years ago.
Though natural gas is likely to be a
critical piece to the energy matrix in
many countries for years to come, it’s
far from the only option that can
handle the intermittency of renew-
ables. Technologies continue to
emerge, and some utilities have
latched on to static VAR compensa-
tors (SVCs), static synchronous
compensators (STATCOMs), capaci-
tor/reactor banks, ywheels, and bat-
tery or pumped storage. But as newer
technologies, all offer pros and cons.
Synchronous condensers are another
possible avenue. Though not a new
technology, they represent a hybrid
solution for balancing the intermit-
tency of renewable sources by offer-
ing reactive power support, a role
previously played by large central-
station generators.
A synchronous condenser is a DC-
excited synchronous machine that
makes use of increasingly plentiful
renewable power to overcome me-
chanical losses, converting that en-
ergy into much needed reactive
power, inertia and system short-cir-
cuit current. These services are es-
sential for everything from charging
transmission lines to starting large
motors, riding through faults, and
enabling the proper operation of
critical protection devices on distri-
bution lines to consumers.
Both old and new technologies will
be needed as the world moves toward
higher and higher percentages of re-
newables as it is unlikely we can ever
build enough wind, solar and other
renewable energy sources to offset
the current fossil generation eet.
Right now, globally, we have 6.6 TW
of generating capacity. If the entire
globe were to transition to 100 per
cent renewable power, it’s projected
that we would need to quadruple our
capacity to 28.7 TW. And it’s not just
changing and building out renew-
ables, it is completely changing our
generation mix. For us to move to-
ward a renewable future, we will need
more exible generation.
Whether it’s a large wind farm or
solar panels on a residential roof, re-
newables are making a profound
mark on the energy landscape – al-
though no one knows yet what to do
with recycled batteries or scrap solar.
But what is known is that the range of
potential options associated with re-
newable energy is shaking up the en-
ergy market as it exists today.
If it is in the direction of signi-
cantly more renewables, it will be
best practice – and nancially worth-
while – to have a robust integrated
resource plan in place, one that pro-
vides utilities with a holistic view that
includes energy’s endless options.
Megan Parsons is Renewable Energy
Development Manager at Burns &
McDonnell
L
imited options make for easy
decisions. Back in the day, en-
ergy markets were one-size-
ts-all, with grids simply functioning
to deliver one-way power ows. Gen-
erating capacity was designed to
cover peak demand on that single hot-
test (or coldest) day. The entire indus-
try was slow to adapt and slow to
change because it didn’t need to.
Fast forward to today. A surge of
distributed, mostly renewable energy
resources, is disrupting the norm.
Before intermittent renewable re-
sources gained traction in the early
2000s, traditional energy resource
planning primarily focused on the
lowest cost of electricity. The for-
mula was fairly straightforward: de-
termine the cost to install a power
plant with a life expectancy of 30-40
years; the cost of fuel to operate it;
and how often it would be dispatched.
The biggest variable was guring out
how much fuel would cost over the
next 20-30 years. This was before
renewable energy resources emerged
on the scene.
Beginning in the early 2000s, the
cost for wind power started to drop
signicantly, thanks mostly to gov-
ernment backing in many countries.
With tax credits and other incentives
available, developers and utilities
began to jump onboard. Then, in
2010, solar photovoltaic costs began
a rapid descent – what was $4 per watt
in 2014 is now projected to be
$0.70/W by 2020. These cost declines
have been roughly parallel in both the
US and in Europe.
But wind and solar generation do
not always align with customer de-
mand, meaning renewable penetra-
tion will produce diminishing returns
if a viable storage market or other
source of backup power supply fails
to emerge.
Enter lithium-ion batteries (LIB).
Coincidental to the rise of renewables,
Tesla has helped propel the electric
vehicle (EV) market, driving innova-
tion and cost reductions in LIB tech-
nologies. Since 2012, the global LIB
manufacturing boom has reduced
prices by 70 per cent, according to
IHS Markit. As prices are projected to
continue to decline, the global de-
ployment of these batteries, as stated
in a recent report by GTM Research,
is anticipated to grow by 55 per cent
each year for the next ve years.
