Similarly to the thermal integration explained in Section “Results and Discussion,” the flow rate of the resulting flue gas with sequential combustion is therefore 28% smaller than in the base case configuration and the integration allows for a smaller total cross-section of the absorber in the capture plant. The model of the GHR reformer is based on the technical and operation specifications reported in a Haldor Topsøe’s report for the 6,000 Nm3/h Topsøe low-energy HTCR hydrogen plant at BorsodChem MCHZ’s facilities in Ostrava in the Czechia (Haldor Topsoe, 2007). The model of the SMR is developed based on the technical and operating parameters of a conventional SMR described in a report commissioned by the IEAGHG (2017a), with the process modified slightly for the purpose of the thermodynamic integration with subsequent heat recovery in a three-pressure level HRSG for steam generation. The model of the carbon capture system based on chemical absorption with 30 wt% MEA solution is developed using gCCS library and gSAFT advanced thermodynamics to evaluate the physical properties of MEA aqueous solutions (Chapman et al., 1990, 1989; Bui et al., 2018). The base case configurations for an SMR and a GHR based hydrogen plant are described in Supplementary Appendices A, B After recovering heat from a gas turbine exhaust to increase steam production, the exhaust flue gas enters the hot windbox of the pulverized coal boiler, where it replaces secondary air to allow for sequential combustion to take place.

Note that energy storage in the above modules does not include long-term energy storage. The overall constraint of an optimal near-zero power system is to ensure that the hourly electricity supply is lower than the electricity demand, as determined in Eq. The objective of the optimal near-zero power system simulation model was to ensure https://open-innovation-projects.org/blog/where-open-source-software-thrives-exploring-its-impact-and-potential-across-industries a minimum national shortage rate under the scenarios with different abated fossil fuel shares, transmission capacities, and storage durations. The hourly electricity demand in the other provinces is defined in Eq.

80,750 Nm3/h (1.86 kg/s), and the performance comparison with the air-fired GHR in the base case configuration is conducted on the basis of the same hydrogen production capacity. The size and flow rate of the GE LM 6000 is compatible with the mass balance and energy balance of sequential combustion in the combustion chamber and the reactor of a gas heated reformer. The gas turbine upstream of the gas heated reformer is a GE’s LM6000 aeroderivative gas turbine modeled according to GE’s design and operation specifications available in the public domain (Badeer, 2000; General Electric Thermal Power Generation, 2017). The reformer and the WGS reactor are simulated as equilibrium reactors based on Gibbs energy minimization approach. Customized models for each unit of the integrated gas heated reformer are developed in gPROMS Model Builder (PSE, 2019) using the library and the thermodynamic models described in Section “Modeling Methodology.” The process flow diagram as implemented in gPROMS is presented in Figure 7.

It uses a conventional 30 wt% MEA capture process as a generic capture technology to quantify the reduction in size of absorber columns, the most capital intensive part of solvent-based post-combustion capture systems. A newly developed rigorous model in gPROMS of gas turbine power generation systems integrated with examples of two hydrogen production technologies quantifies the step change in thermal efficiency and hydrogen production efficiency. Effective thermodynamic integration significantly increases net power output in at constant hydrogen production volume, reducing operating costs, whilst the use of a shared CO2 capture system is expected to contribute to significant capital cost reduction. 3.17 GJ/tCO2, similar to that in the capture plant for the GHR of https://8wsm.com/finance/investing-in-water-the-world-s-most-critical-commodity/ the base case configuration, which is supplied by steam extracted from the combined cycle. The CO2 concentration in the flue gas is higher than the concentration that would result from mixing the two flue gas stream from the gas turbine engine and the reformer, i.e., 10.9 vol% CO2 compared to 6.9 vol% CO2 for a flue gas saturated at 45°C. The increase is necessary to increase steam production in the HRSG to provide additional low-pressure steam for the capture plant.

