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Renewable Portfolio Standards (RPSs) are one of the most prevalent and impactful clean energy policies implemented by states in the United States. This paper investigates the regional spillover effect of RPS policies using a directed dyad panel dataset of renewable electricity generation in US states from 1991 to 2021. Regional spillover effect is measured in two ways: by considering the influence of an RPS enacted in neighboring states and in states in the same regional transmission organization or independent system operator region. We use dyadic fixed effects estimation and conclude that the neighboring state's RPS stringency score is a strong determinant of a state's total renewable electricity generation. For states without an RPS, the positive influence of an RPS in a neighboring state is larger when the non-RPS state has more abundant renewable energy resources than the neighboring RPS state. Our findings suggest that past RPS policy evaluation research using a confined within-state focus may have underestimated the holistic impact of an RPS, as the impacts of an RPS policy can extend beyond the enacting state's borders. Overall, this study contributes to an improved understanding of the holistic impact of state RPS policies. [ABSTRACT FROM AUTHOR]

Returning monarch butterflies (Danaus plexippus) to sustainable levels of abundance will require an array of contributors to protect and restore habitat over broad areas. Due to the diversity and scale of land managed by electric power companies across the monarch range, plus an additional 32 million hectares needed for new solar arrays by 2050 to meet renewable energy goals, the industry may have potential to contribute to monarch conservation. However, it is challenging to clearly understand an individual company's potential for monarch conservation because of the scale and distribution of their specific land assets (ranging from 4,800 to 240,000 hectares in this study alone), the complexity of monarch science, and the lack of a science-based approach for evaluating large land assets for monarch habitat. With monarchs potentially being protected under the United States Endangered Species Act in the future and thereby limiting land management approaches, there is interest from electric power companies to understand how their lands relate to monarchs. In collaboration with companies, we developed a GIS-based model to identify company landholdings that contain high-quality monarch habitat and applied the model to specific landholdings of eight power companies in the United States. We then facilitated discussions with company teams to balance conservation goals, corporate risk, and social opinion. This paper describes non-confidential results for developing a national GIS-based monarch habitat model and applying it to electric power companies who are considering monarch conservation while simultaneously transitioning to a new clean energy future. The model and applied experience may be useful for other organizations working across large landscapes to manage monarchs. [ABSTRACT FROM AUTHOR]

This paper examines the health tradeoffs associated with the historical expansion in coal-fired electricity generation in the United States. We combine newly digitized data on all major coal-fired power plants for the period 1938–1962 with two complementary difference-in-differences strategies. Coal-fired plants imposed large negative health externalities that were partially offset by the benefits of local electricity generation. The health impacts varied widely according to initial electricity access and evolved as the stock of generating capacity expanded over the sample period. These findings highlight the importance of accounting for both current and future payoffs when designing environmental regulation. [ABSTRACT FROM AUTHOR]

Electricity and water systems in the Western US (WUS) are closely connected, with hydropower comprising 20% of total annual WUS generation, and electricity related to water comprising about 7% of total WUS electricity use. Because of these interdependencies, the threat of climate change to WUS resources will likely have compounding electricity impacts on the Western Interconnect grid. This study describes a WUS‐wide water system model with a particular emphasis on estimating climate impacts on hydropower generation and water‐related electricity use, which can be linked with a grid expansion model to support climate‐resilient electricity planning. The water system model combines climatically‐driven physical hydrology and management of both water supply and demand allocation, and is applied to an ensemble of 15 climate scenarios out to 2050. Model results show decreasing streamflow in key basins of the WUS under most scenarios. Annual water‐related electricity use increases up to 4%, and by up to 6% during the summer months, driven by growing agricultural demands met increasingly through a shift toward energy‐intensive groundwater to replace declining surface water. Total annual hydropower generation changes by +5% to −20% by mid‐century but declines in most scenarios, with decreases in summer generation by up to nearly −30%. Water‐related electricity use increases tend to coincide with hydropower generation declines, annually and seasonally, demonstrating the importance of concurrently evaluating the climate signal on both water‐for‐energy and energy‐for‐water to inform planning for grid reliability and decarbonization goals. Plain Language Summary: Electricity and water systems in the Western United States (WUS) have a strong dependency. Water fuels hydropower generation and electricity is used to pump, transport, treat, heat, and dispose of water. Climate change poses a serious threat to water availability in the WUS and is likely to also affect hydropower generation and electricity use related to water. This study develops a WUS water system model to evaluate the impact of a set of climate change scenarios on the dynamic interplay between water availability and demand and hydropower generation and electricity use by the water sector by 2050. We find that in many key basins, streamflow decreases under the climate scenarios. At the same time, reliance on groundwater increases to meet growing agricultural water demand. Hydropower generation shows decreases in most cases while energy use related to water increases. Because these hydropower generation declines tend to occur during periods when electricity demand for water grows, electricity grid planners in the Western Interconnect will benefit from this type of study by informing future grid buildouts that maintain reliability and decarbonization goals. Key Points: Interactions among hydro‐climate, hydropower, and water's energy use are critical for evaluating Western US (WUS) water‐energy climate risksUnder climate change, our WUS water model finds declining streamflows, growing agricultural demands, and increased groundwater useWith warming and drying, water‐related energy use grows while hydropower generation decreases under most climate scenarios by mid‐century [ABSTRACT FROM AUTHOR]

