TECHNICAL PROGRAMME | Primary Energy Supply – Future Pathways
The Role of Biofuels as a Feedstock
Forum 6 | Hall 10 - Technical Programme 1
15
October
09:30
11:00
UTC+3
This session delves into the innovative use of biofuels as a feedstock in various industries, emphasising their potential to contribute to sustainable production processes. The session will explore the latest advancements in biofuel technologies, feedstock optimisation, and the role of biofuels in reducing greenhouse gas emissions, with insights into the scientific principles, engineering challenges, and economic considerations involved in the utilisation of biofuels as a versatile feedstock.
Biogas Integration for Sustainable Petroleum Refineries. Biofuels, particularly biogas, are emerging as transformative feedstocks in the pursuit of sustainable industrial processes, offering a renewable alternative to fossil fuels. This study explores the integration of biogas—a methane-rich fuel derived from bio-methanation of agricultural residues, press-mud, and locally available biomass—into petroleum refineries to enhance energy efficiency and align with global sustainability goals. Traditional refineries consume approximately 10% of crude oil as fuel and losses, relying heavily on non-renewable natural gas (NG), which is not universally available. Biogas, with 40-60% methane content, serves as an eco-friendly, locally sourced substitute, reducing dependence on imported NG. Due to bottom-upgradation technologies such as Delayed Coking Units (DCU), Slurry Hydrocrackers, and Resid Fluid Catalytic Cracking (FCC), coupled with integration with petrochemicals to produce high-value products, biogas can meet the energy demands of refineries and petrochemical operations, acting as a game-changer in resource-constrained regions.
This research proposes a novel framework for integrating bio-methanation plants within refineries, leveraging waste heat, wastewater, and refinery byproducts to optimize energy use and eliminate biogas storage and transportation costs. Hydrogen required for hydroprocessing units can be produced through dry reforming, tri-reforming, or bi-reforming of biogas, even without removing CO2, reducing reliance on Hydrogen Generation Units (HGUs) that may operate on naphtha in the absence of NG. Advanced post-processing techniques, such as Pressure Swing Adsorption (PSA) and membrane separation, enhance methane purity for specific applications, while innovative NG/biogas ejector systems streamline operations by eliminating compressor needs. Computational modeling of a 300 m³/h clean biogas plant demonstrates its feasibility for providing a consistent fuel supply for continuous refinery operations, enhancing product yield through bottom-processing technologies.
Economic assessments indicate that, despite initial setup costs, long-term savings from reduced fuel imports, lower HGU dependency, and emissions compliance ensure viability. The study addresses technical challenges, such as temperature-dependent biogas production and impurity management, through optimized process conditions and cutting-edge technologies. Applicable to both new and existing refineries, this scalable solution mitigates environmental impacts while supporting energy transitions.
The framework positions refineries as sustainable energy hubs, reducing carbon footprints and enhancing resource efficiency. Future research directions include advanced modeling for process optimization and scalability across diverse feedstocks, reinforcing the pivotal role of biofuels in transforming petroleum refineries into greener, self-sustaining systems that contribute to global renewable energy adoption and greenhouse gas emission reduction.
This research proposes a novel framework for integrating bio-methanation plants within refineries, leveraging waste heat, wastewater, and refinery byproducts to optimize energy use and eliminate biogas storage and transportation costs. Hydrogen required for hydroprocessing units can be produced through dry reforming, tri-reforming, or bi-reforming of biogas, even without removing CO2, reducing reliance on Hydrogen Generation Units (HGUs) that may operate on naphtha in the absence of NG. Advanced post-processing techniques, such as Pressure Swing Adsorption (PSA) and membrane separation, enhance methane purity for specific applications, while innovative NG/biogas ejector systems streamline operations by eliminating compressor needs. Computational modeling of a 300 m³/h clean biogas plant demonstrates its feasibility for providing a consistent fuel supply for continuous refinery operations, enhancing product yield through bottom-processing technologies.
Economic assessments indicate that, despite initial setup costs, long-term savings from reduced fuel imports, lower HGU dependency, and emissions compliance ensure viability. The study addresses technical challenges, such as temperature-dependent biogas production and impurity management, through optimized process conditions and cutting-edge technologies. Applicable to both new and existing refineries, this scalable solution mitigates environmental impacts while supporting energy transitions.
