Growing concerns over the persistence and environmental impact of plastic waste highlight the need for recycling strategies that enable a circular economy by converting waste into valuable products. Despite this, integrated process models for chemical recycling of mixed plastic waste (MPW) remain limited. The novelty of this study lies in the integration of gasification of MPW to syngas, fermentation to ethanol, dehydration to ethylene, and polymerization to high-density polyethylene (HDPE) within an Aspen Plus process simulation framework, coupled with process optimization, heat integration, and energy-related GHG assessment, aiming to reduce waste and dependence on fossil resources. The framework was validated against published experimental and other data, with deviations of 0.12–4.0% across all process stages. Operating conditions were optimized through parametric analysis to maximize product yield and minimize energy consumption. Optimal gasification conditions were identified at an equivalence ratio of 0.21, steam-to-plastic ratio of 0.45, and temperature of 1000°C, producing 901.5 tonnes/day of syngas from a 500 tonnes/day plant. This syngas yielded 382 tonnes/day of ethanol, which was dehydrated at 450°C and 1 bar to produce 229 tonnes/day of ethylene. Polymerization of ethylene resulted in 228.4 tonnes/day of HDPE. The overall carbon conversion efficiency was 50.2%, corresponding to the carbon retained in HDPE relative to the carbon entering through the MPW feedstock. Heat integration reduced total heat demand by 56.1 MW (35.23%) and power consumption by 1.5 MW (6.12%), while lowering greenhouse gas emissions associated with energy consumption by 27.8% to 3.9 kg CO2e/kg HDPE. This approach supports scalable, energy-efficient plastic recycling and provides key insights for process design and implementation.

Transporting forest residues as slurry through pipelines offers significant potential for bioenergy applications, largely due to its lower unit transportation costs at scale. An added benefit is the possibility of drag reduction, phenomenon in which the slurry exhibits lower frictional resistance than the carrier fluid under certain conditions. The influence of pipe diameter on the drag reduction behavior of forest residue (wood chip) slurry flows remains largely unexplored, and this study aims to fill this research gap. A pilot-scale pipe loop with a 0.10 internal diameter was fabricated and commissioned, and systematic experiments were conducted over a range particle nominal sizes (4-24 mm), bulk velocities (0.5-3.0 m/s), and solids concentrations (1.5-10.5 wt%). resulting data were compared with previous results from a 0.05 m diameter pipeline to evaluate scale effects frictional pressure loss and drag reduction behavior. A maximum drag reduction of 12.2% was observed in larger pipe, though this was about 40% lower than that in the smaller pipe. Additionally, a shift in the concentration range for which drag reduction occurred was observed with increasing pipe diameter. Empirical modeling using nonlinear regression (NR), support vector regression (SVR), and artificial neural networks (ANNs) was also performed for frictional pressure loss prediction. Though the ANN showed the best prediction performance among these, NR models are recommended for extrapolation beyond the training data. The findings from this study will be crucial for the viability of woody biomass slurry transport for integration into large-scale biorefinery supply chains.

Indian iron and steel industry (IISI) is one of the most carbon-intensive and hard-to-abate sector. While multiple decarbonization pathways are being explored globally, biomass-derived charcoal offers a unique opportunity for India, given the country's vast agricultural residue availability. Existing studies largely focus on technical viability i.e., technical limit of substituting charcoal with coal/coke across various processes (sintering, coking, blast furnace, etc.), while overlooking the critical aspects from a plant's perspective such as amount of charcoal required for decarbonization, biomass availability in regions surrounding steel plants and the associated feasibility of large-scale deployment of charcoal into each process of IISI. Moreover, the CO2 mitigation potential of charcoal in IISI also remains unexplored and unquantified. This study addresses these gaps through a case study that first evaluates the total amount of charcoal required in each process of IISI for decarbonization (based on material and energy flow analysis), considering the technical limits of charcoal substitution. Further, it evaluates the availability of biomass at high spatial resolution in near-by regions, the suitability of different biomass types for charcoal production followed by estimating the quantity of agriculture residues that can be generated and the potential CO2 mitigation achievable after substituting the coke/coal with charcoal. Results show that 5.29 MTPA of charcoal is required to substitute fossil fuels in existing processes, reducing CO2 emission intensity by 56.08%. Neighbouring states can supply 8.76 ± 1.71 MTPA of charcoal from agricultural residues. At high substitution levels (80–100%), annual emissions remain 3.14–5.87 MtCO2 below the declining benchmark trajectory, even under stricter emission caps. While the study quantifies the technical potential and emission reduction from charcoal substitution at the plant scale, key challenge such as biomass supply chain optimization is not addressed and left for further investigation. Policy interventions such as graded blending mandate, organized residue collection systems, and financial incentives for early adopters are recommended to unlock this potential.

