scholarly journals Economic performance evaluation of natural gas vehicles and their fuel infrastructures

2018 ◽  
Vol 51 ◽  
pp. 01008
Author(s):  
Dejene A Hagos ◽  
Erik O Ahlgren
Keyword(s):  
Natural Gas ◽  
Production Cost ◽  
Direct Injection ◽  
Production Costs ◽  
High Price ◽  
Carbon Intensity ◽  
Low Carbon ◽  
Fuel Production ◽  
Long Distance ◽  
Natural Gas Vehicles

The transition from high carbon-intensity to low carbon-intensity transport fuels entails the development of energy efficient and cost-effective decarbonisation pathways. In this paper, 14 potential natural and renewable gas supply pathways and natural gas vehicles (NGVs) have been selected and evaluated with regards to well-to-tank (WTT) fuel production costs and break-even vehicle added investment costs. NGVs are evaluated for both road- and maritime transport applications with three types of gas engines; dedicated, dual fuel, and high pressure direct injection (HPDI) engines. The results indicate that owing to the alternate gas distribution mechanisms and filling stations configuration there exist a substantial fuel production cost differences between the selected gas pathways. Despite its long-distance shipping and distribution, imported LNG showed significant production cost advantage over compressed natural gas (CNG) and liquefied renewable natural gas (LRNG) pathways. Evaluating the current economic performances, all NGVs are found to be competitive corresponding to gasoline cars, but not compared to diesel cars due to the lower price gap between CNG and diesel. In the heavy-duty vehicle and passenger vessel segments, however, owing to the high price gap between LNG and diesel/marine gas oil (MGO), all NGVs and LNG passenger vessels showed high competitiveness compared to their conventional counterparts.

scholarly journals Economic performance evaluation of natural gas vehicles and their fuel infrastructures

2018 ◽  
Vol 51 ◽  
pp. 01008
Author(s):  
Dejene A Hagos ◽  
Erik O Ahlgren
Keyword(s):  
Natural Gas ◽  
Production Cost ◽  
Direct Injection ◽  
Production Costs ◽  
High Price ◽  
Carbon Intensity ◽  
Low Carbon ◽  
Fuel Production ◽  
Long Distance ◽  
Natural Gas Vehicles

The transition from high carbon-intensity to low carbon-intensity transport fuels entails the development of energy efficient and cost-effective decarbonisation pathways. In this paper, 14 potential natural and renewable gas supply pathways and natural gas vehicles (NGVs) have been selected and evaluated with regards to well-to-tank (WTT) fuel production costs and break-even vehicle added investment costs. NGVs are evaluated for both road- and maritime transport applications with three types of gas engines; dedicated, dual fuel, and high pressure direct injection (HPDI) engines. The results indicate that owing to the alternate gas distribution mechanisms and filling stations configuration there exist a substantial fuel production cost differences between the selected gas pathways. Despite its long-distance shipping and distribution, imported LNG showed significant production cost advantage over compressed natural gas (CNG) and liquefied renewable natural gas (LRNG) pathways. Evaluating the current economic performances, all NGVs are found to be competitive corresponding to gasoline cars, but not compared to diesel cars due to the lower price gap between CNG and diesel. In the heavy-duty vehicle and passenger vessel segments, however, owing to the high price gap between LNG and diesel/marine gas oil (MGO), all NGVs and LNG passenger vessels showed high competitiveness compared to their conventional counterparts.

Assessing the Carbon Intensity of Low-Enthalpy Deep Geothermal Heat

2020 ◽  
Author(s):  
Alistair McCay ◽  
Jen Roberts ◽  
Michael Feliks
Keyword(s):  
Natural Gas ◽  
Conventional Heating ◽  
Carbon Intensity ◽  
Emissions Reduction ◽  
Low Carbon ◽  
Geothermal Heat ◽  
Electricity Grid ◽  
Geothermal Heating ◽  
Heat System ◽  
The Uk

