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Addressing climate change requires urgent efforts to reduce carbon dioxide (CO?) emissions from gas-fired power plants (GFPPs), which remain integral to India’s energy sector. While various mitigation strategies have been explored, the integration of solar photovoltaic (PV) systems with demand response (DR) in GFPPs remains under examined. This study evaluates the effectiveness of combining solar PV and DR for emissions reduction using Ant Colony Optimization (ACO) to optimize PV allocation, considering solar variability, demand profiles, and the carbon intensity of gas-fired generation. Unlike previous research focused on single energy sources or isolated optimization techniques, this study integrates PV generation with demand-side management to enhance both emissions reduction and energy efficiency. Tested on the IEEE 33-bus system with real-world Indian GFPP data, the proposed approach achieves a 27.66% CO? reduction, demonstrating its viability. The findings provide a strategic framework for policymakers and industry stakeholders to implement low-carbon technologies in gas-fired power generation.

The paper provides an economic model for the assessment of hydrogen production at the site of an existing thermal power plant, which is then integrated into the existing gas grid. The model uses projections of electricity prices, natural gas prices, and CO2 prices, as well as estimates of the cost of building a power-to-gas system for a 25-year period. The objective of this research is to calculate the yellow hydrogen production price for each lifetime year of the Power-to-gas system to evaluate yellow hydrogen competitiveness compared to the fossil alternatives. We test if an incentive scheme is needed to make this technology economically viable. The research also provides several sensitivity scenarios of electricity, natural gas, and CO2 price changes. Our research results clearly prove that yellow hydrogen is not yet competitive with fossil alternatives and needs incentive mechanisms for the time being. At given natural gas and CO2 prices, the incentive for hydrogen production needs to be 52.90 EUR/MWh in 2025 and 36.18 EUR/MWh in 2050. However, the role of hydrogen in the green transition could be very important as it provides ancillary services and balances energy sources in the power system.

The peak regulation capacity of gas‐fired power plants has always been an important flexibility resource of the power grid. Under the guidance of carbon emission reduction, the coal power units are gradually shut down, making the role of gas‐fired power plants more important. However, in practice, gas‐fired power plants often fail to show satisfactory flexibility. The main reasons are as follows: (1) Part of the capacity mechanism fails to effectively encourage gas‐fired power plants to provide reliable flexibility and (2) the unreliability of fuel supply for gas‐fired power plants. Aiming at these problems, the current capacity mechanism in different countries is first summarised and the applicability of the capacity mechanism for gas‐fired power plants under the government regulation and market‐oriented environment is analysed, respectively. Then, the characteristics of power dispatching and gas dispatching are analysed to explore the internal reasons for the unreliable fuel supply in gas‐fired power plants. Based on the above analysis, the gas‐electric coordination mechanism adapted to different development stages is proposed to solve the problem that the flexibility of gas‐fired power plants cannot be guaranteed. In summary, through the research of this study, it is found that the main reason for the limited flexibility of gas‐fired power plants is the lack of coordination among multiple entities belonging to different energy systems, such as electricity and gas. The cooperation mechanism proposed is an attempt to realise the cooperation between the electric system and the gas system, which provides the reference for closer collaboration among multiple energy systems in the future. Dispatching efficiency of the grid can be improved by the coordination of grid and gas. The coordination scheme between gas and power grid.

Natural gas has become the dominant source of electricity in the United States, and technologies capable of efficiently removing carbon dioxide (CO₂) from the flue emissions of natural gas–fired power plants could reduce their carbon intensity. However, given the low partial pressure of CO₂ in the flue stream, separation of CO₂ is particularly challenging. Taking inspiration from the crystal structures of diamine-appended metal–organic frameworks exhibiting two-step cooperative CO₂ adsorption, we report a family of robust tetraamine-functionalized frameworks that retain cooperativity, leading to the potential for exceptional efficiency in capturing CO₂ under the extreme conditions relevant to natural gas flue emissions. The ordered, multimetal coordination of the tetraamines imparts the materials with extraordinary stability to adsorption-desorption cycling with simulated humid flue gas and enables regeneration using low-temperature steam in lieu of costly pressure or temperature swings.

Global investment in counteracting climate change has galvanized increasing interest in carbon capture and sequestration (CCS) as a versatile emissions mitigation technology. As decarbonization efforts accelerate, CCS can target the emissions of large point-source emitters, such as coal- or natural gas-fired power plants, while also supporting the production of renewable or low-carbon fuels. Furthermore, CCS can enable decarbonization of difficult-to-abate industrial processes and can support net CO 2 removal from the atmosphere through bioenergy coupled with CCS or direct air capture. Here we review the development of porous materials as next-generation sorbents for CO 2 capture applications. We focus on stream- and sector-specific challenges while highlighting case studies within the context of the rapidly shifting energy landscape. We conclude with a discussion of key needs from the materials community to expand deployment of carbon capture technologies. Porous materials can selectively and reversibly adsorb large quantities of gas. This Review highlights progress made in using this class of materials for CO 2 capture processes and discusses key gaps that the materials community can address to accelerate greater adoption of adsorptive carbon capture technologies.

