The sunshine state was ranked second in solar installations by capacity last year, falling behind only Texas. That’s a lot of new distributed energy – and Duke Energy, with its presence in the state as Duke Energy Florida, has plenty to share about the distribution grid of the future, DER management, and more at DTECH (formerly known as DISTRIBUTECH), convening from March 24-27, 2025 in Dallas, Texas.
Below is a breakdown of DTECH sessions from Duke Energy. Register here to secure your spot, and we’ll see you in Dallas!
Duke Energy
March 24
UU202: Regulating and optimizing voltage and vars on the distribution grid of the future
This Utility University course is open to any attendee with an all-access or utility all-access badge. These courses are first come, first served onsite in Dallas, however, pre-registration is still required. To pre-register, please visit the registration resource center or reach out to [email protected].
Distribution feeder circuits have traditionally been designed as radial feeds, with the voltage the highest at the substation and the lowest at the end of the circuit. This allows the voltage to be the highest where the load is greatest and increases profitability for the utility. In today’s environment, this design greatly limits Conservation Voltage Reduction (CVR), as well as solar hosting capacity. For these technologies to be deployed with maximum benefit, the feeder circuit voltage needs to be the lowest at the substation and higher at the end of the feeder.
A concept denoted as “Flipping the Circuit” is introduced in this tutorial with a series of presentations that explore the need to flip the circuit, and how best to accomplish this. The recommended solution attempts to maximize the existing distribution infrastructure while allowing for advanced functionality to support the evolving distribution grid. The tutorial will discuss how to properly engineer the circuit for primary radial applications that can be tied via normal open points to other circuits. Changing feeder configurations either manually or with FLISR schemes impacts the operation of switched capacitor banks and voltage regulators and can lead to voltage violations. The tutorial also explores how the penetration of renewables connected to the distribution feeder impacts the voltage as well as the operation of voltage regulators and switched capacitor banks. The tutorial discusses the trend of no longer performing routine maintenance and how predictive maintenance can limit the exposure of failing equipment that causes outages and possible fires.
The tutorial also presents the centralized volt var optimization (VVO) technology that addresses the complexities of the distribution grid of the future. Impact of cyber-attacks on VVO systems, and how to address the cyber-attacks on field IEDs are discussed. Cost-Benefit Analysis of implementing VVO is also discussed. Verification, Assessment and Monitoring Requirements for CVR along with power quality are also covered in this tutorial. Finally, practical implementation of volt var optimization technologies deployed by electric power company along with performance results are presented.
Prerequisites:
- Basic understanding of the distribution grid
Acquired Knowledge:
- Why the need for voltage regulation
- When to use LTCs versus feeder regulation
- What switching method is best for capacitor banks
- How to coordinate capacitor banks with regulators
- What should be the desired power factor on the system
- What is required to have a voltage reduction system with CVR factors greater than 1
- Benefits of De-centralized and Centralized VVOs schemes
- How to prepare a ROI for the VVO and CVR
- How to validate the results for CVR and VVO
- How to increase DER hosting capacity of feeders
- How to coordinate Capacitor banks with DERs
- How to design the distribution system to better support residential DERs and EVs.
March 25
Duke Energy’s pursuit of grid-scale DER management
Duke Energy has a significant penetration of grid-scale distributed energy resources (DERs) that are both utility and third-party-owned/ operated. The penetration of DERs is expected to grow sixfold by 2035, resulting in the need for integrated and advanced capabilities for monitoring, forecasting, and controlling assets alongside visibility and transparency for owners and operators.
To solve this complex challenge, Duke Energy is implementing the moDERnize project, developing the operating model and platform to enable efficiency, reliability, and scalability in the way Duke integrates, models, monitors, forecasts, controls, and settles front-of-the-meter, grid-scale DERs. The project enhances transmission operations with look-ahead, real-time unit commitment, automatic generation control, and security-constrained dispatch capabilities. It also incorporates a forecasting platform to provide DER generation forecasts to operations in regular time intervals. Finally, the moDERnize initiative includes a suite of modules to manage DER contract details, visualize and report on generation and curtailments, and perform generation volume aggregation for validation and inquiries.
Through this initiative, the moDERnize project aims to unlock three types of benefits: avoiding costs with scale as DER penetration increases; enabling external stakeholders of over 700 DER sites to be partners with Duke Energy; enabling Duke Energy to achieve their carbon reduction goals.
