[Industry report] U.S. Grid Automation Report

xx Title / Section

Presents

U.S. Grid Automation Report

Survey & Analysis By

Table of Contents
Executive Summary........................................................................2
About This Report........................................................................2
Methodology ..............................................................................2
Major Findings .............................................................................2
U.S. Grid Automation Survey Implications.....................................4
U.S. Grid Automation Trends ..........................................................5
U.S. Grid Automation Drivers ..........................................................6
Survey Respondent Characteristics...............................................7
Experience with Distribution Management Systems .................7
Title W ithin Organization .............................................................7
Utility Type ...................................................................................8
Grid Automation Survey Detailed Findings ...................................9
Grid Analytics Software for Distribution System .........................9
Analytics Software Integration ...................................................9
Substation Automation and IEC 61850 ....................................10
Obstacle of IEC 61850 Standard ..............................................10
Advanced DMS Integration .....................................................11
Updating Substations................................................................11
Updating Feeder Circuits with FLISR .........................................12
Initial System Configuration Services for Grid Automation .....12
Obstacles of Initial System Configuration Services..................13
Impact of Distribution System from Utility Rates or Reliability
Indexes ......................................................................................13
Funding of Distribution Equipment ...........................................14
Equipment Life Extension Program...........................................14
Level of Renewable Energy Generation .................................15
Future Renewable Energy Problems........................................15
Electric Vehicle Charging ........................................................16
Future Electric Vehicle Charging .............................................16
Demand Management Option ...............................................17
Reasons Demand Response Option Chosen ..........................17
Assisting with Energy Efficiency (EE) Projects ...........................18
Automated Software System for Energy Efficiency and
Sustainability projects ...............................................................18
Zpryme Outlook............................................................................19

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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.

Schneider Electric Presents: U.S. Grid Automation Report | September 2013

Executive Summary

About This Report

U.S. smart grid expenditures hav e been compromised
largely of adv anced metering infrastructure (AMI ) projects
ov er the past fiv e years. Howev er, many utilities are now
eager to fully optimize their systems with grid automation
projects, which will allow them to fully realize the promise
of the smart grid. Grid automation will create a much
more reliable and efficient grid, enable optimization of
thousands of grid-connected dev ices and distributed
generation sources, and allow for faster outage recov ery
times.

The purpose of this report is to explore the use of grid
automation and analytics among U.S. utilities, assess utility
interest in adopting global standards, and examine the
lev el of concern utilities hav e in regard to the system
impacts of renewable energy sources and electric
v ehicles. Additionally, this report identifies key approaches
and obstacles utilities face when pursuing these
adv anced grid automation projects.

Federal smart grid deployment targets, renewable
portfolio standards, and the need to increase grid
reliability hav e driv en U.S. grid automation. Howev er, as
electricity markets open up in the U.S., grid automation
projects will also be driv en by a strong need to increase
electric prov ider customer satisfaction.

Zpryme surv eyed 83 U.S. utility professionals in Nov ember of
2012. Respondents were asked 23 questions. The surv ey
was conducted ov er the I nternet.

As U.S. utilities embrace global standards such as I EC
61850, v endors with field prov en grid analytics, adv anced
DMS, sensors, I EDs, and FLI SR solutions will be best
positioned in the market. The long-term result of such
inv estments in grid automation will result in a significantly
more reliable and efficient grid, higher utility customer
satisfaction, and lower energy bills.
The major findings in this report show that a large majority
of U.S. utilities are ready to take up the task of building a
grid that meets the needs of tomorrow’s Connected
Economy. Howev er, utilities will need strong support from
industry stakeholders (v endors, integrators, regulators, etc.)
and electric customers to meet this goal.

Methodology

Major Findings


About 3 out 4 (76%) utilities are planning to procure
grid analytics software, and they would most prefer
analytics software integrated into an adv anced
distribution management system (DMS).



Six out of ten (63%) plan to adopt I EC 61850
standard for substation automation. They identified
other higher priority items, testing/v alidation, and a
need for assistance in implementation as the top
three obstacles that would prev ent them from
adopting I EC 61850.



