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The emergence of algal biorefineries has garnered considerable attention to researchers owing to their potential to ensure carbon neutrality via mitigation of atmospheric greenhouse gases. Algae-derived biofuels, characterized by their carbon-neutral nature, stand poised to play a pivotal role in advancing sustainable development initiatives aimed at enhancing environmental and societal well-being. In this context, algae-based wastewater treatment systems are greatly appreciated for their efficacy in nutrient removal and simultaneous bioenergy generation. These systems leverage the growth of algae species on wastewater nutrients—including carbon, nitrogen, and phosphorus—alongside carbon dioxide, thus facilitating a multifaceted approach to pollution remediation. This review seeks to delve into the realization of carbon neutrality through algae-mediated wastewater treatment approaches. Through a comprehensive analysis, this review scrutinizes the trajectory of algae-based wastewater treatment via bibliometric analysis. It subsequently examines the case studies and empirical insights pertaining to algae cultivation, treatment performance analysis, cost and life cycle analyses, and the implementation of optimization methodologies rooted in artificial intelligence and machine learning algorithms for algae-based wastewater treatment systems. By synthesizing these diverse perspectives, this study aims to offer valuable insights for the development of future engineering applications predicated on an in-depth understanding of carbon neutrality within the framework of circular economy paradigms. • Utilization of algae in wastewater treatment helps in acheiving carbon neutrality. • Research trend of algal wastewater treatment is analyzed via bibliometric analysis. • Chlorella vulgaris is the most investigated species in wastewater treatment system. • Binary culture approach has shown significant benefits over conventional systems. • AI and ML integration in algal system has potential benefits in carbon neutrality. [ABSTRACT FROM AUTHOR]

This research assesses the transition of a fossil fuel-based electricity production jurisdiction to a renewable-based electricity jurisdiction through an extensive scenario analysis. This fills a knowledge gap where a wide-range of fossil-to-renewable electricity generation pathways is compared within a single analysis framework. To conduct this study, a novel data-intensive electricity system model was developed with the Long-range Energy Alternatives Planning system and applied to evaluate alternative electricity generation mix scenarios to the year 2050. A case study for Alberta, a fossil fuels-based province in Canada, was conducted. A total of 382 scenarios were analyzed considering different renewable pathways and varying key uncertain future conditions. The greenhouse gas emission abatement and marginal greenhouse gas abatement costs of each scenario were evaluated and compared. Several renewable-based scenarios resulted in significant greenhouse gas abatement at lower costs than the fossil-fuel based business-as-usual scenario. The maximum greenhouse gas abatement possible at a net cost reduction compared to the business-as-usual scenario was found through a specific combination of wind, hydro, and solar power which resulted in over a 90% reduction from 2005 emission levels at −$1.8/t of carbon dioxide equivalent abated. The results of this study provide policy insight for jurisdictions transitioning away from fossil fuel-based electricity to renewables. • A new Long-range Energy Alternatives model is developed and applied. • Extensive analysis of energy transition for a fossil-fuel electricity sector. • 382 scenarios representing different technology mixes and assumptions are evaluated. • Highly renewable technology mixes offer system cost savings compared baseline. • Over 90% greenhouse gas mitigation technically and economically feasible. [ABSTRACT FROM AUTHOR]

The global demand of steel production is growing, and so are the carbon dioxide emissions from the sector. Research has confirmed that 15 to 20% further energy efficiency improvement is possible, which would reduce the sector's greenhouse gas emissions and help meet global emission reduction initiatives. In this context, this research aims at developing a bottom-up system-based model to evaluate the long-term potential of energy efficiency alternatives in greenhouse gas mitigation. A case study was conducted for the Canadian iron and steel sector. The developed framework involves review of the state of the art in iron and steel production technologies, demand tree development, energy-environmental modeling, scenario development, and analysis. Twenty-six mitigation scenarios were developed in planning horizons ending in 2030 and 2050. A 13% improvement in Canadian iron and steel energy efficiency could be achieved by increasing the production share of the electric arc furnace route from 41% in the base year to 56% by 2050. The results of the analysis suggest that 19 and 38 million tonnes of greenhouse gas emission reduction are achievable in the 2010–2030 and 2010–2050 planning horizons, respectively. This translates to an approximately 6% reduction in emissions compared to the baseline scenarios at a cost of − $76 and − $51 per tonne of carbon dioxide equivalent in the 2010–2030 and 2010–2050 time periods, respectively. The results also reveal that more than 85% of the potential emission reductions are achievable with negative costs and are economically attractive. The study provides insights to decision makers at different levels of industry and government. [ABSTRACT FROM AUTHOR]

Abstract: Harnessing the metabolic potential of uncultured microbial communities is a compelling opportunity for the biotechnology industry, an approach that would vastly expand the portfolio of usable feedstocks. Methane is particularly promising because it is abundant and energy‐rich, yet the most efficient methane‐activating metabolic pathways involve mixed communities of anaerobic methanotrophic archaea and sulfate reducing bacteria. These communities oxidize methane at high catabolic efficiency and produce chemically reduced by‐products at a comparable rate and in near‐stoichiometric proportion to methane consumption. These reduced compounds can be used for feedstock and downstream chemical production, and at the production rates observed in situ they are an appealing, cost‐effective prospect. Notably, the microbial constituents responsible for this bioconversion are most prominent in select deep‐sea sediments, and while they can be kept active at surface pressures, they have not yet been cultured in the lab. In an industrial capacity, deep‐sea sediments could be periodically recovered and replenished, but the associated technical challenges and substantial costs make this an untenable approach for full‐scale operations. In this study, we present a novel method for incorporating methanotrophic communities into bioindustrial processes through abstraction onto low mass, easily transportable carbon cloth artificial substrates. Using Gulf of Mexico methane seep sediment as inoculum, optimal physicochemical parameters were established for methane‐oxidizing, sulfide‐generating mesocosm incubations. Metabolic activity required >∼40% seawater salinity, peaking at 100% salinity and 35 °C. Microbial communities were successfully transferred to a carbon cloth substrate, and rates of methane‐dependent sulfide production increased more than threefold per unit volume. Phylogenetic analyses indicated that carbon cloth‐based communities were substantially streamlined and were dominated by Desulfotomaculum geothermicum. Fluorescence in situ hybridization microscopy with carbon cloth fibers revealed a novel spatial arrangement of anaerobic methanotrophs and sulfate reducing bacteria suggestive of an electronic coupling enabled by the artificial substrate. This system: 1) enables a more targeted manipulation of methane‐activating microbial communities using a low‐mass and sediment‐free substrate; 2) holds promise for the simultaneous consumption of a strong greenhouse gas and the generation of usable downstream products; and 3) furthers the broader adoption of uncultured, mixed microbial communities for biotechnological use. [ABSTRACT FROM AUTHOR]