PG&E, Duke Energy and PSEG on how AI/ Analytics is reshaping utility work
The panel will discuss how PG&E, Duke Energy, and PSEG are navigating the convergence of AI and generative AI, AR/ VR, analytics, and cloud, and how they have doubled down in their efforts on automation to drive value within their organizations.
Utility experts will share how they have successfully implemented these technologies in their organizations and have achieved tangible business outcomes. They will also provide guidance on how to identify the right target areas, choose the right technology, and get the right sponsorship within the organization to drive value.
Key Takeaways:
- Effective human-machine collaboration can drive productivity, safety, and quality of work effort thus producing better outcomes. Modern technologies can change the existing work methods for the better and offer advantages to both workers and utility.
- Utilities should invest in assessing, piloting, and adopting new technologies that promote human-machine collaboration within the organization to benefit from it and maximize business value.
- New ways of working require transparent communication, reskilling employees, bolstering confidence, and pursuing AI benefits wisely.
2024 election insights: Navigating policy impacts and perspectives for the energy sector
Every election presents potential changes in the federal and state energy landscape.
In this session, panelists will dive into the dynamic world of energy and grid policy and regulation following the 2024 election. Join us as we explore the possible shifts to shape the energy landscape at both federal and state levels. Hear how the election outcomes may impact grid policies and regulations through the lens of utility grid stakeholders, and policy and regulatory leads.
The industry is on a journey of strategic foresight as we navigate the intricate pathways of the evolving energy sector, share guidance, and weigh in on any new initiatives, executive orders, and agency updates, to steer through this grid modernization and digital transformative era.
March 26
How Duke Energy used generative AI for DER growth and grid reliability
The growth of generative AI (GenAI) has introduced new opportunities for electric utilities. We will explore how Duke Energy and Amazon Web Services (AWS) have partnered to build applications with GenAI that enable engineers to seamlessly connect enterprise data from different sources to perform meaningful analysis for use cases such as transformer health analysis or DER siting. We will also highlight how implementing AI and ML has helped Duke Energy better identify grid assets and fleet electrification opportunities.
We will show how recent advancements in the GenAI space have enabled a deeper and more robust user experience, allowing weeks’ worth of hard-to-do analytics to be completed in minutes via an interactive experience. Users can perform analysis against a variety of sources without worrying about data integrations, data joins, or AI/ML model selection and tuning at scale. This includes tabular data such as historical grid data accessed via SQL databases, asset maintenance reports in an enterprise knowledge base/vendor software systems, real-time telemetry data such as AMI/SCADA accessed via APIs, or external data such as county-provided real-estate parcel data.
Such analytics, made easier and faster with GenAI, is a critical enabler for adding gigawatts of DERs within the next five years, which is orders of magnitude more than the capacity added to date.
VPP, V2H, and DERs — separating fact from fiction
A lively and informative session that brings together leading experts in Virtual Power Plants (VPP), Vehicle-to-Home (V2H), and Distributed Energy Resources (DERs) to discuss and debate the realities and myths surrounding these transformative technologies. This session will draw on real world, development and operational experience to demystify common perceptions and provide a grounded understanding of these critical components in the modern energy landscape.
Key topics for discussion will include:
- VPP Lessons Learned: Explore criteria to achieve success and customer benefit (e.g. VPPs must be location-specific, integrated into utility software, reliant on AMI, etc.)
- Role of Utility Structure: Discuss the relative successes and challenges of VPP projects within vertically integrated utilities compared to those operating within competitive energy markets.
- The Impact of V2H on Residential Batteries: Debating whether Vehicle-to-Home technology will render stationary residential batteries obsolete, considering both technological advancements and market trends.
- Business Viability of VPP-First Models: Evaluating the current viability and challenges of businesses that prioritize VPP solutions from inception.
- Role of AI and Machine Learning: Discussing whether successful VPP and V2G operations can thrive without the integration of advanced AI and machine learning technologies, or if these tools are indispensable.
Transforming power & utilities with AI – a thought leadership conversation
In an era where the energy landscape is rapidly evolving, the integration of Artificial Intelligence (AI) and strategic partnerships are pivotal in transforming utility operations. This panel discussion brings together leaders from the power and utility sector and Microsoft to explore how AI-driven solutions are revolutionizing the way utilities operate.