Sev enty percent of respondents prefer to implement
an adv anced DMS using multi-v endor best-of-breed
components (plus systems integration).








Eight out of ten respondents plan to update older
existing substations with intelligent electronic
dev ices (I EDs) to support DMS or grid automation
capabilities.
Six out of ten respondents are v ery or highly likely to
use a major equipment v endor to prov ide initial
system configuration serv ices for grid automation.
The main reasons cited for not using a major
equipment v endor for initial system configuration
were serv ice lev el agreement concerns for support,
desire to perform “in-house” configurations, and
relationship with existing integrator.
Respondents
indicated
that
the
use
of
performance-based utility rates or reliability indexes
would most likely lead to increased inv estment in:
feeder or substation automation, replacing aging
distribution equipment, and DMS or ADMS software.



Forty-three percent of respondents described their
approach to fund a distribution equipment life
extension program as retro-filling existing equipment
with new Breakers/Switches. Thirty-sev en percent
said they replace with new equipment, and 20%
said they refurbish existing equipment. Utilities cited
av ailability of capital funding and downtime
(outage) considerations as the main reasons they
chose their approach for their equipment life
extension program.



energy is expected to cause significant problems on
their distribution system.


Eighteen-percent of respondents indicated that a
high-penetration of (future) electric v ehicle (EV)
charging is expected to cause significant problems
on their distribution system.



Just ov er four out of ten (44%) respondents chose a
commercial
and
industrial
customer-oriented
demand response program as their most preferred
demand management option. Another 25% chose
a
grid-oriented
solution,
like
Volt-VAR
or
conserv ation v oltage reduction (CVR). Eighteen
percent chose a residential customer-oriented
program.



Thirty-six percent (36%) of respondents said they are
planning to assist large commercial customers with
Energy Efficiency (EE) projects to meet EE portfolio
standards requirements, with another 31% planning
to implement such projects, but the improv ements
are not related to Energy Efficiency Portfolio
Standard requirements.

About one out of fiv e (22%) respondents indicated
that a high-penetration of (future) renewable



management system integration on the customer or
utility side.

U.S. Grid Automation Survey Implications
The surv ey results (presented in figures 1 – 22) in this report
offer key insights about how utilities will proceed with grid
automation projects in the near future. I n this section we
present the major implications of the data, and
recommendations that can assist in adv ancing grid
automation deployments.


U.S. utilities will increasingly embrace grid analytics,
thus creating significant opportunities for utilities to
lev erage the influx of data coming from thousands
of nodes across their entire electrical systems.
Analytics will enable faster and more accurate
decisions to be made about wholesale peak power
purchases, renewable and distributed resource
integration, customer billing, outages, prev enting
energy losses, and emergency response planning.
The result is lower operating costs, higher customer
satisfaction, and reducing unnecessary strain on grid
equipment.



Utilities are going to demand higher lev els of
interoperability,
scalability,
customer support,
training, v alidation and testing from v endors before
approv ing
expenditures
on
new
products,
technologies, and software. I n other words, smallscale testing or controlled env ironment use cases
will no longer be enough to gain the trust of utilities.
Solutions must be prov en in real-world (large-scale)
deployments.

A majority of utilities are prepared to embrace
global standards, I EDs, adv anced DMS, FLI SR,
renewable energy, EVs, and EE standards in an
effort to build a grid that can meet the needs of
today and tomorrow’s Connected Economy.





Utilities will seek to increase large commercial
customer’s participation in demand response
programs. Such programs will require a higher lev el
of customization to meet the needs of large
customers, and also require adv anced energy



U.S. Grid Automation Trends
Data analytics, adv anced substation automation and
demand response, and renewable and electric v ehicle
(EV) integration are key trends in grid automation that will
continue to shape the market in the near term.
Data results from the US Grid Automaton Surv ey indicate
that 73% of US utilities are planning to procure grid
analytics software. They are looking to this solution to
lev erage the influx of data coming from thousands of
nodes across their electrical systems to enable faster and
more accurate decisions about wholesale peak power
purchases,
renewable
and
distributed
resource
integration, customer billing, outages, prev enting energy
losses, and emergency response planning. The two
approaches most likely to be used for grid analytics
software are analytics integrated into an adv anced DMS
or a separate analytics application, and the majority of
the respondents prefer the former approach. Nearly twothirds (65%) of the utilities surv eyed want to use a multiv endor best-of-breed components system, and the
remainder would use an integrated adv anced DMS from
a major v endor, plus system integration.

