[industry report] u.s. grid automation report
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1 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automation Report | September 2013
Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
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 Within 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
2 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automation Report | September 2013
Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Executive Summary
U.S. smart grid expenditures have been compromised
largely of advanced metering infrastructure (AMI) projects
over the past five years. However, 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 devices and distributed
generation sources, and allow for faster outage recovery
times.
Federal smart grid deployment targets, renewable portfolio standards, and the need to increase grid
reliability have driven U.S. grid automation. However, as
electricity markets open up in the U.S., grid automation
projects will also be driven by a strong need to increase electric provider customer satisfaction.
As U.S. utilities embrace global standards such as IEC
61850, vendors with field proven grid analytics, advanced
DMS, sensors, IEDs, and FLISR solutions will be best
positioned in the market. The long-term result of such
investments 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. However, utilities will need strong support from
industry stakeholders (vendors, integrators, regulators, etc.)
and electric customers to meet this goal.
About This Report
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
level of concern utilities have in regard to the system
impacts of renewable energy sources and electric
vehicles. Additionally, this report identifies key approaches
and obstacles utilities face when pursuing these
advanced grid automation projects.
Methodology
Zpryme surveyed 83 U.S. utility professionals in November of
2012. Respondents were asked 23 questions. The survey
was conducted over the Internet.
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 advanced
distribution management system (DMS).
Six out of ten (63%) plan to adopt IEC 61850
standard for substation automation. They identified other higher priority items, testing/validation, and a
need for assistance in implementation as the top
three obstacles that would prevent them from
adopting IEC 61850.
Seventy percent of respondents prefer to implement
an advanced DMS using multi-vendor best-of-breed
components (plus systems integration).
3 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automation Report | September 2013
Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Eight out of ten respondents plan to update older
existing substations with intelligent electronic
devices (IEDs) to support DMS or grid automation
capabilities.
Six out of ten respondents are very or highly likely to
use a major equipment vendor to provide initial
system configuration serv ices for grid automation.
The main reasons cited for not using a major
equipment vendor for initial system configuration
were serv ice level 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 investment 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-seven percent
said they replace with new equipment, and 20%
said they refurbish existing equipment. Utilities cited availability of capital funding and downtime
(outage) considerations as the main reasons they
chose their approach for their equipment life
extension program.
About one out of five (22%) respondents indicated
that a high-penetration of (future) renewable
energy is expected to cause significant problems on
their distribution system.
Eighteen-percent of respondents indicated that a
high-penetration of (future) electric vehicle (EV)
charging is expected to cause significant problems
on their distribution system.
Just over 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
conservation voltage 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 improvements
are not related to Energy Efficiency Portfolio
Standard requirements.
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
U.S. Grid Automation Survey Implications
The survey 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. In this section we
present the major implications of the data, and
recommendations that can assist in advancing grid
automation deployments.
U.S. utilities will increasingly embrace grid analytics,
thus creating significant opportunities for utilities to
leverage 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, preventing
energy losses, and emergency response planning. The result is lower operating costs, higher customer
satisfaction, and reducing unnecessary strain on grid
equipment.
A majority of utilities are prepared to embrace
global standards, IEDs, advanced DMS, FLISR,
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 level of customization to meet the needs of large
customers, and also require advanced energy
management system integration on the customer or
utility side.
Utilities are going to demand higher levels of
interoperability, scalability, customer support,
training, validation and testing from vendors before
approving expenditures on new products,
technologies, and software. In other words, small-
scale testing or controlled environment use cases
will no longer be enough to gain the trust of utilities.
Solutions must be proven in real-world (large-scale)
deployments.
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
U.S. Grid Automation Trends
Data analytics, advanced substation automation and
demand response, and renewable and electric vehicle
(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 Survey indicate
that 73% of US utilities are planning to procure grid
analytics software. They are looking to this solution to
leverage 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, preventing energy
losses, and emergency response planning. The two
approaches most likely to be used for grid analytics
software are analytics integrated into an advanced DMS or a separate analytics application, and the majority of
the respondents prefer the former approach. Nearly two-
thirds (65%) of the utilities surveyed want to use a multi-
vendor best-of-breed components system, and the
remainder would use an integrated advanced DMS from
a major vendor, plus system integration.