In 2022, wind generation accounted for ~10% of total electricity generation in the United States. As wind energy accounts for a greater portion of total energy, understanding geographic and temporal variation in wind generation is key to many planning, operational, and research questions. However, in-situ observations of wind speed are expensive to make and rarely shared publicly. Meteorological models are commonly used to estimate wind speeds, but vary in quality and are often challenging to access and interpret. The Plant-Level US multi-model WIND and generation (PLUSWIND) data repository helps to address these challenges. PLUSWIND provides wind speeds and estimated generation on an hourly basis at almost all wind plants across the contiguous United States from 2018–2021. The repository contains wind speeds and generation based on three different meteorological models: ERA5, MERRA2, and HRRR. Data are publicly accessible in simple csv files. Modeled generation is compared to regional and plant records, which highlights model biases and errors and how they differ by model, across regions, and across time frames. [ABSTRACT FROM AUTHOR]

Policy-makers seeking to limit the impact of coal electricity-generating units (EGUs, also known as power plants) on air quality and climate justify regulations by quantifying the health burden attributable to exposure from these sources. We defined “coal PM2.5” as fine particulate matter associated with coal EGU sulfur dioxide emissions and estimated annual exposure to coal PM2.5 from 480 EGUs in the US. We estimated the number of deaths attributable to coal PM2.5 from 1999 to 2020 using individual-level Medicare death records representing 650 million person-years. Exposure to coal PM2.5 was associated with 2.1 times greater mortality risk than exposure to PM2.5 from all sources. A total of 460,000 deaths were attributable to coal PM2.5, representing 25% of all PM2.5-related Medicare deaths before 2009 and 7% after 2012. Here, we quantify and visualize the contribution of individual EGUs to mortality [ABSTRACT FROM AUTHOR]

Surveys of the costs of inputs assigned to pollution abatement (Stated Costs) have been the principal method used to estimate pollution abatement costs. While surveys have been widely used, problems with these surveys may adversely affect their ability to accurately measure pollution abatement costs. In this paper, we propose a method that does not depend on surveys of input costs. Instead, a nonparametric cost function that models the joint production of good and bad outputs is used to identify the cost of inputs assigned to pollution abatement (Revealed Costs). The increased input costs when the bad output is not freely disposable compared to input costs when the bad output is freely disposable constitute our estimate of the revealed cost of pollution abatement. Our model is illustrated using data from coal-fired electric power plants in the United States for 2000–2005. [ABSTRACT FROM AUTHOR]

Efficient electricity market operations and cost-effective electricity generations are fundamental to a low-carbon energy future. The Western Electricity Coordinating Council (WECC) and Northeast Power Coordinating Council (NPCC) systems were built to provide efficient electrical grid simulation solutions for their respective U.S. regions. Data reuse for electricity economic studies remains a challenge due to the lack of credible and realistic economic data. This paper delivers a comprehensive dataset containing generator aggregations, generator costs, transmission limits, load distributions, and electricity prices for the WECC and NPCC systems based on real-world grid operation data at year 2020, including power plant geographic locations, generation profiles, regional power flow interchanges, and load distributions in both regions. The electricity price from the developed dataset is simulated based on the other items in the dataset, and we show that the variation of the simulated electricity price reasonably aligns with the real-world electricity price in both the WECC and NPCC regions. Overall, the developed dataset is of interest for various electricity market and economic studies, such as the economic dispatch and locational marginal price (LMP) analysis. [ABSTRACT FROM AUTHOR]

The scale and pace of energy infrastructure development required to achieve netzero greenhouse gas (GHG) emissions are unprecedented, yet our understanding of how to minimize its potential impacts on land and ocean use and natural resources is inadequate. Using high-resolution energy and land-use modeling, we developed spatially explicit scenarios for reaching an economy-wide net-zero GHG target in the western United States by 2050. We found that among net-zero policy cases that vary the rate of transportation and building electrification and use of fossil fuels, nuclear generation, and biomass, the "High Electrification" case, which utilizes electricity generation the most efficiently, had the lowest total land and ocean area requirements (84,000 to 105,000 km² vs. 88,100 to 158,000 km² across all other cases). Different levels of land and ocean use protections were applied to determine their effect on siting, environmental and social impacts, and energy costs. Meeting the net-zero target with stronger land and ocean use protections did not significantly alter the share of different energy generation technologies and only increased system costs by 3%, but decreased additional interstate transmission capacity by 20%. Yet, failure to avoid development in areas with high conservation value is likely to result in substantial habitat loss. [ABSTRACT FROM AUTHOR]

