Gasification-based Power Generation Research Articles

Design of a Smart Cabin Lighting System Based on Internet of Things

With the rapid advancements in mobile devices and wireless network technologies, the Internet of Things (IoT) has become more powerful and popular than ever. The aim of IoT is to efficiently control various types of objects through wireless communications. This paper aims to design an IoT-based smart lighting system that reduces development costs and saves power consumption. Unlike public open spaces, the focus of this paper is on ship cabin spaces. As ship cabins have unique properties, such as requiring gas-based power generation and preferring a wireless environment, designing a smart cabin lighting system is crucial and has significant commercial value. The smart cabin lighting system is designed with four features. Firstly, it can automatically control the lighting devices around people using position-sensitive devices. Secondly, it enables setting on/off and adjusting the luminance for lighting devices through Touch Keypads. Thirdly, the system can be controlled using an app to turn on/off and adjust the luminance of lighting devices. Lastly, the lighting devices equipped with sensors collect specific data on cloud servers for analysis. The underlying communication protocol used to interconnect the smart lighting devices, sensors, and Touch Keypads is Zigbee. The smart cabin lighting system can be applied to marine lighting, thus improving the commercial value of enterprises related to marine lighting.

Maximizing flare gas power generation for the design of an optimal energy mix

A major goal of the Sustainable Energy for All (SE4ALL) Initiative is to improve energy efficiency through an energy mix. To assist oil-producing nations in improving their energy efficiency with respect to flare gas management, it is imperative to design an energy mix that combines gas-powered and renewable energy sources. For these nations to combat the environmental degradation caused by flare gas, an optimal energy mix must be based on the maximum power that can be generated from flare gas. Towards this end, this study presents an application of the directional distance data envelopment analysis (DEA) model for estimating the required power. We applied our proposed methodology to selected nations under two different scenarios in order to determine whether data type impacted power estimates. In the first scenario, only positive data was modelled, while in the second scenario, both positive and negative real-world data were modelled. Based on initial results, the first scenario produced higher power estimates than the second scenario. For Indonesia, Iraq, Nigeria, and Venezuela, the estimated power output difference across both scenarios was 33.33%, 20.58%, 44.44%, and 2.13%, respectively. With Venezuela as a case study, and from a realistic and practical perspective, we estimated that 7050 MW of power could be generated from flare gas. Using this estimate, an optimal energy mix was designed for the nation that includes 40% gas-based power generation and 60% renewable energy. Moreover, the 40% gas proportion of the designed energy mix was found to satisfy the nation's energy shortage more than three times over in 2016. In light of our findings, we recommend our proposed methodology to policymakers as a means of improving energy efficiency through the design of energy mixes.

Securing energy while mitigating climate change

Mainstream energy policy emphasizes the exploitation of domestic sources to secure energy. Since readily available, many nations focus on fossil fuels, so they lack investment in the alternatives. The result is increasing atmospheric partial pressure of carbon dioxide, and energy security is still an issue. This study analyzes the impact of different variables on securing energy and reducing carbon emissions and attains this aim by econometrics. Energy-related data for 47 countries have been compiled from the IEA webpage, WDI, and BP databases, covering the period between 1990 and 2017. The results indicate that electricity generation by solar and wind globally helps both securing energy and climate change mitigation as anticipated. The dataset confirms that coal- and gas-based power generation does not contribute to global energy security. The dataset does not cast any distinct role on energy efficiency in terms of energy intensity. Increasing energy intensity, i.e., decreasing energy efficiency releases more carbon as anticipated. However, increasing energy intensity, i.e., decreasing energy efficiency, contributes to the energy security of the countries with wind power in the energy mix. One interesting result is that having a large population promotes energy security, but increasing urban population brings risks.