Renewable energy technology-based power generation is considered to be environmentally friendly and to have a low life cycle greenhouse gas emissions footprint. However, the life cycle water footprint of renewable energy technology-based power generation needs to be assessed. The objective of this study is to develop life cycle water footprints for renewable energy technology-based power generation pathways. Water demand is evaluated through consumption and withdrawals coefficients developed in this study. Sixty renewable energy technology-based power generation pathways were developed for a comprehensive comparative assessment of water footprints. The pathways were based on the use of biomass, nuclear, solar, wind, hydroelectricity, and geothermal as the source of energy. During the complete life cycle, power generation from bio-oil extracted from wood chips, a biomass source, was found to have the highest water demand footprint and wind power the lowest. During the complete life cycle, the water demand coefficients for biomass-based power generation pathways range from 260 to 1289 l of water per kilowatt hour and for nuclear energy pathways from 0.48 to 179 l of water per kilowatt hour. The water demand for power generation from solar energy-based pathways ranges from 0.02 to 4.39 l of water per kilowatt hour, for geothermal pathways from 0.04 to 1.94 l of water per kilowatt hour, and for wind from 0.005 to 0.104 l of water per kilowatt hour. A sensitivity analysis was conducted with varying conversion efficiencies to evaluate the impact of power plant performance on water demand. Cooling systems used in power generation plants were also studied and include once-through, recirculating, dry, and hybrid cooling. When only the power generation stage is considered, hydroelectricity and nuclear power generation with once-through cooling systems showed the highest water consumption (68 l of water per kilowatt hour) and water withdrawals coefficients (178 l of water per kilowatt hour), respectively. [ABSTRACT FROM AUTHOR]

The emissions of greenhouse gas (GHG) from soils are of significant importance for global warming. The biological and physico-chemical characteristics of soil affect the GHG emissions from soils of different land use types. Methane (CH), nitrous oxide (NO), and carbon dioxide (CO) production rates from six forest and agricultural soil types in the Koteshwar hydropower reservoir catchments located in the Uttarakhand, India, were estimated and their relations with physico-chemical characteristics of soils were examined. The samples of different land use types were flooded and incubated under anaerobic condition at 30 °C for 60 days. The cumulative GHG production rates in reservoir catchment are found as 1.52 ± 0.26, 0.13 ± 0.02, and 0.0004 ± 0.0001 μg g soil day for CO, CH, and NO, respectively, which is lower than global reservoirs located in the same eco-region. The significant positive correlation between CO productions and labile organic carbon (LOC), CH and C/N ratio, while NO and N/P ratio, while pH of soils is negatively correlated, conforms their key role in GHG emissions. Carbon available as LOC in the reservoir catchment is found as 3-14% of the total ‟C' available in soils and 0-23% is retained in the soil after the completion of incubation. The key objective of this study to signify the C, N, and P ratios, LOC, and pH with GHG production rate by creating an incubation experiment (as in the case of benthic soil/sediment) in the lab for 60 days. In summary, the results suggest that carbon, as LOC were more sensitive indicators for CO emissions and significant C, N, and P ratios, affects the GHG emissions. This study is useful for the hydropower industry to know the GHG production rates after the construction of reservoir so that its effect could be minimized by taking care of catchment area treatment plan. [ABSTRACT FROM AUTHOR]

Agricultural residues (wheat/barley/oat straw) can be used to produce charcoal, which can then be either landfilled off-site or spread on the agricultural field as a means for sequestering carbon. One centralized and five portable charcoal production technologies were explored in this paper. The centralized system produced 747.95 kg-CO 2 eq/tonne-straw and sequestered 0.204 t-C/t-straw. The portable systems sequestered carbon at 0.141–0.217 t-C/t-straw. The net energy ratio (NER) of the portable systems was higher than the centralized one at 10.29–16.26 compared to 6.04. For the centralized system, the carbon sequestration and the cumulative energy demand were most sensitive to the charcoal yield. Converting straw residues into charcoal can reduce GHG emissions by 80% after approximately 8.5 years relative to the baseline of in-field decomposition, showing these systems are effective carbon sequestration methods. [ABSTRACT FROM AUTHOR]

This study developed a novel assessment framework to analyze long-term energy transition in the road transport sector in which various technology options, market shares, policy measures, costs, and greenhouse gas emissions are considered in a single framework analysis. A data-intensive model was developed with the Low Emissions Analysis Platform (LEAP) and used to analyze policy scenarios up to 2050 for Alberta, Canada, a hydrocarbon-rich province with an emission-intensive energy sector. Three key policy measures – carbon pricing, zero-emission vehicle sales mandate, and incentivization – were analyzed in nine individual and combined policy scenarios. The transition to both hydrogen fuel cell electric vehicles and battery electric vehicles was assessed for all vehicle categories. Each fuel's full energy supply chain was modelled, including resource extraction, conversion, transmission and distribution, and fuelling, allowing for final and primary energy analysis. The findings show that carbon price and zero-emission vehicle incentives do not effectively lower greenhouse gas emissions on their own; zero-emission vehicle mandates are needed to transition the sector to a low-carbon energy system. The system-wide greenhouse gas emission footprints of hydrogen and battery electric vehicles are significantly below conventional vehicles in all cases. Scenarios biased towards battery electric vehicles had the most favorable results. The greenhouse gas emission footprint of hydrogen vehicles supplied by auto-thermal reforming with 91% carbon capture was lower than for battery electric vehicles powered by a primarily natural gas-based power grid. The findings on the effectiveness of carbon prices, incentives, and vehicle mandates should be considered by government policymakers aiming to reduce greenhouse gas emissions, infrastructure planners, and other energy stakeholders. [Display omitted] • Assessment of H 2 -FCEVs and BEVs for system-wide energy and emissions. • Impact of carbon price, ZEV sales mandate, and ZEV incentives analyzed up to 2050. • Evaluation of hydrogen production technologies including SMR and ATR with CCS. • Current policies result in 38% decline in system-wide emissions in 2050. • ZEV sales mandate is the most effective in reducing system-wide energy & emissions. [ABSTRACT FROM AUTHOR]

