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Electric vehicle batteries alone could satisfy short-term grid storage demand by as early as 2030 | Nature Communications
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EV batteries could complement RE generation by providing short-term grid services. However, estimating the market opportunity requires an understanding of many socio-technical parameters and constraints. We quantify the global EV battery capacity available for grid storage using an integrated model incorporating future EV battery deployment, battery degradation, and market participation. We include both in-use and end-of-vehicle-life use phases and find a technical capacity of 32–62 terawatt-hours by 2050. Low participation rates of 12%–43% are needed to provide short-term grid storage demand globally. Participation rates fall below 10% if half of EV batteries at end-of-vehicle-life are used as stationary storage. Short-term grid storage demand could be met as early as 2030 across most regions. Our estimates are generally conservative and offer a lower bound of future opportunities. Renewable energy and electric vehicles will be required for the energy transition, but the global electric vehicle battery capacity available for grid storage is not constrained. 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data-article-title="">Electric vehicle batteries alone could satisfy short-term grid storage demand by as early as 2030</h1> <ul class="c-article-author-list c-article-author-list--short" data-test="authors-list" data-component-authors-activator="authors-list"><li class="c-article-author-list__item"><a data-test="author-name" data-track="click" data-track-action="open author" data-track-label="link" href="#auth-Chengjian-Xu-Aff1" data-author-popup="auth-Chengjian-Xu-Aff1" data-author-search="Xu, Chengjian" data-corresp-id="c1">Chengjian Xu<svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-mail-medium"></use></svg></a><span class="u-js-hide"> <a class="js-orcid" href="http://orcid.org/0000-0002-2512-5876"><span class="u-visually-hidden">ORCID: </span>orcid.org/0000-0002-2512-5876</a></span><sup class="u-js-hide"><a href="#Aff1">1</a></sup>, </li><li 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class="u-js-hide"><a href="#Aff2">2</a></sup>, </li><li class="c-article-author-list__item c-article-author-list__item--hide-small-screen"><a data-test="author-name" data-track="click" data-track-action="open author" data-track-label="link" href="#auth-Kandler-Smith-Aff2" data-author-popup="auth-Kandler-Smith-Aff2" data-author-search="Smith, Kandler">Kandler Smith</a><span class="u-js-hide"> <a class="js-orcid" href="http://orcid.org/0000-0001-7011-0377"><span class="u-visually-hidden">ORCID: </span>orcid.org/0000-0001-7011-0377</a></span><sup class="u-js-hide"><a href="#Aff2">2</a></sup>, </li><li class="c-article-author-list__item c-article-author-list__item--hide-small-screen"><a data-test="author-name" data-track="click" data-track-action="open author" data-track-label="link" href="#auth-Mingming-Hu-Aff1" data-author-popup="auth-Mingming-Hu-Aff1" data-author-search="Hu, Mingming">Mingming Hu</a><sup class="u-js-hide"><a href="#Aff1">1</a></sup>, </li><li class="c-article-author-list__item c-article-author-list__item--hide-small-screen"><a data-test="author-name" data-track="click" data-track-action="open author" data-track-label="link" href="#auth-Arnold-Tukker-Aff1-Aff3" data-author-popup="auth-Arnold-Tukker-Aff1-Aff3" data-author-search="Tukker, Arnold">Arnold Tukker</a><span class="u-js-hide"> <a class="js-orcid" href="http://orcid.org/0000-0002-8229-2929"><span class="u-visually-hidden">ORCID: </span>orcid.org/0000-0002-8229-2929</a></span><sup class="u-js-hide"><a href="#Aff1">1</a>,<a href="#Aff3">3</a></sup> & </li><li class="c-article-author-list__show-more" aria-label="Show all 7 authors for this article" title="Show all 7 authors for this article">…</li><li class="c-article-author-list__item"><a data-test="author-name" data-track="click" data-track-action="open author" data-track-label="link" href="#auth-Bernhard-Steubing-Aff1" data-author-popup="auth-Bernhard-Steubing-Aff1" data-author-search="Steubing, Bernhard">Bernhard Steubing</a><span class="u-js-hide"> <a class="js-orcid" href="http://orcid.org/0000-0002-1307-6376"><span class="u-visually-hidden">ORCID: </span>orcid.org/0000-0002-1307-6376</a></span><sup class="u-js-hide"><a href="#Aff1">1</a></sup> </li></ul><button aria-expanded="false" class="c-article-author-list__button"><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-down-medium"></use></svg><span>Show authors</span></button> <p class="c-article-info-details" data-container-section="info"> <a data-test="journal-link" href="/ncomms" data-track="click" data-track-action="journal homepage" data-track-category="article body" data-track-label="link"><i data-test="journal-title">Nature Communications</i></a> <b data-test="journal-volume"><span class="u-visually-hidden">volume</span> 14</b>, Article number: <span data-test="article-number">119</span> (<span data-test="article-publication-year">2023</span>) <a href="#citeas" class="c-article-info-details__cite-as u-hide-print" data-track="click" data-track-action="cite this article" data-track-label="link">Cite this article</a> </p> <div class="c-article-metrics-bar__wrapper u-clear-both"> <ul class="c-article-metrics-bar u-list-reset"> <li class=" c-article-metrics-bar__item" data-test="access-count"> <p class="c-article-metrics-bar__count">50k <span class="c-article-metrics-bar__label">Accesses</span></p> </li> <li class="c-article-metrics-bar__item" data-test="altmetric-score"> <p class="c-article-metrics-bar__count">591 <span class="c-article-metrics-bar__label">Altmetric</span></p> </li> <li class="c-article-metrics-bar__item"> <p class="c-article-metrics-bar__details"><a href="/articles/s41467-022-35393-0/metrics" data-track="click" data-track-action="view metrics" data-track-label="link" rel="nofollow">Metrics <span class="u-visually-hidden">details</span></a></p> </li> </ul> </div> </header> <div class="u-js-hide" data-component="article-subject-links"> <h3 class="c-article__sub-heading">Subjects</h3> <ul class="c-article-subject-list"> <li class="c-article-subject-list__subject"><a href="/subjects/batteries" data-track="click" data-track-action="view subject" data-track-label="link">Batteries</a></li><li class="c-article-subject-list__subject"><a href="/subjects/environmental-sciences" data-track="click" data-track-action="view subject" data-track-label="link">Environmental sciences</a></li><li class="c-article-subject-list__subject"><a href="/subjects/renewable-energy" data-track="click" data-track-action="view subject" data-track-label="link">Renewable energy</a></li> </ul> </div> </div> <div class="c-article-body"> <section aria-labelledby="Abs1" data-title="Abstract" lang="en"><div class="c-article-section" id="Abs1-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Abs1">Abstract</h2><div class="c-article-section__content" id="Abs1-content"><p>The energy transition will require a rapid deployment of renewable energy (RE) and electric vehicles (EVs) where other transit modes are unavailable. EV batteries could complement RE generation by providing short-term grid services. However, estimating the market opportunity requires an understanding of many socio-technical parameters and constraints. We quantify the global EV battery capacity available for grid storage using an integrated model incorporating future EV battery deployment, battery degradation, and market participation. We include both in-use and end-of-vehicle-life use phases and find a technical capacity of 32–62 terawatt-hours by 2050. Low participation rates of 12%–43% are needed to provide short-term grid storage demand globally. Participation rates fall below 10% if half of EV batteries at end-of-vehicle-life are used as stationary storage. Short-term grid storage demand could be met as early as 2030 across most regions. Our estimates are generally conservative and offer a lower bound of future opportunities.</p></div></div></section> <section aria-labelledby="inline-recommendations" data-title="Inline Recommendations" class="c-article-recommendations" data-track-component="inline-recommendations"> <h3 class="c-article-recommendations-title" id="inline-recommendations">Similar content being viewed by others</h3> <div class="c-article-recommendations-list"> <div class="c-article-recommendations-list__item"> <article class="c-article-recommendations-card" itemscope itemtype="http://schema.org/ScholarlyArticle"> <div class="c-article-recommendations-card__img"><img src="https://media.springernature.com/w215h120/springer-static/image/art%3A10.1038%2Fs41467-024-48554-0/MediaObjects/41467_2024_48554_Fig1_HTML.png" loading="lazy" alt=""></div> <div class="c-article-recommendations-card__main"> <h3 class="c-article-recommendations-card__heading" itemprop="name headline"> <a class="c-article-recommendations-card__link" itemprop="url" href="https://www.nature.com/articles/s41467-024-48554-0?fromPaywallRec=false" data-track="select_recommendations_1" data-track-context="inline recommendations" data-track-action="click recommendations inline - 1" data-track-label="10.1038/s41467-024-48554-0">On the potential of vehicle-to-grid and second-life batteries to provide energy and material security </a> </h3> <div class="c-article-meta-recommendations" data-test="recommendation-info"> <span class="c-article-meta-recommendations__item-type">Article</span> <span class="c-article-meta-recommendations__access-type">Open access</span> <span class="c-article-meta-recommendations__date">16 May 2024</span> </div> </div> </article> </div> <div class="c-article-recommendations-list__item"> <article class="c-article-recommendations-card" itemscope itemtype="http://schema.org/ScholarlyArticle"> <div class="c-article-recommendations-card__img"><img src="https://media.springernature.com/w215h120/springer-static/image/art%3A10.1038%2Fs41560-022-01105-7/MediaObjects/41560_2022_1105_Fig1_HTML.png" loading="lazy" alt=""></div> <div class="c-article-recommendations-card__main"> <h3 class="c-article-recommendations-card__heading" itemprop="name headline"> <a class="c-article-recommendations-card__link" itemprop="url" href="https://www.nature.com/articles/s41560-022-01105-7?fromPaywallRec=false" data-track="select_recommendations_2" data-track-context="inline recommendations" data-track-action="click recommendations inline - 2" data-track-label="10.1038/s41560-022-01105-7">Charging infrastructure access and operation to reduce the grid impacts of deep electric vehicle adoption </a> </h3> <div class="c-article-meta-recommendations" data-test="recommendation-info"> <span class="c-article-meta-recommendations__item-type">Article</span> <span class="c-article-meta-recommendations__access-type">Open access</span> <span class="c-article-meta-recommendations__date">22 September 2022</span> </div> </div> </article> </div> <div class="c-article-recommendations-list__item"> <article class="c-article-recommendations-card" itemscope itemtype="http://schema.org/ScholarlyArticle"> <div class="c-article-recommendations-card__img"><img src="https://media.springernature.com/w215h120/springer-static/image/art%3A10.1038%2Fs41598-023-50825-7/MediaObjects/41598_2023_50825_Fig1_HTML.png" loading="lazy" alt=""></div> <div class="c-article-recommendations-card__main"> <h3 class="c-article-recommendations-card__heading" itemprop="name headline"> <a class="c-article-recommendations-card__link" itemprop="url" href="https://www.nature.com/articles/s41598-023-50825-7?fromPaywallRec=false" data-track="select_recommendations_3" data-track-context="inline recommendations" data-track-action="click recommendations inline - 3" data-track-label="10.1038/s41598-023-50825-7">Strategies and sustainability in fast charging station deployment for electric vehicles </a> </h3> <div class="c-article-meta-recommendations" data-test="recommendation-info"> <span class="c-article-meta-recommendations__item-type">Article</span> <span class="c-article-meta-recommendations__access-type">Open access</span> <span class="c-article-meta-recommendations__date">02 January 2024</span> </div> </div> </article> </div> </div> </section> <script> window.dataLayer = window.dataLayer || []; window.dataLayer.push({ recommendations: { recommender: 'semantic', model: 'specter', policy_id: 'NA', timestamp: 1739897277, embedded_user: 'null' } }); </script> <div class="main-content"> <section data-title="Introduction"><div class="c-article-section" id="Sec1-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Sec1">Introduction</h2><div class="c-article-section__content" id="Sec1-content"><p>Electrification and the rapid deployment of renewable energy (RE) generation are both critical for a low-carbon energy transition<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 1" title="World Energy Outlook 2020 (IEA, 2020). 
 https://www.iea.org/reports/world-energy-outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR1" id="ref-link-section-d14221052e417">1</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e420">2</a></sup>. They also address many other environmental issues, including air pollution. However, the variability of critical RE technologies, wind and solar, combined with increasing electrification may present a challenge to grid stability and security of supply<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 1" title="World Energy Outlook 2020 (IEA, 2020). 
 https://www.iea.org/reports/world-energy-outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR1" id="ref-link-section-d14221052e424">1</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e427">2</a></sup>. There are several supply-side options for addressing these concerns: energy storage, firm electricity generators (such as nuclear or geothermal generators), long-distance electricity transmission, over-building of RE (resulting in curtailment in periods of lower demand), and power-to-gas<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 3" title="Lund, P. D., Lindgren, J., Mikkola, J. & Salpakari, J. Review of energy system flexibility measures to enable high levels of variable renewable electricity. Renew. Sust. Energ. Rev. 45, 785–807 (2015)." href="/articles/s41467-022-35393-0#ref-CR3" id="ref-link-section-d14221052e431">3</a></sup> (in approximate ascending order of today’s estimated cost). Demand-side management is also vital in shifting and flattening peak demand<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 4" title="Palensky, P. & Dietrich, D. Demand Side Management: Demand Response, Intelligent Energy Systems, and Smart Loads. IEEE Trans. Ind. Inform. 7, 381–388 (2011)." href="/articles/s41467-022-35393-0#ref-CR4" id="ref-link-section-d14221052e435">4</a></sup>. Given rapid cost-declines, battery storage is one of the major options for energy storage and can be used in various grid-related applications to improve grid performance. Cost declines in batteries have been the major driver for electric vehicle (EV) cost reductions. Given that many batteries will be produced for light-duty transport these could offer a low-cost and materially-efficient approach for short-term electricity grid storage requirements<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 5" title="Brown, T., Schlachtberger, D., Kies, A., Schramm, S. & Greiner, M. Synergies of sector coupling and transmission reinforcement in a cost-optimised, highly renewable European energy system. Energy 160, 720–739 (2018)." href="/articles/s41467-022-35393-0#ref-CR5" id="ref-link-section-d14221052e439">5</a></sup>.</p><p>EV batteries can be used while in the vehicle via vehicle-to-grid approaches, or after the end of vehicle life (EoL) (when they are removed and used separately to the chassis in stationary storage). “Smart” vehicle-to-grid charging can facilitate dynamic EV charging and load shifting grid services. EVs can also be used to store electricity and deliver it back to the grid at peak times<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 6" title="Guille, C. & Gross, G. A conceptual framework for the vehicle-to-grid (V2G) implementation. Energy Policy 37, 4379–4390 (2009)." href="/articles/s41467-022-35393-0#ref-CR6" id="ref-link-section-d14221052e446">6</a></sup>. These opportunities rely on standards and market arrangements that allow for dynamic energy-pricing and the ability of owners to benefit from the value to the grid. Value to the grid can include deferred or avoided capital expenditure on additional stationary storage, power electronic infrastructure, transmission build-out, and more<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 6" title="Guille, C. & Gross, G. A conceptual framework for the vehicle-to-grid (V2G) implementation. Energy Policy 37, 4379–4390 (2009)." href="/articles/s41467-022-35393-0#ref-CR6" id="ref-link-section-d14221052e450">6</a></sup>. When the remaining battery capacity drops to between 70-80% of the original capacity, batteries generally become unsuitable for use in EVs<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 7" title="Identifying and Overcoming Critical Barriers to Widespread Second Use of PEV Batteries (National Renewable Energy Lab, 2015). 
 https://www.osti.gov/biblio/1171780
 