The framework positions refineries as sustainable energy hubs, reducing carbon footprints and enhancing resource efficiency. Future research directions include advanced modeling for process optimization and scalability across diverse feedstocks, reinforcing the pivotal role of biofuels in transforming petroleum refineries into greener, self-sustaining systems that contribute to global renewable energy adoption and greenhouse gas emission reduction.
In the current linear economy, natural resources are assumed to be plentiful, easily accessible, and reasonably priced. However, this assumption is untenable, given that the world travels beyond its ecological bounds. The circular economy (CE), on the other hand, is a more sustainable alternative to the prevalent linear model since it decreases waste and increases resource efficiency. Waste-based biofuels derived from used cooking oil, animal fats, and industrial food waste offer a sustainable alternative to fossil fuels, reducing waste while contributing to a circular economy. This enhances energy security while lowering greenhouse gas emissions. However, integrating waste-to-biofuel technologies necessitates addressing environmental, technological, and socioeconomic challenges. Globally, governments are starting to realize that petroleum is no longer the best fuel option in terms of pollution, health, and geopolitical harmony. Since petroleum oil is a finite resource, its price will only increase as it becomes more scarce. For example, biodiesel from consumed cooking oil and hydrotreated vegetable oil (HVO) are waste-derived biofuels that offer a low-carbon substitute for traditional petroleum fuels, lowering greenhouse gas emissions and dependency on fossil fuels. Compared to petroleum diesel, biodiesel is non-toxic, renewable, and biodegradable. It also burns cleaner in diesel engines. Biodiesel is less harmful to the environment and is especially better in case of a spill or leak.
Kuwait Petroleum International (KPI) is a part of the BioSFerA project, a large-scale European endeavor to create innovative, high-performing biofuels to lower greenhouse gas emissions in aviation and maritime sectors. The project's goal is to validate an integrated thermochemical-biochemical approach to developing affordable technology for sustainable marine and aviation fuels. KPI contributes to the BioSFerA project by supporting the development of advanced biofuels through innovative gasification and microbial fermentation technologies. This aligns with its commitment to sustainable energy solutions and low-carbon fuel alternatives. Furthermore, the Imdad initiative in Kuwait was the first biodiesel production facility, which will initially be capable of producing 240,000 liters per month. One of the sustainable biofuels the Imdad project provides is pure biodiesel B-100, which can be mixed to create other grades like B-5. Suitable for use in existing equipment, such as boilers, heating equipment, locomotives, marine engines, electricity generation, and all major diesel engine manufacturers, to satisfy local and international standards. Although Imdad's primary product is biodiesel, the process also produces other goods, all of which have applications. Crude glycerin is a by-product of the process of making biodiesel. Foods, medicines, soaps, and other products can all contain glycerin. The Imdad Project in Kuwait faces challenges in converting used cooking oil (UCO) into biodiesel, including feedstock collection logistics, contamination from food residues, and refining compatibility, which can be addressed through structured collection networks, advanced filtration technologies, and refinery co-processing innovations. In addition, cost competitiveness and supply chain development are crucial factors for the advancement of biofuel market.
Kuwait Petroleum International (KPI) is a part of the BioSFerA project, a large-scale European endeavor to create innovative, high-performing biofuels to lower greenhouse gas emissions in aviation and maritime sectors. The project's goal is to validate an integrated thermochemical-biochemical approach to developing affordable technology for sustainable marine and aviation fuels. KPI contributes to the BioSFerA project by supporting the development of advanced biofuels through innovative gasification and microbial fermentation technologies. This aligns with its commitment to sustainable energy solutions and low-carbon fuel alternatives. Furthermore, the Imdad initiative in Kuwait was the first biodiesel production facility, which will initially be capable of producing 240,000 liters per month. One of the sustainable biofuels the Imdad project provides is pure biodiesel B-100, which can be mixed to create other grades like B-5. Suitable for use in existing equipment, such as boilers, heating equipment, locomotives, marine engines, electricity generation, and all major diesel engine manufacturers, to satisfy local and international standards. Although Imdad's primary product is biodiesel, the process also produces other goods, all of which have applications. Crude glycerin is a by-product of the process of making biodiesel. Foods, medicines, soaps, and other products can all contain glycerin. The Imdad Project in Kuwait faces challenges in converting used cooking oil (UCO) into biodiesel, including feedstock collection logistics, contamination from food residues, and refining compatibility, which can be addressed through structured collection networks, advanced filtration technologies, and refinery co-processing innovations. In addition, cost competitiveness and supply chain development are crucial factors for the advancement of biofuel market.
