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Hydrogen production through electrolysis using renewable electricity is considered a major pathway and component for a sustainable energy system of the future. For this production pathway, a high renewable energy potential, especially in solar energy, is crucial. Countries like Germany with a high energy demand and low solar potential strongly depend on hydrogen import. In the present work, a case study with two alternative hydrogen supply options is conducted to evaluate the economic viability of solar hydrogen delivered to a hydrogen pipeline in Stuttgart, Germany. For both options, hydrogen is generated through an 8 MW alkaline electrolyser, solar powered and supported by grid-based electricity to meet the required load. The first option is based on a hydrogen production system that is positioned in Sines, Portugal, an area with high global radiation and proximity to a deep sea port. The hydrogen is processed by liquefaction and transported to Stuttgart by tanker ship via Hamburg and by truck. The second supply option uses an on-site hydrogen production system in Stuttgart. The work shows that the production costs in Sines with 2.09 €/kgH 2 (prices in € 2021) are, as expected, significantly lower than in Stuttgart with 3.24 €/kgH 2. However, this price difference of 1.15 €/kgH 2 for hydrogen production drops to a marginal difference of 0.13 €/kgH 2 when considering the whole value chain to the delivery point in Stuttgart. If the waste heat from electrolysis is used in a district heating system in Stuttgart, the price difference is down to 0.03 €/kgH 2. The first supply option is dominated by costs for processing, especially liquefaction. These costs would need to be reduced to fully exploit the cost advantage of solar hydrogen production in Portugal. Also, a fundamental switch to pipeline transport of gaseous hydrogen should be considered. Both investigated hydrogen supply options show the potential to provide the pipeline in Stuttgart with hydrogen at lower costs than by using the alternative technology of steam reforming of natural gas. • Techno-economic comparison of two hydrogen supply options for Germany • Solar hydrogen production in Portugal significantly cheaper than in Germany • Liquefaction has a remarkable impact on costs and efficiency of supply chain • Potential in both options to provide cheaper hydrogen than by steam reforming • Hydrogen import costs transferable to other inland regions in northern Europe [ABSTRACT FROM AUTHOR]

The Clean Energy for all Europeans Package by the EU aims, among other things, to enable collective self-consumption for various forms of energy. This step towards more prosumer-based and decentralized energy systems comes at a time when energy planning at a neighborhood scale is on the rise in many countries. It is widely assumed that—from a prosumer's cost-perspective—shared conversion and storage technologies supplying more than a single building can be advantageous. However, it is not clear whether this is the case generally or only under certain conditions. By analyzing idealized building clusters at different degrees of urbanization (DOU), a linear-optimization approach is used to study the cost difference between shared energy infrastructure (smart energy neighborhoods, SENs) and individually planned buildings. This procedure is carried out for various emission reduction targets. The results show, that with higher emission reduction targets the advantage of SENs increases within rural environments and can reach up to 16%. Nevertheless, there are constellations in which the share of energetic infrastructure among buildings does not lead to any economic advantages. For example, in the case of building clusters with less than four buildings, almost no cost advantage is found. The result of this study underlines the importance of energy system planning within the process of urban planning. [ABSTRACT FROM AUTHOR]

• Model-based analysis of the impact of PV field design on energy yield and LCOE. • Three examined system designs: fixed tilt, azimuth tracking, elevation tracking. • Analyses conducted for eight European sites. • Evaluation of soil brightening measures to increase energy yield and reduce LCOE. • Validation of the simulation model using the BIFOROT test facility in Zurich. In the design phase of the photovoltaic field for a bifacial photovoltaic power plant (B-PV), the influence of installation parameters on both the energetic and economic performance must be considered, which makes determining the cost-optimal field design a challenge. Although some studies have dealt with this topic, many questions remain unanswered. Therefore, this work investigated the site-dependent impact of the installation parameters row spacing, module elevation, tilt angle and soil reflectivity of a fixed-tilt and a single-axis tracked B-PV with an east–west and north south-axis on the energy yield, the levelized cost of electricity (LCOE) and the bifacial gain. Based on the results, the magnitude of the influence of an installation parameter on the energy yield and LCOE could be quantified for all three system designs. However, three findings are particularly noteworthy: 1. in the case of the fixed-tilt design, the relative energy yield gain caused by a larger row spacing increases with increasing latitude; 2. depending on PV field's configuration, soil brightening measures can significantly increase the energy yield of all three system designs, practically independent of location, and at the same time reduce the LCOE; 3. the choice of a too high module elevation can lead to small yield losses. Finally, the simulation model used was validated with the Swiss BIFOROT test array. In summary, it can be said that the complex interactions of installation parameters must be thoroughly investigated in order to avoid energy yield losses and unnecessarily high LCOE. [ABSTRACT FROM AUTHOR]

