New York Must Expand Solar: How Does Its New Net Metering Process Fit in?
Since 1997, New York has allowed customers with certain types of distributed generation systems, including rooftop solar (sometimes referred to as “mass market” solar) and community solar, to participate in net metering. This simple billing method allows a customer’s consumption and generation to be “netted” at the end of every month. If a customer has consumed more energy from the grid than she has generated from her solar panels, she will pay for the net consumption. However, if a customer has generated more power than she has consumed, then that net generation will be rolled over into the next month’s bill and credited toward future consumption at the retail rate—i.e. the same amount that the customer is charged for using a kWh of electricity.
This form of compensation (sometimes referred to as “retail rate net metering”) has supported solar expansion with a simple, predictable formula. However, because this form of net metering relies only on retail rates, which tend not to vary by time or location, solar systems are not always installed in areas where they are most needed or combined with other technology like energy storage to provide additional value to the grid. Some areas of the grid need more congestion relief, some hours of the day have higher electricity demand, and some distributed energy sources are cleaner than others.
New York has decided to move away from retail rate net metering and toward a smarter and fairer pricing scheme that reflects clean energy resources’ value to the grid. The state is now grappling with creating such a system while at the same time ensuring that this transition is gradual and understandable to consumers.
In 2015, the Public Service Commission (PSC) initiated the Reforming the Energy Vision (REV) process, which seeks to create a new utility business model that incorporates more distributed energy while ensuring that energy remains affordable, resilient, and reliable. Recognizing the need to develop a more accurate way of valuing these clean energy resources, in March 2017 the PSC issued an order transitioning from retail rate net metering to a net metering program referred to as Value of Distributed Energy Resources (VDER) that attempts to more accurately reflect the costs and benefits of these clean resources on the grid.
The first phase of the VDER process applies to larger solar installations including remote net metering (where the electricity produced from a solar installation at one location is credited toward electricity consumption at a different location) and community solar but not to residential rooftop solar. Phase One compensates these projects using a “Value Stack,” which identifies certain components that together represent the value of that clean energy to the grid. The values in the Phase One Value Stack include certain costs that the utility no longer has to incur, which are referred to as “avoided costs” and which are assigned a monetary value. These include:
- The cost of the energy that the utility would otherwise have to generate or purchase (referred to as “wholesale” energy);
- The amount of energy-producing resources that the utility would have to procure to meet demand (referred to as “capacity”); and
- The cost of delivering that energy to customers, as well as the higher costs of delivering the energy in certain congested areas of the grid.
In addition to these avoided costs, the Value Stack also includes a credit for the environmental attributes of certain types of clean energy, primarily the fact that they do not emit greenhouse gases.
A second phase of this transition (referred to as Phase Two Value Stack) is in process to further refine these values. After January 1, 2020, VDER will also apply to new residential rooftop projects under a new compensation method to replace traditional retail rate net metering.
New York’s Solar Gap
Because retail rate is a more straightforward, if blunt, method of net metering, developers may initially struggle to make an easy economic case for solar while transitioning to a value-based compensation structure. However, if done well, this new structure will allow solar to expand more efficiently in New York, with better outcomes for consumers and the climate. Continued expansion of solar is important, because in contrast to other Northeast states such as Massachusetts and Vermont, New York has relatively modest amounts of installed distributed solar given its population (Figure 1). It must accelerate to meet state and regional climate goals.
New York has set a goal of procuring 50% of its energy needs from renewable energy resources by 2030. As shown in Acadia Center’s EnergyVision 2030, with further strategic action New York can reduce greenhouse gas emissions 45% by 2030, a target that will put the state on a path to meet minimum EnergyVision 2030 recommends that, in addition to sharply increasing grid scale wind and solar generation, New York needs to add 13.7 GW of distributed solar, more than 10 times the amount that has been installed to date.
Figure 1 – Per Capita Installed PV
New York’s need for more distributed solar can be addressed from multiple angles: first, by making the transition to value-based compensation as gradual and understandable as possible; and second, by supporting solar expansion through complementary programs. Acadia Center has been an active participant in the VDER proceeding since its inception. Recently, staff from the Department of Public Service approved several changes to the Phase One Value Stack to expand the types of eligible renewable energy resources and make it easier for customers to participate and receive compensation. These changes include:
- Removing certain size limits from eligible clean energy resources
- Expanding the VDER compensation structure to storage and new forms of renewable energy such as tidal energy
- Removing location-based restrictions within utility territories
Acadia Center supported these changes and submitted comments with these and other recommendations for improving various elements of the value stack to make it easier for customers to receive compensation and to ensure these resources are appropriately compensated for the value they add to the system.
