The Impact of Distributed Energy Resources on the Power System and Electricity Markets
February 24-25, 2021 | Online :: Central Time
“This course has helped utilities better prepare for the challenges and opportunities DER technology has to offer, especially around the concepts of hosting capacity, power quality concerns, protection and coordination concerns, and infrastructure offset opportunities.” Manager – Distribution Planning, EPCOR
The growth of distributed generation (DG) and distributed energy resources (DERs) is challenging many of the assumptions upon which traditional utility system planning relies. In many regions already, DER penetration is reaching levels at which it has a measurable impact on system planning and operations.
DER adoption is driven by three major developments:
- Advances in technologies that accommodate multi-directional, rather than uni-directional, power flows
- Fundamental shifts in generation, distribution and transmission grid profiles
- Changing, “more democratic” concepts about the relationship between utility service models and customer pricing
DERs, though, are not just one thing; rather, they are many things. Therefore, a treatment of the system impacts of DER must address several elements that comprise DERs, and how they produce different impacts. This program is a primer. It is intended to collect — in one forum — the content necessary for utilities, load-serving entities (LSEs), grid operators, project developers and others to develop their own approach for evaluating the impact of DG and DER development on their system(s). The course will provide a useful cross-disciplinary blueprint for reference, adaptation and refinement of DER strategies and implementation measures.
- Evaluate the different types and classes of DERs and their special requirements
- Identify the operational differences between renewable and conventional energy DERs
- Review regulatory matters that determine how DERs are governed on a jurisdictional basis
- Examine long-term planning assessment and analysis that properly incorporates DERs
- Discuss challenges that DERs present to existing utility compacts/business models and what options are available to address these issues
- Assess system data access and transparency requirements to facilitate DERs
- Evaluate operational tools required for real-time DER modeling and forecasting
- Discuss DER interconnection issues at the distribution, sub-transmission and transmission levels
EUCI has been accredited as an Authorized Provider by the International Association for Continuing Education and Training (IACET). In obtaining this accreditation, EUCI has demonstrated that it complies with the ANSI/IACET Standard which is recognized internationally as a standard of good practice. As a result of their Authorized Provider status, EUCI is authorized to offer IACET CEUs for its programs that qualify under the ANSI/IACET Standard.
EUCI is authorized by IACET to offer 1.0 CEUs for this course and 0.4 CEUs for the workshop.
Requirements For Successful Completion Of Program
Participants must login for the entirety of the course to be eligible for continuing education credit.
Case studies and PowerPoint presentations will be used in this program.
Wednesday, February 24, 2021 : Central Time
8:15 – 8:30 a.m. :: Log In and Welcome
8:30 a.m. – 4:45 p.m. :: Course Timing (Includes breaks)
12:00 – 12:45 p.m. :: Group Luncheon
Overview and Introductions
Description and Characteristics of DERs by Type
- Customer-sited generation
- Aggregated DR / load management
Long-term DER Trends and Drivers
- RPS mandates
- Utility self-directed
- Business self-directed
- Renewable energy economics and market pricing
DER-Relevant Regulatory Policies
- State Commissions
- Tariff policies
- Utility implementation latitude
- Non-utility engagement
- Federal Energy Regulatory Comm’n (FERC)
- Order 2222
- Business implications
- North American Electric Reliability Corp (NERC)
- RTOs/ISOs and other electricity markets
- Federal non-oversight measures
- Tax policies
- Tariff policies
DER Rate Considerations and Developments
Operational Impacts on Distribution System
- System stability and protection
- Power quality maintenance
- Voltage and frequency fluctuation
- Load masking
- Situational awareness
- Net locational benefits
- Hosting capacity
- Grid security
DERs on the Transmission Network / Bulk Power System
- Relevant codes and standards
4:45 p.m. :: Program Adjourns for Day
Thursday, February 25, 2021 : Central Time
8:15 – 8:30 a.m. :: Log In
8:30 – 11:45 a.m. :: Course Timing (Includes breaks)
Accessing, Managing and Scheduling DERs on the Power System
- Control and networking paradigms
- De-centralized / none
- Third-party aggregators
- Virtual power plants
Utility DER Analytical, Modeling and Forecasting Tools
- Determining impact studies required
- DER planning and roadmaps
- System power flow modeling
- Hosting capacity requirements and availability
- Interconnection aspects
- Mitigation measures identification for protection/safety limit violations
- Valuing locational costs and benefits
- Monitoring and control options and requirements
- Infrastructure requirements for DER
- Revenue impacts from DER
Utility Adaptation to Detect and Manage DER System Interaction
- DERMS (Distributed Energy Resource Management Systems)
- What it is
- How it works
- Where it’s deployed
- Other tools
- Case studies
- Best practices
11:45 a.m. :: Course Adjournment
DERs in Wholesale Electricity Markets
Thursday, February 25, 2021 : Central Time
Well, it’s about time! Many in the power industry would say that FERC’s recent Order 2222 – which is prodding the country’s system operators to actively accommodate distributed energy resources bidding into wholesale power markets – is long overdue. Be that as it may, over the next two years ISOs, OEM, market participant, economist and stakeholder elves will be hard at work in Santa’s workshop. They will be formulating structures, processes and systems to facilitate the participation of these resources in a financially sustainable manner. The ultimate beneficiary, of course, is the grid.