Up to the latest versions of the German renewable energy act (EEG), there had been a constant growth of new biogas plants (BGPs). After reaching a stagnation in the last years, today the focus has shifted to improving the existing BGPs. Assuming that most plants have not reached the technical end of life, the question arises on how an operation can be realized beyond the initial EEG support period of 20 years. In addition, new legal and economic conditions require the implementation of adjustments, that is, "repowering measures." Based on a method review, a plant‐specific model approach is presented to assess repowering measures for a wide range of BGPs differing in capacity, substrate mixture and agricultural structures. The techno‐economic model includes different performance indicators like levelized cost of electricity (LCOE) and temporal aspects like technical progress. Using a data set for BGPs in the state of Baden‐Wuerttemberg (Germany), results are illustrated for the different model modules and three repowering scenarios of an extended operation period of ten years. The scenarios regard different options to meet the requirements of the current EEG, namely the flexibilization and restrictions on energy crops, in comparison with a reference case. While in repowering scenarios, the number of plants decreases between 54% and 69% and the overall power capacity changes between −48% and 13% until 2035. The results further show a reduction potential in the specific area demand and GHG emission up to 12% and 24%, respectively. Technical progress, additional revenues and capacity premiums are shown to be an important factor for efficient substrate utilization, low LCOE and thereby the enabling of an extended operation period. The scenario results indicate that the agricultural areas for energy crop cultivation and the amount of manure used in BGPs will be reduced considerably, inducing new chances and challenges in the future. Due to constantly changing framework conditions, existing biogas plants in Germany are required to conduct repowering measures to continue the operation. Using a plant‐specific model approach, the impact of these repowering measures has been assessed for a wide range of plants in the state of Baden‐Württemberg. Different scenarios show that repowering can improve efficiency and reduce specific GHG emissions. Yet, under current framework conditions, the number of biogas plants is strongly decreasing. Changes in the public support system are needed if more plants should be enabled to continue their operation. [ABSTRACT FROM AUTHOR]

Three landfill gas (LFG) valorization technologies were compared using energy and exergy efficiency and a streamlined Life-Cycle Assessment (LCA) method. The technologies were (i) steam reforming and hydrogen utilization in an in situ cogeneration fuel cell (SR-IS-FCC), (ii) biogas utilization in an in situ gas engine cogeneration plant (IS-GEC), and (iii) amine scrubbing and biomethane utilization in an ex situ gas engine cogeneration plant (AS-ES-GEC). The SR-IS-FCC alternative recorded the highest exergy efficiency and savings in cumulative energy demand (CED), and the lowest global warming potential (GWP) when all the heat is utilized in situ; otherwise, the highest exergy efficiency and the lowest GWP and CED were associated with the AS-ES-GEC alternative. The results indicate that AS-ES-GEC is the preferential choice when heat cannot be utilized in situ. Otherwise, SR-IS-FCC records the best values for the three criteria, and the AS-ES-GEC technology is the least interesting alternative. [ABSTRACT FROM AUTHOR]

Different forms of flexibility can help in balancing variable generation. This work focuses on industrial demand-side flexibility applied in copper production, which is expected to grow for the build-out of green technologies. This study assesses the potential of capacity-based energy demand flexibility (over-sizing production processes) in an industry embedded in fully renewable energy systems. For this, an optimization model for multi-vector energy systems planning is extended so that it also includes the sizing and operation of a production process. A case study is presented for copper production, with greenfield results until 2050. Results show that flexibility at the concentration and refining stages belongs to the cost-optimal system design, at least over the next decade. At current costs, the potential cost savings in the energy system for the production process through capacity-based demand flexibility range from 5 % to 12 %, depending on the technology scenario. These potential savings are expected to decrease over time if cost reductions of renewable energy supply and storage technologies materialize. Technology scenarios considering seawater pumped-hydro energy storage yield lower costs over the entire projected period. • Endogenous integration of industrial process in optimal energy system planning. • Demand flexibility in copper industry beneficial in rapid energy transition. • Cost savings between 5 and 12 % for current costs of energy technologies. [ABSTRACT FROM AUTHOR]