<p>Decarbonising heating presents a significant societal challenge. Deep geothermal energy is widely recognised as a source of low carbon heat. However, to date there has been no assessment of the carbon intensity of heat from low-enthalpy deep geothermal as previous studies have focussed on geothermal power or higher enthalpy heat. Further, there is currently no established method for assessing the CO<sub>2</sub> emissions reduction from implementing a deep geothermal heating scheme.</p><p>To address these gaps, we performed a life cycle assessment of greenhouse gas emissions relating to a typical deep geothermal heat system to (i) calculate the carbon intensity of geothermal heat (ii) identify the factors that most affect these values (iii) consider the carbon abated if geothermal heat substitutes conventional heating sources and (iv) set a benchmark methodology that future projects can adapt and apply to assess and enhance the carbon emissions reduction offered by geothermal heat development in the UK and internationally.</p><p>In the absence of an established deep geothermal heat system in the UK, to inform our work we adopted parameters from a feasibility study for a potential geothermal heat system in Banchory, Scotland. The Banchory project aimed to deliver heat to a network sourced from 2-3 km deep in a radiothermal granite where temperatures were predicted to be 70-90 °C. We assumed a 30 year project lifetime and that the heat system operation was powered by the UK electricity grid which was decarbonising over this period.</p><p>Our analysis found that the carbon intensity of deep geothermal heat is 9.7 - 14.0 kg(CO<sub>2</sub>e)/MWh<sub>th</sub>. This is ~5% of the value for natural gas heating. The carbon intensity is sensitive to several factors, and so the carbon intensity of deep geothermal heat could be reduced further by: replacing diesel fuelled drilling apparatus with natural gas or electricity powered hardware; decarbonise the power grid more rapidly than forecast; or substitute mains power with local renewable electricity to power pumps – or decarbonising the electricity grid faster or deeper; source lower carbon steel and cement; design projects to minimise land use change emissions.</p><p>Overall, our study provides quantitative evidence that deep geothermal systems can produce long term very low carbon heat that is compatible with net-zero, even for low enthalpy geothermal resources.</p>

scholarly journals Greenhouse Gas Reductions under Low Carbon Fuel Standards?

2009 ◽  
Vol 1 (1) ◽  
pp. 106-146 ◽  
Author(s):  
Stephen P Holland ◽  
Jonathan E Hughes ◽  
Christopher R Knittel
Keyword(s):  
Greenhouse Gas ◽  
Carbon Emissions ◽  
Cost Effective ◽  
Carbon Intensity ◽  
Energy Prices ◽  
Low Carbon ◽  
High Carbon ◽  
Fuel Production ◽  
Abatement Costs ◽  
Effective Policy

A low carbon fuel standard (LCFS) seeks to reduce greenhouse gas emissions by limiting the carbon intensity of fuels. We show this decreases high carbon fuel production but increases low carbon fuel production, possibly increasing net carbon emissions. The LCFS cannot be efficient, and the best LCFS may be nonbinding. We simulate a national LCFS on gasoline and ethanol. For a broad parameter range, emissions decrease, energy prices increase, abatement costs are large ($80–$760 billion annually), and average abatement costs are large ($307–$2,272 per CO2 metric ton). A cost effective policy has much lower average abatement costs ($60–$868). (JEL Q54, Q58)

Production of Synthetic Natural Gas From Carbon Dioxide and Renewably Generated Hydrogen: A Techno-Economic Analysis of a Power-to-Gas Strategy

2018 ◽  
Vol 141 (2) ◽  
Author(s):  
William L. Becker ◽  
Michael Penev ◽  
Robert J. Braun
Keyword(s):  
Carbon Dioxide ◽  
Hydrogen Production ◽  
Natural Gas ◽  
Economic Analysis ◽  
Production Costs ◽  
Plant Design ◽  
Low Carbon ◽  
Synthetic Natural Gas ◽  
Methanation Reaction ◽  
Power To Gas

Power-to-gas to energy systems are of increasing interest for low carbon fuels production and as a low-cost grid-balancing solution for renewables penetration. However, such gas generation systems are typically focused on hydrogen production, which has compatibility issues with the existing natural gas pipeline infrastructures. This study presents a power-to-synthetic natural gas (SNG) plant design and a techno-economic analysis of its performance for producing SNG by reacting renewably generated hydrogen from low-temperature electrolysis with captured carbon dioxide. The study presents a “bulk” methanation process that is unique due to the high concentration of carbon oxides and hydrogen. Carbon dioxide, as the only carbon feedstock, has much different reaction characteristics than carbon monoxide. Thermodynamic and kinetic considerations of the methanation reaction are explored to design a system of multistaged reactors for the conversion of hydrogen and carbon dioxide to SNG. Heat recuperation from the methanation reaction is accomplished using organic Rankine cycle (ORC) units to generate electricity. The product SNG has a Wobbe index of 47.5 MJ/m3 and the overall plant efficiency (H2/CO2 to SNG) is shown to be 78.1% LHV (83.2% HHV). The nominal production cost for SNG is estimated at 132 $/MWh (38.8 $/MMBTU) with 3 $/kg hydrogen and a 65% capacity factor. At U.S. DOE target hydrogen production costs (2.2 $/kg), SNG cost is estimated to be as low as 97.6 $/MWh (28.6 $/MMBtu or 1.46 $/kgSNG).