A trend in regard to demand response (DR) programs
suggests that nearly half of US utilities are looking to
employ commercial and industrial demand response
solutions, one-quarter prefer a goal-oriented solution like
Volt-VAR or conserv ation v oltage reduction, and a small
percentage (13%) prefer residential customer-oriented DR
programs.
There is a trending concern among utility executiv es that
high penetrations of future renewable energy and future
EV charging will create significant problems on their
distribution systems.

Eighty percent of the utilities that responded to the surv ey
plan to upgrade older existing substations with intelligent
electronic dev ices (I EDs) to support DMS or grid
automation capabilities. I n addition, the use of
performance-based utility rates or reliability indexes would
most likely lead to increased inv estment in feeder or
substation automation, replacing aging distribution
equipment, and DMS or ADMS software.



U.S. Grid Automation Drivers

AGING INFRASTRUCTURE AND WORKFORCE

The traditional electric grid has been in place since the
mid-19th century, and it is aging along with the workforce
that hav e managed and maintained it. As with many
asset
intensiv e
industries
with
complex
capital
infrastructure, the workforce has grown up with their
respectiv e utilities and the majority of them hav e been
employed for their entire careers. The dev elopment and
implementation of a modern smart grid infrastructure will
require attention to workforce dev elopment to prov ide a
number of well-trained, highly skilled electric power sector
personnel knowledgeable in smart grid operations.
A CRITICAL NEED FOR A FAST, RELIABLE
AND SECURE INFRASTRUCTURE
The smart grid integrates multiple controls and monitoring
systems onto a single I P network to help ensure high priority
is giv en to grid operations traffic. The network
conv ergence enables utility companies to reduce power
outages and serv ice interruptions, as well as to reduce
response times by quickly identifying, isolating, diagnosing
and repairing faults. The security of such a connected
structure from physical or cyber-attacks is of paramount
importance. The grid needs to be able to detect and


isolate any breach to minimize its effect and raise an
alarm to speed serv ice restoration.

THE NEED TO REDUCE INDEPENDENCE
ON FOSSIL FUELS

The current electric system has relied heav ily on fossil fuels,
including oil, coal and natural gas, as energy sources.
These fuels are non-renewable and the reserv es av ailable
on the earth are dwindling rapidly. The success of the
future electric infrastructure will necessitate a heav y
reliance on renewable energy sources.
GLOBAL, FEDERAL AND STATE REGULATIONS
AND TARGETS
The Federal Gov ernment has established smart grid
deployment targets and renewable portfolio standards. I n
addition, state-based regulatory frameworks, as well as
existing and pending state and federal legislation, hav e
created road maps and targets that are critical to plan a
grid automation deployment strategy.
STIMULUS FUNDS BEING REPLACED
BY PRIVATE FUNDS
More than $9 billion is currently inv ested in priv ately funded
projects. I n addition, there is strong interest from v enture
capital and priv ate sector funding for the dev elopment of
innov ativ e smart grid technologies.

Survey Respondent Characteristics
Experience with Distribution Management Systems

Title Within Organization

Ov er half (62%) of the respondents had three years or
more experience with distribution management systems.

More of the professionals identified themselv es as
operations
personnel
(30%)
than
other
types:
director/manager
(22%),
professional
staff
(15%),
superv isory (12%), executiv e (15%), and other (than these
choices) (6%).

How much experience do you have with distribution
management systems?
(figure 1, source: Zpryme)

What is your title?
Other Utility
Position, 6%

Over 15 years, None, 8%
14%
Less than 1
year, 10%
11 to 15 years,
11%

Ex ecutive
(CEO, VP), 15%

Operations,
30%
1 to 2 years,
20%

6 to 10 years,
14%

3 to 5 years,
23%


Professional
Staff, 15%

Director /
M anagerial,
22%

Supervisory,
12%


Utility Type
There was substantial representation of all three types of
electricity utilities: inv estor-owned (51%), municipal (21%),
and cooperativ es (25%).
How would you classify your utility?