Diesel fuel is among the most important fossil fuels derived from crude oil, which has widespread applications in combustion systems such as diesel engines and industrial burners. The environmental challenges associated with diesel fuel and the limited and decreasing fossil fuel resources highlighted the need for environmentally friendly renewable alternative fuel. In recent years, biodiesel fuel has been introduced as a precursor and alternative to diesel fuel due to its high flash point and cetane number, combustion efficiency and characteristics very close to those of diesel fuel. Consequently, there is an effort among the researchers to improve biodiesel synthesis and production from new feedstocks and use high-performance methods. The aim of the present work is synthesis and production of biodiesel from algae as feedstock and comparison the advantages of using algae as biodiesel feedstock with conventional biodiesel feedstocks. Firstly, unlike other conventional biodiesel feedstocks such as palm oil, the algae are fast-growing (the growth period of algae is about 4 weeks). Secondly, unlike the conventional biodiesel feedstocks such as palm which grow in tropical rainforest such as Southeast Asia, they can grow and reproduce in different waters such as sewage, wastewater and different geographical conditions around the world and finally, unlike conventional oilseed biodiesel feddstocks such as Soybeans, Canola which are agricultural and farm products, algaes are non-competitive for agricultural land and the results shows that using SC-CO2 as new oil extraction method combined with RSM optimization of the parameters can enhance the oil extraction up to 37.9%. Also, it is possible to synthesis a green catalyst from algae to convert the oil into biodiesel using transesterification methods such which gives a biodiesel yield as much as 90%.
The accelerating energy transition in Europe, driven by initiatives such as REPowerEU and the target of achieving 35 bcm of biomethane by 2030, is intensifying the search for suitable locations for new facilities. Increasing attention is being directed towards the repurposing of oil and gas assets as renewable energy sources. In particular, depleted natural gas fields and their associated infrastructure can be transformed into biomethane hubs by leveraging existing pipelines, compressors, and industrial sites. The proposed Gas-to-Biomethane Transformation Index (GBTI) is introduced as a conceptual tool for the early-stage assessment of such assets, designed to evaluate their potential for repurposing for biomethane production.
Repurposing gas fields with residual production could offer asset owners the opportunity to monetize remaining resources, defer decommissioning costs, and preserve the value of infrastructure. For biomethane investors, it could provide access to grid connections, land, and facilities that reduce capital expenditure and accelerate project timelines. At the same time, these projects could meaningfully support climate objectives by increasing biomethane supply and demonstrate a pragmatic “brownfield-to-green energy” pathway.
The GBTI framework structures feasibility assessment across four key dimensions: technical, infrastructural, legal-regulatory, and environmental-social. It identifies clear strengths – such as existing grid access or favorable permitting regimes – while highlighting potential risks like small site size, equipment condition, or complex permitting procedures. At this stage, the Gas-to-Biomethane Index remains at the level of a conceptual framework, but it illustrates how systematic and transparent evaluation could guide portfolio reviews, capital allocation, and stakeholder communication in the upstream sector.
Although initially developed in the Polish context, the methodology can be adapted for other regions facing similar challenges in managing late-life oil and gas assets. By embedding infrastructure reuse into corporate strategies, the Index is intended to support decarbonization while generating financial and operational synergies between upstream operators and renewable gas investors. Importantly, it has the potential to enhance ESG transparency by documenting decision-making processes in a structured way, thereby strengthening investor confidence and regulatory alignment.
Repurposing gas fields with residual production could offer asset owners the opportunity to monetize remaining resources, defer decommissioning costs, and preserve the value of infrastructure. For biomethane investors, it could provide access to grid connections, land, and facilities that reduce capital expenditure and accelerate project timelines. At the same time, these projects could meaningfully support climate objectives by increasing biomethane supply and demonstrate a pragmatic “brownfield-to-green energy” pathway.
The GBTI framework structures feasibility assessment across four key dimensions: technical, infrastructural, legal-regulatory, and environmental-social. It identifies clear strengths – such as existing grid access or favorable permitting regimes – while highlighting potential risks like small site size, equipment condition, or complex permitting procedures. At this stage, the Gas-to-Biomethane Index remains at the level of a conceptual framework, but it illustrates how systematic and transparent evaluation could guide portfolio reviews, capital allocation, and stakeholder communication in the upstream sector.
