Landfill Gas Utilization for Water, Electricity and Food Production in Texas

2016 ◽  
Author(s):  
Enakshi Wikramanayake ◽  
Vaibhav Bahadur
Keyword(s):  
Natural Gas ◽  
Food Production ◽  
Electricity Generation ◽  
Power Plants ◽  
Landfill Gas ◽  
Starting Point ◽  
Gas Consumption ◽  
Current Area ◽  
Novel Concept ◽  
Installed Capacity

Methane emissions from US landfills equal 14% of US residential natural gas consumption, and represent a significant waste of energy. This work presents and analyzes three concepts for landfill gas (LFG) utilization, which impact the water, electricity and food sectors. The first novel concept uses LFG to power refrigeration cycles to enable atmospheric water harvesting (AWH). Freshwater produced by LFG-based AWH can be used for water intensive operations (drilling, hydraulic fracturing) in oilfields located near landfills. The second concept is about routing LFG to nearby natural gas-fired power plants, instead of using it for onsite electricity generation. This approach is attractive, since both landfills and power plants are concentrated around population centers. The third novel concept uses LFG as the feedstock and energy source for ammonia production, which is the starting point for fertilizers. A framework and methodology for quantifying the benefits of these concepts is established. Emissions from landfills in Texas are analyzed to map the current LFG management, and quantify the benefits of the proposed concepts. Firstly, LFG-based AWH can meet 14% of the water requirement of the Barnett Shale, which can be served by 20 landfills. Secondly, routing the LFG to gas-fired power plants will enable a 3% increase in statewide installed capacity. Importantly, five power plants can increase their capacity by more than 10%. Thirdly, LFG can be used to produce 3,200 tons of ammonia daily, which yields enough fertilizer to cultivate nine times the current area under corn cultivation. Overall, these concepts offer alternatives to LFG-based onsite electricity generation, which enables utilization of only 22% of the generated LFG. The proposed waste-to-value concepts can be extended to other regions and offer options to augment water, electricity and food production globally.

Turning NGCC Into IGCC: Cycle Retrofitting Issues

2006 ◽  
Author(s):  
Juan Pablo Gutierrez ◽  
Terry B. Sullivan ◽  
Gerald J. Feller
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
Power Plants ◽  
Combined Cycle ◽  
Integrated Gasification Combined Cycle ◽  
Water Steam ◽  
Power Block ◽  
Starting Point ◽  
Natural Gas Combined Cycle ◽  
Gas Plants

The increase in price of natural gas and the need for a cleaner technology to generate electricity has motivated the power industry to move towards Integrated Gasification Combined Cycle (IGCC) plants. The system uses a low heating value fuel such as coal or biomass that is gasified to produce a mixture of hydrogen and carbon monoxide. The potential for efficiency improvement and the decrease in emissions resulting from this process compared to coal-fired power plants are strong evidence to the argument that IGCC technology will be a key player in the future of power generation. In addition to new IGCC plants, and as a result of new emissions regulations, industry is looking at possibilities for retrofitting existing natural gas plants. This paper studies the feasibility of retrofitting existing gas turbines of Natural Gas Combined Cycle (NGCC) power plants to burn syngas, with a focus on the water/steam cycle design limitations and necessary changes. It shows how the gasification island processes can be treated independently and then integrated with the power block to make retrofitting possible. This paper provides a starting point to incorporate the gasification technology to current natural gas plants with minor redesigns.