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Policies to reduce greenhouse gases associated with electricity generation have been a major focus of public policy in the United States, but their implications for achieving environmental justice among historically overburdened communities inappropriately remains a marginal issue. In this study we address research gaps in historical and current ambient air emissions burdens in environmental justice communities from power plants participating in the Regional Greenhouse Gases Initiative (RGGI), the country's first market-based power sector emissions reduction program. We find that in RGGI states the percentage of people of color that live within 0–6.2 miles from power plants is up to 23.5 percent higher than the percent of the white population that lives within those same distance bands, and the percentage of people living in poverty that live within 0–5 miles from power plants is up to 15.3 percent higher than the percent of the population not living in poverty within those same distance bands. More importantly, the transition from coal to natural gas underway before RGGI formally started resulted in large increases in both the number of electric-generating units burning natural gas and total net generation from natural gas in environmental justice communities hosting electric-generating units, compared to other communities. Our findings indicate that power sector carbon mitigation policies' focusing on aggregate emissions reductions have largely benefitted non-environmental justice communities and have not redressed the fundamental problem of disparities in pollutant burdens between EJ and non-EJ communities. These must be directly addressed in climate change and carbon emissions mitigation policy. [ABSTRACT FROM AUTHOR]

Building electrification is essential to many full-economy decarbonization pathways. However, current decarbonization modeling in the United States (U.S.) does not incorporate seasonal fluctuations in building energy demand, seasonal fluctuations in electricity demand of electrified buildings, or the ramifications of this extra demand for electricity generation. Here, we examine historical energy data in the U.S. to evaluate current seasonal fluctuation in total energy demand and management of seasonal fluctuations. We then model additional electricity demand under different building electrification scenarios and the necessary increases in wind or solar PV to meet this demand. We found that U.S. monthly average total building energy consumption varies by a factor of 1.6×—lowest in May and highest in January. This is largely managed by fossil fuel systems with long-term storage capability. All of our building electrification scenarios resulted in substantial increases in winter electrical demand, enough to switch the grid from summer to winter peaking. Meeting this peak with renewables would require a 28× increase in January wind generation, or a 303× increase in January solar, with excess generation in other months. Highly efficient building electrification can shrink this winter peak—requiring 4.5× more generation from wind and 36× more from solar. [ABSTRACT FROM AUTHOR]

Solar photovoltaics (PV) are the fastest growing renewable energy technologies for clean, cheap, and sustainable electricity generation. To prepare for rapid scale‐up, the PV industry needs to project material requirements to build out all aspects of the supply chain appropriately and plan to handle large volumes of module waste. Impacts of deploying different material circularity strategies to reduce waste and conserve primary resources need to be quantified to inform sustainable material management. Here, we introduce the photovoltaic dynamic material flow analysis (PV DMFA) model based on PV electricity generation. The model quantifies material flows and stocks in the cradle‐to‐cradle life cycles of utility‐scale c‐Si PV systems in the United States through 2100. We present case studies for solar flat glass and aluminum frame materials under various scenarios to project the impacts of PV performance, reliability, and processing parameters, material circularity strategies, and module design shifts. In the absence of circularity measures, ~100 million MT of flat glass and ~12 million MT of aluminum would be needed for PV installations by 2100 to meet projected growth in domestic utility PV demand to nearly 1000 TWh in 2100. With optimistic but feasible improvements in efficiency, reliability, and circularity, material intensity and waste could be reduced by nearly 50%. Efficient module collection, minimally intrusive recycling, and careful scrap handling and cleaning could improve material circularity in the PV value chain. This model serves as a sustainability data support tool that may aid in the circular economy transition for PV systems. [ABSTRACT FROM AUTHOR]

This paper describes GCAM-USA v5.3_water_dispatch, an open-source model that represents key interactions across economic, energy, water, and land systems in a consistent global framework with subnational detail in the United States. GCAM-USA divides the world into 31 geopolitical regions outside the United States (US) and represents the US economy and energy systems in 51 state-level regions (50 states plus the District of Columbia). The model also includes 235 water basins and 384 land use regions, and 23 of each fall at least partially within the United States. GCAM-USA offers a level of process and temporal resolution rare for models of its class and scope, including detailed subnational representation of US water demands and supplies and sub-annual operations (day and night for each month) in the US electric power sector. GCAM-USA can be used to explore how changes in socioeconomic drivers, technological progress, or policy impact demands for (and production of) energy, water, and crops at a subnational level in the United States while maintaining consistency with broader national and international conditions. This paper describes GCAM-USA's structure, inputs, and outputs, with emphasis on new model features. Four illustrative scenarios encompassing varying socioeconomic and energy system futures are used to explore subnational changes in energy, water, and land use outcomes. We conclude with information about how public users can access the model. [ABSTRACT FROM AUTHOR]