 " href="/articles/s41467-022-35393-0#ref-CR7" id="ref-link-section-d14221052e454">7</a></sup>. However, these batteries at vehicle EoL (hereafter termed retired batteries) may still have years of useful life in less demanding stationary energy storage applications and represent substantial value to the grid<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 8" title="Haram, M. H. S. M. et al. Feasibility of utilising second life EV batteries: Applications, lifespan, economics, environmental impact, assessment, and challenges. Alex. Eng. J. 60, 4517–4536 (2021)." href="/articles/s41467-022-35393-0#ref-CR8" id="ref-link-section-d14221052e458">8</a></sup>.</p><p>The utilisation of EV batteries could improve the flexibility of supply while reducing the capital costs and material-related emissions associated with additional storage and power-electronic infrastructure. However, the total grid storage capacity of EV batteries depends on different socioeconomic and technical factors such as business models, consumer behaviour (in driving and charging), battery degradation, and more<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 9" title="Sovacool, B. K., Axsen, J. & Kempton, W. The Future Promise of Vehicle-to-Grid (V2G) Integration: A Sociotechnical Review and Research Agenda. Annu. Rev. Environ. Resour. 42, 377–406 (2017)." href="/articles/s41467-022-35393-0#ref-CR9" id="ref-link-section-d14221052e465">9</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 10" title="Sovacool, B. K., Noel, L., Axsen, J. & Kempton, W. The neglected social dimensions to a vehicle-to-grid (V2G) transition: a critical and systematic review. Environ. Res. Lett. 13, 013001 (2018)." href="/articles/s41467-022-35393-0#ref-CR10" id="ref-link-section-d14221052e468">10</a></sup>. Previous global-level studies, including those on vehicle-to-grid capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e472">2</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 11" title="Ralon, P., Taylor, M., Ilas, A., Diaz-Bone, H. & Kairies, K. Electricity storage and renewables: Costs and markets to 2030. International Renewable Energy Agency: Abu Dhabi, UAE (2017)." href="/articles/s41467-022-35393-0#ref-CR11" id="ref-link-section-d14221052e475">11</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 12" title="Global EV Outlook 2020 (IEA, 2020). 
 https://www.iea.org/reports/global-ev-outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR12" id="ref-link-section-d14221052e478">12</a></sup> and retired battery capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 12" title="Global EV Outlook 2020 (IEA, 2020). 
 https://www.iea.org/reports/global-ev-outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR12" id="ref-link-section-d14221052e482">12</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 13" title="Second-life EV batteries: The newest value pool in energy storage (McKinsey & Company, 2019). 
 https://www.mckinsey.com/industries/automotive-and-assembly/our-insights/second-life-ev-batteries-the-newest-value-pool-in-energy-storage
 
 " href="/articles/s41467-022-35393-0#ref-CR13" id="ref-link-section-d14221052e485">13</a></sup> are informative. However, they rarely consider several important factors that determine storage opportunity, such as non-linear, empirically-based battery degradation and neglect the impact of battery chemistry altogether;<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Baghdadi, I., Briat, O., Delétage, J.-Y., Gyan, P. & Vinassa, J.-M. Lithium battery aging model based on Dakin’s degradation approach. J. Power Sources 325, 273–285 (2016)." href="#ref-CR14" id="ref-link-section-d14221052e489">14</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Naumann, M., Spingler, F. B. & Jossen, A. Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell. J. Power Sources 451, 227666 (2020)." href="#ref-CR15" id="ref-link-section-d14221052e489_1">15</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 16" title="Smith, K. et al. Life prediction model for grid-connected Li-ion battery energy storage system. in 2017 American Control Conference (ACC) 4062-4068." href="/articles/s41467-022-35393-0#ref-CR16" id="ref-link-section-d14221052e492">16</a></sup> geographical and/or temporal temperature variance (which impacts battery degradation); and, driving intensity by vehicle type in different countries/regions (which constrains the total capacity available during the day). Additionally, consumer participation in the vehicle-to-grid market and utilisation of retired batteries in the second-use market impact the actual grid storage capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 10" title="Sovacool, B. K., Noel, L., Axsen, J. & Kempton, W. The neglected social dimensions to a vehicle-to-grid (V2G) transition: a critical and systematic review. Environ. Res. Lett. 13, 013001 (2018)." href="/articles/s41467-022-35393-0#ref-CR10" id="ref-link-section-d14221052e496">10</a></sup>, both of which are important but rarely quantified.</p><p>Here we link three models and databases to assess the global grid storage opportunity of EV batteries by 2050 for both vehicle-to-grid applications and EoL opportunities (see Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig1">1</a>, Methods, and Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a>). We cover the main EV battery markets (China, India, EU, and US) explicitly, and combine other markets in a Rest of the World region (RoW). We first use a dynamic battery stock model to estimate future battery demand as part of transport fleets per region (Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">2</a>). The model incorporates two EV fleet development scenarios based on the IEA’s (International Energy Agency), stated policy (STEP) and sustainable development (SD) scenarios. The STEP scenario incorporates existing EV policies only, while the SD scenario is compatible with the climate goals of the Paris agreement and sees a larger EV fleet. The scenarios include two battery chemistry sub-scenarios to capture different technological paths: one dominated by lithium nickel cobalt oxides (NCX, with an “X” denoting manganese or aluminum, i.e., NMC/NCA) and another dominated by lithium-ion phosphate or (LFP). Market shares of NCX and LFP batteries are assumed to reach 98% and 2% in the NCX path by 2050, respectively, and 40% and 60% in the LFP path (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">3</a> for detailed market shares over time).</p><div class="c-article-section__figure js-c-reading-companion-figures-item" data-test="figure" data-container-section="figure" id="figure-1" data-title="Model framework linking EV use model, battery degradation model, and dynamic battery stock models."><figure><figcaption><b id="Fig1" class="c-article-section__figure-caption" data-test="figure-caption-text">Fig. 1: Model framework linking EV use model, battery degradation model, and dynamic battery stock models.</b></figcaption><div class="c-article-section__figure-content"><div class="c-article-section__figure-item"><a class="c-article-section__figure-link" data-test="img-link" data-track="click" data-track-label="image" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/1" rel="nofollow"><picture><source type="image/webp" srcset="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig1_HTML.png?as=webp"><img aria-describedby="Fig1" src="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig1_HTML.png" alt="figure 1" loading="lazy" width="685" height="610"></picture></a></div><div class="c-article-section__figure-description" data-test="bottom-caption" id="figure-1-desc"><p>See legend for use of colours. Square, white boxes indicate model outputs. Please see details for the model framework in the methods section. USDOE US Department of Energy, FASTSim Future Automotive Systems Technology Simulator, NREL National Renewable Energy Laboratory, IEA International Energy Agency, SoH State of Health.</p></div></div><div class="u-text-right u-hide-print"><a class="c-article__pill-button" data-test="article-link" data-track="click" data-track-label="button" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/1" data-track-dest="link:Figure1 Full size image" aria-label="Full size image figure 1" rel="nofollow"><span>Full size image</span><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-right-small"></use></svg></a></div></figure></div><p>These estimates of future demand are linked to an EV driving and charging behavior model for small, mid, and large-size BEVs (battery electric vehicles) and PHEVs (plug-in hybrid electric vehicles) based on daily driving distance distributions for different regions (Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">4</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">6</a>). EV use behavior, battery chemistry, and temperature in each region are combined with the latest battery degradation data for NCX<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 14" title="Baghdadi, I., Briat, O., Delétage, J.-Y., Gyan, P. & Vinassa, J.-M. Lithium battery aging model based on Dakin’s degradation approach. J. Power Sources 325, 273–285 (2016)." href="/articles/s41467-022-35393-0#ref-CR14" id="ref-link-section-d14221052e544">14</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 15" title="Naumann, M., Spingler, F. B. & Jossen, A. Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell. J. Power Sources 451, 227666 (2020)." href="/articles/s41467-022-35393-0#ref-CR15" id="ref-link-section-d14221052e547">15</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 17" title="Naumann, M., Schimpe, M., Keil, P., Hesse, H. C. & Jossen, A. Analysis and modeling of calendar aging of a commercial LiFePO4/graphite cell. J. Energy Storage 17, 153–169 (2018)." href="/articles/s41467-022-35393-0#ref-CR17" id="ref-link-section-d14221052e550">17</a></sup> and LFP<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 16" title="Smith, K. et al. Life prediction model for grid-connected Li-ion battery energy storage system. in 2017 American Control Conference (ACC) 4062-4068." href="/articles/s41467-022-35393-0#ref-CR16" id="ref-link-section-d14221052e554">16</a></sup> chemistries to account for region- and chemistry-specific battery degradation (Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">7</a>).</p><p>We first analyze the technical capacity for short-term grid storage from vehicle-to-grid and second-use. We then analyze the impact of different factors on the real-world capacity. For example, we analyse in detail the impact of different rates of EV owner participation in vehicle-to-grid markets as well as the impact of different utilisation rates of retired EV batteries in stationary storage (see Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig1">1</a> and methods for further details). Finally, we compare the technical and real-world short-term storage capacities against scenarios for future storage requirements from the literature.</p><p>We focus here on short-term energy storage since this accounts for the majority of the required storage capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 18" title="Guerra, O. J. Beyond short-duration energy storage. Nat. Energy 6, 460–461 (2021)." href="/articles/s41467-022-35393-0#ref-CR18" id="ref-link-section-d14221052e570">18</a></sup> and EV batteries are not well suited for longer-term, seasonal storage due to self-discharging over time. Short-term energy storage demand is typically defined as a typical 4-hour storage system, referring to the ability of a storage system to operate at a capacity where the maximum power delivered from that storage over time can be maintained for 4 hours. For example, the 4-hour storage capacity of batteries that together deliver a maximum of 0.25 GW until depletion will be 1 gigawatt hour<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 19" title="Energy Storage Grand Challenge: Energy Storage Market Report (U.S. Department of Energy, 2020). 
 https://www.energy.gov/sites/prod/files/2020/12/f81/Energy%20Storage%20Market%20Report%202020_0.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR19" id="ref-link-section-d14221052e574">19</a></sup> (GWh). The short-term storage capacity and power capacity are defined based on a typical 1-time equivalent full charging/discharge cycle per day (amounting to 4 hours of cumulative maximum discharge power per day). This 4-hour threshold is chosen as it is required by some jurisdictions such as the California Public Utilities Commission and New York Independent System Operator<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 20" title="The Potential for Battery Energy Storage to Provide Peaking Capacity in the United States (NREL, 2019). 
 https://www.nrel.gov/docs/fy19osti/74184.pdf
 