Thermo-Economic analysis of a novel biomass Gasification-Based power system integrated with a supercritical CO2 cycle and a Coal-Fired power plant

The integration of biomass gasification-based power generation, supercritical CO2 power cycle, and coal-fired power generation was implemented to improve biomass utilization. The clean syngas harvested from biomass gasification is exploited by a gas turbine and then the resulting hot exhaust is used to heat the CO2 stream of the supercritical CO2 cycle and the feedwater streams of the coal power plant. The raw syngas cooling is accomplished by delivering thermal energy to the CO2 and feedwater as well. As the biomass energy is sufficiently exploited through the supercritical CO2 cycle and coal power cycle, high biomass-to-electricity efficiency can be expected. Thermodynamic and economic analysis was conducted to examine the performance of the novel scheme, based on a 2.22 kg/s biomass gasifier and 350 MW coal power plant. The results indicated that the energy efficiency and exergy efficiency of biomass-to-electricity can attain 43.98% and 40.58% respectively at the design point, while the net power generated from coal remains constant. Only 1.07 years (irrespective of the construction period) are needed to recoup the initial investment of the biomass gasification-based power project considering discounts, and the net present value reaches 31,358.34 k$. Hence, the new design is advantageous and favorable in the field of biomass utilization.

Evaluating the complementarity of solar, wind and hydropower to mitigate the impact of El Niño Southern Oscillation in Latin America

Latin America has the largest share of renewable energy for power generation in the world, but has historically been dependent on hydropower, and is vulnerable to long-term phenomena like the El Niño-Southern Oscillation (ENSO). The region is currently experiencing a steady increase in gas-based power generation along with a rapid growth in non-hydro renewables, mainly aimed at improving reliability. But exploiting complementarities between hydropower and other renewables could offer additional benefits. This paper investigates to what extent improved deployment of wind turbines and solar photovoltaic cells (PV), aimed at complementing existing hydropower, could mitigate the impacts of ENSO in Latin America. We use a meteorological reanalysis dataset to model the variations in wind-, solar- and hydropower throughout the entire 20th century and their association with different ENSO phases in the same period. A statistical algorithm is then used to identify locations at national and regional levels offering the maximal level of complementarity. The results show that adding 136 GW of wind- and solar-power with high-complementarity has the potential to cost-effectively compensate the fluctuations of hydropower and reduce the variability of renewable power not only during drought ENSO phases but also outside ENSO events. Benefits include: (i) an increase of up to 5-fold the minimum threshold of renewable power available every month, (ii) a reduction of up to 65% in the variability of renewable power generation, and (iii) reaching a levelized cost of electricity (LCOE) of 0.09–0.23 $/kWh, which is comparable to that of new gas plants.

Exergoeconomic analysis of a simulated system of biomass gasification-based power generation with surplus syngas storage in a rural zone in Colombia

An exergetic and exergoeconomic analyses of a power generation system based in biomass gasification in a downdraft gasifier and internal combustion engine, with surplus syngas accumulation in a storage tank in a non-interconnected zone (NIZ) in Colombia, has been made utilizing the Thermoflex software to obtain data of streams and properties and the EES software to solve the energy, exergy and exergoeconomic balances. The effect of gasifying temperature on the performance of the system has been studied as well as its effects on the cost of energy generated to the locality. The results obtained on irreversibilities, the cost of energy, and the exergoeconomic parameters are explained by graphs. for every hour of power demand in the locality selected. The results indicate that the accumulation of energy in the tank does not have a high rate of exergy destruction, but the discharge process does have a high value of irreversibilities or exergy destruction. According to the exergoeconomic balance, the weighted cost of energy is affected by the large irreversibilities in the accumulation of syngas in the tank, increasing this weighted cost as the gasification temperature is higher.

Energy, economic, and environmental analysis of 10-MW biomass gasification based power generation in Malaysia