Reaching a pathway towards net zero GHG emissions requires rapid and massive investments in low-carbon infrastructure. To redirect finance flows accordingly, particularly the European Union places an emphasis on sustainable finance regulation. However, the specific investment shifts required are not fully understood, which could lead to an insufficient steering effect for crucial technologies. Here we conduct a meta-analysis to derive the required technology-level investment shifts for climate-relevant infrastructure until 2035. We find a steep uptick in overall investment need, with almost €90 billion yr−1 being required already within the very near term (2021–25). Investment shifts are most drastic for power plants, electricity grids and rail infrastructure, which is even increased by the ambitions to become independent from Russian gas imports. Our findings highlight the need for sustainable finance policies that take into account the financing structures of these sectors specifically.Urgent and targeted financial investments are essential for reaching the net zero target in Europe, while a comprehensive mapping is still missing. This meta-analysis demonstrates the necessity of rapid increase in investments and displays the potential patterns across various sectors.

International efforts to avoid dangerous climate change aim for large and rapid reductions of fossil fuel CO2 emissions worldwide, including nearly complete decarbonization of the electric power sector. However, achieving such rapid reductions may depend on early retirement of coal- and natural gas-fired power plants. Here, we analyze future fossil fuel electricity demand in 171 energy-emissions scenarios from Integrated Assessment Models (IAMs), evaluating the implicit retirements and/or reduced operation of generating infrastructure. Although IAMs calculate retirements endogenously, the structure and methods of each model differ; we use a standard approach to infer retirements in outputs from all six major IAMs and-unlike the IAMs themselves-we begin with the age distribution and region-specific operating capacities of the existing power fleet. We find that coal-fired power plants in scenarios consistent with international climate targets (i.e. keeping global warming well-below 2 °C or 1.5 °C) retire one to three decades earlier than historically has been the case. If plants are built to meet projected fossil electricity demand and instead allowed to operate at the level and over the lifetimes they have historically, the roughly 200 Gt CO2 of additional emissions this century would be incompatible with keeping global warming well-below 2 °C. Thus, ambitious climate mitigation scenarios entail drastic, and perhaps un-appreciated, changes in the operating and/or retirement schedules of power infrastructure.

Nitrogen oxides (NOx=NO+NO2), produced in urban areas and industrial facilities (particularly in fossil-fuel-fired power plants), are major sources of air pollutants, with implications for human health, leading local and national authorities to estimate their emissions using inventories. In Qatar, these inventories are not regularly updated, while the country is experiencing fast economic growth. Here, we use spaceborne retrievals of nitrogen dioxide (NO2) columns at high spatial resolution from the TROPOspheric Monitoring Instrument (TROPOMI) to estimate NOx emissions in Qatar from 2019 to 2022 with a flux-divergence scheme, according to which emissions are calculated as the sum of a transport term and a sink term representing the three-body reaction comprising NO2 and hydroxyl radical (OH). Our results highlight emissions from gas power plants in the northeast of the country and from the urban area of the capital, Doha. The emissions from cement plants in the west and different industrial facilities in the southeast are underestimated due to frequent low-quality measurements of NO2 columns in these areas. Our top-down model estimates a weekly cycle, with lower emissions on Fridays compared to the rest of the week, which is consistent with social norms in the country, and an annual cycle, with mean emissions of 9.56 kt per month for the 4-year period. These monthly emissions differ from the Copernicus Atmospheric Monitoring Service global anthropogenic emissions (CAMS-GLOB-ANT_v5.3) and the Emissions Database for Global Atmospheric Research (EDGARv6.1) global inventories, for which the annual cycle is less marked and the average emissions are respectively 1.67 and 1.68 times higher. Our emission estimates are correlated with local electricity generation and allow us to infer a mean NOx emission factor of 0.557 tNOx GWh−1 for the three gas power plants in the Ras Laffan area.

The present study proposes a system that can reduce environmental pollution emissions while simultaneously improving production capacity. The current research innovation is the use of the thermoelectric generator system and the organic Rankine cycle in conjunction with a gas turbine based on the Brayton cycle. The thermodynamic engineering equation solver software is utilized in this study to model the investigated system and acquire the system analysis results. The efficiency of the gas turbine, the competency criterion of a thermoelectric generator, compressor pressure ratio, inlet temperature to the organic turbine, and inlet temperature to gas turbine are the most relevant and practical parameters in this study. In addition, the system's exergy study revealed that the most exergy was destroyed in the combustion chamber, evaporator, gas turbine, and thermoelectric. Also, the economic analysis of the system showed that the increased cost of the system is related to the Brayton cycle unit and the steam cycle unit, respectively. Finally, a comparative case study was conducted for four cities: Abadan, Esfahan, Mashhad, and Shiraz, to evaluate the total production capacity of the system. The system performance results were evaluated with the changes in annual ambient temperature. The results showed that the system works best in the cooler climate of Mashhad.

How much more of Earth's fossil fuels can we extract and burn in the short- to medium-term future and still avoid severe global warming? A model provides the answer, and shows where these 'unburnable' reserves are. See Letter p.187 Regional choices between fossil fuels and climate warming If global warming is to be limited in this century to the much-publicized 2 °C rise compared to pre-industrial levels, fossil fuel use and the associated release of greenhouse gases will need to be severely limited. This raises questions regarding the specific quantities and locations of oil, gas and coal that can be safely exploited. Christophe McGlade and Paul Ekins use an integrated assessment model to explore the implications of the 2 °C warming limit for different regions' fossil fuel production. They find that, globally, a third of oil reserves, half of gas reserves and over 80% of current coal reserves should remain unused during the next 40 years in order to meet the 2 °C target and that the development of resources in the Arctic and any increase in unconventional oil production are incompatible with efforts to limit climate change.