Abstract: An increasing number of rural municipalities wants to meet their entire energy demand with biomass. This article gives a system analytic view on these “bioenergy villages” by balancing pros (reduction of CO2 emissions) and cons (increasing costs, land use) using the example of a model municipality in Germany. The results indicate that a 100% energy supply based on biomass from within the boundaries of a rural municipality is technically possible but less reasonable with respect to land use competition and costs of energy supply. Whereas heat and power demand in bioenergy villages can be covered with relatively little land use and to relatively low costs, the production of transport fuel based on energy crops (rape seed) leads to significant negative impacts. For a cost-efficient decarbonization of rural areas it can therefore be recommended to particularly expand the utilization of biomass for heat and power production and to reconsider the transport fuel production. [Copyright &y& Elsevier]

Abstract: In this study an environmental and economic assessment of the trade of fuel ethanol (EtOH) from Brazil (sugarcane), United States (corn) and France (wheat and sugar beet) has been performed. The fuel is supposed to be consumed in Germany. The focus of the work lies on the transportation of fuel ethanol. The anhydrous ethanol from Brazil requires 3.48GJm−3 of fossil energy input for its production and transport to Cologne, whereas the USA supply from corn delivered to the same location would consume 17.1GJm−3 and the wheat and sugar beet derived ethanol from France would consume 10.6GJm−3. The energy ratio (renewable energy output/fossil energy input) resulted in 7.3 for Brazilian, 1.24 for the USA and 1.99 for French ethanol including production and transport to Cologne. The carbon dioxide equivalent emissions is 491kgm−3 of sugarcane ethanol from Brazil, 1,243kgm−3 of corn ethanol from USA and 729kgm−3 of sugar beet and 744kgm−3 of wheat ethanol from France. The final cost of ethanol from Brazil in Cologne was 510€m−3 at 2006 prices, while ethanol from the US is available for a cost of 636€m−3. The costs of wheat and sugar beet ethanol from France are 568€m−3 and 595€m−3 respectively (2006 prices). The results show that the transport to Germany has only a limited impact on total fossil energy consumption, GHG emissions and costs. [Copyright &y& Elsevier]

The residential sector is facing challenges to reduce greenhouse gas (GHG) emissions, since its heat supply is largely based on fossil fuels. One way to accelerate the reduction process is seen in expanding energy planning from single buildings to groups of buildings, forming smart neighborhoods. This study presents a heat and power system optimization for a group of ten residential buildings located in a rural settlement in Germany. Thereby, a simulation platform is interlinked with an optimization model. Demand profiles, solar potentials and options of thermal refurbishment from the simulation platform serve as input data for the optimization model that considers numerous investment options for energy storage units and demand coverage. If costs of GHG emissions are considered in the optimization, a reduction of these emissions by about 60% compared to the status quo is cost-optimal. With regard to heat supply, the cost optimum is identified in the combination of decreasing heat demand through thermal refurbishments and covering the remaining demand mainly by heat from a combined heat and power (CHP) plant in addition with a wood-fired heating system. Therefore, the model results suggest to connect seven of the ten buildings via a local heating network. The demand for electricity is partly covered by the CHP plant, partly covered by solar generated electricity and partly covered by grid consumption. [ABSTRACT FROM AUTHOR]

A highly integrated process for the conversion of biogenic residues in combination with electricity from renewable sources to methane‐based fuels was developed. Forest residues, straw and sewage sludge were identified as particularly relevant input feedstock. By combining gasification, high‐temperature electrolysis and catalytic methanation, the biogenic carbon remains almost completely in the products. The matching temperature levels of the heat streams result in a very efficient process. The production costs are comparable to less resource‐saving technologies and predictably lower than those of biomethane when plant capacities are increased. [ABSTRACT FROM AUTHOR]