Biomass gasification based power plants can play an important role in power sector in Malaysia with her abundant agricultural and forest resources. In this research energy and economic feasibility, and environmental impact of biomass gasification power plant has been analyzed and assessed for sustainable power generation in Malaysia, the plant being a clean development mechanism supported project. Gasification based power generation with a dual fuel internal combustion engine is found more biomass combustion power plant. But, the annual fuel cost is significantly higher with gasification plant claiming MYR 10 million/y for a generation of 67,500 MWh. The net present value, internal rate of return, and PBP for a 10-MW gasification based dual fuel internal combustion engine power plant without loan financing using empty fruit bunch pellet as biomass; with CER issued at USD16/tCO2; and without loan financing provides net present value, internal rate of return, and PBP of MYR 19.68 million, 11.90%, and 6.05 y, respectively. With a loan financing at 3% per year with CER still be effective the net present value, internal rate of return, and PBP is estimated to be MYR 7.03 million, 3.97%, and 11.78 y, respectively. However, if a 60:40 debt equity is applied then the project net present value, internal rate of return, and payback period seen to improve slightly. The net present value attains a positive value of MYR 3.6 million. Internal rate of return and PBP values are found to be 7.08% and 8.27 y, respectively. The emission reduction achieved with the plant is 17,863 t CO2/y, 206 t SO2/y, 90 t NOx/y, and 10.37 t CO/y, respectively. Energy efficiency and tariff policy have been found to have highest impact on economic profitability of gasification based power generation units.

Prospects, progress, challenges and policies for clean power generation from biomass resources

Worldwide primary energy needs are satisfied basically from non-renewable sources that are limited in supply and innately hazardous to the environment. Biomass-based power systems are very much potent to address the environmental issues fostering sustainable development, while being able to provide a secured and uninterrupted power supply at the same time. Biomass-based power generation systems not only reduce the GHG emissions but also have enormous opportunities of job creation and promote biomass re-growth through sustainable land management practices. This paper overviews the biomass scenario in Southeast Asian and EU countries to give an overview of the potential and scalable energy harnessed from biomass resources. Economic analyses presented on biomass gasification-based power generation have been evaluated with three specific cost estimations, namely low, average and high. Key economic performance metrics of biomass gasification-based dual-fuel internal combustion engine generator with low investment estimates are as follows: a positive net present value of USD 7.5 million; internal rate of return 14.45%; and a payback period of 5.45 years. A review of the technologies can provide a base for strategic energy policy for the next generation of sustainable energy policies and helps policymakers to frame strategies aiming for clean technology and sustainable development. Biomass integrated gasification combined cycle-based systems are found to be most suitable for power generation or biofuel synthesis.

Two-stage capacity optimization approach of multi-energy system considering its optimal operation

With the depletion of fossil fuel and climate change, multi-energy systems have attracted widespread attention in buildings. Multi-energy systems, fuelled by renewable energy, including solar and biomass energy, are gaining increasing adoption in commercial buildings. Most of previous capacity design approaches are formulated based upon conventional operating schedules, which result in inappropriate design capacities and ineffective operating schedules of the multi-energy system. Therefore, a two-stage capacity optimization approach is proposed for the multi-energy system with its optimal operating schedule taken into consideration. To demonstrate the effectiveness of the proposed capacity optimization approach, it is tested on a renewable energy fuelled multi-energy system in a commercial building. The primary energy devices of the multi-energy system consist of biomass gasification-based power generation unit, heat recovery unit, heat exchanger, absorption chiller, electric chiller, biomass boiler, building integrated photovoltaic and photovoltaic thermal hybrid solar collector. The variable efficiency owing to weather condition and part-load operation is also considered. Genetic algorithm is adopted to determine the optimal design capacity and operating capacity of energy devices for the first-stage and second-stage optimization, respectively. The two optimization stages are interrelated; thus, the optimal design and operation of the multi-energy system can be obtained simultaneously and effectively. With the adoption of the proposed novel capacity optimization approach, there is a 14% reduction of year-round biomass consumption compared to one with the conventional capacity design approach.

What Role Will LNG Play in Balancing Gas Demand in the MENA Region?

