Abstract:While grid-scale electricity storage (hereafter 'storage') could be crucial for deeply decarbonizing the electric power system, it would increase carbon dioxide (CO 2 ) emissions in current systems across the United States. To better understand how storage transitions from increasing to decreasing system CO 2 emissions, we quantify the effect of storage on operational CO 2 emissions as a power system decarbonizes under a moderate and strong CO 2 emission reduction target through 2045. Under each target, we com… Show more
“…To co-optimize energy and reserves, we set regulation provision costs to $10, $6 and $4 ($ 2017 ) per megawatt-hour (MWh) for coal, NGCC and natural gas steam units, respectively. These costs capture variable operation and maintenance (VOM) and heat rate degradation costs incurred while providing reserves (Craig et al 2018b).…”
Section: Uced Modelmentioning
confidence: 99%
“…To ensure system reliability against variable wind and solar generation and unexpected generator and transmission outages, as well as to approximate current reserve classes in ERCOT (Electric Reliability Council of Texas 2013), the UCED model includes three reserve classes: regulation, flexibility and contingency reserves (table 1) (SI.1). To capture greater reserve requirements at high wind and solar penetrations modeled here, the three reserve classes vary with load and wind and solar generation (Craig et al 2018b, Lew et al 2013. All reserve classes procure positive or up reserves, i.e.…”
Section: Uced Modelmentioning
confidence: 99%
“…Since hydropower accounts for less than 1% of the fleet capacity, we subtract the estimated hourly generation by hydropower units from demand, then remove them from our fleet (SI.1). We augment the CDR generator fleet with carbon dioxide (CO 2 ) emission rates by fuel type (US Energy Information Administration 2017a); unit commitment parameters by plant and fuel type and capacity (Craig et al 2018b); VOM costs by fuel type (Craig et al 2018b); and latitudes and longitudes (US Environmental Protection Agency 2017) (SI.1). Based on 2017 data for Texas, we set coal, natural gas and nuclear fuel costs equal to $2.21, $3.26 and $0.65 per MMBtu ($ 2017 ) (US Energy Information Administration 2018), but test the sensitivity of our results to higher natural gas prices of $6 per MMBtu ($ 2017 ).…”
Section: Generator Fleetmentioning
confidence: 99%
“…Since we conduct our analysis for 2041-2050 climate change conditions and given recent continued growth in Texas renewable penetrations, we add 15 GW wind and 30.5 GW solar to the CDR fleet (which originally contained 20 GW wind and 1 GW solar) to construct a high-renewable fleet with roughly 25% wind and 15% solar penetration by energy. We use greater wind than solar capacity to reflect results of studies on cost-optimal high-renewable generation fleets (Hand et al 2012, Craig et al 2018b. Given that adding renewables increases system reserve and flexibility requirements, we do not remove generators from the CDR fleet.…”
Climate change will likely impact wind and solar resources. As power systems increasingly shift towards wind and solar power, these resource changes will increasingly impact power system operations. We assess how power system operations will be affected by climate change impacts on wind and solar resources by generating wind and solar generation profiles for a reference period and five climate change projections. We then run a unit commitment and economic dispatch model to dispatch a highrenewable generator fleet with these profiles. For climate change projections, we use 2041-2050 output from five global climate models (GCMs) for Representative Concentration Pathway 8.5 for Texas, our study system. All five GCMs indicate increased wind generation potential by 1%-4% under climate change in Texas, while three and two GCMs indicate increased and decreased solar generation potential, respectively, by up to 1%. Uneven generation potential changes across time result in greater changes in dispatched generation by fuel type. Notably, nuclear generation decreases across GCMs by up to 7%, largely in low-demand (winter) months when nuclear plants, which have a high minimum stable load, must reduce their generation to avoid overgeneration. Increased wind and/or solar generation result in reduced system CO 2 emissions and electricity production costs across four of the five GCMs by 8-16 million tons and $216-516 million, or by 2% and 1%, respectively. Future research should assess the atmospheric and climate dynamics that underlie such changes in power system operations.