Acadia Center also supports solar expansion in New York through statewide initiative and grassroots campaigns. One such state initiative is NY Sun, a program administered by NYSERDA that seeks to add 3 GW of installed solar capacity in the state by 2023. The program works by establishing cash incentives for developers that decline over time as solar installation increases in certain regions of the state. Recently, NYSERDA made improvements to the program by expanding the incentives, supporting larger projects, and encouraging solar installations in a greater variety of locations. In addition, Acadia Center is a founding member of Million Solar Strong, which seeks to double this statewide goal to 6 GW of solar capacity by installing solar on 1 million homes by 2023, including 100,000 low-income households. The campaign has been meeting with public officials and building support around the state.
New York must make the leap to close its solar gap, and both regulatory solutions and grassroots support will be necessary. Together, these efforts have the capacity to make lasting change for this key technology.
How Can We Replace Traditional Infrastructure with Clean Energy?
In March, Acadia Center released an analysis demonstrating that outdated financial incentives are driving expenditures on expensive and unnecessary utility infrastructure and inhibiting clean energy in the Northeast. The report, Incentives for Change: Why Utilities Continue to Build and How Regulators Can Motivate Them to Modernize, shows that under current rules, utilities can earn more money on infrastructure expenditures like natural gas pipelines and electric transmission lines than on cleaner, local energy resources like energy efficiency, rooftop solar, and highly efficient electric heat pumps. The key takeaway from the analysis is that without changes to the way they are regulated and rewarded, utilities will continue to advocate for infrastructure over local energy resources because their fiduciary duty to shareholders requires it.
Meanwhile, experience throughout the Northeast shows that clean, local energy resources can replace expensive grid infrastructure proposed by utlilities. These local alternatives include energy efficiency and demand response technologies that reduce demand for electricity at specific times, as well as roof-top solar, battery storage, and efficient combined heat and power.
Energy efficiency investments alone have avoided over $400 million in major transmission upgrades in Vermont and New Hampshire.1 Similarly, the Tiverton/Little Compton pilot project in Rhode Island,2 the Brooklyn/Queens Demand Management Project in New York,3 and the Boothbay Smart Grid Reliability Project in Maine4 are real world examples of local clean energy resources deferring or avoiding upgrades to the distribution grid. Earlier this year, expert witnesses for the New Jersey Division of Rate Counsel argued that a $75 million, 10-mile transmission line is no longer needed due to increasing adoption of distributed generation.5 There are additional examples from California also, where the state’s grid operator (California Independent System Operator, or CAISO) announced in December 2016 that it is putting the Gates-Gregg 230 kV transmission line project on hold, and may cancel the project entirely, due to forecasted increases in the development of solar energy.6
These clean energy projects are possible when consumers are given the ability to shape a cleaner, lower cost energy system through their investment decisions and behaviors. To motivate utilities to give consumers these options, utility regulators need to adopt alternative economic structures that balance the need to bring clean energy resources on-line with the need to keep utilities financially healthy.
Acadia Center’s UtilityVision outlines an alternative economic structure to resolve this conflict. UtilityVision recommends that states adopt performance incentives to motivate utilities to advance priorities such as system efficiency, grid enhancements, distributed generation, energy efficiency, and other energy system goals. Regulators can then increase the portion of revenue recovered through those performance incentives while reducing the portion of revenue that is linked to infrastructure projects, helping to shift utility priorities further towards achieving the performance outcomes.
A handful of states are beginning to adopt reforms to focus the utility’s financial incentives on advancing public policy goals for clean energy development. On January 25, 2017, the New York Public Service Commission issued an Order approving a shareholder incentive to reward Con Edison for deploying distributed energy resources (DER) to defer or avoid traditional transmission and distribution projects and deliver net benefits to ratepayers. The PSC approved a shared-savings model that uses a benefit-cost framework to determine the difference between the net present value of DER and the traditional infrastructure solution. The PSC found that this reward structure effectively signals the utility to find the most cost-effective grid solutions for ratepayers and advances additional energy and environmental goals.7
The California Public Utilities Commission is taking similar steps to resolve the conflict between bringing more DER online and ensuring they do not harm utilities’ profits. In December 2016, Commissioner Florio issued an Order creating a model to financially incentivize utilities to adopt DER. The Order will incentivize the deployment of cost-effective DER that displaces or defers utility spending on infrastructure by offering the utility a reward equal to 4% of the payment made to the DER customer or vendor.8
Whether the New York and California model is the best of many ways to revamp the utility business model to incorporate DER is an open question. One limitation of this model is that it is based on a comparison between DER and the traditional infrastructure projects that would otherwise be built in their place. This model makes it relatively straightforward to compensate the utility based on the cost savings and greater net benefits from the DER solution, but it is not easy to apply to more general deployment of DER. For instance, in Rhode Island,9 stakeholders led by the Office of Energy Resources are considering how to reward the utility for proactively and strategically using DER to improve grid conditions and prevent problems before the grid gets to the point of needing infrastructure upgrades. In this case, the NY/CA model can’t be used because there isn’t a traditional infrastructure project to compare to the proposed DER.