This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 198054, “The Global LNG Price Trend and the Role of LNG in Balancing the Gas Demand in MENA Region,” by Mohamed El Shahati, Haidar Khadadeh, and Fajer Al-Aradah, Kuwait Foreign Petroleum Exploration Company, prepared for the 2019 SPE Kuwait Oil and Gas Conference and Show, Mishref, Kuwait, 13–16 October. This paper has not been peer reviewed. The complete paper analyzes the role of liquefied natural gas (LNG) in balancing the natural gas demand in the Middle East/North Africa (MENA) region. Natural gas increasingly is becoming a main energy source in the region. Contrary to widely held belief, several countries in MENA could fall into deficit regarding their self-supply of gas, leading to the need to import. The options of supply are through pipeline networks, or LNG. The global LNG pricing mechanism is changing toward flexible market-related methods that might encourage some countries to switch to LNG supplies. The study presented in this paper estimates the future demand of natural gas by country using multivariate regression and then compares it with the availability of gas as estimated by the Gas Exporting Countries Forum. The deficit is derived for each country, and the study indicates how the deficit could be filled through pipeline or LNG. Introduction The MENA area has lagged behind the global energy market during the last three decades in switching from oil and coal to natural gas consumption, despite the huge reserves it owns. During the 1980s, many industrial and financial centers in western Europe attracted gas importation from gas-producing regions such as Russia because of the wide difference between domestic and international values. The oil/gas price spread during the period 1980–2005 did not provide a strong economic incentive to MENA oil producers to substantially switch from oil- to gas-based power generation. Since 2005, oil prices have decoupled from gas prices and registered a wide positive spread, which has exaggerated the loss to oil producers from continued dependence on oil for power generation. LNG Potential in the MENA Region Non-oil MENA oil producers or small oil producers have attempted to minimize oil consumption, particularly in power generation, by switching to gas or even coal. However, this process has been hindered by economic difficulties and financing problems. Limited attempts to import LNG to balance energy needs have been carried out in the region. One possible reason for this is the inability to finance investment requirements for LNG receiving and gas-distributing facilities. While it is tempting to assume that MENA could be a semi-self-contained pipeline-supplied region, many obstacles hinder that realization. The gravity of the European and Asian markets for gas producers is a main reason for gas producers overlapping small consumers in the region by focusing on LNG trading schemes. Also, the political conflicts between neighboring nations complicate establishing an international gas pipeline network to cover the region. The planned economic growth for the region, even considering energy conservation, will require additional energy sources. The economical path forward will require switching to natural gas and possibly renewable energy sources. On average, the MENA region needs an annual economic growth of 5% considering population growth trends.

Numerical study on transport properties of the working mixtures for coal supercritical water gasification based power generation systems

Viscosity of H2O/CO2/H2 mixtures or H2O/CO2 mixtures is a vital transport property and required in the design of equipment for coal supercritical water gasification based power generation systems, however, no experimental data and studies have examined these viscosities in supercritical regions of water. In this paper, viscosity of these mixtures in supercritical regions of water is investigated by molecular dynamics method and different theoretical models. Moreover, the self-diffusion coefficient, radial distribution functions and H-bond number are also calculated via molecular dynamics simulations to make a better understanding of the temperature dependences of the viscosity of the mixtures in supercritical regions of water at a molecular level. The breakdown of Stokes–Einstein relation for the H2O/CO2/H2 mixture in supercritical regions of water is found and discussed. The prediction models and data put forth in this paper offer great value for practical application systems involving coal supercritical water gasification.

Life cycle environmental and economic assessment of coal seam gas-based electricity generation

PURPOSE: A large portion of coal seam gas is directly wasted and emitted to the environment, especially China, which is the world’s largest global warming gas emitter and energy consumer. Such emissions place heavy pressure on the Chinese government to achieve its global carbon reduction goals. This study quantified the economic and environmental impacts of coal seam gas-based power generation in China through a cost-combined life cycle assessment to systematically quantify the emission, impact, and mitigation measures caused by coal seam gas release in China. METHODS: Cost-coupled life cycle assessment analysis was conducted with SimaPro 8.4 in accordance with ISO 14040 series standards. Specifically, life cycle assessment was conducted with the IMPACTWorld+ method, and internal (e.g., raw materials, energy, labor, maintenance, infrastructure, and taxes) and external costs (e.g., land eco-remediation cost, human health economic burden, and environmental emission cost) were used to quantify the life cycle cost. RESULTS AND DISCUSSION: Approximately 11.8 kg of CH₄ and 19.8 kg of CO₂ were emitted per ton of coal mining in China in 2015. The direct global warming emission of coal seam gas at the national level accounted for 12% of the national carbon emission in 2015 in China. Coal seam gas-based electricity generation significantly reduced environmental impacts in the key categories of fossil depletion, non-carcinogens, global warming, and respiratory inorganics because of the substitution of coal power. Approximately $ 0.04/kWh of cost benefit was achieved due to the profit from concomitant coal during coal seam gas production. CONCLUSIONS: A win-win situation from economic and environmental perspectives was observed in electricity and freshwater consumption, pollutant emission cost, and human health economic burden. Effective measures to reduce the overall economic and environmental burdens from national coal seam gas-based power generation include alleviation of atmospheric carbon dioxide and dinitrogen oxide emissions, improvement of coal seam gas-based electricity generation and utilization efficiency, intensification of national coal seam gas utilization, and reduction of electricity and freshwater consumption.