This workshop will efficiently lay out 1) the mechanics of the FERC Order, 2) what it is intended to achieve, 3) how the concept is to be translated into market mechanisms, and 4) what the impact is likely to be on market participants and distribution utilities. Though the actual implementation details will be formed up by the individual ISOs for submittal, review and action by the FERC, parties to that process will find this workshop beneficial as they weigh how to engage in that process.
- Discuss the elements of FERC Orders 841 (and especially) 2222
- Identify the key items that ISOs must address as they develop their implementation proposals for FERC review and action
- Evaluate specific challenges and opportunities with respect to creating a level playing field for DERs to bid into to each ISO
- Examine possible impacts on default and distribution utilities as DERs gain traction in the wholesale power markets
- Assess the prospective impacts on DER, aggregator, generator, transmission, financial and other market participants
12:15 – 12:30 p.m. :: Log In
12:30 – 4:45 p.m. :: Course Timing (Includes breaks)
Overview & Introductions
Survey of Relevant FERC Orders
Focus on FERC Order 2222
- What the Order allows
- How it will be implemented
- Administrative timeline
- What ISOs must do
- What is provided for DER aggregations and aggregators
- Examine technical and market components
- Discuss the coordination requirements that involve
- DER aggregator
- Distribution utility
- Electric retail regulatory authority(ies)
Specific ISO Challenges and Opportunities
- Midcontinent ISO
- PJM Interconnection
Potential for Different Classes of DERs
- Front of the meter resource
- Behind the meter resource
- Standalone resource
- Aggregated resource
Impact on Default and Distribution Utilities
- Transmission capacity
- Interconnection path
- Visibility on system
- Value streams and access
- Metering and technology sufficiency
4:45 p.m. :: Workshop Adjournment
Daniel Haughton, Manager – Distribution Engineering and DER Interconnections, Arizona Public Service (APS)
Daniel Haughton is Manager of Distribution Engineering and DER Interconnections at Arizona Public Service (APS). He manages teams that plan the future distribution infrastructure for the rapidly growing state of AZ, as well as residential and commercial renewable technology integration. He has worked at Arizona Public Service (APS) since 2012 in various engineering and technical leadership roles, including Transmission Planning, Transmission Operations Engineering, and Distributed Energy Resource (DER) Engineering. Dr. Haughton is also an advisor to EPRI and NREL Technical Advisory Committees on DER Interconnection practices and Distribution Planning Modernization. Before joining APS, he served in various roles at Tampa Electric, CAISO, Intel Corp and Belize Electricity Limited. He is an adjunct professor of electrical engineering at Arizona State University.
Aram Shumavon, CEO, Kevala, Inc.
Aram Shumavon is co-founder and CEO at Kevala Analytics. He has more than 15 years of experience in regulated energy markets, with a focus on high penetration distributed and renewable energy resources. Prior to forming Kevala, he was the founder and executive director of the non-profit organization, Distributed Energy Consumer Advocates. He has helped develop state and federal policy, managed the development of regulatory strategies, and created innovative market infrastructure and policy analysis tools. Mr. Shumavon’s work includes more than a decade as a senior analyst at the California Public Utilities Commission where he headed the state’s analysis of key wholesale electricity market design and environmental compliance efforts and led long-term procurement and planning efforts focused on California’s high renewables penetration future and renewables integration strategies.
Our courses are designed to be the best possible use of your valuable time – get the information you need to improve your position in the market in an interactive, dynamic format.
We will be using Microsoft Teams to facilitate your participation in the upcoming event. You do not need to have an existing Teams account in order to participate in the broadcast – the course will play in your browser and you will have the option of using a microphone to speak with the room and ask questions, or type any questions in via the chat window and our on-site representative will relay your question to the instructor.
- You will receive a meeting invitation will include a link to join the meeting.
- Separate meeting invitations will be sent for the morning and afternoon sessions of the course.
- You will need to join the appropriate meeting at the appropriate time.
- If you are using a microphone, please ensure that it is muted until such time as you need to ask a question.
- The remote meeting connection will be open approximately 30 minutes before the start of the course. We encourage you to connect as early as possible in case you experience any unforeseen problems.
Please Note: This event is being conducted entirely online. All attendees will connect and attend from their computer, one connection per purchase. For details please see our FAQ
If you are unable to attend at the scheduled date and time, we make recordings available to all registrants for three business days after the event
|Single Connection - The Impact of Distributed Energy Resources on the Power System and Electricity Markets||US $ 1295.00|
|Pack of 5 connections||US $ 5,180.00|
|Pack of 10 Connections||US $ 9,065.00|
|Pack of 20 Connections||US $ 15,540.00|
|Call us at 303.770.8800 if you have any specific questions on the volume discounts|
|* all other discounts do not apply to license packs|
This event has the following workshops:
|DERs in Wholesale Electricity Markets||US $ 495.00
Take advantage of these discounts!
- Attend the Course and workshop and pay US $ 1,695.00 per attendee (save US $ 95.00 each)
Your registration may be transferred to a member of your organization up to 24 hours in advance of the event. Cancellations must be received on or before January 22, 2021 in order to be refunded and will be subject to a US $195.00 processing fee per registrant. No refunds will be made after this date. Cancellations received after this date will create a credit of the tuition (less processing fee) good toward any other EUCI event. This credit will be good for six months from the cancellation date. In the event of non-attendance, all registration fees will be forfeited. In case of conference cancellation, EUCIs liability is limited to refund of the event registration fee only. For more information regarding administrative policies, such as complaints and refunds, please contact our offices at 303-770-8800