The timber industry yields substantial amount of sawdust which acts as a source of pollution without proper management. One of the possible applications of the waste material is in using it as a reinforcing filler in biopolymer composites and thereby fostering the circular economy. However, the brittle nature of such material creates hinderance in its mass production and prevents its widespread commercial use. To address the shortcoming, this study explored the novel application of silly putty as a plasticizing additive in polylactic acid (PLA)-sawdust based composites. The addition of 5 wt

Electrolytic hydrogen could support low-carbon energy systems planning, particularly through power-to-gas-to-power (PtG-GtP) operations in the power sector. However, achieving long-term economic viability has remained uncertain, and limited research exists on how to incentivize PtG-GtP systems for the value provided to the electricity system. This study develops a novel framework to derive a differential pricing (DP) incentive that supports the incremental deployment of PtG-GtP systems in an electricity system undergoing a low-carbon transition. The DP incentive is defined by the difference in electricity marginal prices between a cost-minimizing objective and a risk-averse goal that prioritizes reversible electrolytic hydrogen use. Applying the DP incentive in an emissions-intensive power sector lowers the PtG-GtP system's levelized cost to C$6/kg H2, six times less than without the incentive, while also contributing to reductions in the reserve market electricity cost. The study findings hold under a stepwise, incremental approach to deploying multiple PtG-GtP systems over the long term.

Poly(lactic acid) (PLA) is a promising biodegradable polymer widely explored as a potential alternative to conventional polymers across various applications. However, PLA suffers from limitations, including inadequate gas barrier properties and brittleness. Poly(butylene adipate-co-terephthalate) (PBAT), a biodegradable polymer with excellent flexibility, is a promising candidate for blending with PLA to reduce brittleness. In this work, molecular models of pure PLA, pure PBAT, and their blends have been generated to investigate their gas transport properties. Specifically, the diffusion of oxygen, water and carbon dioxide (O2, H2O and CO2) has been studied in pure PLA, pure PBAT and PLA/PBAT blends containing varying concentrations of PBAT (0 %, 26.7 %, 49.3 %,59.3 %, 68.6 % and 100 % by weight) using molecular dynamics (MD) simulations. The models were validated by calculating the densities, solubility parameters, and glass transition temperatures of the pure polymer models, which compared well with the reported experimental values. Simulations conducted to study the diffusion of oxygen, water and carbon dioxide in the modeled polymers and blends revealed reduced meansquare displacements (MSD) and self-diffusivities of the gas molecules in PLA/PBAT blends compared to those in pure PLA. For instance, the self-diffusivity of oxygen in pure PLA (5.67 & times; 10- 11 m2/s) was up to four times that of pure PBAT (1.77 & times; 10-11 m2/s), while that in PLA/PBAT blends was intermediate. The trend in the gas molecules' self-diffusivities correlated well with the fractional accessible volume in the polymer matrix across the different systems studied. The present study indicates that blending PLA with PBAT is associated with a reduction in the fractional accessible volume for gas molecules, which corresponds to decreased molecular-scale gas mobility in the blends.

Benthic plant microbial fuel cells (BPMFCs) represent an innovative, sustainable technology that effectively integrates plant photosynthesis with microbial electroactivity, facilitating the generation of renewable electricity alongside the remediation of organic waste. This study offers a critical analysis of the latest developments in BPMFC technology, focussing on 4 essential aspects: (1) novel bio-based electrode materials including functionalised conductive polymer composites, nanomaterial hybrids that enhance electron transfer (ET) efficiency; (2) advanced metagenomic and transcriptomic studies elucidating the electroactive microbial consortia and their unique extracellular ET mechanisms in both rhizosphere and BPMFC configurations; (3) the application of genetically modified plants with enhanced root exudation profiles, increasing power output; (4) innovative remote monitoring systems for BPMFCs employing IoT-enabled wireless sensor networks and long range wide area network technology ensuring reliable voltage measurement transmission from distant locations with minimal signal loss. The review rigorously analyses life cycle assessment studies that substantiate the environmental advantages of PMFCs, especially their carbon-negative potential when combined with wastewater treatment. Even with these advancements, there are still considerable obstacles to overcome in scaling BPMFC technology, such as concerns regarding system durability and questions about economic feasibility. A comprehensive roadmap is provided that integrates artificial intelligence-optimized material design, synthetic microbial community engineering, improved monitoring systems, and circular economy concepts to facilitate the transition from laboratory-scale prototypes to real-world applications. This analysis highlights the promise of BPMFCs as distributed renewable energy systems, particularly in agricultural and aquatic environments, while delineating critical research avenues to tackle existing commercialization obstacles.