Between 2010 and 2020, residential solar installations grew at an average rate of 42% per year in the United States with subsidies and promises of rapid payback times contributing to adoption. However, the relationship between geographically localized economic drivers, adoption of residential solar energy, and the impact on carbon emissions remain poorly quantified. Here we assess the geospatial variations in economic payoff and carbon offset within the United States and propose a more efficient geographical roadmap for subsidies focus. The results show that the economic benefits of residential solar depend strongly on local electricity prices and energy mix. We find favorable economics in some regions with low solar irradiance and some sunny locations where residential solar will not be competitive relative to local electricity prices. Similarly, the reduction in the carbon footprint of electricity generation that the adoption of residential solar could provide varies strongly by location. We also identify optimal places for policy deployment and provide helpful data to allow for informed decisions by policymakers. [ABSTRACT FROM AUTHOR]

Electric transmission infrastructure is often undervalued in the United States. However, a recent surge of electrical blackouts due to extreme weather conditions and natural disasters has brought the United States' aging transmission infrastructure to the spotlight. Recent cyberattacks on critical energy infrastructure have also brought attention to the vulnerabilities in the U.S. electric infrastructure. Advancements such as the growth of electrification in the transportation sector and the integration of variable renewable energy critical to the decarbonization of the energy sector, further challenge the capacity of current electrical infrastructure. Addressing deficiencies within U.S. electric infrastructure requires the collaboration of many stakeholders including federal agencies, state governments, local communities, and electricity generation and distribution entities. To properly undertake the challenges to the United States transmission infrastructure, it is recommended that potential solutions are accurately modeled, that the FERC uses its rulemaking capacity to foster collaboration, and that the federal government creates a national transmission loan program to specifically fund nationally significant transmission projects. [ABSTRACT FROM AUTHOR]

This paper evaluates changes in electricity generation costs caused by the introduction of market mechanisms to determine production in the United States. I use the staggered transition to markets from 1999 to 2012 to estimate the causal impact of liberalization using a differences-in-difference design on a comprehensive hourly panel of electricity demand, generators' costs, capacities, and output. I find that markets reduce production costs by 5 percent by reallocating production: gains from trade across service areas increase by 55 percent based on a 25 percent increase in traded electricity, and costs from using uneconomical units fall 16 percent. (JEL L51, L94, L98, Q41, Q48) [ABSTRACT FROM AUTHOR]

Finding and securing employment is a huge challenge for those who have been released from prison. In this paper, we argue that carbon capture technology carries the unique potential to positively impact employment opportunities for those who are undergoing the reentry process. Notably, these careers exist nearly entirely in industries which already employ ex-felons. If carbon capture technology were implemented throughout the United States, our estimates suggest that ex-felons would be eligible for nearly 3.6 million careers. Many of these jobs would be created in industries which directly or indirectly support natural resource extraction, ethanol production, electricity generation, and iron, steel, and cement production. In addition to benefiting the economy, these careers would provide returning individuals with financial security and supportive, prosocial peer relationships. Accordingly, carbon capture carries the unique ability to promote environmental justice while simultaneously providing relief to a tremendously overburdened criminal justice system. [ABSTRACT FROM AUTHOR]

Natural gas is one of the main energy resources for electricity generation. Reliable forecasting is vital to make sensible policies. A randomly optimized fractional grey system model is developed in this work to forecast the natural gas consumption in the power sector of the United States. The nonhomogeneous grey model with fractional-order accumulation is introduced along with discussions between other existing grey models. A random search optimization scheme is then introduced to optimize the nonlinear parameter of the grey model. And the complete forecasting scheme is built based on the rolling mechanism. The case study is executed based on the updated data set of natural gas consumption of the power sector in the United States. The comparison of results is analyzed from different step sizes, different grey system models, and benchmark models. They all show that the proposed method has significant advantages over the other existing methods, which indicates the proposed method has high potential in short-term forecasting for natural gas consumption of the power sector in United States. [ABSTRACT FROM AUTHOR]

