensing process, FERC

required SCE&G to identify and evaluate all

historic properties within the Stevens Creek

project area for eligibility for inclusion in

the National Register of Historic Places.

In 1991, a professional historian studied

the buildings and structures in the project

area, which were found to consist solely of

the generating plant.

From 1991 to 1995, professional archae-

ologists conducted investigations in the

upland and floodplain portions of the Ste-

vens Creek project area. The archaeologists

used a phased approach, with the first phase

designed to define areas disturbed by the

plant operation and to locate archaeological

sites. The second phase was a more inten-

sive study to evaluate whether any of the

identified archaeological sites were eligible

for the National Register of Historic Places.

Ten of the 52 prehistoric archaeological

sites in the Stevens Creek project area on

which archaeologists conducted intensive

excavations were determined eligible for the

National Register of Historic Places. Most

Today, the 18.8-MW Stevens Creek hydro facility continues to produce electricity as needed, providing fittingtestimony to the long-lived, reliable nature of hydroelectric power.
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of these sites are located on private land (six

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