Just cuts for fossil fuels? Supply-side carbon constraints and energy transition

2019 ◽  
Vol 52 (6) ◽  
pp. 1072-1092 ◽  
Author(s):  
Philippe Le Billon ◽  
Berit Kristoffersen
Keyword(s):  
Fossil Fuels ◽  
Fossil Fuel ◽  
Oil And Gas ◽  
Energy Transition ◽  
Economic Consequences ◽  
Production Costs ◽  
Carbon Intensity ◽  
Supply Side ◽  
Fuel Production ◽  
Financial Flows

Reducing greenhouse gas emissions has generally been approached through demand-side initiatives, yet there are increasing calls for supply-side interventions to curtail fossil fuel production. Pursuing energy transition through supply-side constraints would have major geopolitical and economic consequences. Depending on the criteria and instruments applied, supply cuts for fossil fuels could drastically reduce and reorient major financial flows and reshape the spatiality of energy production and consumption. Building on debates about just transitions and supply constraints, we provide a survey of emerging interventions targeting the supply of, rather than the demand for, fossil fuels. We articulate four theories of justice and criteria to prioritize cuts among fossil fuel producers, including with regard to carbon intensity, production costs, affordability, developmental efficiency and support for climate change action. We then examine seven major supply constraint instruments, their effectiveness and possible pathways to supply cuts in the coal, oil and gas sectors. We suggest that supply cuts both reflect and offer purposeful political spaces of interventions towards a ‘just’ transition away from fossil fuel production.

scholarly journals Cost Analysis of Nuclear Hydrogen Production Using IAEA-HEEP 4 Software

2021 ◽  
Vol 2048 (1) ◽  
pp. 012005
Author(s):  
E Dewita ◽  
R Prassanti ◽  
K S Widana ◽  
Y S B Susilo
Keyword(s):  
Carbon Dioxide ◽  
High Temperature ◽  
Hydrogen Production ◽  
Natural Gas ◽  
Production Cost ◽  
Large Scale ◽  
Production Costs ◽  
Outlet Temperature ◽  
Nuclear Heat ◽  
The Cost

Abstract Hydrogen is a commercially important element. Basically, there are several methods of hydrogen production that have been commercially used, such as Steam Methane Reforming (SMR), High Temperature Steam Electrolysis (HTSE), and thermochemical cycles, like Sulphur-Iodine (SI). Among these methods, SMR is the most widely used for large-scale hydrogen production, with conversion efficiency between 74–85% and it has commercially used in some fertilizer industries in Indonesia. Steam reforming is a method to convert alkane (natural gas) compounds to hydrogen and carbon dioxide (synthetic gas) by adding moisture at high pressure and temperature (35-40 bar; 800-900°C). These hydrogen production technologies can be coupled with different nuclear reactors based on the heat required in the process. The High Temperature Gas-cooled Reactor (HTGR) using helium as a coolant, has a high outlet temperature (900°C), so it can potentially be used to supply for process heat for hydrogen production, coal liquefaction/gasification or for other industrial processes requiring high temperature heat. Hydrogen production cost from SMR method is influenced by a range of technical and economic factors. The fuel component of natural gas needed in the SMR method can be replaced by nuclear heat from a nuclear power plant (NPP) operating in cogeneration mode (i.e. simultaneous producing electric power and heat), hence contributing to the reduction of carbon dioxide in the process. In the SMR method, fuel costs are the largest cost component, accounting for between 45% and 75% of production costs. Therefore, there is opportune to assess the economics of hydrogen production by using nuclear heat. The economic evaluation is done by using IAEA HEEP-4 Software. The results comprise cost break up for 2 cases, coupling SMR process for hydrogen production with: (1) 2 HTGRs of 170 MWth/unit; and (2) 1 HTGR of 600 MWth/unit. The cost of hydrogen production is highly depend on the scale of the NPP as energy source and results indicated that hydrogen production cost of the 1 HTGR Unit600 MWth (Case 2) has a lower value (1.72 US$/kgH2), than the cost obtained when 2 HTGR units of 170 MWth each (case 1) are considered (2.72 US$/kgH2). For comparison, the hydrogen production cost by using SMR with carbon capture and storage (CCS) with natural gas as fuel is 2.27 US$/kgH2.

scholarly journals Hybrid Fuel Cell—Supercritical CO2 Brayton Cycle for CO2 Sequestration-Ready Combined Heat and Power

Energies ◽  
2020 ◽  
Vol 13 (19) ◽  
pp. 5043
Author(s):  
Rhushikesh Ghotkar ◽  
Ellen B. Stechel ◽  
Ivan Ermanoski ◽  
Ryan J. Milcarek
Keyword(s):  
Fuel Cell ◽  
Natural Gas ◽  
Supercritical Co2 ◽  
Co2 Sequestration ◽  
High Efficiency ◽  
Air Separation ◽  
Carbon Intensity ◽  
Brayton Cycle ◽  
Low Carbon ◽  
Electrical Efficiency