 " href="/articles/s41467-022-35393-0#ref-CR20" id="ref-link-section-d14221052e578">20</a></sup>, energy system analysts anticipate this threshold as the most important to markets<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 21" title="Storage Futures Study: Economic Potential of Diurnal Storage in the U.S. Power Sector (National Renewable Energy Laboratory, 2021). 
 https://www.nrel.gov/docs/fy21osti/77449.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR21" id="ref-link-section-d14221052e582">21</a></sup>, and is often the length of time used in the literature<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 22" title="Energy Storage Technology and Cost Characterization Report. 
 https://www.osti.gov/servlets/purl/1573487
 
 (2019)." href="/articles/s41467-022-35393-0#ref-CR22" id="ref-link-section-d14221052e586">22</a></sup>.</p><p>We compare our results against storage requirements reported in the IRENA (International Renewable Energy Agency) Planned Energy and Transforming Energy Scenarios (with a warming of “likely 2.5 °C” and “well below 2 °C” in the second half of this century, respectively)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e593">2</a></sup>, along with two Storage Lab scenarios (Conservative and Optimistic)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 23" title="Electric Insights Quarterly (Drax, 2019). 
 https://www.drax.com/wp-content/uploads/2019/12/191202_Drax_Q3_Report.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR23" id="ref-link-section-d14221052e597">23</a></sup>. Both Storage Lab scenarios result in a warming of “well below 2 °C” by 2100, but differ in the role for grid storage please see Supplementary Table <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a> for more). These scenarios report short-term grid storage demands of 3.4, 9, 8.8, and 19.2 terawatt hours (TWh) for the IRENA Planned Energy, IRENA Transforming Energy, Storage Lab Conservative, and Storage Lab Optimistic scenarios, respectively. When assuming a 4-hour storage period for this capacity, this results in power demand of 850-4800 GW, or, 2500 GW when assuming an average storage capacity demand of 10 TWh.</p></div></div></section><section data-title="Results"><div class="c-article-section" id="Sec2-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Sec2">Results</h2><div class="c-article-section__content" id="Sec2-content"><h3 class="c-article__sub-heading" id="Sec3">Total technical capacity</h3><p>We define technical capacity as the total cumulative available EV battery capacity in use and in second use at a specific time while considering battery degradation and the capacity needed to meet driving demand. Globally, the SD scenario sees a total technical capacity twice that of the STEP scenario due to the larger fleet size (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">8</a> and Note <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a>). Globally, the LFP scenario sees a slightly higher cumulative capacity than the NCX scenario, due to different battery market shares and the lower degradation of LFP across most countries/regions (see Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a> for a full comparison). Compared to the SD-NCX scenario, The SD-LFP scenario sees 2.6 TWh of higher technical capacity for China, EU, US, and RoW by 2050 compared to the SD-NCX and a 0.05 TWh lower technical capacity for India (see Supplementary Note <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">2</a>). These capacity differences are small compared to the total technical capacity. As shown in Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig2">2</a>, the SD-LFP scenario has a technical capacity 48% higher by 2030 and 91% higher than the STEP-NCX scenario by 2050 (3.8 TWh and 2.6 TWh in 2030 and 32 TWh and 62 TWh in 2050, respectively).</p><div class="c-article-section__figure js-c-reading-companion-figures-item" data-test="figure" data-container-section="figure" id="figure-2" data-title="Total technical capacity for EV batteries and comparison to grid storage demand."><figure><figcaption><b id="Fig2" class="c-article-section__figure-caption" data-test="figure-caption-text">Fig. 2: Total technical capacity for EV batteries and comparison to grid storage demand.</b></figcaption><div class="c-article-section__figure-content"><div class="c-article-section__figure-item"><a class="c-article-section__figure-link" data-test="img-link" data-track="click" data-track-label="image" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/2" rel="nofollow"><picture><source type="image/webp" srcset="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig2_HTML.png?as=webp"><img aria-describedby="Fig2" src="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig2_HTML.png" alt="figure 2" loading="lazy" width="685" height="324"></picture></a></div><div class="c-article-section__figure-description" data-test="bottom-caption" id="figure-2-desc"><p><b>a</b> STEP-NCX scenario. <b>b</b> SD-NCX scenario. <b>c</b> STEP-LFP scenario. <b>d</b> SD-LFP scenario (see details in Supplementary Table <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a>). IRENA = International Renewable Energy Agency.</p></div></div><div class="u-text-right u-hide-print"><a class="c-article__pill-button" data-test="article-link" data-track="click" data-track-label="button" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/2" data-track-dest="link:Figure2 Full size image" aria-label="Full size image figure 2" rel="nofollow"><span>Full size image</span><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-right-small"></use></svg></a></div></figure></div><p>Under all scenarios, cumulative vehicle-to-grid and second-use capacity will grow dramatically, by a factor of 13–16 between 2030 and 2050. Putting this cumulative technical capacity into perspective against future demand for grid storage we find that our estimated growth is expected to increase as fast or even faster than short-term grid storage capacity demand in several projections<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e669">2</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 23" title="Electric Insights Quarterly (Drax, 2019). 
 https://www.drax.com/wp-content/uploads/2019/12/191202_Drax_Q3_Report.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR23" id="ref-link-section-d14221052e672">23</a></sup> (Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig2">2</a>). Technical vehicle-to-grid capacity or second-use capacity are each, on their own, sufficient to meet the short-term grid storage capacity demand of 3.4-19.2 TWh by 2050. This is also true on a regional basis where technical EV capacity meets regional grid storage capacity demand (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">9</a>).</p><h3 class="c-article__sub-heading" id="Sec4">Vehicle-to-grid opportunities and limitations</h3><p>Examining the vehicle-to-grid opportunity alone, we find that 21%-26% of the global theoretical battery capacity (i.e., on-board EV battery capacity of the entire EV fleet without considering battery degradation) could be available for vehicle-to-grid services by 2050 (Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig3">3a</a>). The most important limiting factor is the battery capacity required to meet consumer driving demands<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 24" title="MPG and Cost Calculator and Tracker (Spritmonitor, 2020). 
 https://www.spritmonitor.de/en/
 
 ." href="/articles/s41467-022-35393-0#ref-CR24" id="ref-link-section-d14221052e693">24</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 25" title="Global EV Data Explorer (IEA, 2021). 
 https://www.iea.org/articles/global-ev-data-explorer
 
 ." href="/articles/s41467-022-35393-0#ref-CR25" id="ref-link-section-d14221052e696">25</a></sup>. Driving demand can limit the available capacity by 57%-63%. PHEVs, which make up around 11% of the theoretical capacity in 2050, are not considered for vehicle-to-grid as they have a low storage potential due to low capacities. On average, just 5% of the theoretical capacity is lost due to battery degradation by 2050. These losses vary between 7% in India and 4% in RoW due to differences in regional factors such as use conditions and temperature (for full regional results see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">10</a>). Overall, taking these factors into account yields an estimated technical vehicle-to-grid capacity of 18-30 TWh by 2050 (see Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig3">3</a>).</p><div class="c-article-section__figure js-c-reading-companion-figures-item" data-test="figure" data-container-section="figure" id="figure-3" data-title="Global available vehicle-to-grid capacity in 2050."><figure><figcaption><b id="Fig3" class="c-article-section__figure-caption" data-test="figure-caption-text">Fig. 3: Global available vehicle-to-grid capacity in 2050.</b></figcaption><div class="c-article-section__figure-content"><div class="c-article-section__figure-item"><a class="c-article-section__figure-link" data-test="img-link" data-track="click" data-track-label="image" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/3" rel="nofollow"><picture><source type="image/webp" srcset="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig3_HTML.png?as=webp"><img aria-describedby="Fig3" src="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig3_HTML.png" alt="figure 3" loading="lazy" width="685" height="240"></picture></a></div><div class="c-article-section__figure-description" data-test="bottom-caption" id="figure-3-desc"><p><b>a</b> Technical vehicle-to-grid capacity. Hatched bars indicate the capacity limits due to key factors and blue bars the technical vehicle-to-grid capacity. <b>b</b> Real-world vehicle-to-grid capacity as a function of participation rates. Results are shown for the STEP-NCX and the SD-NCX scenarios with a comparison to the range of storage demand computed by IRENA and Storage Lab models in 2050 (orange shading). Please see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">16</a> for global real-world vehicle-to-grid capacity under STEP-LFP and the SD-LFP scenarios and Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">17</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">20</a> for regional real-world vehicle-to-grid capacity.</p></div></div><div class="u-text-right u-hide-print"><a class="c-article__pill-button" data-test="article-link" data-track="click" data-track-label="button" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/3" data-track-dest="link:Figure3 Full size image" aria-label="Full size image figure 3" rel="nofollow"><span>Full size image</span><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-right-small"></use></svg></a></div></figure></div><p>However, there are other factors that may limit real-world available storage capacity, primarily the vehicle-to-grid participation rate. Not all EV consumers will necessarily participate in the market and the participation rate is defined as the percentage of the technical vehicle to grid capacity connected to the grid, as shown in Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig3">3b</a>. Participation rates of 38% and 20% are required to satisfy short-term storage demands of 10 TWh in 2050 (for STEP-NCX and SD-NCX scenarios, respectively). In practice, it is likely that EVs with high battery capacities and low degradation will be used for providing vehicle-to-grid services since these will provide the highest revenue for EV owners<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 26" title="Thompson, A. W. Economic implications of lithium ion battery degradation for Vehicle-to-Grid (V2X) services. J. Power Sources 396, 691–709 (2018)." href="/articles/s41467-022-35393-0#ref-CR26" id="ref-link-section-d14221052e746">26</a></sup> (the full battery capacity distributions by 2050 across countries/regions are available in Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">11</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">15</a>).</p><h3 class="c-article__sub-heading" id="Sec5">Impacts of deploying second-use batteries in stationary storage</h3><p>Over time EV batteries degrade to the point they cannot be used to power vehicles<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 27" title="Xu, C. et al. Future material demand for automotive lithium-based batteries. Commun. Mater. 1, 99 (2020)." href="/articles/s41467-022-35393-0#ref-CR27" id="ref-link-section-d14221052e764">27</a></sup>, generally when the battery’s relative State of Health (SoH) drops below 70%-80%<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 7" title="Identifying and Overcoming Critical Barriers to Widespread Second Use of PEV Batteries (National Renewable Energy Lab, 2015). 
 https://www.osti.gov/biblio/1171780
 