The industrial sector accounts for more than one-third of global energy consumption and greenhouse gas (GHG) emissions. In the sector, the chemical industry makes up nearly 30% of global industrial energy consumption. In this study, a framework is developed to apply bottom-up energy modelling for analyzing energy efficiency improvement and GHG mitigation potential in the chemical sector. Also, techno-economic and policy analyses are used to analyze the applicability and economic performance of different mid- to long-term energy efficiency measures. The comprehensive, data-intensive, and technology-rich model is flexible and can be used to study the GHG mitigation potential in different regions. A case study was conducted for Alberta, one of the biggest industrial hubs in Canada, using the Long-range Energy Alternative Planning model. Twenty-eight GHG mitigation scenarios in the petrochemical and fertilizer industries (the two major chemical industry sub-sectors) were developed. The costs of implementing each mitigation measure were calculated and used to develop cost curves. The results suggest that cumulative mitigation potential from the chemical industry would be 7.1 and 29.7 megatonnes CO 2 equivalent in the periods ending 2030 and 2050, respectively. We also found that more than 75% of the emissions reductions are achievable with negative cost. [ABSTRACT FROM AUTHOR]

To ensure the use of water today does not damage the prospects for its use by future generations, there is need to understand long-term water demand and supply through energy production, conversion, and use. This study aims to develop an integrated framework to assess the long-term impacts of climate change scenarios on water requirements and greenhouse gas (GHG) emissions. The framework includes the integration of the Water Evaluation And Planning model (WEAP) and the Long-range Energy Alternative Planning Systems model (LEAP). As many countries are planning to move towards a cleaner electricity grid to mitigate climate change, this work attempts to present the impact of various scenarios on water demand, GHG emissions, and cost effectiveness. This is done by conducting a case study of the western Canadian province of Alberta where more than 85% of electricity is generated by fossil fuels. This paper provides a comprehensive overview of nine integrated LEAP-WEAP climate change scenarios for the years 2015–2050 by forecasting water consumption and greenhouse gas emissions from the power sector. The economic aspects of the developed scenarios are discussed in the form of a cost curve that shows the GHG saving potential, water use, and GHG mitigation costs for each scenario. For the Business-As-Usual (BAU) scenario (coal power phase out by 2030), GHG emissions and water demand will fall by 44% and 34%, respectively, in 2030. The integrated results show that the scenarios will mitigate carbon emissions but will result in higher water consumption, which will directly affect water resources in the region. Because of the high investment cost to install the considered renewable power plants in the climate change scenarios, the cost of mitigating carbon emissions in the power sector is high. Early coal-to-gas power plant conversion is the only scenario that is expected to save water (67 million m 3 ) and reduce emissions (40 million tonnes of CO 2 eq.) and be cost effective ($68/tonne of CO 2 eq.). These LEAP-WEAP model results can help create awareness among policy makers to understand the water-energy demand and supply relationship in a quantifiable way. [ABSTRACT FROM AUTHOR]

Hydrothermal processing, a thermochemical approach, is an excellent method of converting energy-rich biomass into useful products. This approach offers the advantage of handling biomass with relatively high moisture content by precluding an energy-intensive pretreatment step. Hydrothermal processing is of world-wide interest in view of depleting fossil-fuel reserves and increased environmental greenhouse gas emissions. There is potential to develop this novel technology at demonstration scale. This paper reviews the three hydrothermal technologies, namely hydrothermal liquefaction, gasification and carbonization, to provide insight into the likelihood of commercialization. The study discusses the role of different process parameters that have key impacts on the quality and yield of the desired products. This study also identifies the gaps in the literature including the need to establish a baseline to develop key process models and to perform a techno-economic assessment to get a better sense of the viability of the technology in future. [ABSTRACT FROM AUTHOR]

The life cycle energy consumption and greenhouse gas (GHG) emission performances of forest biomass-derived oxymethylene ether (OME) synthesis used as a diesel additive are analyzed in this study. OME, a new alternative liquid fuel, has great miscibility with conventional fuels like diesel. OME can reduce combustion emissions significantly when used as a diesel additive without any modification to the engine. A data-intensive spreadsheet-based life cycle assessment (LCA) model was developed for OME synthesis from woodchips derived from two different kinds of forest biomass, whole tree and forest residue. Woodchip harvesting, chip transportation, chemical synthesis of OME from biomass-derived syngas, OME transportation to blending, and vehicle combustion of this transportation fuel were considered in the system boundary. The results show that the whole tree pathway produces 27 g CO 2 eq/MJ of OME, whereas the forest residue pathway produces 18 g CO 2 eq/MJ of OME over 20 years of plant life. The difference is mainly due to some emissions-intensive operations involved in biomass harvesting and biomass transportation such as skidding, road construction, etc., in the whole tree pathway. Also, vehicle combustion was found to be the most GHG-intensive unit for both pathways. OME combustion in a vehicle accounts for about 77% and 83% of the total life cycle GHG emissions for the whole tree and forest residue pathways, respectively. This study also compares the diesel life cycle emission numbers with the life cycle emissions of OME derived from forest biomass, and it was observed that GHG emissions can be reduced by 20–21% and soot (black carbon) emissions can be reduced by 30% using a 10% OME blended diesel as a transportation fuel compared with conventional diesel. [ABSTRACT FROM AUTHOR]

This study was conducted to identify energy efficiency improvement options and assess these opportunities in terms of potential of energy savings and greenhouse gas (GHG) mitigation for the commercial and institutional sector. In addition, associated GHG abatement cost (GHGAC) curves were developed. A western Canadian province, Alberta, was selected for a case study. A model was developed in the Long-range Energy Alternatives Planning system (LEAP) with 23 energy efficiency improvement scenarios associated with space heating and cooling, lighting, auxiliary equipment, and water heating in the commercial and institutional sector. The scenarios analyzed in this study quantified the reduced demand in energy use and GHG emissions as well as the abatement costs for fast (2013–2030) and slow (2013–2050) penetration periods. Ground source heat pumps (GSHPs) and efficient boilers for space heating, efficient lighting, and high-insulation in building envelopes are identified as having significant potential for GHG mitigation and have low abatement costs. A cumulative GHG mitigation of 28 Mt and 55 Mt is achievable in the fast and slow penetration scenarios in the sector, respectively. [ABSTRACT FROM AUTHOR]

