US Grid Automation Sept2013

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PresentsU.S. Grid Automation Report

Survey & Analysis By



1 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automat ion Report | Septe mber 2013

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

Table of Contents

Executive Summary......................... ........................ .......................2About This Report........................................................................2Methodology ........................... ........................ ......................... ..2Major Findings .......................... ........................ ......................... ..2

U.S. Grid Automation Survey Implications ....................... ..............4

U.S. Grid Automation Trends ................................ ........................ ..5U.S. Grid Automation Drivers ........................ ....................... ...........6

Survey Respondent Characteristics ........................................ .......7Experience with Distribution Management Systems .................7Title Within Organization .......................... ......................... ..........7Utility Type ...................................................................................8

Grid Automation Survey Detailed Findings ............ .......................9Grid Analytics Software for Distribution System .........................9Analytics Software Integration ......................... ........................ ..9Substation Automation and IEC 61850 ....................................10

Obstacle of IEC 61850 Standard .......................... ....................10Advanced DMS Integration ........................ ......................... ....11Updating Substations....................... ........................ .................11Updating Feeder Circuits with FLISR ......................... ................12Initial System Configuration Services for Grid Automation .....12Obstacles of Initial System Configuration Services..................13Impact of Distribution System from Utility Rates or ReliabilityIndexes ......................................................................................13Funding of Distribution Equipment ........................... ................14Equipment Life Extension Program...........................................14

Level of Renewable Energy Generation .......................... .......15Future Renewable Energy Problems ........................ ................15Electric Vehicle Charging ........................ ....................... .........16Future Electric Vehicle Charging .............................................16Demand Management Option ...............................................17Reasons Demand Response Option Chosen ..........................17Assisting with Energy Efficiency (EE) Projects ...........................18Automated Software System for Energy Efficiency andSustainability projects .......................... ........................ .............18

Zpryme Outlook............................................................................19





Executive Summary

U.S. smart grid expenditures have been compromisedlargely of advanced metering infrastructure (AMI) projects

over the past five years. However, many utilities are noweager to fully optimize their systems with grid automation

projects, which will allow them to fully realize the promiseof the smart grid. Grid automation will create a muchmore reliable and efficient grid, enable optimization ofthousands of grid-connected devices and distributed

generation sources, and allow for faster outage recoverytimes.

Federal smart grid deployment targets, renewableportfolio 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 automationprojects will also be driven by a strong need to increaseelectric provider customer satisfaction.

As U.S. utilities embrace global standards such as IEC61850, vendors with field proven grid analytics, advanced

DMS, sensors, IEDs, and FLISR solutions will be bestpositioned in the market. The long-term result of suchinvestments 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 majorityof U.S. utilities are ready to take up the task of building a

grid that meets the needs of tomorrow’s ConnectedEconomy. However, utilities will need strong support fromindustry 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 gridautomation and analytics among U.S. utilities, assess utility

interest in adopting global standards, and examine thelevel of concern utilities have in regard to the systemimpacts of renewable energy sources and electric

vehicles. Additionally, this report identifies key approachesand 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 surveywas conducted over the Internet.

Major Findings

About 3 out 4 (76%) utilities are planning to procuregrid 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 identifiedother higher priority items, testing/validation, and a

need for assistance in implementation as the topthree obstacles that would prevent them from

adopting IEC 61850.

Seventy percent of respondents prefer to implement

an advanced DMS using multi-vendor best-of-breedcomponents (plus systems integration).





Eight out of ten respondents plan to update older existing substations with intelligent electronic

devices (IEDs) to support DMS or grid automationcapabilities.

Six out of ten respondents are very or highly likely touse a major equipment vendor to provide initial

system configuration services for grid automation.The main reasons cited for not using a major

equipment vendor for initial system configurationwere 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 agingdistribution 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 equipmentwith new Breakers/Switches. Thirty-seven percentsaid they replace with new equipment, and 20%

said they refurbish existing equipment. Utilities citedavailability of capital funding and downtime

(outage) considerations as the main reasons theychose their approach for their equipment lifeextension program.

