As shown in a new Infographic, 2013 U.S. Utility Grid Automation Survey, conducted by Zpryme and commissioned by the global specialist in energy management Schneider Electric, three out of four utilities are likely to purchase grid analytics for distribution systems, while 79% are planning to update older existing substations with new intelligent electronic devices (IEDs) to support DMS or grid automation capabilities.
Download the Schneider Electric-sponsored infographic today to view responses from the following utility survey questions:
- Is your utility planning to procure grid analytics software for your distribution system?
- Which approach would you likely use for the grid analytics software?
- 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?
- 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?
- 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?
- What primary obstacle would stop you from using a major equipment vendor to provide initial system configuration services for your grid automation project?
- What will be the major impact on the distribution system from performance-based utility rates or reliability indexes?
- 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?
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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.