March 27
Optimizing Energy & Utility Asset Management through Smart Streetlighting
Utilities and cities have been upgrading their streetlight assets to LED fixtures to realize significant energy efficiency savings. Along with these projects, adding network controls to the assets can enhance energy and asset management capabilities, operational efficiency and support community transformation.
Learn how Duke Energy and Memphis Light Gas and Water are utilizing lighting automation to achieve
- Significant cost savings from reduced energy consumption
- Increased O&M efficiencies through asset condition monitoring, outage alerts and diagnostics, and streamlined repair processes
- Sustainable economic investments and job creation. Enhanced public safety and aesthetics increasing urban development and livability.
Making the most of AMI: Data drives organizational decisions at Exelon and Duke
The utility industry has been facing new challenges in dealing with Big Data, in order to utilize them to improve decision-making and deploy smarter grid infrastructure. In the past decade, how to leverage AMI data for customer analytics, demand response, load research, and rate design, has become a top priority for the utility industry. The criticality of modernizing the load research process from a sample design to using 99% of data could lead to more intelligent rate design and better load forecasting both short-term and long-term at both the distribution and bulk system level.
In this panel, experts from Exelon, Baltimore Gas and Electric (an Exelon company), and Duke Energy will discuss how they leverage data from customer analytics to decarbonization planning. The panelists will discuss the successful experience of investing time and resources into unlocking AMI interval data and customer data to help with internal decision-making, customer programs and experiences, and grid readiness.
Key Takeaways:
- The new development of optimal products and services across demand response, energy efficiency, dynamic rates, and electric vehicles
- How the latest analytics can help a utility better understand each customer’s load shape
- Understand what is going on behind the meter
- Insights into large customers and better forecasting
- Electrification and the future of gas system planning
- How integrating electric and gas systems could offer a cost-effective and realistic approach to decarbonization
- Duke Energy’s autonomous smart charging to alleviate transformer loading
US electric vehicle (EV) adoption is surging, with no signs of slowing down. One major concern for utilities like Duke Energy is the health and performance of individual distribution transformers, given that every five additional EVs are equivalent to one net new utility customer. The impacts of increased demand and evolving load patterns can accelerate the aging and failure of transformers.
To address these challenges, Duke Energy’s Emerging Technology Office initiated the Neighborhood of Shared Charging (NOSC) Project. This project aims to understand the impact of simultaneous EV charging on distribution transformers and develop solutions for mitigating any issues. The project’s testbed includes a transformer, a range of smart and non-smart electric vehicle supply equipment (EVSE) from multiple vendors, as well as controlled and uncontrolled loads to emulate various operating scenarios. Additionally, meters and sensors were installed to achieve the highest level of observability. Out of the project came a distributed intelligence proof of concept that involves real-time metering, grid edge integration with support for various protocols (e.g., Modbus, DNP3, OCPP), and autonomous, low latency load balancing with EVSEs individually. All these features work together to efficiently manage electrical loads and address the challenges of increased EV adoption on the power grid.
This session will provide an in-depth examination of the NOSC project: the testbed design, technological decisions, encountered issues and their resolutions, lessons learned, and next steps. Through the discussion of specific distributed smart charge management use cases, we aim to identify parallels with other applications within the industry.
Evaluating resilience benefits from DER and storage projects: A case study from Duke Energy
Grid resilience relates to the ability of electrical systems to anticipate, absorb, adapt to, and recover from all threats, including high-impact, low-probability (HILP) disruptions. Increasingly, utilities and regulators are seeking to include distributed energy resources (DERs) as part of the overall framework to enhance grid resilience. However, the evaluation and screening of potential projects based on the quantification of resilience benefits is a significant challenge. While there is strong industry belief in the resilience benefits of DERs, there is no industry consensus on how to quantify and measure the value of these benefits.
As a part of its work in support of NCUC REPS, Duke Energy initiated a study to develop and apply a framework for analyzing its portfolio of potential DER projects and quantifying the resilience benefits of each project to inform project prioritization and selection of capital investment.
This session will cover the project and the methodology developed to evaluate technical and community-based characteristics of desirable DER projects from a resilience standpoint and how Duke Energy is applying the framework in its planning and decision-making. The presentation will also discuss the application of survey-based and input-output-based techniques to quantify direct and indirect customer benefits associated with customer interruption costs.