About one out of five (22%) respondents indicated

that a high-penetration of (future) renewable

energy is expected to cause significant problems ontheir distribution system.

Eighteen-percent of respondents indicated that a

high-penetration of (future) electric vehicle (EV)charging is expected to cause significant problemson their distribution system.

Just over four out of ten (44%) respondents chose a

commercial and industrial customer-orienteddemand response program as their most preferreddemand management option. Another 25% chose

a grid-oriented solution, like Volt-VAR or conserv ation voltage reduction (CVR). Eighteenpercent chose a residential customer-oriented

program.

Thirty-six percent (36%) of respondents said they areplanning to assist large commercial customers withEnergy Efficiency (EE) projects to meet EE portfolio

standards requirements, with another 31% planningto implement such projects, but the improvements

are not related to Energy Efficiency PortfolioStandard requirements.





U.S. Grid Automation Survey Implications

The survey results (presented in figures 1 – 22) in this reportoffer key insights about how utilities will proceed with grid

automation projects in the near future. In this section wepresent the major implications of the data, and

recommendations that can assist in advancing gridautomation deployments.

U.S. utilities will increasingly embrace grid analytics,

thus creating significant opportunities for utilities toleverage the influx of data coming from thousands

of nodes across their entire electrical systems.Analytics will enable faster and more accuratedecisions to be made about wholesale peak power

purchases, renewable and distributed resource

integration, customer billing, outages, preventingenergy 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 embraceglobal standards, IEDs, advanced DMS, FLISR,renewable energy, EVs, and EE standards in an

effort to build a grid that can meet the needs oftoday and tomorrow’s Connected Economy.

Utilities will seek to increase large commercialcustomer ’s participation in demand response

programs. Such programs will require a higher levelof customization to meet the needs of largecustomers, 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 beforeapproving 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.





U.S. Grid Automation Trends

Data analytics, advanced substation automation anddemand response, and renewable and electric vehicle

(EV) integration are key trends in grid automation that willcontinue to shape the market in the near term.

Data results from the US Grid Automaton Survey indicatethat 73% of US utilities are planning to procure gridanalytics software. They are looking to this solution to

leverage the influx of data coming from thousands ofnodes across their electrical systems to enable faster and

more accurate decisions about wholesale peak power purchases, renewable and distributed resourceintegration, customer billing, outages, preventing energy

losses, and emergency response planning. The two

approaches most likely to be used for grid analyticssoftware are analytics integrated into an advanced DMSor a separate analytics application, and the majority ofthe 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 froma major vendor , plus system integration.

Eighty percent of the utilities that responded to the surveyplan to upgrade older existing substations with intelligent

electronic devices (IEDs) to support DMS or gridautomation capabilities. In addition, the use ofperformance-based utility rates or reliability indexes would

most likely lead to increased investment in feeder or substation automation, replacing aging distributionequipment, and DMS or ADMS software.

A trend in regard to demand response (DR) programssuggests that nearly half of US utilities are looking to

employ commercial and industrial demand responsesolutions, one-quarter prefer a goal-oriented solution like

Volt-VAR or conservation voltage reduction, and a smallpercentage (13%) prefer residential customer-oriented DRprograms.

There is a trending concern among utility executives that

high penetrations of future renewable energy and futureEV charging will create significant problems on their distribution systems.





U.S. Grid Automation Drivers

AGING INFRASTRUCTURE AND WORKFORCE

The traditional electric grid has been in place since themid-19th century, and it is aging along with the workforce

that have managed and maintained it. As with manyasset intensive industries with complex capitalinfrastructure, the workforce has grown up with their

respective utilities and the majority of them have beenemployed for their entire careers. The development andimplementation of a modern smart grid infrastructure will

require attention to workforce development to provide anumber of well-trained, highly skilled electric power sector

personnel knowledgeable in smart grid operations.