The growing imperative for sustainable waste management and cleaner energy production has spurred global interest in advanced thermochemical processes for valorising municipal solid waste (MSW). This study investigates the thermo-catalytic reforming (TCR®) of pelletized source-separated organic (SSO) feedstock from landfill-diverted waste via a 2 kg h-1 hybrid intermediate pyrolysis system to optimise yields of high-quality bio-oil and hydrogen-rich syngas. There is very limited research on thermo-catalytic reforming of SSO globally. As H2, bio-oil, and biochar gain focus for climate mitigation, this TCR system offers balanced production of all three valuable by-products, leveraging the inherent catalytic activity of the biochar enriched with alkali and alkaline earth metals to enhance reforming reactions and H2 yield. The research identifies optimal reactor/reformer temperatures for maximising bio-oil yield (6.20%), with the highest production observed at 500/500°C. At 500/650°C reactor/ reformer temperatures, syngas contained 36.36 vol% H2 and 11.05 vol% CH4, with a higher heating value (HHV) of 20.12 MJ kg-1, suitable for use as feedstock in Fisher-Tropsch synthesis for chemicals or fuel production. The produced bio-oil has low viscosity (31.79 mPa s-1), low aromatic hydrocarbon content, low total acid number (11.35 mg KOH g-1), and reduced monocyclic and polycyclic aromatic hydrocarbons (6.02% and 15.92% at 400/650°C); biochar at optimal conditions displays low HHV and increasing inorganic content (from 6.02 to 8.89 wt%) with temperature, supporting potential soil remediation applications. These findings demonstrate that TCR® enables efficient waste-to-energy conversion and provides a scalable model for organics valorisation with potential to guide global strategies for MSW management.

Global electricity demand is expected to double as economies decarbonize, posing a dual challenge for fossil-based electricity systems: meet rising demands and transition to low-carbon technologies. Initiatives around the world have begun exploring the use of low-carbon hydrogen in electricity systems; however, research on blue hydrogen in different grid contexts is limited. This paper analyzes blue hydrogen-based firm low-carbon electricity and compares it with alternatives of green hydrogen, nuclear, and natural gas with carbon capture and storage (CCS). A new analysis framework and long-term energy-systems model are applied to Alberta, Canada, a jurisdiction with heavy reliance on natural gas. Ninety-two scenarios representing different technology mixes, technology costs, and carbon pricing were analyzed from 2025 to 2050. Of the technologies to supply blue hydrogen, autothermal reforming (ATR) was the most effective considering cumulative cost and GHG abatement together; however, all assessed alternatives to blue hydrogen were more effective. ATRCCS-based scenarios reduced cumulative system-wide emissions by less than 5 % by 2050, and had the highest marginal abatement costs ($161–$371/t), whereas natural gas with CCS scenarios reduced at least two times more emissions at lower marginal abatement costs ($7–$86/t). The next lowest MACs were from nuclear scenarios ($64–$94/t), then green hydrogen scenarios ($102–$107/t), with 37–39 % and 29–42 % of emissions abatement, respectively. Overall, findings suggest a limited and low-value role for blue hydrogen in future electricity systems, given the available alternatives for providing low-carbon firm electricity. These findings should be considered by decision makers when developing policy, allocating funding, and designing technology support mechanisms.

Electrolytic hydrogen can help decarbonize emissions-intensive sectors, such as ammonia production, where electrification is challenging. However, there is limited information on penetration pathways for small modular nuclear reactor-based electrolytic ammonia (SMNRPP-NH3). This study introduces a framework for modelling the adoption of SMNRPP-NH3 systems and evaluates its potential to displace conventional ammonia. A case study of Alberta, Canada, showed that with a carbon price of $170/tCO2, SMNRPP-NH3 systems can meet 75% of the regional ammonia demand by 2050 at a levelized cost of $420/tNH3, which is 16% lower than natural gas-based ammonia. High technology learning rates, capital cost reductions, and accelerated deployment had more significant effects on the penetration than the GHG footprint of the conventional ammonia. The study findings can inform policy formulation and long-term investment planning to support the integration of electrolysis in the ammonia production sector. The developed framework can also be replicated globally with appropriate adjustments to the data.