States must continue to seek reforms to utility regulations so that clean energy can flourish and both consumers and utilities are treated fairly. Replacing poles, wires, transformers, and substation upgrades with rooftop solar, battery storage, demand response, and energy efficiency can reduce costs and make the grid cleaner—but utilities make a guaranteed rate of return on their million (and billion) dollar grid investments, and any lower cost DER alternatives threaten to undercut those revenues. Until a new system of incentives is created, it will be an uphill battle to achieve states’ goals for a lower cost, cleaner energy grid.
1Schelgel, Hurley, and Zuckerman, 2014, “Accounting for Big Energy Efficiency in RTO Plans and Forecasts: Keeping the Lights on While Avoiding Major Supply Investment.” http://aceee.org/files/proceedings/2014/data/papers/8-1215.pdf
2 Rhode Island Public Utilities Commission Docket No. 4581, “2016 System Reliability Procurement Report”. October 2015. http://www.ripuc.org/eventsactions/docket/4581-NGrid-2016-SRP(10-14-15).pdf
3 New York Public Service Commission Case 14-E-0302, “Petition of Consolidated Edison Company of New York, Inc. for Approval of Brooklyn Queens Demand Management Program.” June 15, 2014.
4 Maine Public Utilities Commission Docket No. 2011-238, “Final Report for the Boothbay Sub-Region Smart Grid Reliability Project.” January 19, 2016.
5 “Rate Counsel Sees No Need For High Voltage Transmission Line,” NJ Spotlight (Jan 19, 2017) available at: http://www.njspotlight.com/stories/17/01/08/rate-counsel-sees-no-need-for-high-voltage-transmission-line/
6 ”Solar Growth Puts Fresno High-Voltage Line on Hold,” Fresno Bee (Dec 20, 2016). Available at: http://www.fresnobee.com/news/local/article122063189.html
7 New York Public Service Commission, Case 15-E-0229, Petition of Consolidated Edison Company of New York, Inc. for Implementation of Projects and Programs that Support Reforming the Energy Vision, Order Approving Shareholder Incentives. January 25, 2017. http://documents.dps.ny.gov/public/MatterManagement/CaseMaster.aspx?MatterSeq=47911
8 California Public Utilities Commission, Decision 16-12-036, Rulemaking 14-10-003, Order Instituting Rulemaking to Create a Consistent Regulatory Framework for the Guidance, Planning, and Evaluation of Integrated Distributed Energy Resources. December 22, 2016. http://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M171/K555/171555623.PDF
9 More about Rhode Island’s Power Sector Transformation initiative can be found at: http://www.ripuc.org/utilityinfo/electric/PST_home.html
NH Regulators Order DER Study; Cut Net Metering Credits
One settlement proposal came from a coalition of utilities and consumer parties (UCC), including Eversource Energy, Liberty Utilities, Unitil Energy Systems, the state Office of Consumer Advocate, the New England Ratepayers Association, Consumer Energy Alliance and Standard Power of America.
The other proposal was filed the same day by a coalition of distributed generation industry advocates and environmental organizations known as the Energy Future Coalition (EFC), which included the Acadia Center, The Alliance for Solar Choice, the Conservation Law Foundation and eight other organizations and companies (docket DE 16-576).
New York Proposes New Rates for Distributed Energy
This blog was co-authored with Miles Farmer, Clean Energy Attorney at Natural Resources Defense Council.
The New York Department of Public Service has proposed to change the way distributed energy resources (like community solar and small wind projects) are rewarded for the benefits that they provide to the electricity system. The Department released a landmark report in its “Value of Distributed Energy Resources” proceeding, recommending a methodology by which these resources can receive credits that align more closely with their true value to the electricity system. Acadia Center and NRDC have been involved in the collaborative process around the report’s creation, and here we examine what these proposed reforms hope to accomplish, give initial feedback, and look toward next steps.