 " href="/articles/s41467-022-35393-0#ref-CR7" id="ref-link-section-d14221052e768">7</a></sup> (defined as actual capacity as percentage of original capacity). The relative SoH could fall even lower if a consumer is willing to accept relatively poor battery health and shorter ranges<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 28" title="Saxena, S., Le Floch, C., MacDonald, J. & Moura, S. Quantifying EV battery end-of-life through analysis of travel needs with vehicle powertrain models. J. Power Sources 282, 265–276 (2015)." href="/articles/s41467-022-35393-0#ref-CR28" id="ref-link-section-d14221052e772">28</a></sup>. Given their economic, value, size, and end-of-life regulations, we assume all batteries will be collected<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 29" title="Harper, G. et al. Recycling lithium-ion batteries from electric vehicles. Nature 575, 75–86 (2019)." href="/articles/s41467-022-35393-0#ref-CR29" id="ref-link-section-d14221052e776">29</a></sup>. This is reasonable given that today’s lead-acid batteries achieve a near 100% collection rate<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 30" title="Gaines, L. The future of automotive lithium-ion battery recycling: Charting a sustainable course. Sustain. Mater. Technol. 1-2, 2–7 (2014)." href="/articles/s41467-022-35393-0#ref-CR30" id="ref-link-section-d14221052e780">30</a></sup> and modern EV batteries are of much higher economic value.</p><p>Once collected, batteries are health tested to determine if they can be used in a less critical second-use application, or if they should be recycled<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 31" title="DeRousseau, M., Gully, B., Taylor, C., Apelian, D. & Wang, Y. Repurposing Used Electric Car Batteries: A Review of Options. JOM 69, 1575–1582 (2017)." href="/articles/s41467-022-35393-0#ref-CR31" id="ref-link-section-d14221052e787">31</a></sup>. Given the technical and economic feasibility of retired batteries for second-use<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 32" title="Neubauer, J., Pesaran, A., Williams, B., Ferry, M. & Eyer, J. Techno-Economic Analysis of PEV Battery Second Use: Repurposed-Battery Selling Price and Commercial and Industrial End-User Value. (Sponsor Org.: USDOE Office of Energy Efficiency and Renewable Energy (EERE), Vehicle Technologies Office (EE-3V))." href="/articles/s41467-022-35393-0#ref-CR32" id="ref-link-section-d14221052e791">32</a></sup>, we consider batteries with an SoH of 70% and higher only for second-use (a threshold often used in the literature<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 32" title="Neubauer, J., Pesaran, A., Williams, B., Ferry, M. & Eyer, J. Techno-Economic Analysis of PEV Battery Second Use: Repurposed-Battery Selling Price and Commercial and Industrial End-User Value. (Sponsor Org.: USDOE Office of Energy Efficiency and Renewable Energy (EERE), Vehicle Technologies Office (EE-3V))." href="/articles/s41467-022-35393-0#ref-CR32" id="ref-link-section-d14221052e795">32</a></sup>). Under this assumption, 74% of retired NCX batteries can be repurposed for second-use globally, while 26% goes to recycling by 2050. Regional differences can be significant due to the impact of temperature on NCX battery degradation (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">21</a> and Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a>). In contrast, nearly all LFP retired batteries can be repurposed.</p><p>Business models are still developing, and repurposing is highly dependent on the technical specifications and market requirements of second-use applications<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 33" title="Reinhardt, R., Christodoulou, I. & Gassó-Domingo, S. & Amante García, B. Towards sustainable business models for electric vehicle battery second use: A critical review. J. Environ. Manag. 245, 432–446 (2019)." href="/articles/s41467-022-35393-0#ref-CR33" id="ref-link-section-d14221052e808">33</a></sup>. Since battery disassembly is costly<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 32" title="Neubauer, J., Pesaran, A., Williams, B., Ferry, M. & Eyer, J. Techno-Economic Analysis of PEV Battery Second Use: Repurposed-Battery Selling Price and Commercial and Industrial End-User Value. (Sponsor Org.: USDOE Office of Energy Efficiency and Renewable Energy (EERE), Vehicle Technologies Office (EE-3V))." href="/articles/s41467-022-35393-0#ref-CR32" id="ref-link-section-d14221052e812">32</a></sup>, battery repurposing will likely happen on the pack level instead of modules and cell level. Repurposing will consist mainly of rebalancing and reconnecting the retired battery packs. There is no strong technical reason to model a capacity difference before and after the repurposing.</p><p>Using these assumptions we find that 2.1–4.8 TWh of retired batteries are estimated to become available as annual technical second-use capacity globally in 2050, as shown in Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig4">4a</a>. The cumulative technical second-use capacity is expected to reach 14.8–31.5 TWh by 2050 when assuming second-use batteries have a lifetime of 10-years<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 34" title="Casals, L. C., Amante García, B. & Canal, C. Second life batteries lifespan: Rest of useful life and environmental analysis. J. Environ. Manag. 232, 354–363 (2019)." href="/articles/s41467-022-35393-0#ref-CR34" id="ref-link-section-d14221052e822">34</a></sup> (Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig4">4b</a>). The actual second second-use lifespan is uncertain due to uncertainties surrounding the retired battery SoH, use conditions, among other factors. Another uncertainty is the further battery degradation during secondary use, which is difficult to model due to complicated degradation mechanisms of retired batteries<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 35" title="Podias, A. et al. Sustainability Assessment of Second Use Applications of Automotive Batteries: Ageing of Li-Ion Battery Cells in Automotive and Grid-Scale Applications. World Electr. Veh. J. 9 (2018)." href="/articles/s41467-022-35393-0#ref-CR35" id="ref-link-section-d14221052e829">35</a></sup>. Further research into degradation and second-use life span is required to improve estimates of technical second-use capacity. If the 10TWh global, short-term storage requirements are met with second-use batteries alone, then a 68% utilisation rate of retired batteries would be needed in the STEP-NCX scenario (14.8 TWh technical capacity) and utilisation rate of 32% in the SD-LFP scenario (31.5 TWh technical capacity).</p><div class="c-article-section__figure js-c-reading-companion-figures-item" data-test="figure" data-container-section="figure" id="figure-4" data-title="Availability of second-use capacity globally in 2050."><figure><figcaption><b id="Fig4" class="c-article-section__figure-caption" data-test="figure-caption-text">Fig. 4: Availability of second-use capacity globally in 2050.</b></figcaption><div class="c-article-section__figure-content"><div class="c-article-section__figure-item"><a class="c-article-section__figure-link" data-test="img-link" data-track="click" data-track-label="image" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/4" rel="nofollow"><picture><source type="image/webp" srcset="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig4_HTML.png?as=webp"><img aria-describedby="Fig4" src="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig4_HTML.png" alt="figure 4" loading="lazy" width="685" height="250"></picture></a></div><div class="c-article-section__figure-description" data-test="bottom-caption" id="figure-4-desc"><p><b>a</b> Average annual additions and cumulative technical capacity of second-use batteries in 2050. Here capacity refers to the technically available capacity considering battery degradation but without considering battery second-use utilisation rate. <b>b</b> Impacts of second-use utilisation rate on cumulative actual second-use capacity and a comparison to storage demand in 2050 (orange shading). See Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">22</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">25</a> for regional actual second-use capacity.</p></div></div><div class="u-text-right u-hide-print"><a class="c-article__pill-button" data-test="article-link" data-track="click" data-track-label="button" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/4" data-track-dest="link:Figure4 Full size image" aria-label="Full size image figure 4" rel="nofollow"><span>Full size image</span><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-right-small"></use></svg></a></div></figure></div><h3 class="c-article__sub-heading" id="Sec6">Combining vehicle-to-grid participation rate and second-use utilisation rates</h3><p>The global technical capacity for short-term grid storage of EV batteries grows rapidly in all scenarios. However, the real-world available capacity depends strongly on the vehicle-to-grid participation rate and the second-use utilisation rates. We show the real-world available capacity as a function of these rates in Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig5">5</a> (for the STEP-NCX scenario, please see Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">26</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">28</a> for other scenarios). Participation and utilisation rates of 50% for vehicle-to-grid and second-use, results in a real-world capacity of 25–48 TWh by 2050, far higher than the short-term storage requirements estimated from the literature. Changes in vehicle-to-grid participation rates of 23–96%<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 36" title="The Present & Future Of Vehicle-To-Grid Technology (CleanTechnica, 2020). 
 https://cleantechnica.com/2020/09/05/the-present-future-of-vehicle-to-grid-technology/
 
 " href="/articles/s41467-022-35393-0#ref-CR36" id="ref-link-section-d14221052e881">36</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 37" title="Zonneveld, J. A. Increasing participation in V2G through contract elements: Examining the preferences of Dutch EV users regarding V2G contracts using a stated choice experiment. (2019)." href="/articles/s41467-022-35393-0#ref-CR37" id="ref-link-section-d14221052e884">37</a></sup> by 2050 could influence this real-world capacity by as much as -24% to +21%. When second-use utilisation rates vary from 10%-100%, the real-world capacity varies between -41% and 12%. Taken together, vehicle-to-grid participation rate and second-use utilisation rate could alter the real-world capacity in 2050 by -61% to +32%.</p><div class="c-article-section__figure js-c-reading-companion-figures-item" data-test="figure" data-container-section="figure" id="figure-5" data-title="Total actual available capacity under various conditions in STEP-NCX scenario in 2050."><figure><figcaption><b id="Fig5" class="c-article-section__figure-caption" data-test="figure-caption-text">Fig. 5: Total actual available capacity under various conditions in STEP-NCX scenario in 2050.</b></figcaption><div class="c-article-section__figure-content"><div class="c-article-section__figure-item"><a class="c-article-section__figure-link" data-test="img-link" data-track="click" data-track-label="image" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/5" rel="nofollow"><picture><source type="image/webp" srcset="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig5_HTML.png?as=webp"><img aria-describedby="Fig5" src="//media.springernature.com/lw685/springer-static/image/art%3A10.1038%2Fs41467-022-35393-0/MediaObjects/41467_2022_35393_Fig5_HTML.png" alt="figure 5" loading="lazy" width="685" height="756"></picture></a></div><div class="c-article-section__figure-description" data-test="bottom-caption" id="figure-5-desc"><p>Blue, white, and red colors depict minimum, average, and maximum values. See Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">26</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">28</a> for other scenarios.</p></div></div><div class="u-text-right u-hide-print"><a class="c-article__pill-button" data-test="article-link" data-track="click" data-track-label="button" data-track-action="view figure" href="/articles/s41467-022-35393-0/figures/5" data-track-dest="link:Figure5 Full size image" aria-label="Full size image figure 5" rel="nofollow"><span>Full size image</span><svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-chevron-right-small"></use></svg></a></div></figure></div><p>We could see many different combinations of vehicle-to-grid and second-use to meet the short-term grid storage demands by 2050 (3.4–19.2 TWh). Without any second-use batteries in stationary storage, grids would require vehicle-to-grid participation rates of a modest 12–43%. If we assume that only half of second-use batteries are used on the grid (with others used off-grid, for other EV or storage purposes, etc.), the required participation rate of vehicle-to-grid drops to below 10%.</p><p>The required market participation rates depend on EV fleet and battery chemistry scenarios but also are influenced by other factors, such as battery capacity per vehicle. To investigate the impact of our capacity assumptions we investigate a scenario where all BEVs are equipped with a smaller 33kWh battery (instead of 33, 66, and 100 kWh battery per vehicle for small, mid-size, and large BEVs globally, see methods for more details). Even in this extreme case, EV batteries can still meet global, short-term grid storage demand by 2050 with participation rates of 10%-40% in vehicle-to-grid and with half second-use batteries used as stationary storage (see Supplementary Table <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">4</a>).</p></div></div></section><section data-title="Discussion"><div class="c-article-section" id="Sec7-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Sec7">Discussion</h2><div class="c-article-section__content" id="Sec7-content"><p>Previous research has suggested that large EV fleets could exert additional stress on grid stability (e.g., if the majority of EVs are charged at grid peak time)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 38" title="Anwar, M. B. et al. Assessing the value of electric vehicle managed charging: a review of methodologies and results. Energy Environ. Sci. (2022)." href="/articles/s41467-022-35393-0#ref-CR38" id="ref-link-section-d14221052e932">38</a></sup>. Our findings reveal a different perspective that EV batteries could promote electricity grid stability via storage solutions from vehicle-to-grid and second-use applications. We estimate a total technical capacity of 32-62 TWh by 2050. This is significantly higher than the 3.4–19.2 TWh required by 2050 in IRENA and Storage lab scenarios.</p><p>The real-world capacity depends on participation rates for vehicle-to-grid and utilisation rates for second-use of batteries. Participation rates may vary regionally depending on future market incentives and infrastructure, along with other factors<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 39" title="A Vision for a Sustainable Battery Value Chain in 2030 (2019). 
 https://www.globalbattery.org/media/publications/WEF_A_Vision_for_a_Sustainable_Battery_Value_Chain_in_2030_Report.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR39" id="ref-link-section-d14221052e939">39</a></sup>. The STEP-NCX scenario presented in Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig5">5</a> has the lowest technical capacity (32 TWh compared to 62 TWh in the SD-LFP scenario) which already easily meets requirements at participation rates of 40%–50% for vehicle-to-grid and with around half second-use batteries used as stationary storage. At a regional level, even lower participation rates may still contribute significantly to grid stability. Overall, EV batteries could meet short-term grid storage demand by as early as 2030 if we assume lower storage requirements from the literature and higher levels of participation and utilisation. By 2040–2050 storage demands are met across almost all scenarios and even low participation and utilisation rates.</p><p>Harnessing this potential will have critical implications for the energy transition and policymakers should be cognizant of the opportunities. The participation rate of EV users in the vehicle-to-grid market is crucial and the government can play an important role in incentivization. This can include market-based efforts such as micro-payments for services to the grid, or regulations to require the connection of commercial fleets to the network while at depots. Further regulations will be required to ensure the required hardware and software solutions for EV integration. This may include smart controllers for consumers in order to facilitate easy market participation and communication of benefits to EV users<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 39" title="A Vision for a Sustainable Battery Value Chain in 2030 (2019). 
 https://www.globalbattery.org/media/publications/WEF_A_Vision_for_a_Sustainable_Battery_Value_Chain_in_2030_Report.pdf
 