Other, 3%
Electric
cooperative,
25%

Investor-owned,
51%

M unicipal, 21%



Grid Automation Survey Detailed Findings
Grid Analytics Software for Distribution System

Analytics Software Integration

When asked whether their utility was planning to procure
grid analytics software, ov er three-fourths (76%) said yes.

The two approaches most likely to be used for grid
analytics software were: analytics integrated into an
adv anced DMS (47%), or a separate analytics application
(29%).

Is your utility planning to procure grid analytics
software for your distribution system?

Which approach would you likely use for the grid
analytics software?

Definitely no,
5%
Other, 6%

Definitely yes,
21%
Probably no,
19%

Analytics
integrated into
an Advanced
DM S, 47%

Probably yes,
55%


Not planning to
procure grid
analytics
softw are, 18%

A separate
analytics
application,
29%


Substation Automation and IEC 61850

Obstacle of IEC 61850 Standard

Sixty-three percent said their utility was planning to adopt
the I EC 61850 standard for substation automation.

The main obstacles listed that would stop them from
adopting I EC 61850 were other higher priorities (35%),
testing/v alidation (18%), need assistance to implement
(13%), and training (13%).

Is your utility planning to adopt the IEC 61850 standard
for substation automation?

What primary obstacle would stop you from adopting
the IEC 61850 standard?

Definitely no,
6%

Definitely yes,
15%

Higher priorities at this time

35%

Testing / Validation

18%

Nothing, we plan to adopt
Probably no,
31%

15%

Need assistance to implement

13%

Training

Probably yes,
48%

13%

Other

6%
0%


5%

10%

15%

20%

25%

30%

35%

40%


Advanced DMS Integration

Updating Substations

The most popular approach to implement an adv anced
DMS would use multi-v endor best-of-breed components,
plus systems integration (70%). The remainder (30%) would
use an integrated adv anced DMS from a major v endor.

The utility professionals were queried about whether they
planned to update existing substations with new electric
dev ices to support DMS or grid automation capabilities.
79% said they planned to do so.

Which approach would you prefer to implement an
Advanced DMS?

Is your utility planning to update older existing
substations with new intelligent electronic devices
(IEDs) to support DMS or grid automation capabilities?
Definitely no,
3%
Definitely yes,
25%

An integrated
Advanced DM S
from a major
vendor, 30%
Probably no,
18%

M ulti-vendor
best-of-breed
components,
plus systems
integration, 70%


Probably yes,
54%


Updating Feeder Circuits with FLISR

Initial System Configuration Services for Grid Automation

They were also asked whether their utility planned to
update existing feeder circuits outside of the substation
with fault location, isolation, and serv ice restoration
upgrades, and 70% said they had such plans.

Ninety-fiv e percent of the respondents said they would
likely (21% extremely likely) use a major v endor to prov ide
initial system configuration serv ices for their grid
automation.

Is your utility planning to update existing feeder circuits
outside of the substation with FLISR (fault location,
isolation, and service restoration)?

How likely are you to use a major equipment vendor to
provide initial system configuration services for your
grid automation?

Definitely yes,
26%

Not likely at all,
5%

Definitely no,
5%

Ex tremely likely,
21%

Somew hat
likely, 33%
Probably no,
25%
Probably yes,
44%


Very likely, 41%


Obstacles of Initial System Configuration Services
The primary obstacles that would stop utilities from using a
major equipment v endor for initial system configuration
were: serv ice lev el agreement concerns for support (30%),
desire to perform “in house” configurations (19%), and
relationship with existing integrator (18%).

What primary obstacle would stop you from using a
major equipment vendor to provide initial system
configuration services for your grid automation
project?