The low prices and its relatively low carbon intensity of natural gas have encouraged the coal replacement with natural gas power generation. Such a replacement reduces greenhouse gases and other emissions. To address the significant energy penalty of carbon dioxide (CO2) sequestration in gas turbine systems, a novel high efficiency concept is proposed and analyzed, which integrates a flame-assisted fuel cell (FFC) with a supercritical CO2 (sCO2) Brayton cycle air separation. The air separation enables the exhaust from the system to be CO2 sequestration-ready. The FFC provides the heat required for the sCO2 cycle. Heat rejected from the sCO2 cycle provides the heat required for adsorption-desorption pumping to isolate oxygen via air separation. The maximum electrical efficiency of the FFC sCO2 turbine hybrid (FFCTH) without being CO2 sequestration-ready is 60%, with the maximum penalty being 0.68% at a fuel-rich equivalence ratio (Φ) of 2.8, where Φ is proportional to fuel-air ratio. This electrical efficiency is higher than the standard sCO2 cycle by 6.85%. The maximum power-to-heat ratio of the sequestration-ready FFCTH is 233 at a Φ = 2.8. Even after including the air separation penalty, the electrical efficiency is higher than in previous studies.

scholarly journals Can Lower Carbon Aviation Fuels (LCAF) Really Complement Sustainable Aviation Fuel (SAF) towards EU Aviation Decarbonization?

Energies ◽  
2021 ◽  
Vol 14 (19) ◽  
pp. 6430
Author(s):  
David Chiaramonti ◽  
Giacomo Talluri ◽  
George Vourliotakis ◽  
Lorenzo Testa ◽  
Matteo Prussi ◽  
...  
Keyword(s):  
Large Scale ◽  
Production Costs ◽  
Aviation Fuel ◽  
Carbon Intensity ◽  
Low Carbon ◽  
Market Prices ◽  
Technical Potential ◽  
Legislative Proposals ◽  
Almost All ◽  
The Eu

The present work provides an analysis of the potential impact of fossil-based Low Carbon Aviation Fuels (LCAF) for the European aviation sector, with a time horizon to 2050. LCAF are a crude-derived alternative to kerosene, offering some Green House Gas (GHG) savings, and have been defined by ICAO as eligible fuels for mitigating the environmental impact of aviation. A methodological framework to evaluate the EU technical potential for LCAF production is developed, based on data on crude utilization for jet fuel production in EU refineries, relevant carbon intensity reduction technologies, market prices, and aviation fuel volumes. Two different baselines for fossil-derived kerosene carbon intensity (CI) are considered: a global figure of 89 gCO2e/MJ and an EU-27-specific one of 93.1 gCO2eq/MJ. Three scenarios considering increasing levels of CI reduction are then defined, taking into account the current and potential commercial availability of some of the most relevant carbon intensity reduction technologies. The analysis demonstrates that, even if LCAF could offer GHG saving opportunities, their possible impact, especially when compared to the ambition level set in the most recent European legislative proposals, is very limited in most of the analysed scenarios, with the exception of the most ambitious ones. At 2030, a non-zero technical potential is projected only in the higher CI reduction scenario, ranging between 1.8% and 14.2% of LCAF market share in the EU-27 (equal to 0.6 to 4.75 Mtoe), depending on the considered Baseline for CI. At 2050, almost all considered scenarios project a larger technical potential, ranging between 6.9% and 22.2% for the global Baseline (2.21 to 7.13 Mtoe), and between 1.8% and 16.2% for the EU-27 Baseline (0.58 to 5.2 Mtoe). LCAF additional costs to current production costs are also discussed, given their relevance in large-scale deployment of these technologies, and are projected to range between 39 and 46.8 USD/toe.

Immaterial Cost and Production: Maximum Production Cost Level Through Marginal Approach

2020 ◽  
Vol 8 (2) ◽  
pp. 128-149
Author(s):  
Dini Maulana Lestari
Keyword(s):  
Quantitative Study ◽  
Marginal Cost ◽  
Production Cost ◽  
Maximum Level ◽  
Production Costs ◽  
Total Production ◽  
Sugar Factory ◽  
Maximum Production ◽  
Cost Approach ◽  
South Sulawesi

This paper will discuss about the immaterial costs and production yields at one of the refined sugar factory companies in Makassar, South Sulawesi. The theory is based on the fact that Immaterial is a cost that is almsgiving, meaning costs that are outside of the basic costs of the company in producing production, so this research aims to find out: (1) what is the production cost needed to produce this production, (2) the maximum level of production at company from 2013 to 2017. This type of research is a quantitative study because it uses a questionnaire in the form of values ​​that are processed using the marginal cost approach formula. The results of the analysis show that (1) the maximum level of production costs occurred in 2016 amounting to 6,912 with an Immaterial cost of Rp. 2,481,796,800 and the total production produced is 359,077.3 tons (2) The required workforce with the total production produced is 359,077.3 tones of 180 people including the maximum production point which means that the lowest value is achieved (optimal).    

Sign in / Sign up

Export Citation Format

Share Document