Conventional Power Plants Equipped With Systems for CO2 Emission Abatement

2008 ◽  
Author(s):  
Marco Gambini ◽  
Michela Vellini
Keyword(s):  
Co2 Emission ◽  
Power Plants ◽  
Emission Trading ◽  
Abatement Cost ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Atmospheric Discharge ◽  
Pressure Transport ◽  
Carbon Dioxide Co2 ◽  
The Cost

This paper presents the results from an evaluation of the performance and cost of Italian power plants (a steam cycle power plants — 500 MW — fed by coal and a combined cycle power plant — 300 MW — fed by natural gas) with CO2 emissions control equipment to achieve a fixed reduction in atmospheric discharge of carbon dioxide (CO2) and so to accomplish the CO2 emission targets established by the Kyoto Protocol. The reduction of the CO2 content in the flue gas is achieved by amine scrubbing (CO2 removal), removal of water from CO2 (drying), compression to pipeline pressure; transport and storage are not considered. The paper presents an economic evaluation of the CO2 abatement cost and compares it with the cost of allowances in the Emission Trading System and with the payment of the penalty for the emissions in excess when there is no CO2 quota available on the market.

scholarly journals A Review of Geothermal Technologies and Their Role in Reducing Greenhouse Gas Emissions in the USA

2020 ◽  
Vol 143 (1) ◽  
Author(s):  
Philip J. Ball
Keyword(s):  
Greenhouse Gas ◽  
Power Plants ◽  
Carbon Tax ◽  
Ghg Emissions ◽  
Abatement Cost ◽  
Combined Cycle ◽  
Low Carbon ◽  
Geothermal Heat ◽  
The Cost

Abstract A review of conventional, unconventional, and advanced geothermal technologies highlights just how diverse and multi-faceted the geothermal industry has become, harnessing temperatures from 7 °C to greater than 350 °C. The cost of reducing greenhouse emissions is examined in scenarios where conventional coal or combined-cycle gas turbine (CCGT) power plants are abated. In the absence of a US policy on a carbon tax, the marginal abatement cost potential of these technologies is examined within the context of the social cost of carbon (SCC). The analysis highlights that existing geothermal heat and power technologies and emerging advanced closed-loop applications could deliver substantial cost-efficient baseload energy, leading to the long-term decarbonization. When considering an SCC of $25, in a 2025 development scenario, geothermal technologies ideally need to operate with full life cycle assessment (FLCA) emissions, lower than 50 kg(CO2)/MWh, and aim to be within the cost range of $30−60/MWh. At these costs and emissions, geothermal can provide a cost-competitive low-carbon, flexible, baseload energy that could replace existing coal and CCGT providing a significant long-term reduction in greenhouse gas (GHG) emissions. This study confirms that geothermally derived heat and power would be well positioned within a diverse low-carbon energy portfolio. The analysis presented here suggests that policy and regulatory bodies should, if serious about lowering carbon emissions from the current energy infrastructure, consider increasing incentives for geothermal energy development.

Incremental Cost of CO2 Reduction in Power Plants

2002 ◽  
Author(s):  
Ram G. Narula ◽  
Harvey Wen ◽  
Kenneth Himes
Keyword(s):  
Incremental Cost ◽  
Co2 Emissions ◽  
Power Plants ◽  
Alternative Fuels ◽  
Co2 Reduction ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Integrated Gasification Combined Cycle ◽  
The Cost ◽  
The Impact

Carbon dioxide (CO2) emissions from fossil-fueled power plants contribute to more than one-third of all CO2 emissions in the U.S. [1]. Any effort to curtail greenhouse gases should therefore include the reduction of this emission source. Methods of CO2 reduction include (1) use of alternative fuels with lower CO2 emissions and (2) CO2 scrubbing and sequestration to prevent its release to the atmosphere. The cost of CO2 reduction varies with the selected technology. This paper compares (1) the cost of electricity (COE) without and with CO2 removal/avoidance and (2) the impact of the incremental cost of CO2 reduction on COE for different technology options, including replacing existing coal plants with natural-gas-fired combined cycle (NGCC), integrated gasification combined cycle (IGCC) with and without CO2 removal, pulverized coal (PC) with CO2 scrubber, and nuclear plants. Full and partial compliance with the Kyoto Protocol are addressed.

scholarly journals Thermo-economic comparative analysis of gas turbine GT10 integrated with air and steam bottoming cycle

2014 ◽  
Vol 35 (4) ◽  
pp. 83-95 ◽  
Author(s):  
Daniel Czaja ◽  
Tadeusz Chmielnak ◽  
Sebastian Lepszy
Keyword(s):  
Economic Analysis ◽  
Gas Turbine ◽  
Power Plants ◽  
Combined Cycle ◽  
Small Range ◽  
Exhaust Gas ◽  
Thermodynamic Optimization ◽  
Technological Structure ◽  
The Cost ◽  
Selection Of