Alberta's food processing industry is the second largest food waste producer after the household sector. Most of the waste currently produced from the food processing industry is landfilled. Decomposing landfill waste, moreover, emits greenhouse gases (GHG), which contribute to global warming. In this paper, we estimated the amount of food waste produced by Alberta's food processing industry by developing a geographical information system (GIS)-based model with data from food processing companies in the province. The companies were selected such that all sizes, types, and geographic locations were considered. The information was gathered on the amount and characteristics of food waste, the location of the processing facilities, and the food waste disposal method and then the total amount of food waste generated in Alberta was estimated. In addition, GIS maps were created to show the distribution of food waste throughout the province and the availability intensity. Finally, we estimated the potential energy that could be produced in the form of biogas and electricity using Alberta's food processing waste and mapped it as well. There is a potential to generate 852 GWh of electricity per year from Alberta's food processing waste, which is about 1% of the province's total electricity generation. This potential capacity could help in the development of waste-to-value-added facilities in Alberta. [ABSTRACT FROM AUTHOR]

Growing concern over climate change has created pressure on the oil and gas industry to reduce their greenhouse gas emissions (GHG). There have been multiple well-to-tank + combustion (WTT + C) studies that have examined various crude oils in an attempt to determine their GHG emission intensities. The majority of these studies published deterministic point estimates with a limited sensitivity analysis. Due to the variation in results between studies and the lack of uncertainty analysis the usefulness of these studies to policy makers and industry representatives is limited. The goal of this study is to expand on the previous literature by identifying a range of WTT + C emissions for crude oils from Saudi Arabia, Venezuela, and Iran. First, the previously published FUN damental E N gineering Principl E s-based Mode L for Estimation of G reen H ouse G ases in C onventional C rude O ils (FUNNEL-GHG-CCO) was used to perform a WTT + C analysis of the crudes GHG emissions. Then a Monte Carlo simulation was carried out using existing literature to define input distributions for the key inputs. The resulting gasoline WTT + C GHG emission ranges are 113.6–138.5 (Venezuela High Steam), 101.6–109.9 (Venezuela Low Steam), 101.1–109.2 (Sirri, Iran), and 95.3–99.9 gCO 2 eq/MJ (Saudi Arabia). This result indicates that even when uncertainty is taken into account the Venezuelan high steam crude clearly has higher emissions than the Saudi Arabia crude. The results of this study will give policy makers and industry representatives a better understanding of how the WTT + C GHG emissions vary between various crude oils. [ABSTRACT FROM AUTHOR]

China relies heavily on coal for power generation, and the demand for coal in a country of this size makes China the world's largest carbon dioxide emitter; hence China is pursuing greener pathways for power generation. Importing shale gas in the form of LNG from Canada is one such pathway. It starts with the recovery of shale gas in Canada and its export to China. This paper quantifies well-to-wire (WTW) greenhouse gas (GHG) emissions per kilowatt hour (kWh) of Canadian shale gas-fuelled electricity in China through models. WTW emissions include emissions from recovery, processing, transmission, liquefaction, marine shipping, re-gasification, power plant operations, and electricity transmission and distribution. Four Canadian shale gas reserves – Montney, Horn River, Liard, and Cordova – are considered. The results show that the WTW GHG emissions of Canadian shale gas-fired combined cycle technology range from 567 to 610 gCO 2 /kWh (57–62% of the GHG emissions from China's present coal-fired electricity), and total well-to-port (WTP) GHG emissions (emissions from recovery, processing, and transmission to a liquefaction facility) range from 7.68 to 13.4 gCO 2e /MJ. Sensitivity analysis results show that venting emissions during raw gas processing, flaring rates during well completion, and lifetime productivity of the gas significantly influence WTP emissions. [ABSTRACT FROM AUTHOR]

A model-FUNNEL-GHG-OS ( FUN damental E N gineering Principl E s- based Mode L for Estimation of G reen H ouse G ases in the O il S ands) based on fundamental engineering principles was developed to estimate the specific energy consumption and GHGs (greenhouse gas emissions) for upgrading bitumen to produce SCO (synthetic crude oil). The model estimates quantity of SCO produced, the consumption of hydrogen, steam, natural gas and power in two different upgrading operations, namely delayed coking and hydroconversion. Hydroconversion upgrading is more energy and GHG (433.4 kgCO 2 eq/m 3 of bitumen) intensive than delayed coker upgrading (240.3 kgCO 2 eq/m 3 of bitumen) but obtains a higher yield of SCO. This research explores bitumen pathways in oil sands – upgrading bitumen to SCO, followed by transporting and refining SCO as compared to transporting and refining dilbit. The energy consumption, GHG emissions and volume of transportation fuels obtained from refining of different oil sands feeds has been investigated. Refining of oil sands products produce 7.9 to 15.72 gCO 2 eq per MJ of refined product. Refining of SCO to transportation fuels produces 41% and 49% less emissions than dilbit and bitumen respectively. [ABSTRACT FROM AUTHOR]

Biomass fuels have long been accepted as useful renewable energy sources, especially in mitigating greenhouse gases (GHG), nitrogen oxides, and sulfur oxide emissions. Biomass fuel is carbon neutral and is usually low in both nitrogen and sulfur. For the past decade, various forms of biomass fuels have been co-combusted in existing coal-fired boilers and gas-fired power plants. Biomass is used as a supplemental fuel to substitute for up to 10% of the base fuel in most full commercial operations. There are several successful co-firing projects in many parts of the world, particularly in Europe and North America. However, despite remarkable commercial success in Europe, most of the biomass co-firing in North America is limited to demonstration levels. This review takes a detailed look at several aspects of biomass co-firing with a direct focus on North America. It also explores the benefits, such as the reduction of GHG emissions and its implications. This paper shows the results of our studies of the biomass resources available in North America that can be used in coal-fired boilers, their availability and transportation to the power plant, available co-firing levels and technologies, and various technological and environmental issues associated with biomass co-firing. Finally, the paper proffers solutions to help utility companies explore biomass co-firing as a transitional option towards a completely carbon-free power sector in North America. [ABSTRACT FROM AUTHOR]

Highlights: [•] This paper evaluated the energy use and GHG emissions for forest harvest residues. [•] Two chipping scenarios were compared for power plant sizes from 10 to 300MW. [•] Feedstock transportation to power plant highest energy use and GHG emissions. [•] Chipping at landing used less energy and GHG emissions than chipping at power plant. [•] Results were most sensitive to biomass moisture content and power plant lifetime. [ABSTRACT FROM AUTHOR]