 ." href="/articles/s41467-022-35393-0#ref-CR39" id="ref-link-section-d14221052e949">39</a></sup>. Strong re-use regulations will also be necessary to ensure that batteries are recovered at EOL and easily integrated into the grid<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 40" title="Bai, Y. et al. Energy and environmental aspects in recycling lithium-ion batteries: Concept of Battery Identity Global Passport. Mater. Today 41, 304–315 (2020)." href="/articles/s41467-022-35393-0#ref-CR40" id="ref-link-section-d14221052e953">40</a></sup>. Finally, policymakers and researchers should aim to understand EV user behavior over time in order to tackle the key factors preventing EV users from participating in vehicle-to-grid (which may include concerns surrounding battery degradation).</p><p>As we include a broader set of limitations for the total opportunity of EV storage our results are difficult to compare with other literature. Our estimated global EV fleet capacity in 2050 (68-144 TWh) is considerably higher than the estimate from IRENA (7.5-14 TWh)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 2" title="Global Renewables Outlook: Energy transformation 2050 (International Renewable Energy Agency, 2020). 
 https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR2" id="ref-link-section-d14221052e960">2</a></sup>. This is due to the IRENA’s very conservative scenarios on future EV fleet size and battery capacity per vehicle. The IRENA scenario also does not consider the availability of EV fleet capacity for grid services. While a different IEA estimate does not extend beyond 2030<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 12" title="Global EV Outlook 2020 (IEA, 2020). 
 https://www.iea.org/reports/global-ev-outlook-2020
 
 " href="/articles/s41467-022-35393-0#ref-CR12" id="ref-link-section-d14221052e964">12</a></sup> it does highlight the importance of including battery degradation in analyses, which we include for our projection to 2050 (Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig4">4</a>).</p><p>We note several limitations in our approach that could be improved as data availability improves. For example, while we include battery degradation by using state-of-art data, future battery degradation is highly uncertain and depends on further technological breakthroughs both in battery chemistry such as Na-ion, Li-Air, and Li-Sulphur<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 41" title="Sapunkov, O., Pande, V., Khetan, A., Choomwattana, C. & Viswanathan, V. Quantifying the promise of ‘beyond’ Li–ion batteries. Transl. Mater. Res. 2, 045002 (2015)." href="/articles/s41467-022-35393-0#ref-CR41" id="ref-link-section-d14221052e975">41</a></sup> along with developments in battery management systems. Further, while we derived driving behaviour from empirical data, future changes in driving habits are uncertain and dependent on various factors such as EV-related infrastructure. Vehicle chargers increase in power output over time and 50 kW charging and above is already common across many countries<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 42" title="Srdic, S. & Lukic, S. Toward Extreme Fast Charging: Challenges and Opportunities in Directly Connecting to Medium-Voltage Line. IEEE Electrif. Mag. 7, 22–31 (2019)." href="/articles/s41467-022-35393-0#ref-CR42" id="ref-link-section-d14221052e979">42</a></sup>. Frequent fast charging could lead to faster degradation, especially in hotter/colder climates<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 43" title="What can 6,000 electric vehicles tell us about EV battery health? (GEOTAB, 2020). 
 https://www.geotab.com/blog/ev-battery-health/
 
 " href="/articles/s41467-022-35393-0#ref-CR43" id="ref-link-section-d14221052e983">43</a></sup>. This challenge may be addressed by future technology improvements to battery materials<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 44" title="Park, Y.-U. et al. A New High-Energy Cathode for a Na-Ion Battery with Ultrahigh Stability. J. Am. Chem. Soc. 135, 13870–13878 (2013)." href="/articles/s41467-022-35393-0#ref-CR44" id="ref-link-section-d14221052e987">44</a></sup>, electrode architectures, and optimized synergy of the cell/module/pack system design<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 45" title="Yang, X.-G., Liu, T. & Wang, C.-Y. Thermally modulated lithium iron phosphate batteries for mass-market electric vehicles. Nat. Energy 6, 176–185 (2021)." href="/articles/s41467-022-35393-0#ref-CR45" id="ref-link-section-d14221052e991">45</a></sup>. A further limitation is that we compare technical and real-world available vehicle-to-grid capacity with an average 4-hour storage requirement as provided in the scenarios by IRENA and Storage Lab. This omits potential differences in storage requirements at shorter time scales (seconds/minutes). Improved modelling and data can overcome this gap. It is however likely that the technical vehicle-to-grid capacity will be sufficient given low vehicle utilisation rates of just 5% for many regions<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 46" title="Alam, M. et al. Real-Time Smart Parking Systems Integration in Distributed ITS for Smart Cities. J. Adv. Transp. 2018, 1485652 (2018)." href="/articles/s41467-022-35393-0#ref-CR46" id="ref-link-section-d14221052e996">46</a></sup>. Additionally, the development of smart charging infrastructure and grid digitization is likely to provide additional flexibility for matching electricity demand and supply<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 47" title="Giordano, V. & Fulli, G. A business case for Smart Grid technologies: A systemic perspective. Energy Policy 40, 252–259 (2012)." href="/articles/s41467-022-35393-0#ref-CR47" id="ref-link-section-d14221052e1000">47</a></sup>.</p><p>A final limitation is that we assume that the rated capacity per vehicle remains the same in the future and that a small number of large BEVs might provide large actual vehicle-to-grid capacity (Fig. <a data-track="click" data-track-label="link" data-track-action="figure anchor" href="/articles/s41467-022-35393-0#Fig3">3</a>). These capacities may change further in the future due to policy incentives, vehicle design, consumer preferences, charging infrastructure, among other factors. Further, the transportation system could see radical and fundamental changes. A significant and rapid shift away from private car use to mass transit, a move to shared electric vehicles, autonomous driving, and the success of battery swap systems<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 48" title="Zheng, Y. et al. Electric Vehicle Battery Charging/Swap Stations in Distribution Systems: Comparison Study and Optimal Planning. IEEE Trans. Power Syst. 29, 221–229 (2014)." href="/articles/s41467-022-35393-0#ref-CR48" id="ref-link-section-d14221052e1010">48</a></sup> could all alter the available capacity by 2050.</p><p>In this study, we build a model framework to combine the EV use model, battery degradation model, and dynamic battery stock model. The model framework combines datasets on the real-world daily driving distance (in the EV use model), battery degradation test datasets (in the battery degradation model), and future EV and battery market data (in the dynamic battery stock model). The framework allows a structured use of diverse data to build a consistent perspective on future battery capacity. Within this model framework, this study provides a more complete understanding of the energy storage capacity available from EV batteries over time in real-world conditions and use. Results reveal a substantial opportunity for EV battery storage to support the stability and flexibility of renewable energy transition, even under modest consumer participation rates. To harness this opportunity, regulations and innovative business models will be needed to incentivize participation.</p></div></div></section><section data-title="Methods"><div class="c-article-section" id="Sec8-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Sec8">Methods</h2><div class="c-article-section__content" id="Sec8-content"><h3 class="c-article__sub-heading" id="Sec9">Model overview</h3><p>We develop an integrated model to quantify the future EV battery capacity available for grid storage, including both vehicle-to-grid and second-use (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a> for an overall schematic). The integrated model includes three sub-models:</p><ol class="u-list-style-none"> <li> <span class="u-custom-list-number">(1)</span> <p>A dynamic battery stock model<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 27" title="Xu, C. et al. Future material demand for automotive lithium-based batteries. Commun. Mater. 1, 99 (2020)." href="/articles/s41467-022-35393-0#ref-CR27" id="ref-link-section-d14221052e1042">27</a></sup> to estimate total future EV battery stock and the retired batteries at vehicle EoL. This model considers EV fleet (i.e., battery stock) development and EV lifespan distribution (Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">2</a>), as well as future chemistry development (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">3</a> for detailed battery market shares by chemistry).</p> </li> <li> <span class="u-custom-list-number">(2)</span> <p>An EV use model which includes behavioral factors such as EV driving cycle and charging behavior (changing power, time, and frequency), based on daily driving distance data for small/mid-size/large BEVs and PHEVs (Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">4</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">6</a>).</p> </li> <li> <span class="u-custom-list-number">(3)</span> <p>A battery degradation model based on the latest battery degradation test data, to estimate battery capacity fading over time under different EV use, battery chemistry, and temperature conditions (Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">7</a>).</p> </li> </ol><h3 class="c-article__sub-heading" id="Sec10">Dynamic battery stock model</h3><p>We build on results and methods from the study<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 27" title="Xu, C. et al. Future material demand for automotive lithium-based batteries. Commun. Mater. 1, 99 (2020)." href="/articles/s41467-022-35393-0#ref-CR27" id="ref-link-section-d14221052e1094">27</a></sup> where we built a global dynamic battery stock model to quantify the stock and flows of EV batteries. We model future EV fleet development (i.e., battery stock) until 2050. We determine the retired battery availability based on battery stock development and EV lifespan distribution (which is assumed to determine the time when EV batteries are retired). Battery degradation does affect the technical performance (such as driving distance capability) of EVs, thus influencing consumers’ choice of time when EVs come into EoL. Here, for model simplicity, we assume batteries will be retired only when EVs come into EoL. While for EV battery capacity, we use an average capacity of 33, 66, and 100 kWh for small/mid-size/large BEVs, and 21, 10, and 15 kWh for small/mid-size/large PHEVs.</p><p>We use two EV fleet scenarios until 2030 from the IEA: the stated policies (STEP) scenario and the sustainable development (SD) scenario. We further extend these two scenarios to 2050 based on a review of EV projections until 2050. We use the EV fleet share across 5 main EV markets (China, India, EU, US, and RoW) from the IEA until 2030, and keep the EV fleet share by countries/regions in 2030-2050 the same as the year 2030 due to lack of reliable data after 2030 (see Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a> for EV fleet scenarios by countries/regions). Further, we include 56 cities in China, 9 cities in India, 32 cities in EU, 53 cities in US, and 9 cities in RoW. We compile future EV sales share among 159 cities globally in STEP scenario and SD scenario based on future EV fleet projections by counties/regions from the IEA<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 25" title="Global EV Data Explorer (IEA, 2021). 
 https://www.iea.org/articles/global-ev-data-explorer
 
 ." href="/articles/s41467-022-35393-0#ref-CR25" id="ref-link-section-d14221052e1104">25</a></sup> and other data sources<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 49" title="Electric vehicle capitals: Cities aim for all-electric mobility (The International Council on Clean Transportation, 2020). 
 https://theicct.org/publications/electric-vehicle-capitals-update-sept2020
 
 " href="/articles/s41467-022-35393-0#ref-CR49" id="ref-link-section-d14221052e1108">49</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 50" title="Electric Vehicle Industry in India: Why Foreign Investors Should Pay Attention (India Briefing, 2021). 
 https://www.india-briefing.com/news/electric-vehicle-industry-in-india-why-foreign-investors-should-pay-attention-21872.html/
 
 " href="/articles/s41467-022-35393-0#ref-CR50" id="ref-link-section-d14221052e1111">50</a></sup> (see Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a>).</p><p>We consider battery market shares by chemistry based on the market share projections until 2030 from Avicenne Energy<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 51" title="The Rechargeable Battery Market and Main Trends 2018-2030 (Avicenne Energy, 2019). 
 https://www.bpifrance.fr/content/download/76854/831358/file/02%20-%20Presentation%20Avicenne%20-%20Christophe%20Pillot%20-%2028%20Mai%202019.pdf
 
 " href="/articles/s41467-022-35393-0#ref-CR51" id="ref-link-section-d14221052e1121">51</a></sup> a specialist consulting firm, and potential trends until 2050 from battery technology roadmaps<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Electrochemical energy storage technical team roadmap (USDRIVE, 2017). 
 https://www.energy.gov/sites/prod/files/2017/11/f39/EESTT%20roadmap%202017-10-16%20Final.pdf
 
 " href="#ref-CR52" id="ref-link-section-d14221052e1125">52</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Inventing the sustainable batteries of the future (BATTERY 2030+, 2020). 
 https://battery2030.eu/digitalAssets/816/c_816048-l_1-k_roadmap-27-march.pdf
 