Safety Implications of Bridging the Energy Supply/Demand Gap in Nigeria through Associated Natural Gas Utilization

2007 ◽  
Vol 18 (3-4) ◽  
pp. 363-372
Author(s):  
Funso A. Akeredolu ◽  
Jacob A. Sonibare
Keyword(s):  
Natural Gas ◽  
Energy Supply ◽  
Energy Demand ◽  
Electricity Generation ◽  
Safe Delivery ◽  
Associated Gas ◽  
Gas Utilization ◽  
Aging Infrastructure ◽  
Generation Capacity ◽  
Installed Capacity

There exists a wide energy supply/demand gap in Nigeria. The local generation of electricity meets only 31% of the demand of 10000 MW. By contrast, only 39.6% of the total installed capacity for electricity generation is achieved, owing to aging infrastructure, etc. The energy demand/supply pattern and infrastructure critically reviewed thus suggested the need to increase the electricity generation capacity. Furthermore, Nigeria flares 77% of her associated natural gas. Apart from the environmental penalties that flaring represents, in monetary terms, over the 110 years' life of Nigeria's gas reserves, a conservative estimate of the cost of the gas so-flared was $330 billion (based on $20/barrel average price of crude). It was safely inferred that the way forward in meeting the country's energy demand should include a strong element of gas utilization. In previous publications by this group, it was established that while domestic cooking could reduce the flared gas by about 5.4%, a cohesive policy on associated gas use for electricity generation could eliminate gas flaring. For domestic utilization of the associated gas, burner design and safety concerns were identified as the key challenges to overcome. The paper reports the effectiveness of odorizers in leakage detection/ prevention by the local consumers. It also discusses the issue of prevention of gas explosions. The previous cases of gas accidents were reviewed. The safety approaches proffered in the paper identified the relevant areas of research for safe delivery and consumption of natural gas in Nigeria.

scholarly journals Long-Term Natural Gas Consumption Forecasting Based on Analog Method and Fuzzy Decision Tree

Energies ◽  
2021 ◽  
Vol 14 (16) ◽  
pp. 4905
Author(s):  
Bartłomiej Gaweł ◽  
Andrzej Paliński
Keyword(s):  
Natural Gas ◽  
Decision Trees ◽  
Energy Intensity ◽  
Fuzzy Decision ◽  
Energy Mix ◽  
Starting Point ◽  
Gas Consumption ◽  
Natural Gas Consumption ◽  
Fuzzy Decision Trees

Classic forecasting methods of natural gas consumption extrapolate trends from the past to subsequent periods of time. The paper presents a different approach that uses analogues to create long-term forecasts of the annual natural gas consumption. The energy intensity (energy consumption per dollar of Gross Domestic Product—GDP) and gas share in energy mix in some countries, usually more developed, are the starting point for forecasts of other countries in the later period. The novelty of the approach arises in the use of cluster analysis to create similar groups of countries and periods based on two indicators: energy intensity of GDP and share of natural gas consumption in the energy mix, and then the use of fuzzy decision trees for classifying countries in different years into clusters based on several other economic indicators. The final long-term forecasts are obtained with the use of fuzzy decision trees by combining the forecasts for different fuzzy sets made by the method of relative chain increments. The forecast accuracy of our method is higher than that of other benchmark methods. The proposed method may be an excellent tool for forecasting long-term territorial natural gas consumption for any administrative unit.

Energy Development in Malaysia

1988 ◽  
Vol 6 (4-5) ◽  
pp. 336-341
Author(s):  
YB Dato' Murad Hashim
Keyword(s):  
Natural Gas ◽  
Electricity Generation ◽  
Security Of Supply ◽  
Total Energy Consumption ◽  
Coal Gas ◽  
Hydropower Potential ◽  
Excess Production ◽  
Gas Consumption ◽  
Natural Gas Consumption ◽  
Year 2000

The Malaysian governments Four Fuel Energy Policy is concerned with security of supply and the need to meet economic development targets through greater use of natural gas, hydropower and with imported coal. Gas reserves are 52 trillion cu. ft. and hydropower potential 29,000MW. Coal is included because of the enormous supplies available worldwide. Indigenous natural gas consumption is expected to grow at 9% p.a. till the year 2000 and to account for 40% of the total energy consumption. The Peninsula Gas Utilisation project will reduce the use of oil in electricity generation, provide it for steel manufacture and deliver gas to the domestic market. Natural gas will be used increasingly in transportation and for petrochemicals, excess production is destined for export.