With increasing emphasis on sustainable waste valorization, the co-processing of lignocellulosic biomass and biobased plastic waste is emerging as a transformative strategy for clean energy recovery and circular material utilization. This study investigates the structural interactions and material evolution arising from cohydrothermal carbonization (co-HTC) of yard waste and cigarette filters across varying feedstock ratios (1:1 to 3:1), followed by pyrolysis, without chemical activation. Systematic characterization revealed that increasing the proportion of yard waste progressively reduced inorganic residue accumulation, mitigated pore blockage, and improved the porous character of the resultant carbon. The electrochemical properties of the resultant carbon material were evaluated for its use in a symmetric supercapacitor. The specific surface area analysis revealed that increasing the proportion of yard waste improved the porous nature of the material. Despite achieving a total pore volume of 0.296 cm3 g_ 1, the micropore volume remained limited (0.070 cm3 g_ 1), with the majority of accessible sites falling within the mesopore range. As a baseline electrochemical assessment of this non-activated mixed-feedstock system, the symmetric supercapacitor device displayed an energy density of 14.5 W h kg_ 1 at 1 A g_ 1 and power density of 1010 W kg_ 1 at 10 A g_ 1. The device also exhibited 94 % capacity retention at 3 A g_ 1, even after 10,000 cycles. Using the modified Fick's law, the electrolyte diffusion coefficient was calculated to be 4.91 & times; 10_14 m2 s_ 1, which suggested that the porous structures in the material improved the diffusion of the electrolyte ions. The findings from prospective Life cycle Assessment (LCA) indicated a significant environmental footprint during electrode fabrication and cell fabrication stage mainly owing to electricity.

Methanol production from natural gas remains highly carbon-intensive. Previous studies have examined its energy, environmental, or economic dimensions in isolation, often neglecting the combined influence of carbon capture, syngas quality adjustment, and process heat substitution under consistent boundaries. This study presents the first integrated techno-economic and environmental assessment of methanol production via steam methane reforming (SMR) and autothermal reforming (ATR), developed as a case study for Alberta, Canada. The analysis integrates detailed Aspen HYSYS simulations to evaluate energy performance, environmental footprint, and cost using Alberta-specific utility prices and grid emission factors. Thirty-seven configurations were evaluated across varying stoichiometric numbers (SNs), carbon capture strategies, and process heat sources (natural gas or hydrogen). SMR with natural gas utility and pre-combustion CCS achieved the highest net energy ratio (0.77), whereas SMR with hydrogen utility and full CCS yielded the lowest GHG emissions (0.48 kg CO2/kg-MeOH). The lowest minimum selling price (MSP, $229.13/t) occurred for SMR with natural gas utility, pre-CCS, and hydrogen by-product revenue. Composite scoring identified SMR (SN = 2.91, pre-CCS) and ATR (SN = 1.77, full CCS) as the most balanced low-carbon pathways. Integrating carbon pricing and hydrogen revenue reduced breakeven prices to $10/t-CO2 (SMR) and $9/t-CO2 (ATR). Morris and Monte Carlo analyses revealed natural gas price, carbon price, discount rate, and hydrogen storage duration as dominant cost drivers, with uncertainties in cost estimates of +1.7 % for SMR and +1.5 % for ATR. This work establishes a comprehensive framework to evaluate conventional reforming with CCS and by-product valorization toward competitive, low-carbon methanol production in fossil-reliant regions.