 " href="#ref-CR53" id="ref-link-section-d14221052e1125_1">53</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 54" title="Chen, K., Zhao, F., Hao, H. & Liu, Z. Selection of lithium-ion battery technologies for electric vehicles under China’s new energy vehicle credit regulation. Energy Procedia 158, 3038–3044 (2019)." href="/articles/s41467-022-35393-0#ref-CR54" id="ref-link-section-d14221052e1128">54</a></sup> and commercial activities<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 55" title="Tesla wins China approval to build Model 3 vehicles with LFP batteries: ministry - Reuters (Reuters, 2020)." href="/articles/s41467-022-35393-0#ref-CR55" id="ref-link-section-d14221052e1132">55</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 56" title="LFP chemistry is emerging as the future of batteries (Clean Future, 2020)." href="/articles/s41467-022-35393-0#ref-CR56" id="ref-link-section-d14221052e1135">56</a></sup>. Current battery technology roadmaps issued by the US<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 52" title="Electrochemical energy storage technical team roadmap (USDRIVE, 2017). 
 https://www.energy.gov/sites/prod/files/2017/11/f39/EESTT%20roadmap%202017-10-16%20Final.pdf
 
 " href="/articles/s41467-022-35393-0#ref-CR52" id="ref-link-section-d14221052e1139">52</a></sup>, EU<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 53" title="Inventing the sustainable batteries of the future (BATTERY 2030+, 2020). 
 https://battery2030.eu/digitalAssets/816/c_816048-l_1-k_roadmap-27-march.pdf
 
 " href="/articles/s41467-022-35393-0#ref-CR53" id="ref-link-section-d14221052e1143">53</a></sup>, and China<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 54" title="Chen, K., Zhao, F., Hao, H. & Liu, Z. Selection of lithium-ion battery technologies for electric vehicles under China’s new energy vehicle credit regulation. Energy Procedia 158, 3038–3044 (2019)." href="/articles/s41467-022-35393-0#ref-CR54" id="ref-link-section-d14221052e1148">54</a></sup> focus on the development of high-energy Lithium Nickel Cobalt Manganese Oxide (transition to low cobalt and high nickel content) and Lithium Nickel Cobalt Aluminum-based chemistries. NCM and NCA batteries will likely make up the majority of next-generation EV Lithium-ion batteries. Future battery chemistry is uncertain after 2030. Existing Lithium Iron Phosphate batteries could also dominate the EV market, as indicated by recent commercial activities<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 55" title="Tesla wins China approval to build Model 3 vehicles with LFP batteries: ministry - Reuters (Reuters, 2020)." href="/articles/s41467-022-35393-0#ref-CR55" id="ref-link-section-d14221052e1152">55</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 56" title="LFP chemistry is emerging as the future of batteries (Clean Future, 2020)." href="/articles/s41467-022-35393-0#ref-CR56" id="ref-link-section-d14221052e1155">56</a></sup>. LFP battery manufacturers intend to improve the specific energy of LFP batteries to compete with NCM batteries<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 45" title="Yang, X.-G., Liu, T. & Wang, C.-Y. Thermally modulated lithium iron phosphate batteries for mass-market electric vehicles. Nat. Energy 6, 176–185 (2021)." href="/articles/s41467-022-35393-0#ref-CR45" id="ref-link-section-d14221052e1159">45</a></sup>. Large-scale deployments of LFP may help avoid potential material supply shortage and price spikes associated with NCM and NCA batteries<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 27" title="Xu, C. et al. Future material demand for automotive lithium-based batteries. Commun. Mater. 1, 99 (2020)." href="/articles/s41467-022-35393-0#ref-CR27" id="ref-link-section-d14221052e1163">27</a></sup>. To encompass these market uncertainties, two battery chemistry scenarios are developed, including an NCX scenario (with X representing Manganese or Aluminum), and an LFP scenario. The market shares of NCX and LFP are assumed to reach 98% and 2% in the NCX path by 2050, and 40% and 60% in the LFP path (see Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">3</a> for detailed battery market shares by chemistry in two scenarios).</p><h3 class="c-article__sub-heading" id="Sec11">EV use model</h3><p>We use the daily driving distance (DDD) of EVs based on data from Spritmonitor.de<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 24" title="MPG and Cost Calculator and Tracker (Spritmonitor, 2020). 
 https://www.spritmonitor.de/en/
 
 ." href="/articles/s41467-022-35393-0#ref-CR24" id="ref-link-section-d14221052e1178">24</a></sup>, an online quality-controlled, crowd-sourced database containing detailed real-world information on distances traveled, fuel consumption, and corresponding costs. It is widely used in the literature, including for estimation of the environmental impacts of vehicles<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 57" title="Plötz, P., Funke, S. Á. & Jochem, P. Empirical Fuel Consumption and CO2 Emissions of Plug-In Hybrid Electric Vehicles. J. Ind. Ecol. 22, 773–784 (2018)." href="/articles/s41467-022-35393-0#ref-CR57" id="ref-link-section-d14221052e1182">57</a></sup> and the CO<sub>2</sub> mitigation potential of EVs<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 58" title="Plötz, P., Funke, S. A., Jochem, P. & Wietschel, M. CO2 Mitigation Potential of Plug-in Hybrid Electric Vehicles larger than expected. Sci. Rep. 7, 16493 (2017)." href="/articles/s41467-022-35393-0#ref-CR58" id="ref-link-section-d14221052e1188">58</a></sup>. We build historical DDD distributions for small/mid-size/large BEVs/PHEVs models, and explore the EV driving behavior of each EV model based on the corresponding DDD distributions. Please see the DDD distributions of each EV model in Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a>. Note DDDs less than 5 km are excluded.</p><p>Further, we compile future DDD in different countries/regions (Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">29</a>–<a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">32</a>) by assuming the future DDD is proportional to the future energy consumption per vehicle. The future energy consumption per vehicle in different countries/regions is estimated by the total EV fleet energy consumption divided by future EV fleet size in each country/region, which are both projected by the IEA<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 25" title="Global EV Data Explorer (IEA, 2021). 
 https://www.iea.org/articles/global-ev-data-explorer
 
 ." href="/articles/s41467-022-35393-0#ref-CR25" id="ref-link-section-d14221052e1204">25</a></sup>.</p><p>By comparing various DDDs in multiples of EV range, we classify 5 DDD classes to formulate driving intensity and charging behavior. These 5 classes divided between 0% of the EV range to 200% of the EV range (i.e., a DDD twice the range of the EV) with intervals of 0–25%, 25–33%, 33–50%, 50–100%, 100–200%. We use the mean DDD of each class for calculations.</p><p>We assume two commuting trips between home and working place per day on weekdays and two entertaining trips on weekends for all countries/regions. Each trip distance is half of DDD. According to the required trip distance, we compile the driving cycle of each trip (speed versus time) based on the standard US combined driving cycle (i.e., 55% city driving and 45% highway driving, see details in Supplementary Figs. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">5</a> and <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">6</a>, and Supplementary Note <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">1</a>).</p><p>Charging behavior may be affected by charging infrastructure, amongst others, on-board EV charger, consumer preferences. We assume an immediate and slow home charging at constant charging power to full charge for all EV sizes and types because home charging is the major charging way (see Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a>). We assume the home charging power as 1.92, 6.6, 22, and 1.92 kW for small, mid-size, large BEV, and PHEV, respectively<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 59" title="Brooker, A. et al. FASTSim: A Model to Estimate Vehicle Efficiency, Cost and Performance. SAE Technical Paper (2015)." href="/articles/s41467-022-35393-0#ref-CR59" id="ref-link-section-d14221052e1230">59</a></sup>. We assume that due to high costs and limited utility no consumers will install higher power charging infrastructure at home. We further anticipate the charging behaviors in terms of changing frequency by comparing the various DDDs in multiples of the EV range. As driving intensity increases, the higher charging frequency is assumed for 5 DDD classes (1x every four days, 1x every three days, 1x every two days, 1x each day, and 2x every day respectively). For example, if the DDD of mid-size BEV (with a 312 km EV range) increases from 75 km to 625 km, and the battery needs to be charged more frequently from 1 time per four days to 2 times per day.</p><p>We calculate battery SoC under three EV states: driving, charging, and parked. For the battery SoC during driving, we use FASTSim model<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 59" title="Brooker, A. et al. FASTSim: A Model to Estimate Vehicle Efficiency, Cost and Performance. SAE Technical Paper (2015)." href="/articles/s41467-022-35393-0#ref-CR59" id="ref-link-section-d14221052e1237">59</a></sup>, Future Automotive Systems Technology Simulator developed by National Renewable Energy Laboratory (NREL), to calculate EV battery SoC second-by-second. The model inputs include the EV driving cycle, EV configurations, and battery performance parameters (specific energy and battery capacity). We select one representative EV model from the FASTSim model<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 59" title="Brooker, A. et al. FASTSim: A Model to Estimate Vehicle Efficiency, Cost and Performance. SAE Technical Paper (2015)." href="/articles/s41467-022-35393-0#ref-CR59" id="ref-link-section-d14221052e1241">59</a></sup> for each EV size and type as EV configuration (Supplementary Table <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">2</a>), and NCM622 as a representative chemistry for all EV types; because it was found that EV configurations and battery performance parameters (such as specific energy) had small effects on the resulting battery SoC simulations. For battery SoC during charging, we assume the battery SoC increases linearly under a constant charging power with a 90% charging efficiency<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 60" title="Mitsubishi i-Miev charging cost and time calculator (EVcompare.io, 2009). 
 https://evcompare.io/cars/mitsubishi/mitsubishi_i-miev/charging/
 
 " href="/articles/s41467-022-35393-0#ref-CR60" id="ref-link-section-d14221052e1248">60</a></sup>. If an EV is parked, the SoC of the battery is slowly decreasing due to losses caused by battery self-discharging. A typical self-discharging rate of 5% per month is assumed for lithium-ion battery<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 61" title="What does Elevated Self-discharge Do? (Battery University, 2011). 
 https://batteryuniversity.com/learn/article/elevating_self_discharge
 
 " href="/articles/s41467-022-35393-0#ref-CR61" id="ref-link-section-d14221052e1252">61</a></sup>. Self-discharging occurs due to parasitic chemical reactions that consume active lithium and form electrochemically inactive species while lithium-ion batteries are at rest. These parasitic reactions both reduce the SoC of the cell, and also reduce the total amount of lithium available for cycling. The impact of self-discharge on the SoH of NCM and LFP batteries is captured in the battery degradation model we use. Note that for the sake of battery safety, a portion of battery capacity is unusable (15% for BEVs and 30% for PHEVs based on the BatPac model<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 62" title="BatPaC: Battery Manufacturing Cost Estimation (Argonne National Laboratory, 2021). 
 https://www.anl.gov/partnerships/batpac-battery-manufacturing-cost-estimation
 
 " href="/articles/s41467-022-35393-0#ref-CR62" id="ref-link-section-d14221052e1257">62</a></sup>), therefore we assume the usable SoC range as 5%-90% for BEV battery and 15%-85% for PHEV battery.</p><p>The battery temperature depends on the heat generation from chemical reactions inside batteries, amongst others, ambient temperature and environment (such as solar power radiation), battery management system (air or liquid cooling system to control battery temperature). The temperature can also vary from cell to cell, module to module, and component to component in the battery pack. The modelling of battery temperature is complicated and out of scope of this study. Here we use city ambient temperature to represent battery temperature, which is then used to calculate battery degradation. The main justification for this simplification is that the degradation for most consumer vehicles is dominated by calendar aging effects, as light-duty vehicles are only driven for a relatively small fraction of time throughout their life. For higher vehicle utilisation, neglecting battery pack thermal management in the degradation model will generally result in worse battery lifetimes, leading to a conservative estimate of electric vehicle lifetime. As such our modelling suggests a conservative lower bound of the potential for EV batteries to supply short-term storage facilities. Here, we use monthly average temperature of total 159 cities to capture the effects of geographic and temporal temperature variance on battery degradation. The temperature data is collected from<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Climate Data Online: Dataset Discovery (National Oceanic and Atmospheric Administration, 2021). 
 https://www.ncdc.noaa.gov/cdo-web/datasets
 
 ." href="#ref-CR63" id="ref-link-section-d14221052e1264">63</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="CLIMATE DATA FOR CITIES WORLDWIDE (CLIMATE-DATA.ORG, 2021). 
 https://en.climate-data.org/
 
 " href="#ref-CR64" id="ref-link-section-d14221052e1264_1">64</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" title="Climates for travelers. Information on the climates in the world to plan a trip (Climates to travel, 2021). 
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 " href="#ref-CR65" id="ref-link-section-d14221052e1264_2">65</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 66" title="Climate Zone Finder (Weather and Climate, 2021). 
 https://tcktcktck.org/
 