Energetic, exergetic and economic (3E) investigation of biomass gasification-based power generation system employing molten carbonate fuel cell (MCFC), indirectly heated air turbine and an organic Rankine cycle

In this paper, a biomass gasification-based molten carbonate fuel cell (MCFC)-integrated advanced power system has been modelled and analyzed. The proposed system consisted of a biomass gasifier with hot gas cleaning equipment, a MCFC module, an indirectly heated air turbine and an organic Rankine cycle. Energetic, exergetic and economic (3E) analyses of the proposed power generation have been carried out. The effects of variation of operating and design parameters on the overall performances of the system have been showcased. Base case energetic and exergetic efficiency is found to be 38.49% and 32.7%, respectively. Exergetic analysis discloses that the highest exergy destruction takes place at gasifier (34.15%) followed by primary heat exchanger (16.15%), after burner (14.88%) and MCFC (13.80%). The proposed power system exhibits minimum unit cost of electricity of 0.17 $/kWh at current density of MCFC of 950 A/m2, fuel cell temperature of 973 K and secondary air blower pressure ratio of 1.6. At this operating condition, the plant gives a net output of 105.3 kW, its energy efficiency is 40.37% and exergy efficiency is 34.38%.

Thermo-economic assessment of biomass gasification-based power generation system consists of solid oxide fuel cell, supercritical carbon dioxide cycle and indirectly heated air turbine

This study energetically, exergetically and economically analyses a hybrid electricity generation system. The proposed system is a combination of a biomass gasifier, a solid oxide fuel cell module, an indirectly heated air turbine and a supercritical carbon dioxide power cycle. Influences of major designing and operating plant parameters, viz. current density of the solid oxide fuel cell, pressure ratio of the air compressor, turbine inlet temperature of the CO2 gas turbine, on the performance of the proposed system have been examined. The proposed system exhibits the highest first law efficiency of 51% at the current density of 2000 A/m2 and cell temperature of 1123 K, air compressor pressure ratio of 4.4, CO2 gas turbine inlet pressure and temperature of 10.14 MPa and 423 K. At this aforesaid condition, the proposed system exhibits a second law efficiency of 45%. It is found that the highest amount (40.70%) of exergy destruction takes place at the biomass gasifier, followed by the solid oxide fuel cell (20.05%). The economic analysis predicts that the minimum achievable levelized unit cost of electricity is 0.095 $/kWh.

Comparative Analysis on Economic Viability of Independent Power Producing System in Nigeria

The aim of this research is to compare the economic benefits of various types of power generating technologies such as gas turbines, wind turbines and solar energy that is suitable for power producing plants in Nigeria. The study conducts economic assessment by developing a data-intensive spread-sheet-based model. The model estimates the unit cost of electricity generated by a 10MW capacity solar photovoltaic system (PV), Wind turbine and Gas Turbine. Comparison based on investment cost and capacity charge indicated that the levelized cost of electricity (LCOEsolar) by solar PV was found to be $0.05188 per kWh with a net present value of (-$3,520,003), (LCOEwind), by Wind turbine was found to be $0.0732per kWh or with a net present cost of (-$24,486,076), while (LCOEgas) by Gas turbine was found to be $0.07214 per kWh or with a net present value of ($11,813,136). Results obtained with reference to LCOE showed that solar PV has the lowest cost of power generation, followed by gas turbine, and then wind turbine. Consequently, comparison based on decision for economic and preferable energy to invest in as well as the annual return the investment is projected to generate indicated that the internal rate of return (IRR) for both solar PV and wind turbine was found to be negative with a simple payback period of 14 and 35 years respectively, while internal rate of return (IRR) for gas turbine was found to be 18.67% with 5 years payback period. Hence, result obtained with reference to IRR and SPBP showed that gas turbine is the most economic and preferable energy generating technology to invest in since it is projected to generate 18.67% annual return from the investment in a minimum of 5 years period as compared to solar PV and wind turbine. Although natural gas-based power generation has lower upfront costs but it is vulnerable to volatile fuel prices, whereas electricity generation from renewables has higher upfront costs but provides electricity at costs that are highly predictable.