• Holistic yield simulation of a bifacial PV power plant in San Felipe, Chile. • Sensitivity analysis of ground reflectivity's impact on energy yield. • Analysis of ground shadows' impact on the energy yield. • Calculation of ground-reflected irradiance (GRI) using 3D view factors. • Decomposition of absorbed irradiation into eight contributions. Bifacial photovoltaics (bifacial PV) offer higher energy yields as compared to monofacial PV. The development of appropriate models for simulating the energy yield of bifacial PV power plants is a major topic in both research and industry. In particular, the adequate calculation of the energy yield from ground-reflected irradiance (GRI) is challenging. The purpose of this work is to investigate the currently available energy yield models and suggest areas for improvement. A new model with the proposed enhancements is used to investigate the behaviour of bifacial PV power plants in more detail. The model calculates the absorbed irradiation originating from eight irradiance contributions for the front and rear of each cell string: DNI, DHI, GRI from DHI (GRI DHI) and GRI from DNI (GRI DNI). The model was tested using a defined case study power plant. The breakdown of absorbed irradiation (subscript "ab") into its contributions revealed that while in summer months GRI DNI-ab-rear is significantly larger than GRI DHI-ab-rear , both are roughly the same in winter months. Furthermore, for the calculation of GRI the common simplification of infinitely long module rows was avoided by implementing an algorithm for the view factor calculation for a three-dimensional space. This procedure allowed for the assessment of impact of the ground size on the annual energy yield. In a sensitivity analysis, it has been shown that the extension of the relevant ground area resulted in an asymptotical increase of the energy yield. Additionally, the impact of ground shadows on the power plant's performance was quantified. The presence of ground shadows reduced the annual electricity generation by almost 4%, compared to a hypothetical scenario where no ground shadows existed. Finally, five different ground surfaces and the resulting bifacial gains were analysed. The results show that while dry asphalt (12% reflectivity) gave less than 6% of bifacial gain related to generated electricity (BG el), the use of a white membrane (70%) would result in 29% of BG el. [ABSTRACT FROM AUTHOR]

Up-scaling in power plant size and new innovative concepts in the solar field design are among the most promising ways to reduce the costs of future concentrated solar tower power plants. Besides the economic benefits, the knowledge about the ecological impacts of new concepts is of increased interest in view of the climate targets set. This paper aims to assess the ecological impacts of two autonomous operated heliostat concepts within a future solar tower power plant. Both concepts include a photovoltaic (PV) energy supply for the heliostats, combined with either an LiFPO 4 or an LiNMC battery system. Both are compared with a conventional energy supply system. The analysis for comparing the different heliostat concepts is embedded in a life-cycle assessment (LCA) of a 440 MW solar tower plant with a 12,166 MWh th molten salt thermal storage. For the solar tower power plant and the autonomous operated heliostat concepts new LCA inventories were developed. The environmental impacts assessed include the Global Warming Potential (GWP), which is found between 15 and 105 gCO 2eq /kWh el , for the entire solar plant depending on the share of fossil fuel co-firing. Indirect life cycle emissions excluding fossil fuel co-firing and thus associated with the life-cycle of the power plant components show, that the conventional solar field is the main contributor to GWP with 9.5 gCO 2eq /kWh el . Results for both autonomous concepts demonstrate, that reductions in the impact on climate change are at about 10% compared to the solar field with conventional heliostats. Thus it is demonstrated, that heliostat concepts with an autonomous renewable energy supply lead to considerable reductions in life cycle emissions. [ABSTRACT FROM AUTHOR]

Solar energy technologies are a promising option to lower the greenhouse gas emissions of energy generation. Using solar technologies in energy-intensive industries located in arid climate zones is an attractive alternative for that purpose. In this work, the environmental benefit of integrating solar energy in the Chilean copper industry is explored in respect of global warming potential (GWP). A new life cycle assessment model for copper cathodes production in Chile and the integration of three solar technologies was developed. The GWP of the production of copper cathodes was calculated considering local representative conditions for climate, energy mix, and energy demand of the industry. It was computed at 6.0 tCO 2eq /t Cu 2 for a pyrometallurgical process (P-Cu) and 4.9 tCO 2eq /t Cu for a hydrometallurgical process (H-Cu). Further contributions of this paper are the consideration of the decline in ore grade (i.e. copper content in the mineral) and the interconnection of Chile's two main power grids as sensitivities to the baseline. The interconnection of the power grids causes a GWP-reduction of 22% for P-Cu and 37% for H-Cu. In parallel, the expected lower ore grade by 2020 would increase the GWP of copper production by 10% for P-Cu and 4% for H-Cu. If the electricity that is currently taken from the grid is exclusively fed by solar technologies, the reduction on the GWP of copper production would be up to 63% and 76% for P-Cu and H-Cu processes. These numbers do not represent the upper bound for the reduction on the GWP of copper production that can be achieved with solar technologies because the substitution of on-site fossil fuel combustion with solar energy is another interesting mitigation option, which was not considered in this study. In order to achieve even less carbon-intensive production processes, an improved understanding of the copper's industry energy flows and profiles is needed. This would allow to assess the integration of further solar energy technologies and conceive the future of solar copper mining . [ABSTRACT FROM AUTHOR]