Eighty percent of the utilities that responded to the survey
plan to upgrade older existing substations with intelligent
electronic devices (IEDs) to support DMS or grid
automation capabilities. In addition, the use of
performance-based utility rates or reliability indexes would
most likely lead to increased investment in feeder or substation automation, replacing aging distribution
equipment, and DMS or ADMS software.
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 conservation voltage reduction, and a small
percentage (13%) prefer residential customer-oriented DR
programs.
There is a trending concern among utility executives that
high penetrations of future renewable energy and future
EV charging will create significant problems on their
distribution systems.
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
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 have managed and maintained it. As with many
asset intensive industries with complex capital
infrastructure, the workforce has grown up with their
respective utilities and the majority of them have been
employed for their entire careers. The development and
implementation of a modern smart grid infrastructure will
require attention to workforce development to provide 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 IP network to help ensure high priority
is given to grid operations traffic. The network
convergence 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 heavily on fossil fuels,
including oil, coal and natural gas, as energy sources. These fuels are non-renewable and the reserves available
on the earth are dwindling rapidly. The success of the
future electric infrastructure will necessitate a heavy
reliance on renewable energy sources.
GLOBAL, FEDERAL AND STATE REGULATIONS AND TARGETS
The Federal Government has established smart grid
deployment targets and renewable portfolio standards. In
addition, state-based regulatory frameworks, as well as
existing and pending state and federal legislation, have 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 invested in privately funded
projects. In addition, there is strong interest from venture
capital and private sector funding for the development of
innovative smart grid technologies.
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Survey Respondent Characteristics
Experience with Distribution Management Systems
Over half (62%) of the respondents had three years or
more experience with distribution management systems.
Title Within Organization
More of the professionals identified themselves as
operations personnel (30%) than other types:
director/manager (22%), professional staff (15%),
superv isory (12%), executive (15%), and other (than these
choices) (6%).
None, 8%
Less than 1
year, 10%
1 to 2 years,
20%
3 to 5 years, 23%
6 to 10 years,
14%
11 to 15 years,
11%
Over 15 years,
14%
How much experience do you have with distribution management systems?
(figure 1, source: Zpryme)
Executive
(CEO, VP), 15%
Director /
M anagerial,
22%
Supervisory,
12%
Professional Staff, 15%
Operations, 30%
Other Utility Position, 6%
What is your title? (figure 2, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Utility Type
There was substantial representation of all three types of
electricity utilities: investor-owned (51%), municipal (21%),
and cooperatives (25%).
Investor-owned, 51%
M unicipal, 21%
Electric
cooperative,
25%
Other, 3%
How would you classify your utility? (figure 3, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Grid Automation Survey Detailed Findings
Grid Analytics Software for Distribution System
When asked whether their utility was planning to procure
grid analytics software, over three-fourths (76%) said yes.
Analytics Software Integration
The two approaches most likely to be used for grid
analytics software were: analytics integrated into an
advanced DMS (47%), or a separate analytics application
(29%).
Definitely yes,
21%
Probably yes, 55%
Probably no,
19%
Definitely no, 5%
Is your utility planning to procure grid analytics software for your distribution system?
(figure 4, source: Zpryme)
Not planning to procure grid
analytics softw are, 18%
A separate
analytics
application,
29%
Analytics
integrated into
an Advanced
DM S, 47%
Other, 6%
Which approach would you likely use for the grid analytics software?
(figure 5, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Substation Automation and IEC 61850
Sixty-three percent said their utility was planning to adopt
the IEC 61850 standard for substation automation.
Obstacle of IEC 61850 Standard
The main obstacles listed that would stop them from
adopting IEC 61850 were other higher priorities (35%),
testing/validation (18%), need assistance to implement
(13%), and training (13%).