A CRITICAL NEED FOR A FAST, RELIABLEAND SECURE INFRASTRUCTURE

The smart grid integrates multiple controls and monitoringsystems onto a single IP network to help ensure high priorityis given to grid operations traffic. The network convergence enables utility companies to reduce power

outages and service interruptions, as well as to reduceresponse times by quickly identifying, isolating, diagnosing

and repairing faults. The security of such a connectedstructure from physical or cyber-attacks is of paramountimportance. The grid needs to be able to detect and

isolate any breach to minimize its effect and raise analarm to speed service 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 thefuture electric infrastructure will necessitate a heavy

reliance on renewable energy sources.

GLOBAL, FEDERAL AND STATE REGULATIONSAND TARGETS

The Federal Government has established smart griddeployment targets and renewable portfolio standards. In

addition, state-based regulatory frameworks, as well asexisting and pending state and federal legislation, havecreated road maps and targets that are critical to plan a

grid automation deployment strategy.

STIMULUS FUNDS BEING REPLACEDBY PRIVATE FUNDS

More than $9 billion is currently invested in privately fundedprojects. In addition, there is strong interest from venture

capital and private sector funding for the development ofinnovative smart grid technologies.





Survey Respondent Characteristics

Experience with Distribution Management Systems

Over half (62%) of the respondents had three years or more experience w ith distribution management systems.

Title Within Organization

More of the professionals identified themselves asoperations personnel (30%) than other types:director/manager (22%), professional staff (15%),

supervisory (12%), executive (15%), and other (than thesechoices) (6%).

None, 8%

Less than 1year, 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 distributionmanagement systems?

(figure 1, source: Zpryme)

Executive(CEO, VP), 15%

Director /M anagerial,

22%

Supervisory,

12%

ProfessionalStaff, 15%

Operations,30%

Other UtilityPosition, 6%

What i s your title?(figure 2, source: Zpryme)





Utility Type

There was substantial representation of all three types ofelectricity utilities: investor-owned (51%), municipal (21%),

and cooperatives (25%).

Investor-owned,

51%

M unicipal, 21%

Electriccooperative,

25%

Other, 3%

How would you classify your utility?






Grid Automation Survey Detailed Findings

Grid Analytics Software for Distribution System

When asked whether their utility was planning to procuregrid analytics software, over three-fourths (76%) said yes.

Analytics Software Integration

The two approaches most likely to be used for gridanalytics software were: analytics integrated into anadvanced 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 analyticssoftware for your distribution system?


Not planning toprocure grid

analytics

softw are, 18%

A separateanalytics

application,29%

Analyticsintegrated into

an AdvancedDMS, 47%

Other, 6%

Which approach would you likely use for the gridanalytics software?




10 w ww.zpryme.com | www.smartgridresearch.org | www.schneider-electric.us Schneider Electric Presents: U.S. Grid Automat ion Report | September 2013


Substation Automation and IEC 61850

Sixty-three percent said their utility was planning to adoptthe IEC 61850 standard for substation automation.

Obstacle of IEC 61850 Standard

The main obstacles listed that would stop them fromadopting IEC 61850 were other higher priorities (35%),

testing/validation (18%), need assistance to implement(13%), and training (13%).

Definitely y es,15%

Probably yes,48%

Probably no,31%

Definitely no,6%

Is your utility planning to adopt the IEC 61850 standardfor 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 adoptingthe IEC 61850 standard?






Advanced DMS Integration

The most popular approach to implement an advancedDMS would use multi-vendor best-of-breed components,

plus systems integration (70%). The remainder (30%) woulduse an integrated advanced DMS from a major v endor.

Updating Substations

The utility professionals were queried about whether theyplanned to update existing substations with new electric

devices to support DMS or grid automation capabilities.79% said they planned to do so.

An integratedAdvanced 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 anAdvanced DMS?


Definitely y es,25%

Probably yes,54%

Probably no,18%

Definitely no,3%

Is your utility planning to update older existingsubstations with new intelligent electronic devices

(IEDs) to support DMS or grid automation capabilities?