Abstract A thermodynamic and economic analysis of a GT10 gas turbine integrated with the air bottoming cycle is presented. The results are compared to commercially available combined cycle power plants based on the same gas turbine. The systems under analysis have a better chance of competing with steam bottoming cycle configurations in a small range of the power output capacity. The aim of the calculations is to determine the final cost of electricity generated by the gas turbine air bottoming cycle based on a 25 MW GT10 gas turbine with the exhaust gas mass flow rate of about 80 kg/s. The article shows the results of thermodynamic optimization of the selection of the technological structure of gas turbine air bottoming cycle and of a comparative economic analysis. Quantities are determined that have a decisive impact on the considered units profitability and competitiveness compared to the popular technology based on the steam bottoming cycle. The ultimate quantity that can be compared in the calculations is the cost of 1 MWh of electricity. It should be noted that the systems analyzed herein are power plants where electricity is the only generated product. The performed calculations do not take account of any other (potential) revenues from the sale of energy origin certificates. Keywords: Gas turbine air bottoming cycle, Air bottoming cycle, Gas turbine, GT10

Comparison of two CO2 removal options in combined cycle power plants

1998 ◽  
Vol 39 (16-18) ◽  
pp. 1653-1663 ◽  
Author(s):  
Olav Bolland ◽  
PhiliPpe Mathieu
Keyword(s):  
Power Plants ◽  
Combined Cycle ◽  
Co2 Removal

scholarly journals The Optimization of Combined Cycle HRSGs as a Function of the Plant Load Duty

1996 ◽  
Author(s):  
P. J. Dechamps
Keyword(s):  
Power Generation ◽  
Steam Generator ◽  
Heat Recovery ◽  
Power Plants ◽  
Combined Cycle ◽  
Load Factor ◽  
Heat Recovery Steam Generator ◽  
Economic Optimization ◽  
Cost Of Electricity ◽  
The Cost

Natural gas fired combined cycle power plants now take a substantial share of the power generation market, mainly because they can be delivering power with a remarkable efficiency shortly after the decision to install is taken, and because they are a relatively low capital cost option. The power generation markets becoming more and more competitive in terms of the cost of electricity, the trend is to go for high performance equipments, notably as far as the gas turbine and the heat recovery steam generator are concerned. The heat recovery steam generator is the essential link in the combined cycle plant, and should be optimized with respect to the cost of electricity. This asks for a techno-economic optimization with an objective function which comprises both the plant efficiency and the initial investment. This paper applies on an example the incremental cost method, which allows to optimize parameters like the pinch points and the superheat temperatures. The influence of the plant load duty on this optimization is emphasized. This is essential, because the load factor will not usually remain constant during the plant life-time. The example which is presented shows the influence of the load factor, which is important, as the plant goes down in merit order with time, following the introduction of more modern, more efficient power plants on the same grid.

scholarly journals Sequestering Biomass for Natural, Efficient, and Low-Cost Direct Air Capture of Carbon Dioxide

2021 ◽  
Author(s):  
Jeffrey Amelse ◽  
Paul K. Behrens
Keyword(s):  
Carbon Dioxide ◽  
Carbon Cycle ◽  
Power Plants ◽  
Low Cost ◽  
Complete Solution ◽  
Combined Cycle ◽  
High Yield ◽  
Total Biomass ◽  
Co2 Removal ◽  
Direct Capture

Many corporations and governments aspire to become Net Zero Carbon Dioxide by 2030-2050. Achieving this goal requires understanding where energy is produced and consumed, the magnitude of CO2 generation, and the Carbon Cycle. Many prior proposed solutions focus on reducing future CO2 emissions from continued use of fossil fuels. Examination of these technologies exposes their limitations and shows that none offer a complete solution. Direct Capture technologies are needed to reduce CO2 already in the air. The best way to permanently remove CO2 already in the atmosphere is to break the Carbon Cycle by growing biomass from atmospheric CO2 and permanently sequestering that biomass carbon in landfills modified to discourage decomposition to CO2 and methane. Tree leaves and switchgrass are proposed as good biomass sources for this purpose. Left unsequestered, leaves decompose with a short Carbon Cycle time constant releasing CO2 back to the atmosphere. Leaves can represent a substantial fraction of the total biomass generated by a tree when integrated over a tree’s lifetime. The cost for Carbon Capture and Storage (CCS) for growing and sequestering high yield switchgrass is estimated to be lower than CCS for steam reforming of methane hydrogen plants (SRM) and supercritical or combined cycle coal power plants. Thus, sequestration of biomass is a natural, carbon efficient, and low-cost method of Direct Capture. Biomass sequestration can provide CO2 removal on giga tonnes per year scale and can be implemented in the needed timeframe (2030-2050).