Emissions from crude recovery contribute significantly to the life cycle GHG (greenhouse gas) emissions of transportation fuels. Recovery emissions come from drilling and land use change, crude extraction, crude oil processing, venting, flaring, and fugitives. In this study an attempt has been made to provide a transparent quantification of GHG emissions from oil well drilling and land use change, crude recovery and associated gas and water treatment, and venting and flaring for five North American conventional crudes through the development of data-intensive engineering models. Estimates of emissions from crude extraction were made from recovery efficiency, the amount of energy used, and process fuel shares in extraction techniques. Extraction emissions vary from 1.24 g-CO2eq/MJ for Bow River heavy oil to 23 g-CO2eq/MJ for California's Kern County heavy oil. The amount of gas vented and flared per m3 of crude extracted was determined to quantify venting and flaring emissions. The amount of energy required for crude oil processing was quantified based on the properties of crude oil and different techniques applied in the oil fields. Of the five crudes we studied, California's Kern County heavy oil and Mars crude oil emit the highest and lowest emissions: 23.85 g-CO2eq/MJ and 3.94 g-CO2eq/MJ, respectively. [ABSTRACT FROM AUTHOR]

• Novel integrated assessment framework for electricity decarbonization. • Electricity generation greenhouse gases decrease 49% in the current policy scenario. • Electricity generation water consumption increases 22% in the current policy scenario. • Electricity decarbonization reduced the water consumption increase by 8% • The marginal abatement cost for decarbonization was found to be −$17.5/tonne. The generation of electricity can have major environmental impacts not only in terms of greenhouse gas (GHG) emissions but also in terms of water use. There has been limited integrated assessment of the environmental footprints of deep decarbonization of electricity generation. This research develops an integrated approach to evaluate the GHG emission mitigation, water footprints, and marginal abatement costs of electricity generation decarbonization pathways. The decarbonization of Canada's electricity sector was used as a case study. A Long-range Energy Alternative Planning model of the electricity generation sector was developed to determine future regional electricity generation technology mixes. A Water Evaluation and Planning model was also developed for the sector considering 530 power plants, 156 electricity generation water demand sites, and 74 major rivers. The energy and water-use models were integrated, and two scenarios were evaluated for a planning horizon of 2019–2050 using this integrated framework. The first scenario was based on current policy trajectories and the second was developed with a deep electricity decarbonization target of 100%. In the current policy scenario, water consumption and GHG emissions increased 22% and decreased 49%, respectively, by 2050 from 2019. The fully decarbonized scenario resulted in water consumption savings and negative marginal GHG abatement costs. The results quantify the co-benefits of decarbonizing electricity systems and show that transitioning toward renewables can reduce GHG emissions, water consumption, and system costs. These results may be important for policy development at the regional and national levels as well as internationally for jurisdictions looking to transition to carbon-free electricity. [ABSTRACT FROM AUTHOR]

The purpose of this research is to evaluate the greenhouse gas reduction potential and associated costs of integrating renewable energy technologies into Canada's oil sands. There is very limited analysis in the literature focused on the integration of renewable technology options in oil sands processes. This research addresses the gap by developing a novel framework that applies market penetration and bottom-up energy modeling techniques. A total of 27 long-term scenarios across oil sands extraction, upgrading, and electricity generation were investigated. The results show that up to 84 million tonnes of greenhouse gas emissions abatement (2.3% of oil sands GHG emissions) at a marginal greenhouse gas abatement cost of $1.3/tCO 2 e is available under a $30/tonne carbon incentive. Scenarios with no carbon incentive resulted in 69 million tonnes less greenhouse gas emissions abatement and a marginal greenhouse gas abatement cost increase of $36/tCO 2 e. Nuclear-based scenarios mitigated the largest amount of greenhouse gases and had the lowest marginal abatement costs. Geothermal energy, bioenergy, and hydropower were cost effective in certain scenarios but had limited greenhouse gas emission reduction potential. Wind and solar technologies failed to displace existing processes in the scenarios considered. The results from this study may be of value to government policy makers and industry representatives aiming to reduce greenhouse gases. • A novel framework applying market penetration and bottom-up energy modeling. • Renewable and low-carbon energy supply options for the Canadian oil sands industry. • Up to 3.7% of GHG emissions between 2019 and 2050 could be mitigated at -$6/tCO 2 e. • Nuclear energy technologies provided most of the GHG emission abatement potential. • Removing a $50 per tonne carbon price reduced GHG abatement by 89%. [ABSTRACT FROM AUTHOR]

Carbon capture, utilization, and storage (CCUS) has been identified as the only option for substantially reducing greenhouse gas (GHG) emissions from fossil fuel-based processes. There has been limited research into the long-term GHG reduction potential of integrating CCUS into unconventional oil extraction processes. We developed a CCUS-oil sands market penetration model and integrated it with a bottom-up energy model (LEAP-Canada) to conduct a cost-benefit case study for the Canadian oil sands. Scenarios were developed considering currently available CCUS technologies and were investigated under different carbon pricing policies. Cumulative GHG emission mitigation potential from the CCUS applications ranged from 3 to 232 million tonnes (Mt) with marginal costs of $-28–42/tCO 2 e. Carbon pricing led to an average 3% increase in 2050 market shares of the technologies, resulting in additional GHG abatement of 4.9% (172 Mt). CCUS was found to be the costliest GHG emission mitigation option compared to increased integration of cogeneration and energy efficiency measures. The maximum cumulative oil sands GHG emission mitigation achieved in this study was 7%. This research ultimately provides insights into applications of CCUS technologies into the oil sands industry that might be useful to industry planners and policymakers and support the sustainable development of oil sands resources. • A novel bottom-up energy modeling framework for carbon capture in the oil sands. • 7% of industry GHG emissions from 2020 to 2050 could be mitigated at -$16.15/tCO 2 e. • Oxyfuel boilers powered by bituminous fuels provide 90% of mitigation potential. • Carbon pricing policies increased GHG abatement potential by 66 Mt. • Opportunities to utilize captured carbon increased GHG abatement potential by 94 Mt. [ABSTRACT FROM AUTHOR]