Definitely yes, 15%
Probably yes,
48%
Probably no,
31%
Definitely no,
6%
Is your utility planning to adopt the IEC 61850 standard for substation automation? (figure 6, source: Zpryme)
6%
13%
13%
15%
18%
35%
0% 5% 10% 15% 20% 25% 30% 35% 40%
Other
Training
Need assistance to implement
Nothing, we plan to adopt
Testing / Validation
Higher priorities at this time
What primary obstacle would stop you from adopting the IEC 61850 standard?
(figure 7, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Advanced DMS Integration
The most popular approach to implement an advanced
DMS would use multi-vendor best-of-breed components,
plus systems integration (70%). The remainder (30%) would
use an integrated advanced DMS from a major vendor.
Updating Substations
The utility professionals were queried about whether they
planned to update existing substations with new electric
devices to support DMS or grid automation capabilities.
79% said they planned to do so.
An integrated
Advanced DM S
from a major
vendor, 30%
M ulti-vendor
best-of-breed
components,
plus systems
integration, 70%
Which approach would you prefer to implement an Advanced DMS?
(figure 8, source: Zpryme)
Definitely yes,
25%
Probably yes,
54%
Probably no,
18%
Definitely no, 3%
Is your utility planning to update older existing substations with new intelligent electronic devices
(IEDs) to support DMS or grid automation capabilities?
(figure 9, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Updating Feeder Circuits with FLISR
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.
Initial System Configuration Services for Grid Automation
Ninety-five percent of the respondents said they would
likely (21% extremely likely) use a major vendor to provide
initial system configuration serv ices for their grid
automation.
Definitely yes, 26%
Probably yes,
44%
Probably no, 25%
Definitely no,
5%
Is your utility planning to update existing feeder circuits outside of the substation with FLISR (fault location,
isolation, and service restoration)?
(figure 10, source: Zpryme)
Extremely likely,
21%
Very likely, 41%
Somew hat likely, 33%
Not likely at all,
5%
How likely are you to use a major equipment vendor to provide initial system configuration services for your
grid automation?
(figure 11, source: Zpryme)
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Copyright © 2013 Zpryme Research & Consulting, LLC All rights reserved.
Obstacles of Initial System Configuration Services
The primary obstacles that would stop utilities from using a
major equipment vendor for initial system configuration
were: serv ice level agreement concerns for support (30%),
desire to perform “in house” configurations (19%), and
relationship with existing integrator (18%).
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 investment in feeder automation
or substation automation (43%), increased investment for
replacing aging distribution equipment (26%), and
increased investment in DMS or ADMS software (13%).
10%
23%
18%
19%
30%
0% 10% 20% 30% 40%
Other
Nothing, we are planning to use a
major equipment vendor
Relationship with existing integrator
Desire to perform “in-house” instead
Service level agreement concerns forsupport
What primary obstacle would stop you from using a major equipment vendor to provide initial system configuration services for your grid automation
project? (figure 12, source: Zpryme)
4%
6%
8%
13%
26%
43%
0% 10% 20% 30% 40%
No impact
Increased investment for refurbishing /
extending life of aging equipment
Other
Increased investment in DMS or ADMS
software
Increased investment for replacing
aging distribution equipment
Increased investment in feeder
automation or substation automation
What will be the major impact on the distribution system from performance-based utility rates or
reliability indexes?
(figure 13, source: Zpryme)
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Funding of Distribution Equipment
Respondents were asked to describe their approach when
their utility funds a distribution equipment life extension
program. Thirty-seven 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.
Equipment Life Extension Program
The main reasons they chose their approach (cited in
figure 14) was the availability 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 provider (8%).
Replace w ith
new
equipment, 43%
Refurbish
ex isting
equipment, 20%
Retro-fill ex isting
equipment w ith
new Breakers /
Sw itches (into ex isting
structures), 37%
When your utility funds a distribution equipment life extension program, which best describes your
approach?
(figure 14, source: Zpryme)
4%
8%
7%
13%
30%
38%
0% 10% 20% 30% 40%
Other
Qualified equipment service provider
Arc Flash exposure risk mitigation
Physical dimensions / size restrictions
Downtime (outage) considerations
Availability of capital funding
What is the main reason your utility chooses this approach for an equipment life extension program?