Service level agreement concerns for
support

Impact of Distribution System from Utility Rates or Reliability
Indexes
The top three major impacts on the distribution system
from using performance-based utility rates or reliability
indexes were: increased inv estment in feeder automation
or substation automation (43%), increased inv estment for
replacing aging distribution equipment (26%), and
increased inv estment in DMS or ADMS software (13%).
What will be the major impact on the distribution
system from performance-based utility rates or
reliability indexes?

Increased investment in feeder
automation or substation automation

30%

43%

Increased investment for replacing
aging distribution equipment

Desire to perform “in-house” instead

26%

19%
Increased investment in DMS or ADMS
software

Relationship with existing integrator

13%

18%

Other
Nothing, we are planning to use a
major equipment vendor

8%

23%
Increased investment for refurbishing /
extending life of aging equipment

Other

6%

10%

No impact
0%

10%

20%

30%

4%

40%
0%


10%

20%

30%

40%


Funding of Distribution Equipment

Equipment Life Extension Program

Respondents were asked to describe their approach when
their utility funds a distribution equipment life extension
program. Thirty-sev en percent said that they would retrofit
existing equipment with new breakers/switches into the
existing structure, 43% would replace with new equipment,
and the remainder (20%) would refurbish existing
equipment.

The main reasons they chose their approach (cited in
figure 14) was the av ailability of capital funding (38%), and
downtime (outage) considerations (30%). Other less
chosen reasons were: physical dimensions/size restrictions
(13%), arc flash exposure risk migration (7%), and qualified
equipment serv ice prov ider (8%).

When your utility funds a distribution equipment life
extension program, which best describes your
approach?

What is the main reason your utility chooses this
approach for an equipment life extension program?
Availability of capital funding

Retro-fill ex isting
equipment w ith
new Breakers /
Sw itches (into
ex isting
structures), 37%

38%

Downtime (outage) considerations

Replace w ith
new
equipment, 43%

30%

Physical dimensions / size restrictions

13%

Arc Flash exposure risk mitigation

7%

Qualified equipment service provider
Refurbish
ex isting
equipment, 20%

8%

Other

4%

0%


10%

20%

30%

40%


Level of Renewable Energy Generation

Future Renewable Energy Problems

A two-part issue first asked what the lev el of renewable
energy generation that was being placed on their
distribution system was today. Responses were: none
(10%), small lev el (57%), moderate lev el (23%), and large
lev el (10%).

The second part of the issue asked whether a highpenetration of (future) renewable energy on their utility
distribution system would cause any problems. Twelv e
percent said it would not cause any problems; 29% said it
would cause small problems; 37% said it would cause
moderate problems; and 22% said it would cause
significant problems.

The level of renewable energy generation being
placed onto my utility distribution system today is:

A high-penetration of (future) renewable energy on my
utility distribution system is expected to:

Large, 10%

None, 10%
Cause
significant
problems, 22%

M oderate, 23%

Not cause any
problems, 12%

Cause small
problems, 29%
Small, 57%
Cause
moderate
problems, 37%



Electric Vehicle Charging

Future Electric Vehicle Charging

Another two-part issue first asked what the lev el of electric
v ehicle charging that was being placed on their
distribution systems was today. Respondents said: none
(38%), small lev el (56%), moderate lev el (4%), and large
lev el (2%).

The follow -on question probed whether a high-penetration
of (future) electric v ehicle charging would cause
problems. Sev enteen percent said it would not cause
problems; 29% said it would cause small problems; 36%
said it would cause moderate problems; and 18% said it
would cause significant problems.

The level of electric vehicle charging being placed on
my utility distribution system today is:

A high-penetration of (future) electric vehicle charging
on my utility distribution system is expected to:

Large, 2%
M oderate, 4%

Cause
significant
problems, 18%

Not cause any
problems, 17%

None, 38%

Small, 56%


Cause
moderate
problems, 36%

Cause small
problems, 29%


Demand Management Option

Reasons Demand Response Option Chosen

The next question asked the sample which demand
management option they preferred. Forty-four percent
said they preferred commercial and industrial customeroriented demand response programs; 25% preferred a
grid-oriented solution like Volt-VAR or conserv ation voltage
reduction; 13% preferred residential customer-oriented
demand response programs; and the remainder, 18%, had
another (than these three) preference.