Direct air capture (DAC) integrated with solid oxide electrolysis (SOEC) and Fischer–Tropsch (FT) synthesis is a promising way to produce carbon-neutral liquid fuels. However, the high demand for renewable electricity, particularly from electrolytic hydrogen production, and limited cross-process integration pose key challenges to this mode of production. This study addressed these constraints by modeling a fully integrated DAC–SOEC–FT diesel system using a commercial, equation-oriented simulation platform under steady-state conditions and assuming that renewable power supplied the SOEC unit. The process design incorporated thermal and process-level integration with waste heat from the calciner, FT reactor, and SOEC burner repurposed for internal heating and feed conditioning. System-derived byproducts (e.g., naphtha, purge gases) were used as internal fuels to minimize external energy inputs and avoid additional emissions. Results showed that under ideal thermal integration scenarios, the theoretical internal recovery of up to 78% of total process heat could substantially reduce reliance on external utilities. While SOEC remained the primary electricity consumer (29.8 MWh/t-diesel), internal energy recovery mitigated auxiliary demands. Cradle-to-gate CO2 emissions were net-negative and reached –1.20 kg-CO2/kg-diesel in Japan and –1.56 kg-CO2/kg-diesel in Canada. These results emphasized the strong synergies unlocked by integrated system design and offered a pathway toward energy-efficient, carbon-negative synthetic diesel suited for hard-to-abate transport sectors.

Deep decarbonization requires pathways that remove CO2 and convert it into products, yet published DAC-electrolysis-methanol studies often assume simplified CO2/H2 inputs and rarely compare dispatchable energy supplies under consistent techno-economic and cradle-to-gate greenhouse-gas boundaries. Here, a bottom-up analysis integrates direct air capture (DAC), alkaline water electrolysis (AWE), and CO2 hydrogenation to methanol, and evaluates three energy-supply configurations: grid or renewable electricity with natural gas process heat (scenario 1); integration of an Allam cycle supplied with electrolytic oxygen from AWE to provide on-site power and additional CO2 (scenario 2); and on-site electricity and heat from high-temperature gas-cooled reactors (scenario 3). Carbon pricing and uncertainty analysis are performed. Each case includes a 1 Mt-CO2/y potassium hydroxide (KOH)-calcium (Ca) looping DAC unit, and methanol capacity varies with available CO2 sources. In scenario 1, CO2 is supplied by DAC and natural gas combustion associated with process heat and electricity generation, yielding 2610 t-MeOH/d. In scenario 2, CO2 is supplied by DAC and the Allam cycle, yielding 4471 t-MeOH/d. In scenario 3, fossil fuels are eliminated and CO2 is supplied only by DAC, yielding 2207 t-MeOH/d. Energy consumption is 40.5, 42.2, and 98.5 GJ/t-MeOH for scenarios 1, 2, and 3, respectively. Scenario 3 achieves the lowest cradle-to-gate GHG intensity (-1.52 t-CO2/t-MeOH), while fossil-dominant grids yield 4.13 and 3.69 t-CO2/t-MeOH in scenarios 1 and 2. Methanol cost ranges from $590 to $1413/t, $655 to $1326/t, and $921/t for scenarios 1, 2, and 3, respectively, with break-even carbon prices of $36.47–$150.31/t-CO2 (scenario 1), $53.80–$168.55/t-CO2 (scenario 2), and $88.05/t-CO2 (scenario 3).

Hydrogen produced from renewable sources is crucial for decarbonizing hard-to-abate sectors and achieving net-zero targets. This study examines hydrogen production through the novel thermo-catalytic reforming (TCR) process using agricultural and forestry residues. The research aims to develop and optimize regression models that integrate feedstock properties (ash, hydrogen-to-carbon molar ratio, and lignin) and process parameters (reactor and reformer temperatures) to predict yields of hydrogen (H2), syngas, methane (CH4) and carbon dioxide (CO2). Three biomass feedstocks-softwood pellets (SWPs), hardwood pellets (HWPs), and wheat straw pellets (WSPs)-were analyzed at reactor temperatures of 400-550 degrees C and reformer temperatures of 500-700 degrees C. Predictive models for H2 (R2 = 0.9642, RMSE = 1.0639) and syngas (R2 = 0.9894, RMSE = 0.0140) yields show strong agreement and accuracy between the predicted and experimental values. In contrast, the models for CH4 and CO2 yields show higher variability in the predictions. Reformer temperature was the most significant parameter influencing the yields of H2 and syngas. The optimal H2 yields predicted for the model were obtained for HWPs at 550/700 degrees C (26.67 g H2/kg dry biomass), followed by SWPs at 550/700 degrees C (24.11 g H2/kg dry biomass) and WSPs at 550/685.2 degrees C (18.78 g H2/kg dry biomass). The volumetric syngas yields were highest for HWPs at 550/700 degrees C (0.831 Nm3/kg dry biomass), followed by SWPs (0.777 Nm3/kg dry biomass) and WSPs (0.634 Nm3/kg dry biomass). This study demonstrates that regression modelling accurately predicts H2 and syngas yields, which would help to expand the applicability of TCR technology for large-scale hydrogen production, contributing to the decarbonization of the energy sector.