Summary: Many electricity consumers around the world are billed electric peak load charges. In the United States, these demand charges can contribute up to 70% of a consumer's electricity bill. Research has shown that the financial impact of these charges to the consumers can be reduced by acting on the intelligence provided by peak electric load day (PELD) forecasts. Unfortunately, published research detailing PELDs forecasting methodologies for facilities adopting behind the meter renewable electricity generation (BTMREG) is non‐existent. This paper contributes: (a) a PELD forecasting methodology applicable to consumers with BTMREG. A case study demonstrates the methodology's ability to achieve 93% of the potential savings in kW, translating to demand charge reductions of approximately US$ 142 129 per year. (b) The first side‐by‐side performance comparisons of electric load and PELD forecasting models for scenarios with and without BTMREG. (c) The first PELD forecasting model savings comparison for scenarios with and without BTMREG. Experimental results suggest that counterintuitively, BTMREG adoption can translate into higher peak load savings for electricity consumers. [ABSTRACT FROM AUTHOR]

The average effect of deregulatory policies on fuel prices at coal-fired power plants is strongly influenced by plants that were initially paying the highest prices for fuel. Primary sources document that these plants were locked into long-term, high-cost fuel contracts, and only secured market rates post-deregulation. While these plants' fuel costs were unusual, their response to deregulation was not: both coal- and gas-fired plants reduce fuel prices one-for-one with the amount they were initially paying above their neighbors' costs. Our understanding of deregulation is not improved by excluding those who stand to benefit most. (JEL L51, L71, L94, L98, Q35, Q41, Q48) [ABSTRACT FROM AUTHOR]

Accurately measuring water use by the economy is essential for developing reliable models of water resource availability. Indeed, these models rely on retrospective analyses that provide insights into shifting human population demands and adaptions to water shortages. However, accurate, methodologically consistent, empirically authentic, and spatiotemporally comprehensive historical datasets for water withdrawals are scarce. Herein, we present a reanalysis of annual resolution (1950–2016) historical data set on irrigation, electric power, and public supply water withdrawal within the conterminous United States (US) at the county‐level, and, for power plants, at the site‐level. To estimate electric power water use, we synthesized a historically comprehensive list of generators and historic patterns in generation across fuels, prime movers, and cooling technologies. Irrigation water use estimation required building a crop‐demand model that utilized historical information on irrigated acreage for crops and golf courses, stage‐specific crop water demand, and climate information. To estimate public water supply use, we developed a random forest model constructed from information on population, infrastructure, climate, and land cover. These estimates generally agree with total county and state water use information provided by the US Geological Survey (USGS) water use circular and estimates generated from independent studies for specific years. However, we also observed discrepancies between our estimates and USGS data that appear to be caused by inconsistencies in the methods used by the USGS's primary data sources at the state level over decades of data collection, highlighting the importance of reanalysis to yield spatiotemporally consistent and intercomparable estimates of water use. Key Points: Spatiotemporally comprehensive water use data are needed to characterize water resource availability and model long‐term hydrologic changesWe present an annual (1950–2016) data set on US agriculture, electric power, and public supply water use at the county levelThe data set provides new spatiotemporally rich information compiled using consistent reanalysis methods to inform multi‐sectoral research [ABSTRACT FROM AUTHOR]

Renewable electricity generation technologies provide a more sustainable solution than the non-renewables. However, as a complete system, renewable energy generation systems have some overall environmental impacts on humankind, resources and ecosystems. This paper will address the environmental effects caused by different types of renewable plants through life-cycle assessment. A comparative study is done among solar PV, biomass, and pumped storage hydropower plants in the United States. Life-cycle impact analysis has been carried out by the Eco-indicator 99, TRACI (Tool for the Reduction and Assessment of Chemical and other Environmental Impacts), CED (Cumulative Energy Demand), Ecopoints 97, RMF (Raw Material Flows) and IPCC (Intergovernmental Panel on Climate Change) methods, using the SimaPro software. The impacts are considered in 10 mid-point impact categories and three end-point indicators. The results show that pumped storage hydropower plants have the highest impact on human health (7.74E-05/kWh) and the ecosystem (3.35E-06/kWh), whereas biomass plants have the maximum effect on resources (4.79E-07/kWh). Overall, the solar PV plants are found to be much more environment-friendly than other renewable electricity generation systems. These findings will guide investors in installing sustainable and clean power plants. • Comparative environmental impacts of solar-PV, biomass and pumped storage hydropower plants was investigated. • Impacts are assessed by a systematic LCA analysis using the ecoinvent database and SimaPro software. • Solar-PV plants are found least hazardous to environment than other renewable energy plants in the United States. • Findings will guide the investors in installing the best renewable power plant considering the environmental aspects. [ABSTRACT FROM AUTHOR]