scholarly journals Absorption of CO2 With Amines in a Semiclosed GT Cycle: Plant Performance and Operating Costs

1998 ◽  
Author(s):  
A. Corti ◽  
L. Lombardi ◽  
G. Manfrida
Keyword(s):  
Flow Rate ◽  
Power Plants ◽  
Energy Requirement ◽  
Co2 Concentration ◽  
Combined Cycle ◽  
Plant Performance ◽  
Co2 Removal ◽  
Additional Costs ◽  
Increased Co2 Concentration ◽  
Removal System

A CO2 removal system, using aqueous solutions of amines, is applied to a Semi-Closed Gas Turbine/Combined Cycle (SCGT/CC) power plant. The SCGT/CC is interesting because of the possibility of achieving low emissions at the stack, with a decreased overall flow rate, lower NOx concentration and an increased CO2 concentration (over 15% in volume), which facilitates the removal treatment. Several compositions of the absorbing solution have been investigated, by means of simulations with ASPEN PLUS. A 18% DEA + 12% MDEA composition resulted the most convenient in terms of flow rate and energy requirement for the stripping. A cost analysis of the removal plant allows to estimate additional costs for CO2 removal with respect to conventional power plants.

Thermoeconomic Analysis of Power Plants With Integrated Exergy Stream

2000 ◽  
Author(s):  
Duck-Jin Kim ◽  
Hyun-Soo Lee ◽  
Ho-Young Kwak ◽  
Jae-Ho Hong
Keyword(s):  
Power Plant ◽  
Gas Turbine ◽  
Power Plants ◽  
Unit Cost ◽  
Combined Cycle ◽  
Cogeneration Plant ◽  
Steam Power ◽  
Unit Costs ◽  
Combined Cycle Plant ◽  
The Cost

Abstract Exegetic and thermoeconomic analysis were performed for a 500-MW combined cycle plant and a 137-MW steam power plant without decomposition of exergy into thermal and mechanical exergy. A unit cost was assigned to a specific exergy stream of matter, regardless of its condition or state in this analysis. The calculated costs of electricity were almost same within 0.5% as those obtained by the thermoeconomic analysis with decomposition of the exergy stream for the combined cycle plant, which produces the same kind of product. Such outcome indicated that the level at which the cost balances are formulated does not affect the result of thermoeconomic analysis, that is somewhat contradictory to that concluded previously. However this is true for the gas-turbine cogeneration plant which produces different kinds of products, electricity and steam whose unit costs are dominantly affected by the mechanical and thermal exergy respectively.

Process Analysis of Selective Exhaust Gas Recirculation for CO2 Capture in Natural Gas Combined Cycle Power Plants Using Amines

2017 ◽  
Author(s):  
Maria Elena Diego ◽  
Jean-Michel Bellas ◽  
Mohamed Pourkashanian
Keyword(s):  
Natural Gas ◽  
Co2 Capture ◽  
Flue Gas ◽  
Power Plants ◽  
Exhaust Gas Recirculation ◽  
Combined Cycle ◽  
Exhaust Gas ◽  
Natural Gas Combined Cycle ◽  
The Cost ◽  
Gas Recirculation

Post-combustion CO2 capture from natural gas combined cycle (NGCC) power plants is challenging due to the large flow of flue gas with low CO2 content (∼3–4%vol.) that needs to be processed in the capture stage. A number of alternatives have been proposed to solve this issue and reduce the costs of the associated CO2 capture plant. This work focuses on the selective exhaust gas recirculation (S-EGR) configuration, which uses a membrane to selectively recirculate CO2 back to the inlet of the compressor of the turbine, thereby greatly increasing the CO2 content of the flue gas sent to the capture system. For this purpose, a parallel S-EGR NGCC system (53% S-EGR ratio) coupled to an amine capture plant using MEA 30%wt. was simulated using gCCS (gPROMS). It was benchmarked against an unabated NGCC system, a conventional NGCC coupled with an amine capture plant (NGCC+CCS), and an EGR NGCC power plant (39% EGR ratio) using amine scrubbing as the downstream capture technology. The results obtained indicate that the net power efficiency of the parallel S-EGR system can be up to 49.3% depending on the specific consumption of the auxiliary S-EGR systems, compared to the 49.0% and 49.8% values obtained for the NGCC+CCS and EGR systems, respectively. A preliminary economic study was also carried out to quantify the potential of the parallel S-EGR configuration. This high-level analysis shows that the cost of electricity for the parallel S-EGR system varies from 82.1–90.0 $/MWhe for the scenarios considered, with the cost of CO2 avoided being in the range of 79.7–105.1 $/tonne CO2. The results obtained indicate that there are potential advantages of the parallel S-EGR system in comparison to the NGCC+CCS configuration in some scenarios. However, further benefits with respect to the EGR configuration will depend on future advancements and cost reductions achieved on membrane-based systems.

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