Comparative Analysis on Economic Viability of Independent Power Producing System in Nigeria

The aim of this research is to compare the economic benefits of various types of power generating technologies such as gas turbines, wind turbines and solar energy that is suitable for power producing plants in Nigeria. The study conducts economic assessment by developing a data-intensive spread-sheet-based model. The model estimates the unit cost of electricity generated by a 10MW capacity solar photovoltaic system (PV), Wind turbine and Gas Turbine. Comparison based on investment cost and capacity charge indicated that the levelized cost of electricity (LCOEsolar) by solar PV was found to be $0.05188 per kWh with a net present value of (-$3,520,003), (LCOEwind), by Wind turbine was found to be $0.0732per kWh or with a net present cost of (-$24,486,076), while (LCOEgas) by Gas turbine was found to be $10.07214 per kWh or with a net present value of ($11,813,136). Results obtained with reference to LCOE showed that solar PV has the lowest cost of power generation, followed by gas turbine, and then wind turbine. Consequently, comparison based on decision for economic and preferable energy to invest in as well as the annual return the investment is projected to generate indicated that the internal rate of return (IRR) for both solar PV and wind turbine was found to be negative with a simple payback period of 14 and 35 years respectively, while internal rate of return (IRR) for gas turbine was found to be 18.67% with 5 years payback period. Hence, result obtained with reference to IRR and SPBP showed that gas turbine is the most economic and preferable energy generating technology to invest in since it is projected to generate 18.67% annual return from the investment in a minimum of 5 years period as compared to solar PV and wind turbine. Although natural gas-based power generation has lower upfront costs but it is vulnerable to volatile fuel prices, whereas electricity generation from renewables has higher upfront costs but provides electricity at costs that are highly predictable.

Conceptual design of membrane-based pre-combustion CO2 capture process: Role of permeance and selectivity on performance and costs

Pre-combustion CO2 capture is regarded as a promising option to mitigate the environmental pollution from coal combustion, due to its relatively low energy duty and prospects for the use of hydrogen in power generation and industrial sectors. Nowadays, research and development efforts are mainly focusing on advanced technologies to separate H2 and CO2 from a synthesis gas of a gasification-based power generation system. In this regard, membrane separation processes are attracting an increasing attention, due to their potential for a more cost-effective and environmental friendly CO2 capture compared to well-established solvent-based processes.A conceptual design and techno-economic analysis is presented of a pre-combustion CO2 capture process based on H2-selective polymeric membranes in an integrated gasification combined cycle (IGCC) power plant, including the water-gas-shift (WGS) system. The design approach is based on the selection of the most effective membrane separation process and economic optimization of operating conditions. The capture process is based on a three-stage membrane separation system, producing a hydrogen stream feeding the power generation unit and a liquid CO2 stream, ready for transport and geological storage. Considering a state-of-the-art polymeric membrane with a H2 to CO2 selectivity of 15 and H2 permeance of 300 GPU, the IGCC efficiency penalty states at around 5% pts when the separation process is operated with a pressure on membrane feed side of 70 bar, corresponding to an estimated cost of CO2 capture of 16.6 €/t CO2. A sensitivity analysis of operating pressure and membrane properties revealed that the cost of CO2 capture can be reduced to less than 15 €/t CO2 by moderately increasing the H2 to CO2 selectivity and adjusting the designed process accordingly. Additionally, a decrease in the feed-side pressure slightly disfavours the economic performance of CO2 capture for H2 permeances greater than 300 GPU. The membrane-based capture process compared most favourably in cost-effectiveness with the well-established solvent based Selexol process.