• A novel energy-environmental model for penetration of oil sands cogeneration. • Interactions between industry cogeneration and provincial grid system considered. • 2% of oil sands greenhouse gas emissions could be mitigated by 2050. • The marginal abatement cost is $15 per tonne of carbon abated. • 92% of emission mitigation came from the steam-assisted gravity drainage sector. The purpose of this research is to evaluate greenhouse gas emission reduction opportunities from cogenerated electricity in oil sands production. A novel combined market penetration and bottom-up energy system modelling framework was developed to assess the long-range potential and marginal costs of cogenerated electricity in the oil sands. Feasible scenarios for incorporating cogeneration into the in situ, surface mining, and upgrading subsectors were developed along with four additional scenarios incorporating electricity-based technologies to improve in situ plant efficiencies. These scenarios were evaluated under three different carbon pricing policies; twenty-one scenarios in total covering the time period 2019 to 2050. The use of cogeneration in the oil sands for new production during this period was determined through market penetration modelling and the results were compared to a reference scenario of limited cogeneration growth. It was found that there is potential to provide 76 million tonnes of greenhouse gas abatement (2% of cumulative projected oil sands emissions) at a marginal cost of $15 per tonne of carbon abated compared to the reference scenario. The incorporation of electrical equipment, specifically well-pad boilers, well-pad compressors, additional steam compressors, and steam superheaters, resulted in additional costs that outweighed the benefits. A $50 per tonne of carbon dioxide equivalent carbon price (within the current Alberta emission reduction regulation) resulted in a 2% increase in forecasted greenhouse gas abatement potential and a $1.4/tonne of carbon dioxide equivalent decrease in marginal abatement costs compared to no carbon pricing. This research provides quantification of the greenhouse gas emission abatement potential and marginal abatement costs of cogeneration technologies to allow industry stakeholders and policymakers to compare these technology options to others when considering long-term greenhouse gas emission reduction. [ABSTRACT FROM AUTHOR]

The industrial sector, accounting for 30% of global greenhouse gas (GHG) emissions, is among the key drivers of human-induced climate change impacts. Given this volume of emissions, the sector could play a critical role in mitigating climate change. Canada is among the top 10 global GHG emitters and its industrial sector is responsible for more than 39% of national emissions. GHG emissions from the sector increased by almost 32% between 1990 and 2017 and are expected to almost double by 2050 if no measures are taken. This paper aims to evaluate how different technical and economic factors have contributed to the increasing GHG emission trends in Canada's industrial sector between 1990 and 2014. The Logarithmic Mean Divisia Index was developed and implemented as the decomposition method. Results from the analysis suggest that activity level is the biggest contributor to the increase in industrial GHG emissions between 1990 and 2014, which ranged from 5 Mt CO 2 eq in 1994 to 57 Mt CO 2 eq in 2014 compared to the 1990 baseline. Increased shares of low carbon-intensive industries and fuel switching contribute to GHG emission mitigation from the sector. The structural change is responsible for GHG reductions of 1.1 and 23.4 Mt CO 2 eq in 2000 and 2014, respectively. The impacts from fuel mixs and increased shares of low-carbon fuel ranged from −1 Mt CO 2 eq in 1994 to 16 Mt CO 2 eq in 2011. Despite improvements in process-energy-intensity (i.e., the energy consumed per unit of product) in several industries, changes in economic energy intensity (energy consumed per unit of economic output) have resulted in increased GHG emissions. These changes are mainly driven by changes in the process-energy intensity of the oil sands mining sector, the largest contributor to industrial GHG emissions in Canada. Image 107490 • Historical GHG emissions trends from Canada's industrial sector were analyzed. • GHG emissions decomposition analysis was done for the years 1990–2014. • The impacts of driving factors on increasing GHG emission trends were examined. • Activity level was found to be the main driver of GHG emissions. • Fuel switching and electricity decarbonization mitigate industrial GHGs. [ABSTRACT FROM AUTHOR]

The objective of this study is to investigate greenhouse gas mitigation pathways for the iron, gold, and potash mining sectors in Canada. These sectors have not widely accepted the available cleaner production strategies and so there is potential to reduce greenhouse gas emissions. It is important to fully realize this potential as soon as possible to support efforts to limit global warming. We conducted cost-benefit analyses of implementable greenhouse gas reduction strategies in order to inform policy and industry. Twenty-four greenhouse gas emission reduction options not yet implemented in Canada were identified following a review of current processes and operations at 102 mine sites. We developed a novel model to assess these options, integrating technology diffusion rates and long-term energy-environmental modelling. We found that the maximum greenhouse gas reduction potential can be realized through simultaneously implementing fifteen technology changes, eliminating 21 million tonnes of CO 2 eq. by 2050. Furthermore, we showed that the marginal greenhouse gas abatement costs are negative, indicating that the industry would also achieve long-term cost savings if these changes were pursued. Implementing high pressure grinding rolls in iron mining and electric and diesel hybrid haul trucks in underground gold mining and potash mining have the most favorable greenhouse gas abatement costs of −4120, −3096, −701 $/tonne, respectively. These results show that these technology changes should be pursued since both environmental benefit and cost savings would be achieved. Image 1 • A bottom-up energy model was developed for iron, gold, and potash mining sectors. • Twenty-four GHG mitigation options were identified and assessed. • Energy consumption reduction potential is 9% through 2020–2050 across the sectors. • 10% and 20% of GHG emissions could be reduced in iron and gold mining, respectively. • More than 95% of the GHG emission reductions have negative marginal abatement costs. [ABSTRACT FROM AUTHOR]

Abstract The cement industry is responsible for between 5% and 9% of global greenhouse gas (GHG) emissions. The increasing trend of GHG emissions from cement sector highlights the importance of GHG mitigation in this industry. In the current study, bottom-up energy modelling and scenario analyses were used to assess long-term GHG mitigation potential in the cement industry. The developed comprehensive, data-intensive, and technology-rich model is flexible and can be used to study the GHG mitigation potential in different regions. For the case study of Canada, a reference scenario along with 20 GHG emissions' reduction scenarios were developed in the Long-range Energy Alternative Planning (LEAP) model. For each scenario, cumulative energy saving and GHG reduction potential were analyzed. Furthermore, the net present value, cost of saved energy, and carbon were calculated to assess the economic performance of different scenarios. Carbon abatement cost curves were also developed using the GHG mitigation potential and the cost of implementing different energy efficiency options. Overall, compared to the reference scenario, the cumulative GHG mitigation potentials in the Canadian cement sector are 27 and 59 million tonnes CO 2 eq. by the years 2030 and 2050, respectively. More than 70% of the emissions' reduction is achievable with negative cost. Highlights • A bottom-up and technology-rich model is developed for the cement industry. • Energy consumption demand tree is used to analyze the energy intense sub-processes. • 20 scenarios are developed to assess the long-term energy saving and GHG mitigation. • Carbon abatement cost curves are developed to rank energy saving options. [ABSTRACT FROM AUTHOR]