scholarly journals Major Utilization of Natural Gas in Turkey

2005 ◽  
Vol 23 (2) ◽  
pp. 125-140 ◽  
Author(s):  
Ahmet Mahmut Kilic
Keyword(s):  
Soviet Union ◽  
Natural Gas ◽  
Former Soviet Union ◽  
Energy Demand ◽  
Power Plants ◽  
Primary Energy ◽  
World Energy ◽  
Western Market ◽  
Oil And Natural Gas ◽  
Gas Consumption

The aim of this paper is the major utilization of natural gas in Turkey. Turkey is rapidly growing in terms of both its economy and population due to its demand for energy. In the new world energy order, gas usage with no doubt will continue to grow well into the 21st century. Natural gas has been available for Turkish consumption for 17 years. Its use expanded sharply after the signing of the first sales and purchase agreement with the former Soviet Union in 1986. Turkish natural gas usage is projected to increase remarkably in coming years, with the prime consumers, expected to be industry and power plants. Energy demand of Turkey is growing by 8% annually, one of the highest rates in the world. In addition, natural gas consumption is the fastest growing primary energy source in Turkey. Gas sales started at 0.5 bcm (billion cubic meters), in 1987 and reached approximately 22 bcm in 2003. Turkey is an important candidate to be the “energy corridor” in the transmission of the abundant oil and natural gas resources of the Middle East and Middle Asia countries to the Western market.

Opportunities for CO2 Capture and Storage in Iranian Electricity Generation

2010 ◽  
Author(s):  
Farshid Zabihian ◽  
Alan S. Fung
Keyword(s):  
Natural Gas ◽  
Co2 Capture ◽  
Co2 Emission ◽  
Electricity Generation ◽  
Power Plants ◽  
Fossil Fuel ◽  
Combined Cycle ◽  
Pure Oxygen ◽  
Co2 Capture And Storage ◽  
And Storage

CO2 capture and storage (CCS) systems are technologies that can be used to reduce CO2 emissions by different industries where combustion is part of the process. A major problem of CCS system utilization in electricity generation industry is their high efficiency penalty in power plants. For different types of power plants fueled by oil, natural gas and coal, there are three main techniques that can be applied: • CO2 capture after combustion (post-combustion); • CO2 capture after concentration of flue gas by using pure oxygen in boilers and furnaces (oxy-fuel power plant); • CO2 capture before combustion (pre-combustion). More than 90% of electricity generation in Iran is based on fossil fuel power plants. Worldwide, electricity generation is responsible for 54% of GHG emissions. Thus, it is vital to reduce CO2 emission in fossil fuel-fired power plants. In this paper, it is shown that, by applying CO2 capture systems in power generation industry, very low CO2 emission intensity is possible but the energy and economic penalties are substantial. The analyses showed that for different technologies efficiency penalty could be as high as 25% and cost of electricity might increase by more than 65%. Two scenarios for Iranian electricity generation sector were investigated in this paper: installing CCS in the existing power plants with current technologies and replacing existing power plants by natural gas combined cycle plants equipped with CO2 capture system. The results revealed that the GHG intensity can be reduced from 610 to 79 gCO2eq/kWh in the first scenario and to 54 gCO2eq/kWh in the second scenario.

Liquefied natural gas as a backup fuel for TPP

2021 ◽  
Vol 14 (2) ◽  
pp. 84-91
Author(s):  
S. N. Lenev ◽  
V. B. Perov ◽  
A. N. Vivchar ◽  
A. V. Okhlopkov ◽  
O. Y. Sigitov ◽  
...  
Keyword(s):  
Natural Gas ◽  
Power Plants ◽  
Large Scale ◽  
Gas Flow ◽  
National Policy ◽  
Liquefied Natural Gas ◽  
Fuel Oil ◽  
Gas Flows ◽  
Gas Industry ◽  
Gas Consumption