The U.S. electric power sector has experienced a substantial shift of the generation mix since the turn of the century, moving from heavy reliance on coal‐powered generation to one drawing more from natural gas and, more recently, renewables. This transition has been forged by a mix of macroeconomic factors (recession and recovery); technological breakthroughs (horizontal drilling coupled with hydraulic fracturing; improvements in natural gas plant efficiency); clean energy policies at federal, state, and local levels of government; and private sector demands for carbon‐free energy sources. These factors have combined to reduce carbon emissions from electric power generation substantially this century. In this article we examine the extent of this transition, its causes, as well as the distinct American institutional factors steering it, including energy and environmental federalism, electoral politics, and the political economy of clean energy policy enactment and resistance. [ABSTRACT FROM AUTHOR]

The implications of national or regional energy policies for technical efficiency and environmental outcomes in electricity generation depend on fossil fuel input substitution. This study uses state level data to examine fossil fuel (coal and natural gas) substitution in electricity generation under increased availability of natural gas in the United States. We observe that changes in elasticities of substitution from pre-2009 to post-2009 differ across states suggesting that the effects of increased availability of inexpensive natural gas on electricity generation have been spatially heterogeneous. We rely on the observed heterogeneity to assess the effects of fossil fuel input substitution on technical efficiency and CO2 emissions. The results reveal that state level elasticity of substitution between natural gas and coal has a positive effect on technical efficiency and a negative effect on CO2 emissions. Therefore, future policy design and analyses should reflect the implications for regional elasticities of fossil fuel substitution and associated environmental outcomes. [ABSTRACT FROM AUTHOR]

The Weather Research and Forecasting (WRF) Model has been extensively used for wind energy applications, and current releases include a scheme that can be applied to examine the effects of wind turbine arrays on the atmospheric flow and electricity generation from wind turbines. Herein we present a high-resolution simulation using two different wind farm parameterizations: 1) the "Fitch" parameterization that is included in WRF releases and 2) the recently developed Explicit Wake Parameterization (EWP) scheme. We compare the schemes using a single yearlong simulation for a domain centered on the highest density of current turbine deployments in the contiguous United States (Iowa). Pairwise analyses are applied to diagnose the downstream wake effects and impact of wind turbine arrays on near-surface climate conditions. On average, use of the EWP scheme results in small-magnitude wake effects within wind farm arrays and faster recovery of full WT array wakes. This in turn leads to smaller impacts on near-surface climate variables and reduced array–array interactions, which at a systemwide scale lead to summertime capacity factors (i.e., the electrical power produced relative to nameplate installed capacity) that are 2%–3% higher than those from the more commonly applied Fitch parameterization. It is currently not possible to make recommendations with regard to which wind farm parameterization exhibits higher fidelity or to draw inferences with regard to whether the relative performance may vary with prevailing climate conditions and/or wind turbine deployment configuration. However, the sensitivities documented herein to the wind farm parameterization are of sufficient magnitude to potentially influence wind turbine array siting decisions. Thus, our research findings imply high value in undertaking combined long-term high-fidelity observational studies in support of model validation and verification. [ABSTRACT FROM AUTHOR]

For the last 12 years, the natural gas industry has been booming, ever since the Shale Revolution took off. It was a while before the industry began to think of itself in supply "abundance" terms—from expecting to import 8 Bcf/day of liquefied natural gas (LNG) by 2030 to expecting to export 14 or so Bcf/day by then—an expectation that looks increasingly conservative in terms of new‐build capacity. The swing between those two numbers, as measurements of the marginal supply‐demand "over‐under," in essence signaled the United States was adding natural gas supply that will surpass two times the exports of Qatar, the largest LNG exporter in the world. Domestic demand was expected to grow mightily, as abundance‐driven decreases in price led to big gains in market share in both industrial use and electric power generation. Wow, compared with the pre‐2008 predictions of $20 per million Btu prices, increasing imports, and decreased availability, it was as if the sun had come up. [ABSTRACT FROM AUTHOR]

Interest and availability of photovoltaic solar (solar PV) as a source of renewable electricity generation is rapidly increasing across the country; however, its penetration on a national scale remains very low. There are many natural constraints that can serve as factors, including large upfront module costs, locations that do not receive enough sunlight throughout the year, and the inability to be self‐sufficient from using solar PV power alone. Although the use of this specific distributed energy resource (DER) universally throughout the United States in the near future is improbable, it is interesting to ponder a future where solar PV and other DERs are as common as the current methods we use to generate, transmit, distribute, and consume power. Thinking this way helps identify where we are prone to imprecisely estimating outcomes that could have far‐reaching impacts. [ABSTRACT FROM AUTHOR]

