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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 http://emergingequity.org/2015/06/26/vladimir-putin-on-the-global-economy-geopolitics-and-russia-europe-relations/?shared=email&msg=fail 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.
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.
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.
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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 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.
- 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.
- 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.
- Performance parameters of the integrated system consisting of a steam methane reformer downstream of a H-class gas turbine and of the hydrogen plant and the CCGT power plant of the base case configuration.
- 850 kg/s and an oxygen concentration of 11.3 vol%, and it is used for sequential combustion of PSA tail gas and natural gas in the SMR furnace.
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.
Abated fossil fuel power generation improves power system reliability
- Third, the national hourly power shortage rate represents the gap between the national hourly electricity supply not meeting the ideal hourly electricity demand divided by the national ideal hourly electricity demand, as defined in Eq.
- 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.
- The study calculated costs and emissions from converting hard-to-decarbonize buildings from fossil fuels to biomethane, synthetic fuels, and full electrification.
- The thermodynamic integration of the hydrogen production and electricity generation is obviously not solvent specific or carbon capture technology specific.
This is an open-access article distributed under the terms of the Creative Commons Attribution License (CC BY). LH developed the model and performed the simulations and wrote the manuscript with support from ML and HC. The lower oxygen concentration in the gas turbine exhaust flue gas, i.e., 11.3 vol% in a H-class gas turbine and 13.7 vol% in an aeroderivative gas turbine, compared to 21 vol% in ambient air, results in larger flow rates to supply the necessary amount of oxygen. The reformer is, however, designed for a change in the comburent composition and, in the case of a SMR, an increase of convective heat transfer rate over the radiative heat transfer rate. Second, the operation of the gas turbine engine is unaffected since sequential combustion takes place in the reformer furnace or combustion chamber.
Considering the uncertainty in the future near-zero power system structure, we considered a total of 10,450 scenarios (19 × 25 × 22) in this study based on different transmission capacity times (1–10 times at 0.5 intervals), short-term energy storage durations (0–24 h at 1-hour intervals9), and abated fossil fuel shares (0%–20% as an integer) or zero-fossil fuel with long-term energy storage for comparison (the inclusion mechanism for long-term energy storage is described in the https://serumset.com/satellite-communications-for-safer-and-greener-aviation.html Supplementary Note 3). For the overall CO2 capture rate of 84.5%, the integrated configuration presents a higher net power output of 76.4 MWe due to the increase in the steam turbine power output, and a higher net thermal efficiency of 57.1%LHV, compared to 57.3 MWe and 39.5%LHV in the base case configuration. This constitutes 34 MWe of additional power with an increase in efficiency of 4.9 perceptual points, compared to the based case configuration. Third, the national hourly power shortage rate represents the gap between the national hourly electricity supply not meeting the ideal hourly electricity demand divided by the national ideal hourly electricity demand, as defined in Eq.
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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.
Sequential Combustion in Steam Methane Reforming Hydrogen Plants
- 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 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).
- In this study, the electricity demand in 2050 was projected based on econometric models, accounting for different future socioeconomic development scenarios.
- 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.
- An increase in natural gas feedstock flow rate of ca 10% reduces the H2 production efficiency in the integrated system.
Convective reformers were developed to improve the energy efficiency and reduce the investment costs due to their compact design and modularization, and they are preferred for smaller capacities up to 50,000 Nm3/h (Wesenberg et al., 2007). It results in a packing volume of approximately 18,850 m3, which constitutes a 17.5 vol% reduction compared to the total packing volume in the absorbers of the two carbon capture systems, i.e., one for the hydrogen plant and another for the CCGT power plant. With the flue gas flow rate being approximately 34% lower than the total flow rate of the two flue gas streams from the CCGT power plant and from the SMR hydrogen plant in the base case configuration, a reduction in the absorber diameter is possible at constant gas velocity. Performance parameters of the carbon capture plant of the integrated system and of the hydrogen plant and the CCGT power plant of the base case configuration.