Kraft pulp and paper mills, significant sources of biogenic CO2 emissions, offer a promising opportunity for carbon capture and valorization. This study develops a framework for assessment of the combined implementation of carbon capture and methanol production through CO2 hydrogenation, using biogenic emissions from kraft pulp mills, assessing both technical and economic viability. Canada has the opportunity to capture approximately 22.2 million tonnes of biogenic CO2 annually from these mills, with capture costs ranging from $62 to $104 per tonne. Sensitivity analysis reveals the process's sensitivity to capital costs, internal rate of return (IRR), and utility costs, while Monte Carlo simulations indicate cost uncertainties of $76.54 +/- 5.60 per tonne. Furthermore, the study extends to methanol synthesis using the captured CO2 and a SMR-CCS-based hydrogen, examining two production pathways: decentralized construction of methanol plants near individual mills and centralized plants with CO2 transported via pipelines. The captured CO2 could be converted into approximately 15.6 million tonnes of methanol annually. Production costs range from $642 to $751 per tonne in the decentralized pathway and $650 to $700 per tonne in the centralized, both competitive with the market price of $722 per tonne. Hydrogen costs drive over 69% of production expenses, with Monte Carlo simulations showing production cost uncertainties of $678.50 +/- 59.86 per tonne. These findings demonstrate the economic feasibility of carbon capture and methanol production from kraft pulp mills and present a transferable framework that can be applied to other regions by substituting Canadian-specific inputs with locally relevant data for biogenic CO2 utilization.

The increasing prevalence of pharmaceutical pollutants, especially antibiotics like ampicillin, in aquatic environments necessitates novel treatment approaches that integrate pollutant removal with resource recovery. Traditional PFAS-based membranes, such as Nafion, frequently used in microbial fuel cells (MFCs), present environmental concerns due to their persistence and toxicity. This study introduces a graphene oxide (GO)-modified cellulose ether membrane, characterized by antifouling properties, as a PFAS-free alternative, and thoroughly evaluates its dual function of ampicillin elimination and bioelectricity generation from hospital wastewater. Physicochemical characterization revealed that the incorporation of GO improved membrane hydrophilicity and mechanical stability, leading to a 2.53-fold increase in tensile strength compared to pure cellulose ether, while concurrently reducing substrate crossing. In a MFC, the CEGO membrane facilitated increased microbial electroactivity and improved electron transfer, achieving a maximum current density of 86.6 mA c m-2. This enhanced electrochemical performance, coupled with a columbic efficiency of 59.3%, was succeeded by a substantial ampicillin degradation of 96.2%, thereby underscoring the relationship between optimized proton transport and strengthened microbe-electrode interactions. Furthermore, the membrane exhibited operational stability under high-COD conditions typical of hospital wastewater, indicating considerable structural resilience and potential for extended application in sustainable wastewater treatment and energy recovery.

The oil sands sector is a significant emitter of greenhouse gases, accounting for 11.3 % of Canada's greenhouse gas emissions. In the next 30 years, bitumen production is expected to increase by 1.2 million cubic meters per year, representing a 42 % increase from the 2020 production level; therefore, advancing low-carbon oil sands extraction technologies is critical. While many strategies to mitigate greenhouse gas emissions from the oil sands sector have been proposed, there are few assessments of associated water-use impacts. To fill this knowledge gap, this research builds on a novel data-intensive and technology-specific model of the in situ bitumen extraction sector in Canada developed to determine the long-term water and greenhouse gas footprints of the penetration of emerging low-carbon oil sands recovery technologies. The market penetration of seven novel low-carbon and three conventional in situ bitumen extraction techniques through four different technology mix scenarios between 2020 and 2050 were considered. The results show maximum water savings and GHG abatement potential in 2050 of 7 % and 17 %, respectively, at a $59/cubic meter water savings cost and a $32/tonne carbon dioxide equivalent greenhouse gas abatement cost in a high carbon tax scenario. Total water consumption and greenhouse gas emissions are projected to reach 43.8 million cubic meters and 49.9 million tonnes in 2050 under the scenario that best reduces water use and emissions. Although freshwater use from in situ recovery is 0.05 % of the Athabasca River flow, projected annual emissions from the oil sands industry are significant, thus further efforts are needed to meet Canada's net-zero emissions target by 2050.