In California and Hawaii, utilities
have started to feel the heat from so-
lar’s rapid popularity increase and
strong renewable policy mandates.
Generation planners now have to ac-
count for abrupt power supply transi-
tions. This requires closer integration
with transmission planners, more
outreach with ratepayers, and more
focus on exibility rather than simply
determining the lowest-cost peaking
capacity.
In the US, integrated resource plan-
ning is being redened, with some
states requiring more engagement
with their customers during the inte-
grated resource plan development,
including a rigorous evaluation of
distributed generation resources.
There’s a real need to look holistically
at transmission and distribution plan-
ning when preparing for generation as
well, but there are few established
best practices in how to do that. With
unclear rules, the entire US utility in-
dustry is starting to look at the early
adopters. But even they don’t have all
the answers yet.
In July 2017, American Electric
Power (AEP), an Ohio-based electric
utility that plans to add more than 3
GW of solar and more than 5 GW of
wind power capacity to its portfolio
by 2030, announced a plan to build
the largest US wind farm in the west-
ern panhandle of Oklahoma. Dubbed
the Wind Catcher, this 2 GW project
was slated to provide 9 TWh of wind
energy annually to customers in Ar-
kansas, Louisiana, Oklahoma and
Texas.
But its $4.5 billion price tag proved
to be too much and last year Texas
utility regulators rejected the project,
citing a lack of benets for ratepayers.
Obstacles included a lengthy 350
miles of transmission line needed for
delivery of electricity to end users.
One takeaway from the AEP experi-
ence is we can’t just be focused on
busbar cost anymore. We have to look
at delivery cost as well as the value of
location in this new power supply
equation. Economies of scale cap-
tured with large central stations have
made the most sense in the past, but in
the new utility model, there’s a lot of
locational value to be unlocked in
bringing more renewables and power
supply to a system.
No single technology, at this point
in time, does everything we need.
With all alternative generation sourc-
es, the economics are completely
different, and none provide the same
level of support to the grid.
Policymakers in both the UK and
US are encouraging utilities to evalu-
ate storage in their integrated resource
planning. But it is difcult to go all-in
without specic regulation around
how energy storage facilities will be
compensated. Planners can’t wait for
regulation to be nalised, energy stor-
age costs to further decline, or tech-
nology risks to be realised through
research and development or pilot
programmes. In the meantime, as ag-
ing fossil fuel plants are retired, elec-
tric utilities are turning to a more ef-
cient fossil fuel: natural gas.
Much like wind and solar, natural
gas is abundant and cost-effective
while also checking the boxes for grid
stability and reliability. In the US,
natural gas is expected to continue as
the primary electricity generation re-
source for at least the next decade.
Moreover, gas is expected to become
even more predominant as more and
more coal red capacity is retired.
One thing we’re doing during the
integrated resource planning process
is helping utilities realise the eco-
nomic benet of faster-response, gas
red generation technologies. In
some markets, smaller aeroderiva-
tive and reciprocating engine tech-
nologies are attractive because they
have a small footprint, can quickly
respond to load demand, and can be
placed near load pockets to offer
highly reliable capacity.
In Denton, Texas, a medium-sized
city located near Dallas-Fort Worth,
city leaders opted to build a 225 MW
gas red reciprocating engine plant as
a bridge to allow them to meet a goal
of grid stability while working toward
an eventual goal of 100 per cent re-
newable energy.
Low-cost, high-efciency gas is an
important component as the grid
transitions to renewable energy, keep-
ing reliable power owing to custom-
ers. There have been great strides
within the gas turbine market, in-
creasing efciency, reducing emis-
sions and lowering cost for reliable
gas generation. The already highly
efcient gas turbines can follow load
demand much more effectively and
efciently than they could just ten
THE ENERGY INDUSTRY TIMES - JULY 2019
Energy Outlook
14
As the grid transitions
to renewable energy,
technologies continue
to emerge to handle
its intermittency.
Although gas red
generation is likely
to be a critical part
of the energy matrix
in this respect, some
utilities have latched
on to other newer
technologies. But all
offer pros and cons.
Megan Parsons
Planning for renewables:
the endless options
Parsons: Both old and new technologies will be
needed as the world moves toward higher and
higher percentages of renewables