Although initially developed in the Polish context, the methodology can be adapted for other regions facing similar challenges in managing late-life oil and gas assets. By embedding infrastructure reuse into corporate strategies, the Index is intended to support decarbonization while generating financial and operational synergies between upstream operators and renewable gas investors. Importantly, it has the potential to enhance ESG transparency by documenting decision-making processes in a structured way, thereby strengthening investor confidence and regulatory alignment.
In the current linear economy, natural resources are assumed to be plentiful, easily accessible, and reasonably priced. However, this assumption is untenable, given that the world travels beyond its ecological bounds. The circular economy (CE), on the other hand, is a more sustainable alternative to the prevalent linear model since it decreases waste and increases resource efficiency. Waste-based biofuels derived from used cooking oil, animal fats, and industrial food waste offer a sustainable alternative to fossil fuels, reducing waste while contributing to a circular economy. This enhances energy security while lowering greenhouse gas emissions. However, integrating waste-to-biofuel technologies necessitates addressing environmental, technological, and socioeconomic challenges. Globally, governments are starting to realize that petroleum is no longer the best fuel option in terms of pollution, health, and geopolitical harmony. Since petroleum oil is a finite resource, its price will only increase as it becomes more scarce. For example, biodiesel from consumed cooking oil and hydrotreated vegetable oil (HVO) are waste-derived biofuels that offer a low-carbon substitute for traditional petroleum fuels, lowering greenhouse gas emissions and dependency on fossil fuels. Compared to petroleum diesel, biodiesel is non-toxic, renewable, and biodegradable. It also burns cleaner in diesel engines. Biodiesel is less harmful to the environment and is especially better in case of a spill or leak.
Kuwait Petroleum International (KPI) is a part of the BioSFerA project, a large-scale European endeavor to create innovative, high-performing biofuels to lower greenhouse gas emissions in aviation and maritime sectors. The project's goal is to validate an integrated thermochemical-biochemical approach to developing affordable technology for sustainable marine and aviation fuels. KPI contributes to the BioSFerA project by supporting the development of advanced biofuels through innovative gasification and microbial fermentation technologies. This aligns with its commitment to sustainable energy solutions and low-carbon fuel alternatives. Furthermore, the Imdad initiative in Kuwait was the first biodiesel production facility, which will initially be capable of producing 240,000 liters per month. One of the sustainable biofuels the Imdad project provides is pure biodiesel B-100, which can be mixed to create other grades like B-5. Suitable for use in existing equipment, such as boilers, heating equipment, locomotives, marine engines, electricity generation, and all major diesel engine manufacturers, to satisfy local and international standards. Although Imdad's primary product is biodiesel, the process also produces other goods, all of which have applications. Crude glycerin is a by-product of the process of making biodiesel. Foods, medicines, soaps, and other products can all contain glycerin. The Imdad Project in Kuwait faces challenges in converting used cooking oil (UCO) into biodiesel, including feedstock collection logistics, contamination from food residues, and refining compatibility, which can be addressed through structured collection networks, advanced filtration technologies, and refinery co-processing innovations. In addition, cost competitiveness and supply chain development are crucial factors for the advancement of biofuel market.
Kuwait Petroleum International (KPI) is a part of the BioSFerA project, a large-scale European endeavor to create innovative, high-performing biofuels to lower greenhouse gas emissions in aviation and maritime sectors. The project's goal is to validate an integrated thermochemical-biochemical approach to developing affordable technology for sustainable marine and aviation fuels. KPI contributes to the BioSFerA project by supporting the development of advanced biofuels through innovative gasification and microbial fermentation technologies. This aligns with its commitment to sustainable energy solutions and low-carbon fuel alternatives. Furthermore, the Imdad initiative in Kuwait was the first biodiesel production facility, which will initially be capable of producing 240,000 liters per month. One of the sustainable biofuels the Imdad project provides is pure biodiesel B-100, which can be mixed to create other grades like B-5. Suitable for use in existing equipment, such as boilers, heating equipment, locomotives, marine engines, electricity generation, and all major diesel engine manufacturers, to satisfy local and international standards. Although Imdad's primary product is biodiesel, the process also produces other goods, all of which have applications. Crude glycerin is a by-product of the process of making biodiesel. Foods, medicines, soaps, and other products can all contain glycerin. The Imdad Project in Kuwait faces challenges in converting used cooking oil (UCO) into biodiesel, including feedstock collection logistics, contamination from food residues, and refining compatibility, which can be addressed through structured collection networks, advanced filtration technologies, and refinery co-processing innovations. In addition, cost competitiveness and supply chain development are crucial factors for the advancement of biofuel market.