Updating Feeder Circuits with FLISR

They were also asked whether their utility planned toupdate existing feeder circuits outside of the substation

with fault location, isolation, and service restorationupgrades, and 70% said they had such plans.

Initial System Configuration Services for Grid Automation

Ninety-five percent of the respondents said they wouldlikely (21% extremely likely) use a major vendor to provide

initial system configuration services for their gridautomation.

Definitely y es,26%

Probably yes,44%

Probably no,25%

Definitely no,5%

Is your utility planning to update existing feeder circuitsoutside of the substation with FLISR (fault location,

isolation, and service restoration)?


Extremely likely,21%

Very likely, 41%

Somewhatlikely, 33%

Not likely at all,5%

How likely are you to use a major equipment vendor toprovide initial system configuration services for your

grid automation?






Obstacles of Initial System Configuration Services

The primary obstacles that would stop utilities from using amajor equipment vendor for initial system configuration

were: service level agreement concerns for support (30%),desire to perform “in house” configurations (19%), andrelationship with existing integrator (18%).

Impact of Distribution System from Utility Rates or ReliabilityIndexes

The top three major impacts on the distribution system

from using performance-based utility rates or reliabilityindexes were: increased investment in feeder automationor substation automation (43%), increased investment for

replacing aging distribution equipment (26%), andincreased investment in DMS or ADMS software (13%).

10%

23%

18%

19%

30%

0% 10% 20% 30% 40%

Other

Nothing, we are planning to use amajor equipment vendor

Relationship with existing integrator

Desire to perform “in-house” instead

Service level agreement concerns for support

What primary obstacle would stop you from using amajor equipment vendor to provide initial systemconfiguration 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 ADMSsoftware

Increased investment for replacingaging distribution equipment

Increased investment in feeder

automation or substation automation

What will be the major impact on the distributionsystem from performance-based utility rates or

rel iability indexes?






Funding of Distribution Equipment

Respondents were asked to describe their approach whentheir utility funds a distribution equipment life extension

program. Thirty-seven percent said that they would retrofitexisting equipment with new breakers/switches into theexisting structure, 43% would replace with new equipment,

and the remainder (20%) would refurbish existingequipment.

Equipment Life Extension Program

The main reasons they chose their approach (cited infigure 14) w as the availability of capital funding (38%), and

downtime (outage) considerations (30%). Other lesschosen reasons were: physical dimensions/size restrictions(13%), arc flash exposure risk migration (7%), and qualified

equipment service provider (8%).

Replace wit hnew

equipment, 43%

Refurbishexisting

equipment, 20%

Retro-fill existingequipment w ith

new Breakers /Switches (into

existingstructures), 37%

When your utility funds a distribution equipment lifeextension program, which best describes your

approach?


4%

8%

7%

13%

30%

38%

0% 10% 20% 30% 40%

Other

Qualified equipment service provider

Arc Flash exposure risk mitigation

Physical dimensions / siz e restrictions

Downtime (outage) considerations

Availability of capital funding

What is the main reason your utility chooses thisapproach for an equipment life extension program?






Level of Renewable Energy Generation

A two-part issue first asked what the level of renewableenergy generation that was being placed on their

distribution system was today. Responses were: none(10%), small level (57%), moderate level (23%), and largelevel (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. Twelvepercent said it would not cause any problems; 29% said itwould cause small problems; 37% said it would cause

moderate problems; and 22% said it would causesignificant problems.

None, 10%

Small, 57%

M oderate, 23%

Large, 10%

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


Not cause anyproblems, 12%

Cause smallproblems, 29%

Causemoderate

problems, 37%

Cause

significantproblems, 22%

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






Electric Vehicle Charging

Another two-part issue first asked what the level of electricvehicle charging that was being placed on their

distribution systems was today. Respondents said: none(38%), small level (56%), moderate level (4%), and largelevel (2%).