“…To co-optimize energy and reserves, we set regulation provision costs to $10, $6 and $4 ($ 2017 ) per megawatt-hour (MWh) for coal, NGCC and natural gas steam units, respectively. These costs capture variable operation and maintenance (VOM) and heat rate degradation costs incurred while providing reserves (Craig et al 2018b).…”
Section: Uced Modelmentioning
confidence: 99%
“…To ensure system reliability against variable wind and solar generation and unexpected generator and transmission outages, as well as to approximate current reserve classes in ERCOT (Electric Reliability Council of Texas 2013), the UCED model includes three reserve classes: regulation, flexibility and contingency reserves (table 1) (SI.1). To capture greater reserve requirements at high wind and solar penetrations modeled here, the three reserve classes vary with load and wind and solar generation (Craig et al 2018b, Lew et al 2013. All reserve classes procure positive or up reserves, i.e.…”
Section: Uced Modelmentioning
confidence: 99%
“…Since hydropower accounts for less than 1% of the fleet capacity, we subtract the estimated hourly generation by hydropower units from demand, then remove them from our fleet (SI.1). We augment the CDR generator fleet with carbon dioxide (CO 2 ) emission rates by fuel type (US Energy Information Administration 2017a); unit commitment parameters by plant and fuel type and capacity (Craig et al 2018b); VOM costs by fuel type (Craig et al 2018b); and latitudes and longitudes (US Environmental Protection Agency 2017) (SI.1). Based on 2017 data for Texas, we set coal, natural gas and nuclear fuel costs equal to $2.21, $3.26 and $0.65 per MMBtu ($ 2017 ) (US Energy Information Administration 2018), but test the sensitivity of our results to higher natural gas prices of $6 per MMBtu ($ 2017 ).…”
Section: Generator Fleetmentioning
confidence: 99%
“…Since we conduct our analysis for 2041-2050 climate change conditions and given recent continued growth in Texas renewable penetrations, we add 15 GW wind and 30.5 GW solar to the CDR fleet (which originally contained 20 GW wind and 1 GW solar) to construct a high-renewable fleet with roughly 25% wind and 15% solar penetration by energy. We use greater wind than solar capacity to reflect results of studies on cost-optimal high-renewable generation fleets (Hand et al 2012, Craig et al 2018b. Given that adding renewables increases system reserve and flexibility requirements, we do not remove generators from the CDR fleet.…”
Climate change will likely impact wind and solar resources. As power systems increasingly shift towards wind and solar power, these resource changes will increasingly impact power system operations. We assess how power system operations will be affected by climate change impacts on wind and solar resources by generating wind and solar generation profiles for a reference period and five climate change projections. We then run a unit commitment and economic dispatch model to dispatch a highrenewable generator fleet with these profiles. For climate change projections, we use 2041-2050 output from five global climate models (GCMs) for Representative Concentration Pathway 8.5 for Texas, our study system. All five GCMs indicate increased wind generation potential by 1%-4% under climate change in Texas, while three and two GCMs indicate increased and decreased solar generation potential, respectively, by up to 1%. Uneven generation potential changes across time result in greater changes in dispatched generation by fuel type. Notably, nuclear generation decreases across GCMs by up to 7%, largely in low-demand (winter) months when nuclear plants, which have a high minimum stable load, must reduce their generation to avoid overgeneration. Increased wind and/or solar generation result in reduced system CO 2 emissions and electricity production costs across four of the five GCMs by 8-16 million tons and $216-516 million, or by 2% and 1%, respectively. Future research should assess the atmospheric and climate dynamics that underlie such changes in power system operations.
“…Many existing studies of high wind and solar penetration assess the role of a couple of drivers in isolation or with a limited number of joint sensitivities (e.g. Fell and Linn 2013, Shearer et al 2014, Hirth 2015, MacDonald et al 2016, Craig et al 2018, Eshraghi et al 2018, Sepulveda et al 2018, as shown in SI appendix, table 1. Although these one-way sensitivities are valuable ceteris paribus experiments, they do not comprehensively assess the relative impact of a range of factors by jointly varying all drivers simultaneously.…”
Much has been made of the potential for wind and solar generation to supply cheap, low-emissions electricity, but considerable disagreement exists as to which combinations of many potential drivers will enable deep penetration of these technologies. Most existing analyses consider limited factors in isolation, such as investment costs or energy storage, and do not provide rigorous support for understanding which combinations of factors could underpin a leading role for wind and solar. This study addresses this gap by undertaking a systematic sensitivity analysis using a state-of-the-art energy-economic model to comprehensively evaluate the relative magnitudes of five key drivers that may influence future wind and solar deployment in the United States. We find future wind and solar capital costs and carbon policy are the dominant factors, causing the average wind and solar share to vary by 38 and 31 percentage points, respectively. Transmission and storage availability have much smaller effects, causing the average share to vary by no more than 15 and 5 percentage points, respectively. No single factor unilaterally determines wind and solar deployment. The variable renewable share of electricity generation never reaches 100% nationally in any scenario even with lowcost storage, as decreasing marginal returns at higher deployments eventually outpace cost reductions. Average wind and solar shares and ranges of possible outcomes are higher in this study relative to recent multi-model comparison studies due to lower renewable costs and the potential for more stringent policies. Understanding drivers and barriers to renewable deployment has important ramifications for technology developers, infrastructure, market design, and policymakers, and this research provides insights as to which combinations of drivers lead to the greatest share of economic wind and solar deployment and why.
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