Major trends in the development of the gas industry point to a large-scale expansion of the liquefied natural gas (LNG) market, which continues to be a fast-growing segment compared to other energy sources. The national policy of the Russian Federation is aimed at developing the infrastructure of LNG complexes. This article analyses the world experience in the use of LNG complexes in gas consumption peak damping installations, which meet the conditions of LNG use as a backup fuel by PJSC Mosenergo branches (low-tonnage production combined with a large volume of LNG storage). It is shown that, in terms of the conditions of production and use of LNG at power plants, the most suitable are installations with 90–100% liquefaction of the incoming gas flow with an external refrigerating circuit using a mixed refrigerant or nitrogen, which provide the composition of regasified LNG almost identical to the composition of the source gas. The authors have formulated requirements for the development of energy-efficient LNG complexes at PJSC Mosenergo branches, including ensuring cycle energy consumption by expanding the network gas in the expander with utilization of refrigerating capacity in the liquefaction cycle, as well as cooling the compressed coolant of the refrigerating circuit by gas flows supplied further for combustion. The technological features of implementation of the LNG complex for production, storage and regasification of LNG as a reserve fuel for TPPs are reviewed. The study has shown that the most suitable power plant for the introduction of an LPG complex is TPP-22, for which a new fuel oil facility is being designed. Despite the current practice of using fuel oil and diesel fuel as backup fuels, LNG can have a competitive advantage through the use of secondary energy resources of TPPs. 

Greenhouse Gas Emissions Reduction Potentials in Iranian Electricity Generation Sector and Comparison With Canada

2008 ◽  
Author(s):  
Farshid Zabihian ◽  
Alan S. Fung
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Greenhouse Gas ◽  
Electricity Generation ◽  
Power Plants ◽  
Thermal Power ◽  
Ghg Emissions ◽  
Combined Cycle ◽  
Reduction Potentials ◽  
Power Stations

In recent years, greenhouse gas (GHG) emissions and their potential effects on the global climate change have been a worldwide concern. Based on International Energy Agency (IEA), power generation contributes half of the increase in global GHG emissions in 2030. In the Middle East, Power generation is expected to make the largest contribution to the growth in carbon-dioxide emissions. The share of the power sector in the region’s total CO2 emissions will increase from 34% in 2003 to 36% in 2030. Therefore, it is very important to reduce GHG emissions in this industry. The purpose of this paper is to examine greenhouse gas emissions reduction potentials in the Iranian electricity generation sector through fuel switching and adoption of advanced power generation systems and to compare these potentials with Canadian electricity generation sector. These two countries are selected because of raw data availability and their unique characteristics in electricity generation sector. To achieve this purpose two different scenarios have been introduced: Scenario #1: Switching existing power stations fuel to natural gas. Scenario #2: Replacing existing power plants by natural gas combined-cycle (NGCC) power stations (The efficiency of NGCC is considered to be 49%). The results shows that the GHG reduction potential for Iranian steam power plants, gas turbines and combined cycle power plants in first scenario are 9.9%, 5.6%, and 2.6%, respectively with the average of 7.6%. For the second scenario the overall reduction of 31.9%, is expected. The average reduction potential for Canadian power plants for scenario number 1 and 2 are 33% and 59%, respectively. As it can be seen, in Canada there are much higher potentials to reduce GHG emissions. The reason is that in Canada majority of power plants use coal as the primary fuel. In fact almost 73% of electricity in thermal power stations is generated by coal. Whereas in Iran almost all power plants (with some exceptions) are dual fuels and 77% of energy consumed in Iran’s thermal power plants come from natural gas. Also, 21% of total electricity generated in Iran is produced by combined-cycle power plants.

Employment benefits of electricity generation: A comparative assessment of lignite and natural gas power plants in Greece

Energy Policy ◽  
2009 ◽  
Vol 37 (10) ◽  
pp. 4155-4166 ◽  
Author(s):  
C. Tourkolias ◽  
S. Mirasgedis ◽  
D. Damigos ◽  
D. Diakoulaki
Keyword(s):  
Natural Gas ◽  
Electricity Generation ◽  
Power Plants ◽  
Comparative Assessment ◽  
Employment Benefits
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