The U.S. needs a plan to transfer electricity long distance between regions, like Europe and China
The U.S. needs a plan to transfer electricity long distance between regions, like Europe and China
February 9, 2023 by Mathias Einberger
The Myth
The Reality
Illustration of major planning boundaries within the US power grid / SOURCE: RMI illustration of RTO and non-RTO regions (including ERCOT), approximated based on FERC Order 1000 transmission planning regions, balancing authorities are based on HIFLD. The map was created in QGIS.
As Aaron Bloom, Executive Director of NextEra Energy Transmission, LLC put it at a recent FERC workshop on the matter, “The United States is the only macro grid in the world that doesn’t have a plan of any type.” Indeed, both the European Union and China have continental-/national-scale grid development plans. The United States does not.
Increasingly frequent high-stress weather events
This type of fragmented planning framework is highly problematic, because the power grid is under growing stress from climate change-related extreme weather. High-stress events like winter Storm Elliot — the extreme cold snap that blitzed much of the nation at the end of last year — or Winter storm Uri in 2021, which led to over 210 deaths, caused almost 70 percent of Texans to lose power and 50 percent to lose water, and cost at least $80 billion, are becoming increasingly frequent. The associated weather patterns are much larger than our current fragmented grids and grid planning regions, which therefore struggle with the coordinated response needed to future-proof our vital power supply system.
Number of hours below freezing during Winter Storm Uri (Feb 12-19, 2021) / SOURCE: Greg Carbin / National Weather Service / National Oceanic and Atmospheric Administration, Public domain, via Wikimedia Commons
Luckily, FERC is working on solutions
Last year, FERC issued a Notice of Proposed Rulemaking (NOPR) that, if adopted, will go a long way in fixing many of the hurdles that plague planners within the 11 FERC transmission planning regions. However, the Commission has yet to take similarly strong action to fix planning between those regions. As a first important step, FERC convened a host of experts on December 5 and 6, 2022 to discuss how it can help improve this type of inter-regional planning.
In that workshop, researchers, industry leaders, regulators, advocates, and other experts discussed key regulatory and technical questions related to how FERC can best spur additional beneficial “inter-regional transfer capability” — the ability to move power between regions. Importantly, there was near-unanimous consensus among the diverse group of experts that increasing today’s limited capabilities to transfer power between regions would bring multiple massive benefits for the US power grid and its customers. From more efficient power plant operation on normal days to ensuring the lights will stay on even during the most challenging periods, inter-regional transfer capability means that neighbours can efficiently share resources and help each other out in a pinch. However, several key questions remain, three of which are summarised below.
Three questions on Inter-Regional Transmission
First, FERC was asking whether it should mandate a minimum amount of power transfer capability between regions, or if it should require a planning process for neighbouring regions to figure out the right transfer capability between them for themselves.
Rob Gramlich, founder and president of Grid Strategies, advocated for a hybrid approach. This would include both a minimum floor set by FERC and provide for a robust inter-regional planning process, through which neighbouring regions would jointly identify additional beneficial inter-regional transmission solutions. Others added that harmonised regional planning standards set by FERC are also desperately needed to facilitate joint planning between willing regions on an equal footing.
Second, the panellists debated whether FERC should set a minimum requirement based on a simple metric. The EU for instance simply asks its member states to enable at least 15 percent of installed electricity production capacity to be deliverable to their neighbours by 2030. However, some panellists argued that complex modelling, potentially involving supercomputers, was needed to robustly quantify all the diverse benefits of improved inter-regional connectivity. Others pointed out that the reliance on simplified metrics, such as the common 1 day in 10 years loss of load expectation standard used for resource adequacy modelling, has long been an established practice in power system planning.
Last, and certainly not least, there was of course debate of the old question “who pays” for the new power lines. It is an established FERC principle, affirmed by the courts, that costs should be allocated at least roughly commensurate with the benefits received. Exactly how rough that cost/benefit calculation may be is however often subject to fierce debate. Furthermore, the cost allocation question here is closely connected to the modelling debate: how precise can and should the expected benefits of new inter-regional links be calculated to allow for a fair and at least roughly commensurate cost allocation?
A path forward
During the FERC workshop, Dr. Dev Millstein from the Lawrence Berkeley National Laboratory, highlighted both the difficulty and importance of forecasting rare but extreme events such as Winter Storm Uri. This is because the ability to transfer power between distant regions yields not only economic benefits on normal days, but also comes with a potentially enormous insurance value for emergency situations. According to a report from Grid Strategies and ACORE, one additional gigawatt (about one large transmission line) between ERCOT and the Southeastern US could have saved nearly $1 billion during winter storm Uri, while keeping the heat on for hundreds of thousands of Texans. Another report from the Energy Systems Integration Group shows inter-regional transmission yields multiple diverse benefits — from production and capital cost as well as emission savings, to resource adequacy and resilience benefits.
Therefore, FERC should require both a minimum amount of inter-regional transfer capability and a robust inter-regional planning process. Recognising the potentially life-saving insurance value of additional inter-regional transfer capability, the minimum requirement should be based on a robust yet simple and readily actionable metric. The increasingly urgent need to protect consumers from future disasters means that the cost allocation question needs to be resolved quickly. This would likely be best achieved by applying the same simple and broad cost socialisation as with any other public good.
However, FERC should not stop there. It should also mandate a robust inter-regional transmission planning process. This process should rely on forward-looking, multi-value, and scenario-based modelling to ensure regional planners identify and seize the multiple additional benefits of inter-regional transmission beyond a minimum requirement — and fairly allocate the associated costs commensurately. Because if the lights stay on when the storm hits, everyone wins.