The accelerating energy transition in Europe, driven by initiatives such as REPowerEU and the target of achieving 35 bcm of biomethane by 2030, is intensifying the search for suitable locations for new facilities. Increasing attention is being directed towards the repurposing of oil and gas assets as renewable energy sources. In particular, depleted natural gas fields and their associated infrastructure can be transformed into biomethane hubs by leveraging existing pipelines, compressors, and industrial sites. The proposed Gas-to-Biomethane Transformation Index (GBTI) is introduced as a conceptual tool for the early-stage assessment of such assets, designed to evaluate their potential for repurposing for biomethane production.
Repurposing gas fields with residual production could offer asset owners the opportunity to monetize remaining resources, defer decommissioning costs, and preserve the value of infrastructure. For biomethane investors, it could provide access to grid connections, land, and facilities that reduce capital expenditure and accelerate project timelines. At the same time, these projects could meaningfully support climate objectives by increasing biomethane supply and demonstrate a pragmatic “brownfield-to-green energy” pathway.
The GBTI framework structures feasibility assessment across four key dimensions: technical, infrastructural, legal-regulatory, and environmental-social. It identifies clear strengths – such as existing grid access or favorable permitting regimes – while highlighting potential risks like small site size, equipment condition, or complex permitting procedures. At this stage, the Gas-to-Biomethane Index remains at the level of a conceptual framework, but it illustrates how systematic and transparent evaluation could guide portfolio reviews, capital allocation, and stakeholder communication in the upstream sector.
Although initially developed in the Polish context, the methodology can be adapted for other regions facing similar challenges in managing late-life oil and gas assets. By embedding infrastructure reuse into corporate strategies, the Index is intended to support decarbonization while generating financial and operational synergies between upstream operators and renewable gas investors. Importantly, it has the potential to enhance ESG transparency by documenting decision-making processes in a structured way, thereby strengthening investor confidence and regulatory alignment.
Repurposing gas fields with residual production could offer asset owners the opportunity to monetize remaining resources, defer decommissioning costs, and preserve the value of infrastructure. For biomethane investors, it could provide access to grid connections, land, and facilities that reduce capital expenditure and accelerate project timelines. At the same time, these projects could meaningfully support climate objectives by increasing biomethane supply and demonstrate a pragmatic “brownfield-to-green energy” pathway.
The GBTI framework structures feasibility assessment across four key dimensions: technical, infrastructural, legal-regulatory, and environmental-social. It identifies clear strengths – such as existing grid access or favorable permitting regimes – while highlighting potential risks like small site size, equipment condition, or complex permitting procedures. At this stage, the Gas-to-Biomethane Index remains at the level of a conceptual framework, but it illustrates how systematic and transparent evaluation could guide portfolio reviews, capital allocation, and stakeholder communication in the upstream sector.
Although initially developed in the Polish context, the methodology can be adapted for other regions facing similar challenges in managing late-life oil and gas assets. By embedding infrastructure reuse into corporate strategies, the Index is intended to support decarbonization while generating financial and operational synergies between upstream operators and renewable gas investors. Importantly, it has the potential to enhance ESG transparency by documenting decision-making processes in a structured way, thereby strengthening investor confidence and regulatory alignment.
Biogas Integration for Sustainable Petroleum Refineries. Biofuels, particularly biogas, are emerging as transformative feedstocks in the pursuit of sustainable industrial processes, offering a renewable alternative to fossil fuels. This study explores the integration of biogas—a methane-rich fuel derived from bio-methanation of agricultural residues, press-mud, and locally available biomass—into petroleum refineries to enhance energy efficiency and align with global sustainability goals. Traditional refineries consume approximately 10% of crude oil as fuel and losses, relying heavily on non-renewable natural gas (NG), which is not universally available. Biogas, with 40-60% methane content, serves as an eco-friendly, locally sourced substitute, reducing dependence on imported NG. Due to bottom-upgradation technologies such as Delayed Coking Units (DCU), Slurry Hydrocrackers, and Resid Fluid Catalytic Cracking (FCC), coupled with integration with petrochemicals to produce high-value products, biogas can meet the energy demands of refineries and petrochemical operations, acting as a game-changer in resource-constrained regions.