Transport accounts for about one quarter of South Africa's final energy consumption. Most of the energy used is based on fossil fuels causing significant environmental burdens. This threat becomes even more dominant as a significant growth in transport demand is forecasted, especially in South Africa's economic hub, Gauteng province. The South African government has realized the potential of biofuel usage for reducing oil import dependency and greenhouse gas ( GHG) and has hence developed a National Biofuels Industrial Strategy to enforce their use. However, there is limited experience in the country in commercial biofuel production and some of the proposed crops (i.e. rapeseed and sugar beet) have not been yet cultivated on a larger scale. Furthermore, there is only limited research available, looking at the feasibility of commercial scale biofuel production or abatement costs of GHG emissions. To assess the opportunities of biofuel production in South Africa, the production costs and consumer price levels of the fuels recommended by the national strategy are analysed in this article. Moreover, the lifecycle GHG emissions and mitigation costs are calculated compared to the calculated fossil fuel reference including coal to liquid ( CTL) and gas to liquid ( GTL) fuels. The results show that the cost for biofuel production in South Africa are currently significantly higher (between 30% and 80%) than for the reference fossil fuels. The lifecycle GHG emissions of biofuels (especially for sugar cane) are considerably lower (up to 45%) than the reference fossil GHG emissions. The resulting GHG abatement costs are between 1000 and 2500 ZAR2007 per saved ton of carbon dioxide equivalent, which is high compared to the current European CO2 market prices of ca. 143 ZAR2007 t−1. The analysis has shown that biofuel production and utilization in South Africa offers a significant GHG-mitigation potential but at relatively high cost. [ABSTRACT FROM AUTHOR]

Abstract: To achieve consensus on the broad term sustainability abstractness is required. In turn, to take sustainability as an action guiding mandate for implementation it needs to be concrete. The paper seeks to bridge the gap from theory of sustainability to practical application by implementing four different methods, i.e. social cost analysis, ecological footprint analysis, exergy approach and multi criteria decision analysis (MCDA). These methods will be exemplarily applied for sustainability analysis of household heating technologies focusing on wood pellet boilers, wood chip fired district heating stations and natural gas fired condensing boilers. Based on the integrated assessment of exemplary heat supply technologies a critical outlook on the four projective approaches is given. [Copyright &y& Elsevier]

• New method for water and energy systems planning. • First endogenous integration of coupled desalination and pumped hydro in planning models. • First design of integrated multi-vector systems for copper production. • Renewable-based desalinated water and energy supply economically attractive today. • Renewable-based is the least-cost alternative by 2030. Copper is required for the transformation of global energy systems, and its production is intensive in water and energy. Several studies have investigated the design of renewable energy systems for copper production, aiming at reducing its environmental footprint. Here, we present the first integrated design for desalinated water and energy supply that considers all forms of energy required in the copper production process. For this, we develop an optimization model for planning integrated multi-vector energy and water systems. The model includes -for the first time in an energy system planning model- a concept for integrated pumped-hydro storage using sweater and reverse osmosis desalination. Our results show that water-energy systems for copper production based exclusively on renewables can today achieve costs as low as those of conventional fossil-based systems, when integrating multi-vector planning and seawater pumped-hydro storage. For a case study in Chile and in fully renewable scenarios, the specific cost of supplying energy and desalinated water decreases from 520–670 € per ton of copper at current costs to 330–360 by 2050. By 2030, using seawater pumped-hydro storage makes a fully renewable, multi-energy scenario the least-cost alternative. Such an integrated system is an enabler for reducing the environmental footprint that copper brings into the global energy transition. [ABSTRACT FROM AUTHOR]

