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2013
UNITED STATES
UTILITY GRID
AUTOMATION SURVEY
[Schneider Electric]

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

21% 55%
definitely YES!

19% 5%

probably yes

probably no

definitely NO!

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

d.6%

a.18%

c.47%

b.29%

a. not planning to procure grid analytics software
b. separate analytics application
c. analytics integrated into an Advanced DMS
d. other

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

15% 48%
definitely YES!

31% 6%

probably yes

probably no

definitely NO!

What primary obstacle would stop you from adopting the
IEC 61850 standard?
higher priorities at this time

18%
15%
13%
13%

testing / Validation
nothing, we plan to adopt
training
need assistance to implement

6%

other

35%

Which approach would you prefer to implement an
Advanced DMS?

mr.

DMS

DMS

integrated Advanced DMS
from a major vendor

multi-vendor best-of-breed components,
plus systems integration

30%

70%

Is your utility planning to update older existing
substations with new intelligent electronic devices
(IEDs) to support DMS or grid automation capabilities?

25% 54%
definitely YES!

18% 3%

probably yes

probably no

definitely NO!

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

26% 44%
definitely YES!

25% 5%

probably yes

probably no

definitely NO!

How likely are you to use a major equipment vendor to
provide initial system configuration services for your
grid automation?
[ NOT LIKELY AT ALL ]

5%

[ EXTREMELY LIKELY ]

21%

[ SOMEWHAT LIKELY ]

33%
[ VERY LIKELY ]

41%
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

23%
19%
18%

30%

desire to perform “in-house” instead
nothing, we are planning to use a
major equipment vendor
relationship with existing integrator

10%

other

What will be the major impact on the distribution system
from performance-based utility rates or reliability
indexes?

43%

iautcreased investment in feeder automation or substation
n omation
iaging distriibutionmequipfoment acing
ncreased nvest ent r repl

26%

13%
8%
6%
4%

increased investment in
DMS or ADMS software
other

increased investment for
refurbishing / extending
life of aging equipment
no impact

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

43%

20%

37%
NEW!

NEW!
NEW!

refurbish existing
equipment

replace with new equipment

NEW!

retro-fil existing equipment
with new breakers / switches
(into existing structures)

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

30%

downtime (outage) considerations

13%
7%
8%
4%

38%

physirestdiimtensions /
cal r c ions
size
arckflmishgation
a ti exposure
ris
qualifice provipdment
ed equi er
servi
other

schneider-electric.com

zpryme.com
Source: Zpryme online survey of 84 U.S. utility professionals conducted in November of 2012.

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[Infographic] 2013 U.S. Utility Grid Automation Survey (Part 1)

  • 1. 2013 UNITED STATES UTILITY GRID AUTOMATION SURVEY [Schneider Electric] Is your utility planning to procure grid analytics software for your distribution system? 21% 55% definitely YES! 19% 5% probably yes probably no definitely NO! Which approach would you likely use for the grid analytics software? d.6% a.18% c.47% b.29% a. not planning to procure grid analytics software b. separate analytics application c. analytics integrated into an Advanced DMS d. other Is your utility planning to adopt the IEC 61850 standard for substation automation? 15% 48% definitely YES! 31% 6% probably yes probably no definitely NO! What primary obstacle would stop you from adopting the IEC 61850 standard? higher priorities at this time 18% 15% 13% 13% testing / Validation nothing, we plan to adopt training need assistance to implement 6% other 35% Which approach would you prefer to implement an Advanced DMS? mr. DMS DMS integrated Advanced DMS from a major vendor multi-vendor best-of-breed components, plus systems integration 30% 70% Is your utility planning to update older existing substations with new intelligent electronic devices (IEDs) to support DMS or grid automation capabilities? 25% 54% definitely YES! 18% 3% probably yes probably no definitely NO! Is your utility planning to update existing feeder circuits outside of the substation with FLISR (fault location, isolation, and service restoration)? 26% 44% definitely YES! 25% 5% probably yes probably no definitely NO! How likely are you to use a major equipment vendor to provide initial system configuration services for your grid automation? [ NOT LIKELY AT ALL ] 5% [ EXTREMELY LIKELY ] 21% [ SOMEWHAT LIKELY ] 33% [ VERY LIKELY ] 41% 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 23% 19% 18% 30% desire to perform “in-house” instead nothing, we are planning to use a major equipment vendor relationship with existing integrator 10% other What will be the major impact on the distribution system from performance-based utility rates or reliability indexes? 43% iautcreased investment in feeder automation or substation n omation iaging distriibutionmequipfoment acing ncreased nvest ent r repl 26% 13% 8% 6% 4% increased investment in DMS or ADMS software other increased investment for refurbishing / extending life of aging equipment no impact When your utility funds a distribution equipment life extension program, which best describes your approach? 43% 20% 37% NEW! NEW! NEW! refurbish existing equipment replace with new equipment NEW! retro-fil existing equipment with new breakers / switches (into existing structures) What is the main reason your utility chooses this approach for an equipment life extension program? availability of capital funding 30% downtime (outage) considerations 13% 7% 8% 4% 38% physirestdiimtensions / cal r c ions size arckflmishgation a ti exposure ris qualifice provipdment ed equi er servi other schneider-electric.com zpryme.com Source: Zpryme online survey of 84 U.S. utility professionals conducted in November of 2012.