Crude oil is currently transported primarily by pipelines and rail from extraction sites to refineries around the world. This research evaluates energy use and greenhouse gas (GHG) emissions for three scenarios (synthetic crude oil and dilbit with and without diluent return) in which 750?000 bpd of Alberta's bitumen is transported 3000 km to determine which method has a lower environmental impact. Each scenario has a pipeline and rail pathway, and the dilbit without diluent return scenario has an additional heated bitumen pathway, which does not require diluent. An Excel based bottom-up model is developed using engineering first-principles to calculate mass and energy balances for each process. Results show that pipeline transportation produced between 61% and 77% fewer GHG emissions than by rail. The GHG emissions decreased by 15% and 73% for rail and pipelines as the capacity increased from 100?000 to 800?000 bpd. A Monte Carlo simulation was performed to determine the uncertainty in the emissions and found that the uncertainty was larger for pipelines (up to ±73%) and smaller for rail (up to ±28%). The uncertainty ranges do not overlap, thus confirming that pipelines have lower GHG emissions, which is important information for policy makers conducting pipeline reviews. [ABSTRACT FROM AUTHOR]

With the growing number of electric vehicles in the transportation sector aimed at reducing greenhouse gas emissions, vehicle-to-grid (V2G) technology can play an important role in stabilizing electricity grids. An electric vehicle could be used as an energy storage system (ESS) that provides electricity to the grid when required. Several studies have evaluated the economic performance of different stationary ESSs; however, research that focuses on the V2G technology economic feasibility is scarce for cold climates. In this study, an engineering principles-based techno-economic model was developed to estimate the levelized cost of storage (LCOS) of V2G technology for energy arbitrage and frequency regulation. A model was also developed to predict the available energy and cost for V2G applications at various temperatures. Sensitivity and uncertainty analyses were performed to identify the key parameters that drive economic performance. The base case values of the LCOS are $230.88 and $329.93/MWh for energy arbitrage and frequency regulation, respectively. The key parameters are ambient temperature, battery cycle life, distance traveled per day, battery depth of discharge, battery capital cost, and electricity price. Considering the variabilities in these parameters, the probable ranges of the LCOS are $158-$290/MWh and $244-$485/MWh for energy arbitrage and frequency regulation, respectively. • The economic viability of a vehicle-to-grid (V2G) system was assessed. • A techno-economic model was developed to estimate the levelized cost of storage for energy arbitrage and frequency regulation. • The effect of temperature on vehicle-to-grid energy availability was studied. • The levelized cost of storage is from $158 to $290/MWh for energy arbitrage. • The levelized cost of storage is $244-$485/MWh for frequency regulation. [ABSTRACT FROM AUTHOR]

Displacement of fossil fuel-based power through biomass co-firing could reduce the greenhouse gas (GHG) emissions from fossil fuels. In this study, data-intensive techno-economic models were developed to evaluate different co-firing technologies as well as the configurations of these technologies. The models were developed to study 60 different scenarios involving various biomass feedstocks (wood chips, wheat straw, and forest residues) co-fired either with coal in a 500 MW subcritical pulverized coal (PC) plant or with natural gas in a 500 MW natural gas combined cycle (NGCC) plant to determine their technical potential and costs, as well as to determine environmental benefits. The results obtained reveal that the fully paid-off coal-fired power plant co-fired with forest residues is the most attractive option, having levelized costs of electricity (LCOE) of $53.12–$54.50/MW h and CO 2 abatement costs of $27.41–$31.15/tCO 2 . When whole forest chips are co-fired with coal in a fully paid-off plant, the LCOE and CO 2 abatement costs range from $54.68 to $56.41/MW h and $35.60 to $41.78/tCO 2 , respectively. The LCOE and CO 2 abatement costs for straw range from $54.62 to $57.35/MW h and $35.07 to $38.48/tCO 2 , respectively. [ABSTRACT FROM AUTHOR]

To reduce the greenhouse gas (GHG) emission from rice and wheat cultivation several mitigation options have been suggested. However, economic impact of these technologies has been poorly documented. In the present study economic analysis of some emerging GHG mitigation technologies for rice-wheat system of the Indo-Gangetic Plains has been carried out. The experiment consisted of six combinations of wheat- rice crop rotation using eight treatments, including conventionally tilled wheat (CTW), zero tilled wheat (ZTW), transplanted puddled rice (TPR), dry direct seeded rice (DSR), intermittent wetting and drying (IWD), application of rice straw (RS) with ZTW and use of neem oil-coated urea (NOCU) in TPR and ZTW. Cost of various inputs and income from grain and straw were used for computing the benefit to cost (B : C) ratio in the different treatments. ZTW showed higher yield and B : C ratio compared to CTW along with reduction in fuel consumption during tillage operation. In spite of lower yield under DSR and IWD, saving of water, labour and energy in these treatments lowered the cost of cultivation and enhanced B : C ratio similar to TPR. Application of rice straw and NOCU also showed positive impact on crop yield. B : C ratio of rice-wheat system ranged from 1.62 to 1.86 in the first year and from 1.86 to 2.16 in the second year. B : C ratio was significantly higher in all the treatments in the experimented rice-wheat system compared to conventional system, i.e. CTW-TPR. The ZTW + RR - DSR (WR5) showed highest B : C ratiofollowed by ZTW + DSR (WR4) in both the seasons. [ABSTRACT FROM AUTHOR]

The urgent challenge of reducing industrial greenhouse gas emissions has created a growing demand for a more comprehensive understanding of how various technology options can contribute to achieving carbon neutrality. Energy efficiency has long been regarded as a key pathway in this context, but the volume and diversity of efficiency options has resulted in an unclear understanding of their combined impacts. In this study, we present a novel technology-explicit method to estimate the overall abatement potential associated with a comprehensive suite of 115 energy efficiency technologies spanning all relevant sector processes and energy types. By applying our flexible analysis framework to a case study of the Canadian pulp and paper sector, we demonstrate that energy efficiency could be the single largest contributor to achieving a carbon-neutral target for the sector. We find that efficiency can reduce emissions by 4.92 MtCO 2 e/yr (66%) relative to business-as-usual by 2050 at a weighted average abatement cost of -$162/tCO 2 e when accounting for capital, operating, maintenance, and energy costs. Abatement at the energy system-wide level is even larger, reaching 6.67 MtCO 2 e in 2050 when accounting for upstream effects. Adoption of the full suite of efficiency measures could materially improve the competitiveness of the sector by reducing energy and carbon costs. On the whole, our results suggest that proven energy efficiency technologies could be the primary element of a credible low-cost pathway towards achieving a target of carbon neutrality for the pulp and paper sector. [ABSTRACT FROM AUTHOR]