Life Cycle Greenhouse Gas Impacts of Coal and Imported Gas-Based Power Generation in the Indian Context.

Few studies have evaluated the life cycle greenhouse gas (GHG) impacts associated with India's power sector, despite the expectation that it will dominate new thermal generation capacity additions over the coming decades. Here, we utilize India-specific supply chain data to estimate life cycle GHG emissions associated with power generated by combustion of Indian coal and liquefied natural gas (LNG) imported from the United States. Life cycle impacts of domestic coal power vary widely (80% confidence interval (CI): 951-1231 kg CO2eq/MWh) because of heterogeneity in existing power plant characteristics such as efficiency, age, and capacity. Less variability is observed for LNG sourced from northeast United States and used in the existing Indian combined cycle gas turbine (CCGT) fleet (80% CI: 523-648 kg CO2eq/MWh). On average, life cycle GHG emissions from LNG imported into India are ∼54% lower than those associated with Indian coal. However, the GHG intensity of the Indian coal-power sector may be reduced by 13% by retiring plants with the lowest efficiencies and replacing them with higher-efficiency supercritical plants. Improvement of the CCGT fleet efficiency from its current level (41%) to that of a new plant with an F-class turbine (50%) could reduce life cycle GHG emissions for LNG-sourced power by 19%.

Sustainability assessment of gas based power generation using a life cycle assessment approach

PurposeIndia is a developing economy along with an increasing population estimated to be the largest populated country in about seven years. Simultaneously, its power consumption is projected to increase more than double by 2020. Currently, the dependence on coal is relatively high, making it the largest global greenhouse gas emitting sector which is a matter of great concern. The purpose of this paper is to evaluate the environmental impacts of the natural gas electricity generation in India and propose a model using a life cycle assessment (LCA) approach.Design/methodology/approachLCA is used as a tool to evaluate the environmental impact of the natural gas combined cycle (NGCC) power plant, as it adopts a holistic approach towards the whole process. The LCA methodology used in this study follows the ISO 14040 and 14044 standards (ISO 14040: 2009; ISO 14044: 2009). A questionnaire was designed for data collection and validated by expert review primary data for the annual environmental emission was collected by personally visiting the power plant. The study follows a cradle to gate assessment using the CML (2001) methodology.FindingsThe analysis reveals that the main impacts were during the process of combustion. The Global warming potential is approximately 0.50 kg CO2 equivalents per kWh of electricity generation from this gas-based power plant. These results can be used by stakeholders, experts and members who are authorised to probe positive initiative for the reduction of environmental impacts from the power generation sector.Practical implicationsConsidering the pace of growth of economic development of India, it is the need of the hour to emphasise on the patterns of sustainable energy generation which is an important subject to be addressed considering India’s ratification to the Paris Climate Change Agreement. This paper analyzes the environmental impacts of gas-based electricity generation.Originality/valuePresenting this case study is an opportunity to get a glimpse of the challenges associated with gas-based electricity generation in India. It gives a direction and helps us to better understand the right spot which require efforts for the improvement of sustainable energy generation processes, by taking appropriate measures for emission reduction. This paper also proposes a model for gas-based electricity generation in India. It has been developed following an LCA approach. As far as we aware, this is the first study which proposes an LCA model for gas-based electricity generation in India. The model is developed in line with the LCA methodology and focusses on the impact categories specific for gas-based electricity generation.

Evaluating the Electricity Supply in Turkey Under Economic Growth and Increasing Electricity Demand

The growing economy and residential consumption cause an increasing trend in the demand for electricity in Turkey. The country imports a quite ratio of its energy resources and heavily depend on the fossil fuels. On the other hand, the demand for the electricity that needs to be provided using resources that have minimum cost, sustainable supply and long term cycle is increasing parallel to the economic growth in the country. The long term investments on the renewable energy resources and hydroelectric plants affect the electricity supply. The country is planning to have a nuclear power plant in near future. Turkey stills provides the large part of its electricity from coal and natural gas. The natural gas based power generation is still expensive and that affect the power prices. In this research, the Turkish electricity market is analysed first, then the relationship between economic growth and electricity demand are analysed. The annual electricity demand and supply are also discussed.