By Josh Duckwall, GDS Project Manager
The role of energy efficiency in the modern utility industry is very simple. The goal is to incent utility customers to invest in a more efficient product or service than they normally would, something better than the business as usual case. The problems begin if a program incentivizes too little and it ends up with no participation and no measurable demand reduction or incentivizes too much and the program becomes oversubscribed and unattainable.
Historically, the onus to improve efficiency has been marketed downstream to the end user, residential or commercial/industrial participants, who either take advantage of utility buy-down programs at the point of purchase or submit rebate applications for facility improvements. While these are highly effective methods to reduce the carbon footprint and total operating cost of a generating utility, a more aggressive and direct approach to target the energy production sources and electric distribution facilities efficiency is gaining in popularity throughout the country. As utilities work to find new markets to target for achieving efficiency goals, this generation and distribution sector remains largely untapped for incentivizing.
GDS worked with the Minnesota Department of Commerce (“MDC”) to develop a number of measures for inclusion in the stateTechnical Reference Manual (TRM) that outline achievable energy savings for certain energy infrastructure and generation improvements. Through a stakeholder consensus effort that included utilities and advocacy groups, the MDC determined that there are quantifiable efficiency gains available in certain upgrades that are above and beyond typical “business as usual” type utility infrastructure maintenance activities. Now on to the more difficult parts of the program, assigning deemed savings values that are justified, from the facility level all the way back to the generation plant and any significant point in between.
So how did the MDC showcase intentional energy savings that far upstream?
Stakeholder groups are the most important voice when determining what is both technically accurate and widely valuable to Minnesota ratepayers and citizens. A successful project of this type begins by creating a master list of all of the potential measures in the applicable sector such as transformer replacement, reconductoring lines, turbine resizing, all the way down to VFDs on pumps and cooling tower fans. The open forum allows for a documented record of opinion where the ratepayers can agree or disagree with the value in upstream improvements, along with the basis of any concerns. Involving the stakeholder groups through the use of multiple forums throughout the process has given the Minnesota project team a boost in speed for moving the measures forward, bringing any issues with policy, rate recovery, or calculation methodology to the front of our project timeline. Past experience has shown these conversations are typically fruitful and productive, even in instances where stakeholders may sit on two different sides of an issue such as the proposed EPA Clean Power Plan and potential ways to prepare for it.
Fortunately, the basic design of infrastructure equipment has been vastly unchanged in recent decades and the methods used today are rooted in solid engineering principles, making the efficient case very easy to define.
In theory, as long as the utility uses the TRM set of algorithms, they are protected from evaluations that question the accuracy of the results, and the need for unique engineering calculations for each rebate application. MDC took the design of the algorithms and determination of the background source information very seriously to make implementation and evaluation a non-issue.
The Minnesota TRM project is employing “Smart Measure” formatting, a design approach provided by a sub-contractor to the state of Minnesota, Energy Platforms. Historically, TRM documents are complicated and lengthy books without a standard format, making it very difficult for a utility planner to determine the deemed savings of a measure and increasing the potential for calculation error. One viable solution is to build these infrastructure measures in a cloud based system where the algorithms and variables are pre-loaded into the database for the utility client. Doing so removes a large portion of the error risk and allows the State or region commission the opportunity to adjust the variables based on comment round or error, without reissuing another TRM version. This streamlined approach is gaining in popularity as the utility commissions or State agencies do not need to perform annual TRM measure update exercises and it certainly allows for more transparency into the savings calculations behind the rebates, at least as much as is desired.
A TRM simplifies utilities’ effort to design energy efficiency programs and streamlines the process of identifying potential energy efficiency projects and spurring their adoption. States like Illinois have already included the types of measures into their TRM that provide for infrastructure incentives, and there is an increased awareness of the national grid as brought to light by significant weather and reliability concerns. As the efforts to repair and update the aging infrastructure are going to continue for the foreseeable future, the time is right to provide these incentive options and reap the benefits for the long term.
Utility infrastructure is a ripe target for harvesting energy efficiency, and small changes can have large effects. Infrastructure is used almost continuously, such that any improvements in efficiency will achieve energy and demand savings every hour of every day. Additionally, utilities do not need to design complicated strategies to market programs and entice customer participation; utilities can directly implement efficiency projects themselves.
So what is holding it all back? On paper these are more complicated projects, less standard calculations, and much closer to custom than prescriptive when considering typical Commercial, Residential, and Industrial measures. Further, generation utilities already have a business case to invest in somewhat efficient infrastructure. Utilities can only charge for electricity delivered to customers’ meters, so any inefficiencies in the delivery system commonly equate to higher fuel costs.
The day is fast approaching that lighting energy use is no longer a hot conference topic at the national energy efficiency consortiums and has been replaced by a lecture series on what homeowners can do to help the Internet of the Utility Grid.
Adding to those concerns is that infrastructure incentive projects will displace programs that target customers from the residential and commercial/industrial sectors. One major generation project may achieve as much savings as an entire residential lighting program in a given year, so in an environmental compliance situation for a State government (theoretical) it would reason that all available budget should be focused on the project with the largest emissions reduction estimates. This is based highly on speculation through, given the greater threat to common end user programs us the advancement of technology and the speed at which current technology is becoming obsolete. The day is fast approaching that lighting energy use is no longer a hot conference topic at the national energy efficiency consortiums and has been replaced by a lecture series on what homeowners can do to help the Internet of the Utility Grid. Such infrastructure improvements are just as entitled to recognition for efficiency efforts as the next smart toaster, and it is high time to share the spotlight.
For more information or to comment on this article, please contact:
GDS Associates, Inc. – Marietta, GA
770.425.8100
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