CO2 capture and storage (CCS) can be an important feature of a decarbonization strategy involving electricity generation. According to the recently revised Section 45Q tax credits, said credits will be provided for implementing CCS, which is motivating some United States (US) electricity generation companies to revisit their business strategies for CCS. This paper discusses alternative business models being considered by companies for undertaking CCS, including providing a 'template' for evaluating the cost‐effectiveness of CCS with Section 45Q tax credits and storage in saline reservoirs. Using stylized illustrative examples, the paper indicates how use of Section 45Q tax credits should be expected to change dispatch at an electricity generating unit. For situations similar to the examples, the paper suggests that Section 45Q tax credits may need to be modified to achieve its intended impact. Modifications can include extending the time period of tax credit availability beyond the current 12 years. In addition, continued R&D investments in CCS and specific support for first‐of‐a‐kind CCS demonstrations would be valuable complements for the deployment of the Section 45Q tax credit. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

As the deployment of wind and solar energy increases in the USA, energy storage (ES) will play an important role in future electric power grids to help manage the variability from high penetration levels of renewable generation, ES can provide promising power/energy demand to coordinate with renewables generation, as a virtual power plant (VPP). There is an industry need for the capability in power system studies to model ternary pumped storage hydropower (T-PSH), a pumped storage technology that offers increased system benefits. This study presents a comprehensive vendor-neutral dynamic model of T-PSH in GE's commercial software positive sequence load flow. A new governor model is developed with detailed gate valve modelling and a shared-penstock function. Specifically, this model is designed to simulate the seamless transition among three operation modes: generation mode, pumping mode, and hydraulic short-circuit mode. The developed T-PSH model has been tested and validated on a 10-bus test system. A comparison study of T-PSH to conventional pumped storage hydropower has also been conducted on the Western interconnection system. [ABSTRACT FROM AUTHOR]

North Korea badly needs energy assistance and has long wanted it in the form of light water reactors, creating a potential bargaining chip in the next round of discussions with Pyongyang. [ABSTRACT FROM AUTHOR]

• Modeling method to quantify technology costs required to reach specific deployment. • Nuclear levelized costs of $53–84/MWh required for incremental 1% by 2050. • Concentrating solar power costs of $65–91/MWh required for incremental 1% by 2050. • Offshore wind costs of $39–77/MWh required for incremental 1% by 2050. • More challenging cost targets found with greater penetration due to value decline. Clean energy deployment scenarios typically assume a diverse mix of low-emission generation. However, because of historically low natural gas prices and cost reductions for onshore wind and photovoltaic technologies, recent new capacity deployment, especially in the United States, has come largely from these three generation sources. Here, we quantify competitive cost targets for three less-common zero-emission generation technologies—nuclear, concentrating solar, and offshore wind—under a range of future conditions. We determine the cost targets based on the technologies' system value, such that technology value equals or exceeds its cost. Using a capacity expansion model that develops system-wide, economically optimal generation scenarios of the United States power sector, we find that nuclear, concentrating solar, and offshore wind would need to attain levelized cost ranges of $53–84/MWh, $65–91/MWh, and $39–77/MWh, respectively, to achieve 1% additional grid penetration. We refer to this metric as the "required cost," which is a technology's levelized cost of energy needed to achieve a specific penetration level. Higher penetrations lead to lower required costs as lower-cost generation is displaced. We estimate that to reach 10% penetration, the required cost for nuclear declines to $45–76/MWh. Because of resource variability and increased transmission needs for concentrating solar power and offshore wind, even lower costs are needed to reach higher penetrations: required cost ranges to achieve 10% penetration are estimated to be $30–56/MWh and $18–40/MWh for these two technologies respectively. Our analysis informs research and development priorities and the design of policies supporting clean technologies. [ABSTRACT FROM AUTHOR]

• Across NYS, a wealth of low-value land exists to support utility-scale solar PV. • Solar generation can reduce summer peak demand by up to 9.6% in certain regions in New York. • Regional ramping requirements may increase by up to 151% during sunny winter days. • PV performance during system peak should be retained in capacity valuation of solar. Rapidly growing utility-scale solar photovoltaic (PV) holds promise for addressing the energy and environmental challenges posed by high electricity demand days (HEDDs). We assessed the implications on strategic planning of future solar development in an emerging solar market, New York State (NYS) in the U.S., by synthesizing information on electrical infrastructure, tax assessment, geographical constraints and measured meteorological data. Considering three solar PV penetration scenarios (4500 MW, 6000 MW, and 9000 MW), we examined the impact of distributed utility-scale solar farms on peak demand reduction and ramping requirements during historical peak events. Our results reiterate that, across NYS, a wealth of low-value land exists to support utility-scale solar PV and that generation from these resources can reduce peak demand by up to 9.6% under the 9000 MW scenario. In addition, peak demand reduction displays locational and temporal dependency. Contingent upon local meteorology, a solar farm can reduce demand during the peak hour by anywhere between 10 and 74% of its rated capacity during summer HEDDs. However, the highest ramping requirements are more likely to occur during winter than summer. Furthermore, because developers cannot predict performance during the annual system peak, current capacity valuation methodologies for solar projects may not be adequate to promote a healthy competitive market for solar. Incorporating a broader spectrum of peak demand conditions into variable resource capacity valuation would improve strategic planning, not only in NYS, but across growing solar markets worldwide. [ABSTRACT FROM AUTHOR]

