The document discusses challenges related to distributed energy resource (DER) growth, including increased variability and reverse power flows affecting reliability. It recommends bottom-up forecasting of DER adoption to better predict growth. Integrated grid planning is needed to assess DER impacts on the bulk power system and distribution levels. This requires coordination between transmission and distribution system operators, DER providers, and visibility of DER operations. Standards are also needed for DER cybersecurity as their use increases.

1. Distributed Energy Resources
MISO Informational Forum
Paul De Martini
July 25, 2017

2. 2
Planning for DER Growth
Issues:
• DER growth increases random variability in net loading, excess
generation and inadvertent reverse power flows that affect system
reliability, efficiency and local service quality
• Traditional forecast methods are underestimating the growth of
customer DER adoption

3. 3
DER Forecasting
Forecasting Challenges:
• Uncertainty of types, amount and pace of DER
growth make singular deterministic forecasts
ineffective for long-term planning
• Top down analysis isn’t granular enough to identify
local issues – traditional socioeconomic and
technology cost-effectiveness models ignore
customer “irrational” choices and often
underestimate growth
Potential Solutions:
• Multiple DER growth scenarios to assess current
system capabilities, identify incremental
infrastructure requirements and enable analysis of
the locational value of DERs
• Bottom-up analysis of DER growth incorporating
methods to assess customer adoption behavior
• Incorporate DER marketing plan information into
forecast development
Source: SCE

4. 4
Integrated Grid Planning
Cyclical process that integrates generation, transmission & distribution
planning to assess resource net benefits & inform rate design/incentives
https://www.hawaiianelectric.com/Documents/about_us/investing_in_the_future/grid_modernization_strategy_draft.pdf

5. 5
Integrated Planning Process
• Alignment with state/utility resource plans reflecting DER policies
• Alignment with utility distribution planning to address potential
T-D interaction and use of DER as Non-wires alternatives (NWA)
for T and/or D
• Note: requires enhancements to distribution planning as discussed
in Minnesota and other Midwest states
(https://energy.gov/sites/prod/files/2016/09/f33/DOE%20MPUC%2
0Integrated%20Distribution%20Planning%208312016.pdf)
• Effective, timely consideration of DER services for NWA
• Stakeholder engagement – building on existing processes in an
any expanded Resource, Transmission & Distribution integration
effort

6. 6
Example Planning Process Integration
Source: CA More Than Smart Working Group

7. 7
Integrated Grid Planning Considerations
• Forecasting DER: Bottom-up approach to assess customer
adoption is essential
• Integrated approach: Increasing DER levels can materially impact
bulk power system along with distribution and need to be
evaluated comprehensively
• Transparent: Regulators and stakeholders want to understand the
planning methods and engage the process at appropriate steps
• Cooperation: Select data needs to be exchanged between DER
providers and utilities to plan and operate the grid
• Equitable: The results of planning must achieve equitable
outcomes for customers

8. 8
Operational Visibility
“Data requirements and sharing of information across the transmission-distribution (T-D) interface should be
further evaluated to allow for adequate assessment of future DER deployments. The important near-term
issue is sharing of information to facilitate accurate modeling for transmission planning and operations. At
some point, additional consideration may be needed for stability, protection, forecasting, reactive needs, and
real time estimates for operating needs.”
NERC DER Connection Modeling and Reliability Considerations, 2017

9. 9
Operational Coordination
• Growth of DER creates operational challenges at the
transmission-distribution interface
• Transmission system operator (TSO) “sees” DER as if
they’re located at the T-D substation => TSO has no
visibility of impact of its DER dispatches on the
distribution system
• Utility distribution operator (DO) must manage the
system with numerous diverse DER, some acting
autonomously, some responding to TSO dispatches, some
able to provide DO services
• Requires physical coordination of the grid through
schedule and operational coordination between TSO and
DO with DER participant/aggregator
• 3-way communication between TSO, DO & DER
• Real-time visibility of DER on distribution grid
• Physical schedules and dispatch coordination
• Operating procedures to manage TSO dispatches of
multiple DER/Aggregators in the same local distribution
area
• Coordination of multi-use DER services to support
distribution system
DER
Participant
/Aggregator
Distribution
Operator
(DO)
Transmission
System Operator
TSO

10. 10
Operational Coordination
California Example: Existing Demand Response Coordination
Source: CAISO, PG&E, SCE, SDG&E & More Than Smart

11. 11
Operational Coordination
California Example: Proposed Enhanced DER Coordination
Source: CAISO, PG&E, SCE, SDG&E & More Than Smart

12. 12
DER Cybersecurity
• Cybersecurity considerations are important for any grid interconnecting
DER. This is particularly true for inverters
• IEEE 1547 does not address cybersecurity
• Grid cybersecurity standards are not required, applied or adhered to by
DER/smart inverter manufacturers or DER providers in the device
manufacture or system integration and operating systems that integrate
with the distribution grid
• This is a significant and growing gap in the grid cyber defenses as
inverter based DER (solar PV and battery storage) increase
“When integrated with energy demand management programs and
technologies, these combined technologies significantly increase the attack
surface of the national power grid and opportunity for risk to system
operation from malicious actors.”
Sandia National Laboratory 2017

13. 13
Resources
NERC DER Report
Distributed Energy Systems:
Security Implications of the
Grid of the Future
http://prod.sandia.gov/techlib/ac
cess-control.cgi/2017/170794.pdf
http://www.nerc.com/comm/O
ther/essntlrlbltysrvcstskfrcDL/D
istributed_Energy_Resources_R
eport.pdf
California
T-D Coordination Paper
http://morethansmart.org/wp-
content/uploads/2017/06/MTS_Co
ordinationTransmissionReport.pdf

14. newportcg.com resnick.caltech.edu