 " href="/articles/s41467-022-35393-0#ref-CR66" id="ref-link-section-d14221052e1267">66</a></sup>, can be found in Supplementary Data <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM4">1</a>.</p><h3 class="c-article__sub-heading" id="Sec12">Battery degradation model</h3><p>Battery degradation is crucially important for determining EV battery capacity both in use and for second-life applications, but there are still many open research questions surrounding the importance of EV driving habits, charging behavior, and battery chemistries on capacity development<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 67" title="Uddin, K., Dubarry, M. & Glick, M. B. The viability of vehicle-to-grid operations from a battery technology and policy perspective. Energy Policy 113, 342–347 (2018)." href="/articles/s41467-022-35393-0#ref-CR67" id="ref-link-section-d14221052e1282">67</a></sup>. Degradation model approaches include physics-based degradation models<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 68" title="Safari, M., Morcrette, M., Teyssot, A. & Delacourt, C. Multimodal Physics-Based Aging Model for Life Prediction of Li-Ion Batteries. J. Electrochem. Soc. 156, A145 (2009)." href="/articles/s41467-022-35393-0#ref-CR68" id="ref-link-section-d14221052e1286">68</a></sup> as well as machine learning models<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 69" title="Zhang, Y. et al. Identifying degradation patterns of lithium ion batteries from impedance spectroscopy using machine learning. Nat. Commun. 11, 1706 (2020)." href="/articles/s41467-022-35393-0#ref-CR69" id="ref-link-section-d14221052e1290">69</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 70" title="Severson, K. A. et al. Data-driven prediction of battery cycle life before capacity degradation. Nat. Energy 4, 383–391 (2019)." href="/articles/s41467-022-35393-0#ref-CR70" id="ref-link-section-d14221052e1293">70</a></sup> though there is no agreed-upon best practice<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 71" title="Edge, J. S. et al. Lithium ion battery degradation: what you need to know. Phys. Chem. Chem. Phys. 23, 8200–8221 (2021)." href="/articles/s41467-022-35393-0#ref-CR71" id="ref-link-section-d14221052e1297">71</a></sup>. Here, to balance the complexity and accuracy of the battery degradation model, we develop a semiempirical battery degradation model based on method from<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 16" title="Smith, K. et al. Life prediction model for grid-connected Li-ion battery energy storage system. in 2017 American Control Conference (ACC) 4062-4068." href="/articles/s41467-022-35393-0#ref-CR16" id="ref-link-section-d14221052e1301">16</a></sup>. The model considers both calendar life and cycle life aging (Eq. (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ1">1</a>)), assuming a square-root dependence on time for calendar life (degradation rates depend on temperature and SoC, see Eq. (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ2">2</a>)) and a linear dependence on energy throughput for cycle life (degradation rates depend on temperature, Depth-of-Discharge (DoD), and Current rate (C<sub>rate</sub>) see Eq. (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ3">3</a>)).</p><div id="Equ1" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$$q=1-{q}_{{{{{{\rm{Loss}}}}}},{{{{{\rm{Calendar}}}}}}}-{q}_{{{{{{\rm{Loss}}}}}},{{{{{\rm{Cycling}}}}}}}$$</span></div><div class="c-article-equation__number"> (1) </div></div><div id="Equ2" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${q}_{{{{{{\rm{Loss}}}}}},{{{{{\rm{Calendar}}}}}}}={k}_{{Cal}}\cdot \exp \left(\frac{-{E}_{a}}{{{{{{\bf{R}}}}}}T}\left(\frac{1}{T}-\frac{1}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)\cdot \exp \left(\frac{\alpha {{{{{\bf{F}}}}}}}{{{{{{\bf{R}}}}}}}\left(\frac{{U}_{a}}{T}-\frac{{U}_{{a},{ref}}}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)\cdot \sqrt{t}$$</span></div><div class="c-article-equation__number"> (2) </div></div><div id="Equ3" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${q}_{{Loss},{Cycling}}={k}_{{Cyc}}\cdot (A\cdot {DOD}+B)\cdot (C\cdot {C}_{{rate}}+D)\cdot (G\cdot {(T-{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}})}^{2}+H)\cdot {EFC}$$</span></div><div class="c-article-equation__number"> (3) </div></div><p>where q is the relative battery degradation, q<sub>Loss, Calendar</sub> is the relative calendar life degradation, q<sub>Loss, Cycling</sub> is the relative cycling life degradation, T is temperature, t is time (unit: days), EFC is equivalent full cycles. Note R is the universal gas constant (8.3144598 J mol<sup>-1</sup> K<sup>-1</sup>), T<sub>ref</sub> is the reference temperature (298.15 K), F is Faraday constant (96485 C mol<sup>-1</sup>), k<sub>Cal</sub> (unit: days<sup>0.5</sup>), E<sub>a</sub> (unit: J mol<sup>-1</sup> K<sup>-1</sup>), and α (no unit) are fitting parameters for calendar life degradation, and k<sub>Cyc</sub> (unit: EFC<sup>-1</sup>). A, B, C, D, G, and H (no units) are fitting parameters for cycling life degradation. The value of the anode-to-reference potential, U<sub>a</sub> (unit: V), is calculated from the storage SoC using the Eqs. (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ4">4</a>) and (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ5">5</a>)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 72" title="Safari, M. & Delacourt, C. Modeling of a Commercial Graphite/LiFePO4 Cell. J. Electrochem. Soc. 158, A562 (2011)." href="/articles/s41467-022-35393-0#ref-CR72" id="ref-link-section-d14221052e1896">72</a></sup>.</p><div id="Equ4" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${U}_{a}({{x}}_{a})= 0.6379+0.5416\cdot \exp (-305.5309\cdot {x}_{a})+0.044\cdot \,\tanh \left(-\frac{{x}_{a}-0.1958}{0.1088}\right)\,\\ -0.1978\cdot \,\tanh \left(\frac{{x}_{a}-1.0571}{0.0854}\right)-0.6875\cdot \,\tanh \left(\frac{{x}_{a}+0.0117}{0.0529}\right) \\ -0.0175\cdot \,\tanh \left(\frac{{x}_{a}-0.5692}{0.0875}\right)$$</span></div><div class="c-article-equation__number"> (4) </div></div><p>where x<sub>a</sub>, which represents the lithiation fraction of the graphite, is a simple linear function of the SoC:<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 73" title="Schimpe, M. et al. Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries. J. Electrochem. Soc. 165, A181–A193 (2018)." href="/articles/s41467-022-35393-0#ref-CR73" id="ref-link-section-d14221052e2199">73</a></sup></p><div id="Equ5" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${x}_{a}({SOC})\,=\,{x}_{{a},{0}}+{SOC}\cdot ({x}_{{a},{100}}-{{x}}_{{a},{0}})$$</span></div><div class="c-article-equation__number"> (5) </div></div><p>where x<sub>a, 0</sub> is the lithiation fraction of the graphite at 0% SoC and x<sub>a, 100</sub> is the lithiation fraction of the graphite at 100% SoC. x<sub>a, 0</sub> equals to 0.0085, and x<sub>a, 100</sub> equals to 0.78.</p><p>To obtain these fitting parameters, we collect publicly available battery degradation data, including calendar life aging and cycle life aging, for NCM<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 16" title="Smith, K. et al. Life prediction model for grid-connected Li-ion battery energy storage system. in 2017 American Control Conference (ACC) 4062-4068." href="/articles/s41467-022-35393-0#ref-CR16" id="ref-link-section-d14221052e2344">16</a></sup> and LFP<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 14" title="Baghdadi, I., Briat, O., Delétage, J.-Y., Gyan, P. & Vinassa, J.-M. Lithium battery aging model based on Dakin’s degradation approach. J. Power Sources 325, 273–285 (2016)." href="/articles/s41467-022-35393-0#ref-CR14" id="ref-link-section-d14221052e2348">14</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 15" title="Naumann, M., Spingler, F. B. & Jossen, A. Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell. J. Power Sources 451, 227666 (2020)." href="/articles/s41467-022-35393-0#ref-CR15" id="ref-link-section-d14221052e2351">15</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 17" title="Naumann, M., Schimpe, M., Keil, P., Hesse, H. C. & Jossen, A. Analysis and modeling of calendar aging of a commercial LiFePO4/graphite cell. J. Energy Storage 17, 153–169 (2018)." href="/articles/s41467-022-35393-0#ref-CR17" id="ref-link-section-d14221052e2354">17</a></sup> chemistry. These data sets represent state-of-the-art lifetime performance for each chemistry; the LFP cells shown reach between 5000 and 8000 equivalent full cycles before reaching 80% remaining capacity, 4000~5000 equivalent full cycles for NCM cells. This experimental data was then fit with the semiempirical model Eqs. (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ1">1</a>), (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ2">2</a>), and (<a data-track="click" data-track-label="link" data-track-action="equation anchor" href="/articles/s41467-022-35393-0#Equ3">3</a>) using a non-linear least squares solver in MATLAB. The NCM model has no C<sub>rate</sub> dependence, due to lack of data in the aging data set, so the parameters C and D are simply set at 0 and 1. We first fit the calendar fade data with the time-dependent portion of the model (q<sub>Loss, Calendar</sub>, parameters k<sub>Cal</sub>, E<sub>a</sub>, and α); the parameter α is bounded between -1 and 1, with other parameters unbounded. The parameters for the cycling fade (A, B, C, and D) are optimized on the cycling aging data. For both LFP and NCM, the raw cycling fade data was processed prior to optimizing a model based on expert judgement. For LFP, only cells with linear fade trajectories and data for at least 5000 EFCs were used for model optimization. For NCM, only data after 200 EFC at T > 5 °C and data at q < 0.85 at T < 5 °C was used for the optimization of the NCM cycling model parameters. The optimized parameters for the LFP and NCM degradation models are shown in Supplementary Table <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">3</a>. Fitting results are shown in Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">33</a> and degradation rates are shown in Supplementary Fig. <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">34</a>.</p><p>Note that we assume NCA battery has the same degradation patterns as NCM battery due to a lack of state-of-the-art open-source data for NCA batteries. Besides cell chemistry, capacity degradation characteristics vary with cell design, manufacturing process, and proprietary additives<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 67" title="Uddin, K., Dubarry, M. & Glick, M. B. The viability of vehicle-to-grid operations from a battery technology and policy perspective. Energy Policy 113, 342–347 (2018)." href="/articles/s41467-022-35393-0#ref-CR67" id="ref-link-section-d14221052e2389">67</a>,<a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 74" title="Peterson, S. B., Apt, J. & Whitacre, J. F. Lithium-ion battery cell degradation resulting from realistic vehicle and vehicle-to-grid utilization. J. Power Sources 195, 2385–2392 (2010)." href="/articles/s41467-022-35393-0#ref-CR74" id="ref-link-section-d14221052e2392">74</a></sup>, which is out of scope of this study. We use cell degradation patterns to represent battery pack degradation without consideration of cell-to-cell and module-module differences.</p><p>For simulation of the degradation under the EV driving loads (battery SoC evolution over time) and during dynamic temperature changes, the degradation model is reformulated to solve for the degradation occurring during consecutive timesteps<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 15" title="Naumann, M., Spingler, F. B. & Jossen, A. Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell. J. Power Sources 451, 227666 (2020)." href="/articles/s41467-022-35393-0#ref-CR15" id="ref-link-section-d14221052e2399">15</a></sup>. We choose a timestep of 1 day for making SoH updates and update the SoC timeseries for each day by the current SoH. At each timestep, the temperature is the average temperature during the simulation month at city from different countries/regions. Average SoC, DoD, C<sub>rate</sub>, and the number of EFCs is extracted from the SoC timeseries. Average SoC refers to the time-averaged value of SoC. DoD is the difference between the maximum and minimum values of SoC. C<sub>rate</sub> is calculated using the absolute change of SoC per second, and then taking the average of all C<sub>rates</sub> greater than 0 during the entire timeseries. The number of EFCs is calculated by summing the changes to SoC over the timeseries. Dependence of the expected degradation rate on current SoH is incorporated by calculating a ‘virtual time’<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 15" title="Naumann, M., Spingler, F. B. & Jossen, A. Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell. J. Power Sources 451, 227666 (2020)." href="/articles/s41467-022-35393-0#ref-CR15" id="ref-link-section-d14221052e2409">15</a></sup>. The virtual time is found by inverting the calendar degradation equation to solve for time:</p><div id="Equ6" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${t}_{{virtual}}={\left({q}_{{Current}}/{k}_{{Cal}}\cdot \exp \left(\frac{-{E}_{a}}{{{{{{\bf{R}}}}}}T}\cdot \left(\frac{1}{T}-\frac{1}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)\cdot \exp \left(\frac{\alpha {{{{{\bf{F}}}}}}}{{{{{{\bf{R}}}}}}}\cdot \left(\frac{{U}_{a}}{T}-\frac{{U}_{{a},{ref}}}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)\right)}^{2}$$</span></div><div class="c-article-equation__number"> (6) </div></div><p>The degradation change ∆q during any given timestep Δt is then calculated by the following equation:</p><div id="Equ7" class="c-article-equation"><div class="c-article-equation__content"><span class="mathjax-tex">$${\Delta }q= \left({k}_{{{{{{\rm{Cal}}}}}}}\cdot \exp \left(\frac{-{E}_{a}}{{{{{{\bf{R}}}}}}T}\cdot \left(\frac{1}{T}-\frac{1}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)\cdot \exp \left(\frac{\alpha {{{{{\bf{F}}}}}}}{{{{{{\bf{R}}}}}}}\cdot \left(\frac{{U}_{a}}{T}-\frac{{U}_{{a},{ref}}}{{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}}}\right)\right)/2 \right. \\ \left. \hskip 2pt \cdot \sqrt{{t}_{{virtual}}+{\Delta }t}\right)\cdot {\Delta }t+{k}_{{Cyc}}\cdot (A\cdot {DOD}+B)\cdot (C\cdot {C}_{{rate}}+D) \\ \cdot (G\cdot {(T-{{{{{{\bf{T}}}}}}}_{{{{{{\bf{ref}}}}}}})}^{2}+H)\cdot {\Delta }EFC$$</span></div><div class="c-article-equation__number"> (7) </div></div><p>For cycling fade, the virtual EFC does not need to be calculated, as the degradation rate is constant with respect to the change of EFC during any given timestep. This reformulation of the degradation model captures the path-dependent degradation observed in real-world battery use. See Supplementary Note <a data-track="click" data-track-label="link" data-track-action="supplementary material anchor" href="/articles/s41467-022-35393-0#MOESM1">2</a> for modelled battery degradation for NCM and LFP.</p><h3 class="c-article__sub-heading" id="Sec13">Available capacity from EV batteries</h3><p>Vehicle EoL does not necessarily correspond to battery EoL. With technological improvements in battery reliability and durability, many batteries in EoL vehicles may still have years of useful life at the end of vehicle end of life. Vehicle battery EoL is usually as defined the time at which remaining battery capacity is between 70 and 80% of the original capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 7" title="Identifying and Overcoming Critical Barriers to Widespread Second Use of PEV Batteries (National Renewable Energy Lab, 2015). 
 https://www.osti.gov/biblio/1171780
 