An open-ended question asked why those demand
management preferences were selected (in figure 20);
and the most frequent reasons were:

Which of the following does your utility prefer as a
demand management option?

Other, 18%

Residential
customeroriented
demand
response
program, 13%

Grid-oriented
solution - like
Volt-VAR or
conservation
voltage
reduction
(CVR), 25%



Grid oriented preference
 Cost sav ings
 Conserv e energy
 Changing grid dynamics



Commercial and industrial oriented
 Ability to control load on a predictable basis
 Best ROI because there is a large MW control
from a few customers



Residential oriented
 Pass sav ings on to customers
 Let customer take control of their energy
usage

No theme emerged when some respondents said they
were not using a demand response program.

Commercial
and industrial
customeroriented
demand
response
program, 44%



Assisting with Energy Efficiency (EE) Projects
The sample of utility professionals was queried about
whether their utility was planning to assist large customers
with energy efficiency (EE) projects. Thirty-six percent said
yes to meet EE portfolio standards requirements; and
another 31% said yes but not related to EE portfolio
standards. Another 33% said they were not activ ely
pursuing EE sav ings with customers.

Is your utility planning to assist large customers with
Energy Efficiency (EE) projects?

Automated Software System for Energy Efficiency and
Sustainability projects
The last item on the surv ey asked whether the respondents
would need an automated software system to track
energy efficiency (EE) sav ings and sustainability of such
projects. Fifty-three percent said yes (28% to meet EE
portfolio standards requirements, 25% not related to EE
portfolio standards). Thirty-one percent reported they were
not activ ely pursuing such a project, with a remaining 16%
responding otherwise.

Would your utility need an automated software system
to track the Energy Efficiency savings and Sustainability
of projects?

Other, 16%

No – w e are not
actively
pursuing Energy
Efficiency
savings w ith
customers., 33%

Yes – to meet
EE portfolio
standards
requirements,
28%

Yes – to meet
EE portfolio
standards
requirements,
36%
No – w e are not
actively
pursuing Energy
Efficiency
savings w ith
customers., 31%

Yes – but not
related to EE
portfolio
standards, 31%


Yes – but not
related to EE
portfolio
standards, 25%


Zpryme Outlook
As U.S. utilities transition from pilot or project mode to full
deployment mode, the grid automation market will
experience rapid transformation in the near term. Utilities
that hav e already started distribution and substation
automation will driv e the growth of this market.
Progressiv e utilities will pioneer the use of grid analytics,
adv anced DMS, sensors, I EDs, and FLI SR. U.S. utilities will
chart the path for global adoption of these technologies.
Additionally, as grid automation deployments increase, it
will become easier for utilities to make the business case
(to PUCs, communities, and inv estors) for inv estments in
such technologies.
Finally, as U.S. utilities embrace global standards such as
I EC 61850, v endors will ramp up their R&D and product
portfolios to be able to meet utility demand for grid
automation products. This increase in competition will lead
to lower equipment prices and increased ROI s for utilities.
The long-term result of such inv estments in grid automation
will result in a significantly more reliable and efficient U.S.
electric grid, higher utility customer satisfaction, and lower
energy bills.



About Schneider Electric
As a global specialist in energy management with operations in more
than 100 countries, Schneider Electric offers integrated solutions across
multiple market segments, including leadership positions in Utilities &
Infrastructure, Industries & Machines Manufacturers, Non-residential
Building, Data Centers & Networks and in Residential. Focused on
making energy safe, reliable, efficient, productive and green, the
company’s 140,000 plus employees achieved sales of 30.8 billion US
dollars (24 billion euros) in 2012, through an active commitment to
help individuals and organizations make the most of their energy.

About Zpryme:
Zpryme helps energy organizations understand their business
environment, engage consumers, inspire innovation, and take action.
This practice represents an evolution beyond traditional market
research and consulting: combining sound fundamentals, innovative
tools and methodologies, industry experience, and creative marketing
savvy to supercharge clients’ success. At Zpryme, we don’t produce
tables and charts; we deliver opportunity-focused, actionable insight
that is both engaging and easy-to-digest.

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