This research proposes a novel framework for integrating bio-methanation plants within refineries, leveraging waste heat, wastewater, and refinery byproducts to optimize energy use and eliminate biogas storage and transportation costs. Hydrogen required for hydroprocessing units can be produced through dry reforming, tri-reforming, or bi-reforming of biogas, even without removing CO2, reducing reliance on Hydrogen Generation Units (HGUs) that may operate on naphtha in the absence of NG. Advanced post-processing techniques, such as Pressure Swing Adsorption (PSA) and membrane separation, enhance methane purity for specific applications, while innovative NG/biogas ejector systems streamline operations by eliminating compressor needs. Computational modeling of a 300 m³/h clean biogas plant demonstrates its feasibility for providing a consistent fuel supply for continuous refinery operations, enhancing product yield through bottom-processing technologies.
Economic assessments indicate that, despite initial setup costs, long-term savings from reduced fuel imports, lower HGU dependency, and emissions compliance ensure viability. The study addresses technical challenges, such as temperature-dependent biogas production and impurity management, through optimized process conditions and cutting-edge technologies. Applicable to both new and existing refineries, this scalable solution mitigates environmental impacts while supporting energy transitions.
The framework positions refineries as sustainable energy hubs, reducing carbon footprints and enhancing resource efficiency. Future research directions include advanced modeling for process optimization and scalability across diverse feedstocks, reinforcing the pivotal role of biofuels in transforming petroleum refineries into greener, self-sustaining systems that contribute to global renewable energy adoption and greenhouse gas emission reduction.
This research proposes a novel framework for integrating bio-methanation plants within refineries, leveraging waste heat, wastewater, and refinery byproducts to optimize energy use and eliminate biogas storage and transportation costs. Hydrogen required for hydroprocessing units can be produced through dry reforming, tri-reforming, or bi-reforming of biogas, even without removing CO2, reducing reliance on Hydrogen Generation Units (HGUs) that may operate on naphtha in the absence of NG. Advanced post-processing techniques, such as Pressure Swing Adsorption (PSA) and membrane separation, enhance methane purity for specific applications, while innovative NG/biogas ejector systems streamline operations by eliminating compressor needs. Computational modeling of a 300 m³/h clean biogas plant demonstrates its feasibility for providing a consistent fuel supply for continuous refinery operations, enhancing product yield through bottom-processing technologies.
Economic assessments indicate that, despite initial setup costs, long-term savings from reduced fuel imports, lower HGU dependency, and emissions compliance ensure viability. The study addresses technical challenges, such as temperature-dependent biogas production and impurity management, through optimized process conditions and cutting-edge technologies. Applicable to both new and existing refineries, this scalable solution mitigates environmental impacts while supporting energy transitions.
The framework positions refineries as sustainable energy hubs, reducing carbon footprints and enhancing resource efficiency. Future research directions include advanced modeling for process optimization and scalability across diverse feedstocks, reinforcing the pivotal role of biofuels in transforming petroleum refineries into greener, self-sustaining systems that contribute to global renewable energy adoption and greenhouse gas emission reduction.
Seyyed Hadi Pourhoseini Hesari
Speaker
Faculty Member (Associate Professor of Mechanical Engineering)
University of Gonabad
Iran
Diesel fuel is among the most important fossil fuels derived from crude oil, which has widespread applications in combustion systems such as diesel engines and industrial burners. The environmental challenges associated with diesel fuel and the limited and decreasing fossil fuel resources highlighted the need for environmentally friendly renewable alternative fuel. In recent years, biodiesel fuel has been introduced as a precursor and alternative to diesel fuel due to its high flash point and cetane number, combustion efficiency and characteristics very close to those of diesel fuel. Consequently, there is an effort among the researchers to improve biodiesel synthesis and production from new feedstocks and use high-performance methods. The aim of the present work is synthesis and production of biodiesel from algae as feedstock and comparison the advantages of using algae as biodiesel feedstock with conventional biodiesel feedstocks. Firstly, unlike other conventional biodiesel feedstocks such as palm oil, the algae are fast-growing (the growth period of algae is about 4 weeks). Secondly, unlike the conventional biodiesel feedstocks such as palm which grow in tropical rainforest such as Southeast Asia, they can grow and reproduce in different waters such as sewage, wastewater and different geographical conditions around the world and finally, unlike conventional oilseed biodiesel feddstocks such as Soybeans, Canola which are agricultural and farm products, algaes are non-competitive for agricultural land and the results shows that using SC-CO2 as new oil extraction method combined with RSM optimization of the parameters can enhance the oil extraction up to 37.9%. Also, it is possible to synthesis a green catalyst from algae to convert the oil into biodiesel using transesterification methods such which gives a biodiesel yield as much as 90%.