 " href="/articles/s41467-022-35393-0#ref-CR7" id="ref-link-section-d14221052e3195">7</a></sup>. We assume an EV lifespan distribution, used in our previous work<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 27" title="Xu, C. et al. Future material demand for automotive lithium-based batteries. Commun. Mater. 1, 99 (2020)." href="/articles/s41467-022-35393-0#ref-CR27" id="ref-link-section-d14221052e3199">27</a></sup>, to account for EoL of EV. In our modelling approach, the vehicle lifespan distribution determines when batteries are not used in EVs any more (i.e., retired batteries). Retired batteries may have quite different capacity under different use conditions. When vehicles reach EoL due to consumer choices or other issues before the battery pack reaches 70% relative capacity, retired batteries will still have over 70% relative SoH and are assumed to be used in a second-life application. When battery pack reaches 70% relative SoH before a vehicle reaches its EoL, we assume that batteries may be still be used in EVs for low distances-driving. Retired batteries from such vehicles will have lower than 70% relative SoH and are assumed to be recycled rather than for a second-use. We assume any battery with a relative SoH lower than 60% is recycled and removed from potential grid storage capacity<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 75" title="Martinez-Laserna, E. et al. Technical Viability of Battery Second Life: A Study From the Ageing Perspective. IEEE Trans. Ind. Appl. 54, 2703–2713 (2018)." href="/articles/s41467-022-35393-0#ref-CR75" id="ref-link-section-d14221052e3203">75</a></sup>. However, even batteries with a relative SoH of 60–70% have a limited economic value and can have relatively high safety risks. (methods)<sup><a data-track="click" data-track-action="reference anchor" data-track-label="link" data-test="citation-ref" aria-label="Reference 32" title="Neubauer, J., Pesaran, A., Williams, B., Ferry, M. & Eyer, J. Techno-Economic Analysis of PEV Battery Second Use: Repurposed-Battery Selling Price and Commercial and Industrial End-User Value. (Sponsor Org.: USDOE Office of Energy Efficiency and Renewable Energy (EERE), Vehicle Technologies Office (EE-3V))." href="/articles/s41467-022-35393-0#ref-CR32" id="ref-link-section-d14221052e3207">32</a></sup>.</p><p>We define technical vehicle-to-grid capacity as the availability of EV battery stock capacity for vehicle-to-grid application, considering the capacity reserved for EV driving, the capacity of PHEVs that will not participate in vehicle-to-grid due to low capacity, and capacity fade due to battery degradation. We further define the actual vehicle-to-grid capacity as the availability of technical vehicle-to-grid capacity for the grid under different consumer participation rates in the vehicle-to-grid business. Results focus on investigating under which participation rate can actual vehicle-to-grid capacity meet grid storage demand.</p><p>The technical second-use capacity is defined as the retired batteries capacity that can be repurposed (i.e., retired batteries with over 70% relative SoH). We further investigate actual second-use capacity under different utilisation rates (i.e., not all retired batteries will be deployed in second-use). The results are intended to determine the required utilisation rate for the second-use battery to meet grid storage demand.</p><p>We investigate the real-world capacity as a function of both vehicle-to-grid participation rate and second-use utilisation rates. We further analyze the market participation rates and utilisation rates that are required to meet short-term grid storage demand globally.</p><h3 class="c-article__sub-heading" id="Sec14">Impact of battery capacity assumptions</h3><p>The model is highly influenced by the battery capacity per vehicle. Therefore, we conduct a sensitivity analysis of battery capacity per vehicle by assuming all BEVs are small BEVs equipped with a battery with a capacity of 33 kWh. This assumption is based on three arguments: first, small BEVs could provide most of the daily driving demand for consumers, even though they have a lower driving range than large BEVs equipped with a high-capacity battery. Second, the development of widespread EV charging infrastructure, including fast charging technology, could help to overcome the range anxiety of small BEV owners. Third, the increasing use of small BEVs would reduce demand for batteries and materials, along with lowering embodied GHG emissions of those batteries.</p></div></div></section> </div> <div class="u-mt-32"> <section data-title="Data availability"><div class="c-article-section" id="data-availability-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="data-availability">Data availability</h2><div class="c-article-section__content" id="data-availability-content"> <p>The datasets, including EV fleet size by country, EV sales share by cities, and battery chemistry share, are all deposited in an Excel file (<a href="https://doi.org/10.6084/m9.figshare.21542472.v1">https://doi.org/10.6084/m9.figshare.21542472.v1</a>). These raw data are used for the dynamic battery stock model for quantifying future battery flows. Please see the dynamic battery stock model from this link (<a href="https://doi.org/10.6084/m9.figshare.13042001.v4">https://doi.org/10.6084/m9.figshare.13042001.v4</a>). City ambient temperature and its effects on battery degradation are also deposited in the Excel file, while the code for estimating battery degradation, which is under privacy and license, is available upon reasonable request.</p> </div></div></section><div id="MagazineFulltextArticleBodySuffix"><section aria-labelledby="Bib1" data-title="References"><div class="c-article-section" id="Bib1-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="Bib1">References</h2><div class="c-article-section__content" id="Bib1-content"><div data-container-section="references"><ol class="c-article-references" data-track-component="outbound reference" data-track-context="references section"><li class="c-article-references__item js-c-reading-companion-references-item" data-counter="1."><p class="c-article-references__text" id="ref-CR1"><i>World Energy Outlook 2020</i> (IEA, 2020). <a href="https://www.iea.org/reports/world-energy-outlook-2020" data-track="click_references" data-track-action="external reference" data-track-value="external reference" data-track-label="https://www.iea.org/reports/world-energy-outlook-2020">https://www.iea.org/reports/world-energy-outlook-2020</a></p></li><li class="c-article-references__item js-c-reading-companion-references-item" data-counter="2."><p class="c-article-references__text" id="ref-CR2"><i>Global Renewables Outlook: Energy transformation 2050</i> (International Renewable Energy Agency, 2020). <a href="https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020" data-track="click_references" data-track-action="external reference" data-track-value="external reference" data-track-label="https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020">https://www.irena.org/publications/2020/Apr/Global-Renewables-Outlook-2020</a></p></li><li class="c-article-references__item js-c-reading-companion-references-item" data-counter="3."><p class="c-article-references__text" id="ref-CR3">Lund, P. 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P.G. and K.S. are supported by the National Renewable Energy Laboratory which is operated by Alliance for Sustainable Energy, LLC, for the U.S. Department of Energy under Contract No. DE-AC36-08GO28308, and acknowledge support from the Assistant Secretary for Energy Efficiency and Renewable Energy, Office of Vehicle Technologies of the U.S. Department of Energy. The views expressed in the article do not necessarily represent the views of the DOE or the U.S. Government. The U.S. Government retains and the publisher, by accepting the article for publication, acknowledges that the U.S. Government retains a nonexclusive, paid-up, irrevocable, worldwide license to publish or reproduce the published form of this work, or allow others to do so, for U.S. Government purposes.</p></div></div></section><section aria-labelledby="author-information" data-title="Author information"><div class="c-article-section" id="author-information-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="author-information">Author information</h2><div class="c-article-section__content" id="author-information-content"><h3 class="c-article__sub-heading" id="affiliations">Authors and Affiliations</h3><ol class="c-article-author-affiliation__list"><li id="Aff1"><p class="c-article-author-affiliation__address">Institute of Environmental Sciences (CML), Leiden University, 2300, RA Leiden, The Netherlands</p><p class="c-article-author-affiliation__authors-list">Chengjian Xu, Paul Behrens, Mingming Hu, Arnold Tukker & Bernhard Steubing</p></li><li id="Aff2"><p class="c-article-author-affiliation__address">National Renewable Energy Lab, 15013, Denver West Parkway, Golden, CO, USA</p><p class="c-article-author-affiliation__authors-list">Paul Gasper & Kandler Smith</p></li><li id="Aff3"><p class="c-article-author-affiliation__address">Netherlands Organisation for Applied Scientific Research TNO, 2595 DA, Den Haag, Netherlands</p><p class="c-article-author-affiliation__authors-list">Arnold Tukker</p></li></ol><div class="u-js-hide u-hide-print" data-test="author-info"><span class="c-article__sub-heading">Authors</span><ol class="c-article-authors-search u-list-reset"><li id="auth-Chengjian-Xu-Aff1"><span class="c-article-authors-search__title u-h3 js-search-name">Chengjian Xu</span><div class="c-article-authors-search__list"><div class="c-article-authors-search__item c-article-authors-search__list-item--left"><a href="/search?author=Chengjian%20Xu" class="c-article-button" data-track="click" data-track-action="author link - 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H., as well as P. G. and K. S. C.X. wrote the manuscript with the help of P.B., A.T., B.S., P. G., and other authors. P.B., A.T., and B.S. contribute significantly to the structure of research results and scientific writing of this research. P. G. and K. S. developed the battery degradation model, and further provided technical inputs on how to integrate the degradation model into the analysis of the results.</p><h3 class="c-article__sub-heading" id="corresponding-author">Corresponding author</h3><p id="corresponding-author-list">Correspondence to <a id="corresp-c1" href="mailto:xuchegjian@gmail.com">Chengjian Xu</a>.</p></div></div></section><section data-title="Ethics declarations"><div class="c-article-section" id="ethics-section"><h2 class="c-article-section__title js-section-title js-c-reading-companion-sections-item" id="ethics">Ethics declarations</h2><div class="c-article-section__content" id="ethics-content"> <h3 class="c-article__sub-heading" id="FPar2">Competing interests</h3> <p>The authors declare no competing interests.</p> </div></div></section><section data-title="Peer review"><div class="c-article-section" id="peer-review-section"><h2 class="c-article-section__title js-section-title 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id="citeas">Cite this article</h3><p class="c-bibliographic-information__citation">Xu, C., Behrens, P., Gasper, P. <i>et al.</i> Electric vehicle batteries alone could satisfy short-term grid storage demand by as early as 2030. <i>Nat Commun</i> <b>14</b>, 119 (2023). https://doi.org/10.1038/s41467-022-35393-0</p><p class="c-bibliographic-information__download-citation u-hide-print"><a data-test="citation-link" data-track="click" data-track-action="download article citation" data-track-label="link" data-track-external="" rel="nofollow" href="https://citation-needed.springer.com/v2/references/10.1038/s41467-022-35393-0?format=refman&flavour=citation">Download citation<svg width="16" height="16" focusable="false" role="img" aria-hidden="true" class="u-icon"><use xmlns:xlink="http://www.w3.org/1999/xlink" xlink:href="#icon-eds-i-download-medium"></use></svg></a></p><ul class="c-bibliographic-information__list" data-test="publication-history"><li 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