(figure 15, source: Zpryme)
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Level of Renewable Energy Generation
A two-part issue first asked what the level of renewable
energy generation that was being placed on their
distribution system was today. Responses were: none
(10%), small level (57%), moderate level (23%), and large
level (10%).
Future Renewable Energy Problems
The second part of the issue asked whether a high-
penetration of (future) renewable energy on their utility
distribution system would cause any problems. Twelve
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.
None, 10%
Small, 57%
M oderate, 23%
Large, 10%
The level of renewable energy generation being placed onto my utility distribution system today is:
(figure 16, source: Zpryme)
Not cause any
problems, 12%
Cause small problems, 29%
Cause
moderate
problems, 37%
Cause significant
problems, 22%
A high-penetration of (future) renewable energy on my utility distribution system is expected to:
(figure 17, source: Zpryme)
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Electric Vehicle Charging
Another two-part issue first asked what the level of electric
vehicle charging that was being placed on their
distribution systems was today. Respondents said: none
(38%), small level (56%), moderate level (4%), and large
level (2%).
Future Electric Vehicle Charging
The follow-on question probed whether a high-penetration
of (future) electric vehicle charging would cause
problems. Seventeen 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.
None, 38%
Small, 56%
M oderate, 4%
Large, 2%
The level of electric vehicle charging being placed on my utility distribution system today is:
(figure 18, source: Zpryme)
Not cause any problems, 17%
Cause small problems, 29% Cause
moderate
problems, 36%
Cause
significant
problems, 18%
A high-penetration of (future) electric vehicle charging on my utility distribution system is expected to:
(figure 19, source: Zpryme)
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Demand Management Option
The next question asked the sample which demand
management option they preferred. Forty-four percent
said they preferred commercial and industrial customer-
oriented demand response programs; 25% preferred a
grid-oriented solution like Volt-VAR or conservation voltage
reduction; 13% preferred residential customer-oriented
demand response programs; and the remainder, 18%, had
another (than these three) preference.
Reasons Demand Response Option Chosen
An open-ended question asked why those demand
management preferences were selected (in figure 20);
and the most frequent reasons were:
Grid oriented preference
Cost savings
Conserve 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 savings 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.
Grid-oriented solution - like
Volt-VAR or conservation
voltage reduction
(CVR), 25%
Commercial
and industrial
customer-
oriented demand
response
program, 44%
Residential
customer-
oriented demand
response program, 13%
Other, 18%
Which of the following does your utility prefer as a demand management option?
(figure 20, source: Zpryme)
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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 actively
pursuing EE savings with customers.
Automated Software System for Energy Efficiency and
Sustainability projects
The last item on the survey asked whether the respondents
would need an automated software system to track
energy efficiency (EE) savings 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 actively pursuing such a project, with a remaining 16%
responding otherwise.
Yes – to meet
EE portfolio
standards
requirements, 36%
Yes – but not related to EE
portfolio standards, 31%
No – w e are not actively
pursuing Energy Efficiency
savings w ith customers., 33%
Is your utility planning to assist large customers with Energy Efficiency (EE) projects?
(figure 21, source: Zpryme)
Yes – to meet
EE portfolio
standards
requirements, 28%
Yes – but not related to EE
portfolio
standards, 25%
No – w e are not
actively
pursuing Energy
Efficiency savings w ith
customers., 31%
Other, 16%
Would your utility need an automated software system to track the Energy Efficiency savings and Sustainability
of projects?
(figure 22, source: Zpryme)
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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 have already started distribution and substation
automation will drive the growth of this market.
Progressive utilities will pioneer the use of grid analytics,
advanced DMS, sensors, IEDs, and FLISR. 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 investors) for investments in such technologies.
Finally, as U.S. utilities embrace global standards such as
IEC 61850, vendors 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 ROIs for utilities.
The long-term result of such investments in grid automation
will result in a significantly more reliable and efficient U.S.
electric grid, higher utility customer satisfaction, and lower
energy bills.
20 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automation Report | September 2013
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