Future Electric Vehicle Charging

The follow -on question probed whether a high-penetrationof (future) electric vehicle charging would cause

problems. Seventeen percent said it would not causeproblems; 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 onmy uti lity distribution system today is:


Not cause anyproblems, 17%

Cause smallproblems, 29%Cause

moderate

problems, 36%

Causesignificant

problems, 18%

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






Demand Management Option

The next question asked the sample which demandmanagement option they preferred. Forty-four percent

said they preferred commercial and industrial customer-oriented demand response programs; 25% preferred agrid-oriented solution like Volt-VAR or conservation voltage

reduction; 13% preferred residential customer-orienteddemand response programs; and the remainder, 18%, had

another (than these three) preference.

Reasons Demand Response Option Chosen

An open-ended question asked why those demandmanagement 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 or iented

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-orientedsolution - like

Volt-VAR or conservation

voltagereduction

(CVR), 25%

Commercialand industrial

customer-oriented

demandresponse

program, 44%

Residentialcustomer-

orienteddemandresponse

program, 13%

Other, 18%

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






Assisting with Energy Efficiency (EE) Projects

The sample of utility professionals was queried aboutwhether their utility was planning to assist large customers

with energy efficiency (EE) projects. Thirty-six percent saidyes to meet EE portfolio standards requirements; andanother 31% said yes but not related to EE portfolio

standards. Another 33% said they were not activelypursuing EE savings with customers.

Automated Software System for Energy Efficiency andSustainability 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 suchprojects. Fifty-three percent said yes (28% to meet EE

portfolio standards requirements, 25% not related to EEportfolio standards). Thirty-one percent reported they were

not actively pursuing such a project, with a remaining 16%responding otherwise.

Yes – to meetEE portfolio

standardsrequirements,

36%

Yes – but notrelated to EE

portfoliostandards, 31%

No – w e are notactively

pursuing EnergyEfficiency

savings w ithcustomers., 33%

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


Yes – to meetEE portfolio

standardsrequirements,

28%

Yes – but notrelated to EE

portfoliostandards, 25%

No – w e are notactively

pursuing Energy

Efficiencysavings w ith

customers., 31%

Other, 16%

Would your utility need an automated software systemto track the Energy Efficiency savings and Sustainability

of projects?






Zpryme Outlook

As U.S. utilities transition from pilot or project mode to fulldeployment mode, the grid automation market will

experience rapid transformation in the near term. Utilitiesthat have already started distribution and substationautomation 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 insuch technologies.

Finally, as U.S. utilities embrace global standards such asIEC 61850, vendors will ramp up their R&D and productportfolios to be able to meet utility demand for gridautomation products. This increase in competition will lead

to lower equipment prices and increased ROIs for utilities.

The long-term result of such inv estments in grid automationwill 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 morethan 100 countries, Schneider Electric offers integrated solutions acrossmultiple market segments, including leadership positions in Utilities &

Infrastructure, Industries & Machines Manufacturers, Non-residentialBuilding, Data Centers & Networks and in Residential. Focused onmaking energy safe, reliable, efficient, productive and green, the

company’s 140,000 plus employees achieved sales of 30.8 billion USdollars (24 billion euros) in 2012, through an active commitment tohelp individuals and organizations make the most of their energy.

About Zpryme:

Zpryme helps energy organizations understand their businessenvironment, 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 marketingsavvy to supercharge clients’ success. At Zpryme, we don’t produce

tables and charts; we deliver opportunity-focused, actionable insightthat is both engaging and easy-to-digest.

Disclaimer:These mat erials and the information contained herein are provided by Zpryme Research & Cons ult ing, LLC and are

int ended to provide general information on a particular subject or subjects and is not an exhaust ive t reat ment ofsuch subject(s). Accordingly, the information in these materials is n ot intended to consti t ut e accounti ng, t ax, legal,inves tment, consulting or other professional advice or services. Theinformation is not int ended to be reli ed upon ast he sole basis for any decision w hich may affect you or your busi ness . B efore making any decis ion or taking any

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