This report marks the latest step in the state’s ambitious Reforming the Energy Vision (“REV”) initiative. REV aims to create a more consumer-centric, efficient, resilient, and cleaner energy system. The Department’s report focuses on reforming an electricity rate structure known as “net energy metering,” where credit for clean energy generation is set equal to the retail rate. Reforms to net energy metering have been a controversial topic across the country for the last several years. Some states have proposed successful new approaches. California, for example, is phasing in time-of-use rates for most customers that recognize when electricity generation is most valuable.
From the outset, New York’s Value of Distributed Energy Resources proceeding has sought to better align credits for community solar and other distributed generation resources with their value to the system. New York’s current net energy metering policies are simple, easy for customers to understand, and have proved to be effective incentives for investments in clean energy, so revising methods for net metering presents risks. A new ‘value-based’ crediting system is more complex by its very nature. But if done correctly, aligning credits more closely with benefits created by distributed generation has the potential to incent more efficient investments in the electric system. Acadia Center discusses value-based crediting here.
The staff report is a good start to a long-term iterative process. Throughout this process, Acadia Center and NRDC will be closely analyzing the report and offering recommendations for improvement. On first review, Acadia Center and NRDC find that the report recommends many approaches to important issues that are worthy of support:
- It protects existing projects from unexpected changes and allows mass market development of small rooftop projects to continue under traditional net energy metering, providing continuity.
- It provides credit to projects for their environmental value, with a floor at the social cost of carbon, pursuant to the New York Public Service Commission’s previous Benefit-Cost Framework Order.
- It provides for a ‘market transition credit’ that incorporates some values that cannot be accurately calculated at this time, recognizing limits in current techniques to estimate the value of benefits provided by distributed energy resources.
- It adopts monetary crediting, where each kilowatt hour generated is translated into a monetary amount based on the value it provides. This approach is more flexible and allows for smarter pricing than traditional volumetric crediting (which tracks only the amount of electricity generated and cannot accommodate details like the time at which the electricity was generated).
When creating a “value-based” crediting system like the Department’s proposal, the most difficult task is to develop a method for calculating the value of each of the benefits that distributed energy resources can provide. These benefits include energy, capacity (the availability of the system to provide electricity at times of peak demand), transmission and distribution value (because distributed energy resources like rooftop solar reduce the need for infrastructure to send electricity to customers), environmental and public health value, and other values that are more difficult to quantify. In practice, there are many ways to define and calculate the value of each of these components. However, the precise methods chosen have significant consequences for what investments will be made and how resources will be operated. Certain methods offer different tradeoffs. For example, using dynamic credit values may allow a resource to respond in real time to system needs, but they set less predictable values that might prevent investors from putting capital into beneficial resources.
The staff report effectively balances these goals in a manner that should facilitate continued growth of the solar industry in New York. It provides a good framework for further refinement, and we look forward to working with the Department and other parties to evaluate it further and carry out additional improvements.
The report also reflects the inclusive approach taken by the New York Department of Public Service. The Department facilitated a collaborative process to allow utilities, solar developers, customer representatives, environmental groups, and others to work together and provide input on a variety of issues including how the values of these different components should be calculated. Department staff has listened carefully to the concerns of all parties, including a range of detailed suggestions by Acadia Center and NRDC.
New York’s approach to valuing distributed energy resources is new and innovative, and regulators in states across the country will be examining it closely. We look forward to continuing to work collaboratively on these important issues as New York refines its proposal and builds upon it in future years.
Video: Energy policy a top issue in campaign
“Obviously, we still have a ways to go,” said Jordan Stutt, policy analyst for the Acadia Center. “We’re still pretty dependent on some fossil fuels, but as we continue to invest in new energy technologies — as those costs come down, as we build out the infrastructure for distributed energy generation — I think we will be able to achieve that goal.”
Watch the news report and read the full article from WMUR here.
Mass. Regulators Reject DER Surcharge in Rate Case
Several intervenors contended that the proposal ran contrary to Massachusetts’ efforts to have its rate design more accurately reflect market conditions.
“Reforms to electricity rate design must strike a careful balance between economic efficiency, equity for all customers, protection of low-income ratepayers and access to community distributed generation,” Mark LeBel, staff attorney at Acadia Center, said in a statement.
Read the full article from RTO Insider here.