• We incorporate life cycle impacts to energy systems models via monetization. • The cost of leaving the Paris Agreement for the US is 1103 billion USD 2013 in 2030. • Further economic savings could be realized by minimizing life cycle impacts. • Wind onshore is critical for minimizing all environmental impacts concurrently. • The Paris Agreement could induce burden-shifting between sustainability criteria. Current energy systems models focus on cost minimization with a bound on some greenhouse gas emissions. This limited environmental scope can lead to mixes that are not consistent with our sustainable development. To circumvent this limitation, we here make use of the concept of monetization and life cycle assessment to quantify the indirect costs of electricity generation in the design of energy systems. Applying our approach to the United States, we found that the indirect costs of electricity generation could be reduced by as much as 63% by meeting the Paris Agreement. Consequently, the total opportunity cost (i.e., direct and indirect costs) of withdrawing from the Paris Agreement and continuing with the current mix would be as high as 1103 ± 206 billion USD 2013 in 2030 (i.e., 6% of the United States gross domestic product in 2017). By optimizing the direct and indirect costs of electricity generation concurrently, we found an optimal ecological solution that attains total economic savings compared to the Paris Agreement mix of as much as 373 ± 164 billion USD 2013 in 2030. Our work highlights the need to extend the environmental policies that regulate energy systems beyond the direct greenhouse emissions to consider other critical environmental criteria. [ABSTRACT FROM AUTHOR]

This paper discusses the growth of wind power generation in the United States. As wind power has spread, states have used different methods for valuing wind farms for property taxation. Generation of electricity by wind takes two forms: in utility-grade generation, large turbines, usually in farms, are designed to produce electricity for the grid, and in distributed generation, smaller units are not connected to the grid but are designed to generate power for a business, manufacturing complex, agriculture, or local networks. Only utility-grade generation is considered here. The valuation methods used in the principal wind states are described. Also, a more detailed analysis of alternative methods of valuation is presented. Finally, specific issues for assessors to consider in valuing wind farms are discussed. [ABSTRACT FROM AUTHOR]

Abstract The economic viability of new energy technologies is held as a central tenet to their future deployment; conventional wisdom posits economically rational decision-makers will readily invest in proven low-risk and affordable technologies. But what happens when this is not true. This paper examines the non-financial barriers facing economically viable Combined Heat and Power (CHP) projects. CHP is a mature and lower carbon technology that efficiently uses waste heat from thermal electricity generation; CHP can also provide flexibility services to help integrate variable renewable resources. CHP is low risk and many industrialized countries, particularly those in colder climates in Northern Europe and Russia, generate as much as 50% of their electricity and heat needs from CHP, but United States deployment remains low and investment hurdle rates high. While lower U.S. energy costs make some projects un-economic, many economically-viable CHP projects are stalled or killed by non-financial barriers. To better understand why financially viable CHP projects are not getting built, developers, owners and operators, regulators, and other stakeholders of this technology were interviewed and three major barriers emerged a) the business model of the electrical utility b) negative subjective impressions and c) challenges in allocating the risks and benefits. [ABSTRACT FROM AUTHOR]

Highlights • Hybrid LCA used to compare global warming potential of water refill stations to bottled water. • Several water consumption scenarios examined in four locations (Israel, USA, UK, and China). • GWP of water refill stations 2-6 times less than bottled water and most strongly influenced by electricity generation mix. Abstract Growing consumption of single-use bottled water has received criticism due to potentially adverse environmental outcomes. Networks of public-sphere water delivery stations have been proposed as a sustainable alternative for water consumption on-the-go, yet the life-cycle impacts of such stations are poorly understood. Here we evaluate the potential cumulative energy demand and climate change impacts of water delivered from a filtered water refill station under various consumption scenarios and provide a comparison to published results for bottled water. Using a hybrid life-cycle analysis framework employing physical and economic data, we model the water station's performance in four locations: Tel-Aviv, Israel; Miami Beach, Florida, USA; London, UK; and Shanghai, China. We find that the climate change impact of the station is two to six times lower than those of bottled water and that use phase electricity is the most influential factor in determining the station's environmental impact. We provide additional observations related to scaling up such a system and recommendations to realize further gains in eco-efficiency. [ABSTRACT FROM AUTHOR]