Global warming, management of soil health, remediation of contaminated wastewater,and sustainable alternate source of energy are the major challenges of the 21st century. Biochar has an enormous potential in addressing these global issues and can act as a catalyst in achieving sustainable development goals (SDGs). Biochar produced from waste biomass (crop residues, algal biomass, municipal waste, etc.) has dual advantages of waste management along with its application in different sectors. The mineral contents and buffering capacity of biochar make it an ultimate catalyst for anaerobic digestion which significantly enhances bioenergy production. Supplementing anaerobic digestion with biochar can increase biogas and biological hydrogen production up to 57% and 118% respectively, over control. Biochar addition to soil improves soil health, porosity and aeration which mitigates greenhouse gas emission from soil. Addition of biochar at the optimum level in rice can reduce cumulative methane emission up to 60%. In this manuscript, the potential of biochar for bioenergy production (biogas and biological hydrogen production), greenhouse gases mitigation, carbon sequestration in soils, and waste water remediation is discussed in detail along with the challenges and future prospects of biochar. This review identifies the key issues which need to be addressed for sustainable utilization of biochar. [Display omitted] • Biochar is nutrient rich biomass and its use is economic and environment friendly. • Biochar enhances biogas and bio-hydrogen production in anaerobic reactors. • Biochar based MFCs are economically and environmentally sustainable. • Biochar addition in soil sequesters carbon and reduces CH 4 and N 2 O emissions. • Biochar use potentially removes several emerging contaminants from wastewater. [ABSTRACT FROM AUTHOR]

Greenhouse gas (GHG) mitigation opportunities from emerging in situ mining technologies in oil sands production can play a role in reducing global warming. There is limited research on quantitative assessments of the penetration of emerging oil sands technology in the energy sector. This study addresses this gap by developing a novel framework (MAPL-OET) to assess the market penetration of emerging oil sands extraction technologies. The framework is robust and data-intensive as it combines diffusion models, econometrics models, cost models, and energy-economy equilibrium models. The combined model evaluates the adoption of new energy technologies resulting from carbon price measures and other economic factors, as well as the GHG mitigation potential in the oil sands sector. The accumulated GHG mitigation potential from high carbon and BAU scenarios (i.e., a carbon price of $30/tonne of CO 2 in 2030, increasing at a rate of 4%/yr to reach about $105/tonne of CO 2) was estimated to be 192.8 Mt of CO 2 eq between 2018 and 2050. New extraction technologies also improve average energy intensities by 1.3% annually in the high carbon price scenarios. The developed new framework can help public and private organizations to achieve energy or environmental targets. • The analysis focuses on oil sands extraction technologies. • A new combined method is developed and used for market penetration modeling. • Efficient in situ bitumen mining technologies shares are modeled from 2020 to 2050. • Effects of carbon price on energy efficiency improvement are analyzed. • Annual energy efficient improvement is evaluated. [ABSTRACT FROM AUTHOR]

Process-level energy efficiency improvement is regarded as an effective technique for emissions reduction from the petroleum refining industry. Assessing the systems-level impacts of these energy efficiency improvements is crucial for effective long-term climate change policy- and decision-making. In this study, we developed a framework that integrates process simulation with integrated resource planning and techno-economic assessment techniques to evaluate long-term GHG mitigation potential in the refining sector. Detailed process simulations were done for eleven energy efficiency improvement measures in the refining sector. A case study was conducted for Alberta's (a province in western Canada) refining sector to assess GHG emissions reduction potential and their implications for long-term climate change policy-making. The GHG mitigation scenarios considered time horizons to the years 2030 and 2050. The results show that compared to the reference scenario, integrating the energy efficiency options in the refining sector will result in cumulative emissions reduction of 5%. About 60% of the anticipated emissions reductions are economically attractive. The proposed framework is an effective tool for the evaluation of long-term refining sector GHG mitigation potential and can be used for decision-making and policy formulation at various levels. • A framework is developed to assess GHG mitigation potential in the refining sector. • Process simulation, economic analysis, and energy planning models are integrated. • 22 mitigation scenarios are developed in time horizons ending in 2030 and 2050. • GHG mitigation potential is calculated and GHG abatement cost curves are developed. • 60% of the GHG emissions reductions are found to be economically attractive. [ABSTRACT FROM AUTHOR]

The main objective of this study is to assess energy-use reduction strategies in extraction and upgrading of oil sands for greenhouse gas mitigation in Canada's oil sands sector. A bottom-up integrated resource-planning model for oil sands extraction and upgrading processes was developed. The model is a novel application of an energy accounting-based framework and accurately simulates energy demand and supply in the oil sands from 2007 to 2050. Thirty energy-use reduction scenarios were evaluated covering in situ extraction, surface mining, and bitumen upgrading processes. The energy savings, greenhouse gas emission mitigation, and costs associated with each scenario were determined with the model. Implementing in situ energy-use reduction measures resulted in the highest single measure greenhouse gas mitigation potential of 86 million tonnes CO 2 e at a marginal greenhouse gas abatement cost of -$91/tonne of CO 2 e by 2050. For the scenarios in surface mining and bitumen upgrading, the highest single measure greenhouse gas mitigation potentials are 17 and 16 million tonnes CO 2 e by 2050 at marginal greenhouse gas abatement costs of -$65/tonne of CO 2 e and -$21/tonne of CO 2 e, respectively. All strategies result in a negative $/tonne of CO 2 e cost, indicating a net benefit for investing in the strategies. If the strategies are implemented together, there is an ultimate potential to reduce sector-wide cumulative energy consumption and greenhouse gas emissions in the oil sands by 8% and 7%, respectively, by 2050. Decision-makers at company or government levels can use these results to support both environmental and cost-saving initiatives. Image 1 • A bottom-up energy supply-demand model for the oil sands sector was developed. • Sector-wide energy consumption could be reduced up to 8%. • An annual average of 7.6 million tonnes of GHG emissions could be mitigated. • 65% of evaluated GHG mitigation potential is from in situ extraction. • All GHG emission mitigation strategies have negative marginal abatement costs. [ABSTRACT FROM AUTHOR]