• Finally, the real-time hourly electricity demand in 2050 in each province can be estimated using the multiplicator derived from the provincial electricity demand in 2050 relative to 2019 estimated by econometric models.
• The gas turbine upstream of the gas heated reformer is a GE’s LM6000 aeroderivative gas turbine modeled according to GE’s design and operation specifications available in the public domain (Badeer, 2000; General Electric Thermal Power Generation, 2017).
• Similarly to the thermal integration explained in Section “Results and Discussion,” the flow rate of the resulting flue gas with sequential combustion is therefore 28% smaller than in the base case configuration and the integration allows for a smaller total cross-section of the absorber in the capture plant.
• In each case, the bars show the average changes or technology-based contributions across dispatch model simulations with climate model ensembles; the vertical lines show the 33rd to 67th percentile ranges; the horizontal lines show the median values.
• Read the Report ACEEE’s study analyzed costs and emissions for decarbonizing buildings through electrification and alternative fuels for combustion, like biomethane from landfills or livestock manure or synthetic gases made from hydrogen and other chemical compounds.

ORIGINAL RESEARCH article

Open Access This article is licensed under a Creative Commons Attribution 4.0 International License, which permits use, sharing, adaptation, distribution and reproduction in any medium or format, as long as you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons licence, and indicate if changes were made. J.L.F. wrote the article with major contributions provided by Z.L., X.Z., K.L., X.L., J.W., K.H., and B.S. Aiming at the coal and biomass co-firing system coupled with CCUS, we developed an optimal matching model to determine the optimal links between CCUS-qualified coal-fired power plants and surrounding biomass feedstocks64. To evaluate the economics of the power system, we calculated the costs of the overall power system and its components under all scenarios and selected the optimal scenario characterized by the lowest total cost and total power shortage lower than 0.1% (i.e., ensuring a general level of the electricity supply reliability of 99.9% in Chinese cities).

The concept of sequential combustion is critical to the thermodynamic integration of hydrogen production with a gas turbine. Sharing the CO2 capture process is possible via sequential combustion of the SMR fuel gases in the gas turbine exhaust flue gas. And while the government wants to encourage generators to invest in new capacity with a long-term vision, such investment has yet to increase significantly, since this auction only guarantees single-year revenue. During the delivery year, OCCTO collects capacity contribution charges from retailers (who purchase the supply capacity) and distributes capacity remuneration to generators based on contracted asset types.

The syngas production process is identical to that of the conventional SMR hydrogen plant of the base case configuration described in Supplementary Appendix A. A desulfurized and pre-heated natural gas stream is mixed with steam to achieve a steam to carbon ratio of 3 in the feed stream of the main reformer. The heat released in the combustion is used to provide the sensible heat to increase the natural gas feedstock temperature up to the reaction temperature and the heat for the endothermic methane reforming process. Schematic diagram of the sequential combustion of natural gas and tail gas in a steam methane reformer furnace using the excess oxygen in a gas turbine exhaust flue gas. Figure 2 shows a schematic diagram of a purpose-built steam methane reformer (SMR) furnace where sequential combustion of natural gas and reformer tail gas takes place, using the excess oxygen in the gas turbine exhaust flue gas. Cost reduction in the capture process is achieved by reducing the number and the size of absorbers due to a reduction in the overall volume of the flue gas entering the carbon capture plant, a direct consequence of the use of the GT flue gas for sequential combustion. For sequential combustion to be applied for the integration of hydrogen and electricity production with CO2 capture, a fairly conventional steam methane reformer is located downstream of a commercially available gas turbine engine.