• Energy yield simulation of vertical bifacial PV array in 12 European locations. • Comparison with a conventional PV array (monofacial, equator-oriented, tilted). • Evaluation of market revenues based on historic day-ahead market prices. • Evaluation of LCOE and net present value. • Evaluation of system cost reduction from a macroeconomic perspective for Germany. Thanks to the two diurnal generation peaks, vertical bifacial photovoltaic power plants (VBPV) with a north-south axis represent an option to meet the challenges of a mismatch between electricity demand and the generation profile of conventional photovoltaic systems (C-PV). Despite this promising characteristic, it is hardly possible to assess the technical and economic properties of VBPV on the basis of existing studies. The present work is a contribution to close this gap. Among other things, the conducted analyses included electricity generation, market revenues, levelized costs of electricity (LCOE) and the cost-reducing effect of VBPV in a national electricity system. C-PV was used as a benchmark in all analyses. Electricity generation was simulated at twelve European sites in four countries. It has been found that above a latitude of 50° VBPV generates more electricity than C-PV. Due to the higher investments, VBPV had higher LCOE at all locations investigated. The results also showed that VBPV can generate higher revenues in electricity markets with a high share of C-PV capacity, but that these additional revenues are not yet sufficient to compensate for the higher investments. With an optimising electricity market model, it was also found that VBPV can contribute to reducing system costs in an electricity system with high shares of C-PV capacity. Against the background of the increasing importance of PV for the electricity supply of most European countries, these findings are of particular importance. In summary, it can be said that VBPV has significant potential at both the business and macro-economic level and that decision makers should promote the market entry of this technology. [ABSTRACT FROM AUTHOR]

Scenario analysis combined with system and market modelling is a well-established method to evaluate technological and societal developments and their impacts on future energy pathways. This paper presents a process-oriented method for developing consistent energy scenarios using multiple energy system models. Its added value is that the developed energy scenarios are consistent in a multi-model environment and practicable for a broader target group from scientists to practitioners. The scenarios consist of comprehensive storylines and systematically defined quantitative parameters. Following a step-by-step process, a condensed set of overlapping descriptors is generated and used to define the scenarios in a consistent parameter matrix. The set of descriptors allow consistent and comparable outputs independent of model-specific characteristics. The corresponding quantitative parameters can be used by diverse energy system tools. Using multiple models, a team of researchers can explore questions from differing points of view. In an example study, we apply the method to develop scenarios in the context of a cellular energy system. This approach enables the development of scenarios that provide a consistent basis for both stakeholder discourse and multi-model system analysis. [ABSTRACT FROM AUTHOR]

Renewable energy systems are now accepted to be mandatory for climate change mitigation. These systems require a higher material supply than conventional ones. Particularly, they require more copper. The production of this metal, however, is intensive in energy consumption and emissions. Therefore, renewable energy systems must be used to improve the environmental performance of copper production. We cover the current state of research and develop recommendations for the design of renewable energy systems for copper production. To complement our analysis, we also consider studies from other industries and regional energy systems. We provide six recommendations for future modeling: (a) current energy demand models for copper production are overly simplistic and need to be enhanced for planning with high levels of renewable technologies; (b) multi-vector systems (electricity, heat, and fuels) need to be explicitly modeled to capture the readily available flexibility of the system; (c) copper production is done in arid regions, where water supply is energy-intensive, then, water management should be integrated in the overall design of the energy system; (d) there is operational flexibility in existing copper plants, which needs to be better understood and assessed; (e) the design of future copper mines should adapt to the dynamics of available renewable energy sources; and (f) life cycle impacts of the components of the system need to be explicitly minimized in the optimization models. Researchers and decision-makers from the copper and energy sector will benefit from this comprehensive review and these recommendations. We hope it will accelerate the deployment of renewables, particularly in the copper industry. • Copper is required to build energy systems of the future. • Smart integration of renewables can lower the cost of cleaner copper production. • We provide six recommendations to model these systems. • Further efforts are required in the modeling of energy demand and flexibility. • Following these recommendations will enable cleaner and cheaper designs. [ABSTRACT FROM AUTHOR]

Upgrading consists of a range of purification processes aimed at increasing the methane content of biogas to reach specifications similar to natural gas. In this perspective, an environmental assessment, based on the Life Cycle Assessment (LCA) method, of different upgrading technologies is helpful to identify the environmental characteristics of biomethane and the critical steps for improvement. The aim of this work is to conduct an LCA of biomethane production from waste feedstock, using the SimaPro software. The study focuses on the comparison of several upgrading technologies (namely, membrane separation, cryogenic separation, pressure swing adsorption, chemical scrubbing, high pressure water scrubbing) and the on-site cogeneration of electricity and heat, including the environmental benefits deriving from the substitution of fossil-based products. The results show a better environmental performance of the cogeneration option in most of the impact categories. The Fossil resource scarcity is the impact category which is mainly benefited by the avoided production of natural gas, with savings of about 0.5 kg oil eq/m3 of biogas for all the investigated technologies, with an average improvement of about 76% compared to conventional cogeneration. The results show that the membrane upgrading technology is slightly more environmentally convenient than the other upgrading technologies. [ABSTRACT FROM AUTHOR]