Abated fossil fuel power generation improves power system reliability

A The lowest cost of the power system and the cost composition for different CCUS retrofitted power proportions at an acceptable 0.1% national total power shortage rate, indicating that the optimal power mix should include 16% abated fossil fuel power generation with CCUS retrofitting. The total cost of the power system includes the cost of nonfossil fuel power generation, the cost of abated fossil fuel power generation with CCUS, the cost of short-term energy storage, the cost of hydrogen energy, and the cost of power transmission (all costs in this study were adjusted to 2020 constant prices), as expressed in Eq. Second, the provincial total power shortage rate represents the cumulative gap in a specific province between the hourly electricity supply not meeting the ideal hourly electricity demand divided by the provincial overall ideal electricity demand, as expressed in Eq. First, the national total power shortage rate represents the cumulative gap between the provincial hourly electricity supply not meeting the ideal hourly electricity demand divided by the national overall ideal electricity demand, as expressed in Eq. Finally, the provincial hourly power shortage rate represents the gap in a specific province between the hourly electricity supply not meeting the ideal hourly electricity demand divided by the provincial ideal hourly electricity demand, as defined in Eq. In this study, we defined four categories of power shortage rates, including the national total power shortage rate, provincial total power shortage rate, national hourly power shortage rate, and provincial hourly power shortage rate, as described below.

An arcade version was developed by Coastal Amusements and released in early November 2012, it was based on the https://leeds-welcome.com/the-future-is-now-top-trends-in-website-development-and-design-for-2023.html iOS version. And J.D.J. developed the experimental design. W.R., J.D.J. and J.H.N. conceptualized the study. The ResFrac reservoir simulation code is commercial software developed by the ResFrac Corporation.

Data availability

Regarding the auction process, power generators submit bids, and OCCTO determines the winning bids and contract prices based on the demand and supply balance. Following the liberalization of the retail market, the single-year capacity auction was introduced in FY 2020 to procure the supply capacity (kW) needed to meet future demand, increase business predictability for generators and retailers, and stabilize electricity prices. This article explores the capacity market, which includes the single-year capacity auction and the Long-Term Decarbonized Power Source Auction (LTDA) — through which the government aims to create better conditions for long-term energy security and enhanced introduction of renewable energy. Points represent average increases in hourly costs due to climate change, while the vertical lines show the median values, and the horizontal lines show the 33rd to 67th percentile ranges of dispatch model simulations with climate model ensembles. In each case, the bars show the average changes or technology-based contributions across dispatch model simulations with climate model ensembles; the vertical lines show the 33rd to 67th percentile ranges; the horizontal lines show the median values. A,b, Changes in hourly costs and their specific contributions from different technologies during extreme (a) and normal (b) periods in 26 major countries.

Data safety

Compared to the literature on electricity demand predictions with Chinese power system models40,54,63, we used a more accurate and refined method to predict the hourly electricity demand in each province in China in 2050. We also updated the storage site database in this study by expanding onshore storage sites to onshore and offshore storage sites. The specific prediction methods for each electricity supply source are described in Supplementary Note 1. A downscaling approach based on real-time hourly climate information for recent decades was used to refine the provincial variable renewable output potential to the hourly scale. The latest Sixth Assessment Report of the United Nations Intergovernmental Panel on Climate Change (IPCC) states that “in pathways limiting climate warming to 1.5 °C, almost all electricity will need to rely on the supply from zero- or low-carbon sources in 2050, such as renewables or fossil fuels with carbon-capture and storage, combined with increased electrification of the energy demand”2.

Although this lowers the specific hydrogen production per unit of volume of fuel, it has the advantage of increasing the steam generation and meet the steam requirements in the capture system for high CO2 capture rates. The introduction of sequential combustion requires modifications to the process to accommodate for changes in the composition of the comburent with a higher CO2 and H2O concentration than in ambient air. In the air-fired GHR of the base case configuration, a methane conversion of 73% is possible with a steam to carbon ratio of 3, an equilibrium temperature of 850°C and a total pressure of 33.9 bar. The heat released in the combustion supplies the sensible heat required to increase the natural gas feedstock temperature up to the equilibrium temperature of approximately 850°C and the heat for the endothermic reforming reactions. For the purpose of this study, the use of a GHR allows a wider range of hydrogen production capacities to be explorer, with the use of different gas turbine engines in the integrated configuration.